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215-057
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-16B KUPARUK RIV UNIT 3O-16B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-16B 50-029-21796-02-00 215-057-0 W SPT 6357 2150570 1589 2900 2900 2900 2900 60 60 60 60 4YRTST P Adam Earl 6/24/2025 MIT-IA 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 3O-16B Inspection Date: Tubing OA Packer Depth 270 1825 1740 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625083603 BBL Pumped:1.4 BBL Returned:1.4 Tuesday, July 22, 2025 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 15,2017 6I P.I.Supervisor l 6 I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-16B FROM: Lou Laubenstein KUPARUK RIV UNIT 30-16B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-16B API Well Number 50-029-21796-02-00 Inspector Name: Lou Laubenstein Permit Number: 215-057-0 Inspection Date: 6/6/2017 Insp Num: mitLOL170607160734 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------- --- Well 30-168 !Type Inj W 'TVD 6357 - Tubing 2780 2780 - 2780 2780 - PTD 2150570 Type Test SPT ,Test psi 1589 - IA 250 1900 ' 1810 1800 - BBL Pumped: 1.9 - BBL Returned: 1.6 • OA 110 130 - 130 • 130 Interval 4YRTST P/F 1 P Notes: A.ANNED SEP05201? Thursday,June 15,2017 Page 1 of 1 21 5057 • • 2613 �� PRINT DISTRIBUTION LIST 2 6 1 3 2 BAKER HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ DATA LOGGED (mandatory) 795 East 94th Avenue ct /ol/201 WELL NAME 30-16BPB1;30-16BPB2 Anchorage, Alaska 99515 :,I.K.BENDPR (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: April 4,2015 TODAYS DATE: 3-Sep-15 andatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: 1trick.ridera(�bakerhughes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #UI-PRIN I S #OF COPIES #OF COPIES#OF COPIES 11 v 1 V 4 L 1 ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 SCANNED AL:G 1 1 2016 2 BP Exploration(Alaska)Inc. I 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep I 1 I Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC I 1 I Attn:Makana Bender Gi � 333 W.7th Ave,Suite 100 CVG Anchorage,Alaska 99501 C I 5 DNR-Division of Oil&Gas *** I I arc 06c/CO 211 'rico rin Attn:Sean Clifton /� rn 550 West 7th Avenue,Suite 802 8 Anchorage,Alaska 99501 l**Stamp"confidential"on all material deliver to DNR r" I I 0 Cil TOTALS FOR THIS PAGE: 0 0 4 0 0 0 TOTALS FOR ALL PAGES: 0 0 4 0 0 0 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,August 26,2015 P.I.Supervisor KT 913/Ice SUBJECT: Mechanical Integrity Tests JJ CONOCOPHILLIPS ALASKA INC 30-16B FROM: Johnnie Hill KUPARUK RIV UNIT 3O-16B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 10-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-16B API Well Number 50-029-21796-02-00 Inspector Name: Johnnie Hill Permit Number: 215-057-0 Inspection Date: 8/5/2015 Insp Num: mitJWH150809135324 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-16B -Type Inj W 'TVD6367 ;Tubing 2700 ' i 2700 ! 2700 2700 - PTD, 2150570 ' `Type Test!SPT Test psi; 1589 IA , 1100 2040 - 1980 • 1970 - INITAL P ✓ OA 20 _ 20 20 + i. Interval ,P/F 20• Notes: Post work over and conversion from a producer to injector per sundry#315-439 Wednesday,August 26,2015 Page 1 of 1 STATE OF ALASKA • AL, _-,(A OIL AND GAS CONSERVATION COIF. .5SION • REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations rFracture Stimulate Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool r- Repair Well r Re-enter Susp Well r Other:PROD to WAG (� 2.Operator Name. 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 215-057-0 _ 3.Address: 6.API Number Stratigraphic r Service r P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21796-02 7. Property Designation(Lease Number) 8 Well Name and Number. ADL 025513,ADL 025520 KRU 30-16B 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 10328 feet Plugs(measured) None true vertical 6415 feet Junk(measured) None Effective Depth measured 10141 feet Packer(measured) 7688 true vertical 6463 feet (true vertical) 6358 Casing Length Size MD TVD Burst Collapse Conductor 79 16 115 115 Surface 2340 9.625 2375 2215 Tieback 1028 7 1061 1061 Casing Patch 110 6.089 1121 1121 Liner 260 4 7947 6531 rt 115t. In 31 ?015 Perforation depth: Measured depth' 8905-10325 True Vertical Depth' 6466-6415 ,-\O G C Tubing(size,grade, MD,and TVD) 4.5x5, L80, 7695 MD,6364 TVD c W Packers&SSSV(type,MD,and TVD) Baker 2RH ZXP Liner Top Packer 7688 MD 6358 TVD SSSV=Nipple 7636 MD,6316 TVD 12 Stimulation or cement squeeze summary: Intervals treated(measured) Treatment descriptions including volumes used and final pressure' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 128 39 358 120 90 Subsequent to operation 825 850 1030 14.Attachments(required per 20 MC 25.070,25 071,&25 283) 15.Well Class after work Daily Report of Well Operations R Exploratory r Development r Service P Stratigraphic r Copies of Logs and Surveys Run r 16 Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG f 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 1 315-439 _ Contact Darrell Humphrey/Bob Christensen Email n1139(Q�conocophillips.com Printed Name Robert D. Christensen Title NSK Production Engineering Specialist Signature Phone:659-7535 Date 74/32Z,o)S VTC- q/ -/ /5- Form 5Form 10-404 Revised 5/2015071,c- Submit riginal Only ApRnMcAIIG - 2 71115 30-16B DESCRIPTION OF WORK COMPLETED SUMMARY 07/14/15 (AC EVAL) : MIT-IA(PASSED) TO 2500 PSI. Initial T/I/O= SI 700NAC/VAC. IA FL @ 36' (600 fps, decimeter), 0.6 bbls fill up volume. Pressured IA to 2500 psi w/3.1 bbls diesel. Starting T/I/O = 725/2500NAC. 15 min T/I/O = 725/2410NAC. (-90). 30 min T/I/O = 725/2400NAC. (-10). (PASSED). Bled IA to 100 psi (fluid) in 10 min. Final T/I/O = SI 700/100NAC. 07/27/15 Open well to WAG injection service • KUP PROD 30-16B ConocoPhillips i° Well Attributes Max Angle&MD TD Alaska,InC. Wellbore API/UWI Field Name Wellbore Status Incl 71 MD(ftKB) Act Btm(ftKB) ocoocoPt4nps 500292179602 KUPARUK RIVER UNIT PROD 97.67 8,285.47 10,328.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-16B,5/19/2015 3'.17:24 PM SSSV:NONE 34.981 4/23/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;33.0 I'., Last Tag: Rev Reason:ADD SIDETRACK B,ADD smsmith II. LATERALS L1&L2 ' "' Casing Strings t t Casing CONDUCTOR Descfiplion OD(in) ID(in) Top(1060) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread SURFACE 95/8 8.921 35.0_ 2,374.9 2,214.8 36.00 J-55 BTC f Casing Description OD(In) ID(In) Top(ORB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread TIEBACK 7 6.276 33.0 1,060.7 1,060.6 26.00 L-80 TC-II CONDUCTOR.36.0-115.o-. a Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'WULen(I...Grade 'Top Thread CASING PATCH 6.089 5.488 1,011.4 1,121.0 1,120.7 FODC-OR Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(BOB) Set Depth(TVD)...Vet/Len(I...Grade 'Top Thread LINER 41/2 4.000 7,687.5 7,947.3 6,531.1 11.60 L-80 BTC Liner Details Nominal ID 1 ' Top(BOB) Top(TVD)(BOB) Top Ind(") Item Des Com (in) 7,687.5 6,357.9 35.88 PACKER BAKER"2RH"ZXP LINER TOP PACKER 4.330 TIEBACK;33.0-,,060.7 7,707.2 6,373.8 35.81 HANGER BAKER FLEX-LOCK HANGER 4.250 CASING PATCH;1,011.4- Casing Description 100(in) IID(in) Top(BOB) 'Set Depth(MKB) I Set Depth(TVD)...I Wt/Len(l...1Grade I Top Thread B LINER-SOLID 31/2 2.992 7,726.6 8,9000 6,466.1 9.201L-80 Hyd511 1,121.0 ler Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,726.6 6,389.6 35.77 DEPLOY BAKER DEPLOYMENT SLEEVE 3.000 SURFACE;35.0-2,374.9 - 7,734.1 6,395.7 35.75 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.9921 • NIPPLE;7,635.8 7,766.4 6,421.9 35.69 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 I 7,798.6 6,447.6 39.75 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 XO Enlarging(Turing);7,6833 Casing Description OD(in) ID(in) -Top(ftKB Set Depth(ftKB) Set Depth(TVD)...Wt/Len ...Grade TopThread LOCATOR;7,6845 t� B LINER-SLOTTED I 23/81 1.992 8,870.81 10.327.01 6.414.61 I 4.601 L-80 I Hyd511 SEAL ASSY;7,685.6 - Liner Details Nominal ID `�=v Top(BOB) Top(TVD)(BOB) Top Incl(°) Item Des Com (in) 2a 8,870.81 6,467.51 93.311 BILLET BAKER ALUMINUM LINER TOP BILLET 1.000 '1y`'. Tubing Strings ' Tubing Description String Ma...ID Top(960 ISO Depth ft..Set Depth TVD Wt(lb/ft) Grade To Connection i..:11. �` 9 1 ion g I (in) I 1 I P ( P (TVD)(.3 ( 1 I 'Top Y TUBING-2014 WO- 4112 4.000 330 7,6954 6,364.3 12.60 L-80 IBTM y: 4v, d! 41/2n5@7683.66 tem j Completion Details \f: .` Nominal ID ,0 ;1 Top(ftKB) Top(WD)(ftKB) Top Incl(") Item Des Com (in) 33.0 33.0 0.00 HANGER CAMERON TUBING HANGER 3.833 \•: I `�, ?,C�. 7,635.8 6,316.1 36.11 NIPPLE DB NIPPLE,SR#T031038 3.813 1 • WHIPSTOCK 7,775.0 w. j 7,684.5 6,355.4 35.89 LOCATOR BULLET SEAL LOCATOR 3.930 WINDOW;7,775.0-7,788.0 ,`i, To ;i 7.685.61 6.356.4 35.88 SEAL ASSY BULLET SEAL ASSEMBLY 4.250 y Y Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) :1'i s,_ ( P u9 �' ✓ Top(TVD) Top Incl ;1 Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) IPERF;7,794.0-7,804.0--4 :Z- 7,775.0 6,428.9 35.67 WHIPSTOCK 3.625"Baker MonoBore XL Whipstock,set 0°HS, 3/18/2015 WHIPSTOCK 7,796.0 ._ 15.73-ft OAL,2ea.RA PIP tags 12-ft down from top gof whipstock. 'AI.%, ,0, Perforations&Slots Shot ;� Dens _';% Top(WD) Ban(WD) (shots/f PLUG;7,829.0 - '_;i, Top(BOB) atm(MKB) (BOB) (BOB) Zone Dale t) Typo Com 8,905.0 10,325.0 6,465.9 6,414.5 A-3,30-16B 4/13/2015 SLOTS Slotted Liner IPERF;7,838.0-7,848.0- "U APERF;7,838.0-7,859.0-- ;:, • Notes:General&Safety ,,,•,, .W End Dale Annotation NZ. . 12/11/2014 NOTE:WORKOVER IPERF;7,850.0-7,860.0, �� .v WINDOW;W 852 HIPSTOCK: ;;sr - 3/12/2015 NOTE:WELL SIDETRACKED TO B,ADD LATERALS L1&L2 WHIPSTOCK:7,852.0 � APERF;7,867.0-7,872.0 IPERF;7,869.0-7,889.0, _gv; ,err, WHIPSTOCK 7,875.0 k - : : -IS' :P ;u. ;'4 WHIPSTOCK 7,900.0 _ ti - o APERF;7,908.0-7,9280 - , y _ ; LINER;7,887.5-7,947.3 ;�' : SLOTS;7,826.4-8,303.4- -I I� �I+_ B LINER-SOLID;7,726.6- 8,900.0 SLOTS;8,305.2-10,139.0.1 ;.. SLOTS;8,905.0-10,325.0 BL2 LINER-SLOTTED;7,825.6` IP -10,141.0 . 8 1 B LINER-SLOTTED;10,3 227.0.0 10,3 • OF TAr, evwN\ I//j%sem THE STATE Alaska Oil and Gas (7.7 ofA LAsKAL Conservation Commission ;� _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS— Fax: 907.276.7542 � , 65 www.aogcc.alaska.gov u Darrell Humphrey NSK Production Engineering Specialist a, 15- 0 s-7 7 ConocoPhillips Alaska, In P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-16B Sundry Number: 315-439 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Oz#.2.7Cathy PFoerster Chair DATED this 24 of July, 2015 Encl. • STATE OF ALASKA • • SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved R-ogram r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well rOther:PROD to WAG I✓ ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc., Exploratory r Development r• 215-057-0 - 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21796-02 A 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1i I KRU 30-16B • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 025513,ADL 025520 ` Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10328 . 6415• 10141'• 6463'. None None Casing Length Size MD TVD Burst Collapse Conductor 79 16 115' 115' Surface 2340 9.625 2375' 2215' Tieback 1028 7 1061' 1061' RECEIVED �Q D Casing Patch 110 6.089 1121' 1121' ,MI I 2,1 21115 Liner 260 4 7947' 6531' /3' -'371 Z. 1/ •AO G C Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8905-10325 ' 6466-6415 4.5x5 L80 7695 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Baker 2RH ZXP Liner Top Packer . 7688 MD 6358 TVD SSSV=None None 12.Attachments: Description Summary of Proposal �' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service ' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/21/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey/Bob Christensen Email: n1139 anconocophillips.com Printed Name Darrell Hump rev Title: NSK Production Engineering Specialist Signature 31)•yr.‘„A \/.../tl,., Phone:659-7535 Date -7. 17 I. t5 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31 -4117e1 Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: ft v Sfa bl it CI i ce. I C.C`7cti, fwfr wi fV1 r 55td iwf -T- i� r��vy`�rd a f �` Spacing Exception Required? Yes ❑ No 2( Subsequent Form Required: /0 — 40 4-- APPROVED -APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7 `24"LS vn, W/ z/)5- Approved applicati n is va d or 12 months from tf� date of approval. Submit Form and Form 10-403 Revised 5/2015 OI G tL4 / fq, ?/Z i Atta a is in Duplicate R ��zr//�- RBDMS3 AUG 2 2015 • • RECEIVEDDarrell Humphrey/Robert Christensen Production Engineering Specialists. J U L 2 1 2 01 5 Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhConocoPhillips AOGCC Phone:r(90,AK 7 6 9-7535 6105 Fax:659-7314 July 17, 2015 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 30- 16B, 30-16BL1, 30-16BL2 from Oil Production to WAG Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 30-16B and it's associated laterals (PTD# 215-057, 215-030, 215- 031). If you have any questions regarding this matter,please contact myself or Robert Christensen at 659-7535. Sincerely, "'`'"414\ 1)4L---RA0-7 Darrell Humphrey Attachments Sundry applications Well schematics ire d �`S G�+ / h J e ct�r n 0 CO b y ,e1i a vi en, llecef,�i. fermi • . • 30-16B DESCRIPTION SUMMARY OF PROPOSAL ConcoPhillips Alaska Inc. requests approval to convert Kuparuk well 30-16B (PTD#215-057-0)from a Pre- produced >30 days Oil producer back to WAG Injection service.. The conversion to injection service is required to provide reservoir pressure support to offset producers 3N-17 and 30-11. The 9-5/8" Surface casing (2375'md/2215'tvd)was cemented with 900 sx AS III Lite followed by 300 sx ASII and 100 sx AS I. The 7" Production casing (8201'md/6678' tvd)was cemented with 700 sx TLW and 300 sx Class G and 175 sx AS I. The top of the Kuparuk C sand was found at 7775' and/6429'tvd. The top of the Kuparuk A sand was found at 7963' and/6418' tvd. The CBL, dated 12/18/14, identified a cement top of approximately 1060' RKB. The CBL was run to a depth of approximately 7420' RKB and indicated good cement for the entire interval from 1200' to 7420' RKB. 7/14/15: MIT-IA to 2500 psi - Passed KUP PROD • 30-16B ConocoPhillipso Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) ,, ylpp. 500292179602 KUPARUK RIVER UNIT PROD 97.67 8,285.47 10,328.0 ... w6 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-160,5/192015 3 1724 PM SSSV:NONE 34.98 4/230988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,33.0 p`0./:II Last Tag: Rev Reason:ADD SIDETRACK B,ADD smsmith LATERALS L1 8 L2 asing rings it Casing Description 013(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(1...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SURFACE 9 5/8 8.921' 35.0 2,374.9 2,214.8 36.00 J-55 BTC `Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread TIEBACK 7 6.276 33.0 1,060.7 1,060.6 26.00 L-80 TC-II CONDUCTOR;38.0-1150 A Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CASING PATCH 6.089 5.488 1,011.4 1,121.0 1,120.7 FODC-OR Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...-Wt./Len(I...Grade Top Thread LINER 41/2 4.000 7,687.5 7,947.3 6,531.1 11.60 L-80 BTC Liner Details Nominal ID ( ) Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,687.5 6,357.9 35.88 PACKER BAKER"2RH"ZXP LINER TOP PACKER 4.330 TIEBACK 33.0-1,060.7 7,7072 6,373.8 35.81 HANGER BAKER FLEX-LOCK HANGER 4.250 I :ir Casing Description [00(in) I ID(in) Top(ftKB) I Set Depth(ftKB) I Set Depth(TVD)...I WULen(1...1Grade I Top Thread BLINER-SOLID I 31/2 2.992 7,7266 8,900.0 6,4661 9.20 L-80 Hyd511 CASING PATCH;1,011.4- 1,121.0 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,726.6 6,389.6 35.77 DEPLOY BAKER DEPLOYMENT SLEEVE 3.000 SURFACE;35.0-2,374.9 I ,! 7,734.1 6,395.7 35.75 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 NIPPLE;7,635.8 7,766.4 6,421.9 35.69 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 - 7,798.6 6,447.6 39.75 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 XO Enlarging(Turing);7,883 7 5 CasingDescription OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade TopThread LOCATOR 7,684.5 p ) ) p ( ) BLINER-SLOTTED 23/8 1.992 8,870.8 10,327.0 6,414.6 4.60 L-80 Hyd511 SEAL ASSY,7,685.6 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) :1Mg 8,870.8 6,467.5 93.31 BILLET BAKER ALUMINUM LINER TOP BILLET 1.000 0 Tubing Strings JTubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection �. TUBING-2014 WO- 41/2 4.000 33.0 7,695.4 6,364.3 12.60 L-80 IBTM w,@ 41/2x5@7683.66 Completion Details ,i Nominal ID fl Iil Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 9rir !j 33.0 33.0° 0.00 HANGER CAMERON TUBING HANGER 3.833 kV1r‘.1 7,635.8 6,316.1 36.11 NIPPLE DB NIPPLE,SR#T031038 3.813 WHIPSTOCK 7,775.0 g y l�` 7,684.5 6,355.4' 35.89 LOCATOR BULLET SEAL LOCATOR 3.930 WINDOW;7,775.0-7,788.0 •s" ;y .� 7,685.6 6,3564 35.88 SEAL ASSY BULLET SEAL ASSEMBLY 4.250 -w; i,`�',;.- Other In Hole(Wireline retrievable plugs,valves,pumps,fish,`etc.) -\y' Top(TVD) Top Incl �f Top(565) (ftKB) (°) Des Com Run Date ID(in) !PEW 7,794.0-7,804.0-- 1 7.775.0 6,428.9 35.67 WHIPSTOCK 3.625"Baker MOnoBere XL Whipstock,set 0°HS, 3/18/2015 WHIPSTOCK;7,796.0 15.73-ft OAL,2ea.RA PIP tags 12-ft down from top -ii0'- of whipstock, Perforations&Slots Shot Dens N Top(TVD) Bin(TVD) (sholsil PLUG 7,0290 _ Top(ftKB) _ Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 8,905.0 10,325.0 6,465.9 6,414.5 A-3,30-16B 403/2015 SLOTS Slotted Liner IPERF;7',083388:O-77,045970 038 0-7,848.0- APERF;7838.0-7,0so.0� Notes:General&Safety 5,, End Date Annotation 12/11/2014 NOTE:WORKOVER IPERF;7,850.0-7,880.0 w1NDOW;7,652.0-7,657.013/12/2015 NOTE:WELL SIDETRACKED TO B,ADD LATERALS L1 8 L2 WHIPSTOCK;7,852.0 ---- '. APERF;7,067.0-7,672.0- IPERF;7,869.0-7,889.0 _� .re,_ _ WHIPSTOCK 7,875.0 r! WHIPSTOCK;7,900.0 APERF;7,908.0-7,9280 LINER;7,007.5-7,947.3 - SLOTS;7,826.4-8,303.4- 1 I T1_ 1 1 B LINER-SOLID;7,726.6- 8,900.0 SLOTS;8,305.2-10,139.0 SLOTS;8,005.0-10,325.0 BL2 LINER-SLOTTED;7,825.6\\\ -10,141.0 B LINER-SLOTTED;0,070.8- 10 327.0 o I o • o N • n N 9 • 71 ri .- >- \ ..5 x 0 ix z X 0 ft z - a) a) l 65 co m> >U Z E�,o) ) col dN N N N N CO W CO CO pLo .9 D N O CO 9 0 0 0 0 0 0 0 0 0 0 0 O . In 0 T co o O O O O O O O O O N • 0_ z O a) J 'D O a) N to d In 6 6 In In In In 0 = a �. 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E CLO U .... 2 0 0 ii �n o 0 Cl) • 0 0 n V U w c w o CO } 0 E a) Q E 0 o e4 a 0 m U c000 8 Z N z 12 c r m > N .m. o a) E a' v 5 0 1- E Z' 3 /M M a)It0 c - U) .d V / Uco a 0 y` 0 c g ICC D Y c 0 LPiia) c n 0 c Q n m O Z E y U TIl m U c 0 2 0 1 H C co co Z U) (0 CO N CO N Lo m LO 0 O O O co aa) c Q N To c-o g m as co m rn rn • ii ?ID 1 0 a) r N N N N N V p O H 3 N U)Q c N N 11 .- 0. d n 2 di H a) E E Z y Y w co 1 CL c6 c o CV o m Z < o o 2 Z C CO C RI c c V ., 0 U U U 0 C J a) y Q d ca 0 0 a o o a a co u E n UO LE 0 0 0 0 0 o a) O o ° a°) 0 o ami m E o a .e w w w w _ 3 Z 0 a 0 0 0 ce 0 0 > 215-057 30-16B 26173 215-057 30-16BPB1 26174 215-057 30-16BPB2 26175 PRINT DISTRIBUTION LIST 215-0310 30-16BL1 26127 BAKER 30-16BL2 26128 HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ (mandatory) 795 East 94th Avenue DATA LOGGED 9/ 1, ,tot 5 WELL NAME 30-16B; 16BL1; 16BL2; 16BPB1; 16BPB2 Anchorage,Alaska 99515 M K.BENDER (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: April 4,2015 TODAYS DATE: 21-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: atrick.rider(abakerhughes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-I*(IN I S #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. 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No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-1-1-(IN I S #OF COPIES #OF COPIES#OF COPIES 1 ,ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BPExploration(Alaska)Inc. 114 I E I E Wr' Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 AUG 2 6 ZU I i Attn:Dodie Stinson 3 Chevron/KRU Rep 1 1 `I 1 Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4jState of Alaska -AOGCC I 1 I 1 2 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 'Anchorage,Alaska 99501 • 5IDNR-Division of Oil&Gas *** I 1 I I I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 Lin r e- 04 - CO ,rte1111 N y W II Z eg 113,_ YI; gl N 1 It Cr., .404 Cr i C t RS O CU 0 a) W W til Z 2 hi C 0 Y Y a N a) C 4-9N O c 2 P. m .— = V t0 N 1*- ` O aa ' o Co 0 a V Y Y ch CO CI N • W M o o a Mime of v o L+ m Y0 as N _ N OVco m 2 co O coO N Zc N LO 01 fA co C) CO LL Q. 0 0 c o 0 r C0 0 _ U) N CO CI 0 0 a N Z N N Co •2 u) v N N M > N N hi O J 7 V C y OI COm J O J 0 co _ a` o Q Q O. 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CL o 3 > CO m (O (O CO co V N (h co co m co V V O l6 N CO 0 O CO CO CO N CO CO CQ O_ 0 0 0 C •-• U) UI h.: r CO CO N r N N o o0 Y Y 0 0 0 c •e.... m m m m m m m m m m 'o 6) u N 0 0 0 M M m m C O ( 0 � 0 LO U) U) U) OD O Cn UV N C C cii CO ( m m (ClC ` c U) O d 4-; 0 m i ` CCOCOD DOD O V o E z m m m 2 CVn. ✓ a co 3 3 0 co N LIJ-UD/ JU-I 201/.3 215-057 30-16BPB1 26174 >215-057 30-16BPB2 26175 .71. 215-030 30-16BL1 26127 BAKER PRINT DISTRIBUTION LIST 215-03130-16BL2 26128 HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ DATA LOGGED (mandatory) 795 East 94th Avenue DATA` /2015 WELL NAME 30-16B; 16BL1; 16BL2; 16BPB1; 16BPB2 Anchorage,Alaska 99515 M. K.BENDER (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: April 4,2015 TODAYS DATE: 21-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: 1trick.rider(@.bakerhughes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF NKIN I S #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 E I EI Petrotechnical Data Center,LR2-1 be 900 E.Benson Blvd. Anchorage,Alaska 99508 AUG 2 6 Z Attn:Dodie Stinson i 3 Chevron/KRU Rep 1 1 AP q( I Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 41 State of Alaska -AOGCC I 1 1 I 2 I 1 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 I 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 Ln Ln O in to N 1111 °I iii AO i :W; m U M C 0 Cr C t CU O cn 0. co 0 0 w W Q H v) z a) P"' u O.O ; a to _ .— O O m C7 i 4-• o C 0 . a. 0 C N 0 cli O a. a. � q (a G0 a o Y Y O 2 CO 13 N § © iii tn tnm a ° s 0 §■ c _ �a 0 & \ \ ! 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Y gf, CO N N .-Cr; O V co co co ‘;1- 6 U co- -....7CO co- co- co- C c6 Y N Q N Z.«. COO r NCID O 0 OD N = ) Q r CD 6) 0 5 5 N Q N Q N N N L ce co m m /� d Y 8 d d 0 3 2 m m o m m ' ' ' r) ' o 2 2c 1:1 Q o S U Y Y 0 0 0 c co 0) rn rn 6 co co co ' a 11 *o co oCOO 0 0 co 0 ai Oa u o t >, 2 v of of m of of U C O m m d m 7 N U d N s 3 G 4) N v STATE OF ALASKA , AL,-,..)KA OIL AND GAS CONSERVATION COM....SSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate Alter Casing r r" Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:WAG to PROD 2.Operator Name. 4.Well Class Before Work: 5. Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory r 215-057-0 3.Address: 6.API Number. Stratigraphic r Service ri P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21796-02 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025513;ADL025520 KRU 30-16B 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 10328 feet Plugs(measured) None true vertical 6415 feet Junk(measured) None Effective Depth measured 10141 feet Packer(measured) true vertical 6463 feet (true vertical) Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 2340 9 625 2375 2215 TIEBACK 1028 7 1061 1061 CASING PATCH 110 6.089 1121 1121 RE 99i.. � LINER 260 4 7947 6531 lam'�" .JUN 0 8 2015 Perforation depth: Measured depth: 8905'- 10325' 4/��^-► True Vertical Depth: 6466'-6415' AOGCC Tubing(size,grade,MD,and TVD) 4-1/2 x 5, L-80, 7695 MD, TVD Packers&SSSV(type,MD,and TVD) Packer=BAKER"2RH"ZXP LINER TOP PACKER Packer @ 7688' md, 6358'TVD SSSV=None 12.Stimulation or cement squeeze summary. Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 682 481 2463 900 169 14.Attachments(required per 20 AAC 25 070,25.071,&25 283) 15.Well Class after work. Daily Report of Well Operations ri Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16 Well Status after work: Oil r Gas r WDSPL r Printed and Electronic 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 0 Exempt N/A Contact Darrell Humphrey/Bob Christensen Email n1139(a)conocophillips.com Printed Name Robert D. Christensen Title NSK Production Engineering Specialist Signature sto Phone:659-7535 Date biL Vi b , v`n 6/15/15 4l/Yl� RBDmsick JUN 1 1 2015 Form 10-404 Revised 5/2015 Submit Original Only 30-16B DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/03/15 Commence Injector pre-production > 30 days KUP PROD 30-16B • ConocoPhillips r Well Attributes Max Angie&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(f15/3) -Act Btm(0KB) cpm davt9pc 500292179602 KUPARUK RIVER UNIT PROD 97.67 8,285.47 10,328.0 -•- Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-168,5/19/2015 3'.1724 PM SSSV:NONE 34.98 4/23/1988 Vertical schematic(actual) Annotation Depth(ftK8) End Date Annotation Last Mod By End Date HANGER;33.0 - 1 tL - --Last Tag: Rev Reason:ADD SIDETRACK B,ADD smsmith �. LATERALS L1 8 L2 CasinCasingg DescriptionStrings OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread _ CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 2,374.9 2,214.8 36.00 J-55 BTC `'''Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread TIEBACK 7 6.276 33.0 1,060.7 1,060.6 26.00 L-80 TC-II CONDUCTOR;36.0-115.0 .• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CASING PATCH 6.089 5.488 1,011.4 1,121.0 1,120.7 FODC-OR Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 4.000 7,687.5 7,947.3 6.531.1 11.60 L-80 BTC Liner Details Nominal ID 4 ; Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Corn (in) 7,687.5 6,357.9 35.88 PACKER BAKER"2RH"ZXP LINER TOP PACKER 4.330 TIEBACK;33.0-1,060.7 7,707.2 6,373.8 35.81 HANGER BAKER FLEX-LOCK HANGER 4.250 • • Casing Description 100(in) I ID(in) Top(ftKB) I Set Depth(ftKB) I Set Depth(TVD)...(Wt/Len(I...I Grade I Top Thread B LINER-SOLID 31/2 2.992 7,7266 8,9000 6,4661 9.20 L-80 Hyd511 CASING PATCH;1,011.4- 1,121.0 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,726.6 1 6,389.6 35.77 DEPLOY BAKER DEPLOYMENT SLEEVE 3.000 SURFACE;35.0-2,3749 7,734,1' 6,395.7 35.75 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 NIPPLE;7,635.8 . 7,766.4 6,421.9 35.69 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 7,798.6' 6,4476 39.75 CENTRALIZER UNIQUE CEMENTRALIZER 3.75"OD BLADES 2.992 00 Enlarging(Tubing);7,683.7 1 " LOCATOR;7,684.5 Casing Description 100(in) IID(in) Top(ftKB) (Set Depth(ftKB) I Set Depth(TVD)...I Wt/Len(I...I Grade I Top Thread B LINER-SLOTTED 23/6 1.992 8,8708 10,3270 6,4146 4.60 L-80 1I Hyd511 SEAL ASSY;7,685.6 -w.. Liner Details noon N ore na l ID "i111'Of Top(ftKB) I Top(TOD)(ftKB) Top Incl(°) Item Des Corn (in) �. 8,870.8 6,467.5 93.31 BILLET BAKER ALUMINUM LINER TOP BILLET 1.000 kJ i*VK. Tubing Strings ..,Z1 Tubing Description (String Ma...ID(in) (Top(ftKB) (Set Depth(ft..f Set Depth(TVD)(...I Wt(IbHt) (Grade Top Connection �� j, TUBING-2014 WO- 41)2 4.000 33 0 7,6954 6,364 3fll 12.60 L-80 (BTM At �n �, .I 4112x5@7683.66 v=✓ yCompletion Details , 0 Nominal ID �' :% Top(ftKB) Top(TVD)(MB) Top Ind(") Item Des Com (in) ��) ✓' 33.0 33.0 0.00'HANGER CAMERON TUBING HANGER 3.833 p7 ik 7,635.8 6,316.1 36.11-NIPPLE DB NIPPLE,SR#T031038 3.813 WHIPSTOCK 7,775.0 i ✓ 7,684,5 6,355.4 35.89'LOCATOR BULLET SEAL LOCATOR 3.930 WINDOW;7,775.0-7,788.0 �1;: ,y .� 7,685.6 6,356.4 35.88 SEAL ASSY BULLET SEAL ASSEMBLY 4,250 -vl 1� Other In Hole(Wireline retrievable plugs,valves,pumps,fish, X P 9 P P etc.) PVi Top(TVD) Top Incl V A Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) IPERF;7,794.0-7,804.0- 7,775.0 6,428.9 35.67 WHIPSTOCK 3.625"Baker MonoBore XL Whipstock,set 0°HS, 3/18/2015 WHIPSTOCK;7,796.0 'if 44 15.73-ft OAL,2ea.RA PIP tags 12-ft down from top of whipstock, Perforations&Slots :v: .✓ Shot Dens '2 V Top(TVD) Btm(TVD) (shotslf PLUG;7,829.0 ;i. Top(ftKB) Britt(ftKB) (558) (ftKB) Zone Date t) Type Corn 8,905.0 10,325.0 6.465.9 6,414.5 A-3,30-168 4/13/2015 SLOTS Slotted Liner IPERF;7,838.0-7,848.0- ." APERF;7,839.07,859.0- ,�. Notes:General&Safety End Date - Annotation 12/11/2014 NOTE:WORKOVER IPERF;7, A , . WINDow;7.852BSO,D-7-7,860657.00 3/12/2015 NOTE:WELL SIDETRACKED TO B,ADD LATERALS L1&L2 WHIPSTOCK;7,852.0 - N4t ,1 APERF;7,867.0-7,872n a J R -.vi IPERF;7,889.0-7,8890_ ',. A WHIPSTOCK'7,8750 „`; WHIPSTOCK;7,900.0 fig. APERF;7,908.0-7,928.0-_',3. 11 A gd \J A LINER;7,887.5-7,947.3 tioClW SLOTS;7,828.4-8,303.4 B LINER-SOLID;7,726.6ik- - 8.900.0 SLOTS;8,305.2-10,139.0 SLOTS;8,905.0-10,325.0 BL2 LINER-SLOTTED;7,825.8 -10.141.0 FB LINER-SLOTTED; 10,327 8- 10,327.0 RECEIVED STATE OF ALASKA MAY 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND Lo CC 1a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended[1] 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ -1 WINJ ❑ WAGE - WDSPL❑ No.of Completions: Service ❑ __ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: '4/20/2015 215-057. 3.Address: 7. Date� Spudded: MG 15.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 3iu9/2015 50-029-21796-02 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1106'FNL,2060'FWL,Sec. 22,T13N, R9E, UM . .4/12/2015 ;,,,.,_ 30-16B - Top of Productive Interval: 9. KB(ft above MSL): -59' 17. Field/Pool(s): 315'FSL,2245'FEL, Sec. 21,T13N, R9E, UM GL(ft above MSL): .23' Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 179'FSL,2323'FEL, Sec. 21,T13N, R9E, UM 10328'MD/6415'TVD ADL 25513,25520 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit. Surface: x- 525698 y- 6021714 Zone-4 - 10328'MD/6415'TVD 2554,2556 TPI: x- 521414 y- 6017841 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 521337 y- 6017705 Zone-4 none 1636'MD/1612'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) .7775'MD/6429'TVD 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 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" 62.5# H-40 36' 115' 36' 115' 24" 175 sx AS I 9.625" 36# J-55 35' 2375' 35' 2215' 12.25" 900 sx AS III, 300 sx AS II 7" 26# J-55 1062' 8201' 1062' 6778' 8.5" 700 sx TLW,300 sx Class G&175 sx AS I 4.5" 4.6# L-80 7687' 7947' 6357' 6531' 6" 15#bbls of 15.8'G'Neat 3.5" 9.3# L-80 7726' 8900' 6329' 6406' 4.25" 10 bbls 15.8 ppg 2.375" 4.7# L-80 8867' 10328' 6408' 6355' 3" 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): 4.5" 7695' 7688'MD/6357'TVD slots from 8903'-10327'MD 6466'-6415'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No ❑ Per 20 AAC 25.283(i)(2)attach electronic and printed information a} DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 5/16/2015 pre-produced injector Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 5/6/2015 15 hours Test Period 410 283 1504 176 658 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 164 not available 24-Hour Rate 762 502 2286 not available 28.CORE DATA Conventional Core,, Yes ❑ No ❑✓ Sidewall Cores: ❑ No Q If Yes, list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered). 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1636' 1612' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25 071. Kuparuk C4 7775' 6429' Top Kuparuk Al 7963' 6535' Kuparuk A2 10171' 6418' NA 30-16BPB1 total depth 8922' 6490' 30-16BPB2 total depth 9191' 6417' Formation at total depth: Kuparuk A2 31. List of Attachments: Summary of daily operations,schematic,final 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' Jason Burke @ 265-6097 Email. Jason Burke a(�conocophillips corn Printed Name. Dan Venhaus Title: CTD Supervising Engineer Signature' V----7;4s i:� _ Phone: 2e 3-2/3FZ Date: s'—%g — /5 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b. TPI(Top of Producing Interval) Item 9: The Kelly Bushing 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 r ii YY C C N N (�j OD N Q_M O Q m O SOD cn� C 1 _D m Lo �F0 �o -m LflN W J O © u-) 60 m m Q .0 v N "6 O N O0 .T..-, C a O a) O - C N fp N N v _ N - p0 M O -M -O o° in O m O CO ru N in 0 rn N a) c)O 0 .-- C .0 C6 C_ f- CV m U d n cocE CO co N m 0 .- 0 0) - 0 ,,r1 O O N 2V o20N- M w _ , 0 Q. � corms C U N7 M3 m 0 Q � a CO11 Q O CO 3 N o m (911 V 0-r O a W 0 U / O N O -o q:\71 - _ i O c - O 0 O F:-- 1 J Q O c )Q. N 0 y -0 Q'ai _ CO N N S U 'C 1E i /'D N O C Cn� J 0 3 ! '98r N 2 x NN X a) 000 — -,1j N 0 N N N -5 - N 0 r O �' Q m X _ E2 oo 0 I;' Er) V i0 V iO Er) Ts) CD 0CD j �i�; To 0 CV N � p.- 00 MM Nom if.'V SP_ O b / f` N J O Q� M r _.d // CO O 000 O0 C _ ..4, CO F-- J . N " )nI,�I1yn� nyIIIII1' M i ALS MIM f }..•~iZ�1 :'iltti n}�-..:S�"�. J�f:i}i,:.:.l:,'V1,•....-.=-4.:27.,,s41:,..•••••••••...........-;:L••�lly{�, 1.1••:ti•1.1•ti 11 Lit:�1:L:L ?:•.`.f..-:.•: i. iii{�{•' •J.�'?•f.+•JL{'I .4 j:: 3r`-16A PRE-RIG WELL WORK DATE SUMMARY 2/21/2015 Late start due to extended safety meeting, construction equipment blocking access and waiting on hardline rig up. RIH w/venturi to 7,710'Work venturi for a while and POOH. Job in progress. 2/22/2015 RIH with a Venturi w/burn-over shoe and make hole. Returned to surface with just a few pieces of rubber, teflon, but a soild 6' of cement. RIH next with a 3.70 mill and used 9.4 PowerPro Mud from CDR2 and worked down to 7,780'from an initial tag of 7,708'. Job in progress. 2/24/2015 RIH w/3.75" OD 5 Blade Inseted Mill to clean out cement. Mill from 7,752' CTMD down to 7,842'CTMD (7,862' RKB). Could not get past this depth and bit was giving indications we were milling on something other than cement. POOH to inspect bit and found a large chunk of aluminum stuck in center of the concave bit. Confer with town engineer and decision made to RDMO until procedures can be reviewed. Well is ready for E-Line to perform a Jewerly Log. Diesel from 7,842'to surface. 2/28/2015 LOCATED DB NIPPLE @ 7607' SLM, 7636' RKB. DRIFT TBG W/3.45"x 20'1" DUMMY GUN TO 7846' SLM, EST. 7875' RKB. PHASE 3 WX MOVED IN RAPIDLY. R/D EQUIPMENT& SECURED WELL. WAITED OUT STORM @ RIG CDR2. 3/6/2015 (PRE-CTD)TREE VALVE TEST SV,SSV,MV ALL PASSED POSTIVE TESTS. AND DDT TO 0 PSI. TREE SHELL TEST TO 4900 PSI. - PASSED 3/6/2015 PERFORM MULITI FINGER CALIPER SURVEY FROM 7872 TO 7550. PERFORATE FROM 78387859. CCL TO TOP SHOT IS 7.5', CCL STOP AT 7830.5. ATTEMPTED TO PERFORATE THE TOP OF THE A2 SANDS FROM 78687872 BUT WAS UNABLE TO GET THAT DEEP WITH THE SECOND GUN STRING. 3/8/2015 MEASURED BHP © 7865' RKB ( 3892 PSI ), RAN 2.5" BAILER WORKED DOWN TO 7881' RKB OBTAINED SAMPLE, DRIFT TO 7830' RKB WITH 12'X 3.63" DUMMY WHIPSTOCK, JOB COMPLETE. 3/10/2015 CORRELATE TO PERF RECORD DATED 6-MAR-2015 AND PERFORATE A2 SANDS FROM 7867'-7872'. WILL BE BACK TO SET WEATHERFORD PACKER TOMORROW. ***IN PROGRESS*** 3/11/2015 CORRELATE TO PERF RECORD DATED 6-MAR-2015 AND SET WEATHERFORD WS-R-BB PACKER MID ELEMENT © 7829.1'. READY FOR SLICKLINE TO SET WHIPSTOCK TRAY. 3/12/2015 SET WEATHERFORD STARBURST HOLLOW WHIPSTOCK(12.41') (2 RA TAGS 2.2' FROM TOP OF WHIPSTOCK) @ 7815' RKB; RAN 3.5" LIB INDICATED WHIPSTOCK TRAY SET 180 DEGREES. SET BPV. Conoc Phillips Time Log & Summary Wellview Web Reporting Report Well Name: 30-16 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/14/2015 12:00:00 PM Rig Release: 4/20/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/12/2015 24 hr Summary Lay down gooseneck and install 2 3/8"rollers, reinstall gooseneck. Swap BOP rams. Swap coil tubing reels, install shim hubs, install reel drive motor, install pack-offs. 12:00 18:00 6.00 0 0 MIRU MOVE CTOP P PJSM-Lay down goose neck, change out rollers, install goose neck. change out gripper blocks, stripper,swap BOP rams. 18:00 22:00 4.00 0 0 MIRU MOVE CTOP P PJSM with Peak, lower reel onto Peak truck,swap reel drive motors out, install new reel,shim hubs, install reel drive and motor. 22:00 00:00 2.00 0 0 MIRU MOVE CTOP P PJSM. Secure coil reel. Install brass and pack-offs,clean-up, 03/13/2015 Stab 2 3/8"coil into injector head. Install new inner reel iron. ND BOP stack,secure wellhead on 30-12. Pull rig modules off well 12, cleanand inspect wellhead/work area.Spot modules over 30-16. Start rigging up CDR. 00:00 02:30 2.50 0 0 MIRU MOVE CTOP P PJSM. P/U stabbing cable, install grapple, pull test. Stab coil in injector, RD stabbing equipment. 02:30 05:00 2.50 0 0 MIRU MOVE CTOP P PJSM. Install new inner reel iron, pre-move checklist. 05:00 10:00 5.00 0 0 MIRU MOVE RURD P Complete RD from 30-12, ND BOP stack, secure stack for move,secure wellhead, load with methanol,check tree flange bolts,two bolts not snug, 40 minutes to complete. 10:00 13:00 3.00 0 0 MIRU MOVE PRLO P Working on pad prep, installing work platform after flow cross swap,work platform will not allow installation of MP valves, MU temp scafolding, install double swabs, double wings off companion, prep site for move. 13:00 18:00 5.00 0 0 MIRU MOVE MOB P Peak on location, PJSM-cold weather ppe, communication. Pull subs off of 30-12, clean and inspect wellhead/work area. Continue working on 30-16 tree configuration. 18:00 22:00 4.00 0 0 MIRU MOVE MOB P PJSM.Spot modules over 30-16. Release Peak crew. 22:00 00:00 2.00 0 0 MIRU MOVE RURD P PJSM.MIRU CDR2, berm cellar, RU PUTZ,steam. 33/14/2015 MIRU CDR2 on 30-16, complete rig up. Rig accept @ 12:00. NU BOP stack. Perform initial BOP test,test PDL's, in progress. 00:00 12:00 12.00 0 0 MIRU MOVE RURD P Continue RU operations, inter connect, TT hardline, pre spud checklist check,tree flange bolts, Page 1 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:15 2.25 0 0 MIRU WHDBO RURD P Accept rig @ 12:00 on 03-14-15. NU BOP equipment, MP line,fill stack and shell test, good test. 14:15 23:00 8.75 0 0 MIRU WHDBO BOPE P Perform initial BOPE test,250/4900 psi,annular 2500 psi.Test witnessed by AOGCC(John Hill) 23:00 00:00 1.00 0 0 MIRU WHDBO RURD P PJSM. Lay down test joints and BOP test equipment, blow down. 33/15/2015 Rehead coil connector, Pull BPV. PT PDL's, inner reel iron,TT line. RIH w/BHA#1 to fish whipstock @ 7,815',got two up licks came free. POOH to check BHA, no fish,disconnect sheared. RIH w/BHA#2, in progress. 00:00 03:15 3.25 0 0 MIRU MOVE CTOP P PJSM. Install coil connector, pull test connector 41K. MU E-line, meg test, MU blind sub. 03:15 04:45 1.50 0 0 MIRU MOVE MPSP P PJSM. Pull BPV, LD FMC equipment 04:45 08:45 4.00 0 0 MIRU MOVE PRTS T PJSM. Load coil, attempt to P/T TT line,froze up, hose and first stick of hardline at rig thawed, intake hose to TT thawed. 08:45 12:00 3.25 0 0 MIRU MOVE PRTS P PJSM. PT inner reel iron, stripper and TT and surface lines. Initial Tubing 1275 psi, IA 1657 psi, OA 0 _ psi, bleed TBG to 0 psi IA to 10 psi. _ 12:00 12:30 0.50 0 0 SLOT WELLPF OWFF T Monitor well 30 minutes,TBG 0 psi, IA 39 psi, OA 0 psi. Fish is set. 12:30 13:00 0.50 0 0 SLOT WELLPF CTOP T PJSM-Install checks, PT CTC and head 4k. 13:00 14:18 1.30 0 77 SLOT WELLPF FISH T PJSM-MU Weatherford fishing BHA #1, M to CoilTrak, Strip over well. 14:18 15:54 1.60 77 7,776 SLOT WELLPF FISH T TIH with fishing BHA#1, EDC open. Tie in to K1, plus 10-ft correction, continue in hole. 15:54 16:54 1.00 7,776 7,776 SLOT WELLPF FISH T 7,776-ft, Close EDC,swap well over to 11.7 ppg formate KWF 16:54 17:09 0.25 7,776 7,797 SLOT WELLPF FISH T Establish parameters 1 bpm at 530 psi, Diff 178, PUW 40k, RIH per Weatherford rep. RIW 14k, IA 180, OA 0. 7796-ft,sat down 10k, PU clean, sat down 10k, hit down jar, PU 4k overpull, sat back down 11k, PU 70k, -21k WOB, Bi-Di jar hit and __ came free, 17:09 18:45 1.60 7,797 73 SLOT WELLPF FISH T TOOH per Weatherford rep,on surface. 18:45 19:15 0.50 73 73 SLOT WELLPF OWFF T PJSM. Flow check 30 minutes, no flow. 19:15 22:30 3.25 73 66 SLOT WELLPF PULD T PJSM. LD BHA#1.Weatherford disconnect sheared, no fish. Discuss with town, decide to run second fishing string. PJSM. MU BHA#2 with 2.5"Hyd.GS. 22:30 00:00 1.50 66 7,600 SLOT WELLPFTRIP T RIH w/BHA#2 to 7,600' Page 2 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/16/2015 24 hr summary Made two unsuccessful runs to fish Weatherford whipstock @ 7,792', no fish. Stand by for new marching orders from town. Decide to make one under reamer run. MU BHA#4, RIH w/under remer assembly to 7,610'. 00:00 01:00 1.00 7,600 7,788 SLOT WELLPF FISH T Continue in hole to fish whipstock, tie-in to K1 for+7'correction, close EDC, PUW=42K. RIH @ min rate, engage fish @ 7,788'.Shut down pump,stack 2K down,straight pull 15K over. Hit five up jar licks @ 15K over, hit four more at 20K over, pull free, set back down 2K, pulled free, PUW=44K. 01:00 02:39 1.65 7,788 66 SLOT WELLPF TRIP T POOH to check BHA,open EDC. On surface. 02:39 03:09 0.50 66 66 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. 03:09 05:09 2.00 66 0 SLOT WELLPF PULD T PJSM. LD BHA#2, no fish,brought back lower section of disconnect and box trap. Does not appear that box trap fully engaged fish, pictures on "S"drive. PT above WS to 250 psi, monitor 30 mins. 05:09 09:45 4.60 0 0 SLOT WELLPF WAIT T Waiting on marching orders from town.2nd PT above WS at 05:30 to 320 psi, 30 minutes 30 psi, at 07:30- 13 psi,at 09:30-8 psi. maintinence and cleaning on rig, choke B motor, DS counterhead ram. 09:45 10:15 0.50 0 0 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. Note: PJSM-Load out Weatherford equipment 10:15 11:39 1.40 0 57 SLOT WELLPF PULD T PJSM-MU BHA#3, Clean out assembly. 11:39 13:15 1.60 57 7,750 SLOT WELLPF TRIP T TIH with BHA#3, 0°straight motor, 3.80"bald nose crayola mill.Tie in to K1,plus 7-ft correction,close EDC, PUW 40k, continue in hole at min rate. 13:15 14:03 0.80 7,750 7,791 SLOT WELLPF WASH T On line 2.2 bpm, 1708 psi at 7,750-ft, wash down, stall at 7,792.8-ft, pumps off, PUW 40k,wash up/ down 7,760-ft to 7,791-ft while CBU, pump sweep. Note: lateral vibration 3 to 4 during passes after. 14:03 14:36 0.55 7,791 7,700 SLOT WELLPF WASH T PUH and wash up/down 7,700-ft to 7,730-ft per town, open EDC. 14:36 16:00 1.40 7,700 57 SLOT WELLPF TRIP T POOH chasing sweep out of hole. No signifficant cuttings or solids arcoss shaker. 16:00 16:30 0.50 57 57 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. PJSM-laying down BHA 16:30 17:15 0.75 57 0 SLOT WELLPF PULD T LD BHA#3, Page 3 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 20:45 3.50 0 0 SLOT WELLPF WAIT T Waiting on under reamer from Prudhoe, Plan forward is to under ream 4 1/2"liner from 7,723-ft to 7,791-ft. 20:45 22:30 1.75 0 70 SLOT WELLPF PULD T PJSM. MU BHA#4, under reamer assembly 22:30 00:00 1.50 70 7,610 SLOT WELLPF TRIP T RIH w/BHA#4 under reamer 03/17/2015 Under ream from 7,724'to 7,791' 00:00 00:45 0.75 7,610 7,724 SLOT WELLPF DLOG T Log K1 for+7.5'correction. Continue in hole. 00:45 02:03 1.30 7,724 7,791 SLOT WELLPF UREM T Start under reaming at 7,724 @ 3 fpm. Pumping at 2 bpm @ 2450 psi, BHP=4025 psi,WOB=0. PUH to 7,724'with same parameters, PUW=40K, no real motor work observed. Open EDC, pump bottoms up. 02:03 03:18 1.25 7,791 71 SLOT WELLPF TRIP T POOH at 50 fpm to 7,600'. Continue OOH @ 100 fpm. 03:18 03:33 0.25 71 71 SLOT WELLPF OWFF T Flow check 03:33 05:51 2.30 71 83 INTRM1 RPEQP1PULD T PJSM. LD BHA#4. PJSM. MU BHA #5 05:51 07:45 1.90 83 7,610 INTRM1 RPEQP1TRIP T RIH w/BHA#5 whipstock assembly, EDC open. 07:45 08:06 0.35 7,610 7,791 INTRM1 RPEQP1 DLOG T Tie in to K1, plus 5-ft correction, PUW 42k,continue in hole pumps off. _ 08:06 08:15 0.15 7,791 7,775 INTRM1 RPEQP1WPST T 7,790.73-ft, Bit depth, positioned 0° HS,close EDC, released at 3400 psi,set down 5k, TOWS at 7,775-ft. 08:15 10:09 1.90 7,775 83 INTRM1 RPEQP1TRIP T 7,775-ft, TOOH for window milling assembly. 10:09 10:39 0.50 83 83 INTRM1 RPEQP1OWFF T Monitor well for flow. PJSM-lay down BHA. 10:39 11:21 0.70 83 0 INTRM1 RPEQPI PULD T LD BHA#5 11:21 13:00 1.65 0 0 INTRM1 WHPST PULD P PJSM-Add riser for PD/PUD,open top doors to rig to allow gooseneck room to raise. 13:00 16:45 3.75 0 82 INTRM1 WHPST PULD P PJSM-MU BHA#6 window milling assembly, 1°AKO motor with string mill and 3.79"string mill and 3.80" DSM, unable to raise injector head high enough to MU to BHA, height of tree a lesson learned,drop 1-ft out of riser assembly. MU to CoilTrak, surface test, P/T riser 1500 psi. 16:45 18:21 1.60 82 7,620 INTRM1 WHPST TRIP P TIH with window milling BHA#6 EDC open. 18:21 18:36 0.25 7,620 7,620 INTRM1 WHPST DLOG P 7620ft,tie into the K1 marker correction of plus 4.5ft. PUW 42.5k 18:36 18:51 0.25 7,620 7,760 INTRM1 WHPST TRIP P 7620ft, continue RIH, RIW 14.3k 18:51 19:36 0.75 7,760 7,760 INTRM1 WHPST DISP P 7760ft,Swap well to 9.8ppg drilling mud. 1__ Page 4 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:36 19:51 0.25 7,760 7,775 INTRM1 WHPST WPST P 7775ft, Dry tag TOWS, bring up pump 2.5bpm at 2300psi. IA 650, OA 0 19:51 00:00 4.15 7,775 7,779 INTRM1 WHPST WPST P Mill window as per recommended practice and Baker rep. 03/18/2015 Mill 3.80"Window 7775ft 00:00 04:30 4.50 7,779 7,787 INTRM1 WHPST WPST P Continue milling window as per Baker rep, ROP 1fph,2.5bpm, 2500psi, 3.25k WOB ****Note: Bled down IA from 700psi to 150psi 04:30 10:35 6.09 7,787 7,787 INTRM1 WHPST WPST P 7,786.6-ft Decrease in WOB,exited 4 1/2"liner, milling window as per schedule and Baker rep, ROP-.6 fph,2.5 bpm,2500 psi,3.90k WOB 10:35 12:05 1.50 7,787 7,788 INTRM1 WHPST WPST P Milling window as per Baker rep, ROP 1 fph,2.5 bpm,2350 psi, 3.90k WOB 12:05 14:35 2.50 7,788 7,791 INTRM1 WHPST WPST P 7,788.2-ft, Decrease in WOB to.5k, milling as per schedule and Baker rep. 1 fph, 2.5 bpm at 2300 psi, some cement across shaker 14:35 16:59 2.41 7,791 7,795 INTRM1 WHPST WPST P 7,791-ft, Milling 2.5 bpm at 2350 psi, .5 WOB,WH 17, BHP 3596, EDC 10.9 ppg, call form town,work up to 11.7 EMW at window,2.5 bpm at 2,580 psi, BHP 3,880 psi, EDC 11.7 ppg,WHP 280 psi, ROP 1.7. 16:59 17:59 1.00 7,795 7,800 INTRM1 WHPST WPST P 7,795-ft, Milling rathole 2.5 bpm at 2,580 psi, BHP 3,855 psi,WHP 280, 11.7 ECD 17:59 20:44 2.75 7,800 7,800 INTRM1 WHPST REAM P 7800ft,TD rat hole, Back ream window area as per plan,7770ft- 7798ft, highside, 30L,and 30R. 60fph,dry drift window area at 15 fph clean,tag TD at 7800ft. 20:44 22:29 1.75 7,800 82 INTRM1 WHPST TRIP P POOH,with Open EDC, pumping 3.0bpm at 2400psi. 22:29 22:59 0.50 82 82 INTRM1 WHPST SFTY P PJSM for undeploying BHA#6 22:59 23:59 1.00 82 82 INTRM1 WHPST PULD P Undeploy milling BHA 03/19/2015 RIH,drilled build section from 7800'to 8090'. POOH, undeployed build BHA, MU and deploy lateral drilling BHA, RIH,drill lateral. 00:00 02:00 2.00 82 0 INTRM1 WHPST PULD P Continue Undeploying milling BHA, ****Note:While undeploying found that we had to break the connection above the QTS breaking an o-ring connection that couldn't be tested when deploying build BHA,after discussing this rig team, recommendation from BHI was to remove wear sub from above the P&C to allow, proper break of QTS when deploying the next BHA's. Page 5 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:30 1.50 0 0 INTRM1 DRILL PULD P Swap tool around in pipeshed, remove wear sub from BHA, retest tools, **"*Note: Mills gauged 3.79OD no-go 03:30 04:00 0.50 0 0 INTRM1 DRILL PULD P M/U build BHA 04:00 04:15 0.25 0 0 INTRM1 DRILL PULD P PU, MU, QTS and retest riser connection to 4900psi. 04:15 06:30 2.25 0 82 INTRM1 DRILL PULD P Deploy BHA#7 build assembly,2.0° AKO motor and 3.75"X 4.25"HCC Bi-center bit, MU to CoilTrak,surface test. 06:30 07:54 1.40 82 7,600 INTRM1 DRILL TRIP P TIH with BHA#7, EDC open 07:54 08:12 0.30 7,600 7,800 INTRM1 DRILL DLOG P Tie in to K1, plus 5-ft correction, close EDC, PUW 37k. Continue in hole. 08:12 12:12 4.00 7,800 7,953 INTRM1 DRILL DRLG P 7,800-ft, OBD 2.52 bpm at 2,949 psi, BHP 3914,WHP 300, IA 300, OA 0,stall at 7,861-ft(6th), 10k overpull, BOBD 2.70 bpm at 3456, BHP 3,947 psi,WHP 243, IA 391, OA 0 12:12 12:33 0.35 7,953 7,600 INTRM1 DRILL WPRT P 7,953-ft, PUH for logging RA markers, PUW 40k, 12:33 13:15 0.70 7,600 7,953 INTRM1 DRILL DLOG P 7,600-ft, Tie in to K1, no correction, Log RA markers on both whipstocks, Top RA marker 7,787.5-ft, Btm RA marker(Weatherford WS)7,796-ft, BOW 7,790-ft. 13:15 15:45 2.50 7,953 8,090 INTRM1 DRILL DRLG P 7,953-ft, BOBD 2.70 bpm at 3,221 psi, BHP 3,990 psi,WHP 259, IA 376,OA 0, pump sweeps, 15:45 18:00 2.25 8,090 82 INTRM1 DRILL TRIP P 8,090-ft, TD build section land in projected Al pay, TOOH chasing sweeps to swab. 18:00 18:30 0.50 82 82 INTRM1 DRILL SFTY P PJSM for LD build section BHA#7 18:30 19:45 1.25 82 0 INTRM1 DRILL PULD P Undeploy build BHA 19:45 20:45 1.00 0 0 INTRM1 DRILL PULD P Reconfigure MWD tools in pipeshed, installing USMR below DGS. 20:45 22:15 1.50 0 82 INTRM1 DRILL PULD P Deploy BHA#8 22:15 23:51 1.60 82 7,615 INTRMI DRILL TRIP P RIH with BHA#8,0.9 AKO motor with rebuilt 4.25OD bi-center bit. 23:51 00:00 0.15 7,615 7,637 INTRMI DRILL DLOG P 7615ft,tie into the K1 marker correction of plus 6ft, PUW 41k 33/20/2015 Drilled from 8090ft to 8737ft. 00:00 00:15 0.25 7,637 8,090 INTRMI DRILL TRIP P Continue RIH thorugh window, clean. 00:15-C72:33 2.30 8,090 8,290 INTRMI DRILL DRLG P 8090ft, BOBD 2.8bpm at 3100psi, BHP 3949,WHP 235, IA 348, OA 0 02:33 03:00 0.45 8,290 7,836 INTRM1 DRILL WPRT P 8290ft,wiper up hole. PUW 38.5k 03:00 0315 0.25 7,836 8,290 INTRM1 DRILL WPRT P 7,836-ft, Wiper back in hole. Page 6of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:33 0.30 8,290 8,358 INTRM1 DRILL DRLG P 8,290-ft, OBD 2.6bpm at 3010psi, BHP 3981,WHP 235, IA 328, OA 0, ROP 215 fpm, pushing on it for turn right, not working. 03:33 07:06 3.55 8,358 82 INTRM1 DRILL TRIP P 8,358-ft, PUH, discuss with town. TOOH for higher AKO motor. 07:06 08:33 1.45 82 0 INTRMI DRILL PULD P PJSM-Un-deploy BHA#8, bit 1-1, looks good. 08:33 09:33 1.00 0 0 INTRM1 DRILL PULD P Adjust motor to 1.5°AKO. 09:33 11:09 1.60 0 82 INTRM1 DRILL PULD P PJSM-MU BHA#9, 1.5°AKO Motor and HYC 3 3/4"x 4.25"Bi-center bit, deploy, MU to CoilTrak,surface test. 11:09 12:30 1.35 82 7,610 INTRM1 DRILL TRIP P TIH with BHA#9 EDC open. 12:30 12:45 0.25 7,610 7,640 INTRM1 DRILL DLOG P Log K1, plus 5-ft correction, close EDC, PUW 39k. 12:45 13:15 0.50 7,640 8,358 INTRMI DRILL TRIP P Continue in hole,clean thru window, 11.8k RIW. 13:15 14:54 1.65 8,358 8,560 INTRM1 DRILL DRLG P 8,358-ft, OBD 2.77 bpm at 3,124 psi, BHP 4,001 psi,WHP 268, IA 472,OA 0,averageing 11 degree DLS, last survey 14° DLS. 14:54 15:24 0.50 8,560 7,850 INTRM1 DRILL WPRT P 8,560-ft,Wiper up hole. PUW 42k 15:24 15:48 0.40 7,850 8,560 INTRM1 DRILL WPRT P 7,850-ft, Wiper back in hole, RIW 1 1 k 15:48 17:48 2.00 8,560 8,684 INTRM1 DRILL DRLG P 8,560-ft, OBD 2.77 bpm at 3,354 psi, BHP 3,987 psi,WHP 224, IA 777, OA 0,WOB 1.8k, ROP 90 from 8,486-ft Note:bleed down IA to 50 psi 17:48 18:03 0.25 8,684 8,684 INTRM1 DRILL WPRT P 8684ft, BHA wiper up to 8590ft, PUW 44k Looks like we transitioned into a different formation,WOB 2.7k, ROP 20 fph 18:03 21:03 3.00 8,684 8,717 INTRM1 DRILL DRLG P 8684ft, BOBD 2.79 bpm at 3354psi, BHP 4064,WHP 300, IA 406, OA 0 21:03 21:18 0.25 8,717 8,717 INTRM1 DRILL WPRT P 8717ft, BHA wiper up to 8600ft, PUW 42k 21:18 00:00 2.70 8,717 8,737 INTRM1 DRILL DRLG P 8717ft, BOBD 2.77 bpm at 3244psi, BHP 4079,WHP 325, IA 375, OA 0 33/21/2015 Drilled lateral from 8737ft to TD 8920ft. Performed a swab wiper, RBIH to confirm TD 8922ft, Lay in 11.75ppg liner pill without beads up to the window, and displace well to 11.85ppg to surface,check well for flow, LD drilling BHA, Function test BOPE. 00:00 02:45 2.75 8,737 8,760 INTRM1 DRILL DRLG P 8737ft, OBD 2.77 bpm at 3365psi, BHP 4050 psi,WHP 292, IA 409, OA 0 02:45 03:45 1.00 8,760 8,760 INTRMI DRILL WPRT P 8760ft, Scheduled wiper up hole to 8200ft, PUW 42k " *Note: Pumping drilling rate 2.6bpm,set down at 8630ft, PU, lowered pump rate to 0.75 bpm, pass through without issue. Page 7 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 08:51 5.10 8,760 8,850 INTRM1 DRILL DRLG P 8760ft, BOBD 2.76 bpm at 3250 psi, BHP 3998,WHP 277, IA 408,OA 0, WOB 3k, ROP 11fph Looks like we transitioned into a different formation,WOB 1.4k, ROP 20 fph 08:51 09:45 0.90 8,850 8,850 INTRM1 DRILL WPRT P 8,850-ft, Geo wiper to discuss TD in town. 09:45 12:21 2.60 8,850 8,920 INTRMI DRILL DRLG P 8,850-ft, OBD 2.78 bpm at 3,315 psi, BHP 4,047 psi,WHP 302, IA 490, OA 0,WOB 1.6k, ROP 16. Note: Final ROP 55 fpm,WOB 1.6k. 13 degree DLS on last 70-ft drilled. 12:21 13:21 1.00 8,920 7,820 INTRM1 DRILL WPRT P 8,920-ft, TD called, PUW 41k, Chase sweeps to swabs,5k overpull at 8,690-ft, 10k ovrepull at 8,650-ft, reduce pump rate to pull thru, call town. 13:21 14:03 0.70 7,820 8,800 INTRM1 DRILL WPRT P 7,820-ft, Wiper back in hole, PUH at 8,580-ft, choke plugging, BU from 8,650-ft, dime size clay balls, heavy shales across shaker, RBIH, reduce rate.5 bpm at 8,630-ft, RIW 9.0k to 8,760-ft with no problem. 14:03 16:30 2.45 8,800 82 INTRMI DRILL WPRT P 8,800-ft, PUW 42k,TOOH 1.4 bpm at 1,774 psi, max overpull of 2k from 8,760-ft to 8,630-ft,TOOH, EDC open at 7,720-ft, Jog at 200-ft. 16:30 18:00 1.50 82 7,620 INTRM1 DRILL TRIP P At surface, reset depth, RBIH with BHA#9 18:00 18:15 0.25 7,620 7,620 INTRM1 DRILL DLOG P 7620ft-7645ft, Tie into K1 correction plus 4.0ft 18:15 18:45 0.50 7,620 7,650 INTRM1 DRILL TRIP P Pressure Survey at window. PUW 40k 1.)0.25 bpm/WHP 425/CHP 340/ANN 3910/ECD 11.93 2.)0.5 bpm/WHP 400/CHP 320/ANN 3911/ECD 11.93 3.) 1.0 bpm/WHP 355/CHP 280/ANN 3911/ECD 11.93 4.)2.0 bpm/WHP 290/CHP 200/ANN 3911/ECD 11.93 Stactic BHP 3865 psi, 11.79 ppg ECD 18:45 20:00 1.25 7,650 8,922 INTRM1 DRILL TRIP P Close EDC,and continue through window to confirm TD. 20:00 20:45 0.75 8,922 7,682 INTRM1 DRILL TRIP P Confirm TD 8922ft, POOH, laying in 11.75 ppg liner running pill without beads up to the window, ****Note: Paint EOP flags at 7600ft and 6400ft. Page 8 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:15 1.50 7,682 82 INTRM1 DRILL TRIP P POOH,with drilling BHA displacing well to 11.8 ppg complition fluid without beads. 22:15 22:45 0.50 82 82 INTRM1 DRILL SFTY P At surface, PJSM for LD drilling BHA#9, check well for flow. """Note: Lost 10 bbls of Nabr to formation during displacement. 22:45 23:30 0.75 82 0 INTRM1 DRILL PULD P LD Drilling BHA 23:30 00:00 0.50 0 0 INTRM1 DRILL CTOP P PU test joint and function test BOPE. 33/22/2015 MU the B lateral 3.5"completion with composite shoe track. POOH and LD liner. MU and RIH with CO BHA. 00:00 00:30 0.50 0 0 INTRM1 CASING SFTY P PJSM,for MU B Lateral completion assembly with compostite shoe. 00:30 03:45 3.25 1,186 1,186 INTRM1 CASING PUTB P MU B lateral completion with 37jts of solid Hyd.511, 9.2#, L-80 with 7 cementrilizers,and shorty deployment sleeve. 03:45 05:00 1.25 1,186 1,230 INTRM1 CASING RUNL P MU BHI and BOT setting tools with GS. 05:00 07:27 2.45 1,230 8,222 INTRM1 CASING RUNL P RIH with 3.5"liner completion with BOT GS. Plus 0.5-ft correction at flag. PUW 45.5k. Continue in hole, RIW 12k. 07:27 08:21 0.90 8,222 7,927 INTRM1 CASING RUNL T 8,222-ft, Sat down 12k,work pipe 4 times, confer with town, pump 1 bpm in tension, PU to 67k to free liner, PUH slowly while discussing with town. 08:21 08:33 0.20 7,927 8,220 INTRM1 CASING RUNL T 7927-ft, RBIH pumping 1 bpm,slow down to 15 fph,start seeing weight swing at 8,145-ft,sat down 5k at 8,220-ft, not moving down,shut down pump, PUW 52k. 08:33 09:12 0.65 8,220 8,000 INTRM1 CASING RUNL T 8,220-ft, PUH slowly while discussing options with town. 09:12 11:30 2.30 8,000 1,230 INTRM1 CASING RUNL T 8,000-ft, POOH for clean out assembly,pumping over the top. 11:30 12:00 0.50 1,230 1,230 INTRM1 CASING OWFF T Flow check. PJSM-laying down BHA. 12:00 12:45 0.75 1,230 1,183 INTRM1 CASING PULD T LD BHA#10 12:45 13:30 0.75 1,183 1,183 INTRM1 CASING PUTB T PJSM-prep floors for laying down liner. 13:30 16:30 3.00 1,183 0 INTRM1 CASING PUTB T PJSM- LD B lateral completion with composite cement retainer, 37 jts of solid Hyd511, 9.2#, L-80 with 7 cementrilizers and deployment sleeve.Clean floors. 16:30 18:30 2.00 0 79 INTRM1 CASING PULD T PJSM-MU BHA#11, 1°AKO motor and 3.80"D331 mill(no back cutters) 18:30 20:00 1.50 79 7,620 INTRM1 CASING TRIP T RIH with clean out BHA#11. 20:00 20:15 0.25 0 7,600 INTRM1 CASING DLOG T 7620ft,Tie into the K1 marker correction of plus 5.0ft. 20:15 22:30 2.25 7,600 7,750 INTRM1 CASING DISP T 7750ft,displace well to 9.8ppg drilling fluid. Page 9 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:15 0.75 8,625 7,912 INTRM1 CASING WPRT T PUH to 7912ft 23:15 00:00 0.75 7,750 8,625 INTRM1 CASING TRIP T RIH,through window down to 8625ft, Pump 5x5 sweep, and chase up hole above window. 03/23/2015 RIH with clean out BHA#11. Set down at 8631'. Perform swab wiper trip. Set anchored aluminum billet at 8250'. __ _ 00:00 00:15 0.25 7,912 7,730 INTRM1 CASING WPRT T 7912ft, Continue PUH to 7730ft 00:15 00:39 0.40 7,730 8,636 INTRM1 CASING TRIP T 7730ft, RBIH to bottom sat down at 8631', PU heavy,try again and worked pipe down to 8636'. 00:39 01:57 1.30 8,636 7,700 INTRM1 CASING TRIP T PU,pump sweep and wiper to 7700'. 01:57 02:51 0.90 7,700 8,620 INTRM1 CASING TRIP T RBIH to 8620', pump 10 x 10 sweep. 02:51 05:12 2.35 8,620 79 INTRM1 CASING TRIP T Perform swab wiper. 05:12 08:12 3.00 79 8,480 INTRM1 CASING TRIP T At surface, reset counters, RBIH,tie in to K1 with plus 4.5-ft correction, continue in hole, clean thru window, no problem thru build or lateral section 08:12 10:42 2.50 8,480 79 INTRM1 CASING TRIP T 8,480-ft, Chase sweeps to surface, shale across shaker 10:42 13:00 2.30 79 0 INTRM1 CASING PULD T PJSM-Undeploy, replace failed o-ring on PDL, LD BHA#11, blow down BHI tools, Bit 3.78"no-go(in 3.79"no-go) 13:00 14:54 1.90 0 78 INTRM1 STK PULD T PJSM-MU BHA#12, 3 5/8"OD OH anchored billet, deploy, make up to ColiTrak, surface test. 14:54 16:21 1.45 78 7,610 INTRM1 STK TRIP T TIH with BHA#12, EDC open pumping minimum rate. 16:21 16:33 0.20 7,610 7,630 INTRM1 STK DLOG T Tie in to K1, plus 5-ft correction,off on pump, PUW 41k. 16:33 17:03 0.50 7,630 8,262 INTRM1 STK TRIP T Continue in hole pumps off,close EDC at window,slacked off 2k at 7,790-ft, PU, reorientate slips 40 LOHS, RBIH through winndow with slight bobble, continue in hole. 17:03 17:15 0.20 8,262 8,250 INTRM1 STK WPST T 8,262.42-ft, Bit depth, PU neutral, release off Billet at 4,500 psi, set down 5k, OH anchored billet set with top at 8,250-ft. 17:15 19:00 1.75 8,250 78 INTRM1 STK TRIP T TOOH with billet setting BHA for drilling BHA. 19:00 20:42 1.70 78 0 INTRM1 STK PULD T PJSM-Undeploy, replace failed o-ring on PDL, LD BHA#12 Open hole anchored billet. 20:42 21:42 1.00 0 0 INTRM1 STK PULD T Reconfigure MWD tools in pipeshed, installed DGS below USMR. 21:42 23:06 1.40 0 0 INTRM1 STK PULD T PJSM-MU BHA#13,0.9°AKO Motor and HCC 3 3/4"x 4.25" Bi-center bit and pressure deploy. Surface test. 23:06 00:00 0.90 0 4,290 INTRM1 STK TRIP T RIH with BHA#13. Page 10 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/24/2015 24 hr Summary RIH with drilling BHA#13 to sidetrack off anchored billet. Swap well to new 9.8 ppg mud.Tried to time milled off billet, but had several stalls. Displaced well to 11.8 ppg completion fluid and POOH for second anchored billet. RIH with BHA#14 and set second billet at 8183'. 00:00 00:36 0.60 4,290 7,600 INTRM1 STK TRIP T RIH with BHA#13. 00:36 01:24 0.80 7,600 7,600 INTRM1 STK DLOG T Tie in to K1, plus 4-ft correction, close EDC, PUW 37k. Continue in hole. 01:24 01:42 0.30 8,250 8,250 INTRM1 STK KOST T Tag up on anchored aluminum billet and start time drilling High Side, stalled PU, restart 01:42 02:42 1.00 8,250 8,255 INTRM1 STK KOST T 8250ft,time milling again,2.7 bpm at 3046psi, BHP 3984,WHP 204, IA 6, OA 0, Stall morning 8253ft 02:42 03:27 0.75 8,255 8,263 INTRM1 STK KOST T 8255ft, Push on it and stall at 8263ft. 03:27 03:42 0.25 8,263 8,263 INTRM1 STK KOST T 8263ft, PUW clean 40k 03:42 07:57 4.25 8,263 8,263 INTRM1 STK KOST T Work pipe down to 8256ft, stalled motor 7 times trying to get back to bottom.Try and RIH dry set down at 8257', PUH, bring up pump RBIH stalled again at 8256ft.PUH and restart pump, stall again at 8256.81'. PUW 44k, minus 4k BHIWOB 07:57 08:27 0.50 8,263 8,263 INTRM1 STK TRIP T 8256ft, PUH, prepair for mud swap, call town about plan forward. 08:27 09:12 0.75 8,263 8,263 INTRM1 STK DISP T 8250ft,swap hole over to new 9.8ppg drilling fluid. 09:12 09:57 0.75 8,263 8,263 INTRM1 STK DISP T RBIH to displace well to 11.8+ppg completion fluid from 8245ft. 09:57 10:57 1.00 8,263 82 INTRM1 STK TRIP T POOH,displacing well with 11.8+ ppg completion fluid. 10:57 12:42 1.75 82 82 INTRM1 STK SFTY T At surface,check well for flow, PJSM for LD tools. 12:42 13:42 1.00 82 0 INTRM1 STK PULD T LD tools 13:42 14:57 1.25 0 0 INTRMI STK PULD T Reconfigure BHI tools in pipeshed. 14:57 15:27 0.50 0 0 INTRM1 STK SFTY T PJSM,for MU billet setting tools. 15:27 17:27 2.00 0 141 INTRM1 STK PULD T MU 3-5/8"Open Hole Anchored Billet with 2 joints of 2-7/8"ST-L. 17:27 19:21 1.90 141 7,594 INTRM1 STK TRIP T Trip in hole with BHA#14. 19:21 19:36 0.25 7,594 7,594 INTRM1 STK DLOG T Tie in at K1 marker at 7594'with a +4.5'correction. Close EDC. PU wt 41K. 19:36 20:21 0.75 7,564 8,258 INTRMI STK TRIP T RIH at20 fpm orientated HS sat down at 7857',try 40 L,try HS at 30 fpm,try 30 R and 40L at 30 fpm. Call town and discuss.Tried 20L at 15 fpm then 30R made it through the window. 20:21 20:51 0.50 8,258 8,258 INTRM1 STK WPST T Wt check 42K.Tag up on first aluminum billet at 8260'and picked up to nuetral wt 3 times.All three set downs at 8260'and nuetral wt 8258'. Pumped up to 3800 psi and sheared off billet.Set down on billet with 5K. Page 11 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:51 22:21 1.50 8,183 134 INTRM1 STK TRIP T POOH with BHA#14. 22:21 23:33 1.20 0 0 INTRM1 STK PULD T PJSM-LD BHA#14 Open hole anchored billet. No flow test. 23:33 00:00 0.45 0 82 INTRM1 STK PULD T PJSM-MU BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 03/25/2015 Drilled off billet at 8186'and drilled to 9076'. 00:00 01:15 1.25 82 82 INTRMI STK PULD T PJSM-MU BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 01:15 04:45 3.50 82 8,186 INTRM1 STK TRIP T RIH with drilling BHA#15 to sidetrack off anchored aluminum billet. Swap well back to drilling mud. Dry tag the billet at 8186'. 04:45 06:15 1.50 8,186 8,200 INTRM1 STK KOST T Start time drilling on billet. 06:15 08:45 2.50 8,200 8,310 INTRM1 DRILL DRLG T Drill ahead at 30 fph,with 1K WOB, 2.75bpm at 2845psi, BHP 3982, WHP 282, IA 8, OA 0 08:45 09:00 0.25 8,310 8,310 INTRM1 DRILL WPRT T 8310ft,Wiper up hole to 8156ft, PUW 40k, Dry drift billet area clean. RBIH to drill ahead. 09:00 10:00 1.00 8,310 8,410 INTRM1 DRILL DRLG T 8310ft, BOBD 2.7 bpm at 2850psi, BHP 4044,WHP 301, IA 16, OA 0 10:00 10:45 0.75 8,410 8,410 INTRM1 DRILL WPRT T 8410ft,Wiper up hole to 7850ft, PUW 40k 10:45 12:45 2.00 8,410 8,600 INTRM1 DRILL DRLG T 8410ft, BOBD 2.75 bpm at 2850psi, BHP 4050,WHP 290, IA 26, OA 0 12:45 13:00 0.25 8,600 8,600 INTRM1 DRILL WPRT T 8600ft,wiper up hole to 8300ft, PUW 41k 13:00 13:30 0.50 8,600 8,666 INTRM1 DRILL DRLG T 8600ft, BOBD 2.79bpm at 3000psi, BHP 4024,WHP 254, IA 195,OA 0 13:30 14:30 1.00 8,666 8,666 INTRM1 DRILL WPRT T 8666ft,Wiper up hole to 7870ft, PUW 38k 14:30 16:30 2.00 8,666 8,804 INTRM1 DRILL DRLG T 8666ft, BOBD 2.8 bpm at 3000 psi, BHP 4019,WHP 273, IA 183,OA 0 16:30 16:39 0.15 8,804 8,804 INTRM1 DRILL WPRT T 200'BHA wiper, PUW 42K 16:39 17:09 0.50 8,804 8,825 INTRMI DRILL DRLG T 8804 ft, BOBD 2.8 bpm at 3062 psi, BHP 4019,WHP 275, IA 239, OA 0 17:09 17:21 0.20 8,825 8,825 INTRMI DRILL WPRT T 200'BHA wiper, PUW 41K 17:21 18:06 0.75 8,825 8,894 INTRM1 DRILL DRLG T 8825ft, BOBD 2.75 bpm at 3113 psi, BHP 4019,WHP 270, IA 392, OA 0 18:06 20:24 2.30 8,894 8,894 INTRM1 DRILL DLOG T Log tie-in wiper trip. Plus 7' correction. 20:24 21:09 0.75 8,894 8,922 INTRM1 DRILL DRLG T 8894 ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 264, IA 398, OA 0 21:09 00:00 2.85 8,922 9,029 INTRM1 DRILL DRLG P 8922 ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 264, IA 398,OA 0 03/26/2015 Drilled lateral from 9029' to 9191'. POOH,changed out the motor and cleaned off the ballled up bit. 00:00 00:06 0.10 9,029 9,037 INTRM1'DRILL DRLG P 9029ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 274, IA 398, OA 0 00:06 01:24 1.30 9,037 9,037 INTRM1 DRILL WPRT P 9037 ft,Wiper up hole to 8260 ft, PUW 44k Page 12 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:24 04:39 3.25 9,037 9,088 INTRM1 DRILL DRLG P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 04:39 05:54 1.25 9,088 7,860 INTRM1 DRILL WPRT P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 05:54 06:54 1.00 7,860 9,088 INTRM1 DRILL WPRT P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 06:54 11:24 4.50 9,088 9,137 INTRM1 DRILL DRLG P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 11:24 12:18 0.90 9,137 9,137 INTRMI DRILL WPRT P 9137ft, BHA wiper, pumping 10 bbls pill of Drill Zone. 12:18 18:36 6.30 9,137 9,178 INTRM1 DRILL DRLG P 9137 ft, BOBD 2.80 bpm at 3245 psi, BHP 4000,WHP 276, IA 450, OA 0 18:36 19:06 0.50 9,178 9,178 INTRM1 DRILL WPRT P 9181 ft, BHA wiper, pumping 10 bbls pill of Drill Zone. 19:06 20:12 1.10 9,178 9,186 INTRMI DRILL DRLG P 9137 ft, BOBD 2.80 bpm at 3245 psi, BHP 4000,WHP 276, IA 450, OA 0 20:12 20:36 0.40 9,186 9,186 INTRM1 DRILL WPRT P 9181 ft, BHA wiper, pumping 10 bbls pill of Drill Zone mixed with beads. 20:36 22:36 2.00 9,186 9,191 INTRM1 DRILL DRLG P 9186 ft, BOBD 2.80 bpm at 3250 psi. 22:36 00:00 1.40 9,191 9,191 INTRM1 DRILL TRIP P POOH with BHA#15 to check bit. PU wt 38K. 33/27/2015 LD drilling BHA#16, MU 37 jts liner and RIH and set it at 8900'. 00:00 00:12 0.20 9,191 82 INTRM1 DRILL TRIP P POOH with BHA#15 to check bit. PU wt 38K. 00:12 01:54 1.70 82 0 INTRM1 DRILL PULD P PJSM-LD BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. 01:54 03:00 1.10 0 82 INTRM1 DRILL PULD P PJSM-MU BHA#16, 1.0°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 03:00 05:30 2.50 82 7,600 INTRM1 DRILL TRIP P RIH with BHA#16. 05:30 05:45 0.25 7,600 7,600 INTRM1 DRILL DLOG P 7600ft,Tie into the K1 marker correction of plus 14ft. 05:45 06:15 0.50 7,600 9,164 INTRM1 DRILL TRIP P Continue RIH to bottom 06:15 06:30 0.25 9,164 9,164 INTRM1 DRILL TRIP P 9164ft, Stack out, PUW 55k 06:30 07:00 0.50 9,164 9,089 INTRM1 DRILL TRIP P 9164ft, PUH, make call to town on plan forward, 07:00 09:30 2.50 9,089 82 INTRM1 DRILL TRIP P 9098ft, pump 10x10 sweep and perform swab wiper. 09:30 11:00 1.50 82 7,600 INTRM1 DRILL TRIP P At surface, reset counters, RBIH 11:00 11:15 0.25 7,600 7,600 INTRM1 DRILL DLOG P 7600ft,Tie into the K1 marker correction of plus 5.5ft. 11:15 12:36 1.35 7,600 9,120 INTRM1 DRILL TRIP P 7600ft, continue RIH """"Note: Set down at the bottom of the window 8k, PUH, Run back through window at 18 fpm clean, continue RIH. 12:36 14:36 2.00 9,120 85 INTRM1 DRILL DISP P 9120ft, Lay in liner running pill with bead up to the window. Displacing well to 12.0 ppg completion fliud without beads to surface, Painting EOP flags at 6500ft, and 7600ft. Page 13 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:36 15:06 0.50 85 85 INTRM1 DRILL SFTY P At surface,check well for flow, PJSM for LD drilling BHA 15:06 16:06 1.00 85 0 INTRM1 DRILL PULD P LD drilling BHA#16 16:06 16:36 0.50 0 0 INTRM1 CASING SFTY P PJSM for MU liner assembly 16:36 18:36 2.00 0 1,173 INTRM1 CASING PULD P MU 37 jts of 3-1/2"solid liner with a composite cement retainer/ shoetrack and aluminum bullnose. The top 3 jts have cementralizers installed. 18:36 20:06 1.50 1,173 1,221 INTRMI CASING PULD P PJSM and MU BHA. Surface test. 20:06 21:48 1.70 1,221 6,500 INTRM1 CASING RUNL P RIH with BHA#17 21:48 22:00 0.20 6,500 6,500 INTRM1 CASING RUNL P 6500' EOP flag,zero correction. Up wt 46K. 22:00 00:00 2.00 8,494 8,560 INTRM1 CASING RUNL P Tag up at 8494 and start working pipe in hole at various speed,pumps on and off. 03/28/2015 Finish running liner in to hole. Perform a full BOPE test. 00:00 02:36 2.60 8,560 8,900 INTRM1 CASING RUNL P Working pipe in hole at various speed,pumps on and off from 8560' to 8900'. PU to neutral wt and pressure up to 3000 psi to release liner. 02:36 04:06 1.50 8,900 48 INTRM1 CASING RUNL P Pooh with liner setting BHA#17. 04:06 04:36 0.50 48 48 INTRM1 CASING PULD P At surface,check well for flow. 04:36 05:36 1.00 48 0 INTRM1 CASING PULD P LD liner setting BHA#17. 05:36 06:51 1.25 0 0 INTRM1 CASING PULD P MU nozzle and jet BOPE. 06:51 07:21 0.50 0 0 INTRM1 CASING PULD P Unstab INJH, RD nozzle and BHI checks. 07:21 09:36 2.25 0 0 INTRM1 CASING PULD P Flush surface lines, Grease BOP's and service tree. 09:36 21:36 12.00 0 0 INTRM1 WHDBO BOPE P BOPE test. Test waived by Matthew Herrera 9:25pm 3/26/15 21:36 22:36 1.00 0 0 INTRM1 CEMEN-CTOP P RD BOPE testing equipment, 22:36 00:00 1.40 0 INTRM1 CEMEN-PULD P Cut CTC off and boot end of e-line. 33/29/2015 M/U Cement BHA with stinger and RIH, Displace well to 8.6PPG fluid, Sting into retainer. Pump 10 BBIs 15.8PPG cement. Pump 8 BBIs then unsting from retainer, Pump remainder of cement. POOH filling coil voidage 00:00 00:18 0.30 0 0 INTRM1 CEMEN"PULD P PJSM about pumping slack forward. 00:18 02:33 2.25 0 0 INTRM1 CEMEN-PULD P Pumping slack forward.Cut 90'off. 02:33 03:33 1.00 0 0 INTRMI CEMEN-PULD P Change of plan. Pump slack back into reel. Cut coil to find a-line. Rehead and pump slack forward. 03:33 06:33 3.00 0 0 INTRMI CEMEN-PULD P PJSM, Install CTC, pull test to 35k, install UQC, PT 4300psi, 06:33 08:33 2.00 0 0 INTRM1 CEMEN-PULD P MU nozzle, stab on INJH and displace coil to 12.0 ppg NaBr. 08:33 10:03 1.50 0 11 INTRM1 CEMEN-PULD P MU cementing BHA#18,pump one coil volume forward Page 14 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:03 12:33 2.50 11 7,600 INTRM1 CEMEN-TRIPP RIH,with cementing BHA#18 with Fixed bladed Centralizer,weight bar, and snap-latch cementing stinger, 100 fpm circulating 0.3 bpm. 12:33 14:33 2.00 7,600 8,840 INTRM1 CEMEN-TRIPP 7600ft,weight check 38k, slow down at the top of liner, 15 fpm, continue RIH to 8840ft 50'above CMT retainer. ****Note: Started stacking weight at 8823ft,stop coil, looks like we are in the high dog area of the hole,push on it, got weight back,continued in hole to 8400ft. 14:33 18:03 3.50 8,840 8,887 INTRM1 CEMEN-DISP P Displace liner to 9.8 ppg while POOH at 30 fpm, park at 7600ft and displace with 9.8". RBIH to 8886.57ft sting into the retainer, seen an pressure increase of 200 lbs. Set down 5k 8886.57ft.bring pump up to 1.0 bpm at 1259 psi, IA 0, OA 0 18:03 18:57 0.90 8,887 8,887 INTRM1 CEMEN-DISP P Crew change, run valave checklist, check SLB R/U to rig, PJSM with SLB cementers, Batch up cement @ weight 15.8 @ 18:55 18:57 19:27 0.50 8,887 8,887 INTRM1 CEMEN"DISP P Line up on pill pit and pump 4.3 BBIs 8.6 PPG mud to MM 19:27 19:51 0.40 8,887 8,887 INTRM1 CEMEN"DISP P S/D pump and line up to cement unit,WHP=579, IA=0, 0A=0, Pump 5 BBIs Fresh water. S/D for cementers PT,4K, Line back up to coil 19:51 20:09 0.30 8,887 8,887 INTRM1 CEMEN-CMNT P Cementers on line with 15.8PPG cement, 1 BPM, 2.34 BBIs between cemeters and rig MM, Pump 10 BBIs Cement,followed by 3 BBIs fresh, S/D and swap to rig pump 20:09 20:45 0.60 8,887 8,865 INTRM1 CEMEN-CMNT P Swap to rig pump and line up on 8.6PPG fluid,Vol in 12.9,34.9 BBIs in goto 9.8PPG Power vis, 20:45 20:51 0.10 8,865 8,879 INTRM1 CEMEN-CMNT P 41.7BBIs in, reset out micro motion, 49.7 BBIs, all cement pumped at one for one. S/D pump and unsting from cement retainer, PUW=38K, Pump one more BBI 20:51 23:45 2.90 8,879 50 INTRM1 CEMEN-TRIPP POOH replace coil voidage, PUW=34K, Discuss WHP with Jason. Unable to get below–600 PSI,Continue out 23:45 00:00 0.25 50 0 INTRM1 CEMEN-TRIPP 50'from surface, Continue out following slimhole procedure 03/30/2015 Flush coil and pump inhibitor.Test wire-good. PT Cement-Fail. Blow down CT with N2. Remove coil from injector and secure to spool. Rig up to swap out L_ �. _ __. � ---___ ____—..________. __. Page 15 of 31 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 INTRM1 CEMEN-PULD P Master shut, bleed off WHP and remove tools, Shut swabs. Open master and monitir MP line.Trip sheets out at one to one.WHP @ 620. Bleed off 100 psi pressure came right back up 00:30 06:00 5.50 0 0 INTRM1 CEMEN"WOC P WOC 06:00 11:00 5.00 0 0 INTRM1 CEMEN-WOC P Line up, mix inhibitor, and flush surface lines, Stage 2 inch parts for reel swap. 11:00 14:30 3.50 0 0 INTRM1 CEMEN-WOC P Call out SLB N2 pumpers from Deadhorse, Remove CTS counter, stage new brass, and pac-offs. Unboot wire and test cable>2kMeg/38 Ohmes 14:30 17:00 2.50 0 0 INTRM1 CEMEN-WOC P PJSM with SLB N2 Pumpers, R/U and blow down coil to TT.Shut down Rig down N2 17:00 18:00 1.00 0 INTRM1 CEMEN-PRTS P Pressure test cement, Pump up 200 PSI pressure bled right back down 18:00 00:00 6.00 INTRM1 CEMEN-CTOP P R/D inner reel iron, Dress coil and install internal grapple connector. Unstab coil from injector and secure to storage reel. Rig up spool to lifting rams 03/31/2015 Reel swap from 2 3/8"to 2"coil. Change out BOP rams and gooseneck rollers. Stab coil in injector head, MU inner reel iron,test bulkhead. Rehead coil connector and UQC,test. Load coil and test inner reel iron and pack-offs. Prep for BOP test. 00:00 06:00 6.00 0 0 INTRM1 CEMEN"CTOP P PJSM with Peak-Load out 2 3/8" coil to truck, P/U 2"CT string. Swap out brass in stuffing box, C/O injector gripper blocks, C/O horsehead rollers,Torque reel saddle clamps 06:00 19:15 13.25 0 0 INTRM1 CEMEN'CTOP P PJSM, C/O BOP Rams and gooseneck rollers, Install stripper on injector and install packoff. Prep coil and install grapple, Stab coil in injector. M/U inner reel iron and pressure bulkhead. Meg test E-Line, good test. 19:15 23:30 4.25 0 0 INTRM1 CEMEN CTOP P Rehead coil connector,and pull test. Rehead upper quick connect, meg test good. Load coil, pressure test inner reel iron, pack-offs. 23:30 00:00 0.50 0 0 PROD1 DRILL BOPE P Prep rig floor for BOP test. 34/01/2015 Finish prep for BOP test.Complete bi-weekly BOP test. PD BHA#19, RIH w/4.5"clean-out assembly to 7,590', in progress. 00:00 01:00 1.00 0 0 PROD1 DRILL BOPE P Continue prepping for BOP test,shell test to 4,900 psi. 01:00 13:00 12.00 0 0 PROD1 DRILL BOPE P Perform full BOP test 250/4900 psi, annular 2,500 psi. Test waived by AOGCC(Johnnie Hill)at 16:45 on 03-31-15. Page 16 of 31 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 18:00 5.00 0 0 PROD1 DRILL BOPE T Troubleshoot choke leaks. Change-out valves C5, C8,and C16. Retest. BOP test complete.Stab on wellhead,test inner iron and pack-offs. Start NAD NPT 5 Hrs 18:00 19:30 1.50 0 0 PROD1 DRILL RURD P PJSM. LD BOP test equipment, prep floor for pressure deployment. 19:30 22:00 2.50 0 0 PROD1 DRILL PULD P PJSM. MU/PU BHA#19 clean-out assembly. Pressure deployment BHA. 22:00 00:00 2.00 0 7,590 PROD1 DRILL TRIP P RIH w/4.5"clean-out assembly 34/02/2015 Make 4.5"liner clean-out run to 7,732'. Make 3.5" liner clean-out run to 8,700', milled continual cement from 8,500'to 8,700'. POOH for whipstock assembly. PUD BHA#20, PD BHA#21. RIH w/whipstock,whipstock became stuck @ 7,950',work pipe, in progress. 00:00 01:21 1.35 7,590 7,732 PROD1 DRILL TRIP P Continue in hole with clean-out assembly,tie-in K1 for+7' correction, close EDC. RIH watching for cement stringers, saw nothing. Shut down pump,dry tag TOL @ 7,732'.Open EDC, pump sweeps. 01:21 02:45 1.40 7,732 53 PROD1 DRILL TRIP P Chase sweeps to surface at max rate. 02:45 04:48 2.05 53 0 PROD1 DRILL PULD P PJSM. PUD BHA#19, LD BHA. 04:48 06:15 1.45 0 52 PROD1 DRILL PULD P PJSM. PD BHA#20 06:15 07:39 1.40 52 7,590 PROD1 DRILL TRIP P RIH w/3.5"clean-out assembly, EDC Open 07:39 07:45 0.10 7,590 7,618 PROD1 DRILL DLOG P Log K1 for+9' 07:45 07:57 0.20 7,618 7,700 PROD1 DRILL TRIP P Continue in 07:57 10:27 2.50 7,700 8,700 PROD1 DRILL MILL P Stop and shut EDC, PUW=34K, clean trip past liner top,first set down at 8024, stringers down to 8500 then constant milling to 8700' 10:27 11:03 0.60 8,700 8,700 PROD1 DRILL MILL P Recip across whipstock setting depth 8660 to 8700 while waiting for 10 X 10 sweeps 11:03 13:27 2.40 8,700 60 PROD1 DRILL TRIP P Chase sweeps to surface 13:27 14:57 1.50 60 0 PROD1 DRILL PULD P At surface, PJSM PUD BHA#20 3.5"liner clean out 14:57 16:15 1.30 0 0 PROD1 RPEQPI PULD P M/U Whipstock BHA#21 16:15 17:30 1.25 0 73 PROD1 RPEQPI PULD P PD BHA#21 Set Whipstock Page 17 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 00:00 6.50 73 7,950 PROD1 RPEQP1TRIP T RIH w/WS assembly,tie-in K1 for +8'correction,weight check above TOL @ 7,635'34K. Continue in hole, stack out @ 7,899'. PUW=37K. Make four more attempts,work WS to 7,926'. Call town, decide to POOH check BHA.Town change minds, decide to pump more lubes, RBIH. pump lubes around, start stacking and getting weight back @ 7,930', work down to 7,950', not getting weight back, stuck @ 7,950',work pipe, pump on/off and different orientation, no luck. Discuss with town. 04/03/2015 Pull free from stuck whipstock @ 7,950'. POOH LD BHA#21,whipstock left in hole. RIH w/nozzle,jet above fish @ 7,940'max rate. POOH, LD BHA. RIH w/dummy whipstock assembly, drift to top of fish @ 7,940', no issues. POOH, LD BHA. RIH w/new whipstock assembly,set whipstock @ 7,911', TOWS 7,900'40 ROHS. 00:00 00:15 0.25 7,950 7,950 PROD1 RPEQP1TRIP T Start pulling on stuck BHA with pump off,eight cycles to 65K,pump on at 1 bpm, pull 70K, pull free, HOT tool still working. 00:15 01:30 1.25 7,950 80 PROD1 RPEQPI TRIP T POOH to check BHA. 01:30 02:45 1.25 80 0 PROD1 RPEQPI PULD T PJSM. PUD BHA#21, Check BHA, no whipstock, hard cemment in collars of setting tool,pictures of setting tool in folder on"S"drive. LD BHA. 02:45 03:45 1.00 0 0 PROD1 RPEQPI PULD T Wait on Baker fishing tools.Town decided to run nozzle first. 03:45 05:00 1.25 0 26 PROD1 RPEQPI PULD T PJSM. PU/MU nozzle assembly. 05:00 06:48 1.80 26 7,941 PROD1 RPEQP1TRIP T RIH w/nozzle assembly 06:48 07:48 1.00 7,941 7,941 PROD1 RPEQPI TRIP T On top of fishpump 2.07 BPM @ 3780, Pump 10 X 10 sweep, recip on top of fish 07:48 09:24 1.60 7,941 25 PROD1 RPEQPI TRIP T Trip out 09:24 09:42 0.30 25 0 PROD1 RPEQPI PULD T On Surface, PJSM, Lay down FCO BHA 09:42 11:00 1.30 0 0 PROD1 RPEQP1SVRG T Service/inspect injector&reel. Pull choke b apart 11:00 12:00 1.00 0 0 PROD1 RPEQP1WAIT T Conference call with town-explore options decide to prep hole and run second whipstock 12:00 13:30 1.50 0 71 PROD1 RPEQP1PULD T Crew change, PJSM, Make up BHA #23 with Dummy whipstock and Deploy 13:30 15:12 1.70 71 7,939 PROD1 RPEQP1TRIP T Trip in hole with BHA#23 Dummy Whipstock tie into K1 @ 7610 to 7637 for+11 15:12 16:24 1.20 7,939 7,700 PROD1 RPEQPI CIRC T Tag pinchpoint,Jet and recip to 7880 with sweeps, pumped second set of sweeps jetted 7939 to 7700'. 2.1 BPM 0 4500 PSI 16:24 18:00 1.60 7,700 71 PROD1 RPEQP1TRIP T POOH at 2.09 BBIs/Min Page 18 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:30 1.50 71 0 PROD1 RPEQP1 PULD T PJSM. PUD BHA#23, LD BHA 19:30 21:00 1.50 0 74 PROD1 RPEQPI PULD T PJSM. PD BHA#24 21:00 00:00 3.00 74 7,911 PROD1 RPEQPI TRIP T RIH w/whipstock assembly, tie-in K1 for+7.5'correction,continue in hole to set septh @ 7,910'. PUW=34K. RBIH to set depth, close EDC, pressure up to release from WS @ 4,100 psi,stack 4K down. TOWS @ 7,900'40 ROHS. 34/04/2015 POOH, LD BHA#24. PD BHA#25. RIH w/window milling assembly. Mill window from 7,900'to 7,905', milling in progress. 00:00 01:30 1.50 7,911 74 PROD1 RPEQPI TRIP P POOH for milling assembly. 01:30 04:00 2.50 74 72 PROD1 RPEQPI PULD P PJSM. PUD BHA#24, LD BHA. PJSM. PD BHA#25. 04:00 05:18 1.30 72 7,600 PROD1 WHPST TRIP P RIH w/window milling assembly, tie-in 05:18 05:36 0.30 7,600 7,643 PROD1 WHPST DLOG P Log K1 tie in for+5.5'correction 05:36 06:00 0.40 7,643 7,901 PROD1 WHPST TRIP P RIH to dry tag whipstock 06:00 15:00 9.00 7,901 7,904 PROD1 WHPST WPST P 7800, bring pumps on, 1.7 BPM @ 4000 PSI FS, BHP=3905, Call pinch point @ 7899.9 with motor work and DHWOB 15:00 16:48 1.80 7,904 7,905 PROD1 WHPST WPST P Confer with town,window going slowly,double check liner tally,way away from connection. Keep on, Pump up sample looking for dirt, Good supply of metal on magnets, 150 PSI motorwork 16:48 00:00 7.20 7,905 7,905 PROD1 WHPST WPST P P/U and restart, 1.52 BPM @ 3890 PSI FS, See DHWOB @ 7904.2. Only metal in sample. Slow going, several pick-ups, clean pick-ups, mainly metal across shakers. 04/05/2015 Continue milling window to 7,906'. POOH to check BHA. PUD BHA#25, PD BHA#26. Mill on window exit @ 7,906', no progress made. POOH.Wait on new orders from town, make clean-out run to 7,890'with dummy drift.Start out hole with BHA#27. 00:00 04:54 4.90 7,905 7,906 PROD1 WHPST WPST P Continue milling whiptock @ 7,905'. Cut pump rate to 1.53 BPM @ 3,650 PSI, BHP=3950 PSI, CTW=10K, WOB=4K. Restart several times, metal across shaker. 04:54 06:12 1.30 7,906 77 PROD1 WHPST TRIP T Forward progress stopped,Trip out to inspect BHA 06:12 08:12 2.00 77 0 PROD1 WHPST PULD T At surface, PUD BHA#25. Bit shows little evidence of crossing centerline. Motor tight and holding fluid. Check scribe down tool string good. Mill out @ 2.79 No Go 08:12 09:24 1.20 0 73 PROD1 WHPST PULD T M/U BHA#26 with 0° motor, new 2.80 window mill, new string reamer and pressure deploy 09:24 10:48 1.40 73 7,610 PROD1 WHPST TRIP T Trip in hole, EDC open Page 19 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:48 11:00 0.20 7,610 7,640 PROD1 WHPST DLOG T Log K1 for+4.5'correction, close EDC 11:00 11:18 0.30 7,640 7,905 PROD1 WHPST TRIP T Continue in well, dry tag @ 7905.81 11:18 15:18 4.00 7,905 7,906 PROD1 WHPST MILL T Bring pumps on 1.53 BPM @ 3450 PSI FS, BHP=3900, Getting DHWOB with no motorwork, Run at it to get motor work-150 PSI 15:18 16:36 1.30 7,906 80 PROD1 WHPST TRIP T Making no progress, no metal coming out, POOH 16:36 18:00 1.40 80 81 PROD1 WHPST PULD T At Surface, PJSM, PUD BHA#26, service injector and reel. 18:00 20:00 2.00 81 0 PROD1 WHPST PULD T Waiting new marching orders from town. 20:00 21:00 1.00 0 72 PROD1 WHPST PULD T PJSM. MU BHA#27, PD BHA. 21:00 23:30 2.50 72 7,890 PROD1 WHPST TRIP T RIH w/Dummy drift/nozzle,tie-in to K1 for+4.5'correction, continue in hole, no issues. Pump bottoms up at max rate 1.9 bpm @ 4,300 psi, clean 3.5" liner. 23:30 00:00 0.50 7,890 6,370 PROD1 WHPST TRIP T Start out of hole. 04/06/2015 POOH w/BHA#27, PUD BHA. PD BHA#28, Set 3.5"Monobore whipstock @ 7,875'. POOH and PUB BHA#28. PD BHA#29, RIH w/magnets and LIB,tag whipstock @ 7,877', POOH, PUD BHA#29. PD BHA #30,RIH w/milling assembly,dry tag whipstock 7,876',start milling window exit, in progress. 00:00 01:15 1.25 6,370 78 PROD1 WHPST TRIP T Continue out of hole with BHA#27. 01:15 02:30 1.25 78 0 PROD1 WHPST PULD T PJSM. PUD BHA#27 02:30 03:30 1.00 0 73 PROD1 RPEQP1PULD T PJSM. MU BHA#28, PD BHA. 03:30 05:36 2.10 73 7,613 PROD1 RPEQP1TRIP T RIH w/Whipstock assembly,tie-in 05:36 05:42 0.10 7,613 7,641 PROD1 RPEQP1 DLOG T Log K1 for+5'correction 05:42 06:24 0.70 7,641 7,886 PROD1 RPEQP1TRIP T Continue in to set depth @ 7885.5, TOWS=7875 @ 20L, see tool shift @ 4200PS1,Set down 4K Looks good 06:24 07:42 1.30 7,886 78 PROD1 RPEQP1 TRIP T Trip out after setting whipstock 07:42 08:30 0.80 78 0 PROD1 RPEQP1PULD T At surface, PJSM PUD BHA#29 Whipstock setting tools 08:30 10:00 1.50 0 0 PROD1 WHPST WAIT T Waiting on Magnets from Deadhorse 10:00 11:06 1.10 0 67 PROD1 WHPST PULD T PJSM, P/U BHA#29, Magnets and 2.50 LIB 11:06 12:30 1.40 67 7,600 PROD1 WHPST TRIP T Trip in hole, EDC open 12:30 12:36 0.10 7,600 7,633 PROD1 WHPST DLOG T Tie into K1 for+5.5 12:36 12:48 0.20 7,633 7,878 PROD1 WHPST TRIP T Continue in with LIB, Tag @ 7877.87, see 2.6K DHWOB 12:48 14:00 1.20 7,878 75 PROD1 WHPST TRIP T Trip out of well 14:00 15:12 1.20 75 0 PROD1 WHPST TRIP T At surface,Tag up and space out, PJSM PUD BHA#29 15:12 16:00 0.80 0 0 PROD1 WHPST WAIT T Pics on LIB to S Drive,clean magnets, formulate plan forward 16:00 17:15 1.25 0 71 PROD1 WHPST PULD T PJSM, M/U and deploy BHA#30.6° motor and 2.80 window mill Page 20 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 19:21 2.10 71 7,877 PROD1 WHPST TRIP T RIH w/millinf assembly,tie-in to K1 for+5'correction, continue in hole. PUW=34K. Dry tag whipstock @ 7,876.7'. 19:21 00:00 4.65 7,877 7,879 PROD1 WHPST WPST T Start stick milling window: 1.50 bpm @ 3,775 psi, BHP=3,960 psi, CTW=12.4K,WOB=2.5K. 04/07/2015 Mill window exit from 7,876'to 7,880'. Progress not being made on window. POOH, PD BHA#30, LD BHA. Rig maintenance. PD BHA#31, RIH w/caliper assembly, log CCL from 7,600'to 7,865'. Log caliper survey from 7,880'to 6,980'. POOH and PUD BHA#31, LD BHA. Download caliper data, send for processing. Waiting on orders. 00:00 03:00 3.00 7,879 7,880 PROD1 WHPST WPST T Continue milling window exit. 1.52 bpm @ 3,740', BHP=3,924 psi, CTW=11K,WOB=2.7K. have motor work, but progress is slowing down. 03:00 07:06 4.10 7,880 7,880 PROD1 WHPST WPST T Continue milling window: 1.53 bpm @ 3,725 psi, BHP=3,920 psi. CTW=11.5K,WOB=3K. Progress is slowing down, made about 4'total. _ 07:06 08:42 1.60 7,880 71 PROD1 WHPST WPST T 7880,Trip out for something else, PUW=33.5K 08:42 12:00 3.30 71 0 PROD1 WHPST PULD T PJSM-Un-deploy and LD 2.6BHA #30, P/T BHA and CTC,good, mill gauge 2.79"no-go,good shape, no damage or indication of wear to BHA, wait on PDS tools. 12:00 12:30 0.50 0 0 PROD1 WHPST SFTY T PDS tools on site, rig orientation for new to rig hand. 12:30 13:30 1.00 0 0 PROD1 WHPST PULD T Confirm plan forward caliper BHA set up, program tools,set timer for tool to open. 13:30 14:54 1.40 0 59 PROD1 WHPST PULD T PJSM-MU/Deploy BHA#31,tool set to open at 19:12. 14:54 16:00 1.10 59 7,595 PROD1 WHPST TRIP T RIH with caliper BHA#31. 16:00 16:45 0.75 7,595 7,865 PROD1 WHPST DLOG T Log K1 marker, plus 5-ft correction, PUW 32k, RBIH, CCL log from 7,600' to 7,865'@ 20 fpm..75 16:45 19:30 2.75 7,865 7,880 PROD1 WHPST TRIP T RBIH to 7,870'.Waiting on caliper to engage. RIH to 7,880'. 19:30 21:00 1.50 7,880 63 PROD1 WHPST DLOG T TOOH logging caliper survey @ 50 fpm to 6,980'. Caliper arms released, POOH at normal spped. 21:00 22:30 1.50 63 0 PROD1 WHPST PULD T PJSM. PUD BHA#31, LD Caliper BHA. 22:30 00:00 1.50 0 0 PROD1 WHPST WAIT T Waiting on orders. Download caliper data, send for processing, rig maintenance. 04/08/2015 Waiting on caliper survey.Waiting on orders,decide to run another whipstock,wait on whipstock assembly. RIH w/BHA#32 whipstock with OH anchor assembly, in progress. 00:00 06:30 6.50 0 0 PROD1 WHPST WAIT T Continue waiting on orders, process Caliper data, monitored MP. 06:30 07:00 0.50 0 0 PROD1 WHPST BOPE T PJSM-Function test BOPE 07:00 15:00 8.00 0 0 PROD1 WHPST WAIT T Continue waiting on orders, rig maintenance, monitor MP. Page 21 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:15 1.25 0 0 PROD1 RPEQP1 PULD T PJSM-Un load and reconfigure BHI tools, pre load DS PDL for whistock run. 16:15 20:00 3.75 0 0 PROD1 RPEQP1WAIT T Waiting on whipstock from Prudhoe, rig maintenance, monitor MP. 20:00 21:54 1.90 0 74 PROD1 RPEQP1PULD T PJSM. PU/MU/PD BHA#32 Whipstock assembly 21:54 00:00 2.10 74 7,610 PROD1 RPEQP1TRIP T RIH w/Whipstock OH anchor assembly 04/09/2015 Set whipstock @ 7,862.5',TOWS @ 7,852'. POOH. PUD BHA#32, PD BHA#33. RIH w/milling assembly, dry tag whipstock @ 7,851', mill window exit from 7,851'to 7,857'. Drill rahole from 7,857'to 7,866', back ream window,dry drift clean. POOH. PUD BHA#33, PD BHA#34, RIH w/build section drilling assembly, in progress. _ 00:00 00:39 0.65 7,610 7,862 PROD1 RPEQP1TRIP T Continue in hole with whipstock, tie-in to K1 for+6'correction. RBIH to set depth, PUW=35K, set depth 7,862.3'TOWS @ 7,852', release from WS @ 4,200 psi, stack 4K down. 00:39 02:00 1.35 7,862 74 PROD1 RPEQP1TRIP T POOH for milling assembly 02:00 04:15 2.25 74 72 PROD1 RPEQP1 PULD T PJSM. PUD BHA#32, LD BHA. PJSM. PD BHA#33. 04:15 06:09 1.90 72 7,851 PROD1 WHPST TRIP T RIH w/milling assembly, tie-in for plus 5-ft correction, continue in hole. 06:09 12:18 6.15 7,851 7,854 PROD1 WHPST WPST T 7,851.2-ft, Dry tag top of whipstock, PUW 34k, bring up pump 1.54 bpm at 3,712 psi, begin time milling window 1.54 bpm at 4,010 psi, BHP 3,934 psi, CWT 12.4k,WOB 1.2k 12:18 13:39 1.35 7,854 7,855 PROD1 WHPST WPST T 7,854.2-ft, time milling 1.54 bpm at 4,046 psi, BHP 3,957 psi, CWT 12.4k,WOB 3.4k, IA 0, OA 0, lots of metal across shaker. 13:39 15:33 1.90 7,855 7,857 PROD1 WHPST WPST T 7,855-ft, decrease of WOB, continue milling 1 fph, 1.55 bpm at 3,850 psi, BHP 3,956 psi, CWT 13.5k,WOB 0.8k for 2-ft 15:33 16:57 1.40 7,857 7,866 PROD1 DRILL DRLG T 7,857-ft, Drill rathole 1.55 bpm at 3,880 psi, BHP 3,958 psi, CWT 11k, WOB 2.4k. 16:57 18:06 1.15 7,866 7,866 PROD1 DRILL REAM T 7,866-ft, TD rat hole, Back ream window area as per plan, highside, 30L, and 30R. 60fph, dry drift window area at 15 fph clean,tag TD at 7,866-ft. 18:06 19:33 1.45 7,866 78 PROD1 DRILL TRIP T POOH w/BHA#33 19:33 23:12 3.65 78 72 PROD1 DRILL PULD T PJSM. PUD BHA#33, LD BHA, string&window mill both mic'd at 2.79" NO-GO. PJSM. PD BHA#34 23:12 00:00 0.80 72 4,150 PROD1 DRILL TRIP T Start in hole with build asembly 04/10/2015 Drill build section to TD @ 7,995'. POOH. PUD BHA#34. PD BHA#35. Drill B lateral from 7,995'to 8,545', in progress. Page 22 of 31 Time Logs _ Date _ From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 4,150 7,866 PROD1 DRILL TRIP T Continue in hole with build section assembly,start pumping new 10 ppg mud system @ 4,300'.Tie-in to K1 for+5.5'correction,tag up @ 7,866'. New mud around, 02:15 08:39 6.40 7,866 7,995 PROD1 DRILL DRLG T BOBD: 1.35 BPM @ 4,160 PSI, BHP=4,060 PSI, CTW=11.8K, WOB=1.85K, ROP=40. bit balling at 7,950-ft, pump 30 bbl 5% DrillZone pill 08:39 09:30 0.85 7,995 7,885 PROD1 DRILL DLOG T 7,995-ft, Build TD'd, PUW 33k, Tie in to K1, 0-ft correction, RBIH Log RA tag, TOW 7,851-ft, BOW 7,855-ft, RA 7,858-ft 09:30 11:00 1.50 7,885 72 PROD1 DRILL TRIP T TOOH with BHA#34 11:00 13:00 2.00 72 0 PROD1 DRILL PULD T PJSM-Un-deploy/Crew changeout, PJSM- LD BHA#34, bit 2-1-BF-N-X-I-PN-BHA,change out check valves. 13:00 14:12 1.20 0 72 PROD1 DRILL PULD T PJSM-MU/Deploy BHA#35, .8° AKO motor and HYC Bi-center bit, surface test. 14:12 16:00 1.80 72 7,995 PROD1 DRILL TRIP T RIH with BHA#35, EDC open, plus 5-ft correction at K1, PUW 33k, continue in hole. 16:00 18:15 2.25 7,995 8,190 PROD1 DRILL DRLG T 7,995-ft, OBD 1.36 bpm at 4,320 psi, BHP 4,106 psi, CWT 12.6k, WOB 1.6k, ROP 80, IA 0, OA 0. 18:15 18:45 0.50 8,190 8,190 PROD1 DRILL WPRT T Wiper to window, PUW=34K, RBIH. 18:45 21:15 2.50 8,190 8,390 PROD1 DRILL DRLG T DOBD: 1.38 BPM @ 4,430 PSI, BHP=4,135 PSI, CTW=12K, WOB=1.3K, ROP=80. 21:15 22:00 0.75 8,390 8,390 PROD1 DRILL WPRT T Wiper to window, PUW=35K, RBIH. 22:00 00:00 2.00 8,390 8,545 PROD1 DRILL DRLG T DOBD: 1.38 BPM @ 4,330 PSI, BHP=4,135 PSI, CTW=11.8K, WOB=1.1K, ROP=70. 04/11/2015 Drill ahead B lateral from 8,545'to 9,790', drilling in progress. 00:00 00:36 0.60 8,545 8,590 PROD1 DRILL DRLG T Continue drilling: 1.38 BPM @ 4,410 PSI, BHP=4,145 PSI, CTW=10.6K, WOB=1.5K, ROP=90. 00:36 02:06 1.50 8,590 8,590 PROD1 DRILL WPRT T Pump sweeps, PUW=35K,wiper trip for tie-in, +1'correction,jet liner max rate, RBIH. 02:06 04:21 2.25 8,590 8,790 PROD1 DRILL DRLG T DOBD: 1.39 BPM @ 4,480 PSI, BHP=4,165 PSI, CTW=11.5K, WOB=1.2K, ROP=80. Note: Off trouble time at 8,670-ft/ 03:00 am. 04:21 05:00 0.65 8,790 8,790 PROD1 DRILL WPRT P Wiper to window, PUW=34K, RBIH. 05:00 07:48 2.80 8,790 8,990 PROD1 DRILL DRLG P DOBD: 1.40 BPM @ 4,430 PSI, BHP=4,180 PSI, CTW=11K, WOB=1.4K, ROP=95. Page 23 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:48 08:45 0.95 8,990 8,990 PROD1 DRILL WPRT P 8,990-ft, Wiper up hole to 8,000-ft, PUW=35K. RBIH 08:45 11:15 2.50 8,990 9,190 PROD1 DRILL DRLG P 8,990-ft OBD 1.4 bpm at 4,404 psi, BHP 4,202 psi, CWT 10.2k,WOB 1.6k, ROP 90, IA 174, OA 0 11:15 13:15 2.00 9,190 9,190 PROD1 DRILL WPRT P Wiper up hole for tie in, pump sweeps, PUW 35k,jet liner, RBIH, plus 3-ft correction at RA. 13:15 16:03 2.80 9,190 9,390 PROD1 DRILL DRLG P 9,190-ft OBD 1.37 bpm at 4,410 psi, BHP 4,206 psi, CWT 9.0k,WOB 1.6k, ROP 85, IA 220, OA 0 16:03 17:00 0.95 9,390 9,390 PROD1 DRILL WPRT P Wiper up hole, PUW 35k, RBIH. 17:00 19:27 2.45 9,390 9,590 PROD1 DRILL DRLG P DOBD: 1.38 BPM @ 4,480 PSI, BHP=4,220 PSI, CTW=8.5K, WOB=1.4K, ROP=80. 19:27 20:30 1.05 9,590 9,590 PROD1 DRILL WPRT P Wiper to window, PUW=35K, RBIH. 20:30 22:30 2.00 9,590 9,790 PROD1 DRILL DRLG P DOBD: 1.37 BPM @ 4,505 PSI, BHP=4,250 PSI, CTW=7.5K, WOB=1.0K, ROP=100. 22:30 00:00 1.50 9,790 9,450 PROD1 DRILL WPRT P Wiper up hole for tie in, pump sweeps, PUW 36k,jet liner, RBIH, plus 4-ft correction. Start pumping new mud system. 04/12/2015 Drill ahead B lateral from 9,790'to called early TD @ 10,327.Wiper trip to swab,jet 4.5"tubing at 30 fpm. Reset depth, start RBIH corrected TD. 00:00 00:21 0.35 9,450 9,790 PROD1 DRILL WPRT P Continue RBIH after tie-in wiper. New _ mud around. 00:21 02:30 2.15 9,790 9,990 PROD1 DRILL DRLG P DOBD: 1.40 BPM @ 4,420 PSI, BHP=4,280 PSI, CTW=6.2K, WOB=1.3K, ROP=95. 02:30 03:39 1.15 9,990 9,990 PROD1 DRILL WPRT P Wiper to window, PUW=36.5K, RBIH. 03:39 06:48 3.15 9,990 10,119 PROD1 DRILL DRLG P DOBD: 1.40 BPM @ 4,380 PSI, BHP=4,250 PSI, CTW=5.5K, WOB=1.4K, ROP=90,weight transfer problems starting at 10,060-ft,work to 10,119-ft after a couple BHA wipers, several pick ups, all PUWs 34k and clean. 06:48 07:21 0.55 10,119 9,000 PROD1 DRILL WPRT P 10,119-ft, Wiper up hole, PUW 34k. 07:21 07:51 0.50 9,000 10,119 PROD1 DRILL WPRT P 9,000-ft, Wiper back in hole, RIW 10k. 07:51 09:39 1.80 10,119 10,221 PROD1 DRILL DRLG P 10,119-ft OBD 1.4 bpm at 4,364 psi, BHP 4,295 psi, CWT 3.0k,WOB 1.6k, ROP 70, IA 413, OA 0, negitive 5k CWT,WOB .3k, no motor work 09:39 13:06 3.45 10,221 10,221 PROD1 DRILL WPRT P Early wiper up hole for tie in, pump sweeps, PUW 34k,jet liner at full rate, RBIH, plus 3.5-ft correction at RA, RIW 10k. Page 24 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:06 16:21 3.25 10,221 10,321 PROD1 DRILL DRLG P 10,221-ft, OBD 1.36 bpm at 4,401 psi, BHP 4,326 psi, CWT 7.2k, WOB 1.4k, ROP 70, IA 362, OA 0. Lost push, retry six times, loosing WOB. Continue drilling, restart several times. 16:21 16:51 0.50 10,321 10,321 PROD1 DRILL WPRT P 500'wiper trip, PUW=35K, RBIH. 16:51 17:06 0.25 10,321 10,327 PROD1 DRILL DRLG P Drill ahead same parameters, no string weight or WOB. 17:06 17:42 0.60 10,327 9,050 PROD1 DRILL WPRT P Another wiper to window, PUW=35K. Town decided to call TD @ 10,327'. 17:42 22:57 5.25 9,050 76 PROD1 DRILL WPRT P Wiper to top 3.5"liner @ 7,732'.Jet 4.5"tubing max rate at 30 fpm to swab. 22:57 00:00 1.05 76 4,895 PROD1 DRILL TRIP P Reset depth. RBIH for corrected TD. 04/13/2015 Tag corrected TD @ 10,328'. POOH laying in completion fluids, flow check. LD BHA#35. PU/MU liner assembly, MU BHA. RIH w/BHA#36 B lateral liner assembly, set liner @ 10,327', TOL @ 8,770'. POOH, LD BHA#36. Start BOP test, in progress. 00:00 02:30 2.50 4,895 10,328 PROD1 DRILL TRIP P Continue in hole for corrected TD, tie-in to K1 for+5'correction,tag TD @ 10,328'. PUH,start pumping beaded pill. 02:30 05:39 3.15 10,328 73 PROD1 DRILL DISP P POOH laying in liner pill/completion fluid 05:39 06:15 0.60 73 73 PROD1 DRILL OWFF P Monitor well for flow. 06:15 07:00 0.75 73 0 PROD1 DRILL PULD P PJSM-LD BHA#35, bit 2-1-BT-N-X-I-BU-TD 07:00 10:15 3.25 0 1,456 COMPZ CASING PUTB P PJSM-Prep floors for running liner, MU bullnose,XO,45 jts of 2 3/8" slotted,XO, 3 pup jts, aluminum liner top billet, LD liner running equipment. 10:15 11:33 1.30 1,456 1,501 COMPZ CASING PULD P PJSM-MU Liner assembly to BHA #36, CoilTrak, surface test. 11:33 14:27 2.90 1,501 10,327 COMPZ CASING RUNL P RIH with 2 3/8"slotted liner assembly on BHA#36 pumping minimum rate, plus 1.3-ft at flag, PUW 36k, continue in hole pumps off. 14:27 14:39 0.20 10,327 8,870 COMPZ CASING RUNL P On depth, PUW 39k,stack 5k, on line 1.4 bpm, PUW 36k, no differance in WOB wieght, on line 1.4 bpm, RBIH and stack 5k at at 10,224-ft, PUW 36k, 2k WOB change, liner released, correct counter to BHA depth. 14:39 16:48 2.15 8,870 44 COMPZ CASING TRIP P TOOH, Tie in to RA, plus 2-ft correction,top of liner at 8,870-ft, continue out of hole. 16:48 17:18 0.50 44 44 COMPZ CASING OWFF P Monitor well for flow, PJSM-LD of BHA. 17:18 18:18 1.00 44 0 COMPZ CASING PULD P LD BHA#36 Page 25 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:18 22:00 3.70 0 0 PROD2 WHDBO RURD P PJSM-Prep for BOPE test. Flush stack, PT inner reel valve and pack-offs. Grease tree valves and stack. 22:00 00:00 2.00 0 0 PROD2 WHDBO BOPE P Start BOP test, 250/4,900 psi, annular 2,500 psi.Test waived by AOGCC(Jeff Jones)@ 05:40 on 04-13-15. 04/14/2015 Complete BOP test, Kick off of billet at 8865ft, and drill ahead to 9233ft. 00:00 05:30 5.50 0 0 PROD2 WHDBO BOPE P Complete BOP test 250/4,900 psi, annular 2,500 psi. Teat waived by AOGCC(Jeff Jones)at 05:40 on 04-13-15. 05:30 06:15 0.75 0 0 PROD2 STK DISP P Displace coil back to KWF. 06:15 07:30 1.25 0 72 PROD2 STK PULD P PJSM. MU BHA#37, MU to Coil Trak, surface test. 07:30 08:51 1.35 72 7,610 PROD2 STK TRIP P RIH with BHA#37, 0.8 AKO motor and HYC Bi-center bit pumping _ drilling fluid minimum rate. 08:51 09:30 0.65 7,610 7,630 PROD2 STK DLOG P Tie in to K1, plus 4-ft correction, PUW 35k,continue up to prime pump#2. RBIH 09:30 11:12 1.70 8,867 7,720 PROD2 STK DISP P 8,867-ft, Dry tag billet, PUH displaceing out completion fluid to 10 ppg drilling fluid, PUW 32k. 11:12 11:21 0.15 7,720 7,710 PROD2 STK CIRC P Perform choke calibration, 1.45 bpm at 4,075 psi,WH 340 psi, BHP 3,880 psi, EDC 11.9. 11:21 11:54 0.55 7,710 8,866 PROD2 STK TRIP P Continue in hole 11:54 14:51 2.95 8,866 8,895 PROD2 STK KOST P 8,866.4-ft,Tag top of billet, PUW 37k, begin time milling off billet 1.44 bpm at 4,167 psi, BHP 4,025, CWT 11.4k,WOB 1.8k, IA 10, OA O. 14:51 15:15 0.40 8,895 8,895 PROD2 STK KOST P 8,895-ft, Pick up hole to drift billet, PUW 36k to 8,855-ft, RBIH,dry drift, clean down through billet. 15:15 20:00 4.75 8,895 9,090 PROD2 DRILL DRLG P 8„895-ft, OBD 1.44 bpm at 4,180 psi, BHP 4,048 psi, CWT 10.4k, WOB 1.6k, ROP 40, IA 51, OA O. 20:00 21:00 1.00 9,090 9,090 PROD2 DRILL WPRT P 9090ft,Wiper up hole 8050ft, PUW 35k 21:00 23:00 2.00 9,090 9,290 PROD2 DRILL DRLG P 9090ft, BOBD 1.45 bpm at 4140 psi, BHP 4057,WHP 319, IA 211, OA 0 23:00 23:30 0.50 9,290 9,290 PROD2 DRILL WPRT P 9290ft,Wiper up hole to 8290ft, PUW 35k 23:30 00:00 0.50 9,290 9,322 PROD2 DRILL DRLG P 9290ft, BOBD 1.45 bpm at 4000 psi, _ BHP 4043,WHP 300, IA 205, OA 0 04/15/2015 Drilled ahead from 9233ft to 10220ft 00:00 02:00 2.00 9,322 9,490 PROD2 DRILL DRLG P 9233ft, OBD 1.40 bpm at 4291 psi, BHP 4079,WHP 305, IA 249, OA 0, 1.7k WOB, ROP 77 fph. 02:00 02:48 0.80 9,490 7,880 PROD2 DRILL WPRT P 9490ft,Wiper up hole to 7875ft, PUW 34k 02:48 03:03 0.25 7,880 7,895 PROD2 DRILL DLOG P 7880ft,tie into the RA marker correction of plus 5.0ft. Page 26 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:03 03:48 0.75 7,895 9,490 PROD2 DRILL WPRT P 7895ft,Wiper back in hole to bottom. RIW 14k 03:48 05:57 2.15 9,490 9,690 PROD2 DRILL DRLG P 9490ft, BOBD 1.4 bpm at 4030 psi, BHP 4030,WHP 248, IA 249, OA 0 05:57 07:06 1.15 9,690 9,690 PROD2 DRILL WPRT P 9,690-ft,Wiper up hole to 8,490ft, PUW 34k, RBIH. 07:06 09:36 2.50 9,690 9,890 PROD2 DRILL DRLG P 9,690-ft, OBD 1.43 bpm at 4,226 psi, BHP 4,088 psi,WHP 257, CWT 8.2k,WOB 1.6k, ROP 80, IA 339, OA 0. Note: Mud swap with new mud at bit at 9,800-ft. 09:36 10:33 0.95 9,890 9,890 PROD2 DRILL WPRT P 9,890-ft,Wiper up hole to 8,990ft, PUW 34k, RBIH. 10:33 12:18 1.75 9,890 10,021 PROD2 DRILL DRLG P 9,890-ft, OBD 1.42 bpm at 4,144 psi, BHP 4,085 psi,WHP 361, CWT 8.1k,WOB 1.4k, ROP 60, IA 374, OA 0.attempt to get more WOB for drillers directional help, CWT Ok, WOB 2k, pull early wiper, getting a lot of aluminum in cuttings samples from 9,500-ft. 12:18 14:39 2.35 10,021 3,952 PROD2 DRILL WPRT P 10,021-ft, Early wiper for tie in and hole cleaning, PUW 33k, pull up into liner, open EDC,wiper up 1.74 bpm at 4,175 psi, 60 fpm, 2 bottoms up, more sand than aluminum in cuttings. 14:39 16:36 1.95 3,952 10,021 PROD2 DRILL WPRT P 3,952-ft, Wiper back in hole, close EDC,weight check 34k,sat down at 7,854-ft, PU 35k, RBIH 20 fph, clean thru billet, tie in to RA, plus 5-ft correction, continue in hole RIW 12k 16:36 20:06 3.50 10,021 10,220 PROD2 DRILL DRLG P 10,021-ft, OBD 1.43 bpm at 4,363 psi, BHP 4,098 psi,WHP 338, CWT 3.2k,WOB 1.8k, ROP 100, IA 302, OA O. 20:06 21:06 1.00 10,220 7,955 PROD2 DRILL WPRT P 10220ft,Wiper up hole to 7955ft, PUW 33k 21:06 21:36 0.50 7,955 8,700 PROD2 DRILL WPRT P 7955ft, RBIH to TOB, pump 10x10 sweep ****Note: TD was called per JB and Geo's. 10220ftMD unconfirmed. 21:36 00:00 2.40 8,700 4,896 PROD2 DRILL WPRT P 8700ft, Continue wiper up hole, POOH at 30 fpm pump max rate 1.47 bpm at 4212 psi 34/16/2015 Drilled BL1 lateral to TD 10220ft, performed swab wiper, confirmed TD, POOH, MU slotted liner completion with 46 jts of slotted liner with Open Hole Anchored Billet. 00:00 01:00 1.00 4,896 244 PROD2 DRILL WPRT P Continue swab wiper up hole 01:00 01:15 0.25 244 550 PROD2 DRILL WPRT P Perform Jog RIH at 120 fpm 244ft- 550ft Page 27 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:30 0.25 550 72 PROD2 DRILL WPRT P Continue swab wiper up hole to tag up. """"Note: Seen increase in cuttings/MW out at shaker after performing jog. 01:30 02:51 1.35 72 7,610 PROD2 DRILL TRIP P Reset counters, RBIH 02:51 03:06 0.25 7,610 7,629 PROD2 DRILL DLOG P 7610ft,tie into the K1 marker correction of plus 4.5ft 03:06 04:06 1.00 7,629 10,220 PROD2 DRILL TRIP P Continue RIH to confirm TD 10220ft. 04:06 07:51 3.75 10,220 71 PROD2 DRILL DISP P POOH laying in 12.0 ppg completion fluid with beads up to the window. 07:51 08:21 0.50 71 71 PROD2 DRILL OWFF P Monitor well for flow. PJSM-LD BHA 08:21 09:00 0.65 71 0 PROD2 DRILL PULD P LD BHA#37, bit 1-1-BU-G-X-I-NO-TD 09:00 11:30 2.50 0 1,459 COMPZ CASING PUTB P PJSM-prep floors, MU bull nose, XO,45 jts slotted,XO, 3 pup jts, OH anchored billet, LD liner equipment. 11:30 12:30 1.00 1,459 1,520 COMPZ CASING PULD P PJSM-MU BL1 liner assembly to BHA#38, MU to CoilTrak, surface test. 12:30 15:18 2.80 1,520 10,217 COMPZ CASING RUNL P RIH with BL1 liner assembly on BHA #38, EDC open,tie in at flag plus .7-ft, continue in hole 15:18 15:30 0.20 10,217 8,757 COMPZ CASING RUNL P 10,217-ft, Tag up, PUW 39k, on depth, release off liner at 3,400 psi, PUW 36k, reset counters to BHA depth 15:30 17:15 1.75 8,757 61 COMPZ CASING TRIP P 8,757-ft, POOH for kick off assembly. 17:15 18:00 0.75 61 61 COMPZ CASING OWFF P Monitor well for flow, crew change out. 18:00 19:00 1.00 61 0 COMPZ CASING PULD P LD Liner setting tools, load out BOT tools. 19:00 20:00 1.00 0 72 PROD3 STK PULD P MU kickoff/drilling BHA#39 20:00 21:15 1.25 72 7,610 PROD3 STK TRIP P RIH, BHA#39 with rebuilt Hughes bi-center bit 21:15 21:30 0.25 7,610 7,629 PROD3 STK DLOG P 7610ft,tie into the K1 marker correction of plus 4.0ft,WC 21:30 22:00 0.50 7,629 8,740 PROD3 STK TRIP P 7629ft, Continue RIH through window to TOB, 22:00 00:00 2.00 8,740 8,740 PROD3 STK DISP P Displace well to drilling fluid 34/17/2015 MU kickoff/drilling BHA#39, kickoff at 8758ft, drilled ahead BL2 lateral to 9672ft 00:00 00:30 0.50 8,740 8,758 PROD3 STK TRIP P Finished displacing well to drilling fluid, continue tripping in hole to tag billet. """"Note: Tag TOB at 8758ft 00:30 02:30 2.00 8,758 8,761 PROD3 STK KOST P Start time milling off billet, 1.41 bpm at 4100 psi, BHP 4043,WHP 350, IA 134, OA 0 02:30 04:00 1.50 8,761 8,800 PROD3 DRILL DRLG P Drill ahead 1.4 bpm at 4252 psi, BHP 4044,WHP 351, IA 134, OA 0 Page 28 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 8,800 8,800 PROD3 DRILL WPRT P 8800ft,Wiper up past billet to 8670ft clean, PUW 33k 04:15 06:45 2.50 8,800 8,970 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4130 psi, BHP 4047,WHP 337, IA 155, OA 0 06:45 08:15 1.50 8,970 8,970 PROD3 DRILL WPRT P Wiper trip from 8970'to 7880' 08:15 11:50 3.59 8,970 9,170 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4434 psi, BHP 4028,WHP 297, IA 213, OA 0. Averaging approximately 2k lbs WOB&40 ft/hr ROP. 11:50 12:54 1.08 9,170 9,170 PROD3 DRILL WPRT P Wiper trip from 9170'to 8168'. PUW at 9170'=35k lb. 12:54 15:43 2.83 9,170 9,370 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4240 psi, BHP 4045,WHP 290, IA 280, OA 0. 15:43 17:18 1.59 9,370 9,370 PROD3 DRILL WPRT P Wiper trip from 9370'to 7896'. Tie in to RA tag in whipstock. +3.5'. PUW at 9370'=35k lb. 17:18 20:51 3.56 9,370 9,570 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4294 psi, BHP 4052,WHP 265, IA 306, OA 0. 20:51 22:06 1.25 9,570 9,570 PROD3 DRILL WPRT P 9570ft,wiper up hole to 8840ft, PUW 36k 22:06 23:57 1.85 9,570 9,672 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4170 psi, BHP 4081,WHP 270, IA 386, OA 0 04/18/2015 Drilled ahead BL2 lateral,from 9672ft to 10138ft. 00:00 00:45 0.75 9,672 9,770 PROD3 DRILL DRLG P OBD 1.40 bpm at 4112 psi, BHP 4084,WHP 278, IA 407, OA 0 00:45 02:00 1.25 9,770 9,770 PROD3 DRILL WPRT P 9770ft,Wiper up hole to 8875ft, PUW 35k 02:00 09:00 7.00 9,770 9,916 PROD3 DRILL DRLG P BOBD 1.40 bpm at 4100 psi, BHP 4090,WHP 279, IA 409, OA 0, Mud swap, new mud at the bit at 9907'.Wait until-5 bbls of new mud is around the bit and PU for short wiper trip to 9824'. PUW=33k lb. Then BOBD. Experiencing some low ROPs. 09:00 12:00 3.00 9,916 9,916 PROD3 DRILL WPRT P Pump-10 bbls high vis sweep. When it reaches bit, start wiper trip from 9916'to surface. PUW at 9916'=33k lb. 12:00 15:19 3.33 9,916 9,916 PROD3 DRILL WPRT P At approx 150',jog back down to 500'. Saw an increase in the cuttings return-aluminum and rock. Tie in to K1 marker on way back to bottom: +4.5 correction. 15:19 21:34 6.25 9,916 10,120 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4200 psi, BHP 4095,WHP 328, IA 214, OA 0. 21:34 22:34 1.00 10,120 10,120 PROD3 DRILL WPRT P 10120ft,wiper up hole to 8855ft, PUW 31k 1 22:34 23:59 1.42 10,120 10,138 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4120 psi, BHP 4116,WHP 373, IA 408, OA 0 04/19/2015 Drilled ahead BL2 lateral from 10138ft to TD 10141ft, perform swab wiper, confirm TD 10141, POOH, MU BL2 liner completion with 73 jts of slotted liner,displace well to seawater Page 29 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 10,138 10,141 PROD3 DRILL DRLG P 10138ft, OBD 1.41 bpm at 4224, BHP 4116,WHP 371, IA 406, OA 0, ROP 3-15 fph, DHWOB 750 lbs, CSW- 10k 01:00 04:30 3.50 10,141 72 PROD3 DRILL WPRT P 10140ft, TD was called due to lockup. Pump 10x10 sweep, pull swab wiper. 04:30 06:00 1.51 72 7,610 PROD3 DRILL TRIP P Rezero counters, RBIH 06:00 06:09 0.15 7,610 7,610 PROD3 DRILL DLOG P Tie into the K1 marker correction of plus 3.5 06:09 07:18 1.15 7,610 10,141 PROD3 DRILL DLOG P RIH to tag bottom at 10,141' 07:18 11:27 4.15 10,141 72 PROD3 DRILL DISP P POOH laying in liner running pill(12 ppg NaBr with beads)and completion fluid(12 ppg NaBr). PUW @ 10,130'=29k lb. Paint EOP flags at 7772'bit depth/7670' EOP and at 5072'bit depth/5000' EOP. 11:27 11:57 0.50 72 72 PROD3 DRILL OWFF P At surface. Perform no flow test. 11:57 13:44 1.79 72 0 PROD3 DRILL PULD P Lay down drilling BHA#39. Bit condition: 3-1-BT-N-X-I-PN-TD 13:44 19:44 6.00 0 2,315 COMPZ CASING PUTB P PJSM for running liner. MU and run non-ported bull nose, Hyd511 x STL XO, 58 jts 2 3/8"4.6#L-80, Hyd511 slotted liner, STL x Hyd511 XO, 15 jts 2 3/8"4.6#L-80 STL slotted liner, and shorty deployment sleeve. 19:44 20:59 1.25 2,315 5,000 COMPZ CASING RUNL P RIH,with BL2 liner assembly 20:59 21:59 1.00 5,000 10,141 COMPZ CASING RUNL P No correction at the flag, Continue RIHTB 21:59 22:14 0.25 10,141 10,141 COMPZ CASING RUNL P 10141ft, set down on bottom, PUW 35.5k, Set back down 5k, bring pump up, release from liner, PUW 29k 22:14 22:59 0.75 10,141 10,141 COMPZ CASING TRIP P 10141ft, reset counters to BOT GS, line up sea water down the coil. 22:59 23:59 1.00 10,141 4,006 COMPZ CASING DISP P POOH,displacing well to sea water 04/20/2015 Freeze protect well from 2500ft, set BPV, FTP 1135psi, RDMO to 2K-pad Well 15 00:00 00:45 0.75 4,006 2,500 COMPZ CASING DISP P 4006ft, continue POOH while displacing well to sea water. 00:45 01:45 1.00 2,500 2,500 COMPZ CASING SFTY P PJSM,with Little Red, RU, PT line to 3500 psi, freeze protect well from 2500ft. 01:45 02:30 0.75 2,500 44 COMPZ CASING TRIP P POOH, puming pipe displacemet 02:30 04:00 1.50 44 0 COMPZ CASING PULD P PJSM, undeploy and LD liner running tools """"Note: FTP 1140 psi 04:00 07:30 3.50 0 0 DEMOB WHDBO NUND P PJSM, MU nozzle to circulate inhibitor through surface equipment. Pumped 37 bbls freshwater followed corrosion inhibitor. Blow down surface lines and reel. Page 30 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:30 2.00 0 0 DEMOB WHDBO MPSP P PJSM-Lubricate in BPV, off load FMC equipment. 09:30 12:00 2.50 0 0 DEMOB WHDBO NUND P Nipple down BOPE. Trucks on location PJSM for RDMO of well. """"Note Rig Released 1200 noon Page 31 of 31 Cement Detail Report 30-16 ConocoPhillips Ess String: 4 1/2" liner Job: RECOMPLETION, 12/11/2014 09:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 4 1/2"liner 1/10/2015 00:00 1/11/2015 00:00 30-16A Comment Cement 4 1/2"liner assembly for upcoming CTD from 7947'-7707'. Pumped 5bbls fresh, mud flush 15 bbls. pumped 15 bbls of 15.8#G neat cement, 5 bbls fresh,dropped plug displaced with 60 bbls of 12.2#mud. Set packer and hanger assembly @ 4300 psi against cement plug. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? 4.5 liner Cement in Liner 7,707.0 7,947.0 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) 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) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/13/2015 ,;ii,0. Cement Detail Report 0 30-16 ConocoPhillips String: CMT SQUEEZE Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name CMT SQUEEZE 7/9/2013 00:00 30-16A Comment CEMENT SQUEEZE PLUG INTO THE PERFS. PUMPED/BULLHEADED THE FOLLOWING DOWN THE TBG. 10.5#PPG INHIBITED BRINE, 68 BBLS FOR WELL KILL&STEP RATE INJECTION,5 BBLS WATER SPACER, 17 BBLS OF 15.8 CLASS G CEMENT Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? CMT PLUG 7,790.0 8,200.0 Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl!... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment CEMENT SQUEEZE PLUG INTO THE PERFS. PUMPED/BULLHEADED THE FOLLOWING DOWN THE TBG. 10.5#PPG INHIBITED BRINE,68 BBLS FOR WELL KILL&STEP RATE INJECTION,5 BBLS WATER SPACER, 17 BBLS OF 15.8 CLASS G CEMENT Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) 'Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/13/2015 Cement Detail Report 0 4 30-16 ConocoPhillips Akxka String: Production Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 30-16A Comment Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Production Casing 0.0 8,201.0 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) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/13/2015 �Pa Cement Detail Report ►fit �s 30-16 ConocoPhitlips String: Surface Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 30-16A Comment Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 0.0 2,375.0 Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/13/2015 IP W MI i`W? 4Z m N el I ci C ^ i 0 a. as 0 w W W a H ,, Q Cl) Z > . a C/1 I- .- - IMMO .- s •- = _c co a EQ. Ig cc; 0") U o > to _ — O + ' + _ 0 .. • L. Y N C 0 c� N C 0 to N `= L 2. 2. - U0 C (a a) C. a O Y Y 2 2 m 0 , all (lt .73 Lig mo 1 1 CO _ O _ Ihr � • rN O "' l'N r N Q 0 ON .4- iC aO I� d a7 _ O 0O 2 0 N N (0 C Nr CO 1 51 e V 'adLL , u.ic KM. V Q a U c 0 10 1.0 f � vN 2dd O NO E NOy e 2 -cr op NON > E- G y al ? a J 77 N wC ( I ; w 0) 3 , p O c J JC c P a1 C Q E... O a ¢ a w co co G O O CO CO O N a) a I N 0 0 = a 02• CO a,• 2 E M 6 D a H 'E.: 0 � o J. o U 'a a + 0) - 2 o i C O) c C >a) 0 0 2 c 0 c O d co co r- .a W d v .0 (n (A _ a O `')0 v = 0 a) . 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Y Q 'C , 7N ^ o, o O O N co N Q -r, a. m d O N N {Aa M d d Q„ 0 2 2 m CO O 0 CO Ca CO CO CO (7 O O2 VO) C ,l a — .— v .0 U Y Y O O O £ - 0) 0 ° 2 ! fro 0- V 0 0 0 co 0 0 0) O n u 0 C >. V 0) 0) 0) 0) of 0) 0 0 LI £• O .'. d d N Letter of Transmittal RECEIVED BAKER Date: D DATA LOGGEApril 27, 2015 APR 2 8 2015 DATA iv1OGGE . K.BENDER HUGHES AOGCC To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 30-16BPB1 30-16BPB2 30-16B 215-057 25729 30-16B PB1 215-057 25730 30-16B 30-16B PB2 215-057 25731 30-16BL1 30-16BL1 215-030 25732 30-16BL2 30-16BL2 215-031 25733 (5) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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AOGCC M.K.BENDER To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 07-Apr-15 30-16B 1 Report / CD 50-029-21796-01 2) •Signed : fs/..l�c.7.GNz„`1,� 6"�� Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFiles\Templates\Distnbunon\TransmittalSheets\ConocoPhdhps_Transmit docx Pry Loepp, Victoria T (DOA) From: Burke, Jason <Jason.Burke@conocophillips.com> Sent: Friday, March 27, 2015 4:50 PM To: Loepp, Victoria T (DOA) Cc: Eller, J Gary; Gantt, Lamar L; Herring, Keith E; Ohlinger,James J; Phillips, Ron L; Pohler, Cody J; Starck, Kai;Venhaus, Dan E Subject: 30-16B Plug back(215-057) Follow Up Flag: Follow up Flag Status: Flagged Victoria, While drilling the 30-16B sidetrack we encountered faulting that put us into unstable geology. We have been unable to maintain this section of the well and as a result will not be able to get liner down. We will be plugging back this sidetrack by milling a new window in our newly set 3.5" liner at 8667' MD. This will result in a 30-16B PB2. We will be continuing to drill the 30-16B sidetrack to planned TD at 10650'. Please let me know if you have any questions. Jason ConocoPhillips Jason Burke CTD Engineer- Greater Xuparuk Area 700 G St#12149 .Ancl1 orage,i4X 99501 (0):(907)-265-6097 (M):(9o7)-231-4568 Jason.Burke@conocophillips.com 1 p-D I,5-' -05-7' 30-16B Proposed CTD Sidetrack Modified by JAB 3-30-15 16"62#H-40 4-1/2"12.6#L-80 IBT-Mod tubing to surface shoe©115' MD Ill L.""---- 5-1/2"MetalSkin 7"casing patch 16.98#(1015-1125) 9-5/8"36#J- 55 shoe @ 2375'MD 4-1/2"X-nipple @-7636'MD(3.813"min ID) 5"Bullet Seal Assembly @ 7685'MD 5"x7"2-RH ZAP Liner top packer @ 7687'MD 5"Flex Lock Hanger©7707'MD ii m 3-1/2",8.2 ppf,L-80 cemented liner top aat 7726'MD. Shoe 8900'MD C-sand perfs(sqz'd) Ii 7794'-7804'MD c._ n 30-18BPB2:8670'-9191'. 3-1/2"liner 5: "": down to 8900' b• N CTD KOP at 7775'MD via 4 Qyy' 4W monobore WS 30-168L1 lateral(A3 sand) 3-1/2"mono-bore whip- TD @ 10650'MD Mit- ....... Billet @ 8750 MD stock @ 8670' 2-3/8"slotted liners FISH:Starburst tray at 7796'MD E: ' 4111, — — _ WSRBB packer at 7829'MD , i ',, / — —I PBTD=7872'MD ■ ❑ f,' /.. -. _-_ 30-168(A2 sand) '<i, '//— _ — — — TD @ 10650'MD A-sand pens _ + \___,...74 Billet @ 8925'MD 7838'-7859'MD(reperld) 4 ..:15--,— \ - 7867'-7872'MD(repert'd) 8889,. 7872'-7889'MD(sqz'd) _— f88 ` 7908'-7928'MD(sqz'd) ° cUo 4 1 30-16B12 lateral(Al sand) �a� � 1 TD@10650'MD ° 88888(' .I 30-16BPB1:8185-8922'. 2 Joints of 2- Liner top @ 8800'MD . uca000 7/8"solid liner below billet,failed billet ne000 iasmoeoe ;I below the liner :oe���o°o�41a. ,0000000no o,l ,noonnn000 ,on000 a 7"26#J-55 shoe �;$o����°i;i�s6';I ©7222'MD :co°O o cMI: A'' of T;c Alaska Oil and Gas �w _ STATEALASh:A i'lt>F - 333 West Seventh Avenue ' - ., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ,.. Main: 907.279.1433 �FALAS�� Fax: 907.276.7542 www.aogcc.alaska gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-16B ConocoPhillips Alaska, Inc. Permit No: 215-057 Surface Location: 1106' FNL, 2060' FWL, SEC. 22, T13N, R9E, UM Bottomhole Location: 249' FNL, 2421' FEL, SEC. 28, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. With the approval of Permit to Drill (PTD) No. 215-057 for the drilling of KRU 30-16B, any production from lateral wells KRU 30-16BL1 (PTD 215-030) and KRU 30-16BL2 (PTD 215- 031) shall be reported as a function of the wellbore KRU 30-16B, API number 50-029-21796- 02-00 and PTD 215-057. 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, /77,6+11----,-- Cathy P. Foerster Chair DATED this 24ay of March, 2015. RECEIVED ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 8 2015 PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work 1 b Proposed Well Class Development-Oil ❑ Service-Winj ❑ Single Zone E, 1c Specify if well is proposed for Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill M • Reentry[I Exploratory ❑ Service-WAG ❑✓ •Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name 5. Bond ,,U Blanket U Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. . Bond No. 59-52-180 • KRU 30-16B ,, 3.Address 6.Proposed Depth 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10650' • TVD: 6433' ' Kuparuk River Field , 4a Location of Well(Governmental Section) 7.Property Designation(Lease Number): Surface: 1106'FNL,2060'FWL,Sec.22,T13N,R9E, UM ' ADL 25513,25520 • Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit 13 Approximate Spud Date 1890'FSL, 1048'FEL, Sec 21,T13N, R9E, UM 2554,2556 3/18/2015 Total Depth: 9 Acres in Property 14.Distance to 249'FNL,2421'FEL,Sec.28,T13N,R9E, UM 5120 • Nearest Property 7100 4b.Location of Well(State Base Plane Coordinates-NAD 27). 10 KB Elevation above MSL: • 59 feet 15 Distance to Nearest Well Open Surface:x- 525698 y- 6021714 Zone- 4 GL Elevation above MSL 24 feet to Same Pool: 3N-13,1253 16 Deviated wells Kickoff depth •7775 ft.' 17 Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle , 99° deg Downhole:5300 psig ' Surface:4651 psig v 18 Casing Pro•ram Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 4.25" 3.5" 9 2# L-80 Hydril 511 1065' 7750' 6354' 8815' 6495' 10 bbls Class G cement 3" 2.375" 4.7# L-80 ST-L 1725' 8925' 6478' 10650' 6429' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft) Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 8351' 6901' 7827 8115 6709' none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 175 sx AS I 115' 115' Surface 2340' 9.625" 900 sx AS III,300 sx AS II, 2375' 2215' 100 sx AS I Liner 8168' 7" 700 sx TLW,300 sx Class G,175 sx 8201' 6778' Liner 238' 4.5" liner 7945' 6571' Perforation Depth MD(ft): Perforation Depth TVD(ft): 7838-7859,7867-7872 I 6444-6452,6480-6498 20 Attachments Property Plal❑ BOP Sketch ❑ Drilling Progran- ❑ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 MC 25 050 requirements Q 21 Verbal Approval Commission Representative. Date 3 Ik0 I15 22 I hereby certify that the foregoing is true and correct Contact Gary Eller @ 265-6097 Email J.Ga .Eller co .co Printed Name D. Ven aus Title CTD Engineering Supervisor Signature 1 �i •4---- Phone:263-4372 Date 3-1 3 p - (5 Commission Use Only Permit to Drill API Number: Permit A5JclLf al See cover letter Number 5— o7 50- Co - r 7_96-OZ—O0 Date. ' 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: 121 Other: j30p rT7 /- /„ % y OL-c.-. , Samples req'd: Yes IJ No ❑✓g Mud log req'd: Yes❑ No[,� /�,i i/a ,pi(-.7/,, ( / - " fir--' / HiS measures: Yes No ❑ Directional svy req'd: Yes No❑ 4, , j f f ,,tr, `r'+-'//'�'-%'f�'� '— Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes No[, ' 1,---,w , u�"-r rr /rr t,//jr'r' ,n1Tc t7.:t-7 , Approved by C� `7(p•l;v} /�f/ - COMMISSIONER COMMISSION Date: - Z // -1 S Form 10-401 ( vised 10/2012) This APPROVED BY THE j ei�lip fir k i iothslfrom the date of approval(20 AAC 25.005(g)) f(<.1 4I0I I i -- ,/n.„/e-- ConocoPhillips RECEIVED ED Alaska MAR 1 S 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC March 17, 2015 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. submits a sundry application to plug KRU 30-16Kfor purposes of redrill. Our original intention was to drill laterals while preserving the 30-16A mother completion, but a mechanical failure has rendered this impossible. The 10-403 application provides detail on the proposed abandonment of 30-16A. Due to spatial limitations, we are unable to satisfy the requirements of 20 AAC 25.112(c)(1), but we believe that the proposed method will effectively satisfy the intent. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to abandon the KTU 30-16A completion in preparation for redrill. Along with the sundry application, ConocoPhillips submits a permit to drill for KRU 30-16B. This permit replaces the previously approved drilling permit for 30-16AL1 (215-029). A revised operations summary is provided that reflects the name change from 30-16AL1 to 30-16B. Attached to this application are the following documents that explain the proposed operations. - Operation summary for plugging of KRU 30-16A - 10-403 Sundry application form for 30-16A - Revised operation summary for PTDs for 30-16B, BL1, and BL2 - 10-401 Permit to drill for KRU 30-16B - Proposed CTD schematic If you have any questions or require additional information please contact me at my office 907-265-6097. Sincerely, '‘) J. ,a Iler ConcoP 'IlipsA ka Coile• b g Drilling Engineer Kuparuk CTD Laterals NABOBS ALASKA w l 30-16B, BL1 & BL2 2fICApplication for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 8 Attachment 1: Directional Plans for 30-16B, BL1 & BL2 8 Attachment 2: Current Well Schematic for 30-16A 8 Attachment 3: Proposed Well Schematic for 30-16B, BL1 &BL2 8 Page 1 of 8 Revised: March 17, 2015 PTD 'Application: 30-16B, BL1 & BL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))1 The proposed laterals described in this document 30-16B, BL1 & BL2. These laterals will be classified as "Service- WAG Injection" well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the Al, A2 &A3 sand packages in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 30-16B, BL1 & BL2. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 5000 psi. Using the maximum formation pressure in the area of 5300'psi in the 30-10, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4646 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 30-16A in June 2013 indicated a reservoir pressure of 4095 psi or 12.1 ppg equivalent mud weight. The recent work over done on this well was done with a 12.2 ppg NaBr. The maximum down hole pressure in the 30-16A pattern is at 30-10 with 5300 psi. It is not expected that reservoir pressure as high as 30-10 will be encountered while drilling the 30-16B, BL1 & BL2 because we are drilling away from the 30-10 and the two wells are separated by 2 separate faults. Using the 30-10 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4651- psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed on the 30 pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 30-16B laterals will be drilling into a highly faulted zone directly outside of the mother bore. Managed pressure drilling will be used to reduce this risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 8 Revised: March 17,2015 PTD /Application: 30-16B, BL1 & BL2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3 1/", 9.2#, L-80, Hydril 511 solid 30-16B (first7750' 8815' 6354' 6495' liner; cemented in place with a 6' stage) seal bore deployment sleeve on top. 30-16B (second 8925' 10650' 6478' 6429' 23/8', 4.7#, L-80, ST-L slotted liner; stage) with an aluminum billet on top. 30-16BLI 8885' 10650' 6486' 6413' 2%', 4.7#, L-80, ST-L slotted liner; with an aluminum billet on top. 23/", 4.7#, L-80, ST-L slotted liner; 30-16BL2 8800' 10650' 6436' 6462' with a shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Conn. Top MD Btm Top Btm Burst Collapse (PPOMD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 36' 115' 0' 115' 1640 630 Surface 9-5/8" 36 J-55 BTC 35' 2375' 0' 2214' 3520 2020 Casing 7" 26 L-80 TCII 35' 1056' 0' 1056' 7240 5410 Casing 7" 26 J-55 BTC 1800' 8201' 1756' 6778' 4980 4330 Liner 41/" 11.6 L-80 EUE 7707' 7945' 6309' 6448' 7780 6360 Tubing 41/" 12.6 L-80 IBT-Mod 35' 7707' 0' 6309' 8430 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System / — Window milling operations: Chloride-based Flo-Pro mud (10.0 ppg) — Drilling operations: Chloride-based Flo-Pro mud (10.0 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.5 ppg K-Formate completion fluid in order to provide formation over-balance while running completions. Page 3 of 8 Revised: March 17, 2015 Wzb PTD Application: 30-16B, BL1 & BL2 — Kill Weight fluid: Two wellbores offkill weight fluid will be stored at a central location in the Kuparuk field and accessible for trucking to the rig during CTD operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 12.5 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and the fault blocks being drilled into. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 30-16B Window(7775' MD, 6428' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.1 ppg) 4066 psi 4066 psi Mud Hydrostatic(10.0 ppg) 3360 psi 3360 psi Annular friction (i.e. ECD, 0.050 psi/ft) 391 psi 0 psi Mud + ECD Combined 3751 psi 3360 psi (no choke pressure) (underbalanced (underbalanced —315 psi) —706 psi) at Window(12.5 ppg) 4200 psi 4200 psi Choke Pressure Required to Maintain i arget f3!iP 449 psi 840 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 8 Revised: March 17, 2015 PTD /Application: 30-16B, BL1 & BL2 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 30-16A is a Kuparuk A-sand service well equipped with 4%2"tubing and a 4 %2" liner. Three laterals will be drilled from the mother bore in order to provide injection support to the area. A packer-whipstock was placed in the 4W'liner at the original planned kickoff point of 7815' MD,but due to mechanical problems it is no longer usable. Another whipstock has recently been placed at 7775' MD inside the 4%2"liner. One complication arising from this change in kickoff point is that the original 30-16A wellbore must be abandoned. After kicking off at 7775' MD,a protection hole(4.125")will be drilled from the mother bore for 1000', then the 3'/2"liner will be cemented in place. Cementing this 3'/2"liner will effectively abandon and isolate the 30-16A completion. From there we will pick up 3"tools and drill the `B' sidetrack to a depth of 10,650' in the A2 sand. We will run 2-3/8"slotted liner with an aluminum billet back up to 8925'. We will kick off the BL1 and drill to a depth of 10650' in the A3 sand. We will run 2-3/8"slotted liner with an aluminum billet back up to 8885'. We will kick off the BL2 and drill to a depth of 10650' in the Al sand. We will run 2-3/8" slotted liner with 6' deployment sleeve back up to 8800' MD. Pre-CTD Work • Coil: Perform FCO of old mud left over from RWO • E-line: Perform jewelry log from 7900' —7550' MD. Perforate the A sand from 7908`—7928', 7869`- 7889`&7838`—7860'MD. • Pump: Perform breakdown at 2 BPM. • Slick-line: Run a dummy whip-stock down to 7830' MD,and obtain a SBHP • E-line: Set a 41/2" starburst packer-whip-stock at 7815' MD and 0°HS Rig Work 1. MIRU Nabors CDR2-AC rig using 2%"coil tubing. NU 7-1/16"BOPE,test. 2. 30-16B Sidetrack(A2 sand-Southwest) i. Set replacement whipstock at 7775' MD ii. Mill 3.80"window at 7775' MD iii. Drill 3.74"x 4.13"bi-center lateral to TD of 8815' MD iv. Run 3%"solid liner and cement in place v. Swap over to 2"CT and re-test BOPE vi. Drill 2.74"x 3.00"bi-center lateral to TD of 10650' MD vii. Run 2%"slotted liner with an aluminum billet from TD up to 8925' MD 3. 30-16BL1 Lateral(A3 sand-Southwest) i. Kick off the billet at 8925' ii. Drill 2.74"x 3.00"bi-center lateral to TD of 10650' MD iii. Run 2%" slotted liner with an aluminum billet from TD up to 8885' MD 4. 30-16BL2 Lateral(A3 sand-Southwest) i. Kick off the billet at 8885' ii. Drill 2.74"x 3.00"bi-center lateral to TD of 10650'MD Page 5 of 8 Revised: March 17, 2015 PTD Application: 30-16B, BL1 & BL2 iii. Run 2%"slotted liner with 6' deployment sleeve from TD up to 8800' MD 5. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pu11 BPV 2. Obtain static BHP. 3. MIRU CT and N2 lift well for flow back(less than 30 days) 4. Return to injection Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree, so we will use the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — All the laterals will be displaced to an overbalancing fluid (12.5 ppg K-Formate) prior to running liner. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 8 Revised: March 17, 2015 PTD Application: 30-16B, BL1 & BL2 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. / — Distance to Nearest Property Line (measured to KPA boundary at closest point) _Lateral Name Distance 30-16B 7100' 30-16BL1 7100' 30-16BL2 7100' — Distance to Nearest Well within Pool (measured to offset well) Lateral Name Distance Well 30-16B 728' 30-16 _ 30-16BL1 1253' 3N-13 30-16BL2 1253' 3N-13 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AA C 25.402) 30-16B is within 1/4-mile of the 30-16 well 30-16B, BL1 & BL2 are within 1/4-mile of the 3N-13 well 30-16A (mother bore) Injector • Recently worked over and new 7" 26#casing was run from 1056' to surface and cemented in place with 15 bbl G neat cement • Classified as a "Normal Well" • C-sand perforations (cemented): 7794'-7804' MD • A-sand perforations: Al: 7908`—7928', A2: 7869`—7889'&A3: 7838'—7860`MD • Packer is located at 7687' and 4 '/2" liner below is cemented in place • MetalSkin patch was installed during RWO from 1015' — 1128' and pressure tested to 3500 psi • The cement bond log shows adequate cement as per original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. 30-16 (abandoned well bore), —728' away from B lateral to south • 9-5/8" casing was cemented down to 2375', 900 sks ASIII © 12.1 ppg and 300 sks ASII @ 15.2 ppg • Set a balanced cement plug of 183 sks 15.8 ppg "G" cement from TD of 7980' —7680' MD • Set a balanced cement plug of 194 sks 16.5 ppg "G" cement from 5195'—4900' MD • Well was sidetracked in 1988 from 5100' MD. 3N-13 (injector), —1253' away from 30-16B, BL1 & BL2 lateral to southwest • The 3N-13 is currently injecting into the Kuparuk A&C-sand intervals. • Recently received RWO to fix communication problem, original waiver cancelled • Completed with 7", 26#, J-55 casing • C-sand perforations: Cl: 7485'-7505' MD • A-sand perforations: A3: 7557'-7571' MD, A2: 7580'-7607' MD &A1: 7621'-7654' MD • Packers at 7333', and 7253' MD, for a C-sand Straddle • Classified as a "Normal Well" and passed the last MIT-IA on 9/08/13 • The cement bond log shows adequate cement as per original injection order Page 7 of 8 Revised: March 17, 2015 PTD Application: 30-16B, BL1 & BL2 17. 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D O N V O N Y lJ (uy}jsn 00Z)(+)4uoN/(-)4�nos o 0, ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-16 30-16B Plan: 30-16B_wp08 Standard Planning Report 17 March, 2015 r' u BAKER HUGHES Ird- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16B Design: 30-16B_wp08 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 Site Kuparuk 30 Pad Site Position: Northing: 6,022,094.67 usft Latitude: 700 28'17.333 N From: Map Easting: 525,478.25 usft Longitude: 149°47'30.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.20 ° Well 30-16 Well Position +N/-S 0.00 usft Northing: 6,021,714.15 usft Latitude: 70°28'13.583 N +El-W 0.00 usft Easting: 525,698.17 usft Longitude: 149°47'24.470 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 30-16B Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 2/1/2015 19.01 81.01 57,582 Design 30-16B_wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,700.00 Vertical Section: Depth From(TVD) +1,11S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 225.00 3/17/2015 3:04:40PM Page 2 COMPASS 5000.1 Build 61 VAS ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-168 Design: 30-16B_wp08 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°1100ft) 0100ft) (°) Target 7,700.00 35.82 245.61 6,309.02 -2,269.19 -3,074.62 0.00 0.00 0.00 0.00 7,775.00 35.67 245.45 6,369.89 -2,287.34 -3,114.50 0.24 -0.20 -0.21 -148.14 7,800.00 40.17 245.45 6,389.61 -2,293.72 -3,128.47 18.00 18.00 0.00 0.00 8,016.65 90.00 245.45 6,478.03 -2,372.81 -3,301.61 23.00 23.00 0.00 0.00 8,086.65 92.76 261.32 6,476.33 -2,392.76 -3,368.45 23.00 3.94 22.67 80.00 8,156.65 93.18 266.21 6,472.70 -2,400.36 -3,437.92 7.00 0.60 6.98 85.00 8,375.00 90.31 251.18 6,466.01 -2,443.03 -3,651.30 7.00 -1.31 -6.88 259.50 8,675.00 95.27 230.75 6,451.25 -2,587.55 -3,911.86 7.00 1.65 -6.81 284.00 8,825.00 98.76 220.77 6,432.89 -2,691.23 -4,018.39 7.00 2.33 -6.65 290.00 9,040.00 91.30 207.64 6,413.96 -2,867.93 -4,138.31 7.00 -3.47 -6.11 241.00 9,400.00 91.18 182.43 6,406.05 -3,212.72 -4,230.93 7.00 -0.03 -7.00 270.00 9,550.00 89.25 172.11 6,405.48 -3,362.34 -4,223.79 7.00 -1.28 -6.88 259.50 10,000.00 89.36 203.61 6,411.04 -3,802.49 -4,284.55 7.00 0.02 7.00 90.00 10,175.00 94.13 192.32 6,405.69 -3,968.55 -4,338.42 7.00 2.72 -6.45 293.00 10,305.00 94.40 201.44 6,396.00 -4,092.48 -4,376.02 7.00 0.20 7.02 88.00 10,465.00 93.34 190.26 6,385.16 -4,245.80 -4,419.55 7.00 -0.66 -6.99 265.00 10,650.00 93.26 203.24 6,374.47 -4,422.27 -4,472.66 7.00 -0.05 7.01 90.00 3/17/2015 3:04:40PM Page 3 COMPASS 5000.1 Build 61 ri- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16B Design: 30-16B_wp08 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +El-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 7,700.00 35.82 245.61 6,309.02 -2,269.19 -3,074.62 3,778.64 0.00 0.00 6,019,434.58 522,631.71 TIP 7,775.00 35.67 245.45 6,369.89 -2,287.34 -3,114.50 3,819.67 0.24 -148.14 6,019,416.30 522,591.90 KOP 7,800.00 40.17 245.45 6,389.61 -2,293.72 -3,128.47 3,834.07 18.00 0.00 6,019,409.87 522,577.95 End 18 dls,Start 23 dls 7,900.00 63.17 245.45 6,451.21 -2,326.10 -3,199.34 3,907.08 23.00 0.00 6,019,377.26 522,507.19 8,000.00 86.17 245.45 6,477.47 -2,365.90 -3,286.48 3,996.83 23.00 0.00 6,019,337.16 522,420.20 8,016.65 90.00 245.45 6,478.03 -2,372.81 -3,301.61 4,012.43 23.00 0.00 6,019,330.19 522,405.09 4 8,086.65 92.76 261.32 6,476.33 -2,392.76 -3,368.45 4,073.79 23.00 80.00 6,019,310.01 522,338.33 End 23 dls,Start 7 dls 8,100.00 92.84 262.25 6,475.68 -2,394.67 -3,381.64 4,084.47 7.00 85.00 6,019,308.06 522,325.15 8,156.65 93.18 266.21 6,472.70 -2,400.36 -3,437.92 4,128.29 7.00 85.05 6,019,302.18 522,268.90 6 8,200.00 92.62 263.22 6,470.51 -2,404.34 -3,481.02 4,161.58 7.00 -100.50 6,019,298.04 522,225.81 8,300.00 91.31 256.34 6,467.08 -2,422.07 -3,579.32 4,243.62 7.00 -100.65 6,019,279.98 522,127.59 8,375.00 90.31 251.18 6,466.01 -2,443.03 -3,651.30 4,309.34 7.00 -100.89 6,019,258.77 522,055.69 7 8,400.00 90.74 249.49 6,465.78 -2,451.44 -3,674.83 4,331.93 7.00 -76.00 6,019,250.28 522,032.19 8,500.00 92.42 242.69 6,463.03 -2,491.94 -3,766.16 4,425.14 7.00 -76.02 6,019,209.48 521,941.01 8,600.00 94.07 235.87 6,457.36 -2,542.90 -3,851.94 4,521.83 7.00 -76.20 6,019,158.22 521,855.42 8,675.00 95.27 230.75 6,451.25 -2,587.55 -3,911.86 4,595.78 7.00 -76.59 6,019,113.37 521,795.65 8 8,700.00 95.86 229.09 6,448.83 -2,603.57 -3,930.90 4,620.56 7.00 -70.00 6,019,097.29 521,776.67 8,800.00 98.20 222.44 6,436.57 -2,672.74 -4,001.97 4,719.74 7.00 -70.16 6,019,027.87 521,705.84 8,825.00 98.76 , 220.77 6,432.89 -2,691.23 -4,018.39 4,744.42 7.00 -70.98 6,019,009.33 521,689.49 9 8,900.00 96.19 216.15 6,423.12 -2,749.45 -4,064.62 4,818.27 7.00 -119.00 6,018,950.96 521,643.47 9,000.00 92.71 210.06 6,415.36 -2,832.91 -4,119.03 4,915.76 7.00 -119.60 6,018,867.32 521,589.35 9,040.00 91.30 207.64 6,413.96 -2,867.93 -4,138.31 4,954.16 7.00 -120.07 6,018,832.24 521,570.19 10 9,100.00 91.30 203.44 6,412.60 -2,922.04 -4,164.17 5,010.70 7.00 -90.00 6,018,778.05 521,544.53 9,200.00 91.28 196.43 6,410.35 -3,015.96 -4,198.23 5,101.21 7.00 -90.10 6,018,684.01 521,510.79 9,300.00 91.24 189.43 6,408.16 -3,113.34 -4,220.60 5,185.88 7.00 -90.25 6,018,586.57 521,488.76 9,400.00 91.18 182.43 6,406.05 -3,212.72 -4,230.93 5,263.45 7.00 -90.41 6,018,487.16 521,478.78 11 9,500.00 89.90 175.55 6,405.11 -3,312.64 -4,229.16 5,332.86 7.00 -100.50 6,018,387.26 521,480.88 9,550.00 89.25 172.11 6,405.48 -3,362.34 -4,223.79 5,364.21 7.00 -100.56 6,018,337.58 521,486.43 12 9,600.00 89.26 175.61 6,406.13 -3,412.04 -4,218.44 5,395.57 7.00 90.00 6,018,287.91 521,491.95 9,700.00 89.27 182.61 6,407.42 -3,511.96 -4,216.89 5,465.12 7.00 89.95 6,018,188.01 521,493.85 9,800.00 89.29 189.61 6,408.68 -3,611.32 -4,227.53 5,542.90 7.00 89.86 6,018,088.62 521,483.55 9,900.00 89.32 196.61 6,409.89 -3,708.65 -4,250.19 5,627.75 7.00 89.78 6,017,991.22 521,461.23 10,000.00 89.36 203.61 6,411.04 -3,802.49 -4,284.55 5,718.40 7.00 89.69 6,017,897.27 521,427.19 13 10,100.00 92.10 197.17 6,409.76 -3,896.15 -4,319.37 5,809.25 7.00 -67.00 6,017,803.50 521,392.71 10,175.00 94.13 192.32 6,405.69 -3,968.55 -4,338.42 5,873.92 7.00 -67.08 6,017,731.04 521,373.90 14 10,200.00 94.19 194.07 6,403.87 -3,992.83 -4,344.11 5,895.11 7.00 88.00 6,017,706.75 521,368.30 10,300.00 94.39 201.09 6,396.38 -4,087.83 -4,374.21 5,983.57 7.00 88.13 6,017,611.65 521,338.53 10,305.00 94.40 201.44 6,396.00 -4,092.48 -4,376.02 5,988.13 7.00 88.65 6,017,607.00 521,336.74 3/17/2015 3:04:40PM Page 4 COMPASS 5000.1 Build 61 ri- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16B Design: 30-16B_wp08 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 15 10,400.00 93.79 194.80 6,389.21 -4,182.48 -4,405.47 6,072.60 7.00 -95.00 6,017,516.90 521,307.60 10,465.00 93.34 190.26 6,385.16 -4,245.80 -4,419.55 6,127.32 7.00 -95.47 6,017,453.55 521,293.74 16 10,500.00 93.34 192.72 6,383.12 -4,280.03 -4,426.51 6,156.45 7.00 90.00 6,017,419.29 521,286.90 10,600.00 93.30 199.73 6,377.33 -4,375.83 -4,454.38 6,243.90 7.00 90.14 6,017,323.41 521,259.36 10,650.00 93.26 203.24 6,374.47 -4,422.27 -4,472.66 6,289.67 7.00 90.55 6,017,276.90 521,241.25 Planned TD at 10650.00 3/17/2015 3:04:40PM Page 5 COMPASS 5000.1 Build 61 Fa" ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16B Design: 30-16B_wp08 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +El-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 30-16AL1_T07 0.00 0.00 6,411.00 -8,000.861,135,859.71 6,017,635.00 1,661,466.00 70°12'49.684 N 140°36'0.764 W -plan misses target center by 1138948.76usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16AL1_T09 0.00 0.00 6,370.00 -8,656.201,135,646.43 6,016,979.00 1,661,255.00 70°12'43.637 N 140°36'9.734 W -plan misses target center by 1138738.96usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16AL1_T01 0.00 0.00 6,402.00 -6,480.641,137,001.08 6,019,159.00 1,662,602.00 70°13'2.755 N 140°35'21.417 W -plan misses target center by 1140083.48usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16AL1_Fault4 0.00 0.00 0.00 -8,780.041,135,598.00 6,016,855.00 1,661,207.00 70°12'42.507 N 140°36'11.662 W -plan misses target center by 1138708.71 usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Rectangle(sides W500.00 H1.00 D0.00) 30-16AL1_Fault3 0.00 0.00 0.00 -8,304.561,135,762.66 6,017,331.00 1,661,370.00 70°12'46.879 N 140°36'4.870 W -plan misses target center by 1138870.74usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Rectangle(sides W340.00 H1.00 D0.00) 30-16AL1_Fault2 0.00 0.00 0.00 -6,851.001,136,223.72 6,018,786.00 1,661,826.00 70°13'0.309 N 140°35 45.314 W -plan misses target center by 1139325.02usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Rectangle(sides W280.00 H1.00 D0.00) 30-16AL1_T05 0.00 0.00 6,426.00 -6,959.701,136,135.34 6,018,677.00 1,661,738.00 70°12'59.385 N 140°35 48.322 W -plan misses target center by 1139219.62usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16AL1_T03 0.00 0.00 6,370.00 -8,656.201,135,646.43 6,016,979.00 1,661,255.00 70°12'43.637 N 140°36'9.734 W -plan misses target center by 1138738.96usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16AL1_T04 0.00 0.00 6,447.00 -6,851.001,136,223.72 6,018,786.00 1,661,826.00 70°13'0.309 N 140°35 45.314 W -plan misses target center by 1139307.56usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16AL1_Fault1 0.00 0.00 0.00 -6,601.571,136,686.63 6,019,037.00 1,662,288.00 70°13'2.046 N 140°35 30.958 W -plan misses target center by 1139786.94usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Rectangle(sides W220.00 H1.00 D0.00) 30-16AL1_T08 0.00 0.00 6,394.00 -8,304.561,135,761.65 6,017,331.00 1,661,369.00 70°12'46.881 N 140°36'4.899 W -plan misses target center by 1138852.27usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16A CTD Polygon 0.00 0.00 0.00 -6,376.381,136,928.43 6,019,263.00 1,662,529.00 70°13'3.874 N 140°35'23.044 W -plan misses target center by 1140027.91 usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Polygon Point 1 0.00 0.00 0.00 6,019,263.00 1,662,529.00 Point2 0.00 -137.88 -334.50 6,019,123.98 1,662,195.01 Point3 0.00 -434.77 -963.58 6,018,824.95 1,661,567.02 Point4 0.00 -903.10 -1,174.19 6,018,355.94 1,661,358.05 Point 5 0.00 -1,403.02 -1,213.90 6,017,855.94 1,661,320.07 Point6 0.00 -1,794.60 -1,350.24 6,017,463.93 1,661,185.10 Point? 0.00 -2,214.26 -1,462.68 6,017,043.92 1,661,074.12 Point 8 0.00 -2,316.26 -1,172.00 6,016,942.94 1,661,365.12 Point 9 0.00 -1,875.75 -1,013.48 6,017,383.95 1,661,522.10 Point 10 0.00 -1,477.09 -901.12 6,017,782.95 1,661,633.07 Point 11 0.00 -991.25 -840.46 6,018,268.95 1,661,692.05 Point 12 0.00 -616.68 -700.17 6,018,643.97 1,661,831.03 Point 13 0.00 -343.13 -265.19 6,018,918.99 1,662,265.02 Point 14 0.00 -202.35 96.32 6,019,061.00 1,662,626.01 Point 15 0.00 0.00 0.00 6,019,263.00 1,662,529.00 30-16AL1 T06 0.00 0.00 6,406.00 -7,427.081,135,940.70 6,018,209.00 1,661,545.00 70°12'55.135 N 140°35'55.939 W 3/17/2015 3:04:40PM Page 6 COMPASS 5000.1 Build 61 r Ird ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16B Design: 30-16B_wp08 -plan misses target center by 1139027.00usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point 30-16AL1_T02 0.00 0.00 6,480.00 -6,534.251,136,884.88 6,019,105.00 1,662,486.00 70°13'2.406 N 140°35 24.982 W -plan misses target center by 1139967.49usft at 7700.00usft MD(6309.02 TVD,-2269.19 N,-3074.62 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,650.00 6,374.47 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 7,700.00 6,309.02 -2,269.19 -3,074.62 TIP 7,775.00 6,369.89 -2,287.34 -3,114.50 KOP 7,800.00 6,389.61 -2,293.72 -3,128.47 End 18 dls,Start 23 dls 8,016.65 6,478.03 -2,372.81 -3,301.61 4 8,086.65 6,476.33 -2,392.76 -3,368.45 End 23 dls,Start 7 dls 8,156.65 6,472.70 -2,400.36 -3,437.92 6 8,375.00 6,466.01 -2,443.03 -3,651.30 7 8,675.00 6,451.25 -2,587.55 -3,911.86 8 8,825.00 6,432.89 -2,691.23 -4,018.39 9 9,040.00 6,413.96 -2,867.93 -4,138.31 10 9,400.00 6,406.05 -3,212.72 -4,230.93 11 9,550.00 6,405.48 -3,362.34 -4,223.79 12 10,000.00 6,411.04 -3,802.49 -4,284.55 13 10,175.00 6,405.69 -3,968.55 -4,338.42 14 10,305.00 6,396.00 -4,092.48 -4,376.02 15 10,465.00 6,385.16 -4,245.80 -4,419.55 16 10,650.00 6,374.47 -4,422.27 -4,472.66 Planned TD at 10650.00 3/17/2015 3:04:40PM Page 7 COMPASS 5000.1 Build 61 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 30 Pad 30-16 30-16B 30-16B_wp08 Travelling Cylinder Report 16 March, 2015 BAKER HUGHES Baker Hughes INTEQ VAT ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-16 Project: Kuparuk River Unit TVD Reference: 30-16A @ 59.00usft(30-16A) Reference Site: Kuparuk 30 Pad MD Reference: 30-16A @ 59.00usft(30-16A) Site Error: 0.00usft North Reference: True Reference Well: 30-16 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 30-166 Database: OAKEDMP2 Reference Design: 30-16B_wp08 Offset TVD Reference: Offset Datum Reference 30-16B_wp08 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.Oousft Error Model: ISCWSA Depth Range: 7,700.00 to 10,650.Oousft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,259.10usft Error Surface: Elliptical Conic Survey Tool Program Date 3/16/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,700.00 30-16A(30-16A) GCT-MS Schlumberger GCT multishot 7,700.00 10,650.00 30-16B_wp08(30-16B) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,650.00 6,433.47 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 30 Pad 30-10-30-10-30-10 Out of range 30-15-30-15-30-15 Out of range 30-16-30-16-30-16 7,717.50 7,800.00 703.24 241.30 463.15 Pass-Major Risk 30-16-30-16A-30-16A 7,775.00 7,775.00 0.00 2.80 -2.75 FAIL-Major Risk 30-16-30-16BL1-30-16BL1_wp02 7,775.00 7,775.00 0.00 1.08 -1.03 FAIL-Minor 1/10 30-16-30-16BL2-30-16BL2_wp02 7,775.00 7,775.00 0.00 1.08 -1.03 FAIL-Minor 1/10 30-17-30-17-30-17 Out of range 30-19-30-19-30-19 Out of range Kuparuk UGNU Plan:UGNU SAGD-UGNU SAGD-UGNU SAGD Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/16/2015 4:29:43PM Page 2 of 11 COMPASS 5000.1 Build 65 Baker Hughes INTEQ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-16 Project: Kuparuk River Unit TVD Reference: 30-16A @ 59.00usft(30-16A) Reference Site: Kuparuk 30 Pad MD Reference: 30-16A @ 59.00usft(30-16A) Site Error: 0.00usft North Reference: True Reference Well: 30-16 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 30-16B Database: OAKEDMP2 Reference Design: 30-16B_wp08 Offset TVD Reference: Offset Datum Reference Depths are relative to 30-16A @ 59.00usft(30-16A) Coordinates are relative to:30-16 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.19° Ladder pry Plot I I 800 I I I I I I I 1 J J J J __ I I ) I �y� I I {. I I C I O I Q J J J J J J a) U) I O I Ea,400— I o O I I a) _J —___J_—__ _J J __ C a) U �yy� LUT I I I I I I I I I I I I J J J J I I I \ t 0 t ` �= I 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND -XF 30-16,30-16,30-16 V1 -8- 30-16,30-16BL1,30-16BL1 wp(QVO -e- 30-16,30-16A,30-16A V1 -A- 30-16,30-16BL2,30-16BL2_wp(QVO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/16/2015 4:29:43PM Page 11 of 11 COMPASS 5000.1 Build 65 • 8 •N 0 •8 . o' a 0 0 ' r r, o Iii> V . W a'N ,c Q L g Ob j O I O m81 T \ O e .0 ra g• g s4g O e $I EE�lA5 ? +q Q N8 % O L' Ifni F.E.'IN 4116,... o m. fl• U' NI,.I1 O 8 j n 0 o c - .n M 0 1 e 0 8 O N 1 o ,v47 7j .$ .o 0.I N m 6 N 0 ° .8 C h m Mo 8 ` tn r° Qo g - O .-o d� ,Q _co' -- _N 00 Fo�O p p p pp . ' 0 _ .O O W .6 O 8 O O O 8 8 8 qX O 8 8 8 8 N 1 '21w m D o g N 'v M M `° q 4 M. 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U N co C n co f`O C n O N M C l')O A z v) (ui/gsn Os)tpdaa IraI aA a►ui V Bettis, Patricia K (DOA) I% From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Monday, February 23, 2015 4:03 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 30-16AL1, 30-16AL1-01, 30-16-AL1-02: Permit to Drill Application Patricia Sorry for the delayed response, I was out of the office quite sporadically last week. This well will not be pre-produced and the KWF will be at least 12.2 ppg. Jason ConocoPhillips Jason Burke CT17 Engineer - Greater Xuparuk area 700 G St#1210 .Anchorage, AX 99501 (0): (907)-265-6097 01): (907)-231-4568 Jason.BurkePconocophillips.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, February 23, 2015 1:43 PM To: Burke, Jason Subject: [EXTERNAL]FW: KRU 30-16AL1, 30-16AL1-01, 30-16-AL1-02: Permit to Drill Application Good afternoon Jason, Did you receive my email of last Wednesday? Thanks, Patricia From: Bettis, Patricia K (DOA) Sent: Wednesday, February 18, 2015 4:39 PM To: Burke, Jason (Jason.BurkePconocophillips.com) Subject: KRU 30-16AL1, 30-16AL1-01, 30-16-AL1-02: Permit to Drill Application Good afternoon Jason, Does ConocoPhillips plan to pre-produce any of the KRU 30-16A laterals? On page 4 of the "Application for Permit to drill Document" it states that "two wellbores of kill weight fluid will be available". What would be the weight of the available KWF? Thank you, 1 Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 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. ADDITIONAL TEXT FOR TRANSMITTAL LETTER-- KRU 30-16B With the approval of Permit to Drill No. 215-057 for the drilling of KRU 30-16B, any production from lateral wells KRU 30-16BL1 (PTD No. 215-Wand KRU 30-16BL2 (PTD No. 2153 shall be reported as a function of the wellbore KRU 30-16B,API number 50-029-21796-02-00 and Permit No. 215-057. TRANSMITTAL LETTER CHECKLIST WELL NAME: KAO.. 3 0 — f(o J3 PTD: )5-- oS Development /Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: 4„ } ►VE POOL: gy44.7L, kA (46, wx f q v4 v Q; Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. 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