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215-174
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-08 KUPARUK RIV UNIT 2S-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2S-08 50-103-20722-00-00 215-174-0 G SPT 6103 2151740 1526 3575 3580 3582 3582 183 315 293 276 4YRTST P Brian Bixby 7/2/2022 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2S-08 Inspection Date: Tubing OA Packer Depth 230 2030 1980 1970IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704083441 BBL Pumped:1.9 BBL Returned:1.9 Friday, July 22, 2022 Page 1 of 1 • ConocoPhillips RECEIVED Alaska SEP 2 6 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC 4OG`��r C September 24, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 %ANNE° Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sin rely, 71" Roger Winter ConocoPhillips Well Integrity Field Supervisor i • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 3.4 9/10/2017 2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 2S-10 501032071700 215-110-0 10' 1.50 9" 6/10/2017 1.7 9/10/2017 2S-11 501032073200 215-219-0 20" 0.10 10" 6/7/2017 3.4 9/10/2017 2S-12 _ 501032074300. 216-074-0 25" 0.10 13" 6/7/2017 4.8 9/10/2017 2S-13A 501032072001 216-104-0 30" 0.40 9" 6/7/2017 3.4 9/10/2017 2S-14 501032073300 215-220-0 27" _ 0.24 12" 6/7/2017 3.9 9/10/2017 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 09,2016 TO: Jim Regg P.I.Supervisorefci II(1€111,o SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA INC 2S-08 FROM: Chuck Scheve KUPARUK RIV UNIT 2S-08 Petroleum Inspector Src: Inspector Reviewed B, P.I.Supry J Se-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2S-08 API Well Number 50-103-20722-00-00 Inspector Name: Chuck Scheve Permit Number: 215-174-0 Inspection Date: 11/4/2016 Insp Num: mitCS161105073500 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 25-08 Type Inj W 'TVD 6103 ' Tubing' 2289 2289 - 2275 - 2289 - PTD 2151740 - Type Testi SPT Test psi 1526 - IA 300 3080 ' 3000 , 2980 - Interval INITAL P/F P v OA 247 412 . 385 - 364 - Notes: Well converted from producer to injector Sundry#316-344. SCANNED APR 2 4 2017 Wednesday,November 09,2016 Page 1 of 1 STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing ( Operations shutdown E Performed: Suspend E Perforate Alter Casing r Other r r Change Approved Program E Plug for Redrill E Perforate New Pool r Repair Well r Re-enter Susp Well E Other:PROD to WAG F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen F Exploratory r 215-174-0 3.Address: 6.API Number: Stratigraphi r Service E P. O. Box 100360, Anchorage,Alaska 99510 50-103-20722-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25603, 25608 KRU 2S-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 14345 feet Plugs(measured) None true vertical 6296 feet Junk(measured) None Effective Depth measured 14345 feet Packer(measured) 6856, 6933, 6984 true vertical 6296 feet (true vertical) 6038, 6079, 6103 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 108' 108' SURFACE 2624' 10 3/4 2652' 2548' INTERMEDIATE 7115' 7 5/8 7141' 6169' SLOTTED LINER 7319' 4 1/2 14275' 6305' (,)r.i"? �'t? t r'� R. Perforation depth: Measured depth: 7470-8562, 8683-10072, 10197-14158 True Vertical Depth: 6276-6305,6305-6280,6279-6293 NOV 0 8 2016 AOL2Ce Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80,6984 MD,6103 TVD Packers&SSSV(type,MD,and TVD) SSSV=None SLIDING SLEEVE=BAKER CMU SLIDING SLEEVE @ 6856 MD and 6038 TVD PLUG=MIRAGE PLUG RIG SHEARED, DISSOLVED @ 6933 MD and 6079 TVD LOCATOR=BAKER LOCATOR @ 6984 MD and 6103 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 464 1378 82 904 257 __- Subsequent to operation 0 0 1589 748 1868 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development E Service F Stratigraphic r Copies of Logs and Surveys r 16.Well Status after work: Oil r Gas r WDSPL E Printed and Electronic Fracture Stimulation r GSTOR r WINJ r WAG F GINJ r SUSP r SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-344 Contact Darrell Humphrey Email: n1139@G.conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature � t Phone:659-7535 Date ` ( ` (2 • 1, / Norm 10-404 Revised 7 , VTI, 3/2 s If? RBDMS GV NOV 1 0 2016 Submit Original Only .. • 2S-08 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/04/16 (ISW) : INITIAL STATE WITNESSED (CHUCK SCHEVE) MIT-IA(PASSED) TO 3080 PSI. 10/25/16 Well converted to produced water injection. Well brought online. III - KUP PROD 2S-08 ✓ \ ConocoPhillips if I Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/DWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r_mat, 501032072200 KUPARUK RIVER UNIT PROD 93.63 8,022.21 14,345.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 1Rig Release Date 2S-08,7/13/20164:03:24 PM SSSV:NONE 50 12/24/2015 Last WO: 27.051 11/28/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ., Last Tag: Rev Reason:GLV C/O,H2S pproven 7/13/2016 ,..7i, .....................Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1 7 Conductor 16 15.250 27.5 107.5 107.5 62.50 H-40 P Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Surface 10 3/4 9.950 28.6 2,652.4 2,547.5 45.50 L-80 HYD 563 HANGE ;25.3 a: 9 ( ) ( ) P(ftKB) (ftKB) (TVD)...Wt/Len(I...Grade Top Thread HANGER;25.3 casing Description OD In ID in To ftKB Set Depth ftKB Set Depth In V Intermediate 75/8 6.875 25.8 7,141.0 6,169.0 27.90 L80 H563 ....................._..........._....._............__.... ...... "'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread II Slotted Liner 4 1/2 3.958 6,955.9 14,275.0 6,294.6 11.60 L-80 IBTM XO Reducing 69 4 I Liner Details Nominal lD Top(ftKB) Top(TVD)(ftKB) Top Icl(") Item Des Com (in) 6,855.8 6,090.0 60.71 PACKER HRD-E ZXP Liner top packer 51/2"x75/8"L-80 5 5.740 1/2"Hydril 563 pin xo Redanirg sea 6,975.6 6,099.5 61.60 Setting Sleeve RS packeff Seal Nipple 5 12"L-80 5 1/2"Hydril 563 4.940 box X box 6,978.5 6,100.9 61.73 HANGER DG Flex-Lock Liner hanger 51/2"x75/8"L-80-5 4.830 1/2"Hydril 563 pin X pin -AMA•Corauctor;27.s-107.6• 6,988.3 6,105.5 62.17 LOCATOR NO GO XO-5 1/2"Hydril 563 box 5"Hydril 521 4.370 box U ,] 6,999.6 6,110.7 62.68 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 4 1/2"Hydril 521 box 7,457.8 6,272.0 74.15 Swell Packer 4%"IBTM Swell Packer Baker 6.37"OD ser# 3.960 Surface;28.e-2,652.4-A Ilk 04916900123) Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 25.3 7,013.3 6,117.0 9.30 L-80 EUE-M GAS LIFT;3,741.3 aliCompletion Details Nominal ID lop(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 25.3 25.3 0.00 HANGER 4-1/2"Tubing Hanger with 3.11'pup 3.958 69.4 69.4 0.20'XO Reducing XO,2',4-1/2"12.68 L-80 IBTM box x 3-1/2"9.3#L-80 3.000 EUE-Mod pin 6,856.3 6,038.1 56.87 SLIDING Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 GAS LIFT;6,732.5 SLEEVE 2.813"profile 1i 6,912.0 6,067.9 58.74 NIPPLE Cam.2.75 D nipple-Ser#T091440 2.750 6,933.2 6,078.8 59.69 PLUG Mirage Plug RIG SHEARED,DISSOLVED 2.962 a 6,983.6 6,103.3 61.96 LOCATOR Baker Locator 2.990 SLIDING SLEEVE;6,856.3 II 6,984.1 6,103.5 61.98 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 Seal,36 ft for Seal travels) Perforations&Slots II Shot Dens 2 11 Top(TVD) Btm(TVD) (shots/f I Top(ftKB) Bim(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,474.0 8,562.0 6,276.4 6,305.0 11/24/2015 SLOTS Alternating solid/slotted PLUG;6,933.2 Ili pipe-.125"x 2.5"@ 4 I circumferential adjacent rows I8,683.0 10,072.0 6,305.4 6,280.4 11/242015 SLOTS Alternating solid/slotted pipe-.125"x2.5"@4 11 a II circumferential adjacent rows 10,197.0 14,158.0 6,279.3 6,293.4 11/24/2015 SLOTS Alternating solid/slotted I pipe-.125"x2.5" @ 4 circumferential adjacent rows LOCATOR;6,983.8 II li � Mandrel Inserts at i IN' ° Top(TVD) Valve Latch Port Size TRO Run SEAL ASSY;8,98x.1 i N` Top(ftKB) (ftKB) Make Model OD(in) Seen Type Type (in) (psi) Run Date Com I 1 3,741.3 3,501.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/26/2015 ! I 2 6,732.5 5,967.7 Comm MMG 1 1/2'GAS LIFT DMY RK 0.000 0.0 7/3/2016 I Notes:General&Safety End Date Annotation NOTE: iii Intermediate;25.8-7,141.0 SLOTS;7,474.0-8,562.0 1 SLOTS;8,683.0-10,072.0 SLOTS;10,197.0-14,158.0 Sbded Liner;8,955.9-14,275.0 !I I > • • Brooks, Phoebe L (DOA) $ 215 17 q D From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, November 07, 2016 3:39 PM To: Brooks, Phoebe L(DOA) Subject: RE: KRU MITs Attachments: 2S-08 schematic.pdf; 2S-07 schematic.pdf; 2S-04 schematic.pdf Here you go. Thanks Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, November 07, 2016 2:24 PM To: NSK Problem Well Supv<n1617@conocophillips.com> Subject: [EXTERNALJRE: KRU MITs Kelly/Brent, Will you send me the well schematics for 2S-04, 2S-07, & 2S-08? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent:Saturday, November 05, 2016 8:45 AM To: Regg,James B (DOA)<jim.regg@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: KRU MITs Attached are the MIT forms from the tests completed yesterday at 2S pad. 1 KUP PROD 0 2S-08 ConocoPh - 'illips " IfIteIl Attributes ', Mix AngieAMCf TD AlaskaliV.: Wehbore , API/UWI Flettl Name Wellbore Status Inel(°) MD(ftKB) Act Btm(ftKB) � ,y®lam 501032072200 KUPARUK RIVER UNIT PROD 93.63 8,022.21 14,345.0 "SL Comment 112S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2S-oa.7/13120164:03:24 PM_.. SSSV:NONE 50 12/24/2015 Lest WO: 27.05 11/28/2015 Vemcal echam000(eckw0 `Annotation Depth(ftKB) End Date Annotation Last Med By Entl Dale Last Tag: Rev Reason:GLV C/O,H2S pproven 7/13/2016 Casing Strings ", 9 e Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1 Grade Top Thread Conductor 16 15.250 27.5 107.5 107.5 62.50 H-40 I A. 3 Casing Description 00(in) ID(in) Top(ftKB)8 Set Depth(ftKB)2 Set Depth(NO)...WULen(I...Grade Top Thread •""":4unmauuvmuw „ ,R,, "i":""ue Surface sing (in) 9.950 B) (ftKB)4 2,47.5 45-50 Gra0 Toy h83 HANGER 25.3 � Casing g De crfpt on OD ID( ) Tap(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ♦ utu, I I Intermediate 7 5/8 6 875 25.8 7 141.0 6,169 0 27 90 L80 H563 'I : "" ""Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO) Wt/Len(t Grade Top Thread e 1 Slotted Liner 4 1/2 3.958 6,955.9 14,275.0 6,294.6 11.60 L-80 IBTM Liner Details .: Nominal ID Top(ftKB) Top(TVD)(ftKB) Top loci(°) Item Des Com (in) 6,955.9 6,090.0 60.71 PACKER HRD-E ZXP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.740 1/2"Hydril 563 pin xo Reduciig;694 6,975.6 6,099.5 61.60 Setting Sleeve RS packoff Seal Nipple 51/2"L-80 51/2"Hydril 563 4.940 box X box 6,978.5 6,100.9 61.73 HANGER DG Flex-Lock Liner hanger 51/2"x75/8"L-80-5 4.830 1/2"Hydril 563 pin X pin ...A.A."-A-Conductor,27.5.10.5 1.A., 6,988.3 6,105.5 62.17 LOCATOR NO GO XO-5 1/2"Hydril 563 box X 5"Hydril 521 4.370 box I • J 6,999.6 6,110.7 62.68 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 4 1/2"Hydril 521 box 7,457.8 6,272.0 74.15 Swell Packer 4'/,"IBTM Swell Packer Baker 6.37"OD ser# 3.960 Surface;266-2.652.4 04916900123) Tubing Strings ,fir' ; Tubing Description Sting Ma...ID pn) Top(ftKB) Set Depth(ft..,Set Depth(ND)(...Wt(lbHQ Grade Top Connection TUBING 3 1/2 2.992 25.3 7,013.31 6,117.0 9 30 L 80 EUE-M II GAs LIFT;3.741,3 Completion Dell i A Nominal ID Top(ftKB) Top)ND)(ftKB) Top Incl(°) Item Dee Com (in) 25.3 25.3 0.00 HANGER 4-1/2"Tubing Hanger with 3.11'pup 3.958 69.4 69.4 0.20 XO Reducing XO,2',4-1/2"12.66 L-80 IBTM box x 3-1/2"9.3#L-80 3.000 EUE-Mod pin 6,856.3 6,038.1 56.87 SLIDING Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 GAS LIFT;6.]72.5 SLEEVE 2.813"profile 6,912.0 6,067.9' 58.74 NIPPLE Camco 2.75 D nipple-Ser#T091440 2.750 6,933.2 6,078.8 59.69 PLUG Mirage Plug RIG SHEARED,DISSOLVED 2.962 1 6,983.6 6,103.3 61.96 LOCATOR Baker Locator 2.990 SLIDING SLEEVE;6.65fi.3 i■ 6,984.1 6,103.5 61.98 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 Seal,36 ft for Seal travels) -I Perforations&Slots Shot Dens Top(ND) Btm(TVD) ' (shols1 I. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date . t) Type Com 7,474.0 8,562.0 6,276.4 6,305.0 11/24/2015 SLOTS Alternating solid/slotted PLUG;6,033.2 t pipe-.125"x2.5"@4 circumferential adjacent rows 8,683.0' 10,072.0 6,305.4 6,280.4 11/24/2015 SLOTS Alternating solid/slotted pipe-.125"x2.5"@4 circumferential adjacent I I rows 1:. 10,197.0Insefts 14,158.0 6,279.3 6,293.4 11/24/2015 SLOTS Alternating solid/slotted s( pipe-.125"x 2.5" ` @ 4 circumferential 11.1 '� adjacent rows LOCATOR;6,963.6 ,j Ia. E Mandrelsl au ate. Top(ND) Valve Lateh Port Sim TRO Run SEAL ASSY;6,984.1 - N Top(ftKB) (ftKB) Make Model OD(in) Sery Type _ Type (in) (psi) Ran Date Com i "( '� 3,741.3 3,501.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/26/2015 ) I 2' 6,732.5 5,967.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/3/2016 1 I Notes:General$t Safety,. , k.,' iL' End Date Annotation Ell NOTE: 11 11. 1111 Intermediate;25.8-7,141 0 . SLOTS;7,4]4.0-e,502.0 + SLOTS,8,683.0-10,072.0-- ° SLOTS;10,197,0-14,158.0 Slotted Liner,6,956 9.14,275.0 OF Tit • • e,\ • THE STATE Alaska Oil and Gas F -ice o f® ®® c 11 Conservation Commission 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER Main: 907.279.1433 ALA "S$P Fax: 907.276.7542 www.aogcc.alaska.gov Darrell Humphrey NSK Production Engineering Specialist SC LINED DEC 0 92016 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-08 Permit to Drill Number: 215-174 Sundry Number: 316-344 Dear Mr. Humphrey: Enclosed is the approved application for 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, Cathy . Foerster Chair DATED this ZSday of June, 2016. RBDMS k,✓!2".-! 7 8 2016 40 III OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 3 2016 APPLICATION FOR SUNDRY APPROVALS �-,s (L 20 AAC 25.280 AOGCG 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other:PROD to WAG P.- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory r Development 215-174-0 ' 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage, Alaska 99510 50-103-20722-00 ' 7. If perforating, 'PSD 8.Well Name and Number: /►� What Regulation or Conservation Order governs well spacing in this pool? I v i- Will planned perforations require spacing exception? Yes r No ,7 KRU 2S-08 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25603,25608 . Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14345' 6296 W 14345' ` 6296'. 3800 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 108' 108' SURFACE 2624' 10 3/4 2652' 2548' INTERMEDIATE 7115' 7 5/8 7141' 6169' SLOTTED LINER 7319' 4 1/2 14275' 6305' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7470-8562,8683-10072, 10197-14158 . 6276-6305,6305-6280,6279-6293 3 1/2 L-80 6984 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=None MD=N/A TVD=N/A Packer-HRD-E ZXP MD=6956 TVD=6090 12.Attachments: Proposal Summary WellBore Schematic 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development E Service 17• 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 07/11/16 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG Fi . GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17. I hereby certify that the foregoing is true Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Phone:659-7535 Email: n1139aconocophillips.com Title: NSK Production Engineering Specialist Signature =ZM Date: C.c, , ZZ • 1 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Post Initial Injection MIT Req'd? Yes itV No r Spacing Exception Required? Yes r No Subsequent Form Required: f 0 ' 11 2 Li— APPROVED BY Approved by: 9Iiik-141/4.-- COMMISSIONERTHE COMMISSION Date: G ..zg- V/` �/� �rp n // Gis Submit Form and Form 10-403 Revised 11/2015 Ir464,4_ p �ralid for 12 months from the date of approval. Attachments in Duplicate O RBDI�g (,V JUN 2 8 2016 • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhil I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 June 20,2016 AOGCC Commissioner RECEIVED State of Alaska, Oil & Gas Conservation Commission JUN 2 3 2016 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 AOGCC Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 2S-08 from Oil Production to Water Alternating Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2S-08 (PTD# 215-1740). If you have any questions regarding this matter,please contact myself or Bob Christensen at 659-7535. Sincerely, Darrell Humphrey Attachments Sundry application Area Map AOR AOR detail Well schematic • • 2S-08 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2S-08 (PTD# 215-174) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk well 2S-08 was completed as an injector on 11/28/15 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support new producer 2S-12 (currently being drilled). / The top of the A sand was found at 7053' and /6,134' tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset producers (2S-12), there are no additional production/injection wells located within a 1/4 mile radius of the 2S-08 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2S-08 is good and is classified as a "dual Casing"well. The injection tubing/casing annulus is isolated via a Baker HRD-E ZXP packer located at 6,955.9' and (6,090.0' tvd). A State-witnessed MIT-IA will be performed once well 2S-08 is converted to water injection, online, and stabilized A State-witnessed MIT-IA will be performed once well 2S-08 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (4105' -7120' and/3822' -6160' tvd) to insure injection zone conformance. The CBL was submitted with the PTD. The 16" Conductor was pre-driven The 10-3/4" Surface casing was cemented with 1131sx DeepCrete followed by 205sx bbls DeepCrete. The 7-5/8" Intermediate casing was cemented with 875sx 15.3 PPG GasBLOK. W c// ( v41 1'f-re ID 6e 9„ ,,hr�n`D` JIIo reyeves feo ecern� %3-W1 • 13Jun16 • ConocoPhillips Alaska, Inc. ADL025590 2S-08 N ADL390680 10-403 SundryA Southern , 0 0.1 02 03 0.4 Miluveach 1 _=_===Miles Kuparuk River Unit 1 Unit 2S a ADL025604 ADL380051 AD 025603 2S-12 2S-08 - 2S-08 Interval ADL025608 —2S-08 Trajectory ADL025607 1/4 Mi. 2S-08 Open Interval Radius Well Currently Being Drilled *Well Pad -- Kuparuk PA r i: Unit Boundary P BRPC Lease 111 CPAI Lease • • fa a.a = ra 2 e- 0 0 E E o m �`o — � o �+ o d N c Z � W 6 N O N tm GJ E C ,E — O ra 0 u o Q c v u C o f— a O '^^, c m ta °a o0 o a O c s N Q G `o i m u Z 4 P. KUP PROD • 2S-08 r ConocoPhillips1.2' Well Attributes Max Angle&MD TD Alaska IncWellbore API/UWI Field Name Wellbore Status net(7 MD(ftKB) Act Btm(ftKB) rxn000rvnrc 501032072200 KUPARUK RIVER UNIT PROD 93.63 8,022.21 14,345.0 \ ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 28-08.3/6/201612:51.17 PM SSSV:NONE Last WO: 27.05 11/28/2015 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:NEW WELL lehallf 12/21/2015 il Casing Strings Casing Description OD lint ID(in) Top(ftKB) Set Depth(ftKB) Sot Depth(TVD)... Wt/Len(I...Grade Top Thread Conductor 16 15250 27.5 107.5 107.5 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Surface 10 3/4 9.950 28.6 2,652.4 2,547.5 45.50 L-80 HYD 563 ����� �����°CHANGER;25.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Intermediate 75/8 6.875 25.8 7,141.0 6,169.0 27.90 L80 H563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread it I t rr Slotted Liner 41/2 3.958 6,955.9 14,275.0 6,294.6 11.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 6,955.9 6,090.0 60.71 PACKER -HRD-E ZXP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.740 1/2"Hydril 563 pin XO Reducing;69 4el 6,975.6 6,099.5 61.60 Setting Sleeve RS packoff Seal Nipple 5 1/2"L-80 5 1/2"Hydril 563 4.940 box X box 6,978.5 6,100.9 61.73 HANGER DG Flex-Lock Liner hanger 5 1/2"x 7 5/8"L-80-5 4.830 1/2"Hydril 563 pin X pin ,AAAA.Conductor;27.5-1075 6,988.3 6,105.5 62.17 LOCATOR NO GO XO-51/2"Hydril 563 box X5"Hydril 521 4.370 box I € 1 6,999.6 6,110.7 62.68 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 4 1/2"Hydril 521 box • 7,457.8 6,272.0 74.15 Swell Packer 4%"IBTM Swell Packer Baker 6.37"OD ser# 3.960 Surface;28.6-2,652.4 04916900123) • I Tubing Strings Tubing Description String Ma...ID(in) Top(5561 Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection GAS LIFT;3,741.3 TUBING 31/21 2.9921 25.31 7,013.31 6117.01 9.301 L-80 I EUE-M Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 25.3 25.3 0.00 HANGER 4-1/2"Tubing Hanger with 3.11'pup 3.958 GAS LIFT;6,732.5 69.4 69.4 0.20 XO Reducing XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 3.000 EUE-Mod pin I 6,856.3 6,038.1 56.87 SLIDING Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 I SLEEVE 2.813"profile I 6,912.0 6,067.9 58.74 NIPPLE Camco 2.75 D nipple-Ser#TO91440 2.750 SLIDING SLEEVE;6,856.3 I■i 6,933.2 6,078.8 59.69 PLUG Mirage Plug RIG SHEARED,DISSOLVED 2.962 A 6,983.6 6,103.3 61.96 LOCATOR Baker Locator 2.990 6,984.1 6,103.5 61.98 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 Seal,36 ft for Seal travels) I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc! GAUGES;6,912.0 � Top(5581 (ftKB) (°) Des Corn Run Date ID(in) Am 6,912.0 6,067.9 58.74 GAUGES 2.78"BOMB HANGER,SS,GAUGES(OAL 87") 3/2/2016 PLUG;6.933.2 : Perforations&Slots I Shot Den Top(ND) Btm(ND) (shots/f Top(566) Btm(660) (ftKB) (ftKB) Zone Date t) Type Com 7,474.0 8,562.0 6,276.4 6,305.0 11/242015 SLOTS Alternating solid/slotted II III pipe-.125"x2.5"a4 circumferential adjacent II rows l j) 8,683.0 10,072.0 6,305.4 6,280.4 11/242015 SLOTS Alternating solid/slotted I pipe- 125'x2.5"t 4 I circumferential adjacent LOCATOR;6,983.6 rows 1 It I1 10,197.0 14,158.0 6,279.3 6,293.4 11/24/2015 SLOTS Alternating solid/slotted pipe-.125"x2.5" St @ 4 circumferential -: adjacent rows SEAL ASSY;6,984.1 •M Mandrel Inserts 1I St I a I ati Top(TVD) Valve Latch Port Size TRO Run I N Top(MB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com M. 1 3,741.3 3,501.2-Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/26/2015 2 6,732.5 5,967.7 Camco MMG 1 1/2 GAS LIFT 'SO-Dy RKP 0.438 0.0 1126/2015 Notes:General&Safety End Date Annotation Intermediate;25.6-7,141.0 NOTE: SIZO SLOTS;7,474.0-8,562.0 SLOTS;8,683.0-10,072.0 SLOTS;10,197.0-14,158.0 i__.,... 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All i J_ O 1 1 Z co 3 N ea 16 CeQ 0 0 LL Q c aJ_ W = L a O z J 0 o CC rd Z o E ,n VU o J w, Q 9 , H a y N lf) — z N 0 2 G Z N n co W ' h COCn 01 a. Q ' c Y m Q z E E is z a) rn N 1, Cr CO >-9 I- I, d Ya N N N N ce M H1 V c R U d -C7 E E a0. O o E E ¢ • 215176 26 80 3 WELL LOG TRANSMITTAL#903053122 To: Alaska Oil and Gas Conservation Comm. February 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 DATA LOGGED FEB 1 0 2016 1../2.1/201c. (� M.K.BENDER AOGCC RE: Multi Finger Caliper(MFC)/Static Bottom Hole Pressure Survey/Jewelry Log: 2S-08 Run Date: 1/13/2016 and 1/14/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2S-08 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20722-00 Multi Finger Caliper/Static Bottom Hole Pressure Survey/Jewelry Log 1 Color Log-each 50-103-20722-00 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: P')A412-a-P1-4) 6-€4"€et lEJISED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: OilEI Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development (] Exploratory ❑ GINJ ❑ WINJ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 11/28/2015 2 215-174/ , 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 11/6/2015 50-103-20722-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3056'FNL, 1467'FEL, Sec. 17,T1ON, RO8E, UM 11/22/2015I KRU 2S-08 ' Top of Productive Interval: 9. Ref Elevations: KB: 1-13, w 17. Field/Pool(s): 4359'FNL,4022' FEL,Sec. 17,T1ON, RO8E, UM GL: 120 BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 522'FNL, 308'FEL, Sec. 30,T1ON, RO8E, UM n/a ADL 25603,25608 ' 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 481103 y- 5929992 Zone-4 14,345/6,296 2677,2681 TPI: x- 478549 y- 5928696 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 476987 y- 5921978 Zone-4 none 1430/1412 5. Directional or Inclination Survey: Yes ❑ (attached) No 2 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Sonic Scope RECEIVED JAN 0 4 2016 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 28 106 28 106 24 Pre-driven 10.75 45.5 L-80 28 2737 28 2614 13.5 1131 sx DeepCRETE,205sx DeepCRETE 7.625 29.7 L-80 28 7262 28 6191 9.875x11 875 SX15.3PPG GasBLOK 4.5 12.6 L-80 7112 16226 6132 6429 6.75 Slotted Liner 24. Open to production or injection? Yes El No ❑ 25.TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 7013 6956/6090 SLOTTED LINER FROM 7470-8562=MD,6276-6305=TVD SLOTTED LINER FROM 8683-10072=MD,6305-6280=TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. SLOTED LINER FROM 10197-14158=MD,6279-6293=TVD,MPLETION Was hydraulic fracturing used during completion? Yes❑ No ❑ DATE Per 20 AAC 25.283(1)(2)attach electronic and printed information It i2a/v5" DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIF!ED I..-'- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 12/18/2015 Gas Lift Date of Test: Hours Tested: 0„ Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 12/20/2015 44 &f996r ZAQ Test Period -890.5 161.4 496.2 52/64 181 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. Fcan PS 2288 PSI 24-Hour Rate -.► 822 BOPD 149 MSCFD 458 BWPD 20.4 q Form 10-407 Revised 11/2015 V 17- 4/Z 7/l(e COn�TINUEq ON GE 2 RBDMS �L I A'd 1 q 2O16Submit ORIGINIAL o>IW ,W 2--76 7114 `i 13.7-1 fr ����1I 28.CORE DATA Conventional Core(s): Yes ❑ No ❑ Sidewall Cores: es ❑ No ❑ 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 ❑I Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1430 1412 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7433 6265 information, including reports,per 20 AAC 25.071. Top of W Sak D 1885 1845 Top of C-80 3048 2886 Top of C-37 5132 4730 Top of HRZ 6738 5973 Top of Upper Kalubik 6961 6093 Top of Lower Kalubik(k-1 mkr) 7160 6176 Top of Kuparuk C4 7430 6265 Top of Kuparuk A5 7493 6282 Top of Kuparuk A4 7549 6295 Top of Lower Kalubik 14293 6292 TD Lower Kalubik 14293 6292 Formation at total depth: Lower Kalubik 31. List of Attachments: Summary of Operations, Definitive Survey,Schematic,Cement Report 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 well test results. per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo(a)265-1487 Email: Haibin.GuoAcop.com 6 Printed Name: G. L.Alvvo/o��rdTitle: Alaska Drilling Manager //�� Signature: t}. . LL.( Phone: 265-6120 Date: 1 1 4(?_es' 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 la: 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 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to: core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only ' KUP INJ a 2S-08T ConocoPhillips a aw Well Attributes Max Angle&MD D t a Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Crno.Ptafilts•. 501032072200 KUPARUK RIVER UNIT INJ 93.63 8,022 21 14,345.0 ..- : Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-08,1208/201510.06'55 AM SSSV:NONE Last WO: 27.05 11/28/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL lehallf 12/21/2015 Casing Strings B'. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Se[Depth(TVD)... WtlLen(I...Grade Top Thread Conductor 16 15.250 27.5 107.5 107.5 62.50 H-40 r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Surface 10 3/4 9.950 28.6 2,652.4 2,547.5 45.50 L-80 HYD 563 •••.••••• ••••••"••••••••••••• 'ucuuW.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER,253i Intermediate 75/8 6.875 25.8 7,141.0 6,169.0 27.90 L80 H563 l FUBD i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sat Depth(ND)...Wt/Len(l...Grade Top Thread .............................................. � Slotted Liner 4 ill 3.958 6,955.9 14,275.0 6,294.6 11.60 L-80 IBTM at Liner Details I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Das Com (in) 6,955.9 6,090.0 60.71 PACKER HRD-E ZXP Liner top packer 5 1/2"X 7 5/8"L-80 5 5.740 1/2"Hydril 563 pin XO Reducing;69.4 if 6,975.6 6,099.5 61.60 Setting Sleeve RS packoff Seal Nipple 5 1/2"L-80 5 1/2"Hydril 563 4.940 box X box 6,978.5 6,100.9 61.73 HANGER DG Flex-Lock Liner hanger 5 1/2"x 7 5/8"L-80-5 4.830 1/2"Hydril 563 pin X pin -MM•coneucror;27.5-107.5• 6,988.3 6,105.5 62.17 LOCATOR NO GO XO-51/2"HydnI 563 box X 5"Hydril 521 4.370 box 6,999.6 6,110.7 62.68 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 41/2"Hydril 521 box 7,457.8 6,272.0 74.15 Swell Packer 4W IBTM Swell Packer Baker 6.37"OD ser# 3.960 Surface;28.6-2,652.4 04916900123) Tubing Strings Tubing Description Stnng Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;3,741.3 TUBING 31/2 2.992 25.3 7,013.3 6,117.0 9.30 L-80 EUE-M Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 25.3 25.3 0.00 HANGER 4-1/2"Tubing Hanger with 3.11'pup 3.958 I 69.4 69.4 0.20 XO Reducing XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 3.000 GAS LIFT;6,732.5 - EUE-Mod pin 6,856.3 6,038.1 56.87 SLIDING Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 SLEEVE 2.813"profile 6,912.0 6,067.9 58.74 NIPPLE Cameo 2.75Dnipple-Ser#T091440 2.750 ■ 6,9332 6,078.8 59.69 PLUG Mirage Plug RIG SHEARED,DISSOLVED 2.962 SLIDING SLEEVE;6,656.3 6,983.6 6,103.3 61.96 LOCATOR Baker Locator 2.990 I 6,984.1 6,103.5 61.98 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 Seal,36 ft for Seal travels) Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotsk fit Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PLUG;8,933.2 7,474 0 8,562.0 6,276.4 6,305.0 11/24/2015 SLOTS Alternating solid/slotted I pipe-.125"x 2.5"@ 4 circumferential adjacent rows 8,683.0 10,072.0 6,305.4 6,280.4 11/24/2015 SLOTS Altemating solid/slotted fl ! pipe-.125"x2.5"@4 circumferential adjacent rows I 10,197.0 14,158.0 6,279.3 6,293.4 11/24/2015 SLOTS Alternating solid/slotted 1� pipe-.125"x2.5" ©4 circumferential LOCATOR;6,963.6 adjacent rows i { Mandrel Inserts St ah on Top(TVD) Valve Latch Port Size TRO Run SEAL ASSY;6,984.1 " N Top(ftKB) (ftKB) Make Model OD(in) Sore Type Type (in) (psi) Run Date Com Iii I 1 3,741.3 3,501.2 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/26/2015 Il IS Ib 2 6,732.5 5,967.7 Camco MMG ' 11/2 GAS LIFT SO-OV RKP 0.438 0.0 11/26/2015 I 1 I E: Notes:General&Safety End Date Annotation p NOTE: Intermediate;25.n-7,141.0 - SLOTS;7,474.0-6,562.0 SLOTS;8,683.0-10,072.0 I - I SLOTS;10,197.0-14,158.0 Slotted Liner;6,955.9-14,275.0 � � Iperations Summary (with TimelogSpths) 0:: "kig5;'f:,:', 2S-08 conocoPhllps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code _ Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/4/2015 11/4/2015 1.00 MIRU MOVE RURD P Con't to blow down steam and water 0.0 0.0 06:00 07:00 systems.Disconnect inter-connects 11/4/2015 11/4/2015 1.00 MIRU MOVE 'MOB P Move pipe sheds&rock washer, 0.0 0.0 07:00 08:00 spotting out of way. 11/4/2015 11/4/2015 1.00 MIRU MOVE 'MOB P Move boiler,motor,pump,&pits 0.0 0.0 08:00 09:00 modules out of way to move sub base. 11/4/2015 11/4/2015 0.75 MIRU MOVE MOB P Move sub base off of 2S-04 0.0 0.0 09:00 09:45 11/4/2015 11/4/2015 2.25 MIRU MOVE `MOB P Clear rig mats and prep location 0.0 0.0 09:45 12:00 around 2S-08 11/4/2015 11/4/2015 1.50 MIRU MOVE MOB P Lay herculite amd rig mats around 2S- 0.0 0.0 12:00 13:30 08 for sub base 11/4/2015 11/4/2015 3.50 MIRU MOVE NUND P Set dirverter adapter head,diverter 0.0 0.0 13:30 17:00 spool,annular preventer,knife valve and diverter vent lines. 11/4/2015 11/4/2015 0.75 MIRU MOVE MOB P Crab sub base iron 2S-04 to 2S-08. 0.0 0.0 17:00 17:45 11/4/2015 11/4/2015 1.50 MIRU MOVE MOB P Spot and level sub base over 2S-08. 0.0 0.0 17:45 19:15 11/4/2015 11/4/2015 2.50 MIRU MOVE MOB P Lay rig mats for support modules. 0.0 0.0 19:15 21:45 11/4/2015 11/5/2015 2.25 MIRU MOVE MOB P Spot and level support modules 0.0 0.0' 21:45 00:00 11/5/2015 11/5/2015 3.00 MIRU MOVE MOB P Spot and level support modules and 0.0 0.0 00:00 03:00 rock washer.Lay mats and spot pipe sheds. 11/5/2015 11/5/2015 3.00 MIRU MOVE RURD P Work on rig acceptance check list. 0.0 0.0 03:00 06:00 Hook up inter connects,berm rock washer,set cuttings tank,set all stairs, assemble mud pumps,install drain plugs in centrifugal pumps and trim herculite. Rig accepted @ 0600 hrs 11/5/15 11/5/2015 11/5/2015 5.00 MIRU MOVE NUND P Torque up flange bolts on diverter 0.0 0.0 06:00 11:00 system. Install riser.Energize and test seals to 500 psi/5 mins.Sim- ops/Change out iron roughneck heads and master bushings.Load BHA into pipe shed. 11/5/2015 11/5/2015 1.00 MIRU MOVE PULD P Pick up and stand back 5"DP. 0.0 0.0 11:00 12:00 11/5/2015 11/5/2015 0.25 MIRU MOVE SFTY P PJSM on picking up DP. 0.0 12:00 12:15 11/5/2015 11/5/2015 2.25 MIRU MOVE PULD P Pick up and stand back 5"DP.(Total 12:15 14:30 of 69 jts DP&18 jts HWDP picked up). 11/5/2015 11/5/2015 0.50 MIRU MOVE 'RURD P Clear rig floor of thread protectors and 0.0 0.0 14:30 15:00 split master bushings.Lay down mousehole 11/5/2015 11/5/2015 1.25 MIRU MOVE SLPC P Slip and cut drilling line.(75') 0.0 0.0 15:00 16:15 Rig on shore power @ 16:00 hrs 11/5/2015 11/5/2015 1.25 MIRU MOVE SFTY P Safety Stand Down/Discussed recent 0.0 0.0 16:15 17:30 incidents involving CPAI contracted rigs. 11/5/2015 11/5/2015 0.50 MIRU MOVE SVRG P Service rig 0.0 0.0 17:30 18:00 Page 1/24 Report Printed: 12/21/2015 •perations Summary (with TimelogSepths) 0 0 2S-08 Con000Philhps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time , Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE() 11/5/2015 11/5/2015 1.00 MIRU MOVE SEQP P Rig up and pump through surface 0.0 0.0 18:00 19:00 lines to ensure they are debri free. 11/5/2015 11/5/2015 1.00 MIRU MOVE BOPE P Perform diverter test,knife valve open 0.0 0.0 19:00 20:00 in 15 sec,annular closed in 27 sec. Accumulator test;system pressure 2950 psi,pressure after closure 1995, 200 psi recharge time 44 sec,full recharge time 158 sec.5 nitrogen bottles averaged 1950 psi.Tested gas &pit level(gain/loss)alarms,good. Witnessed waived by AOGCC Rep Matt Herrera 11/5/2015 11/5/2015 0.50 MIRU MOVE BHAH P Mobilize BHA tools to rig floor. 0.0 0.0 20:00 20:30 11/5/2015 11/5/2015 0.50 MIRU MOVE SFTY P Conduct pre spud meeting 0.0 0.0 20:30 21:00 11/5/2015 11/5/2015 2.00 MIRU MOVE BHAH P Make up BHA#1 as per SLB DD. 0.0 90.0 21:00 23:00 11/5/2015 11/6/2015 1.00 MIRU MOVE SEQP P Fill conductor.Test mud lines to 3500 90.0 90.0 23:00 00:00 psi. 11/6/2015 11/6/2015 3.25 SURFAC DRILL DDRL P PJSM,Spud well,Drilled ahead f/ 90.0 270.0 00:00 03:15 107'MD to 270'MD.TVD=270',ADT= 2.53 hrs,Total bit hrs=2.53 Total Jar hrs=0,Pump @ 525 gpm=550 psi, 85%FO.Rotate @ 40 rpm's w/1K Tq on/.5K off.P/U=50K,S/O=50K, ROT=50K.WOB=5-10K. 11/6/2015 11/6/2015 1.75 SURFAC DRILL BHAH P Stand back 2 stands of 5"HWDP and 270.0 270.0 03:15 05:00 L/D XO.M/U 8"drill collars,stabilizer and Jars to 270'MD.No fill 11/6/2015 11/6/2015 7.00 SURFAC DRILL DDRL P Drilled ahead f/270'MD to 928'MD. 270.0 928.0 05:00 12:00 TVD=923',AST=1.79 hrs,ART=3.14. Total bit hrs=7.64 Total Jar hrs=5.11, Pump @ 560 gpm=1100 psi,81% FO.Rotate @ 50 rpm's w/2-10K Tq on/1-2K off.P/U=80K,S/O=79K, ROT=80K.WOB=20-25K. 11/6/2015 11/6/2015 0.25 SURFAC DRILL TRIP T Swivel packing leaking.POOH to 839' 928.0 839.0 12:00 12:15 MD. 11/6/2015 11/6/2015 0.50 SURFAC DRILL SVRG P Blow down top drive.Change out 839.0 839.0 12:15 12:45 swivel packing. 11/6/2015 11/6/2015 0.25 SURFAC DRILL TRIP P RIH to 928'MD.No fill. 839.0 928.0 12:45 13:00 11/6/2015 11/6/2015 5.00 SURFAC DRILL DDRL P Drilled ahead f/928'MD to 1490'MD. 928.0 1,490.0 13:00 18:00 TVD=1468',AST=.94 hrs,ART=2.88. Total bit hrs=11.46 Total Jar hrs= 8.93,Pump @ 548 gpm=1375 psi, 76%FO.Rotate @ 50 rpm's w/7-11K Tq on/2-4K off.P/U=95K,S/O=90K, ROT=92K.WOB=30-35K. 11/6/2015 11/7/2015 6.00 SURFAC DRILL DDRL P Drilled ahead f/1490'MD to 2235' 1,490.0 2,235.0 18:00 00:00 MD.TVD=2173',AST=1.91 hrs, ART=1.28.Total bit hrs=14.65 Total Jar hrs=12.12,Pump @ 754 gpm= 2100 psi,78%FO.Rotate @ 100 rpm's w/5K Tq on/1-3K off.P/U= 105K,S/O=99K,ROT=100K.WOB= 20-25K. Page 2/24 Report Printed: 12/21/2015 •perations Summary (with TimelogSpths) 0 ,ti 2S-08 ConocoPhi►tips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/7/2015 11/7/2015 4.00 SURFAC DRILL DDRL P Drilled ahead f/2235'MD to 2665' 2,235.0 2,665.0 00:00 04:00 MD.TVD=2559',AST=1.19 hrs, ART=2.83.Total bit hrs=17.48 Total Jar hrs=14.95,Pump @ 754 gpm= 1930 psi,80%FO.Rotate @ 80 rpm's w/7K Tq on/3-4K off. P/U=127K, S/O=100K,ROT=107K.WOB=20- 30K. 11/7/2015 11/7/2015 1.50 SURFAC CASING CIRC P Pump 28 bbl NutPlug M sweep,CBU 2,665.0 2,552.0 04:00 05:30 X 3 pumping @ 785 gpm=2320 psi,80 psi, 100 rpm's,Tq 3-4K.Stand back 1 stand every BU f/2665'MD to 2522' MD. 11/7/2015 11/7/2015 0.25 SURFAC CASING OWFF P OWFF,static. 2,552.0 2,552.0 05:30 05:45 11/7/2015 11/7/2015 0.50 SURFAC CASING TRIP P POOH elevators f/2522'MD to 2400' 2,552.0 2,400.0 05:45 06:15 MD.Pulled 40K over,drop down below tight spot to CBU. 11/7/2015 11/7/2015 0.75 SURFAC CASING CIRC T Circulate hole clean,pump @ 785 2,400.0 2,522.0 06:15 07:00 gpm=2050 psi,89%FO,50 rpm's,Tq 1-2K. 11/7/2015 11/7/2015 0.75 SURFAC CASING TRIP P POOH on elevators f/2522'MD to 2,522.0 2,334.0 07:00 07:45 2334'MD,pulled into tight spot @ 2334'MD.Attempted to work though, unable.Decision made to BROOH. 11/7/2015 11/7/2015 3.00 SURFAC CASING BKRM P BROOH f/2334'MD to 1303'MD. 2,334.0 1,303.0 07:45 10:45 Pump @ 750 gpm, 1900 psi,88%FO, 50 rpm's w/1-2K Tq.Slow BROOH speed to 300 fph the last 2 stands to get BU per stand. 11/7/2015 11/7/2015 1.25 SURFAC CASING TRIP P POOH on elevators f/1303'MD 11565' 1,303.0 565.0 10:45 12:00 MD. Calc disp=7.8 bbls Act disp=6.63 bbls 11/7/2015 11/7/2015 0.75 SURFAC CASING SRVY P Pick up and drop multi shot gyro 565.0 565.0 12:00 12:45 @565'MD.Allow to seat on UBHO as per Gyro Data rep. 11/7/2015 11/7/2015 0.50 SURFAC CASING TRIP P POOH f/565'MD t/193'MD taking 565.0 193.0 12:45 13:15 gyro shot each stand. 11/7/2015 11/7/2015 2.25 SURFAC CASING BHAH P Lay down BHA#1 as per SLB DD to 193.0 30.0 13:15 15:30 mud motor.Retrieved multi shot gyro. No data on gyro tool. Calc disp=25.27 bbls Act disp=25.56 bbls 11/7/2015 11/7/2015 0.75 SURFAC CASING BHAH T Make up UBHO,2 NMDC's,saver sub 30.0 131.0 15:30 16:15 and fars. 11/7/2015 11/7/2015 0.50 SURFAC CASING TRIP T RIH to 495'MD. 131.0 495.0 16:15 16:45 Calc disp=14.85 bbls Act disp=12.92 bbls 11/7/2015 11/7/2015 0.50 SURFAC CASING SRVY T Pick up redressed multi shot gyro and 495.0 495.0 16:45 17:15 drop @495'MD.Allow to fall to UBHO. 11/7/2015 11/7/2015 0.50 SURFAC CASING TRIP T POOH f/495'MD 1/131'MD taking 495.0 131.0 17:15 17:45 gyro shot each stand. Calc disp=15.7 bbls Act disp=18.36 bbls 11/7/2015 11/7/2015 1.25 SURFAC CASING BHAH T Lay down jars,saver sub,2 NMDC's 131.0 30.0 17:45 19:00 and UBHO as per SLB DD.Retrieve gyro.Good data recovered from gyro. Page 3/24 Report Printed: 12/21/2015 a Iperations Summary (with Timelog'Gepths) 0 2S-08 Con000Pt>villips Ai... Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code TimeP-T-X Operation (ftKB) End Depth(EKE) 11/7/2015 11/7/2015 0.50 SURFAC CASING BHAH P Break off bit and lay down motor. 30.0 0.0 19:00 19:30 11/7/2015 11/7/2015 0.75 SURFAC CASING BHAH P Clean and clear rig floor. 0.0 0.0 19:30 20:15 11/7/2015 11/7/2015 1.75 SURFAC CASING RURD P Rig up Volant CRT/bail extensions. 0.0 0.0 20:15 22:00 Bring casing equip to rig floor. 11/7/2015 11/7/2015 1.50 SURFAC CASING PUTB P Thread lock and MU float track.PU 10 0.0 207.0 22:00 23:30 3/4"45.5#L-80 Hyd 563 dopeless casing to 204'MD 11/7/2015 11/8/2015 0.50 SURFAC CASING PUTB T Improper make up on#6 jt.Joint did 207.0 207.0 23:30 00:00 not make up to mark.Rig up GBR power tongs in order to break out jt. 11/8/2015 11/8/2015 1.00 SURFAC CASING PUTB T RU GBR power tongs.Break out and 207.0 207.0 00:00 01:00 lay down joint#6.Replace with joint #68. 11/8/2015 11/8/2015 2.75 SURFAC CASING PUTB P PU 10 3/4"45.5#L-80 Hyd 563 207.0 1,428.0 01:00 03:45 dopeless casing to 1428'MD.Casing required to be pushed into hole from 650'MD to 1428'MD.Could not go past base of permafrost @ 1428'MD. 11/8/2015 11/8/2015 1.00 SURFAC CASING PUTB T Work pipe.Pump 1-2 bpm, 100 psi, 1,428.0 1,478.0 03:45 04:45 74%FO,Rotate @ 20 rpm.Shut down rotary and work pipe to 1478'MD. 11/8/2015 11/8/2015 0.25 SURFAC CASING CIRC P Stage pump up to 5 bpm, 140 psi 86% 1,478.0 1,478.0 04:45 05:00 FO.Finish casing volume circulation 11/8/2015 11/8/2015 2.75 SURFAC CASING PUTB P PU 10 3/4"45.5#L-80 Hyd 563 1,478.0 2,623.0 05:00 07:45 dopeless casing from 1478'MD to 2623'MD.Place one pup joint(14.82') one full joint below hanger. 10 3/4"Hyd 563 Dopeless-1 reject/0 remakes 11/8/2015 11/8/2015 0.25 SURFAC CASING HOSO P Make up hanger and landing jt..Land 2,623.0 2,652.0 07:45 08:00 casing at 2652'MD. 11/8/2015 11/8/2015 0.75 SURFAC CEMENT RURD P Blow down top drive and rig up 2,652.0 2,652.0 08:00 08:45 cement hose. 11/8/2015 11/8/2015 2.00 SURFAC CEMENT CIRC P Circ and cond mud for cement job. 2,652.0 2,652.0 08:45 10:45 Stage pump up from 2 bpm,210 psi, 63%FO to 6 bpm,465 psi,89%FO. PU 145K SO 117K. Sim-ops/PJSM on cement job. 11/8/2015 11/8/2015 3.25 SURFAC CEMENT CMNT P Pump 61 bbls nut plug mud marker 2,652.0 2,652.0 10:45 14:00 pill.Pump 5 bbls of CW-100&PT lines to 900/4000 psi.Continue pumping 8.35 ppg CW-100 for a total of 75 bbls,4.8 bpm, 150 psi.Pump 75 bbls of 10.5 ppg MPII w/red dye at 4.5 bpm,200 psi.Drop bottom plug& pump 396 bbls of 11.0 ppg Lead Cement at 6 bpm,360 psi.Pump 64 bbls of 12.0 ppg Tail Cement at 5.2 bpm,420 psi.Drop top plug&kick out with 10 bbls of fresh H2O at 5.5 bpm, 300 psi. Page 4/24 Report Printed: 12/21/2015 01- Iperations Summary (with Timeloglpths) 38 2S-08 Conocait illips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time ':Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(ftKB) 11/8/2015 11/8/2015 1.00 SURFAC CEMENT CMNT P Swap to rig&displace cement with 2,652.0 2,652.0 14:00 15:00 9.7 ppg mud at 6 bpm,525 psi.Bump plug w/236.8 bbls,pressure up to 1025 psi&hold for 5 min.Check floats,good.CIP at 14:45 hrs.Total of 113 bbls of cement returns to surface. Hanger flutes packed off and lost returns to pits.Lost 70 bbls to formation. Observed well flowing @ 10 bph diminishing to static in 30 mins 11/8/2015 11/8/2015 1.50 SURFAC CEMENT RURD P Drain and clean out stack.Flush 2,652.0 2,652.0 15:00 16:30 diverter w/black water pill through 4" outlets in conductor. 11/8/2015 11/8/2015 1.00 SURFAC CEMENT RURD P Hanger flutes packed off,unable to 2,652.0 2,652.0 16:30 17:30 drain diverter and riser.Use rig vac system to remove fluid from riser.Sim- ops/Lay down bail extensions,power tongs,thread protectors,centralizers and x-overs. 11/8/2015 11/8/2015 1.50 SURFAC CEMENT OWFF T Monitor well at conductor outlets.Very 2,652.0 2,652.0 17:30 19:00 minor flow steadily diminishing. 11/8/2015 11/8/2015 0.75 SURFAC CEMENT RURD P Lay down landing joint and rig down 2,652.0 0.0 19:00 19:45 Volant CRT 11/8/2015 11/8/2015 0.25 SURFAC CEMENT SFTY P PJSM on ND diverter 0.0 0.0 19:45 20:00 11/8/2015 11/8/2015 0.75 SURFAC CEMENT NUND P Clean out and remove riser.Wash out 0.0 0.0 20:00 20:45 annular preventer. 11/8/2015 11/8/2015 2.00 SURFAC CEMENT NUND P ND diverter vent lines,knife valve, 0.0 0.0 20:45 22:45 diverter adapter,diverter spool and annular preventer. TOC-24"down conductor 11/8/2015 11/8/2015 0.25 SURFAC WHDBOP NUND P Prep T103 hanger connection and 0.0 0.0 22:45 23:00 grease o-rings. 11/8/2015 11/9/2015 1.00 SURFAC WHDBOP NUND P PU and orient Cameron 11"5000 psi 0.0 0.0 23:00 00:00 MBS wellhead 11/9/2015 11/9/2015 0.75 SURFAC WHDBOP PRTS P PJSM,Test seals on wellhead to 5000 0.0 0.0 00:00 00:45 psi f/15 minutes,good. 11/9/2015 11/9/2015 2.00 SURFAC WHDBOP MPDA P Install flange on MPD air valve and 0.0 0.0 00:45 02:45 install MPD air valve on BOP stack. SIMOPS,remove diverter vent line from cellar area w/crane. 11/9/2015 11/9/2015 1.00 SURFAC WHDBOP NUND P 'N/U BOPE and attach kill line. 0.0 0.0 02:45 03:45 11/9/2015 11/9/2015 3.75 SURFAC WHDBOP SVRG P Perform BWM.Open all ram doors 0.0 0.0 03:45 07:30 and pressure wash out.Take pictures or wear plates and rams.Observed damaged top seal on blind rams,CIO seal on blind rams.Inspect all BOP equipment as per CPAI BWM policy. 11/9/2015 11/9/2015 0.50 SURFAC WHDBOP NUND P N/U choke line.SIMOPS,pull boot 0.0' 0.0 07:30 08:00 protector and R/U RCD clamp. 11/9/2015 11/9/2015 2.50 SURFAC WHDBOP MPDA P Set test plug,install MPD test cap and 0.0 0.0 08:00 10:30 M/U MPD lines and valves as per rig engineer. 11/9/2015 11/9/2015 3.00 SURFAC WHDBOP PULD P PJSM,R/U and pick up 29 stands of 0.0 0.0 10:30 13:30 5"DP and stand back in derrick. SIMOPS,build scaffolding around BOP stack. Page 5/24 Report Printed: 12/21/2015 of'i Iperations Summary (with Timelog•pths) 2S-08 Conocc hilIps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/9/2015 11/9/2015 0.25 SURFAC WHDBOP OTHR P Lay mousehole and DP thread 0.0 0.0 13:30 13:45 protectors. 11/9/2015 11/9/2015 1.50 SURFAC WHDBOP MPDA P Rig up KatchKan,drain lines,2" 0.0 0.0 13:45 15:15 equalizing line and flow line for MPD system 11/9/2015 11/9/2015 2.50 SURFAC WHDBOP MPDA P Flood BOPE and MPD choke skid and 0.0 0.0 15:15 17:45 perform body test to 1000 psi.Test MPD chokes and valves to 250/1000 psi for 5 mins each. 11/9/2015 11/9/2015 2.25 SURFAC WHDBOP MPDA P Blow down MPD lines and choke skid. 0.0 0.0 17:45 20:00 Remove MPD test plug.Install trip nipple.Nipple too short.Remove and send to weld shop for modification 11/9/2015 11/9/2015 1.50 SURFAC WHDBOP RURD P Rig up to test BOPE.Purge air and 0.0 0.0 20:00 21:30 perform body test. 11/9/2015 11/10/2015 2.50 SURFAC WHDBOP BOPE P Test BOPE w/5"test joint to 250/3500 0.0 0.0 21:30 00:00 psi for 5 min each.#1:Top pipe rams, CV 1,12,13, 14&manual kill valve. #2:Upper IBOP,HCR kill,CV 9,&11. #3:Lower IBOP,CV 5,8&10. #4: Dart,CV 4,6&7. #5:FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7:Manual choke valve& HCR kill. #8:Annular preventer tested to 250/2500 psi.#9:Lower pipe rams. 11/10/2015 11/10/2015 1.00 SURFAC WHDBOP BOPE P PJSM;Continue BOPE test.Test 0.0 0.6- 00:00 01:00 accumulator initial system pressure 3000 psi,pressure after closing 1800 psi,200 psi attained in 52 sec,full pressure attained in 194 sec.5 nitrogen bottles average system pressure of 2050 psi.Test blind rams, CV#3,to 250/3500 psi for 5 min each.Perform draw down test on manual&hydraulic choke valves.Test witness waived by AOGCC Rep Jeff Jones. 11/10/2015 11/10/2015 1.00 SURFAC WHDBOP RURD P PJSM;rig down test equipment,blow 0.0 0.0 01:00 02:00 down all lines,pull test plug&intstall 10"wear bushing. 11/10/2015 11/10/2015 0.75 SURFAC CEMENT RURD P PJSM;pick up split bushings&install 0.0 0.0 02:00 02:45 riser.SIMOPS mobilize BHA 2 tools to rig floor. 11/10/2015 11/10/2015 1.75 SURFAC CEMENT BHAH P PJSM;make up BHA 2 as per SLB 0'- 0.0 126.0 02:45 04:30 126'MD. 11/10/2015 11/10/2015 0.75 SURFAC CEMENT BHAH P PJSM;attempt to open WFT reamer, 126.0 126.0 04:30 05:15 300 gpm,300 psi.Could not achieve the higher flow rate needed to open reamer due to BHA source near rig floor.Change nozzles manually& close tool. 11/10/2015 11/10/2015 1.25 SURFAC CEMENT BHAH P Finish picking up BHA 2 as per SLB F/ 126.0 721.0 05:15 06:30 126'-721'MD. 11/10/2015 11/10/2015 0.50 SURFAC CEMENT SVRG P PJSM;service rig. 721.0 721.0 06:30 07:00 11/10/2015 11/10/2015 1.00 SURFAC CEMENT PULD P PJSM;single in the hole w/5"DP f/ 721.0 1,561.0 07:00 08:00 721'-1561'MD. 11/10/2015 11/10/2015 0.50 SURFAC CEMENT DHEQ T Attempt shallow hole test of MWD. 1,561.0 1,561.0 08:00 08:30 String packed,off decision made to TOH. Page 6/24 Report Printed: 12/21/2015 ,. Iperations Summary (with Timeloglpths) 2S-08 ConrocoPhillps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 11/10/2015 11/10/2015 1.25 SURFAC CEMENT TRIP T PJSM;f/1561'-167'MD. 1,561.0 167.0 08:30 09:45 Kick w/Tripping Drill CRT 38 sec @ 09:00 hrs. 11/10/2015 11/10/2015 2.00 SURFAC CEMENT BHAH T PJSM;lay down BHA 2 as per SLB. 167.0 0.0 09:45 11:45 Cement was found packed off on top of float. 11/10/2015 11/10/2015 1.00 SURFAC CEMENT BHAH T PJSM;clean out packed off stabilizer, 0.0 0.0 11:45 12:45 clear&clean rig floor.Rig up mouse hole. 11/10/2015 11/10/2015 2.00 SURFAC CEMENT PULD T PJSM;lay down 114 joints of 5"DP. 0.0 0.0 12:45 14:45 11/10/2015 11/10/2015 2.25 SURFAC CEMENT RURD T PJSM;load 144 joints of 5"DP in pipe ' 0.0 0.0 14:45 17:00 shed,remove protectors,inspect& tally. 11/10/2015 11/10/2015 3.00 SURFAC CEMENT PULD T PJSM;pick up&rack back 29 stands 0.0 0.0 17:00 20:00 of DP in the derrick.Drifted w/2.94". 11/10/2015 11/10/2015 0.25 SURFAC CEMENT RURD T Rig down mouse hole&remove 0.0 0.0 20:00 20:15 thread protectors from rig floor. 11/10/2015 11/10/2015 2.00 SURFAC CEMENT BHAH T PJSM;pick up BHA 3 as per SLB f/0- 0.0 720.0 20:15 22:15 720'MD. 11/10/2015 11/10/2015 1.50 SURFAC CEMENT PULD T PJSM;single in the hole w/5"DP f/ 720.0 1,648.0 22:15 23:45 720'-1648'MD. 11/10/2015 11/11/2015 0.25 SURFAC CEMENT DHEQ P Shallow hole test MWD 415 gpm,900 1,648.0 1,648.0 23:45 00:00 psi.Tested good. 11/11/2015 11/11/2015 1.00 SURFAC CEMENT PULD P PJSM,Cont.to RIH picking up 5"DP 1,648.0 2,486.0 00:00 01:00 f/1648'MD to 2486'MD,picked up a total of 57 joints while RIH.Actual displacement=7 bbls.Calculated displacement=6.67 bbls. 11/11/2015 11/11/2015 1.00 SURFAC CEMENT RURD P PJSM;R/U to test 10-3/4"casing and 2,486.0 2,486.0 01:00 02:00 pump though kill line at 7 bpm=800 psi. 11/11/2015 11/11/2015 0.75 SURFAC CEMENT PRTS P PJSM;pressure test 10-3/4"casing to 2,486.0 2,486.0 02:00 02:45 3500 psi for 30 min chart,good.Rig down test equipment. 11/11/2015 11/11/2015 0.50 SURFAC CEMENT COCF P Wash down f/2486'MD to plugs @ 2,486.0 2,564.0 02:45 03:15 2564'MD.TOC @ 2558'MD 11/11/2015 11/11/2015 5.00 SURFAC CEMENT DRLG P Drill out float collar,shoe track,float 2,564.0 2,665.0 03:15 08:15 shoe and rat hole to 2665'MD.Pump @ 400 gpm=965 psi,40 rpm w/5K Tq.P/U=109K,S/O=93K, ROT=101 K. 11/11/2015 11/11/2015 0.50 SURFAC CEMENT DDRL P Directional drill f/2665'-2685'MD, 2,665.0 2,685.0 08:15 08:45 2577'TVD,ADT.33,JARS 158.61, PU 109K,SO 93K,ROT 101K,Tq on 6-7K,off 3-4K,ECD 10.17,FO 39%, WOB 10-15K,80 rpm,650 gpm, 1975 psi,Max gas 265.Total footage 20' MD. 11/11/2015 11/11/2015 0.50 SURFAC CEMENT CIRC P CBU @ 650 gpm, 1975 psi,FO 39%, 2,685.0 2,685.0 08:45 09:15 60 rpm,Tq 5-6K. 11/11/2015 11/11/2015 0.25 SURFAC CEMENT TRIP P PJSM;TOH f/2685'-2581'MD,blow 2,685.0 2,581.0 09:15 09:30 down TD. 11/11/2015 11/11/2015 0.75 SURFAC CEMENT FIT P PJSM;rig up&perform FIT to an 2,581.0 2,581.0 09:30 10:15 EMW of 16.1 ppg,860 psi applied.Rig down test equipment. 11/11/2015 11/11/2015 0.25 INTRM1 DRILL TRIP P TIH f/2581'-2685'MD. 2,581.0 2,685.0 10:15 10:30 Page 7/24 Report Printed: 12/21/2015 •perations Summary (with Timeloglepths) CA 0 ry 2S-08 CConocoPhillps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ttKB) End Depth(MKS) 11/11/2015 11/11/2015 1.75 INTRM1 DRILL DDRL P Directional drill f/2685'-2785'MD, 2,685.0 2,785.0 10:30 12:15 2662'TVD,ADT 1.2,Bit hrs 1.53, JARS 159.81,PU 110K,SO 95K, ROT 102K,Tq on 5-6K,off 2-4K,ECD 10.34,FO 38%,WOB 5-8K,80 rpm, 657 gpm, 1530 psi,Max gas 46.Total footage 100'MD. Pump 23 bbl Hi-Vis Sweep&displace mud system over to 9.6 ppg LSND while drilling. SPR's©2763'MD,2496'TVD,MW 9.7 ppg, 11:45 hrs. #1 @ 30 spm=100 psi @ 40 spm= 140 psi #2 @ 30 spm=90 psi @ 40 spm= 140 psi 11/11/2015 11/11/2015 0.75 INTRM1 DRILL CIRC P PJSM;pull up to 2765'MD,break 2,785.0 0.0 12:15 13:00 connection&pump down RFID chips per WFT Rep to open reamer.Wash down to 2785 MD @ 300 gpm,425 psi,FO 28%,20 rpm,Tq 3-4K.Shut down pumps&bleed off psi.Pump 650 gpm,initial pressure 1500 psi, dropping to 1275 psi indicating knives opened.Pull up to shoe&observe 5K over pull to verify reamer open. 11/11/2015 11/11/2015 5.00 INTRM1 DRILL DDRL P Directional drill f/2785'-3228'MD, 2,785.0 3,228.0 13:00 18:00 3048'TVD,ADT 4.21,Bit hrs 5.74, JARS 164.02,PU 116K,SO 99K, ROT 109K,Tq on 5-10K,off 4.5K, ECD 10.48,FO 45%,WOB 10-14K, 120 rpm,803 gpm, 1990 psi,Max gas 79.Total footage 443'MD. 11/11/2015 11/12/2015 6.00 INTRM1 DRILL DDRL P Directional drill f/3228'-3606'MD, 3,228.0 3,606.0 18:00 00:00 3382'TVD,ADT 2.91,Bit hrs 8.65, JARS 166.93,PU 120K,SO 105K, ROT 110K,Tq on 6-9K,off 4K,ECD 10.43,FO 45%,WOB 10-13K, 120 rpm,803 gpm,2100 psi,Max gas 72. Total footage 378'MD. SPR's @ 3606'MD,3374'TVD,MW 9.6 ppg,23:15 hrs. #1 @30 spm=120 psi @40 spm= 180 psi #2 @ 30 spm=130 psi @40 spm= 180 psi 11/12/2015 11/12/2015 6.00 INTRM1 DRILL DDRL P Directional drill f/3606'MD to 4252' 3,606.0 4,252.0 00:00 06:00 MD,3951'TVD,ADT 4.86,Bit hrs 13.51,JARS 171.49,PU 142K,SO 113K,ROT 125K,Tq on 6-11K,off 5- 6K,ECD 10.36,FO 34%,WOB 15- 20K, 120 rpm,803 gpm,2060 psi, Max gas 94.Total footage 646'MD. Kick w/Drilling CRT 46 sec @ 05:30 hrs. SPR's @ 4252'MD,3805'TVD,MW 9.8 ppg,6:15 hrs. #1 @ 30 spm=130 psi @ 40 spm= 170 psi #2 @ 30 spm=130 psi @ 40 spm= 170 psi 11/12/2015 11/12/2015 0.50 INTRM1 DRILL CIRC P Pump high-vis sweep and circulate the 4,252.0 4,252.0 06:00 06:30 hole clean @ 800 gpm=2050 psi Page 8/24 Report Printed: 12/21/2015 111114 •perations Summary (with Timelog.pths) 0:3 to 2S-08 Canochiihps A6r.A. Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/12/2015 11/12/2015 0.25 INTRM1 DRILL OWFF P OWFF,static. 4,252.0 4,252.0 06:30 06:45 11/12/2015 11/12/2015 0.75 INTRM1 DRILL MPDA P Remove trip nipple and install MPD 4,252.0 4,252.0 06:45 07:30 bearing. 11/12/2015 11/12/2015 0.50 INTRM1 DRILL MPDA P Align BOP stack with MPD bearing 4,252.0 4,252.0 07:30 08:00 installed and flood MPD chokes with mud. 11/12/2015 11/12/2015 4.00 INTRM1 DRILL DDRL P Directional drill f/4252'MD to 4436' 4,252.0 4,436.0 08:00 12:00 MD,4112'TVD,ADT 2.69,Bit hrs 16.20,JARS 174.48,PU 146K,SO 115K, ROT 126K,Tq on 9-11K,off 6- 7K,ECD 10.82,FO 92%,WOB 16- 20K, 130 rpm,800 gpm,2300 psi, Max gas 280.Total footage 184'MD. 11/12/2015 11/12/2015 2.50 INTRM1 DRILL DDRL P Directional drill f/4436'MD to 4662' 4,436.0 4,662.0 12:00 14:30 MD,4311'TVD,ADT 2.08,Bit hrs 18.28,JARS 176.56,PU 153K,SO 115K,ROT 129K,Tq on10-12K,off 7- 8K,ECD 11.07,FO 64%,WOB 20- 25K, 140 rpm,800 gpm,2600 psi, Max gas 83.Total footage 226'MD. 11/12/2015 11/12/2015 0.50 INTRM1 DRILL MPDA T Recalibrate MPD chokes due to power 4,662.0 4,662.0 14:30 15:00 outage. 11/12/2015 11/12/2015 3.00 INTRM1 DRILL DDRL P Directional drill f/4662'MD to 4996' 4,662.0 4,996.0 15:00 18:00 MD,4608'TVD,ADT 2.4,Bit hrs 20.68,JARS 178.96,PU 155K,SO 123K,ROT 130K,Tq on10-12K,off 8K,ECD 11.28,FO 65%,WOB 15- 20K, 140 rpm,800 gpm,2750 psi, Max gas 192.Total footage 334'MD. 11/12/2015 11/13/2015 6.00 INTRM1 DRILL DDRL P Directional drill f/4996'MD to 5460' 4,996.0 5,460.0 18:00 00:00 MD,5014'TVD,ADT 3.86,Bit hrs 24.54,JARS 182.82,PU 165K,SO 124K,ROT 141K,Tq on 5-17K,off 9K, ECD 11.22,FO 56%,WOB 20-25K, 140 rpm,810 gpm,2920 psi,Max gas 168.Total footage 464'MD. SPR's @ 5460'MD,5012'TVD,MW 10.1 ppg,23:39 hrs. #1 @ 30 spm=200 psi @ 40 spm= 250 psi #2 @ 30 spm=200 psi @ 40 spm= 240 psi Kick w/Drilling CRT 120 sec @ 23:15 hrs. 11/13/2015 11/13/2015 4.50 INTRM1 DRILL DDRL P Directional drill f/5460'MD to 5834' 5,460.0 5,834.0 00:00 04:30 MD,5334'TVD,ADT 3.54,Bit hrs 28.08,JARS 186.36,PU 175K,SO 135K,ROT 150K,Tq on 5-20K,off 10- 20K,ECD 11.40,FO 59%,WOB 20- 29K, 140 rpm,800 gpm,2850 psi, Max gas 143.Total footage 374'MD. 11/13/2015 11/13/2015 1.00 INTRM1 DRILL SVRG P Change out wash pipe on top drive, 5,834.0 5,834.0 04:30 05:30 test to 3500 psi. 11/13/2015 11/13/2015 0.50 INTRM1 DRILL DDRL P Directional drill f/5834'MD to 5870' 5,834.0 5,870.0 05:30 06:00 MD,5360'TVD,ADT.28,Bit hrs 28.36,JARS 186.64,PU 175K,SO 135K,ROT 150K,Tq on 5-20K,off 10- 20K,ECD 11.5,FO 59%,WOB 20- 30K, 140 rpm,800 gpm,2900 psi, Max gas 1262.Total footage 36'MD. Page 9/24 Report Printed: 12/21/2015 operations Summary (with Timelogpths) 0,NimatoRNEEE 2S-08 LonocoPhillfps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/13/2015 11/13/2015 6.00 INTRM1 DRILL DDRL P Directional drill f/5870'MD to 6488' 5,870.0 6,488.0 06:00 12:00 MD,5815'TVD,ADT 4.86,Bit hrs 32.22,JARS 191.64,PU 177K,SO 145K,ROT 153K,Tq on 14-16K,off 7- 8K,ECD 11.11,FO 59%,WOB 25- 30K, 140 rpm,800 gpm,3025 psi, Max gas 1062.Total footage 618'MD. SPR's @ 6488'MD,5812'TVD,MW 10.1 ppg, 12:00 hrs. #1 @ 30 spm=190 psi @ 40 spm= 240 psi #2 @ 30 spm=180 psi @ 40 spm= 240 psi 11/13/2015 11/13/2015 6.00 INTRM1 DRILL DDRL P Directional drill f/6488'MD to 7052' 6,488.0 7,052.0 12:00 18:00 MD,6135'TVD,ADT 4.06,Bit hrs 37.28,JARS 195.56,PU 177K,SO 130K,ROT 145K,Tq on 14-16K,off 5- 18K,ECD 11.12,FO 59%,WOB 21- 27K, 140 rpm,800 gpm,3150 psi, Max gas 1409.Total footage 564'MD. 11/13/2015 11/13/2015 1.50 INTRM1 DRILL DDRL P Directional drill f/7052'MD to 7151' 7,052.0 7,151.0 18:00 19:30 MD,6173'TVD,ADT.72,Bit hrs 38, JARS 196.28,PU 176K,SO 129K, ROT 145K,Tq on 14-16K,off 5-12K, ECD 11.12,FO 59%,WOB 23-27K, 140 rpm,800 gpm,3150 psi,Max gas 825.Total footage 99'MD. TD 7151'MD,6173'TVD.K1 @ 7143' MD,6171'TVD. 11/13/2015 11/13/2015 0.75 INTRM1 CASING CIRC P CBU @ 800 gpm,3100 psi, 140 rpm, 7,151.0 7,151.0 19:30 20:15 Tq 9-10K,FO 59%,PU 152K,SO 129K. 11/13/2015 11/13/2015 0.75 INTRM1 CASING CIRC P Close under reamer as per WFT rep. 7,151.0 7,151.0 20:15 21:00 pump RFID chips down at 775 gpm, 2950 psi.Shut down&bleed off.Work pipe for 10 min.Pump @ 650 gpm, 2600 psi verifying reamer closed. 11/13/2015 11/13/2015 0.50 INTRM1 CASING OWFF P Perform finger print to verify no 7,151.0 7,151.0 21:00 21:30 wellbore pressure. SPR's @ 7150'MD,6171'TVD,MW 10.0 ppg,21:00 hrs. #1 @30 spm=210 psi @40 spm= 275 psi #2 @ 30 spm=210 psi @ 40 spm= 260 psi 11/13/2015 11/14/2015 2.50 INTRM1 CASING PMPO P PJSM;PumpOOH f/7151'-6579'MD, 7,151.0 6,579.0 21:30 00:00 650 gpm,2450 psi,500 fph,PU 175K, SO 130K. 11/14/2015 11/14/2015 0.75 INTRM1 CASING CIRC P CBU @ 650 gpm,2450 psi,90 rpm, 6,579.0 6,579.0 00:00 00:45 Tq 7-8K,PU 175K,SO 130K. 11/14/2015 11/14/2015 0.75 INTRM1 CASING OWFF P Perform finger print,observe no 6,579.0 6,579.0 00:45 01:30 increase in pressure.Blow down TD. 11/14/2015 11/14/2015 3.50 INTRM1 CASING TRIP P PJSM;TOH utilizing MPD f/6579'- 6,579.0 2,581.0 01:30 05:00 2581'MD,holding 100 psi in the slips, per trip schedule.Calculated fill 34.65, actual 39.9 bbls. 11/14/2015 11/14/2015 0.50 INTRM1 CASING CIRC P CBU @ 650 gpm, 1900 psi,60 rpm, 2,581.0 2,581.0 05:00 05:30 Tq 4-5K. Page 10/24 Report Printed: 12/21/2015 •perations Summary (with Timelog9 pths) 0 2S-08 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr)i Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKES) 11/14/2015 11/14/2015 0.50 INTRM1 CASING MPDA P Monitor well,static.SIMOPS flush 2,581.0 2,581.0 05:30 06:00 MPD choke system w/H2O&blow down same. 11/14/2015 11/14/2015 1.00 INTRM1 CASING MPDA P PJSM;pull RCD,align stack&install 2,581.0 2,581.0 06:00 07:00 trip nipple. 11/14/2015 11/14/2015 1.00 INTRM1 CASING TRIP P PJSM;TOH f/2581-720'MD.Hole fill 2,581.0 720.0 07:00 08:00 for entire trip,calculated 30.39,actual 33.22 bbls. Kick w/Tripping Drill CRT 45 sec @ 08:00 hrs. 11/14/2015 11/14/2015 0.25 INTRM1 CASING OWFF P Monitor well,static. 720.0 720.0 08:00 08:15 11/14/2015 11/14/2015 0.50 INTRM1 CASING TRIP P PJSM;TOH f/720'-166'MD,standing 720.0 166.0 08:15 08:45 back HWDP&Jars. 11/14/2015 11/14/2015 1.75 INTRM1 CASING BHAH P PJSM;lay down BHA 3 lay down as 166.0 0.0 08:45 10:30 per SLB. 11/14/2015 11/14/2015 0.50 INTRM1 CASING BHAH P PJSM;clear&clean rig floor. 0.0 0.0 10:30 11:00 11/14/2015 11/14/2015 0.50 INTRM1 CASING WWWH P PJSM;flush stack&blow down top 0.0 0.0 11:00 11:30 drive. 11/14/2015 11/14/2015 0.50 INTRM1 CASING BOPE P PJSM;pull wear bushing&install test 0.0 0.0 11:30 12:00 plug. 11/14/2015 11/14/2015 1.00 INTRM1 CASING BOPE P PJSM;change out upper VBR's to 7- 0.0 0.0 12:00 13:00 5/8"solid body rams.SIMOPS rig up Volant CRT. 11/14/2015 11/14/2015 1.00 INTRM1 CASING BOPE P PJSM;rig up&test upper rams w/7- 0.0 0.0 13:00 14:00 5/8"joint to 250/3500 psi.Test annular to 250/2500 psi.All tests charted for 5 minutes each.Rig down test equipment. 11/14/2015 11/14/2015 0.75 INTRM1 CASING RURD P PJSM;rig up casing handling 0.0 0.0 14:00 14:45 equipment. 11/14/2015 11/14/2015 1.00 INTRM1 CASING SFTY P Safety stand down with crew. Discuss 0.0 0.0 14:45 15:45 hazard ID&elimination techniques. 11/14/2015 11/14/2015 5.50 INTRM1 CASING PUTB P PJSM;run 7-5/8",29.7#,L-80,Hydril 0.0 2,500.0 15:45 21:15 563,dopeless casing as per detail from surface to 2500'MD. 11/14/2015 11/14/2015 1.00 INTRM1 CASING CIRC P Circulate&condition mud staging up 2,500.0 2,500.0 21:15 22:15 pumps to 5 bpm,220 psi,PU 95K,SO 90K,ROT 93K,Tq 1-2K. 11/14/2015 11/15/2015 1.75 INTRM1 CASING PUTB P PJSM;run 7-5/8",29.7#,L-80,Hydril 2,500.0 3,313.0 22:15 00:00 563,dopeless casing as per detail from 2500'-3313'MD.Calculated displacement 31,actual 26 bbls. 11/15/2015 11/15/2015 2.25 INTRM1 CASING PUTB P PJSM;run 7-5/8",29.7#,L-80,Hydril 3,313.0 4,993.0 00:00 02:15 563,dopeless casing as per detail from 3313'-4993'MD. 11/15/2015 11/15/2015 2.75 INTRM1 CASING CIRC P Break circulation staging up pumps 4,993.0 4,993.0 02:15 05:00 from 1-3.5 bpm,475-250 psi,FO 14%. Circulate out up to 10.8 ppg mud till 10.0+ppg mud back.PU 142K,SO 120K. 11/15/2015 11/15/2015 2.75 INTRM1 CASING PUTB P PJSM;run 7-5/8",29.7#,L-80,Hydril 4,993.0 6,582.0 05:00 07:45 563,dopeless casing as per detail from 4993'-6582'MD.Improper hole fill,decision made to CBU. Page 11/24 Report Printed: 12/21/2015 i. 0 iterations Summary (with Timelog�epths) r 2S-08 ConoCo`Philhps AF,7,4,.. Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/15/2015 11/15/2015 2.50 INTRM1 CASING CIRC T Break circulation staging up pumps 6,582.0 6,582.0 07:45 10:15 from.5-3.5 bpm,450-350 psi,FO slight-14%.Circulate out up to 10.8 ppg mud till 10.0 ppg mud back.PU 192K,SO 145K. 11/15/2015 11/15/2015 1.00 INTRM1 CASING PUTB P PJSM;run 7-5/8",29.7#,L-80,Hydril 6,582.0 7,112.0 10:15 11:15 563,dopeless casing as per detail from 6582'-7112'MD.PU 225K,SO 150K.Calculated displacement for trip 45.63,actual 39.95 bbls. Ran 61 Hydroform centralizers per detail. Ran 173 joints of casing with no damaged pipe or rejects. 11/15/2015 11/15/2015 0.50 INTRM1 CASING HOSO P PJSM;make up hanger&landing joint 7,112.0 7,141.0 11:15 11:45 f/7112'-7141'MD.Land hanger. 11/15/2015 11/15/2015 0.25 INTRM1 CEMENT RURD P PJSM;rig up cement line to cement 7,141.0 7,141.0 11:45 12:00 swivel.Blow down top drive. 11/15/2015 11/15/2015 2.25 INTRM1 CEMENT CIRC P Circulate&condition for cement job 7,141.0 7,141.0 12:00 14:15 staging up the pumps to 6 bpm,550 psi,FO 20%,PU 210K,SO 155K. 11/15/2015 11/15/2015 3.00 INTRM1 CEMENT CMNT P PJSM;line up to cementers&pump 5 7,141.0 0.0 14:15 17:15 bbls of CW-100.Pressure test lines 500/4000 psi for 5 min.Pump 65 bbls of CW-100,4.5 bpm,350 psi.Pump 40 bbls of 11.5 ppg MPII at 4.7 bpm, 350 psi.Load bottom plug in pipe. Pump 186 bbls of 15.3 ppg cement slurry w/1lb/bbl CemNet at 5.5 bpm, 275 psi.Load top plug in pipe.Pump 10 bbls of H20.Swap to rig&displace with 310 bbls of 10.0 ppg mud at 5 bpm, 150-900 psi.Bump plug& pressure up to 1400 psi&hold for 5 min.Bleed off&check floats,good. CIP 16:55 hrs. 11/15/2015 11/15/2015 1.25 INTRM1 CEMENT RURD P Rig down cement equipment,lay 0.0 0.0 17:15 18:30 down landing joint&Volant CRT. 11/15/2015 11/15/2015 2.00 INTRM1 CEMENT WWSP P PJSM;make up 7-5/8"pack off&set. 0.0 0.0 18:30 20:30 RILDS&test to 5000 psi for 10 min. SIMOPS load pipe shed w/4"DP. 11/15/2015 11/16/2015 3.50 INTRM1 CEMENT PULD P PJSM;rig up&lay down 126 joints of 0.0 0.0 20:30 00:00 5"DP from derrick. 11/16/2015 11/16/2015 2.00 INTRM1 CEMENT PULD P PJSM;lay down 35 stands of 5"DP, 0.0 0.0 00:00 02:00 using mousehole. 11/16/2015 11/16/2015 0.75 INTRM1 CEMENT FRZP P PJSM;spot LRS&Vac truck,rig up 0.0 0.0 02:00 02:45 lines to well head.SIMOPS level rig over well. 11/16/2015 11/16/2015 2.25 INTRM1 CEMENT FRZP P PJSM;flush with 130 bbls of H2O. 0.0 0.0 02:45 05:00 Pump at 1 bpm,observe pressure break over at 1500 psi with 3.1 bbls pumped. Increase rate to 2 bpm, ICP 1200 psi,FCP 1400 psi.Swap over to diesel,pumping 83 bbl @ 2 bpm, 1250 psi. Rig down lines&secure well.OA shut in 600 psi.SIMOPS;load pipe shed with remaining 4"DP&change handling equipment over to 4". Page 12/24 Report Printed: 12/21/2015 1111 •perations Summary (with Timeloggepths) 1/0•2'd .t 2S-08 no codilbiltips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End,Depth(ftKB) 11/16/2015 11/16/2015 2.00 INTRM1 CEMENT PULD P PJSM;pick up&rack back 16 stands 0.0 0.0 05:00 07:00 in the derrick. Fire Drill CRT 60 sec @ 05:15 hrs. 11/16/2015 11/16/2015 0.50 INTRM1 CEMENT SVRG P PJSM;service rig 0.0 0.0 07:00 07:30 11/16/2015 11/16/2015 1.25 INTRM1 CEMENT BOPE P PJSM;change out upper rams to 3.5" 0.0 0.0 07:30 08:45 X 6"VBR's.SIMOPS change out saver sub from 4-1/2 IF to 4"XT39. 11/16/2015 11/16/2015 1.50 INTRM1 CEMENT RURD P Continue changing out saver sub. 0.0 0.0 08:45 10:15 11/16/2015 11/16/2015 0.50 INTRM1 CEMENT MPDA P PJSM;install trip nipple. 0.0 0.0 10:15 10:45 11/16/2015 11/16/2015 6.25 INTRM1 CEMENT PULD P PJSM;pick up&rack back 89 stands 0.0 0.0 10:45 17:00 of 4"DP in derrick. OA pressure 500 psi @ 12:00 hrs. 11/16/2015 11/16/2015 0.75 INTRM1 CEMENT RURD P PJSM;rig down mouse hole.Clear& 0.0 0.0 17:00 17:45 clean rig floor. 11/16/2015 11/16/2015 0.75 INTRM1 WHDBOP RURD P PJSM;rig up to test BOPE. 0.0 0.0 17:45 18:30 11/16/2015 11/16/2015 4.50 INTRM1 WHDBOP BOPE P Test BOPE w/4.5"test joint to 0.0 0.0 18:30 23:00 250/3500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP,HCR kill, CV 9,&11.#3:Lower IBOP,CV 5,8& 10. #4:Dart,CV 4,6&7. #5:FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7: Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.#9: Lower pipe rams.#10:Blind rams and CV 3.Perform manual and hydraulic draw down test.#11;Test annular w/ 3.5"joint 250/2500 psi for 5 min ea. #12 Test top VBR w/3.5"joint 250/3500 psi,#12 Lower VBR w/3/5" joint 250/3500 psi 5 min.Test gas, flow&pit level alarms.Accumulator test:system pressure=3000 psi,After closing=2000 psi,200 psi attained after 38 sec,full pressure attained after 140 sec,Five bottle nitrogen avg=1950 psi. The BOP test witness was waived by AOGCC Rep.Chuck Scheve. 11/16/2015 11/17/2015 1.00 INTRM1 WHDBOP RURD P PJSM;rig down test equipment,blow 0.0 0.0 23:00 00:00 down lines,drain stack&set 10"ID wear bushing. Spill Drill CRT 92 sec @ 23:45 hrs. OA pressure 320 psi @ 24:00 hrs. 11/17/2015 11/17/2015 1.00 INTRM1 CEMENT BHAH P PJSM;bring BHA tools to the rig floor 0.0 0.0 00:00 01:00 11/17/2015 11/17/2015 3.00 INTRM1 CEMENT SHAH P PJSM;make up BHA4. Load nuclear 0.0 448.0 01:00 04:00 sources 11/17/2015 11/17/2015 1.00 INTRM1 CEMENT PULD P RIH with BHA picking up singles out of 448.0 1,582.0 04:00 05:00 the pipeshed from 448'to 1582' 11/17/2015 11/17/2015 0.50 INTRM1 CEMENT DHEQ P Shallow test MWD @ 230 gpm, 1200 1,582.0 1,582.0 05:00 05:30 psi @ 21%flow 11/17/2015 11/17/2015 2.25 INTRM1 CEMENT PULD P RIH with BHA picking up singles out of 1,582.0 4,229.0 05:30 07:45 the pipe shed from 1582'to 4229'. Spill Drill CRT 95 sec @ 07:45 hrs. Page 13/24 Report Printed: 12/21/2015 Iperations Summary (with Timeloglepths) 0 2S-08 LonocoPhiilapes Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/17/2015 11/17/2015 0.50 INTRM1 CEMENT DLOG P Fill drillpipe and turn on MWD to Fast 4,229.0 4,229.0 07:45 08:15 Mode. Pump @ 230 gpm, 1450 psi @ 21%flow 11/17/2015 11/17/2015 3.75 INTRM1 CEMENT DLOG P RIH with BHA picking up singles out of 4,229.0 5,741.0 08:15 12:00 the pipeshed from 4229'to 5741'. Perform MAD Pass at—900'fph. P/U = 126 kips,S/O=96 kips. Calculated displacement=35.03 bbl,actual displacement=34.55 bbl OA pressure 320 psi at 12:00 hrs. 11/17/2015 11/17/2015 2.75 INTRM1 CEMENT DLOG P RIH with BHA picking up singles out of 5,741.0 6,965.0 12:00 14:45 the pipeshed from 5741'to 6965'. Perform MAD Pass at—900 fph. Kick w/Tripping CRT 68 sec @ 14:75 hrs. 11/17/2015 11/17/2015 1.00 INTRM1 CEMENT SLPC P PJSM;cut and slip 59'of drilling line. 6,965.0 6,965.0 14:45 15:45 11/17/2015 11/17/2015 0.50 INTRM1 CEMENT SVRG P PJSM;service rig and top drive. 6,965.0 6,965.0 15:45 16:15 11/17/2015 11/17/2015 1.00 INTRM1 CEMENT CIRC P Circulate and condition mud for casing 6,965.0 6,965.0 16:15 17:15 test @ 230 gpm, 1625 psi,FO 17%, 60 rpm,Tq 7-8K. 11/17/2015 11/17/2015 1.50 INTRM1 CEMENT PRTS P PJSM;rig up&test casing to 3500 psi 6,965.0 6,965.0 17:15 18:45 for 30 min.Rig down&blow down test equipment. 11/17/2015 11/17/2015 2.50 INTRM1 CEMENT DRLG P Wash down&tag up on cement plugs 6,965.0 7,052.0 18:45 21:15 @ 7048'MD.Drill out plugs&float collar to 7052'MD,230 gpm, 1700 psi, 60 rpm,Tq 7-10K,FO 17%,WOB 6- 14K, 11/17/2015 11/17/2015 0.50 INTRM1 CEMENT SVRG P PJSM;service TD&grease 7,052.0 7,052.0 21:15 21:45 drawworks. 11/17/2015 11/17/2015 1.75 INTRM1 CEMENT DRLG P Drill out shoe track f/7052'-7143'MD, 7,052.0 7,143.0 21:45 23:30 230 gpm, 1700 psi,60 rpm,Tq 7-10K, FO 17%,WOB 6-14K. 11/17/2015 11/18/2015 0.50 INTRM1 CEMENT CIRC P CBU @ 230 gpm, 1700 psi,FO 17%, 7,143.0 7,143.0 23:30 00:00 60 rpm,Tq 7-9K OA pressure 480 psi @ 24:00 hrs. 11/18/2015 11/18/2015 1.00 INTRM1 CEMENT CIRC P PJSM.Continue to CBU @ 230 gpm, 7,143.0 7,143.0 00:00 01:00 1700 psi,60 rpm,7-9k TQ,flow out 17% 11/18/2015 11/18/2015 1.50 INTRM1 CEMENT MPDA P PJSM,Pull trip nipple,install RCD 7,143.0 7,143.0 01:00 02:30 bearing. 11/18/2015 11/18/2015 0.75 INTRM1 CEMENT CIRC P Test drill string floats.get SPR's. 7,143.0 7,143.0 02:30 03:15 SPR's @ 7143'MD,6175'TVD,MW 10.0 ppg,03:00 hrs. #1 20 spm=430 psi,30 spm=650 psi #2 20 spm=430 psi,30 spm=650 psi 11/18/2015 11/18/2015 0.50 INTRM1 CEMENT DRLG P DRLG from 7143'to 7151'. 7,143.0 7,151.0 03:15 03:45 TVD=6188'.P/U Wt=155k,S/O Wt=105k,Rot=125k,Tq on=10k,Tq off=8k,ECD-10.53 ppg, Flow out= 20%,wob=5-7k,rpm=60,gpm=230, spm=54,PP=1500,max gas=36 11/18/2015 11/18/2015 0.25 INTRM1 CEMENT DDRL P Directional drill f/7151'MD to 7171' 7,151.0 7,171.0 03:45 04:00 MD,6180'TVD,ADT.43,Bit hrs.43, JARS 70.82,PU 155K,SO 105K, ROT 125K,Tq on 10K,off 8-9K,ECD 10.49,FO 20%,WOB 10-12K,80 rpm, 230 gpm, 1650 psi,Max gas 43.Total footage 20'MD. Page 14/24 Report Printed: 12/21/2015 Iperations Summary (with Timelogepths) oo 2S-08 Conoao`f'hilhps Mkx.1n Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/18/2015 11/18/2015 0.75 INTRM1 CEMENT CIRC P CBU laying down a single 7171'-7157' 7,171.0 7,157.0 04:00 04:45 MD @ 230 gpm, 1675 psi,FO 22%, 60 rpm,Tq 8-9K. 11/18/2015 11/18/2015 0.25 INTRM1 CEMENT TRIP P PJSM;TOH f/7157'-7058'MD.Blow 7,157.0 7,058.0 04:45 05:00 down TD. 11/18/2015 11/18/2015 1.00 INTRM1 CEMENT LOT P PJSM;rig up test equipment& 7,058.0 7,058.0 05:00 06:00 perform LOT to an EMW of 14.2 ppg. Applied 1350 psi to break over.Shut in and bled down to 1090 psi in 10 min.Blow down&rig down test equipment. 11/18/2015 11/18/2015 0.50 PROD1 DRILL TRIP P TIH f/7058'-7171 MD. 7,058.0 7,171.0 06:00 06:30 11/18/2015 11/18/2015 1.00 PROD1 DRILL DISP P PJSM;displace to Flo-Thru 10.8 ppg 7,171.0 7,171.0 06:30 07:30 mud.Pump 30 bbls, 11.2 ppg hi-vis spacer.Followed by 350 bbls of 10.8 ppg Flo-Thru mud @ 250 gpm, 1980 psi,FO 22%,60 rpm,Tq 8-9K. 11/18/2015 11/18/2015 1.00 PROD1 DRILL MPDA P PJSM;shell test RCD to 800 psi, 7,171.0 7,171.0 07:30 08:30 calibrate chokes&obtain SPR's. SPR's @ 7171'MD,6180'TVD,MW 10.8 ppg,07:45 hrs #1 @ 20=430;@ 30=650 psi #2 @ 20=430;@ 30=650 psi 11/18/2015 11/18/2015 3.50 PROD1 DRILL DDRL P Directional drill f/7171'MD to 7300' 7,171.0 7,300.0 08:30 12:00 MD,6226'TVD,ADT 2.8,Bit hrs 3.23, JARS 73.73,PU 151K,SO 95K,ROT 118K,Tq on 10K,off 7K,ECD 11.7, FO 22%,WOB 10-15K, 100 rpm,230 gpm,2145 psi,Max gas 735.Total footage 129'MD. OA pressure 410 psi @ 12:00 hrs. 11/18/2015 11/18/2015 7.50 PROD1 DRILL DDRL P Directional drill f/7300'MD to 7534' 7,300.0 7,534.0 12:00 19:30 MD,6291'TVD,ADT 6.24,Bit hrs 9.47,JARS 79.96,PU 147K,SO 88K, ROT 109K,Tq on 7-10K,off 6-7K, ECD 11.97,FO 31%,WOB 9-13K, 140 rpm,240 gpm,2250 psi,Max gas 640.Total footage 234'MD. 11/18/2015 11/18/2015 0.75 PROD1 DRILL OWFF P Perform fingerprint of well,bled down 7,534.0 7,534.0 19:30 20:15 pressure&stabilized at 327 psi for an EMW of 11.8 ppg. 11/18/2015 11/18/2015 0.75 PROD1 DRILL CIRC P CBU @ 240 gpm,2250 psi, 140 rpm, 7,534.0 7,534.0 20:15 21:00 Tq 6-7K,FO 31%,PU 145K,SO 87K, ROT 110K. 11/18/2015 11/19/2015 3.00 PROD1 DRILL DDRL P Directional drill f/7534'MD to 7723' 7,534.0 7,723.0 21:00 00:00 MD,6325'TVD,ADT 1.92,Bit hrs 11.39,JARS 81.88,PU 149K,SO 86K,ROT 110K,Tq on 9-10K,off 7- 8K,ECD 12.0,FO 31%,WOB 9-13K, 140 rpm,250 gpm,2450 psi,Max gas 956.Total footage 189'MD. SPR's @ 7672'MD,6321'TVD,MW 10.8 ppg,23:00 hrs #1 @ 20=550;@ 30=810 psi #2 @ 20=540;@ 30=800 psi OA pressure 340 psi @ 24:00 hrs. Page 15/24 Report Printed: 12/21/2015 •perations Summary (with Timelog epths) 0 2S-08 (.onocoPhitthps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/19/2015 11/19/2015 6.00 PROD1 DRILL DDRL P Directional drill f/7723'MD to 8197' 7,723.0 8,197.0 00:00 06:00 MD,6308'TVD,ADT 3.98,Bit hrs 15.37,JARS 85.86,PU 153K,SO 79K,ROT 108K,Tq on 10K,off 7-8K, ECD 12.12,FO 30%,WOB 9-12K, 140 rpm,250 gpm,2425 psi,Max gas 711.Total footage 474'MD. 11/19/2015 11/19/2015 6.25 PROD1 DRILL DDRL P Directional drill f/8197'MD to 8670' 8,197.0 8,670.0 06:00 12:15 MD,6305'TVD,ADT 3.57,Bit hrs 18.84,JARS 89.33,PU 153K,SO 76K,ROT 113K,Tq on 10-11K,off 8- 10K,ECD 12.11,FO 25%,WOB 8- 10K, 140 rpm,250 gpm,2440 psi, Max gas 1720.Total footage 473'MD. SPR's @ 8616'MD,6305'TVD,MW 10.8 ppg, 12:00 hrs #1 @ 20=450;@ 30=720 psi #2 @ 20=460;@ 30=725 psi OA pressure 410 psi @ 12:00 hrs. 11/19/2015 11/19/2015 0.50 PROD1 DRILL CIRC T CBU and evaluate cuttings to ensure 8,670.0 8,670.0 12:15 12:45 bit didn't fault into the C Sand. Sent commands to Power Drive to drop to 88.2°Inclination while circulating.CBU @ 250 gpm,2440 psi,80 rpm,Tq 8- 10K. 11/19/2015 11/19/2015 1.00 PROD1 DRILL MPDA T Trouble shoot hydraulic oil pump for 8,670.0 8,670.0 12:45 13:45 RCD,250 gpm,2325 psi, 15rpm,Tq 8K. 11/19/2015 11/19/2015 5.25 PROD1 DRILL DDRL P Directional drill f/8670'MD to 9237' 8,670.0 9,237.0 13:45 19:00 MD,6302'TVD,ADT 4.03,Bit hrs 22.87,JARS 93.36,PU 148K,SO 75K,ROT 108K,Tq on 10-11K,off 7- 8K,ECD 12.28,FO 26%,WOB 10- 15K, 140 rpm,250 gpm,2650 psi, Max gas 805.Total footage 567'MD. SPR's @ 9232'MD,6302'TVD,MW 10.8 ppg, 19:00 hrs #1 @ 20=530;@ 30=810 psi #2 @ 20=530;@ 30=760 psi 11/19/2015 11/19/2015 0.25 PROD1 DRILL TRIP T Top drive swivel packing leaking. 9,237.0 9,143.0 19:00 19:15 Rack back 1 stand f/9237'-9143'MD. Blow down TD. 11/19/2015 11/19/2015 1.00 PROD1 DRILL SVRG P PJSM,service TD&change out 9,143.0 9,143.0 19:15 20:15 swivel packing. 11/19/2015 11/19/2015 0.25 PROD1 DRILL REAM T Wash back to bottom f/9143'-9237' 9,143.0 9,237.0 20:15 20:30 MD,250 gpm,2440 psi, 140 rpm,Tq 8 -10K. 11/19/2015 11/20/2015 3.50 PROD1 DRILL DDRL P Directional drill f/9237'MD to 9521' 9,237.0 9,521.0 20:30 00:00 MD,6288'TVD,ADT 2.03,Bit hrs 24.9,JARS 95.39,PU 151K,SO 75K, ROT 106K,Tq on 11K,off 6-8K,ECD 12.23,FO 28%,WOB 12-14K, 140 rpm,250 gpm,2650 psi,Max gas 931. Total footage 284'MD. OA pressure 350 psi @ 24:00 hrs. Page 16/24 Report Printed: 12/21/2015 operations Summary (with Timelog epths) 0 2S-08 t onaocttiiiips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/20/2015 11/20/2015 6.00 PROD1 DRILL DDRL P Directional drill f/9521'MD to 10182' 9,521.0 10,182.0 00:00 06:00 MD,6278'TVD,ADT 4.48,Bit hrs 29.38,JARS 99.87,PU 153K,SO 74K,ROT 108K,Tq on 11-12K,off 10K,ECD 12.26,FO 29%,WOB 10- 15K, 140 rpm,250 gpm,2640 psi, Max gas 1047.Total footage 661'MD. Spill Drill CRT 88 sec @ 05:00 hrs. SPR's @ 9805'MD,6281'TVD,MW 10.8 ppg,09:25 hrs #1 @ 20=580;@ 30=890 psi #2 @ 20=625;@ 30=880 psi 11/20/2015 11/20/2015 2.50 PROD1 DRILL CIRC T CBU and evaluate cuttings to ensure 10,182.0 10,182.0 06:00 08:30 bit didn't fault down into lower A4 or up into A5.Send commands to Power Drive. CBU @ 250 gpm,2720 psi,FO 28%, 100 rpm,Tq 8-9K. 11/20/2015 11/20/2015 3.50 PROD1 DRILL DDRL P Directional drill f/10182'MD to 10420' 10,182.0 10,420.0 08:30 12:00 MD,6269'TVD,ADT 1.78,Bit hrs 31.16,JARS 101.65,PU 155K,SO 70K,ROT 107K,Tq on 11-12K,off 7- 8K, ECD 12.20,FO 28%,WOB 10- 15K, 140 rpm,250 gpm,2665 psi, Max gas 956.Total footage 238'MD. OA pressure @ 12:00 hrs 410 psi. SPR's @ 10272'MD,6281'TVD,MW 10.8 ppg,09:25 hrs #1 @ 20=580;@ 30=890 psi #2 @ 20=625;@ 30=880 psi 11/20/2015 11/20/2015 2.50 PROD1 DRILL DDRL P Directional drill f/10420'MD to 10604' 10,420.0 10,604.0 12:00 14:30 MD,6260'TVD,ADT 1.31,Bit hrs 32.47,JARS 102.96,PU 150K,SO 66K,ROT 105K,Tq on 12-13K,off 8K, ECD 12.35,FO 29%,WOB 15-17K, 140 rpm,250 gpm,2750 psi,Max gas 814.Total footage 184'MD. 11/20/2015 11/20/2015 1.25 PROD1 DRILL MPDA T PJSM;RCD element starting fail. 10,604.0 10,604.0 14:30 15:45 Rack back stand&change out RCD bearing. 11/20/2015 11/20/2015 0.75 PROD1 DRILL DDRL P Directional drill f/10604'MD to 10655' 10,604.0 10,655.0 15:45 16:30 MD,6260'TVD,ADT.27,Bit hrs 32.74,JARS 103.23,PU 150K,SO 66K,ROT 105K,Tq on 12-13K,off 8- 9K,ECD 12.35,FO 29%,WOB 15- 17K, 140 rpm,250 gpm,2750 psi, Max gas 804.Total footage 51'MD. 11/20/2015 11/20/2015 0.50 PROD1 DRILL SRVY T Pick up,shoot surrey&send 10,655.0 10,655.0 16:30 17:00 commands to Power Drive to steer down aggressively. Page 17/24 Report Printed: 12/21/2015 iii •perations Summary (with Timelog'ffepths) 2S-08 Conoao`Phillips Abo a Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) r End Depth(ftKB) 11/20/2015 11/20/2015 1.00 PROD1 DRILL DDRL P Directional drill f/10655'MD to 10751' 10,655.0 10,751.0 17:00 18:00 MD,6255'TVD,ADT.79,Bit hrs 33.53,JARS 103.23,PU 150K,SO 66K,ROT 105K,Tq on 12-13K,off 8- 9K,ECD 12.35,FO 29%,WOB 15- 17K, 140 rpm,250 gpm,2750 psi, Max gas 2019.Total footage 96'MD. SPR's @ 10747'MD,6254'TVD,MW 10.8 ppg, 18:00 hrs #1 @ 20=650;@ 30=880 psi #2 @ 20=635;@ 30=930 psi 11/20/2015 11/21/2015 6.00 PROD1 DRILL DDRL P Directional drill f/10751'MD to 11272' 10,751.0 11,272.0 18:00 00:00 MD,6282'TVD,ADT 3.96,Bit hrs 37.49,JARS 107.98,PU 154K,SO 67K,ROT 105K,Tq on 13-14K,off 8- 9K,ECD 12.40,FO 29%,WOB 12- 14K, 140 rpm,250 gpm,2850 psi, Max gas 1618.Total footage 521'MD. OA Pressure 390 psi @ 24:00 hrs. Kick w/Drilling CRT 97 sec @ 23:45 hrs. 11/21/2015 11/21/2015 6.00 PROD1 DRILL DDRL P Directional drill f/11272'MD to 11786' 11,272.0 11,786.0 00:00 06:00 MD,6279'TVD,ADT 3.92,Bit hrs 41.41,JARS 111.90,PU 153K,SO 62K,ROT 105K,Tq on 12-13K,off 10K,ECD 12.42,FO 24%,WOB 12- 14K, 140 rpm,250 gpm,2880 psi, Max gas 1209.Total footage 514'MD. SPR's @ 11411'MD,6286'TVD,MW 10.8+ppg,01:10 hrs #1 @ 20=650;@ 30=900 psi #2 @ 20=600;@ 30=920 psi 11/21/2015 11/21/2015 6.00 PROD1 DRILL DDRL P Directional drill f/11786'MD to 12358' 11,786.0 12,358.0 06:00 12:00 MD,6278'TVD,ADT 4.54,Bit hrs 45.95,JARS 116.44,PU 156K,SO 57K,ROT 106K,Tq on 11-13K,off 11K,ECD 12.46,FO 24%,WOB 11- 13K, 140 rpm,250 gpm,2900 psi, Max gas 2566.Total footage 572'MD. Spill Drill CRT 105 sec @ 11:00 hrs. SPR's @ 11979'MD,6279'TVD,MW 10.8+ppg,07:45 hrs #1 @ 20=680;@ 30=940 psi #2 @ 20=680;@ 30=960 psi OA Pressure 390 psi @ 12:00 hrs. 11/21/2015 11/21/2015 6.00 PROD1 DRILL DDRL P Directional drill f/12358'MD to 13021' 12,358.0 13,021.0 12:00 18:00 MD,6282'TVD,ADT 4.41,Bit hrs 50.32,JARS 120.81,PU 165K,SO 57K,ROT 102K,Tq on 15K,off 8-10K, ECD 12.63,FO 24%,WOB 12-15K, 140 rpm,250 gpm,3050 psi,Max gas 2083.Total footage 572'MD. Spill Drill CRT 105 sec @ 11:00 hrs. SPR's @ 12545'MD,6280'TVD,MW 10.8 ppg, 13:45 hrs #1 @ 20=660;@ 30=980 psi #2 @ 20=680;@ 30=1000 psi Page 18/24 Report Printed: 12/21/2015 V operations Summary (with Timelog epths) ;:g 0 2S-08 Conocoitillips ARzk, Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time ':.End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/21/2015 11/22/2015 6.00 PROD1 DRILL DDRL P Directional drill f/13021'MD to 13586' 13,021.0 13,586.0 18:00 00:00 MD,6288'TVD,ADT 3.92,Bit hrs 54.24,JARS 124.73,PU 175K,SO 45K,ROT 103K,Tq on 15K,off 10- 11K,ECD 12.65,FO 24%,WOB 12- 13K, 140 rpm,250 gpm,3100 psi, Max gas 1754.Total footage 565'MD. SPR's @ 13396'MD,6287'TVD,MW 10.8 ppg,21:45 hrs #1 @ 20=700;@ 30=1000 psi #2 @ 20=700;@ 30=1050 psi OA Pressure 390 psi at 24:00 hrs. 11/22/2015 11/22/2015 2.00 PROD1 DRILL DDRL P Directional drill f/13586'MD to 13813' 13,586.0 13,813.0 00:00 02:00 MD,6287'TVD,ADT 2,Bit hrs 57.66, JARS 128.15,PU 175K,SO 35K, ROT 103K,Tq on 15K,off 12K,ECD 12.64,FO 30%,WOB 11-16K, 140 rpm,250 gpm,3130 psi,Max gas 2406.Total footage 227'MD. 11/22/2015 11/22/2015 5.50 PROD1 DRILL DDRL X Directional drill f/13813'MD to 14250' 13,813.0 14,250.0 02:00 07:30 MD,6295'TVD,ADT 3.42,Bit hrs 59.66,JARS 130.15,PU 175K,SO 35K,ROT 103K,Tq on 15K,off 12K, ECD 12.64,FO 30%,WOB 11-16K, 140 rpm,250 gpm,3130 psi,Max gas 2406.Total footage 437'MD. SPR's @ 13966'MD,6288'TVD,MW 10.8 ppg,03:45 hrs #1 @ 20=700;@ 30=1050 psi #2 @ 20=700;@ 30=1075 psi 11/22/2015 11/22/2015 1.75 PROD1 DRILL CIRC X CBU to ensure clean hole before 14,250.0 14,250.0 07:30 09:15 drilling suspected fault @ 250 gpm, 3120 psi, 120 rpm,Tq 12K. 11/22/2015 11/22/2015 1.75 PROD1 DRILL DDRL X Directional drill f/14250'MD to 14345' 14,250.0 14,345.0 09:15 11:00 MD,6298'TVD,ADT 1.13,Bit hrs 60.79,JARS 131.28,PU 176K,SO 35K,ROT 107K,Tq on 13-15K,off 12K,ECD 12.60,FO 30%,WOB 9- 14K, 140 rpm,250 gpm,3130 psi, Max gas 1334.Total footage 95'MD. TD at 14345'MD,6298'TVD.Drill into Kalubik shales due to down throw fault. 11/22/2015 11/22/2015 2.00 PROD1 CASING CIRC P 'CBU @ 250 gpm,3080 psi, 120 rpm, 14,345.0 14,345.0 11:00 13:00 Tq 12K. SPR's @ 14345'MD,6298'TVD,MW 10.8 ppg, 13:00 hrs #1 @ 20=650;@ 30=1000 psi #2@20=700;@30=1010 psi OA Pressure 425 psi @ 12:00 hrs. 11/22/2015 11/22/2015 0.25 PROD1 CASING OWFF P Perform draw down test to establish 14,345.0 14,345.0 13:00 13:15 kill weight mud. Decrease pressure 4 times observeing increase to 340 each time.Establish pore pressure @ 11.9 ppg, 10 rpm, 10K tq. Page 19/24 Report Printed: 12/21/2015 0'" tut:..., :.-l':-'i, operations Summary (with Timelogl pths) ►a ►ti i` 2S-08 LoniocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 11/22/2015 11/22/2015 7.50 PROD1 CASING BKRM P PJSM;BROOH f/14345'-11480'MD 14,345.0 11,480.0 13:15 20:45 @ 250 gpm,3100 psi, 140 rpm,Tq 10K,FO 30%. 11/22/2015 11/22/2015 0.75 PROD1 CASING MPDA T PJSM;change out RCD bearing due 11,480.0 11,480.0 20:45 21:30 to element failure. 11/22/2015 11/23/2015 2.50 PROD1 CASING BKRM P PJSM;BROOH f/11480'-10472'MD 11,480.0 10,472.0 21:30 00:00 @ 250 gpm,2650 psi, 140 rpm,Tq 10K,FO 30%,PU 154K,SO 70K, ROT 105K.Calculated fill 21.6,actual 25.68 bbls. OA Pressure 330 psi @ 24:00 hrs. 11/23/2015 11/23/2015 7.50 PROD1 CASING BKRM P PJSM;BROOH f/10472'-7726'MD @ 10,472.0 7,726.0 00:00 07:30 250 gpm,2470 psi,140 rpm,Tq 7K, FO 30%, PU 154K,SO 70K,ROT 105K.Calculated fill 37.8,actual 41.88 bbls. 11/23/2015 11/23/2015 2.75 PROD1 CASING CIRC P CBU 3X f/7726'-7631'MD @ 250 7,726.0 7,631.0 07:30 10:15 gpm,2430 psi, 140 rpm,Tq 6K,FO 31%,racking back 1 stand. 11/23/2015 11/23/2015 5.25 PROD1 CASING BKRM P PJSM;BROOH f/7631'-7141'MD @ 7,631.0 7,141.0 10:15 15:30 2.5 bpm,900 psi,20 rpm,Tq 5-10K, FO 30%, 100 fph,250-350 psi back pressure. OA Pressure 290 psi @ 12:00 hrs. Table Top Man Down Drill Held @ PTSM 11/23/2015 11/23/2015 5.25 PROD1 CASING CIRC P Circulate&condition mud @ 250 gpm, 7,141.0 7,141.0 15:30 20:45 2400 psi,120 rpm,Tq 5-6K. 11/23/2015 11/23/2015 1.00 PROD1 CASING PMPO P PJSM;spot 12.2 ppg viscous KW 7,141.0 6,641.0 20:45 21:45 brine f/7141'-6641'MD, 1 bpm,200 psi, 1110 fph,60 rpm,Tq 4-5K. 11/23/2015 11/23/2015 1.25 PROD1 CASING DISP P Displace casing to 12.1 ppg KW brine, 6,641.0 6,641.0 21:45 23:00 250 gpm,2400 psi, 120 rpm,Tq 5-6K, FO 54%. 11/23/2015 11/24/2015 1.00 PROD1 CASING CIRC P Circulate to weight up system f/12.1 6,641.0 6,641.0 23:00 00:00 ppg to 12.2+ppg,250 gpm,2400 psi, 120 rpm,Tq 5-6K,FO 54%. OA Pressure 220 psi @ 24:00 hrs. 11/24/2015 11/24/2015 0.50 PROD1 CASING CIRC P Circulate to weight up system f/12.1 6,641.0 6,641.0 00:00 00:30 ppg to 12.2+ppg,250 gpm,2400 psi, 120 rpm,Tq 5-6K,FO 54% 11/24/2015 11/24/2015 0.50 PROD1 CASING OWFF P Monitor well.Static. 6,641.0 6,641.0 00:30 01:00 11/24/2015 11/24/2015 1.50 PROD1 CASING MPDA P Pull RCD bearing assy. Install trip 6,641.0 6,687.0 01:00 02:30 nipple.Blow down MPD choke skid and disconnect MPD lines 11/24/2015 11/24/2015 4.25 PROD1 CASING TRIP P Drop 2"OD rabbit.POOH on elevators 6,687.0 448.0 02:30 06:45 f/6687'MD t/448'MD. Calc disp=35.6 bbls Act disp=45.7 bbls. 11/24/2015 11/24/2015 0.50 PROD1 CASING OWFF P Monitor well.Static.Sim-ops/PJSM on 448.0 448.0 06:45 07:15 laying down BHA and removing nuclear sources. 11/24/2015 11/24/2015 0.25 PROD1 CASING BHAH P Bring source shield and 3 1/2" 448.0 448.0 07:15 07:30 elevators to rig floor. 11/24/2015 11/24/2015 1.00 PROD1 CASING BHAH P Stand back two stands HWDP and 448.0 157.0 07:30 08:30 jars.Lay down DC's and subs. 11/24/2015 11/24/2015 0.50 PROD1 CASING BHAH P Pull nuclear sources.Remove source 157.0 157.0 08:30 09:00 shield from rig floor. Page 20/24 Report Printed: 12/21/2015 operations Summary (with Timelogepths) 0 ►�t 2S-08 LonotoPhitlaps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation - (ftKB) End Depth(5KB) 11/24/2015 11/24/2015 1.25 PROD1 CASING BHAH P Change out elevator to 3 1/2".Lay 157.0 0.0 09:00 10:15 down BHA#4.Break off bit. Calc disp=40.9 bbls Act disp=68.8 bbls for TOH. 11/24/2015 11/24/2015 1.25 PROD1 CASING BHAH P Clear rig floor 0.0 0.0 10:15 11:30 11/24/2015 11/24/2015 0.75 COMPZN CASING WWWH P Make up stack washing tool.Flush 0.0 0.0 11:30 12:15 BOPE. 11/24/2015 11/24/2015 7.25 COMPZN CASING PUTB P Ran 4 1/2"11.6#L-80 IMT-M slotted 0.0 7,254.0 12:15 19:30 &blank liner as follows:Ray Oil Tools silver bullett shoe- 3 jts blank-94 jts slotted-3 jts.blank-33 jts slotted-3 jts.blank-26 jts slotted-Swell packer -11 jts blank-All jts 4 1/2"liner have torque rings installed-Run 6.13" Hydroform centralizers on every third jt(58 total) 4 1/2" 11.6#IBTM-0 rejects/0 remakes 11/24/2015 11/24/2015 1.25 COMPZN CASING OTHR P Confirm proper lift sub in SBE.MU 7,254.0 7,319.0 19:30 20:45 SBE.PU liner hanger assembly-MU stinger&pack-off to btm of hanger assembly -MU liner hanger assembly w/ZXP packer to seal bore extenstion. Mix &Spot Pal mix in liner hanger sleeve 11/24/2015 11/24/2015 0.50 COMPZN CASING CIRC P PU one stand of DP.Break circ and 7,319.0 7,410.0 20:45 21:15 obtain torque and drag parameters.3 bpm, 120 psi,PU 104K,SO 82K,Rot 93K 15 rpm,3K tq 11/24/2015 11/25/2015 2.75 COMPZN CASING RUNL P RIH w/4 1/2", 11.6#L-80 liner on 7,410.0 10,063.0 21:15 00:00 drillpipe f/7410'MD to 10,063'MD. Work through tight hole f/9150'MD t/9795'MD.PU 120K,SO 75K,Rot 92K. Calc disp=43.75 bbls Act disp=17.51 bbls OA=210 psi 11/25/2015 11/25/2015 7.75 COMPZN CASING RUNL P RIH w/4 1/2", 11.6#L-80 liner on 10,063.0 14,275.0 00:00 07:45 drillpipe f/10,063'MD to 13,937'MD. Work through tight hole at 10,267'MD and 10,656'MD.RIH f/13,937'MD to 14,275'MD while pumping @ 1 bpm, 80 psi.PU 155K,SO 80K. Calc disp=67.5 bbls Act disp=38.9 bbls 11/25/2015 11/25/2015 0.75 COMPZN CASING CIRC P Circ DP volume. 1 bpm,80 psi 14,275.0 14,275.0 07:45 08:30 11/25/2015 11/25/2015 0.50 COMPZN CASING RURD P Blow down TD. Drop 1.25'OD 14,275.0 14,275.0 08:30 09:00 phenolic setting ball.Rig up circ lines on circ sub. Page 21/24 Report Printed: 12/21/2015 operations Summary (with TimelogSepths) 0; 2S-08 cor�ocoPhillip�s Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code '. Time P-T X Operation (EKE) End Depth(ftKB) 11/25/2015 11/25/2015 1.75 COMPZN CASING PACK P Pump ball on seat 2 bpm, 150 psi. 14,275.0 14,275.0 09:00 10:45 Seat ball w/263 stks -Pressure up to 1700 to set liner hanger- slack off wt to confirm hanger is set OK-Pressure up to 4000 psi to set ZXP liner top packer &release running tool-Test ZXP liner top packer to 3000 psi for 5 mins-bleed off pressure-pressure up to 400 psi-Pull up slowly to pull setting tool f/liner-observed pressure drop-running tool free f/liner-Break circ Liner top @ 6956'MD Shoe @ 14,275'MD 11/25/2015 11/25/2015 2.25 COMPZN WELLPR CIRC P LD single of DP.CBU 2x.4 bpm.340 14,275.0 6,956.0 10:45 13:00 psi. 11/25/2015 11/25/2015 0.50 COMPZN WELLPR OWFF P Blow down TD. Monitor well.Static. 6,956.0 6,956.0 13:00 13:30 11/25/2015 11/25/2015 0.50 COMPZN WELLPR CRIH P Pump and spot 21 bbls 12.2 ppg 6,956.0 6,956.0 13:30 14:00 inhibited brine f/6956'MD to 6450'MD leaving 5 bbls in DP. 11/25/2015 11/25/2015 1.00 COMPZN WELLPR TRIP P POOH on elevators f/6956'MD to 6,956.0 6,429.0 14:00 15:00 6429'MD 11/25/2015 11/25/2015 1.25 COMPZN WELLPR CIRC P CBU to balance brine in well.275 6,429.0 6,429.0 15:00 16:15 gpm,700 psi.Weight up to 12.3 ppg. 11/25/2015 11/25/2015 0.50 COMPZN WELLPR OWFF P Monitor well. 1 bph static loss rate. 6,429.0 6,429.0 16:15 16:45 11/25/2015 11/25/2015 3.25 COMPZN WELLPR TRIP P POOH on elevators f/6429'MD to 89' 6,429.0 89.0 16:45 20:00 MD. 11/25/2015 11/25/2015 0.50 COMPZN WELLPR BHAH P Lay down running tool as per Baker 89.0 0.0 20:00 20:30 rep. 11/25/2015 11/25/2015 0.25 COMPZN WELLPR BHAH P Clean and clear rig floor. 0.0 0.0 20:30 20:45 11/25/2015 11/25/2015 1.00 COMPZN RPCOMP WWWH P Pull wear bushing.Make up stack 0.0 0.0 20:45 21:45 washing tool.Flush BOPE.Lay down stack washing tool. 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP RURD P Rig up to run upper completion 0.0 0.0 21:45 22:15 11/25/2015 11/25/2015 0.25 COMPZN RPCOMP PUTB P PJSM;RIH w/9.3#,L-80,3-1/2"EUE 0.0 140.0 22:15 22:30 tubing as per detail from surface to 140'MD. 11/25/2015 11/25/2015 0.25 COMPZN RPCOMP PRTS P Pressure test Mirage plug to 1000 140.0 140.0 22:30 22:45 psi/5 min charted. 11/25/2015 11/26/2015 1.25 COMPZN RPCOMP PUTB P PJSM;continue RIH w/9.3#,L-80,3- 140.0 1,270.0 22:45 00:00 1/2"EUE tubing as per detail from 140'MD to 1270'MD. Calc disp=3.28 bbls Act disp=2.3 bbls OA=200 psi Kick w/tripping drill.CRT=95 sec 11/26/2015 11/26/2015 0.75 COMPZN RPCOMP PRTS P Rig up and test SOOV to 1000 psi/5 1,270.0 1,270.0 00:00 00:45 min charted 11/26/2015 11/26/2015 6.00 COMPZN RPCOMP PUTB P Continue RIH w/9.3#,L-80,3-1/2" 1,270.0 5,022.0 00:45 06:45 EUE tubing as per detail from 1270' MD to 5022'MD. 11/26/2015 11/26/2015 0.50 COMPZN RPCOMP PRTS P Rig up and test tbg to 3000 psi/5 min 5,022.0 5,022.0 06:45 07:15 charted. Page 22/24 Report Printed: 12/21/2015 ii •perations Summary (with Timeloglepths) Oro o 2S-08 Conti iIIips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB). 11/26/2015 11/26/2015 3.00 COMPZN RPCOMP PUTB P Continue RIH w/9.3#,L-80,3-1/2" 5,022.0 7,005.0 07:15 10:15 EUE tubing as per detail from 5022' MD to 7011'MD. Calc disp=23.6 bbls Act disp=10.8 bbls for trip 11/26/2015 11/26/2015 0.50 COMPZN RPCOMP RURD P Install head pin.Rig up to test tbg and 7,005.0 7,005.0 10:15 10:45 IA. 11/26/2015 11/26/2015 0.50 COMPZN RPCOMP HOSO P Pick up to expose seals.Sting in and 7,005.0 7,017.0 10:45 11:15 tag locator. 11/26/2015 11/26/2015 1.50 COMPZN RPCOMP PRTS P Test tbg to 3500 psi/5 min.Bleed tbg 7,017.0 7,017.0 11:15 12:45 down to 2000 psi.Test annulus to 3500 psi/30 min. 11/26/2015 11/26/2015 1.25 COMPZN RPCOMP HOSO P Lay down 3 jts.tbg.Pick up x-o, 1 jt of 7,017.0 6,984.0 12:45 14:00 4 1/2"IBTM tbg.MU hanger with tested BPV installed.MU landing jt. 11/26/2015 11/26/2015 3.25 COMPZN RPCOMP THGR T RIH to land hanger.Set down string 6,984.0 7,013.0 14:00 17:15 wt.Hanger did not fully seat.PU and flush BOPE from rig floor and through annulus.Land hanger.Not fully seated.Pull hanger to rig floor and inspect.No visible problems.Land hanger. Not fully seated.Set down 5k top drive weight.Hanger seated.PU 85K SO 67K. 3 1/2" 9.3#EUE 8rdM L-80-1 reject/0 remakes 11/26/2015 11/26/2015 0.75 COMPZN RPCOMP THGR P RILDS.Test hanger seals to 5000 7,013.0 7,013.0 17:15 18:00 psi/15 min.Witnessed by Co.Man 11/26/2015 11/26/2015 1.00 COMPZN RPCOMP RURD P Lay down landing jt.Blow down lines. 7,013.0 0.0 18:00 19:00 Wash and drain BOPE. 11/26/2015 11/26/2015 1.75 COMPZN WHDBOP NUND P Remove MPD lines.Pull trip 0.0 0.0 19:00 20:45 nipple.Nipple down BOPE. 11/26/2015 11/26/2015 1.75 COMPZN WHDBOP NUND P Dress tubing head.Install adapter 0.0 0.0 20:45 22:30 flange.Test SRL seal to 250/5000 psi for 10 min each.Witnessed by Co. Man 11/26/2015 11/26/2015 1.25 COMPZN WHDBOP PRTS P Test tubing head adapter flange to 0.0 0.0 22:30 23:45 250/5000 psi for 10 min each.Witnessed by Co. Man 11/26/2015 11/27/2015 0.25 COMPZN WHDBOP NUND P Pick up tree and dress ring groove. 0.0 0.0 23:45 00:00 11/27/2015 11/27/2015 1.00 COMPZN WHDBOP NUND P Orient and NU tree. 0.0 0.0 00:00 01:00 11/27/2015 11/27/2015 0.75 COMPZN WHDBOP PRTS P Rig up test equip and circ lines. 0.0 0.0 01:00 01:45 11/27/2015 11/27/2015 1.50 COMPZN WHDBOP PRTS P Test tree to 250/5000 psi for 15 min 0.0 0.0 01:45 03:15 each.Charted.Rig down test equip. 11/27/2015 11/27/2015 1.00 COMPZN WHDBOP PRTS P Rig up scaffold around tree. 0.0 0.0 03:15 04:15 11/27/2015 11/27/2015 0.75 COMPZN WHDBOP MPSP P Unseat poppet on BPV.Well static. 0.0 0.0 04:15 05:00 Dry rod out BPV. 11/27/2015 11/27/2015 1.75 COMPZN WHDBOP PRTS P Test lines to 4500 psi.Test tbg to 0.0 0.0 05:00 06:45 3500 psi/30 min.Charted.Bleed tbg pressure to 2000 psi and hold.Test IA to 3500 psi/30 min.Charted. Bleed tbg pressure to 0 psi and shear SOOV. Pressure tbg to 4300 psi and shear Mirage plug.Sim-ops/Load pipe shed w/114 jts 5"DP and 17 jts 5"HWDP. Page 23/24 Report Printed: 12/21/2015 :: -,,kY.,„41,:,,:,::,',,r... ., operations Summary (with Timelogitpths) 0 ... , .,. 2S-08 ConocoPhi111ps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log r' Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/27/2015 11/27/2015 1.50 COMPZN WHDBOP CIRC P Bleed tbg pressure to 0 psi and shear 0.0 0.0 06:45 08:15 SOOV.Pressure tbg to 4300 psi and shear Mirage plug.Bull head 10 bbls 12.3 ppg brine down tbg to clear Mirage plug of debris. 1 bpm/540 psi. Sim-ops/Load pipe shed w/114 jts 5" DP and 17 jts 5"HWDP. 11/27/2015 11/27/2015 1.75 COMPZN WHDBOP FRZP P RU choke hose and LRS to freeze 0.0 0.0 08:15 10:00 protect through choke manifold.Test lines to 2500 psi. 11/27/2015 11/27/2015 5.00 COMPZN WHDBOP FRZP P Freeze protect well w/260 bbls diesel 0.0 0.0 10:00 15:00 @ 1 bpm,ICP 125 psi,FCP 2000 psi. Blow&rig down lines.SIMOPS/Rig up to lay down DP. Lay down 36 jts of 4"DP via mousehole. 11/27/2015 11/27/2015 1.25 COMPZN WHDBOP MPSP P Rig up lubricator and test to 1500.Set 0.0 0.0 15:00 16:15 BPV.Rig down lubricator. 11/27/2015 11/27/2015 2.50 DEMOB MOVE RURD P Rig down cellar scaffold,secure tree. 0.0 0.0 16:15 18:45 Clean and prep cellar for rig move. 11/27/2015 11/27/2015 0.75 DEMOB MOVE SVRG P Service rig. Inspect top drive, 0.0 0.0 18:45 19:30 draworks,iron roughneck and pipe skate 11/27/2015 11/27/2015 0.25 DEMOB MOVE SFTY P PJSM on laying down DP via 0.0 0.0 19:30 19:45 mousehole. 11/27/2015 11/28/2015 4.25 DEMOB MOVE PULD P Lay down 159 jts of 4"DP via 0.0 0.0 19:45 00:00 mousehole. Tbg=750 psi IA=400 psi OA=320 psi 11/28/2015 11/28/2015 0.75 DEMOB MOVE PULD P Continue to lay down 4"DP from 0.0 0.0 00:00 00:45 derrick inot pipeshed,via mouse hole. 11/28/2015 11/28/2015 0.50 DEMOB MOVE RURD P Clean rig floor,suck out cellar,empty 0.0 0.0 00:45 01:15 out pipeshed. 11/28/2015 11/28/2015 6.00 DEMOB MOVE PULD P Continue to lay down drill pipe. 0.0 0.0 01:15 07:15 11/28/2015 11/28/2015 0.50 DEMOB MOVE RURD P Empty pipeshed of 4"DP. 0.0 0.0 07:15 07:45 11/28/2015 11/28/2015 0.75 DEMOB MOVE PULD P Complete the task of laying down all 0.0 0.0 07:45 08:30 4"XT 39 drill pipe from derrick into pipeshed via mousehole. 11/28/2015 11/28/2015 3.50 DEMOB MOVE RURD P Clear rig floor of all 4"tools,clean rig 0.0 0.0 08:30 12:00 floor,remove the 4"DP from shed. Secure the 114 joints of 5"DP and all tools in the pipshed.Secure well.Blow down all rig water and steam lines. prep for rig move. Final OA=210, IA=0,Tubing has BPV installed.H type. Release rig @ 12:00 hrs 11/28/15 Page 24/24 Report Printed: 12/21/2015 • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-08 Definitive Survey Report 24 November, 2015 Schlumberger • Definitive Survey Report Company: NADConversion Local CO-ordinate Reference: Well 2S-08 Pry Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) S Kuparuk 2S Pad MD:Reference: ,, 27.5+120 @ 147.50usft(Doyon141) Welt: 2S-08 North Reference: True Wekbbof „ ': 2S-08 Survey Calculation Method: Minimum Curvature Design 2S-08 Database: OAKEDMP2 Project Kuparuk River Unit,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 2S-08 Well Position +N/-S 0.00 usft Northing: 5,929,992.42 usfl Latitude: 70°13'11.622 N +El-W 0.00 usft Easting: 481,103.50 usfl Longitude: 150°9'8.804 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wettbete 2S-08 �... �netics Mq $ ne Seto ,,---- " •%;•.___,,,..,,,,L, 1 13 A e Field Strength ,i l (iffy BGGM2015 11/25/2015 18.47 80.87 57,487 Design 2S-08 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 V ckton Depth From(TVD) +N/-S +E/-W Direction on ( StO ( f (0)...: ;., iH ar,;. 27.50 0.00 0.00 245.00 Survey ProgramEfate' From Td �. +�y , .; ,; (usft) (uaft) Su ;(Wellbore) Tool Name Description Survey Date 71.00 438.00 2S-08 Srvy#1 -Gyro Battery(2S-08) GYD-GC-MS Gyrodata gyrocompassing m/s 11/10/2015 2:: 485.04 2,594.28 2S-08 Srvy#2-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 2:: 2,695.86 7,076.67 2S-08 Srvy#3-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/20/2015 9: 7,171.07 7,171.07 2S-08 Srvy#4-INC ONLY(2S-08) INC+TREND Inclinometer+known azi trend 11/20/2015 9: 7,264.20 14,265.49 2S-08 Srvy#5-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/20/2015 9:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (n) (ft) (°1100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,992.42 481,103.50 0.00 0.00 UNDEFINED 71.00 0.46 33.48 71.00 -76.50 0.15 0.10 5,929,992.57 481,103.60 1.06 -0.15 GYD-GC-MS(1) 107.50 0.54 31.92 107.50 -40.00 0.41 0.27 5,929,992.83 481,103.77 0.21 -0.42 GYD-GC-MS(1) 16"x 20" 162.00 0.65 30.28 162.00 14.50 0.90 0.56 5,929,993.31 481,104.06 0.21 -0.88 GYD-GC-MS(1) 254.00 0.76 14.86 253.99 106.49 1.94 0.98 5,929,994.35 481,104.48 0.24 -1.70 GYD-GC-MS(1) 345.00 2.07 325.41 344.96 197.46 3.87 0.20 5,929,996.29 481,103.71 1.84 -1.82 GYD-GC-MS(1) 438.00 4.21 322.93 437.82 290.32 7.98 -2.81 5,930,000.41 481,100.71 2.31 -0.82 GYD-GC-MS(1) 485.04 4.78 322.64 484.71 337.21 10.92 -5.04 5,930,003.35 481,098.49 1.21 -0.04 MWD+IFR-AK-CAZ-SC(2) 578.31 5.65 324.07 577.59 430.09 17.72 -10.09 5,930,010.17 481,093.45 0.94 1.66 MWD+IFR-AK-CAZ-SC(2) 670.23 8.20 323.54 668.84 521.34 26.66 -16.65 5,930,019.12 481,086.92 2.77 3.82 MWD+IFR-AK-CAZ-SC(2) 11/24/2015 5:04:07PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 plojeot; Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site; Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbo ' -----,2S-08 Survey Calculation Method: Minimum Curvature Design; 2S-08 Database: OAKEDMP2 Survey Map Map 'VOoal MD Inc Azi TVD NDSB +NI-S +Ei W Northing Ming DLS Section (usft) (°) (°} (c ft} it) (usft) (ft) {ft} ('1100') (ft) Survey Tool Name 764.53 8.68 325.12 762.11 614.61 37.91 -24.71 5,930,030.38 481,078.89 0.57 6.38 MWD+IFR-AK-CAZ-SC(2) 856.01 9.57 324.53 852.44 704.94 49.76 -33.07 5,930,042.26 481,070.56 0.98 8.94 MWD+IFR-AK-CAZ-SC(2) 950.06 10.01 323.99 945.12 797.62 62.74 -42.41 5,930,055.26 481,061.25 0.48 11.93 MWD+IFR-AK-CAZ-SC(2) 1,043.14 10.28 324.34 1,036.74 889.24 76.03 -52.01 5,930,068.58 481,051.68 0.30 15.01 MWD+IFR-AK-CAZ-SC(2) 1,135.08 11.86 325.26 1,126.97 979.47 90.46 -62.18 5,930,083.03 481,041.55 1.73 18.12 MWD+IFR-AK-CAZ-SC(2) 1,228.47 13.52 328.24 1,218.07 1,070.57 107.63 -73.40 5,930,100.23 481,030.38 1.91 21.03 MWD+IFR-AK-CAZ-SC(2) 1,323.98 15.95 331.65 1,310.44 1,162.94 128.68 -85.51 5,930,121.30 481,018.33 2.70 23.11 MWD+IFR-AK-CAZ-SC(2) 1,417.11 17.17 332.45 1,399.70 1,252.20 152.13 -97.94 5,930,144.78 481,005.95 1.33 24.47 MWD+IFR-AK-CAZ-SC(2) 1,511.55 17.61 325.67 1,489.84 1,342.34 176.29 -112.45 5,930,168.97 480,991.51 2.19 27.41 MWD+IFR-AK-CAZ-SC(2) 1,602.63 18.20 316.23 1,576.52 1,429.02 197.94 -130.06 5,930,190.67 480,973.95 3.25 34.22 MWD+IFR-AK-CAZ-SC(2) 1,695.32 18.09 305.09 1,664.63 1,517.13 216.67 -151.85 5,930,209.45 480,952.20 3.74 46.06 MWD+IFR-AK-CAZ-SC(2) 1,788.92 18.02 292.46 1,753.66 1,606.16 230.56 -177.13 5,930,223.40 480,926.96 4.18 63.10 MWD+IFR-AK-CAZ-SC(2) 1,884.31 19.14 280.43 1,844.11 1,696.61 239.03 -206.16 5,930,231.94 480,897.96 4.18 85.83 MWD+IFR-AK-CAZ-SC(2) 1,978.23 19.25 272.13 1,932.82 1,785.32 242.40 -236.78 5,930,235.38 480,867.35 2.91 112.16 MWD+IFR-AK-CAZ-SC(2) 2,070.63 20.17 262.48 2,019.83 1,872.33 240.88 -267.80 5,930,233.94 480,836.33 3.66 140.91 MWD+IFR-AK-CAZ-SC(2) 2,162.32 22.27 260.67 2,105.30 1,957.80 235.99 -300.62 5,930,229.14 480,803.50 2.40 172.72 MWD+IFR-AK-CAZ-SC(2) 2,259.27 22.94 262.76 2,194.80 2,047.30 230.63 -337.50 5,930,223.87 480,766.62 1.08 208.41 MWD+IFR-AK-CAZ-SC(2) 2,352.62 24.51 259.54 2,280.26 2,132.76 224.82 -374.59 5,930,218.16 480,729.51 2.18 244.48 MWD+IFR-AK-CAZ-SC(2) 2,447.67 26.48 258.12 2,366.06 2,218.56 216.88 -414.72 5,930,210.32 480,689.37 2.17 284.20 MWD+IFR-AK-CAZ-SC(2) 2,541.77 27.44 258.59 2,449.93 2,302.43 208.27 -456.50 5,930,201.81 480,647.57 1.05 325.71 MWD+IFR-AK-CAZ-SC(2) 2,594.28 27.79 258.91 2,496.46 2,348.96 203.52 -480.37 5,930,197.13 480,623.68 0.72 349.35 MWD+IFR-AK-CAZ-SC(2) 2,652.40 29.37 259.35 2,547.49 2,399.99 198.28 -507.68 5,930,191.95 480,596.37 2.75 376.32 MWD+IFR-AK-CAZ-SC(3) 10 314"x 13-112 2,695.86 30.56 259.66 2,585.14 2,437.64 194.33 -529.03 5,930,188.06 480,575.01 2.75 397.33 MWD+IFR-AK-CAZ-SC(3) 2,786.86 32.76 258.18 2,662.59 2,515.09 185.14 -575.89 5,930,178.98 480,528.13 2.56 443.69 MWD+IFR-AK-CAZ-SC(3) 2,879.96 30.48 257.80 2,741.87 2,594.37 174.98 -623.63 5,930,168.95 480,480.37 2.46 491.25 MWD+IFR-AK-CAZ-SC(3) 2,972.44 27.48 257.54 2,822.76 2,675.26 165.42 -667.40 5,930,159.50 480,436.58 3.25 534.96 MWD+IFR-AK-CAZ-SC(3) 3,065.25 28.31 258.80 2,904.79 2,757.29 156.53 -709.90 5,930,150.71 480,394.07 1.10 577.23 MWD+IFR-AK-CAZ-SC(3) 3,157.07 28.09 259.93 2,985.71 2,838.21 148.52 -752.54 5,930,142.81 480,351.41 0.63 619.27 MWD+IFR-AK-CAZ-SC(3) 3,250.49 28.00 263.93 3,068.17 2,920.67 142.35 -796.00 5,930,136.75 480,307.93 2.02 661.26 MWD+IFR-AK-CAZ-SC(3) 3,343.12 28.02 265.80 3,149.95 3,002.45 138.46 -839.33 5,930,132.97 480,264.61 0.95 702.17 MWD+IFR-AK-CAZ-SC(3) 3,435.53 28.05 263.93 3,231.51 3,084.01 134.57 -882.58 5,930,129.19 480,221.35 0.95 743.02 MWD+IFR-AK-CAZ-SC(3) 3,529.67 27.82 260.81 3,314.69 3,167.19 128.72 -926.28 5,930,123.45 480,177.64 1.57 785.09 MWD+IFR-AK-CAZ-SC(3) 3,622.09 28.30 261.07 3,396.25 3,248.75 121.88 -969.21 5,930,116.71 480,134.69 0.54 826.89 MWD+IFR-AK-CAZ-SC(3) 3,715.67 28.35 261.66 3,478.62 3,331.12 115.21 -1,013.11 5,930,110.16 480,090.79 0.30 869.50 MWD+IFR-AK-CAZ-SC(3) 3,808.04 27.71 258.29 3,560.16 3,412.66 107.67 -1,055.84 5,930,102.72 480,048.04 1.85 911.41 MWD+IFR-AK-CAZ-SC(3) 3,900.41 28.52 257.81 3,641.63 3,494.13 98.66 -1,098.42 5,930,093.82 480,005.44 0.91 953.81 MWD+IFR-AK-CAZ-SC(3) 3,997.15 28.48 257.95 3,726.65 3,579.15 88.97 -1,143.55 5,930,084.24 479,960.29 0.08 998.81 MWD+IFR-AK-CAZ-SC(3) 4,087.22 28.24 257.95 3,805.91 3,658.41 80.03 -1,185.40 5,930,075.41 479,918.43 0.27 1,040.51 MWD+IFR-AK-CAZ-SC(3) 4,181.15 28.43 257.90 3,888.58 3,741.08 70.71 -1,228.99 5,930,066.20 479,874.81 0.20 1,083.96 MWD+IFR-AK-CAZ-SC(3) 11/24/2015 5:04:07PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD R1 rence: 27.5+120 @ 147.50usft(Doyon141) Site;; Kuparuk 2S Pad MD rence: • 27.5+120 @ 147.50usft(Doyon141) Wet 2S-08 North Reference True Wellbore:' " `'2S-08 Survey Calculation Method: Minimum Curvature Design:. ;" '2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD inc .,....,Az Iva "NDSB +NI-S +EI-W Northing Easting DE. '_ Section (usft) (') a t) (usft) (usft) (usft) (ft) (ft) ('1100') {ft) Survey Tool Name 4,273.93 28.59 258.19 3,970.11 3,822.61 61.53 -1,272.32 5,930,057.13 479,831.47 0.23 1,127.10 MWD+IFR-AK-CAZ-SC(3) 4,366.15 28.94 257.35 4,050.95 3,903.45 52.13 -1,315.68 5,930,047.84 479,788.08 0.58 1,170.38 MWD+IFR-AK-CAZ-SC(3) 4,458.53 28.82 257.13 4,131.84 3,984.34 42.28 -1,359.20 5,930,038.10 479,744.55 0.17 1,213.99 MWD+IFR-AK-CAZ-SC(3) 4,551.12 28.17 256.81 4,213.22 4,065.72 32.32 -1,402.24 5,930,028.25 479,701.49 0.72 1,257.20 MWD+IFR-AK-CAZ-SC(3) 4,644.32 27.00 255.71 4,295.82 4,148.32 22.08 -1,444.16 5,930,018.11 479,659.55 1.37 1,299.52 MWD+IFR-AK-CAZ-SC(3) 4,736.62 25.98 256.07 4,378.43 4,230.93 12.04 -1,484.08 5,930,008.17 479,619.60 1.12 1,339.95 MWD+IFR-AK-CAZ-SC(3) 4,831.48 26.72 254.86 4,463.44 4,315.94 1.47 -1,524.84 5,929,997.70 479,578.82 0.96 1,381.35 MWD+IFR-AK-CAZ-SC(3) 4,923.51 27.31 254.67 4,545.42 4,397.92 -9.52 -1,565.17 5,929,986.82 479,538.47 0.65 1,422.55 MWD+IFR-AK-CAZ-SC(3) 5,016.27 27.53 257.09 4,627.76 4,480.26 -19.93 -1,606.59 5,929,976.51 479,497.03 1.22 1,464.49 MWD+IFR-AK-CAZ-SC(3) 5,110.04 28.83 259.55 4,710.42 4,562.92 -28.88 -1,649.95 5,929,967.68 479,453.65 1.86 1,507.56 MWD+IFR-AK-CAZ-SC(3) 5,203.44 29.26 257.58 4,792.08 4,644.58 -37.87 -1,694.39 5,929,958.79 479,409.19 1.12 1,551.64 MWD+IFR-AK-CAZ-SC(3) 5,297.20 29.76 251.77 4,873.69 4,726.19 -50.08 -1,738.88 5,929,946.70 479,364.68 3.10 1,597.12 MWD+IFR-AK-CAZ-SC(3) 5,389.18 29.94 245.35 4,953.49 4,805.99 -66.80 -1,781.43 5,929,930.09 479,322.08 3.48 1,642.76 MWD+IFR-AK-CAZ-SC(3) 5,483.65 30.59 241.10 5,035.09 4,887.59 -88.25 -1,823.91 5,929,908.74 479,279.56 2.37 1,690.32 MWD+IFR-AK-CAZ-SC(3) 5,576.30 30.72 236.71 5,114.80 4,967.30 -112.64 -1,864.33 5,929,884.46 479,239.08 2.42 1,737.26 MWD+IFR-AK-CAZ-SC(3) 5,668.49 32.29 232.28 5,193.41 5,045.91 -140.63 -1,903.50 5,929,856.57 479,199.84 3.03 1,784.59 MWD+IFR-AK-CAZ-SC(3) 5,764.27 34.19 228.05 5,273.53 5,126.03 -174.28 -1,943.76 5,929,823.02 479,159.50 3.13 1,835.30 MWD+IFR-AK-CAZ-SC(3) 5,858.48 35.89 224.36 5,350.67 5,203.17 -211.73 -1,982.76 5,929,785.68 479,120.41 2.88 1,886.47 MWD+IFR-AK-CAZ-SC(3) 5,952.24 37.48 222.66 5,425.86 5,278.36 -252.36 -2,021.31 5,929,745.15 479,081.77 2.01 1,938.58 MWD+IFR-AK-CAZ-SC(3) 6,043.73 38.96 222.19 5,497.73 5,350.23 -294.14 -2,059.49 5,929,703.47 479,043.48 1.65 1,990.84 MWD+IFR-AK-CAZ-SC(3) 6,137.08 42.01 221.81 5,568.73 5,421.23 -339.18 -2,100.04 5,929,658.53 479,002.83 3.28 2,046.62 MWD+IFR-AK-CAZ-SC(3) 6,229.66 44.75 218.94 5,636.01 5,488.51 -387.63 -2,141.18 5,929,610.19 478,961.56 3.65 2,104.39 MWD+IFR-AK-CAZ-SC(3) 6,324.31 46.48 216.13 5,702.22 5,554.72 -441.27 -2,182.37 5,929,556.66 478,920.25 2.80 2,164.39 MWD+IFR-AK-CAZ-SC(3) 6,418.56 47.68 211.67 5,766.42 5,618.92 -498.55 -2,220.82 5,929,499.48 478,881.66 3.69 2,223.44 MWD+IFR-AK-CAZ-SC(3) 6,511.17 48.40 207.59 5,828.36 5,680.86 -558.39 -2,254.84 5,929,439.73 478,847.49 3.37 2,279.57 MWD+IFR-AK-CAZ-SC(3) 6,604.34 50.54 204.01 5,888.91 5,741.41 -622.14 -2,285.62 5,929,376.07 478,816.56 3.71 2,334.40 MWD+IFR-AK-CAZ-SC(3) 6,699.75 52.78 201.13 5,948.10 5,800.60 -691.24 -2,314.31 5,929,307.05 478,787.70 3.33 2,389.60 MWD+IFR-AK-CAZ-SC(3) 6,791.69 55.34 200.44 6,002.06 5,854.56 -760.82 -2,340.71 5,929,237.53 478,761.12 2.85 2,442.95 MWD+IFR-AK-CAZ-SC(3) 6,886.29 57.58 200.90 6,054.32 5,906.82 -834.59 -2,368.55 5,929,163.84 478,733.11 2.40 2,499.35 MWD+IFR-AK-CAZ-SC(3) 6,980.99 61.84 201.22 6,102.08 5,954.58 -910.88 -2,397.93 5,929,087.63 478,703.54 4.51 2,558.22 MWD+IFR-AK-CAZ-SC(3) 7,076.67 66.16 200.97 6,144.01 5,996.51 -991.10 -2,428.87 5,929,007.50 478,672.40 4.52 2,620.16 MWD+IFR-AK-CAZ-SC(3) 7,141.00 68.20 201.59 6,168.96 6,021.46 -1,046.35 -2,450.39 5,928,952.32 478,650.74 3.29 2,663.01 INC+TREND(4) 7.518"x8.718"by 11" 7,171.07 69.15 201.87 6,179.90 6,032.40 -1,072.37 -2,460.76 5,928,926.33 478,640.31 3.29 2,683.41 INC+TREND(4) 7,264.20 70.23 202.96 6,212.22 6,064.72 -1,153.10 -2,494.07 5,928,845.68 478,606.80 1.60 2,747.71 MWD+IFR-AK-CAZ-SC(5) 7,358.82 71.85 200.88 6,242.97 6,095.47 -1,236.11 -2,527.46 5,928,762.76 478,573.20 2.69 2,813.06 MWD+IFR-AK-CAZ-SC(5) 7,410.37 72.94 198.64 6,258.56 6,111.06 -1,282.35 -2,544.07 5,928,716.57 478,556.48 4.65 2,847.66 MWD+IFR-AK-CAZ-SC(5) 7,453.04 74.01 199.40 6,270.70 6,123.20 -1,321.03 -2,557.40 5,928,677.93 478,543.05 3.03 2,876.08 MWD+IFR-AK-CAZ-SC(5) 7,499.36 75.35 198.94 6,282.93 6,135.43 -1,363.22 -2,572.07 5,928,635.78 478,528.28 3.05 2,907.21 MWD+IFR-AK-CAZ-SC(5) 7,547.86 77.33 197.68 6,294.39 6,146.89 -1,407.96 -2,586.87 5,928,591.08 478,513.37 4.80 2,939.53 MWD+IFR-AK-CAZ-SC(5) 11!24/2015 5:04:07PM Page 4 COMPASS 5000.1 Build 74 Schlumberger 111 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey • Map Map VertI, �T`,.n MD Mi TVD 1VDSS +NI-S +E(-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft)', (usft) (usft) (ft) (ft) (°lltln*) (ft)' Survey Tool Name 7,593.84 79.82 196.35 6,303.50 6,156.00 -1,451.05 -2,600.06 5,928,548.02 478,500.08 6.11 2,969.69 MWD+IFR-AK-CAZ-SC(5) 7,642.79 82.68 196.51 6,310.94 6,163.44 -1,497.45 -2,613.74 5,928,501.66 478,486.28 5.85 3,001.70 MWD+IFR-AK-CAZ-SC(5) 7,689.90 84.74 196.51 6,316.10 6,168.60 -1,542.35 -2,627.05 5,928,456.81 478,472.86 4.37 3,032.74 MWD+IFR-AK-CAZ-SC(5) 7,738.63 86.56 195.57 6,319.80 6,172.30 -1,589.04 -2,640.47 5,928,410.15 478,459.32 4.20 3,064.64 MWD+IFR-AK-CAZ-SC(5) 7,785.59 88.35 194.22 6,321.88 6,174.38 -1,634.38 -2,652.53 5,928,364.85 478,447.15 4.77 3,094.73 MWD+IFR-AK-CAZ-SC(5) 7,832.94 89.82 195.36 6,322.64 6,175.14 -1,680.15 -2,664.61 5,928,319.11 478,434.95 3.93 3,125.02 MWD+IFR-AK-CAZ-SC(5) 7,927.35 93.39 193.34 6,320.00 6,172.50 -1,771.56 -2,688.00 5,928,227.77 478,411.34 4.34 3,184.85 MWD+IFR-AK-CAZ-SC(5) 8,022.22 93.63 191.91 6,314.19 6,166.69 -1,863.96 -2,708.70 5,928,135.43 478,390.41 1.53 3,242.66 MWD+IFR-AK-CAZ-SC(5) 8,117.20 90.50 192.13 6,310.77 6,163.27 -1,956.79 -2,728.46 5,928,042.67 478,370.42 3.30 3,299.80 MWD+IFR-AK-CAZ-SC(5) 8,212.14 90.42 189.87 6,310.00 6,162.50 -2,049.97 -2,746.58 5,927,949.53 478,352.07 2.38 3,355.60 MWD+IFR-AK-CAZ-SC(5) 8,307.26 92.16 188.74 6,307.86 6,160.36 -2,143.81 -2,761.95 5,927,855.74 478,336.47 2.18 3,409.19 MWD+IFR-AK-CAZ-SC(5) 8,401.37 90.75 192.70 6,305.47 6,157.97 -2,236.23 -2,779.45 5,927,763.38 478,318.74 4.47 3,464.11 MWD+IFR-AK-CAZ-SC(5) 8,495.84 89.84 191.36 6,304.98 6,157.48 -2,328.62 -2,799.14 5,927,671.05 478,298.82 1.71 3,521.00 MWD+IFR-AK-CAZ-SC(5) 8,588.36 90.28 188.98 6,304.89 6,157.39 -2,419.68 -2,815.47 5,927,580.04 478,282.26 2.62 3,574.28 MWD+IFR-AK-CAZ-SC(5) 8,682.37 89.07 187.83 6,305.42 6,157.92 -2,512.67 -2,829.21 5,927,487.09 478,268.29 1.78 3,626.04 MWD+IFR-AK-CAZ-SC(5) 8,779.02 87.93 189.01 6,307.95 6,160.45 -2,608.25 -2,843.36 5,927,391.56 478,253.90 1.70 3,679.25 MWD+IFR-AK-CAZ-SC(5) 8,872.45 89.65 188.44 6,309.92 6,162.42 -2,700.57 -2,857.53 5,927,299.28 478,239.50 1.94 3,731.11 MWD+IFR-AK-CAZ-SC(5) 8,967.66 91.27 190.39 6,309.16 6,161.66 -2,794.49 -2,873.10 5,927,205.41 478,223.70 2.66 3,784.91 MWD+IFR-AK-CAZ-SC(5) 9,061.75 91.39 190.21 6,306.98 6,159.48 -2,887.04 -2,889.92 5,927,112.91 478,206.65 0.23 3,839.27 MWD+IFR-AK-CAZ-SC(5) 9,157.73 92.39 187.94 6,303.81 6,156.31 -2,981.76 -2,905.05 5,927,018.24 478,191.28 2.58 3,893.01 MWD+IFR-AK-CAZ-SC(5) 9,251.65 92.43 188.35 6,299.86 6,152.36 -3,074.65 -2,918.34 5,926,925.40 478,177.76 0.44 3,944.32 MWD+IFR-AK-CAZ-SC(5) 9,346.59 92.49 189.49 6,295.79 6,148.29 -3,168.35 -2,933.05 5,926,831.74 478,162.82 1.20 3,997.25 MWD+IFR-AK-CAZ-SC(5) 9,440.61 91.67 190.31 6,292.37 6,144.87 -3,260.91 -2,949.20 5,926,739.23 478,146.43 1.23 4,051.01 MWD+IFR-AK-CAZ-SC(5) 9,536.52 91.50 190.68 6,289.72 6,142.22 -3,355.18 -2,966.67 5,926,645.02 478,128.74 0.42 4,106.67 MWD+IFR-AK-CAZ-SC(5) 9,631.01 91.82 190.10 6,286.98 6,139.48 -3,448.08 -2,983.70 5,926,552.17 478,111.47 0.70 4,161.37 MWD+IFR-AK-CAZ-SC(5) 9,725.86 90.81 190.20 6,284.81 6,137.31 -3,541.42 -3,000.41 5,926,458.88 478,094.53 1.07 4,215.96 MWD+IFR-AK-CAZ-SC(5) 9,820.77 90.18 191.17 6,283.99 6,136.49 -3,634.68 -3,018.01 5,926,365.67 478,076.70 1.22 4,271.33 MWD+IFR-AK-CAZ-SC(5) 9,915.66 91.05 191.77 6,282.97 6,135.47 -3,727.66 -3,036.88 5,926,272.74 478,057.60 1.11 4,327.72 MWD+IFR-AK-CAZ-SC(5) 10,009.52 91.02 192.50 6,281.27 6,133.77 -3,819.41 -3,056.60 5,926,181.05 478,037.65 0.78 4,384.38 MWD+IFR-AK-CAZ-SC(5) 10,104 17 90.36 194.16 6,280.13 6,132.63 -3,911.50 -3,078.42 5,926,089.03 478,015.60 1.89 4,443.07 MWD+IFR-AK-CAZ-SC(5) 10,197.86 90.64 194.24 6,279.31 6,131.81 -4,002.33 -3,101.41 5,925,998.27 477,992.39 0.31 4,502.28 MWD+IFR-AK-CAZ-SC(5) 10,245.39 92.51 194.10 6,278.01 6,130.51 -4,048.39 -3,113.04 5,925,952.24 477,980.65 3.95 4,532.29 MWD+IFR-AK-CAZ-SC(5) 10,292.56 92.21 193.50 6,276.07 6,128.57 -4,094.16 -3,124.28 5,925,906.50 477,969.29 1.42 4,561.82 MWD+IFR-AK-CAZ-SC(5) 10,387.20 92.70 193.15 6,272.01 6,124.51 -4,186.17 -3,146.07 5,925,814.56 477,947.27 0.64 4,620.46 MWD+IFR-AK-CAZ-SC(5) 10,481.67 93.04 194.41 6,267.28 6,119.78 -4,277.80 -3,168.54 5,925,722.99 477,924.57 1.38 4,679.55 MWD+IFR-AK-CAZ-SC(5) 10,577.69 92.56 195.13 6,262.59 6,115.09 -4,370.54 -3,192.99 5,925,630.33 477,899.89 0.90 4,740.90 MWD+IFR-AK-CAZ-SC(5) 10,670.30 91.05 195.58 6,259.67 6,112.17 -4,459.79 -3,217.50 5,925,541.14 477,875.16 1.70 4,800.84 MWD+IFR-AK-CAZ-SC(5) 10,765.46 88.92 196.25 6,259.70 6,112.20 -4,551.30 -3,243.60 5,925,449.71 477,848.84 2.35 4,863.16 MWD+IFR-AK-CAZ-SC(5) 10,859.10 87.57 195.38 6,262.57 6,115.07 -4,641.35 -3,269.10 5,925,359.73 477,823.11 1.71 4,924.33 MWD+IFR-AK-CAZ-SC(5) 10,954.37 87.56 194.11 6,266.61 6,119.11 -4,733.40 -3,293.33 5,925,267.75 477,798.66 1.33 4,985.19 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 5:04:07PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger 411 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 Wirth ReferenceTrue Wellbore: 2S-08 ourvey C"11orn(tod: Minimum Curvature Design; 2S-08 Database;':. OAKEDMP2 Map men Vertical MD Inc • A . *, , '4lTVDSS +NI-S +EI-W = Northing . . Easting DLS Section (usft) (°) (I (usft)', (usft) (usft) (ft)_ (ft) (°11001 (ft) Survey Tool Name 11,047.14 87.25 193.72 6,270.82 6,123.32 -4,823.35 -3,315.62 5,925,177.86 477,776.15 0.54 5,043.41 MWD+IFR-AK-CAZ-SC(5) 11,142.60 86.92 193.99 6,275.67 6,128.17 -4,915.91 -3,338.45 5,925,085.37 477,753.09 0.45 5,103.21 MWD+IFR-AK-CAZ-SC(5) 11,237.61 87.80 194.35 6,280.05 6,132.55 -5,007.93 -3,361.68 5,924,993.42 477,729.63 1.00 5,163.16 MWD+IFR-AK-CAZ-SC(5) 11,330.02 88.37 195.02 6,283.13 6,135.63 -5,097.28 -3,385.09 5,924,904.14 477,705.99 0.95 5,222.14 MWD+IFR-AK-CAZ-SC(5) 11,424.42 90.03 194.27 6,284.45 6,136.95 -5,188.60 -3,408.96 5,924,812.89 477,681.90 1.93 5,282.36 MWD+IFR-AK-CAZ-SC(5) 11,520.08 90.75 193.36 6,283.80 6,136.30 -5,281.48 -3,431.80 5,924,720.07 477,658.83 1.21 5,342.32 MWD+IFR-AK-CAZ-SC(5) 11,614.35 90.78 192.82 6,282.54 6,135.04 -5,373.30 -3,453.15 5,924,628.32 477,637.26 0.57 5,400.47 MWD+IFR-AK-CAZ-SC(5) 11,709.66 90.27 191.85 6,281.67 6,134.17 -5,466.40 -3,473.51 5,924,535.28 477,616.67 1.15 5,458.27 MWD+IFR-AK-CAZ-SC(5) 11,804.82 90.40 192.69 6,281.11 6,133.61 -5,559.38 -3,493.73 5,924,442.35 477,596.21 0.89 5,515.89 MWD+IFR-AK-CAZ-SC(5) 11,899.24 90.22 193.32 6,280.60 6,133.10 -5,651.38 -3,514.98 5,924,350.42 477,574.74 0.69 5,574.03 MWD+IFR-AK-CAZ-SC(5) 11,993.85 90.92 192.87 6,279.66 6,132.16 -5,743.53 -3,536.41 5,924,258.34 477,553.07 0.88 5,632.39 MWD+IFR-AK-CAZ-SC(5) 12,087.85 90.68 192.65 6,278.35 6,130.85 -5,835.19 -3,557.17 5,924,166.73 477,532.09 0.35 5,689.95 MWD+IFR-AK-CAZ-SC(5) 12,182.19 89.53 191.92 6,278.18 6,130.68 -5,927.37 -3,577.24 5,924,074.61 477,511.79 1.44 5,747.10 MWD+IFR-AK-CAZ-SC(5) 12,277.66 89.55 192.46 6,278.94 6,131.44 -6,020.69 -3,597.40 5,923,981.36 477,491.40 0.57 5,804.80 MWD+IFR-AK-CAZ-SC(5) 12,370.68 89.55 191.74 6,279.67 6,132.17 -6,111.64 -3,616.90 5,923,890.47 477,471.67 0.77 5,860.91 MWD+IFR-AK-CAZ-SC(5) 12,465.09 89.72 191.01 6,280.27 6,132.77 -6,204.19 -3,635.52 5,923,797.97 477,452.82 0.79 5,916.90 MWD+IFR-AK-CAZ-SC(5) 12,561.30 90.33 191.15 6,280.23 6,132.73 -6,298.61 -3,654.01 5,923,703.61 477,434.10 0.65 5,973.56 MWD+IFR-AK-CAZ-SC(5) 12,654.81 90.30 189.92 6,279.72 6,132.22 -6,390.54 -3,671.10 5,923,611.73 477,416.77 1.32 6,027.91 MWD+IFR-AK-CAZ-SC(5) 12,750.69 89.33 191.18 6,280.03 6,132.53 -6,484.79 -3,688.66 5,923,517.53 477,398.99 1.66 6,083.65 MWD+IFR-AK-CAZ-SC(5) 12,846.06 89.37 191.32 6,281.11 6,133.61 -6,578.32 -3,707.26 5,923,424.05 477,380.15 0.15 6,140.04 MWD+IFR-AK-CAZ-SC(5) 12,939.91 88.40 191.93 6,282.94 6,135.44 -6,670.23 -3,726.17 5,923,332.20 477,361.01 1.22 6,196.02 MWD+IFR-AK-CAZ-SC(5) 13,035.77 88.79 192.06 6,285.29 6,137.79 -6,763.97 -3,746.09 5,923,238.53 477,340.86 0.43 6,253.68 MWD+IFR-AK-CAZ-SC(5) 13,129.55 88.78 192.82 6,287.27 6,139.77 -6,855.52 -3,766.28 5,923,147.03 477,320.44 0.81 6,310.68 MWD+IFR-AK-CAZ-SC(5) 13,224.01 89.85 194.57 6,288.40 6,140.90 -6,947.29 -3,788.64 5,923,055.33 477,297.85 2.17 6,369.73 MWD+IFR-AK-CAZ-SC(5) 13,318.46 89.82 195.38 6,288.68 6,141.18 -7,038.53 -3,813.05 5,922,964.16 477,273.22 0.86 6,430.41 MWD+IFR-AK-CAZ-SC(5) 13,411 89 89.96 195.36 6,288.85 6,141.35 -7,128.62 -3,837.81 5,922,874.14 477,248.23 0.15 6,490.92 MWD+IFR-AK-CAZ-SC(5) 13,506.35 90.33 196.43 6,288.62 6,141.12 -7,219.46 -3,863.68 5,922,783.37 477,222.14 1.20 6,552.76 MWD+IFR-AK-CAZ-SC(5) 13,600.07 90.44 196.91 6,287.99 6,140.49 -7,309.24 -3,890.57 5,922,693.67 477,195.03 0.53 6,615.07 MWD+IFR-AK-CAZ-SC(5) 13,693.94 90.48 198.24 6,287.23 6,139.73 -7,398.73 -3,918.91 5,922,604.26 477,166.47 1.42 6,678.58 MWD+IFR-AK-CAZ-SC(5) 13,789.83 89.22 197.15 6,287.48 6,139.98 -7,490.08 -3,948.05 5,922,513.00 477,137.10 1.74 6,743.60 MWD+IFR-AK-CAZ-SC(5) 13,884.99 89.34 196.96 6,288.68 6,141.18 -7,581.04 -3,975.96 5,922,422.11 477,108.97 0.24 6,807.33 MWD+IFR-AK-CAZ-SC(5) 13,979.49 88.64 195.85 6,290.35 6,142.85 -7,671.68 -4,002.65 5,922,331.55 477,082.06 1.39 6,869.82 MWD+IFR-AK-CAZ-SC(5) 14,074.78 88.74 195.06 6,292.52 6,145.02 -7,763.50 -4,028.03 5,922,239.80 477,056.44 0.84 6,931.63 MWD+IFR-AK-CAZ-SC(5) 14,168.83 90.23 194.38 6,293.37 6,145.87 -7,854.46 -4,051.93 5,922,148.91 477,032.32 1.74 6,991.73 MWD+IFR-AK-CAZ-SC(5) 14,265.49 88.62 194.68 6,294.34 6,146.84 -7,948.02 -4,076.18 5,922,055.42 477,007.84 1.69 7,053.25 MWD+IFR-AK-CAZ-SC(5) 14,345.00 88.62 194.68 6,296.25 6,148.75 -8,024.91 -4,096.32 5,921,978.59 476,987.51 0.00 7,104.00 PROJECTED to TD 11!24/2015 5.'04:07PM Page 6 COMPASS 5000.1 Build 74 • • ._, Cement Detail Report 2S-08 ConocoPhi lips String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/4/2015 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 11/8/2015 10:45 11/8/2015 15:00 2S-08 Comment Pump 61 bbls nut plug mud marker pill. Pump 5 bbls of CW-100&PT lines to 900/4000 psi.Continue pumping 8.35 ppg CW-100 for a total of 75 bbls,4.8 bpm, 150 psi.Pump 75 bbls of 10.5 ppg MPII w/red dye at 4.5 bpm,200 psi. Drop bottom plug&pump 396 bbls of 11.0 ppg Lead Cement at 6 bpm,360 psi. Pump 64 bbls of 12.0 ppg Tail Cement at 5.2 bpm,420 psi. Drop top plug&kick out with 10 bbls of fresh H2O at 5.5 bpm,300 psi.Swap to rig&displace cement with 9.7 ppg mud at 6 bpm,525 psi.Bump plug w/236.8 bbls,pressure up to 1025 psi&hold for 5 min.Check floats,good.CIP at 14:45 hrs.Total of 113 bbls of cement returns to surface. Cement Stages. Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 30.6 2,665.0 No Yes Yes Q Pump!nit(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) 6 6 6 525.0 1,025.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 61 bbls nut plug mud marker pill. Pump 5 bbls of CW-100&PT lines to 900/4000 psi.Continue pumping 8.35 ppg CW-100 for a total of 75 bbls,4.8 bpm, 150 psi.Pump 75 bbls of 10.5 ppg MPII w/red dye at 4.5 bpm,200 psi. Drop bottom plug&pump 396 bbls of 11.0 ppg Lead Cement at 6 bpm,360 psi. Pump 64 bbls of 12.0 ppg Tail Cement at 5.2 bpm,420 psi. Drop top plug&kick out with 10 bbls of fresh H2O at 5.5 bpm,300 psi.Swap to rig&displace cement with 9.7 ppg mud at 6 bpm,525 psi. Bump plug w/236.8 bbls,pressure up to 1025 psi&hold for 5 min.Check floats,good.CIP at 14:45 hrs.Total of 113 bbls of cement returns to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 30.6 1,848.0 1,166 LiteCRETE 396.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.75 11.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,848.0 2,665.0 221 LiteCRETE 64.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.66 5.76 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Page 1/1 Report Printed: 12/28/2015 • • Cement Detail Report `'` 4 &Wens 2S-08 ConocoPhit ps String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 11/4/2015 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/15/2015 14:15 11/15/2015 17:15 2S-08 Comment SLB cementers pump 5 bbls of CW-100. Pressure test lines 500/4000 psi for 5 min. Pump 65 bbls of CW-100,4.5 bpm,350 psi. Pump 40 bbls of 11.5 ppg MPII at 4.7 bpm,350 psi.Load bottom plug in pipe. Pump 186 bbls of 15.3 ppg cement slurry w/1lb/bbl CemNet at 5.5 bpm,275 psi. Load top plug in pipe.Pump 10 bbls of H20.Swap to rig&displace with 310 bbls of 10.0 ppg mud at 5 bpm, 150-900 psi. Bump plug&pressure up to 1400 psi&hold for 5 min. Bleed off& check floats,good.CIP 16:55 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 4,652.0 7,151.0 No Yes Yes Cement Q Pump!nit(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) 5 5 175 900.0 1,400.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to cementers&pump 5 bbls of CW-100. Pressure test lines 500/4000 psi for 5 min. Pump 65 bbls of CW-100,4.5 bpm,350 psi.Pump 40 bbls of 11.5 ppg MPII at 4.7 bpm,350 psi. Load bottom plug in pipe. Pump 186 bbls of 15.3 ppg cement slurry w/11b/bbl CemNet at 5.5 bpm,275 psi. Load top plug in pipe. Pump 10 bbls of H20.Swap to rig&displace with 310 bbls of 10.0 ppg mud at 5 bpm, 150-900 psi. Bump plug&pressure up to 1400 psi&hold for 5 min.Bleed off&check floats,good.CIP 16:55 hrs. Cement Fluids&Additives ' Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/28/2015 • • 215174 26560 SchlumbergerDrilling & Measurements Transmittal#: 18DEC15-SPO1 DATA LOGGED MWD/LWD Log Product Delivery t Ttgi2oi6 it K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-08 Date Dispatched: 18-Dec-15 Job#: 14AKA0061 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 5"MicroScope Resistivity Image x x VISION*Service 5'MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico(a�conocophillips.com AlaskaPTSPrintCenter(d slb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 6...e. - C Received By: m,,,,,,,..,..„,c/7) • • 215174 16580 RECEIVED 18 FINAL AOGCC= NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-08 Definitive Survey Report 24 November, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Project Kuparuk River Unit,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 2S-08 Well Position +N/-S 0.00 usft Northing: 5,929,992.42 usfl Latitude: 70° 13'11.622 N +E/-W 0.00 usft Easting: 481,103.50 usfl Longitude: 150°9'8.804 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-08 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGG M2015 11/25/2015 18.47 80.87 57,487 Design 2S-08 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 245.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 71.00 438.00 2S-08 Srvy#1 -Gyro Battery(2S-08) GYD-GC-MS Gyrodata gyrocompassing m/s 11/10/2015 2:: 485.04 2,594.28 2S-08 Srvy#2-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 2:. 2,695.86 7,076.67 2S-08 Srvy#3-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/20/2015 9: 7,171.07 7,171.07 2S-08 Srvy#4-INC ONLY(2S-08) INC+TREND Inclinometer+known azi trend 11/20/2015 9: 7,264.20 14,265.49 2S-08 Srvy#5-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/20/2015 9:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,992.42 481,103.50 0.00 0.00 UNDEFINED 71.00 0.46 33.48 71.00 -76.50 0.15 0.10 5,929,992.57 481,103.60 1.06 -0.15 GYD-GC-MS(1) 107.50 0.54 31.92 107.50 -40.00 0.41 0.27 5,929,992.83 481,103.77 0.21 -0.42 G NOT an Actual Survey 16"x 20" 162.00 0.65 30.28 162.00 14.50 0.90 0.56 5,929,993.31 481,104.06 0.21 -0.88 GYD-GC-MS(1) 254.00 0.76 14.86 253.99 106.49 1.94 0.98 5,929,994.35 481,104.48 0.24 -1.70 GYD-GC-MS(1) 345.00 2.07 325.41 344.96 197.46 3.87 0.20 5,929,996.29 481,103.71 1.84 -1.82 GYD-GC-MS(1) 438.00 4.21 322.93 437.82 290.32 7.98 -2.81 5,930,000.41 481,100.71 2.31 -0.82 GYD-GC-MS(1) 485.04 4.78 322.64 484.71 337.21 10.92 -5.04 5,930,003.35 481,098.49 1.21 -0.04 MWD+IFR-AK-CAZ-SC(2) 578.31 5.65 324.07 577.59 430.09 17.72 -10.09 5,930,010.17 481,093.45 0.94 1.66 MWD+IFR-AK-CAZ-SC(2) 670.23 8.20 323.54 668.84 521.34 26.66 -16.65 5,930,019.12 481,086.92 2.77 3.82 MWD+IFR-AK-CAZ-SC(2) 11/24/2015 5:04:07PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 764.53 8.68 325.12 762.11 614.61 37.91 -24.71 5,930,030.38 481,078.89 0.57 6.38 MWD+IFR-AK-CAZ-SC(2) 856.01 9.57 324.53 852.44 704.94 49.76 -33.07 5,930,042.26 481,070.56 0.98 8.94 MWD+IFR-AK-CAZ-SC(2) 950.06 10.01 323.99 945.12 797.62 62.74 -42.41 5,930,055.26 481,061.25 0.48 11.93 MWD+IFR-AK-CAZ-SC(2) 1,043.14 10.28 324.34 1,036.74 889.24 76.03 -52.01 5,930,068.58 481,051.68 0.30 15.01 MWD+IFR-AK-CAZ-SC(2) 1,135.08 11.86 325.26 1,126.97 979.47 90.46 -62.18 5,930,083.03 481,041.55 1.73 18.12 MWD+IFR-AK-CAZ-SC(2) 1,228.47 13.52 328.24 1,218.07 1,070.57 107.63 -73.40 5,930,100.23 481,030.38 1.91 21.03 MWD+IFR-AK-CAZ-SC(2) 1,323.98 15.95 331.65 1,310.44 1,162.94 128.68 -85.51 5,930,121.30 481,018.33 2.70 23.11 MWD+IFR-AK-CAZ-SC(2) 1,417.11 17.17 332.45 1,399.70 1,252.20 152.13 -97.94 5,930,144.78 481,005.95 1.33 24.47 MWD+IFR-AK-CAZ-SC(2) 1,511.55 17.61 325.67 1,489.84 1,342.34 176.29 -112.45 5,930,168.97 480,991.51 2.19 27.41 MWD+IFR-AK-CAZ-SC(2) 1,602.63 18.20 316.23 1,576.52 1,429.02 197.94 -130.06 5,930,190.67 480,973.95 3.25 34.22 MWD+IFR-AK-CAZ-SC(2) 1,695.32 18.09 305.09 1,664.63 1,517.13 216.67 -151.85 5,930,209.45 480,952.20 3.74 46.06 MWD+IFR-AK-CAZ-SC(2) 1,788.92 18.02 292.46 1,753.66 1,606.16 230.56 -177.13 5,930,223.40 480,926.96 4.18 63.10 MWD+IFR-AK-CAZ-SC(2) 1,884.31 19.14 280.43 1,844.11 1,696.61 239.03 -206.16 5,930,231.94 480,897.96 4.18 85.83 MWD+IFR-AK-CAZ-SC(2) 1,978.23 19.25 272.13 1,932.82 1,785.32 242.40 -236.78 5,930,235.38 480,867.35 2.91 112.16 MWD+IFR-AK-CAZ-SC(2) 2,070.63 20.17 262.48 2,019.83 1,872.33 240.88 -267.80 5,930,233.94 480,836.33 3.66 140.91 MWD+IFR-AK-CAZ-SC(2) 2,162.32 22.27 260.67 2,105.30 1,957.80 235.99 -300.62 5,930,229.14 480,803.50 2.40 172.72 MWD+IFR-AK-CAZ-SC(2) 2,259.27 22.94 262.76 2,194.80 2,047.30 230.63 -337.50 5,930,223.87 480,766.62 1.08 208.41 MWD+IFR-AK-CAZ-SC(2) 2,352.62 24.51 259.54 2,280.26 2,132.76 224.82 -374.59 5,930,218.16 480,729.51 2.18 244.48 MWD+IFR-AK-CAZ-SC(2) 2,447.67 26.48 258.12 2,366.06 2,218.56 216.88 -414.72 5,930,210.32 480,689.37 2.17 284.20 MWD+IFR-AK-CAZ-SC(2) 2,541.77 27.44 258.59 2,449.93 2,302.43 208.27 -456.50 5,930,201.81 480,647.57 1.05 325.71 MWD+IFR-AK-CAZ-SC(2) 2,594.28 27.79 258.91 2,496.46 2,348.96 203.52 -480.37 5,930,197.13 480,623.68 0.72 349.35 MWD+IFR-AK-CAZ-SC(2) 2,652.40 29.37 259.35 2,547.49 2,399.99 198.28 -507.68 5,930,191.95 480,596.37 2.75 376.32 NOT an Actual Survey (3) 10 3/4"x 13-1/2 2,695.86 30.56 259.66 2,585.14 2,437.64 194.33 -529.03 5,930,188.06 480,575.01 2.75 397.33 MWD+IFR-AK-CAZ-SC(3) 2,786.86 32.76 258.18 2,662.59 2,515.09 185.14 -575.89 5,930,178.98 480,528.13 2.56 443.69 MWD+IFR-AK-CAZ-SC(3) 2,879.96 30.48 257.80 2,741.87 2,594.37 174.98 -623.63 5,930,168.95 480,480.37 2.46 491.25 MWD+IFR-AK-CAZ-SC(3) 2,972.44 27.48 257.54 2,822.76 2,675.26 165.42 -667.40 5,930,159.50 480,436.58 3.25 534.96 MWD+IFR-AK-CAZ-SC(3) 3,065.25 28.31 258.80 2,904.79 2,757.29 156.53 -709.90 5,930,150.71 480,394.07 1.10 577.23 MWD+IFR-AK-CAZ-SC(3) 3,157.07 28.09 259.93 2,985.71 2,838.21 148.52 -752.54 5,930,142.81 480,351.41 0.63 619.27 MWD+IFR-AK-CAZ-SC(3) 3,250.49 28.00 263.93 3,068.17 2,920.67 142.35 -796.00 5,930,136.75 480,307.93 2.02 661.26 MWD+IFR-AK-CAZ-SC(3) 3,343.12 28.02 265.80 3,149.95 3,002.45 138.46 -839.33 5,930,132.97 480,264.61 0.95 702.17 MWD+IFR-AK-CAZ-SC(3) 3,435.53 28.05 263.93 3,231.51 3,084.01 134.57 -882.58 5,930,129.19 480,221.35 0.95 743.02 MWD+IFR-AK-CAZ-SC(3) 3,529.67 27.82 260.81 3,314.69 3,167.19 128.72 -926.28 5,930,123.45 480,177.64 1.57 785.09 MWD+IFR-AK-CAZ-SC(3) 3,622.09 28.30 261.07 3,396.25 3,248.75 121.88 -969.21 5,930,116.71 480,134.69 0.54 826.89 MWD+IFR-AK-CAZ-SC(3) 3,715.67 28.35 261.66 3,478.62 3,331.12 115.21 -1,013.11 5,930,110.16 480,090.79 0.30 869.50 MWD+IFR-AK-CAZ-SC(3) 3,808.04 27.71 258.29 3,560.16 3,412.66 107.67 -1,055.84 5,930,102.72 480,048.04 1.85 911.41 MWD+IFR-AK-CAZ-SC(3) 3,900.41 28.52 257.81 3,641.63 3,494.13 98.66 -1,098.42 5,930,093.82 480,005.44 0.91 953.81 MWD+IFR-AK-CAZ-SC(3) 3,997.15 28.48 257.95 3,726.65 3,579.15 88.97 -1,143.55 5,930,084.24 479,960.29 0.08 998.81 MWD+IFR-AK-CAZ-SC(3) 4,087.22 28.24 257.95 3,805.91 3,658.41 80.03 -1,185.40 5,930,075.41 479,918.43 0.27 1,040.51 MWD+IFR-AK-CAZ-SC(3) 4,181.15 28.43 257.90 3,888.58 3,741.08 70.71 -1,228.99 5,930,066.20 479,874.81 0.20 1,083.96 MWD+IFR-AK-CAZ-SC(3) 11/24/2015 5:04:07PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,273.93 28.59 258.19 3,970.11 3,822.61 61.53 -1,272.32 5,930,057.13 479,831.47 0.23 1,127.10 MWD+IFR-AK-CAZ-SC(3) 4,366.15 28.94 257.35 4,050.95 3,903.45 52.13 -1,315.68 5,930,047.84 479,788.08 0.58 1,170.38 MW D+I FR-AK-CAZ-SC(3) 4,458.53 28.82 257.13 4,131.84 3,984.34 42.28 -1,359.20 5,930,038.10 479,744.55 0.17 1,213.99 MWD+IFR-AK-CAZ-SC(3) 4,551.12 28.17 256.81 4,213.22 4,065.72 32.32 -1,402.24 5,930,028.25 479,701.49 0.72 1,257.20 MWD+IFR-AK-CAZ-SC(3) 4,644.32 27.00 255.71 4,295.82 4,148.32 22.08 -1,444.16 5,930,018.11 479,659.55 1.37 1,299.52 MW D+I FR-AK-CAZ-SC(3) 4,736.62 25.98 256.07 4,378.43 4,230.93 12.04 -1,484.08 5,930,008.17 479,619.60 1.12 1,339.95 MWD+IFR-AK-CAZ-SC(3) 4,831.48 26.72 254.86 4,463.44 4,315.94 1.47 -1,524.84 5,929,997.70 479,578.82 0.96 1,381.35 MWD+I FR-AK-CAZ-SC(3) 4,923.51 27.31 254.67 4,545.42 4,397.92 -9.52 -1,565.17 5,929,986.82 479,538.47 0.65 1,422.55 MWD+IFR-AK-CAZ-SC(3) 5,016.27 27.53 257.09 4,627.76 4,480.26 -19.93 -1,606.59 5,929,976.51 479,497.03 1.22 1,464.49 MWD+IFR-AK-CAZ-SC(3) 5,110.04 28.83 259.55 4,710.42 4,562.92 -28.88 -1,649.95 5,929,967.68 479,453.65 1.86 1,507.56 MWD+IFR-AK-CAZ-SC(3) 5,203.44 29.26 257.58 4,792.08 4,644.58 -37.87 -1,694.39 5,929,958.79 479,409.19 1.12 1,551.64 MW D+I FR-AK-CAZ-SC(3) 5,297.20 29.76 251.77 4,873.69 4,726.19 -50.08 -1,738.88 5,929,946.70 479,364.68 3.10 1,597.12 MWD+IFR-AK-CAZ-SC(3) 5,389.18 29.94 245.35 4,953.49 4,805.99 -66.80 -1,781.43 5,929,930.09 479,322.08 3.48 1,642.76 MWD+IFR-AK-CAZ-SC(3) 5,483.65 30.59 241.10 5,035.09 4,887.59 -88.25 -1,823.91 5,929,908.74 479,279.56 2.37 1,690.32 MWD+IFR-AK-CAZ-SC(3) 5,576.30 30.72 236.71 5,114.80 4,967.30 -112.64 -1,864.33 5,929,884.46 479,239.08 2.42 1,737.26 MW D+I FR-AK-CAZ-SC(3) 5,668.49 32.29 232.28 5,193.41 5,045.91 -140.63 -1,903.50 5,929,856.57 479,199.84 3.03 1,784.59 MWD+I FR-AK-CAZ-SC(3) 5,764.27 34.19 228.05 5,273.53 5,126.03 -174.28 -1,943.76 5,929,823.02 479,159.50 3.13 1,835.30 MWD+IFR-AK-CAZ-SC(3) 5,858.48 35.89 224.36 5,350.67 5,203.17 -211.73 -1,982.76 5,929,785.68 479,120.41 2.88 1,886.47 MWD+IFR-AK-CAZ-SC(3) 5,952.24 37.48 222.66 5,425.86 5,278.36 -252.36 -2,021.31 5,929,745.15 479,081.77 2.01 1,938.58 MWD+IFR-AK-CAZ-SC(3) 6,043.73 38.96 222.19 5,497.73 5,350.23 -294.14 -2,059.49 5,929,703.47 479,043.48 1.65 1,990.84 MWD+IFR-AK-CAZ-SC(3) 6,137.08 42.01 221.81 5,568.73 5,421.23 -339.18 -2,100.04 5,929,658.53 479,002.83 3.28 2,046.62 MWD+IFR-AK-CAZ-SC(3) 6,229.66 44.75 218.94 5,636.01 5,488.51 -387.63 -2,141.18 5,929,610.19 478,961.56 3.65 2,104.39 MWD+IFR-AK-CAZ-SC(3) 6,324.31 46.48 216.13 5,702.22 5,554.72 -441.27 -2,182.37 5,929,556.66 478,920.25 2.80 2,164.39 MWD+IFR-AK-CAZ-SC(3) 6,418.56 47.68 211.67 5,766.42 5,618.92 -498.55 -2,220.82 5,929,499.48 478,881.66 3.69 2,223.44 MWD+IFR-AK-CAZ-SC(3) 6,511.17 48.40 207.59 5,828.36 5,680.86 -558.39 -2,254.84 5,929,439.73 478,847.49 3.37 2,279.57 MWD+IFR-AK-CAZ-SC(3) 6,604.34 50.54 204.01 5,888.91 5,741.41 -622.14 -2,285.62 5,929,376.07 478,816.56 3.71 2,334.40 MWD+IFR-AK-CAZ-SC(3) 6,699.75 52.78 201.13 5,948.10 5,800.60 -691.24 -2,314.31 5,929,307.05 478,787.70 3.33 2,389.60 MWD+IFR-AK-CAZ-SC(3) 6,791.69 55.34 200.44 6,002.06 5,854.56 -760.82 -2,340.71 5,929,237.53 478,761.12 2.85 2,442.95 MWD+IFR-AK-CAZ-SC(3) 6,886.29 57.58 200.90 6,054.32 5,906.82 -834.59 -2,368.55 5,929,163.84 478,733.11 2.40 2,499.35 MWD+IFR-AK-CAZ-SC(3) 6,980.99 61.84 201.22 6,102.08 5,954.58 -910.88 -2,397.93 5,929,087.63 478,703.54 4.51 2,558.22 MWD+IFR-AK-CAZ-SC(3) 7,076.67 66.16 200.97 6,144.01 5,996.51 -991.10 -2,428.87 5,929,007.50 478,672.40 4.52 2,620.16 MWD+IFR-AK-CAZ-SC(3) 7,141.00 68.20 201.59 6,168.96 6,021.46 -1,046.35 -2,450.39 5,928,952.32 478,650.74 3.29 2,663.01 NOT an Actual Survey 7-518"x 9-7/8"by 11" 7,171.07 69.15 201.87 6,179.90 6,032.40 -1,072.37 -2,460.76 5,928,926.33 478,640.31 3.29 2,683.41 INC+TREND(4) 7,264.20 70.23 202.96 6,212.22 6,064.72 -1,153.10 -2,494.07 5,928,845.68 478,606.80 1.60 2,747.71 MWD+IFR-AK-CAZ-SC(5) 7,358.82 71.85 200.88 6,242.97 6,095.47 -1,236.11 -2,527.46 5,928,762.76 478,573.20 2.69 2,813.06 MW D+I FR-AK-CAZ-SC(5) 7,410.37 72.94 198.64 6,258.56 6,111.06 -1,282.35 -2,544.07 5,928,716.57 478,556.48 4.65 2,847.66 MWD+I FR-AK-CAZ-SC(5) 7,453.04 74.01 199.40 6,270.70 6,123.20 -1,321.03 -2,557.40 5,928,677.93 478,543.05 3.03 2,876.08 MWD+IFR-AK-CAZ-SC(5) 7,499.36 75.35 198.94 6,282.93 6,135.43 -1,363.22 -2,572.07 5,928,635.78 478,528.28 3.05 2,907.21 MWD+IFR-AK-CAZ-SC(5) 7,547.86 77.33 197.68 6,294.39 6,146.89 -1,407.96 -2,586.87 5,928,591.08 478,513.37 4.80 2,939.53 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 5:04:07PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 7,593.84 79.82 196.35 6,303.50 6,156.00 -1,451.05 -2,600.06 5,928,548.02 478,500.08 6.11 2,969.69 MWD+IFR-AK-CAZ-SC(5) 7,642.79 82.68 196.51 6,310.94 6,163.44 -1,497.45 -2,613.74 5,928,501.66 478,486.28 5.85 3,001.70 MWD+IFR-AK-CAZ-SC(5) 7,689.90 84.74 196.51 6,316.10 6,168.60 -1,542.35 -2,627.05 5,928,456.81 478,472.86 4.37 3,032.74 MWD+IFR-AK-CAZ-SC(5) 7,738.63 86.56 195.57 6,319.80 6,172.30 -1,589.04 -2,640.47 5,928,410.15 478,459.32 4.20 3,064.64 MWD+IFR-AK-CAZ-SC(5) 7,785.59 88.35 194.22 6,321.88 6,174.38 -1,634.38 -2,652.53 5,928,364.85 478,447.15 4.77 3,094.73 MWD+IFR-AK-CAZ-SC(5) 7,832.94 89.82 195.36 6,322.64 6,175.14 -1,680.15 -2,664.61 5,928,319.11 478,434.95 3.93 3,125.02 MWD+IFR-AK-CAZ-SC(5) 7,927.35 93.39 193.34 6,320.00 6,172.50 -1,771.56 -2,688.00 5,928,227.77 478,411.34 4.34 3,184.85 MWD+IFR-AK-CAZ-SC(5) 8,022.22 93.63 191.91 6,314.19 6,166.69 -1,863.96 -2,708.70 5,928,135.43 478,390.41 1.53 3,242.66 MWD+IFR-AK-CAZ-SC(5) 8,117.20 90.50 192.13 6,310.77 6,163.27 -1,956.79 -2,728.46 5,928,042.67 478,370.42 3.30 3,299.80 MWD+IFR-AK-CAZ-SC(5) 8,212.14 90.42 189.87 6,310.00 6,162.50 -2,049.97 -2,746.58 5,927,949.53 478,352.07 2.38 3,355.60 MWD+IFR-AK-CAZ-SC(5) 8,307.26 92.16 188.74 6,307.86 6,160.36 -2,143.81 -2,761.95 5,927,855.74 478,336.47 2.18 3,409.19 MWD+IFR-AK-CAZ-SC(5) 8,401.37 90.75 192.70 6,305.47 6,157.97 -2,236.23 -2,779.45 5,927,763.38 478,318.74 4.47 3,464.11 MWD+IFR-AK-CAZ-SC(5) 8,495.84 89.84 191.36 6,304.98 6,157.48 -2,328.62 -2,799.14 5,927,671.05 478,298.82 1.71 3,521.00 MWD+IFR-AK-CAZ-SC(5) 8,588.36 90.28 188.98 6,304.89 6,157.39 -2,419.68 -2,815.47 5,927,580.04 478,282.26 2.62 3,574.28 MWD+IFR-AK-CAZ-SC(5) 8,682.37 89.07 187.83 6,305.42 6,157.92 -2,512.67 -2,829.21 5,927,487.09 478,268.29 1.78 3,626.04 MWD+IFR-AK-CAZ-SC(5) 8,779.02 87.93 189.01 6,307.95 6,160.45 -2,608.25 -2,843.36 5,927,391.56 478,253.90 1.70 3,679.25 MWD+IFR-AK-CAZ-SC(5) 8,872.45 89.65 188.44 6,309.92 6,162.42 -2,700.57 -2,857.53 5,927,299.28 478,239.50 1.94 3,731.11 MWD+IFR-AK-CAZ-SC(5) 8,967.66 91.27 190.39 6,309.16 6,161.66 -2,794.49 -2,873.10 5,927,205.41 478,223.70 2.66 3,784.91 MWD+IFR-AK-CAZ-SC(5) 9,061.75 91.39 190.21 6,306.98 6,159.48 -2,887.04 -2,889.92 5,927,112.91 478,206.65 0.23 3,839.27 MWD+IFR-AK-CAZ-SC(5) 9,157.73 92.39 187.94 6,303.81 6,156.31 -2,981.76 -2,905.05 5,927,018.24 478,191.28 2.58 3,893.01 MWD+IFR-AK-CAZ-SC(5) 9,251.65 92.43 188.35 6,299.86 6,152.36 -3,074.65 -2,918.34 5,926,925.40 478,177.76 0.44 3,944.32 MWD+IFR-AK-CAZ-SC(5) 9,346.59 92.49 189.49 6,295.79 6,148.29 -3,168.35 -2,933.05 5,926,831.74 478,162.82 1.20 3,997.25 MWD+IFR-AK-CAZ-SC(5) 9,440.61 91.67 190.31 6,292.37 6,144.87 -3,260.91 -2,949.20 5,926,739.23 478,146.43 1.23 4,051.01 MWD+IFR-AK-CAZ-SC(5) 9,536.52 91.50 190.68 6,289.72 6,142.22 -3,355.18 -2,966.67 5,926,645.02 478,128.74 0.42 4,106.67 MWD+IFR-AK-CAZ-SC(5) 9,631.01 91.82 190.10 6,286.98 6,139.48 -3,448.08 -2,983.70 5,926,552.17 478,111.47 0.70 4,161.37 MWD+IFR-AK-CAZ-SC(5) 9,725.86 90.81 190.20 6,284.81 6,137.31 -3,541.42 -3,000.41 5,926,458.88 478,094.53 1.07 4,215.96 MWD+IFR-AK-CAZ-SC(5) 9,820.77 90.18 191.17 6,283.99 6,136.49 -3,634.68 -3,018.01 5,926,365.67 478,076.70 1.22 4,271.33 MWD+IFR-AK-CAZ-SC(5) 9,915.66 91.05 191.77 6,282.97 6,135.47 -3,727.66 -3,036.88 5,926,272.74 478,057.60 1.11 4,327.72 MWD+IFR-AK-CAZ-SC(5) 10,009.52 91.02 192.50 6,281.27 6,133.77 -3,819.41 -3,056.60 5,926,181.05 478,037.65 0.78 4,384.38 MWD+IFR-AK-CAZ-SC(5) 10,104.17 90.36 194.16 6,280.13 6,132.63 -3,911.50 -3,078.42 5,926,089.03 478,015.60 1.89 4,443.07 MWD+IFR-AK-CAZ-SC(5) 10,197.86 90.64 194.24 6,279.31 6,131.81 -4,002.33 -3,101.41 5,925,998.27 477,992.39 0.31 4,502.28 MWD+IFR-AK-CAZ-SC(5) 10,245.39 92.51 194.10 6,278.01 6,130.51 -4,048.39 -3,113.04 5,925,952.24 477,980.65 3.95 4,532.29 MWD+IFR-AK-CAZ-SC(5) 10,292.56 92.21 193.50 6,276.07 6,128.57 -4,094.16 -3,124.28 5,925,906.50 477,969.29 1.42 4,561.82 MWD+IFR-AK-CAZ-SC(5) 10,387.20 92.70 193.15 6,272.01 6,124.51 -4,186.17 -3,146.07 5,925,814.56 477,947.27 0.64 4,620.46 MWD+IFR-AK-CAZ-SC(5) 10,481.67 93.04 194.41 6,267.28 6,119.78 -4,277.80 -3,168.54 5,925,722.99 477,924.57 1.38 4,679.55 MWD+IFR-AK-CAZ-SC(5) 10,577.69 92.56 195.13 6,262.59 6,115.09 -4,370.54 -3,192.99 5,925,630.33 477,899.89 0.90 4,740.90 MWD+IFR-AK-CAZSC(5) 10,670.30 91.05 195.58 6,259.67 6,112.17 -4,459.79 -3,217.50 5,925,541.14 477,875.16 1.70 4,800.84 MWD+IFR-AK-CAZ-SC(5) 10,765.46 88.92 196.25 6,259.70 6,112.20 -4,551.30 -3,243.60 5,925,449.71 477,848.84 2.35 4,863.16 MWD+IFR-AK-CAZ-SC(5) 10,859.10 87.57 195.38 6,262.57 6,115.07 -4,641.35 -3,269.10 5,925,359.73 477,823.11 1.71 4,924.33 MWD+IFR-AK-CAZ-SC(5) 10,954.37 87.56 194.11 6,266.61 6,119.11 -4,733.40 -3,293.33 5,925,267.75 477,798.66 1.33 4,985.19 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 5:04:07PM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/10(r) (ft) Survey Tool Name 11,047.14 87.25 193.72 6,270.82 6,123.32 -4,823.35 -3,315.62 5,925,177.86 477,776.15 0.54 5,043.41 MW D+I FR-AK-CAZ-SC(5) 11,142.60 86.92 193.99 6,275.67 6,128.17 -4,915.91 -3,338.45 5,925,085.37 477,753.09 0.45 5,103.21 MWD+IFR-AK-CAZ-SC(5) 11,237.61 87.80 194.35 6,280.05 6,132.55 -5,007.93 -3,361.68 5,924,993.42 477,729.63 1.00 5,163.16 MWD+I FR-AK-CAZ-SC(5) 11,330.02 88.37 195.02 6,283.13 6,135.63 -5,097.28 -3,385.09 5,924,904.14 477,705.99 0.95 5,222.14 MW D+I FR-AK-CAZ-SC(5) 11,424.42 90.03 194.27 6,284.45 6,136.95 -5,188.60 -3,408.96 5,924,812.89 477,681.90 1.93 5,282.36 MW D+I FR-AK-CAZ-SC(5) 11,520.08 90.75 193.36 6,283.80 6,136.30 -5,281.48 -3,431.80 5,924,720.07 477,658.83 1.21 5,342.32 MW D+I FR-AK-CAZ-SC(5) 11,614.35 90.78 192.82 6,282.54 6,135.04 -5,373.30 -3,453.15 5,924,628.32 477,637.26 0.57 5,400.47 MWD+I FR-AK-CAZ-SC(5) 11,709.66 90.27 191.85 6,281.67 6,134.17 -5,466.40 -3,473.51 5,924,535.28 477,616.67 1.15 5,458.27 MWD+I FR-AK-CAZ-SC(5) 11,804.82 90.40 192.69 6,281.11 6,133.61 -5,559.38 -3,493.73 5,924,442.35 477,596.21 0.89 5,515.89 MW D+I FR-AK-CAZ-SC(5) 11,899.24 90.22 193.32 6,280.60 6,133.10 -5,651.38 -3,514.98 5,924,350.42 477,574.74 0.69 5,574.03 MW D+I FR-AK-CAZ-SC(5) 11,993.85 90.92 192.87 6,279.66 6,132.16 -5,743.53 -3,536.41 5,924,258.34 477,553.07 0.88 5,632.39 MWD+I FR-AK-CAZ-SC(5) 12,087.85 90.68 192.65 6,278.35 6,130.85 -5,835.19 -3,557.17 5,924,166.73 477,532.09 0.35 5,689.95 MWD+IFR-AK-CAZ-SC(5) 12,182.19 89.53 191.92 6,278.18 6,130.68 -5,927.37 -3,577.24 5,924,074.61 477,511.79 1.44 5,747.10 MWD+IFR-AK-CAZ-SC(5) 12,277.66 89.55 192.46 6,278.94 6,131.44 -6,020.69 -3,597.40 5,923,981.36 477,491.40 0.57 5,804.80 MWD+IFR-AK-CAZ-SC(5) 12,370.68 89.55 191.74 6,279.67 6,132.17 -6,111.64 -3,616.90 5,923,890.47 477,471.67 0.77 5,860.91 MWD+IFR-AK-CAZSC(5) 12,465.09 89.72 191.01 6,280.27 6,132.77 -6,204.19 -3,635.52 5,923,797.97 477,452.82 0.79 5,916.90 MWD+IFR-AK-CAZ-SC(5) 12,561.30 90.33 191.15 6,280.23 6,132.73 -6,298.61 -3,654.01 5,923,703.61 477,434.10 0.65 5,973.56 MWD+IFR-AK-CAZ-SC(5) 12,654.81 90.30 189.92 6,279.72 6,132.22 -6,390.54 -3,671.10 5,923,611.73 477,416.77 1.32 6,027.91 MWD+IFR-AK-CAZ-SC(5) 12,750.69 89.33 191.18 6,280.03 6,132.53 -6,484.79 -3,688.66 5,923,517.53 477,398.99 1.66 6,083.65 MWD+IFR-AK-CAZ-SC(5) 12,846.06 89.37 191.32 6,281.11 6,133.61 -6,578.32 -3,707.26 5,923,424.05 477,380.15 0.15 6,140.04 MWD+IFR-AK-CAZ-SC(5) 12,939.91 88.40 191.93 6,282.94 6,135.44 -6,670.23 -3,726.17 5,923,332.20 477,361.01 1.22 6,196.02 MWD+IFR-AK-CAZ-SC(5) 13,035.77 88.79 192.06 6,285.29 6,137.79 -6,763.97 -3,746.09 5,923,238.53 477,340.86 0.43 6,253.68 MWD+IFR-AK-CAZ-SC(5) 13,129.55 88.78 192.82 6,287.27 6,139.77 -6,855.52 -3,766.28 5,923,147.03 477,320.44 0.81 6,310.68 MWD+IFR-AK-CAZ-SC(5) 13,224.01 89.85 194.57 6,288.40 6,140.90 -6,947.29 -3,788.64 5,923,055.33 477,297.85 2.17 6,369.73 MWD+IFR-AK-CAZ-SC(5) 13,318.46 89.82 195.38 6,288.68 6,141.18 -7,038.53 -3,813.05 5,922,964.16 477,273.22 0.86 6,430.41 MWD+IFR-AK-CAZ-SC(5) 13,411.89 89.96 195.36 6,288.85 6,141.35 -7,128.62 -3,837.81 5,922,874.14 477,248.23 0.15 6,490.92 MW D+I FR-AK-CAZ-SC(5) 13,506.35 90.33 196.43 6,288.62 6,141.12 -7,219.46 -3,863.68 5,922,783.37 477,222.14 1.20 6,552.76 MWD+IFR-AK-CAZ-SC(5) 13,600.07 90.44 196.91 6,287.99 6,140.49 -7,309.24 -3,890.57 5,922,693.67 477,195.03 0.53 6,615.07 MWD+IFR-AK-CAZ-SC(5) 13,693.94 90.48 198.24 6,287.23 6,139.73 -7,398.73 -3,918.91 5,922,604.26 477,166.47 1.42 6,678.58 MWD+IFR-AK-CAZ-SC(5) 13,789.83 89.22 197.15 6,287.48 6,139.98 -7,490.08 -3,948.05 5,922,513.00 477,137.10 1.74 6,743.60 MWD+IFR-AK-CAZ-SC(5) 13,884.99 89.34 196.96 6,288.68 6,141.18 -7,581.04 -3,975.96 5,922,422.11 477,108.97 0.24 6,807.33 MWD+IFR-AK-CAZ-SC(5) 13,979.49 88.64 195.85 6,290.35 6,142.85 -7,671.68 -4,002.65 5,922,331.55 477,082.06 1.39 6,869.82 MWD+I FR-AK-CAZ-SC(5) 14,074.78 88.74 195.06 6,292.52 6,145.02 -7,763.50 -4,028.03 5,922,239.80 477,056.44 0.84 6,931.63 MWD+IFR-AK-CAZ-SC(5) 14,168.83 90.23 194.38 6,293.37 6,145.87 -7,854.46 -4,051.93 5,922,148.91 477,032.32 1.74 6,991.73 MWD+IFR-AK-CAZ-SC(5) 14,265.49 88.62 194.68 6,294.34 6,146.84 -7,948.02 -4,076.18 5,922,055.42 477,007.84 1.69 7,053.25 MWD+IFR-AK-CAZ-SC(5) 14,345.00 88.62 194.68 6,296.25 6,148.75 -8,024.91 -4,096.32 5,921,978.59 476,987.51 0.00 7,104.00 PROJECTED to TD 11/24/2015 5.04:07PM Page 6 COMPASS 5000.1 Build 74 • • 215174 26580 RECEIVED 18 Liv FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-08 Definitive Survey Report 24 November, 2015 NAD 83 • 41/ Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-08 Well Position +N/-S 0.00 usft Northing: 5,929,742.01 usfl Latitude: 70° 13'10.502 N +E/-W 0.00 usft Easting: 1,621,136.82 usfl Longitude: 150°9'19.954 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-08 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 11/25/2015 18.47 80.87 57,487 Design 2S-08 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usfl) (usft) (0) 27.50 0.00 0.00 245.00 Survey Program Date 11/24/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 71.00 438.00 2S-08 Srvy#1 -Gyro Battery(2S-08) GYD-GC-MS Gyrodata gyrocompassing m/s 11/10/2015 2: 485.04 2,594.28 2S-08 Srvy#2-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 2: 2,695.86 7,076.67 2S-08 Srvy#3-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/20/2015 9: 7,171.07 7,171.07 2S-08 Srvy#4-INC ONLY(2S-08) INC+TREND Inclinometer+known azi trend 11/20/2015 9: 7,264.20 14,265.49 2S-08 Srvy#5-GMAG(2S-08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/20/2015 9:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,742.01 1,621,136.82 0.00 0.00 UNDEFINED 71.00 0.46 33.48 71.00 -76.50 0.15 0.10 5,929,742.15 1,621,136.92 1.06 -0.15 GYD-GC-MS(1) 107.50 0.54 31.92 107.50 -40.00 0.41 0.27 5,929,742.42 1,621,137.09 0.21 -0.42 NOT an Actual Survey 16"x20" 162.00 0.65 30.28 162.00 14.50 0.90 0.56 5,929,742.90 1,621,137.38 0.21 -0.88 GYD-GC-MS(1) 254.00 0.76 14.86 253.99 106.49 1.94 0.98 5,929,743.94 1,621,137.80 0.24 -1.70 GYD-GC-MS(1) 345.00 2.07 325.41 344.96 197.46 3.87 0.20 5,929,745.88 1,621,137.03 1.84 -1.82 GYD-GC-MS(1) 438.00 4.21 322.93 437.82 290.32 7.98 -2.81 5,929,749.99 1,621,134.03 2.31 -0.82 GYD-GC-MS(1) 485.04 4.78 322.64 484.71 337.21 10.92 -5.04 5,929,752.93 1,621,131.81 1.21 -0.04 MWD+IFR-AK-CAZ-SC(2) 578.31 5.65 324.07 577.59 430.09 17.72 -10.09 5,929,759.75 1,621,126.77 0.94 1.66 MWD+IFR-AK-CAZ-SC(2) 670.23 8.20 323.54 668.84 521.34 26.66 -16.65 5,929,768.71 1,621,120.24 2.77 3.82 MWD+IFR-AK-CAZ-SC(2) 11/24/2015 4:13:28PM Page 2 COMPASS 5000.1 Build 74 s • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 764.53 8.68 325.12 762.11 614.61 37.91 -24.71 5,929,779.97 1,621,112.21 0.57 6.38 MWD+IFR-AK-CAZ-SC(2) 856.01 9.57 324.53 852.44 704.94 49.76 -33.07 5,929,791.85 1,621,103.88 0.98 8.94 MWD+IFR-AK-CAZ-SC(2) 950.06 10.01 323.99 945.12 797.62 62.74 -42.41 5,929,804.85 1,621,094.57 0.48 11.93 MWD+IFR-AK-CAZ-SC(2) 1,043.14 10.28 324.34 1,036.74 889.24 76.03 -52.01 5,929,818.17 1,621,085.01 0.30 15.01 MWD+IFR-AK-CAZ-SC(2) 1,135.08 11.86 325.26 1,126.97 979.47 90.46 -62.18 5,929,832.62 1,621,074.88 1.73 18.12 MWD+IFR-AK-CAZ-SC(2) 1,228.47 13.52 328.24 1,218.07 1,070.57 107.63 -73.40 5,929,849.82 1,621,063.71 1.91 21.03 MWD+IFR-AK-CAZ-SC(2) 1,323.98 15.95 331.65 1,310.44 1,162.94 128.68 -85.51 5,929,870.89 1,621,051.65 2.70 23.11 MWD+IFR-AK-CAZ-SC(2) 1,417.11 17.17 332.45 1,399.70 1,252.20 152.13 -97.94 5,929,894.37 1,621,039.28 1.33 24.47 MWD+IFR-AK-CAZ-SC(2) 1,511.55 17.61 325.67 1,489.84 1,342.34 176.29 -112.45 5,929,918.56 1,621,024.84 2.19 27.41 MWD+IFR-AK-CAZ-SC(2) 1,602.63 18.20 316.23 1,576.52 1,429.02 197.94 -130.06 5,929,940.26 1,621,007.28 3.25 34.22 MWD+IFR-AK-CAZ-SC(2) 1,695.32 18.09 305.09 1,664.63 1,517.13 216.67 -151.85 5,929,959.04 1,620,985.53 3.74 46.06 MWD+IFR-AK-CAZ-SC(2) 1,788.92 18.02 292.46 1,753.66 1,606.16 230.56 -177.13 5,929,973.00 1,620,960.29 4.18 63.10 MWD+IFR-AK-CAZ-SC(2) 1,884.31 19.14 280.43 1,844.11 1,696.61 239.03 -206.16 5,929,981.54 1,620,931.29 4.18 85.83 MWD+IFR-AK-CAZ-SC(2) 1,978.23 19.25 272.13 1,932.82 1,785.32 242.40 -236.78 5,929,984.98 1,620,900.68 2.91 112.16 MWD+IFR-AK-CAZ-SC(2) 2,070.63 20.17 262.48 2,019.83 1,872.33 240.88 -267.80 5,929,983.54 1,620,869.66 3.66 140.91 MWD+IFR-AK-CAZ-SC(2) 2,162.32 22.27 260.67 2,105.30 1,957.80 235.99 -300.62 5,929,978.74 1,620,836.83 2.40 172.72 MWD+IFR-AK-CAZ-SC(2) 2,259.27 22.94 262.76 2,194.80 2,047.30 230.63 -337.50 5,929,973.48 1,620,799.95 1.08 208.41 MWD+IFR-AK-CAZ-SC(2) 2,352.62 24.51 259.54 2,280.26 2,132.76 224.82 -374.59 5,929,967.76 1,620,762.84 2.18 244.48 MWD+IFR-AK-CAZ-SC(2) 2,447.67 26.48 258.12 2,366.06 2,218.56 216.88 -414.72 5,929,959.92 1,620,722.70 2.17 284.20 MWD+IFR-AK-CAZ-SC(2) 2,541.77 27.44 258.59 2,449.93 2,302.43 208.27 -456.50 5,929,951.42 1,620,680.90 1.05 325.71 MWD+IFR-AK-CAZ-SC(2) 2,594.28 27.79 258.91 2,496.46 2,348.96 203.52 -480.37 5,929,946.74 1,620,657.02 0.72 349.35 MWD+IFR-AK-CAZ-SC(2) 2,652.40 29.37 259.35 2,547.49 2,399.99 198.28 -507.68 5,929,941.57 1,620,629.70 2.75 376.32 n NOT an Actual Survey 3) 10 3/4"x 13-1/2 2,695.86 30.56 259.66 2,585.14 2,437.64 194.33 -529.03 5,929,937.67 1,620,608.35 2.75 397.33 MWD+IFR-AK-CAZ-SC(3) 2,786.86 32.76 258.18 2,662.59 2,515.09 185.14 -575.89 5,929,928.59 1,620,561.46 2.56 443.69 MWD+IFR-AK-CAZ-SC(3) 2,879.96 30.48 257.80 2,741.87 2,594.37 174.98 -623.63 5,929,918.57 1,620,513.70 2.46 491.25 MWD+IFR-AK-CAZ-SC(3) 2,972.44 27.48 257.54 2,822.76 2,675.26 165.42 -667.40 5,929,909.12 1,620,469.91 3.25 534.96 MWD+IFR-AK-CAZ-SC(3) 3,065.25 28.31 258.80 2,904.79 2,757.29 156.53 -709.90 5,929,900.33 1,620,427.40 1.10 577.23 MWD+IFR-AK-CAZ-SC(3) 3,157.07 28.09 259.93 2,985.71 2,838.21 148.52 -752.54 5,929,892.43 1,620,384.74 0.63 619.27 MWD+IFR-AK-CAZ-SC(3) 3,250.49 28.00 263.93 3,068.17 2,920.67 142.35 -796.00 5,929,886.38 1,620,341.26 2.02 661.26 MWD+IFR-AK-CAZ-SC(3) 3,343.12 28.02 265.80 3,149.95 3,002.45 138.46 -839.33 5,929,882.60 1,620,297.93 0.95 702.17 MWD+IFR-AK-CAZ-SC(3) 3,435.53 28.05 263.93 3,231.51 3,084.01 134.57 -882.58 5,929,878.82 1,620,254.67 0.95 743.02 MWD+IFR-AK-CAZ-SC(3) 3,529.67 27.82 260.81 3,314.69 3,167.19 128.72 -926.28 5,929,873.08 1,620,210.97 1.57 785.09 MWD+IFR-AK-CAZ-SC(3) 3,622.09 28.30 261.07 3,396.25 3,248.75 121.88 -969.21 5,929,866.35 1,620,168.02 0.54 826.89 MWD+IFR-AK-CAZ-SC(3) 3,715.67 28.35 261.66 3,478.62 3,331.12 115.21 -1,013.11 5,929,859.80 1,620,124.11 0.30 869.50 MWD+IFR-AK-CAZ-SC(3) 3,808.04 27.71 258.29 3,560.16 3,412.66 107.67 -1,055.84 5,929,852.37 1,620,081.37 1.85 911.41 MWD+IFR-AK-CAZ-SC(3) 3,900.41 28.52 257.81 3,641.63 3,494.13 98.66 -1,098.42 5,929,843.46 1,620,038.76 0.91 953.81 MWD+IFR-AK-CAZ-SC(3) 3,997.15 28.48 257.95 3,726.65 3,579.15 88.97 -1,143.55 5,929,833.89 1,619,993.61 0.08 998.81 MWD+IFR-AK-CAZ-SC(3) 4,087.22 28.24 257.95 3,805.91 3,658.41 80.03 -1,185.40 5,929,825.06 1,619,951.75 0.27 1,040.51 MWD+IFR-AK-CAZ-SC(3) 4,181.15 28.43 257.90 3,888.58 3,741.08 70.71 -1,228.99 5,929,815.85 1,619,908.14 0.20 1,083.96 MWD+IFR-AK-CAZ-SC(3) 11/24/2015 4:13:28PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,273.93 28.59 258.19 3,970.11 3,822.61 61.53 -1,272.32 5,929,806.79 1,619,864.79 0.23 1,127.10 MWD+IFR-AK-CAZ-SC(3) 4,366.15 28.94 257.35 4,050.95 3,903.45 52.13 -1,315.68 5,929,797.50 1,619,821.40 0.58 1,170.38 MWD+IFR-AK-CAZ-SC(3) 4,458.53 28.82 257.13 4,131.84 3,984.34 42.28 -1,359.20 5,929,787.75 1,619,777.87 0.17 1,213.99 MWD+IFR-AK-CAZ-SC(3) 4,551.12 28.17 256.81 4,213.22 4,065.72 32.32 -1,402.24 5,929,777.91 1,619,734.81 0.72 1,257.20 MWD+IFR-AK-CAZ-SC(3) 4,644.32 27.00 255.71 4,295.82 4,148.32 22.08 -1,444.16 5,929,767.77 1,619,692.87 1.37 1,299.52 MWD+IFR-AK-CAZ-SC(3) 4,736.62 25.98 256.07 4,378.43 4,230.93 12.04 -1,484.08 5,929,757.84 1,619,652.92 1.12 1,339.95 MWD+IFR-AK-CAZ-SC(3) 4,831.48 26.72 254.86 4,463.44 4,315.94 1.47 -1,524.84 5,929,747.37 1,619,612.14 0.96 1,381.35 MWD+IFR-AK-CAZ-SC(3) 4,923.51 27.31 254.67 4,545.42 4,397.92 -9.52 -1,565.17 5,929,736.49 1,619,571.79 0.65 1,422.55 MWD+IFR-AK-CAZ-SC(3) 5,016.27 27.53 257.09 4,627.76 4,480.26 -19.93 -1,606.59 5,929,726.18 1,619,530.35 1.22 1,464.49 MWD+IFR-AK-CAZ-SC(3) 5,110.04 28.83 259.55 4,710.42 4,562.92 -28.88 -1,649.95 5,929,717.35 1,619,486.97 1.86 1,507.56 MWD+IFR-AK-CAZ-SC(3) 5,203.44 29.26 257.58 4,792.08 4,644.58 -37.87 -1,694.39 5,929,708.47 1,619,442.51 1.12 1,551.64 MWD+IFR-AK-CAZ-SC(3) 5,297.20 29.76 251.77 4,873.69 4,726.19 -50.08 -1,738.88 5,929,696.37 1,619,398.00 3.10 1,597.12 MWD+IFR-AK-CAZ-SC(3) 5,389.18 29.94 245.35 4,953.49 4,805.99 -66.80 -1,781.43 5,929,679.76 1,619,355.40 3.48 1,642.76 MWD+IFR-AK-CAZ-SC(3) 5,483.65 30.59 241.10 5,035.09 4,887.59 -88.25 -1,823.91 5,929,658.42 1,619,312.88 2.37 1,690.32 MWD+IFR-AK-CAZ-SC(3) 5,576.30 30.72 236.71 5,114.80 4,967.30 -112.64 -1,864.33 5,929,634.14 1,619,272.39 2.42 1,737.26 MWD+IFR-AK-CAZ-SC(3) 5,668.49 32.29 232.28 5,193.41 5,045.91 -140.63 -1,903.50 5,929,606.25 1,619,233.16 3.03 1,784.59 MWD+IFR-AK-CAZ-SC(3) 5,764.27 34.19 228.05 5,273.53 5,126.03 -174.28 -1,943.76 5,929,572.71 1,619,192.81 3.13 1,835.30 MWD+IFR-AK-CAZ-SC(3) 5,858.48 35.89 224.36 5,350.67 5,203.17 -211.73 -1,982.76 5,929,535.37 1,619,153.72 2.88 1,886.47 MWD+IFR-AK-CAZ-SC(3) 5,952.24 37.48 222.66 5,425.86 5,278.36 -252.36 -2,021.31 5,929,494.84 1,619,115.07 2.01 1,938.58 MWD+IFR-AK-CAZ-SC(3) 6,043.73 38.96 222.19 5,497.73 5,350.23 -294.14 -2,059.49 5,929,453.16 1,619,076.79 1.65 1,990.84 MWD+IFR-AK-CAZ-SC(3) 6,137.08 42.01 221.81 5,568.73 5,421.23 -339.18 -2,100.04 5,929,408.23 1,619,036.13 3.28 2,046.62 MWD+IFR-AK-CAZ-SC(3) 6,229.66 44.75 218.94 5,636.01 5,488.51 -387.63 -2,141.18 5,929,359.88 1,618,994.87 3.65 2,104.39 MWD+IFR-AK-CAZ-SC(3) 6,324.31 46.48 216.13 5,702.22 5,554.72 -441.27 -2,182.37 5,929,306.35 1,618,953.55 2.80 2,164.39 MWD+IFR-AK-CAZ-SC(3) 6,418.56 47.68 211.67 5,766.42 5,618.92 -498.55 -2,220.82 5,929,249.19 1,618,914.95 3.69 2,223.44 MWD+IFR-AK-CAZ-SC(3) 6,511.17 48.40 207.59 5,828.36 5,680.86 -558.39 -2,254.84 5,929,189.44 1,618,880.78 3.37 2,279.57 MWD+IFR-AK-CAZ-SC(3) 6,604.34 50.54 204.01 5,888.91 5,741.41 -622.14 -2,285.62 5,929,125.77 1,618,849.85 3.71 2,334.40 MWD+IFR-AK-CAZ-SC(3) 6,699.75 52.78 201.13 5,948.10 5,800.60 -691.24 -2,314.31 5,929,056.76 1,618,820.98 3.33 2,389.60 MWD+IFR-AK-CAZ-SC(3) 6,791.69 55.34 200.44 6,002.06 5,854.56 -760.82 -2,340.71 5,928,987.24 1,618,794.40 2.85 2,442.95 MWD+IFR-AK-CAZ-SC(3) 6,886.29 57.58 200.90 6,054.32 5,906.82 -834.59 -2,368.55 5,928,913.55 1,618,766.38 2.40 2,499.35 MWD+IFR-AK-CAZ-SC(3) 6,980.99 61.84 201.22 6,102.08 5,954.58 -910.88 -2,397.93 5,928,837.34 1,618,736.81 4.51 2,558.22 MWD+IFR-AK-CAZ-SC(3) 7,076.67 66.16 200.97 6,144.01 5,996.51 -991.10 -2,428.87 5,928,757.22 1,618,705.67 4.52 2,620.16 MWD+IFR-AK-CAZ-SC(3) 7,141.00 68.20 201.59 6,168.96 6,021.46 -1,046.35 -2,450.39 5,928,702.03 1,618,684.01 3.29 2,663.01 NOT anActual Survey 7-5/8"x 9-718"by 11" 7,171.07 69.15 201.87 6,179.90 6,032.40 -1,072.37 -2,460.76 5,928,676.04 1,618,673.57 3.29 2,683.41 INC+TREND(4) 7,264.20 70.23 202.96 6,212.22 6,064.72 -1,153.10 -2,494.07 5,928,595.39 1,618,640.07 1.60 2,747.71 MWD+IFR-AK-CAZ-SC(5) 7,358.82 71.85 200.88 6,242.97 6,095.47 -1,236.11 -2,527.46 5,928,512.48 1,618,606.46 2.69 2,813.06 MWD+IFR-AK-CAZ-SC(5) 7,410.37 72.94 198.64 6,258.56 6,111.06 -1,282.35 -2,544.07 5,928,466.28 1,618,589.74 4.65 2,847.66 MWD+IFR-AK-CAZ-SC(5) 7,453.04 74.01 199.40 6,270.70 6,123.20 -1,321.03 -2,557.40 5,928,427.65 1,618,576.31 3.03 2,876.08 MWD+IFR-AK-CAZ-SC(5) 7,499.36 75.35 198.94 6,282.93 6,135.43 -1,363.22 -2,572.07 5,928,385.50 1,618,561.53 3.05 2,907.21 MWD+IFR-AK-CAZ-SC(5) 7,547.86 77.33 197.68 6,294.39 6,146.89 -1,407.96 -2,586.87 5,928,340.80 1,618,546.62 4.80 2,939.53 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 4:13:28PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 7,593.84 79.82 196.35 6,303.50 6,156.00 -1,451.05 -2,600.06 5,928,297.74 1,618,533.32 6.11 2,969.69 MWD+IFR-AK-CAZ-SC(5) 7,642.79 82.68 196.51 6,310.94 6,163.44 -1,497.45 -2,613.74 5,928,251.38 1,618,519.52 5.85 3,001.70 MWD+IFR-AK-CAZ-SC(5) 7,689.90 84.74 196.51 6,316.10 6,168.60 -1,542.35 -2,627.05 5,928,206.53 1,618,506.10 4.37 3,032.74 MWD+IFR-AK-CAZ-SC(5) 7,738.63 86.56 195.57 6,319.80 6,172.30 -1,589.04 -2,640.47 5,928,159.87 1,618,492.56 4.20 3,064.64 MWD+IFR-AK-CAZ-SC(5) 7,785.59 88.35 194.22 6,321.88 6,174.38 -1,634.38 -2,652.53 5,928,114.57 1,618,480.39 4.77 3,094.73 MWD+IFR-AK-CAZ-SC(5) 7,832.94 89.82 195.36 6,322.64 6,175.14 -1,680.15 -2,664.61 5,928,068.84 1,618,468.19 3.93 3,125.02 MWD+IFR-AK-CAZ-SC(5) 7,927.35 93.39 193.34 6,320.00 6,172.50 -1,771.56 -2,688.00 5,927,977.50 1,618,444.57 4.34 3,184.85 MWD+IFR-AK-CAZ-SC(5) 8,022.22 93.63 191.91 6,314.19 6,166.69 -1,863.96 -2,708.70 5,927,885.16 1,618,423.64 1.53 3,242.66 MWD+IFR-AK-CAZ-SC(5) 8,117.20 90.50 192.13 6,310.77 6,163.27 -1,956.79 -2,728.46 5,927,792.39 1,618,403.64 3.30 3,299.80 MWD+IFR-AK-CAZ-SC(5) 8,212.14 90.42 189.87 6,310.00 6,162.50 -2,049.97 -2,746.58 5,927,699.26 1,618,385.29 2.38 3,355.60 MWD+IFR-AK-CAZ-SC(5) 8,307.26 92.16 188.74 6,307.86 6,160.36 -2,143.81 -2,761.95 5,927,605.47 1,618,369.68 2.18 3,409.19 MWD+IFR-AK-CAZ-SC(5) 8,401.37 90.75 192.70 6,305.47 6,157.97 -2,236.23 -2,779.45 5,927,513.11 1,618,351.95 4.47 3,464.11 MWD+IFR-AK-CAZ-SC(5) 8,495.84 89.84 191.36 6,304.98 6,157.48 -2,328.62 -2,799.14 5,927,420.78 1,618,332.02 1.71 3,521.00 MWD+IFR-AK-CAZ-SC(5) 8,588.36 90.28 188.98 6,304.89 6,157.39 -2,419.68 -2,815.47 5,927,329.77 1,618,315.46 2.62 3,574.28 MWD+IFR-AK-CAZ-SC(5) 8,682.37 89.07 187.83 6,305.42 6,157.92 -2,512.67 -2,829.21 5,927,236.82 1,618,301.48 1.78 3,626.04 MWD+IFR-AK-CAZ-SC(5) 8,779.02 87.93 189.01 6,307.95 6,160.45 -2,608.25 -2,843.36 5,927,141.29 1,618,287.09 1.70 3,679.25 MWD+IFR-AK-CAZ-SC(5) 8,872.45 89.65 188.44 6,309.92 6,162.42 -2,700.57 -2,857.53 5,927,049.01 1,618,272.69 1.94 3,731.11 MWD+IFR-AK-CAZ-SC(5) 8,967.66 91.27 190.39 6,309.16 6,161.66 -2,794.49 -2,873.10 5,926,955.15 1,618,256.88 2.66 3,784.91 MWD+IFR-AK-CAZ-SC(5) 9,061.75 91.39 190.21 6,306.98 6,159.48 -2,887.04 -2,889.92 5,926,862.65 1,618,239.82 0.23 3,839.27 MWD+IFR-AK-CAZ-SC(5) 9,157.73 92.39 187.94 6,303.81 6,156.31 -2,981.76 -2,905.05 5,926,767.98 1,618,224.45 2.58 3,893.01 MWD+IFR-AK-CAZ-SC(5) 9,251.65 92.43 188.35 6,299.86 6,152.36 -3,074.65 -2,918.34 5,926,675.13 1,618,210.92 0.44 3,944.32 MWD+IFR-AK-CAZ-SC(5) 9,346.59 92.49 189.49 6,295.79 6,148.29 -3,168.35 -2,933.05 5,926,581.48 1,618,195.98 1.20 3,997.25 MWD+IFR-AK-CAZ-SC(5) 9,440.61 91.67 190.31 6,292.37 6,144.87 -3,260.91 -2,949.20 5,926,488.97 1,618,179.59 1.23 4,051.01 MWD+IFR-AK-CAZ-SC(5) 9,536.52 91.50 190.68 6,289.72 6,142.22 -3,355.18 -2,966.67 5,926,394.75 1,618,161.89 0.42 4,106.67 MWD+IFR-AK-CAZ-SC(5) 9,631.01 91.82 190.10 6,286.98 6,139.48 -3,448.08 -2,983.70 5,926,301.91 1,618,144.62 0.70 4,161.37 MWD+IFR-AK-CAZ-SC(5) 9,725.86 90.81 190.20 6,284.81 6,137.31 -3,541.42 -3,000.41 5,926,208.62 1,618,127.67 1.07 4,215.96 MWD+IFR-AK-CAZ-SC(5) 9,820.77 90.18 191.17 6,283.99 6,136.49 -3,634.68 -3,018.01 5,926,115.41 1,618,109.84 1.22 4,271.33 MWD+IFR-AK-CAZ-SC(5) 9,915.66 91.05 191.77 6,282.97 6,135.47 -3,727.66 -3,036.88 5,926,022.48 1,618,090.73 1.11 4,327.72 MWD+IFR-AK-CAZ-SC(5) 10,009.52 91.02 192.50 6,281.27 6,133.77 -3,819.41 -3,056.60 5,925,930.80 1,618,070.77 0.78 4,384.38 MWD+IFR-AK-CAZ-SC(5) 10,104.17 90.36 194.16 6,280.13 6,132.63 -3,911.50 -3,078.42 5,925,838.77 1,618,048.72 1.89 4,443.07 MWD+IFR-AK-CAZ-SC(5) 10,197.86 90.64 194.24 6,279.31 6,131.81 -4,002.33 -3,101.41 5,925,748.02 1,618,025.51 0.31 4,502.28 MWD+IFR-AK-CAZ-SC(5) 10,245.39 92.51 194.10 6,278.01 6,130.51 -4,048.39 -3,113.04 5,925,701.99 1,618,013.76 3.95 4,532.29 MWD+IFR-AK-CAZ-SC(5) 10,292.56 92.21 193.50 6,276.07 6,128.57 -4,094.16 -3,124.28 5,925,656.25 1,618,002.40 1.42 4,561.82 MWD+IFR-AK-CAZ-SC(5) 10,387.20 92.70 193.15 6,272.01 6,124.51 -4,186.17 -3,146.07 5,925,564.31 1,617,980.38 0.64 4,620.46 MWD+IFR-AK-CAZ-SC(5) 10,481.67 93.04 194.41 6,267.28 6,119.78 -4,277.80 -3,168.54 5,925,472.74 1,617,957.67 1.38 4,679.55 MWD+IFR-AK-CAZ-SC(5) 10,577.69 92.56 195.13 6,262.59 6,115.09 -4,370.54 -3,192.99 5,925,380.08 1,617,932.99 0.90 4,740.90 MWD+IFR-AK-CAZ-SC(5) 10,670.30 91.05 195.58 6,259.67 6,112.17 -4,459.79 -3,217.50 5,925,290.89 1,617,908.25 1.70 4,800.84 MWD+IFR-AK-CAZ-SC(5) 10,765.46 88.92 196.25 6,259.70 6,112.20 -4,551.30 -3,243.60 5,925,199.46 1,617,881.93 2.35 4,863.16 MWD+IFR-AK-CAZ-SC(5) 10,859.10 87.57 195.38 6,262.57 6,115.07 -4,641.35 -3,269.10 5,925,109.49 1,617,856.20 1.71 4,924.33 MWD+IFR-AK-CAZ-SC(5) 10,954.37 87.56 194.11 6,266.61 6,119.11 -4,733.40 -3,293.33 5,925,017.51 1,617,831.74 1.33 4,985.19 MWD+IFR-AK-CAZSC(5) 11/24/2015 4:13:28PM Page 5 COMPASS 5000.1 Build 74 • S • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: 2S-08 North Reference: True Wellbore: 2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) , , (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,047.14 87.25 193.72 6,270.82 6,123.32 -4,823.35 -3,315.62 5,924,927.62 1,617,809.22 0.54 5,043.41 MWD+IFR-AK-CAZ-SC(5) 11,142.60 86.92 193.99 6,275.67 6,128.17 -4,915.91 -3,338.45 5,924,835.13 1,617,786.16 0.45 5,103.21 MWD+I FR-AK-CAZ-SC(5) 11,237.61 87.80 194.35 6,280.05 6,132.55 -5,007.93 -3,361.68 5,924,743.17 1,617,762.69 1.00 5,163.16 MWD+IFR-AK-CAZ-SC(5) 11,330.02 88.37 195.02 6,283.13 6,135.63 -5,097.28 -3,385.09 5,924,653.90 1,617,739.06 0.95 5,222.14 MWD+1FR-AK-CAZ-SC(5) 11,424.42 90.03 194.27 6,284.45 6,136.95 -5,188.60 -3,408.96 5,924,562.65 1,617,714.96 1.93 5,282.36 MWD+IFR-AK-CAZ-SC(5) 11,520.08 90.75 193.36 6,283.80 6,136.30 -5,281.48 -3,431.80 5,924,469.83 1,617,691.88 1.21 5,342.32 MWD+1FR-AK-CAZ-SC(5) 11,614.35 90.78 192.82 6,282.54 6,135.04 -5,373.30 -3,453.15 5,924,378.08 1,617,670.30 0.57 5,400.47 MWD+1FR-AK-CAZ-SC(5) 11,709.66 90.27 191.85 6,281.67 6,134.17 -5,466.40 -3,473.51 5,924,285.04 1,617,649.71 1.15 5,458.27 MWD+IFR-AK-CAZ-SC(5) 11,804.82 90.40 192.69 6,281.11 6,133.61 -5,559.38 -3,493.73 5,924,192.12 1,617,629.25 0.89 5,515.89 MWD+IFR-AK-CAZ-SC(5) 11,899.24 90.22 193.32 6,280.60 6,133.10 -5,651.38 -3,514.98 5,924,100.19 1,617,607.77 0.69 5,574.03 MWD+IFR-AK-CAZ-SC(5) 11,993.85 90.92 192.87 6,279.66 6,132.16 -5,743.53 -3,536.41 5,924,008.11 1,617,586.10 0.88 5,632.39 MWD+IFR-AK-CAZ-SC(5) 12,087.85 90.68 192.65 6,278.35 6,130.85 -5,835.19 -3,557.17 5,923,916.50 1,617,565.11 0.35 5,689.95 MWD+1FR-AK-CAZ-SC(5) 12,182.19 89.53 191.92 6,278.18 6,130.68 -5,927.37 -3,577.24 5,923,824.38 1,617,544.81 1.44 5,747.10 MWD+1FR-AK-CAZ-SC(5) 12,277.66 89.55 192.46 6,278.94 6,131.44 -6,020.69 -3,597.40 5,923,731.13 1,617,524.41 0.57 5,804.80 MWD+IFR-AK-CAZ-SC(5) 12,370.68 89.55 191.74 6,279.67 6,132.17 -6,111.64 -3,616.90 5,923,640.24 1,617,504.68 0.77 5,860.91 MW D+I FR-AK-CAZ-SC(5) 12,465.09 89.72 191.01 6,280.27 6,132.77 -6,204.19 -3,635.52 5,923,547.74 1,617,485.83 0.79 5,916.90 MWD+IFR-AK-CAZ-SC(5) 12,561.30 90.33 191.15 6,280.23 6,132.73 -6,298.61 -3,654.01 5,923,453.38 1,617,467.10 0.65 5,973.56 MW D+I FR-AK-CAZ-SC(5) 12,654.81 90.30 189.92 6,279.72 6,132.22 -6,390.54 -3,671.10 5,923,361.51 1,617,449.77 1.32 6,027.91 MWD+IFR-AK-CAZ-SC(5) 12,750.69 89.33 191.18 6,280.03 6,132.53 -6,484.79 -3,688.66 5,923,267.30 1,617,431.98 1.66 6,083.65 MWD+IFR-AK-CAZ-SC(5) 12,846.06 89.37 191.32 6,281.11 6,133.61 -6,578.32 -3,707.26 5,923,173.83 1,617,413.13 0.15 6,140.04 MWD+IFR-AK-CAZ-SC(5) 12,939.91 88.40 191.93 6,282.94 6,135.44 -6,670.23 -3,726.17 5,923,081.98 1,617,393.99 1.22 6,196.02 MWD+IFR-AK-CAZ-SC(5) 13,035.77 88.79 192.06 6,285.29 6,137.79 -6,763.97 -3,746.09 5,922,988.30 1,617,373.84 0.43 6,253.68 MWD+IFR-AK-CAZ-SC(5) 13,129.55 88.78 192.82 6,287.27 6,139.77 -6,855.52 -3,766.28 5,922,896.81 1,617,353.41 0.81 6,310.68 MWD+IFR-AK-CAZ-SC(5) 13,224.01 89.85 194.57 6,288.40 6,140.90 -6,947.29 -3,788.64 5,922,805.11 1,617,330.82 2.17 6,369.73 MWD+1FR-AK-CAZ-SC(5) 13,318.46 89.82 195.38 6,288.68 6,141.18 -7,038.53 -3,813.05 5,922,713.94 1,617,306.18 0.86 6,430.41 MWD+1FR-AK-CAZ-SC(5) 13,411.89 89.96 195.36 6,288.85 6,141.35 -7,128.62 -3,837.81 5,922,623.93 1,617,281.19 0.15 6,490.92 MWD+1FR-AK-CAZ-SC(5) 13,506.35 90.33 196.43 6,288.62 6,141.12 -7,219.46 -3,863.68 5,922,533.16 1,617,255.09 1.20 6,552.76 MWD+IFR-AK-CAZ-SC(5) 13,600.07 90.44 196.91 6,287.99 6,140.49 -7,309.24 -3,890.57 5,922,443.45 1,617,227.98 0.53 6,615.07 MWD+IFR-AK-CAZ-SC(5) 13,693.94 90.48 198.24 6,287.23 6,139.73 -7,398.73 -3,918.91 5,922,354.05 1,617,199.41 1.42 6,678.58 MWD+1FR-AK-CAZ-SC(5) 13,789.83 89.22 197.15 6,287.48 6,139.98 -7,490.08 -3,948.05 5,922,262.79 1,617,170.04 1.74 6,743.60 MWD+IFR-AK-CAZ-SC(5) 13,884.99 89.34 196.96 6,288.68 6,141.18 -7,581.04 -3,975.96 5,922,171.90 1,617,141.90 0.24 6,807.33 MWD+I FR-AK-CAZ-SC(5) 13,979.49 88.64 195.85 6,290.35 6,142.85 -7,671.68 -4,002.65 5,922,081.34 1,617,114.99 1.39 6,869.82 MWD+1FR-AK-CAZ-SC(5) 14,074.78 88.74 195.06 6,292.52 6,145.02 -7,763.50 -4,028.03 5,921,989.59 1,617,089.37 0.84 6,931.63 MWD+IFR-AK-CAZ-SC(5) 14,168.83 90.23 194.38 6,293.37 6,145.87 -7,854.46 -4,051.93 5,921,898.71 1,617,065.25 1.74 6,991.73 MWD+IFR-AK-CAZ-SC(5) 14,265.49 88.62 194.68 6,294.34 6,146.84 -7,948.02 -4,076.18 5,921,805.22 1,617,040.76 1.69 7,053.25 MWD+IFR-AK-CAZ-SC(5) 14,345.00 88.62 194.68 6,296.25 6,148.75 -8,024.91 -4,096.32 5,921,728.39 1,617,020.42 0.00 7,104.00 PROJECTED to TD 11/24/2015 4:13:28PM Page 6 COMPASS 5000.1 Build 74 • • 215174 16544 ConocoPhillips TRANSMITTAL -CONFIDENTIAL DATA /1/'o r A4 6_ FROM; Sandra D. Lemke,ATO3-0346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC R.O. Box 100360 333 W.7th Ave.,Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 2S-08 DATA LOGGED /5/201(p DATE: 12/04/2015 M. K.BENDER Transmitted: Ikuparuk River Unit, Alaska iteC e. ZS-08ift el DEC 14 20/5 1 CD&1 hardcopy report including 1 color prints each log: 44w _ Surface Data Logging End of Well report-Mud Log;2S-08; 11/17/2015; general information, daily summary, days vs. depth, after action review, Mud record, bit record, morning reports, Survey data;digital data includes: IFinal log files, final end of well report, Final LAS exports, Halliburton Log viewer, EMF log viewer 91 2" MD Formation Evaluation log 12"MD Drilling Engineering log 2"MD Gas ration log Please promptly sign, scan and return electronically to Sandra.D.Lemke0Conocophilllps.com CC: 25-08 transmittal folder, production well files, eSearch Receipt: MAL-0,17) GIS-Technical Data Management I ConocoPhillips I Anchorage,Alaska I Ph: 9072656947 • S Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, November 18, 2015 9:56 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-08 (PTD 215-174) Attachments: Signed_DS2S New Well 13.pdf 25-08: 5,929,992.42/481,103.5 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, November 18, 2015 9:40 AM To: Brunswick, Scott A Subject: [EXTERNAL]FW: KRU 2S-08 (PTD 215-174) Good morning Scott, As Habin is on the north slope, can you provide the information? Thank you, Patricia From: Bettis, Patricia K(DOA) Sent: Wednesday, November 18, 2015 9:34 AM To: Guo, Haibin (Haibin.Guo@conocophillips.com) <Haibin.Guo(cconocophillips.com> Subject: KRU 2S-08 (PTD 215-174) Good morning Habin, Please provide the As-Built survey for the surface location for the KRU 2S-08 conductor. On Form 10-401, Box 4b,the X and Y coordinates on the revised application is different from those coordinates on the original application, even though the footage remains the same. The As-Built Survey with X and Y coordinates (NAD 27) can be emailed to me.. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 • • 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 per K150013ACS 1] �fi 15 1 tE i] •16' .,-"'NOTES: a osz► L.___._ 1. BASIS OF LOCATION AND ELEVATION IS DS2S 24 19 20 21 22 23 MONUMENTATION PER LOUNSBURY & ASSOC. - 25 30 29 28 27 - • i• <6 27 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 29 ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES q`� ��_410111,,, / r. , ARE NAD 27. ' 36 " �,,.,i0 .:° nm 3. ELEVATIONS ARE B.P.M.S.L. f "I 4 3 ?) , 6 5 4 nm 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED o SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, , ] Pe16 9 10 1112 ' 9 0 10 UMIAT MERIDIAN. �w, 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS f;•/). �/ 19 V .6 ,g 19 i3 18 17 16 ,y w L15-28, L15-29, L15-32, L15-35, 11-13-2015 22 23 FIELD BOOK L15-75. 14 ,9 0 21 24 9 28 2 22 PROJECT LOCATION 6. ALL DISTANCES SHOWN ARE TRUE. 25 30 29 2i. 27 i6 25 30 29 .6 27 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR , 13. N VICINITY MAP NTS 36 1'6'.DS2S "i 6 4 • • • 12 .1° .• • 5• 3 2 1 14 • • • • 9 7 13 15 11 ..- --- LEGEND .- ,LEGEND O AS—BUILT CONDUCTOR LOCATION 17 16 • EXISTING CONDUCTOR LOCATIONS ` 20+21 GRAPHIC SCALE o ioI 200 400 i0_ LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. 1 inch = 200 ft. SURVEYORS ENGINEERS PLANNERS To `/ AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillipsDS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA—D2SX-6219D24 I 1 OF 2 I 2 • • tREV DATE DY 0< APP DESCRIPTION REV DATE DY CK APP DESCRIPTION J 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70° 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70° 13' 11.873" 150° 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150° 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70° 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70° 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150° 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70° 13' 11.436" 150° 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,948.70 480,898.09 70' 13' 11.187" 150° 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. 4 . F>;:o; ' p SURVEYOR'S CERTIFICATE p 49th °- $ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ° •• •• ••°° °� LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 0 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY fJEREMIAH F. CORNELL! 8e DONE BY ME OR UNDER MY DIRECT SUPERVISION AND • J+ LS-12663 ••: r THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT 4 'c •'•. SSS AS OF NOVEMBER 13, 2015. 1 I1`; ESSIONA0,1r `• r,.���r� LOUNSBURY & ASSOCIATES, INC. SUURVVEYORS ENGINEERS PLNNNERS 11I,/ AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillipsDS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION REV: 2 of 2 • 2 _. CALK6219d24 5/28/15 DRAw�Nc NO. CEA-D2SX-6219D24 PART: • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, November 18, 2015 9:40 AM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: FW: KRU 2S-08 (PTD 215-174) Good morning Scott, As Habin is on the north slope, can you provide the information? Thank you, Patricia From: Bettis, Patricia K(DOA) Sent: Wednesday, November 18, 2015 9:34 AM To: Guo, Haibin (Haibin.Guo@conocophillips.com)<Haibin.Guo@conocophillips.com> Subject: KRU 2S-08 (PTD 215-174) Good morning Habin, Please provide the As-Built survey for the surface location for the KRU 2S-08 conductor. On Form 10-401, Box 4b,the X and Y coordinates on the revised application is different from those coordinates on the original application, even though the footage remains the same. The As-Built Survey with X and Y coordinates (NAD 27) can be emailed to me.. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 ‘, 0 F • 47,\ I%%%4A THE STATE Alaska Oil and Gas LAsKA. Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 4Wp Main: 907.279.1433 ALA` Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-08 ConocoPhillips Alaska, Inc. Permit No: 215-174 (revised) Surface Location: 3056' FNL, 1467' FEL, SEC. 17, T1ON, RO8E, UM Bottomhole Location: 2337' FNL, 778' FEL, SEC. 30, T1ON, RO8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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, Cathy . Foerster Chair DATED this t 7 day of November, 2015. RECEIVED STATE OF ALASKA KA OIL AND GAS CONSERVATION CO ION NOV 0 9 2015 IIVISED PERMIT TO DRILL (215- 4) 20 AAC 25.005 A nrt re r• la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj Q • Single Zone ❑✓ - 1c.Specify if well is proposed for: Drill ❑✓ , Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. ' Bond No. 59-52-180 ' KRU 2S-08 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16226' . ND: 6429' i Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3056'FNL, 1467'FEL, Sec 17, T 10N,R008E,UM i ADL 25603,25608, Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4597'FNL,4003'FEL,Sec 17,T1ON,R008E,UM 2677,2681 11/3/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2337'FNL, 778'FEL, Sec 30,T1ON,R008E,UM 5035 , 3971 4b.Location of Well(State Base Plane Coordinates-NAD 27): tit 10.KB Elevation above MSL: 148 , feet 15.Distance to Nearest Well Open Surface: x- 4$11:5C4 y- 592560 Zone- 4 , GL Elevation above MSL: 120 t feet to Same Pool: 2S-07, 29' 44g1 /ol 5944942, 16.Deviated wells: Kickoff depth: • 450 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 90 degrees Downhole: 3922 psig - Surface: 3293 psig 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' pre-driven 13.5" 10.75" 45.5# L-80 Hydril 563 2709' 28' 28' 2737 2614 1131 sx DeepCRETE,205sx DeepCRETE 9.875"x 11" 7.625" 29.7# L-80 Hydril 563 7228' 28' 28' 7262 6191 875 sx 15.3ppg GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 9114' 7112' 6132' 16226' 6429' slotted liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Haibin Guo @ 265-1487 Email Haibin.Guo@cop.com Printed Name G.L Alvord Title Alaska Drilling Manager /Z6/5 Signature f6g,(„_ 4�LVL Ott Phone 265-6120 Date 1`/ . Commission Use Only Permit to Drill i API Number: Permit Approval See cover letter for other Number: 215-174 tev�`)@c.1. 50-103-20722-00-00 Date: \d /(e 12tl lS 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:d Other: if 3 5 O D ps g C J'' �;s j- Samples req'd: YesNo[d( Mud log req'd:Yes❑ No[' �� � \ HZS measures: Yes No 0/ Directional svy req'd:Yes[vrNo❑ 10,„4.-_,,,,_ I°I�` zs. Z. Spacing exception req'd: Yes❑ Nog Inclination-onlysvyreq'd:Yes❑ NOG!' rq� c 6L_ rw (r- 1r4 ,X) ,....,_,-,,j2‹,n,e. a 4--To 4 C-.) APPROVED BY Approved byCJ/ 99,..L.4 COMMISSIONER THE COMMISSION U-7Date: -� - 7� Q" OlgtiGviliNraths Submn Form ane Form 10-401(Revised 1oi2o12) from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • Application for Permit to Drill,Well 2S-08 Saved:2-Nov-15 Post Office Box 100360Nye' Anchorage,Alaska 99510-0360 ConocoPhillips Phone(907)263-4180 V October 30,2015 Alaska Oil and Gas Conservation Commission 333 West 7t"Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Revised Permit(215-174)to Drill Well 2S-08,a Kuparuk A4 Sand Pre-Produced Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a revised permit to drill an onshore grassroots pre-produced injector well from the 2S pad. The expected spud date for this well is November 4, 2015.It is planned to use rig Doyon 141. Revisions will be highlighted in Red The main changes are:new directional plan(wp12.1); enlarge intermediate hole size from 9-7/8"to 11";new intermediate cement program. 2S-08 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,737'MD/2,614'TVD.The intermediate section will be drilled with 9-7/8"bit with 11"under reamer and run 7-5/8"casing to 7,262'MD/6,19l'TVD.The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 16,226'MD/6,429'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 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 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. 8. Request for waiver of AOGCC regulation 20 AAC 25.412(b)on packer setting depth for injectors 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 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 Haibin Guo at 265-1487 (Haibin.Guo(a,conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager • • 0Y V Application forPermit to Dill Document Kuparuk Well 2S-08 ConocoPhiilips Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-08 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identiMng the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3056' FNL, 1467'FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 148'AMSL Northings: 5,929,992.42' Eastings: 481,103.50' Pad Elevation 120'AMSL Location at Intermediate 4204'FNL,3922'FEL, Sec 17,T10N,R008E,UM Casing NGS Coordinates Measured Depth, RKB: 7,262' Northings: 5,928,850.61' Eastings: 478,649.44' Total Vertical Depth, RKB: 6,191' Total Vertical Depth, SS: 6,043' Location at Total Depth 2337' FNL, 778'FEL, Sec 30,T10N,R008E,UM NGS Coordinates Measured Depth, RKB: 16,226' Northings: 5,920,164.51' Eastings: 476,517.68' Total Vertical Depth, RKB: 6,429' • Total Vertical Depth, SS: 6,281' and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. . • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4' An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-08 is calculated using an estimated maximum reservoir pressure of 3,922 psi (12.0 ppg, based on nearby recently drilled 2S wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6286' TVD (WP 12.1): C Sand Estimated. BHP = 3,922 psi '-" C Sand estimated depth(WP10) = 6,286' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =629 psi (6,286' TVD * 0.10 psi/ft) k;C— MPSP =BHP—gas column =3,293 psi (3,922 psi—629 psi) c.--- (B)data on potential gas:ones; The well bore is not expected to penetrate any shallow gas zones. And (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; See attached 2S-08 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(/); A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casingand Cementing Program Csg/Tbg Hole weigh Length Top MD/TVD Btm MD/TVD ize OD(in) Sin) t(Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,709 Surf 2,737/2,614 1,131 sx DeepCRETE Lead 11.0 ppg, 205 sx DeepCRETE Tail Slurry 12.0 ppg 9-7/8 x Hydril 875 sx Class G+GASBLOK at 15.3 ppg w/ 7-5/811 29.7 L-80 563 7,228 Surf 7,262/6,191 TOC at 4,652'MD 4 1/2 6-3/4 11.6 L-80 IBTM 9,114 7,112/6,132 16,226/6,429 Slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: • • (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematics on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8" Casing 4-1/2" Liner FLO-PRO NT Mud System Spud mud L D ' (WBM) Density 9.0- 10 9.2- 10.5) 10.5-12.6 PV 30-50 - 0 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 1-61/14Pi;> Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A- Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. • • Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,737' MD/2,614'TVD as per directional plan (wp 12.1). Survey with MWD,Gamma,Resistivity,Gyro. I 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 0i" 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16.0 ppg EMW leak off,recording results. 8. Directionally drill to intermediate TD of+/-7,262'MD/6,191' TVD with MPD(Managed Pressure Drilling)to keep near constant BHP for shale stability,and landing approximately at 50' TVD below the K-1 marker in the lower Kalubik Shale. Wellsite geologist will call intermediate TD. t' Il" Tp 9. Trip out of hole.Laydown intermediate BHA and rack back 5"DP. 10. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD. 11. Pump two stage cement job as per Schlumberger proposal. Top of cement first stage to be+1-4,652' MD(50' MD above top of Cairn formation),top of second stage to be+/1,500' MD(500' above C37). 12. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. I 13. Lay down 5"DP. 14. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope, Sonicscope and neutron density). 15. RIH and clean out cement to 100' above shoe. Mad pass with sonic log to verify top of cement on the way in the hole. Test intermediate casing to 3500 psi for 30 minutes. 16. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16.0 ppg EMW leak off,recording results. X17. Directionally drill 6-3/4"hole with MPD to control ECD and keep the hole over balanced,geosteering through the Kuparuk A4 sand to TD+/-16,226'MD as per directional plan(wp l 2.1). 18. Circulate hole clean and POOH. 19. Lay down Production BHA. 20. PU and run 4-1/2", 11.6#slotted liner. The top of liner will be placed at+/-7,112' MD,allowing for 150' of overlap in the 7-5/8"casing. NOTE: This will put the liner+/-566'MD/109' TVD above the top of the A4 reservoir,greater than the 200' MD required. ConocoPhillips requests a›ivtgrio use this well for injection with the packer at this depth. • 21. Set liner hanger. Slackoff and set liner top packer. 22. Monitor well for flow for 15 minutes 23. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 24. Flow check well for 30 minutes to run 3-1/2"upper completion. 25. Nipple down BOPE,nipple up tree and test. 26. Freeze protect well with diesel and install BPV. 27. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries Attachment 6 Request for Waiver of Packer Setting Depth 2S-08 Grassroots Horizontal A-Sand Injector ConocoPhillips Proposed Wellbore Schematic (Topset) a 1\ I ''CAMERON :: / 4-'W tree,top joint is 4-'/z" Last Edited: ;,0.) 12.6#IBTM Guo-10/29/2015 1O 16"Conductor to- :oo :-a & 115' E 13.5" Surface Hole •: 3 a co• • 3-'/"2.875"DS Landing • Nipple • • Surface Casing 10-3/4" 45.5# L-80 nu /2,737' MD 9-7/8" Intermediate Hol` ly.', 2,737' MD /3 2,614' TVD ' •I, L� 3-1/2" 9.3#L-80 EUE 8RD- MOD Tubing 4,652' MD/4,293'TVD ; * (-500' MD above C37) .. J t '-C;-37:5,152'MD/4,733'TVD CrQWre((fc°eberg): 5,4.15':MD/4,964':TVD \\\\ Bjker2.812"CMU SIi<ini \\\\\ 1st Stage TOC: 5,765'MD/5,471'TVD Slea„a JTop of Cairn/Bermuda) 3-1/2"2.75"D Nippl: ► ':•:•: ;::•. • °' Bermida/Cairr1::6;031 :MO:/5 472':ND 3'7"HES Mirage Di¢Ρap.•arin,� a 7-5/8"Flex Lock Lirerl Piny 4. -. Hanger/ZXP HRZ: 6,899' MD/6,034'TVD Kalubik:7,028'MD/6,095'TVD trjter di'iti i�SFng •-•. °K'uparuk A4 7,678 MO:/6,300'TVD 1 :p=5/S".:29:.701;40i H\45. Casi • - • a-r'or�n--I ' ALk2t�2`�I�f.8t91?TVD . :i .� . . . , . . , . . . . ._ I . . . •:. •:•:•:•:.:•:.:•:•:•:.:•:.:•:•::: o 0.', . . . . . . . .T•:.:•:.:•:.:. :.:•:•:•:•:.:•: :; III SI 2S-08wp12. 1 [Hammerheac 6 . 687 Plan Summary -Top W Sak(W Sak D) Growler-AA Top HRZ(K-2 mkr) ' - , ,( > 5- Top Calm Top Bermuda Kuparuk C(Top C4) -5 top i-3 Sand I C-35 __ A4 • I C-50 I K-1.5 MP. permafrost(' C-401 ' '' z -_Lower Kalubik(K-1 mkr) l Ba.-e W Sak , \ Upper Kalubik(bat HRZ) pa _ - o °/All'141111; 1 •i i \\C-37 Base Be dE C-8C ' I 0 l l I I�7-5/8 x 9-7/8"x 11'1 r I , I I I i 0ArtAllif-- ---(.11 iiiiIt°1111111114k 'tapir 0 4000 8000 12000 16000 rP ' 110-3/4"x 13-1/21' Measured Depth I • o-0' Geodetic Datum: North American Datum 1983 - '--.. 1000 110-3/4"x 13-1/21' Deptlh Reference: 2T5+120©147.50usft(Doyon141) / Rig: Doyon141 o 2.0(/ _ / to 3000 14 1/2"x 6-3/41 "" - ..... 4At�00 17-5/8"x 9-7/8"x 11'1 , \ o yoo4 0 0 0 0 0 0 0� "~ O r50 A'OO .° 0 0 0 0 0 0 0 0 \ON �^ X000 O O 0 N M V O \00 , _ _... r r r i r r r r = /{ l I I I I I I I I I I i I I I I I f I I I I I r I ' - 101 28 " 450 0 1500 3000 4500 6000 7500 9000 10500 12000 0 Horizontal Departure 450 - 640 330 30 640 - 840 840 - 1030 ' 1030 - 1220 i.O i� II • 1220 - 1420 _ - 300 ' `' . ,0 1420 - 1610 60 ,,,„1„,,r1,111,1111,1,!,II � Ib ,F_-.•` ' �y >>`•"sme+noe[samo"11610 - 1800 J.I. 1rllr •,� --; . �� 1800 : 2400 4 --:__ 111 � 1111 v n 2S- 0 / _ :-_. 2400 3000 °) �9i�Ill Ilinil ,I IIIM 1111 1111 • at111111' 1 t I- le✓ 3 vl 1,123 1 3000 - 3600 If. s,a 3600 - 4200 c` 2S\064\ 270 l�� 11��� /' 4200 - 4800 11111 wP [ =Imon] \ N�•�//w/�/,/�/, �°dofgor- 11,111101'1 1,,, , 4 :Nr, A s 4800 - 5400 d U G �S-09wk106[Tier '0 ,;,,a, `'a,, ,ri."/,r'ill 7 X1,0, • zsoswwew",5400 - 6000 ] 'd • ,�'A , 6000 - 6600 r 'L'( ' �i - 6600 - 7800 0 1500 3000 4500 6000 7500 9000 240 .w.t.4. ��r•=� 'do iegoer'>"I►i+��� ��� '1i%r01 �l X11 Se 7800 - sola SURVEY PROGRAM X460•, `r +4p 6'7,•7°./..', 9010 10210, Surface Location '6i4, I i-00, P + y--.� c��yl >flgR, e� _ l 10210 - Hato.; Depth From Depth To Survey/Plan Tool Pad Elevation: 120.00 14, �4►1r4 ,' -1 11410 1262027.50 450.00 450.00 1650.00 2S-08wwp12.1 p12.1 Hammerhead](Plan:2S-08 Plan:2S-08 INC+T MWDD 210 �n�� 4,,,b�r 150 12620 13820 450.00 2736.60 2S-08wp12.1 Hammerhead](PUPATE*,8H-AK-CAZ-SC 180 13820 15020 27.50 650.00 2S-08wp12.1 Hammerhead](Plan:2S-08)GYD-GC-SS CASING DETAILS 15020 - 16226 2736.60 4236.60 2S-08wp12.1 Hammerhead](Plan:2S-08) MWD 2736.60 7261.78 2S-08wp12.1 Hammerhead](PI01WP8083-AK-CAZ-SC TVD MD Name ' 7261.78 8761.78 2S-08wp12.1Hammerhead Plan:2S-08 MWD 2614.00 2736.60 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 7261.78 16225.93 2S-08wp12.1]Hammerhead](Plan 6190.50 7261.78 7-5/8"x 9-7/8"x11" Magnetic Model Date: 25-Nov-15 6428.64 16225.93 4 1/2"x 6-3/4" Magnetic Declination: 18.47° - To convert a Magnetic Direction to a True Direction,Add 18.47°East SECTION DETAILS =3g@cii)T-3 Sand Sec MD Inc Az! TVD ON/-S •E/-W Dleg TFace VSect Target Annotation 1 27.50 0.00 0.00 27.50 0.00 0.00 0.00 0.00 0.00 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,330°TF,for 150.04' K-15 Marker 3 600.04 2.25 330.00 600.00 2.55 -1.47 1.50 330.00 0.26 Start 2°/100'DLS,0°TF,for 751.51' 4 1351.55 17.28 330.00 1338.50 112.63 -65.03 2.00 0.00 11.33 Hold for 104.73' 5 1456.28 17.28 330.00 1438.50 139.57 -80.58 0.00 0.00 14.05 Start 3°/100'DLS,-102.88°TF,for 915.88' -1388.5 6 2372.16 28.64 260.20 2294.15 221.59 -370.46 3.00 -102.86 242.10 Hold for 2832.31' Base permafrost(? 7 5204.46 28.64 260.20 4779.94 -9.49 -1708.13 0.00 0,00 1552.10 Start 3°/100'DLS,-82.18°TF,for 2057.31' 8 7261.78 69.00 191.05 6190.50 -1148.25 -2451.31 3.00 -82.18 2706.91 2S-Hammerhead 0.Intermediate casing 102915 VOHold for 20' -1827.5 9 7281.78 69.00 191.05 6197.67 -1166.57 -2454.89 0.00 0.00 2717.90 Start 3°/100'DLS,0.1"TF,for 57.13' 10 7338.91 70.71 191.05 6217.34 -1219.21 -2465.17 3.00 0.10 2749.46 Hold for 19.42' Top W Sak(W Sak)) 11 7358.32 70.71 191.05 6223.75 -1237.20 -2468.68 0.00 0.00 2760.25 Start 3.5°/100'DLS,-0.14°TF,for 36.75' 12 7395.07 72.00 191.05 6235.50 -1271.37 -2475.38 3.50 -0.14 2780.74 2S-Hammerhead 1.Heel 102915 VO Adjust TF to 7.73°,for 514.45' -2563.5 13 7909.52 89.85 193.43 6316.31 -1785.73 -2582.89 3.50 7.73 3087.12 Hold for 6130.35' Base W Sak 14 14039.87 89.85 193.43 8332.09 -7728.33 -4007.07 0.00 0.00 6897.77 Start 3°/100'DLS,145.4°TF,for 75.03' -2803.5 15 14114.89 88.00 194.71 6333.50 -7801.09 -4025.31 3.00 145.40 6945.05 2S-Hammerhead 2.2nd point 002115 PB Start 2°/100'DLS,-180°TF,for 29.36' 16 14144.25 87.41 194.71 8334.67 -7829.48 -4032.78 2.00 180.00 6983.79 Hold for 1081.88' 17 15225.93 87.41 194.71 8383.50 -8874.61 -4307.18 0.00 0.00 7654.21 2S-Hammerhead 3.Toe 092115 Adjust IF to 0°,for 1000' 18 16225.93 87.41 194.71 6428.64 -9840.84 -4560.89 0.00 0.00 8292.49 TD:18225.93'MD,6428.84'ND C-80 -4165.5 C-50 Permit Pack 495' -4983.5 Growler-AA _lai@gi1)4a C-35 -i2pf A ghlmta,kr)z) E signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vinent Osara Adam Sallee Ifeanyi Ifesie I p 72 i � lig O.�N 2' N N • O p} eft Northing (orthin 4 Q7 N N NY YN N CV USfUIn) , I I 1=1 I I 1 1 1 1 1 rh IQ - -..,1,,% C4 Tfr " O 0 n O N Q Q r `1 ., L.. N NN a N J 1� \: " N C-r = I‘00 •:.. ..44111./ O p Q N N N '-'•li 1 Q N Q N MM O N " O N N 4o, Y f6 y , O J i‘ `�' CO g V N i O o O N CO3 N I. O fn O N O N cv 4) CNI _------....._,.......„.....„.... ...:2? .1. a)" co 13 ai M O (n O_ O N C'') N N 73 N N ?� M ,L c C11 _--\ O ars) m O o coO d N N CO J N p1 N /`/�q I-- - M M M NJ O C_ < 2 N g L...."................................................ C\ti ( Cr 0 O - CS) N N S- -7,.../4,410 I "0 CO N a,� 0 CD- N M Oi I• • CI W _ cM� J` M`�` n N I W a I i — N O N ,` O i 9 Ia. . Oa N \ ` O y O G �l� " M= N - �, N m CD M " Qin O O o O p - M - m M w .- Z •:. N II. M N N 2 O Z . - .. M N N O _ 1 / co CO J - J M " .r CO h " J a6 03 d = �± N . ��I (.0 A. J M J CO O N «) J N J Co — N J i;A M Ca. 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N c3. o T- o _o a 6 o 0 N ' 00 ..z.-- Co C 1 0 0 0 0 0 tin oN0 000 0 N I (uu4sn oobz) (+)u�aoN/(')uunoS I • 410 0 0 o IPeayaawwe Hi VZldmgo-sZ ' o a) \ o -0 ._ rn 8660k \ C ' 0 0004F X o .NMI (110) 000171. _ Cl)a) 000sL o o c o 000Z1. 1 cfl n 0 00006o r O o 00001. o 0 0006 N pi., c- 13 00080 0 CC o 0fi QD ®� Cr) cn EC O , X Sim O( - CD O °O N- • 00 co E °OO0 � < EO O00� , coR.!r$ Oo N I :�� °o C N ro o M X ■ 4 N co 0 T— 00 I o o 0 0 0 0 o o N- Cn Lc) co CD N- N N (u!/Tjsn 0090 Ludaa !ea!1aan emu_ 0 • [Pea .raw • 9ZZ91;:.,,a 00096 O —o co oL8 6 56 x 000 x , III MEM = O N C 000176 O V NMI 411.1 V obost. COco __ ,.--- 0010ZI- o CD O o C) 00006 _ o O N Nr 0000 ° a Y U cn o To MC D co 0L. 0006 _ > YE O J ‘ t E \ \\ \ ‘ ,\ 0008 OO N CO I _ • -av X 0 VII. 0 e Ii N N �' X C No O co 00 CZ c o co o o N CO CONr N co <rui/}4sn 09) AG le3! J8A anal co co • • IPeagJawwe 0000 HJ 6'ZI, mgo-SZ rCCi o -Lr) N- 000171. 00017 X 6 (V r /1♦ 000E I- �/ O ■— _O > 000Z6 CD o C 00®®6 0 O III NMI ima 00001, -0 v a) 0006 Cl) 0008 __ o Off® 0= o = x 0 oa o•�, • th o �� x o Lsi • 61 `r' r �7 Op �c-1 (NI u o O ti 3 I 0 0CC N �� - v a) O r —� N- U) EN O u) Co (a 0 x = /L` a) - A Co '-- 17(1Z > EO O O E , _.r as IO V O O Co N v o Q. ts-07 Co O O 1 0 0 0 0 0 0 Lc) o in 0 r r Co m N- N (uoisn 0086) 43daa Ieai1an enii • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-08 Plan: 2S-08 Plan: 2S-08wp12.1 [Hammerhead] Report 30 October, 2015 Permit Pack Schlumberger Comments apply to Report the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 Project Kuparuk River Unit,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 Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well Plan:2S-08 -d . . . Well Position +N/-S 0.00 usft Northing: usfi Latitude: +EI-W 0.00 usft Easting: usfi Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan:2S-08 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 11/25/2015 18.47 80.87 57,487 Design 2S-08wp12.1 [Hammerhead] Audit Notes: Version: Phase: PLAN Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 245.00 Survey Tool Program Date 10/30/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 27.50 450.00 2S-08wp12.1 [Hammerhead](Plan:2S-08 INC+TREND Inclinometer+known azi trend 450.00 1,650.00 2S-08wp12.1 [Hammerhead](Plan:2S-08 MWD MWD-Standard 450.00 2,736.60 2S-08wp12.1 [Hammerhead](Plan:2S-08 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 27.50 650.00 2S-08wp12.1 [Hammerhead](Plan:2S-08 GYD-GC-SS Gyrodata gyro single shots 2,736.60 4,236.60 2S-08wp12.1 [Hammerhead](Plan:2S-08 MWD MWD-Standard 2,736.60 7,261.78 2S-08wp12.1 [Hammerhead](Plan:2S-08 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,261.78 8,761.78 2S-08wp12.1 [Hammerhead](Plan:2S-08 MWD MWD-Standard 7,261.78 16,225.93 2S-08wp12.1 [Hammerhead](Plan:2S-08 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey xw MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -47.50 0.00 0.00 0.48 200.00 0.00 0.00 200.00 52.50 0.00 0.00 1.65 282.50 0.00 0.00 282.50 135.00 0.00 0.00 2.70 top T-3 Sand 300.00 0.00 0.00 300.00 152.50 0.00 0.00 2.70 10/30/2015 4:07:08PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 366.50 0.00 0.00 366.50 219.00 0.00 0.00 3.72 K-15 Marker 400.00 0.00 0.00 400.00 252.50 0.00 0.00 3.72 450.00 0.00 0.00 450.00 302.50 0.00 0.00 4.20 KOP:Start 1.5°/100'DLS,330°TF,for 150.04' 500.00 0.75 330.00 500.00 352.50 1.50 330.00 4.44 600.00 2.25 330.00 599.96 452.46 1.50 0.00 4.44 600.04 2.25 330.00 600.00 452.50 1.50 0.00 4.44 Start 2°/100'DLS,0°TF,for 751.51' 700.00 4.25 330.00 699.80 552.30 2.00 0.00 4.45 800.00 6.25 330.00 799.37 651.87 2.00 0.00 4.46 900.00 8.25 330.00 898.57 751.07 2.00 0.00 4.49 1,000.00 10.25 330.00 997.26 849.76 2.00 0.00 4.53 1,100.00 12.25 330.00 1,095.33 947.83 2.00 0.00 4.59 1,200.00 14.25 330.00 1,192.67 1,045.17 2.00 0.00 4.69 1,300.00 16.25 330.00 1,289.14 1,141.64 2.00 0.00 4.83 1,351.55 17.28 330.00 1,338.50 1,191.00 2.00 0.00 4.92 Hold for 104.73' 1,400.00 17.28 330.00 1,384.76 1,237.26 0.00 0.00 5.02 1,403.91 17.28 330.00 1,388.50 1,241.00 0.00 0.00 5.14 Base permafrost(?) 1,456.28 17.28 330.00 1,438.50 1,291.00 0.00 0.00 5.14 Start 3°/100'DLS,-102.86°TF,for 915.88' 1,500.00 17.04 325.63 1,480.28 1,332.78 3.00 -102.86 5.23 1,600.00 16.84 315.34 1,575.96 1,428.46 3.00 -98.69 5.38 1,700.00 17.15 305.12 1,671.62 1,524.12 3.00 -88.84 4.76 1,800.00 17.96 295.53 1,766.98 1,619.48 3.00 -79.07 4.80 1,863.75 18.70 289.92 1,827.50 1,680.00 3.00 -69.92 4.86 Top W Sak(W Sak D) 1,900.00 19.19 286.93 1,861.78 1,714.28 3.00 -64.59 4.86 2,000.00 20.77 279.46 1,955.78 1,808.28 3.00 -61.76 4.92 2,100.00 22.63 273.08 2,048.70 1,901.20 3.00 -54.74 4.99 2,200.00 24.70 267.68 2,140.29 1,992.79 3.00 -48.82 5.08 2,300.00 26.94 263.09 2,230.31 2,082.81 3.00 -43.86 5.18 2,372.16 28.64 260.20 2,294.15 2,146.65 3.00 -39.73 5.27 Hold for 2832.31' 2,400.00 28.64 260.20 2,318.58 2,171.08 0.00 0.00 5.31 2,500.00 28.64 260.20 2,406.35 2,258.85 0.00 0.00 5.47 2,600.00 28.64 260.20 2,494.11 2,346.61 0.00 0.00 5.65 2,679.06 28.64 260.20 2,563.50 2,416.00 0.00 0.00 5.84 Base W Sak 2,700.00 28.64 260.20 2,581.88 2,434.38 0.00 0.00 5.84 2,736.60 28.64 260.20 2,614.00 2,466.50 0.00 0.00 4.87 10-3/4"x 13-1/2" 2,800.00 28.64 260.20 2,669.64 2,522.14 0.00 0.00 4.87 10/30/2015 4:07:08PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 2,900.00 28.64 260.20 2,757.41 2,609.91 0.00 0.00 5.00 2,952.51 28.64 260.20 2,803.50 2,656.00 0.00 0.00 5.24 C-80 3,000.00 28.64 260.20 2,845.18 2,697.68 0.00 0.00 5.24 3,100.00 28.64 260.20 2,932.94 2,785.44 0.00 0.00 5.58 3,200.00 28.64 260.20 3,020.71 2,873.21 0.00 0.00 6.01 3,300.00 28.64 260.20 3,108.47 2,960.97 0.00 0.00 6.50 3,400.00 28.64 260.20 3,196.24 3,048.74 0.00 0.00 7.05 3,500.00 28.64 260.20 3,284.01 3,136.51 0.00 0.00 7.64 3,600.00 28.64 260.20 3,371.77 3,224.27 0.00 0.00 8.26 3,700.00 28.64 260.20 3,459.54 3,312.04 0.00 0.00 8.91 3,800.00 28.64 260.20 3,547.30 3,399.80 0.00 0.00 9.58 3,900.00 28.64 260.20 3,635.07 3,487.57 0.00 0.00 10.27 4,000.00 28.64 260.20 3,722.84 3,575.34 0.00 0.00 10.96 4,100.00 28.64 260.20 3,810.60 3,663.10 0.00 0.00 11.67 4,200.00 28.64 260.20 3,898.37 3,750.87 0.00 0.00 12.39 4,300.00 28.64 260.20 3,986.13 3,838.63 0.00 0.00 7.16 4,400.00 28.64 260.20 4,073.90 3,926.40 0.00 0.00 7.41 4,500.00 28.64 260.20 4,161.66 4,014.16 0.00 0.00 7.67 4,504.37 28.64 260.20 4,165.50 4,018.00 0.00 0.00 7.93 C-50 4,600.00 28.64 260.20 4,249.43 4,101.93 0.00 0.00 7.93 4,700.00 28.64 260.20 4,337.20 4,189.70 0.00 0.00 8.20 4,800.00 28.64 260.20 4,424.96 4,277.46 0.00 0.00 8.48 4,900.00 28.64 260.20 4,512.73 4,365.23 0.00 0.00 8.76 5,000.00 28.64 260.20 4,600.49 4,452.99 0.00 0.00 9.04 5,033.05 28.64 260.20 4,629.50 4,482.00 0.00 0.00 9.33 C-40 5,100.00 28.64 260.20 4,688.26 4,540.76 0.00 0.00 9.33 5,151.55 28.64 260.20 4,733.50 4,586.00 0.00 0.00 9.62 C-37 5,200.00 28.64 260.20 4,776.03 4,628.53 0.00 0.00 9.62 5,204.46 28.64 260.20 4,779.94 4,632.44 0.00 0.00 9.63 Start 3°l100'DLS,-82.18°TF,for 2057.31' 5,300.00 29.16 254.36 4,863.60 4,716.10 3.00 -82.18 9.80 5,400.00 29.96 248.50 4,950.60 4,803.10 3.00 -77.07 9.83 5,414.89 30.10 247.65 4,963.50 4,816.00 3.00 -71.96 9.82 Growler-AA 5,500.00 31.01 242.96 5,036.80 4,889.30 3.00 -71.23 9.82 5,600.00 32.28 237.77 5,121.95 4,974.45 3.00 -67.19 9.76 5,700.00 33.74 232.97 5,205.82 5,058.32 3.00 -62.77 9.69 5,800.00 35.38 228.54 5,288.18 5,140.68 3.00 -58.74 9.62 5,900.00 37.17 224.46 5,368.81 5,221.31 3.00 -55.09 9.54 6,000.00 39.08 220.72 5,447.48 5,299.98 3.00 -51.81 9.48 10/30/2015 4:07:08PM Page 4 COMPASS 5000.1 Build 74 0 Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120©147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True , Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 ; Planned Survey ____.,.,� , , R"R'k�5ev�%rs, is *i a %a �"Vr�sf� ,^»�,,,�r�v��� 4 { �^.� ;ss�' a �~`.4 z. MD Inc Azi(azimuth) TVD TVDSS DLeg TEace Lat.Error (usft) (0) (0) (usft) (usft) (°1100usft) (0) (usft) 6,031.08 39.70 219.62 5,471.50 5,324.00 3.00 -48.86 9.45 Top Cairn 6,100.00 41.11 217.29 5,523.98 5,376.48 3.00 -48.01 9.45 6,174.58 42.68 214.90 5,579.50 5,432.00 3.00 -46.23 9.43 Top Bermuda 6,200.00 43.23 214.12 5,598.10 5,450.60 3.00 -44.46 9.43 6,279.94 44.98 211.77 5,655.50 5,508.00 3.00 -43.89 9.45 Base Bermuda 6,300.00 45.43 211.20 5,669.64 5,522.14 3.00 -42.20 9.45 6,337.13 46.27 210.18 5,695.50 5,548.00 3.00 -41.80 9.50 C-35 6,400.00 47.70 208.50 5,738.39 5,590.89 3.00 -41.08 9.50 6,500.00 50.03 205.99 5,804.18 5,656.68 3.00 -39.94 9.58 6,600.00 52.41 203.64 5,866.82 5,719.32 3.00 -38.29 9.69 6,700.00 54.83 201.44 5,926.13 5,778.63 3.00 -36.82 9.84 6,800.00 57.29 199.37 5,981.97 5,834.47 3.00 -35.51 10.02 6,898.68 59.75 197.44 6,033.50 5,886.00 3.00 -34.36 10.23 Top HRZ(K-2 mkr) 6,900.00 59.78 197.41 6,034.16 5,886.66 3.00 -33.35 10.23 7,000.00 62.30 195.55 6,082.58 5,935.08 3.00 -33.33 10.48 7,028.12 63.01 195.04 6,095.50 5,948.00 3.00 -32.43 10.75 Upper Kalubik(base HRZ) 7,100.00 64.84 193.77 6,127.09 5,979.59 3.00 -32.20 10.75 7,200.00 67.41 192.07 6,167.56 6,020.06 3.00 -31.64 11.05 7,261.78 69.00 191.05 6,190.50 6,043.00 3.00 -30.95 11.25 Hold for 20'-Lower Kalubik(K-1 mkr)-7-518"x9-7/8"x11" 7,281.78 69.00 191.05 6,197.67 6,050.17 0.00 -30.57 11.36 Start 3°/100'DLS,0.1°TF,for 57.13' 7,300.00 69.55 191.05 6,204.12 6,056.62 3.00 0.10 11.46 7,338.91 70.71 191.05 6,217.34 6,069.84 3.00 0.10 11.70 Hold for 19.42' 7,358.32 70.71 191.05 6,223.75 6,076.25 0.00 0.00 11.82 Start 3.5°/100'DLS,-0.14°TF,for 36.75' 7,395.07 72.00 191.05 6,235.50 6,088.00 3.50 -0.14 12.07 Adjust TF to 7.73°,for 514.45' 7,400.00 72.17 191.07 6,237.02 6,089.52 3.50 7.73 12.11 7,500.00 75.64 191.56 6,264.73 6,117.23 3.50 7.72 12.94 7,594.29 78.91 192.00 6,285.50 6,138.00 3.50 7.59 13.89 Kuparuk C(Top C4) 7,600.00 79.11 192.03 6,286.59 6,139.09 3.50 7.49 13.89 7,677.92 81.81 192.39 6,299.50 6,152.00 3.50 7.49 14.94 A4 7,700.00 82.58 192.49 6,302.50 6,155.00 3.50 7.43 14.94 7,800.00 86.05 192.94 6,312.40 6,164.90 3.50 7.41 16.06 7,900.00 89.52 193.39 6,316.26 6,168.76 3.50 7.37 17.25 10/30/2015 4:07:08PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120© 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (0) (usft) 7,909.52 89.85 193.43 6,316.31 6,168.81 3.50 7.35 17.36 Hold for 6130.35' 8,000.00 89.85 193.43 6,316.55 6,169.05 0.00 0.00 18.44 8,100.00 89.85 193.43 6,316.81 6,169.31 0.00 0.00 19.66 8,200.00 89.85 193.43 6,317.06 6,169.56 0.00 0.00 20.91 8,300.00 89.85 193.43 6,317.32 6,169.82 0.00 0.00 22.19 8,400.00 89.85 193.43 6,317.58 6,170.08 0.00 0.00 23.50 8,500.00 89.85 193.43 6,317.83 6,170.33 0.00 0.00 24.82 8,600.00 89.85 193.43 6,318.09 6,170.59 0.00 0.00 26.16 8,700.00 89.85 193.43 6,318.35 6,170.85 0.00 0.00 27.51 8,800.00 89.85 193.43 6,318.61 6,171.11 0.00 0.00 16.44 8,900.00 89.85 193.43 6,318.86 6,171.36 0.00 0.00 16.88 9,000.00 89.85 193.43 6,319.12 6,171.62 0.00 0.00 17.32 9,100.00 89.85 193.43 6,319.38 6,171.88 0.00 0.00 17.77 9,200.00 89.85 193.43 6,319.64 6,172.14 0.00 0.00 18.23 9,300.00 89.85 193.43 6,319.89 6,172.39 0.00 0.00 18.69 9,400.00 89.85 193.43 6,320.15 6,172.65 0.00 0.00 19.16 9,500.00 89.85 193.43 6,320.41 6,172.91 0.00 0.00 19.64 9,600.00 89.85 193.43 6,320.67 6,173.17 0.00 0.00 20.12 9,700.00 89.85 193.43 6,320.92 6,173.42 0.00 0.00 20.61 9,800.00 89.85 193.43 6,321.18 6,173.68 0.00 0.00 21.10 9,900.00 89.85 193.43 6,321.44 6,173.94 0.00 0.00 21.60 10,000.00 89.85 193.43 6,321.70 6,174.20 0.00 0.00 22.10 10,100.00 89.85 193.43 6,321.95 6,174.45 0.00 0.00 22.60 10,200.00 89.85 193.43 6,322.21 6,174.71 0.00 0.00 23.11 10,300.00 89.85 193.43 6,322.47 6,174.97 0.00 0.00 23.62 10,400.00 89.85 193.43 6,322.73 6,175.23 0.00 0.00 24.13 10,500.00 89.85 193.43 6,322.98 6,175.48 0.00 0.00 24.65 10,600.00 89.85 193.43 6,323.24 6,175.74 0.00 0.00 25.17 10,700.00 89.85 193.43 6,323.50 6,176.00 0.00 0.00 25.69 10,800.00 89.85 193.43 6,323.75 6,176.25 0.00 0.00 26.21 10,900.00 89.85 193.43 6,324.01 6,176.51 0.00 0.00 26.74 11,000.00 89.85 193.43 6,324.27 6,176.77 0.00 0.00 27.27 11,100.00 89.85 193.43 6,324.53 6,177.03 0.00 0.00 27.80 11,200.00 89.85 193.43 6,324.78 6,177.28 0.00 0.00 28.33 11,300.00 89.85 193.43 6,325.04 6,177.54 0.00 0.00 28.86 11,400.00 89.85 193.43 6,325.30 6,177.80 0.00 0.00 29.40 11,500.00 89.85 193.43 6,325.56 6,178.06 0.00 0.00 29.94 11,600.00 89.85 193.43 6,325.81 6,178.31 0.00 0.00 30.48 11,700.00 89.85 193.43 6,326.07 6,178.57 0.00 0.00 31.02 11,800.00 89.85 193.43 6,326.33 6,178.83 0.00 0.00 31.56 11,900.00 89.85 193.43 6,326.59 6,179.09 0.00 0.00 32.10 12,000.00 89.85 193.43 6,326.84 6,179.34 0.00 0.00 32.65 12,100.00 89.85 193.43 6,327.10 6,179.60 0.00 0.00 33.19 12,200.00 89.85 193.43 6,327.36 6,179.86 0.00 0.00 33.74 10/30/2015 4:07:08PM Page 6 COMPASS 5000.1 Build 74 ISchlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 12,300.00 89.85 193.43 6,327.62 6,180.12 0.00 0.00 34.29 12,400.00 89.85 193.43 6,327.87 6,180.37 0.00 0.00 34.83 12,500.00 89.85 193.43 6,328.13 6,180.63 0.00 0.00 35.38 12,600.00 89.85 193.43 6,328.39 6,180.89 0.00 0.00 35.94 12,700.00 89.85 193.43 6,328.65 6,181.15 0.00 0.00 36.49 12,800.00 89.85 193.43 6,328.90 6,181.40 0.00 0.00 37.04 12,900.00 89.85 193.43 6,329.16 6,181.66 0.00 0.00 37.59 13,000.00 89.85 193.43 6,329.42 6,181.92 0.00 0.00 38.15 13,100.00 89.85 193.43 6,329.67 6,182.17 0.00 0.00 38.70 13,200.00 89.85 193.43 6,329.93 6,182.43 0.00 0.00 39.26 13,300.00 89.85 193.43 6,330.19 6,182.69 0.00 0.00 39.81 13,400.00 89.85 193.43 6,330.45 6,182.95 0.00 0.00 40.37 13,500.00 89.85 193.43 6,330.70 6,183.20 0.00 0.00 40.93 13,600.00 89.85 193.43 6,330.96 6,183.46 0.00 0.00 41.48 13,700.00 89.85 193.43 6,331.22 6,183.72 0.00 0.00 42.04 13,800.00 89.85 193.43 6,331.48 6,183.98 0.00 0.00 42.60 13,900.00 89.85 193.43 6,331.73 6,184.23 0.00 0.00 43.16 14,000.00 89.85 193.43 6,331.99 6,184.49 0.00 0.00 43.72 14,039.87 89.85 193.43 6,332.09 6,184.59 0.00 0.00 43.94 Start 3°/100'DLS,145.4°TF,for 75.03' 14,100.00 88.37 194.46 6,333.03 6,185.53 3.00 145.40 44.17 14,114.89 88.00 194.71 6,333.50 6,186.00 3.00 145.38 44.18 Start 2°/100'DLS,-180°TF,for 29.36' 14,144.25 87.41 194.71 6,334.67 6,187.17 2.00 -180.00 44.17 Hold for 1081.68' 14,200.00 87.41 194.71 6,337.19 6,189.69 0.00 177.90 44.30 14,300.00 87.41 194.71 6,341.71 6,194.21 0.00 0.00 44.86 14,400.00 87.41 194.71 6,346.22 6,198.72 0.00 0.00 45.42 14,500.00 87.41 194.71 6,350.73 6,203.23 0.00 0.00 45.98 14,600.00 87.41 194.71 6,355.25 6,207.75 0.00 0.00 46.54 14,700.00 87.41 194.71 6,359.76 6,212.26 0.00 0.00 47.10 14,800.00 87.41 194.71 6,364.27 6,216.77 0.00 0.00 47.67 14,900.00 87.41 194.71 6,368.79 6,221.29 0.00 0.00 48.23 15,000.00 87.41 194.71 6,373.30 6,225.80 0.00 0.00 48.79 15,100.00 87.41 194.71 6,377.82 6,230.32 0.00 0.00 49.36 15,200.00 87.41 194.71 6,382.33 6,234.83 0.00 0.00 49.92 15,225.93 87.41 194.71 6,383.50 6,236.00 0.00 0.00 50.06 Adjust TF to 0°,for 1000' 15,300.00 87.41 194.71 6,386.84 6,239.34 0.00 0.00 50.48 15,400.00 87.41 194.71 6,391.36 6,243.86 0.00 0.00 51.05 15,500.00 87.41 194.71 6,395.87 6,248.37 0.00 0.00 51.61 15,600.00 87.41 194.71 6,400.38 6,252.88 0.00 0.00 52.18 15,700.00 87.41 194.71 6,404.90 6,257.40 0.00 0.00 52.74 15,800.00 87.41 194.71 6,409.41 6,261.91 0.00 0.00 53.31 15,900.00 87.41 194.71 6,413.93 6,266.43 0.00 0.00 53.87 10/30/2015 4:07:08PM Page 7 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 16,000.00 87.41 194.71 6,418.44 6,270.94 0.00 0.00 54.44 16,100.00 87.41 194.71 6,422.95 6,275.45 0.00 0.00 55.01 16,200.00 87.41 194.71 6,427.47 6,279.97 0.00 0.00 55.57 16,225.93 87.41 194.71 6,428.64 6,281.14 0.00 0.00 55.72 TD:16225.93'MD,6428.64'TVD 10/30/2015 4:07:08PM Page 8 COMPASS 5000.1 Build 74 1 Schlumberger • Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp12.1 [Hammerhead] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 16,225.93 6,428.64 4 1/2"x 6-3/4" 4-1/2 6-3/4 2,736.60 2,614.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 7,261.78 6,190.50 7-5/8"x 9-7/8"x 11" 7-5/8 9-7/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 282.50 282.50 top T-3 Sand 2,679.06 2,563.50 Base W Sak 2,952.51 2,803.50 C-80 6,174.58 5,579.50 Top Bermuda 5,414.89 4,963.50 Growler-AA 6,031.08 5,471.50 Top Cairn 6,898.68 6,033.50 Top HRZ(K-2 mkr) 7,677.92 6,299.50 A4 6,337.13 5,695.50 C-35 7,261.78 6,190.50 Lower Kalubik(K-1 mkr) 0.00 7,594.29 6,285.50 Kuparuk C(Top C4) 5,033.05 4,629.50 C-40 1,403.91 1,388.50 Base permafrost(?) 7,028.12 6,095.50 Upper Kalubik(base HRZ) 6,279.94 5,655.50 Base Bermuda 5,151.55 4,733.50 C-37 4,504.37 4,165.50 C-50 366.50 366.50 K-15 Marker 1,863.75 1,827.50 Top W Sak(W Sak D) 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 450.00 450.00 0.00 0.00 KOP:Start 1.5°/100'DLS,330°TF,for 150.04' 600.04 600.00 2.55 -1.47 Start 2°/100'DLS,0°TF,for 751.51' 1,351.55 1,338.50 112.63 -65.03 Hold for 104.73' 1,456.28 1,438.50 139.57 -80.58 Start 3°/100'DLS,-102.86°TF,for 915.88' 2,372.16 2,294.15 221.59 -370.46 Hold for 2832.31' 5,204.46 4,779.94 -9.49 -1,708.13 Start 3°/100'DLS,-82.18°TF,for 2057.31' 7,261.78 6,190.50 -1,148.25 -2,451.31 Hold for 20' 7,281.78 6,197.67 -1,166.57 -2,454.89 Start 3°/100'DLS,0.1°TF,for 57.13' 7,338.91 6,217.34 -1,219.21 -2,465.17 Hold for 19.42' 7,358.32 6,223.75 -1,237.20 -2,468.68 Start 3.5°/100'DLS,-0.14°TF,for 36.75' 7,395.07 6,235.50 -1,271.37 -2,475.36 Adjust TF to 7.73°,for 514.45' 7,909.52 6,316.31 -1,765.73 -2,582.89 Hold for 6130.35' 14,039.87 6,332.09 -7,728.33 -4,007.07 Start 3°/100'DLS,145.4°TF,for 75.03' 14,114.89 6,333.50 -7,801.09 -4,025.31 Start 2°/100'DLS,-180°TF,for 29.36' 14,144.25 6,334.67 -7,829.46 -4,032.76 Hold for 1081.68' 15,225.93 6,383.50 -8,874.61 -4,307.18 Adjust TF to 0°,for 1000' 16,225.93 6,428.64 -9,840.84 -4,560.89 TD:16225.93'MD,6428.64'TVD 10/30/2015 4:07:08PM Page 9 COMPASS 5000.1 Build 74 • • Nd CIL ..,NG ir`U N 0 C ' O S.. L f6 ■ CD f6 a) Y. E O U 0E p N d N Z.; co O 2 U C N W O E' 4. x O „ow..., yd. m O co r cc O .c O i N d Z pp O ‘IMI O _ O SM yMI N• N 7NC CV QCO O NO O N �■/ ^iuv m w n W, 9 — Cl) (Q • Cs 1 p d E ct oO CD = c = ca c Q0. C Ca3 o `° o R c o is umsi smo G) 0 , N * 2 w ca ■_ •N (sCO O w I v tiJI L RS ■� X 6 N d o L rO Q N0a LL op p> C0 Y + p a; 3 Q 'v+ to co co csi N '• a co oreNOO CU O t t m N O 0Ln ' Ir .� co V/// C. ti � Z .� Y ON .. 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Q Q Q (1) O` 'C N Y y y N N V• N V V h V' h 3 3 3 3 3 0 1 O o 7 cc co co co co co co c0 c0 = d N Z O 'E d "" 0 0 0 0 0 0 0 0 C p co _ ci) • O c ca O C N N N N N N N N N O j I la N C C Cl) m co = c 0 0 0 0 0 0) 0) ) c 3 ` a t o DI x X 0 0 0 0 0 N-N- 0) 0 a c = m caCA oocooco L) a) E S_ (l) Co) y U d O O i_N V CO h (0 N N � N O C N U C 03 c ' D O 4) 7,-, - - r N V h ccO O .O p ❑ 2 N d l06 d L L CT CT >. co N L 3 c y LL E• a •0 N O V 16 N d Z h h CO O 7 O N C w C UN C = 4 0 a O c d 0 0 Q. 0. L 0 0 0 0 0 0 0 0 N . N c R O 3 3 3 3 cn O O 0 0 cq t— t— co p O r a ca m $ R a v v O 0 4. L U a o d d CL )_ t$' N 10 co O O N C')) CO') CO CO O 5 c4 N a) = N 9 9 O N V V h h N N co C >"N r U N N N N ► lL.3.. N N h h N p U CO CI. +-' C i Ncr) N p C O a) E ` O N d r (0 (O O O O N com U CO Q N r- X N 3 {d C/) (n (n (/) N N O N N C N O 7 W Z N N N CN d d a) �O fl- N N p ' d - V V 7 d' N N C N N n O O C O W z co ' U U N �N L .. 0 0 d d d d cz 03 co 9 9 c) (n C p N ❑ O r = N N N N 0 co 0 N c I� C L • 'y O N O o V V (0 co O O O O ' Q „_, d N a .0 _ d N r r r 3 p O 15 c d - RS G N N N N N C) (c().1 O) O` C m LL OU 0 C "O Z N N N p N C I o = ct CC d p m c0 0 000 0) o) o) 0) °� as is 0 c - M ++ a) :° i� > m = = fA U d d d d Q U Q@ c4 N Q F- C4 C CO 5 U (n 5 5 Q • • 16:12, October 30 2C15 12.1 [Hammerhead] Ladder View 2S-08w p [ � The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors k0.7 I° 0 0` ai E- wwm' mn urh ^4^®44?MA •-4'742; N'N 4,44 NN 300— `VIag I � r I7��' rNII,I II _ j ... ._.... ..... \11 � , Q — III9 ] 0Il II' � IIIill0lII,;I�, ilI CO !)II{ I(IIII q!,, � �� 1iIIIIIIiI11Iol�;olp� aiI/II I111 ill ill 150 . t I , w 111111011111IV II fIl HO Oi 11 l 1 mgiuliu� p �� �P glaD! UllhJ• . iI�' U ] I1I- I .40 6,1,1, II I IIIIIIII .Ir II1 _ :.... ......._..I- 1n'ulipulllllllll11,1!:111100 . ,.... ........ 11 0-Equivelant Magnetic Distance I I I I I I I I I I I I I i I 1 i I I I I I I I IIIII 0 1500 3000 4500 6000 7500 9000 Displayed interval could be less than entire well:Measured Depth 27.50 To 16225.93 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 27.50 450.00 2S-08wp12.1 [Hammerhead] (Plan1126+QSgEND 2614.71736.60 10-3/4"x 13-1/2" 450.00 1650.00 2S-08wp12.1 [Hammerhead] (PIanM3608) 6190.561.7785/8"x 9-7/8"x 11" 450.00 2736.60 2S-08wp12.1 [Hammerhead] (PlanMISEIDBITR-AK-CAZ-SC 6428138225.93 4 1/2"x 6-3/4" 27.50 650.00 2S-08wp12.1 [Hammerhead] (PlanjOSp-SS 2736.60 4236.60 2S-08wp12.1 [Hammerhead] (PIanMaSED8) 2736.60 7261.78 2S-08wp12.1 [Hammerhead] (PlanMISEI R-AK-CAZ-SC 7261.78 8761.78 2S-08wp12.1 [Hammerhead] (Plants ED8) 7261 7816225 93 2S-08wn12 1 FHammerheadl (PIanMNtU)8(FR-AK-CA7-SC E• `v • N E a a bx q o N fil N N N / 60 .,,' III _..r/ ! / 1/ 0 a) . i ' I -Ea U 30 •��N I 0 '! *il , C U — 0 I I: 1 I I I I i ii IIIIIII IIII I I I I IIII I Equivalent Magnetic Distance00 1000 1500 2000 2500 3000 3500 Partial Measured Depth 26 4 b U 243-08wp12.1 [Hammerhea Inc Azi TVD Dleg TFace Target 450 640 27.50 ).00 0.00 27.50 0.00 0.00 27.50 To 1622593 ).00 0.00 450.00 0.00 0.00 640 840 600.04 2.25 330.00 600.00 1.50 330.00 .28 330.00 1338.50 2.00 0.00 840 1030 16:13,October 30 2015 .28 330.00 1438.50 0.00 0.00 1030 1220 3.64 260.20 2294.15 3.00 -102.86 CASING DETAILS 5204.46 23.64 260.20 4779.94 0.00 0.00 1220 _ 1420 x241.18 83.00 191.05 6190.50 3.00 -82.18 2S-Hammerhead 0. Intermediate casing 10291154i/00_ 1610 TVD MD 7281 78Nam�3.00 191.05 6197.67 0.00 0.00 2614.00 2736.60 10-3/qy y 1-3.-1/2" 6190.50 7261.787-5/8" x 73 8",, 11 3.71 191.05 6217.34 3.00 0.10 1610 1800 6428.64 16225.93 4 1/ 8x 3/43 3•71 191.05 6223.75 0.00 0.00 7395.07 72.00 191.05 6235.50 3.50 -0.14 28-Hammerhead 1. Heel 102915 VO 1800 2400 7909.52 83.85 193.43 6316.31 3.50 7.73 SUMS MOWN 3.85 193.43 6332.09 0.00 0.00 2400 3000 Septa!cm Depth so oo yi12.1 en�rnwd f2laToolo 3.00 194.71 6333.50 3.00 145.40 2S-Hammerhead 2. 2nd point 002115 PB 3000 3600 6600SO 450 00.66 1 s-06„,12.1[...mead] ,21..026-00, 7.41 194.71 6334.67 2.00 180.00 450 00 2is3000 26-00,12 s oe,iii Re.,ei iei 6C 7.41 194.71 6383.50 0.00 0.00 2S-Hammerhead 3. Toe 092115 ins:co iz 2s-°06`"°,iz:i da �ni iPia,1.6 26�u -c�z-6c 7.41 194.71 6428.64 0.00 0.00 3600 4200 7261.78 6 78 20-0855,12.1[...,n.rn.ad] ,21®.5022-001 "....."..., 7261.78 16225.93 29-0855,12.1 cxann61n.aaJ (P16.5D�K-u.-6c 4200 4800 4800 5400 5400 6000 6000 6600 6600 7800 0/360 7800 9010 _:4---:::2-72---71-----: 9010 10210 �� , 30 10210 11410 30/330 210 - •'P.11,-- 11410 12620 195 �� 12620 13820 ,:. / ;- 13820 15020 / , iF 1 i 150 �� N A ` � 13 SL [S aImo 7 ] 020 16226 60/300 --/' / ,M \ i ; _ ,, i� ri;h• ;rsp� 1• ,12;;;14:74:: , ,t ,t . YBambo n o ,', • „ , I I II ilf Hit HP Hi/ ' I. '' w--j `,,�.p.n 4 • ,•11404-1.".)-•1,'c1 8 [Mako] p -90/270 :I =gm-nss ""'�1�;m'j''s/ . `� yl t/3 �as. - #j.�Q,@,.�;. .--1,1;,...,.."1,,,,-.,..,:„'n . �=90 e\"ts ,744,,,,.. 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The top of the tail slurry is designed to be at 2192' MD. Client: CPAI Revision Date: October 21, 2015 Prepared by: Jenna Houston Location:Anchorage, AK Phone: (907)223-8916 Lead Slurry Minimum pump time: -230 min. (pump time plus 120 min.) Email:jhouston2@slb.com DeepCRETE @ 11 ppg- 1.91 ft3/sk 0.5985 ft3/ft x(115') x 1.00 (no excess) = 69 ft3 < TOC at Surface 0.3637 ft3/ft x (1404- 115') x 3.50 (250% excess) = 1641 ft3 0.3637 ft3/ft x(2192- 1404) x 1.50 (50% excess) = 430 ft3 69 ft3 + 1641 ft3+430 ft3 = 2140 ft3 2140 ft3/ 1.91 ft3/sk = 1121 sksC______D Please have extra DeepCRETE on location for top out. Previous Csg. Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.) l < 16"casing DeepCRETE @ 12 ppg - 1.63 ft3/sk at 115'MD 0.3637 ft3/ft x(2692-2192) x 1.50 (50% excess) = 273 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 44 ft 273 ft3 +44 ft3= ,,, 317 ft3/ 1.63 ft3/sk = 195 sks _.-- Round up to 205 sks BHST= 62°F, Estimated BHCT= 74°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at 1,404'MD(-1,389'TVD) I PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 7.00 75.0 10.7 10.7 MUDPUSH H 7.00 75.0 10.7 21.4 < Top of Tail at Pause 0.00 0.0 5.0 26.4 2,192'MD 11 ppg DeepCRETE 7.00 381.9 54.6 81.0 Surface Tail 7.00 56.3 8.0 DeepCRETE Slurry 89.0 Pause 0.00 0.0 5.0 94.0 Fresh Water 7.00 10.0 1.4 95.4 Pause 0.00 0.0 5.0 100.4 Mud 8.00 231.2 28.9 129.1 Mud 3.00 10.0 3.3 132.4 < 10-3/4",45.5#casing in 13.5"OH MUD REMOVAL Expected Mud Properties: 9.5 ppg, Pv< 20, Tv<20 TD at 2,692'MD (2,614'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv 17-21, Ty 20-25 Centralizers: As per CPAi program. *Mark of Schlumberger 0 • 2S-08 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 One Stage (v1) Location: Kuparuk Client: CPAI Revision Date: October 30,2015 Volume Calculations and Cement Systems Prepared by: Jenna Houston Volumes are based on 20% excess. The top of the 1st stage tail slurry is designed to be Location:Anchorage, AK Phone: (907)223-8916 at 4,652' MD. Email:jhouston2@slb.com Tail Slurry Minimum pump time: -225 min. (pump time plus 120 min.) 15.3 ppg Class G +GASBLOK*adds - 1.25 ft3/sk 0.2148 ft3/ft x (7262'-7157') x 1.20 (20% excess) = 28 ft3 0.3429 ft3/ft x(7157'-4652')x 1.20 (20% excess) = 1031 ft3 0.2578 ft3/ft x 80' = 20 ft3 28 ft3+ 1031 ft3+ 20 ft3= 1079 ft3 1079 ft3/ 1.25 ft3/sk = 864 sks Previous Csg. Rotifid up to 875 sks < 10-3/4",45.5.#casing ` at 2,736'MD \_ - --- - BHST = 150°F, Estimated BHCT= 106°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) C W 100 7.00 70.0 10.0 10.0 MUDPUSH II 7.00 40.0 5.7 15.7 Pause 0.00 0.0 5.0 20.7 15.3 ppg Slurry 7.00 192.0 27.4 48.1 Pause 0.00 0.0 5.0 53.1 Fresh Water 7.00 10.0 1.4 54.5 Pause 0.00 0.0 5.0 59.5 Mud 7.00 279.8 40.0 99.5 < Top of Cement at Mud 2.50 25.0 10.0 109.5 Mud 1.00 15.0 15.0 124.5 4,652 MD III: MUD REMOVAL Expected Mud Properties: -10.3 ppg, Pv< 20, Yield Point < 25. < 7-5/8",29.7#casing in 11"x 9 7/8"OH Spacer Properties: 11.5 ppg MudPUSH* II, Pv=20-24, Yield Point= 20-30 Centralizers: As per program ii TD at-7,262 MD (6,190'TVD) *Mark of Schlumberger • • Request for Waiver of AOGCC Regulation 20 AAC 25.412(b) ConocoPhillips requests approval of our proposed plan to topset the Kuparuk sands per the following Alaska Administrative Codes. 20 AAC 25.412(b)A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval,unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone.The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations,unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. 20 AAC 25.030(c)(5)"production casing must be set and cemented through,into,or just above the production interval" 20 AAC 25.030(d)(5)"intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet above all significant hydrocarbon zones and abnormally geo-pressured strata or,if zonal coverage is not required under(a) of this section, from the casing shoe to a minimum of 500 feet above the casing shoe;if indications of improper cementing exist, such as lost returns,or if the formation integrity test shows an inadequate cement job,remedial action must be taken" Due to the elevated reservoir pressure(estimated—11.4 ppg)of the Kuparuk'A' Sands and the low fracture gradient(11.8 ppg)observed in shallow sand stringers in offset wells, landing intermediate casing in the Kuparuk Sands is not feasible. We propose to topset the overpressured Kuparuk 'A' sands by landing—35' TVD above them, setting our 7-5/8" intermediate casing in the Lower Kalubik shale, and cementing from the shoe to the top of the Cairn formation. - - . •- •• ' e - : casing wilt— ,Cc • . • •9 . • - -' •9 • -.I o ceme • - . • - - with a second cement - stAge-chis plan is similar to our recent wells on 2S pad that adjusted to a topset design on the fly after encountering losses in the intermediate section(2S-02, 2S-07, and 2S-10). Please refer to the attached schematic for a diagram of the planned design. To confirm the presence of cement behind the intermediate casing, a recorded mode sonic log to confirm top of cement and integrity, as well as a leak-off test below the intermediate casing shoe,will be performed. Additionally,the heel of the 4-1/2"production liner will be blank pipe,with a swell packer run on the blank pipe to isolate the 7-5/8"casing shoe from the slotted liner. Due to this top set design,ConocoPhillips requests a waiver to the AOGCC regulation(20 AAC 25.412(b))stating that injection packers must be within 200 feet of the upper most perforations on injection wells. Packer placement is planned to be—566' MD/109' TVD above the slotted liner/top of Kuparuk A-sand. • • pro ZL S-/-4- Loepp. Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday,October 29, 2015 9:14 AM To: 'Guo, Haibin' Cc: Bettis, Patricia K(DOA) Subject: RE: Enlarge hole size from 9-7/8"to 11"on 2S-08 PTD#215-174 Send in revised permit with new casing program, new cementing program and anything else that changes. You can show changes in red text on original permit. Will also need a revised 10-407 form with changes. Two hardcopies will need to be submitted to our office. Thanx, Victoria From: Guo, Haibin [mailto:Haibin.GuoCalconocophillips.com] Sent: Wednesday, October 28, 2015 4:42 PM To: Loepp,Victoria T(DOA) Subject: Enlarge hole size from 9-7/8"to 11"on 2S-08 PTD# 215-174 Hi Victoria, This email is to let you know:Well 2S-08(PTD#215-174),a Kuparuk A sand injector, probably will be spudded around 11/05/15 according to current rig schedule.The well was originally planned to drill a 9-7/8"intermediate hole.Since we saw lost return issues due to high ECD and weak formations on last 3 wells just drilled on the same pad.Also the casings run were challenging and difficult to reach bottom,and hard to get full returns during cement jobs.So we are thinking to enlarge the hole size from 9-7/8"to 11"with under reamer to get some ECD relief while drilling to avoid lost returns. And hope the big hole size also helps the casing to get to bottom and the cement job can get full returns. If you need us to do something for the change please let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 1 • • TRANSMITTAL LETTER CHECKLIST WELL NAME: KR.L. .2S —o G2..ucsk, I) PTD: 0215- 171 Development 1' Service Exploratory Stratigraphic Test Non-Conventional FIELD: KtApt,,X Rd1/ki POOL: Litiut. ,t Vkir KylAil,S, b it Check Box for Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 6 0 J LJ y ° , , m a . Cr) NN C - 8 , , N ui o- >. , C9 a M, C, o f6 a) C ° c 0, c > CL L 2, ° 3; o o, o O), iii a v, U L, 5 0, ° E o N, cc ate)' v. - . E cD y, o, p. cas , ti w v, �' E GO y, , , a`) c o �° ° v � ° :°, : of 0 a L y = �, v, Y, o, co 3 c ° a) c ` W, a °' ' M' co w Z rn, '3. ° 3 �, o v W, q - a), v, �,. ° a v, a o 2 , of o N �, -c-'„ J O ` C, a, ''� > t6 fa0, M, d, a a tf) O ca I- =. -0, O, o, �, . , E , , , 13, 0, v', a E, a, N, , o .E' N, . Z. 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D 'OO .0 O, .0 vHC , OaCCO, CE Ea)' O a), a) 3 ' co, o' O o Va ti, a co, m o, a) co, 0 � U U O O UU) a N 0 0w . , ° ° v ' m ' a- 0 > > 0) a, m WaYEs ' E ) 0ai 10 YTo ` N. ° 0co •EEm; N3 a v,' ,o' II- '7,C,' c7, .) o > a sY' a ` E0, aoa) yc a)' a)'' a) V a a aai; -, o : ' '0ca v V E 0; 0. ; °' ; a m m, 0, a; ; zaJD � co OOaa. a aaacno (-) ( oaaa mma5N2a, a, co, co, a — _ E r ,- N M v U c0 n. ao 0) O N M V O `" N N N N N N N N N N M M M M N M M M CO f0') V 0 �. 0 U) _U) U .. C O O O N C C 2 N .2N 1.13 N V Ce <7 O ON CO CO ON co N (n F- a. 7) w - ° E J N C a) cn O C O Q a s IE. CO c ° 0 a) a s 0 L: s a W a O a or • ",\I y/,'+ THE STATE Alaska Oil and Gas o f TTAsKA Conservation Commission x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 'eft:* Main: 907.279.1433 OALAS'°' Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-08 ConocoPhillips Alaska, Inc. Permit No: 215-174 Surface Location: 3056' FNL, 1467' FEL, SEC. 17, T1ON, RO8E, UM Bottomhole Location: 1371' FNL, 521' FEL, SEC. 30, T1ON, RO8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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, Cathy P. Foerster Chair DATED this to day of October, 2015. • S RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 4 2015 PERMIT TO DRILL /� ^^ (° 20 AAC 25.005 O C la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑✓ . Single Zone O, 1c.Specify if well is proposed for: Drill ❑✓ Lateral C Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry C Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: ❑ Blanket Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 , KRU 2S-08 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 16151'- TVD: 6383' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3056'FNL, 1467'FEL,Sec. 17,T1ON, RO8E, UM ` ADL 25603, 25608 Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4056'FNL,3713'FEL, Sec. 17,T1ON, RO8E, UM 2677,2681 10/8/2015 Total Depth: 9.Acres in Property: 14.Distance to 1371'FNL,521'FEL, Sec. 30,T1ON, RO8E, UM - 792tSo3S Nearest Property: 1567 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 148 feet 15.Distance to Nearest Well Open Surface:x- 481103.5 y- 5929992 Zone- 4 • GL Elevation above MSL:I4.0eet41) to Same Pool: 2S-07,29 16.Deviated wells: Kickoff depth: . 450 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 89.8° deg Downhole: 3833 psig - Surface: 3203 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 welded 78' 28' 28' 106' 106' existing 13.5 10.75" 45.5# L-80 Hydril 563 2739' 28' 28' 2768' 2614 1155 sx DeepCRETE,205 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 7978' 28' 28' 8008' 6282' 490 sx GasBLOK,175 sx GasBLOK 6.75" 4.5" 11.6# L-80 IBTM 8294' 7856' 6243' 16150' 6383' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Sint Cement Volume MD TVD Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plal ❑ BOP Sketch ❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements o 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Haibin Guo @ 265-1487 a -1' Email Haibin.GuoAcop.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature 4e_ G Phone: 265-6120 Date `(2312 Is- , Commission Use Only Permit to Drill API Number: n Permit Approval See cover letter Number: a 15- 17.y 50- 1D3- a03.0.1....00-oo -c O Date: f l01 1 Ifor other requirements Conditions of approval : If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: �-,( Other: 13 C P 7-C 51 fc) 3.SL� 5 i o Samples req'd: Yes No [j Mud log req'd: Yes❑ No u f}vi VI Via 1-1)).-6-V L.-" -Cr f<S f--L61-61.{ 9-neasures: Yes [. No I Directional svy req'd: Yes No❑ 4 kva/ v Cr / �',rei r->?cd fio al 1 l ct-12., d"' ,+ p a c ker. fo b p-a C€d ev,foo'n-i o Spacing exception req'd: Yes ❑ No l Inclination-only svy req'd: Yes❑ No[J a, o o vG fk S/otic-Cl 1 i fr�r (�?o 4 A-C 5.4/Z!6)) 3 a fic f�r55 yr{ T rr�r.�. -4 �rft<��t/r bRO DBYTHE iv,frcfifar / D APPROVED BY THE / Approved by . , COMMISSIONER COMMISSION DatjJ/ ' : 1 "4-r!Ss Form 10-401 (R vised 10/2012) i i i i 2 o the from the date of approval(20 AAC 25.005(g)) { �0 ���l • • Application for Permit to Drill,Well 2S-08 RECEIVED Saved:23-Sep-15 Post Office Box 100360 SEP 24 2015 Anchorage,Alaska 99510-0360 ConoCAP fillips Phone(907)263-4180 AOGCC Email: mike.callahan@conocophillips.com AOGCC September 21,2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-08,A Kuparuk A4 Sand Pre-Produced Injector Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a permit to drill an onshore grassroots pre-produced injector well from the 2S pad. The expected spud date for this well is October 08,2015. It is planned to use rig Doyon 141. / f 2S-08 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,768'MD/2,614'TVD.The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 8,008'MD/6,282'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/- 16,150'MD/6,384'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 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 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. 8. Request for waiver of AOGCC regulation 20 AAC 25.412(b)on packer setting depth for injectors 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 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 Haibin Guo at 265-1487 (Haibin.Guo@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, e. Chip Alvord Drilling Manager • • a Application for Permit to Drill Document i Kuparuk Well 2S-08 ConocoPhiiiips Well Name Requirements of 20 AAC 25.005(0 The well for which this application is submitted will be designated as 2S-08 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identdying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3056' FNL, 1467'FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 148'AMSL • Northings: 5,929,992.42' Eastings: 481,103.50' Pad Elevation 120'AMSL Location at Intermediate 4056' FNL,3713'FEL, Sec 17,T10N,R008E,UM Casing NGS Coordinates Measured Depth, RKB: 8,008' Northings: 5,928,998.45' Eastings: 478,858.42' Total Vertical Depth, RKB: 6,282' Total Vertical Depth, SS: 6,134' Location at Total Depth 1371'FNL, 521' FEL, Sec 30,T10N,R008E,UM NGS Coordinates Measured Depth, RKB: 16,150' Northings: 5,921,129.97' Eastings: 476,773.85' Total Vertical Depth, RKB: 6,383' Total Vertical Depth, SS: 6,235' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP)while drilling 2S-08 is calculated using an estimated maximum reservoir pressure of 3,833 psi (11.7 ppg, based on nearby recently drilled 2S wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,300' TVD (WP08): A Sand Estimated. BHP = 3,833 psi A Sand estimated depth(WP10) = 6,300' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 630 psi (6,300' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,203 psi (3,833 psi—630 psi) (B)data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (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; See attached 2S-08 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030 f; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) Size t(Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/ 106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,739 Surf 2,768/2,614 1,155 sx DeepCRETE Lead 11.0 ppg, 205 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 490 sx Class G+GASBLOK at Hydril 15.8 ppg w/TOC at 6,000'MD 7-5/8 9-7/8 29.7 L-80 563 7,978 Surf 8,008/6,282 Stage 2: 175 sx Class G+GASBLOK at 15.8 ppg w/TOC at 4,500'MD 4 1/2 6-3/4 11.6 L-80 IBTM 8,294 7,856/6,243 16,150/6,383 Slotted liner S i Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the divetter system as required by 20 MC 25.035,unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematics on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Spud mud LSND(WBM) (WBM) Density 9.0- 10 9.2- 10.5 10.5-12.0 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. i S 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,768' MD/2,614' TVD as per directional plan (wp08). Survey with MWD,Gamma,Resistivity,Gyro. / 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16.0 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at+/-7,244' MD/6,034' TVD. Begin applying back pressure on connections with MPD for shale stability at this time. 9. Directionally drill to intermediate TD of+/-8,008'MD/6,282' TVD, landing approximately 50' TVD below the K-1 marker in the lower Kalubik Shale. Wellsite geologist will call intermediate TD. 10. Trip out of hole.Laydown intermediate BHA and rack back 5"DP. 11. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD. 12. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be+/-6,000'MD(50' MD above top of Cairn formation),top of second stage to be+/-4,500' MD(600' above C37). 13. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 14. Lay down 5"DP. 15. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope, Sonicscope and neutron density).' 16. RIH and clean out cement to 100' above shoe. Mad pass with sonic log to verify top of cement on the way in the hole. Test intermediate casing to 3500 psi for 30 minutes. 17. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16.0 ppg EMW leak off,recording results. 18. Directionally drill 6-3/4"hole,geosteering through the Kuparuk A4 sand to TD+/-16,150'MD as per directional plan(wp08). 19. Circulate hole clean and POOH. 20. Lay down Production BHA. 21. PU and run 4-1/2", 11.6#slotted liner. The top of liner will be placed at+/-7,856' MD,allowing for 150' of overlap in the 7-5/8"casing. NOTE: This will put the liner+/-292' MD/50' TVD above the top of the A4 reservoir,greater than the 200' MD required. ConocoPhillips requests a waiver to use this well for injection with the packer at this depth. • • 22. Set liner hanger. Slackoff and set liner top packer. 23. Monitor well for flow for 15 minutes 24. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 25. Flow check well for 30 minutes to run 3-1/2"upper completion. 26. Nipple down BOPE,nipple up tree and test. 27. Freeze protect well with diesel and install BPV. 28. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS 1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment I Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries Attachment 6 Request for Waiver of Packer Setting Depth i 0 2S-08 Grassroots Horizontal A-Sand Injector ConocoPhillips Proposed Wellbore Schematic (Topset) s : a INI CAMERON ,� 4-%"tree,top joint is 4-'/z' Last Ed Iced :'f 12.6#IBTM Guo-9/23/2015 I;:`�'• , 16"Conductor to— r`r 0 OK 115' 13.5" Surface N4 '.3 Hole I. fig, Ot ;11$` c'/"2.875"DS Landing 74 Nipple n.�� 4 iiSurface Casing �.� '5 i';.N 10-3/4"45.5# L-80 Hydrn563 9-7/8" Intermediate 21 2,768' MD /2,614' TVD Hole IN t_ 3-1/2" 9.3#L-80 EUE 8RD- MOD Tubing l 11 Ant pili 2nd Stage TOC 4,500'MD/ ' 4,177'TVD (-600' MD above C37) ® ® Weatherford Stage,ColLar:5i,200 Mi,la:: :::::::::: ; : : :C-37 5,;1'0•. ib i;47'4'TVD 4,73'T n(-Ann.h lnw•(-.7 ffarentiot1) - : .•. - :,Orai.it ,(Iceberg);5,376':Mr?/4,;764':TVD B:ker 2.812 CM ., .\\\\\\\\\ 1st Stage TOC: 6,000' MD/5,438'TVD To• of Cairn/Bermuda sW'27.5•D Nippl 110 ;Beririia/Ci1irn:6;050 i11,[ /5;472':fil/D 3 "HESNFrageni P•-- '4 •Flex :•: . . . . , Ply �' : HRZ: 7,244'MD/6,034'TVD ,�� Hanger/ZXP Kalubik:7,399' MD/6,095'TVD Intermed*Cacina • .:7700.! Casi • 4/2"Orane-I ,008'MD;f.6,282':TVDY;-, ei � t :;:11.1:1p,1 691 M R 7:6,383'TVD 6.38"x4'/,"Swell Packer 6-3/4" Production Hole NOTE: Swell Packer will be adjusted as necessary using microscope and periscope data • • o zvgF i ARi awe rz ;I D IN r FN N m N N w FTA II o Cai -D o m r O o. o r72-1 z I I 0 0 m o v a ao 0 x•A ' pF M I x F OC v _m n O Ii F. v I - 0 O O ` Et MI !EI I _ � � � � ' '` .l ACM WO IV NMI u)„,,,, ... . ...1 Pls $j41II!: : LI II W r m n _ ® El p o O 4 v W r ao o • N � � i 111 lEIGH r, ± f F I n m 3�J 0 cn NI I I OP--AI D CEEED -< c 0 0 a I0 oE o ,m, D Q Z 0 N T-_- I I I I T m • a 2S-08wp08. 1 [Hammerheac 6 . 7 7 Plan Summary C=.) Growler-AA Top Bermuda Lower Kalubik(K-1 mkr) CD CZ) C top T-3 Sand Top Cairn Base Bermuda (=) CZI•------- C-50 '.C-40 \ ,i . /' _5 . .. , '., ‘-‘, C-37 C-351 /A4 Xuparuk C(Top C4) . I,K-15 imlarker ..,, ,, -s. , , , i , , . - , Fr , • . . . , > - \ ' - . . co a, Rise permafrost(?) ,,. /, . \ r -• -._, Top HRZ(K-2 mkr) , 'V - . ..,.. i w Sak(W , I Sak D) L -4- _ . --- t...14. I /'Upper Kalul bik(base HRZ) . I re ii Base VV Si k - , \••i •:.\.... , I'INZiirAIIITI,' 0 " .o. ?_\00o14".2x31,'11r0,2-31'./4c"li1x'1i 34-10/201'0 1 17-5/81, Me1as0u0rGD0eeedypo1 tdDheetRipc1 ethfDearet1 unmce::1 12000 141/12 6"Nx 6O-1/21 0 (Doon141) Rgy1124014750usft .,.. ., / ikt i . ------- / N ; . 17-5/8"X 9-7/81 4-1/2"x 6-1121 ; ; o i • 0 c, o ci o 0 o ,„ o 4tQ:iiVc; ', • t• 2 8 . . 0 . . . . 0 i.. 0 0 cp . ',.?cc,0•11 0 C> 0 N- 0 0.1 C) , V) I., I .:. ,,, , 0mit izititil..., V) . le,- ,. I I - , I I 1 1- 1 I 1 I I I I I I I I 28 450 0 1500 3000 4500 6000 7500 9000 10500 12000450 - 640 Horizontal Departure 640 - 840 840 - 1030 IIIV I 1030 - 1220 , , , . 1220 - 1420 .Q 1111 30 ip:60 , , 11 . roov.. . 1420 - 1610 • 60 ca \ I , • .. 4 4*7:.: 1610 - 1800 ct. . . • k , \ s ... ' Co i 1 \' 25-07 , tf f-=.;,:‘,1k.1.". 548.,06[Sulu 1800 - 2400 Ii \\ \ ;h--7., .,, . 4,,,,,,„°,123: _ 3000 0 0 -a'30 - , . , 11 ' •."• - yeipx, \t4:::„..,.;,,...,,,:,,,,,., ,,.. .........: , 3600 - 4200 $2 t h 270 -... ...' .........„.,,....... ,.... -.,"0. pft, 2S-I 406[Salmon a.) , 2S-I•wp06[Tiger] 111 II .1. •;7-„.c_.,,..........„1.........L.,,,,,-- 7.yrie, ,,,..,cwl',,Fes, ifi7;-,,,,, ,...,:,:f..,; 1.1:125152111 :280000 4.11°A ' ?,..„.„...: ,,,„,„ --. ,tt...,..!'2S-05,06[Nur 5400 - 6000 6000 - 6600 0 ,f°01-4-.P4, h'htlh2 t7',h4,.f:h.h°,*10,l;e1...zhth hh,-:,,N,-..1i.,..AO; ;,;. 0 h.a. 41:: -71.;;;.:7;5-?f.:'4,1,';;;Tp;;"4',,Or''.'i-0,4i Ateti 7 i fh,r;*0,0,-WiAt'Ai!' 6600 - 7790 0 2500 5000 7500 10000 12500 15000 240 41'.0....,...A:PA 'k...Z•T‘trio iirr4i:1.47,,:'rASNA.,Af44,14. 120 7790 - 8990 %Se#740, 111.4.1r,-11, 1%Sr;% 14ISE SURVEY PROGRAM Ni4r.",..41-1.m.....4.11.416.3..,-..,,--14:41„ii7;;..i,;',••1404.1,!„„19. 8990 - 10180 Surface Location 1"--4,16::.7airra7415 .----4•F':..lritOr 10180 - 11380 Depth From Depth To Survey/Plan Tool ,r4fairgir41110.!AP-4;..‹,--'1*.-10-52113 27.50 650.00 2S-08wp08.1[Hammerhead](Plan'2S-08)INC+TREND Pad Elevation: 120.00 11380 -- 12570 650.00 1650.00 2S-08wp08.1[Hammerhead](Plan:2S-08) MWD 21° ' 8°I/Aimi..050.A.01°- 150 ‘645°11174=1:0 12570 13760 650.00 2768.60 2S-08wp08.1 Hammerhead](PIAIWZ8-138 AK CAZ SC 180 13760 14960 27.50 650.00 2S-08wp08.1 Hammerhead](Plan:2S-08)GYD-GC-SS CASING DETAILS 2768.60 4268.60 2S-08wp08.1 Hammerhead](Plan:2S-08) MWD 14960 - 16151 2768.60 8007.16 2S-08wp08.1 Hammerhead](PlaIWES4I83-AK-CAZ-SC TVD MD Name -----Pit 8007.16 9507.16 2S-08wp08.1 Hammerhead (Plan:2S-08) MWD 2614.00 2768.60 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 8007.16 16151.39 25-08wp08.1 Hammerhead](PIM8683-AK-CAZ-SC 6282.00 8007.80 7-5/8"X 9-7/8" Magnetic Model Date: 01-Nov-15 6383.47 16150.75 4-1/2"x 6-1/2" Magnetic Declination: 18.51° To convert a Magnetic Direction to a True Direction,Add 18.51°East SECTION DETAILS -gm,T-3 Sand Sec MD Inc Azi TVD ON/-S •E/-W Dleg TFace VSect Target Annotation 1 27.50 0.00 0.00 27.50 0.00 0.00 0.00 0.00 0.00 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,330°TF,for 150.04' K-15 Marker 3 600.04 2.25 330.00 600.00 2.55 -1.47 1.50 330.00 -2.08 Start 2.5°/100'DLS,0°TF,for 757.67' 4 1357.71 21.19 330.00 1338.50 135.25 -78.09 2.50 0.00 -11043 Hold for 107.25' 5 1464.97 21.19 330.00 1438.50 188.83 -97.47 0.00 0.00 -137.85 Start 3.5°/100'DLS,-56.05°TF,for 210.45' -1388.5 6 1675.42 26.00 315.96 1631.45 235.02 -148.63 3.50 -56.05 -188.54 Hold for 2412.73' 7 4088.15 26.00 315.96 3800.00 995.33 -883.88 0.00 0.00 -732.65 Start 3°/100'DLS,-120°TF,for 2601.37' Base permafrost(? 8 6689.52 66.38 203.58 5811.19 183.44 -1922.85 3.00 -120.00 320.48 Adjust TF to-91.74°,for 301.3' 9 7158.82 66.48 193.34 5999.28 -223.86 -2058.81 2.00 -9146 749.09 -1957.5 10 7531.64 66.48 193.34 6148.07 -55647 -2137.69 0.00 0.00 1090.79 11 8149.05 85.00 193.30 6299.50 -1136.23 -2274.94 3.00 -0.13 1686.31 2S-Hammerhead 1.Heel 092115 VO Hold for 30' Top EV Sak(W Sak 3) 12 8179.05 85.00 193.30 6302.11 -1165.31 -2281.82 0.00 0.00 1716.18 Start 3°/100'DLS,0°TF,for 160.28' -2563.5 13 8346.39 89.81 194.74 6309.69 -1327.45 -2322.31 3.00 16.67 1883.28 Base W Sak 14 14960.69 89.81 194.74 6331.58 -7724.07 -4005.07 0.00 0.00 8497.47 Start 3°/100'DLS,-179.93°TF,for 79.57' -2803.5 15 15040.35 87.42 194.71 6333.50 -7801.09 -4025.31 3.00 -179.36 8577.10 2S-Hammerhead 2.2nd point 002115 PB Hold for 1111.04' 16 16151.39 87.42 194.71 6383.50 -8874.61 -4307.18 0.00 0.00 9687.00 2S-Hammerhead 3.Toe 092115 TD:16150/5'MD,6383.5'TVD C-80 -4165.5 C-50 -; 19f-1°7 Permit Pack TCR required for --4963.5 2S-07. Growler-AA laliggprima C-35 fh,qt-lailiathr Ith.By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve 6 as the basis for the final well hh..-........--,-. ..,v)........,......----,,, Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Ifeanyi Ifesie ! co N • a . a • noI thing (4500 usftlin) i 1 1 Y Ni 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i N (=�1 Y O,3 N J N N Is. La N - C C N - O O 2 = N O N N N I ! N O _ CL �� N -� J O i It N N a Q - p l� `�' `r (� N N N _ Nr10gL J N N co .- -5r r. Itik— . cs, — NCf N N N = 1 , ,...i Y Y - J N _ 1 Q' N 0 N N (.1 M M O Nco N N �. N 3 N co �i N O J �, Ai; O co 4 V O - N ¢ N�' 1 1F. 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QQ�, T RI -0OOw o 0 _ aits `� v o + CZ .n N — M N ': 0 ca c_ 1 LLI X ,I Cl)d _ ' `n Loa)O L r--- o �+ N -o 0 4C13 a) oo tI 0 a) .�., ' , I 0 E z- a) .5 / .-- i N ._ E '47e) E C o ,' _© Ch N a) N � O T� N CO H (0 N- i a) M O u a 1 �Q a) E m N _o z E -4- Co CX ' E = N I 0 CLN a o CO , o O O O O o O C 0 o O O O O o O CV M CoO (u!/gjsn 000£) (+)u1aoN/(-)ulnoS 0 • 0 0 I I 0 I , I I I N II I [pPayaau WeH]'' l'80dAl80-SZ I 1,, , to 0 r r. O N -Ln O O O n, CV W k k Fo 2 meiM 0L8 O as C 0 00051. _B a)" °' O 1 E .11..r c) V = O00ti —o CD ' N O , m d C . Q00£1, _ (N = I o 0 1 0 0 0 c _0o Ln 0002 6 a 0 0 , ; L 0 N E 006 � C 0 ,, N Lf) I; O 2 Y (N rp 0) '-- 0001-6 m 0 -- 03 .X C 0a N Y ; a NCE a3 as w N Y 3 2 0 is O 6 2 Q � _ QJ N Ln O i /1\ - O N �j� L N p 006 N co 2 •(T3 � m . . .y\ V Q 00 iii W„ E la-, L 8-QI- \ \ \ I \ \ // TW \(13 0 _ r Cf3 03 TS LO Q co U 1 \ \ i 0 9 \ � - (B r `1 Q • 1 1 J\ \ �O` i 05 I\ \ a ,‘ \ \\ \V hA \ \\ I , • • • • • ` \\ O \\ \ I�\ \ \\ \ \ \\ L \\� v - bo cu . \ , c, , ,,,,* , . • N �aV \\; \\ O\1 0\ 'e H 1 (n O N CD Mo ,l ° U / ; D X M L - I Q CO � U Y o MI W 1 I —� O r. 0 I e I 1 1 0 0 0 0 0 0 0 in Ln o Ln o Ln CO co I� N 1 (ui/}4sn 005 i) ujdea leo!lJeA anal • gli 0 0 LU o0 o N N al am [peOLJ eWW8H] L 80d^^80-SZ o 0 O N CD -LU o 0 ll MINE 0 Alla H V __ 00096 9 C ' c� o L 8 ,°;° m o 0 `U -c45 oo =_ 00056 N E o E : o C I 0 *O _ LU 000b6 cl CV N N o Q 'c LU O N N.- o N X Lri 000£6 N N 0 j o C 11 0 E Oo O q L FO 0002 =Eo .�c 4 E U 006 N U II N- : 0_ 0001,1. o f -LU : Y "t 't II Y • m 00006 N • o � o)0 0 0 -J 11 i X ,i 'i N o0 1 i co' 0i06 ` I co " 0 az a) ■ 0008 o •u E o E `n 1111.10 Ca I •1 C N 1 - - •0T I 1 I I 11110do' o oM o 0 N N CO CO CO CO ui/Tj n 08) ujdaa e!1J8A en-11 co ( • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-08 Plan: 2S-08 Plan: 2S-08wp08.1 [Hammerhead] Permit Pack Report 23 September, 2015 . • 0 Schlumberger Comments apply to Report the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Project Kuparuk River Unit,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 Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-08 Well Position +N/-S 0.00 usft Northing: usfi Latitude: +E/-W 0.00 usft Easting: usfi Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan:2S-08 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 11/1/2015 18.51 80.87 57,487 Design 2S-08wp08.1 [Hammerhead] Audit Notes: Version: Phase: PLAN Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 195.00 Survey Tool Program Date 9/23/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 27.50 650.00 2S-08wp08.1 [Hammerhead](Plan:2S-08 INC+TREND Inclinometer+known azi trend 650.00 1,650.00 2S-08wp08.1 [Hammerhead](Plan:2S-08 MWD MWD-Standard 650.00 2,768.60 2S-08wp08.1 [Hammerhead](Plan:2S-08 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 27.50 650.00 25-08wp08.1 [Hammerhead](Plan:2S-08 GYD-GC-SS Gyrodata gyro single shots 2,768.60 4,268.60 2S-08wp08.1 [Hammerhead](Plan:2S-08 MWD MWD-Standard 2,768.60 8,007.16 2S-08wp08.1 [Hammerhead](Plan:2S-08 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,007.16 9,507.16 25-08wp08.1 [Hammerhead](Plan:2S-08 MWD MWD-Standard 8,007.16 16,151.39 2S-08wp08.1 [Hammerhead](Plan:2S-08 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (0) (usft) 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -47.50 0.00 0.00 0.48 200.00 0.00 0.00 200.00 52.50 0.00 0.00 1.65 282.50 0.00 0.00 282.50 135.00 0.00 0.00 2.70 top T-3 Sand 300.00 0.00 0.00 300.00 152.50 0.00 0.00 2.70 9/23/2015 9:44:28AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit ND Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 366.50 0.00 0.00 366.50 219.00 0.00 0.00 3.72 K-15 Marker 400.00 0.00 0.00 400.00 252.50 0.00 0.00 3.72 450.00 0.00 0.00 450.00 302.50 0.00 0.00 4.20 KOP:Start 1.5°/100'DLS,330°TF,for 150.04' 500.00 0.75 330.00 500.00 352.50 1.50 330.00 4.66 600.00 2.25 330.00 599.96 452.46 1.50 0.00 5.71 600.04 2.25 330.00 600.00 452.50 1.50 0.00 5.71 Start 2.5°/100'DLS,0°TF,for 757.67' 700.00 4.75 330.00 699.77 552.27 2.50 0.00 6.34 800.00 7.25 330.00 799.21 651.71 2.50 0.00 6.35 900.00 9.75 330.00 898.11 750.61 2.50 0.00 6.36 1,000.00 12.25 330.00 996.26 848.76 2.50 0.00 6.39 1,100.00 14.75 330.00 1,093.49 945.99 2.50 0.00 6.45 1,200.00 17.25 330.00 1,189.61 1,042.11 2.50 0.00 6.54 1,300.00 19.75 330.00 1,284.43 1,136.93 2.50 0.00 6.67 1,357.71 21.19 330.00 1,338.50 1,191.00 2.50 0.00 6.77 Hold for 107.25' 1,400.00 21.19 330.00 1,377.93 1,230.43 0.00 0.00 6.85 1,411.34 21.19 330.00 1,388.50 1,241.00 0.00 0.00 7.00 Base permafrost(?) 1,464.97 21.19 330.00 1,438.50 1,291.00 0.00 0.00 7.00 Start 3.5°/100'DLS,-56.05°TF,for 210.45' 1,500.00 21.90 327.27 1,471.09 1,323.59 3.50 -56.05 7.08 1,600.00 24.14 320.38 1,563.14 1,415.64 3.50 -53.51 7.32 1,675.42 26.00 315.96 1,631.45 1,483.95 3.50 -47.16 6.59 Hold for 2412.73' 1,700.00 26.00 315.96 1,653.55 1,506.05 0.00 0.00 6.61 1,800.00 26.00 315.96 1,743.43 1,595.93 0.00 0.00 6.70 1,900.00 26.00 315.96 1,833.31 1,685.81 0.00 0.00 6.80 2,000.00 26.00 315.96 1,923.18 1,775.68 0.00 0.00 6.91 2,038.18 26.00 315.96 1,957.50 1,810.00 0.00 0.00 7.03 Top W Sak(W Sak D) 2,100.00 26.00 315.96 2,013.06 1,865.56 0.00 0.00 7.03 2,200.00 26.00 315.96 2,102.94 1,955.44 0.00 0.00 7.16 2,300.00 26.00 315.96 2,192.82 2,045.32 0.00 0.00 7.30 2,400.00 26.00 315.96 2,282.70 2,135.20 0.00 0.00 7.44 2,500.00 26.00 315.96 2,372.58 2,225.08 0.00 0.00 7.60 2,600.00 26.00 315.96 2,462.46 2,314.96 0.00 0.00 7.77 2,700.00 26.00 315.96 2,552.34 2,404.84 0.00 0.00 7.94 2,712.42 26.00 315.96 2,563.50 2,416.00 0.00 0.00 6.07 Base W Sak 2,768.60 26.00 315.96 2,614.00 2,466.50 0.00 0.00 6.07 10-3/4"x 13-1/2" 2,800.00 26.00 315.96 2,642.22 2,494.72 0.00 0.00 6.07 9/23/2015 9:44:28AM Page 3 COMPASS 5000.1 Build 74 • 0 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 2,900.00 26.00 315.96 2,732.10 2,584.60 0.00 0.00 6.15 2,979.44 26.00 315.96 2,803.50 2,656.00 0.00 0.00 6.31 C-80 3,000.00 26.00 315.96 2,821.98 2,674.48 0.00 0.00 6.31 3,100.00 26.00 315.96 2,911.86 2,764.36 0.00 0.00 6.54 3,200.00 26.00 315.96 3,001.74 2,854.24 0.00 0.00 6.83 3,300.00 26.00 315.96 3,091.62 2,944.12 0.00 0.00 7.18 3,400.00 26.00 315.96 3,181.50 3,034.00 0.00 0.00 7.58 3,500.00 26.00 315.96 3,271.38 3,123.88 0.00 0.00 8.02 3,600.00 26.00 315.96 3,361.26 3,213.76 0.00 0.00 8.50 3,700.00 26.00 315.96 3,451.13 3,303.63 0.00 0.00 9.00 3,800.00 26.00 315.96 3,541.01 3,393.51 0.00 0.00 9.53 3,900.00 26.00 315.96 3,630.89 3,483.39 0.00 0.00 10.08 4,000.00 26.00 315.96 3,720.77 3,573.27 0.00 0.00 10.65 4,088.15 26.00 315.96 3,800.00 3,652.50 0.00 0.00 11.17 Start 3°/100'DLS,-120°TF,for 2601.37' 4,100.00 25.82 315.25 3,810.66 3,663.16 3.00 -120.00 11.22 4,200.00 24.48 308.93 3,901.19 3,753.69 3.00 -119.36 11.54 4,300.00 23.43 302.01 3,992.59 3,845.09 3.00 -113.64 7.23 4,400.00 22.71 294.57 4,084.61 3,937.11 3.00 -107.31 7.14 4,487.56 22.37 287.77 4,165.50 4,018.00 3.00 -100.47 6.98 C-50 4,500.00 22.35 286.80 4,177.00 4,029.50 3.00 -94.19 6.98 4,600.00 22.37 278.90 4,269.51 4,122.01 3.00 -93.28 6.76 4,700.00 22.77 271.15 4,361.87 4,214.37 3.00 -85.98 6.52 2S_W9-Toe 4,800.00 23.52 263.76 4,453.84 4,306.34 3.00 -78.82 6.28 4,900.00 24.61 256.89 4,545.16 4,397.66 3.00 -72.03 6.07 4,993.22 25.87 251.04 4,629.50 4,482.00 3.00 -65.75 5.92 C-40 5,000.00 25.97 250.64 4,635.60 4,488.10 3.00 -60.46 5.92 5,100.00 27.58 245.01 4,724.88 4,577.38 3.00 -60.10 5.84 5,109.73 27.75 244.50 4,733.50 4,586.00 3.00 -55.08 5.81 C-37 5,200.00 29.40 240.00 4,812.78 4,665.28 3.00 -54.62 5.81 5,300.00 31.37 235.54 4,899.05 4,751.55 3.00 -50.67 5.85 5,376.14 32.98 232.48 4,963.50 4,816.00 3.00 -46.82 5.94 Growler-AA 5,400.00 33.49 231.57 4,983.46 4,835.96 3.00 -44.23 5.94 5,500.00 35.72 228.04 5,065.77 4,918.27 3.00 -43.47 6.08 5,600.00 38.04 224.87 5,145.76 4,998.26 3.00 -40.56 6.25 5,700.00 40.44 222.02 5,223.21 5,075.71 3.00 -38.03 6.46 5,740.65 41.44 220.95 5,253.91 5,106.41 3.00 -35.82 6.70 2S W9-Heel 5,800.00 42.91 219.45 5,297.90 5,150.40 3.00 -35.00 6.70 9/23/2015 9:44:28AM Page 4 COMPASS 5000.1 Build 74 • III Schlurnberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 5,900.00 45.42 217.10 5,369.63 5,222.13 3.00 -33.89 6.96 6,000.00 47.98 214.95 5,438.21 5,290.71 3.00 -32.21 7.25 6,050.37 49.28 213.93 5,471.50 5,324.00 3.00 -30.73 7.57 Top Cairn 6,100.00 50.58 212.96 5,503.45 5,355.95 3.00 -30.06 7.57 6,200.00 53.20 211.12 5,565.17 5,417.67 3.00 -29.44 7.90 6,224.11 53.84 210.70 5,579.50 5,432.00 3.00 -28.30 8.26 Top Bermuda 6,300.00 55.86 209.40 5,623.19 5,475.69 3.00 -28.05 8.26 6,358.76 57.43 208.44 5,655.50 5,508.00 3.00 -27.30 8.64 Base Bermuda 6,400.00 58.53 207.79 5,677.37 5,529.87 3.00 -26.78 8.64 6,435.22 59.48 207.24 5,695.50 5,548.00 3.00 -26.43 9.04 C-35 6,500.00 61.23 206.27 5,727.54 5,580.04 3.00 -26.15 9.04 6,600.00 63.94 204.82 5,773.58 5,626.08 3.00 -25.66 9.46 6,689.52 66.38 203.58 5,811.19 5,663.69 3.00 -25.00 9.85 Adjust TF to-91.74°,for 301.3' 6,700.00 66.37 203.35 5,815.39 5,667.89 2.00 -91.46 9.88 6,800.00 66.34 201.17 5,855.49 5,707.99 2.00 -91.37 10.05 6,900.00 66.34 198.99 5,895.62 5,748.12 2.00 -90.49 10.24 6,990.82 66.37 197.00 5,932.05 5,784.55 2.00 -89.61 10.45 Hold for 537.39' 7,000.00 66.37 196.80 5,935.74 5,788.24 2.00 -88.82 10.45 7,100.00 66.43 194.62 5,975.78 5,828.28 2.00 -88.74 10.67 7,158.82 66.48 193.34 5,999.28 5,851.78 2.00 -87.86 10.80 7,200.00 66.48 193.34 6,015.71 5,868.21 0.00 0.00 10.94 7,244.57 66.48 193.34 6,033.50 5,886.00 0.00 0.00 11.30 Top HRZ(K-2 mkr) 7,300.00 66.48 193.34 6,055.62 5,908.12 0.00 0.00 11.30 7,399.92 66.48 193.34 6,095.50 5,948.00 0.00 0.00 11.68 Upper Kalubik(base HRZ) 7,400.00 66.48 193.34 6,095.53 5,948.03 0.00 0.00 11.68 7,500.00 66.48 193.34 6,135.44 5,987.94 0.00 0.00 12.07 7,528.20 66.48 193.34 6,146.70 5,999.20 0.00 0.00 12.20 Start 3°/100'DLS,3.12°TF,for 620.24' 7,531.64 66.48 193.34 6,148.07 6,000.57 0.00 0.00 12.20 7,600.00 68.53 193.34 6,174.22 6,026.72 3.00 -0.13 12.48 7,645.53 69.89 193.33 6,190.38 6,042.88 3.00 -0.13 12.90 2S-Hammerhead 1.Heel 7,700.00 71.53 193.33 6,208.38 6,060.88 3.00 -0.12 12.90 7,777.75 73.86 193.32 6,231.50 6,084.00 3.00 -0.12 13.33 Lower Kalubik(K-1 mkr) 7,800.00 74.53 193.32 6,237.56 6,090.06 3.00 -0.12 13.33 7,900.00 77.53 193.32 6,261.70 6,114.20 3.00 -0.12 13.77 8,000.00 80.53 193.31 6,280.73 6,133.23 3.00 -0.12 14.23 9/23/2015 9:44:28AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°i100usft) (0) (usft) 8,007.80 80.76 193.31 6,282.00 6,134.50 3.00 -0.12 14.74 7-5/8"X 9-7/8" 8,030.43 81.44 193.31 6,285.50 6,138.00 3.00 -0.12 14.74 Kuparuk C(Top C4) 8,100.00 83.53 193.30 6,294.60 6,147.10 3.00 -0.12 14.74 8,140.84 84.75 193.30 6,298.77 6,151.27 3.00 -0.12 15.04 2S-Hammerhead 1.Heel 021315 BP 8,148.45 84.98 193.30 6,299.45 6,151.95 3.00 -0.12 15.04 Hold for 30' 8,149.05 85.00 193.30 6,299.50 6,152.00 3.00 -0.12 15.04 A4-2S-Hammerhead 1.Heel 092115 VO-2S-08 1.Heel 092115 VO Circle 8,178.45 85.00 193.30 6,302.06 6,154.56 0.00 0.00 15.24 Start 3°/100'DLS,0°TF,for 160.26' 8,179.05 85.00 193.30 6,302.11 6,154.61 0.00 0.00 15.24 8,200.00 85.60 193.48 6,303.83 6,156.33 3.00 16.67 15.39 8,300.00 88.48 194.34 6,309.00 6,161.50 3.00 16.66 16.21 8,338.71 89.59 194.67 6,309.65 6,162.15 3.00 16.62 16.62 Hold for 6621.44' 8,346.39 89.81 194.74 6,309.69 6,162.19 3.00 16.61 16.62 8,400.00 89.81 194.74 6,309.87 6,162.37 0.00 0.00 17.09 8,500.00 89.81 194.74 6,310.20 6,162.70 0.00 0.00 18.02 8,600.00 89.81 194.74 6,310.53 6,163.03 0.00 0.00 19.02 8,700.00 89.81 194.74 6,310.86 6,163.36 0.00 0.00 20.08 8,800.00 89.81 194.74 6,311.19 6,163.69 0.00 0.00 21.18 8,900.00 89.81 194.74 6,311.52 6,164.02 0.00 0.00 22.33 9,000.00 89.81 194.74 6,311.85 6,164.35 0.00 0.00 23.52 9,100.00 89.81 194.74 6,312.18 6,164.68 0.00 0.00 24.73 9,200.00 89.81 194.74 6,312.51 6,165.01 0.00 0.00 25.98 9,300.00 89.81 194.74 6,312.84 6,165.34 0.00 0.00 27.24 9,400.00 89.81 194.74 6,313.18 6,165.68 0.00 0.00 28.53 9,500.00 89.81 194.74 6,313.51 6,166.01 0.00 0.00 29.83 9,600.00 89.81 194.74 6,313.84 6,166.34 0.00 0.00 19.04 9,700.00 89.81 194.74 6,314.17 6,166.67 0.00 0.00 19.43 9,800.00 89.81 194.74 6,314.50 6,167.00 0.00 0.00 19.84 9,900.00 89.81 194.74 6,314.83 6,167.33 0.00 0.00 20.25 10,000.00 89.81 194.74 6,315.16 6,167.66 0.00 0.00 20.68 10,100.00 89.81 194.74 6,315.49 6,167.99 0.00 0.00 21.11 10,200.00 89.81 194.74 6,315.82 6,168.32 0.00 0.00 21.54 10,300.00 89.81 194.74 6,316.15 6,168.65 0.00 0.00 21.98 10,400.00 89.81 194.74 6,316.48 6,168.98 0.00 0.00 22.43 10,500.00 89.81 194.74 6,316.82 6,169.32 0.00 0.00 22.89 10,600.00 89.81 194.74 6,317.15 6,169.65 0.00 0.00 23.35 10,700.00 89.81 194.74 6,317.48 6,169.98 0.00 0.00 23.82 10,800.00 89.81 194.74 6,317.81 6,170.31 0.00 0.00 24.29 10,900.00 89.81 194.74 6,318.14 6,170.64 0.00 0.00 24.76 9/23/2015 9:44:28AM Page 6 COMPASS 5000.1 Build 74 • 0 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 11,000.00 89.81 194.74 6,318.47 6,170.97 0.00 0.00 25.24 11,100.00 89.81 194.74 6,318.80 6,171.30 0.00 0.00 25.72 11,200.00 89.81 194.74 6,319.13 6,171.63 0.00 0.00 26.21 11,300.00 89.81 194.74 6,319.46 6,171.96 0.00 0.00 26.70 11,400.00 89.81 194.74 6,319.79 6,172.29 0.00 0.00 27.20 11,500.00 89.81 194.74 6,320.12 6,172.62 0.00 0.00 27.70 11,600.00 89.81 194.74 6,320.46 6,172.96 0.00 0.00 28.20 11,700.00 89.81 194.74 6,320.79 6,173.29 0.00 0.00 28.70 11,800.00 89.81 194.74 6,321.12 6,173.62 0.00 0.00 29.21 11,900.00 89.81 194.74 6,321.45 6,173.95 0.00 0.00 29.72 12,000.00 89.81 194.74 6,321.78 6,174.28 0.00 0.00 30.23 12,100.00 89.81 194.74 6,322.11 6,174.61 0.00 0.00 30.74 12,200.00 89.81 194.74 6,322.44 6,174.94 0.00 0.00 31.26 12,300.00 89.81 194.74 6,322.77 6,175.27 0.00 0.00 31.78 12,400.00 89.81 194.74 6,323.10 6,175.60 0.00 0.00 32.30 12,500.00 89.81 194.74 6,323.43 6,175.93 0.00 0.00 32.82 12,600.00 89.81 194.74 6,323.76 6,176.26 0.00 0.00 33.35 12,700.00 89.81 194.74 6,324.09 6,176.59 0.00 0.00 33.87 12,800.00 89.81 194.74 6,324.43 6,176.93 0.00 0.00 34.40 12,900.00 89.81 194.74 6,324.76 6,177.26 0.00 0.00 34.93 13,000.00 89.81 194.74 6,325.09 6,177.59 0.00 0.00 35.46 13,100.00 89.81 194.74 6,325.42 6,177.92 0.00 0.00 35.99 13,200.00 89.81 194.74 6,325.75 6,178.25 0.00 0.00 36.53 13,300.00 89.81 194.74 6,326.08 6,178.58 0.00 0.00 37.06 13,400.00 89.81 194.74 6,326.41 6,178.91 0.00 0.00 37.60 13,500.00 89.81 194.74 6,326.74 6,179.24 0.00 0.00 38.14 13,600.00 89.81 194.74 6,327.07 6,179.57 0.00 0.00 38.68 13,649.88 89.81 194.74 6,327.24 6,179.74 0.00 0.00 39.22 2S-Hammerhead 2.Toe 13,700.00 89.81 194.74 6,327.40 6,179.90 0.00 0.00 39.22 13,800.00 89.81 194.74 6,327.73 6,180.23 0.00 0.00 39.76 13,900.00 89.81 194.74 6,328.07 6,180.57 0.00 0.00 40.30 14,000.00 89.81 194.74 6,328.40 6,180.90 0.00 0.00 40.84 14,100.00 89.81 194.74 6,328.73 6,181.23 0.00 0.00 41.39 14,200.00 89.81 194.74 6,329.06 6,181.56 0.00 0.00 41.93 14,300.00 89.81 194.74 6,329.39 6,181.89 0.00 0.00 42.48 14,400.00 89.81 194.74 6,329.72 6,182.22 0.00 0.00 43.03 14,500.00 89.81 194.74 6,330.05 6,182.55 0.00 0.00 43.57 14,600.00 89.81 194.74 6,330.38 6,182.88 0.00 0.00 44.12 14,700.00 89.81 194.74 6,330.71 6,183.21 0.00 0.00 44.67 14,800.00 89.81 194.74 6,331.04 6,183.54 0.00 0.00 45.22 14,900.00 89.81 194.74 6,331.37 6,183.87 0.00 0.00 45.77 14,960.14 89.81 194.74 6,331.57 6,184.07 0.00 0.00 46.11 Start 3°/100'DLS,-179.93°TF,for 79.57' 14,960.69 89.81 194.74 6,331.58 6,184.08 0.00 0.00 46.11 9/23/2015 9:44:28AM Page 7 COMPASS 5000.1 Build 74 10 S . Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit TVD Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (0) (usft) 15,000.00 88.63 194.73 6,332.11 6,184.61 3.00 -179.36 46.20 15,039.72 87.44 194.71 6,333.47 6,185.97 3.00 -179.36 46.17 Hold for 1111.04' 15,040.35 87.42 194.71 6,333.50 6,186.00 3.00 -179.36 46.17 2S-Hammerhead 2.2nd point 002115 PB 15,100.00 87.42 194.71 6,336.18 6,188.68 0.00 0.00 46.31 15,200.00 87.42 194.71 6,340.68 6,193.18 0.00 0.00 46.86 15,300.00 87.42 194.71 6,345.18 6,197.68 0.00 0.00 47.41 15,400.00 87.42 194.71 6,349.69 6,202.19 0.00 0.00 47.97 15,500.00 87.42 194.71 6,354.19 6,206.69 0.00 0.00 48.52 15,600.00 87.42 194.71 6,358.69 6,211.19 0.00 0.00 49.07 15,700.00 87.42 194.71 6,363.19 6,215.69 0.00 0.00 49.63 15,734.18 87.42 194.71 6,364.72 6,217.22 0.00 0.00 50.18 2S-Hammerhead 1.Toe 012815 PB 15,800.00 87.42 194.71 6,367.69 6,220.19 0.00 0.00 50.18 15,900.00 87.42 194.71 6,372.19 6,224.69 0.00 0.00 50.74 16,000.00 87.42 194.71 6,376.69 6,229.19 0.00 0.00 51.30 16,100.00 87.42 194.71 6,381.19 6,233.69 0.00 0.00 51.85 16,149.77 87.42 194.71 6,383.43 6,235.93 0.00 0.00 52.14 2S-Hammerhead 1.Toe 021315 BP 16,150.75 87.42 194.71 6,383.47 6,235.97 0.00 0.00 52.14 TD:16150.75'MD,6383.5'TVD-4-1/2"x 6-1/2" 16,151.39 87.42 194.71 6,383.50 6,236.00 0.00 0.00 52.14 2S-08 3.Toe 092115 PB Circle-2S-Hammerhead 3.Toe 092115 9/23/2015 9:44:28AM Page 8 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-08 Project: Kuparuk River Unit ND Reference: 27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: 27.5+120 @ 147.50usft(Doyon141) Well: Plan:2S-08 North Reference: True Wellbore: Plan:2S-08 Survey Calculation Method: Minimum Curvature Design: 2S-08wp08.1 [Hammerhead] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 8,007.80 6,282.00 7-5/8"X 9-7/8" 7-5/8 9-7/8 16,150.75 6,383.47 4-1/2"x 6-1/2" 4-1/2 6-1/2 2,768.60 2,614.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 366.50 366.50 K-15 Marker 2,038.18 1,957.50 Top W Sak(W Sak D) 6,435.22 5,695.50 C-35 282.50 282.50 top T-3 Sand 7,399.92 6,095.50 Upper Kalubik(base HRZ) 7,777.75 6,231.50 Lower Kalubik(K-1 mkr) 6,358.76 5,655.50 Base Bermuda 6,224.11 5,579.50 Top Bermuda 5,109.73 4,733.50 C-37 6,050.37 5,471.50 Top Cairn 2,979.44 2,803.50 C-80 7,244.57 6,033.50 Top HRZ(K-2 mkr) 4,487.56 4,165.50 C-50 8,149.05 6,299.50 A4 1,411.34 1,388.50 Base permafrost(?) 4,993.22 4,629.50 C-40 2,712.42 2,563.50 Base W Sak 5,376.14 4,963 50 Growler-AA 8,030.43 6,285.50 Kuparuk C(Top C4) � ans°F� �� NYUVAMUMAIMI li Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 450.00 450.00 0.00 0.00 KOP.Start 1.5°/100'DLS,330°TF,for 150.04' 600.04 600.00 2.55 -1.47 Start 2.5°/100'DLS,0°TF,for 757.67' 1,357.71 1,338.50 135.25 -78.09 Hold for 107.25' 1,464.97 1,438.50 168.83 -97.47 Start 3.5°/100'DLS,-56.05°TF,for 210.45' 1,675.42 1,631.45 235.02 -148.63 Hold for 2412.73' 4,088.15 3,800.00 995.33 -883.88 Start 3°/100'DLS,-120°TF,for 2601.37' 6,689.52 5,811.19 183.44 -1,922.85 Adjust TF to-91.74°,for 301.3' 6,990.82 5,932.05 -75.28 -2,018.52 Hold for 537.39' 7,528.20 6,146.70 -553.41 -2,136.96 Start 3°/100'DLS,3.12°TF,for 620.24' 8,148.45 6,299.45 -1,135.64 -2,274.80 Hold for 30' 8,178.45 6,302.06 -1,164.73 -2,281.68 Start 3°/100'DLS,0°TF,for 160.26' 8,338.71 6,309.65 -1,320.02 -2,320.36 Hold for 6621.44' 14,960.14 6,331.57 -7,723.54 -4,004.93 Start 3°/100'DLS,-179.93°TF,for 79.57' 15,039.72 6,333.47 -7,800.48 -4,025.15 Hold for 1111.04' 16,150.75 6,383.47 -8,874.00 -4,307.02 TD: 16150.75'MD,6383.5'TVD Checked By: Approved By: Date: 9/23/2015 9:44:28AM Page 9 COMPASS 5000.1 Build 74 0 i i " 1 - ' cu Co s" cra oG ! 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N- N LO O V 6) LLO N LO 6) CO CC CK) W of W CO CC d L4 O p C) N 6j 6i p 0 0 0 0 0 0 0 0 Nr (n -p = p_4- O N O CA O .4- N1 V N O N O N e0+ R O U) O M CO N CO N V V' CO V N N N COCOCOODCOCOODCO 0 0 0 0 0 0 0 0 G ?o E U) U) u) u) (n (n0i0) (3 C N N N N N N N N (1)1 03 N -. CI C.. N N o m :•.--- c C CO m 0000000rn L a s o CD a CD CD X X O O CO O CO c? = ' c5 •y o 2 2 m m oocdocoN.: N _ co 3p C) U C) (3 0 o 0 V LO LO CO LO CO O O LO O 0 C) p) N N U U i_ N O OD N O N O LO ^ (n a O O - 0 (3 3 7 N V O C (O 0- N i R O `Ns- 3 r s 1-_, C y 0_ E CO CO U) U) C d C) U Z ▪ M C) 0 0 O O 6 T QS aF 0 c m M - - ¢ 3 3 0 _0 o o 0 0 0 0 0 0 CO (o (` O 5 Ln O O Ln (o (o L (C6 aN e+ N .fl (n N N V V CO (O Ch (n O 1� O O I� Cb Cl) r r Q^ U) a C U O N . . (!) (n (n Ch O O N N L O N N N CO CO O O °. ?...^N M E 00 N N N N (n Cn �_ �_ 0_ N N W O J C1 (L ' ' N N E E O N d y m CO v CO CO O of 0 C m Cn (n U) 6 ch U) 6 o 0 0 0 pOj Z NNNNN N N w 0) � (n Q) tn D. `1 p N C C C C C C C N N N N O r O @ CO (3 CO 03 CO 0) •• • •• •• O NO • o � o � aLLaaa aa. � E -Eo' L. N O N C) 0 co co co N- x- CO V V V ':1- , •4 O N O O O O E a ° C) = l£3 R Cn Cn Cn (n CI) CI) CI) O C O C.- Z a NNNNN N N N N N N Q U MS O 4▪-1 0 o re CS « 0 (C3 EEE m o m m 0) 0) a) Cr) = j O C C 0) 0 C1 0_ Cl Cl Cl Cl LL ct LL' Et K N Q 8,3 O u u s • H et cti cn fa. Cr.,at O G O C O V 60 4) s s03- 4) o ca a 2 I V" 00 O Q 00 CO O (/J U O 'C N m 0 °) - c 00 13 O N 0 c 3 2 CD Q as m O c N o m c ) D .o c E a) as _ U N C R O O C O O N 0 N , N • e- 'O N LE _ al N 0 0 0 N aa.) a) — 0 0 3 rn c a 0 (6 N '� N m ami N 3 m AQ a� 0 c w m N 0 N Ct a O N N 0 `o 2- 'o 2m a`) c' C m c 3 to O _ o (1) V-- N N (O C % C C N Q o a °o o 0 o m o C a a) a, C _ 0 m C C O = a1 C a5 n3 N U) C. N CO N N Q W O U) 5 Q • • ConocoPhillips 2S-08wp08. 1 [Hammerhead] Schlumberger Alaska o� ° 'o e o0 . .: E 3 r r my N MrN I IIIDI I I1�1 300- II �f I I,... _ _ - i '• , IIIIAll II II,,I, m JII /111 a IIID IIS d 1150 II v _ i [ ��I I� o III, 1 II 0.2 ,�I , I I'i�ll I I :: 11u11I 111 U 91 li 1,1 11 Equivelant Magnetic Distance [ 'IV 1 I 0 1 I 1 I I I I I I I I I I I I I I I I I I I i1 11111111r 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire range: Measured Dept127.50 To 16151.39 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 27.50 To 16151.39 Results Limited By: Centre Distance: 1812.39 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 27.50 650.00 2S-08wp08.1 [Hammerhead](Plan: 2S-08) INC+TREND 650.00 1650.00 25-08wp08.1 [Hammerhead](Plan:2S-08) MWD 650.00 2768.60 25-08wp08.1 [Hammerhead](Plan:2S-08) MWD+IFR-AK-CAZ-SC 27.50 650.00 25-08wp08.1 [Hammerhead](Plan:2S-08) GYD-GC-SS 2768.60 4268.60 25-08wp08.1 [Hammerhead](Plan: 2S-08) MWD 2768.60 8007.16 2S-08wp08.1 [Hammerhead](Plan:2S-08) MWD+IFR-AK-CAZ-SC 8007.16 9507.16 25-08wp08.1 [Hammerhead](Plan:2S-08) MWD 8007.16 16151.39 25-08wp08.1 [Hammerhead](Plan:2S-08) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2614.00 2768.60 10-3/4" x 13-1/2" 10-3/4 6282.00 8007.80 7-5/8"X 9-7/8" 7-5/8 6383.47 16150.75 4-1/2"x 6-1/2" 4-1/2 LEGEND -e- Prelim:2L-302(Langley),2L-302L1,2L-302L?®p01]Gfl:2S-03,Plan 2S-03,2S-03wp06[Bamboo]VO -1--- Plan:2S-11,Plan:2S-11L1,2S-t1L1wp06[Great White]VO -h- Plan:2S-14,Plan:25-14,2S-14wp07[Whale]VO 2S-02,2S-02,25-02 VO -e- Plan 25-05,Plan 2S-05,2S-05wp06[Nurse]VO - Plan:2S-12,Plan:2S-12,2S-12wp07[Bull]VO -e-- Plan:2S-16,Plan:25-16,2S-t6wp06[Squalicoran] '7:).- 2S-07,2S-07,2S-07 VO -X- Plan 2S-06,Plan.2S-06,2S-06wp06[Salmon]VO -i- Plan:2S-13,Plan:2S-13,2S-13wp12Megalodon]VO -e- Rig:2S-04,Rig:25-04,2S-04wp10.1 VO 2S-10,2S-10,25-10 VO -X- Plan:25-09,Plan 2S-09,2S-09wp06[Tiger]VO -8- Plan:2S-13,Plan:2S-13L1,2S-13Lwp12Megalodon]VO --X- Rig:2S-04,Rig:2S-04,Rig:2S-04 VO -8- Plan:25.01,Plan:2S-01,2S-01wp07[Mako]r Plan:2S-11,Plan 2S-11,2S-11wp06[Great White]VO 4,-- Plan:2S-13,Plan 2S-13PB1,2S-13PB1wp12[Megalodon]VO--- 2S-08wp08.1[Hammerhead] • • ConocoPhiilips 2S-08wp08. 1 [Hammerhead] Schlumberger Alaska I rnE i7 - N 3 ' 3 n N I'„' iv a 4; , I I ---____ iii , '4 1 i . r i /: • . % Ft (,,i : .i. I . .. ... ... ... ... . : a) , , , Ail 1,P4Or 1 . 4111 i 030 _ Ail / IIIIII Ill r il" ;/ 2 Eqr . uivelant Magnetic Distance ,,,, 0 _ \ II' lI r . o II•-.4111111111111 - 0 1 1 1 1 1 I 1 I 1111111111111111111111 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire range: Measured Dept127.50 To 16151.39 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 27.50 To 16151.39 Results Limited By: Centre Distance: 1812.39 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 27.50 650.00 2S-08wp08.1 [Hammerhead](Plan:2S-08) INC+TREND 650.00 1650.00 25-08wp08.1 [Hammerhead](Plan:2S-08) MWD 650.00 2768.60 25-08wp08.1 [Hammerhead](Plan:2S-08) MWD+IFR-AK-CAZ-SC 27.50 650.00 2S-08wp08.1 [Hammerhead](Plan: 2S-08) GYD-GC-SS 2768.60 4268.60 2S-08wp08.1 [Hammerhead](Plan:2S-08) MWD 2768.60 8007.16 2S-08wp08.1 [Hammerhead](Plan:2S-08) MWD+IFR-AK-CAZ-SC 8007.16 9507.16 25-08wp08.1 [Hammerhead](Plan:2S-08) MWD 8007.16 16151.39 2S-08wp08.1 [Hammerhead](Plan:2S-08) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2614.00 2768.60 10-3/4"x 13-1/2" 10-3/4 6282.00 8007.80 7-5/8"X 9-7/8" 7-5/8 6383.47 16150.75 4-1/2"x 6-1/2" 4-1/2 LEGEND - Prelim:2L-302(Langley),2L-302L1,2L-302L-1Qp61p1M:2S-03,Plan:2S-03,2S-03wp06[Bamboo]VO -i- Plan:2S-11,Plan:2S-11L1,2S-11 L1wp06[Great White]VO --A- Plan:2S-14,Plan:2S-14,2S-14wp07[Whale]VO -0- 2S-02,2S-02,25-02 VO -e-- Plan:2S-05,Plan:2S-05,2S-05wp06[Nurse]VO --f- Plan:2S-t2,Plan:2S-12,2S-12wp07[Bull]VO $ Plan:2S-16,Plan:2S-16,2S-16wp06[Squalicorax] 2S-07,2S-07,2S-07 VO --x-- Plan:2S-06,Plan:2S-06,2S-06wp06[Salmon]VO --T.- Plan:2S-13,Plan:2S-13,2S-13wp12Megalodon]VO -.a- Rig:2S-04,Rig:2S-04,2S-04wp10.1 VO - 2S-10,2S-10,2S-10 VO -X- Plan:2S-09,Plan:2S-09,2S-09wp06[Tiger]VO -B- Plan:2S-13,Plan:2S-13L1,2S-13Lwp12Megalodon]VO (- Rig:2S-04,Rig:2S-04,Rig:20-04 VO -8-- Plan:2S-01,Plan:2S-01,2S-01wp07[Mako]- - Plan:2S-11,Plan:2S-11,2S-11wp06[Great White]VO -A- Plan:2S-13,Plan:2S-13PB1,2S-13PB1wp12[Megalodon]VO-B- 2S-08wp08.1[Hammerhead] MD Azi TVD +N/-S +E/-W Dleg TFacearget LtS 40U 27.50 0.00 27.50 0.00 0.00 0.00 0.00 450 640 2 3-08wp08.1 [Hammer^hea 500:040 2:25 330.00 0.00 600:00 255 0.00 1.47 1.50 330.00 2.08 27.50 To 16151 .39 357.71 21.19 330.00 1338.50 135.25 -78.09 2.50 0.00 -110.43 640 840 1464.97 21.19 330.00 1438.50 168.83 -97.47 0.00 0.00 -137.85 1675.42 26.00 315.96 1631.45 235.02 -148.63 3.50 -56.05 -188.54 088.15 26.00 315.96 3800.00 995.33 -883.88 0.00 0.00 -732.65 840 1030 689.52 66.38 203.58 5811.19 183.44 -1922.85 3.00 -120.00 320.48 9:50,September 23 2015 158.82 66.48 193.34 5999.28 -223.88 -2058.81 2.00 -91.48 749.09 1030 1220 531.64 66.48 193.34 6148.07 -556.47 -2137.69 0.00 0.00 1090.79 4149.05 85.00 193.30 6299.50 -1136.23 -2274.94 3.00 -0.13 1686.31 2S-Hammerhead 1.Heel 092115 VO 1220 1420 SURVEY PR000/00 9179.05 85.00 193.30 6302.11 -1165.31 -2281.82 0.00 0.00 1716.18 .pm zi so 65000 2s-0Bwp0H.1[Hammerhead]016/061"6.61169346.39 89.81 194.74 6309.69 -1327.45 -2322.31 3.00 16.67 1883.28 ... 650.00 1650.00 25-0Bwp08.1[Hammerhead]In.25-08) 8960.69 89.81 194.74 6331.58 -7724.07 -4005.07 0.00 0.00 8497.47 1420 -_ -__ - 1610 650.00 2768.60 26-08wp08.1[Hammerhead]141180+26W]6CP2-5C 5040.35 87.42 194.71 6333.50 -7801.09 -4025.31 3.00 -179.38 8577.10 2S-Hammerhead 2.2nd point 002115 PB 27.50 650.00 25-0ew308.1[Hammerhead](80614266ae) 3151.39 87.42 194.71 6383.50 -8874.61 -4307.18 0.00 0.00 9687.00 2S-Hammerhead 3.Toe 092115 1610 1800 2760.60 6268.60 25-08wp08.1[Hammerhead]0711010 25-00) 2768.60 8007.16 25-08,08.1[Hammerhead]0180+26UOJ(L8Z-sc 8007.10 9507.16 25-08wp0.1[Hammerhead]gat.25-08) 8007.16 16151 39 25-08wp06.1[Hammerhead]Qa100+26Ua(SPZSC 1800 2400 CASING DETAILS 2400 3000 TVD MD Name Size 3000 3600 2614.00 2768.60 10-3/4"x 13-1/2" 10-3/4 6282.00 8007.80 7-5/8"X 9-7/8" 7-5/8 3600 4200 6383.47 16150.75 4-1/2"x6-1/2" 4-1/2 4200 " -" 4800 4800 5400 5400 ' 6000 0/360 6000 6600 k--:_"----_-- 225 -4 6600 7790 -30/330//! , � ,.: _:210 6 30 7790 8990 195 I2S-o4wplo.11 8990 10180 .:,0 ,141.4 10180 11380 165 e � �� 11380 12570 y►_ �� 1� 12570 13760 „4, ____--------__ 444,-.. 'IS 13760 14960 60/300 �� . ����\��'��," � 60 14960 16151 l''' 1111-1----_72:-: i R'�N��s�c�,:: �2S O6wp06[Salmo 1 .4: i 4.7 ..o" L.,�n 1.�4- - ♦ ,k. 2S-03wp06[Bamboo] �e :X54 1\ ,4��6 • ':1 o,,,,,,,,,,::��A`h��`� jR� .t}1���1��V11►1.a�4����A��A. III lilt /(// �] �! (� _ a r�r�"ti�` ,�,'y'(i����� �F �ajimaa�r',=°:'�:s+�N j /�l'` S� +V`. r u4:,',2,.• .' 3+ 6.®e o o 2SA1wp07[Mako]111 1 )1:r j )/) / i/ i/� �1' i 1{ 1, �,'A� d . tl +,;,,i ' .71.,:•% ..4.1'..',+t6 ,r9♦ �'►•Ii :11 „.„,:„..; $1, e•t! •L.A 4 1ti • f��p�ji..!...1221..,' .1/. !Ii90/270 � ®� �/,�p{�'/ , ,,,,``` a a t\•�.. ..- I r , ,,,„;,,,,,x,„„„,.,,,..,,,,...,.,„,wa90 1� 'C11 1 V' a w*1i w 1 -4;74i itnl a/'r a /. 5 ) j1 ,41111 X111412@ �t �. 3 , �#/i/ - r 1. 1; / -f"'-,^-. i 1�6� .�✓��k11 N�Ni�17a►tl� f 1►. 1 ;z[1 1x1111"1 1 , t.4 : o _ t1, v 1 aWil 111N1 1 � 1}}j��f� t P''' a ia�g•,;i��r�� �'�-` �`'♦�ry � O/1 �i'�gNNp�a. ,, ��p\ ee' '9! "r 1 �i'i' I qA v I ''''',),'''''R-1',J,,,/ �1 ^ Ii�A11 ii... "+ ✓fv.V-0 *x .tea'* . P 7' $ v ✓Drib ;'' ♦ 11 �1 ,1'/ - 114 ,11 r l 411�. ,I2S-021 1r& e � ♦ r .t'4A•► sg1 � I >r a. I� p�N � _ a ry V��A� - •:8.g6 r*1.0 mef: ',tF yid 1D�s N <Y ,1 9 � t!£a4 ; �. +, $♦yup .141\ :T� �, 4e k,gi��//)� a+y ��g�11 �y,$qry��% ,,,,,:•,,v-a i ` 1'��A �.�� SA . ata 44/,',i,'..7....".4%.4,,,,.,!.(-.a]�� IIl a♦��4ey I/ �. ',,,t.,147';,'��'�4,10:1,47.10,q ♦, Q�``�`, ,b 14,♦41 ��‘..,,,.:„.7.4:7,...;?.. e-r p,;1 Ii 1171 so7 f®39/ a •+a 1e , ri,,ii `` e4,lora w--.Srt y ;pp®,' a 6� 0 �gt /IsK)1�1 1 /`s�: 14'f •eW ijilkyp. �Q� � It `1 �� ei'l l .fi �f i 4'I qa I� t 6:� ,l i�' r�'.'. =: i+�2'1, 1@' rsir ,40 i r.,,{r.y.Il/1®• �,Oio�q0 k.; • ..,,'1; l%7 t. 2S-12 07[Bola' %i 1 ♦' r1®•�6 lid --1.44. Ir..-Ir.. 11..e.... 4 t 9x417 r e .► :Is.; /i'i1��{ wP [ aI .L„-z �� .eg gO w s® l♦a 417 �j! 19 ♦ r9 ,41 « y�V 1 1'� Y1� Q1 I$r��,;�� r\ GwA ��11w �1 1 I,r� w.4,.,-"lit-rryhl-i•rrril ,I2S-701 --. .a.`d' j P�� 7-#4 ♦s�//Or.7,ie i,4"�+s+ 'rw�74ATI♦11� 44f44 eyr ®i le.irOr 12S-13wp12Megalodon]� . .♦ ilk,444,� ���� �i 1447�'���� �Z? 7x' 4eA',�tilai �4,3,w "�.1 r'$`�tl16Y4.V��' ���� '!'� ! 16,i 'r 1:,, '®r�40,-, r=�ii1► l ssor"®�� .,♦! 120/240 �``.,1 ..q2r�L \1' •40,- 6 .,y,111. 1t s ` .1�°� o,, .ate ./A0, 1 ,$rte '�.t; _ •i ai Ir r/ 'Ra 4:1441''�`.; vp�` 120 dpi 141,4 �e m Ai$Da 4!� <r.= rt tint � 111 ♦ .sad"."® � � .Q\! � ,, ar�rb• Ar 125.13Lwp12M¢galodon]i�C101/ '.4. '4\\ �fr ®��4t ,' �./. pro ,A�I 10,i1i ,y 4y1 y41,7�ilp 2S-13P81 12 egalodon ♦ / ®�0 0ftfAtpl a�� ,y'�ei o1,Wr.,";,1 25-05wp06(Nurse]] �•AP s' 1� � � ® �a� /may wP 11,e� ►44,14, �.���•4 ,arliku -Ti'1!0 VI gi���0 1.eli ey d110: e QAC 1, �`�.1',• ��701rA atrw� jq �s'v �''�° Q� 125-lawpo7�,nmale]I '4,. !'�� 4- 1�'' ►°BCW- iy,e;- . w ��.II1®®y` ens, _� $l�.*-, � �1t�'!¢. --I Rig:2S-041 774 1 IFfied t,..a'-`.i �•A -150/210 s 1'-T :. .i._rsm�_�3'-� -,z-e•--......et---". 150 er Am 41 : q y-18. :1! 12S-o n 12S-11wp06[Great White]]___ ►� ,. 11C1�trirroSt .�!?if a� I2s-11L1wp06(Greatwr,lte]1 -180/180 I2S-o9wpos(ager]] -.- Maw a020argny,a'22u.21.-601 *52pk02501,Pte:23.04.2n.0,....71H343i 90 -i(- Plan n.2509,26-06.60617)96100 $- Pan n 2643 2512.m1211.r3633130 t Plan 23-16,061saaan85106 -0- 2002 $ Pim. n. 620. 610a.ee.1 Vo P . s1ws06101..O W428Va $ man. . emnl22 -} R4'.2804.P6:23042S045010.100 $ 25a2 $ Pa n. 26,15.1.61.4.100 -I- men 2311,Plan 161..x26[Gnat w4s.100 -,E, Pan. n. 5P1010.9aaec.1V0 Rd 2500,Ry:2004,70 2204v0 -B- 38-10.onw,2n10vo -K. man 02-08,man.2306.23.6«F06(Saaanrv0 ;- Plan 23-12.P.251220-12.mo710..)vo -� P...zSu,P..z5,4.z51mS07710.rv0 -g- ......8.11Ham....a01 • s q Northing (3000 usft/in) 1 I I I I I I I I I 1 I I I I I I I I I I I I I Iu1 1 1 I I I I I I I I I I I I I I I I I I I I I I I I 1 I 1 1 I 1 I I I I I I I 1 I 1 I I I I a.) Z N — 0 - O N - a - 3 - o — N O - O - a m - rn o co _ N a - co 3 3 0140 / p N - - ,bN _ 3 09 _'� ttS o c (V CL -CI 0.., 0 0_ . _ _ _ ` CO 0 s.- .t RS i E Q E ami 2 43. — 1 2 \ CO - L `- N O 3 o I Nco E crc cn j cir 7 Oo—V N ^O Mr - N a- v C Y C 0 - w co co W n W Q•a - so - - cn to = — C) t0 eu � -N 3 N = - 11 1 1 1 1 1 1 1 1 I I I I I I I I I I I I I I I 1 1 1 1 1 1 1 1 II I I I I I I I I I I I I I I 1 I I I I I I 1 I I I I I 1 1 1 1 1 o N (umisn 000£) 6u143JoN co 0) Pool Report Imimmimmmmemm J N i _ O o guoono �'.` L.0 JIH w o N O o O o O oI. ^��M:mom m 1 co p p 0. a N it m o O aJ_ N O 0,.., _ Lo o QIPh 3N m co N2 xNno I!II !I . _ xoxxx 3 .43 ZNNNNNNN ier \` Vm a 401 yin �R N os oLIIIIIL lic m3 Oo c o q ° 70 . "MN 1 Ihmom; All .Fr o 0 L M . x 4-1 N La ■ ° , n. i ..O ilit, ■- ^ 1 i 34 I ^O N — ; LO 00 N... O i loom m 0 N E Q I I O E ti N O 0 O r Ii 1 O 0 L0 LO o N N N I N L 2 I I I I I E O O O O O O Q 0 0 O O O in Lf) Ln O LOO N N Ln !` O a (u!/�4sn 0096 (+)upaoN/(-)ulnoS N J F 11111*" I 6 O O N , r • , n o 7 N , ,71 m F W111• A, „)11.i.,..:......... .../ . / ..„....... M1 H .1 1 I ''''',„. •Il ,/ • rminii • LIE E I. ii E i, .... . „ . . . . . .„ , .., ..... . .... .../ ....: / .... . . -,,... .„, . .. ...' ...._ .. ccs i ,".. .., / . ..., .. Z „. ..„ ,_.:_. . ../. .. • . .. . V . .. .. . . . .. . . ,. . . . .. . . .... . .. ,. . .,„. : r ,. .../ .......... ../ ....,...... , . . , 00 , ... , .... ,, ... ,/ „ .„. /, ... ... , CO .. ........ .., . : ... , .„. • •• 0 N , . ii 41 v's, 0 M t13 I . 7 ..... . / E / -.... ,, ..., . ... E , . ./ ..........•. .. • . . . . .. . . . . . . . . . . . . . .. . . . . . . .. . . . t� . . .. . .. . ... . ... . .• . . , ,\, „/"..,,.... . ... • . . . . . ... . . . . . . . . . .. . . . . . ... , , Igi, I u Co 0 - / .."\--,..„ / ....... CO CI / N / , W 1 m / • .• • CI • 111 i I II 0 ♦ r / SAIA. vg !...1 .... .: ., W , ... . ) ,, .MC IL a) i . ,./...; E / , .. ... .. / E / . . .........% / Co I •u Co Oi ..... / CO o • N a 0 M 1 __ Ilip' /I) cs E E 1 co coi / 01 a co 0 0 N i • 2S-08 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. Squeeze job or top job to remediate if needed. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Moderate Use PWD and T&D to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—12.5 ppg in Tarn formations crossed in intermediate. Hole cleaning Low Use PWD and T&D to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight, PWD to monitor ECD. 6-3/4" Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and T&D to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. • I Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD to monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. ZS-°$ Schlumberger CemCADE* Preliminary Job Design 10-3/4" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 250% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2030' MD. Client: CPAI Revision Date: Sept 9, 2015 Prepared by: Eric Hannum Location:Anchorage,AK Phone: (812)243-0650 Lead Slurry Minimum pump time: -215 min. (pump time plus 120 min.) email: ehannum@slb.com DeepCRETE @ 11 ppg- 1.91 ft3/sk 1.339 ft3/ft x (110') x 1.00 (no excess) = 148 ft3 < TOC at Surface 0.3637 ft3/ft x(1465- 110') x 3.50 (250% excess) = 1725 ft3 0.3637 ft3/ft x(2030- 1465) x 1.50 (50% excess) = 308 ft3 148 ft3+ 1725 ft3+ 308 ft3= 2181 ft3 2181 ft3/1.91 ft3/sk = 1.142 sks (-1155 sks) Please have extra Deep CRETE on location for top out. Previous Csg. Tail Slurry Minimum pump time: -160 min. (pump time plus 120 min.) < 20", 106.5#casing DeepCRETE @ 12 ppg - 1.63 ft3/sk at 110'MD 0.3637 ft3/ft x(2530-2030) x 1.50 (50% excess) = 273 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/ 1.63 ft3/sk = 195 sks Round up to 205 sks BHST=63°F, Estimated BHCT=75°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at 1,465'MD(-1,438'TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) _ MUDPUSH II 7.00 100.0 14.3 14.3 Pause 0.00 0.0 5.0 19.3 < Top of Tail at 11 ppg DeepCRETE 7.00 388.5 55.5 74.8 2,030' MD Surface Tail 7.00 56.3 8.0 DeepCRETE Slurry 82.8 Pause 0.00 0.0 5.0 87.8 Fresh Water 7.00 10.0 1.4 89.2 Pause, 0.00 0.0 5.0 94.4 £ Mud 8.00 225.6 28.2 122.6 - Mud 3.00 10.0 3.3 125.9 < 10-3/4",45.5#casing MUD REMOVAL in 13.5"OH Expected Mud Properties: 9.5 ppg, Pv<20, Tv< 20 TD at 2,530' MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv= 17-21, TY m 20-25 (2,400'TVD) Centralizers: As per CPAI program. Mark of Schl umberger • i 2S_08 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Casing Rig: Sta.e (V1) Doyon 141 Preliminary Job Design based on limited input data.For estimate purposes only. Location: Kuparuk Client: CPAI Revision Date: Sept22, 2015 Volume Calculations and Cement Systems Prepared by: Eric Hannum Volumes are based on 30% excess. The top of the 1st stage tail slurry is designed to be Location:Anchorage,AK Phone: (812)243-0650 at-6,000 MD. email: ehannum©slb.com Tail Slurry Minimum pump time: -213 min. (pump time plus 120 min.) 15.8 ppg Class G + GASBLOK*adds - 1.17 ft3/sk 0.2148 ft3/ft x (8006'-6000')x 1.30 (30% excess) = 560 ft3 0.2578 ft3/ft x 80' = 20 ft3 560 ft3+20 ft3 = 580 ft3 580 ft3/ 1.17 ft3/sk = 479 sks Round up to 490 sks Previous Csg. < 10-3/4",45.5.#casing at 2,530'MD BHST= 154°F, Estimated BHCT= 108°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) ChemWash ii 5.00 45.0 9.0 10.0 MUDPUSH it 5.00 45.0 9.0 18.0 < Stage tool at 5,200'MD Pause 0.00 0.0 5.0 23.0 15.8 ppg GASBLOK* 5.00 103.3 20.7 43.7 Slurry Pause 0.00 0.0 5.0 48.7 Fresh Water 5.00 10.0 2.0 50.7 Pause 0.00 0.0 5.0 55.7 Mud 5.00 352.1 70.4 126.1 Mud 3.00 10.0 3.3 129.4 " < Top of Cement at -6,000 MD MUD REMOVAL Expected Mud Properties: -11.1 ppg, Pv<20, Yield Point< 25. Spacer Properties: 12.0 ppg MudPUSH* II, Pv=20 -24, Yield Point = 20-30 < 7-5/8",29.7#casing in 9-7/8"OH Centralizers: As per program i TD at-8,006 MD (6,282'TVD) *Mark of Schlumberger • i 2S-08 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Casing Rig: Sta.e (V1) Doyon 141 Preliminary Job Design based on limited input data.For estimate purposes only. Location: Kuparuk Client: CPAI Revision Date: Sept22, 2015 Volume Calculations and Cement Systems Prepared by: Eric HageVolumes are based on 30% excess. The top of the 2nd stage tail slurry is designed to be Location:Anchorage,,AK AK Phone: (812)243-0650 at-4,500 MD. email:ehannum©slb.com Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.) 15.8 ppg Class G + GASBLOK* +adds - 1.17 ft3/sk 0.2148 ft3/ft x(5200'-4500')x 1.30 (30% excess) = 196 ft3 196 ft3= 196 ft3 196 ft3/ 1.17 ft3/sk = 168 sks Previous Csg. Round up to 175sks < 10-3/4",45.5.#casing at 2,530'MD BHST= 118°F, Estimated BHCT= 79°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.00 40.0 8.0 8.0 Pause 0.00 0.0 5.0 13.0 • 15.8 ppg GASBLOK* 5.00 34.9 7.0 20 Slurry Pause 0.00 0.0 5.0 25 Fresh Water 5.00 10.0 2.0 27 Pause 0.00 0.0 5.0 32 Mud 5.00 232.1 46.4 78.4 Mud 2.00 15.0 7.5 85.9 < Top of Cement at -4,500 MD MUD REMOVAL `i Expected Mud Properties:-11.1 ppg, Pv<20, Yield Point< 25. ;t; Spacer Properties: 12.0 ppg MudPUSH* II, Pv=20-24, Yield Point = 20-30 io < 7-5/8",29.7#casing Centralizers: As per program in 9-7/8"OH se Stage tool at-5,200' MD (4,812'TVD) *Mark of Schlumberger Reque or Waiver of AOGCC Regulation 20 AA .412(b) ConocoPhillips requests approval of our proposed plan to topset the Kuparuk sands per the following Alaska Administrative Codes. 20 AAC 25.412(b)A well used for injection must be equipped with tubing and a packer,or with other equipment that isolates pressure to the injection interval,unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone.The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent.The packer must be placed within 200 feet measured depth above the top of the perforations,unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. 20 AAC 25.030(c)(5)"production casing must be set and cemented through,into,or just above the production interval" 20 AAC 25.030(d)(5)"intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet above all significant hydrocarbon zones and abnormally geo-pressured strata or,if zonal coverage is not required under(a) of this section,from the casing shoe to a minimum of 500 feet above the casing shoe;if indications of improper cementing exist,such as lost returns,or if the formation integrity test shows an inadequate cement job,remedial action must be taken" Due to the elevated reservoir pressure(estimated–11.4 ppg)of the Kuparuk'A' Sands and the low fracture gradient(11.8 ppg)observed in shallow sand stringers in offset wells,landing intermediate casing in the Kuparuk Sands is not feasible. We propose to topset the overpressured Kuparuk'A' sands by landing–35' TVD above them, setting our 7-5/8" intermediate casing in the Lower Kalubik shale,and cementing from the shoe to the top of the Cairn formation. A cement stage tool in the 7-5/8"casing will also provide an additional+/-600' of cement above the C-37(Tarn area)interval with a second cement stage. This plan is similar to our recent wells on 2S pad that adjusted to a topset design on the fly after encountering losses in the intermediate section(2S-02,2S-07, and 2S-10). Please refer to the attached schematic for a diagram of the planned design. To confirm the presence of cement behind the intermediate casing,a recorded mode sonic log to confirm top of cement and integrity, as well as a leak-off test below the intermediate casing shoe,will be performed. Additionally,the heel of the 4-1/2"production liner will be blank pipe,with a swell packer run on the blank pipe to isolate the 7-5/8"casing shoe from the slotted liner. Due to this top set design,ConocoPhillips requests a waiver to the AOGCC regulation(20 AAC 25.412(b))stating that injection packers must be within 200 feet of the upper most perforations on injection wells.Packer placement is planned to be—292' MD/50' TVD above the slotted liner/top of Kuparuk A-sand. —' • • Bettis, Patricia K (DOA) et .2IS -4?At From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday, September 08, 2015 11:51 AM To: Bettis, Patricia K (DOA) Subject: RE: -1 • ..' . . ' _ Patricia, we are planning to pre-produce 2S-04 for approximately 6 months because of the following reasons: (1) it improves project economics by accelerating its production profile, and (2) it improves drillability on upcoming offset wells by drawing down expected pressures. We have modeled cases where injectors are pre-produced for 3 months and several other cases(see graph below). It shows how "2.5% HCPV Withdrawn (which occurs at"6months) is in the sweet spot of pre-production based on the early volumes.Anything beyond this point reduces reservoir pressure and could impair economics significantly. 1 • • Ill Impaired Initial Prod Impaired EUR Less initial volume Reduced reservoir Pressure. pre-produced before producers bought online al 5 Inkgr I ry '.:4-1.4 ..;,,,,,,i; , Ay :::;:1':''''I'I'll 1 . 334 a. C i ¢ p axy 0 1 2 3 4 5 6 HCPV Withdrawn Before Start of Injection 0.0 0.6 0.9 1.1 1.6 2.2 2.7 Avg Injector GOR at End of Pre-Prod Period, mscf/stb Please let me know if this answers your question or if you would like any further information. Thanks, Mike From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, September 08, 2015 11:02 AM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2S-04: Permit to Drill Application (PTD 215-159) Good morning Mike, 2 • • How long does ConocoPhillips anticipate to pre-produce the KRU 2S-04? If the duration of pre-production is more than 3 months, please provide a justification. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 3 • • Bettis, Patricia K (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Wednesday, September 30, 2015 10:48 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-08: PTD 215-174 Patricia,you are right. ConocoPhillips plans to pre-produce the well for about 6 months.Then switch to be an injection well. Haibin From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, September 30, 2015 10:43 AM To: Guo, Haibin Subject: [EXTERNAL]KRU 2S-08: PTD 215-174 Haibin, Does ConocoPhillips plan to pre-produce this well for 6 months? Thank you. Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, September 30, 2015 10:43 AM To: Guo, Haibin (Haibin.Guo@conocophillips.com) Subject: KRU 2S-08: PTD 215-174 Haibin, Does ConocoPhillips plan to pre-produce this well for^'6 months? Thank you. Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Tuesday, September 29, 2015 2:11 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-08: Permit to Drill Application (PTD 215-174) Patricia, As to today (9/29/2015), no well has penetrated in the injection zone within a one-quarter mile radius of the permitting 2S-08.The wells we have drilled on this pad are 2S-02, 2S-07 and 25-10.They are all more than one quarter miles away. The well we are drilling, 2S-04, is still under drilling, has not penetrated the injection zone yet. Hopefully this help. Any question or more information you need please let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.227.6048 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, September 29, 2015 1:37 PM To: Guo, Haibin Subject: [EXTERNAL]KRU 2S-08: Permit to Drill Application (PTD 215-174) Good afternoon Haibin, Under 20 AAC 25.402, ConocoPhillips needs to provide a report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of a proposed injection well. Please submit this information as soon as possible. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 1 • 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, September 29, 2015 1:37 PM To: Guo, Haibin (Haibin.Guo@conocophillips.com) Subject: KRU 2S-08: Permit to Drill Application (PTD 215-174) Good afternoon Haibin, Under 20 AAC 25.402, ConocoPhillips needs to provide a report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of a proposed injection well. Please submit this information as soon as possible. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. 0 O TRANSMITTAL LETTER CHECKLIST WELL NAME: 1<RL. eQS — 6� PTD: ovs-ay Development ✓Service Exploratory Stratigraphic Test Non-Conventional FIELD: KrAAK RAI POOL: Ktw G, JRA I€f'( 1(kra114-1‹. 2V r 61 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. 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'c, a'' O y, 3. o a g. a�i, m. @ a) 3 ° o a 2, M, 2 c`aa -a, co -o :o -c 0; 0; t; ° a a E,_ ) as a aa)i o 0 Cr) z. a. �. �. �', �, �, m, "--, o, o, a, a; U, �', Q; a; C.) cn, 0c�, c); c); ¢ 4-; ¢ '. o', m, m, 0 �, �''. 2, a, o, cn. cn. 0 0. O EN- O _ N M (O CO CO CO O N M U) (0 h a0 0) O N M C() CO N- a0 0) ° - ,- N M V O CO 0- CO 0) . . . ,- N N N N N N N N N N 01 M M C7 01 01 M M (O M_L i. �;x C..1 Cf) (P) O O 2 O C 0 ( r a) c) f6 2 U -n ix 0 0 0 0) O N O M .5-2 co v I W (Cl rn c o a 0E l'' aN Y a) >. O E J H C c ° ` m o 1,11-1 0 a s c Q > 0 0. a 'S: a a a • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 141 Date: November 17, 2015 Surface Data Logging End of Well Report 2S-08 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. Mud Record 5. Bit Record 6. Morning Reports 7. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska, Inc. Rig: Doyon 141 Well: 2S-08 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20722-00-00 Sperry Job Number: AK-AM-0902894891 Job Start Date: 9 November 2015 Spud Date: 6 November 2015 Total Depth: 13813’ MD, 6306’ TVD North Reference: True Declination: 18.528° Dip Angle: 80.866° Total Field Strength: 57487.505 nT Date Of Magnetic Data: 21 Oct 2015 Wellhead Coordinates N: North 70° 13’ 10.502” Wellhead Coordinates W: West 150° 9’ 19.954“ Drill Floor Elevation 147.5’ Ground Elevation: 120.0’ Permanent Datum: Mean Sea Level SDL Engineers: Macy Williams, Elijah Callan, Michael LaDouceur SDL Sample Catchers: Enoc Velez-Martinez, Jacob Floyd Company Geologist: Phil Bottrell Company Representatives: Dave Coates, Andy Lundale SSDS Unit Number: 125 DAILY SUMMARY 11/9/2015 Begin rigging up mud logging unit. Rigged up, calibrated and tested gas equipment. 11/10/2015 Singled into the hole with 5” drill pipe from 721’ MD to 1561’ MD. String packed off. Pull out of hole from 1561’ MD to 721’ MD and lay down BHA. Cement found packed off on top float. Cleaned out packed off stabilizer. Laid down 38 stands of 5” drill pipe due to cement as well. Picked up and racked back 29 stands of 5” drill pipe. Picked up BHA and singled into the hole from 720’ MD to 1648’ MD. Gas: Max gas was 6 units. Fluids: No losses/gains for 24 hour period. 11/11/2015 Continue running into the hole from 1648’ MD to 2486’ MD. Rig up to test casing. Drill out 20’ of hole from 2665’ MD to 2685’ MD. Perform FIT at 16.1 EMW. Displace mud to 9.6 ppg LSND on the fly. Begin drilling from 2685’ MD to 3655’ MD. Gas: Max gas was 264 units at 2676’ MD. Fluids: No losses/gains for 24 hour period. Geology: The samples have been predominantly Claystone. Very light to light gray, gummy to soft, slightly silty, poorly compacted, amorphous, with occ siltstone in places. 11/12/2015 Continue drilling ahead from 3606’ MD to 4252’ MD. Pump Hi Vis sweep and circulate out. Pull trip nipple and install RCD bearing. Continue drilling from 4436’ MD to 4662’ MD. Experience rig power outage. Recalibrate MPD chokes, and continue drilling ahead from 4662’ MD to 5460’ MD. Gas: Max gas was 373 units at 5236’ MD. Fluids: No losses/gains for 24 hour period. Geology: The samples have been predominantly Siltstone. Light to medium gray, soft to slightly firm in places, some friable, unconsolidated in places, crumbly, poorly compacted, and subblocky to blocky. 11/13/2015 Continue drilling ahead from 5470’ MD to 7151’ MD. TD declared at 7151’ MD (6173’ TVD). Gas: Max gas was 1514 units at 6832’ MD. Fluids: No losses/gains for 24 hour period. Geology: The samples have been predominantly Shale. Light to medium gray, occasionally dark gray, slightly firm to firm, soft in places, platy to flakey, moderately to well indurated, very silty, no fluorescence, no cut. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 5 10 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2S-08 OPERATOR: ConocoPhillips Alaska, Inc MUD CO: MI Swaco RIG: Doyon 141 SPERRY JOB: AK-XX-0902894891 Days vs. Depth 09 Nov 2015 Halliburton SDL Arrived on Location 14 Nov 2015 Halliburton SDL Released from Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 9-Nov-2015 TD: 13-Nov-2015 Commenced 14.5" Intermediate Hole Section On Bot: 08:30 11 Nov 2015 TD Intermediate Hole Section 7151' MD, 6173' TVD Off Bot: 19:00 13 Nov 2015 2S-08 ConocoPhillips Alaska, Inc. MI Swaco Doyon 141 AK-XX-0902894891 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 10-Nov 2665 9.60 82 48 26 9/13/17 6.6 122/74/55/33/9/8 1/NA 7.5 -/93 tr 0.40 9.9 25.5 .2/.75 400 120 Pre-Intermediate 11-Nov 3451 9.60 50 11 23 12/14/17 6.4 51/40/34/27/12/11 1/NA 6.0 1/93 tr 0.70 10.2 5.0 .4/1.1 750 200 Drill Ahead 12-Nov 5273 10.00 56 13 31 13/17/22 4.6 57/44/38/30/14/12 1/NA 8.5 1/91 tr 0.35 9.5 14.5 .2/1.3 760 280 Drill Ahead 13-Nov 7151 10.00 49 12 24 11/16/24 3.5 48/36/31/25/11/9 1/1 9.8 3/88 0.20 0.40 9.5 20.8 .25/1.4 800 260 TD Intermediate Section Casing Record WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:6-Nov-2015 SPERRY JOB:TD:13-Nov-2015 Remarks 10.75" Casing @ 2652' MD, 2547' TVD 7.625" Casing @ 7141' MD, 6169'TVD W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 3 100 3 PDC 9.875 2665 7151 4486 38.00 0.982 117.9 30 140 3125 800 1-1-W I-N-X-I-NO Intermediate TD WELL NAME:2S-08 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902894891 TD:13-Nov-2015 MI Swaco STATE:Alaska RIG:Doyon 141 SPUD:6-Nov-2015 B i t R e c o r d . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 62.84 -183328610 20 (max)(current) Cly Set AtSize 45.5 Grade 10.75" (907)-670-4906Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan \ Macy Williams 0 0 Units* Casing Summary Lithology (%) MBT pH 0.982 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 25.582 C-5n 0.0 C-2 in Minimum Depth Time: Singled into hole with 5" DP from 721' MD to 1561' MD. Attempted to SHT MWD tools. String packed off. POOH from 1561' MD to 2665' 2665' 0' Max @ ft. Current 0'0.0 Date: Avg. to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary (current) Dave Coates /Bob Finkbiner ShClyst TuffGvlCoal cP 48 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902894891 Tripping into hole PV 24 hr. Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90Spud6.62665'26 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Surface 100% Gas In Air=10,000 UnitsConnection representative. Singled into hole with 5" DP from 720' MD to 1648' MD. Performed SHT for MWD tools. of 5" DP because of cement found in the DP. Picked up and racked back 29 stands of 5" DP. Picked up BHA #3 PER Schlumberger 721' MD. Laid down BHA #2. Cement was found packed off on top float. Cleaned out packed off stabilizer. Laid down 38 stands 2652' ConditionBit # 1 7.5 9.875"PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2S-08 ConocoPhillips Alaska, Inc. Kuparuk 2S Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 10-Nov-2015 12:00 AM Current Pump & Flow Data: 0 Max Chlorides mg/l 400.00 Tested accumulator. B/D Choke and lines. Picked up Split bushings, riser and BHA tools. BHA #2 was made up. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 282.6 -284737132 15 (max)(current) 236 0 Cly 33778 Set AtSize 45.5 L-80 Grade 10.75" (907)-670-4906Unit Phone: 34 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan \ Macy Williams 10% 4201 22 807 190 Units* Casing Summary Lithology (%) 6 MBT 3655' pH 0.982 0 162 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.050 C-5n 2676' 138.0 C-2 264 in 1 2685'Minimum Depth Time: casing. Rigged down eqipment, Washed down from 2486' to 2665' MD. Drilled out 20' of hole from 2665' to 2685' MD. Circulated 32 from 2765' to 3655' MD (3382' TVD). 2665' 3655' 990' Max @ ft. Current 3509'128.0 Date: Avg. to2665' Yesterday's Depth: Current Depth: 24 Hour Progress: 162.0 Flow In (gpm) Flow In (spm) Gas Summary 0 15 55 (current) Dave Coates /Andy Lundale ShClyst TuffGvlCoal cP 11 Footage 90% Ss (ppb Eq) C-1 C-5i AK-AM-0902894891 Drilling Ahead PV 24 hr. Max Weight 15 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.20 227 123.0 LSND 6.43606'29 Depth in / out Mud Type Lst Type Average 40Background (max) Trip 9.9610.36 Avg Min Comments RPM ECD (ppg) ml/30min Tools SLB Ecoscope API FL Chromatograph (ppm) 15.52665' WOB Surface 100% Gas In Air=10,000 UnitsConnection 65 LSND. Drilled from 2685' to 2765' MD and then opened 11' under reamer. Continue to drill ahead through intermediate section Rigged down test equipment. Ran into hole from 2675' to 2686' MD. Pumped a 23 bbl Hi-Vis sweep. Displaced mud to 9.6 ppg bottoms at 650 BPM. Pulled out of hole from 2685' to 2675' MD. Reigged up test equipment and performed FIT at 16.1 EMW. 2652' ConditionBit # 2 6.0 9.875" 9.60 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.74 Doyon 141 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2S-08 ConocoPhillips Alaska, Inc. Kuparuk 2S Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Nov-2015 12:00 AM Current Pump & Flow Data: 2036 Max 4 Chlorides mg/l 750.00 Singled into hole with 5" DP from 1648' to 2486' MD. Rigged up to test casing. Circulated at 7.5 BPM. Tested rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled from 3606' to 4252' MD. Pumped a High Viscosity Sweep and circulated out the sweep at the drilling rate. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 760.00 40 12-Nov-2015 12:00 AM Current Pump & Flow Data: 2809 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2S-08 ConocoPhillips Alaska, Inc. Kuparuk 2S Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.56 Doyon 141 Report For: ConditionBit # 2 8.5 9.875" 10.05 PDC 10.05 Size drilling ahead from 4662' to 5460' MD (5014' TVD). Drilled from 4436' to 4662' MD and experienced a rig power outage. MPD chokes were re-calibrated after power outage. Continue 2652' 100% Gas In Air=10,000 UnitsConnection 510 Tools SLB Ecoscope API FL Chromatograph (ppm) 15.52665' WOB Surface 10.2410.96 Avg Min Comments RPM ECD (ppg) ml/30min 125Background (max) Trip Average Mud Type Lst 60% Type 123.0 LSND 4.65241'31 Depth in / out YP (lb/100ft2) 9.50 2102 00 CementChtSilt C-4i C-4n 24 hr. Max Weight 89 Hours C-3 30% Ss (ppb Eq) C-1 C-5i AK-AM-0902894891 Drilling Ahead PV Footage Dave Coates /Andy Lundale ShClyst TuffGvlCoal cP 13 Gas Summary 0 1625 42 (current) Avg. to3655' Yesterday's Depth: Current Depth: 24 Hour Progress: 185.0 Flow In (gpm) Flow In (spm) 3655' 5470' 1815' Max @ ft. Current 5469'118.0 Date: Time: OWFF: Static. Pulled the trip nipple, installed the RCD bearing and aligned the stack with the RCD bearing. Flooded MPD Unit. 70 in 25 4100'Minimum Depth C-5n 5236' 122.0 C-2 373 SPP (psi) Gallons/stroke TFABit Type Depth 14.556 MBT 5470' pH 0.982 0 79 0 Siltst 791 187 Units* Casing Summary Lithology (%) 64415 0 (907)-670-4906Unit Phone: 40 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan \ Macy Williams Set AtSize 45.5 L-80 Grade 10.75" (max)(current) 770 0 Cly 18733 10% Bottoms Up Time 459 -465058635 23 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Drilled from 5470' MD to 7151' MD. TD declared at 7151' MD (6173' TVD). While Drilling max formation gas was rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800.00 749 13-Nov-2015 12:00 AM Current Pump & Flow Data: 2809 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2S-08 ConocoPhillips Alaska, Inc. Kuparuk 2S Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.43 Doyon 141 Report For: ConditionBit # 2 9.8 9.875" 10.05 PDC 10.00 Size indication of high formation pore pressure. POOH from 7151' MD to 6584' MD. The max trip gas was 374 units. 2652' 100% Gas In Air=10,000 Units1846Connection 2266 Tools SLB Ecoscope API FL Chromatograph (ppm) 2665' 7151' WOB Surface 10.6611.14 Avg Min Comments RPM ECD (ppg) ml/30min 220Background (max) Trip Average 374 Mud Type Lst 10% Type LSND 3.57151'24 Depth in / out YP (lb/100ft2) 9.50 7531666 1776 CementChtSilt C-4i C-4n 24 hr. Max Weight 1209 Hours C-3 20% Ss (ppb Eq) C-1 C-5i AK-AM-0902894891 POOH PV 4486' Footage Dave Coates /Andy Lundale ShClyst TuffGvlCoal cP 12 Gas Summary 19 833 146 (current) Avg. to3655' Yesterday's Depth: Current Depth: 24 Hour Progress: 267.5 Flow In (gpm) Flow In (spm) 5470' 7150' 1680' Max @ ft. Current 6267'69.0 Date: Time: 1514 units. Max connection gas was 1846 units. Circulated 3 bottoms up to clean and condition hole. Performed fingerprint with no 402 No gains or losses from formation in last 24 hours in 5 5579'Minimum Depth C-5n 6832' 0.0 C-2 1514 SPP (psi) Gallons/stroke TFABit Type Depth 20.849 MBT 7151' pH 0.982 168 227 29 Siltst 791 187 Units* Casing Summary Lithology (%) 89 70% 18799 5498 (907)-670-4906Unit Phone: 156 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur \ Macy Williams Set AtSize 45.5 L-80 Grade 10.75" (max)(current) 3724 252 Cly 66776 Bottoms Up Time 620 -6158784121 33 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes WELL INFORMATION Created On : Nov 18 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2S-08 Job Number :AK-XX-0902894891 Rig Name :Doyon 141 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 27.50 0.00 0.00 27.50 0.00 N 0.00 E 0.00 0.00 71.00 0.52 33.48 71.00 0.16 N 0.11 E 0.16 1.20 162.00 0.66 30.28 161.99 0.96 N 0.60 E 0.96 0.16 254.00 0.74 14.86 253.99 1.99 N 1.02 E 1.99 0.22 345.00 2.02 325.41 344.96 3.88 N 0.26 E 3.88 1.80 438.00 4.26 322.93 437.82 7.99 N 2.75 W 7.99 2.41 485.04 4.78 322.64 484.71 10.94 N 4.99 W 10.94 1.11 578.31 5.65 324.07 577.59 17.75 N 10.05 W 17.75 0.94 670.23 8.20 323.54 668.83 26.68 N 16.60 W 26.68 2.77 764.53 8.68 325.12 762.11 37.93 N 24.66 W 37.93 0.57 856.01 9.57 324.53 852.43 49.79 N 33.02 W 49.79 0.98 950.06 10.01 323.99 945.12 62.77 N 42.37 W 62.77 0.48 1043.14 10.28 324.34 1,036.74 76.06 N 51.97 W 76.06 0.30 1135.08 11.86 325.26 1,126.97 90.49 N 62.13 W 90.49 1.73 1228.47 13.52 328.24 1,218.07 107.66 N 73.35 W 107.66 1.91 1323.98 15.95 331.65 1,310.44 128.70 N 85.46 W 128.70 2.70 1417.11 17.17 332.45 1,399.70 152.15 N 97.89 W 152.15 1.33 1511.55 17.61 325.67 1,489.83 176.31 N 112.40 W 176.31 2.19 1602.63 18.20 316.23 1,576.52 197.96 N 130.01 W 197.96 3.25 1695.32 18.09 305.09 1,664.63 216.70 N 151.81 W 216.70 3.74 1788.92 18.02 292.46 1,753.65 230.59 N 177.09 W 230.59 4.18 1884.31 19.14 280.43 1,844.11 239.06 N 206.11 W 239.06 4.18 1978.23 19.25 272.13 1,932.82 242.42 N 236.73 W 242.42 2.91 2070.63 20.17 262.48 2,019.83 240.90 N 267.76 W 240.90 3.66 2162.32 22.27 260.67 2,105.30 236.02 N 300.58 W 236.02 2.40 2259.27 22.94 262.76 2,194.80 230.66 N 337.45 W 230.66 1.08 2352.62 24.51 259.54 2,280.26 224.85 N 374.54 W 224.85 2.18 2447.67 26.48 258.12 2,366.05 216.90 N 414.67 W 216.90 2.17 2541.77 27.44 258.59 2,449.93 208.30 N 456.45 W 208.30 1.05 2594.28 27.79 258.91 2,496.45 203.55 N 480.33 W 203.55 0.72 INSITE V8.3.0 Page 1Job No:AK-XX-0902894891 Well Name:2S-08 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2695.86 30.56 259.66 2,585.14 194.36 N 528.98 W 194.36 2.75 2786.86 32.76 258.18 2,662.59 185.16 N 575.84 W 185.16 2.56 2879.96 30.48 257.80 2,741.87 175.01 N 623.58 W 175.01 2.46 2972.44 27.48 257.54 2,822.76 165.45 N 667.35 W 165.45 3.25 3065.25 28.31 258.80 2,904.78 156.55 N 709.85 W 156.55 1.10 3157.07 28.09 259.93 2,985.71 148.54 N 752.49 W 148.54 0.63 3250.49 28.00 263.93 3,068.16 142.38 N 795.96 W 142.38 2.02 3343.12 28.02 265.80 3,149.95 138.48 N 839.28 W 138.48 0.95 3435.53 28.05 263.93 3,231.51 134.60 N 882.53 W 134.60 0.95 3529.67 27.82 260.81 3,314.69 128.75 N 926.23 W 128.75 1.57 3622.09 28.30 261.07 3,396.25 121.90 N 969.16 W 121.90 0.54 3715.67 28.35 261.66 3,478.62 115.24 N 1,013.06 W 115.24 0.30 3808.04 27.71 258.29 3,560.16 107.70 N 1,055.79 W 107.70 1.85 3900.41 28.52 257.81 3,641.63 98.68 N 1,098.38 W 98.68 0.91 3997.15 28.48 257.95 3,726.65 88.99 N 1,143.51 W 88.99 0.08 4087.22 28.24 257.95 3,805.91 80.06 N 1,185.35 W 80.06 0.27 4181.15 28.43 257.90 3,888.58 70.73 N 1,228.94 W 70.73 0.20 4273.93 28.59 258.19 3,970.11 61.56 N 1,272.27 W 61.56 0.23 4366.15 28.94 257.35 4,050.95 52.16 N 1,315.64 W 52.16 0.58 4458.53 28.82 257.13 4,131.84 42.30 N 1,359.15 W 42.30 0.17 4551.12 28.17 256.81 4,213.22 32.34 N 1,402.19 W 32.34 0.72 4644.32 27.00 255.71 4,295.82 22.10 N 1,444.11 W 22.10 1.37 4736.62 25.98 256.07 4,378.43 12.06 N 1,484.04 W 12.06 1.12 4831.48 26.72 254.86 4,463.43 1.49 N 1,524.79 W 1.49 0.96 4923.51 27.31 254.67 4,545.42 9.49 S 1,565.12 W -9.49 0.65 5016.27 27.53 257.09 4,627.76 19.91 S 1,606.54 W -19.91 1.22 5110.04 28.83 259.55 4,710.42 28.85 S 1,649.90 W -28.85 1.86 5203.44 29.26 257.58 4,792.08 37.85 S 1,694.34 W -37.85 1.12 5297.20 29.76 251.77 4,873.69 50.06 S 1,738.83 W -50.06 3.10 5389.18 29.94 245.35 4,953.49 66.78 S 1,781.38 W -66.78 3.48 5483.65 30.59 241.10 5,035.09 88.23 S 1,823.86 W -88.23 2.37 5576.30 30.72 236.71 5,114.80 112.61 S 1,864.28 W -112.61 2.42 5668.49 32.29 232.28 5,193.41 140.61 S 1,903.45 W -140.61 3.03 5764.27 34.19 228.05 5,273.53 174.26 S 1,943.71 W -174.26 3.13 5858.48 35.89 224.36 5,350.67 211.70 S 1,982.71 W -211.70 2.88 5952.24 37.48 222.66 5,425.86 252.33 S 2,021.26 W -252.33 2.01 6043.73 38.96 222.19 5,497.73 294.12 S 2,059.44 W -294.12 1.65 6137.08 42.01 221.81 5,568.72 339.16 S 2,099.99 W -339.16 3.28 6229.66 44.75 218.94 5,636.01 387.61 S 2,141.14 W -387.61 3.65 6324.31 46.48 216.13 5,702.22 441.25 S 2,182.32 W -441.25 2.80 6418.56 47.68 211.67 5,766.42 498.52 S 2,220.77 W -498.52 3.69 6511.17 48.40 207.59 5,828.35 558.37 S 2,254.79 W -558.37 3.37 6604.34 50.54 204.01 5,888.91 622.12 S 2,285.57 W -622.12 3.71 6699.75 52.78 201.13 5,948.10 691.21 S 2,314.26 W -691.21 3.33 6791.69 55.34 200.44 6,002.06 760.80 S 2,340.67 W -760.80 2.85 INSITE V8.3.0 Page 2Job No:AK-XX-0902894891 Well Name:2S-08 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6886.29 57.58 200.90 6,054.32 834.57 S 2,368.50 W -834.57 2.40 6980.99 61.84 201.22 6,102.08 910.86 S 2,397.88 W -910.86 4.51 7076.67 66.16 200.97 6,144.01 991.07 S 2,428.82 W -991.07 4.52 7150.00 68.00 199.00 6,172.57 1,054.54 S 2,451.90 W -1054.54 3.52 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (Grid) - A total correction of 18.47 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 7,150.00 feet is 2,669.06 feet along 246.73 degrees (Grid) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.3.0 Page 3Job No:AK-XX-0902894891 Well Name:2S-08 Survey Report
