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215-079
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-07 KUPARUK RIV UNIT 2S-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2S-07 50-103-20713-00-00 215-079-0 G SPT 6216 2150790 1554 3579 3578 3579 3579 133 325 296 290 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-07 Inspection Date: Tubing OA Packer Depth 275 2010 1950 1945IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704083044 BBL Pumped:2 BBL Returned:1.9 Friday, July 22, 2022 Page 1 of 1 S Zr 5- 079 ConocoPhillips RECEIVED Alaska P.O.BOX 100360 ?017 ANCHORAGE,ALASKA 99510-0360 AOGCC September 24, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 t3 2 7 20 Anchorage, AK 99501 SCANNED 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, ifou have anyquestions. Y 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 —‘442S-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 l� I P.I.Supervisor I �(l� SUBJECT: Mechanical Integrity Tests 6 CONOCOPHILLIPS ALASKA INC 2S-07 FROM: Chuck Scheve KUPARUK RIV UNIT 2S-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J-" NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2S-07 API Well Number 50-103-20713-00-00 Inspector Name: Chuck Scheve Permit Number: 215-079-0 Inspection Date: 11/4/2016 Insp Num: mitCS161105073209 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 25-07 . Type Inj W'TVD6216 ' Tubing! 1791 1789 - 1792 1791 PTD 2150790 - Type Test SPT Test psi 1554 - IA 640 2600 - 2560 - 2550 Interval INITAL / P/F P ! OA 258 404 391 - 385 Notes: Well converted from producer to injector Sundry#316-448. SCAMS APR 2 4 20F Wednesday,November 09,2016 Page 1 of 1 f STATE OF ALASKA AL111,A OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: E Suspend Perforate p r Other Stimulate r Alter Casing r Change Approved Program 1— Plug Plug for Redrill r Perforate New Pool r Repair Well E Re-enter Susp Well r Other: PROD to WAG F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 215-079-0 _ 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50-103-20713-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025603; ADL025604; ADL025589 KRU 2S-07 • 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 14390 feet Plugs(measured) None true vertical 6280 feet Junk(measured) None Effective Depth measured 14380 feet Packer(measured) 504, 7749 true vertical 6280 feet (true vertical) 504,6216 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 106' 106' SURFACE 2934' 10 3/4 2961' 2638' INTERMEDIATE 7841' 7 5/8 7868' 6261' SLOTTED LINER 6660' 4 1/2 14380' 6280' RECEIVED Perforation depth: Measured depth: 8020-8273;9223-11244;11443-14339 NOV ® $ 2016 True Vertical Depth: 6280-6371 „A AO CC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7778 MD,6216 TVD Packers&SSSV(type,MD,and TVD) SSSV=CAMCO DS NIPPLE W/2.875"PROFILE @ 504 MD and 504 TVD PACKER=BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY©7749 MD and 6216 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): ��� � „ ti', 4`e ' ' 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 387 620 0 561 240 Subsequent to operation 0 0 6293 766 1944 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 Run r 16.Well Status after work: Oil r Gas E WDSPL r Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ r WAG F GINJ E SUSP r SPLUG r 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: 316-448 Contact Darrell Humphrey Email: n1139@conocophillips.com Printed Name Darrell Humphre Title: NSK Production Engineering Specialist Signature / Phone:659-7535 Date /,r . // Form 10-404 Revised 5/2015 - Submit Original Only y,�ez- VTL 312 ' 1 / 7 RBDMS L-(-- NOV 1 0 2016 • 2S-07 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/04/16 (ISW) : INITIAL STATE WITNESSED (CHUCK SCHEVE) MIT-IA(PASSED) TO 2600 PSI. 10/25/16 Convert to Produced Water Injection. Well brought online • - KUP SVC • 2S-07 r." At ConocoPhillips it Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) - atm l 501032071300 KUPARUK RIVER UNIT SVC 96.05 9,485.24 14,390.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2S-07,9/15/201553932 PM SSSV:NIPPLE Last WO: 27.30 8/21/2015 Vertical schematic(actual) - _ -- -Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 9/14/2015 Casing Strings HANGER,25.2 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ••••-- ----T ICONDUCTOR 16 15.250 26.0 106.0 106.0 62.50 H-40 Casing Description OD(in) 113(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 27.3 2,961.0 2,638.2 45.50 L-80 HYD 563 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread fit✓• ' 'i'• M•INTERMEDIATE 7 5/8 6.875 26.9 7,868.0 6,260.9 29.70 L80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SLOTTED LINER 41/2 3.958 7,719.9 14,380.0) 6,280.3 11.60 L-80 IBTM Liner Details Nominal ID Top(MB) Top(ND)(ftKB) Top Incl(') Item Des Corn (in) 7,719.9 6,205.3 67.97 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 �- 7,739.9 6,212.7 67.98 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 I 7,742.7 6,213.8 67.98 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.810 . A /�'uA. .AA/CONDUCTOR;26.0-106.0 "_s A,0L 7,752.5 6,217.5 67.97 XO-NOGO NO GO XO-5.5"Hydril 563 box X 5"Hydril 521 box 4.420 7,763.9 6,221.7 67.97 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;504.3 7,9922 6,306.6 69.89 SWELL FSC-124 WATER ACTIVATED TAM SWELL 3.958 PACKER PACKER Tubing Strings �� Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection V .ri TUBING-4.5"x 3.5" 3 1/2 2.992 25.2 7,778.2 6,227.1 9.30 L-80 EUE-M } @69.63' I Completion Details SURFACE:27.3-2,961.0 5' Top(ftKB) Top(TVD)ftKB Top IndItem Des Com Nominal ID 25.2 25.2 0.07 HANGER CAMERON TUBING HANGER 3.900 69.6 69.6 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;4,038.8 .II EUE-Mod pin 504.3 504.2 1.90 NIPPLE CAMCO DS NIPPLE W/2.875"PROFILE 2.875 -- 7,632.1 6,172.3 67.93 SLEEVE BAKER CMU SLIDING SLEEVE[CLOSED] 2.810 7,656.3 6,181.4 67.93 NIPPLE CAMCO D NIPPLE 2.750 7,673.4 6,187.8 67.94 PLUG HES MIRAGE PLUG 2.962 r- - 7,747.9 6,215.7 67.97 LOCATOR BAKER LOCATOR 2.990 7,749.0 6,216.2 67.97 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT,6,894.2 Perforations&Slots - Shot Dens --- Top(ND) Btm(TVD) (shots/f Top(ftKB) Bbn OMB) (ftKB) (ftKB) Zone Date t) Type Com SLEEVE;7,632.1 1 8,020.4 8,273.4 6,316.1 6,371.2 A-4,2S-07 8/18/2015 SLOTS Slotted Liner ll9,222.9 11,244.1 6,328.5 6,314.4 A-4,25-07 8/18/2015 SLOTS 'Slotted Liner _ 11,442.9 14,339.1 6,311.5 6,279.5 A-4,2S-07 8/18/2015 SLOTS Slotted Liner NIPPLE;7,656.3 _ Cement Squeezes Top(ND) Btm(ND) PLUG;7,673.4 Top(ftKB) Btrn(ftKB) (860) (ftKB) Des Start Date Com -- 2,700.0 3,023.0 2,433.1 2,687.4 Cement Squeeze 7/29/2015 RU cmt line-Spot cmt plug as follows:Pumped 5 _ bbls 12.5 ppg MudPush II-Tested lines to 900& 3800 psi(Good)-Pumped 13 bbls 12.5 ppg Mud Push II @ 5 bbls/min @ 275 psi-Dropped wiper ball- Batch mix&pumped 30 bbls 15.8 ppg Class G cmt @ 5 bbls/min @ 332 psi-Followed by 3 bbls/12.5 ppg Mud Push II-switch to rig pump&displaced w/ 23.5 bbls-9.6 ppg mud @ 6 bbls/min @ 275 psi to equailze-CIP @ 10:35 hrs. RU&Perform hesitation squeeze as follows:Closed annular-Pumped 1/2 bbls pressured up to 450 psi- Hold 15 mins.-Pumped 1/2 bbl-pressured up to 700psi-Shut in for l5 misn s.bleddownto575psi- Pumped(/2 bbl-presured up to 800 psi-shut in for LOCATOR;7.747.8 15 mins.bled down t550 psi-Pumped 4 bbls- ". pressured l0 700 psi shutinfor15mins.bleddownc. to520psi-Pumped bbls-pressured up to 875 psi- shut in for 15 mins.-bled down to 520 psi-Pupped 1/2 bbl-pressured up to 850 psi-shut in forl5 mins. -bled down to 700 psi-Pumped 1/2 bbl-pressured SEAL ASSY;7,749.0 up to 1000 psi-shut in for 15 mins.-bled down to 800 psi-Pumped 1/2 bbl pressured up to 1100 psi- shut in for 20 mins:bled down to 975 psi Squeezed total of 9 bbls away-Bled off pressure- CMOpened annular-RD squeeze equipment Mandrel Inserts St all on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com INTERMEDIATE;28.9-7,686.0 1 4,038.8 3,493.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 8/20/2015 2' 6,894.2 5,872.5 CAMCO MMG 1 1/2 GAS LIFT SOV RKP ' 0.438 3,000.0 8/20/2015 S02- 30R laNotes:General&Safety End Date Annotation - NOTE. SLOTS;8,020.4-8273.4 SLOTS;9,222.9-11,244.1 SLOTS;11,442.9-14,339.1 SLOTTED LINER;7,719.9- J I 14,380.0 ` • • Brooks, Phoebe L (DOA) 'T® k 215 07c'Q 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. SCpk�E® ,A.1,1\110 1 Vi i 7: 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: [EXTERNAL]RE: 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 t KUP SVC • 2S-07 ,444: ConocoPhillips "4 Well Attributesll l Max Angle&MD TD Alaska,Ins i Wellbore API/UWI Field Name Wellbore Status Inel(°) MD(ftKB) Act Blm(kKB) 0„.,,, ,,,,,7 „.,,, Mrs 501032071300 KUPARUK RIVER UNIT SVC 96.05 9.485.24 14,390.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-07,9/15/20155:39:32 PM SSSV:NIPPLE Last WO: 27.30 8/21/2015 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 9/14/2015 li as wp Casing Strings HANGER;252 ImmCasing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -- -- --- IIm. -- CONDUCTOR 16 15.250 26.0 106.0 106.0 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) 'Sat Depth(ftKB) -Set Depth(ND)...WVLen(I...Grade Top Thread SURFACE 10 3/4 9.950 27.3 2,961.0 2,638.2 45.50 L-80 HYD 563 t Casing Description OD In ID in To ftKB Set Depth ftKB Set Da th 4 ! A S :lint): ((lion)) P( 1 ( 1 P (ND)...WtlLen(I...Grade Top Thread "aQ, 0/,INTERMEDIATE 7 5/8 6.875 26.9 7,868.0 6,260.9 29.70 L80 Hyd 563 l. ;J' Casing Description OD(In) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(NO)...Wt/Len(I...Grade Top Thread I. SLOTTED LINER 41/2 3.958 7,719.9 14,380.0 6,280.3 11.60 L-80 IBTM Liner Details Top(ftKB) Top(TVD)(k(B) Top Incl(°1 Item Des Corn (in)inal ID 7,719.9 6,205.3 67.97 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 9 t Nom 7,739.9 6,212.7 67.98 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 7,742.7 6,213.8 67.98 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.810 -AAJCONDUCTOR;26.0-1060 7,752.5 6,217.5 67.97 XO-NOGO NO GO XO-5.5"Hydril 563 box X 5"Hydril 521 box 4.420 7,763.9 6,221.7 67.97 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE 504.3 -fi: 7,992.2 6,306.6 69.89 SWELL FSC-124 WATER ACTIVATED TAM SWELL 3.958 111 PACKER PACKER Tubing Strings a r40 T bine Description Stang Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection �� 4',4 TUBING-4.5"x3.5" 31/2 2.992 25.2 7,778.2 6,227.1 9.30 L-80 EUE-M F` @69.63' N� r Completion Details SURFACE,27.3-2,961.0 f Top(kKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com Nominal ID 25.2 25.2 0.07 HANGER CAMERON TUBING HANGER 3.900 69.6 69.6 0.20 XO Reducing XO,2',4-1/2"12.68 L-80 I8TM box x 3-1/2"9.3#L-80 3.000 GAS LIFT;4,038.8 EUE-Mod pin 11 504.3 504.2 1.90 NIPPLE CAMCO DS NIPPLE W/2.875"PROFILE 2.875 7,632.1 6,172.3 67.93 SLEEVE BAKER CMU SLIDING SLEEVE[CLOSED] 2.810 ` II 7,656.3 6,181.4 67.93 NIPPLE CAMCO D NIPPLE 2.750 7,673.4 6,187.8 67.94 PLUG HES MIRAGE PLUG 2.962 7,747.9 6,215.7 67.97 LOCATOR BAKER LOCATOR 2.990 ` 7,749.0 6,216.2 67 97 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;6,894.2 SI Perforations&Slots Shot ens Top(ND) elm(ND) (h otslt Top(ftKB) Bt.(ftKB) (kKB) (ftKB) Zone Date t) Type Com SLEEVE:7,632.I 8,020.4 8,273.4 6,316.1 6,371.2 A-4,2S-07 8/18/2015 SLOTS Slotted Liner a� 9,222.9 11,244.1 6,328.5 6,314.4 A-4,2S-07 8/18/2015 SLOTS Slotted Liner NIPPLE 7,656.3 11,442.9 14,339.1 6,311.5 6,279.5 A-4,2S-07 8118/2015 SLOTS Slotted Liner Cement Squeezes 11 Top(TVD) Btm(TVD) PLUG:7,673.4 Top(ftKB) Bim(ftKB) (kKB) (ftKB) Des Start Date Com 2,700.0 3,023.0 2,433.1 2,687.4 Cement Squeeze 7/29/2015 RU cmt line-Spot cmt plug as follows.Pumped 5 bbls 12.5 ppg MudPush II-Tested lines to 900& 3800 psi(Good)-Pumped 13 bbls 12.5 ppg Mud Push II @ 5 bbls/min @ 275 psi-Dropped wiper ball- Batch mix&pumped 30 bbls 15.8 ppg Class G cmt II �°r @ 5 bbls/min @ 332 psi-Followed by 3 bbls/12.5 ppg Mud Push II-switch to rig pump&displaced w/ 23.5 bbls-9.6 ppg mud @ 6 bbls/min @ 275 psi to equailze-CIP @ 10:35 hrs. RU&Perform hesitation squeeze as follows:Closed annular-Pumped 1/2 bbls pressured up to 450 psi- f. Hold 15 mins.-Pumped 1/2 bbl-pressured up to 700 psi-Shut in for 15 mins.bled down to 575 psi- Pumped 1/2 bbl-pressured up to 800 psi-shut in for LOCATOR;7.7478 I ®� 15 mins.bled down to 550 psi-Pumped 4 bbls- pressured to 700 psi-shut in for 15 mins.bled down to 520 psi-Pumped 2 bbls-pressured up to 875 psi- _ shut in for 15 mins.-bled down to 520 psi-Punped 1/2 bbl-pressured up to 850 psi-shut in for 15 mins. -bled down to 700 psi-Pumped 1/2 bbl•pressured SEAL ASSN.7 7451.0 up to 1000 psi-shut in for 15 mins.-bled down to fpr 800 psi-Pumped 1/2 bbl pressured up to 1100 psi- ' shut In for 20 mins:bled down to 975 psi Squeezed ntotal of 9 bbls away-Bled off pressure- i Openedsqueeze equipment Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run INTERMEDIATE;26.9-],888.0 N Top(ftKB) OMB) Make Model 00(in) Sery Type Type (In) (psi) Run Date Com 4,038.8 3,493.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/20/2015 2 6,894.2 5,872.5 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.438 3,000.0 8/20/2015 SO2- 30R WI Notes:General&Safety End Date Annotation NOTE: SLOTS:8,020.4-8.273 4 SLOTS;9,222.9-11.244.1 _ SLOTS;11.442.9-14,339.1 t SLOTTED LINER',7,719.9- , 1 14.380.0 • • • tiOF ?pi �w\��\���%s� THE STATE Alaska Oil and Gas f:,,o .�o, ofAT j\ J(j\S Conservation Commission - = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 °44' F Am7,. p. Main: 907.279,1433 LAS' Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensen NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. 0 : 7 P.O. Box 100360 SCO FEB . a L.,J I" Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-07 Permit to Drill Number: 215-079 Sundry Number: 316-448 Dear Mr. Christensen: 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, a/11 41°4e-d54-- Cathy . Foerster Chair DATED this Ay of September, 2016. RBDMS V" SEP 1 6 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUu 30 205 APPLICATION FOR SUNDRY APPROVALS o.T5 13//,c 20 AAC 25.280 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 R-ogram 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 p". 215-079-0 • 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360, Anchorage,Alaska 99510 50-103-20713-00, 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No j'/ KRU 2S-07 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025603;ADL025604;ADL025589 . 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): 14390 6280 14380' 6280' • 1377 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 106' 106' SURFACE 2934' 10 3/4 2961' 2638' INTERMEDIATE 7841' 7 5/8 7868' 6261' SLOTTED LINER 6660' 4 1/2 14380' 6280' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8020-8273;9223-11244;11443-14339 , 6280-6371 3 1/2 L-80 7778 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=CAMCO DS NIPPLE W/2.875"PROFILE . MD=504 TVD=504 PACKER=BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY . MD=7749 TVD=6216 12.Attachments: Proposal Summary !r WellBore Schematic p' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P+ 14.Estimated Date for 15. Well Status after proposed work: 10/07/16 OIL WINJ Suspended Commencing Operations: r r WDSPL r P r 16.Verbal Approval: Date: GAS r WAG 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 Robert D. hristensen Phone:659-7535 Email: n1139conocophillips.com Title: NSK Production Engineering Specialist Signature (--Li 1" ` Date: /Z /e) 6 6 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 1' Location Clearance r Other: RAF 9Ik;IIL Post Initial Injection MIT Req'd? Yes No r�/ Spacing Exception Required? Yes r No 1✓ Subsequent Form Required: ` d —4 a 4- RBDMS L L SEP 1 6 2016 APPROVED BY Approved by: / ra ( COMMISSIONER THE COMMISSION Date: e9_/4L , -ea T1 1 t' r ro giwil i�o I 1 NI A I pp Subs in Form and Duplicate Form 10-403 Revised 11/2015 Approved application is v M fop �pf approval. Attachments in Duplicate . • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPh i I lips Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 August 28, 2016 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 <<,w aha Anchorage, AK 99501 !n ed Pe" %trek �"Or ��0,10 04 Ph e. rs Ccmp�er.� / Dear Commissioner, No fe5vvtf re ew �gt�'��Qd ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 2S-07 from _ Production service to Water Alternating Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2S-07 (PTD# 215-0790). If you have any questions regarding this matter,please contact myself or Darrell Humphrey at 659-7535. Sincerely, - Robert D. Christensen Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • 2S-07 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kupaurk River Well 2S-07 (PTD# 215-0790) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk River well 2S-07 was completed as an injector on August 21st 2015 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing 'A' sand producers 2S-05 and 2S-09 which is expected to be completed mid October 2016. The top of the Kuparuk A4 sand was found at 8004' and/6311' tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that there are no additional production/injection wells located within a 1/4 mile radius of the 2S-07 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2S-07 is good and is classified as a "Dual Casing -Single"well. The injection tubing/casing annulus is isolated via a BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY located at 7749' and 6216' tvd). A State-witnessed MIT-IA will be performed once well 2S-07 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: Attached AOR detail The 16" Conductor was cemented with 242 sx ArcticSet I followed by 78 sx ArcticSet I. The 10-3/4" Surface casing was cemented with 1495 sx Class 'G' followed by 205 sx Class 'G'. The 7-5/8" Intermediate casing was cemented with 377 sx GasBLOK followed by 155 sx GasBLOK. KUP SVC 2S-07 ConocoPh1 ips Well Attributes Max Angle&MD TD Alaska,Inc Wellbore APl/DWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r,M.,r,ls '.'' 501032071300 KUPARUK RIVER UNIT SVC 96.05 9,485.24 14,390.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-07,9/15/2015 539:32 PM SSSV:NIPPLE Last WO: 27.30 8/21/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 9/14/2015 Casing Strings HANGER 25.2 ;1# Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread --•••••••-••••••••-•••••-•••••--•-•----- - ) - - -CONDUCTOR 16 15.250 26.0 106.0 106.0 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 27.3 2,961.0 2,638.2 45.50 L-80 HYD 563 l [. ;' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread r ''(� INTERMEDIATE 7 5/8 6.875 26.9 7,868.0 6,260.9 29.70 L80 Hyd 563 '`r Casing Description OD(in) ..ID (in) Top(MKS) Set Depth(ftKB) 'Set Depth(TVD[..Wt/Len(I...Grade Top Thread _....__...__.._...._ ....---- - SLOTTED LINER 41/2 3.958 7,719.9 14,380.0 6,280.3 1160 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 7,719.9 6,205.3 67.97 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 7,739.9 6,212.7 67.98 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 7,742.7 6,213.8 67.98 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.810 ,wA/COND5CTOR;26.0-106.0 �,(.,n�. 7,752.5 6,217.5 67.97 XO-NOGO NO GO XO-5.5"Hydra 563 box X 5"Hydril 521 box 4.420 81 7,763.9 6,221.7 67.97 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;504.3 j] 7,992.2 6,306.6 69.89 SWELL FSC-124 WATER ACTIVATED TAM SWELL 3.958 PACKER PACKER Tubing Strings __ �` Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(9...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection `Q` TUBING-4.5"x3.5" 31/2 2.992 25.2 7,778.2 6,227..4441 rho 1 9.30L 80 EUEM p. 569.63' Completion Details y; 9 Nominal ID SURFACE;27.3-2,961.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 25.2 25.2 0.07 HANGER -CAMERON TUBING HANGER 3.900 69.6 69.6 0.20 XO Reducing XO,7,4-1/2"12.68 L-80 IBTM box x 3-1/7'9.3#L-80 3.000 GAS LIFT;4.038.8 EUE-Mod pin 504.3 504.2 1.90 NIPPLE CAMCO DS NIPPLE W/2.875"PROFILE 2.875 7,632.1 6,172.3 67.93 SLEEVE BAKER CMU SLIDING SLEEVE[CLOSED] 2.810 7,656.3 6,181.4 67.93 NIPPLE CAMCO D NIPPLE 2.750 7,673.4 6,187.8 67.94 PLUG HES MIRAGE PLUG 2.962 7,747.9 6,215.7 67.97 LOCATOR BAKER LOCATOR 2.990 7,749.0 6,216.2 67.97 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;6,894.2 Perforations&Slots Shot Den -- Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SLEEVE;7,632.1 i 8,020.4 8,273.4 6,316.1 6,371.2 A-4,2S-07 8/18/2015 SLOTS Slotted Liner 9,222.9 11,244.1 6,328.5 6,314.4 A-4,2S-07 8/18/2015 SLOTS Slotted Liner 11,442.9 14,339.1 6,311.5 6,279.5 A-4,2S-07 8/18/2015 SLOTS Slotted Liner NIPPLE;7,656.3 Cement Squeezes yy.. Top(ND) Btm(TVD) PLUG;7,673.4 4 Top(kKB) Btm(ftKB) (ftKB) (580) Des Start Date Com 2,700.0 3,023.0 2,433.1 2,687.4 Cement Squeeze 7/29/2015 RU cmt line-Spot cmt plug as follows:Pumped 5 _ bbls 12.5 ppg MudPush II-Tested lines to 900& 3800 psi(Good)-Pumped 13 bbls 12.5 ppg Mud Push II 5 5 bbls/min©275 psi-Dropped wiper ball- Batch mix&pumped 30 bbls 15.8 ppg Class G cmt 5 5 bbls/min©332 psi-Followed by 3 bbls/12.5 ppg Mud Push II-switch to rig pump&displaced w/ 23.5 bbls-9.6 ppg mud @ 6 bbls/min 51 275 psi to 1 ` ! equalize-CIP 5 10:35 hrs. RU&Perform hesitation squeeze as follows:Closed annular-Pumped 1/2 bbls pressured up to 450 psi- Hold 15 mins.-Pumped 1/2 bbl-pressured up to 700 psi-Shut in for 15 mins.bled down to 575 psi- 11` Pumped 1/2 bbl-pressured up to 800 psi-shut in for LOCATOR;7747.8 �'•-- 15 mins.bled down to 550 psi-Pumped 4 bbls- pressured to 700 psi-shut in for 15 mins.bled down 11 ,ffto520psi-Pumped2bbls-pressuredupto875psi- ' shut in for 15 mins.-bled down to 520 psi-Pumped 1/2 bbl-pressured up to 850 psi-shut in forl5 mins. ma -bled down to 700 psi-Pumped 1/2 bbl-pressured SEAL ASSY;7,749.0 a up to 1000 psi-shut in for 15 mins.-bled down to ii i 800 psi-Pumped 1/2 bbl pressured up to 1100 psi- shut in for 20 mins.-bled down to 975 psi Squeezed total of 9 bbls away-Bled off pressure- Opened annular-RD squeeze equipment I i Mandrel Inserts St i on Top(TVD) Valve Latch Port Size TRO Run N_ Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com INTERMEDIATE;26.9-7,866.0 - 'j' 4,038.8 3,493.0 CAMCO 'MMG ' 1 1/2-GAS LIFT -DMY RK - 0.000- 0.0 8/20/2015 2 6,894.2 5,872.5 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.438 3,000.0 8/20/2015 SO2- 30R srNotes:General&Safety End Date Annotation - NOTE SLOTS;8,020.4-8,273.4 ) SLOTS;9.222.9-11,244.1 SLOTS;11,442.9-14,339.1 SLOTTED LINER,7,719.9- L 14.380.0 . • . L To III r g r Cl 3 „ E o o a ,0--5' E ill aE m 8 `o n m c E ~ o i 2 °- v N5 m —E 3 ut.a \ ,0 Lu m u c @1 v 0 n� E o r 06 2 o 0 V O V O F n p N Y O = o s LL `w em / w w e N r 3 4—A NO °IXw ., a N `o Z 6 4:( H u2 , m `o a \ on H O._ Q n G b 1- a O c S a O'l o i n 0 r G N o 2" a z 3 na 03Aug16 . • ConocoPhillips Alaska, Inc. 2S-07 N 10-403 Sundry 0 0.1 0.2 0.3 0.4 Miles ADL025590 ADL025589 2S-09 r i 2S-07 J r 2S-05 17 J T ONR8, 1. 5 2S � /� l r r r r / d , 41/4 ADL025604 ADL025603 —2S-07 Open Interval —2S-07 Trajectory ❑1/4 Mi. Radius -- Planned Well —Well Within Radius ,DL025608 ADL025607 0 Well Pad ,,) (5- OTq • ! x(230 4< add,Lgf S cblumberger Transmittal#: 28MAR16-SPO3 MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-07 Date Dispatched: 28-Mar-15 Job#: 14AKA0058 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A VISION*Service MicroScope Resistivity x x LAS Digital Data N/A Contents on CD N/A Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a�conocophillips.com AlaskaPTSPrintCenterslb.com Tom Osterkamp Attn:Stephanie Pacillo C 907-263-4795 I , 4/1 /// ' Received By: - A �� SCANNED MAY 0 2 2016 4 _ STATE OF ALASKA AKA OIL AND GAS CONSERVATION COARSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Rill Tubing r Operations shutdown !— Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool [" Repair .Well r Re-enter Susp Well [ Other:WAG to Prod (� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: r ConocoPhillips Alaska, Inc. Development r Exploratory r 215-079-0 3.Address: 6.API Number: Stratigraphic r Service 1 • P. O. Box 100360,Anchorage,Alaska 99510 50-103-20713-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25603,25604,25589 ' KRU 2S-07 • 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 14390 ' feet Plugs(measured) 7673 true vertical 6280 ' feet Junk(measured) None Effective Depth measured 14380 feet Packer(measured) 7632,7656, 7673, 7748, 7749 true vertical 6280 feet (true vertical) 6172,6181, 6188,6216,6216 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 106 106 0 0 SURFACE 2934 11.78 2961 2638 0 0 INTERMEDIATE 7841 7.625 7868 6261 0 0 SLOTTED LINER 6660 6.55 14380 6280 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 8020-8273,9223-11244,11443-14339 py True Vertical Depth: 6316-6371,6329-6314,6311-6279 RECEVE�1 NOV 102015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7748 MD, 6216 TVD AOGCC Packers&SSSV(type,MD,and ND) SLEEVE-BAKER CMU SLIDING SLEEVE[CLOSED]@ 7632 MD and 6172 TVD NIPPLE-CAMCO D NIPPLE @ 7656 MD and 6181 TVD PLUG-HES MIRAGE PLUG @ 7673 MD and 6188 TVD LOCATOR-BAKER LOCATOR @ 7748 MD and 6216 TVD SEAL ASSY-BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY @ 7749 MD and 6216 TVD 12.Stimulation or cement squeeze summary: t1 tf** Intervals treated(measured): Jai] 2 9 Treatment descriptions including volumes used and final pressure: 5C[���� 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 1056 1731 1 1068 318 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations [d Exploratory r Development F Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil (N Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 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: N/A Contact Darrell Humphrey/Bob Christensen Email n1139conocophillips.com Printed Name Darrell Humphr Title NSK Production Engineering Specialist Signature Phone:659-7535 Date / _ 62 , i 5 Form 10-404 Revised 5/2015 V7L 17/7/ !6— RBDMS VW 13 2015 Submit Original Only • • 2S-07 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/11/15 Open well to production/ produce greater than 30 days KUP SVC ID 2S-07 ConocoPhillips Oi well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status rid(°) MD(ftKB) Act Btm(ftKB) cv'«oayslps 501032071300 KUPARUK RIVER UNIT SVC 96.05 9,485.24 14,390.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) --Rig Release Date 2S-07,9/15/2015 539'.32 PM SSSV:NIPPLE Last WO: 27.30 8/21/2015 Vertical schema0c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ............................................................................................ Last Tag: Rev Reason:NEW WELL smsmith 9/14/2015 Casing Strings HANGER 252 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ...................__.......................................-r................ ....................CONDUCTOR 16 15.250 26.0 106.0 106.0 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 27.3 2,961.0 2,638.2 45.50 L-60 HYD 563 '; C;: 1 Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .111.1111.1111111111111111311•^^^^^^^�^•^^�•^ ,''',. la INTERMEDIATE 7 5/8 6.875 26.9 7,868.0 6,260.9 29.70 L80 Hyd 563 • M U. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...wt/Len(I...Grade Top Thread - SLOTTED LINER 41/2 3.958 7,719.9 14,380.0 6,280.3 11.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 7,719.9 6,205.3 67.97 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 7,739.9 6,212.7 67.98 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 --- 7,742.7 6,213.8 67.98 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.810 ,.A.AJCONDUCTOR,26.0-109.0 - 7,752.5 6,217.5 67.97 XO-NOGO NO GO XO-5.5"Hydril 563 box X 5"Hydril 521 box 4.420 7,763.9 6,221.7 67.97 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;504.3 I.- 7,992.2 6,306.6 69.89 SWELL FSC-124 WATER ACTIVATED TAM SWELL 3.958 's' PACKER PACKER Tubing Description St Tubing Strings Stung Ma...ID(in) Top(ftKB) Set Depth(ft. (TVD)I...Wt(Ib/it) Grade Top Connection Set Depth( TUBING-4.5"x3.5" I 31/2 2.992 25.2 7,778.2 6,227.1 9.30 L-80 EUE-M @69.63' I l 4.4t 1 Completion Details qNominal ID SURFACE;27.3-2,961.0 'v` •ei Top(ftKB) Top(TVO)(ftKB) Top Incl(°) Item Des Corn 501 25.2 25.2 0.07 HANGER CAMERON TUBING HANGER 3.900 69.6 69.6 0.20 XO Reducing XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.311 L-80 3.000 GAS LIFT;4,038.8 J EUE-Mod pin 504.3 504.2 1.90 NIPPLE CAMCO DS NIPPLE W/2.875"PROFILE 2.875 I7,632.1 6,172.3 67.93 SLEEVE BAKER CMU SLIDING SLEEVE[CLOSED] 2.810 7,656.3 6,181.4 67.93 NIPPLE CAMCO D NIPPLE 2.750 ' 7,673.4 6,187.8 67.94 PLUG HES MIRAGE PLUG 2.962 7,747.9 6,215.7 67.97 LOCATOR BAKER LOCATOR 2.990 7,749.0 6,216.2 67.97 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;6,894.2 1IF. Perforations&Slots it Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn SLEEVE;7,6321 8,020.4 8,273.4 6,316.1 6,371.2 A-4,2S-07 8/18/2015 SLOTS Slotted Liner I■ 9,222.9 11,244.1 6,328.5 6,314.4 A-4,2S-07 8/18/2015 SLOTS Slotted Liner 11,442.9 14,339.1 6,311.5 6,279.5 A-4,2S-07 8118/2015 SLOTS Slotted Liner NIPPLE;7,656.3 Cement Squeezes Top(TVD) Btm(TVD) PLUG;7,6734 IIMIB>� Top(ftKB) Btm(ftKB) (9K13) (ftKB) Des Start Date Com 2,700.0 3,023.0 2,433.1 2.687.4 Cement Squeeze 7/29/2015 RU cmt line-Spot cmt plug as follows:Pumped 5 bbls 12.5 ppg MudPush II-Tested lines to 900& 3800 psi(Good)-Pumped 13 bbls 12.5 ppg Mud Push II @ 5 bbls/min @ 275 psi-Dropped wiper ball- Batch mix&pumped 30 bbls 15.8 ppg Class G cmt @ 5 bbls/min @ 332 psi-Followed by 3 bbls/12.5 ppg Mud Push II-switch to rig pump&displaced w/ 23.5 bbls-9.6 ppg mud @ 6 bbls/min @ 275 psi to I. equailze-CIP @ 10:35 hrs. RU&Perform hesitation squeeze as follows:Closed annular-Pumped 1/2 bbls pressured up to 450 psi- Hold 15 mins.-Pumped 1/2 bbl-pressured up to 700 1- psi-Shut in for 15 mins.bled down to 575 psi- 11 Pumped 1/2 bbl-pressured up to 800 psi-shut in for 15 mins.bled down to 550 psi-Pumped 4 bbls- LOCATOR 7.7,Et pressured to 700 psi-shut in for 15 mins.bled down i to 520 psi-Pumped 2 bbls-pressured up to 875 psi- 'M shut in for 15 mins:bled down to 520 psi-Pumped 1/2 bbl-pressured up to 850 psi-shut in forl5 mins. 1 emir f r -bled down to 700 psi-Pumped 1/2 bbl-pressured 0 t SEAL ASSY;77494 a. uptosi-Ppsi-d1/inforremine.-pto 1100 o 800 psi-Pumped 1/2 bbl pressured up to 1100 psi- shut in for 20 mins-bled down to 975 psi Squeezed total of 9 bbls away-Bled off pressure- f.� Opened annular-RD squeeze equipment • i Mandrel Inserts St ati on Top(TVD) Valve Latch Port Stu TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn INTERMEDIATE;26.9-7,8680 w � 4,038.8 3,493.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 8/20/2015 2 6,894.2 5,872.5 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.438-3,000.0 8/20/2015 S02- 30R StNotes:General&Safety End Dale Annotation - NOTE. SLOTS;8,020.4-8,273.4 SLOTS;9,222.9-11,244.1 SLOTS;11,442.9-14,339.1 SLOTTED LINER;7,719.9- J 14,380.0 • • Kett ZS _0 '1 !T -lac o19c Regg, James B (DOA) From: Doyon 141 Company Man <n1334@conocophillips.com>>�� 1‘L�'I%S Sent: Monday, August 17, 2015 7:22 PM \ To: Jones,Jeffery B (DOA) Cc: DOA AOGCC Prudhoe Bay; Guo, Haibin Subject: RE: Notification of Annular BOP Closure on Doyon 141 Attachments: Doyon 8-17-15.pdf Here is the chart testing the components(annular preventer and choke valve 5) used when the well was shut in on v 8/16/15. Dave Coates/Bob Finkbiner Drilling Supervisors Doyon 141 Office: 907-670-4963 Rig Floor: 907-670-4976a) E Mail: n1334@conocophillips.com � � � From: Jones, Jeffery B (DOA) [mailto:jeff.jones©alaska.gov] Sent: Monday, August 17, 2015 10:02 AM To: Doyon 141 Company Man Cc: DOA AOGCC Prudhoe Bay; Guo, Haibin Subject: [EXTERNAL]Re: Notification of Annular BOP Closure on Doyon 141 Dave, I will not be able to witness these tests but please scan your test chart when you finish and send it to us at the group AOGCC email address. Thank you, Jeff Jones AOGCC Petroleum Inspector 907 659 2714- Office 907 744 4446 - Mobile Reply message From: "Doyon 141 Company Man" <n1334@conocophillips.com> To: "Jones, Jeffery B (DOA)" <jeff.jones@alaska.gov> Cc: "DOA AOGCC Prudhoe Bay" <doa.aogcc.prudhoe.bay@alaska.gov>, "Guo, Haibin" <Haibin.Guo@conocophillips.com> Subject: Notification of Annular BOP Closure on Doyon 141 Date: Mon, Aug 17, 2015 9:49 AM Guys, We are just starting to trip out of the hole now, we should have BHA laid down and be rigged up to test— 6pm today. We used our Annular preventer and CV#5 to determine that we did not have an influx and confirmed breathing. We are going to test the Annular and CV#5 once we get out of the hole. Would you guys like a 2 hour call out to witness the test? Please fill free to call if you have any questions. 1 • • • Thanks Dave Dave Coates/Bob Finkbiner Drilling Supervisors Doyon 141 Office: 907-670-4963 Rig Floor: 907-670-4976 E Mail: n1334@conocophillips.com From: Jones, Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent: Sunday, August 16, 2015 7:00 PM To: Guo, Haibin; Regg, James B (DOA); Loepp, Victoria T(DOA); Grimaldi, Louis R (DOA); Crisp, John H (DOA); Noble, Robert C (DOA); Hill, Johnnie W (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Scheve, Charles M (DOA) Cc: Doyon 141 Company Man; Herbert, Frederick 0; Alvord, Chip; Shultz, Steve (Orbis Engineering, Inc.); Bearden, 3 Daniel; NSK Fld Drlg Supv; Brunswick, Scott A; Voss, Jake; Callahan, Mike S Subject: [EXTERNAL]RE: Notification of Annular BOP Closure on Doyon 141 MR. Huo, Thank you for the well control notification. Please provide us an update on your well control operations Jeff B.Jones Petroleum Inspector Alaska Oil & Gas Conservation Commission N. Slope Ofc: 907-659-2714 Mobile: 907-448-1228 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 Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent: Sunday, August 16, 2015 3:14 PM To: Regg, James B (DOA); Loepp, Victoria T(DOA); Grimaldi, Louis R (DOA); Crisp, John H (DOA); Noble, Robert C (DOA); Hill, Johnnie W (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Scheve, Charles M (DOA); Jones, Jeffery B (DOA) Cc: Doyon 141 Company Man; Herbert, Frederick 0; Alvord, Chip; Shultz, Steve (Orbis Engineering, Inc.); Bearden, J Daniel; NSK Fld Drlg Supv; Brunswick, Scott A; Voss, Jake; Callahan, Mike S Subject: Notification of Annular BOP Closure on Doyon 141 This notification is to inform all parties that Doyon 141 closed the annular BOP at—12:10am on Sunday 08/16/2015 to circulate bottom up through chokes. Date,Time of BOPE Use: 08/16/2015 @ ^'1210 hrs Well/Location/PTD: 2S-07, Kuparuk Oil Pool, PTD#215-079 Rig Name: Doyon 141 2 • • • • Operator Contact: Haibin Guo 227-6048, Dan Bearden 602-7068, Co. Man 670-4963 Ops Summary: Observed hole slightly packed off while back reaming in 6-3/4" horizontal production hole. Lost about 90bbI 10.6ppg FloThru mud. Saw 711psi pressure on shut-in MPD chokes with pumps off. Decided to close the annular - BOP and switch to rig chokes to circulate BU to see if the pressure on chokes is from the breathing back pressure due to losses or the well is taking influx. BOPE Used: Annular BOP Reason for BOP Use: To circulate BU to determine if the well is breathing or taking influx. Actions to Be Taken: If determined the hole is breathing, continue back reaming into intermediate casing shoe, circulate casing clean. Displace casing to kill weight brine with trip margin(^'0.4ppg) and strip out of hole with MPD. If the hole is taking influx, strip back to bottom to circulate out the influx. Back ream into intermediate casing and displace the casing to kill weight brine with trip margin (-0.4ppg). Any questions let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.227.6048 3 \\\\\ xiklm 1: >:':'' :,„,,,,.:_,,,::, _:' ,;. ---j,:,,,.:; ::::::__________::::_______1 ja_low--....w..._-::LI-t,.-:::---1,_,.:-., :44144b4%,s1‘*''4%4L\‘‘‘4,N%Nix% x.\. ' -41 d,jtuvz,,i at°,i,6 ,, ;,‘‘„„ ,.- ;:, • -- ' ....„AWIO .4$4*‘ik\S ‘1 kZ‘‘‘\\\''I\NN\N\\X\, eleik z-S-0 7 \\*St' , E "'�atie, ® � ` (fir l� 745-0-no /%9;-1"°° r� 1A \liStIlt 11 �p0 wrr�=ice �`��� `eitt.44* \ ```� ' : 4400.10ftefitat #ASS itIVITSIV‘1%. 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V , r, - ,_.__ `. ted. .. .,...- 1 • • pT) 2 /5s-07- 9 Loepp, Victoria T (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Sunday,August 16, 2015 7:41 PM To: Jones, Jeffery B (DOA); Regg,James B (DOA); Loepp,Victoria T (DOA);Grimaldi, Louis R (DOA);Crisp,John H (DOA); Noble, Robert C (DOA); Hill,Johnnie W (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay; Scheve, Charles M (DOA) Cc: Doyon 141 Company Man; Herbert, Frederick 0;Alvord, Chip; Shultz, Steve (Orbis Engineering, Inc.); Bearden,J Daniel; NSK FId DrIg Supv; Brunswick, Scott A;Voss, Jake; Callahan, Mike S Subject: RE: Notification of Annular BOP Closure on Doyon 141 Follow Up Flag: Follow up Flag Status: Flagged OWED LIAR I 2016 Jeff, After circulating bottom up, no influx was seen. Performed exhale tests, indicated that the hole was breathing due to the losses of the pack off. We are back to the normal operation now. We'll pressure and function test annular BOP and choke manifold after the trip out as per Victoria mentioned in another email. Any questions let me know. Thanks, Haibin From: Jones, Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent: Sunday, August 16, 2015 7:00 PM To: Guo, Haibin; Regg, James B (DOA); Loepp, Victoria T(DOA); Grimaldi, Louis R (DOA); Crisp, John H (DOA); Noble, Robert C (DOA); Hill, Johnnie W (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay; Scheve, Charles M (DOA) Cc: Doyon 141 Company Man; Herbert, Frederick 0; Alvord, Chip; Shultz, Steve (Orbis Engineering, Inc.); Bearden, J Daniel; NSK FId DrIg Supv; Brunswick, Scott A; Voss, Jake; Callahan, Mike S Subject: [EXTERNAL]RE: Notification of Annular BOP Closure on Doyon 141 MR. Huo, Thank you for the well control notification. Please provide us an update on your well control operations Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N.Slope Ofc:907-659-2714 Mobile: 907-448-1228 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 1 • • 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 Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: Guo, Haibin [mailto:Haibin.Guo@aconocophillips.com] Sent: Sunday, August 16, 2015 3:14 PM To: Regg, James B (DOA); Loepp, Victoria T(DOA); Grimaldi, Louis R(DOA); Crisp, John H (DOA); Noble, Robert C (DOA); Hill, Johnnie W (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay; Scheve, Charles M (DOA); Jones, Jeffery B (DOA) Cc: Doyon 141 Company Man; Herbert, Frederick 0; Alvord, Chip; Shultz, Steve (Orbis Engineering, Inc.); Bearden, J Daniel; NSK Fid Drlg Supv; Brunswick, Scott A; Voss, Jake; Callahan, Mike S Subject: Notification of Annular BOP Closure on Doyon 141 This notification is to inform all parties that Doyon 141 closed the annular BOP at "12:10am on Sunday 08/16/2015 to circulate bottom up through chokes. Date,Time of BOPE Use: 08/16/2015 @ —1210 hrs Well/Location/PTD: 2S-07, Kuparuk Oil Pool, PTD#215-079 Rig Name: Doyon 141 Operator Contact: Haibin Guo 227-6048, Dan Bearden 602-7068, Co. Man 670-4963 Ops Summary: Observed hole slightly packed off while back reaming in 6-3/4" horizontal production hole. Lost about 90bbl 10.6ppg FloThru mud. Saw 711psi pressure on shut-in MPD chokes with pumps off. Decided to close the annular BOP and switch to rig chokes to circulate BU to see if the pressure on chokes is from the breathing back pressure due to losses or the well is taking influx. BOPE Used: Annular BOP Reason for BOP Use:To circulate BU to determine if the well is breathing or taking influx. Actions to Be Taken: If determined the hole is breathing, continue back reaming into intermediate casing shoe,circulate casing clean. Displace casing to kill weight brine with trip margin("'0.4ppg) and strip out of hole with MPD. If the hole is taking influx, strip back to bottom to circulate out the influx. Back ream into intermediate casing and displace the casing to kill weight brine with trip margin (^'0.4ppg). Any questions let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell:907.227.6048 2 pro Z/S - o79 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday,August 14, 2015 1:50 PM To: 'Klem,Adam' Subject: 2S-07 (PTD 215-079) Packer depth waiver Follow Up Flag: Follow up Flag Status: Completed Adam, A waiver is granted to allow theacker to beplaced"400'-460' MD above the top perforation(slotted liner) (20 AAC 25.412(b)) based on information provided in the waiver request. Please include this information with the approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska SCANNED MAR 1 b 2016 Oil&Gas Conservation Commission �^'- 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(&alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Klem, Adam [mailto:Adam.Klem©conocophillips.com] Sent: Friday, August 14, 2015 1:34 PM To: Loepp, Victoria T(DOA) Subject: RE: Liner top waiver 2S-07 (PTD 215-079) Here you go. From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@aialaska.gov] Sent: Friday, August 14, 2015 1:27 PM To: Klem, Adam Subject: [EXTERNAL]RE: Liner top waiver 2S-07 (PTD 215-079) Please send a proposed wellbore schematic. From: Klem, Adam [mailto:P lam.Klem©conocophillips.com] Sent: Tuesday, August 11, 2015 9:11 AM 1 • To: Loepp, Victoria T(DOA) • Subject: Liner top waiver 2S-07 (PTD 215-079) Victoria, Please find the RT TOC log (attached from 4500—7840 MD) indications the TOC is at around 4900 MD with high amplitude and clear casing arrival. Overall the cement quality looks good,the low amplitude and clear formation arrival on slowness projection are qualitatively indications of good cement. Also attached is a liner top waiver request, due to topsetting the reservoir. Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1410 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com 2 • • Request for waiver concerning the placement of the injection packer a minimum of 200' above the upper most perforation in the well. ConocoPhillips is drilling an injection well, 2S-07, in the Kuparuk field. This well has already been approved for drilling by AOGCC (PTD#: 215-079) as an injector with a seal assembly located in the liner hanger which will serve as our isolation packer. While drilling, we encountered some issues that lead to top setting the reservoir vs the original plan on landing in zone. Authorization was given for our plan to topset by the AOGCC on 8/2/2015. On 2S-07, the 7 5/8" intermediate casing is cemented fully from the casing shoe at 7,868'MD, all the way up to 4,900' MD, —650' MD above the top of the C-37, for a total a length of 2,968 feet of cement column. The sonic log shows continuous cement between the first and second stage (stage collar at 5,640' MD), with high quality cement from 28' above the shoe to 6,675' MD(-1,193') and multiple intervals of good quality above that to the TOC at 4,900' MD. Due to the setup of the sonic logging tool, we are unable to log the bottom 28' of the casing until after we TD the production hole and TOOH with the drilling BHA, logging on memory. A 14.5 ppg LOT was achieved after drilling out the intermediate shoe track, indicating high quality cement with no channels around the shoe. The 6 3/" production hole will be drilled to 14,390'MD/6,360'TVD and a 4 %2" slotted liner will be run with an open hole swell packer at the top of the Kuparuk reservoir. ConocoPhillips requires around 150 feet of lap length once the production liner is in place and with the added open hole to the top of the Kuparuk on 2S-07, the total for the well in this case is estimated at 412 feet from the seal assembly to the top of the Kuparuk. However that is just the estimate from the wellsite geologist, since we have not drilled into the Kuparuk at this moment. Our top perforation (it is slotted liner, not perforations)will be right at the top of the reservoir which would give an over-all length of 400'-460' between the upper most perforation to the seal assembly leaving us out of compliance with the AOGCC. Therefore, we would like to request a waiver on the AOGCC regulation requiring a minimum of 200 feet from the upper most perforation to the injection packer(seal assembly)on 2S-07. 2S-07 Grassroots Horizontal A-Sand Injector ConocoPhillips Wellbore Schematic (Topset) L. \ ) ("CAMERON Last Edited: 4-'/z"tree,top joint is 4-1/2" Guo-8/13/2015 m 12.6#IBTM `A l 6"Conductor to 108 13.5" Surface i E Hole 74 3-1/2"2.875"DS Landing Nipple Y 1 GJ Surface Casing L 10-3/4"45.5#L-80 HydriI563 9-7/8" Intermediate 2,961' MD/2,638'TVD Hole 0 L 3-1/2" 9.3#L-80 EUE 8RD- MOD Tubing 2nd Stage TOC 4,900' MD/ 4,255'TVD(650'MD above I c J C37) L III III Weatherford Stage Collar:55,640'MD/ C-37:5,549'MD/4,845'TVD 4,925'TVI')(1(ln'halow C-37 formation) Growler(Iceberg): 5,969'MD/4,979'TVDI 3aker 2.812"CN 'dl \\\\\\\ Sleeve 3-''/"2.75", 'ppl l Bermuda: 6,509'MD/5,637'TVD a , 7-5/a'Flex Lock Liner Plu• e: sa•,ea i,°41, Hanger/ZXP HRZ: 7,218'MD/6,017'TVD 1, ang f Kalubik:7,525'MD/6,132'TVD 1r Kuparuk A4: 8,004'MD/6,308'TVD Intermediate Casing – — III _`_ ' •4W'Orange 7-5/8"29.7#L-80 Hyd563 Casi _"� _ . 7868' MD/6,262'TVD 68°) S R MO iii ITD:14,390'MD/6,360' 1 / TVD 6.38"x 4-''I"Swell Packer 6-3/4" Production Hole NOTE: Swell Packer will be adjusted as necessary using microscope and periscope data • • o •p• 0 O - N O N , 'p l� )• N @ • N vI O ›- \ , o c O -p V p p co U M NI p NI @ NIONI NI ao I '_ • r a N co O Cl. w n D im aN aM a. —'I OOJ n 0 Oo Oo O ) OO u a0O us > ~ ~ I O ai @ aui iii< iii ua) I in 7I 1 1 O o Z EEE I E< E (-- . > O r t.... a @ J @ J @ 2 @ J @ O 7 I 1 O O O Er. co c1cIcacIcu0nuuu2du) %) vc1 % c1 Q @ NaN — I -2 — N N - N- N- N'- N'- J Q it. a CC a 10 Ip Ip 1-1 Niw Ni Ni INI IN 1 o M - I 0- I i- > - aI i_ m Q < 1 •_ I Q@ _ t) • -: @ _ @ 02 g N0@a5 ag ag a2 an a a a° a J � oN cC cc tiZ uU1 U aoa02 U� 0 0 0Z 02 pO c @ @ m p @ a, @ Q aEuanuauOaau )aa (a ✓ E c m c m a m a m u ( J a u) I up Z Ed 0o pp O ppOZ O Z O E L 1 LL p w p IL Zi Lt-2 IL a L ZIa Z .-0 °0 U p O p p ° o °0 .°I: v .Ci 0 '0@ a. o, o o 5 o 5 ou) ou) o z o. o 5 o 5 ou) o 8 2 2 ON o' I— N p V -,W W > > U N W Ill > 0 > v> Q J a) I p 1 p 1 p I p I p rn a) I a) 1 a) I a) 0 ID a) a) 1 a) 1 Ce Q a) @o o a) E Do Do Do Do Do [LW Do Do Do w(n w w Do Do co a a c a us us us in LO LO LO LO LO LO LO LO LO CL Y > 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J CO N N N N N N N N N N N N N N w 2 u O O O O O O O O O O O O O O p @ Warn a a a a a a rn rn a) a a a rn 0 O. 0. w °• Z U OV Z0 0 Q r O N N- O M M 6) 0 (6 N M W (Ne7- J Q (0 \ 1 CL in 0 Z (� o s - o) co a a • Q • N u) N N N p a) C14..1 o n V E U @c o Q � Z N. 0 cd 9 LInL U) m F... 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N p it 0 d ' w° m :-..c m CL J p p W a o, O co ii E V Z N W O < coo c a £ C.) U Q Q ro . o co co O N 0 J n c J d = v E 0 2 0 0 CL in F, o o rD n U ti U Ej N c w do J } E Q n >-c oto @ 1' Va. m 1— N o Z N m 0 c N O al o EE CO CL co o E Y O To' Cr) rc m U a) 0. p c o Qmc � c c111 - Q c a ° co O Z Eli Giii0 o 2 o co Z 3 Z0 000 N 0 N 00 O p G o A In Z n NCO a) aa) o O 4.) a) - W a, :3 p v Q o o Q o 03 « iii a) c40 cco • U :.44aco o a o. c 0 E o. c_ 0 a`) 0 o ° a°� O o m d cp In o o d 0. Z 0 a C7 I C.) 0 G !,1 0 0 Guhl, Meredith D (DOA) From: Allsup-Drake, Sharon K <Sharon.K.Allsup-Drake@conocophillips.com> Sent: Friday, October 02, 2015 10:59 AM To: Guhl, Meredith D (DOA) Cc: Guo, Haibin; Noel, Brian; Bottrell, Phil M Subject: request for geologic markers for KRU2S-07 PTD#215-079 Meredith — Below is a list of the geologic markers you requested for KRU 2S-07 (PTD#215-079). Let us know if you want a revised completion report. Formation MD TVD Lower Kalubik 7739 6212 Upper Kalubik 7525 6132 West Sak Sand 2813 2521 C-37 5549 4844 C-80 3310 2910 HRZ 7218 6016 A4 8004 6311 Thank you, Sharon Allsup-Drake 263-4612 1 I /lb 4111 21 5079 26284 bEt= 2 9 101` Schlurn ergerAQG Transmittal#: 29SEP15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD LogProduct Delivery `IiL`V2oiS (N. K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-07 Date Dispatched: 29-Sep-15 Job#: 14AKA0058 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A VISION*Service SonicScope Top of Cement x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso c(�conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn: Stephanie Pacillo 907-265-6189 ATO 1707 p7A/2.a.47.6k..4) Received By: 6....eoteeet • • Guhl, Meredith D (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Thursday, September 24, 2015 8:58 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2S-07, PTD 215-079, 10-407 isuses Meredith, NEU/DEN log is obtained only on intermediate and production section.The surface section has GR/RES only. Here is the complete logging list: • Surface: GR/RES • Intermediate:GR/RES/NEU/DEN/Sonic(TOC) • Production: : GR/RES/NEU/DEN If you are also missing other logs, let me know. I'll have someone send to you as soon as we can. Thanks, Haibin From: Guhl, Meredith D (DOA) [mailto:meredith.guhl©alaska.gov] Sent: Thursday, September 24, 2015 8:39 AM To: Guo, Haibin Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]RE: KRU 2S-07, PTD 215-079, 10-407 isuses Haibin, I asked which logs had been collected because only GR/Res is noted on the form. If more logs were obtained, please provide the complete list of logs. Thank you, Meredith From: Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent: Thursday, September 24, 2015 8:37 AM To: kevin.bosworth@halliburton.com; Ifeanyi Ifesie (IIfesie@slb.com); Bottrell, Phil M Cc: Bettis, Patricia K(DOA); Guhl, Meredith D (DOA); Allsup-Drake, Sharon K Subject: RE: KRU 2S-07, PTD 215-079, 10-407 isuses All, I just got an email form AOGCC Meredith that some of the logging data on 2S-07 has not been received yet. 1. Kevin, please send an electronic and a hard copy of the mud logging to Meredith. 2. Ify, please send an electronic and a hard copy of the NEU/DEN log to Meredith. 1 3. Phil, please email a complete list of all geologic formation and markers to Meredith. Any question let me know. Thanks, Haibin From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, September 24, 2015 8:17 AM To: Guo, Haibin Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 2S-07, PTD 215-079, 10-407 isuses Haibin, During a review of the 10-407 form submitted for KRU 2S-07, PTD 215-079,completed 8/21/2015, it was noted that two of the boxes on the form were not filled out correctly. Box 22: Logs Obtained only lists GR/Res,when the original permit to drill application stated that a mudlog and neutron/density logs would also be obtained. Which logs were obtained in this wellbore? Box 29: Geologic Markers and Formations: Only the Upper Kalubik, Lower Kalubik, and Kuparuk A4 are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the logs obtained and the complete list of formations and markers by October 19, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 �� 1621 5 Q 7 9 RECEIVE li SEP 1 s eui.�; ConocoPhiOi 26251 AOGCC TRANSMITTAL FROM: Sandra a Lemke,ATQ3-0346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.Q. Box 100360 333 W.7th Ave,Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 2S-07 DATA LOGGED DATE:09/16/2015 9 /2tt2015 r:r.K. BENDER Transmitted: #I iKuparuk River Unit, Alaska [2S-07 111 CD&hardcopy I Halliburton-Surface data logging and End of Well report- mud logging data for 2S-07; 08/10/2015; general information, daily summary, days vs. depth, after action review, mud record,bit record. morning reports.survey reports; II Digital data; Final Log Files, Final End of well report, Final las export, Halliburton Log Viewer, EMF log viewer color log presentations, 1 color log image and 1 print each: IlFormation Evaluation 2"MD Gas ratio 2"MD r, Drilling Engineering 2"MD Please promptly sign, scan and return electronically to Sandra.D.LemkeCc)Conocophr/lips com CC: 2S-07 transmittal folder,production well files, eSearch � L Receit: 6-eite6tate: ., , - GIS-Technical Data Management 1 ConocoPhillips I Anchorage,Alaska I Ph: X07.265.6947 RECEIVE • STATE OF ALASKA • SEP 1 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND6aaCC la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended L 1b.Well Class: 20AAC25.105 20AAC25.11U Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: Service ❑I Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: •8/21/2015 215-079 3.Address: 7. Date Spudded: 15.API Number: P.0. Box 100360,Anchorage,AK 99501 •7/22/2015 50-103-20713-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2230'FSL, 1437'FEL, Sec. 17,T1ON, R8E, UM •8/15/2015 KRU 2S-07 Top of Productive Interval: 9. KB(ft above MSL): ..147.5' 17. Field/Pool(s): 1129'FSL,456'FWL, Sec. 16,T1ON, R8E, UM GL(ft above MSL): .120' Kuparuk River Field/Kuparuk River Oil Poo Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1935'FSL,2186'FWL, Sec.9,T1ON, R8E, UM 14380'MD/6280'TVD ADL 25603,25604,25589 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 481133 y- 5929999 Zone- 4 •14390'MD/6280'TVD 2677,2678,2675 TPI: x- 483027 y- 5928893 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 484753 y- 5934974 Zone- 4 nipple @ 504'MD/504'TVD 1387'MD/1370'TVD 5. Directional or Inclination Survey: Yes • ❑(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 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 I wt,�,�L o., �1U CT 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.58# B 29' 106' 29' 106' 42" pre-installed 10.75" 45.5# L-80 28' 2961' 28' 2638' 13.5" 1495 sx Class G,205 sx Class G 7.625" 29.7# L-80 27' 7868' 27' 6261' 9.875" 377 sx GasBLOK, 155 sx GasBLOK 4.5" 11.6# L-80 7120' 14380' 5978' 6280' 6.75" slotted liner 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 7778' 7720'MD/6205'TVD slotted liner from 8020'-8273'MD/6316'-6371'TVD and 9223'-11244'MD/ 6329'-6314'TVD and 11443'-14339'MD/6311'-6279'TVD __ 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. L MPLETIQM , Was hydraulic fracturing used during completion? Yes❑ No ❑✓ Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED -441t4*i squeeze 2700'-3023' 145 sx Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 Revised 5/2015 ( 'TL 61/Z_ i C�rONTIN ON PAGE 2 RBDMCv+ �?SEP 16 2015Subtn 013IGIM L onlyr- 28.CORE DATA Conventional Core Yes ❑ No ❑ Sidewall Cores: 5 ❑ 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. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1387' 1370' Attach separate pages to this form, if needed,and submit detailed test information, including reports, per 20 AAC 25.071. Upper Kalubik 7525' 6132' Lower Kalubik 7739' 6212' NONE Kuparuk A4 8004' 6311' Formation at total depth: Kuparuk A4 31. List of Attachments: Summary of Daily Operations,schematic,directional survey,cement reports 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 @ 265-1487 d-} Email: Haibin.Guocop.com Printed Name: Graham L.Alvord Title: Alaska Drilling Manager Signature:, , '\ Phone: 265-6120 Date: 1114 1201S INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level 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 5/2015 Submit ORIGINAL Only • • Guhl, Meredith D (DOA) From: Allsup-Drake, Sharon K <Sharon.K.Allsup-Drake@conocophillips.com> Sent: Friday, October 02, 2015 10:59 AM To: Guhl, Meredith D (DOA) Cc: Guo, Haibin; Noel, Brian; Bottrell, Phil M Subject: request for geologic markers for KRU2S-07 PTD#215-079 Meredith — Below is a list of the geologic markers you requested for KRU 2S-07 (PTD#215-079). Let us know if you want a revised completion report. Formation MD TVD Lower Kalubik 7739 6212 Upper Kalubik 7525 6132 West Sak Sand 2813 2521 C-37 5549 4844 C-80 3310 2910 HRZ 7218 6016 A4 8004 6311 Thank you, Sharon Allsup-Drake 263-4612 1 KUP SVC 2S-07 ConocoPhillipsWell Attributes •Max Angle&MD TD Ataska,Inc Wellbore API/UWI Fold Name Wellbore Status not r) MD(ftKB) Act!Mtn(ftKB) ,- ,,,,,,,e" 501032071300 KUPARUK RIVER UNIT SVC 96.05 9,485.24 14,390.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2S-07,9/15/20155.39.32 PM SSSV:NIPPLE Last WO: 27.30 8/21/2015 >.Vertcel schematic(actua I Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 9/14/2015 II Casing Strings HANGER;25.2 LI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,.-.- .--- ----.---••--•• - --- --- iii. CONDUCTOR 16 15.250 26.0 106.0 106.0 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 27.3 2,961.0 2,638.2 45.50 L-80 HYD 563 k1 j', Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread •-- .� uu,INTERMEDIATE 7 5/8 6.875 26.9 7,868.0 6,260.9 29.70 L80 Hyd 563 !' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SLOTTED LINER.],i. 41/2 3.958 7,719.9 14,380.01 6,280.31 11.60 L-80 IBTM Liner Details Nominal lD Top(ftKB) Top(TVD)(ftKB) Top Incl I") Item Des Com (in) 7,719.9 6,205.3 67.97 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 7,739.9 6,2)2.7 67.98 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 7,742.7 6,213.8 67.98 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.810 M./CONDUCTOR;26.0-106.0 - - 7,752.5 6,217.5 67.97 XO-NOGO NO GO XO-5.5"Hydril 563 box X 5"Hydril 521 box 4.420 7,763.9 6,221.7 67.97 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;504.3TI.: 7,992.2 6,306.6 69.89 SWELL FSC-124 WATER ACTIVATED TAM SWELL 3.958 PACKER PACKER Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) ret Depth(ft..f Set Depth(TVD)(...Wt(ib/ft) Grade Top Connection C TUBING-4.5"x 3.6" 3 1/2 2.992 25 2 7,778.2 6,227.1 9.30 L-80 EUE-M h @69.63' Completion Details Nominal ID SURFACE;27.3-2,961.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 25.2 25.2 0.07 HANGER CAMERON TUBING HANGER 3.900 It 69.6 69.6 0.20 XO Reducing XO,2',4-1/2"12.61t L-80 IBTM box x 3-1/2"9.39 L-80 3.000 GAS LIFT;4,038.8 EUE-Mod pin ft 504.3 504.2 1.90 NIPPLE CAMCO DS NIPPLE W/2.875"PROFILE 2.875 7,632.1 6,172.3 67.93 SLEEVE BAKER CMU SLIDING SLEEVE[CLOSED] 2.810 • 7,656.3 6,181.4 67.93 NIPPLE CAMCO D NIPPLE 2.750 7,673.4 6,187.8 67.94 PLUG HES MIRAGE PLUG 2.962 7,747.9 6,215.7 67.97 LOCATOR BAKER LOCATOR 2.990 7,749.0 6.216.2 67.97 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3 000 GAS LIFT;6,894.2 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SLEEVE;7,632.1 8,020.4 8,273.4 6,316.1 6,371.2 A-4,2S-07 8/18/2015 SLOTS Slotted Liner I ' 9,222.9 11,244.1 6,328.5 6,314.4 A-4,2S-07 8/18/2015 SLOTS Slotted Liner 11,442.9 14,339.1 6,311.5 6,279.5 A-4,2S-07 8/18/2015 SLOTS Slotted Liner NIPPLE;7,656.3 Cement Squeezes Top(IVO) Btm(TOD) PLUG;7,673.4 ) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) I Des Start Date Com 2,700.0 3,023.0 2,433.1 2,687.4 Cement Squeeze 7/29/2015 RU cmt line-Spot cmt plug as follows:Pumped 5 bbls 12.5 ppg MudPush II-Tested lines to 900& I 3800 psi(Good)-Pumped 13 bbls 12.5 ppg Mud Push II @ 5 bbls/min @ 275 psi-Dropped wiper ball- Batch mix&pumped 30 bbls 15.8 ppg Class G cmt @ 5 bbls/min @ 332 psi-Followed by 3 bbls/12.5 ppg Mud Push II-switch to rig pump&displaced w/ 23.5 bbls-9.6 ppg mud @ 6 bbls/min @ 275 psi to equailze-CIP @ hrs. RU&a Perform hesitation10:35 squeeze as follows:Closed annular-Pumped 1/2 bbls pressured up to 450 psi- 1A "' Hold 15 mins.-Pumped 1/2 bbl-pressured up to 700 ," psi-Shut in for 15 mins.bled down to 575 psi- Pumped 1/2 bbl-pressured up to 800 psi-shut in for LOCATOR'7,7476 15 mins.bled down to 550 psi-Pumped 4 bbls- !{' • il pressured to 700 psi-shut in for 15 mins.bled down ! al 1. to 520 psi-Pumped 2 bbls-pressured up to 875 psi- shut in for 15 mins:bled down to 520 psi-Pumped 1/2 bbl-pressured up to 850 psi-shut in for 15 mins. -bled down to 700 psi-Pumped 1/2 bbl-pressured SEAL ASSY;7,749.0 J up to 1000 psi-shut infor 15 mins.-bled down to I 800 psi-Pumped 1/2 bbl pressured up to 1100 psi- i shut in for 20 mins.-bled down to 975 psi Squeezed total of 9 bbls away-Bled off pressure- iii � Opened annular-RD squeeze equipment 11 It Mandrel Inserts St ori Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sore Type Type (in) (psi) Run Date Com INTERMEDIATE,zs s-7 esa o 1 4,038.8 3,493.0 CAMCO MMG I 1/2 GAS LIFT DMY RK 0.000 0.0 8/20/2015 2 6,894.2 5,872.5 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.438 3,000.0 8/20/2015 SO2- 30R Notes:General&Safety ---,----,-E,5-7.- End Date Annotation NOTE SLOTS;8,020.4-8,273.4 SLOTS;9,222.9-11,244.1 SLOTS;11,442.9-14,339.1 SLOTTED LINER;7,719.9- J 14,380.0 • ! CanocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2S-07 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 7/21/2015 4:00:00 PM Rig Release: 8/21/2015 9:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/20/2015 24 hr Summary Released from 2S-02 @ 06:00 hrs 7-20-15. Cut drilling line.Wait on trucks. Blow down steam and water lines. Disconnect interconnects and electrical lines. Split apart and stage on pad rig modules. 06:00 08:00 2.00 0 0 MIRU MOVE SLPC P Slip and cut 59'drilling line 08:00 12:00 4.00 0 0 MIRU MOVE WAIT T Wait on trucks. Prep rig for move. Change shaker screens in pits and rock washer. Perform MP2's 12:00 16:00 4.00 0 0 MIRU MOVE WAIT T Wait on trucks. Prep pipe shed, rock washer, pits and cold start for move. 16:00 19:00 3.00 0 0 MIRU MOVE RURD P Blow down steam and water lines. Disconnect interconnects and electrical lines 19:00 21:45 2.75 0 MIRU MOVE MOB P Split apart rock washer, boiler, motor, pump and pit complexes and spot on pad. 21:45 00:00 2.25 0 0 MIRU MOVE MOB P Level location. Sim-ops/Move pipe shed section from 2M pad to 2S pad. 07/21/2015 Finish moving from 2S-02 to 2S-07. Rig up all interconnects&spill containment. Rig accepted @ 16:00 hrs. Nipple up diverter system. Load 5" DP in pipe shed. 00:00 00:30 0.50 0 0 MIRU MOVE MOB P PJSM, continue to level location, lay Herculite, prep pipe shed module for move from 2M to 2S. 00:30 02:45 2.25 0 0 MIRU MOVE MOB P PJSM, move pipe shed module from 2M to 2S. SIMOPS nipple up diverter system. 02:45 03:00 0.25 0 0 MIRU MOVE MOB P PJSM, pull sub base off of 2S-02& stage on pad. 03:00 03:45 0.75 0 0 MIRU MOVE MOB P PJSM, prep pad&lay mats for sub base. 03:45 05:30 1.75 0 0 MIRU MOVE NUND P PJSM, nipple up knife valve&one stick of diverter line. 05:30 07:30 2.00 0 0 MIRU MOVE MOB P PJSM, spot sub base over 2S-07. 07:30 08:30 1.00 0 0 MIRU MOVE MOB P Prep pad&lay mats for remaining rig modules. 08:30 12:30 4.00 0 0 MIRU MOVE MOB P PJSM;spot remaining rig modules. 12:30 16:00 3.50 0 0 MIRU MOVE RURD P PJSM,work on rig acceptance checklist. hook up all lines& berming. Rig accepted at 16:00 hrs. 16:00 19:30 3.50 0 0 MIRU MOVE NUND P PJSM, nipple up diverter w/crane& chain down diverter line. Page 1 of 39 111 Time Logs I Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:30 00:00 4.50 0 0 MIRU MOVE NUND P PJSM, nipple up diverter system, diverter adapter seals tested to 500 psi for 10 min. Diverter length from well center 104.9', from ignition source 87.5'. SIMOPS load pipe shed w/91 jts of 5"DP&20 jts of 5"HWDP. 37/22/2015 Finish strap&tally 5"DP. Pick up DP&HWDP, racking back in derrick.Test surface diverter system. Pick up drilling assembly&spud well. Drill ahead from 89'-845'MD, 844'TVD. Total footage 756'. 00:00 02:15 2.25 0 0 MIRU MOVE RURD P PJSM; strap/tally 91 joints of 5"DP &20 joints of 5"HWDP. Rig up to pick up DP. 02:15 06:15 4.00 0 0 MIRU MOVE PULD P PJSM; pick up/rack back 30 stands of 5"DP&7 stands of HWDP. 06:15 06:45 0.50 0 0 MIRU MOVE RURD P PJSM; rig down mouse hole& mobilize tools from beaver slide. 06:45 07:30 0.75 0 0 MIRU MOVE BOPE P PJSM; perform diverter test as follows. Knife valve opened in 4 sec. Annular closed in 28 sec. Initial system pressure 3000 psi; pressure after closure 1800 psi;200 psi attained in 42 sec; full pressure attained in 168 sec; 5 bottles averaged 2000 psi;gas&pit volume alarms tested good.Test waived by _ AOGCC Rep. John Crisp. 07:30 07:45 0.25 0 0 MIRU MOVE SFTY P Pre-spud meeting with rig team. Table Top Diverter Drill 07:45 09:45 2.00 0 89 MIRU MOVE BHAH P PJSM; make up BHA 1 as per SLB Rep. 0'-89' MD. 09:45 10:15 0.50 89 89 MIRU MOVE SEQP P PJSM; flood lines&conductor. Test high pressure lines to 3500 for 10 minutes, good. 10:15 12:00 1.75 89 178 SURFA( DRILL DDRL P PJSM; DDrlg f/89'-178' MD, 178' TVD,ART 1.28,AST 0,ADT 1.28, BIT 1.28, Jars 100.15, PU 45K, SO 47K, ROT 45K, Tq on 1K, off 1K, FO 75%,WOB 5-10K,40 rpm, 500 gpm, 450 psi, Max gas 0, total footage 72'. 12:00 12:45 0.75 178 178 SURFA( DRILL TRIP P PJSM; rack back 1 stand of HWDP &TIH w/NMFC. 12:45 13:00 0.25 178 178 SURFA( DRILL SRVY P Survey on bottom as per SLB. 13:00 18:00 5.00 178 455 SURFA( DRILL DDRL P PJSM; DDrIg f/178'-455' MD,454' TVD,ART 3.06,AST.4,ADT 3.54, BIT 4.87, Jars 103.74, PU 63K, SO 65K, ROT 65K,Tq on 2K, off 1K, ECD 10.39, FO 57%,WOB 8-19K, 60 rpm, 550 gpm, 725 psi, Max gas 2,total footage 277'. 18:00 00:00 6.00 455 845 SURFA( DRILL DDRL P PJSM; DDrlg f/455'-845' MD, 844' TVD,ART 1.76,AST 2.17,ADT 3.93, BIT 8.8, Jars 112.54, PU 76K, SO 76K, ROT 76K,Tq on 2K, off 1K, ECD 10.18, FO 83%,WOB 10-30K, 60 rpm, 650 gpm, 1250 psi, Max gas 5,total footage 390'. Page 2 of 39 IIITime Logs I Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 37/23/2015 24 hr Summary Directional drilled surface section as per plan from 845-2745' MD, 2453'TVD. Total footage for 24hrs 1880' MD. 00:00 06:00 6.00 845 1,384 SURFA( DRILL DDRL P PJSM; DDrIg f/845'-1384' MD, 1369' TVD,ART 1.41,AST 2.90,ADT 4.31, BIT 13.11, Jars 116.85, PU 86K, SO 85K, ROT 87K, Tq on 3-5K, off 1K, ECD 10.19, FO 76%,WOB 15-20K, 60 rpm, 658 gpm, 1300 psi, Max gas 23,total footage 539'. Spill Drill CRT 87 sec @ 05:30 hrs. 06:00 10:15 4.25 1,384 1,689 SURFA( DRILL DDRL P PJSM; DDrIg f/1384'-1689' MD, 1641'TVD,ART 1.19,AST.99,ADT 2.18, BIT 15.29, Jars 119.03, PU 90K, SO 86K, ROT 92K, Tq on 3-5K, off 2K, ECD 10.31, FO 75%,WOB 1-20K,60 rpm, 675 gpm, 1500 psi, Max gas 172,total footage 305'. 10:15 10:30 0.25 1,689 1,689 SURFA( DRILL SVRG P PJSM; sevice rig. SIMOPS change out air boot on flow line. 10:30 12:00 1.50 1,689 1,809 SURFA( DRILL DDRL P PJSM; DDrIg f/1689'-1809' MD, 1744'TVD,ART.25,AST.47,ADT .72, BIT 16.01, Jars 119.75, PU 91K, SO 87K, ROT 93K, Tq on 5-8K, off 2K, ECD 10.45, FO 82%,WOB 20-25K,40 rpm, 700 gpm, 1600 psi, Max gas 44, total footage 120'. Kick w/Drilling CRT 80 sec @ 13:30 hrs. 12:00 18:00 6.00 1,809 2,223 SURFA( DRILL DDRL P PJSM; DDrlg f/1809'-2223' MD, 2070'TVD,ART 1.95, AST 1.95, ADT 3.90, BIT 19.91,Jars 123.65, PU 105K, SO 88K, ROT 94K, Tq on 4-6K, off 2-4K, ECD 10.52, FO 72%, WOB 20-25K, 60 rpm, 700 gpm, 1800 psi, Max gas 301,total footage 414'. 18:00 00:00 6.00 2,223 2,725 SURFA( DRILL DDRL P PJSM; DDrIg f/2223'-2725' MD, 2453'TVD,ART 4.46,AST.21,ADT 4.67, BIT 24.58,Jars 128.32, PU 112K, SO 90K, ROT 94K,Tq on 5K, off 1-8K, ECD 10.98, FO 85%,WOB 13-25K,60 rpm, 725 gpm, 1975 psi, Max gas 1118, total footage 502'. 07/24/2015 Directional drilled surface section as per plan to TD @ 2971'MD. CBU 3X&monitor well. Back reamed out of the hole&laid down BHA 1. Rig up&run 10-3/4"surface casing as per detail to125'MD. 00:00 05:30 5.50 2,725 2,971 SURFA( DRILL DDRL P PJSM; DDrIg f/2725'-2971'MD, 2645 TVD,ART 4.51,AST 0,ADT 4.51, BIT 29.09, Jars 132.83, PU 115K, SO 93K, ROT 104K, Tq on 5K, off 4-5K, ECD 11.0, FO 62%, WOB 15-17K,60 rpm, 725 gpm, 2100 psi, Max gas 961,total footage 246'. TD @ 2971'MD,2645'TVD. Page 3 of 39 410 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 07:45 2.25 2,971 2,692 SURFA( CASING CIRC P CBU 3X, f/2971'-2692'MD @ 725 gpm, 2100 psi,60 rpm,Tq 4K, FO 62%. 07:45 08:00 0.25 2,692 2,692 SURFA( CASING OWFF P Monitor well, static. 08:00 12:00 4.00 2,692 1,943 SURFA( CASING BKRM P PJSM; BROOH f/2692'-1943' MD© 650 gpm, 1600 psi, FO 63%. Hole frequently unloaded&loosing mud over the shakers, slowed pumps to 300 gpm, 900 psi&reciprocate pipe to clean hole. Calculated fill 7.8, actual 26.4 bbls. 12:00 17:00 5.00 1,943 827 SURFA( CASING BKRM P PJSM; BROOH f/1943'-827'MD @ 650-500 gpm, 1500-900 psi, 50 rpm, FO 62-60%. 17:00 17:15 0.25 827 827 SURFA( CASING OWFF P Monitor well, static. 17:15 19:00 1.75 827 182 SURFA( CASING BKRM P PJSM; BROOH w/HWDP f/ 827'-182'MD @ 500 gpm, 750 psi, 50 rpm, 600 fph, FO 60%. 19:00 20:45 1.75 182 0 SURFA( CASING BHAH P PJSM; lay down BHA1 as per SLB, calculated fill 31.3, actual 36 bbls. 20:45 21:30 0.75 0 0 SURFA( CASING WWWH P PJSM; flush stack. 21:30 22:00 0.50 0 0 SURFA( CASING BHAH P PJSM; clear&clean rig floor. 22:00 23:30 1.50 0 0 SURFA( CASING RURD P PJSM; rig up casing handling equipment. 23:30 00:00 0.50 0 125 SURFA( CASING PUTB P PJSM; run 10.75", 45.5#, L-80, Hydril 563 casing f/0-125' MD. Make up shoe track&test floats,good. 07/25/2015 Run 10-3/4"surface casing as per detail f/125'-2961' MD. Circulate&condition mud for cement. Cement per SLB w/CIP @ 19:10 hrs. Nipple down diverter equipment. 00:00 02:30 2.50 125 900 SURFA( CASING PUTB P PJSM; run 10.75",45.5#, L-80, Hydril 563 casing f/125-900'MD. Lost slack off weight at 900'& attempt to work through. 02:30 03:15 0.75 900 949 SURFA( CASING PUTB T Work pipe through tight spot w/2-3 bpm, 125-200 psi.After multiple attempts rotated at 10 rpm,TQ 10-15K.Work pipe f/900'-949', observed hole unloading with cuttings. 03:15 03:45 0.50 949 949 SURFA( CASING CIRC P Circulate BU @ 4 bpm, 275 psi to clean up wellbore. 03:45 05:30 1.75 949 1,275 SURFA( CASING PUTB P PJSM; run 10.75",45.5#, L-80, Hydril 563 casing f/949-1275'MD. Lost slack off weight at 1275'& attempt to work through. 05:30 06:00 0.50 1,275 1,320 SURFA( CASING PUTB T Work pipe through tight spot w/3 bpm,200 psi.After multiple attempts rotated at 10-15 rpm,TQ 9-10K. Work pipe f/1275'-1320'. 06:00 06:15 0.25 1,320 1,485 SURFA( CASING PUTB P PJSM; run 10.75",45.5#, L-80, Hydril 563 casing f/1320-1485' MD. PU 100K, SO 83K. Page 4 of 39 •Time Logs ,` Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:15 07:00 0.75 1,485 1,485 SURFA( CASING CIRC P Circulate casing volume @ 3-6 bpm, 150 psi, FO 63%, PU 100K, SO 90K. 07:00 09:00 2.00 1,485 2,113 SURFA( CASING PUTB P PJSM; run 10.75",45.5#, L-80, Hydril 563 casing f/1485-2113' MD. 09:00 10:00 1.00 2,113 2,350 SURFA( CASING PUTB T Work pipe through tight spot w/3 bpm, 200 psi.Attempt to rotate& torque up.Work pipe f/2113'-2350'. 10:00 12:00 2.00 2,350 2,961 SURFA( CASING PUTB P PJSM; run 10.75", 45.5#, L-80, Hydril 563 casing f/2350-2961' MD; picking up hanger&landing joint. Installed 71 bow spring centralizers. 12:00 14:45 2.75 2,961 2,961 SURFA( CEMEN"CIRC P Circulate&condition for cement @ 3-8 bpm, 225-150 psi, FO 63%, PU 150K, SO 115K. 14:45 15:00 0.25 2,961 2,961 SURFA( CEMEN-SEQP P PJSM, PT cement lines to 4000 psi for 5 min, good. 15:00 15:30 0.50 2,961 2,961 SURFA( CEMEN-CIRC P Circulate&condition for cement @ 8 bpm, 150 psi, FO 63%, PU 150K, SO 115K. SIMOPS batch up CW-100. 15:30 19:30 4.00 2,961 0 SURFA( CEMEN-CMNT P PJSM; pump 75 bbls of CW-100 @ 5 bpm =230 psi. Pump 71 bbls of Mud Push II @ 4.7 bpm =200 psi. Drop bottom plug. Pump 498 bbls of 11 ppg lead cement @ 7-4 bpm= 225-165 psi. Pump 59 bbls of 12 ppg tail cement @ 4.7 bpm =280 psi. Drop bottom plug. Pump 10 bbls of H2O @ 7 bpm =375 psi. Displace with rig pumps @ 8-3 bpm=800-600 psi.After cement back to surface hanger flutes plugged off&diverted returns to cellar box. Bumped plug @ 2637 strokes. Pressured up to 1100 psi&hold for 5 min. Check floats,good. CIP at 19:10 hrs.Total cement to surface was 65 bbls. 19:30 20:00 0.50 0 0 SURFA( CEMEN-CMNT P PJSM, monitor 4"outlets on conductor&suck down cement to outlets on conductor. 20:00 21:30 1.50 0 0 SURFA( CEMEN RURD P PJSM; rig down landing joint, Volant CRT, &riser. 21:30 00:00 2.50 0 0 SURFA( CEMEN NUND P PJSM; nipple down diverter line, knife valve, &annular. 07/26/2015 Finish ND of diverter system. NU well head&BOPE. Perform BWM on BOPE. Hook up all MPD equipment &test. Rig up&begin testing BOPE. 00:00 02:15 2.25 0 0 SURFA( CEMEN-NUND P PJSM; finish nipple down of diverter tee, Cameron diverter adapter, &4" valves on conductor. SIMOPS mobilize tree&well head equipment to cellar area w/a crane. 02:15 03:00 0.75 0 0 SURFA( WHDBO NUND P PJSM; nipple up Cameron casing head&tubing spool. 03:00 03:15 0.25 0 0 SURFA(WHDBO PRTS P PJSM;test casing head seals to 5000 psi for 10 min, good. Page 5of39 iTime Logs _Date From To Dur ' S. Depth E. Depth Phase Code Subcode T Comment 03:15 04:30 1.25 0 0 SURFA(WHDBO MPDA P PJSM; install MPD air valve on BOPE stack. 04:30 06:00 1.50 0 0 SURFA(WHDBO NUND P PJSM; nipple up BOPE. SIMOPS pick up&install test plug. Spill Drill CRT=98 sec @ 04:50 hrs. 06:00 13:00 7.00 0 0 SURFA( WHDBO SVRG P PJSM; perform CPAI BWM inspection on BOPE. 13:00 14:00 1.00 0 0 SURFA( WHDBO NUND P PJSM; nipple up kill&choke lines. SIMOPS tighten up MPD air valve 14:00 15:30 1.50 0 0 SURFA( WHDBO MPDA P PJSM; remove trip nipple&install MPD test cap. Rig up to test MPD system. 15:30 18:30 3.00 0 0 SURFA( WHDBO MPDA P PJSM; rig up scaffolding in cellar around BOP stack. SIMOPS rig up lines in cellar for MPD. 18:30 20:15 1.75 0 0 SURFA( WHDBO MPDA P PJSM; rig up&test MPD air valve 250/1400 psi, choke valves 250/1200 psi. Hold each 5 minutes on low& 10 minutes on high. Rig down test equipment&blow down lines. 20:15 22:15 2.00 0 0 SURFA(WHDBO OTHR P PJSM; change out saver sub from 4-1/2"IF to 4"XT39. Change out back up wrench from 5"to 4". SIMOPS install trip nipple. 22:15 23:00 0.75 0 0 SURFA( WHDBO RURD P PJSM; rig up to test BOPE. 23:00 00:00 1.00 0 0 SURFA( WHDBO BOPE P PJSM; test BOPE w/5"joint 250/3500 psi for 5 min each.#1 Top VBR's, CV 1, 12, 13, 14&manual kill valve.#2 Upper IBOP, HCR kill valve, CV 9& 11. 07/27/2015 Finish testing BOPE w/4"&5"test joints. Pick up 4"DP&rack back in derrick. Make up BHA 2&TIH to 2035'MD. 00:00 05:00 5.00 0 0 SURFA( WHDBO BOPE P 'PJSM; continue testing BOPE w/5" &4"test joints to 250/3500 psi for 5 min each.#3 lower IBOP, CV 5,8,10.#4 5" Dart valve, CV 4,6,7.#5 5"FOSV, CV 2.#6 4"FOSV, HCR Choke,4"Kill line Demco valve.#7 4"Dart valve, Manual choke valve, HCR Kill valve.#8 Annular w/5"TJ. 250/2500 psi.#9 Lower VBR's.#10 Blind rams&CV 3.#11 Annular w/ 4"TJ 250/2500 psi.#12 Upper VBR's w/4"TJ.#13 Lower VBR's w/ 4"TJ.#14 Manual choke&super choke.Accumulator test; Int system pressure 2900 psi, after closure 1800 psi,200 psi attained in 40 sec, full psi attained in 173 sec. 5 bottles @ 2000 psi.Test gas&pit level alarms. Test witness waived by AOGCC John Crisp. Page 6 of 39 Time Logs S S Date From To Dur S. Depth=E. Depth Phase Code Subcode T Comment 05:00 07:00 2.00 0 0 SURFA( WHDBO RURD P PJSM; rig down test equipment blow down all lines&choke manifold. SIMOPS install 1502 to flange on annulus valve. Accumulator Drill @ 05:00 hrs. 07:00 07:30 0.50 0 0 SURFA( CEMEN.RURD P PJSM; rig up to pick up 4"DP. 07:30 09:00 1.50 0 0 SURFA( CEMEN-PULD P PJSM; pick up 18 stands of 4"DP& rack back in the derrick. 09:00 09:15 0.25 0 0 SURFA( CEMEN-RURD P PJSM; install wear bushing w/10" ID per CIW Rep. 09:15 13:00 3.75 0 0 SURFA( CEMEN'PULD P PJSM; pick up 65 stands of 4"DP& rack back in the derrick. Lay down mouse hole. 13:00 13:45 0.75 0 0 SURFA( CEMEN-BHAH P PJSM; mobilize BHA 2 to rig floor. 13:45 14:45 1.00 0 0 SURFA( CEMEN-BHAH T PJSM; pick up BHA 2 as per SLB DD. Found different connections for bit&rotary steerable. Confer w/ town. 14:45 15:45 1.00 0 0 SURFA( CEMEN-BHAH T Continue to pick up BHA 2 while waiting on a bit. Spill Drill CRT 98 sec @ 15:30 hrs. 15:45 17:15 1.50 0 0 SURFA( CEMEN-SVRG T PJSM, service rig while waiting on a bit. 17:15 18:15 1.00 0 79 SURFA( CEMEN BHAH P PJSM; continue to pick up BHA 2 per SLB 0-79' MD. 18:15 19:45 1.50 79 79 SURFA( CEMEN BHAH T While installing floats in sub it was noted that float&sub bore did not fit correctly(float a little loose). Rigged up test equipment&tested to 700 psi. 250 psi loss observed in 5 min. Calls made to mobilize different float subs from SLB shop in Prudhoe Bay. 19:45 22:00 2.25 79 79 SURFA( CEMEN WAIT T PJSM;work on MP2's& housekeeping while waiting on float subs. 22:00 23:00 1.00 79 731 SURFA( CEMEN'BHAH P PJSM; continue picking up BHA 2 as per SLB DD, from 79'-731' MD. 23:00 23:15 0.25 731 731 SURFA( CEMEN-BHAH P PJSM, continue picking up BHA 2 23:15 00:00 0.75 731 2,035 SURFA( CEMEN-TRIPP TIH with 5"DP f/731'-2035' MD, PU 75K, SO 74K, calculated displacement 23.03, actual 26.5 bbls. 07/28/2015 RIH w/BHA#2 to 2695'. Install MPD bearing&test MPD. Shallow test MWD. Pull MPD bearing & Install trip nipple.Test csg to 3500 psi for 30 mins. Clean out shoe track. Drill f/2971'-2991' MD. CBU. Perform LOT to 12.3 ppg EMW. DDrill ahead f/2991'-3023'MD. Decision made to TOH to perform remedial cement work at shoe. CBU&TOH, laying down BHA 2. Load shed w/3.5"tubing&RU to PU tubing. 00:00 01:00 1.00 2,035 2,695 SURFA( CEMEN-TRIPP RIH w/BHA#@ f/2035'to 2695' MD -PU wt 105 SO wt 75 ROT wt 96- Torque 5/6 k Calc. displacement 8.34 bbls Actual -3.1 bbls 01:00 01:45 0.75 2,695 2,695 SURFA( CEMEN-MPDA P Pull trip nipple-Install MPD bearing Page 7 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 03:00 1.25 2,695 2,695 SURFA( CEMEN-MPDA P Test MDP to 800 psi-Ramp up& down w/PLT-Install Katch Kan& skirt 03:00 03:15 0.25 2,695 2,695 SURFA( CEMEN-DHEQ P Shallow pulse test MWD tools 03:15 04:15 1.00 2,695 2,695 SURFA( CEMEN-MPDA P Continue simmulation ramp up& ramp down with MPD-Blow down MPD skid 04:15 05:00 0.75 2,695 2,695 SURFA( CEMEN-MPDA P Pull MPD bearing-Install trip nipple 05:00 05:15 0.25 2,695 2,695 SURFA( CEMEN-CIRC P Break circ 450 gpm 700 psi w/27% flow out. Kick w/Tripping CRT 79 sec© 05:15 hrs. 05:15 06:30 1.25 2,695 2,695 SURFA( CEMEN-PRTS P RU&test 10 3/4"csg to 3500 psi for 30 mins. (Good test) RD 06:30 07:15 0.75 2,695 2,874 SURFA( CEMEN-COCF P Wash&ream f/2695'to 2874'@ 500 gpm @ 875 psi w/29%flow out -40 rpm's w/5/6 k torque Obtain SPR's @ 2874'MD 2502' TVD w/9.5 ppg mud @ 0700 hrs #1 30/40 SPM @ 60/100 psi #2 30/40 SPM @ 60/100 psi 07:15 12:00 4.75 2,874 2,915 SURFA( CEMEN-DRLG P Drill cement f/2874'to 2876'-Drilled float collar f/2876'to 2877'-Drilled cement f/2877'to 2915'@ 500 gpm @ 875 psi w/30%flow out-40 rpm's w/5/6k torque-PU wt. 106 SO wt. 75 ROT wt. 96 12:00 14:15 2.25 2,915 2,971 SURFA( CEMEN-DRLG P PJSM;drill cement f/2915'to 2971' MD, 500 gpm, 875 psi, FO 30%, 50 rpm,4-8k Tq, PU 112, SO 85, ROT 99K,WOB 5-8K. 14:15 15:30 1.25 2,971 2,991 SURFA( CEMEN-DDRL P PJSM; DDrlg f/2971'-2991'MD, 2661'TVD,ART.58,AST 0,ADT .58, BIT.58, Jars 128.96, PU 115K, SO 85K, ROT 99K,Tq on 7-10K, off 5-6K, ECD 9.95, FO 35%,WOB 7-15K, 80 rpm, 700 gpm, 1550 psi, Max gas 0,total footage 20'. 15:30 16:00 0.50 2,991 2,961 SURFA( CEMEN-CIRCP Circulate&condition @ 700 gpm, 1550 psi, 60 rpm, Tq 4-6K. From 2991'-2961' MD. 16:00 17:45 1.75 2,961 2,991 SURFA( CEMEN LOT T PJSM; RU&perform LOT. Pressure up to 900 psi, pressure bled down to 260 psi.Attempt test 2 more times& each time pressure broke over at 350 psi. Page 8 of 39 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 18:45 1.00 2,991 3,023 SURFA( CEMEN-DDRL P PJSM; DDrIg f/2991'-3023' MD, 2686'TVD,ART 1.0,AST 0,ADT 1.0, BIT 1.58, Jars 129.54, PU 115K, SO 85K, ROT 99K, Tq on 7-10K, off 5-6K, ECD 9.95, FO 35%,WOB 7-15K, 80 rpm, 707 gpm, 1550 psi, Max gas 0,total footage 32'. Decision made to stop drilling& come out of hole to perform remedial cement work. 18:45 19:15 0.50 3,023 3,023 SURFA( CEMEN-CIRCT CBU @ 700 gpm, 1550 psi, 60 rpm, Tq 4-6K. SPR @ 3020' MD, 2652'TVD, MW 9.5+, 19:00 hrs #1 30/40 SPM @ 55/100 psi #2 30/40 SPM @ 60/100 psi 19:15 19:30 0.25 3,023 3,023 SURFA( CEMEN-OWFF T Monitor well, static. 19:30 20:45 1.25 3,023 731 SURFA( CEMEN-TRIP T PJSM; TOH f/3023'-731' MD. 20:45 21:00 0.25 731 731 SURFA( CEMEN'OWFF T Monitor well,static. 21:00 22:30 1.50 731 0 SURFA( CEMEN-BHAH T PJSM; lay down BHA 2 as per SLB DD. Calculated fill 33.6, actual 35.3 bbls. 22:30 23:00 0.50 0 0 SURFA( CEMEN-BHAH T PJSM; clear&clean rig floor. 23:00 23:30 0.50 0 0 SURFA( CEMEN RURD T PJSM; load shed w/14 joints of 3.5" tubing, strap&rabbit. 23:30 00:00 0.50 0 0 SURFA( CEMEN-RURD T PJSM; pick up&rig up tubing _ handling equipment. 07/29/2015 MU 3 1/2"cmt stinger(14 jts)RIH on 4"DP to 2902'-Circ btms up-Wait on cementers(service rig and work on work orders) RU cementers-RIH to 3023'-Spotted 30 bbls 15.8 ppg cmt plug-POOH to 2619'- Circ 1.5's btms up @ 38 gpm @ 1025'-Perform hesitation squeeze(squeezed total of 9 bbls. cmt final pressure 1000 psi) Bleed off pressure&POOH w/4"Dp&3 1/2"tbg-Test annular w/4"TJ 250/2500 psi- TIH w/BHA 3 to 2688'MD-CBU 00:00 01:00 1.00 0 446 SURFA( CEMEN PULD T MU 14 jts 3 1/2"tbg(445.97')w/ mule shoe for cement stinger 01:00 01:30 0.50 446 446 SURFA( CEMEN-RURD T RD tbg tongs 01:30 02:00 0.50 446 2,902 SURFA( CEMEN TRIP T RIH w/3 1/2"cmt stinger on 4" DP f/ 446'to 2902'-Calc displacement- 15.51 bbls Actual-16.1 bbls 02:00 03:00 1.00 2,902 2,902 SURFA( CEMEN-CIRC T Circ btms up @ 6 bbls/min @ 250 psi w/16%flow out 03:00 06:30 3.50 2,902 2,902 SURFA( CEMEN-WAIT T Wait on cementers-Monitor well on TT-Service rig and work on work orders 06:30 07:30 1.00 2,902 2,902 SURFA( CEMEN-RURD T Spot cement trucks&RU cement lines to cellar 07:30 09:00 1.50 2,902 2,902 SURFA( CEMEN CIRC T Circ btms up @ 6 bbls/min @ 250 psi w/17%flow out 09:00 09:15 0.25 2,902 2,902 SURFA( CEMEN-SFTY T Held PJSM on spotting cmt plug 09:15 09:45 0.50 2,902 3,023 SURFA( CEMEN-TRIPT RIH f/2902'to 3023'(PU working single) Page 9 of 39 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:30 0.75 3,023 3,020 SURFA( CEMEN-CMNT T RU cmt line-Spot cmt plug as follows: Pumped 5 bbls 12.5 ppg MudPush II-Tested lines to 900& 3800 psi(Good)-Pumped 13 bbls 12.5 ppg Mud Push II @ 5 bbls/min @ 275 psi-Dropped wiper ball- Batch mix&pumped 30 bbls 15.8 ppg Class G cmt @ 5 bbls/min @ 332 psi-Followed by 3 bbls/12.5 ppg Mud Push II-switch to rig pump &displaced w/23.5 bbls-9.6 ppg mud @ 6 bbls/min @ 275 psi to equalize-CIP @ 10:35 hrs. 10:30 11:30 1.00 3,020 2,619 SURFA( CEMEN TRIP T POOH f/3023'to 2619'-pulled first std @ 400'/hr&next 3 Stds @ 650'/hr-LD working single 11:30 12:15 0.75 2,619 2,619 SURFA( CEMEN CIRC T Drop wiper ball&Circ 1.5 X btms up @ 386 gpm @ 1025 psi w/25%flow out 12:15 15:00 2.75 2,619 2,619 SURFA( CEMEN-SQEZ T RU&Perform hesitation squeeze as follows: Closed annular-Pumped 1/2 bbls pressured up to 450 psi-Hold 15 mins. -Pumped 1/2 bbl- pressured up to 700 psi-Shut in for 15 mins. bled down to 575 psi- Pumped 1/2 bbl-pressured up to 800 psi-shut in for 15 mins. bled down to 550 psi-Pumped 4 bbls- pressured to 700 psi-shut in for 15 mins. bled down to 520 psi-Pumped 2 bbls-pressured up to 875 psi- shut in for 15 mins.-bled down to 520 psi-Pumped 1/2 bbl- pressured up to 850 psi-shut in for 15 mins.-bled down to 700 psi- Pumped 1/2 bbl-pressured up to 1000 psi-shut in for 15 mins. -bled down to 800 psi-Pumped 1/2 bbl pressured up to 1100 psi-shut in for 20 mins.-bled down to 975 psi Squeezed total of 9 bbls away-Bled off pressure-Opened annular-RD squeeze equipment 15:00 15:30 0.50 2,619 2,619 SURFA( CEMEN CIRC T Circ btms. up @ 465 gpm @ 700 psi (mud out of balance) 15:30 16:30 1.00 2,619 445 SURFA( CEMEN TRIP T POOH w/4" DP f/2619'to 445' 16:30 16:45 0.25 445 445 SURFA( CEMEN RURD T RU to LD 3 1/2"tbg 16:45 17:15 0.50 445 0 SURFA( CEMEN-PULD T Pull and LD 14 jts 3 1/2"tbg&mule shoe 17:15 18:00 0.75 0 0 SURFA( CEMEN-RURD T RD tbg tong-LD csg equipment- clean up rig floor 18:00 18:30 0.50 0 0 SURFA( CEMEN-BOPE T PJSM; pull wear bushing&install test plug. 18:30 19:15 0.75 0 0 SURFA( CEMEN BOPE T PJSM; RU&test annular w/4"test joint to 250/2500 psi for 5 min each. 19:15 20:00 0.75 0 0 SURFA( CEMEN-BOPE T PJSM; remove test plug&install 10" ID wear bushing. Page 10 of 39 Time Logs , . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:15 1.25 0 174 SURFA( CEMEN-BHAH T PJSM; pick up BHA 3 as per SLB DD. 21:15 21:45 0.50 174 1,662 SURFA( CEMEN-TRIPT PJSM; TIH f/174'-1662' MD 21:45 22:00 0.25 1,662 1,662 SURFA( CEMEN-DHEQ T Shallow hole test MWD, 500 gpm, 1000 psi. 22:00 22:30 0.50 1,662 2,600 SURFA( CEMEN-TRIP T PJSM; TIH f/1662'-2600' MD. 22:30 23:15 0.75 2,600 2,688 SURFA( CEMEN-WASH T PJSM;wash down f/2600'-2688' MD @ 500 gpm, 1000 psi. Calculated displacement 31.48, actual 34.3 bbls. 23:15 23:30 0.25 2,688 2,688 SURFA( CEMEN-CIRC T CBU @ 500 gpm, 1100 psi. 23:30 00:00 0.50 2,688 2,688 SURFA( CEMEN'WOC T Monitor well circulating over the top w/the hole fill. SIMOPS check all connections on MPD choke skid. 07/30/2015 Wait on cmt. -Pressure test MPD skid unit-Pull trip nipple-install MPD bearing-Test MPD chokes-Pull MPD bearing-Install trip nipple(while waiting on cmt)-Wash down to top of cmt©2835'-Drilled cmt f/ 2835'to 3023'-Drilled 20' new hole to 3043'-Circ hole clean-Performed FIT to 14.6 ppg EMW-Drill 9 7/8" hole f/3043'-4000' MD. Displace from spud mud to 9.6 ppg LSND mud system while drilling ahead. Total footage 1184' MD. 00:00 02:00 2.00 2,688 2,688 SURFA( CEMEN-WOC T Wait on cmt. -SIMOPS-Pressure test MPD choke skid to 250& 1200 psi Kick w/Tripping Drill CRT 70 sec @ 00:30 hrs. 02:00 03:00 1.00 2,688 2,688 SURFA( CEMEN WOC T Wait on Cmt.-SIMOPS-Pull trip nipple-Install MPD bearing 03:00 04:45 1.75 2,688 2,688 SURFA( CEMEN MPDA T Test MPD chokes as/SafeKlck Rep.-Blow down lines&MDP unit- Pull MPD bearing-Install trip nipple 04:45 05:30 0.75 2,688 2,835 SURFA( CEMEN REAM T Wash&ream down f/2688'to 2835' (top of cmt.)@ 6000 gpm @ 1575 psi w/60 rpm/w 5 k torque SPR @ 2700'MD, 2453'TVD, MW 9.7, 05:30 hrs #1 30/40 SPM @ 40/80 psi #2 30/40 SPM @ 40/80 psi 05:30 07:00 1.50 2,835 3,023 SURFA( CEMEN-DRLG T Drill cmt f/2835'to 3023'@ 600 gpm @ 1575 psi w/36%flow out-60 rpms'w/5 to 8 K torque-5/10 k wt. on bit-PU wt. 115 SO wt 85 ROT wt. 95 07:00 07:30 0.50 3,023 3,043 SURFA( CEMEN DDRL P Drilled 9 7/8" hole w/RSS f/3023'to 3043' MD 2702'TVD ADT-.16 hrs. ECD-10.41 ppg Footage-20' WOB 5 to 10 k RPM 60 GPM 600 @ 1650 psi w/39%flow out String wt. PU 115 SO 85 ROT 95 Torque on/off btm.-7/5 k Max. gas 165 units Total bit hrs. .16 hrs Total jar hrs. 129.70 hrs Page 11 of 39 Time Logs . ,Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 10:00 2.50 3,043 2,978 SURFA( CEMEN-CIRCT Circ hole c lean for FIT @ 600 gpm @ 1650 psi w/60 RPM-Mud was contamatated w/cmt-Pulled back into casing(2978')&continue circ& condition mud Obtained SPR's @ 2700' MD 2453' TVD w/9.7 ppg @ 0740 hrs #1 30/40 SPM @ 40/80 psi #2 30/40 SPM @ 40/80 psi 10:00 11:15 1.25 2,978 2,978 SURFA( CEMEN-FIT T RU&performed FIT to 14.6 ppg EMW w/9.6 ppg mud @ 2638'TVD w/680 psi applied surface pressure- RD 11:15 11:30 0.25 2,978 3,043 INTRM1 DRILL REAM P Wash&ream f/2978'to 3043'@ 600 gpm @ 1580 psi w/37%flow out -@ 40 rpm w/5 to 6 K torque 11:30 12:00 0.50 3,043 3,052 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/3043'to 3052'MD 2710'TVD ADT-.15 hrs. ECD-9.95 ppg Footage-9' WOB 3 to 5 k RPM 80 GPM 650 @ 1740 psi w/37%flow out String wt PU 115 SO 85 ROT 95 Torque on/off btm.-9/6 k Total bit hrs. .31 hrs Total jar hrs. 129.85 hrs Max gas 143 units 12:00 18:00 6.00 3,052 3,452 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3052'to 33452' MD-3020'TVD ADT-4.14 hrs ECD- 10.21 to 10.24 ppg Footage-418' WOB-3 to 9 k RPM 80 to 120 GPM 650 to 680 @ 1350 to 1575 psi String wt. PU 117 to 119 SO 86 to 92 ROT 100 to 104 Torque on btm 3 to 9 k off btm. 3 to 6k Total bit hrs.4.45 hrs Total jar hrs 133.99 hrs Changed over to 9.6 ppg LSND mud while drilling ahead f/3070' SPR @ 3355' MD, 2967'TVD, MW 9.6, 16:45 hrs #1 30/40 SPM @ 90/130 psi #2 30/40 SPM @ 95/130 psi Page 12 of 39 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 3,452 4,000 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3452'to 4000' MD-3459'TVD ADT-4.58 hrs ECD- 10.3 ppg Footage-548' WOB-5 to 9 k RPM 140 GPM 725 @ 1850 psi String wt. PU 118 SO 99 ROT 107 Torque on btm 5 to 7 k off btm. 2 k Total bit hrs. 9.03 hrs Total jar hrs 138.57 hrs SPR @ 3828' MD, 3313'TVD, MW 9.6,22:00 hrs #1 30/40 SPM @ 140/170 psi #2 30/40 SPM @ 140/170 psi Kick w/Drilling CRT 87 sec @ 23:30 hrs 07/31/2015 Drilled 9 7/8"hole w/RSS f/4000'to 5347'-Pump sweep-Monitor well-Pull trip nipple&Install MPD bearing-Test MPD skid-Test choke closing pressures on MPD system-DDrill f/5344'-5490' MD.Total footage 1490'MD. 00:00 06:00 6.00 4,000 4,596 INTRMI DRILL DDRL P Drilled 9 7/8" hole f/4000'to 4586' MD 3975'TVD ADT-4.84 hrs. ECD- 10.55 ppg Footage-586' WOB 5/7 k RPM 140 GPM 725 @ 2150 psi w/42%flow out String wt. PU 133 SO 109 ROT 120 Torque on/off btm.-7/3 k Max gas-91 units Total bit hrs. 13.87 hrs Total jar hrs. 143.41 hrs Spill Drill CRT 80 sec @ 04:30 hrs. 06:00 12:00 6.00 4,596 5,059 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4586'to 5059' MD 4396"TVD ADT-4.23 hrs ECD- 10.54 ppg Footage-472' WOB 5/8 k RPM 140 GPM 720 @ 2350 psi w/40%flow out String wt. PU 141 SO 115 ROT 125 Torque on/off btm.-7/4 k Total bit hrs.18.10 hrs Total jar hrs. 147.64 hrs Max gas-69 units SPR's @ 4869'MD 4224'TVD w/ 9.6+ppg 2 0915 hrs #1 30/40 SPM @ 150/190 psi #2 30/40 SPM @ 160/200 psi Page 13 of 39 Time Logs , 110' Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:00 15:00 3.00 5,059 5,344 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5059'to 5344'MD 4657'TVD ADT-2.56 hrs. ECD- 10.91 ppg Footage-285' WOB 5/9 k RPM 140 GPM 725 @ 2550 psi w/39%flow out String wt. PU 148 SO 117 ROT 117 Torque on/off btm.-9/4 k Total bit hrs.20.66 hrs Total jar hrs. 150.20 hrs 15:00 16:00 1.00 5,344 5,190 INTRM1 DRILL CIRC P PJSM;weight up mud system f/9.6 ppg to 10.0 ppg. Circulate shakers clean. SPR's @ 5344' MD 4568'TVD w/ 10.0 ppg© 16:00 hrs #1 30/40 SPM @ 160/210 psi #2 30/40 SPM @ 160/210 psi 16:00 16:30 0.50 5,190 5,190 INTRM1 DRILL OWFF P Monitor well, static. 16:30 17:45 1.25 5,190 5,190 INTRMI DRILL MPDA P PJSM; pull trip nipple&install MPD bearing. 17:45 19:30 1.75 5,190 5,190 INTRM1 DRILL MPDA P PJSM; pressure test MPD system per Rig Engineer. 19:30 21:45 2.25 5,190 5,190 INTRM1 DRILL MPDA T PJSM;trouble shoot MPD choke skid. Perform series of ramp up& down of system. Trap psi&observe reactions of chokes. Tests inconclusive decide to drill ahead& operate chokes in manual mode. 21:45 22:15 0.50 5,190 5,344 INTRM1 DRILL REAM P PJSM;wash&ream to bottom f/ 5190'-5344'MD, 725 gpm, 2750 psi, 120 rpm, Tq 5K. 22:15 00:00 1.75 5,344 5,490 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5344'to 5490' MD 4791'TVD ADT- 1.38 hrs. ECD- 11.05 ppg Footage- 146' WOB 7-10 k RPM 140 GPM 725© 2750 psi w/77%flow out String wt. PU 145 SO 114 ROT 126 Torque on/off btm.-7/4 k Total bit hrs.22.04 hrs Total jar hrs. 151.58 hrs 08/01/2015 Drilled 9 7/8"hole w/RSS f/5490'to 6668'MD. Perform open hole FIT to 11.9 ppg EMW, calculated to the C37 @ 4845 TVD. Drill ahead f/6668'-6973'MD. Lose power to rig®ain power. Establish drilling parameters&calibrate MPD. Incur 80 bph losses @ 6973'MD, pump LCM pill. Page 14 of 39 Time Logs • • Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 5,490 6,035 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS&MPD f/ 5490'to 6035' MD 5272'TVD ADT-4.98 hrs. ECD- 11.10 ppg Footage-545' WOB 5/10 k RPM 140 GPM 725 @ 3080 psi w/75%flow out String wt.-PU 155 SO 120 ROT 133 Torque on/off btm.-10/5 k Max gas.408 units Total bit hrs.27.02 hrs Total jar hrs. 156.56 hrs. SPR's @ 5533'MD 4827'TVD w/ 10.0 ppg @ 0030 hrs. #1 30/40 SPM @ 180/240 psi #2 30/40 SPM @ 170/240 psi 06:00 12:00 6.00 6,035 6,385 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS&MPD f/ 6035'to 6385'MD-5549'TVD ADT-3.95 hrs. - ECD 10.98 ppg Footage-350' WOB 10k RPM 140 GPM725@ 3150 psi String wt.-PU 160 SO 120 ROT 135 Torque on/off btm.-11/5 k Max. gas-525 units Total bit hrs. 30.97 hrs Total jar hrs.160.51 hrs SPR's @ 6097' MD 5325'TVD w/ 10.0 ppg @ 0600 hrs #1 30/40 SPM @ 180/220 psi #2 30/40 SPM @ 175/225 psi 12:00 16:45 4.75 6,385 6,668 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS&MPD f/ 6385'to 6668'MD-5742'TVD ADT-3.03 hrs. - ECD 10.97 ppg Footage-283' WOB 10 k RPM 140 GPM 725 @ 3425 psi String wt.-PU 167 SO 117 ROT 133 Torque on/off btm.-10/4 k Max.gas-74 units Total bit hrs. 34.0 hrs Total jar hrs.163.54 hrs SPR's @ 6570'MD 5678'TVD w/ 10.0 ppg @ 15:15 hrs #1 30/40 SPM @ 190/240 psi #2 30/40 SPM @ 180/240 psi 16:45 17:30 0.75 6,668 6,668 INTRM1 DRILL CIRC P Circulate hole clean, pump high-vis sweep @ 725 gpm, 3350 psi, 120 rpm, Tq 6-7K. Page 15 of 39 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:00 0.50 6,668 6,668 INTRM1 DRILL FIT P Perform open hole FIT©6603'MD, 5698'TVD, MW 10.0 ppg,to EMW 11.9 ppg calculated @ the C37 4845 TVD. 13.5 ppg EMW seen at the shoe. Good test. 18:00 22:00 4.00 6,668 6,973 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS&MPD f/ 6668'to 6973'MD-5901'TVD ADT-3.16 hrs. - ECD 11.46 ppg Footage-305' WOB 11 k RPM 140 GPM 725 @ 3700 psi String wt.-PU 165 SO 117 ROT 134 Torque on/off btm.- 10/4 k Max.gas-238 units Total bit hrs. 37.16 hrs Total jar hrs.166.70 hrs 22:00 22:45 0.75 6,973 6,973 INTRM1 DRILL RGRP T Power loss while drilling ahead, bringing the mud weight up to 10.5 ppg from 10.2 ppg before drilling the HRZ. . Reestablish drilling parameters after power back on& CBU to determine cause of failure, 720 gpm, 3700 psi, 120 rpm,Tq 7-8K. Recalibrate MPD system. Began taking mud losses, initially measured 80 bph. 22:45 00:00 1.25 6,973 6,973 INTRM1 DRILL CIRC T Began taking losses established @ 80 bph, reduce pump rate to 500 gpm, 2100 psi, 120 rpm, Tq 7-8K. Pump 30 bbl, 15 ppb LCM pill. 08/02/2015 Pump sweep-establish loss rate @ 50 bbls/hr-Spot LCM pill f/6955'to 6671'- Circ&monitor losses @ 45 bbls/hr. -RIH to 6955'-Wash down to 6973'Drill 9 7/8"hole f/6973'to 7142'-Perform Exhale test to confirm well breathing-Drill 9 7/8"hole f/7142'-7835' MD, 6248'TVD. Total footage 862'. Total losses 220 bbls for 24 hrs. 00:00 00:30 0.50 6,968 6,968 INTRMI DRILL CIRC T Continue pumping sweep @ 6968' © 400gpm @w/105 rpm's w/7 k torque-Loss rate 50 bbls/hr 00:30 01:45 1.25 6,968 6,955 INTRM1 DRILL CIRC T Rack back 1 std DP to 6955'-stage pump up to 650 gpm @ 3250 psi w/ 60 rpm-establish loss rate @ 60 bbls/hr 01:45 02:30 0.75 6,955 6,671 INTRMI DRILL PMPO T Mix&spot LCM pill 15 Ib/bbl f/6955' to to 6671'@ 2 bbls/min @ 300 psi w/40 rpm's w/7 k torque 02:30 03:45 1.25 6,671 6,671 INTRM1 DRILL CIRC T Circ btms. up @ 6671' @ 500 gpm @ 2050 psi w/120 rpm's w/7 k torque-ECD 11.34 ppg-stage pump up to 600 gpm @ 2900 psi- Losses @ 45 bbl/hr 03:45 04:15 0.50 6,671 6,955 INTRM1 DRILL TRIP T RIH f/6671'to 6955' Page 16 of 39 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 6,955 6,973 INTRM1 DRILL REAM T Wash&ream f/6955'to 6973'© 600 gpm @ 2900 psi w/140 rpm's w/ 7 k torque-ECD 11.34 ppg SPR's @ 6973'MD 5911'TVD w/ 10.6 ppg @ 04:30 hrs #1 30/40 SPM @ 250/320 psi #2 30/40 SPM @ 250/315 psi 04:30 06:00 1.50 6,973 7,047 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS&MPD f/ 6973'to 7047' MD 5946'TVD ADT- 1.09 hrs ECD- 11.36 ppg Footage-74' WOB 7/11 k RPM 140 GPM 600 @ 2950 psi w/74%flow out String wt. PU 165 SO 117 ROT 134 Torque on/off btm.-12/7 k Max gas-215 units Total bit hrs. 38.25 hrs. Total jar hrs. 167.79 hrs SPR's @ 6973' MD 5911'TVD w/ 10.6 ppg @ 0430 hrs. #1 30/40 SPM @ 250/320 psi _ #2 30/40 SPM @ 250/315 psi _ 06:00 08:15 2.25 7,047 7,142 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS&MPD f/ 7047'to 7142' MD 5986'TVD ADT-1.53 hrs. ECD-11.36 ppg Footage-95' WOB 8/11 k RPM 140 GPM 600 @ 2950 psi w/70%flow out String wt. PU 160 SO 113 ROT 127 Torque on/off btm.- 12/7 Max gas 554 units. Total bit hrs. 39.78 hrs Total jar hrs. 169.32 hrs Spill Drill CRT 120 sec @ 07:00 hrs. 08:15 09:00 0.75 7,142 7,142 INTRM1 DRILL OWFF T Performed Exhale test to confirm well breathing-well bleed back 12 bbls/in 30 mins. @ 50 bbls/hr- Slowed to 8 bbls/hr 09:00 09:30 0.50 7,142 7,142 INTRM1 DRILL MPDA T Trouble shoot Servo motor A on MPD manifold Page 17of39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:00 2.50 7,142 7,236 INTRM1 DRILL DDRL P Drilled 9 7/8"hole f/7142'to 7236' MD 6026' TVD ADT-1.75 hrs ECD- 11.36 ppg Footage-94' WOB 8/11 k RPM 140 GPM 600 @ 3050 psi String wt.-PU 160 SO 113 ROT 127 Torque on/off btm.-11/7 k Max gas 669 units Total bit hrs.41.53 hrs Total jar hrs. 171.07 hrs. Total losses f/midnight to noon- 133 bbls 12:00 18:00 6.00 7,236 7,519 INTRM1 DRILL DDRL P Drilled 9 7/8" hole f/7236'to 7519' MD 6129' TVD ADT-4.64 hrs ECD- 11.42 ppg Footage-283' WOB 9/12 k RPM 120-130 GPM 640 @ 3250 psi String wt.-PU 163 SO 113 ROT 127 Torque on/off btm.-11/5 k Max gas 590 units Total bit hrs.46.17 hrs Total jar hrs. 175.71 hrs. SPR's @ 7422'MD 6091'TVD w/ 10.5 ppg @ 16:00 hrs #1 30/40 SPM @ 200/245 psi #2 30/40 SPM @ 210/250 psi 18:00 00:00 6.00 7,519 7,835 INTRM1 DRILL DDRL P Drilled 9 7/8"hole f/7519'to 7835' MD 6248' TVD ADT-5.24 hrs ECD- 11.28 ppg Footage-316' WOB 8/12 k RPM 120-130 GPM 640 @ 3250 psi String wt.-PU 170 SO 108 ROT 127 Torque on/off btm.- 11/5 k Max gas 613 units Total bit hrs. 51.41 hrs Total jar hrs. 180.95 hrs. Losses for tour 87 bbls. 08/03/2015 Drilled 9 7/8"hole f/7835'to 7878'-Circ 9 X btms up standing back 1 std DP/btms up to 7050'-RIH to 7878' -Pump Hi-vis sweep&perform 385 bbl whole mud dilution-Monitor well on TT to confirm well bore breathing. TOH w/MPD f/7806'-6558' MD.Attempt to work through tight spot 4X at 6558'MD. Rig up to CBU. Page 18 of 39 Time Logs • 41111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 7,835 7,878 INTRM1 DRILL DDRL P Drilled 9 7/8"hole f/7835'to 7878' MD 6264'TVD ADT-.73 hrs. ECD- 11.29 ppg Footage-43' WOB 8/14 k RPM 110 GPM 640 @ 3125 psi w/70%flow out String wt. -PU 170 SO 108 ROT 127 Torque on/off btm-11/6 k Max gas 896 units Total bit hrs. 52.41 hrs. Total jar hrs. 181.68 hrs. SPR's©7878' MD 6264'TVD w/ 10.5 ppg©0045 hrs. #1 30/40 SPM @ 375/450 psi #2 30/40 SPM ©380/460 psi 00:45 08:45 8.00 7,878 7,050 INTRM1 CASING CIRC P Circ 9 X btms up @ 640 gpm @ 3100 to 2900 psi w/140 rpm w/7 k torque-standing back 1 std DP/ every btms up to 7050'-Pumped 27 bbls hi-vis sweep @ 7600'-No increase in cuttings observed @ shakers. Fire Drill CRT 120 sec©06:00 hrs. 08:45 11:15 2.50 7,050 7,878 INTRM1 CASING REAM P Ream back in hole f/7050'to 7878' @ 640 gpm @ 3100 psi w/80 rpm's w/6/8 k torque-ECD-11.24 ppg 11:15 12:45 1.50 7,878 7,878 INTRM1 CASING CIRC P Pumped 27 bbls hi-vis sweep @ 640 gpm @ 3100 psi w/120 rpm's w/6/8 K torque-ECD- 11.24 ppg-Rot wt 120 PU 75 SO 69 12:45 14:15 1.50 7,878 7,878 INTRM1 CASING CIRC P Circ&performed 385 bbls whole mud dilution @ 550 gpm @ 23000 psi-Stood back 1 std DP to 7806' 14:15 16:30 2.25 7,806 7,806 INTRM1 CASING OWFF P Monitor well on TT to confirm well bore breathing. Flow slowed down from 28.56 bph to 1.02 bph. Table Top Man Down Drill 16:30 20:30 4.00 7,806 7,806 INTRM1 CASING OWFF T Monitor well at cellar to confirm well bore breathing. Flow slowed down from 1.78 bph to.23 bph. Confer with town&line up to trip tank. Observe for 30 min circulating across the top with no increase. 20:30 00:00 3.50 7,806 6,558 INTRM1 CASING TRIP P PJSM;TOH w/MPD from 7806'-6558'MD with 150 psi, 800 fph. Worked through tight spots at 7031'-6918 10-25K over,work up& down to clean up. Pulled 30K over @ 6558' MD,4 times&decide to CBU. 38/04/2015 Cont. Circ btms up-POOH f/6577'to 5900' Stripping w/MPD-Tight @ 5900'-Circ btms up-Cont. POOH f/5916' to 4873'stripping w/MPD-Tight @ 4873;-RIH to 4936'-Circ btms up-Cont. POOH f/4873'to 4684'stripping w/MPD-Tight spots f/4873'to 4684'-RIH to 4873'-Back ream out f/4873'to 3644'-Hole took fluid @ 3644'(lost 48 bbls)reduce pump rate. BROOH to 2961'MD. CBU and pump weighted/nut plug sweep. OWFF. Pull MPD bearing and set trip nipple. POOH to 2887'MD. Hole swabbing. Pump out of hole to 2601' MD. Page 19 of 39 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 6,665 6,577 INTRM1 CASING CIRC T Cont. circ btms up@ 6665'-Stgae pump up to 550 gpm @ 2100 psi w/ 120 rpm w/6 k torque-ECD- 11.28 ppg Pull&std back 1 std to 6577' 01:30 03:00 1.50 6,577 5,900 INTRM1 CASING TRIP P POOH f/6577'to 5900'Stripping w/ MPD holding 150 psi-reduec pressure to 100 psi-Pulled tight @ 5900'-worked pipe to 40 k over pull 3 X-unable to pass 03:00 03:45 0.75 5,900 5,900 INTRM1 CASING CIRC T Circ btms up @ 520 gpm @ 1780 psi w/120 rpm's w/6 k torque-ECD- 11.36 ppg-Hole unloaded on btms up w/increase in cuttings-Lost 15 k up wt. after circ hole clean 03:45 05:30 1.75 5,900 4,873 INTRM1 CASING TRIP P Cont. POOH f/5900'to 4873'- stripping w/MPD holding 100 psi- Pulled tight @ 4873'-30 k over 05:30 07:15 1.75 4,936 4,873 INTRM1 CASING CIRC T PU 1 std DP&RIH to 4936'-Circ btms up @500 w/1500 psi @ 80 rpm's w/5 k torque-ECD- 11.41 ppg(Ghost reamer inside casing) Std back 1 std DP to 4873' 07:15 08:00 0.75 4,873 4,873 INTRM1 CASING TRIP P Cont. POOH f/4873'to 4664'- working tight spots-pulling 30 k over -decided to break ream OOF-RIH to 4873' 08:00 10:45 2.75 4,873 3,644 INTRM1 CASING BKRM P BROOH f/4873'to 3644'@ 550 gpm w/1450 psi- 120 rpm's w/5 k torque -ECD-11.29 ppg Calc hole fill 5.4 bbls-Actual 8.7 bbls 10:45 12:00 1.25 3,739 3,644 INTRM1 CASING CIRC T Lost 50%flow out @ 3644'-Lost 36 bbls-Reduce pump rate to 84 gpm -Wash down to 3739'-staging pump to 425 gpm-cont.staging pump up to 500 gpm-Loss rate 20 bbls/hr- reduce pump to 450 pgm-ECD- 11.6 ppg-Rack back 1 std to 3644'- Lost 48 bbls. Loss rate 26 bbl/hr. 12:00 13:00 1.00 3,644 3,550 INTRM1 CASING BKRM P BROOH f/3644' MD t/3550' MD.450 gpm w/1100 psi. 25 bph lossw rate. Slow pump rate t/300 gpm w/550 psi.80 rpm 5-6K tq. 13:00 15:45 2.75 3,550 2,961 INTRM1 CASING BKRM P BROOH f/3550'MD t/2961'MD. 300 gpm w/550 psi. 80 rpm 5-6K tq. 15:45 17:45 2.00 2,961 2,961 INTRM1 CASING CIRC P CBU.480 gpm, 1100 psi, 110 rpm, 4-5k tq. Pump 20 bbl 10.9 ppg weighted/nut plug sweep. 17:45 19:45 2.00 2,961 2,961 INTRM1 CASING OWFF T OWFF on trip tank.Well breathing. Initial flow back 47 bph diminishing to 3 bph. 19:45 22:45 3.00 2,961 2,961 INTRM1 CASING OWFF T OWFF monitoring in cellar.When static monitor for 30 mins. Sim-ops/ Pull MPD bearing and install trip nipple. _._ Page 20 of 39 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 2,961 2,887 INTRM1 CASING PMPO P Attempt to POOH on elevators f/2961'MD t/2887' MD. Hole swabbing. Pump out of hole f/2887' MD t/2601' MD. PU 100K SO 95K. Losses to hole for tour=48 bbls. 38/05/2015 Change saver sub to 4 1/2" IF for 5" DP-Attempt to POOH on elevators(well swabbing) BROOH to 1670'- Circ btms up @ 600 gpm-Monitor-Pump out to 1574'Monitor well-POOH on elevators to 531'-Monitor well -LD BHA-Flush stack-Change top rams&TD saver sub Test upper pipe rams and annular preventer w/7 5/8"test jt. Rig up to run 7 5/8"csg. PU 7 5/8"csg to 1278' MD 00:00 02:30 2.50 2,887 2,887 INTRM1 CASING RURD P Change TD saver sub f/XT-39 to 4 1/2" IF&grabbers&bell guide for 5" _ DP- 02:30 06:00 3.50 2,887 1,670 INTRM1 CASING BKRM P Attempt to Pump out of hole-No circ-Decission made to BROOH f/ 2887'to 1670' ©2 bbls/min @ 110 psi @ 600 ft/hr w/40 rpm's w/2/3 k torque Calc. fill 7.4 bbls-Actual 10.5 bbls LD ghoast reamer 06:00 07:00 1.00 1,670 1,670 INTRM1 CASING CIRC T Circ btms up-Stage pump up to 600 gpm-shakers clean-no losses- _ gained 2 bbls. 07:00 07:30 0.50 1,670 1,670 INTRM1 CASING OWFF T Monitor well-breathing 07:30 07:45 0.25 1,670 1,574 INTRM1 CASING PMPO P Pump out of hole f/1670'to 1574'@ 3 bbls/min @ 100 psi PU wt 64 Calc fill- 1.48 bbls Actual-.7 bbls 07:45 08:15 0.50 1,574 1,574 INTRMI CASING OWFF T Monitor well-well breathing-Slightly 08:15 09:30 1.25 1,574 761 INTRM1 CASING TRIP P POOH on elevators f/1574'to 731' Calc. fill 6.6 bbls Actual 5.4 bbls 09:30 10:00 0.50 731 731 INTRM1 CASING OWFF P Monitor well @ HWDP(static) SIMOPS held PJSM on LD BHA 10:00 11:15 1.25 731 80 INTRM1 CASING BHAH P Pull&std back HWDP-LD NM flex DC's to 80' 11:15 12:00 0.75 80 80 INTRM1 CASING BHAH P Remove RA sources f/MWD tool 12:00 12:45 0.75 80 0 INTRM1 CASING BHAH P LD remaining BHA tools-float sub- TeleScope-EcoScope w/stab- Xceed w/stab&bit- Note: Top stab was packed w/clay- Stab on Xceed&bit had clay packed on one side Pictures sent to S drive 12:45 13:45 1.00 0 0 INTRMI CASING WWWH P MU stack washer& Flush stack w/ full std 5" DP-LD stack washer-std back DP 13:45 14:15 0.50 0 0 INTRM1 CASING RURD P Rig up and pull wear bushing 14:15 17:00 2.75 0 0 INTRMI CASING BOPE P Rig down scaffold in cellar.Change upper VBR's to 7 5/8"rams. Sim-ops/Change out saver sub from 4 1/2 IF to XT-39. 17:00 18:45 1.75 0 0 INTRMI CASING BOPE P Rig up test equip. Test annular to 250/2500 psi and upper pipe rams to 250/3500 psi for 5 mins each using 7 5/8"test jt. Rig down test equip. Page 21 of 39 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 21:15 2.50 0 0 INTRM1 CASING RURD P Pick up and rig up casing running tools. 21:15 00:00 2.75 0 1,278 INTRM1 CASING PUTB P Make up float equip and baffle collar. PU 7 5/8"29.7# L-80 Hyd 563 casing to 1278' MD. PU 65K SO 63K 08/06/2015 PU 7 5/8"csg to 2880'MD. Circ csg volume. PU 7 5/8"csg to 4521 MD. Circ and cond mud. PU 7 5/8"csg to 5338' MD. Circ. 30%loss rate. PU 7 5/8"csg to 6185' MD. Circ. 50%loss rate. PU 7 5/8"csg to 6621' MD.Work through tight hole f/6621'MD t/6731' MD. PU 7 5/8"csg to 7838'MD. Make up hanger and landing jt. Land casing @7868.Attempt to establish circ. Stage up to 2.5 bpm. Losing 35 to 130 bph.Rig up for first stage cement job. Test lines and pump spacers as per program. 00:00 04:00 4.00 1,278 2,880 INTRM1 CASING PUTB P PJSM. Crew change. Continue to run 7.625"casing from 1287'to 2880' MD. P/U 95K, S/0 90K. Using the volant tool.2 to 2.5 mins per joint. 04:00 05:00 1.00 2,880 2,880 INTRM1 CASING CIRC P CBU at shoe. Stage pump on in'% barrel increments up to 5 bpm. 200 psi, no losses. 05:00 08:30 3.50 2,880 4,521 INTRM1 CASING PUTB P Continue to run casing @ 800'to 1000'/hr. From 2880'to 4521'MD. Joint 110. Half returns on the last 10 joints. Stop. 08:30 10:45 2.25 4,521 4,521 INTRM1 CASING CIRC T CBU @ 4521.Joint#110. Stage pumps up to 3.5 bpm. Began with 30%losses, ended with 10%losses. Circulate and condition mud.10.7 ppg mud on bottoms up. 10:45 13:00 2.25 4,521 5,338 INTRM1 CASING PUTB P Run 7.625"29.7#L-80 HYD 563 Dopelesss casing with Doyon Volant tool. From 4521'to 5338' MD. P/U wt=148k, S/O wt=122k, Calc. 40.8 Actual 44.4 bbls. 13:00 13:30 0.50 5,338 5,338 INTRM1 CASING CIRC T Circ @ 5338' MD. 2 bpm,240 psi. 36 bph loss rate. 13:30 15:15 1.75 5,338 6,185 INTRM1 CASING PUTB P Run 7.625"29.7#L-80 HYD 563 Dopelesss casing with Doyon Volant tool. From 5338'to 6185' MD. 15:15 15:45 0.50 6,185 6,185 INTRM1 CASING CIRC T Circ @ 6185'MD.2.5 bpm, 300 psi. 75 bph loss rate. 15:45 16:45 1.00 6,185 6,621 INTRM1 CASING PUTB P Run 7.625"29.7#L-80 HYD 563 Dopelesss casing with Doyon Volant tool. From 6185'to 6621'MD. 16:45 18:45 2.00 6,621 6,731 INTRM1 CASING PUTB T Work through tight hole f/6621'MD t/6731'MD. Pumping @ 1 bpm w/300 psi setting down 25 to 45K. PU 200K SO 145K 18:45 20:45 2.00 6,731 7,838 INTRMI CASING PUTB P Run 7.625"29.7#L-80 HYD 563 Dopelesss casing with Doyon Volant tool. From 6715'to 7838' MD. 20:45 21:00 0.25 7,838 7,868 INTRMI CASING PUTB P Make up hanger and landing jt. Land casing on depth @7868'MD. PU 225K SO 140K 21:00 23:00 2.00 7,868 7,868 INTRMI CEMEN"CIRC P Circ and cond mud. Stage pumps up to 2.5 bpm, 375 psi. Loss rate varied f/40 bph to 130 bph. 23:00 23:15 0.25 7,868 7,868 INTRM1 CEMEN-RURD P Install cement hose, rig up for first stage cement job. Page 22 of 39 Time Logs . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 7,868 7,868 INTRMI CEMEN-CMNTP Pump 5 bbls CW-100. Test lines to 400/4000 psi. Pump 40 bbls CW-100 followed by 45 bbls 12 ppg MP2.4.5 bpm, 500 psi. 272 bbls lost to hole for tour. 38/07/2015 Continue pumping first stage cmt job as per program. Check floats. Open stage collar.Attempt to establish circ. Pump second stage program as per program. Close stage collar.Well breathing back. Shut in well and monitor pressures to hold cement in place Lay down landing jt. Set and test packoff. Freeze protect OA. Install mouse hole. 00:00 02:00 2.00 7,868 7,868 INTRM1 CEMEN-CMNT P Load btm plug-Batch up cmt. - Pumped 79 bbls 15.8 ppg Class G w/GASBLOK slurry @ 4.5 bbls/min @660 to 198 psi-Shutdown- Loaded top plug-kicked out w/10 bbls/fresh water-switched over to rig pumps&displaced cmt w/10.6 ppg mud @ 5 bbls/min @ 200 psi-slow pump&bumped plug w/1251 psi- Bleed off&checked floats-floats held-CIP 0145 hrs.-Lost 332 bbls during cmt job. -Recipcated pipe to just before bumping plug 02:00 03:00 1.00 7,868 7,868 INTRM1 CEMEN-CIRC P Pressure up and open stage collar w/3300 psi. Break circ and stage up to 2 bpm, 300 psi. Lost 45 bbls to hole. 03:00 05:15 2.25 7,868 7,868 INTRM1 CEMEN-CMNT P Pump 45 bbls CW-100 @ 4 bpm, 300 psi. Batch mix and pump 45 bbls 12 ppg MD2 @ 4.3 bpm, 400 psi. Batch up cmt.-Pumped 32 bbls 15.8 ppg Class G w/GASBLOK slurry @ 4.5 bbls/min @ 340 to 205 psi-Shut down-Loaded closing plug-kicked out w/10 bbls/fresh water-switched over to rig pumps& displaced cmt w/10.6 ppg mud @ 6 bbls/min @ 500 psi-slow pump& land plug w/400 psi. Pressure up to 1600 psi and hold for 5 mins to close stage collar. Bleed off&confirm stage collar closure. CIP 0500 hrs. - Lost 90 bbls during cmt job. 05:15 12:00 6.75 7,868 7,868 INTRMI CEMEN-OWFF T Slight flow from casing @.099 bph diminishing to.0626 bph in 90 mins. Flow from annulus @ 78 bph. Shut annular preventer to hold cement in place and monitor well pressures. 50 psi on annulus. 12:00 14:15 2.25 7,868 7,868 INTRM1 CEMEN-OWFF T Con't to monitor shut in annulus pressure. Gained 14.5 bbls when bleeding off 25 psi. 14:15 14:45 0.50 7,868 7,868 INTRM1 CEMEN-OWFF T Bleed off and monitor flow back. Flowed back 8.15 bbls in 24 min's. 20 bph flow rate. 14:45 15:30 0.75 7,868 7,868 INTRMI CEMEN-OWFF T Shut in well for 20 mins. 0 psi. Bleed off to trip tank 3.9 bbls @ 15 bph flow rate. Open annular preventer Page 23 of 39 11110 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 17,868 0 INTRM1 CEMEN.RURD P Drain BOPE. Lay down landing jt. 16:00 17:00 1.00 0 0 INTRM1 CEMEN-WWSP P RU and set 7 5/8"packoff. 17:00 18:30 1.50 0 0 INTRM1 CEMEN-WWSP P RILDS. Test packoff to 5000 psi/10 min. RD tools and equip. 18:30 23:00 4.50 0 0 INTRM1 CEMEN-FRZP P Shut in well for 20 mins. 0 psi. Bleed off to trip tank 3.9 bbls @ 15 bph flow rate. Open annular preventer 23:00 23:30 0.50 0 0 INTRM1 CEMEN-FRZP P Blow down and rig down LRS and circ equip in cellar. 23:301 00:00 0.50 0 0 INTRM1 CEMEN-RURD P Rig up and install mouse hole. 08/08/2015 LD 5" HWDP&DP f/derrick-Change tools for 4"DP-PU&Std. back 46 stds.4"DP-Change top pipe rams f/7 5/8"to 3 1/2"x 6"VBR-RU&Test BOPE. Rig down test equip. Set wear ring. MOB BHA to rig floor. Make up BHA#4. 00:00 03:00 3.00 0 0 INTRM1 CEMEN PULD P LD 17 jts 5" HWDP,jars&90 jts 5" DP f/derrick 03:00 03:30 0.50 0 0 INTRM1 CEMEN-RURDP Change elevators, Iron roughneck grabbers-Unload 5"DP f/pipe shed 03:30 08:30 5.00 0 0 INTRMI CEMEN PULD P PU&stand back 138 jts(46 stds)4" DP f/pipe shed via mouse hole 08:30 09:00 0.50 0 0 INTRM1 CEMEN-RURDP LD mouse hole&clean&clear rig floor 09:00 09:15 0.25 0 0 INTRM1 CEMEN SFTY P PJSM-on changing rams 09:15 11:30 2.25 0 0 INTRM1 CEMEN BOPE P Changed upper pipe rams f/7 5/8" solid body to 3 1/2"x 6"VBR-Set trip nipple 11:30 13:30 2.00 0 0 INTRMI WHDBO RURD P RU to test BOPE 13:30 20:00 6.50 0 0 INTRM1 WHDBO BOPE P Test BOPE w/4"test joint to 250/3500 psi for 5 min each.Test#1: Top pipe rams, CV 1,12,13, 14& manual kill valve. Test#2: Upper IBOP, HCR kill, CV 9, & 11. Test#3: Lower IBOP, CV 5,8& 10. Test#4: Dart„ CV 4,6&7. Test#5: FOSV valve&CV 2. Test#6: HCR choke. Test#7: Manual choke valve&HCR Kill.Test#8:Annular preventer tested to 250/2500 psi. Test#9: Lower pipe rams.Test#10, Blind rams, CV 3. Test#11 Upper pipe rams with 4'/z"test joint,Test#12. Lower pipe rams with 4'/2'test joint. Test#13 Annular with 4'W test joint. Test#14 Upper pipe rams with 3'/z' test joint. Test#15. Lower pipe rams with 3'/2"test joint.Test#16.Annular with 3%"test joint.Accumulator test: system pressure=3000 psi,After closing= 1850 psi,200 psi attained after 50 sec,full pressure attained after 178 sec, Five bottle nitrogen avg=2100 psi. The BOP test witness was waived by AOGCC Rep Johnnie Hill. Page 24 of 39 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:00 21:45 1.75 0 0 INTRM1 WHDBO RURD P RD test equip. Set wear ring. Blow down choke and kill lines. Rig down floor valves. Install split rotary bushings 21:45 23:00 1.25 0 0 INTRM1 CEMEN-BHAH P Mobilize BHA tools to rig floor. Rig up tools and equip for BHA. Sim-Ops/Remove and cap MPD hose from flow line. 23:00 00:00 1.00 0 0 INTRM1 CEMEN-BHAH P Make up 6 3/4"rotary steerable BHA #4 as per SLB reps. OA=560 psi 08/09/2015 Finish MU BHA-Slip&cut drill line-RIH w/BHA -picking up 4" DP f/shed to 1557'-Shallow pulse test MWD-Cont. RIH picking up 4"DP to 4512'-Begin MAD pass @ 4512'to 5626' MD. Test csg 3500 psi/10 min. Drill out stage collar. Cont to MAD pass f/5645 t/6897' MD. 00:00 01:00 1.00 23 158 INTRM1 CEMEN-BHAH P PJSM-Cont. MU BHA#4- MicroScope-ImPulse-SonicScope -adnVision to 158' 01:00 01:30 0.50 158 158 INTRMI CEMEN BHAH P PJSM-Load RA sources in MWD 01:30 03:00 1.50 158 444 INTRM1 CEMEN BHAH P Cont. MU BHA-Float sub-NM flex DC-Stab-NM flex DC-Float sub- NM flex DC-XO-3 jts.4' HWDP- Jars-2 jts.4' HWDP to 443.73' 03:00 04:30 1.50 444 444 INTRMI CEMEN'SLPC P PJSM-Slip&cut 70'drill line- Service TD&draworks 04:30 06:00 1.50 444 1,557 INTRM1 CEMEN-PULD P PJSM-RIH w/BHA#4 f/444'to 1557'-picking up 4"DP f/shed 06:00 06:45 0.75 1,557 1,557 INTRMI CEMEN DHEQ P Shallow pulse test MWD @ 200 gpm @ 1150 psi w/30 rpm's-down link to power dirve 06:45 09:30 2.75 1,557 4,512 INTRM1 CEMEN-PULD P Cont. RIH w/BHA f/1557'to 4512'- picking up 4" DP f/shed 09:30 09:45 0.25 4,512 4,512 INTRM1 CEMEN-DHEQ P Fill pipe&stage pump to 200 gpm @ 1400 psi-send down link 09:45 12:00 2.25 4,512 5,077 INTRM1 CEMEN DLOG T Begin MAD pass w/SonicScope to evaulate cement job on 7 5/8"csg f/ 4512'to 5077'-@ 400 to 450 ft/hr pumping 210 gpm OA=700 psi. 12:00 15:00 3.00 5,077 5,626 INTRMI CEMEN-DLOG T Cont.w/MAD pass w/SonicScope f/ 5077' t/5626' MD. @ 400 to 450 fph pumping 205 gpm w/1425 psi. 15:00 16:15 1.25 5,626 5,626 INTRM1 CEMEN PRTS P Lay down single DP. Rig up to test csg.Test csg 3500 psi/10 min. Charted. Rig down test equip. 16:15 18:00 1.75 5,626 5,645 INTRMI CEMEN DRLG P PU single DP. Clean out cmt f/5626' MD t/5640' MD.Drill out stage collar t/5645' MD. 80 rpm, 200 gpm, 1500 psi, 5-7k tq,WOB 5-13k 18:00 00:00 6.00 5,645 6,897 INTRM1 CEMEN-DLOG T MAD pass f/5645' t/6897' MD. 210 gpm, 1500 psi,400-450 fph. 08/10/2015 Cont. MAD pass to 7740'-tagged baffle collar-Circ btms up-RU&test csg to 3500 psi-Pull trip nipple& install MPD bearing-Test MPD-Pull MPD bearing&Reinstall trip nipple-Drill shoe track and rat hole. Drill 20' new hole. CBU. Perform FIT. Displace to 10.5 ppg Flo Thru mud. Monitor well. Prep to install RCD bearing assy. Page 25 of 39 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:45 3.75 6,897 7,730 INTRM1 CEMEN-DLOG T Cont.w/MAD pass w/SonicScope to evaluate 7 5/8"csg cmt job f/ 6897'to 7740'w/205 gpm @ 1600 psi @ 450 ft/hr. -Tagged baffle collar @ 7740'-Rack back std to 7730' 03:45 05:30 1.75 7,730 7,730 INTRM1 CEMEN-CIRC P Circ btms up @ 7730'-205 gpm @ 1600 psi w/49 rpm's 05:30 07:00 1.50 7,730 7,730 INTRM1 CEMEN PRTS P RU&test 7 5/8"csg to 3500 psi for 30 mins. (Good test)RD 07:00 12:00 5.00 7,730 7,730 INTRM1 CEMEN MPDA P PJSM-Pulled trip nipple-Installed MPD bearing-Test MPD-Pulled MPD bearing&reinstall trip nipple 12:00 17:45 5.75 7,730 7,878 INTRM1 CEMEN DRLG P PJSM-Drilled top plug& baffle collar @ 7740'to 7742'-Drilled cmt f/7742'to 7781'-Drilled btm plug& float collar f/7781'to 7783'-Drilled cmt f/7783'to 7866'-Drilled float shoe f/7866'to 7868'-Cleaned out rat hole to 7878'@ 200 gpm @ 1600 psi w/80 rpm's w/8 k torque SPR's @ 7868'MD 6260'TVD w/ 10.5 ppg @ 15:00 hrs #1 20/30 SPM @ 520/710 psi #2 20/30 SPM @ 500/720 psi 17:45 18:15 0.50 7,878 7,898 INTRM1 CEMEN-DDRL P Drilled 6 3/4"hole f/7878'to 7898' MD 6272'TVD-w/240 gpm©2050 psi w/80 rpm's w/10 k torque ADT-.5 hrs. 18:15 19:30 1.25 7,898 7,898 INTRM1 CEMEN-CIRCP Circ btms up 19:30 20:15 0.75 7,898 7,868 INTRM1 CEMEN-FIT P RU&Perform FIT to 14.5 ppg EMW w/10.5 ppg mud @ 6261'TVD w/ 1310 psi-Bled off&RD 20:15 21:45 1.50 7,868 7,898 PROD1 DRILL DISP P PU stand of DP. Displace well from 10.5 ppg LSND mud to 10.5 ppg Flo Thru mud.225 gpm,2000 psi, 80 rpm, 8.5k tq, 20% FO. 21:45 23:45 2.00 7,898 7,898 PROD1 DRILL OWFF P Obtain SPR's. OWFF. Slight flow.79 bph diminishing to static. SPR's @ 7883'MD 6266'TVD w/ 10.5 ppg @21:54 hrs #1 20/30 SPM @ 430/660 psi #2 20/30 SPM @ 420/680 psi 23:45 00:00 0.25 7,898 7,816 PROD1 DRILL MPDA P Rack back one stand of DP in preparation to install RCD bearing assy. OA=560 psi 08/11/2015 Install RCD bearing assy. Simulate connection ramp up/ramp down practices.Wash and ream to 7898'MD. DDrlg 6 3/4"production hole section w/MPD to 7933'MD, Trouble shoot power drive comm problem. Monitor well. Shut in MPD choke and monitor pressure. Built to 250 psi/15 min. CBU.Trouble shoot power drive comm problem. DDrlg 6 3/4"production hole section w/MPD to 8767' MD 00:00 01:15 1.25 7,816 7,804 PROD1 DRILL MPDA P Remove trip nipple. Install RCD bearing assy. Connect 4"flow line. Page 26 of 39 ��N� ��� Time � - � ���� ' ^/ , . ���� Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 02:00 0.75 7,804 7,804 PROD1 DRILL MPDA P Function tesMPD ramp up/down schedules 02:00 02:30 0.50 7,804 7,898 PROD1 DRILL REAM P Wash and ream f/7804MD t/7898 MD. 1'fill on bottom.240 gpm, 2100 psi, 80 rpm, 9k tq. 02:30 03:30 1.00 7,898 7,933 PROD1 DRILL DDRL P Drilled O3/4'' hole from 78SO'to7Q33' MD 6272' TVD ADT .36 hrs ECD 11.70 ppg Footage 35' WOB 7-14 k RPM 80 GPM 240 @ 2350 psi String wt,PU145 SO 92 ROT 117 Torque on/off bUn,10Sk FO 27% Max gas 133 units Total bit hrs. 1.25 hrs Total jar hrs. 75.03 hrs. 03:30 05:15 1.75 7,933 7,933 PROD1 DRILL CIRC T Lost real time communication w/Power Drive. Trouble shoot Power Drive communication problem, 05:15 06:45 1.50 7,933 7,933 PROD1 DRILL OWFF T Decision made toPOOH. OVVFF@ trip tank. Slight flow 1.5 bph increasing to 6 bph. Close MPD choke. Monitor pressure build up. Pressure increased to 250 psi/15 mins. 06:45 07:45 1.00 7,933 7,933 PROD1 DRILL CIRC T CBU. 240 gpm,2200 psi,40 rpm, ECD 11.7 ppg, 1733 units max gas on BU. 07:45 09:30 1.75 7,933 7.933 PROD1 DRILL CIRC T Trouble shoot Power Drive communication.Attempt to activate PD signal and down link commands. 09:30 12:00 2.50 7,933 8,044 PROD1 DRILL DDRL P Drilled O3/4'' hole from 7838'toOO44' MD 6326'TVD ADT 1.84hre ECD 11.81 ppg Footage 111' WOB 7-14 k RPM 120 GPM 250 @ 2475 psi String vt,PU143 SO 90 ROT 114 Torque on/off btm.- 10/8 k FO 22% Max gas 113 units Total bit hrs.2.89 hrs Total jar hrs. 76.67 hrs. SPR's@8O11' MDO315'TVD w/ 1O.5ppg @11:30hre #1 20/30 SPM @ 550/800 psi #2 20/30 SPM @ 500/795 psi 12:00 18:00 6.00 8.044 8,320 PROD1 DRILL DDRL P Drilled O3/4'' hole from 8O44'toO52O' MD 6380'TVD ADT 3.45 hrs ECD 11.74 ppg Footage 276' WOB 5-10 k RPM 120 GPM 250 @ 2400 psi String wt. PU 156 SO 85 ROT 110 Torque on/off btm.- 10/7 k FO 27% Max gas 120 units Total bit hrs. 6.34 hrs Total jar hrs. 80.12 hrs. Page 27 of 39 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 8,320 8,767 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 8320'to 8767' MD 6354'TVD ADT-4.18 hrs ECD- 11.93 ppg Footage-447' WOB 15-20 k RPM 140 GPM 250 @ 2550 psi String wt.-PU 160 SO 85 ROT 112 Torque on/off btm.-10/8 k FO 39% Max gas 125 units Total bit hrs. 10.52 hrs Total jar hrs. 84.30 hrs. SPR's @ 8577' MD 6380'TVD w/ 10.5 ppg @21:30 hrs #1 20/30 SPM @ 535/783 psi #2 20/30 SPM @ 555/900 psi OA=600 psi X8/12/2015 DDrlg 6 3/4"production hole section w/MPD from 8767' MD to 10592'MD 00:00 06:00 6.00 8,767 9,301 PROD1 DRILL DDRL P Drilled 6 3/4" hole from 8767'to 9301' MD 6327'TVD ADT-4.41 hrs ECD- 11.81 ppg Footage-534' WOB 15-20 k RPM 140 GPM 250 @ 2650 psi String wt.-PU 160 SO 75 ROT 110 Torque on/off btm.-11/9 k FO 27% Max gas 113 units Total bit hrs. 14.93 hrs Total jar hrs. 88.71 hrs. SPR's @ 9050'MD 6327'TVD w/ 10.5+ppg @ 03:00 hrs #1 20/30 SPM @ 475/755 psi #2 20/30 SPM @ 525/820 psi 06:00 12:00 6.00 9,301 9,618 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 9301'to 9618' MD 6305'TVD ADT-2.43 hrs ECD- 11.78 ppg Footage-317' WOB 10-15 k RPM 140 GPM 250 @ 2700 psi String wt.-PU 162 SO 76 ROT 112 Torque on/off btm.- 12/9 k FO 27% Max gas 94 units Total bit hrs. 17.36 hrs Total jar hrs. 91.14 hrs. SPR's @ 9618'MD 6305'TVD w/ 10.5+ppg @ 11:30 hrs #1 20/30 SPM @ 550/790 psi #2 20/30 SPM @ 540/860 psi OA=590 psi Page 28 of 39 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 9,618 10,164 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 9618'to 10164'MD 6304'TVD ADT-3.51 hrs ECD- 11.94 ppg Footage-546' WOB 10 k RPM 140 GPM 250 @ 2600 psi String wt.-PU 160 SO 75 ROT 105 Torque on/off btm.- 11.5/9 k FO 29% Max gas 792 units Total bit hrs. 20.87 hrs Total jar hrs. 94.65 hrs. 18:00 00:00 6.00 10,164 10,592 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 10164' to10592'MD 6315'TVD ADT-3.65 hrs ECD- 12.01 ppg Footage-428' WOB 10 k RPM 140 GPM 250 @ 2600 psi String wt.-PU 162 SO 74 ROT 110 Torque on/off btm.-12/10 k FO 27% Max gas 1030 units Total bit hrs.24.52 hrs Total jar hrs. 98.30 hrs. SPR's @ 10279'MD 6307'TVD w/ 10.5+ppg @ 19:50 hrs #1 20/30 SPM @ 588/834 psi #2 20/30 SPM @ 550/860 psi OA=660 psi 38/13/2015 DDrlg 6 3/4"production hole section w/MPD to 10753'MD. Change out swivel packing. DDrIg 6 3/4" production hole section w/MPD to 11389' MD CBU for geologic evaluation after crossing fault at 11348'MD. DDrlg 6 3/4"production hole section w/MPD to 11810'MD 00:00 01:45 1.75 10,592 10,753 PROD1 DRILL DDRL P Drilled 6 3/4" hole from 10592' to10753' MD 6312'TVD ADT-1.29 hrs ECD-12.08 ppg Footage-161' WOB 8-12 k RPM 140 GPM 250 @ 2650 psi String wt.-PU 171 SO 74 ROT 110 Torque on/off btm.-12/10 k FO 27% Max gas 949 units Total bit hrs. 25.81 hrs Total jar hrs. 99.59 hrs. 01:45 02:45 1.00 10,753 10,753 PROD1 DRILL RGRP T Swivel packing leaking, Stand back 1 stand to 10662'MD, change out swivel packing and test. Ran back in the hole one stand. Page 29 of 39 Time Logs • • Date From To Dur ` ' S. Depth E. Depth Phase Code Subcode T =Comment 02:45 06:00 3.25 10,753 11,039 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 10753' to11039'MD 6315'TVD ADT-2.31 hrs ECD- 12.01 ppg Footage-286' WOB 8-10 k RPM 140 GPM 250 @ 2600 psi String wt.-PU 166 SO 74 ROT 110 Torque on/off btm.-13/12 k FO 28% Max gas 712 units Total bit hrs. 28.12 hrs Total jar hrs. 101.90 hrs. SPR's @ 10847'MD 6312'TVD w/ 10.6 ppg @03:30 hrs #1 20/30 SPM @ 550/860 psi #2 20/30 SPM @ 560/865 psi 06:00 11:15 5.25 11,039 11,389 PROD1 DRILL DDRL P Drilled 6 3/4" hole from 11039' to11389' MD 6316'TVD ADT-4.09 hrs ECD-12.11 ppg Footage-350' WOB 5-10 k RPM 140 GPM 250 @ 2700 psi String wt.-PU 175 SO 72 ROT 110 Torque on/off btm.-13/11 k FO 28% Max gas 1120 units Total bit hrs. 32.21 hrs Total jar hrs. 105.99 hrs. SPR's @ 11321'MD 6312'TVD w/ 10.6 ppg @ 10:30 hrs #1 20/30 SPM @ 600/860 psi #2 20/30 SPM @ 600/900 psi 11:15 12:45 1.50 11,389 11,389 PROD1 DRILL CIRC P Drilled into fault @ 11348' MD. After LWD tools crossed the fault, CBU for Geo to catch samples to confirm plan forward. Pump @ 250 gpm= 2700 psi, Rot @ 140 rpm's. 12:45 18:00 5.25 11,389 11,742 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 11039' to11742' MD 6284'TVD ADT-3.72 hrs ECD- 12.07 ppg Footage-703' WOB 7-10 k RPM 140 GPM 247 @ 2600 psi String wt.-PU 175 SO 64 ROT 110 Torque on/off btm.- 12-13/11 k FO 29% Max gas 716 units Total bit hrs. 35.93 hrs Total jar hrs. 109.71 hrs. Page 30 of 39 Time Logs 1110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 11,742 11,810 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 11742' to11810' MD 6284'TVD ADT-5.10 hrs ECD- 12.05 ppg Footage-68' WOB 20 k RPM 120 GPM 250 @ 2675 psi String wt.-PU 175 SO 64 ROT 110 Torque on/off btm.-13/11 k FO 22% Max gas 857 units Total bit hrs. 41.03 hrs Total jar hrs. 114.81 hrs. SPR's @ 11808'MD 6285'TVD w/ 10.6 ppg @23:15 hrs #1 20/30 SPM @ 662/915 psi #2 20/30 SPM @ 655/965 psi OA=690 psi 08/14/2015 DDrlg 6 3/4"production hole section w/MPD to 13401'MD. 00:00 06:00 6.00 11,810 12,169 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 11810' to12169'MD 6281'TVD ADT-3.94 hrs ECD- 12.27 ppg Footage-359' WOB 10-15 k RPM 140 GPM 250 @ 2800 psi String wt.-PU 177 SO 65 ROT 106 Torque on/off btm.-13/12 k FO 29% Max gas 783 units Total bit hrs.44.97 hrs Total jar hrs. 118.75 hrs. 06:00 12:00 6.00 12,169 12,549 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 12169' to 12549' MD 6297'TVD ADT-3.98 hrs ECD- 12.17 ppg Footage-380' WOB 10 k RPM 140 GPM 250 @ 2850 psi String wt.-PU 175 SO 65 ROT 105 Torque on/off btm.- 13.5/12 k FO 29% Max gas 1150 units Total bit hrs.48.95 hrs Total jar hrs. 122.73 hrs. SPR's @ 12265'MD 6286'TVD w/ 10.6 ppg @07:30 hrs #1 20/30 SPM©705/990 psi #2 20/30 SPM @ 690/1010 psi OA=620 psi Page 31 of 39 Time Logs . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 12,549 12,991 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 12549' to12991' MD 6295'TVD ADT-3.79 hrs ECD- 12.31 ppg Footage-442' WOB 12-13 k RPM 140 GPM 249 @ 2875 psi String wt.-PU 177 SO 65 ROT 106 Torque on/off btm.-12-14/11.5 k FO 27% Max gas 1193 units Total bit hrs. 52.74 hrs Total jar hrs. 126.52 hrs. 18:00 00:00 6.00 12,991 13,401 PROD1 DRILL DDRL P Drilled 6 3/4" hole from 12991'to 13401' MD 6264'TVD ADT-3.76 hrs ECD- 12.34 ppg Footage-410' WOB 9-11 k RPM 140 GPM 252 @ 2950 psi String wt.-PU 182 SO 56 ROT 108 Torque on/off btm.-1410-14 k FO 29% Max gas 1073 units Total bit hrs. 56.50 hrs Total jar hrs. 130.28 hrs. SPR's @ 13021'MD 6295'TVD w/ 10.6+ppg @ 18:30 hrs #1 20/30 SPM @ 690/988 psi #2 20/30 SPM @ 702/1015 psi OA=650 psi 08/15/2015 DDrlg 6 3/4"production hole section w/MPD to TD @—14390'. CBU. Finger print well. CBU. Repeat finger print procedure. CBU. BROOH to 12,362' MD. Perform exhale test. BROOH to 11,796'MD. 00:00 06:00 6.00 13,401 13,922 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 13401'to 13922' MD 6272'TVD ADT-4.07 hrs ECD- 12.44 ppg Footage-521' WOB 10-12 k RPM 140 GPM 250 @ 2920 psi String wt.-PU 190 SO 0 ROT 112 Torque on/off btm.-15/13 k FO 29% Max gas 1130 units Total bit hrs. 60.57 hrs Total jar hrs. 134.35 hrs. Page 32 of 39 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 11:30 5.50 13,922 14,390 PROD1 DRILL DDRL P Drilled 6 3/4"hole from 13922'to 14390'MD 6281'TVD ADT-3.68 hrs ECD- 12.59 ppg Footage-468' WOB 10-15 k RPM 140 GPM 250 @ 3020 psi String wt.-PU 195 SO 0 ROT 106 Torque on/off btm.- 15/13 k FO 29% Max gas 948 units Total bit hrs. 64.25 hrs Total jar hrs. 138.03 hrs. SPR's @ 14158'MD 6273'TVD w/ 10.6+ppg @9:30 hrs #1 20/30 SPM @ 670/1060 psi #2 20/30 SPM @ 715/1060 psi OA=580 psi 11:30 13:00 1.50 14,390 14,347 PROD1 CASING CIRC P CBU at TD, pump @ 250 gpm=3000 psi, rot 140 rpm's. Stand back one stand DP 13:00 13:30 0.50 14,347 14,347 PROD1 CASING OWFF P Finger print pore pressure per rig engineer w/MPD. Erratic pressures observed. Decision made to continue to circulate. 13:30 14:15 0.75 14,347 14,347 PROD1 CASING CIRC P Continue to circulate, pump @ 250 gpm=3000 psi, rot 140 rpm's. 14:15 14:30 0.25 14,347 14,347 PROD1 CASING OWFF P Finger print pore pressure per rig engineer w/MPD. 11.7 ppg EMW observed. 14:30 15:45 1.25 14,347 14,347 PROD1 CASING CIRC P CBU.250 gpm, 3000 psi, 140 rpm, 13k tq, 28%FO. 15:45 21:30 5.75 14,347 12,362 PROD1 CASING BKRM P BROOH (/14347'MD t/12362'MD. 250 gpm, 3000 psi, 100 rpm. 14k tq, 20%FO. 21:30 22:15 0.75 12,362 12,362 PROD1 CASING OWFF T Improper hole fill observed. Perform exhale test. Confirm well bore breathing. Program new ramp schedule per rig engineer. 22:15 00:00 1.75 12,362 11,796 PROD1 CASING BKRM P BROOH f/12,362' MD t/11,796' MD. 250 gpm, 2800 psi, 1200 rpm. 11k tq, 25% FO. PU 108k. Calc disp=13.5 bbls Act disp=15.74 bbls Function test BOPE. 38/16/2015 BROOH to 7930'MD. Hole packed off Work pipe and attempt to establish circ. Close MPD choke and monitor pressure. 711 psi on choke. Close annular preventer and attempt to establish circ through rig choke. Minimal returns.Strip into 7 5/8"shoe. Consult with drilling engineer. Perform exhale test. Confirm well bore breathing. CBU. Strip into hole to 8014'MD. Ream tight hole to 8108' MD. Strip into hole to 8391' MD. Strip out of hole to 7862' MD. CBU. 00:00 11:00 11.00 11,796 7,930 PROD1 CASING BKRM P BROOH f/11,796 MD t/7,930'MD. 250 gpm, 2800 psi, 120 rpm, 11k tq, 25%FO Page 33 of 39 Time Logs . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 7,930 7,920 PROD1 CASING OTHR T Hole packed off @ 7930'MD. Pull pipe to 7920' MD. Pump 94 bbls mud into formation Work pipe to 7925' MD.Work pipe up to 7920' MD. Close MPD choke to monitor pressure build up. Pressure built to 711 psi. Consult w/drilling engineer. 12:00 14:30 2.50 7,920 7,920 PROD1 CASING CIRC T Close annular preventer. Consult w/drilling engineer.Attempt to CBU using drillers method well control procedure. Minimal returns while circulating. Lost 70 bbls mud while attempting to circ. Decision made to perform exhale test. 14:30 14:45 0.25 7,920 7,857 PROD1 CASING TRIP T Attempt to pull into 7 5/8"shoe 4X. Required 50k over pull for bit to clear shoe. Pull to 7857'MD, 14:45 15:45 1.00 7,857 7,857 PROD1 CASING WAIT T Consult w/rig engineer on plan forward and pressures. 15:45 17:15 1.50 7,857 7,857 PROD1 CASING OWFF T Perform exhale test to confirm well bore breathing. Start pressure=720 psi. Bleed 5 bbls mud to 690 psi. Shut in. Built to 707 psi. Bleed 5 bbls mud to 660 psi. Shut in. Built to 690 psi. Bleed 5 bbls mud to 620 psi. Built to 650 psi. 17:15 19:00 1.75 7,857 7,857 PROD1 CASING CIRC T CBU. 250gpm, 2550 psi,40 rom, 7k tq, 27% FO. Max gas=350 units. 19:00 19:30 0.50 7,857 8,014 PROD1 CASING TRIP T Strip in hole f/7857' MD t/8014' MD holding back pressure with MPD. Hold 330 psi while slacking off and 390 psi while in the slips. Tight hole @8014' MD. 19:30 21:00 1.50 8,014 8,108 PROD1 CASING REAM T Ream f/8014' MD t/8108' MD. 250 gpm,2550 psi, 80 rpm, 8k tq, 27% FO. 21:00 21:45 0.75 8,108 8,391 PROD1 CASING TRIP T Strip in hole f/8108' MD t/8391' MD holding back pressure with MPD. Hold 330 psi while slacking off and 390 psi while in the slips. 21:45 22:45 1.00 8,391 7,862 PROD1 CASING TRIP T Strip out of hole f/8391' MD t/7862' MD holding back pressure with MPD. Hold 430 psi while picking up and 390 psi while in the slips. Required 60k overpull to pull bit into shoe. 22:45 00:00 1.25 7,862 7,862 PROD1 CASING CIRC P CBU.250 gpm,2450 psi,40 rpm, 7k tq, 27% FO. Lost 44 bbls for tour. OA=630 psi 38/17/2015 Circ and prep displacement brine. Lay in 12.1 ppg hi-vis brine pill. Displace well to 12.1 ppg brine. OWFF. Drop 2.25"drift. Pull RCD bearing assy and set trip nipple. POOH. Lay down BHA. Rig up and test annular preventer and choke valve#5. Rig up to pick up 4 1/2"liner. PU 4 1/2"slotted/blank liner to 1935' MD. 00:00 02:00 2.00 7,862 7,862 PROD1 CASING CIRC P Circulate and prep for brine displacement.250 gpm, 2450 psi,40 rpm, 7k tq,27%FO. Page 34 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:45 0.75 7,862 7,862 PROD1 CASING DISP P Pump 53 bbls 12.1 ppg hi-vis brine spacer @ 250 gpm, 2450 psi,26% FO,40 rpm, 6-7k tq. Chase w/12.1 ppg brine and spot at bit. 02:45 03:45 1.00 7,862 7,157 PROD1 CASING DISP P POOH @ 1100 fph laying in 33 bbls 12.1 ppg hi-vis brine spacer f/7862' MD t/7157' MD @ .8 bpm, 100 psi, 40 rpm, 5-6k tq. Hold 400 psi back pressure w/MPD 03:45 07:30 3.75 7,157 7,157 PROD1 CASING DISP P Displace 10.6 ppg Flo Thru mud w/ 12.1 ppg brine. 230 pgm, 25% FO, 40 rpm, 5-6k tq. Circulate and condition brine until uniform 12.1 ppg in/out. FCP=1400 psi. PU 141k SO 90k Rot 130k. 07:30 08:15 0.75 7,157 7,157 PROD1 CASING OWFF P Obtain SPR's. OWFF. Static. SPR's @ 7161'MD 5990'TVD w/ 12.1 ppg @ 07:30 hrs #1 20/30 SPM @ 200/430 psi #2 20/30 SPM @ 200/430 psi 08:15 09:00 0.75 7,157 7,157 PROD1 CASING RURD P Drain BOPE, blow down choke line, _ kill line and top drive. 09:00 10:00 1.00 7,157 7,157 PROD1 CASING MPDA P Pull RCD bearing assy. Install trip nipple. 10:00 10:15 0.25 7,157 7,060 PROD1 CASING TRIP P Drip 2.2"OD rabbit on stand#71. POOH f/7157'MD t/7060' MD. Monitor well 5/min. Static. 10:15 12:00 1.75 7,060 4,133 PROD1 CASING TRIP P POOH on elevators f/7060' MD t/4133'MD. Calc disp=16.2 bbls Act disp=19.89 bbls. 12:00 13:45 1.75 4,133 444 PROD1 CASING TRIP P POOH on elevators f/4133' MD t/444'MD. 13:45 14:15 0.50 444 444 PROD1 CASING OWFF P OWFF. Slight loss. Sim-ops/PJSM on removing nuclear sources and laying down BHA. 14:15 16:15 2.00 444 0 PROD1 CASING BHAH P Lay down BHA as per SLB. Calc disp for trip=44.64 bbls.Act disp for trip=53.91 bbls. 16:15 17:00 0.75 0 0 PROD1 CASING BHAH P Clean and clear rig floor 17:00 18:30 1.50 0 0 COMPZ CASING BOPE P Rig up to test BOPE 18:30 19:15 0.75 0 0 COMPZ CASING BOPE P Test annular preventer and choke valve#5 to 250/3500 psi 5 min each w/4"test jt. 19:15 19:45 0.50 0 0 COMPZ CASING BOPE P Rig down test equipment. 19:45 21:00 1.25 0 0 COMPZ CASING RURD P Mobilize casing equipment to rig floor. Rig up to run liner. 21:00 00:00 3.00 0 1,935 COMPZ CASING PUTB P PU 4 1/2", L-80, 11.6#IBTM slotted/blank liner to 1935'MD. Calc disp=8.1 bbls Act disp=6.46 bbls 38/18/2015 PU 4 1/2"liner f/ 1935'-6673'. MU liner top hanger/packer.TIH Miner on DP 6673'-7840'MD. TIH w/liner on DP to-14380'MD,working through tight hole f/9620'-10141' MD. Circ one DP volume. Set hanger and packer. Release from liner. Test liner top packer to 3000 psi. for 5 min. Circulate to get 12.0 ppg brine in/out. Spot corrosion inhibitor. Monitor well. Slip&cut drill line.TOH f/7691'-6973'MD. Page 35 of 39 Time Logs 41111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:15 3.25 1,935 6,594 COMPZ CASING PUTB P PJSM, PU 4 1/2", L-80, 11.6#, IBTM slotted/blank liner f/1935-6594' MD. Calculated displacement 19.86, actual 17.34 bbls. 03:15 04:30 1.25 6,387 6,387 COMPZ CASING PUTB T While making up swell packer with pups,damage was noted on swell packer. C/O with 5.75"OD, TAM swell packer. 04:30 05:15 0.75 6,387 6,673 COMPZ CASING PUTB P PJSM, PU 4 1/2", L-80, 11.6#, IBTM slotted/blank liner&liner top hanger/packer f/6387'-6594' MD. 05:15 05:30 0.25 6,673 6,673 COMPZ CASING RURD P PJSM, rig down casing equipment& rig up to run liner on DP. 05:30 05:45 0.25 6,673 6,768 COMPZ CASING WASH P Wash down f/6673'-6768' MD, @ 3 bpm, 100 psi, FO 12%, PU 105K, SO 80K. 05:45 06:45 1.00 6,768 7,840 COMPZ CASING RUNL P PJSM, TIH w/4.5"liner on DP f/ 6768'-7840' MD, calculated displacement 16.2,actual 16.1 bbls. 06:45 07:00 0.25 7,840 7,840 COMPZ CASING CIRC P Obtain parameters at the shoe PU 117K, SO 83K, ROT 93K,20 rpm,Tq 4.5k, 3 bpm, 125 psi. 07:00 08:30 1.50 7,840 9,620 COMPZ CASING RUNL P TIH w/4.5"liner on DP from 7840'-9620'MD as per rig engineer running speeds. 08:30 13:45 5.25 9,620 10,141 COMPZ CASING RUNL T Work through tight hole f/ 9620'-10141' MD.Tagged up on a tight spot at—9620'at 08:30 and worked the pipe down one inch at a time until it finally broke free at 9660' at 12:00. Had to work the pipe down with 30 rpm and 8k1b-ft max TQ to make any progress. Tagged up again at 9727'and had to work the pipe down again with 35 rpm and 8k1b-ft max TQ. 13:45 18:00 4.25 10,141 14,380 COMPZ CASING RUNL P TIH w/4.5"liner on DP from 10141'-14380'MD. Tagged bottom w/ 5K @ 14390'. P/U 10'to set at 14380' MD. PU 180K, SO 65K, calculated displacement 43.9, actual 36.4 bbls. 18:00 18:30 0.50 14,380 14,380 COMPZ CASING CIRC P Circulate DP volume @ 3 bpm, 250 psi, FO 7%, 81 bbls pumped. 18:30 19:15 0.75 14,380 7,792 COMPZ CASING PACK P PJSM, set liner top packer/hanger per Baker Rep. drop 1.5"ball& pump down at 3 bpm, 225 psi, ball on seat with 693 strokes. Shoe @ 14380'MD, Liner Top @ 7742'MD. 19:15 19:45 0.50 7,792 7,792 COMPZ CASING PRTS P PJSM, rig up&test liner top to 3000 psi for 5 min good. Rig down test equipment. 19:45 21:15 1.50 7,792 7,691 COMPZ WELLPF CIRC P PJSM, unsting from liner top 7792'-7691' MD&circulate till 12.0 ppg brine in&out 7 bpm, 820 psi, FO 23%. Page 36 of 39 •Time Logs Date From To Dur S. Depth E. Depth Phase -Code Subcode T Comment 21:15 21:45 0.50 7,691 7,691 COMPZ WELLPF CRIH P PJSM, spot 28 bbls of 12.0 ppg Conqor 303a corrosion inhibited brine. 21:45 22:00 0.25 7,691 7,691 COMPZ WELLPF OWFF P Monitor well, static. 22:00 23:00 1.00 7,691 7,691 COMPZ WELLPF SLPC P PJSM, slip&cut 66'of drill line. Continue monitoring well via the trip _tank. 23:00 23:30 0.50 7,691 7,691 COMPZ WELLPF RURD P PJSM, blow down TD&kill line. PU in string single. 23:30 00:00 0.50 7,691 6,973 COMPZ WELLPF TRIP P PJSM, TOH f/7691'-6973' MD, PU 150K, calculated fill 5.4, actual 4.84 bbls. 08/19/2015 TOH laying down running tools. Pull wear bushing&flush stack.Ran 3.5"completion as per detail to 7749'. Pressure test tubing to 3000 psi&IA to 3500psi. Space out&land tubing hanger, RILDS.Test seals to 5000 psi. Nipple down MPD equipment from BOPE. 00:00 02:00 2.00 6,973 46 COMPZ WELLPF TRIP P PJSM, TOH f/6973'-46'MD, calculated fill 45.39, actual 40.85 bbls. 02:00 03:00 1.00 46 0 COMPZ WELLPF BHAH P PJSM, lay down Baker running tools. 03:00 04:30 1.50 0 0 COMPZ RPCOM WWWH P PJSM, pull wear bushing&flush stack. SIMOPS clear rig floor. Spill Drill CRT 79 sec @ 04:30 hrs. 04:30 05:15 0.75 0 0 COMPZ RPCOM RURD P PJSM, mobilize&rig up casing equipment. 05:15 06:00 0.75 0 180 COMPZ RPCOM PUTB P PJSM, run 3.5', 9.3#, L-80, EUE 8RD tubing as per detail f/0'-180' MD. 06:00 06:45 0.75 180 180 COMPZ RPCOM PRTS P PJSM, rig up&test Mirage plug to 1000 psi for 5 min, charted. Rig down test equipment. 06:45 12:45 6.00 180 5,006 COMPZ RPCOM PUTB P PJSM, run 3.5', 9.3#, L-80, EUE 8RD tubing as per detail f/180'-5006' MD, PU 65K, SO 60K. 12:45 13:15 0.50 5,006 5,006 COMPZ RPCOM PRTS P PJSM, rig up&test tubing to 3000 psi for 5 min, charted. Rig down test _ equipment. 13:15 16:15 3.00 5,006 7,753 COMPZ RPCOM PUTB P PJSM, run 3.5', 9.3#, L-80, EUE 8RD tubing as per detail f/5006'-7753'MD tagged NOGO, PU 94K, SO 70K, calculated displacement 41.47, actual 29.57 bbls. 16:15 16:45 0.50 7,753 7,746 COMPZ RPCOM HOSO P PJSM, lay down joint 249, measure joint in shed. 16:45 17:15 0.50 7,746 7,746 COMPZ RPCOM RURD P PJSM, rig up to test. 17:15 18:30 1.25 7,746 7,746 COMPZ RPCOM PRTS P PJSM, rig up&test tubing to 3000 psi for 5 min, charted. Bleed down tubing to 2000 psi. Test IA to 3500 psi for 30 min, charted. Bleed down IA&tubing to 0. Rig down test equipment. 18:30 19:30 1.00 7,746 7,706 COMPZ RPCOM HOSO P PJSM, space out laying down joints 248,247, &246. Pick up 3.5"pup joints 4.21', 10.19', & 10.20'. 19:30 20:00 0.50 7,706 7,706 COMPZ RPCOM RURD P PJSM, change out casing equipment to 4.5". Page 37 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:45 0.75 7,706 7,732 COMPZ RPCOM HOSO P PJSM, make up XO,4.5"joint of tubing, 4.5"pup,tubing hanger, & landing joint. 20:45 21:00 0.25 7,732 7,732 COMPZ RPCOM RURD P PJSM, drain stack&blow down lines. 21:00 22:30 1.50 7,732 7,749 COMPZ RPCOM THGR P PJSM, land hanger, RILDS, rig up& test seals to 5000 psi for 15 min's. SIMOPS lay down landing joint& casing equipment. 22:30 00:00 1.50 0 0 COMPZ WHDBO MPDA P PJSM, nipple down MPD equipment from stack. SIMOPS test MPD choke in the cellar. 08/20/2015 Nipple down MPD&BOPE. Nipple up tree&test. Pressure test tubing&IA. Shear out Mirage plug&SOV. Freeze protect well. Lay down 4"DP. 00:00 01:00 1.00 0 0 COMPZ WHDBO MPDA P PJSM, continue nippling down MPD equipment from the stack. SIMOPS test MPD choke. 01:00 02:00 1.00 0 0 COMPZ WHDBO MPDA P PJSM, blow down MPD lines&rig down remaining lines. 02:00 03:00 1.00 0 0 COMPZ WHDBO NUND P PJSM, nipple down BOPE. 03:00 05:15 2.25 0 0 COMPZ WHDBO NUND P PJSM, nipple up tree adapter flange. 05:15 06:00 0.75 0 0 COMPZ WHDBO PRTS P PJSM, rig up&test neck seals to 5000 psi for 15 min. Test void to 250/5000 psi for 15 min each. (test witnessed) Fire Drill CRT 102 sec @ 05:45 hrs. 06:00 06:30 0.50 0 0 COMPZ WHDBO NUND P PJSM, nipple up tree. 06:30 07:30 1.00 0 0 COMPZ WHDBO OTHR P PJSM, set up scaffolding around tree. 07:30 09:00 1.50 0 0 COMPZ WHDBO PRTS P PJSM, rig up&test tree to 400/5000 psi for 15 min each. 09:00 11:00 2.00 0 0 COMPZ WHDBO MPSP P PJSM, remove test dart&BPV as per Cameron Rep. 11:00 12:30 1.50 0 0 COMPZ WHDBO OTHR P PJSM, rig up lines to test tubing& IA. 12:30 13:00 0.50 0 0 COMPZ WHDBO SEQP P PJSM, pressure test lines. 13:00 14:45 1.75 0 0 COMPZ WHDBO PRTS P PJSM,test tubing to 3000 psi for 30 min, charted. Test IA to 3500 psi for 30 min, charted. 14:45 15:30 0.75 0 0 COMPZ WHDBO CIRC P PJSM, bleed IA to 0 psi, pressure up tubing to 3500 psi&hold for 10 min. Continue to pressure up to 3800 psi to shear Mirage plug. Bull head 12 bbls to clear Mirage plug of debris @ 3 bpm, ICP 800 psi, FCP 700 psi. Line up&pump down IA shearing SOV at 3200 psi. 15:30 19:45 4.25 0 0 COMPZ WHDBO FRZP P PJSM, rig up LRS to IA&PT lines to 3000 psi. Freeze protect well w/280 bbls @ 2 bpm, ICP 1600 psi, FCP 2400 psi. Blow&rig down lines. SIMOPS lay down 39 stands of 4" DP. Page 38 of 39 Time Logs Date: From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 21:30 1.75 0 0 COMPZ WHDBO MPSP T PJSM, rig up lubricator to set BPV. Problem with lubricator retracting. Rig down lubricator. 21:30 00:00 2.50 0 0 COMPZ WHDBO PULD P ,Lay down 30 stands of 4" DP. OA pressure prior to freeze protect 600 psi,410 psi @ 24:00 hrs. Tubing&IA pressure 850 psi© 24:00 hrs. 38/21/2015 Install BPV. Finish laying down 4" DP. Secure well. Blow down&disconnect all lines. RDMO. Rig release @ 09:00 hrs. 00:00 01:00 1.00 0 0 COMPZ WHDBO PULD P PJSM L/D 10 STDS 4" DRILL PIPE F/DERRICK. 01:00 02:15 1.25 0 0 COMPZ WHDBO MPSP P PJSM, SET BPV W/LUBRICATOR AS PER CAMERON REP. R/D LUBRICATOR. 02:15 06:30 4.25 0 0 DEMOB MOVE PULD P PJSM, CONTINUE L/D 4" DRILL PIPE F/DERRICK 75 STDS. 06:30 09:00 2.50 0 0 DEMOB MOVE RURD P PJSM, L/D MOUSE HOLE. SECURE WELL REMOVE 1502 FLANGE ON TREE AND INSTALL BLANK FLANGE ON TREE. CLEAN DRIP PAN UNDER FLOOR. RIG RELEASE @ 09:00 HRS. IA PRESSURE 760 PSI OA PRESSURE 400 PSI Page 39 of 39 • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-07 Definitive Survey Report 09 September, 2015AD 2 0 Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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-07 Well Position +N/-S 0.00 usft Northing: 5,929,998.58 usfi Latitude: 70° 13'11.684 N +EI-W 0.00 usft Easting: 481,133.41 usfi Longitude: 150°9'7.936 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-07 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 7/31/2015 18.66 80.87 57,490 Design 2S-07 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 15.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 96.99 289.73 2S-07 Srvy#1 INC+TREND(2S-07) INC+TREND Inclinometer+known azi trend 7/23/2015 9:2 383.23 2,894.47 2S-07 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/23/2015 9:31 2,976.14 2,976.14 2S-07 Srvy#3 INC TREND(2S-07) INC+TREND Inclinometer+known azi trend 7/30/2015 3:3. 3,005.91 7,810.85 2S-07 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/3/2015 9:44 7,904.92 14,307.38 2S-07 Srvy#5 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/12/2015 2:41 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,998.58 481,133.41 0.00 0.00 UNDEFINED 96.99 0.23 343.08 96.99 -50.51 0.13 -0.04 5,929,998.72 481,133.37 0.33 0.12 INC+TREND(1) 106.00 0.26 337.47 106.00 -41.50 0.17 -0.05 5,929,998.75 481,133.36 0.38 0.15 INC+TREND(1) 16"x 42„ NOT an Actual Survey 195.23 0.56 314.04 195.23 47.73 0.66 -0.44 5,929,999.24 481,132.97 0.38 0.52 INC+TREND(1) 246.18 0.30 318.25 246.18 98.68 0.93 -0.71 5,929,999.51 481,132.70 0.51 0.71 INC+TREND(1) 289.73 0.15 293.72 289.73 142.23 1.04 -0.84 5,929,999.62 481,132.57 0.40 0.78 INC+TREND(1) 383.23 0.54 213.01 383.22 235.72 0.72 -1.19 5,929,999.30 481,132.22 0.57 0.38 MWD+IFR-AK-CAZ-SC(2) 474.85 1.79 180.92 474.82 327.32 -1.08 -1.45 5,929,997.51 481,131.96 1.49 -1.42 MWD+IFR-AK-CAZ-SC(2) 566.12 2.13 181.18 566.04 418.54 -4.20 -1.51 5,929,994.39 481,131.89 0.37 -4.44 MWD+IFR-AK-CAZ-SC(2) 658.12 3.12 173.58 657.94 510.44 -8.40 -1.26 5,929,990.19 481,132.13 1.14 -8.44 MWD+IFR-AK-CAZ-SC(2) 9/9/2015 8:23:55AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 Database: OAKEDM P2 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 750.77 5.18 167.99 750.35 602.85 -14.99 -0.11 5,929,983.59 481,133.26 2.26 -14.51 MWD+IFR-AK-CAZ-SC(2) 843.37 5.61 167.15 842.54 695.04 -23.49 1.77 5,929,975.09 481,135.12 0.47 -22.24 MWD+IFR-AK-CAZ-SC(2) 895.14 6.68 170.69 894.01 746.51 -28.93 2.82 5,929,969.65 481,136.15 2.19 -27.22 MWD+IFR-AK-CAZ-SC(2) 937.24 7.76 172.40 935.77 788.27 -34.17 3.59 5,929,964.41 481,136.91 2.62 -32.07 MWD+IFR-AK-CAZ-SC(2) 1,031.04 9.81 174.56 1,028.47 880.97 -48.40 5.18 5,929,950.17 481,138.47 2.21 -45.41 MWD+IFR-AK-CAZ-SC(2) 1,124.37 12.71 175.01 1,119.99 972.49 -66.55 6.83 5,929,932.02 481,140.07 3.11 -62.51 MWD+IFR-AK-CAZ-SC(2) 1,218.31 14.49 175.18 1,211.29 1,063.79 -88.55 8.72 5,929,910.01 481,141.91 1.90 -83.28 MWD+IFR-AK-CAZ-SC(2) 1,264.41 17.25 175.22 1,255.63 1,108.13 -101.12 9.77 5,929,897.45 481,142.93 5.99 -95.14 MWD+IFR-AK-CAZ-SC(2) 1,312.33 20.57 175.04 1,300.96 1,153.46 -116.59 11.09 5,929,881.98 481,144.21 6.93 -109.74 MWD+IFR-AK-CAZ-SC(2) 1,361.42 21.66 175.04 1,346.75 1,199.25 -134.20 12.62 5,929,864.36 481,145.69 2.22 -126.37 MWD+IFR-AK-CAZ-SC(2) 1,404.80 21.07 173.97 1,387.15 1,239.65 -149.94 14.13 5,929,848.63 481,147.17 1.63 -141.17 MWD+IFR-AK-CAZ-SC(2) 1,497.81 24.67 172.15 1,472.84 1,325.34 -185.80 18.54 5,929,812.75 481,151.49 3.94 -174.67 MWD+IFR-AK-CAZ-SC(2) 1,590.70 29.25 173.52 1,555.61 1,408.11 -227.58 23.75 5,929,770.97 481,156.59 4.98 -213.68 MWD+IFR-AK-CAZ-SC(2) 1,683.95 29.48 173.67 1,636.88 1,489.38 -273.02 28.85 5,929,725.52 481,161.58 0.26 -256.25 MWD+IFR-AK-CAZ-SC(2) 1,776.06 31.24 176.14 1,716.36 1,568.86 -319.38 32.96 5,929,679.15 481,165.57 2.34 -299.97 MWD+IFR-AK-CAZ-SC(2) 1,869.93 36.30 177.46 1,794.37 1,646.87 -371.46 35.83 5,929,627.07 481,168.31 5.45 -349.53 MWD+IFR-AK-CAZ-SC(2) 1,918.82 39.03 176.53 1,833.06 1,685.56 -401.29 37.41 5,929,597.24 481,169.81 5.70 -377.94 MWD+IFR-A1C-CAZ-SC(2) 1,962.67 38.36 176.79 1,867.29 1,719.79 -428.66 39.00 5,929,569.87 481,171.34 1.57 -403.96 MWD+IFR-AK-CAZ-SC(2) 2,055.37 38.74 176.81 1,939.79 1,792.29 -486.34 42.23 5,929,512.19 481,174.42 0.41 -458.84 MWD+IFR-AK-CAZ-SC(2) 2,150.20 40.20 178.59 2,012.99 1,865.49 -546.57 44.63 5,929,451.96 481,176.67 1.95 -516.39 MWD+IFR-AK-CAZ-SC(2) 2,243.27 40.17 178.27 2,084.09 1,936.59 -606.60 46.28 5,929,391.93 481,178.17 0.22 -573.95 MWD+IFR-AK-CAZ-SC(2) 2,336.09 40.12 178.88 2,155.05 2,007.55 -666.42 47.77 5,929,332.11 481,179.51 0.43 -631.35 MWD+IFR-AK-CAZ-SC(2) 2,428.45 40.23 179.08 2,225.62 2,078.12 -725.99 48.83 5,929,272.54 481,180.42 0.18 -688.62 MWD+IFR-AK-CAZ-SC(2) 2,521.34 40.12 178.79 2,296.59 2,149.09 -785.91 49.94 5,929,212.63 481,181.38 0.23 -746.21 MWD+IFR-AK-CAZ-SC(2) 2,616.17 40.54 178.97 2,368.88 2,221.38 -847.27 51.14 5,929,151.27 481,182.43 0.46 -805.16 MWD+IFR-AK-CAZ-SC(2) 2,709.17 39.25 177.47 2,440.23 2,292.73 -906.89 52.98 5,929,091.66 481,184.12 1.73 -862.27 MWD+IFR-AK-CAZ-SC(2) 2,801.82 38.04 177.32 2,512.60 2,365.10 -964.68 55.61 5,929,033.86 481,186.60 1.31 -917.42 MWD+IFR-AK-CAZ-SC(2) 2,894.47 38.06 177.92 2,585.56 2,438.06 -1,021.74 57.98 5,928,976.80 481,188.83 0.40 -971.92 MWD+IFR-AK-CAZ-SC(2) §if 2,961.00 37.46 178.88 2,638.15 2,490.65 -1,062.46 59.12 5,928,936.08 481,189.87 1.27 -1,010.96 INC+TREND(3) NOT an Actual Survey 10 3/4"x 13-1/2" 2,976.14 37.32 179.10 2,650.18 2,502.68 -1,071.65 59.29 5,928,926.89 481,190.01 1.27 -1,019.79 INC+TREND(3) 3,005.91 37.30 179.56 2,673.86 2,526.36 -1,089.70 59.50 5,928,908.85 481,190.18 0.94 -1,037.17 MWD+IFR-AK-CAZ-SC(4) 3,099.74 39.00 179.45 2,747.65 2,600.15 -1,147.65 60.00 5,928,850.90 481,190.53 1.81 -1,093.02 MWD+IFR-AK-CAZ-SC(4) 3,194.63 39.41 177.83 2,821.18 2,673.68 -1,207.61 61.43 5,928,790.94 481,191.81 1.16 -1,150.56 MWD+IFR-AK-CAZ-SC(4) 3,290.11 39.24 177.08 2,895.04 2,747.54 -1,268.06 64.11 5,928,730.49 481,194.35 0.53 -1,208.26 MWD+IFR-AK-CAZ-SC(4) 3,384.55 39.45 176.03 2,968.07 2,820.57 -1,327.82 67.71 5,928,670.73 481,197.79 0.74 -1,265.05 MWD+IFR-AK-CAZ-SC(4) 3,478.20 39.15 174.45 3,040.55 2,893.05 -1,386.93 72.63 5,928,611.61 481,202.57 1.12 -1,320.87 MWD+IFR-AK-CAZ-SC(4) 3,573.32 38.63 172.93 3,114.58 2,967.08 -1,446.28 79.19 5,928,552.25 481,208.98 1.14 -1,376.51 MWD+IFR-AK-CAZ-SC(4) 3,667.27 38.82 171.35 3,187.88 3,040.38 -1,504.50 87.23 5,928,494.02 481,216.87 1.07 -1,430.66 MWD+IFR-AK-CAZ-SC(4) 3,762.83 35.73 169.88 3,263.91 3,116.41 -1,561.59 96.64 5,928,436.91 481,226.13 3.36 -1,483.37 MWD+IFR-AK-CAZ-SC(4) 9/9/2015 8:23:55AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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) (°/100') (ft) Survey Tool Name 3,857.65 34.29 170.36 3,341.57 3,194.07 -1,615.18 105.97 5,928,383.30 481,235.34 1.55 -1,532.72 MWD+IFR-AK-CAZ-SC(4) 3,952.60 33.41 170.78 3,420.43 3,272.93 -1,667.36 114.64 5,928,331.11 481,243.87 0.96 -1,580.87 MWD+IFR-AK-CAZ-SC(4) 4,046.97 31.83 167.12 3,499.92 3,352.42 -1,717.27 124.35 5,928,281.18 481,253.46 2.68 -1,626.57 MWD+IFR-AK-CAZ-SC(4) 4,141.81 30.32 162.46 3,581.16 3,433.66 -1,764.49 137.15 5,928,233.93 481,266.13 2.99 -1,668.87 MWD+IFR-AK-CAZ-SC(4) 4,236.26 28.34 156.00 3,663.52 3,516.02 -1,807.71 153.45 5,928,190.67 481,282.33 3.95 -1,706.40 MWD+IFR-AK-CAZ-SC(4) 4,330.18 27.21 149.06 3,746.64 3,599.14 -1,846.51 173.57 5,928,151.83 481,302.34 3.65 -1,738.67 MWD+IFR-AK-CAZ-SC(4) 4,424.97 26.54 144.35 3,831.20 3,683.70 -1,882.31 197.06 5,928,115.98 481,325.74 2.35 -1,767.17 MWD+IFR-AK-CAZ-SC(4) 4,519.60 26.62 147.14 3,915.83 3,768.33 -1,917.30 220.88 5,928,080.93 481,349.48 1.32 -1,794.80 MWD+IFR-AK-CAZ-SC(4) 4,614.64 27.00 150.19 4,000.66 3,853.16 -1,953.90 243.16 5,928,044.27 481,371.66 1.50 -1,824.39 MWD+IFR-AK-CAZ-SC(4) 4,708.89 26.67 149.21 4,084.76 3,937.26 -1,990.64 264.62 5,928,007.49 481,393.03 0.59 -1,854.32 MWD+IFR-AK-CAZ-SC(4) 4,802.56 26.75 147.08 4,168.44 4,020.94 -2,026.39 286.84 5,927,971.68 481,415.16 1.03 -1,883.10 MWD+IFR-AK-CAZ-SC(4) 4,895.11 26.79 145.52 4,251.07 4,103.57 -2,061.07 309.97 5,927,936.95 481,438.20 0.76 -1,910.61 MWD+IFR-AK-CAZ-SC(4) 4,991.43 26.57 144.43 4,337.13 4,189.63 -2,096.49 334.79 5,927,901.47 481,462.92 0.56 -1,938.40 MWD+IFR-AK-CAZ-SC(4) 5,086.16 25.63 140.77 4,422.21 4,274.71 -2,129.59 360.07 5,927,868.31 481,488.12 1.97 -1,963.83 MWD+IFR-AK-CAZ-SC(4) 5,181.09 24.29 137.30 4,508.27 4,360.77 -2,159.85 386.30 5,927,837.99 481,514.27 2.09 -1,986.27 MWD+IFR-AK-CAZ-SC(4) 5,276.38 23.24 128.79 4,595.51 4,448.01 -2,186.04 414.25 5,927,811.73 481,542.16 3.76 -2,004.33 MWD+IFR-AK-CAZ-SC(4) 5,370.86 23.57 120.39 4,682.24 4,534.74 -2,207.28 445.09 5,927,790.42 481,572.93 3.55 -2,016.87 MWD+IFR-AK-CAZ-SC(4) 5,464.67 24.37 114.54 4,767.97 4,620.47 -2,224.81 478.88 5,927,772.81 481,606.68 2.67 -2,025.06 MWD+IFR-AK-CAZ-SC(4) 5,559.41 25.62 104.84 4,853.87 4,706.37 -2,238.18 516.47 5,927,759.34 481,644.24 4.52 -2,028.24 MWD+IFR-AK-CAZ-SC(4) 5,654.62 26.69 96.11 4,939.36 4,791.86 -2,245.73 557.65 5,927,751.69 481,685.39 4.19 -2,024.88 MWD+IFR-AK-CAZ-SC(4) 5,749.73 28.00 88.04 5,023.87 4,876.37 -2,247.24 601.22 5,927,750.07 481,728.95 4.13 -2,015.06 MWD+IFR-AK-CAZ-SC(4) 5,844.26 29.19 80.96 5,106.90 4,959.40 -2,242.86 646.17 5,927,754.34 481,773.91 3.80 -1,999.19 MWD+IFR-AK-CAZ-SC(4) 5,939.62 30.42 72.68 5,189.68 5,042.18 -2,232.01 692.21 5,927,765.07 481,819.97 4.50 -1,976.80 MWD+IFR-AK-CAZ-SC(4) 6,034.23 31.84 66.17 5,270.68 5,123.18 -2,214.79 737.92 5,927,782.17 481,865.72 3.86 -1,948.34 MWD+IFR-AK-CAZ-SC(4) 6,128.52 34.04 62.14 5,349.82 5,202.32 -2,192.40 784.01 5,927,804.44 481,911.86 3.29 -1,914.78 MWD+IFR-AK-CAZ-SC(4) 6,221.51 37.28 59.41 5,425.37 5,277.87 -2,165.90 831.28 5,927,830.83 481,959.19 3.88 -1,876.95 MWD+IFR-AK-CAZ-SC(4) 6,319.59 41.18 57.13 5,501.33 5,353.83 -2,133.25 883.99 5,927,863.35 482,011.98 4.24 -1,831.76 MWD+IFR-AK-CAZ-SC(4) 6,411.87 44.36 55.45 5,569.07 5,421.57 -2,098.45 936.09 5,927,898.01 482,064.16 3.66 -1,784.67 MWD+IFR-AK-CAZ-SC(4) 6,506.31 46.45 53.71 5,635.37 5,487.87 -2,059.47 990.88 5,927,936.85 482,119.04 2.57 -1,732.83 MWD+IFR-AK-CAZ-SC(4) 6,600.63 49.11 52.35 5,698.75 5,551.25 -2,017.45 1,046.67 5,927,978.72 482,174.93 3.02 -1,677.81 MWD+IFR-AK-CAZ-SC(4) 6,695.00 51.83 50.23 5,758.81 5,611.31 -1,971.92 1,103.44 5,928,024.11 482,231.81 3.36 -1,619.14 MWD+IFR-AK-CAZ-SC(4) 6,789.58 54.95 50.01 5,815.21 5,667.71 -1,923.24 1,161.69 5,928,072.63 482,290.17 3.30 -1,557.04 MWD+IFR-AK-CAZ-SC(4) 6,884.44 58.25 48.90 5,867.42 5,719.92 -1,871.76 1,221.85 5,928,123.96 482,350.46 3.61 -1,491.75 MWD+IFR-AK-CAZ-SC(4) 6,980.57 61.51 47.36 5,915.66 5,768.16 -1,816.26 1,283.75 5,928,179.30 482,412.48 3.66 -1,422.12 MWD+IFR-AK-CAZ-SC(4) 7,075.25 64.16 46.40 5,958.88 5,811.38 -1,758.68 1,345.22 5,928,236.72 482,474.10 2.94 -1,350.59 MWD+IFR-AK-CAZ-SC(4) 7,167.96 67.24 45.07 5,997.03 5,849.53 -1,699.71 1,405.71 5,928,295.54 482,534.73 3.57 -1,277.97 MWD+IFR-AK-CAZ-SC(4) 7,262.64 68.43 43.09 6,032.75 5,885.25 -1,636.72 1,466.70 5,928,358.37 482,595.87 2.31 -1,201.34 MWD+IFR-AK-CAZ-SC(4) 7,356.98 67.10 40.99 6,068.45 5,920.95 -1,571.88 1,525.18 5,928,423.06 482,654.50 2.50 -1,123.57 MWD+IFR-AK-CAZ-SC(4) 7,451.24 67.96 40.58 6,104.48 5,956.98 -1,505.92 1,582.07 5,928,488.86 482,711.56 1.00 -1,045.14 MWD+IFR-AK-CAZ-SC(4) 7,547.07 68.02 37.84 6,140.40 5,992.90 -1,437.09 1,638.23 5,928,557.54 482,767.88 2.65 -964.12 MWD+IFR-AK-CAZ-SC(4) 9/9/2015 8:23:55AM Page 4 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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) 0100') (ft) Survey Tool Name 7,639.92 67.92 37.50 6,175.23 6,027.73 -1,368.96 1,690.83 5,928,625.53 482,820.65 0.36 -884.70 MWD+IFR-AK-CAZ-SC(4) 7,734.64 67.98 38.02 6,210.79 6,063.29 -1,299.56 1,744.59 5,928,694.80 482,874.57 0.51 -803.74 MWD+I F R-AK-CAZ-SC(4) 7,810.85 67.95 37.80 6,239.38 6,091.88 -1,243.82 1,787.99 5,928,750.42 482,918.11 0.27 -738.67 MWD+IFR-AK-CAZ-SC(4) 7,868.00 67.80 37.59 6,260.90 6,113.40 -1,201.93 1,820.37 5,928,792.23 482,950.58 0.44 -689.83 MWD+IFR-AK-CAZ-SC(5) 7-5/8"x 9-7/8" NOT an Actual Survey 7,904.92 67.70 37.45 6,274.88 6,127.38 -1,174.83 1,841.18 5,928,819.27 482,971.46 0.44 -658.26 MWD+IFR-AK-CAZ-SC(5) 7,927.22 68.06 37.20 6,283.28 6,135.78 -1,158.40 1,853.70 5,928,835.67 482,984.03 1.92 -639.15 MWD+IFR-AK-CAZ-SC(5) 7,976.56 69.42 36.30 6,301.17 6,153.67 -1,121.55 1,881.21 5,928,872.44 483,011.63 3.24 -596.45 MWD+IFR-AK-CAZ-SC(5) 8,021.99 70.78 35.99 6,316.63 6,169.13 -1,087.06 1,906.41 5,928,906.87 483,036.90 3.06 -556.61 MWD+IFR-AK-CAZ-SC(5) 8,070.03 73.36 35.56 6,331.42 6,183.92 -1,049.98 1,933.12 5,928,943.88 483,063.71 5.44 -513.87 MWD+IFR-AK-CAZ-SC(5) 8,116.43 75.93 34.45 6,343.71 6,196.21 -1,013.33 1,958.79 5,928,980.46 483,089.46 6.00 -471.83 MWD+IFR-AK-CAZ-SC(5) 8,161.90 78.42 33.85 6,353.80 6,206.30 -976.64 1,983.67 5,929,017.08 483,114.44 5.63 -429.95 MWD+IFR-AK-CAZ-SC(5) 8,210.45 80.79 32.46 6,362.56 6,215.06 -936.67 2,009.78 5,929,056.99 483,140.65 5.64 -384.58 MWD+IFR-AK-CAZ-SC(5) 8,249.55 82.49 32.35 6,368.24 6,220.74 -904.01 2,030.51 5,929,089.59 483,161.46 4.36 -347.67 MWD+IFR-AK-CAZ-SC(5) 8,305.12 84.91 31.84 6,374.34 6,226.84 -857.22 2,059.86 5,929,136.30 483,190.91 4.45 -294.88 MWD+IFR-AK-CAZ-SC(5) 8,399.79 89.51 31.37 6,378.95 6,231.45 -776.71 2,109.40 5,929,216.68 483,240.65 4.88 -204.29 MWD+IFR-AK-CAZ-SC(5) 8,494.27 93.63 29.47 6,376.36 6,228.86 -695.29 2,157.21 5,929,297.97 483,288.66 4.80 -113.27 MWD+IFR-AK-CAZ-SC(5) 8,588.74 94.76 29.10 6,369.45 6,221.95 -613.11 2,203.29 5,929,380.03 483,334.95 1.26 -21.97 MWD+IFR-AK-CAZ-SC(5) 8,682.92 95.04 28.77 6,361.41 6,213.91 -530.99 2,248.69 5,929,462.03 483,380.54 0.46 69.11 MWD+IFR-AK-CAZ-SC(5) 8,777.19 95.11 28.78 6,353.07 6,205.57 -448.69 2,293.89 5,929,544.21 483,425.95 0.08 160.31 MWD+IFR-AK-CAZ-SC(5) 8,872.12 94.80 27.94 6,344.87 6,197.37 -365.46 2,338.82 5,929,627.31 483,471.07 0.94 252.32 MWD+IFR-AK-CAZ-SC(5) 8,969.34 94.83 24.90 6,336.70 6,189.20 -278.71 2,381.92 5,929,713.94 483,514.39 3.12 347.27 MWD+IFR-AK-CAZ-SC(5) 9,062.79 91.79 23.10 6,331.31 6,183.81 -193.50 2,419.86 5,929,799.06 483,552.53 3.78 439.40 MWD+IFR-AK-CAZ-SC(5) 9,156.09 90.74 21.97 6,329.25 6,181.75 -107.34 2,455.60 5,929,885.11 483,588.49 1.65 531.87 MWD+IFR-AK-CAZ-SC(5) 9,249.36 90.36 18.95 6,328.35 6,180.85 -19.97 2,488.20 5,929,972.39 483,621.30 3.26 624.70 MWD+IFR-AK-CAZ-SC(5) 9,345.81 91.28 17.54 6,326.97 6,179.47 71.62 2,518.39 5,930,063.90 483,651.72 1.75 720.98 MWD+IFR-AK-CAZ-SC(5) 9,439.81 93.82 13.33 6,322.79 6,175.29 162.11 2,543.38 5,930,154.31 483,676.94 5.23 814.86 MWD+IFR-AK-CAZ-SC(5) 9,485.25 96.05 10.92 6,318.88 6,171.38 206.36 2,552.89 5,930,198.54 483,686.55 7.21 860.07 MWD+IFR-AK-CAZ-SC(5) 9,534.40 95.79 9.61 6,313.81 6,166.31 254.47 2,561.60 5,930,246.62 483,695.39 2.70 908.79 MWD+IFR-AK-CAZ-SC(5) 9,578.50 94.32 9.48 6,309.93 6,162.43 297.79 2,568.89 5,930,289.92 483,702.78 3.35 952.52 MWD+IFR-AK-CAZ-SC(5) 9,628.43 92.45 9.77 6,306.98 6,159.48 346.92 2,577.22 5,930,339.03 483,711.23 3.79 1,002.14 MWD+IFR-AK-CAZ-SC(5) 9,724.17 90.24 9.75 6,304.73 6,157.23 441.25 2,593.44 5,930,433.30 483,727.69 2.31 1,097.44 MWD+IFR-AK-CAZ-SC(5) 9,819.46 90.44 8.34 6,304.17 6,156.67 535.35 2,608.42 5,930,527.35 483,742.90 1.49 1,192.22 MWD+IFR-AK-CAZ-SC(5) 9,914.25 90.40 7.94 6,303.47 6,155.97 629.18 2,621.84 5,930,621.14 483,756.56 0.42 1,286.32 MWD+IFR-AK-CAZ-SC(5) 10,009.12 89.54 6.92 6,303.52 6,156.02 723.25 2,634.11 5,930,715.17 483,769.06 1.41 1,380.37 MWD+IFR-AK-CAZ-SC(5) 10,103.90 89.10 5.87 6,304.64 6,157.14 817.43 2,644.67 5,930,809.32 483,779.85 1.20 1,474.07 MWD+IFR-AK-CAZ-SC(5) 10,195.73 88.02 7.04 6,306.95 6,159.45 908.65 2,654.99 5,930,900.50 483,790.40 1.73 1,564.85 MWD+IFR-AK-CAZ-SC(5) 10,292.26 85.41 6.97 6,312.48 6,164.98 1,004.29 2,666.74 5,930,996.11 483,802.39 2.70 1,660.28 MWD+IFR-AK-CAZ-SC(5) 10,387.11 87.93 6.70 6,317.99 6,170.49 1,098.30 2,678.01 5,931,090.08 483,813.89 2.67 1,754.00 MWD+IFR-AK-CAZ-SC(5) 10,481.40 91.63 6.85 6,318.35 6,170.85 1,191.92 2,689.13 5,931,183.66 483,825.24 3.93 1,847.30 MWD+IFR-AK-CAZ-SC(5) 9/9/2015 8:23:55AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 10,574.54 91.05 8.18 6,316.18 6,168.68 1,284.23 2,701.31 5,931,275.93 483,837.65 1.56 1,939.62 MWD+IFR-AK-CAZ-SC(5) 10,668.45 90.71 8.99 6,314.73 6,167.23 1,377.08 2,715.32 5,931,368.73 483,851.90 0.94 2,032.93 MWD+IFR-AK-CAZ-SC(5) 10,763.74 89.89 11.01 6,314.23 6,166.73 1,470.91 2,731.87 5,931,462.51 483,868.68 2.29 2,127.85 MWD+IFR-AK-CAZ-SC(5) 10,858.59 89.72 11.17 6,314.56 6,167.06 1,563.99 2,750.11 5,931,555.54 483,887.15 0.25 2,222.48 MWD+IFR-AK-CAZ-SC(5) 10,954.75 89.65 11.92 6,315.09 6,167.59 1,658.20 2,769.36 5,931,649.69 483,906.63 0.78 2,318.46 MWD+IFR-AK-CAZ-SC(5) 11,048.50 90.16 12.96 6,315.24 6,167.74 1,749.75 2,789.55 5,931,741.18 483,927.05 1.24 2,412.12 MWD+IFR-AK-CAZ-SC(5) 11,143.83 90.84 13.01 6,314.41 6,166.91 1,842.64 2,810.97 5,931,834.00 483,948.70 0.72 2,507.38 MWD+IFR-AK-CAZ-SC(5) 11,236.97 89.32 12.82 6,314.28 6,166.78 1,933.42 2,831.79 5,931,924.72 483,969.74 1.64 2,600.46 MWD+IFR-AK-CAZ-SC(5) 11,333.53 90.11 13.92 6,314.76 6,167.26 2,027.36 2,854.12 5,932,018.60 483,992.30 1.40 2,696.98 MWD+IFR-AK-CAZ-SC(5) 11,427.14 92.87 14.70 6,312.33 6,164.83 2,118.02 2,877.25 5,932,109.20 484,015.65 3.06 2,790.54 MWD+IFR-AK-CAZ-SC(5) 11,522.13 95.45 13.75 6,305.44 6,157.94 2,209.85 2,900.52 5,932,200.95 484,039.16 2.89 2,885.26 MWD+IFR-AK-CAZ-SC(5) 11,615.99 95.20 13.77 6,296.73 6,149.23 2,300.62 2,922.75 5,932,291.66 484,061.61 0.27 2,978.69 MWD+IFR-AK-CAZ-SC(5) 11,709.50 92.72 12.41 6,290.27 6,142.77 2,391.48 2,943.88 5,932,382.45 484,082.96 3.02 3,071.92 MWD+IFR-AK-CAZ-SC(5) 11,803.84 92.44 14.95 6,286.02 6,138.52 2,483.04 2,966.16 5,932,473.95 484,105.48 2.71 3,166.13 MWD+IFR-AK-CAZ-SC(5) 11,898.32 90.63 15.77 6,283.49 6,135.99 2,574.11 2,991.18 5,932,564.95 484,130.72 2.10 3,260.57 MWD+IFR-AK-CAZ-SC(5) 11,992.18 90.55 15.93 6,282.52 6,135.02 2,664.39 3,016.81 5,932,655.16 484,156.57 0.19 3,354.41 MWD+IFR-AK-CAZ-SC(5) 12,088.34 89.13 15.52 6,282.79 6,135.29 2,756.95 3,042.87 5,932,747.64 484,182.86 1.54 3,450.56 MWD+IFR-AK-CAZ-SC(5) 12,181.52 88.79 14.72 6,284.48 6,136.98 2,846.89 3,067.18 5,932,837.51 484,207.39 0.93 3,543.73 MWD+IFR-AK-CAZ-SC(5) 12,275.31 88.48 13.43 6,286.72 6,139.22 2,937.84 3,089.98 5,932,928.39 484,230.41 1.41 3,637.48 MWD+IFR-AK-CAZ-SC(5) 12,370.16 87.73 13.31 6,289.85 6,142.35 3,030.06 3,111.90 5,933,020.56 484,252.56 0.80 3,732.24 MWD+IFR-AK-CAZ-SC(5) 12,466.11 87.86 12.20 6,293.55 6,146.05 3,123.58 3,133.07 5,933,114.01 484,273.96 1.16 3,828.04 MWD+IFR-AK-CAZ-SC(5) 12,561.11 88.82 12.97 6,296.30 6,148.80 3,216.25 3,153.76 5,933,206.62 484,294.88 1.30 3,922.91 MWD+IFR-AK-CAZ-SC(5) 12,654.82 89.10 12.34 6,298.00 6,150.50 3,307.67 3,174.28 5,933,297.98 484,315.64 0.74 4,016.53 MWD+IFR-AK-CAZ-SC(5) 12,748.56 90.37 13.71 6,298.43 6,150.93 3,398.99 3,195.41 5,933,389.24 484,336.99 1.99 4,110.21 MWD+IFR-AK-CAZ-SC(5) 12,843.28 91.04 17.26 6,297.27 6,149.77 3,490.25 3,220.69 5,933,480.43 484,362.50 3.81 4,204.90 MWD+IFR-AK-CAZ-SC(5) 12,938.02 93.15 18.17 6,293.80 6,146.30 3,580.43 3,249.50 5,933,570.53 484,391.52 2.43 4,299.47 MWD+IFR-AK-CAZ-SC(5) 13,031.26 95.17 18.01 6,287.04 6,139.54 3,668.83 3,278.37 5,933,658.84 484,420.62 2.17 4,392.32 MWD+IFR-AK-CAZ-SC(5) 13,125.89 95.15 16.67 6,278.53 6,131.03 3,758.79 3,306.46 5,933,748.72 484,448.93 1.41 4,486.49 MWD+IFR-AK-CAZ-SC(5) 13,222.71 94.07 15.10 6,270.75 6,123.25 3,851.61 3,332.87 5,933,841.46 484,475.57 1.96 4,582.98 MWD+IFR-AK-CAZ-SC(5) 13,316.54 90.47 14.99 6,267.03 6,119.53 3,942.13 3,357.21 5,933,931.92 484,500.13 3.84 4,676.72 MWD+IFR-AK-CAZ-SC(5) 13,411.67 87.80 14.24 6,268.47 6,120.97 4,034.17 3,381.20 5,934,023.88 484,524.35 2.92 4,771.83 MWD+IFR-AK-CAZ-SC(5) 13,506.90 88.76 12.30 6,271.32 6,123.82 4,126.81 3,403.05 5,934,116.46 484,546.43 2.27 4,866.96 MWD+IFR-AK-CAZ-SC(5) 13,600.65 89.82 12.60 6,272.49 6,124.99 4,218.34 3,423.26 5,934,207.94 484,566.86 1.18 4,960.61 MWD+IFR-AK-CAZ-SC(5) 13,695.82 90.38 12.14 6,272.32 6,124.82 4,311.30 3,443.65 5,934,300.83 484,587.48 0.76 5,055.68 MWD+IFR-AK-CAZ-SC(5) 13,790.56 89.89 11.52 6,272.10 6,124.60 4,404.03 3,463.07 5,934,393.50 484,607.13 0.83 5,150.28 MWD+IFR-AK-CAZ-SC(5) 13,885.48 89.85 12.03 6,272.31 6,124.81 4,496.95 3,482.44 5,934,486.37 484,626.73 0.54 5,245.04 MWD+IFR-AK-CAZ-SC(5) 13,979.56 89.82 11.93 6,272.58 6,125.08 4,588.98 3,501.97 5,934,578.34 484,646.49 0.11 5,338.99 MWD+IFR-AK-CAZ-SC(5) 14,075.39 89.17 13.18 6,273.43 6,125.93 4,682.52 3,522.80 5,934,671.81 484,667.55 1.47 5,434.73 MWD+IFR-AK-CAZ-SC(5) 14,168.58 88.45 15.27 6,275.36 6,127.86 4,772.82 3,545.69 5,934,762.05 484,690.67 2.37 5,527.89 MWD+IFR-AK-CAZ-SC(5) 14,261.97 88.55 16.41 6,277.81 6,130.31 4,862.63 3,571.17 5,934,851.79 484,716.37 1.22 5,621.23 MWD+IFR-AK-CAZ-SC(5) 9/9/2015 8.23:55AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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) (°/100') (ft) Survey Tool Name 14,307.38 88.86 16.77 6,278.83 6,131.33 4,906.14 3,584.14 5,934,895.26 484,729.44 1.05 5,666.61 MWD+IFR-AK-CAZ-SC(5) 14,380 00 88.86 16.77 6,280.28 6,132.78 4,975.66 3,605.09 5,934,964 72 484,750.56 0.00 5,739.18 NOT an Actual Survey 4 1/2"x 6-3/4" 14,390.00 88.86 16.77 6,280.48 6,132.98 4,985.23 3,607.97 5,934,974.28 484,753.47 0.00 5,749.18 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Ye LINo have checked to the best of my ability that the following data is correct: El Surface Coordinates El Declination & Convergence • GRS Survey Corrections E Survey Tool Codes • qrad by Vdra;rk • cn.Artrant Dun, SLB DE: Vincent OS a ra 01, Ghent Representative: H&bin Guo Date: 09-Sep-2015 9/9/2015 8:23:55AM Page 7 COMPASS 5000.1 Build 74 • Cement Detail Report:,.,... - .:c..a...z,„1,1N,,,,...,_ ::,,w,,1„i,,,,orie., rt lu k_.4 h 2S-07 If idit. ConocaoPhiltips r. String: Surface Casing Cement Job: DRILLING ORIGINAL, 7/20/2015 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 7/25/2015 16:15 7/25/2015 19:10 2S-07 Comment PJSM;pump 75 bbls of CW-100 @ 5 bpm=230 psi. Pump 71 bbls of Mud Push II @ 4.7 bpm=200 psi. Drop bottom plug. Pump 498 bbls of 11 ppg lead cement @ 7-4 bpm=225-165 psi. Pump 59 bbls of 12 ppg tail cement @ 4.7 bpm=280 psi. Drop bottom plug. Pump 10 bbls of H2O @ 7 bpm=375 psi. Displace with rig pumps @ 8-3 bpm=800-600 psi.After cement back to surface hanger flutes plugged off&diverted returns to cellar box. Bumped plug @ 2637 strokes. Pressured up to 1100 psi&hold for 5 min.Check floats,good.CIP at 19:10 hrs.Total cement to surface was 116 bbls. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 28.7 2,971.0 No 65.0 No 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) 8 3 8 600.0 1,100.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 28.7 2,471.0 1,495 G 498.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.87 6.42 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 2,471.0 2,971.0 205 G 59.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 1.62 5.38 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx 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) Mud Push II 71.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW-100 75.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.40 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/9/2015 • • Cement Detail Report 2S-07 ConocoPhillips Akka String: Cement Squeeze Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Squeeze 7/29/2015 09.00 7/29/2015 14.30 2S-07 Comment RU cmt line-Spot cmt plug as follows: Pumped 5 bbls 12.5 ppg MudPush II-Tested lines to 900&3800 psi(Good)-Pumped 13 bbls 12.5 ppg Mud Push II @ 5 bbls/min @ 275 psi-Dropped wiper ball-Batch mix&pumped 30 bbls 15.8 ppg Class G cmt @ 5 bbls/min @ 332 psi-Followed by 3 bbls/12.5 ppg Mud Push II-switch to rig pump&displaced w/23.5 bbls-9.6 ppg mud @ 6 bbls/min @ 275 psi to equailze-CIP @ 10:35 hrs. RU&Perform hesitation squeeze as follows:Closed annular-Pumped 1/2 bbls pressured up to 450 psi-Hold 15 mins.-Pumped 1/2 bbl-pressured up to 700 psi-Shut in for 15 mins. bled down to 575 psi-Pumped 1/2 bbl-pressured up to 800 psi-shut in for 15 mins.bled down to 550 psi-Pumped 4 bbls- pressured to 700 psi-shut in for 15 mins. bled down to 520 psi-Pumped 2 bbls-pressured up to 875 psi-shut in for 15 mins.-bled down to 520 psi-Pumped 1/2 bbl-pressured up to 850 psi-shut in for 15 mins.-bled down to 700 psi-Pumped 1/2 bbl-pressured up to 1000 psi-shut in for 15 mins.-bled down to 800 psi-Pumped 1/2 bbl pressured up to 1100 psi-shut in for 20 mins-bled down to 975 psi Squeezed total of 9 bbls away-Bled off pressure-Opened annular-RD squeeze equipment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Squeeze Sugeeze for FIT 2,700.0 3,023.0 No No No 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) 3 2 4 95.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,835.0 Drill Bit 3,023.0 9 7/8 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 2,700.0 3,023.0 145 G 30.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/9/2015 s • 0 Cement Detail Report ti2S-07 P iltips _� String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement I 8/6/2015 23:15 8/7/2015 05:15 2S-07 Comment Pump 5 bbls CW-100.Test lines to 400/4000 psi. Pump 40 bbls CW-100 followed by 45 bbls 12 ppg MP2.4.5 bpm,500 psi.Load btm plug-Batch up cmt.- Pumped 79 bbls 15.8 ppg Class G w/GASBLOK slurry @ 4.5 bbls/min @ 660 to 198 psi-Shut down-Loaded top plug-kicked out w/10 bbls/fresh water- switched over to rig pumps&displaced cmt w/10.6 ppg mud©5 bbls/min @ 200 psi-slow pump&bumped plug w/1251 psi-Bleed off&checked floats- floats held-CIP 0145 hrs.-Lost 332 bbls during cmt job. -Recipcated pipe to just before bumping plug. Pressure up and open stage collar w/3300 psi. Break circ and stage up to 2 bpm,300 psi. Lost 45 bbls to hole. Pump 45 bbls CW-100 @ 4 bpm,300 psi. Batch mix and pump 45 bbls 12 ppg MD2 @ 4.3 bpm,400 psi. Batch up cmt.-Pumped 32 bbls 15.8 ppg Class G w/GASBLOK slurry @ 4.5 bbls/min @ 340 to 205 psi-Shut down-Loaded closing plug-kicked out w/ 10 bbls/fresh water-switched over to rig pumps&displaced cmt w/10.6 ppg mud @ 6 bbls/min @ 350 psi-slow pump&land plug w/400 psi. Pressure up to 1600 psi and hold for 5 mins to close stage collar. Bleed off&confirm stage collar closure.CIP 0500 hrs.-Lost 90 bbls during cmt job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 5,640.0 7,868.0 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) 4 5 5 700.0 1,251.0 Yes 12.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,363.0 7,868.0 377 G 77.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 3.95 15.80 132.0 4.25 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.12 gal/sx Additive Type Concentration Conc Unit label Gas Block D6000 1.0 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 4,900.0 5,640.0 No No No Cement Q Pump lnit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 6 6 350.0 1,600.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,991.0 5,640.0 155 G 32.2 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 3.95 15.80 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.2 gal/sx Page 1/2 Report Printed: 9/9/2015 Cement Detail Report 2S-07 C. coPhillips A,€:skm String: Intermediate Casing Cement Job: Additives Additive Type Concentration Conc Unit label Gas Block D600G 1.6 gal/sx Page 2/2 Report Printed: 9/9/2015 • 21 `. 1199 • 26230 SchlumbergerDrilling & Measurements Transmittal#: 10SEP15-SP01 DATA LOGGED MWD/LWD LogProduct Delivery .) /%%/2oi5 M. K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-07 Date Dispatched: 10-Sep-15 Job#: 14AKA0058 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 7 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 2'TVDSS x x SEP 0 g 201j VISION*Service 5'MD x x VISION*Service 5'TVD x x AOGCC VISION*Service 5'TVDSS x x VISION*Service SonicScope Top of Cement 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: Catherine.Roso(cconocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn: Stephanie Pacillo 907-265-6189 ATO 1707 p,),,t4,,,,,,,,e,„,<./7) Received By: • 21 5079 26230 FINAL � J NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-07 RECEIVED SEP 0 8 2u is AOGCC Definitive Survey Report 09 September, 2015 NAD 27 IISchlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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-07 Well Position +N/-S 0.00 usft Northing: 5,929,998.58 usfl Latitude: 70° 13'11.684 N +E/-W 0.00 usft Easting: 481,133.41 usfl Longitude: 150°9'7.936 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-07 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 7/31/2015 18.66 80.87 57,490 Design 2S-07 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) (°) 27.50 0.00 0.00 15.00 Survey Program Date ' From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 96.99 289.73 2S-07 Srvy#1 INC+TREND(2S-07) INC+TREND Inclinometer+known azi trend 7/23/2015 9:Z 383.23 2,894.47 2S-07 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/23/2015 9:31 2,976.14 2,976.14 2S-07 Srvy#3 INC TREND(2S-07) INC+TREND Inclinometer+known azi trend 7/30/2015 3:3• 3,005.91 7,810.85 2S-07 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/3/2015 9:44 7,904.92 14,307.38 2S-07 Srvy#5 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/12/2015 2:41 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 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,998.58 481,133.41 0.00 0.00 UNDEFINED 96.99 0.23 343.08 96.99 -50.51 0.13 -0.04 5,929,998.72 481,133.37 0.33 0.12 INC+TREND(1) 106.00 0.26 337.47 106.00 -41.50 0.17 -0.05 5,929,998.75 481,133.36 0.38 0.15 INC+TREND(1) NOT an Actual Survey 16"x 42" 195.23 0.56 314.04 195.23 47.73 0.66 -0.44 5,929,999.24 481,132.97 0.38 0.52 INC+TREND(1) 246.18 0.30 318.25 246.18 98.68 0.93 -0.71 5,929,999.51 481,132.70 0.51 0.71 INC+TREND(1) 289.73 0.15 293.72 289.73 142.23 1.04 -0.84 5,929,999.62 481,132.57 0.40 0.78 INC+TREND(1) 383.23 0.54 213.01 383.22 235.72 0.72 -1.19 5,929,999.30 481,132.22 0.57 0.38 MWD+IFR-AK-CAZ-SC(2) 474.85 1.79 180.92 474.82 327.32 -1.08 -1.45 5,929,997.51 481,131.96 1.49 -1.42 MWD+IFR-AK-CAZ-SC(2) 566.12 2.13 181.18 566.04 418.54 -4.20 -1.51 5,929,994.39 481,131.89 0.37 -4.44 MWD+IFR-AK-CAZ-SC(2) 658.12 3.12 173.58 657.94 510.44 -8.40 -1.26 5,929,990.19 481,132.13 1.14 -8.44 MWD+IFR-AK-CAZ-SC(2) 9/9/2015 8:23:55AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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) (°11001 (ft) Survey Tool Name 750.77 5.18 167.99 750.35 602.85 -14.99 -0.11 5,929,983.59 481,133.26 2.26 -14.51 MWD+IFR-AK-CAZ-SC(2) 843.37 5.61 167.15 842.54 695.04 -23.49 1.77 5,929,975.09 481,135.12 0.47 -22.24 MWD+IFR-AK-CAZ-SC(2) 895.14 6.68 170.69 894.01 746.51 -28.93 2.82 5,929,969.65 481,136.15 2.19 -27.22 MWD+IFR-AK-CAZ-SC(2) 937.24 7.76 172.40 935.77 788.27 -34.17 3.59 5,929,964.41 481,136.91 2.62 -32.07 MWD+IFR-AK-CAZ-SC(2) 1,031.04 9.81 174.56 1,028.47 880.97 -48.40 5.18 5,929,950.17 481,138.47 2.21 -45.41 MWD+IFR-AK-CAZ-SC(2) 1,124.37 12.71 175.01 1,119.99 972.49 -66.55 6.83 5,929,932.02 481,140.07 3.11 -62.51 MWD+IFR-AK-CAZ-SC(2) 1,218.31 14.49 175.18 1,211.29 1,063.79 -88.55 8.72 5,929,910.01 481,141.91 1.90 -83.28 MWD+IFR-AK-CAZ-SC(2) 1,264.41 17.25 175.22 1,255.63 1,108.13 -101.12 9.77 5,929,897.45 481,142.93 5.99 -95.14 MWD+IFR-AK-CAZ-SC(2) 1,312.33 20.57 175.04 1,300.96 1,153.46 -116.59 11.09 5,929,881.98 481,144.21 6.93 -109.74 MWD+IFR-AK-CAZ-SC(2) 1,361.42 21.66 175.04 1,346.75 1,199.25 -134.20 12.62 5,929,864.36 481,145.69 2.22 -126.37 MWD+IFR-AK-CAZ-SC(2) 1,404.80 21.07 173.97 1,387.15 1,239.65 -149.94 14.13 5,929,848.63 481,147.17 1.63 -141.17 MWD+IFR-AK-CAZ-SC(2) 1,497.81 24.67 172.15 1,472.84 1,325.34 -185.80 18.54 5,929,812.75 481,151.49 3.94 -174.67 MWD+IFR-AK-CAZ-SC(2) 1,590.70 29.25 173.52 1,555.61 1,408.11 -227.58 23.75 5,929,770.97 481,156.59 4.98 -213.68 MWD+IFR-AK-CAZ-SC(2) 1,683.95 29.48 173.67 1,636.88 1,489.38 -273.02 28.85 5,929,725.52 481,161.58 0.26 -256.25 MWD+IFR-AK-CAZ-SC(2) 1,776.06 31.24 176.14 1,716.36 1,568.86 -319.38 32.96 5,929,679.15 481,165.57 2.34 -299.97 MWD+IFR-AK-CAZ-SC(2) 1,869.93 36.30 177.46 1,794.37 1,646.87 -371.46 35.83 5,929,627.07 481,168.31 5.45 -349.53 MWD+IFR-AK-CAZ-SC(2) 1,918.82 39.03 176.53 1,833.06 1,685.56 -401.29 37.41 5,929,597.24 481,169.81 5.70 -377.94 MWD+IFR-AK-CAZ-SC(2) 1,962.67 38.36 176.79 1,867.29 1,719.79 -428.66 39.00 5,929,569.87 481,171.34 1.57 -403.96 MWD+IFR-AK-CAZ-SC(2) 2,055.37 38.74 176.81 1,939.79 1,792.29 -486.34 42.23 5,929,512.19 481,174.42 0.41 -458.84 MWD+IFR-AK-CAZ-SC(2) 2,150.20 40.20 178.59 2,012.99 1,865.49 -546.57 44.63 5,929,451.96 481,176.67 1.95 -516.39 MWD+IFR-AK-CAZ-SC(2) 2,243.27 40.17 178.27 2,084.09 1,936.59 -606.60 46.28 5,929,391.93 481,178.17 0.22 -573.95 MWD+IFR-AK-CAZ-SC(2) 2,336.09 40.12 178.88 2,155.05 2,007.55 -666.42 47.77 5,929,332.11 481,179.51 0.43 -631.35 MWD+IFR-AK-CAZ-SC(2) 2,428.45 40.23 179.08 2,225.62 2,078.12 -725.99 48.83 5,929,272.54 481,180.42 0.18 -688.62 MWD+IFR-AK-CAZ-SC(2) 2,521.34 40.12 178.79 2,296.59 2,149.09 -785.91 49.94 5,929,212.63 481,181.38 0.23 -746.21 MWD+IFR-AK-CAZ-SC(2) 2,616.17 40.54 178.97 2,368.88 2,221.38 -847.27 51.14 5,929,151.27 481,182.43 0.46 -805.16 MWD+IFR-AK-CAZ-SC(2) 2,709.17 39.25 177.47 2,440.23 2,292.73 -906.89 52.98 5,929,091.66 481,184.12 1.73 -862.27 MWD+IFR-AK-CAZ-SC(2) 2,801.82 38.04 177.32 2,512.60 2,365.10 -964.68 55.61 5,929,033.86 481,186.60 1.31 -917.42 MWD+IFR-AK-CAZ-SC(2) 2,894.47 38.06 177.92 2,585.56 2,438.06 -1,021.74 57.98 5,928,976.80 481,188.83 0.40 -971.92 MWD+IFR-AK-CAZ-SC(2) 2,961.00 37.46 178.88 2,638.15 2,490.65 -1,062.46 59.12 5,928,936.08 481,189.87 1.27 -1,010.96 INC+TREND(3) NOT an Actual Survey 10 3/4"x 13-1/2" 2,976.14 37.32 179.10 2,650.18 2,502.68 -1,071.65 59.29 5,928,926.89 481,190.01 1.27 -1,019.79 INC+TREND(3) 3,005.91 37.30 179.56 2,673.86 2,526.36 -1,089.70 59.50 5,928,908.85 481,190.18 0.94 -1,037.17 MWD+IFR-AK-CAZ-SC(4) 3,099.74 39.00 179.45 2,747.65 2,600.15 -1,147.65 60.00 5,928,850.90 481,190.53 1.81 -1,093.02 MWD+IFR-AK-CAZ-SC(4) 3,194.63 39.41 177.83 2,821.18 2,673.68 -1,207.61 61.43 5,928,790.94 481,191.81 1.16 -1,150.56 MWD+IFR-AK-CAZ-SC(4) 3,290.11 39.24 177.08 2,895.04 2,747.54 -1,268.06 64.11 5,928,730.49 481,194.35 0.53 -1,208.26 MWD+IFR-AK-CAZ-SC(4) 3,384.55 39.45 176.03 2,968.07 2,820.57 -1,327.82 67.71 5,928,670.73 481,197.79 0.74 -1,265.05 MWD+IFR-AK-CAZ-SC(4) 3,478.20 39.15 174.45 3,040.55 2,893.05 -1,386.93 72.63 5,928,611.61 481,202.57 1.12 -1,320.87 MWD+IFR-AK-CAZ-SC(4) 3,573.32 38.63 172.93 3,114.58 2,967.08 -1,446.28 79.19 5,928,552.25 481,208.98 1.14 -1,376.51 MWD+IFR-AK-CAZ-SC(4) 3,667.27 38.82 171.35 3,187.88 3,040.38 -1,504.50 87.23 5,928,494.02 481,216.87 1.07 -1,430.66 MWD+IFR-AK-CAZ-SC(4) 3,762.83 35.73 169.88 3,263.91 3,116.41 -1,561.59 96.64 5,928,436.91 481,226.13 3.36 -1,483.37 MWD+IFR-AK-CAZ-SC(4) 9/9/2015 8:23:55AM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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) (°1100') (ft) Survey Tool Name 3,857.65 34.29 170.36 3,341.57 3,194.07 -1,615.18 105.97 5,928,383.30 481,235.34 1.55 -1,532.72 MWD+IFR-AK-CAZ-SC(4) 3,952.60 33.41 170.78 3,420.43 3,272.93 -1,667.36 114.64 5,928,331.11 481,243.87 0.96 -1,580.87 MWD+IFR-AK-CAZ-SC(4) 4,046.97 31.83 167.12 3,499.92 3,352.42 -1,717.27 124.35 5,928,281.18 481,253.46 2.68 -1,626.57 MWD+IFR-AK-CAZ-SC(4) 4,141.81 30.32 162.46 3,581.16 3,433.66 -1,764.49 137.15 5,928,233.93 481,266.13 2.99 -1,668.87 MWD+IFR-AK-CAZ-SC(4) 4,236.26 28.34 156.00 3,663.52 3,516.02 -1,807.71 153.45 5,928,190.67 481,282.33 3.95 -1,706.40 MWD+IFR-AK-CAZ-SC(4) 4,330.18 27.21 149.06 3,746.64 3,599.14 -1,846.51 173.57 5,928,151.83 481,302.34 3.65 -1,738.67 MWD+IFR-AK-CAZ-SC(4) 4,424.97 26.54 144.35 3,831.20 3,683.70 -1,882.31 197.06 5,928,115.98 481,325.74 2.35 -1,767.17 MWD+IFR-AK-CAZ-SC(4) 4,519.60 26.62 147.14 3,915.83 3,768.33 -1,917.30 220.88 5,928,080.93 481,349.48 1.32 -1,794.80 MWD+IFR-AK-CAZ-SC(4) 4,614.64 27.00 150.19 4,000.66 3,853.16 -1,953.90 243.16 5,928,044.27 481,371.66 1.50 -1,824.39 MWD+IFR-AK-CAZ-SC(4) 4,708.89 26.67 149.21 4,084.76 3,937.26 -1,990.64 264.62 5,928,007.49 481,393.03 0.59 -1,854.32 MWD+IFR-AK-CAZ-SC(4) 4,802.56 26.75 147.08 4,168.44 4,020.94 -2,026.39 286.84 5,927,971.68 481,415.16 1.03 -1,883.10 MWD+IFR-AK-CAZ-SC(4) 4,895.11 26.79 145.52 4,251.07 4,103.57 -2,061.07 309.97 5,927,936.95 481,438.20 0.76 -1,910.61 MWD+IFR-AK-CAZ-SC(4) 4,991.43 26.57 144.43 4,337.13 4,189.63 -2,096.49 334.79 5,927,901.47 481,462.92 0.56 -1,938.40 MWD+IFR-AK-CAZ-SC(4) 5,086.16 25.63 140.77 4,422.21 4,274.71 -2,129.59 360.07 5,927,868.31 481,488.12 1.97 -1,963.83 MWD+IFR-AK-CAZ-SC(4) 5,181.09 24.29 137.30 4,508.27 4,360.77 -2,159.85 386.30 5,927,837.99 481,514.27 2.09 -1,986.27 MWD+IFR-AK-CAZ-SC(4) 5,276.38 23.24 128.79 4,595.51 4,448.01 -2,186.04 414.25 5,927,811.73 481,542.16 3.76 -2,004.33 MWD+IFR-AK-CAZ-SC(4) 5,370.86 23.57 120.39 4,682.24 4,534.74 -2,207.28 445.09 5,927,790.42 481,572.93 3.55 -2,016.87 MWD+IFR-AK-CAZ-SC(4) 5,464.67 24.37 114.54 4,767.97 4,620.47 -2,224.81 478.88 5,927,772.81 481,606.68 2.67 -2,025.06 MWD+IFR-AK-CAZ-SC(4) 5,559.41 25.62 104.84 4,853.87 4,706.37 -2,238.18 516.47 5,927,759.34 481,644.24 4.52 -2,028.24 MWD+IFR-AK-CAZ-SC(4) 5,654.62 26.69 96.11 4,939.36 4,791.86 -2,245.73 557.65 5,927,751.69 481,685.39 4.19 -2,024.88 MWD+IFR-AK-CAZ-SC(4) 5,749.73 28.00 88.04 5,023.87 4,876.37 -2,247.24 601.22 5,927,750.07 481,728.95 4.13 -2,015.06 MWD+IFR-AK-CAZ-SC(4) 5,844.26 29.19 80.96 5,106.90 4,959.40 -2,242.86 646.17 5,927,754.34 481,773.91 3.80 -1,999.19 MWD+I FR-AK-CAZ-SC(4) 5,939.62 30.42 72.68 5,189.68 5,042.18 -2,232.01 692.21 5,927,765.07 481,819.97 4.50 -1,976.80 MWD+IFR-AK-CAZ-SC(4) 6,034.23 31.84 66.17 5,270.68 5,123.18 -2,214.79 737.92 5,927,782.17 481,865.72 3.86 -1,948.34 MWD+IFR-AK-CAZ-SC(4) 6,128.52 34.04 62.14 5,349.82 5,202.32 -2,192.40 784.01 5,927,804.44 481,911.86 3.29 -1,914.78 MWD+IFR-AK-CAZ-SC(4) 6,221.51 37.28 59.41 5,425.37 5,277.87 -2,165.90 831.28 5,927,830.83 481,959.19 3.88 -1,876.95 MWD+IFR-AK-CAZ-SC(4) 6,319.59 41.18 57.13 5,501.33 5,353.83 -2,133.25 883.99 5,927,863.35 482,011.98 4.24 -1,831.76 MWD+IFR-AK-CAZ-SC(4) 6,411.87 44.36 55.45 5,569.07 5,421.57 -2,098.45 936.09 5,927,898.01 482,064.16 3.66 -1,784.67 MWD+IFR-AK-CAZ-SC(4) 6,506.31 46.45 53.71 5,635.37 5,487.87 -2,059.47 990.88 5,927,936.85 482,119.04 2.57 -1,732.83 MWD+IFR-AK-CAZ-SC(4) 6,600.63 49.11 52.35 5,698.75 5,551.25 -2,017.45 1,046.67 5,927,978.72 482,174.93 3.02 -1,677.81 MWD+IFR-AK-CAZ-SC(4) 6,695.00 51.83 50.23 5,758.81 5,611.31 -1,971.92 1,103.44 5,928,024.11 482,231.81 3.36 -1,619.14 MWD+IFR-AK-CAZ-SC(4) 6,789.58 54.95 50.01 5,815.21 5,667.71 -1,923.24 1,161.69 5,928,072.63 482,290.17 3.30 -1,557.04 MWD+IFR-AK-CAZ-SC(4) 6,884.44 58.25 48.90 5,867.42 5,719.92 -1,871.76 1,221.85 5,928,123.96 482,350.46 3.61 -1,491.75 MWD+IFR-AK-CAZ-SC(4) 6,980.57 61.51 47.36 5,915.66 5,768.16 -1,816.26 1,283.75 5,928,179.30 482,412.48 3.66 -1,422.12 MWD+I FR-AK-CAZ-SC(4) 7,075.25 64.16 46.40 5,958.88 5,811.38 -1,758.68 1,345.22 5,928,236.72 482,474.10 2.94 -1,350.59 MWD+IFR-AK-CAZ-SC(4) 7,167.96 67.24 45.07 5,997.03 5,849.53 -1,699.71 1,405.71 5,928,295.54 482,534.73 3.57 -1,277.97 MWD+I FR-AK-CAZ-SC(4) 7,262.64 68.43 43.09 6,032.75 5,885.25 -1,636.72 1,466.70 5,928,358.37 482,595.87 2.31 -1,201.34 MWD+IFR-AK-CAZ-SC(4) 7,356.98 67.10 40.99 6,068.45 5,920.95 -1,571.88 1,525.18 5,928,423.06 482,654.50 2.50 -1,123.57 MWD+IFR-AK-CAZ-SC(4) 7,451.24 67.96 40.58 6,104.48 5,956.98 -1,505.92 1,582.07 5,928,488.86 482,711.56 1.00 -1,045.14 MWD+I FR-AK-CAZ-SC(4) 7,547.07 68.02 37.84 6,140.40 5,992.90 -1,437.09 1,638.23 5,928,557.54 482,767.88 2.65 -964.12 MWD+IFR-AK-CAZ-SC(4) 9/9/2015 8:23:55AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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 7,639.92 67.92 37.50 6,175.23 6,027.73 -1,368.96 1,690.83 5,928,625.53 482,820.65 0.36 -884.70 MWD+IFR-AK-CAZ-SC(4) 7,734.64 67.98 38.02 6,210.79 6,063.29 -1,299.56 1,744.59 5,928,694.80 482,874.57 0.51 -803.74 MWD+IFR-AK-CAZ-SC(4) 7,810.85 67.95 37.80 6,239.38 6,091.88 -1,243.82 1,787.99 5,928,750.42 482,918.11 0.27 -738.67 MWD+IFR-AK-CAZ-SC(4) 7,868.00 67.80 37.59 6,260.90 6,113.40 -1,201.93 1,820.37 5,928,792.23 482,950.58 0.44 -689.83 MWD+IFR-AK-CAZ-SC(5) 7-5/8"x 9-7/8" NOT an Actual Survey 7,904.92 67.70 37.45 6,274.88 6,127.38 -1,174.83 1,841.18 5,928,819.27 482,971.46 0.44 -658.26 MWD+IFR-AK-CAZ-SC(5) 7,927.22 68.06 37.20 6,283.28 6,135.78 -1,158.40 1,853.70 5,928,835.67 482,984.03 1.92 -639.15 MWD+IFR-AK-CAZ-SC(5) 7,976.56 69.42 36.30 6,301.17 6,153.67 -1,121.55 1,881.21 5,928,872.44 483,011.63 3.24 -596.45 MWD+IFR-AK-CAZ-SC(5) 8,021.99 70.78 35.99 6,316.63 6,169.13 -1,087.06 1,906.41 5,928,906.87 483,036.90 3.06 -556.61 MWD+IFR-AK-CAZ-SC(5) 8,070.03 73.36 35.56 6,331.42 6,183.92 -1,049.98 1,933.12 5,928,943.88 483,063.71 5.44 -513.87 MWD+IFR-AK-CAZ-SC(5) 8,116.43 75.93 34.45 6,343.71 6,196.21 -1,013.33 1,958.79 5,928,980.46 483,089.46 6.00 -471.83 MWD+IFR-AK-CAZ-SC(5) 8,161.90 78.42 33.85 6,353.80 6,206.30 -976.64 1,983.67 5,929,017.08 483,114.44 5.63 -429.95 MWD+IFR-AK-CAZ-SC(5) 8,210.45 80.79 32.46 6,362.56 6,215.06 -936.67 2,009.78 5,929,056.99 483,140.65 5.64 -384.58 MWD+IFR-AK-CAZ-SC(5) 8,249.55 82.49 32.35 6,368.24 6,220.74 -904.01 2,030.51 5,929,089.59 483,161.46 4.36 -347.67 MWD+IFR-AK-CAZ-SC(5) 8,305.12 84.91 31.84 6,374.34 6,226.84 -857.22 2,059.86 5,929,136.30 483,190.91 4.45 -294.88 MWD+IFR-AK-CAZ-SC(5) 8,399.79 89.51 31.37 6,378.95 6,231.45 -776.71 2,109.40 5,929,216.68 483,240.65 4.88 -204.29 MWD+IFR-AK-CAZ-SC(5) 8,494.27 93.63 29.47 6,376.36 6,228.86 -695.29 2,157.21 5,929,297.97 483,288.66 4.80 -113.27 MWD+IFR-AK-CAZ-SC(5) 8,588.74 94.76 29.10 6,369.45 6,221.95 -613.11 2,203.29 5,929,380.03 483,334.95 1.26 -21.97 MWD+IFR-AK-CAZ-SC(5) 8,682.92 95.04 28.77 6,361.41 6,213.91 -530.99 2,248.69 5,929,462.03 483,380.54 0.46 69.11 MWD+IFR-AK-CAZ-SC(5) 8,777.19 95.11 28.78 6,353.07 6,205.57 -448.69 2,293.89 5,929,544.21 483,425.95 0.08 160.31 MWD+IFR-AK-CAZ-SC(5) 8,872.12 94.80 27.94 6,344.87 6,197.37 -365.46 2,338.82 5,929,627.31 483,471.07 0.94 252.32 MWD+IFR-AK-CAZ-SC(5) 8,969.34 94.83 24.90 6,336.70 6,189.20 -278.71 2,381.92 5,929,713.94 483,514.39 3.12 347.27 MWD+IFR-AK-CAZ-SC(5) 9,062.79 91.79 23.10 6,331.31 6,183.81 -193.50 2,419.86 5,929,799.06 483,552.53 3.78 439.40 MWD+IFR-AK-CAZ-SC(5) 9,156.09 90.74 21.97 6,329.25 6,181.75 -107.34 2,455.60 5,929,885.11 483,588.49 1.65 531.87 MWD+IFR-AK-CAZ-SC(5) 9,249.36 90.36 18.95 6,328.35 6,180.85 -19.97 2,488.20 5,929,972.39 483,621.30 3.26 624.70 MWD+IFR-AK-CAZ-SC(5) 9,345.81 91.28 17.54 6,326.97 6,179.47 71.62 2,518.39 5,930,063.90 483,651.72 1.75 720.98 MWD+IFR-AK-CAZ-SC(5) 9,439.81 93.82 13.33 6,322.79 6,175.29 162.11 2,543.38 5,930,154.31 483,676.94 5.23 814.86 MWD+IFR-AK-CAZ-SC(5) 9,485.25 96.05 10.92 6,318.88 6,171.38 206.36 2,552.89 5,930,198.54 483,686.55 7.21 860.07 MWD+IFR-AK-CAZ-SC(5) 9,534.40 95.79 9.61 6,313.81 6,166.31 254.47 2,561.60 5,930,246.62 483,695.39 2.70 908.79 MWD+IFR-AK-CAZ-SC(5) 9,578.50 94.32 9.48 6,309.93 6,162.43 297.79 2,568.89 5,930,289.92 483,702.78 3.35 952.52 MWD+IFR-AK-CAZ-SC(5) 9,628.43 92.45 9.77 6,306.98 6,159.48 346.92 2,577.22 5,930,339.03 483,711.23 3.79 1,002.14 MWD+IFR-AK-CAZ-SC(5) 9,724.17 90.24 9.75 6,304.73 6,157.23 441.25 2,593.44 5,930,433.30 483,727.69 2.31 1,097.44 MWD+IFR-AK-CAZ-SC(5) 9,819.46 90.44 8.34 6,304.17 6,156.67 535.35 2,608.42 5,930,527.35 483,742.90 1.49 1,192.22 MWD+IFR-AK-CAZ-SC(5) 9,914.25 90.40 7.94 6,303.47 6,155.97 629.18 2,621.84 5,930,621.14 483,756.56 0.42 1,286.32 MWD+IFR-AK-CAZ-SC(5) 10,009.12 89.54 6.92 6,303.52 6,156.02 723.25 2,634.11 5,930,715.17 483,769.06 1.41 1,380.37 MWD+IFR-AK-CAZ-SC(5) 10,103.90 89.10 5.87 6,304.64 6,157.14 817.43 2,644.67 5,930,809.32 483,779.85 1.20 1,474.07 MWD+IFR-AK-CAZ-SC(5) 10,195.73 88.02 7.04 6,306.95 6,159.45 908.65 2,654.99 5,930,900.50 483,790.40 1.73 1,564.85 MWD+IFR-AK-CAZ-SC(5) 10,292.26 85.41 6.97 6,312.48 6,164.98 1,004.29 2,666.74 5,930,996.11 483,802.39 2.70 1,660.28 MWD+IFR-AK-CAZ-SC(5) 10,387.11 87.93 6.70 6,317.99 6,170.49 1,098.30 2,678.01 5,931,090.08 483,813.89 2.67 1,754.00 MWD+IFR-AK-CAZ-SC(5) 10,481.40 91.63 6.85 6,318.35 6,170.85 1,191.92 2,689.13 5,931,183.66 483,825.24 3.93 1,847.30 MWD+IFR-AK-CAZ-SC(5) 9/9/2015 8:23:55AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,574.54 91.05 8.18 6,316.18 6,168.68 1,284.23 2,701.31 5,931,275.93 483,837.65 1.56 1,939.62 MWD+IFR-AK-CAZ-SC(5) 10,668.45 90.71 8.99 6,314.73 6,167.23 1,377.08 2,715.32 5,931,368.73 483,851.90 0.94 2,032.93 MWD+IFR-AK-CAZ-SC(5) 10,763.74 89.89 11.01 6,314.23 6,166.73 1,470.91 2,731.87 5,931,462.51 483,868.68 2.29 2,127.85 MWD+I FR-AK-CAZ-SC(5) 10,858.59 89.72 11.17 6,314.56 6,167.06 1,563.99 2,750.11 5,931,555.54 483,887.15 0.25 2,222.48 MWD+I FR-AK-CAZ-SC(5) 10,954.75 89.65 11.92 6,315.09 6,167.59 1,658.20 2,769.36 5,931,649.69 483,906.63 0.78 2,318.46 MWD+IFR-AK-CAZ-SC(5) 11,048.50 90.16 12.96 6,315.24 6,167.74 1,749.75 2,789.55 5,931,741.18 483,927.05 1.24 2,412.12 MWD+I FR-AK-CAZ-SC(5) 11,143.83 90.84 13.01 6,314.41 6,166.91 1,842.64 2,810.97 5,931,834.00 483,948.70 0.72 2,507.38 MWD+I FR-AK-CAZ-SC(5) 11,236.97 89.32 12.82 6,314.28 6,166.78 1,933.42 2,831.79 5,931,924.72 483,969.74 1.64 2,600.46 MWD+IFR-AK-CAZ-SC(5) 11,333.53 90.11 13.92 6,314.76 6,167.26 2,027.36 2,854.12 5,932,018.60 483,992.30 1.40 2,696.98 MWD+IFR-AK-CAZ-SC(5) 11,427.14 92.87 14.70 6,312.33 6,164.83 2,118.02 2,877.25 5,932,109.20 484,015.65 3.06 2,790.54 MWD+IFR-AK-CAZ-SC(5) 11,522.13 95.45 13.75 6,305.44 6,157.94 2,209.85 2,900.52 5,932,200.95 484,039.16 2.89 2,885.26 MWD+I FR-AK-CAZ-SC(5) 11,615.99 95.20 13.77 6,296.73 6,149.23 2,300.62 2,922.75 5,932,291.66 484,061.61 0.27 2,978.69 MWD+I FR-AK-CAZ-SC(5) 11,709.50 92.72 12.41 6,290.27 6,142.77 2,391.48 2,943.88 5,932,382.45 484,082.96 3.02 3,071.92 MWD+I FR-AK-CAZ-SC(5) 11,803.84 92.44 14.95 6,286.02 6,138.52 2,483.04 2,966.16 5,932,473.95 484,105.48 2.71 3,166.13 MWD+I FR-AK-CAZ-SC(5) 11,898.32 90.63 15.77 6,283.49 6,135.99 2,574.11 2,991.18 5,932,564.95 484,130.72 2.10 3,260.57 MWD+IFR-AK-CAZ-SC(5) 11,992.18 90.55 15.93 6,282.52 6,135.02 2,664.39 3,016.81 5,932,655.16 484,156.57 0.19 3,354.41 MWD+IFR-AK-CAZ-SC(5) 12,088.34 89.13 15.52 6,282.79 6,135.29 2,756.95 3,042.87 5,932,747.64 484,182.86 1.54 3,450.56 MWD+I FR-AK-CAZ-SC(5) 12,181.52 88.79 14.72 6,284.48 6,136.98 2,846.89 3,067.18 5,932,837.51 484,207.39 0.93 3,543.73 MWD+I FR-AK-CAZ-SC(5) 12,275.31 88.48 13.43 6,286.72 6,139.22 2,937.84 3,089.98 5,932,928.39 484,230.41 1.41 3,637.48 MWD+IFR-AK-CAZ-SC(5) 12,370.16 87.73 13.31 6,289.85 6,142.35 3,030.06 3,111.90 5,933,020.56 484,252.56 0.80 3,732.24 MWD+IFR-AK-CAZ-SC(5) 12,466.11 87.86 12.20 6,293.55 6,146.05 3,123.58 3,133.07 5,933,114.01 484,273.96 1.16 3,828.04 MWD+IFR-AK-CAZ-SC(5) 12,561.11 88.82 12.97 6,296.30 6,148.80 3,216.25 3,153.76 5,933,206.62 484,294.88 1.30 3,922.91 MWD+IFR-AK-CAZ-SC(5) 12,654.82 89.10 12.34 6,298.00 6,150.50 3,307.67 3,174.28 5,933,297.98 484,315.64 0.74 4,016.53 MWD+IFR-AK-CAZ-SC(5) 12,748.56 90.37 13.71 6,298.43 6,150.93 3,398.99 3,195.41 5,933,389.24 484,336.99 1.99 4,110.21 MWD+IFR-AK-CAZ-SC(5) 12,843.28 91.04 17.26 6,297.27 6,149.77 3,490.25 3,220.69 5,933,480.43 484,362.50 3.81 4,204.90 MWD+I FR-AK-CAZ-SC(5) 12,938.02 93.15 18.17 6,293.80 6,146.30 3,580.43 3,249.50 5,933,570.53 484,391.52 2.43 4,299.47 MWD+IFR-AK-CAZ-SC(5) 13,031.26 95.17 18.01 6,287.04 6,139.54 3,668.83 3,278.37 5,933,658.84 484,420.62 2.17 4,392.32 MWD+IFR-AK-CAZ-SC(5) 13,125.89 95.15 16.67 6,278.53 6,131.03 3,758.79 3,306.46 5,933,748.72 484,448.93 1.41 4,486.49 MWD+I FR-AK-CAZ-SC(5) 13,222.71 94.07 15.10 6,270.75 6,123.25 3,851.61 3,332.87 5,933,841.46 484,475.57 1.96 4,582.98 MWD+I FR-AK-CAZ-SC(5) 13,316.54 90.47 14.99 6,267.03 6,119.53 3,942.13 3,357.21 5,933,931.92 484,500.13 3.84 4,676.72 MWD+I FR-AK-CAZ-SC(5) 13,411.67 87.80 14.24 6,268.47 6,120.97 4,034.17 3,381.20 5,934,023.88 484,524.35 2.92 4,771.83 MWD+IFR-AK-CAZ-SC(5) 13,506.90 88.76 12.30 6,271.32 6,123.82 4,126.81 3,403.05 5,934,116.46 484,546.43 2.27 4,866.96 MWD+I FR-AK-CAZ-SC(5) 13,600.65 89.82 12.60 6,272.49 6,124.99 4,218.34 3,423.26 5,934,207.94 484,566.86 1.18 4,960.61 MWD+IFR-AK-CAZ-SC(5) 13,695.82 90.38 12.14 6,272.32 6,124.82 4,311.30 3,443.65 5,934,300.83 484,587.48 0.76 5,055.68 MWD+I FR-AK-CAZ-SC(5) 13,790.56 89.89 11.52 6,272.10 6,124.60 4,404.03 3,463.07 5,934,393.50 484,607.13 0.83 5,150.28 MWD+I FR-AK-CAZ-SC(5) 13,885.48 89.85 12.03 6,272.31 6,124.81 4,496.95 3,482.44 5,934,486.37 484,626.73 0.54 5,245.04 MWD+IFR-AK-CAZ-SC(5) 13,979.56 89.82 11.93 6,272.58 6,125.08 4,588.98 3,501.97 5,934,578.34 484,646.49 0.11 5,338.99 MWD+IFR-AK-CAZ-SC(5) 14,075.39 89.17 13.18 6,273.43 6,125.93 4,682.52 3,522.80 5,934,671.81 484,667.55 1.47 5,434.73 MWD+IFR-AK-CAZ-SC(5) 14,168.58 88.45 15.27 6,275.36 6,127.86 4,772.82 3,545.69 5,934,762.05 484,690.67 2.37 5,527.89 MWD+IFR-AK-CAZ-SC(5) 14,261.97 88.55 16.41 6,277.81 6,130.31 4,862.63 3,571.17 5,934,851.79 484,716.37 1.22 5,621.23 MWD+IFR-AK-CAZ-SC(5) 9/9/2015 8:23:55AM Page 6 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,307.38 88.86 16.77 6,278.83 6,131.33 4,906.14 3,584.14 5,934,895.26 484,729.44 1.05 5,666.61 MWD+IFR-AK-CAZ-SC(5) 14,380.00 88.86 16.77 6,280.28 6,132.78 4,975.66 3,605.09 5,934,964.72 484,750.56 0.00 5,739.18 NOT an Actual Survey 4 1/2"x 6-3/4" 14,390.00 88.86 16.77 6,280.48 6,132.98 4,985.23 3,607.97 5,934,974.28 484,753.47 0.00 5,749.18 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes ❑ No have checked to the best of my ability that the following data is correct: Q Surface Coordinates [7] Declination & Convergence Q GRS Survey Corrections ]] Survey Tool Codes DY9Yal!zed t Vr t Osa'n Vincent Osara°� °.5[Nund>Plpr.°4-5diUPbotyel. SLB DE: 2O1S. t TM`-'~ DgWrsigned by Wi6in Gua Client Representative: H bin Guo D DtthGun, wDf �gbwaus, amai-iOdinGuoeo US Date: 09-Sep-2015 9/9/2015 8:23:55AM Page 7 COMPASS 5000.1 Build 74 • • 215079 26230 FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-07 EntD SEP 0 S ZUt. Definitive Survey Report 08 September, 2015 NAD 83 • • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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-07 Well Position +N/-S 0.00 usft Northing: 5,929,748.17 usfl Latitude: 70° 13'10.563 Nil +E/-W 0.00 usft Easting: 1,621,166.73 usfi Longitude: 150°9'19.086 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-07 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 7/31/2015 18.66 80.87 57,490 Design 2S-07 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) (°) 27.50 0.00 0.00 15.00 Survey Program Date 9/8/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 96.99 289.73 2S-07 Srvy#1 INC+TREND(2S-07) INC+TREND Inclinometer+known azi trend 7/23/2015 9:2 383.23 2,894.47 2S-07 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/23/2015 9:31 2,976.14 2,976.14 2S-07 Srvy#3 INC TREND(2S-07) INC+TREND Inclinometer+known azi trend 7/30/2015 3:3. 3,005.91 7,810.85 2S-07 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/3/2015 9:44 7,904.92 14,307.38 2S-07 Srvy#5 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/12/2015 2:4 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-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 5,929,748.17 1,621,166.73 0.00 0.00 UNDEFINED 96.99 0.23 343.08 96.99 -50.51 0.13 -0.04 5,929,748.30 1,621,166.69 0.33 0.12 INC+TREND(1) 106.00 0.26 337.47 106.00 -41.50 0.17 -0.05 5,929,748.34 1,621,166.68 0.38 0.15 INC+TREND/1I NOT an Actual Survey 16"x 42" 195.23 0.56 314.04 195.23 47.73 0.66 -0.44 5,929,748.83 1,621,166.29 0.38 0.52 INC+TREND(1) 246.18 0.30 318.25 246.18 98.68 0.93 -0.71 5,929,749.10 1,621,166.02 0.51 0.71 INC+TREND(1) 289.73 0.15 293.72 289.73 142.23 1.04 -0.84 5,929,749.21 1,621,165.89 0.40 0.78 INC+TREND(1) 383.23 0.54 213.01 383.22 235.72 0.72 -1.19 5,929,748.89 1,621,165.54 0.57 0.38 MWD+IFR-AK-CAZ-SC(2) 474.85 1.79 180.92 474.82 327.32 -1.08 -1.45 5,929,747.10 1,621,165.28 1.49 -1.42 MWD+IFR-AK-CAZ-SC(2) 566.12 2.13 181.18 566.04 418.54 -4.20 -1.51 5,929,743.98 1,621,165.21 0.37 -4.44 MWD+IFR-AK-CAZ-SC(2) 658.12 3.12 173.58 657.94 510.44 -8.40 -1.26 5,929,739.78 1,621,165.45 1.14 -8.44 MWD+IFR-AK-CAZ-SC(2) 9/8/2015 2:48:34PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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) (°11001 (ft) Survey Tool Name 750.77 5.18 167.99 750.35 602.85 -14.99 -0.11 5,929,733.18 1,621,166.58 2.26 -14.51 MWD+IFR-AK-CAZ-SC(2) 843.37 5.61 167.15 842.54 695.04 -23.49 1.77 5,929,724.67 1,621,168.44 0.47 -22.24 MWD+IFR-AK-CAZ-SC(2) 895.14 6.68 170.69 894.01 746.51 -28.93 2.82 5,929,719.23 1,621,169.47 2.19 -27.22 MWD+IFR-AK-CAZ-SC(2) 937.24 7.76 172.40 935.77 788.27 -34.17 3.59 5,929,714.00 1,621,170.23 2.62 -32.07 MWD+IFR-AK-CAZ-SC(2) 1,031.04 9.81 174.56 1,028.47 880.97 -48.40 5.18 5,929,699.76 1,621,171.79 2.21 -45.41 MWD+IFR-AK-CAZ-SC(2) 1,124.37 12.71 175.01 1,119.99 972.49 -66.55 6.83 5,929,681.61 1,621,173.39 3.11 -62.51 MWD+IFR-AK-CAZ-SC(2) 1,218.31 14.49 175.18 1,211.29 1,063.79 -88.55 8.72 5,929,659.60 1,621,175.22 1.90 -83.28 MWD+IFR-AK-CAZ-SC(2) 1,264.41 17.25 175.22 1,255.63 1,108.13 -101.12 9.77 5,929,647.04 1,621,176.24 5.99 -95.14 MWD+IFR-AK-CAZ-SC(2) 1,312.33 20.57 175.04 1,300.96 1,153.46 -116.59 11.09 5,929,631.57 1,621,177.52 6.93 -109.74 MWD+IFR-AK-CAZ-SC(2) 1,361.42 21.66 175.04 1,346.75 1,199.25 -134.20 12.62 5,929,613.95 1,621,179.01 2.22 -126.37 MWD+IFR-AK-CAZ-SC(2) 1,404.80 21.07 173.97 1,387.15 1,239.65 -149.94 14.13 5,929,598.21 1,621,180.48 1.63 -141.17 MWD+IFR-AK-CAZ-SC(2) 1,497.81 24.67 172.15 1,472.84 1,325.34 -185.80 18.54 5,929,562.34 1,621,184.80 3.94 -174.67 MWD+IFR-AK-CAZ-SC(2) 1,590.70 29.25 173.52 1,555.61 1,408.11 -227.58 23.75 5,929,520.55 1,621,189.90 4.98 -213.68 MWD+IFR-AK-CAZ-SC(2) 1,683.95 29.48 173.67 1,636.88 1,489.38 -273.02 28.85 5,929,475.10 1,621,194.88 0.26 -256.25 MWD+IFR-AK-CAZ-SC(2) 1,776.06 31.24 176.14 1,716.36 1,568.86 -319.38 32.96 5,929,428.74 1,621,198.87 2.34 -299.97 MWD+IFR-AK-CAZ-SC(2) 1,869.93 36.30 177.46 1,794.37 1,646.87 -371.46 35.83 5,929,376.65 1,621,201.61 5.45 -349.53 MWD+IFR-AK-CAZ-SC(2) 1,918.82 39.03 176.53 1,833.06 1,685.56 -401.29 37.41 5,929,346.82 1,621,203.11 5.70 -377.94 MWD+IFR-AK-CAZ-SC(2) 1,962.67 38.36 176.79 1,867.29 1,719.79 -428.66 39.00 5,929,319.46 1,621,204.64 1.57 -403.96 MWD+IFR-AK-CAZ-SC(2) 2,055.37 38.74 176.81 1,939.79 1,792.29 -486.34 42.23 5,929,261.77 1,621,207.71 0.41 -458.84 MWD+IFR-AK-CAZ-SC(2) 2,150.20 40.20 178.59 2,012.99 1,865.49 -546.57 44.63 5,929,201.55 1,621,209.96 1.95 -516.39 MWD+IFR-AK-CAZ-SC(2) 2,243.27 40.17 178.27 2,084.09 1,936.59 -606.60 46.28 5,929,141.52 1,621,211.46 0.22 -573.95 MWD+IFR-AK-CAZ-SC(2) 2,336.09 40.12 178.88 2,155.05 2,007.55 -666.42 47.77 5,929,081.70 1,621,212.79 0.43 -631.35 MWD+IFR-AK-CAZ-SC(2) 2,428.45 40.23 179.08 2,225.62 2,078.12 -725.99 48.83 5,929,022.13 1,621,213.70 0.18 -688.62 MWD+IFR-AK-CAZ-SC(2) 2,521.34 40.12 178.79 2,296.59 2,149.09 -785.91 49.94 5,928,962.21 1,621,214.66 0.23 -746.21 MWD+IFR-AK-CAZ-SC(2) 2,616.17 40.54 178.97 2,368.88 2,221.38 -847.27 51.14 5,928,900.86 1,621,215.70 0.46 -805.16 MWD+IFR-AK-CAZ-SC(2) 2,709.17 39.25 177.47 2,440.23 2,292.73 -906.89 52.98 5,928,841.24 1,621,217.39 1.73 -862.27 MWD+IFR-AK-CAZ-SC(2) 2,801.82 38.04 177.32 2,512.60 2,365.10 -964.68 55.61 5,928,783.44 1,621,219.88 1.31 -917.42 MWD+IFR-AK-CAZ-SC(2) 2,894.47 38.06 177.92 2,585.56 2,438.06 -1,021.74 57.98 5,928,726.39 1,621,222.10 0.40 -971.92 MWD+IFR-AK-CAZ-SC(2) 2,961.00 37.46 178.88 2,638.15 2,490.65 -1,062.46 59.12 5,928,685.67 1,621,223.14 1.27 -1,010.96 INC+TRENt{fQ1 NOT an Actual Survey 10314"x13-1/2" 2,976.14 37.32 179.10 2,650.18 2,502.68 -1,071.65 59.29 5,928,676.48 1,621,223.28 1.27 -1,019.79 INC+TREND(3) 3,005.91 37.30 179.56 2,673.86 2,526.36 -1,089.70 59.50 5,928,658.43 1,621,223.44 0.94 -1,037.17 MWD+IFR-AK-CAZ-SC(4) 3,099.74 39.00 179.45 2,747.65 2,600.15 -1,147.65 60.00 5,928,600.48 1,621,223.79 1.81 -1,093.02 MWD+IFR-AK-CAZ-SC(4) 3,194.63 39.41 177.83 2,821.18 2,673.68 -1,207.61 61.43 5,928,540.53 1,621,225.07 1.16 -1,150.56 MWD+IFR-AK-CAZ-SC(4) 3,290.11 39.24 177.08 2,895.04 2,747.54 -1,268.06 64.11 5,928,480.08 1,621,227.60 0.53 -1,208.26 MWD+IFR-AK-CAZ-SC(4) 3,384.55 39.45 176.03 2,968.07 2,820.57 -1,327.82 67.71 5,928,420.31 1,621,231.05 0.74 -1,265.05 MWD+IFR-AK-CAZ-SC(4) 3,478.20 39.15 174.45 3,040.55 2,893.05 -1,386.93 72.63 5,928,361.20 1,621,235.81 1.12 -1,320.87 MWD+IFR-AK-CAZ-SC(4) 3,573.32 38.63 172.93 3,114.58 2,967.08 -1,446.28 79.19 5,928,301.83 1,621,242.22 1.14 -1,376.51 MWD+IFR-AK-CAZ-SC(4) 3,667.27 38.82 171.35 3,187.88 3,040.38 -1,504.50 87.23 5,928,243.60 1,621,250.11 1.07 -1,430.66 MWD+IFR-AK-CAZ-SC(4) 3,762.83 35.73 169.88 3,263.91 3,116.41 -1,561.59 96.64 5,928,186.49 1,621,259.37 3.36 -1,483.37 MWD+IFR-AK-CAZ-SC(4) 9/8/2015 2:48:34PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5©147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,857.65 34.29 170.36 3,341.57 3,194.07 -1,615.18 105.97 5,928,132.88 1,621,268.57 1.55 -1,532.72 MWD+IFR-AK-CAZ-SC(4) 3,952.60 33.41 170.78 3,420.43 3,272.93 -1,667.36 114.64 5,928,080.69 1,621,277.11 0.96 -1,580.87 MWD+IFR-AK-CAZ-SC(4) 4,046.97 31.83 167.12 3,499.92 3,352.42 -1,717.27 124.35 5,928,030.76 1,621,286.69 2.68 -1,626.57 MWD+IFR-AK-CAZ-SC(4) 4,141.81 30.32 162.46 3,581.16 3,433.66 -1,764.49 137.15 5,927,983.52 1,621,299.36 2.99 -1,668.87 MWD+IFR-AK-CAZ-SC(4) 4,236.26 28.34 156.00 3,663.52 3,516.02 -1,807.71 153.45 5,927,940.25 1,621,315.56 3.95 -1,706.40 MWD+IFR-AK-CAZ-SC(4) 4,330.18 27.21 149.06 3,746.64 3,599.14 -1,846.51 173.57 5,927,901.41 1,621,335.57 3.65 -1,738.67 MWD+IFR-AK-CAZ-SC(4) 4,424.97 26.54 144.35 3,831.20 3,683.70 -1,882.31 197.06 5,927,865.55 1,621,358.96 2.35 -1,767.17 MWD+IFR-AK-CAZ-SC(4) 4,519.60 26.62 147.14 3,915.83 3,768.33 -1,917.30 220.88 5,927,830.51 1,621,382.70 1.32 -1,794.80 MWD+IFR-AK-CAZ-SC(4) 4,614.64 27.00 150.19 4,000.66 3,853.16 -1,953.90 243.16 5,927,793.85 1,621,404.88 1.50 -1,824.39 MWD+IFR-AK-CAZ-SC(4) 4,708.89 26.67 149.21 4,084.76 3,937.26 -1,990.64 264.62 5,927,757.06 1,621,426.25 0.59 -1,854.32 MWD+IFR-AK-CAZ-SC(4) 4,802.56 26.75 147.08 4,168.44 4,020.94 -2,026.39 286.84 5,927,721.25 1,621,448.37 1.03 -1,883.10 MWD+IFR-AK-CAZ-SC(4) 4,895.11 26.79 145.52 4,251.07 4,103.57 -2,061.07 309.97 5,927,686.52 1,621,471.41 0.76 -1,910.61 MWD+IFR-AK-CAZ-SC(4) 4,991.43 26.57 144.43 4,337.13 4,189.63 -2,096.49 334.79 5,927,651.05 1,621,496.14 0.56 -1,938.40 MWD+IFR-AK-CAZ-SC(4) 5,086.16 25.63 140.77 4,422.21 4,274.71 -2,129.59 360.07 5,927,617.88 1,621,521.33 1.97 -1,963.83 MWD+IFR-AK-CAZ-SC(4) 5,181.09 24.29 137.30 4,508.27 4,360.77 -2,159.85 386.30 5,927,587.56 1,621,547.48 2.09 -1,986.27 MWD+IFR-AK-CAZ-SC(4) 5,276.38 23.24 128.79 4,595.51 4,448.01 -2,186.04 414.25 5,927,561.30 1,621,575.37 3.76 -2,004.33 MWD+IFR-AK-CAZ-SC(4) 5,370.86 23.57 120.39 4,682.24 4,534.74 -2,207.28 445.09 5,927,539.99 1,621,606.14 3.55 -2,016.87 MWD+IFR-AK-CAZ-SC(4) 5,464.67 24.37 114.54 4,767.97 4,620.47 -2,224.81 478.88 5,927,522.37 1,621,639.88 2.67 -2,025.06 MWD+IFR-AK-CAZ-SC(4) 5,559.41 25.62 104.84 4,853.87 4,706.37 -2,238.18 516.47 5,927,508.91 1,621,677.44 4.52 -2,028.24 MWD+IFR-AK-CAZ-SC(4) 5,654.62 26.69 96.11 4,939.36 4,791.86 -2,245.73 557.65 5,927,501.25 1,621,718.59 4.19 -2,024.88 MWD+IFR-AK-CAZ-SC(4) 5,749.73 28.00 88.04 5,023.87 4,876.37 -2,247.24 601.22 5,927,499.63 1,621,762.15 4.13 -2,015.06 MWD+IFR-AK-CAZ-SC(4) 5,844.26 29.19 80.96 5,106.90 4,959.40 -2,242.86 646.17 5,927,503.90 1,621,807.12 3.80 -1,999.19 MWD+IFR-AK-CAZ-SC(4) 5,939.62 30.42 72.68 5,189.68 5,042.18 -2,232.01 692.21 5,927,514.62 1,621,853.17 4.50 -1,976.80 MWD+IFR-AK-CAZ-SC(4) 6,034.23 31.84 66.17 5,270.68 5,123.18 -2,214.79 737.92 5,927,531.73 1,621,898.92 3.86 -1,948.34 MWD+IFR-AK-CAZ-SC(4) 6,128.52 34.04 62.14 5,349.82 5,202.32 -2,192.40 784.01 5,927,553.99 1,621,945.07 3.29 -1,914.78 MWD+IFR-AK-CAZ-SC(4) 6,221.51 37.28 59.41 5,425.37 5,277.87 -2,165.90 831.28 5,927,580.37 1,621,992.40 3.88 -1,876.95 MWD+IFR-AK-CAZ-SC(4) 6,319.59 41.18 57.13 5,501.33 5,353.83 -2,133.25 883.99 5,927,612.89 1,622,045.19 4.24 -1,831.76 MWD+IFR-AK-CAZ-SC(4) 6,411.87 44.36 55.45 5,569.07 5,421.57 -2,098.45 936.09 5,927,647.55 1,622,097.38 3.66 -1,784.67 MWD+IFR-AK-CAZ-SC(4) 6,506.31 46.45 53.71 5,635.37 5,487.87 -2,059.47 990.88 5,927,686.39 1,622,152.26 2.57 -1,732.83 MWD+IFR-AK-CAZ-SC(4) 6,600.63 49.11 52.35 5,698.75 5,551.25 -2,017.45 1,046.67 5,927,728.26 1,622,208.15 3.02 -1,677.81 MWD+IFR-AK-CAZ-SC(4) 6,695.00 51.83 50.23 5,758.81 5,611.31 -1,971.92 1,103.44 5,927,773.64 1,622,265.03 3.36 -1,619.14 MWD+IFR-AK-CAZ-SC(4) 6,789.58 54.95 50.01 5,815.21 5,667.71 -1,923.24 1,161.69 5,927,822.16 1,622,323.40 3.30 -1,557.04 MWD+I FR-AK-CAZ-SC(4) 6,884.44 58.25 48.90 5,867.42 5,719.92 -1,871.76 1,221.85 5,927,873.48 1,622,383.68 3.61 -1,491.75 MWD+IFR-AK-CAZ-SC(4) 6,980.57 61.51 47.36 5,915.66 5,768.16 -1,816.26 1,283.75 5,927,928.82 1,622,445.71 3.66 -1,422.12 MWD+I FR-AK-CAZ-SC(4) 7,075.25 64.16 46.40 5,958.88 5,811.38 -1,758.68 1,345.22 5,927,986.24 1,622,507.33 2.94 -1,350.59 MWD+IFR-AK-CAZ-SC(4) 7,167.96 67.24 45.07 5,997.03 5,849.53 -1,699.71 1,405.71 5,928,045.05 1,622,567.96 3.57 -1,277.97 MWD+IFR-AK-CAZ-SC(4) 7,262.64 68.43 43.09 6,032.75 5,885.25 -1,636.72 1,466.70 5,928,107.88 1,622,629.10 2.31 -1,201.34 MWD+I FR-AK-CAZ-SC(4) 7,356.98 67.10 40.99 6,068.45 5,920.95 -1,571.88 1,525.18 5,928,172.57 1,622,687.74 2.50 -1,123.57 MWD+I FR-AK-CAZ-SC(4) 7,451.24 67.96 40.58 6,104.48 5,956.98 -1,505.92 1,582.07 5,928,238.37 1,622,744.80 1.00 -1,045.14 MWD+IFR-AK-CAZ-SC(4) 7,547.07 68.02 37.84 6,140.40 5,992.90 -1,437.09 1,638.23 5,928,307.05 1,622,801.13 2.65 -964.12 MWD+IFR-AK-CAZ-SC(4) 9/8/2015 2:48:34PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 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) (°/100') (ft) Survey Tool Name 7,639.92 67.92 37.50 6,175.23 6,027.73 -1,368.96 1,690.83 5,928,375.04 1,622,853.89 0.36 -884.70 MWD+IFR-AK-CAZ-SC(4) 7,734.64 67.98 38.02 6,210.79 6,063.29 -1,299.56 1,744.59 5,928,444.30 1,622,907.83 0.51 -803.74 MWD+IFR-AK-CAZ-SC(4) 7,810.85 67.95 37.80 6,239.38 6,091.88 -1,243.82 1,787.99 5,928,499.92 1,622,951.37 0.27 -738.67 MWD+IFR-AK-CAZ-SC(4) 7,868.00 67.80 37.59 6,260.90 6,113.40 -1,201.93 1,820.37 5,928,541.72 1,622,983.84 0.44 -689.83 MWD+IFR-AK-r.A7 SC ( 1 NOT an Actual Survey 7-5/8"x 9-7/8" 7,904.92 67.70 37.45 6,274.88 6,127.38 -1,174.83 1,841.18 5,928,568.77 1,623,004.72 0.44 -658.26 MWD+IFR-AK-CAZ-SC(5) 7,927.22 68.06 37.20 6,283.28 6,135.78 -1,158.40 1,853.70 5,928,585.16 1,623,017.29 1.92 -639.15 MWD+IFR-AK-CAZ-SC(5) 7,976.56 69.42 36.30 6,301.17 6,153.67 -1,121.55 1,881.21 5,928,621.93 1,623,044.89 3.24 -596.45 MWD+IFR-AK-CAZ-SC(5) 8,021.99 70.78 35.99 6,316.63 6,169.13 -1,087.06 1,906.41 5,928,656.36 1,623,070.17 3.06 -556.61 MWD+IFR-AK-CAZ-SC(5) 8,070.03 73.36 35.56 6,331.42 6,183.92 -1,049.98 1,933.12 5,928,693.37 1,623,096.98 5.44 -513.87 MWD+IFR-AK-CAZ-SC(5) 8,116.43 75.93 34.45 6,343.71 6,196.21 -1,013.33 1,958.79 5,928,729.95 1,623,122.73 6.00 -471.83 MWD+IFR-AK-CAZ-SC(5) 8,161.90 78.42 33.85 6,353.80 6,206.30 -976.64 1,983.67 5,928,766.57 1,623,147.71 5.63 -429.95 MWD+IFR-AK-CAZ-SC(5) 8,210.45 80.79 32.46 6,362.56 6,215.06 -936.67 2,009.78 5,928,806.47 1,623,173.92 5.64 -384.58 MWD+IFR-AK-CAZ-SC(5) 8,249.55 82.49 32.35 6,368.24 6,220.74 -904.01 2,030.51 5,928,839.08 1,623,194.73 4.36 -347.67 MWD+IFR-AK-CAZ-SC(5) 8,305.12 84.91 31.84 6,374.34 6,226.84 -857.22 2,059.86 5,928,885.79 1,623,224.19 4.45 -294.88 MWD+IFR-AK-CAZ-SC(5) 8,399.79 89.51 31.37 6,378.95 6,231.45 -776.71 2,109.40 5,928,966.16 1,623,273.93 4.88 -204.29 MWD+IFR-AK-CAZ-SC(5) 8,494.27 93.63 29.47 6,376.36 6,228.86 -695.29 2,157.21 5,929,047.45 1,623,321.94 4.80 -113.27 MWD+IFR-AK-CAZ-SC(5) 8,588.74 94.76 29.10 6,369.45 6,221.95 -613.11 2,203.29 5,929,129.50 1,623,368.23 1.26 -21.97 MWD+IFR-AK-CAZ-SC(5) 8,682.92 95.04 28.77 6,361.41 6,213.91 -530.99 2,248.69 5,929,211.50 1,623,413.84 0.46 69.11 MWD+IFR-AK-CAZ-SC(5) 8,777.19 95.11 28.78 6,353.07 6,205.57 -448.69 2,293.89 5,929,293.68 1,623,459.24 0.08 160.31 MWD+IFR-AK-CAZ-SC(5) 8,872.12 94.80 27.94 6,344.87 6,197.37 -365.46 2,338.82 5,929,376.78 1,623,504.37 0.94 252.32 MWD+IFR-AK-CAZ-SC(5) 8,969.34 94.83 24.90 6,336.70 6,189.20 -278.71 2,381.92 5,929,463.41 1,623,547.69 3.12 347.27 MWD+IFR-AK-CAZ-SC(5) 9,062.79 91.79 23.10 6,331.31 6,183.81 -193.50 2,419.86 5,929,548.52 1,623,585.84 3.78 439.40 MWD+IFR-AK-CAZ-SC(5) 9,156.09 90.74 21.97 6,329.25 6,181.75 -107.34 2,455.60 5,929,634.57 1,623,621.81 1.65 531.87 MWD+IFR-AK-CAZ-SC(5) 9,249.36 90.36 18.95 6,328.35 6,180.85 -19.97 2,488.20 5,929,721.85 1,623,654.62 3.26 624.70 MWD+IFR-AK-CAZ-SC(5) 9,345.81 91.28 17.54 6,326.97 6,179.47 71.62 2,518.39 5,929,813.36 1,623,685.05 1.75 720.98 MWD+IFR-AK-CAZ-SC(5) 9,439.81 93.82 13.33 6,322.79 6,175.29 162.11 2,543.38 5,929,903.77 1,623,710.26 5.23 814.86 MWD+IFR-AK-CAZ-SC(5) 9,485.25 96.05 10.92 6,318.88 6,171.38 206.36 2,552.89 5,929,948.00 1,623,719.88 7.21 860.07 MWD+IFR-AK-CAZ-SC(5) 9,534.40 95.79 9.61 6,313.81 6,166.31 254.47 2,561.60 5,929,996.08 1,623,728.72 2.70 908.79 MWD+IFR-AK-CAZ-SC(5) 9,578.50 94.32 9.48 6,309.93 6,162.43 297.79 2,568.89 5,930,039.37 1,623,736.11 3.35 952.52 MWD+IFR-AK-CAZ-SC(5) 9,628.43 92.45 9.77 6,306.98 6,159.48 346.92 2,577.22 5,930,088.49 1,623,744.57 3.79 1,002.14 MWD+IFR-AK-CAZ-SC(5) 9,724.17 90.24 9.75 6,304.73 6,157.23 441.25 2,593.44 5,930,182.76 1,623,761.03 2.31 1,097.44 MWD+IFR-AK-CAZ-SC(5) 9,819.46 90.44 8.34 6,304.17 6,156.67 535.35 2,608.42 5,930,276.81 1,623,776.25 1.49 1,192.22 MWD+IFR-AK-CAZ-SC(5) 9,914.25 90.40 7.94 6,303.47 6,155.97 629.18 2,621.84 5,930,370.60 1,623,789.91 0.42 1,286.32 MWD+IFR-AK-CAZ-SC(5) 10,009.12 89.54 6.92 6,303.52 6,156.02 723.25 2,634.11 5,930,464.63 1,623,802.42 1.41 1,380.37 MWD+IFR-AK-CAZ-SC(5) 10,103.90 89.10 5.87 6,304.64 6,157.14 817.43 2,644.67 5,930,558.77 1,623,813.21 1.20 1,474.07 MWD+IFR-AK-CAZ-SC(5) 10,195.73 88.02 7.04 6,306.95 6,159.45 908.65 2,654.99 5,930,649.96 1,623,823.76 1.73 1,564.85 MWD+IFR-AK-CAZ-SC(5) 10,292.26 85.41 6.97 6,312.48 6,164.98 1,004.29 2,666.74 5,930,745.56 1,623,835.76 2.70 1,660.28 MWD+IFR-AK-CAZ-SC(5) 10,387.11 87.93 6.70 6,317.99 6,170.49 1,098.30 2,678.01 5,930,839.53 1,623,847.26 2.67 1,754.00 MWD+IFR-AK-CAZ-SC(5) 10,481.40 91.63 6.85 6,318.35 6,170.85 1,191.92 2,689.13 5,930,933.11 1,623,858.62 3.93 1,847.30 MWD+IFR-AK-CAZ-SC(5) 9/8/2015 2:48:34PM Page 5 COMPASS 5000.1 Build 74 • ' • Schlumberger i Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,574.54 91.05 8.18 6,316.18 6,168.68 1,284.23 2,701.31 5,931,025.38 1,623,871.04 1.56 1,939.62 MWD+IFR-AK-CAZ-SC(5) 10,668.45 90.71 8.99 6,314.73 6,167.23 1,377.08 2,715.32 5,931,118.18 1,623,885.29 0.94 2,032.93 MWD+IFR-AK-CAZ-SC(5) 10,763.74 89.89 11.01 6,314.23 6,166.73 1,470.91 2,731.87 5,931,211.96 1,623,902.07 2.29 2,127.85 MWD+IFR-AK-CAZ-SC(5) 10,858.59 89.72 11.17 6,314.56 6,167.06 1,563.99 2,750.11 5,931,304.98 1,623,920.55 0.25 2,222.48 MWD+I FR-AK-CAZ-SC(5) 10,954.75 89.65 11.92 6,315.09 6,167.59 1,658.20 2,769.36 5,931,399.14 1,623,940.03 0.78 2,318.46 MWD+I FR-AK-CAZ-SC(5) 11,048.50 90.16 12.96 6,315.24 6,167.74 1,749.75 2,789.55 5,931,490.62 1,623,960.46 1.24 2,412.12 MWD+IFR-AK-CAZ-SC(5) 11,143.83 90.84 13.01 6,314.41 6,166.91 1,842.64 2,810.97 5,931,583.45 1,623,982.11 0.72 2,507.38 MWD+IFR-AK-CAZ-SC(5) 11,236.97 89.32 12.82 6,314.28 6,166.78 1,933.42 2,831.79 5,931,674.17 1,624,003.16 1.64 2,600.46 MWD+I FR-AK-CAZ-SC(5) 11,333.53 90.11 13.92 6,314.76 6,167.26 2,027.36 2,854.12 5,931,768.04 1,624,025.73 1.40 2,696.98 MWD+IFR-AK-CAZ-SC(5) 11,427.14 92.87 14.70 6,312.33 6,164.83 2,118.02 2,877.25 5,931,858.64 1,624,049.08 3.06 2,790.54 MWD+I FR-AK-CAZ-SC(5) 11,522.13 95.45 13.75 6,305.44 6,157.94 2,209.85 2,900.52 5,931,950.39 1,624,072.59 2.89 2,885.26 MWD+I FR-AK-CAZ-SC(5) 11,615.99 95.20 13.77 6,296.73 6,149.23 2,300.62 2,922.75 5,932,041.10 1,624,095.05 0.27 2,978.69 MWD+I FR-AK-CAZ-SC(5) 11,709.50 92.72 12.41 6,290.27 6,142.77 2,391.48 2,943.88 5,932,131.89 1,624,116.40 3.02 3,071.92 MWD+I FR-AK-CAZ-SC(5) 11,803.84 92.44 14.95 6,286.02 6,138.52 2,483.04 2,966.16 5,932,223.39 1,624,138.92 2.71 3,166.13 MWD+I FR-AK-CAZ-SC(5) 11,898.32 90.63 15.77 6,283.49 6,135.99 2,574.11 2,991.18 5,932,314.38 1,624,164.17 2.10 3,260.57 MWD+I FR-AK-CAZ-SC(5) 11,992.18 90.55 15.93 6,282.52 6,135.02 2,664.39 3,016.81 5,932,404.59 1,624,190.03 0.19 3,354.41 MWD+IFR-AK-CAZ-SC(5) 12,088.34 89.13 15.52 6,282.79 6,135.29 2,756.95 3,042.87 5,932,497.08 1,624,216.32 1.54 3,450.56 MWD+IFR-AK-CAZ-SC(5) 12,181.52 88.79 14.72 6,284.48 6,136.98 2,846.89 3,067.18 5,932,586.94 1,624,240.85 0.93 3,543.73 MWD+I FR-AK-CAZ-SC(5) 12,275.31 88.48 13.43 6,286.72 6,139.22 2,937.84 3,089.98 5,932,677.82 1,624,263.88 1.41 3,637.48 MWD+IFR-AK-CAZ-SC(5) 12,370.16 87.73 13.31 6,289.85 6,142.35 3,030.06 3,111.90 5,932,769.99 1,624,286.04 0.80 3,732.24 MWD+IFR-AK-CAZ-SC(5) 12,466.11 87.86 12.20 6,293.55 6,146.05 3,123.58 3,133.07 5,932,863.43 1,624,307.44 1.16 3,828.04 MWD+IFR-AK-CAZ-SC(5) 12,561.11 88.82 12.97 6,296.30 6,148.80 3,216.25 3,153.76 5,932,956.05 1,624,328.37 1.30 3,922.91 MWD+IFR-AK-CAZ-SC(5) 12,654.82 89.10 12.34 6,298.00 6,150.50 3,307.67 3,174.28 5,933,047.40 1,624,349.12 0.74 4,016.53 MWD+IFR-AK-CAZ-SC(5) 12,748.56 90.37 13.71 6,298.43 6,150.93 3,398.99 3,195.41 5,933,138.66 1,624,370.48 1.99 4,110.21 MWD+IFR-AK-CAZ-SC(5) 12,843.28 91.04 17.26 6,297.27 6,149.77 3,490.25 3,220.69 5,933,229.85 1,624,395.99 3.81 4,204.90 MWD+IFR-AK-CAZ-SC(5) 12,938.02 93.15 18.17 6,293.80 6,146.30 3,580.43 3,249.50 5,933,319.95 1,624,425.02 2.43 4,299.47 MWD+I FR-AK-CAZ-SC(5) 13,031.26 95.17 18.01 6,287.04 6,139.54 3,668.83 3,278.37 5,933,408.26 1,624,454.12 2.17 4,392.32 MWD+IFR-AK-CAZ-SC(5) 13,125.89 95.15 16.67 6,278.53 6,131.03 3,758.79 3,306.46 5,933,498.14 1,624,482.44 1.41 4,486.49 MWD+IFR-AK-CAZ-SC(5) 13,222.71 94.07 15.10 6,270.75 6,123.25 3,851.61 3,332.87 5,933,590.88 1,624,509.08 1.96 4,582.98 MWD+I FR-AK-CAZ-SC(5) 13,316.54 90.47 14.99 6,267.03 6,119.53 3,942.13 3,357.21 5,933,681.34 1,624,533.64 3.84 4,676.72 MWD+IFR-AK-CAZ-SC(5) 13,411.67 87.80 14.24 6,268.47 6,120.97 4,034.17 3,381.20 5,933,773.30 1,624,557.88 2.92 4,771.83 MWD+I FR-AK-CAZ-SC(5) 13,506.90 88.76 12.30 6,271.32 6,123.82 4,126.81 3,403.05 5,933,865.87 1,624,579.96 2.27 4,866.96 MWD+IFR-AK-CAZ-SC(5) 13,600.65 89.82 12.60 6,272.49 6,124.99 4,218.34 3,423.26 5,933,957.35 1,624,600.40 1.18 4,960.61 MWD+I FR-AK-CAZ-SC(5) 13,695.82 90.38 12.14 6,272.32 6,124.82 4,311.30 3,443.65 5,934,050.25 1,624,621.02 0.76 5,055.68 MWD+I FR-AK-CAZ-SC(5) 13,790.56 89.89 11.52 6,272.10 6,124.60 4,404.03 3,463.07 5,934,142.92 1,624,640.68 0.83 5,150.28 MWD+I FR-AK-CAZ-SC(5) 13,885.48 89.85 12.03 6,272.31 6,124.81 4,496.95 3,482.44 5,934,235.78 1,624,660.28 0.54 5,245.04 MWD+I FR-AK-CAZ-SC(5) 13,979.56 89.82 11.93 6,272.58 6,125.08 4,588.98 3,501.97 5,934,327.75 1,624,680.04 0.11 5,338.99 MWD+IFR-AK-CAZ-SC(5) 14,075.39 89.17 13.18 6,273.43 6,125.93 4,682.52 3,522.80 5,934,421.22 1,624,701.11 1.47 5,434.73 MWD+I FR-AK-CAZ-SC(5) 14,168.58 88.45 15.27 6,275.36 6,127.86 4,772.82 3,545.69 5,934,511.46 1,624,724.23 2.37 5,527.89 MWD+IFR-AK-CAZ-SC(5) 14,261.97 88.55 16.41 6,277.81 6,130.31 4,862.63 3,571.17 5,934,601.20 1,624,749.94 1.22 5,621.23 MWD+IFR-AK-CAZ-SC(5) 9/8/2015 2:48:34PM Page 6 COMPASS 5000.1 Build 74 Schlumberger i Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-07 Project: Kuparuk River Unit TVD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual: 120+27.5 @ 147.50usft(Doyon141) Well: 2S-07 North Reference: True Wellbore: 2S-07 Survey Calculation Method: Minimum Curvature Design: 2S-07 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,307.38 88.86 16.77 6,278.83 6,131.33 4,906.14 3,584.14 5,934,644.67 1,624,763.01 1.05 5,666.61 MWD+IFR-AK-CAZ-SC(5) 14,380.00 88.86 16.77 6,280.28 6,132.78 4,975.66 3,605.09 5,934,714.12 1,624,784.13 0.00 5,739.18 NOT an Actual Survey 4 1/2"x 6-3/4" 14,390.00 88.86 16.77 6,280.48 6,132.98 4,985.23 3,607.97 5,934,723.69 1,624,787.04 0.00 5,749.18 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved ❑ Yes ❑ No I have checked to the best of my ability that the following data is correct: 2 Surface Coordinates 7j Declination & Convergence GRS Survey Corrections Survey Tool Codes DrgMwamecum Vincent Osara°"`�"°`�'°�" SLB DE: osu �. aomri-wnorsbmrnc-us T,iu 21f1 ia4tA ffi3QS±d60V DN.o H rodt�a,o-tPfico ON,m-fFa�+n Guo.o-03A1 ou-Drit+SbWdls. Client Representative: H i n Guo Date: 09-Sep-2015 9/8/2015 2:48:34PM Page 7 COMPASS 5000.1 Build 74 • • Ku 25-07 Pr-6 7350710 Regg, James B (DOA) From: Doyon 141 Company Man <n1334@conocophillips.com> I Sent: Friday, August 07, 2015 9:15 AM / E3! ' I" To: DOA AOGCC Prudhoe Bay; Guo, Haibin;Whitlock, Guy D (SolstenXP) Cc: Hill, Johnnie W (DOA) Subject: Doyon 141. Reporting BOPE use to prevent flow from Wellbore. 8.07.2015 8.07.2015.05:10 AM close annular preventer on 7.625" landing joint. 2S-07. Kuparuk. PTD 215-079 .i Doyon 141 " Robert Wall After the second stage of the two stage intermediate casing cement job was completed, the well was flowing. After observing 10 bbls of volume the well was shut in. 50 psi was observed @ 05:10. 30 psi is currently on the annulus at the time of this email, 09:02. Our well has a history of lost returns and breathing.We believe the pressure and flow was caused by a loss zone being cemented in, and some of the lost returns flowing back. The annisenter was used. We will hold cement in •la - • • ' com.r-_ - -•: • ' •• ..ned. 9 hours. Once we complete this task we will conduct a full BOPE test on Saturday the 8th.The casing rams will be changed out, and the variables installed prior to the full test. We are in contact with AOGCC Inspector Johnnie Hill as to the timing of our test. Respectfully, Robert Robert Wall Don Mickey Bob Finkbiner Doyon 141 Rig Supervisors 670-4963 office 670-4976 rig floor 1 • 1-,TP /5--O 7 410 Loepp, Victoria T (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Sunday, August 02, 2015 2:30 PM To: Loepp, Victoria T (DOA) Subject: Re: [EXTERNAL]Re: 2S-07 (PTD#215-079) intermediate casing set depth change Follow Up Flag: Follow up Flag Status: Flagged Victoria,thank you very much for the quick response. Thanks, Haibin On Aug 2,2015, at 2:15 PM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov<mailto:victoria.loepp@alaska.gov>> wrote: Haibin, Approval is granted for the proposed drilling plan outlined below, intermediate casing set depth change. Thanx, Victoria On Aug 2, 2015, at 12:24 PM, Guo, Haibin<Haibin.Guo@conocophillips.com<mailto:Haibin.Guo@conocophillips.com» wrote: Hi Victoria, We encountered a rig lost power event last night while drilling the 9-7/8" intermediate hole section on the second Shark Tooth pad well - injection well 2S-07 (PTD#215-079).After we re-established circulation and calibrating the MPD chokes,the hole started taking fluid at"80bph. We pumped two LCM pills,the losses decreased from 80bph to"45bph. Lost zone is most likely between the base of the Bermuda (6668'MD) and the depth of 7140'MD (which is"'100' above the top of the HRZ interval). We are drilling with low parameters 10.5ppg MW/600gpm/14Orpm/60fph.The losses is "20bph. The original drilling plan was to land the intermediate in the higher pressured (11.1-11.4 ppg) Kuparuk sands. However, knowing that we have weak zones above us,to the safety of rig personnel and the operation, we are proposing to topset the overpressured Kuparuk sands by landing—20'TVD above them, setting our 7-5/8" intermediate casing in the Lower Kalubik shale, and cementing with a ^'1500' of cement above the shoe to the top of Cairn. A second stage cement job will provide an additional 500'of cement above the C-37 (Tarn area) interval. This plan is very similar to our just successfully completed injection well 2S-02(PTD#215-070). On production section,we'll drill out the left"20'TVD Kalubik shale and continue to drill horizontally in to Kuparuk A4 sand and to planned TD. Run our planned 4-1/2" slotted liner and place a swell packer at the top of the Kuparuk sands to provide pressure isolation for the 7-5/8" casing shoe. 1 • • Please approve the proposed plan. Attached is the new proposed well schematic.Any questions let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell: 907.227.6048 <Visio-25-07 injector Top Set.pdf> 2 41110 PTD 2/S-a Loepp, Victoria T (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Thursday,July 30, 2015 11:06 AM To: Loepp, Victoria T (DOA) Cc: Guo, Haibin;Alvord, Chip Subject: RE: 2S-07 (PTD#215-079) Surface Casing Shoe Cement Squeeze Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, The surface casing shoe cement squeeze went textbook. We pumped away 30 bbl of 15.8 ppg Class G cement,and squeezed away 9 bbl into a sandstone stringer and ended up with 1,100 psi squeeze pressure.This morning, we drilled out the 20' and obtained a 14.5 ppg EMW formation integrity test(FIT). This exceeds our minimum requirement to drill ahead in the intermediate section. Thank you, Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Loepp, Victoria T(DOA) Hailto:victoria.loepp(aalaska.gov] Sent: Wednesday, July 29, 2015 11:49 AM To: Bearden, J Daniel Subject: [EXTERNAL]RE: 2S-07 (PTD# 215-079) Surface Casing Shoe Cement Squeeze Daniel, Thanx for the notification. Please forward the results of the next FIT/LOT when obtained. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppAalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • RID From: Bearden, 3 Daniel [mailto:J.Daniel.Bearden@conocophillips.com] Sent: Wednesday, July 29, 2015 10:35 AM To: Loepp, Victoria T(DOA) Cc: Guo, Haibin Subject: 2S-07 (PTD# 215-079) Surface Casing Shoe Cement Squeeze Hi Victoria, This note is to inform the AOGCC that ConocoPhillips will perform a surface casing shoe cement squeeze on 2S-07 (PTD# 215-079). After successfully testing the 10-3/4" surface casing to 3,000 psi,we drilled our 9-7/8" intermediate hole 20' into new formation (2,661'TVD)with 9.6 ppg mud. We performed a LOT to 16.0 ppg EMW, however after the 10 minute SI time, the surface pressure had dropped from 900 psi to 250 psi indicating a breakdown. A second LOT was performed to confirm this,and subsequently achieved LOT of 12.2 ppg EMW with 10 minute SI pressure test holding constant. We deemed this leakoff pressure insufficient to drill ahead in the intermediate hole section with the confidence for the potential kick tolerance needed to drill in to the Kuparuk. The surface casing cement job is not suspected to be the problem, as the floats held and 65 bbls of cement was returned to surface as expected. Since the geology at this depth indicated a possible sandstone stringer,the decision was made to pump a 25 bbl 15.8 ppg cement hesitation squeeze. After sufficient hardening time,we will again drill out our cement and perform a follow up FIT to 14.5 ppg EMW(with a minimum acceptable LOT of 13.3 ppg EMW) prior to drilling ahead. Thanks, and let me know if you have any questions, Daniel Bearden Supervising Drilling (Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell 2 • KCtit Z3 07 Regg, James B (DOA) From: Rig 141 <rig141@doyondrilling.com> Sent: Monday, July 27, 2015 7:55 AM To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay; Herbert, Frederick 0; Hill, Larry G.; Regg, James B (DOA); Michael Worthy; Michael.L.Kneale@contractor.conocophillips.com; n1334@conocophillips.com; Brooks, Phoebe L (DOA);Whitlock, Guy D. Cc: Todd Driskill; Mike Meadows Subject: BOP-Doyon141-7-27-15 Rev. 1 Attachments: Doyon 141 BOP 7-27-15.xlsx 1 0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq(a,alaska.gov AOGCC.Inspectors@alaska.gov phoebe.brooks(a,alaska.qov Contractor: Doyon Rig No.: 141 . DATE: 7/27/15 Rig Rep.: B.Ingram/J.Huschle Rig Phone: 907-670-4274 Operator: Conoco/Phillips Alaska Op. Phone: 907-670-4963 Rep.: D.Coates/A.Lundale E-Mail N1334@conoco/phillips.com Well Name: KRU 2S-07 - PTD# 215-079 Sundry# N/A Operation: Drilling: X - Workover: Explor.: Test: Initial: X - Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3500 • Annular: 250/2500 - Valves: 250/3500 -MASP: 2981 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P . Well Sign P • Upper Kelly 1 . P . Housekeeping P Rig P • Lower Kelly 1 , P PTD On Location P . Hazard Sec. P Ball Type 2 P Standing Order Posted P - Misc. NA Inside BOP 2 _ P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P . P . Annular Preventer 1 • 13 5/8 x 5000 • P - Pit Level Indicators P P . #1 Rams 1 • 3 1/2"X 6" • P - Flow Indicator P P #2 Rams 1 Blinds P • Meth Gas Detector P P • #3 Rams 1 2 7/8 x 5 • P • H2S Gas Detector P P . #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 • 3 1/8 X 5000' P • Inside Reel valves 0 NA HCR Valves 2 3 1/8 X 5000 - P Kill Line Valves 2 " 3 1/8 X 5000 • P . Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 2900 - P • CHOKE MANIFOLD: Pressure After Closure(psi) 1800 P • Quantity Test Result 200 psi Attained(sec) 40 - P • No.Valves 14 - P . Full Pressure Attained(sec) 173 P . Manual Chokes 1 . P . Blind Switch Covers: All stations Yes . Hydraulic Chokes 1 . P . Nitgn. Bottles Avg. (#and psi): 5 @ 2000 psi . P . CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 6.0 ✓ Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Test with 4"&5"test jts.All Rams and Valves tested 250 psi-low/3500 psi-high.Annular tested 250 psi-low/2500 psi-high.All tests 5 min each.Tested 1 Ea. 4"XT-39 Ball Valve,4"XT-39 Inside BOP ,4.5" IF Ball Valve,4.5"IF Inside BOP due to running tapered drill string. AOGCC Inspection 24 hr Notice Yes Date/Time 7/25/15 01:36AM Waived By John Crisp Test Start Date/Time: 7/26/2015 23:00 (date) (time) Witness Test Finish Date/Time: 7/27/2015 5:00 P CALIVA — Nisaks5t.A of- CPA-Is oeti li er.-Leen Welk Ma tic,,,,, (6 L-UPA) Form 10-424(Revised 06/2014) Doyon 141 BOP 7-27-15.xlsx Ptcf-kme,t -1-0 369 PE — Regg, James B (DOA) itvv>v t41 ; 'i(Z71 is- From: Doyon 141 Company Man <n1334@conocophillips.com> Sent: Saturday,July 25, 2015 6:41 AM To: Crisp,John H (DOA); DOA AOGCC Prudhoe Bay Subject: RE: AOGCC Test Witness Notification Request: BOPE, Doyon 141, 2S-07, 2S Pad, KRU John, CPAI objective with BWM is to • Ensure all Well Control Equipment will Operate in Compliance with COP Standards, AOGCC Requirements and Federal Regulations • Increased Efficiency through Operational Performance - Less Downtime This is what the BWM entails Critical Well Control Equipment r Required Actions during Operation: ■ Visual Inspections&Scheduled Maintenance ■ Cycle Counts on all Major Well Control Equipment, i.e. Annular, BOPs, and Associated Safety Equipment ■ Between Well Inspections ■ Bores, Cavities, Sealing areas for extensive wear and damage leading to premature failure • Ram Block Assemblies—Cracks, damaged Top Seals, Front Packers, and Ram Guides ■ Ensure Contractors follow their Planned Preventive Maintenance program while Equipment is in service. Equipment Storage ■ Ensure our contractors follow Proper Storage Procedures, OEM recommendations for Equipment - and Elastomers, .i.e. seal removal and the use of preservation fluid ■ Ensure Equipment is Functioned and has been Hydrostatically Tested per OEM Recommendations and the Contractors Maintenance Programs prior to installation. After we N/U BOPE we will perform BWM then move into our BOP test Please call if you want more info Thanks Dave David Coates/Andy Lundale Drilling Supervisors Doyon 141 Office: 907-670-4963 Rig Floor: 907-670-4976 E Mail: n1334@conocophillips.com From: Crisp, John H (DOA) [mailto:john.crisp@alaska.gov] Sent: Saturday, July 25, 2015 5:41 AM To: Doyon 141 Company Man; DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 141, 2S-07, 2S Pad, KRU 1 • • Thanks for the notification. I was talking to the Guy's on 9ES about the BWM and I thought it was for workovers. Please explain the new BWM theory. From: Andy Lundale [mailto:noreply@iformresponse.com] Sent: Saturday, July 25, 2015 1:36 AM To: DOA AOGCC Prudhoe Bay Subject: AOGCC Test Witness Notification Request: BOPE, Doyon 141, 2S-07, 2S Pad, KRU Question Answer Type of Test Requested: BOPE Requested Time for 07-26-2015 7:00 AM Inspection Location Doyon 141, 2S-07, 2S Pad, KRU Name Andy Lundale E-mail n1334@conocophillips.com Phone Number (907) 670-4963 Company Conoco Phillips We are currently running surface casing & expect to be cementing this afternoon. We do intend on performing our Other Information: between wells maintenance on our BOPE. We can provide updates on our progress. Thank you, Andy Submission ID: 313626185621475666 2 V OF T�cp II • ‘,47„,,,,,74..„, THE STATE Alaska Oil and Gas 4w = _'� o Conservation Commission irk�e, fASKAL II Witt =�- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Op,ALAS�Q' 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-07 ConocoPhillips Alaska, Inc. Permit No: 215-079 Surface Location: 3050' FNL, 1437' FEL, Sec. 17, TION, RO8E, UM Bottomhole Location: 3364' FNL, 3062' FEL, Sec. 9,T10N, R08E,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, l67CathyFoerster ,, ,_ Chair DATED this 2-/' day of May, 2015. 0 • STATE OF ALASKA RECEIVEDMAY 11 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone ✓❑ 1c.Specify if well is proposed for: Drill • Q Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill El Reentry C Exploratory ❑ Service-WAG . m Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: I_1 Blanket • Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc.' Bond No. 59-52-180 i KRU 2S-07- 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 14387'. TVD: 6360' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:3050'FNL, 1437'FEL,Sec. 17,T1ON, RO8E, UM , ADL 25603,25604,25589 Kuparuk River Oil Pool. Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4018'FNL,4709'FEL, Sec. 16,T1ON, RO8E,UM 2677,2678,2675 6/21/2015 Total Depth: 9.Acres in Property: pq) 14.Distance to 3364'FNL,3062'FEL, Sec.9,T1ON, RO8E, UM • 2--?Q 3Z Nearest Property: 3843' 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- 481133 y- 5929999 Zone- 4' GL Elevation above MSL: t 120 feet to Same Pool: KRU 21-10-8, 16.Deviated wells: Kickoff depth: •450 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: -96.5° deg Downhole:3612 psig• Surface:2981 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 2900' 28' 28' 2928' ' 2623' 983 sx ALC,195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 8120' 28' 28' 8148' 6358' 422 sx GasBLOK,145 sx GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 6439' 7948' 6291' 14387' 6359' 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 Size Cement Volume MD ND Conductor/Structural Surface Liner 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. Alvord Title Alaska Drilling Manager fl Signature ,, O.LA Phone:263-4372 Date S(cp (2.1(c ///���777 Commission Use Only Permit to Drill API Number: Permit Approval ^ See cover letter Number: Q11-6-- 1"' 50- 103-p20-13-w -.O� Date: l I, 5 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: Do P fc5 f p 1---e- 5 tire. ie. 35-Go psi Samples req'd: Yes No Mud log req'd: Yes❑ No ,qnrw1a prc'vlhfe"/ 7' f to 2 5-6 0/0 12S measures: Yes No ❑ Directional svy req'd: Yes No❑ , Spacing exception req'd: Yes ❑ No E Inclination-only svy req'd: Yes❑ No raf APPROVED BY THE Approved by0 COMMISSIONER COMMISSION Date:�/1 5r-�`� Form 10-401 (R ised 10/2012) Th e i vpp��irk*todthstfrom the date of approval(20> 5.015(g)) 'fa 5/141 J � Vis 4r . - ,,//,,,-- ttt • • Application for Permit to Drill,Well 2S-07 Saved:8-May-15 May 8th, 2015 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 MAY 1 1 2015 Anchorage,Alaska 99501 OA GCC Re: Application for Permit to Drill Well 2S-07,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 June 21st,2015. It is planned to use rig Doyon 141/ ✓ / 2S-07 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 -2,928'MD/2,638'TVD. The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to—8,148'MD/6,358'TVD. The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to— 14,387'MD/6,359'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. 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, hip Alvord Drilling Manager • • Application for Permit to Drill Document Kuparuk Well 2S-07 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-07 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 3050' FNL, 1437' FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 148'AMSL Northings: 5,929,998.29' Eastings: 481,132.96' Pad Elevation 120'AMSL Location at Top of 4018'FNL,4709'FEL,Sec 16,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 8,148' Northings: 5,929,025.04' Eastings: 483,141.10' Total Vertical Depth, RKB: 6,358' Total Vertical Depth, SS: 6,210' Location at Total Depth 3364' FNL, 3062' FEL, Sec 09,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 14,387' Northings: 5,934,955.25' Eastings:487,785.83' Total Vertical Depth,RKB: 6,359' Total Vertical Depth,SS: 6,211' 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-07 is calculated using an estimated reservoir pressure of 3,612 psi (11.0 ppg EMW), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,314' TVD (WP10): A Sand Estimated. BHP = 3,612 psi A Sand estimated depth (WP10) = 6,314' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 631 psi (6,314' TVD * 0.10 psi/ft) MPSP = BHP—gas column =2,981 psi (3,612 psi—631 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-07 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 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 Cementin. Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) f) t(lb/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 2,900 Surf 2,928/2,623 983 sx ALC Lead 11.0 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 422 sx Class G+GASBLOK at Hydril 15.8 ppg w/TOC at 6,350'MD 7-5/8 9-7/8 29.7 L-80 563 8,120 Surf 8,148/6,358 Stage 2: 145 sx Class G+GASBLOK at 15.8 ppg w/TOC at 4,950'MD 4 1/2 6-3/4 12.6 L-80 IBTM 6,439 7,948/6,291 14,387/6,359 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 AAC 25.035(h)(2); Please reference diverter schematic 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 AAC 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 Drilplex LSND(WBM) (WBM) Density 8.8-9.5 9.5- 11.5 11.3-12.0 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. 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+/-2,928' MD/2,623'TVD as per directional plan (wp10). Survey with MWD, Gamma,Resistivity. 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 3000 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 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at 7,212' MD/6,016' TVD. Install RCD bearing at this time for use of MPD if necessary. 9. Directionally drill to intermediate TD of 8,148' MD/6,358' TVD,landing in the Kuparuk A4 sand.Close MPD chokes on connections.Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. Backream through tights spots only if necessary. If substantial drag was observed through a large part of the trip,consider making a wiper trip back to bottom from the surface casing shoe,otherwise continue pulling out of hole. 11. Laydown intermediate BHA. 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 8,148' MD. 13. Pump two stage cement job as per Schlumberger proposal. TOC of first stage to be 6,350' MD(top of Bermuda formation),TOC of second stage to be-4,950' MD(500' above C37). 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. / l 5. PU 6-3/4"PDC bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope,and neutron density). 16. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3000 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 ppg EMW leak off,recording results. 18. Directionally drill 6-3/4"hole geo-steering though the Kuparuk A4 sand to TD 14,387'MD as per directional plan(wp10). 19. Circulate hole clean and POOH. 20. Lay down Production BHA. 21. PU and run 4-1/2", 12.6#slotted liner. The top of liner will be placed at 7,948' MD,allowing for-200' of overlap in the 7-5/8"casing. 22. Set liner hanger. Slackoff and set liner top packer. 23. PT liner hanger to 3,000 psi at surface for 30 minutes,chart results. • 24. Displace to clear brine. 25. Flow check well for 30 minutes. 26. POOH liner hanger running tool. 27. Run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. 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 4 Cement Summaries • • 2S-07 ConocoPhillips Grassroots Horizontal A-Sand Injector Proposed Wellbore Schematic (wp10) "'CAMERON Last Edited: 4-% tree,top joint is 4-W 12.6#IBTM Guo-5/07/15 116"Conductor to-115' ,\' 13.5" Surface Hole : n�xnra 3-% 2.875"DS Landing Nipple 1 . qty tM1'• ir ,Iii ' six, ,, m Surface Casing h,„ 10-3/4"45.5#L-80 Hydri1563 2,928' MD/2,623'TVD 9-7/8" Intermediate Hole - � ,, . � ,.,. 3-%"GLM 3-1/2" 9.3#L-80 EUE 8RD-MOD Tubing ° 2nd Stage TOC:4,950'MD/4,305'TVD (500'MD above C37) ' L 4 ® ® Weatherford Stage Collar 5,600'MD/ . :":C-37:5,454"MD/4,763'TVD. 4,895'TVD(C-37 formation) Growler,(Iceberg):5,709'MD/4,993'TVD i ., 1a'Stage TOC:6,350'MD/5,523'TVD (Top of Bermuda) I Bermuda:6,350'MD!5,523'TVDb Wi '7',zi MD/$,01W TVD , \ f(aiubik:780"M41$,1x6'IVO \ 400000 '°i€� 75l"Flex Lock Liner Hanger I ZX Kuparuk A4:8,014'MD/6,314 TVD: Baker 2.812"CMU Sliding Sleeve ..�, S.6,8'' .� � I A'Orange PeeAIM = SM1oe 3'�..2.75"D Nipple i �,- :: t,_ 3!/"HES Mirage Disappearing Plug 1'D.14 38T MD/6 359 TVD Intermediate Casino 7-5/8"29.7#L-80 Hyd563 Casing 6.38"x 4-%"Swell Packer 6-3/4" Production Hole 8,148' MD/6,358'TVD(85°) NOTE: Swell Packer will be adjusted as necessary using microscope and periscope data • • W 11 I I I I Ict >- N o NS ' .41 g c-1711, o — Z 0 ► 1 CI o �/ di 0 1v a >- w a ® 0 to 5 El ® _ _ co a El ® 1-7 >� Q El ® u ; . 0 (Inor ` a s 1 I' I ® ! n C Lc, \ V N N - s q p OM xv E / MI PI FEI 0\ I. PEI 0 •' N N O 1 H NLI N It..%" Ei o aW 0 N. El 0 _ 00 Ii▪m ao N 1111 — - El ® _ ,�CI a , El ® > - 6 2 - 8 FA ® a ® pr, .5..-5w2,, o�kpN ya,..- zazm�? YON b El ® �y�gl'�— �- 3a UzL.i El ® Z Q 1\1 > ,-- o 0 a 3 z s ° W n ,q .':Hi" p > (.7 5 :La 1. c•, .,,.8 ?[GobIin] 2S-07wp16 . 758 Plan Summary Top Cairn- Growler-AA Base Bermudy4 Top W Sak(W Sak D) , Trip Bermuda, , 5- C-37 , ` 1 ,Top WIZ(K-2 mkr) -5 C-4O' • i i 1-" `m Base permafrost,(?) -: , t 1 ,' '1 A5 o C• - �t Ease W Sak ,4 Kwoaruk-C-(Teo:4, - o K-15 Ma er Sok A Lpper Kal nik(base H ) -... ..._... p I 11C EO C 50 _ ap !/�,/. I.._Mer♦�lilubik(K-1 m )< -,.... _.._ -- -..... -- top T.315and al IA411 1 , 4 _ _ 0 1 1 i1 r 'I I I t ' 1 I 1 r I i 1 ( 0 l _� /, i o 13500 7000 17-5/8"X 9-7/81 10500 14000 I10-314"x 13-1/2'� Measured Depth 4-1/2 x 6_3/4"� ' ''�4 \` 0- Depth Reference: Plan:120+28 @ 148.00usft(Doyon - - . / ---"--""" -0i°�p 110-3/4"x 13-12'� 141) A401 ‘1/4 _-...,,' ... ..,-_ 'Z T -Op • Rig: Doyon 141 o 400 o N A 271°000 7-5/8"X 9 7/8" I4-1/2"x 6-3/4"I 0 1 0 o n f I ti 0 1500 3000 4500 60 07500 c' 91:0 10500 12s-04,6061 il oI2s �"p^II 28 `--- 450 Horizontal Departure 450 - 640 I 1041 840 dl za-opo r wl l 1330 . tj� 'v ri 840 - 103 'IJI1030 - 1220 840 - 1030 OM 111111ill,1 ° I (��Ap� i4l B 61 ./�r�r.:,��' 1220 - 1420 m 60 ill 1 I 1 SII 1111 I ill IIlilr 2S 09wp06[l igerl 300 r 4� ��i/i �i.060 1420 - 1610 III� ,°/ a -. �I 4 III ill f ..... es: rt�r ..f7ix 1610 - 1800 �IIIi VIII r, o s \$ Ss-m'''''°"'"' CC - ,. - ...., zs-nuvgcis In' �.4 1800 '^ 2330 m 2S 1:1107[Hammerhead] % ... 'pe nb00 2330 2050 U 30 _ 2` r \, • _.. r-, ' ' „ 2850 - 3380 Njiglit .1 {Ca1mord p 270 I'''''•- - .. 90 3380 - 3900 _. 2"-DSwp06[Nurse] - _, - - 3900 - 4430 C. ° 41 4430 - 4950 r / 4950 - 5480 0 I I 1 1 I 1 I 1 I I I I I I I 1 I I I,v� 5480 - 6000 I 240 •)t//120 6000 - 7000 0 1500 3000 4500 6000 7500 9000 7050 - 8100 SURVEY PROGRAM 8100 - 9140 Surface Location • 9140 - 10190 lepth From Depth To Survey/Plan Tool pad Elevation:120.00 10190 - 11240 28.00 750.00 2S-07wp10[Goblin](Plan:2S-07) GYD-GC-SS 210 ��•," • 150 11240 12290 750.00 1750.00 2S-07wp10[Goblin](Plan:2S-07) MWD 750.00 2927.93 2S-07wp10[Goblin](Plan:2S-07) MWD+IFR-AK-CAZ-SC 180 12290 - 13340 2927.93 4427.93 2S-07wp10[Goblin](Plan:2S-07) MWD CASING DETAILS 13340 - 14367 2927.93 8183.98 2S-07wp10[Goblin](Plan:2S-07) MWD+IFR-AK-CAZ-SC TVD MD Name 8183.98 9683.98 2S-07wp10[Goblin](Plan:2S-07) MWD 2623.00 2927.93 10-3/4"x 13-1/2" Magnetic Model: BGGM2014 T 8183.98 14387.22 25-07wp10[Goblin](Plan:2S-07) MWD+IFR-AK-CAZ-SC 6358.00 8183.98 7-5/8"X 9-7/8" Magnetic Model Date: 31-Jul-15 A 6360.00 14387.22 4-1/2"x 6-3/4" Magnetic Declination: 18.54° To convert a Magnetic Direction to a True Direction,Add 18.54°East SECTION DETAILS - gggg - Sec MD Inc Azi ND 41/-S .E/-W Dleg TFace VSect Target Annotation 372`,T-3 Sand 1 28.00 0.00 0.00 28.00 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,171.27°TF,for 150.04' K-15 Marker 3 600.04 2.25 171.27 600.00 -2.91 0.45 1.50 171.27 -2.70 Start 2.51100'DLS,0°TF,for 899.43' 4 1499.47 24.74 171.27 1469.00 -209.02 32.10 2.50 0.00 -193.59 Hold for 110.1' 5 1609.57 24.74 171.27 1569.00 -254.56 39.09 0.00 0.00 -235.77 Start 3.51100'DLS,16.92°TF,for 419.42' -1360.3 6 2028.99 39.00 178.00 1924.39 -474.39 57,11 3.50 16.92 -443.44 Hold for 1712.41' 7 3741.40 39.00 178.00 3255.18 -1551.39 94.72 0.00 0.00-1474.01 Start 3.51100'DLS,-139.3°TF,for 546.58' Base permafrost(? 8 4287.98 27.05 149.97 3715.24 -1833.51 163.57 3.50 -139.30-1728.71 Hold for 662.78' _185inIQV,/Sak(W Sak > 9 4950.76 27.05 149.97 4305.49 -2094.51 314.42 0.00 0.00-1941.76 Start 3.50100'DLS,-117.44°TF,for 2259.21' 9'zro ) 10 7209.97 68.00 40.00 6015.00 -1666.89 1427.24 3.50 -117.44-1240.70 Hold for 734.1' W Sak A4 11 7944.07 68.00 40.00 6290.00 -1145.48 1864.75 0.00 0.00 -623.82 Start 4.610100'DLS,-5.18°TF,for 395.25' -2290.6 12 8339.32 86.15 38.38 6378.04 -848.03 2107.00 4.61 -5.18 -273.80 Hold for 14.38' W Sak Al 13 8353.70 86.15 38.38 6379.00 -836.79 2115.90 0.00 0.00 -260.64 2S-Goblin 1.Heel 061214 BP Start 31100'DLS,-82.67°TF,for 994.2' -2573.0 14 9347.90 90.29 8.82 6410.52 63.67 2508.96 3.00 -82.67 710.87 Hold for 1370.47' Base W Sak 15 10718.37 90.29 8.82 6403.50 1417.92 2719.09 0.00 0.00 2073.36 Start 30100'DLS,92.86°TF,for 195.59' -3028 0 16 10913.96 90.00 14.68 6403.00 1609.33 2758.90 3.00 92.86 2268.55 2S-Goblin 2.71 050714 PB Adjust TF to 179.36°,for 9.56' 17 10923.52 89.71 14.68 6403.02 1618.57 2761.32 3.00 179.36 2278.11 Hold for 443.45' 18 11366.97 89.71 14.68 6405.24 2047.53 2873.72 0.00 0.00 2721.54 Start 30100'DLS,0.18°TF,for 176.23' 19 11543.19 95.00 14.70 6398.00 2217.80 2918.36 3.00 0.18 2897.55 20-Goblin 3.T2 050714 PB Adjust TF to 1.47°,for 49.7' C-80 20 11592.89 96.49 14.74 6393.03 2265.62 2930.93 3.00 1.47 2947.00 Hold for 113.1' 21 11705.99 96.49 14.74 6380.24 2374.30 2959.52 0.00 0.00 3059.38 Start 30100'DLS,179.99°TE,for 216.35' 22 11922.34 90.00 14.74 6368.00 2583.08 3014.44 3.00 179.99 3275.26 2S-Goblin 4.T3 050714 PB Hold for 763.66' -4133.0 23 12686.00 90.00 14.71 6368.00 3321.65 3208.58 0.00 -90.00 4038.91 2S-Goblin 5.T4 050714 PB Start 0.171100'DLS,0.01°TF,for 994.51' 24 13680.50 91.73 14.71 6353.00 4283.39 3461.15 0.17 0.01 5033.25 20-Goblin 6.T5 050714 PB Start 20100'DLS,-179.54°TF,for 126.05' C-50 25 13806.55 89.21 14.69 6351.97 4405.29 3493.14 2.00 -179.54 5159.28 Hold for 580.15' 26 14386.70 89.21 14.69 6359.99 4966.42 3640.29 0.00 0.00 5739.37 Start 10100'DLS,-63.52°TF,for 0.52' -19.1/4'i 27 14387.22 89.21 14.69 6360.00 4966.92 3640.43 1.00 -63.52 5739.89 2S-Goblin 7.Toe 050714 PB Start 10100'DLS,-63.52°TF,for 0.52' - -4993.0 �,{gqG�Growler-AA 58 - 2,410 Egg fuda Base Bermuda is subject to Change _ 8"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 collisi-on 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: Brij Potnis Nate Beck Ifeanyi Ifesie Haibin Guo 0 O r N J J F o 0- a N ,004 N• Y N Jh ig (3500 usft/in) • 0, .: il,\,, c CO N La Y _ o Q N m. N — Y N - :l' Q N Q - CO MO N O - Y — T N Y _ _ r N d5- - o r Y E — N Q os i a O - — N O N O (n 00 n C O_ N - O N 73 3 Y - o 0 N N C7 N — O _ 7_-. n m - E. O a O O M E. th O a — N ami 3 _ N N ? - CO'm 0�C`fj O(n - 4110H-"lj1* N — a CI _ J p Cls NN- N -- y � CO 2 La 0N --�\\ :al •-c-' —- In CO ' 0\AN, , iiii, . IP N i IT*JFFttIII al� r (. C.) O - ON- N • �3AIIIIIIIw Y N •� C p 0 — 3 co r (n N ` M ea M �`E (n fn - N 0 \ N 0. ��"" N — 3 , m 3 c a. M • a N M r n • J CD nQ� 2 _ - J (U M N g C_ r - N , J �' 0 (n — m = n ,iia• N I N _ _ 0 1al r' J N Ch O M N M J ,_ p — J M _ ./ J N Q N Y ���. M CV O N N 1_J N N m R- 02ii N Z N M N QmQ��m ZC? co. C\IZ ca �� J ('7� N N N f N Z I CO O III /r c? 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C 0 Nr r r CO CO V CO CO O CD CO 0 CO O CO O 0 O 0 CO O (O O O 0 am ` n. 0 U) N- N- o L f N 0 O O Vr r 0) 0 CO O n N- N 0 0 n O N N- 0) 0) T V 0 0 (O 0 N a Y Y U) UO-) a co O V co 0) V 0) N- 0) 0 CO N- 0) CO 0) (O 0) r CO 0) CO O (O (() C- N OV ` 2 N Nn 2L O O 6 O06 N- O Qi V Di M N- CO M M (O M Ni U) N (O O (O (fl o 0 0) 0 N V CO )O. 0 V CO U) V r r N CO V 0) 0 N CO CO 0 CO CO C a a C C O y a y V]V CO V CO O Is N 0) N 0) CO CO CO (- 0) o co U) LO Ns 0) CO O CO CO M O Y Y O_ D- N cam) 0 `=-' r r N CO- V V N- n CO CO W O O O r ,- r r r N CO- CO- V V U) E Q C N- O >, COco N D Cas N C O a y 9 O) N NO C O E O .,a', m m y C m • 0 N /1 i•(m -o.., E c a N I c • j•▪ U C 6 C � m N co 2 0 m C9 a `o — U - O W O CU w N O Ce• O '2 O s + t N d O E oN ▪ N = ' Q ca 0 o c y dT - 3wN g Za _ sc 2 co• n Gm v oD V) 9T i N Cl d U Q 7 c a _coL •— = U m H m 0 W a a d o0 a CIO ca yW•- 4., ON U a. Q s E _— •. NvN W 1 oO sw.., ARS 0 v ■— x 'y M ° d t(12O W LL LL li N O` . ,F N Q Q u 0. m a m 0 Cl)Ce O O O RS 0 to t • m y `M° ° m' ON r c m a o , _ 0 N O Y a L 0 o z — o w N N d s 5 o C2 co •. a . a iL 7 U O L L N N ti 4-1 >+ c U m 2' ._ Cl) U) ci ui O �I co T C 2 l0 R V E T T I2 U E ce 0 o V 0 < `O iYYaa N • omn � > i • 0 N O C a I 0 O c P a 0 03 �. x Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y C e` I. N N N N N N N N N N N N N N 1 a) N N / N N N N N N N N t ▪ 0 CC CC 4! K cC it it Lt cC ct cC ct ceceEce wrxcrce ct rxecwct Q 12 CSC (a o o .0 '''.12c 0 0 0 0 0 0 0 0 0 0 0 _a o 0 0 0 0 0 0 7 0000 0. m m m m m m m m •m m m m m m m m m 'm m 'm 'm m m m m m m m Q w 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 CA 0.1 (0 CO N N N CO0) 0) 0) 0) 0) 00 (0 00 N N CM (0 N 0) 0) 0) 0) CO N 0( 0) N N m m m m m m m m m m m m m CO CO m m m CO m CO CO CO m CO m m m CL n. n. O LL CL CL CL LL CL 0 0 0- 0 0_ 0 Cl_ 0 CL CL CL CL a O a d x a O0 0 a CD a) E o O o O o O o O o O o O o O o O 0 O 0 O o O o O o O o O © O U O U o U O o O O O o o O o Z o U O U O U O O O O O U mE 0 (0 C m C m 00) 00) 0 (0 0 (00 (Q C m C m C m C m 0 (000) V 2,• E m LL m LL m LL m LL m LL m LL m LL a LL m LL m LL 0 LL m LL O LL m LL CO E) a) N a) N m w m N a) m 0) W a) N m N a) Cn a) CC 0 N a) N a) N a) C 0 () p U p U p c) p U p U p c) p () O u p c) p U 0 0 OO () G CO C C C C C C C C C C C C C E a) m ( m o m m m a) m N as N m N 2 m N m N m N (a d m N (` O C m C m C mC m C m C m C C0 C m C m C CO C m C N C C6 C (6 (0 a) m a) m o a) a) 0 0 0 o m a) m o d) o al 0) 0 a) m o a) o a) a) m 000000 U U U U U U 000000 U U U U 0 U 0 0 0 0 N LO C0 0) r (O 0) CO CO CO N- 0) CO CO CO N r V 0) V Cr, V CO 0) CO 0) CO (0 r 6) V CO V 0) CO 0 0 CO 0) CO s- CO 0) CO CO CO CO (O 0 (O CO (0 00 U r _N CO CO 0 N (O 0) CO O CO M (O N CO 0 CO O CO r CO 0) CO O) Co N V C0 0) CO V V V M6 M M r N (O (O r V r V M W 6 N6 N i 1 co CO CO s- s- s- s- ,- s- CO s- CO CO CO CO m a1 LL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0) 0 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 O Cn vi O O O CO O O O (0 O O CO p (N O O Cn O CO O O O C0 O C() O m LO N N N N (0 r 0 0 CO N (O (O r N r O CO N O r 0 (0 (O N CO N (0 O a C=" CO V CO V CO V CO CO V (O V CO V CO V (D CO CO CO p CO CO CO V CO V CO V 0r, 00 0 m p2 V N CO CO (0 V O V CO (O CO CO O) 0) CO CO N V CO CO CO O) V 0) V C CO (O O 0) CO CO r CO r V CO CO CO N CO CO O r CO CO CO CO CO CO 0 0) 0 0) 0 494° V M V CO CO CO CO CO O 0 CO N CO V CO CO CO CO M CO V CO V CO to' r r V V s- s- co co CO CO N N N N 0) et r N r- s- s- s- V V r N N N- - W 2-,W m co C0 0 0 CO O 00 0 0) C0 C0 00 CO 0 CO 0 CO CO (0 0 0 0 0 0 CO 0 CO 0 CO CO 'O 0 0) 0 0) 0 6) 0) CO 0 O) 0 CO 0 0) 0 N CO 0 0 s- 0 s- 0 0) 0 0) 0 0) i O V (0 O) O m O V 6 6 CA d) 6 V (C) O) OO r CO O C0 O O 6) (0 0) CC) 0) 01 c L O N N V C0 V CO CO 0 V N V CO r N N W V N 0 r 0 (O V N V N V (a CC G.' CO V CO V M V N N V CO V CO V CO V (O r CO CO (0 CO (0 CO V CO V CO V Q 03 d V rf E C O O O co O r CO V O co 60) N O N 0 CO V COO 0 N-CO 0 N 0 0))CO 0 CO 0 CO •A d O O O O O s- O O O) O O O O O) N CO O O O O O O O O O O ii o U co CO (O (O N N CO CO (D CO N CO CO M CO ice. CO CO N N N N (O (0 CO 00 CO CO O .0 E R cp /A O C_ ul v co .2 0 C. r C co ii C CO SO 0 0))CO 0 0M) 0 00) Op) W 0 O) O CO O 00) 0 CO CO 0 0 0 0 0 0 00)) 0 00)) 0 OO) N E L O V CO 0) O V O W CO 0) O V (O O r( (O O (0 O O W (0 O) COoi 0 CO CO V CO V CD CO O V CO V (O r CO N Cf) V r 0 r 0 CO V CO V CO V U C O Oy O)M V CO V M V N N V (0 V p V CO V CO r CO CO CO CO (0 M V CO V CO V 0 w ; _ .R Cl) 0 o 2 N C• 4cn-4m 0 z r E_ 0 (a, . (o' N . L O O O O co 0 C N (0 N p) O) O O O O N m m c 0) 0) C C °3 w m m CO CO E t w ' 0 0 L 9) T T O ) = n r COa ( y° ao OO ooEE YYmNN �E° aoo m To m m oaO m C 0 o o E E E E m rt, co 9 r 0• 0 = m m m m CL i N ` 2 CO E r CO CO J J z z m x x F c? c? a n El m 3 (... 0 0 L 3 C N LLCO N- r CO CO (O CO 0) 0) (O (O CO CO r r (O 0) O) CO CD r r N CO V W m U Z 0. a d Q C_ n a a a a a a Cl d d d fl. d d J J d CL co CO CO M c a a c E 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 • 3 3 ` 0 N • N CO M V V (O (0 CD CO CO CO O 0 0 ,- CO CO oh oh oh LlC0 c $ m L 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 s- r- — ,- N N 7 N N N N p OA y y 7 V TD • N N N N N N NNNNNN NNNNNN N N N N(0 OS ( N N Om .Z` N (Cl • C C C C C 1 1 ( ( C C C C C ( i C C ( s- _J � C J J J J O0 , CO CO CO CO V V (O (0 CO CO CO CO 0) O) 0 0 CO CON CO CO CO CO W E YY r CO 0 0 0 O 0 O 0 0 0 O 0 0 0C 0 0C 0 s- s- s-( s-' s-(- s-C s- s- s- s- s- s- et 70 ',F, CO m oh 66666 666666 mnn666 6665U6 666 MS CONNNNN CONNNNN CONNNNN CONNNNN CONNN (n d N Z R O d O 0... C C CCCC CCCCCC CC C C C C C mCC N O as o pu = dm m m m m nm am m m m 0m Om am a m a m om am nm m m m m a m 0m om • O _N ( (I0 Z .yOW CO 000000N CO CO V O o N O O o CO O W 0 0 r r r COrN CO p0 N N ' E L m 6 (n 6 (n (n 6 U7 (n (n (n (n (n (n N 6 m UJ (n (n (n (n (n (A (n m m 6 O CO _m m CO (Q N N N N CO N CO N N N N N CO N N N N N CO N N N N N CO N N N V • U C C 'a Z 0. E Q' C CC C C CECECC C C C C CECCC CEEC } U 0C re Ce N 0 0m mLL m CO 0m CO dm m om m m m am m m m Om m am am 0m 0m Om m dm 0 O.m m O c c Qi o U U F- K (n CO • • N G = (i) I ( rn = 0 G • = U ,-, ,� .x 3 CS 7 N N N N U) tl_) N N N N 0 COCI 0 0 0 0 0 0 o `o `o I. Q y (n 2 2 2 2 2 2 :Ci. 2 2 2 U) N N N N N N N N N N W N N N Co N (0 N co co LL a a LL LL LL LL LL d CL O c O a G /22 E d O d O d O d O d O O m E C( UO C (UO c N C c c m U 1° LL N LL 23 LL N LL 2 LL W 0 U o U D U oi O U Q U E d CO d CO d CO d ` d N C U) U) U) O c (o c (0 c N c W c m H N N N U) d d d 0) d d d d d d >, < < < U U (.) U U 3 0 0 0 0 o Y Y CO O) CO CO O O co N N- ° U) < < < S U) CO M V (O U) V 0 N CO U) O M O) N N- V N- V CO N- Co L CL 2' CTI aO O N W 0) 1� O (0 (O U) U LL W W M N M N V M U) V N.- CO co lj 6000000 0 } 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 vi 0 0 0 Ui o o vi Ui o L N U) 0 0 N- U) (I) N N O N a=" co V M V N M N M N M (p d N CD 0 a 2 U C O 0V) co (Vo 00)) M V 000 CO N dN- 0MMV N. 0 (O CO 0) 0) N id = s- 1- N N N N N N N N O. N N V W W Cl, 6 O 0 00 O 03 0 0 O 0 0 0 a 0 O 0 0) 0 0 0 0 0 0 0) E) Ui O) O O U) O O U) N O C bf N L tN V O M N1� MU) N N N O 4 N (Ated• -2- d d V j II E U) N r- CO M M N CO s- V N C 0 OO 0 N. 0 U) 0 (0 0 (0 _ • 7 d O O O O O O O O O O �{ N = U W a0 V N N- N- 0 0 'On = E y a - N N N N N N M M C V O C_ N 2 V R 2 0 N O a. C C C C C C C Q _a .0 d C d 0 0 0 0 0 0 0 co 0. o d •p 0 m 0 CO0, 0 0 0 0 0 00 0 N U • 6 = O. M V OM M N N N <C>i N OM O. a a a a a a U! a 0 d x d 0 1- N- r r N N r c .Li -6 w ; CO 2 0 0 0 0 0 0 0 a) m r C/) d (8 2 u) u) (n 6 6 66 w d N K O N N N N N N N d O E C N N _a LL N t ? N- E O O M co co co N N 3 (U 9 0 0 0) O) O) CO N C d C • Z r U) C O O I� r M M (` •O d d (U N N N N N W 00 (0 `)- c).) U) co 0 Cl) N (0 CO O y r r O) V co co C N y N •� C N 00) C C N N I- V ,- N V 0(] O) 0 d U j p, t O .ca 2 O O O O N m N N N E 7 d C (0 O a s U U TB 6 U W C N O d 0 a d 10 (0 U OU .`-'? T. U O a N O L O ^ = co a .2 3 3 > d d O' a- T T >. N m d CL N ` U d u 5 2 2 U) (0 2 2 d a 'O N .L.. R E m m E 0 0 0 M M 00 co Z N - d d U1 L V m N N Z CL d N.0 0 (o 0 0 O to O (p O O O W D7 Q) O) O N 4= C coco O O o O 0 0 0 O L W O O 1- N- M M N C - Q {O C 1 N U d 0. a a a a a a a E N U) U) N N N m j o _ (h N 3 3 3 3 3 3 3 3 O 0 1` rn rn w °1 o L o }I G a E d N N • V) LO CO CO N. i LL ` N N W 00 O U O) c -2 p d d L R R ' d N U) U) U) (n U) (n U) U) N t N d N 7 O M C 7 V m 0] N N N N N N N N Q a = 0) N 0_ d d N U d d U O On ?+) N N M M V V U) U) (0 (0 N- N- w (0 d C ... ) U II K m M 7 E U) U) U) U) U) U) U) U) U) U) y `) O m N C N10 O 3 C ONi Z N N N N N N N N N N (`O) O. a d d d O LL - ECCCEE CCCC ' '112 U j C N N N Y y ui a m m m m m m m m m mc d 0 O c 3 a a a LL LL a a a a 0 N 'N 0 0 n m pm C O C C — Z •� 0 m d O r) r) V V N Lo CO (0 1` 1` E O_ Ld.. N • f3 (O N r r r r .Ld. _ U O O a o d N E • (N (n U) (n (n (n U) U) U) (N N o O 7 (C t0 N N N N N N N N N N O` a C m '- t.) V •C U = Z E c C C C C C C C C C d U O iJ U d 0 s r O CO CO CO CO CO CO (0 CO CO CO d (p N U C .- O > w c m m U LL a o a LL LL a a a n Q 2 o_ 2 C Q N_ d _ F y y W U U) O U Q • 2S-07w 10 [Goblin] Lad er View pThe Reference Well is along the X-axis, Error Ellipses are the Sum of the Reference and Offset Well Errors. >° 1 § o �1 „ a° d m a fa @i E E C a S �t��pp I t ($ J Z 2G o C m®® O Q�0 0 :103; e3 3 5�3N a Q�/Q t NN laNh fQl N N N N N N I 300— nl � 0 I [ _.... 4__' y IDI1lt 0I�Ip c �Ir IIllI1ii i I- .......InI01II II �p I )! I ! i- ;I 1pXl � �! ',I'll nnYIIplllIIi ; '����' II � ca I IIY� II �lII 111,, j[II1II` a ��All ,IIi IlI IIr alPmnnllllYl[Id ,II ( 0/1114lil_ 150 nll . d i' ,lo IV i ���I .. IiI Ill 1 — ..u1nI1I ( � i. it �011lti1 .......Ilnlpl] 1, 11II110Y mi1i 00, iii(Il�l� IIlnijWU ...„I III + Ioin„„,„,, lll ! ........... .. . 0 Equivelant Magnetic Distance I I I I , I I I I I I I I I I I I I I I TZ 0 1500 3000 4500 6000 7500 9000 Displayed interval could be less than entire well:Measured Depth 28.00 To 14387.22 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 14387.22 Results Limited By: Centre Distance: 1635.92 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 750.00 2S-07wp10[Goblin] (Plan:2S-07) GYD-GC-SS 750.00 1750.00 2S-07wp10[Goblin] (Plan:2S-07) MWD 750.00 2927.93 2S-07wp10[Goblin] (Plan:2S-07) MWD+IFR-AK-CAZ-SC 2927.93 4427.93 2S-07wp10[Goblin] (Plan:2S-07) MWD 2927.93 8183.98 2S-07wp10[Goblin] (Plan:2S-07) MWD+IFR-AK-CAZ-SC 8183.98 9683.98 2S-07wp10[Goblin] (Plan:2S-07) MWD 8183.98 14387.22 2S-07wp10[Goblin] (Plan:2S-07) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2623.00 2927.93 10-3/4" x 13-1/2" 10-3/4 6358.00 8183.98 7-5/8"X 9-7/8" 7-5/8 6360.00 14387.22 4-1/2"x 6-3/4" 4-1/2 LEGEND -i— Plan:2S-01,Plan:2S-01,2S-01wp07[Mako]VO —ti— Plan:2S-09,Plan:2S-09,2S-09wp06[Tiger]VO —X— Plan:2S-13,Plan:2S-13PB1,2S-13PB1wp06[Megalodon]VO -e- Plan:2S-02,Plan:2S-02,2S-02wp08[Thresher]VO --- Plan:2S-10,Plan:2S-10,2S-10wp09[Wobbegong]VO —X— Plan:2S-14,Plan:2S-14,2S-14wp07[Whale]VO -9- Plan:2S-03,Plan:2503,2S-03wp06[Bamboo]V0 —e— Plan:2S-11,Plan:2S-11,2S-11wp06[Great White]VO --X— PIan:2S-15,Plan:2S-15,2S-15wp06[Helicoprion]V0 — Plan:2S-04,Plan:2S-04,25-04wp09[Lemon]VO -e- Plan:2S-11,Plan:2S-11L1,2S-11L1wp06[Great White]VO -e- Plan:2S-16,Plan:2S-16,2S-16wp06[Squalicorax]VO -8- Plan:2S-05,Plan:2S-05,2S-05wp06[Nurse]VO --zr- Plan:2S-12,Plan:2S-12,2S-12vp07[Bull]VO -e- Plan:2S-17,Plan:2S-17,2S-17wp06[Hybodus]VO Plan:2S-06,Plan:2S-06,2S-06wp06[Salmon]VO -A- Plan:2S-13,Plan:2S-13L1,2S-13L/wp06[Megalodon]VO -9- 2S-07wp10[Goblin] --e- Plan:2S-08,Plan:2S-08,2S-08wp07[Hammerhead]VO —1-- Plan:2S-13,Plan:2S-13L2,2S-13L2wp06[Megalodon]VO • 2S-07wn10 Goblin'] Lad Per View r The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 3 N 2 fS t 3 I m cA JN fOl r wuv 60— f , ii112i 4 30_ :... U 0 a� c 0 U - Equivelant Magnetic Distance 0 I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I 1 I I I 0 500 1000 1500 2000 2500 3000 3500 Displayed interval could be less than entire well:Measured Depth 28.00 To 14387.22 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 14387.22 Results Limited By: Centre Distance: 1635.92 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 750.00 25-07wp10[Goblin] (Plan:2S-07) GYD-GC-SS 750.00 1750.00 25-07wp10[Goblin] (Plan:2S-07) MWD 750.00 2927.93 25-07wp10[Goblin] (Plan:2S-07) MWD+IFR-AK-CAZ-SC 2927.93 4427.93 2S-07wp10[Goblin] (Plan:2S-07) MWD 2927.93 8183.98 25-07wp10[Goblin] (Plan:2S-07) MWD+IFR-AK-CAZ-SC 8183.98 9683.98 25-07wp10[Goblin] (Plan:2S-07) MWD 8183.98 14387.22 25-07wp10[Goblin] (Plan:2S-07) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2623.00 2927.93 10-3/4"x 13-1/2" 10-3/4 6358.00 8183.98 7-5/8" X 9-7/8" 7-5/8 6360.00 14387.22 4-1/2"x 6-3/4" 4-1/2 LEGEND Plan:2S-0t,Plan:2S-01,2S-01wp07[Make]VO -6,- Plan:2S-09,Plan:2S-09,2S-09wp06[Tiger]VO --X— Plan:2S-13,Plan:2S-13PB1,2S-13PB1wp06[Megalodon]VO -e- Plan:2S-02,Plan:2S-02,2S-02wp08[Thresher]VO —X— Plan:2S-10,Plan:2S-10,2S-10wp09[Wobbegong]VO --e Plan:2S-14,Plan:2S-14,2S-14wp07[Whale]VO -B- Plan:2S-03,Plan:25-03,2S-03wp06[Bamboo]VO -Q- Plan:2S-11,Plan:2S-11,2S-11wp06[Great White]VO — Plan:2S-15,Plan:2S-15,2S-15wp06[Helicoprion]VO - — Plan:2S-04,Plan:2S-04,2S-04wp09[Lemon]VO --e— Plan:2S-11,Plan:2S-11L1,25-11L1wp06[Great White]VO —e— Plan:2S-16,Plan:2S-16,2S-16wp06[Squalicorax]V0 -B- Plan:2S-05,Plan:2S-05,20-05wp06[Nurse]VO -- Plan:2S-12,Plan:2S-12,2S-12wp07[Bull]VO -e- Plan:2S-17,Plan:2S-17,20-17wp06[Hybodus]VO �— Plan:2S-06,Plan:2S-06,2S-06wp06[Salmon]VO -- Plan:2S-13,Plan:2S-13L1,2S-13L1wp06[Megalodon]VO -8-- 20-07wp10[Goblin] - Plan:2S-O8,Plan:2S-08,2S-08wp07[Hammerhead]VO —i— Plan:25-13,Plan:2S-13L2,2S-13L2wp06[Megalodon]VO Inc Azi TVD +W-S +E/-W Dleg TFace Target a • r 2 1.00 0.00 28.00 0.00 0.00 0.00 0.00 2S-07wp10 [Goblin] 600.r. 225 171.27 450.002s� 0.00 0.00 171.27 -.0 450 640 28.00 To 14387.22 1499.47 24.74 171.27 1469.00 -209.02 32.10 2.50 0.00 -193.59 640 840 1609.57 24.74 171.27 1569.00 -254.56 39.09 0.00 0.00 -235.77 2028.99 39.00 178.00 1924.39 -474.39 57.11 3.50 16.92 -443.44 3741.40 39.00 178.00 3255.18 -1551.39 94.72 0.00 0.00 -1474.01 840 1030 4287.98 27.05 149.97 3715.24 -1833.51 163.57 3.50 -139.30 -1728.71 10:42,May 06 2015 4950.76 27.05 149.97 4305.49 -2094.51 314.42 0.00 0.00 -1941.76 1030 1220 7209.97 68.00 40.00 6015.00 -1666.89 1427.24 3.50 -117.44 -1240.70 7944.07 68.00 40.00 6290.00 -1145.48 1864.75 0.00 0.00 -623.82 12,20 1420 SURVEY PROGRAM 8339.32 86.15 38.38 6378.04 -848.03 2107.00 4.61 -5.18 -273.80 ,-pu.From Depth To an Tool 2So 8353.70 86.15 38.38 6379.00 -836.79 2115.90 0.00 0.00 -260.64 2S-Goblin 1.Heel 061214 BP 28.00 750.00 2SOTopl°[Goblin](Pion:MVO-GC-SS 9347.90 90.29 8.82 6410.52 63.67 2508.96 3.00 -82.67 710.87 1420 - 1610 750.00 175.00 2s-OT9p1o[Goain](Rom navy 10718.37 90.29 8.82 6403.50 1417.92 2719.09 0.00 0.00 2073.36 759.5 29993 29a7w1,10[Goblin](Plan:25M91O.1FRAK.CAz-SC 10913.96 90.00 14.68 6403.00 1609.33 2758.90 3.00 92.86 2268.55 2S-Goblin 2.T1 050714 PB 299.90 44993 2s-07wT1o[GoeoI(Plan:zs�O 1610 1800 299.93 818399 2sa7wp10[Goaiml(Men.29,9510,TR-Ax-CAZ.SC 10923.52 89.71 14.68 6403.02 1618.57 2761.32 3.00 179.36 2278.11 8160.98 909399 2907wp10[Gcdln](Plan.2509000 11366.97 89.71 14.68 6405.24 2047.53 2873.72 0.00 0.00 2721.54 1800 2330 8183.98 10397.7.7. 7.s-07wp10 1.01111](wen:xs165yO.iFR Ax CAz.sc 11543.19 95.00 14.70 6398.00 2217.80 2918.36 3.00 0.18 2897.55 2S-Goblin 3.T2 050714 PB 11592.89 96.49 14.74 6393.03 2265.62 2930.93 3.00 1.47 2947.00 CASING DETAILS 11705.99 96.49 14.74 6380.24 2374.30 2959.52 0.00 0.00 3059.38 2330 2850 11922.34 90.00 14.74 6368.00 2583.08 3014.44 3.00 179.99 3275.26 2S-Goblin 4.73 050714 PB TVD MD Name Size 12686.00 90.00 14.71 6368.00 3321.65 3208.58 0.00 -90.00 4038.91 2S-Goblin 5.T4 050714 PB 2850 3380 2623.00 2927.93 10-3/4"x 13-1/2" 10-3/4 13680.50 91.73 14.71 6353.00 4283.39 3461.15 0.17 0.01 5033.25 2S-Goblin 6.T5 050714 PB 6358.00 8183.98 7-5/8"X 9-7/8" 7-5/8 13806.55 89.21 14.69 6351.97 4405.29 3493.14 2.00 -179.54 5159.28 6360.00 14387.22 4-1/2"x6-3/4" 4-1/2 14386.70 89.21 14.69 6359.99 4966.42 364029 0.00 0.00 5739.37 3380 3900 14387.22 89.21 14.69 6360.00 4966.92 3640.43 1.00 -63.52 5739.89 2S-Goblin 7.Toe 050714 PB 3900 4430 4430 4950 0/360 _25-D6wp06[Salmon] 4950 "..._.._. 5480 5480 6000 12S-08wp07[Hammerhead]] �`y `1 A ' •����i `„-�� 6000 7050 -30/330 ��;a �`` � y, 30 12S.03wp06[Bamboo] 7050 8100 .a. • 41 ps, 1, `N - 8100 9140 ` wp09[L 11l - -A .g- *ma.`C' ,�?1'' • •.� `or 9140 10190 i�.P �.. ' •�'x'44` t` �1�' 1'`��'-' 10190 11240 414 N 2S-09wp06[Tiger]r- K �r s ` 1 ,►��4 j/r;; ��e ���I;1.1. !'..:•q r.�` s�� 12 11240 12290 /• �/,0e... .s 1, t- ,l -�\ 4-,le W 4, 12290 13340 -60/300 I%////i. - .. r��.1^.,:'�.�s,�90.x�' � �- +>C$: 1® a����-. �� \ 60 13340 --. 14387 F'�it/pj0 � ��ay7. 4GPi®P �'� �� �: p` �1��t11i {!/� O -"�t�-i ,L�,c ,� �'�',„40/�i[��6�� 1 �, �pQO �►� A1.��� f1 2J" "�!#s C ii1 i/'�, y is ���\ e� l�• �t `\ [Bun]] . so y` r alaiv,� 2S•1 7 Bul y p G n i �� I/j!► ► i 5�i. '�'1� l �Jij� k .� / lifia...,Ki7:19i4,.fioiFfi , ‘ r i/rif �y �`��OA�s1� 1 `��,\>> 46,,i�1,A�1 _ _ -'� _ �� �\ ��11�1 I2S-01707[Mako]I rig/64 %/ rt 4o:.i1.', `` ;�i�po+oi_.*A�� lalik.r� �3 _-� >, �a i/ v�, a +quo l'Ife' 1. � - ���' r41 ♦e���i *rirr :V 'G Abp .ate ' I2$42wp08[Thresher]I NT/I��� y-- :.-,7------17:,...,;_____:; '711-....":.',,...1.,.. %'' Vii.%'' 11A lel`baa v :47� �® ' ��� • 4 --- liwe4 �� ��. :, �,a sf� q4 \\\'` 's t..r�11rt �[ 12S-05wp06[Nurse] . ,...,..:,.......„,..,. .......,,,,, \. .lig„ ,,q' v✓�w�a F. w.,✓: 1/�ieF ATtgt 4v.:-�' 1_i•,1;;4*� -90/270 I ��A'.:;■�I i I��'llfi ��� '� �•�'11;` `,, v� �, .� . - - .��, .� 90 III 1111 II] a��'a i:'` " •h •l"Willi II' � 11 � 111 �t�IIS � t `.� f`►I11..�/' �"�W �i� iii ;; 2S 11L1wp06[Great Wh.:1 1 mA ✓ t0 2S 11wp06[Great j1 rj�V 1 Pe�l�4�pire .�p11 1 Aiiiii ' / f d it tg i I2S 14wp07[Whale] i I 1 i;J, �s. 60 rk 4,�1`l/10.0.jprgt Q 11 ,I yy.1. 1 ..:� % ,/i.,10,,/•-�li a I���ib.. rfill 2S 13L2wp06[ e alodon]1if 111 i 90 - J/ii ®10 "7 �®�O��I/I`.'"si a sow, i 1/412S"13L1wp06[Megalodon]S.\1/4 ` 121 ®� Y� I�I�.` 120/240 11 �yi' � yr 120 for ir 150 �, - - ! �� ��0 ��� 165 WYAT, 180 ►0L®' / 12S•10wp09[wobbegon9]I 195 -150/210 - ►1II 150 ,, -180/180 t 5-01.291 M.nl ro $ nem 2.5,Plan:2505.2829.29099.nel vo "9(- 09m x510.Ran:2810,2810.x0 wab0aaorv,Va -A Pam 01,5559(M-.0001(vo -X- r 15o000[t.h000"em v0 i 0.022,027nn.n.100 "A" Marc 2sre.Nan:afa,2s-0a.295(9.2naa Vo ? Plan 20.n,Mart 2811,2811.295(08.1 wnaai v0 } PlartPlan 810105505 IM2 .W.1(V. ♦ P 15.x5lPnn.ennlv0 } an:2000,25-00.295[Bamboo]v0 "♦ Pon n 20207 6ann.70,9 v. ♦ w nL,al.19nv Wive]V0 -9F 7...10.P.20-tann, 28.15P0108.26 nt.a.a9 9 vo $ Pan 20.17.Pan 26 IT,20-17,0019v50a..]VI [- an 2S-02.Plan:2304.250..009en0n1 V. "Sr Pan 2550.Pon:2909.2509.,,05 NO VO "0" Plan 2512,Kan:2512828 2.07 Pug!v0 4E- Pan 2514.Plan.00.10.28.12297 507221V0 $ 2801,210 M..m II • Northing (3500 usft/in) • 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11111111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1 1 1 i 1 1 1 1 1 1 1 1 1 1 1 - O - - Y — N 00. la 'S N cob - - Q _ - A z - (0p' - C Q N 3 N - O p O 0 _ C7 — p N 0 O R! N ti m app p cp O O N Cs)Q Co - a ED o v) p N 411 Fp^y� — -ic.3 [01,400,441# Q LL I;- = c �p� fti CCS _ .� _ `i. - c0 ` �. O - Niiiiiiiiii....._ I Ir. - ,., —'" "*"1114. Ir. 41 ifS W L f o \ _ 03 �_ W pN i• \ N U Q - CO N'IIILA . - N N \ LL_�.� ��GO N _ - �, N = p«+ - CZE 6 — =N 3� -- U) it \ - CV — 6 — = N Ls Cr3 - 0- - - = - - - ;;,t� 1— - - Q? _ • -a - a _ — co — • _ - to - Z - NT yr �p _ O - m I i I I I I i I I I I i I I 1 I i I I I I I I I I I i I I 1 1 I 1 1 1 1 I I I I I I I I I I I I I I 1 I 1 1 1 111111111111111111 q, (ui/ltsn 005E) 6uiylaoN a T Pool Report • • �Q. 4 kv N 13/41 i 2K-14 4f �ti� 00 LON T— h b ' X888888888 " , Z p.- ;n8888888N§ '; ._-13 x-190 -19 y `45 ;7....myN. . . i O b � o ammmmv O 9. mmmvdL�a -9.,.:22222.-H) i. w00 W 888888888 ' 9A oc'ommioinoorio 2 ���8`82,18 2 13A `C 0 w ?� �--I x,19 00 in ao_aaaadae �Z-�Z N- ^<a< n�� a o�-�z nay !HOP acv riovi ion�r ,C kiC in A9 g co NLV O ^ 47 LO a r N CD 0 J I- N ♦o u w T Nvo o LON a o o co o o 0 Ln c_iO ,o 1 O t LO a y O O O O O O in O O O O O Ln O LO Ln O +)U��N/�-)u�nos cv in 0 • . I O O — Lf) N 1-- LT;w Z X8.8.8.8.88.88$ -,.9.3' m8888888NF, O s':;H _O .5-.5--5.5,5b.-522mmmmmmmmro mro m2......= O i tl� UUUUUUUUU H W O 888$$88$$ F O We 55 1.....aalt .-_. m, LO w aaaaaaa'p (Z. 8-o1.-2 no 3 NaevQQvvnN^ lki Qs- ! —. — Ln o .. cv : ImW o Iv Cj ' rl � r C t< - Q O O O S O Two o 0. I=2 N Oas CO 0 o O LO 1 . g o O a O O O O O O g O O O O O Li) O LO Ln O r Ln +)U��N/(-)u1noS c� Ln i • 2S-07 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.First well on pad,so no real anti-collision risk,only with future plans. 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. 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 across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—13.0 ppg in Tarn formations crossed in intermediate. Hole cleaning Low Use PWD and TAD 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 monitor ECD. 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. • • 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 TAD 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. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD 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. 2S-07 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 2428' MD. Client: CPAI Revision Date: May 6, 2015 Prepared by: Jenna Houston Location: Anchorage, AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -225 min. (pump time plus 120 min.) Mobile: (907)223-8916 DeepCRETE @ 11 ppg-1.91 ft3/sk email:jhouston2@slb.com 1.339 ft3/ft x(110') x 1.00 (no excess) = 148 ft3 < TOC at Surface 0.3637 ft3/ft x(1381 - 110') x 2.50 (150% excess) = 1156 ft3 0.3637 ft3/ft x(2428- 1381) x 1.50 (50% excess) = 572 ft3 148 ft3+ 1156 ft3+ 572 ft3= 1876 ft3 1876 ft3/ 1.91 ft3/sk = 983 sks (-1000 sks) �' Please have extra DeepCRETE on location for top out. Previous Csg. Tail Slurry Minimum pump time: -180 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(2928-2428) 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) ,'Illl < Base of Permafrost at 1381'MD(-1,360'ND) PUMP SCHEDULE Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH ll 7.00 100.0 14.3 14.3 Pause 0.00 0.0 5.0 19.3 < Top of Tail at 11 ppg DeepCRETE 7.00 333.8 47.7 67.0 2,428'MD - Surface Tail 7.00 56.3 8.0 DeepCRETE Slurry75.0 Pause 0.00 0.0 5.0 80.0 Fresh Water 7.00 10.0 1.4 81.4 Pause 0.00 0.0 5.0 86.4 Mud 8.00 253.9 31.7 118.1 Mud 3.00 10.0' 3.3 121.4 < 10 3/4",45.5#casing MUD REMOVAL in 13.5"OH Expected Mud Properties: 9.5 ppg, Pv<20, Ty<20 TD at 2,928'MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv z 17-21, Ty m 20-25 (2,623'ND) . l Centralizers: As per CPAi program. Mark of Schlumberger • • 2S-07 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 1St Stage (V1) Location: Kuparuk Client: CPAI Revision Date: May 6, 2015 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 40% excess. The top of the 1st stage tail slurry is designed to be Location:Anchorage, AK Phone: (907)263-4207 at-6,350 MD. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -230 min. (pump time plus 120 min.) 15.8 ppg Class G +GASBLOK*adds- 1.17 ft3/sk 0.2148 ft3/ft x(8184'-6350')x 1.20 (20%excess) = 473 ft3 0.2578 ft3/ft x 80' = 20 ft3 473 ft3+20 ft3 = 493 ft3 493 ft3/1.17 ft3/sk = 422 sks Round up to 432 sks Previous Csg. < 10-3/4",45.5.#casing at 2,928'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) MUDPUSH II 5.00 50.0 10.0 10.0 Pause 0.00 0.0 5.0 15.0 < Stage tool at 5,600'MD 15.8 ppg GASBLOK* 5.00 87.9 17.6 32.6 Slurry Pause 0.00 0.0 5.0 37.6 Fresh Water 5.00 10.0 2.0 39.6 Pause 0.00 0.0 5.0 44.6 Mud 5.00 352.1 70.4 115.0 Mud 3.00 10.0 3.3 118.3 < Top of Cement at -6,350 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 Centralizers: As per program in 9-7/8"OH TD at 8,184 MD (6,357'TVD) Mark of Schlumberger • • 2S_07 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 2nd Stage (V1) Location: Kuparuk Client: CPAI Revision Date: May 6, 2015 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 40%excess. The top of the 2nd stage tail slurry is designed to be Location:Anchorage,AK Phone: (907)263-4207 at-4,950 MD, 500'above the C37. Mobile: (907)223-8916 email:jhouston2@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(5600'-4950')x 1.20 (20% excess) = 168 ft3 168 ft3= 168 ft3 168 ft3/1.17 ft3/sk = 145 sks Previous Csg. Round up to 155 sks < 10-3/4",45.5.#casing at 2,928'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 Cumulative Stage Time Stage Volume Time (bpm) (min) (bbl) (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 29.8 6.0 19.0 Slurry Pause 0.00 0.0 5.0 24.0 Fresh Water 5.00 10.0 2.0 26.0 Pause 0.00 0.0 5.0 31.0 Mud 5.00 232.1 46.4 77.4 Mud 2.00 15.0 7.5 84.9 < Top of Cement at 4,950 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 Centralizers: As per program in 9-7/8"OH Stage tool at-5,600' MD (4,895'TVD) Mark of Schlumberger • • 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. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: /S—O??f Development V Service _Exploratory Stratigraphic Test Non-Conventional FIELD: 1• cAtt"F` Ri V POOL: KEN VEJ /�kyx,l'tnl JCi Az , Check BoxforAppropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • 0 N , ,. co o a) 0- „ 0 0) 2 E y. _o oS To c m' Q �' , C3. -C Ca ' 5' N, ' a) cc) G re w co O °� ° . , , m u.1' c' E 0 �, a 3' N' 0' N co c' °. (00, c O' 'O I- o 0 0 Y' E' .0 }? , 0. v' p' �, �, C ' x ' O 4Y a N. a) �' ' a)' L' D CC. a , �, �� E :: O, O L' _� re _..1d' u) L-• ' q , N' ' L ' 3. 0� -0, N, ' d, , v, y v co, ' o d O Q Y. c w. o. 0 •3' •y, 3, 0 m. , 'S, 3' '0, 0- Yco t' , ix, CO -' ' E , a o c ' co' ' y' >> -' as 0 2', 0 3 w o' ° va c0' Z' c' a)' a) a aa) m' > _CO c, ' a, O 0. CO 0. 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Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 141 Date: August 10, 2015 Surface Data Logging End of Well Report 2S-07 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. 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-07 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20713-00-00 Sperry Job Number: AK-XX-0902604811 Job Start Date: 21 July 2015 Spud Date: 22 July 2015 Total Depth: 7878’ MD, 6263’ TVD North Reference: True Declination: 18.657° Dip Angle: 80.867° Total Field Strength: 57489.786 nT Date Of Magnetic Data: 31 July 2015 Wellhead Coordinates N: North 70° 13’ 10.563” Wellhead Coordinates W: West 150° 9’ 19.086“ Drill Floor Elevation 147.5’ Ground Elevation: 120.0’ Permanent Datum: Mean Sea Level SDL Engineers: Hilary Garney, Macy Williams SDL Sample Catchers: William Halliburton, Jacob Floyd Company Geologist: Phill B Company Representatives: Don Mickey, Bob Finkbiner, Robert Wall, Andy Lundale SSDS Unit Number: 125 DAILY SUMMARY 07/21/2015 Begin rigging up mud logging unit. 07/22/2015 Finished rigging up mudlogging unit. Calibrated and tested gas gear. Began to pick up and rack back 5 inch drill pipe. Tested the diverter per AOGCC requirements then began to make up bottom hole assembly #1 and drill ahead in surface section. Fluids: 0 barrels lost downhole Gas: Max Gas 3 U and Average Gas 1 U 07/23/2015 Continuing to drill ahead in surface section. Fluids: 0 barrels lost downhole Gas: Max Gas 1118 U and Average Gas 135 U 07/24/2015 Continuing to drill ahead in and TD surface section at 2971’ MD and circulated bottoms up three times to ensure the shakers came back clean then performed a flow check, which was static. Began to back ream out of the hole to the base of the permafrost where the hole unloaded. Then began to pump out of the hole to the bottom hole assembly, which was laid down. Then began to make up and run into the hole with 10.75” surface casing. Fluids: 0 barrels lost downhole Gas: Max Gas 799 U and Average Gas 332 U 07/25/2015 Continued to run into the hole with 10.75” surface casing to casing point of 2958’ MD from which the mud was circulated and conditioned prior to rigging up and performing cement job per SLB. The cementers were rigged down and the landing joint was pulled out of the hole. The diverter was then in the process of being nippled down and prepping for nippling up the BOPs. Fluids: 0 barrels lost downhole Gas: Max Gas 94 U and Average Gas 10 U 07/26/2015 Continued to nipple down diverter and began to nipple up the blowout preventers. MPD crew rigged up and tested their equipment. The saver sub was changed out and equipment was rigged up to begin testing the blowout preventers per AOGCC. Fluids: 0 barrels lost downhole Gas: No significant gas data. 07/27/2015 Continued testing the blowout preventers per AOGCC then rigged down the testing equipment and began to pick up 4” drill pipe and rack it back into the derrick. Began to make up bottom hole assembly #2 per SLB rep when it was discovered that the wrong bit and floats were sent out to location. Waited for the right parts to arrive and continued to pick up the bottom hole assembly. Fluids: 0 barrels lost downhole Gas: No significant gas data. 07/28/2015 Continued to trip into the hole to 2695’ MD when the trip nipple was uninstalled and the MPD bearing was installed and tested per MPD rep. The MWD tools underwent a shallow hole test per SLB and then the MPD bearing was uninstalled and the trip nipple was reinstalled. The mud was circulated and conditioned prior to performing the casing pressure test to 3500 pounds per square inch for 30 minutes then continued to wash and ream down to 2915’ MD and began to drill out the cement. Once drilled out with 20 feet of new formation, the mud was circulated and conditioned before performing the formation integrity test, which was to 12.37 pounds per gallon, 16.0 pounds per gallon was what was wanted. The decision was made to pull out of the hole to perform a cement squeeze. Fluids: 0 barrels lost downhole Gas: Max gas was 346 U and average was 114 U. Geology: The sample consisted of translucent to transparent, clear, light to dark gray/brown, firm to hard, sub-angular to sub-rounded, fine to very fine grained, moderately well sorted sand with trace sandstone and mica. There was no odor, stain or fluorescence. 07/29/2015 Made up 3-1/2" tubing and ran into the hole to 445' MD then added 4" DP to 2902' MD. Circulated bottoms up and wait for cementers to arrive while monitoring the well on the trip tank. The rig was serviced as well. Pumped cement per SLB then pulled out of the hole to 2619' MD and circulated bottoms up prior to performing hesitation squeeze while holding pressure at 1000 pounds per square inch for 15 minutes. Then pulled out of the hole to 445' MD and rigged down and laid down tubing. Clean and cleared the rig floor before rigging up to test annular. Then began to pick up bottom hole assembly #3 per SLB and run into the hole to 2688' MD circulated and conditioned while waiting on cement. Fluids: 0 barrels lost downhole Gas: Max gas was 121 U and average was 12 U. 07/30/2015 Tested MPD bearing while waiting on cement to harden then uninstalled the bearing and reinstalled trip nipple. Washed and reamed from 2697' MD to 2835' MD and drilled out cement to 3023' MD and 20ft of new formation to 3043' MD. Circulated and Conditioned the mud until it had even mud weight in and out. Then rigged up and performed formation integrity test to 14.6 pounds per gallon. Control drilled while displacing well to 9.6 pounds per gallon LSND then continued to drill ahead. Fluids: 0 barrels lost downhole Gas: Max gas was 216 U and average was 60 U. Geology: Samples have been light to medium gray, soft, gummy, plastic, blocky, amorphous clay stone with trace amounts of sand, sandstone, siltstone, glauconite, pyrite and rare amounts of coal. 07/31/2015 Continued to drill ahead while weighting up mud system from 9.6 to 10.0 pounds per gallon and circulate the shakers clean. Proceeded to monitor the well for 30 minutes, static the pulled the trip nipple and installed the MPD bearing per company rep from which some troubleshooting took place on the MPD equipment. Then began to wash down to bottom and continue to drill ahead. Fluids: 0 barrels lost downhole Gas: Max gas was 149 U and average was 67 U. Geology: Samples have been medium to dark gray, firm to hard, platey, flaky in some places siltstone with some claystone and sand mixed in along with calcite. 08/01/2015 Continued to drill ahead pumping sweeps as needed then at 6668' MD pulled off bottom and performed open hole Formation Integrity Test to 12.5 pounds per gallon equivalent mud weight then continued to drill ahead when the power went out on rig. After regaining power, MPD recalibrated equipment then circulated bottoms up when the hole began to take losses, pumped nut plug sweep to try to control losses. Fluids: 110 barrels lost downhole Gas: Max gas was 1565 U and average was 150 U. Geology: Samples have been medium to dark gray, firm to hard, platey, flaky in some places siltstone with shale and occasional sandstone. 08/02/2015 Continued to pump sweeps with a loss rate of 50 barrels per hour; racked back one stand to establish loss rate at 650 gallons per minute with a loss rate of 60 barrels per hour. Spotted a lost circulation pill and circulated bottoms up with a loss rate of 45 barrels per hour. Washed and reamed back down to bottom and performed a breathing test per Company Man with 12 barrels gained in 30 minutes. Troubleshoot MPD then continued to drill ahead. Fluids: 220 barrels lost downhole Gas: Max gas was 1407 U and average was 362 U. Geology: Samples have been medium to dark gray, firm to hard, waxy shale with siltstone, occasional sandstone and pyrite. 08/03/2015 Drilled to TD @ 7878’ MD. Circulated 9 B/U and racked back a stand every B/U to 7050’ MD. Pumped 27 bbl H-Vis Sweep @ 7600’ MD. Reamed back into hole to 7878’ MD and pumped a second 27 bbl Hi-VIS Sweep followed by 2 B/U circulated. Performed a Dilution of the mud at TD by pumping 385 bbls new mud. Monitored well via Trip Tank due to well breathing. Monitored the well on the cellar till flow stopped. Stripped OOH w/ MPD F/7806’ T/6580’. trapping 150 PSI on hole. Fluids: 22 barrels lost downhole Gas: Max gas was 898 U and average was 90 U. 08/04/2015 Gas peak of 660 units was observed at just before 1AM while circulating. The Gas Chromatograph temporarily flamed-out during the peak. Stripped out of hole to the casing shoe while showing losses of 25 bph. CBU at the shoe and pumped a 20 bbl 10.9 ppg sweep. The well was breathing and was monitored for flow until static. The rig then began POOH on elevators. Fluids: 145 barrels lost downhole Gas: Max gas was 660 U and average was 29 U. 08/05/2015 POOH, L/D BHA, and remove radioactive sources. Changed SDL runs to run 340 while casing equipment was rigged up. Pressure Tested annular and Casing Rams. Began to RIH with 7 5/8” Casing. Fluids: 0 barrels lost downhole Gas: Max gas was 10 U and average was 3 U. 08/05/2015 Continued to RIH with 7 5/8" casing and started experiencing losses starting at approximately 4500'MD. Continued to RIH while losing all the way to bottom. Landed Casing and then circulated and conditioned the mud in preparation for the cement job. The Cement lines were rigged up and the cement lines were pressure tested to 4000 PSI. Fluids: 345 barrels lost downhole Gas: Max gas was 253 U and average was 53 U. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 0 5 10 15 20 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2S-07 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: Mi Swaco RIG: Doyon 141 SPERRY JOB: AK-XX-902604811 Days vs. Depth 21 July 2015 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 22-Jul-2015 TD: 3-Aug-2015 Commenced 13.5" Surface Hole Section On Bot: 10:56 22 Jul 2015 TD Surface Hole Section 2971' MD, 2646' TVD Off Bot: 06:00 24 Jul 2015 Landed 10.75" Casing 2961' MD, 2687' TVD 25 July 2015 POOH for FIT Failure Cement Squeeze 28 July 2015 Commenced 9.875" Intermediate Hole Section On Bot: 12:42 28 July 2015 TD Intermediate Hole Section 7878' MD, 6263' TVD Off Bot: 00:31 03 Aug 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The gas trap did get clogged up quite a bit but since the crew kept a close eye on the readings we were able to deal with these issues promptly resulting in minimal loss of gas data. Recommendations: Stay in communication with the pitwatcher regarding flow in the possum belly. Check on the trap on regular basis, if sample catchers are on location, they can also check it when they get a sample. Innovations and/or cost savings: N/A Doyon 141 Surface Hilary Garney 24-Jul-2015 What went as, or better than, planned: Even though we did have issues with the gas trap when it got clogged up, we were able to deal with the issue quickly. The gas equipment worked very well. No computer interruptions or crashes. It was a very successful surface section. 2S 07 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope -XX-0902604811 Alaska Surface Data Logging After Action Review 2S-07 ConocoPhillips Alaska, Inc. Mi Swaco Doyon 141 AK-XX-0902604811 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++ 22-Jul 845 9.00 180 29 44 26/32/37 -102/73/61/47/25/24 2/-3.0 /97 0.50 0.50 10.1 25.0 .40/.80 860 160 Drilling Ahead in Surface 23-Jul 2725 9.60 315 48 52 21/45/51 6.1 148/100/81/58/25/23 2/-7.5 1/92 0.50 0.32 9.7 25.0 .25/.80 300 120 Drilling Ahead in Surface 24-Jul 2971 9.70 220 41 54 30/55/72 6.1 136/95/80/54/25/24 3/-7.5 1/92 0.50 0.55 9.6 32.5 0.25/0.80 310 180 Running Surface Casing 25-Jul 2971 9.60 58 28 10 4/7/14 -72/44/33/21/4/3 -/-7.0 1/92 0.50 0.30 9.0 28.0 0.20/0.55 310 180 Cement Surface 26-Jul 2971 9.60 79 30 18 4/7/8 -78/48/34/21/4/3 -/-7.0 1/92 0.50 0.10 8.0 26.3 0.50/5.30 420 -BOP Test 27-Jul 2971 9.60 70 32 19 5/9/12 -83/51/37/23/4/4 -/-7.0 1/92 0.50 0.10 8.3 25.8 0.50/5.10 400 -P/U BHA #2 28-Jul 3023 9.60 47 21 5 3/9/13 -47/26/20/10/3/3 -/-7.0 1/92 0.25 0.20 9.0 25.0 0.10/5.30 400 -POOH for failed FIT 29-Jul 3023 9.70 68 28 6 5/16/22 -62/34/21/13/5/4 -/-7.0 1/92 0.25 0.20 9.4 25.0 0.10/5.40 500 20 WOC 30-Jul 3734 9.60 52 11 28 12/15/15 6.5 50/39/34/27/12/11 1/NA 6.0 3/92 Tr 0.30 9.2 6.3 0.20/1.30 280 100 Drilling Ahead in Intermediate 31-Jul 5340 10.00 49 11 30 13/14/15 4.8 52/41/35/28/13/12 1/NA 8.0 3/89 Tr 0.40 9.7 15.0 0.20/1.30 250 20 Drilling Ahead in Intermediate 1-Aug 6973 10.60 58 17 28 12/18/24 4.1 62/45/38/29/13/11 1/NA 10.5 3/87 Tr 0.30 9.2 18.8 0.20/1.00 300 20 Drilling Ahead in Intermediate 2-Aug 7688 10.50 47 14 29 11/14/16 3.1 57/43/35/27/11/10 1/2 12.0 4/84 Tr 0.30 9.4 20.0 0.20/1.30 420 20 Drilling Ahead in Intermediate 3-Aug 7878 10.50 46 13 27 11/13/15 4.1 53/40/34/26/11/10 1/2 12.0 4/84 Tr 0.30 9.5 12.5 0.20/1.10 420 20 TD'd Intermediate Section 4-Aug 7878 10.50 51 14 28 12/14/15 2.9 56/42/37/28/12/10 1/2 12.0 4/84 Tr 0.30 9.5 14.3 0.20/1.00 400 20 BROOH, Monitor Well 5-Aug 7878 10.50 52 14 29 11/14/15 3.1 57/43/37/28/12/10 1/2 12.0 4/84 Tr 0.50 9.6 14.5 0.30/1.20 420 20 POOH and LD BHA, RIH w/ Casing 6-Aug 7878 10.50 71 13 27 11/13/15 3.2 53/40/34/27/11/10 1/2 12.0 4/84 Tr 0.40 9.6 14.0 0.20/1.00 400 20 RIH w/Casing, R/U for Cement Casing Record SPUD:22-Jul-2015 SPERRY JOB:TD:3-Aug-2015 Remarks 16" Conductor @ 115' MD, 115'TVD 10.75" Casing @ 2961' MD, 2687'TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG: 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 1 100 1 Mill tooth 13.50 115 2971 2856 58.00 0.994 88.0 30 60 2075 725 1-1-WT-A-E-1/16-NO-TD TD Surface Section 2 200 2 PDC Bit 9.875 2971 3023 52 23.50 0.910 72.0 -177 810 708 1-2-CT-A-X-I-SP-HP POOH for Squeeze, Failed FIT 3 300 3 PDC Bit 9.875 3023 7878 4855 54.77 0.902 88.7 31 140 3730 728 1-1-PN-A-X-I-CT-TD TD Intermediate Section Alaska RIG:Doyon 141 SPUD:22-Jul-2015 WELL NAME:2S-07 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902604811 TD:3-Aug-2015 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: (lb/bbl)% P/U and racked back 5" DP in derrick. Tested diverter per AOGCC. M/U BHA #1 and began to drill surface section. rig Density (ppg) out (sec/qt) Viscosity C-5i 0 100% Gas In Air=10,000 Units- 22-Jul-2015 12:00 AM Current Pump & Flow Data: 1222 Max 96% - Lime Cor Solids ROP ROP (ft/hr) 4.23 @ Mud Data - Tools arcVISION, Telescope API FL Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 3.0 13.5" 9.00 Mill Tooth 9.00 Size 115' ConditionBit # 1 Chromatograph (ppm) 00 C-1 WOB Conductor Connection 0 -- Avg Min Comments Mud RPM ECD (ppg) ml/30min -Background (max) Trip Average - Mud Type Lst Type Ss Spud Mud -652'44 Depth in / out 0.50 000 CementChtSilt C-4i C-4n 0 Hours C-3 0' Larry Hill / Andy Lundale cP 29 24 hr Max Weight (ppb Eq) YP (lb/100ft2) Footage AK-AM-0902604811 Drilling Ahead PV ShClyst TuffGvlCoal Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 517.0 Flow In (gpm) Flow In (spm) Time: 0' 870' 870' Max @ ft Current 817'91.0 Date: 1 0 bbls lost down hole last 24 hours in 0 97'Minimum Depth C-5n 860' 82.0 C-2 3 SPP (psi) Gallons/stroke TFABit Type Depth 25.0180 MBT - Alkal 0.994 0 0 0 Siltst 636 152 Units* Casing Summary Lithology (%) 098 0 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney, Macy Williams Set AtSize 62.5 H-40 Grade 16.00'' (max)(current) 0 0 Cly 337 . . * 24 hr Recap: 144024 16.00'' (max)(current) 847 0 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney, Macy Williams 1619216 0 707 170 Units* Casing Summary Lithology (%) Set At - Alkal 0.994 0 418 0 Siltst 62.5 H-40 SPP (psi) Gallons/stroke TFABit Type Depth 25.0315 C-5n 2448' 44.0 C-2 1118 in 0 1041'Minimum Depth Size 135 0 bbls lost down hole last 24 hours 870' 2739' 1869' Max @ ft Current 2315'152.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 746.0 Flow In (gpm) Flow In (spm) Time: Gas Summary 0 15 128 (current) TuffGvlCoal Drilling Ahead PV ShClyst MBT Grade Cly YP (lb/100ft2) Footage 0' Larry Hill / Andy Lundale cP 48 Weight (ppb Eq) CementChtSilt C-4i C-4n 013 2525'52 Depth in / out Hours Mud Type Lst Type Ss Average -150Background (max) Trip Comments Mud RPM ECD (ppg) ml/30min 6.1 0.32 Connection 65 43 C-3 Chromatograph (ppm) 00 C-1 115' ConditionBit # 1 7.5 13.5" 9.60 Mill Tooth 9.60 Size WOB Spud Mud Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max AK-AM-0902604811 Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope - Tools arcVISION, Telescope API FL Depth -- Avg Min 96% - Lime Cor Solids ROP ROP (ft/hr) 4.23 @ Mud Data =10,000 Units443 23-Jul-2015 12:00 AM Current Pump & Flow Data: 2125 Max 3 100% Gas In Air Density (ppg) out (sec/qt) Viscosity Conductor (lb/bbl)% Continuing to drill ahead in surface section. rig C-5i . . * 24 hr Recap: 16.00'' (max) - (current) Surface 841 0 Cht Silt 907-670-4906Unit Phone: 2 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney, Macy Williams 40657 88 10.75'' 0 0 Units* Casing Summary Lithology (%) Set At 0.994 0 436 0 Siltst 62.5 H-40 101212 SPP (psi) Gallons/stroke TFABit Type Depth 32.5220 2971' 2781' - C-2 799 in 10 2739'Minimum Depth Size BROOH to base of permafrost shakers unloaded. POOH and L/D BHA #1. M/U and began running surface casing. 332 0 bbls lost down hole last 24 hours 189 2739' 2971' 232' Max @ ft Current 2863'65.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 95.0 Flow In (gpm) Flow In (spm) Time: 0 15 139 (current) C-5n TuffGvlCoal CementShClyst L-80 MBT Grade Cly Alkal 0' 2971' 2971' RIH w/ 10.75" Casing PV Dave Coates/Andy Lundale cP 41 45.5 Weight (ppb Eq) YP (lb/100ft2) Footage C-4n 07 Gas Summary 2971'54 Depth in / out Hours Mud Type Lst Type Ss Connection Average -Background (max) Trip Mud RPM ECD (ppg) ml/30min 6.1 0.55 321 Comments 64 C-3 Chromatograph (ppm) 00 C-1 59 C-4i 115' ConditionBit # 1 7.5 13.5" 9.70 Mill Tooth 9.70 Size WOB Spud Mud Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max AK-AM-0902604811 Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope - Tools arcVISION, Telescope API FL Depth -- Avg Min 96% - Lime Cor Solids ROP ROP (ft/hr) 4.23 @ Mud Data =10,000 Units- 24-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max 25 100% Gas In Air Density (ppg) out (sec/qt) Viscosity Conductor (lb/bbl)% Continued to drill ahead to TD surface @ 2971' MD. CBUx3 until shakers were clean. Flow check, static. rig C-5i . . * 24 hr Recap: 10.75'' (max) - (current) Surface 43 0 Cht Silt 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney, Macy Williams 1796 0 Units* Casing Summary Lithology (%) Bit Type 2971' in Depth 16.00'' Set At 0.994 0 8 0 Siltst 62.5 H-40 14198 SPP (psi) Gallons/stroke TFA Depth - - C-2 94 1 -Minimum Size pumped cement per SLB. Backed out landing joint, R/D riser and volant tool. N/D diverter. 10 2971' 2971' 0' Max @ ft Current -- Date: 0 Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm)0 Time: 0 0 2 (current) C-5n TuffGvlCoal C-4n Gas Summary C-3C-1 CementShClyst Cly Alkal 58.30 89' 2971' 2882' N/D Diverter PV Dave Coates/Andy Lundale cP MBT 45.5 Weight (ppb Eq) YP (lb/100ft2) Footage L-80 Grade 00 Chromatograph (ppm) 00 Depth in / out 30.0 Hours Mud Type Lst Type Ss Average - 31 Background (max) Trip Connection Mud RPM ECD (ppg) ml/30min 5 Comments 24 0 C-4i 115' Condition 1-1-WT-A-E-1/16-NO-TD Bit # 1 13.5"Mill Tooth Size WOB Spud Mud 60.0 2971' Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max AK-AM-0902604811 Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope - Tools arcVISION, Telescope API FL Depth -- Avg Min 96% - Lime Cor Solids ROP ROP (ft/hr) 4.23 @ Mud Data =10,000 Units- 25-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max 4 100% Gas In Air Density (ppg) out (sec/qt) Viscosity Conductor (lb/bbl)% Continued to RIH w/ surface casing. Circ and cond mud for cement job. R/U cementers, pressure tested lines, rig C-5i . . * 24 hr Recap: C-5i rig Viscosity Conductor 0 100% Gas In Air Continued to N/D diverter, N/U BOPEs. R/U and test MPD equipment. C/O saver sub. R/U and test BOPEs. SDL crew 26-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max (lb/bbl)% 96% - Lime Cor Solids ROP ROP (ft/hr) 4.23 @ Mud Data - Tools - API FL Depth -- Avg Min Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max AK-AM-0902604811 7.0 13.5" 9.60 Mill Tooth 9.60 Size WOB Spud Mud 60.0 2971' Condition 1-1-WT-A-E-1/16-NO-TD Bit # 1 =10,000 Units- 0.861 2961' C-4i 2 115' 0 Comments 0 0 Connection Mud RPM ECD (ppg) ml/30min -0.10 - 0 Background (max) Trip 30.0 Hours Mud Type Lst Type 00 Chromatograph (ppm) 00 (lb/100ft2) Footage 2971' L-80 Grade 18 Depth in / out BOP Test PV Dave Coates/Andy Lundale cP MBT (ppb Eq) YP Cly Alkal 58.30 89' 2971' 2882' 30 45.5 Weight CementShClyst C-5n TuffGvlCoal C-4n Gas Summary C-3C-1 Time: 0 0 0 (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm)0 2971' 2971' 0' Max @ ft Current -- Date: 0 calibrated gas equipment for intermediate section. 0 0 bbls lost last 24 hours Average -Minimum 9.875 Size Ss PDC Bit - - C-2 0 0 SPP (psi) Gallons/stroke TFA Depth 26.379 Set At 0.994 0 0 0 Siltst 62.5 H-40 Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Hilary Garney, Macy Williams 0 0 Silt 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers: (current) Surface 0 0 Cht 10.75'' (max) - Units* Casing Summary Lithology (%) 0 . . * 24 hr Recap: 0 Cht 10.75'' (max) - Units* Casing Summary Lithology (%) Surface 0 0 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney, Macy Williams 0 0 Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Silt 0.994 0 0 0 Siltst 62.5 H-40 0 0 SPP (psi) Gallons/stroke TFA 9.875 Size Ss PDC Bit - C-2 Troubleshoot and wait on bit. Troubleshoot and wait on floats. Continued to P/U BHA per SLB. 0 0 bbls lost last 24 hours Average 2971' 2971' 0' Max @ ft Current -- Date: 0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm)0 Avg to- C-3C-1 Time: 0 0 0 25.870 Set At C-5n TuffGvlCoal C-4n Gas Summary 45.5 Weight CementShClyst Alkal 58.30 89' 2971' 2882' 32 P/U BHA #2 PV Dave Coates/Andy Lundale cP MBT (ppb Eq) YP (lb/100ft2) Footage 2971' L-80 Grade 19 Depth in / out 00 Chromatograph (ppm) 00 30.0 Hours Mud Type Lst Background (max) Trip (current) -0.10 - 0 Type Cly 0 0 Connection 115' 0 (current) -Minimum 2961' C-4i 1 =10,000 Units- 0.8612 AK-AM-0902604811 7.0 13.5" 9.60 Mill Tooth 9.60 Size WOB Spud Mud 60.0 MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max - Depth Rig: 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: -- Avg Min Morning Report Report # 6 Customer: Well: Area: Location: ROP ROP (ft/hr) 4.23 @ Mud Data - Tools - API FL (lb/bbl)% 96% - Lime Cor Solids Condition 1-1-WT-A-E-1/16-NO-TD Comments 27-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max Mud RPM ECD (ppg) ml/30min 0 100% Gas In Air Finished BOPE testing. R/D testing equipment. P/U 4" DP for intermediate section. M/U BHA #2 per SLB. Viscosity Conductor Depth 2971' Bit # C-5i rig . . * 24 hr Recap: Depth 3023' Bit # C-5i rig 7 100% Gas In Air Continued to TIH to 2695' MD, uninstalled trip nipple and installed MPD bearing. Test MPD bearing and MWD tools. 28-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max Mud RPM ECD (ppg) ml/30min (lb/bbl)% 96% - Lime Cor Solids Condition 1-1-WT-A-E-1/16-NO-TD Comments 4.23 @ Mud Data - Tools - API FLViscosity -- Avg Min Morning Report Report # 7 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max - Depth Rig: ROP (ft/hr) AK-AM-0902604811 7.0 13.5" 9.60 Mill Tooth 9.60 Size WOB Spud Mud 60.01 =10,000 Units46 0.8612 Decision was made to TOOH to perform squeeze job. and washed and reamed down to 2915' MD. Drilled out cement. Circ and Cond. Performed FIT to 12.37ppg, wanted 16.0ppg. 2961' C-4i 115' 87 (current) 2971'Minimum Conductor Type Cly 67 25 (max) Trip (current) 30 Connection Mud Type Lst 100% Background - Chromatograph (ppm) 00 30.0 44 5214 2971' L-80 Grade 5 Depth in / out Hours 0.20 Prep for Cmt Squeeze PV Robert Wall/Andy Lundale cP MBT (ppb Eq) YP (lb/100ft2) Alkal 58.30 89' 2971' 2882' 21 Footage CementShClyst C-5n TuffGvlCoal C-4n Gas Summary 48 232 25.047 Set At 45.5 Weight Avg to- C-3 Yesterday's Depth: Current Depth: 24 Hour Progress: 227.0 Flow In (gpm) Flow In (spm)0 Time: 2971' 3023' 52' Max @ ft Current 2992'71.0 Date: 0 Uninstall MPD bearing and install trip nipple. Circ and Cond. R/U and tested casing to 3500PSI for 30 mins. R/D test equipment 114 0 bbls lost last 24 hours Average PDC Bit 2998' C-2C-1 0 35694 SPP (psi) Gallons/stroke TFA 9.875 Size 0.994 0 153 0 Siltst 62.5 H-40 Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Silt Hilary Garney, Macy Williams 11557 0 907-670-4906Unit Phone: 191 Hilary Garney Maximum Report By:Logging Engineers: Lithology (%) Surface 323 0 346 Ss 6 Cht 10.75'' (max) - Units* Casing Summary . . * 24 hr Recap: 3023' 52'1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 2971' Cht 10.75'' (max) - Units* Casing Summary Lithology (%) Surface 94 0 121 Ss 907-670-4906Unit Phone: 76 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney, Macy Williams 1357 0 Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Silt 0.994 0 57 0 Siltst 62.5 H-40 12288 SPP (psi) Gallons/stroke TFA 9.875 Size C-2C-1 Pumped cement per SLB. POOH to 2619' MD. CBU. Performed hesitation squeeze holding pressure at 1000PSI for 15 mins. 12 0 bbls lost last 24 hours Average 3023' 3023' 0' Max @ ft Current -- Date: 0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm)0 Time: Avg to- C-3 PDC Bit -19 97 25.068 Set At 45.5 Weight Clyst C-5n TuffGvlCoal C-4n Alkal 58.30 89' 2971' 2882' 28 Footage Wait On Cement PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP (lb/100ft2) 3023' L-80 Grade 6 Depth in / out Hours 0.20 265 Cement 30.0 13 Sh Gas Summary Mud Type Lst 100% Background - (max) Trip (current) 11 Connection Type Cly 27 8 Chromatograph (ppm) 0 115' 13 (current) -Minimum Conductor Circ and Cond. WOC. POOH to 445' MD then R/U to L/D tubing. Clean rig floor. R/U to test annular then R/D. P/U BHA #3 per SLB, RIH to 2688' MD. 2961' C-4i 1 =10,000 Units- 0.9023 AK-AM-0902604811 7.0 13.5" 9.70 Mill Tooth 9.70 Size WOB Spud Mud 60.0 MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max - Depth Rig: ROP (ft/hr) ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: - Avg Min Morning Report Report # 8 Customer: Well: Area: Location: ROP 2S-07 4.23 @ Mud Data - Tools - API FLViscosity - (lb/bbl)% 96% - Lime Cor Solids Condition 1-1-WT-A-E-1/16-NO-TD Comments 29-Jul-2015 12:00 AM Current Pump & Flow Data: 0 Max Mud RPM ECD (ppg) ml/30min 0 100% Gas In Air 0 06 M/U 3-1/2" tubing to 445' MD then 4" DP to 2902' MD. CBU. Wait on cementers. Monitor well on TT. Service rig. Depth 3023' Bit # C-5i rig . . * 24 hr Recap: Tested MPD bearing. Uninstalled bearing and reinstalled trip nipple. Wahed and reamed from 2697' MD to 2835' MD rig 100% Gas In Air 0 05 ECD (ppg) ml/30min 0 Depth 3734' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments 30-Jul-2015 12:00 AM Current Pump & Flow Data: 1884 Max Mud (lb/bbl)% 96% - Lime Cor Solids 4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity -- Avg Min Morning Report Report # 9 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max 0.0 Depth Rig: ROP (ft/hr) AK-AM-0902604811 6.0 13.5" 9.60 Mill Tooth 9.60 Size WOB LSND 60.01 =10,000 Units- 0.9023 performed FIT to 14.6ppg. Control drilled while displacing well to 9.6ppg LSND. Continued to drill ahead. 2961' C-4i 115' 27 (current) 3273'Minimum Conductor Cly 2 13 Chromatograph (ppm) 0 (max) Trip (current) -Connection Mud Type Lst 10% Background 6.5 30.0 1 Sh Gas Summary 20 Cement 3023' L-80 Grade 28 Depth in / out 0.30 Type RPM Drilling Ahead PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP (lb/100ft2) Alkal 58.30 89' 2971' 2882' 11 Footage Hours C-5n TuffGvlCoal C-4n 6.352 Set At 50% 45.5 Weight Clyst Avg to2961' C-3 PDC Bit 3025'26 120 Yesterday's Depth: Current Depth: 24 Hour Progress: 179.0 Flow In (gpm) Flow In (spm)204 Time: 3023' 4018' 995' Max @ ft Current 3079'113.0 Date: 717 and drilled out cement to 3023' MD and 20ft of new formation to 3043' MD. Circ and Cond mud for even MW in/out. R/U and 60 0 bbls lost last 24 hours Average C-2C-1 24371 SPP (psi) Gallons/stroke TFA 9.875 Size 0.994 0 79 0 Siltst 62.5 H-40 40% Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Silt Hilary Garney, Macy Williams 8236 39 907-670-4906Unit Phone: 98 Hilary Garney Maximum Report By:Logging Engineers: Lithology (%) Surface 175 0 216 Ss 2971' Cht 10.75'' (max) 25 Units* Casing Summary 3023' 52'1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 . . * 24 hr Recap: 23.50 Casing Summary 3023' 52'-177 1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 Ss 2971' Cht 10.75'' (max) 50 Units* Lithology (%) Surface 431 6 149 907-670-4906Unit Phone: 0 Hilary Garney Maximum Report By:Logging Engineers: Silt Hilary Garney, Macy Williams 6758 792 Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Size 0.994 0 16 0 Siltst 62.5 H-40 60% 19475 SPP (psi) Gallons/stroke TFA 9.875 30 mins, static. Pull trip nipple and install MPD bearing per rep. Troubleshoot MPD. Wash down to bottom and continue to drill 67 0 bbls lost last 24 hours Average 4018' 5505' 1487' Max @ ft Current 5345'116.0 Date: 703 Yesterday's Depth: Current Depth: 24 Hour Progress: 437.0 Flow In (gpm) Flow In (spm)200 Time: 2961' C-3 PDC Bit 5277'12 C-2 45.5 Weight Clyst Avg to 0 C-1 C-5n TuffGvlCoal C-4n 2971' 2882' 11 Footage Hours 15.049 Set At Type RPM Drilling Ahead PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP Cement 3023' L-80 Grade 30 Depth in / out 0.40 00 30.0 0 Sh Gas Summary Lst 10% Background 30% (max) Trip (current) -Connection 0 67 Chromatograph (ppm) 0 Conductor Cly 115' 48 (current) 4086'Minimum 3 ahead. 2961' C-4i 60.01 =10,000 Units- 0.902 13.5" 10.00 Mill Tooth 10.00 Size WOB LSND 4.8 58.30 89' 105.0 Depth Rig: ROP (ft/hr) AK-AM-0902604811 8.0 Mud Type (lb/100ft2) Alkal North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max Min Morning Report Report # 10 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk 4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity - 31-Jul-2015 12:00 AM Current Pump & Flow Data: 2756 Max Mud (lb/bbl)% 96% Depth 5340' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments - ECD (ppg) ml/30min 0 Lime Cor Solids - Avg rig 100% Gas In Air 0 010 Continued to drill ahead while weighting up mud system from 9.6 to 10.0. Circulate shakers clean. Monitor well for . . * 24 hr Recap: Continued to drill ahead pumping sweeps as needed. At 6668' MD pulled off bottom and performed open hole FIT rig 100% Gas In Air 0 03 ECD (ppg) ml/30min 421 Lime Cor Solids - Avg Depth 6973' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments - Current Pump & Flow Data: 2103 Max Mud (lb/bbl)% 96%4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity - Morning Report Report # 11 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk 1-Aug-2015North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max 0.0 Depth Rig: ROP (ft/hr) AK-AM-0902604811 10.5 Mud Type (lb/100ft2) Alkal 13.5" 10.60 Mill Tooth 10.60 Size WOB LSND 4.1 58.30 89' 60.01 =10,000 Units- 0.9023 nut plug sweep to try to control losses. 2961' C-4i 115' 1036 (current) 6061'Minimum Cly Conductor 31 2430 Chromatograph (ppm) 0 (max) Trip (current) -Connection 10% Background 30.0 52 Sh Gas Summary Depth in / out 0.30 37148 Lst Circulating PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP Min 12:00 AM Hours 18.858 Set At 30% Type RPM Cement 2971' 2882' 17 Footage L-80 Grade 28 TuffGvlCoal C-4n Clyst Avg to 114 C-1 C-5n 2961' C-3 PDC Bit 6412'572 C-2 Yesterday's Depth: Current Depth: 24 Hour Progress: 757.0 Flow In (gpm) Flow In (spm)137 Time: 5505' 6973' 1468' Max @ ft Current 6291'105.0 Date: 478 to 12.5ppg. Continued to drill ahead, power outage on rig. Regained power, recalibrate MPD. CBU. Started taking losses, pumped 150 110 bbls lost last 24 hours Average 152741 SPP (psi) Gallons/stroke TFA 9.875 0.994 4 234 0 Siltst 62.5 H-40 60% 45.5 Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Hilary Garney, Macy Williams 15537 77 907-670-4906Unit Phone: 129 Hilary Garney Maximum Report By:Logging Engineers: Lithology (%) Surface 7157 6 1565 Silt (max) 55 Units* 1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 Ss 2971' Cht 10.75'' 23.50 Casing Summary 3023' 52'-177 Size Weight 3023' . . * 24 hr Recap: 23.50 Casing Summary 3023' 52'-177 Size Weight 3023' 1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 Ss 2971' Cht 10.75'' (max) 250 Units* Surface 8959 528 907-670-4906Unit Phone: 294 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney, Macy Williams 36999 6692 Bit Type - in Depth 16.00'' Density (ppg) out (sec/qt) Lithology (%) 118030 SPP (psi) Gallons/stroke TFA 9.875 0.994 60bbls/hr. Spotted LCM pill. CBU, loss rate of 45bbls/hr. Washed and reamed back to bottom and continued drilling. Performed 362 220 bbls lost last 24 hours Average 6973' 7842' 869' Max @ ft Current 7806'44.9 Date: 626 Yesterday's Depth: Current Depth: 24 Hour Progress: 868.0 Flow In (gpm) Flow In (spm)178 Time: 2961' C-3 PDC Bit 7613'1541 C-2 Avg to 283 C-1 C-5n 461 TuffGvlCoal C-4n ClystSiltst 62.5 H-40 30% 2971' 2882' 14 Footage L-80 Grade 29 Hours 20.047 Set At 60% Type RPM Cement Drilling Ahead PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP Min 12:00 AM 176639 30.0 172 Sh Gas Summary Background 299 42 (max) Trip (current) -Connection 161 4400 Chromatograph (ppm) 57 Conductor 10% Lst 45.5 Cly 1407 Silt 115' 2638 (current) 7671'Minimum breathing test per CoMan, 12bbls in 30 mins. Troubleshoot MPD. Continued to drill ahead. 2961' C-4i 1 =10,000 Units1407 0.9023 Mill Tooth 10.50 Size WOB LSND 3.1 58.30 89' 60.0 Depth in / out 41.0 Depth Rig: ROP (ft/hr) AK-AM-0902604811 12.0 Mud Type (lb/100ft2) Alkal North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max Morning Report Report # 12 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk 2-Aug-2015 4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity - Current Pump & Flow Data: 3131 Max Mud (lb/bbl)% 96% 0.30 Depth 7688' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments - 13.5" 10.50 ECD (ppg) ml/30min 1310 Lime Cor Solids - Avg rig 100% Gas In Air 164 4356 Continued to pump sweeps with loss rate of 50bbls/hr. Racked back one stand to establish loss rate at 650GPM, . . * 24 hr Recap: Drilled to TD @ 7878’ MD. Circulated 9 B/U and racked back a stand every B/U to 7050’ MD. Pumped 27 bbl H-Vis Sweep rig 100% Gas In Air 0 00 ECD (ppg) ml/30min 350 Lime Cor Solids - Avg Depth 7878' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments - 13.5" 10.50 Current Pump & Flow Data: 407 Max Mud (lb/bbl)% 96% 0.30 4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity - Morning Report Report # 13 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk 3-Aug-2015North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max - Depth Rig: ROP (ft/hr) AK-AM-0902604811 12.0 Mud Type (lb/100ft2) Alkal Mill Tooth 10.50 Size WOB LSND 4.1 58.30 89' 60.0 Depth in / out 1 =10,000 Units- 0.9023 cellar till flow stopped. Stripped OOH w/ MPD F/7806’ T/6580’. Dilution of the mud at TD by pumping 385 bbls new mud. Monitored well via Trip Tank due to well breathing. Monitored the well on the 2961' C-4i 115' 610 (current) 7800'Minimum 45.5 Cly 898 Silt Conductor Lst 2437 Chromatograph (ppm) 0 (max) Trip (current) 140 ConnectionBackground 0 0 30.0 4854' 50 Sh Gas Summary 5617747 TOOH PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP Min 12:00 AM Hours 12.546 Set At Type RPM Cement 2971' 2882' 13 Footage L-80 Grade 27 7877' TuffGvlCoal C-4n ClystSiltst 62.5 H-40 Avg to 204 C-1 C-5n 290 2961' C-3 PDC Bit 7878'806 C-2 Yesterday's Depth: Current Depth: 24 Hour Progress: 81.8 Flow In (gpm) Flow In (spm)36 Time: 7842' 7878' 36' Max @ ft Current 7842'69.4 Date: 152 @ 7600’ MD. Reamed back into hole to 7878’ MD and pumped a second 27 bbl Hi-VIS Sweep followed by 2 B/U circulated. Performed a 90 22 bbls lost last 24 hours Average 82192 SPP (psi) Gallons/stroke TFA 9.875 0.994 Bit Type 7878' in Depth 16.00'' Density (ppg) out (sec/qt) Lithology (%) Connor Murray, Macy Williams 7935 0 907-670-4906Unit Phone: 217 Connor Murray Maximum Report By:Logging Engineers: Surface 6142 0 (max) 10 Units* 1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 Ss 2971' Cht 10.75'' 23.50 Casing Summary 3023' 52'-177 Size Weight 3023' . . * 24 hr Recap: 23.50 Casing Summary 3023' 52'-177 Size Weight 3023' 1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 Ss 2971' Cht 10.75'' (max) 10 Units* Surface - 0 907-670-4906Unit Phone: - Connor Murray Maximum Report By:Logging Engineers:Connor Murray, Macy Williams 2173 0 Bit Type 7878' in Depth 16.00'' Density (ppg) out (sec/qt) Lithology (%) - SPP (psi) Gallons/stroke TFA 9.875 0.994 out during the peak. Stripped out of hole to the casing shoe while showing losses of 25 bph. CBU at the shoe and pumped a 20 bbl 10.9 29 145 bbls lost last 24 hours Average 7878' 7878' 0' Max @ ft Current -- Date: 0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm)0 Time: 2961' C-3 PDC Bit N/A - C-2 Avg to - C-1 C-5n - TuffGvlCoal C-4n ClystSiltst 62.5 H-40 2971' 2882' 14 Footage L-80 Grade 28 7877' Hours 14.351 Set At Type RPM Cement POOH on Elevators PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP Min 12:00 AM 185114 30.0 4854' 14 Sh Gas Summary Background 0 0 (max) Trip (current) 660 Connection - Chromatograph (ppm) 0 Conductor Lst 45.5 Cly 660 Silt 115' 89 (current) N/AMinimum ppg sweep. The well was breathing and was monitored for flow until static. The rig then began POOH on elevators. 2961' C-4i 1 =10,000 Units- 0.9023 Mill Tooth 10.50 Size WOB LSND 2.9 58.30 89' 60.0 Depth in / out - Depth Rig: ROP (ft/hr) AK-AM-0902604811 12.0 Mud Type (lb/100ft2) Alkal North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max Morning Report Report # 14 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk 4-Aug-2015 4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity - Current Pump & Flow Data: 0 Max Mud (lb/bbl)% 96% 0.30 Depth 7878' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments - 13.5" 10.50 ECD (ppg) ml/30min 74 Lime Cor Solids - Avg rig 100% Gas In Air 0 03 Gas peak of 660 units was observed at just before 1AM while circulating. The Gas Chromatograph temporarily flamed- . . * 24 hr Recap: POOH, L/D BHA, and remove radioactive sources. Changed SDL runs to run 340 while casing equipment was rigged up. rig 100% Gas In Air 8 02 ECD (ppg) ml/30min 16 Lime Cor Solids - Avg Depth 7878' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments - 13.5" 10.50 Current Pump & Flow Data: 0 Max Mud (lb/bbl)% 96% 0.50 4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity - Morning Report Report # 15 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk 5-Aug-2015North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max - Depth Rig: ROP (ft/hr) AK-AM-0902604811 12.0 Mud Type (lb/100ft2) Alkal Mill Tooth 10.50 Size WOB LSND 3.1 58.30 89' 60.0 Depth in / out 1 =10,000 Units- 0.9023 2961' C-4i 115' 9 (current) N/AMinimum 45.5 Cly 10 Silt Conductor Lst 21 Chromatograph (ppm) 0 (max) Trip (current) -ConnectionBackground 6 0 30.0 4854' 5 Sh Gas Summary 2192 RIH w/ Casing PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP Min 12:00 AM Hours 14.552 Set At Type RPM Cement 2971' 2882' 14 Footage L-80 Grade 29 7877' TuffGvlCoal C-4n ClystSiltst 62.5 H-40 Avg to 5 C-1 C-5n 8 2961' C-3 PDC Bit N/A 25 C-2 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm)0 Time: 7878' 7878' 0' Max @ ft Current -- Date: 0 Pressure Tested annular and Casing Rams. Began to RIH with 7 5/8” Casing. 3 0 bbls lost last 24 hours Average 141 SPP (psi) Gallons/stroke TFA 9.875 0.994 Bit Type 7878' in Depth 16.00'' Density (ppg) out (sec/qt) Lithology (%) Connor Murray, Macy Williams 104 31 907-670-4906Unit Phone: 11 Connor Murray Maximum Report By:Logging Engineers: Surface 13 0 (max) 7 Units* 1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 Ss 2971' Cht 10.75'' 23.50 Casing Summary 3023' 52'-177 Size Weight 3023' . . * 24 hr Recap: 23.50 Casing Summary 3023' 52'-177 Size Weight 3023' 1-2-CT-A-X-I-SP-HP2PDC Bit 9.875 0.910 Ss 2971' Cht 10.75'' (max) 245 Units* Surface 487 0 907-670-4906Unit Phone: 18 Connor Murray Maximum Report By:Logging Engineers:Connor Murray, Macy Williams 3776 61 Bit Type 7878' in Depth 16.00'' Density (ppg) out (sec/qt) Lithology (%) 31385 SPP (psi) Gallons/stroke TFA 9.875 0.994 while losing all the way to bottom. Landed Casing and then circulated and conditioned the mud in preparation for the cement job. The 53 345 bbls lost last 24 hours Average 7878' 7878' 0' Max @ ft Current -- Date: 0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm)0 Time: 2961' C-3 PDC Bit N/A 79 C-2 Avg to 19 C-1 C-5n 28 TuffGvlCoal C-4n ClystSiltst 62.5 H-40 2971' 2882' 13 Footage L-80 Grade 27 7877' Hours 14.071 Set At Type RPM Cement Cementing Casing PV Wall/Lundale/Mickey cP MBT (ppb Eq) YP Min 12:00 AM 2172 30.0 4854' 5 Sh Gas Summary Background 11 0 (max) Trip (current) 189 Connection 185 Chromatograph (ppm) 0 Conductor Lst 45.5 Cly 253 Silt 115' 50 (current) N/AMinimum Cement lines were rigged up and the cement lines were pressure tested to 4000 PSI. 2961' C-4i 1 =10,000 Units- 0.9023 Mill Tooth 10.50 Size WOB LSND 3.2 58.30 89' 60.0 Depth in / out - Depth Rig: ROP (ft/hr) AK-AM-0902604811 12.0 Mud Type (lb/100ft2) Alkal North Slope Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: Doyon 141 Report For: 24 hr Max Morning Report Report # 16 Customer: Well: Area: Location: ROP 2S-07 ConocoPhillips Alaska, Inc. Kuparuk 6-Aug-2015 4.23 @ Mud Data - Tools EcoScope, Telescope API FLViscosity - Current Pump & Flow Data: 0 Max Mud (lb/bbl)% 96% 0.40 Depth 7878' Bit # C-5i Condition 1-1-WT-A-E-1/16-NO-TD Comments - 13.5" 10.50 ECD (ppg) ml/30min 25 Lime Cor Solids - Avg rig 100% Gas In Air 13 04 Continued to RIH with 7 5/8" casing and started experiencing losses starting at approximately 4500'MD. Continued to RIH WELL INFORMATION Created On : Sep 05 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2S-07 Job Number :-XX-0902604811 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') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 27.50 0.00 0.00 27.50 0.00 N 0.00 E 0.00 0.00 96.99 0.23 343.08 96.99 0.13 N 0.04 W 0.13 0.33 195.23 0.56 314.04 195.23 0.66 N 0.44 W 0.66 0.38 246.18 0.30 318.25 246.18 0.93 N 0.71 W 0.93 0.51 289.73 0.15 293.72 289.73 1.04 N 0.84 W 1.04 0.40 383.23 0.54 213.01 383.22 0.72 N 1.19 W 0.72 0.57 474.85 1.79 180.92 474.82 1.08 S 1.45 W -1.08 1.49 566.12 2.13 181.18 566.04 4.20 S 1.51 W -4.20 0.37 658.12 3.12 173.58 657.94 8.40 S 1.26 W -8.40 1.14 750.77 5.18 167.99 750.35 14.99 S 0.11 W -14.99 2.26 843.37 5.61 167.15 842.54 23.49 S 1.77 E -23.49 0.47 895.14 6.68 170.69 894.01 28.93 S 2.82 E -28.93 2.19 937.24 7.76 172.40 935.77 34.17 S 3.59 E -34.17 2.62 1031.04 9.81 174.56 1,028.47 48.40 S 5.18 E -48.40 2.21 1124.37 12.71 175.01 1,119.99 66.55 S 6.83 E -66.55 3.11 1218.31 14.49 175.18 1,211.29 88.55 S 8.72 E -88.55 1.90 1264.41 17.25 175.22 1,255.63 101.12 S 9.77 E -101.12 5.99 1312.33 20.57 175.04 1,300.96 116.59 S 11.09 E -116.59 6.93 1361.42 21.66 175.04 1,346.75 134.20 S 12.62 E -134.20 2.22 1404.80 21.07 173.97 1,387.15 149.94 S 14.13 E -149.94 1.63 1497.81 24.67 172.15 1,472.84 185.80 S 18.54 E -185.80 3.94 1590.70 29.25 173.52 1,555.61 227.58 S 23.75 E -227.58 4.98 1683.95 29.48 173.67 1,636.88 273.02 S 28.85 E -273.02 0.26 1776.06 31.24 176.14 1,716.36 319.38 S 32.96 E -319.38 2.34 1869.93 36.30 177.46 1,794.37 371.46 S 35.83 E -371.46 5.45 1918.82 39.03 176.53 1,833.06 401.29 S 37.41 E -401.29 5.70 1962.67 38.36 176.79 1,867.29 428.66 S 39.00 E -428.66 1.57 2055.37 38.74 176.81 1,939.79 486.34 S 42.23 E -486.34 0.41 2150.20 40.20 178.59 2,012.99 546.57 S 44.63 E -546.57 1.95 INSITE V8.3.0 Page 1Job No:-XX-0902604811 Well Name:2S-07 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2243.27 40.17 178.27 2,084.09 606.60 S 46.28 E -606.60 0.22 2336.09 40.12 178.88 2,155.05 666.42 S 47.77 E -666.42 0.43 2428.45 40.23 179.08 2,225.62 725.99 S 48.83 E -725.99 0.18 2521.34 40.12 178.79 2,296.59 785.91 S 49.94 E -785.91 0.23 2616.17 40.54 178.97 2,368.88 847.27 S 51.14 E -847.27 0.46 2709.17 39.25 177.47 2,440.23 906.89 S 52.98 E -906.89 1.73 2801.82 38.04 177.32 2,512.60 964.68 S 55.61 E -964.68 1.31 2894.47 38.06 177.92 2,585.56 1,021.74 S 57.98 E -1021.74 0.40 2976.14 37.32 179.10 2,650.18 1,071.65 S 59.29 E -1071.65 1.27 3005.91 37.30 179.56 2,673.86 1,089.70 S 59.50 E -1089.70 0.94 3099.74 39.00 179.45 2,747.65 1,147.65 S 60.00 E -1147.65 1.81 3194.63 39.41 177.83 2,821.18 1,207.61 S 61.43 E -1207.61 1.16 3290.11 39.24 177.08 2,895.04 1,268.06 S 64.11 E -1268.06 0.53 3384.55 39.45 176.03 2,968.07 1,327.82 S 67.71 E -1327.82 0.74 3478.20 39.15 174.45 3,040.55 1,386.93 S 72.63 E -1386.93 1.12 3573.32 38.63 172.93 3,114.58 1,446.28 S 79.19 E -1446.28 1.14 3667.27 38.82 171.35 3,187.88 1,504.50 S 87.23 E -1504.50 1.07 3762.83 35.73 169.88 3,263.91 1,561.59 S 96.64 E -1561.59 3.36 3857.65 34.29 170.36 3,341.57 1,615.18 S 105.98 E -1615.18 1.55 3952.60 33.41 170.78 3,420.43 1,667.36 S 114.64 E -1667.36 0.96 4046.97 31.83 167.12 3,499.92 1,717.27 S 124.35 E -1717.27 2.68 4141.81 30.32 162.46 3,581.16 1,764.49 S 137.15 E -1764.49 2.99 4236.26 28.34 156.00 3,663.52 1,807.71 S 153.46 E -1807.71 3.95 4330.18 27.21 149.06 3,746.64 1,846.51 S 173.57 E -1846.51 3.65 4424.97 26.54 144.35 3,831.20 1,882.31 S 197.06 E -1882.31 2.35 4519.60 26.62 147.14 3,915.83 1,917.30 S 220.88 E -1917.30 1.32 4614.64 27.00 150.19 4,000.66 1,953.90 S 243.16 E -1953.90 1.50 4708.89 26.67 149.21 4,084.76 1,990.64 S 264.62 E -1990.64 0.59 4802.56 26.75 147.08 4,168.44 2,026.39 S 286.84 E -2026.39 1.03 4895.11 26.79 145.52 4,251.07 2,061.07 S 309.97 E -2061.07 0.76 4991.43 26.57 144.43 4,337.13 2,096.49 S 334.79 E -2096.49 0.56 5086.16 25.63 140.77 4,422.21 2,129.59 S 360.07 E -2129.59 1.97 5181.09 24.29 137.30 4,508.27 2,159.85 S 386.30 E -2159.85 2.09 5276.38 23.24 128.79 4,595.51 2,186.04 S 414.25 E -2186.04 3.76 5370.86 23.57 120.39 4,682.24 2,207.28 S 445.09 E -2207.28 3.55 5464.67 24.37 114.54 4,767.97 2,224.81 S 478.88 E -2224.81 2.67 5559.41 25.62 104.84 4,853.87 2,238.18 S 516.48 E -2238.18 4.52 5654.62 26.69 96.11 4,939.37 2,245.73 S 557.65 E -2245.73 4.19 5749.73 28.00 88.04 5,023.88 2,247.24 S 601.22 E -2247.24 4.13 5844.26 29.19 80.96 5,106.90 2,242.86 S 646.18 E -2242.86 3.80 5939.62 30.42 72.68 5,189.68 2,232.01 S 692.21 E -2232.01 4.50 6034.23 31.84 66.17 5,270.68 2,214.79 S 737.92 E -2214.79 3.86 6128.52 34.04 62.14 5,349.82 2,192.40 S 784.01 E -2192.40 3.29 6221.51 37.28 59.41 5,425.37 2,165.90 S 831.28 E -2165.90 3.88 6319.59 41.18 57.13 5,501.33 2,133.25 S 883.99 E -2133.25 4.24 INSITE V8.3.0 Page 2Job No:-XX-0902604811 Well Name:2S-07 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6411.87 44.36 55.45 5,569.07 2,098.45 S 936.10 E -2098.45 3.66 6506.31 46.45 53.71 5,635.37 2,059.47 S 990.88 E -2059.47 2.57 6600.63 49.11 52.35 5,698.75 2,017.45 S 1,046.67 E -2017.45 3.02 6695.00 51.83 50.23 5,758.81 1,971.92 S 1,103.44 E -1971.92 3.36 6789.58 54.95 50.01 5,815.21 1,923.24 S 1,161.69 E -1923.24 3.30 6884.44 58.25 48.90 5,867.42 1,871.76 S 1,221.85 E -1871.76 3.61 6980.57 61.51 47.36 5,915.66 1,816.26 S 1,283.75 E -1816.26 3.66 7075.25 64.16 46.40 5,958.88 1,758.68 S 1,345.22 E -1758.68 2.94 7167.96 67.24 45.07 5,997.03 1,699.71 S 1,405.71 E -1699.71 3.57 7262.64 68.43 43.09 6,032.75 1,636.72 S 1,466.70 E -1636.72 2.31 7356.98 67.10 40.99 6,068.45 1,571.88 S 1,525.18 E -1571.88 2.50 7451.24 67.96 40.58 6,104.48 1,505.92 S 1,582.07 E -1505.92 1.00 7547.07 68.02 37.84 6,140.40 1,437.09 S 1,638.23 E -1437.09 2.65 7639.92 67.92 37.50 6,175.23 1,368.96 S 1,690.83 E -1368.96 0.36 7734.64 67.98 38.02 6,210.79 1,299.56 S 1,744.59 E -1299.56 0.51 7810.85 67.95 37.80 6,239.38 1,243.82 S 1,788.00 E -1243.82 0.27 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 0.00 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 7,810.85 feet is 2,178.08 feet along 124.82 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:-XX-0902604811 Well Name:2S-07 Survey Report
