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215-224
j STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Rill Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing 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 ' Exploratory r 215-224-0 _ 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50-029-21664-62 7.Property Designation(Lease Number): 8.Well Name and Number: ADL25512 KRU 3Q-13L1-02 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 10552 feet Plugs(measured) None true vertical 6238 feet Junk(measured) None Effective Depth measured 10552 feet Packer(measured) 7566 true vertical 6238 feet (true vertical) 6114 Casing Length Size MD TVD Burst Collapse L1-02 SLOTTED LINER 2810' 2 3/8 10552' 6247' sektit ttiAX 0 22.017, RECOVED Perforation depth: Measured depth: 7742-10552 True Vertical Depth: 6248-6238 SEP 13 .20/ AOGCTubing(size,grade,MD,and TVD) 3 1/2 ,L-80,7681 MD,6200 TVD C Packers&SSSV(type,MD,and TVD) SSSV=None PACKER=BAKER 7"26#F-1 PACKER @ 7566 MD and 6114 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 156 1221 694 1050 185 Subsequent to operation 0 0 4514 550 1096 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development r Service 1 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 Pr GINJ r SUSP r SPLUG r- 17. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-419 Contact Darrell Humphrey/Bob Christensen Email: n1139(p7conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date .....4...vsrit..4 12sk.k........,e_1/4....ci V`Tt- !o/ /6 f- jo/a 7/,6 Form 10-404 Revised 5/2015 RBDMS 1,V 5e, 1 3 2016 Submit Original Only I • • 3Q-13L1-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/03/16 Well converted to injection and brought online KUP PROD 3Q-13L1-02 ConocoPhillips ' Well Attributes Max Angle&MD TD sk Alaa.inn y Wellbore API/UWI Field Name Wellbore Status not(°) MD(ftKB) Act She(0KB) 500292166462 KUPARUK RIVER UNIT PROD 96.77 8,785.24 10,552.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) 1 Rig Release Date 30-13L1-02,2/420169:16:04 AM SSSV: NONE Last WO: 42.511 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:ADD LATERALS;GLV 0/0 lehalif 2/4/2016 HANGER;34.0..........._..... ell;fill Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L1-02 SLOTTED LINER 2 3/8 1.992 7,742 2 10,552.0 6,238.3 4.60 L-80 ST-L I Liner Details Nominal ID Top(ftKB) Top(TOD)(ftKB) Top Incl(1) Item Des Corn (in) at 7,742.2 6,246.5 41.43 DEPLOY Shorty Deployment Sleeve 1.920 Perforations&Slots Shot Den Top(TVD) atm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com CONDUCTOR;30.0.115.0 . 7,743.0 10,546.0 6,247.1 6,238.1 A-1,3Q-13 1/20/2016 SLOTS Notes:General&Safety End Date Annotation NOTE GAS LIFT;2 690 8 OSTV Tubing Shut OH;3,509.3 y;ut 9 I SURFACE;3T0-4,325.3 GAS LIFT;4,323.6 GAS LIFT;5,551.5-1 GAS LIFT;6,401.9 GAS LIFT;7,062.6 GAS LIFT,7,502 4 LOCATOR;7,563.2 IIM 1.1PACKER;7,565.7 SEAL ASSY;7,564.0 PBR;7,569.1 -e,. NIPPLE;7,606.1 X0 Enlarging;7,680.5 Liner;7,681.2 - Liter;7,725.6 ^4) APERF;7,743.0-7,755.0y: PRODUCTION;34.0.8,168.8 ass— SLOTS;7,743.0-10,5460 .. Lt-02 SLOTTED LINER;7,742.2 I -10,552.0 • • tiOF Tit • 4,40.I//7:.5A THE STATE Alaska Oil and Gas -5117� of®® TTSKA Conservation Commission 1�L 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *' Main: 907.279.1433 LAS� Fax: 907.276.7542 AL www.aogcc.alaska.gov Darrell Humphrey sQi , NSK Production Engineering Specialist SCO j° ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 q ^ Re: Kuparuk River Field, Kuparuk River Oil Pool, KRIJ 3=Q-13L1-02 Permit to Drill Number: 215-224 Sundry Number: 316-422 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, fil 1° 0-444.711 - Cathy 6. Foerster Chair DATED this /clay of August, 2016. RBDMS v✓ AUG 1 6 2016 � GMED • STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 1 2016 APPLICATION FOR SUNDRY APPROVALS /L 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdow n Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG Fi • 2.Operator Name: 4.Current Well Class: ; 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory Development raj' 215-224-0 ' 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21664-62' 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No Fr, KRU 3Q-13L1-02 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25512 Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10552 6238 10552' 6238' 3000 None None Casing Length Size MD TVD Burst Collapse L1-02 SLOTTED LINER 2810' 2 3/8 10552' 6247' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7742-10552 • 6248-6238 3 1/2 L-80 7681 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=None MD=0 TVD=0 PACKER=BAKER 7"26#F-1 PACKER MD=7566 TVD=6114 12.Attachments: Proposal Summary Fr, WellBore Schematic p 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch r Exploratory r Stratigraphic r Development r Service ' i 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 09/10/16 OIL rWINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG - GSTOR r SPLUG r Commission Representative: GINJ Op Shutdown Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Phone:659-7535 Email: n1139@conocophillips.com Title: NSK Production Engineering Specialist Signature _..,..........A Date: . 3, Signature . i 44� Com ission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 2—2— Rug Integrity r BOP Test 1 Mechanical Integrity Test Location Clearance r Other: c Post Initial Injection MIT Req'd? Yes No r�,/ 6 �I('f)L Spacing Exception Required? Yes r No I/ Subsequent Form Required: ( 9— 4 U 4 APPROVED S 8'l 6 —` Y Approved by: P% COMMISSIONER THE COMMISSION Date: 9Ka sl ally VTC g //5-/IL /✓ p��/^�p� At /C �('�// Submit Form and Form 10-403 Revised 11/2015 V c IpBaliN1aIit4 Adror 12 months from the date of approval. Attachments in Duplicate V LL RBDMS V/ AUG 1 6 2016 • • 3Q-13L1-02 • • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3Q-13 and it's associated laterals L1, L1- 01, L1-02 (PTD# 186-176, 215-221, 215-223, 215-224) from Oil Production service to Water Alternating Gas Injection service as the production period for this well has been completed. Area of Review: Kuparuk well 3Q-13 and it's associated laterals was completed as an injector on 7/25/16 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 3Q-07, 3Q-09 and 3Q-11. The top of the A sand was found at 9115' and/6275'tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that with the exception of the offset producers 3Q-07 and 3M-13, there are no additional production/injection wells are located within a 1/4 mile radius of the 3Q-13, 3Q-13L1, 3Q-13L1-01, 3Q-13L1-02 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3Q-13 and it associated laterals is good and is classified as a"CTD horizontal tri-lateral"well. The injection tubing/casing annulus is isolated via a Baker 7"26# F-1 packer located at 7565' and (6114'tvd). A State-witnessed MIT-IA will be performed once well 3Q-13 and it's associated laterals are converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (6450' -8169' and/5287' -6567'tvd) to insure injection zone conformance. The CBL interpretation was completed on the PTD's. The 16" Conductor was cemented with 1875# Polyset. The 9-5/8" Surface casing was cemented with 1200sx ASIII and 300sx Class G. The 7" Intermediate casing was cemented with 300sx Class G and 175sx AS1. Pe rv,--1 z d ccs w x- 17 � nJ c c �d � gi,(/)- kci /4 i o o g -o . 8 2 a FT a r € < < < E E Ul UI ob V � U U U O� M O u m m • 2 m c rt ro2 at a0 n O n ry o o 2 o m o E E E Yeo c oL o of o oL o m o p 00 00 0 o a+J p o c m e c 0 O O O O � m u u u •_ c w e 8 ° c 4 c 4 QJ o.; � G2 7, 6 09 -o w d• a a s a s Z i c a Ea c o E u m 3 4o v ✓ d uC ry o v P O • O W Q C E G O `o`. n -,c°1 'o_ n S a °o O 0. C O Q C 711 .63 o d n m m m H O S' c m 0 0 0 a ;11 N z a m F' d N 0 o q N o c 0 0 a o o o • • 0 • otos to ° a a a a p U a a To F F ti o ti 2 n 55E2 ❑ 781 L r Q O \ _ in F F n o n e Z E a ¢ a E 0 oa p 0 0 0 V m M m G @, 2 @) 6 n � O - ° E o 0 0 o c _ _ a' o oa '"' o u« u$u $ o m o m O 91 8 u u u 2 8 o'$ wt o c o i 2 E. o v °w o G 't.I > 't v a E: $ et) d 4 I E u u u `o `w c •r o En u>p>°C. n ry m co LV F ct Q E 'IN c m n 5 O N S m A G V a- d G n G F 6 a it 'c o N a o n ca m `o n° n I 'o 'o 'o � 6 6 a 2 g cA &M El, 'o 'a E 0 p O 6 b •S . 29Jul16 • ConocoPhillips Alaska, Inc. Injection Swap Analysis N 3Q-13 et al 0 0.08 0.16 0.24 0.32 Miles 3Q 0 17 T ' I • / ADL025512 3Q-13 1 / 3Q-13 L1 PB1 ADL0255'3 3Q-07 lit/ jo,, , 3Q 13L1 13Q-13L1-01 3Q-13L1-02 3M-1'3.- 3Q-22 3Q-13 Open Interval rl 1/4 Mi. Radius 3Q-13 3Q-13L1 Open Interval 1/4 Mi. Radius 3Q-13L1 —3Q-13L1PB1 Open Interval❑ 1/4 Mi. Radius 3Q-13L1PB1 ADL025520 -- 3Q-13L1-01 Open Interval 0 1/4 Mi. Radius 3Q-13L1-01 _025521 3Q-13L1-02 Open Interval 0 1/4 Mi. Radius 3Q-13L1-02 Well Within Radius Well Pad --R/-7V1V-cS J067\i/ • • 09Aug16 ConocoPhillips Alaska, Inc. Injection Swap Analysis N 3Q-13 et al 0 0.08 0.16 0. 0.32 Miles 3Q 0 17 T : • J //L025512 3Q-13 '/ 3Q-13LI PBI ADL0255'3 / 3Q-07 ;> N 21 _i 1 llw 19 -13L1 3Q-13L1-01 3Q-13L1-02 3M-1'3 —3Q-13 Open Interval ❑ 1/4 Mi. Radius 3Q-13 3Q-13L1 Open Interval 1/4 Mi. Radius 3Q-13L1 —3Q-13L1 PB1 Open Interval ❑ 1/4 Mi. Radius 3Q-13L1PB1 ADL025520 —3Q-13L1-01 Open Interval 0 1/4 Mi. Radius 3Q-13L1-01 .025521 --3Q-13L1-02 Open Interval 0 1/4 Mi. Radius 3Q-13L1-02 ®Well Within Radius 4 Well Pad KUP PROD 3Q-13L1-02 ConocoPhillips Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) aurcoPNCiFs 500292166462 KUPARUK RIVER UNIT PROD 96.77 8,785.24 10,552.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13L1-02.2/420169'16',04 AM SSSV:NONE Last WO: 42.51 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _... ...... .... IT ` ._... Last Tag: Rev Reason:ADD LATERALS;GLV C/O lehallf 2/4/2016 HANGER 34.0 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB( Set Depth(TVD)... WULen(I...Grade Top Thread L1-02 SLOTTED LINER 2 3/8 1.992 7,742.2 10,552.0 6,238.3 4.60 L-80 ST-L Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(') Item Des Com (in) 7,742.2 6,246.5 41.43 DEPLOY Shorty Deployment Sleeve 1.920 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com CONDUCTOR,3e.0a150 €I 7,743.0 10,546.0 6,247.1 6,238.1 A-1,3Q-13 1/20/2016 SLOTS Notes;General&Safety End Date Annotation NOTE: GAS LIFT 2690.8 — OSN Tubing Shut Off,3509.3 f:. SURFACE;37.0-4.325.3 GAS LIFT;4.323 6 GAS LIFT;5,551 5 " GAS LIFT;6.401.9 GAS LIFT,7.062.6 GAS LIFT;7502.4 I LOCATOR;7 563 2 a PACKER;7,565.7 SEAL ASSY,,7,564 01 PBR,7569.1 1 a NIPPLE,7,606.1 XO Enlarging 7680.5 Liner,7.681.2 Liner;7725 -_ APER F;7,743 0-7755 0 PRODUCTION;340-8,168.8 SLOTS;77430-10,546.0— L1-02 SLOTTED LINER,7,742.2 I , -10.552.0 • • o1 .o o { o ry v' ' J J . m m • a a ' ❑ N O o j .� N N (N ~ •C O Z N O O O O7 m oa m m (6 . O co m D. N .4 a) a) J J c J J c N a) C 9css }I IIS N 7 coco M C_ C (n C_ C_ (/) = 7 J 'O LL it (0 it it (0 Co > G F- H H 0 0 c D L N 0Li.' in 0 N N LO LO N LO LO W W LL fn N N Z Z E N N N N N N N N N N Z OO O n n C O O O O O O O O O O Q a) > > a) J J J J J J �p iiiJ J a. a. 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IJ" N U zz_ Y y m jp rN < (I) 0 Ct Q c O y N a E a J W = a a O U W 0z U ° o Q r2 cn J Q m O- (0 o en E o 0 O E U N N O r; c CJ r M, J J M _U H s- IIIP 5 Z 0 G W a'• r D N Q f0 a a Q D o Y Iii Q ° a z E Q E U R z d • CO M N CO N > m N 1- '6 LW N 3 N N N Q in ce N in V O o c U EE Q a D 2 U RECEIVE 1 J 4 4 j L 1 � v 2 1 5 2 2 4 - - 6 19 �'%�'� FEB 12201ii 26 8 1 7 26 8 1 8 2 26 820 BAKER PRINT DISTRIBUTION LIST HUMORS A3.0 Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED WELL NAME 3Q-13L1; L1-01;L1-02; L1PB1 700 G Street. rt M..K.BBENDG ENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska LOG DATE January 19,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.RiderAbakerhughes.com TODAYS DATE February 10,2016 Revision STATUS Final Replacement: No Details: Requested by: -_- COMPANY FIELD FINAL CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX CDLOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #Ul-PION I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope ( 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I I 0 I 0 I 0 I Attn:Lynda M.Yaskell and/or Leonardo Elias 1 3201 C Street,Suite 505 ,Anchorage,AK 99503 4 State of Alaska -AOGCC 1 I I 1 ,Attn:Makana Bender 333 W.7th Ave,Suite 100 ,Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 I 1 I 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 I 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • 0 c) c., c4 (' 1 LO00 Lo <-4 mi MI Z MS. logo 1 gi 0 446 ..:...., 0: JmC. 712J E8 C NW I'L 1Z1 Cr CN1 0- Z I . 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N.: U 0 o 0 ,..., 6 U)C , 0 e 'D l; 2 o co 0 zs L.) , z = o co Cs/ ,.. $ 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil E, Gas❑ SPLUG El Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development E✓ , Exploratory E GINJ ❑ WINJ ❑ WAGE WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test E 2.Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. , Aband.: 1/20/2016 215-224 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510 1/16/2016 50-029-21664-62 , 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2283'FNL, 2037'FEL, Sec. 17,T13N, R9E, UM 1/20/2016 3Q-13L1-02 Top of Productive Interval: 9. Ref Elevations: KB: 60' 17. Field/Pool(s): 727' FNL, 3563' FEL,Sec 20,T13N, R9E, UM GL: 42' BF: 42' • Kuparuk River Field/Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3015'FNL, 5072'FEL, Sec 20,T13N, R9E, UM N/A ADL 25512 - 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 516300 y- 6025789 Zone- 4 10,552'MD/6,238'TVD ALK 2553 TPI: x- 514794 y- 6022062 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 513297 y- 6019772 Zone- 4 N/A 1658'MD/1604'TVD 5. Directional or Inclination Survey: Yes (attached) No D 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 8,755'MD/6,291'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 1 CEIVE GR/RES FEB 10 2016 nktf)GCO 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 38 115 38 115 24" 1875#Polyset 9-5/8" 36 J-55 37 4325 37 3713 12-1/4" 1200 sx ASIII&300 sx Class G 7" 26 J-55 34 8168 34 6567 8-1/2" 300 sx Class G&175 sx ASI 5-1/2" 14 H-40 7681 7768 6200 6234 N/A KO joint 2-3/8" 4.6 L-80 7742 10552 6248 6238 3.0" Slotted Liner 24.Open to production or injection? Yes 7 No ❑ 25.TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 7681' 7565'MD/6114'TVD Slotted Liner from 7742'-10552'MD/6248'-6238'TVD :OMPLETION 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE Was hydraulic fracturing used during completion? Yes D No E l Izc' Per 20 AAC 25.283(1)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Lt- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift,etc.): 1,- 2/1/2016 Gas Lifted Date of Test: Hours Tes ed: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/3/2016 1/7 0 4Nli' Test Period -73 281 752 176/176 3861 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 287 1171 24-Hour Rate 230 887 2376 21.7 Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 RBDMS Ll_ FFR 1 U 7f' ,bmit ORIGINIAL onl 28. CORE DATA Conventional es): Yes ❑ No 0 Sidewall Core(es ❑ No 0 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 Li No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1658' 1604' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 7745' 6249' information, including reports, per 20 AAC 25.071. lop Kuparuk A3 9115' D Kuparuk A3 10552' Formation at total depth: Kuparuk A3 - 31. List of Attachments: 5tiMNA1Rly/ DF Tally °1i 11DI25, V j,vi it' �` e " '' J , Sctfittone. 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@cop.co Printed Name: K.Starck Title: CTD Team Lead Signature: Phone: 263-4093 Date: 2- - � /6 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection, Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only KUPOD 3Q-13 Con©caPhiflips 3 Well Attrib Max Ang D TD Alaska.Inc. w' Wellbore API/UWField Name Wellbore Status ncl(°I MD( ) Act Btm(kKB) Wisps""g^ 500292166400 KUPARUK RIVER UNIT PROD . 44.68 3,100.00 8,190.0 ... Ate.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13,2/9/20162:55:04 PM SSSV:NONE _Last WO: 42.51 12/10/1986 Verocal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,954.0 12/13/2015 Rev Reason:ADD LATERALS; GLV C/O lehallf 2/4/2016 HANGER 34.0 kill __-- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... W6Len IL..Grade Top Thread I CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 Welded Casing Description Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I... Top Thread SURFACE 37.0 4,325.3 36.00 BTC I Top Thread ^/�nu PROD Casing• � ®®' 6 .. 1 • 2.11®BTC TubingComletion StringsDetails Tubing Description String Ma....ID(int Top(ftKB)34.0 I Set Depth 7585(ft.O.J Set Depth(ND)(...Wt(Ib/ft 9.30 GL -80 I TopEUE Connection8rtl TUBING-UPPER 31/2 2.992 6,128.7 WO 2015 CONDUCTOR;38.0-115.0 p Nominal ID Top(kKB) Top(ND)(kKB) Top not C) Item Des Com (in) 34.0 34.0 0.19 HANGER CIW tubing hanger 3.500 GAS LIFT:20900 7,563.2 6,112.5 41.81 LOCATOR Baker GBH-22 locator sub 3.000 7,564.0 6,113.1 41.81 SEAL ASSY Baker GBH-22 Seal assembly W/7 ft out 3.000 Tubing Description l String Ma...ID(in) Top(kKB) Set Depth(ft..Set Depth(ND)(...Wt pb/ft) Grade Top Connection W0ING5 LOWER- 31/2 2.992 7,565.8 7,770.0 6,267.3 9.30 L-80 EUE 8rd aSTVTubing Shut Off,3,5093 r.:1. Completion Details III Nominal ID Top OMB) Top(TVD)(kKB) Top Incl(') Item Des Com (in) I7,565.8 6,114.4 41.80 PACKER Baker 7"26#F-1 Packer 4.600 7,569.1 6,116.8 41.77 PBR Baker 80/40 PBR 3.990 7,606.1 6,144.5 41.54 NIPPLE 3.5 X 2.813 X nipple 2.813 7,680.5 6,200.3 41.45 XO Enlarging 3.5"8rd X 5.5"H-40 Ported sub 2.992 � 7,681.2 6,200.7 41.45 Liner 5.5"X 14#H-40 Wear sox with 5 15/16"wear rings 5.000 SURFACE;37.04,325.3 7,725.6 6,234.0 41.43 Liner 5.5"X 14#H-40 Wear sox with 515/16"wear rings Mule 5.000 GAS LIFT;4,323.8 , shoe g Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 17111 Top(ND) Top 1001 Top(ftKB) (ftKB) (") Des Com Run Sate ID(in) 7,745.0 6,248.6 41.43 WHIPSTOCK BAKER GEN II WHIPSTOCK 2 5/8"X 5.5" 12/30/3015 GAS LIFT;5,551.5 Perforations&Slots Ill Shot Dens Top(ND) Btm(ND) (shots/ Top(kKB) Btm(kKB) (kKB) (kKB) Zone Date k) Type Com GAS LIFT;6,4019 '� 7,743.0 7,755.0 6,247.1 6,256.1 A-3,30-13 8/4/2000 4.0 APERF 21/8"Enerjet;180 deg .. phasing;+/-90 degs f/low side. 7,760.0 7,784.0 6,259.8 6,277.8 A-2,30-13 3/26/2000 4.0 RPERF 21/8"EJ III DP;+/-90 deg orient 7,790.0 7,828.0 6,282.3 6,310.8 A-1,3Q-13 3/26/2000 4.0 RPERF •2 1/8"EJ(8 DP;+/-90 GAS LIFT 7,062.6 deg orient IMandrel Inserts ai N Top(ND) Valve Latch Port Size TRO Run ,� Top(ftKB) (kKB) Make Model OD(in) Sery Type Type tin) (psi) Run Date Com GAS DIET 7562/ 1 2,690-8 2,508.0 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,249.0 1/28/2016 2 4,323.7 3,712.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,247.0 1/28/2016 II3 5,551.5 4,617.7 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 1/28/2016 / DMY RK 0.000 1111/22/2015 LOCATOR;7,563.2 • 16DMY RK 0.000 0.0 015 '1.., Ai:. 6 7,502 4 616DMY RKP 0 000 11 12/10/2015 PACKER;7,585.7 SEAL ASSY;7,564.0, y- PBR;7,568.1 IIII#� Notes:General&Safety Iinriii. • NIPPLE.7.6061 II XO Enlarging;7,680.5 Ai Liner;7,681,2 1 Liner;7,7256 h APERF;7,743.07,755.0I SLOTS;7,743.0-10,546.0 I i L1-02 SLOTTED LINER;7,7422 I 1 l -10,5520 I I RPERF;7,780.0.7,784.0---. I RPERF;7,780.0-7,828.0 . I PRODUCTION;34.0-8,168.8 8 , KUP P OD 3Q-13L1-02 Con©coPhillip Well Attrib Max Ang D TD , ` Wellbore API/UWI Field Name Wellbore Status ncl(°) MD( 1 Act Btm(ftKB) Alaska,Inc, KUPARUK RIVER UNIT PROD 96.77 8,785.24 10,552.0 L....Ph II ps'' 500292166462 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13L1-02,2/9/20162.52.27 PM SSSV: NONE Last WO: 42.51 12/10/1986 Vertical schematic(actual) ADD LATERALS,GLV C/O ILeah'atIMIf'd BY End D274te/2016 HANGER;34.0 !!1',r(,1''4 14`r' 1 asing rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L1-02 SLOTTED0,5521 6 238 3 4.60 80 Liner Details Nominal ID rigs' NMI INI a Top(f6(13) Top(TVD)(ItKB) Top Inc!(1 Item Des Com (in) 7 742 2 6 246 5 41 43 DEPLOY Shorty Deployment Sleeve 1 920 Perforations&Slots snot Dent Top(TVD) Elm(TVD) (shots/ Top(ftKB) Btm(9KB) 1ft6B1 (ftKB) Zone Date ft) Type Com CONDUCTOR;380-115.0 7,743.0 10,546.0 6,247.1 6,238.1 A-1,30-13 1/20/2016 SLOTS Notes:General&Safety End Date Annotation f-. NOTE GAS LIFT;2,&90.8 A OSTV Tubng Shut Off'.3,509.3 Ii ' ,„>F, SURFACE;37 0-4,325.3 111 L GAS LIFT;4,3236 III GAS LIFT;5,551.5 -d. III GAS LIFT;6,401 9 a .11 pi GAS LIFT,7.062.6 'I '- GAS LIFT;7,502.4 d . ,.: LOCATOR;7,553.2 all 00, PACKER;7,565.7 SEAL ASSY'7,584.0-.. PBR;7,569.1 I`=i NIPPLE;7,606.1 I XO Enlarging;7,660.5 Liner,7,621 6 Liner,77256 PI APERF;7,743.0-7,755.0 , , PRODUCTION;34.0-8,166.8 I / -►m one— SLOTS;7,743.0-10,546 0—• L1-02 SLOTTED LINER;7,742.2 -10,552.0 *orations Summary (with Timelog.ths) ps `�` 3Q-13 ConacoPhitlips °: Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/4/2016 1/4/2016 0.50 MIRU MOVE MOB P Prep for rig move to 3Q-pad.Load and 0.0 0.0 00:00 00:30 secure tree.check all tree bolts,and complete RD checklist,Prep shop for move.Prep for sow arrival. 1/4/2016 1/4/2016 2.50 MIRU MOVE MOB P PJSM,with Peak and rig crew.Pull rig 0.0 0.0 00:30 03:00 modules off of 3Q-13,install jeeps, ready to move. 1/4/2016 1/4/2016 2.50 MIRU MOVE MOB P Move rig modules and shop to 3Q-pad 0.0 0.0 03:00 05:30 1/4/2016 1/4/2016 1.50 MIRU MOVE MOB P Remove jeeps,prep well,remove tree 0.0 0.0 05:30 07:00 caps,spot rig modules over well. 1/4/2016 1/4/2016 1.50 MIRU MOVE MOB T Rig won't clear well 22,inform rig prep 0.0 0.0 07:00 08:30 crew,dispatch crane to remove well house on well 14,move well house on 22 over 1 ft. Finish spotting over well 13. 1/4/2016 1/4/2016 3.50 MIRU MOVE MOB P Finish spotting rig modules over well 0.0 08:30 12:00 13. 1/4/2016 1/4/2016 2.50 MIRU MOVE MOB P MIRU,CDR2,RU checklist,check tree 0.0 0.0 12:00 14:30 flange bolts,Work on tree alignment, clean and reinstall drip pan, MU MP and cellar lines. 1/4/2016 1/4/2016 1.50 MIRU WHDBOP NUND P ***"Rig Accept: 14:30 hrs on 1/4/16 0.0 14:30 16:00 1/4/2016 1/4/2016 2.00 MIRU WHDBOP NUND P PJSM,Nipple up BOPE stack 0.0 0.0 16:00 18:00 1/4/2016 1/5/2016 6.00 MIRU WHDBOP BOPE P Start full BOPE Test.Test witness by 0.0 0.0 18:00 00:00 Brian Bixby,AOGCC 1/5/2016 1/5/2016 3.50 MIRU WHDBOP BOPE P Continue full BOPE test,3 failures 0.0 0.0 00:00 03:30 Blind Shears,R1 valve,and door seal. Replaced and tested. 1/5/2016 1/5/2016 2.50 MIRU WHDBOP RGRP T Replace BOPE Upper shear seals 0.0 0.0 03:30 06:00 1/5/2016 1/5/2016 1.75 MIRU WHDBOP MPSP P PJSM,with rig and valve shop,load 0.0 0.0 06:00 07:45 lubricator and equipment to rig floor, pulled BPV,LD equipment. 1/5/2016 1/5/2016 4.60 MIRU WHDBOP CTOP P PJSM. Rehead coil and pull test. 0.0 0.0 07:45 12:21 Install UQC,and test. Install nozzle, MU QTS and stab on,fill coil,chase methanol to TT. 1/5/2016 1/5/2016 2.70 MIRU WHDBOP PRTS P PT inner reel iron and pack-offs. Install 0.0 0.0 12:21 15:03 floats and PT.PT PDL's. 1/5/2016 1/5/2016 1.80 MIRU WHDBOP CTOP P PJSM.Make several attempts to 0.0 0.0 15:03 16:51 perform closure test on Baker Orbit valve,able to bleed off wellhead,but will not hold.Perforn Valve alignment and prep for pressure deployment. Orbit valve now holding 1/5/2016 1/5/2016 2.60-PROD1 WHPST PULD P M/U BHA#1 Window milling BHA 0.0 74.3 16:51 19:27 with.6°motor,2.79 String Ramer, 2.80 Dimond window mill,Make up to coil and surface test.Position reel to tighten-inspect inner reel iron.Pump meth out of TT 1/5/2016 1/5/2016 1.80 PROD1 WHPST TRIP P RIH BHA#1 EDC open.Pumping 1 74.3 7,560.0 19:27 21:15 BPM seawater 1/5/2016 1/5/2016 0.30 PROD1 WHPST DLOG P Log K1 for+5.5',PUW=30K 7,560.0 7,598.0 21:15 21:33 Page 1/13 Report Printed: 2/2/2016 g "4; *orations Summary (with Timelogekoths) , 3Q-13 vl Conocoi'himlips htr.Aa Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/5/2016 1/5/2016 0.10 PROD1 WHPST TRIP P Continue in well,dry tag whipstock 7,598.0 7,751.0 21:33 21:39 pinch point @ 7750,PUH 1/5/2016 1/5/2016 1.35 PROD1 WHPST CIRC P Displace system to 9.3PPG used flow 7,751.0 7,751.0 21:39 23:00 pro to mill window. Close EDC 1/5/2016 1/6/2016 1.00 PROD1 WHPST WPST P Bring pumps up to 1.47 BPM.3756 psi 7,751.0 7,751.0 23:00 00:00 FS. Begin milling the window per the program.Motor work=125 psi with 500lbs WOB. 1/6/2016 1/6/2016 11.00 PROD1 WHPST WPST P Continue milling the window per the 7,751.0 7,757.0 00:00 11:00 drilling program.Out of casing© 7,756',continue milling to 7,757'. 1/6/2016 1/6/2016 3.20 PROD1 WHPST WPST P Mill rathole: 1.52 BPM @ 3,730 PSI, 7,757.0 7,770.0 11:00 14:12 BHP=3,840,CTW=8.5K,WOB=2K, ROP=4.Lost pump three times,had to pick-up,PUW=31 K,breaker issue, problem resolved. 1/6/2016 1/6/2016 2.10 PROD1 WHPST REAM P Make back reaming passes as per 7,770.0 7,770.0 14:12 16:18 well plan,dress window.Dry drift, clean.Jet 5.5"BTP. 1/6/2016 1/6/2016 2.70 PROD1 WHPST TRIP P POOH for build assembly.Open EDC 7,770.0 72.0 16:18 19:00 and jet Baker Orbit valve @ 3,509'. Continue out of the hole, Shut Orbit valve,and observe well.Static. 1/6/2016 1/6/2016 0.75 PROD1 WHPST PULD P LD BHA#1. Window mill 2.79"no go. 72.0 0.0 19:00 19:45 1/6/2016 1/6/2016 1.00 PROD1 DRILL PULD P PU build BHA#2,with 2.5°AKO motor 0.0 72.0 19:45 20:45 and HCC 3.25"short shank bit.Hang off in WH. Injector maintenance,check pack-offs. 1/6/2016 1/6/2016 0.50 PROD1 DRILL PULD P MU QC,stab on WH. Test MWD. 72.0 72.0 20:45 21:15 Equalize pressure above the Orbit valve and open. 1/6/2016 1/6/2016 1.75 PROD1 DRILL TRIP P RIH with Build BHA#2. Tie into the 72.0 7,760.0 21:15 23:00 K1 for a+4.5 ft correction.Continue RIH. 1/6/2016 1/6/2016 0.25 PROD1 DRILL TRIP P Set down at 7760 ft. PUH,roll pumps 7,760.0 7,770.0 23:00 23:15 and RBIH.Slight bobble runnig back though. Continue running in the hole. 1/6/2016 1/7/2016 0.75 PROD1 DRILL DRLG P On bottom.Begin drilling build section 7,770.0 7,788.0 23:15 00:00 from 7770 ft to midnight depth of 7788 ft. 1/7/2016 1/7/2016 2.00 PROD1 DRILL DRLG P Continue drilling build section from 7,788.0 7,872.0 00:00 02:00 7788 ft to end of section at 7872 ft. Pumping 1.5 BPM at 2942 psi FS. 3870 psi BHP. 164 psi WHP.Swap mud to 9.5 PPG PWR PRO,New mud @ bit 7793. Ave 43.6°DLS over build interval. 1/7/2016 1/7/2016 2.00 PROD1 DRILL TRIP P POOH with build BHA#2.Cycle orbit 7,872.0 72.0 02:00 04:00 valve closed. Valve appears to be leaking.Cycle valve open and closed again.WHP still increasing. 1/7/2016 1/7/2016 3.00 PROD1 DRILL TRIP T Run back in hole to jet Orbit valve 72.0 4,000.0 04:00 07:00 area through the EDC several times. 1/7/2016 1/7/2016 0.75 PROD1 DRILL TRIP T POOH.Make several attempt for 4,000.0 72.2 07:00 07:45 closure test on Orbit valve,all failed. Page 2/13 Report Printed: 2/2/2016 *orations Summary (with Timelogepths) so- � 4,4i 3Q-13 Conocornillips ;:' Rl:s:ks Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/7/2016 1/7/2016 2.25 PROD1 DRILL PULD P PJSM.PUD BHA#2,make another 72.2 0.0 07:45 10:00 attempt to closure test Orbit valve, failed. 1/7/2016 1/7/2016 1.50 PROD1 DRILL PULD , P PJSM.PD BHA#3,open Orbit valve. 0.0 72.0 10:00 11:30 1/7/2016 1/7/2016 2.50 PROD1 DRILL TRIP P RIH w/lateral drilling assembly,+0.5 72.0 7,872.0 11:30 14:00 AKO HCC bit,tie-in K1 for+2.5' correction,continue in hole,log RA @ 7,752'.Mad pass 7,871'to 7,777'. RBIH. 1/7/2016 1/7/2016 5.00 PROD1 DRILL DRLG P BOBD:1.50 BPM @ 3,290 PSI, 7,872.0 8,180.0 14:00 19:00 BHP=3,900 PSI,CTW=8 klbs- 10.5klbs,WOB=1.5K,ROP=45. 1/7/2016 1/7/2016 1.00 PROD1 DRILL WPRT P Wiper trip to 7800 ft. PUW=31 klbs. 8,180.0 8,180.0 19:00 20:00 1/7/2016 1/8/2016 4.00 PROD1 DRILL DRLG P Back on bottom drilling. 1.6 BPM at 8,180.0 8,445.0 20:00 00:00 3390 psi FS. BHP=3880 psi. 1.5-2 klbs WOB.CTW=8 klbs.ROP=70 fph.At 8350 add.5%776 due to less then exspected surface weight. Observed no appriciable increase in surface weight.No problems with weight transfer 1/8/2016 1/8/2016 6.00 PROD1 DRILL DRLG P Conintue drilling L1 lateral.Pumping 8,445.0 8,580.0 00:00 06:00 1.6 BPM at 3390 psi FS.BHP=3900 psi.CTW=6 klbs,WOB=2-3 klbs. ROP 10-20 fph. 1/8/2016 1/8/2016 0.50 PROD1 DRILL WPRT P Wiper trip to 7,780',PUW=30K,RBIH. 8,580.0 8,580.0 06:00 06:30 1/8/2016 1/8/2016 5.00 PROD1 DRILL DRLG - P BOBD: 1.62 BPM @ 3,610, 8,580.0 8,625.0 06:30 11:30 BHP=3,900,CTW=7K,WOB=1.8K, ROP=10.Drilling for data.Town called,time to plug back,pump sweep. 1/8/2016 1/8/2016 2.25 PROD1 STK TRIP T POOH for plug back assembly,jet 5.5" 8,625.0 72.0 11:30 13:45 BTP,continue OOH.Small jog at surface,more solids in returns, POOH. 1/8/2016 1/8/2016 1.25 PROD1 STK PULD T PJSM.PUD BHA#3 72.0 0.0 13:45 15:00 1/8/2016 1/8/2016 1.50 PROD1 STK PULD T PJSM.MU Anchored billet,PD BHA 0.0 73.5 15:00 16:30 #4 1/8/2016 1/8/2016 2.50 PROD1 STK TRIP T RIH w/OH anchored billet,tie-in at K1 73.5 8,160.0 16:30 19:00 for+2 ft correction. 1/8/2016 1/8/2016 0.25 PROD1 STK WPST T Pick up to set depth.27klbs PUW.Set 8,160.0 8,150.0 19:00 19:15 anchor and release running tool.Top of billet at 8150 ft. 1/8/2016 1/8/2016 2.00 PROD1 STK TRIP T POOH with running tool BHA#4. 8,150.0 72.0 19:15 21:15 Jetted around orbit valve area through EDC before continuing out of the hole. 1/8/2016 1/8/2016 0.25 PROD1 STK TRIP T Closed Orbit valve with 800 psi WHP. 72.0 72.0 21:15 21:30 Bled WHP down to 500 psi and shut in. WHP slowly increasing.Bleed additonal 300 psi and shut in. WHP climbing. Orbit valve not holding pressure. Prepare to PUD. 1/8/2016 1/8/2016 1.50 PROD1 STK PULD T PJSM.PUD running tool BHA#4. 72.0 0.0 21:30 23:00 Page 3/13 Report Printed: 2/2/2016 •erations Summary (with Timelogliksths) i - 3Q-13. A.44-404,„; x Conocanditps , AE.14. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/8/2016 1/9/2016 1.00 PROD1 STK PULD T PJSM.PD lateral BHA#5 with 0.7°+ 0.0 0.0 23:00 00:00 AKO motor and RR HCC 3.25"bit. 1/9/2016 1/9/2016 0.50 PROD1 STK PULD T Finish PD lateral BHA#5.Begin RIH. 0.0 72.0 00:00 00:30 1/9/2016 1/9/2016 1.00 PROD1 STK TRIP T RIH with lateral BHA#5.Tie in to K1 72.0 8,150.0 00:30 01:30 for a+2.5 ft correction.Continue RIH and dry tag billet at 8150.9 ft. 1/9/2016 , 1/9/2016 2.95 PROD1 STK KOST T Time mill off of billet. 1.65 BPM at 8,150.0 7,158.0 01:30 04:27 3508 psi FS.700-1000 lbs WOB.Off billet. 1/9/2016 1/9/2016 1.75 PROD1 DRILL DRLG T Drill ahead. 1.64 BPM @ 3,670, BHP= 7,158.0 8,255.0 04:27 06:12 3910 PSI,CTW=10.5K,WOB=1K, ROP=60. 1/9/2016 1/9/2016 0.25 PROD1 DRILL TRIP T PUW=30K,dry drift billet,billet clean, 8,255.0 8,255.0 06:12 06:27 RBIH. 1/9/2016 1/9/2016 6.75 PROD1 DRILL DRLG T Drill ahead. 1.64 BPM @ 3,652,BHP= 8,255.0 8,560.0 06:27 13:12 3940 PSI,CTW=10.5K,WOB=1K, ROP=30. 1/9/2016 1/9/2016 0.80 PROD1 DRILL WPRT T Wiper trip,PUW=30K,RBIH. 8,560.0 8,560.0 13:12 14:00 1/9/2016 1/9/2016 3.00 PROD1 DRILL DRLG T Drill ahead. 1.64 BPM @ 3,725,BHP= 8,560.0 8,625.0 14:00 17:00 3930 PSI,CTW=7.5K,WOB=1.5K, ROP=35.Off trouble time. 1/9/2016 1/9/2016 3.50 PROD1 DRILL DRLG P Drill ahead.1.64 BPM @ 3,770,BHP= 8,625.0 8,716.0 17:00 20:30 3935 PSI,CTW=8.5K,WOB=1.5K, ROP=30. ROP dropping to<20 fph.Suspect bit balling. Pump 5/10 low/high vis pill followed by 20bbl screenkleen pill. 1/9/2016 1/9/2016 0.25 PROD1 DRILL CIRC P Pick up and work pipe off bottom 8,716.0 8,716.0 20:30 20:45 at1.75 BPM to try and clear bit. 1/9/2016 1/10/2016 3.25 PROD1 DRILL CIRC P Back on bottom drilling.ROP up to 45 8,716.0 8,841.0 20:45 00:00 FPH.Pumping 1.64 GPM at 3553 psi FS.BHP=3930 psi.CTW=9KIbs,WOB =1.5-2KIbs. ROP continues to be variable depending on formation. Note:Choke B showed signs of plugging.Switch to Choke A.Blow down Choke B.:ine back up on Choke B. 1/10/2016 1/10/2016 3.00 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 8,841.0 8,912.0 00:00 03:00 1.68 BPM at 3684 psi FS.BHP=3940 psi.CTW=7 klbs,WOB= 1.7 klbs. ROP between15 fph and 50 fph depending on formation.Start mud swap. 1/10/2016 1/10/2016 0.50 PROD1 DRILL DRLG P Geo wiper to ft. RBIH,new mud at bit 8,912.0 8,912.0 03:00 03:30 at 8912 ft. 1/10/2016 1/10/2016 0.50 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 8,912.0 8,925.0 03:30 04:00 1.7 PM at 3720 psi FS.BHP=3925 psi.CTW=7.8 Klbs,WOB=2 klbs. ROP=80 fph. 1/10/2016 1/10/2016 0.60 PROD1 DRILL WPRT P Choke B appears to have packed off. 8,925.0 8,925.0 04:00 04:36 Trouble shoot same.Pull off bottom to clear, RBIH to pull wiper from 8905 Page 4/13 Report Printed: 2/2/2016 4.-„, ,,,;p-,- Serations Summary (with Timelog.ths) 3Q-13 Conoco`Nhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/10/2016 1/10/2016 2.35 PROD1 DRILL WPRT P 8905, Pull wiper to window, 8,925.0 8,925.0 04:36 06:57 PUW=29K,tie-in for+1'correction, resolve choke issues,recalibrate choke.RBIH. 1/10/2016 1/10/2016 2.50 PROD1 DRILL DRLG P Drill ahead: 1.63 BPM @ 3,650 PSI, 8,925.0 9,075.0 06:57 09:27 BHP=3,950 PSI,CTW=6.5K, WOB=1.7K,ROP=40.Multiple wipers, drilling break,stacking,trouble getting started,increase Safe lube.5%to 1.5%. 1/10/2016 1/10/2016 1.00 PROD1 DRILL WPRT P Wiper to 8,300', PUW=32K,RBIH. 9,075.0 9,075.0 09:27 10:27 Lost 3K CTW through silt zone. 1/10/2016 1/10/2016 6.55 PROD1 DRILL DRLG P Drill ahead: 1.60 BPM @ 3,550 PSI, 9,075.0 9,192.0 10:27 17:00 BHP=3,960 PSI,CTW=-2.5K, WOB=1.5K,ROP=20.Multiple wipers, stacking,weight transfer issues, pumped 5 X5 sweeps couple times, gain additional 50'each time. 1/10/2016 1/10/2016 1.00 PROD1 DRILL WPRT P Wiper to 8,300',PUW=31K,add.5% 9,192.0 9,192.0 17:00 18:00 776 to mud system. CTW down to-5KIbs while tripping back through the lower Al silt. Regained weight after exiting that interval. 1/10/2016 1/10/2016 3.50 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 9,192.0 9,315.0 18:00 21:30 1.67 BPM at 3450 psi FS.CTW 7 Klbs. WOB 1.5 Klbs.ROP variable depending on formation,5-40 fph. 1/10/2016 1/10/2016 0.75 PROD1 DRILL DRLG P Continue drilling L1 lateral. Losing 9,315.0 9,322.0 21:30 22:15 CTW and weight transfer to the bit. Pull 3 BHA wipers in an attempt to make it drill. 1/10/2016 1/11/2016 1.75 PROD1 DRILL WPRT P Made decsion to pull wiper and jet big 9,322.0 9,322.0 22:15 00:00 tail pipe area. Begin wiper trip to 7,690 ft. No overpulls coming up through the lower Al silt.Saw an increase in cuttings from the BTP area. RBIH and tie-in to RA for a+3 ft correction.No drag observed on the way back to bottom.Hole is in good shape. 1/11/2016 1/11/2016 0.25 PROD1 DRILL WPRT P Finish wiper trip. 9,322.0 9,322.0 00:00 00:15 1/11/2016 1/11/2016 3.75 PROD1 DRILL DRLG P BOBD.Pumping 1.62 BPM at 3608 9,322.0 9,520.0 00:15 04:00 psi FS.BHP=3933 psi.CTW=8 Klbs,WOB=1.55 Klbs,ROP=30-60 fph 1/11/2016 1/11/2016 1.00 PROD1 DRILL WPRT P Wiper trip.PUW=29 Klbs.RBIH. 9,520.0 9,520.0 04:00 05:00 1/11/2016 1/11/2016 3.35 PROD1 DRILL DRLG P BOBD. Pumping 1.64 BPM at 3630 9,520.0 9,700.0 05:00 08:21 psi FS.BHP=3985 psi.CTW=2 Klbs,WOB=1.8 Klbs, ROP=60-80 fph.Couple of mini wipers,pump 5 x 5 sweeps,losing weight transfer. 1/11/2016 1/11/2016 2.25 PROD1 DRILL WPRT P Wiper for tie-in, PUW=30K,jet 5.5" 9,700.0 9,700.0 08:21 10:36 BTP,log RA for+2'correction, RBIH. _.1/11/2016 1/11/2016 3.75 PROD1 DRILL DRLG P BOBD.Pumping 1.66 BPM at 3630 9,700.0 9,915.0 10:36 14:21 psi FS.BHP=3975 psi.CTW=4 Klbs,WOB=2.2 Klbs,ROP=60-80 fph,losing weight transfer again. Page 5/13 Report Printed: 2/2/2016 aerations Summary (with TimelogSths) 3Q-13 Ccno PhiIiips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/11/2016 1/11/2016 0.65 PROD1 DRILL WPRT P Wiper to 8,900',PUW=30K,RBIH. 9,915.0 9,915.0 14:21 15:00 1/11/2016 1/11/2016 0.75 PROD1 DRILL DRLG P BOBD.Pumping 1.64 BPM at 3,630 9,915.0 9,985.0 15:00 15:45 psi FS.BHP=3995 psi.CTW=-2 Klbs,WOB=1.7 Klbs,ROP=30.Did not gain much with that wiper,pump sweep,wait on sweep,continue drilling.Mini wiper @ 9,985'. 1/11/2016 1/11/2016 2.00 PROD1 DRILL DRLG P BOBD.Pumping 1.64 BPM at 3,630 9,985.0 9,999.0 15:45 17:45 psi FS.BHP=3995 psi.CTW=-2 Klbs,WOB=1.3 Klbs.Stacking weight.PU and restart.Try reducing pump rate to 1.5 bpm. 1/11/2016 1/11/2016 0.50 PROD1 DRILL CIRC P Pump 5/5 sweep. 9,999.0 9,999.0 17:45 18:15 1/11/2016 1/11/2016 0.75 PROD1 DRILL DRLG P BOBD.Pumping 1.64 BPM at 3,630 9,999.0 10,025.0 18:15 19:00 psi FS.BHP=3995 psi.CTW=-3 Klbs,WOB=1.8 Klbs.Stacking weight.PU and restart.Try reducing pump rate to 1.5 bpm. 1/11/2016 1/11/2016 2.50 PROD1 DRILL WPRT P Pump 5/5 sweep. Wiper trip to the 10,025.0 10,025.0 19:00 21:30 window.Pull into pipe with minimum rate through the window.Jet BTP. RBIH,tie into RA for+2 ft correction. 1/11/2016 1/12/2016 2.50 PROD1 DRILL DRLG P BOBD.Pumping 1.62 BPM at 3618 10,025.0 10,124.0 21:30 00:00 psi FS.BHP 4000 psi.CTW between- 5 and+3 Klbs.WOB between 0 and 1.9 klbs.Variable ROP. Difficult drilling conditions.Multiple pick ups and mini wipers to try and get drilling and improve weight transfer. Prepare for mud swap. 1/12/2016 1/12/2016 3.00 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 10,124.0 10,180.0 00:00 03:00 1.62 BPM at 3620 psi FS.BHP 3990 psi.CTW between-5 and+3 Klbs. WOB between 0 and 1.9 klbs. Variable ROP. Still having weight transfer issues. New mud at the bit at 10,167 ft (02:15). No improvement in weight transfer. 1/12/2016 1/12/2016 2.00 PROD1 DRILL WPRT P Pull wiper to 8,200 ft.No increase in 10,180.0 10,180.0 03:00 05:00 cutttings. Clean trip in and out of the hole.Hole appears to be in good condition. 1/12/2016 1/12/2016 2.95 PROD1 DRILL DRLG P BOBD:1.63 BPM @ 3,925 PSI, 10,180.0 10,351.0 05:00 07:57 BHP=3,990 PSI,CTW=7K, WOB=1.8K,ROP=70.Lost push. 1/12/2016 1/12/2016 1.50 PROD1 DRILL WPRT P . Wiper to 8,250',PUW=28K,RBIH. 10,351.0 10,351.0 07:57 09:27 1/12/2016 1/12/2016 3.00 PROD1 DRILL DRLG P BOBD.Trouble getting started, 10,351.0 10,450.0 09:27 12:27 several mini wipers,pumped 5 X5 sweeps,stacking ,try reduced pump rate,no luck,perform 500'wiper,no help. 100'in 3 HRS. 1/12/2016 1/12/2016 2.55 PROD1 DRILL WPRT P Wiper to jet BTP,PUW=28K,clean 10,450.0 10,450.0 12:27 15:00 5.5"BTP,log RA tie-in for+2' correction,RBIH. Page 6/13 Report Printed: 2/2/2016 6f )erations Summary (with Timelog•pths) 3Q-13 Cono hiWW ps : .; Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/12/2016 1/12/2016 2.25 PROD1 DRILL DRLG P BOBD: 1.63 BPM @ 3,915 PSI, 10,450.0 10,504.0 15:00 17:15 BHP=4,005 PSI,CTW=2-4K, WOB=1.8K,ROP=70.Start losing weight transfer @ 10,505,pump 10 bbl lube pill,try another 500'wiper, pump 20 lube pill. 1/12/2016 1/12/2016 2.25 PROD1 DRILL DRLG P BOBD.Pumping 1.3 bpm.3066 psi 10,504.0 10,537.0 17:15 19:30 FS.BHP 4000 psi.WOB 2.2 Klbs. Saw brief increase in ROP then began stacking again.Discussion with town.Called TD at 10537 ft. 1/12/2016 1/12/2016 3.00 PROD1 DRILL WPRT P Pump sweeps,begin wiper trip to the 10,537.0 72.0 19:30 22:30 swabs.Open EDC above window.No issues pulling out of the hole.Hole is clean. 1/12/2016 1/13/2016 1.50 PROD1 DRILL WPRT P Tag up.Reset depths.Run back in the 72.0 6,112.0 22:30 00:00 hole. 1/13/2016 1/13/2016 1.50 PROD1 DRILL WPRT P Continue running in the hole.Tie into 6,112.0 10,537.0 00:00 01:30 the K1 for a+5 ft correction.Close EDC above the window.No issues RIH.Hole is in good condition.Tag bottom.Confirm TD at 10,537 ft. 1/13/2016 1/13/2016 3.00 PROD1 DRILL DISP P Pull out of the hole laying in 45 10,537.0 72.0 01:30 04:30 bbls11.8 ppg liner running pill followed by 11.8 ppg NaBr completion fluid. Paint window and TD EOP flags. 1/13/2016 1/13/2016 0.50 PROD1 DRILL OWFF P Flow check 72.0 72.0 04:30 05:00 1/13/2016 1/13/2016 2.50 PROD1 DRILL PULD P PJSM.LD BHA#5,prep floor for 72.0 0.0 05:00 07:30 function test.Function test BOP. 1/13/2016 1/13/2016 4.05 COMPZ1 CASING PUTB P PJSM.MU L1 liner assembly,bull 0.0 1,590.0 07:30 11:33 nose,52 jts slotted,one solid pup,OH anchored billet.MU BHA#6. 1/13/2016 1/13/2016 3.65 COMPZ1 CASING RUNL P RIH w/liner assembly,tie-in flag for 1,590.0 10,536.0 11:33 15:12 -.5 correction,weight above window, PUW=31 K,saw 5K bobble @ 7,782', sounded like injector chain slipped, inspected coil,excessive lube on coil, check pack-offs,replace pack-off, pressure washed chains.Continue in hole,no issues to TD @ 10,536', PUW=33K,set back down,PU to 30K, pressure up 4,200 psi,release from liner,TOL depth @ 9,009',PUW=30K. Reset depth. 1/13/2016 1/13/2016 1.75 COMPZ1 CASING TRIP P POOH for drilling assembly 10,536.0 70.0 15:12 16:57 1/13/2016 1/13/2016 0.55 COMPZ1 CASING OWFF P Flow check. Well is static. 70.0 70.0 16:57 17:30 1/13/2016 1/13/2016 1.00 COMPZ1 CASING PULD P PJSM.LD Liner running BHA#6 70.0 0.0 17:30 18:30 1/13/2016 1/13/2016 1.25 PROD2 STK PULD P PJSM,PU lateral drilling BHA#7 with 0.0 72.0 18:30 19:45 0.7°AKO motor and new HYC 3.25" bit. MU QC.Test MWD,tag,set depth, open EDC and RIH. 1/13/2016 1/13/2016 2.50 PROD2 STK TRIP P RIH with BHA#7.Tie in to K1 for a 72.0 9,010.0 19:45 22:15 +2.5 ft correction.Close EDC.No issues through window. Dry tag billet at 9010 ft. Page 7/13 Report Printed: 2/2/2016 aerations Summary (with Timelogths) * 3Q-13 iWWWps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/13/2016 1/13/2016 0.75 PROD2 STK DISP P Displace 11.8 ppg NaBr completion 9,010.0 9,010.0 22:15 23:00 fluid with 9.5 ppg PowerPro drilling mud. 1/13/2016 1/14/2016 1.00 PROD2 STK KOST P Tag and begin time milling off of billet. 9,010.0 9,010.0 23:00 00:00 Pumping 1.59 BPM at 3761 psi FS. 1/14/2016 1/14/2016 2.00 PROD2 STK KOST P Continue time milling off of billet at 1.5 9,010.0 9,020.0 00:00 02:00 fph,working up to 2 fph.Lost prime on charge pump. PU,regain pump rate, RBIH.1 stall.Restart time milling at 2 fph increasing to 3 fph. Control drill with 1 klbs WOB to 9020 ft. 1/14/2016 1/14/2016 0.75 PROD2 DRILL DRLG P Continue drilling pumping 1.53 BPM at 9,020.0 9,060.0 02:00 02:45 3850 psi FS. 1.5 klbs WOB. 1/14/2016 1/14/2016 0.25 PROD2 DRILL DRLG P Dry drift billet at 25 fpm.Clean.RBIH. 9,060.0 9,060.0 02:45 03:00 - 1/14/2016 1/14/2016 2.50 PROD2 DRILL DRLG P Continue drilling the L1-01 lateral. 9,060.0 9,220.0 03:00 05:30 1.57 BPM at 3580 psi FS. 1.8 klbs WOB.ROP 50-70 fph. 1/14/2016 1/14/2016 1.75 PROD2 DRILL WPRT , P Wiper trip,PUW=29K,RBIH. 9,220.0 9,220.0 05:30 07:15 1/14/2016 1/14/2016 5.90 PROD2 DRILL DRLG P Drill ahead:1.55 BPM @ 3,560 PSI, 9,220.0 9,427.0 07:15 13:09 BHP=3,925 PSI,CTW=10K, WOB=1.5K,ROP=35.Trouble getting bit to drop,several restarts,try back reaming,couple drilling breaks,trying to acquire bottom of Al pay. 1/14/2016 1/14/2016 1.85 PROD2 DRILL WPRT P Wiper for tie-in,PUW=31K,Clean 5.5" 9,427.0 9,427.0 13:09 15:00 BTP,log RA for+1'correction,RBIH. 1/14/2016 1/14/2016 0.50 PROD2 DRILL DRLG P Drill ahead:1.58 BPM @ 3,560 PSI, 9,427.0 9,437.0 15:00 15:30 BHP=3,975 PSI,CTW=10K, WOB=1.8K,ROP=60-90.GEO quit trying to get drop. 1/14/2016 1/14/2016 2.75 PROD2 DRILL DRLG P Drill ahead: 1.58 BPM @ 3,560 PSI, 9,437.0 9,601.0 15:30 18:15 BHP=3,925 PSI,CTW=10K, WOB=1.5K,ROP=35.Starting to stack weight. 1/14/2016 1/14/2016 0.50 PROD2 DRILL WPRT P Pump 5/5 sweep and pull 500 ft wiper 9,601.0 9,601.0 18:15 18:45 to improve weight transfer.Observed increase in cuttings come up with sweep. 1/14/2016 1/14/2016 3.50 PROD2 DRILL DRLG P Drill ahead:1.56 BPM @ 3,495 PSI, 9,601.0 9,753.0 18:45 22:15 BHP=3,950 PSI,CTW=6-10K, WOB=1.5K,ROP=35-40. Erratic ROP.Trouble bringing inclination down. 1/14/2016 1/14/2016 0.75 PROD2 DRILL WPRT P Pull 500 ft wiper.Lost comms with 9,753.0 9,753.0 22:15 23:00 MWD. Reboot MWD system. Continued wiper trip keeping BHA below any jewelry using Academy screen for depth control.No issues with reset.Re-established comms with MWD.RBIH. 1/14/2016 1/15/2016 1.00 PROD2 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,536 PSI, 9,753.0 9,798.0 23:00 00:00 BHP=3,920 PSI,CTW=8.4K, WOB=1.5K,ROP=60 fph. Page 8/13 Report Printed: 2/2/2016 aerations Summary (with Timelogilpths) 3Q-13 7.fsAa Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/15/2016 1/15/2016 0.50 PROD2 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,536 PSI, 9,798.0 9,801.0 00:00 00:30 BHP=3,920 PSI,CTW=1.7K, WOB=2K,ROP=10 fph.Observed increase in vibration. 1/15/2016 1/15/2016 2.00 PROD2 DRILL WPRT P Pull wiper to the BTP and clean out 5- 9,801.0 9,801.0 00:30 02:30 1/2".PUW=35 Klbs.Tie in to the RA for a+2 foot correction and confirmed depth after MWD reboot yesterday. 1/15/2016. 1/15/2016 5.75 PROD2 DRILL DRLG P Drill ahead: 1.54 BPM @ 3,532 PSI, 9,801.0 10,003.0 02:30 08:15 BHP=3,965 PSI,CTW=8K, Vary WOB to try and get BHA to drop. Mini wiper,pump 5 x5 sweeps, BHA wiper,several restarts. 1/15/2016 1/15/2016 0.70 PROD2 DRILL WPRT P Wiper trip to 9,100',PUW=35K,RBIH. 10,003.0 10,003.0 08:15 08:57 1/15/2016 1/15/2016 3.25 PROD2 DRILL DRLG P Drill ahead: 1.55 BPM @ 3,955 PSI, 10,003.0 10,220.0 08:57 12:12 BHP=4,005 PSI,CTW=7K, WOB=1.6K,ROP=60-80.Start pumping new mud system,at bit @ 10,036'. 1/15/2016 1/15/2016 2.20 PROD2 DRILL WPRT P Wiper for tie-in,PUW=30K,clean 5.5" 10,220.0 10,220.0 12:12 14:24 BTP,log RA for+3'correction,RBIH. 1/15/2016 1/15/2016 3.10 PROD2 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,980 PSI, 10,220.0 10,420.0 14:24 17:30 BHP=4,010 PSI,CTW=7.5K, WOB=2K,ROP=70-90. Mini wiper at 10,297 ft. Started stacking weight.Could not restart. Pump 5/5 sweep. 1/15/2016 1/15/2016 0.50 PROD2 DRILL WPRT P Pull 1,000 ft wiper to improve weight 10,420.0 10,420.0 17:30 18:00 transfer.PUW 28Klbs. 1/15/2016 1/15/2016 1.25 PROD2 DRILL DRLG P Drill ahead: 1.54 BPM @ 3,850 PSI, 10,420.0 10,457.0 18:00 19:15 BHP=4,000 PSI,CTW=7K,WOB=2K, ROP=70-90. Attempt to PU and restart.CT would not go up or down.Appears to be differentially stuck.Begin working pipe. 1/15/2016 1/15/2016 1.25 PROD2 DRILL DRLG T Worked pipe up to 42KIbs max.No 10,457.0 10,457.0 19:15 20:30 WOB change.Orients freely.Full returns.Lower annular pressure 150 psi to 11.4 ppgemw.Continue to work pipe with max PU of 52Klbs.Stop pump,relax CT and continue to work pipe with no success. 1/15/2016 1/15/2016 2.50 PROD2 DRILL CIRC T Pump 5/5 sweep and prepare to pump 10,457.0 10,457.0 20:30 23:00 mineral oil pill.Saw an increase in cuttings with 5/5 sweep at surface. Continued to work pipe while loading pill pit with 15 bbls of mineral oil. 1/15/2016 1/15/2016 0.50 PROD2 DRILL CIRC T Pump 14 bbls of mineral oil into the 10,457.0 10,457.0 23:00 23:30 OH annulus,underdisplacing leaving 2 bbls in the CT.Push 3-5Klbs down on CT below normal SO weight.CTW= 7Klbs. As mineral oil turned the corner,WOB began to increase from 100Ibs to 400Ibs. PU CT and broke over at 32Klbs.CT free. Page 9/13 Report Printed: 2/2/2016 •erations Summary (with Timelog pths) ` ; 3Q-13 conoca'hifflps „ Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/15/2016 1/16/2016 0.50 PROD2 DRILL WPRT T With pipe free,pull wiper to the big tail 10,457.0 10,457.0 23:30 00:00 pipe. 1/16/2016 1/16/2016 1.50 PROD2 DRILL DRLG P Continue wiper trip to the window.Jog 10,457.0 10,450.0 00:00 01:30 5-1/2"casing.Tie into RA for a+3 ft correction.RBIH to 10450 ft. A sample from the shakers from the build section,showed thin steel shavings.Pictures in the well file. 1/16/2016 1/16/2016 3.50 PROD2 DRILL WPRT P From 10,450 ft,pump 10/10 sweep 10,450.0 72.0 01:30 05:00 and begin chasing to the swab valves. 1/16/2016 1/16/2016 2.90 PROD2 DRILL TRIP P Tag up and reset depths.Run back in 72.0 10,450.0 05:00 07:54 the hole,tie-in K1 for+2.5'correction, continue in hole. 1/16/2016 1/16/2016 3.45 PROD2 DRILL CIRC P POOH laying in liner pill/completion 10,450.0 73.0 07:54 11:21 fluid,paint EOP flags @ 8,706'& 5,900',continue OOH. 1/16/2016 1/16/2016 0.50 PROD2 DRILL OWFF P Flow check,no flow. 73.0 73.0 11:21 11:51 1/16/2016 1/16/2016 0.90 PROD2 DRILL PULD P PJSM. LD BHA#7,bit had one 73.0 0.0 11:51 12:45 chipped tooth and some balling. 1/16/2016 1/16/2016 0.65 COMPZ2 CASING PUTB P Prep floor to run liner 0.0 0.0 12:45 13:24 1/16/2016 1/16/2016 3.60 COMPZ2 'CASING PUTB P PJSM.MU L1-01 Liner assembly,bull 0.0 1,745.0 13:24 17:00 nose,58 jts slotted,two pups,billet. MU BHA#8 1/16/2016 1/16/2016 3.00 COMPZ2 CASING RUNL P RIH w/liner assembly.Stop at pipe 1,745.0 10,457.0 17:00 20:00 flag for a minus 1 ft correction. ' Suspect that is incorrect.Tie in to K1 on the fly for a+2 ft correction.Tag bottom on depth at 10,457 ft.Weight check,PUW=36 Klbs.Release liner on bottom.PUW=32 Klbs.Continue POOH. 1/16/2016 1/16/2016 1.50 COMPZ2 CASING TRIP P POOH with liner running BHA#8. 10,457.0 72.0 20:00 21:30 1/16/2016 1/16/2016 0.50 COMPZ2 CASING OWFF P Flow check well.Static. 72.0 72.0 21:30 22:00 1/16/2016 1/16/2016 0.50 COMPZ2 CASING PULD P PJSM,LD liner running BHA#8.Prep 72.0 0.0 22:00 22:30 for BOP Test. 1/16/2016 1/17/2016 1.50 PROD3 WHDBOP BOPE Remove checks from UQC,install 0.0 0.0 22:30 00:00 nozzle,stab WH. Line up and flush stack and lines. Swap coil to fresh water. 1/17/2016 1/17/2016 1.50 PROD3 WHDBOP BOPE P Line up and test Inner-reel valve and 0.0 0.0 00:00 01:30 stripper. Unstab,remove nozzle and QTS. Skid. Install Night cap,fluid pack lines. 1/17/2016 1/17/2016 10.50 PROD3 WHDBOP BOPE P Continue testing BOPE.250/4500 psi, 0.0 0.0 01:30 12:00 annular 2500 psi.BOP test waived by AOGCC(Chuck Scheve). 1/17/2016 1/17/2016 1.50 PROD3 STK -CIRC P Move cart,install nozzle,swap coil 0.0 0.0 12:00 13:30 back to KWF.Check for flow. 1/17/2016 1/17/2016 1.00 PROD3 STK PULD P PJSM.MU BHA#9,surface test,open 0.0 72.5 13:30 14:30 EDC Page 10/13 Report Printed: 2/2/2016 ;' 3' Serations Summary (with Timelog liths) 3Q-13 .,` I ConocaPhiilips <=n Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log I Start Depth Start Time End Time Dur(hr) Phase - Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/17/2016 1/17/2016 2.50 PROD3 STK TRIP 'P RIH w/drilling assembly, .7 AKO 72.5 8,754.0 14:30 17:00 motor,3"Hughes bit,pumping forward,tie-in for+1'correction, continue in hole,dry tag billet @ 8,754'. 1/17/2016 1/17/2016 0.75 PROD3 STK DISP , P Circulate hole back to drilling mud. 8,754.0 8,754.0 17:00 17:45 RIH and dry tag billet. PU,bring pumps up,and RIH.Begin time drilling billet. 1/17/2016 1/17/2016 4.25 PROD3 STK KOST P Time drilling billet at 1.51 BPM 13KIbs 8,754.0 8,785.0 17:45 22:00 CTW,and 0.5Klbs WOB.Observed 4 motor stalls while trying to get kicked off the billet.Drilled to 8785. 1/17/2016 1/18/2016 2.00 PROD3 DRILL DRLG -P Dry drift billet area.Clean drift up and 8,785.0 8,862.0 22:00 00:00 down.Continue drilling the L1-02 lateral. 1.51 BPM @ 3535 PSI FS, BHP=3,930 PSI,CTW=11K WOB=2.3K,ROP=50 FPH 1/18/2016 1/18/2016 3.00 PROD3 DRILL DRLG P Continue drilling the L1-02 lateral. 8,862.0 8,956.0 00:00 03:00 1.50 BPM @ 3380 PSI FS, BHP=3,930 PSI,CTW=9K dropping to 6K WOB=2.3K, ROP=50 FPH 1/18/2016 1/18/2016 0.75 PROD3 DRILL WPRT -P Lower than expected surface weight. 8,956.0 8,956.0 03:00 03:45 Pump 5/5 sweep,pull wiper to the window chasing sweep. Substantial cuttings observed over the shakers as low vis and hi vis came to surface.RBIH from 7789 ft to Bottom. 1/18/2016 1/18/2016 5.40 PROD3 DRILL DRLG P Continue drilling the L1-02 lateral. 8,956.0 9,210.0 03:45 09:09 1.50 BPM @ 3330 PSI FS, BHP=3,920 PSI,CTW=Back up to 9K. WOB=1.8K,ROP=50 FPH 1/18/2016 1/18/2016 0.85 PROD3 DRILL WPRT P Wiper trip,PUW=28K,RBIH. 9,210.0 9,210.0 09:09 10:00 1/18/2016 1/18/2016 4.25 PROD3 DRILL DRLG P Drill ahead:1.56 BPM @ 3,700 PSI, 9,210.0 9,460.0 10:00 14:15 BHP=3,950 PSI,CTW=9K,WOB=2K, ROP=60-80. 1/18/2016 1/18/2016 1.75 PROD3 'DRILL WPRT P Wiper for tie-in,PUW=28K,clean 5.5" 9,460.0 9,460.0 14:15 16:00 BTP,tie-in for+2.5'correction, RBIH.Start pumping new mud system. 1/18/2016 1/18/2016 3.50 PROD3 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,640 PSI, 9,460.0 9,712.0 16:00 19:30 BHP=3,940 PSI,CTW=9.1K, WOB=1.3K,ROP=70. New mud at bit at 9466 ft. 1/18/2016 1/18/2016 0.75 PROD3 DRILL DRLG P Wiper trip to 8800 ft.PUW=32 Klbs. 9,712.0 9,712.0 19:30 20:15 RBIH. 1/18/2016 1/19/2016 3.75 PROD3 DRILL DRLG P Drill ahead:1.50 BPM @ 3,590 PSI, 9,712.0 9,960.0 20:15 00:00 BHP=4,000 PSI,CTW=9K, WOB=1.5K,ROP=80-100 FPH. 1/19/2016 1/19/2016 0.75 PROD3 DRILL WPRT -P Wiper trip to 8800 ft. 9,960.0 9,960.0 00:00 00:45 1/19/2016 1/19/2016 2.00 PROD3 DRILL DRLG P Continue drilling the L1-02 lateral. 9,960.0 10,120.0 00:45 02:45 1.50 BPM @ 3630 PSI FS,BHP=4100 PSI,CTW=8K.WOB=1.5K,ROP=100 FPH Page 11/13 Report Printed: 2/2/2016 a , ,. Serations Summary (with Timelog liths) ` xx,„:;,A, , 3Q-13 _ ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/19/2016 1/19/2016 1.25 PROD3 DRILL WPRT T Lost some WITS data to BHI display. 10,120.0 10,120.0 02:45 04:00 HMI screen still displaying all drilling parameters. PUH to troubleshoot MWD computers/WITS feed.RBIH. 1/19/2016 1/19/2016 1.00 PROD3 DRILL DRLG Continue drilling L1-02 lateral.All 10,120.0 10,210.0 04:00 05:00 drilling parameters correctly displayed on HMI screen. BHI screen still missing some data but is displaying GR/RES data for steering. 1.50 BPM @ 3640 PSI FS,BHP=4100 PSI,CTW=8K.WOB=1.8K,ROP=50- 110 FPH 1/19/2016 1/19/2016 2.35 PROD3 DRILL WPRT P Wiper trip,PUW=29K,jet 5.5"BTP, 10,210.0 10,210.0 05:00 07:21 log RA for+4'correction,RBIH. 1/19/2016 1/19/2016 3.85 PROD3 DRILL DRLG P Drill ahead: 1.48 BPM @ 4,035 PSI, 10,210.0 10,460.0 07:21 11:12 BHP=4,005 PSI,CTW=8K, WOB=1.8K, ROP=90. 1/19/2016 1/19/2016 0.85 PROD3 DRILL WPRT P 10,460 ft.wiper up hole to 9,460 ft. 10,460.0 9,460.0 11:12 12:03 PUW 29k 1/19/2016 1/19/2016 0.50 PROD3 DRILL WPRT P 9,460 ft.wiper back in hole.RIW 10k 9,460.0 10,460.0 12:03 12:33 1/19/2016 1/19/2016 1.25 PROD3 DRILL DRLG P 10,460 ft.BOBD 1.6 bpm at 3736 psi. 10,460.0 10,550.0 12:33 13:48 FS,BHP 3997,WHP 150, IA 447,OA 375 1/19/2016 1/19/2016 2.85 PROD3 DRILL WPRT P 10,550 ft.TD L1-02 lateral,PUH,line 10,550.0 72.2 13:48 16:39 up and pump 10x10 sweep,wiper to the swab valve,jetting 5.5"BTP 1/19/2016 1/19/2016 3.20 PROD3 DRILL TRIP P Tag up and reset depths.RBIH,tie-in 72.2 10,552.0 16:39 19:51 at K1 for+2.5 ft. correction,continue in hole,confirm TD at 10,552 ft,Pump beaded liner pill. 1/19/2016 1/19/2016 2.70 PROD3 DRILL DISP P POOH laying in liner pill/completion 10,552.0 72.2 19:51 22:33 fluid,paint EOP flags at 7,600 ft.and 4,800 ft. 1/19/2016 1/19/2016 0.50 PROD3 DRILL OWFF P On surface,monitor well for flow.LD 72.2 72.2 22:33 23:03 BHA on dead well. 1/19/2016 1/19/2016 0.70 PROD3 DRILL PULD P LD BHA#9,bit condition 72.2 0.0 23:03 23:45 1/19/2016 1/20/2016 0.25 COMPZ3 CASING PUTB P Prep floors to run liner. 0.0 0.0 23:45 00:00 1/20/2016 1/20/2016 0.35 COMPZ3 CASING PUTB P Continue prep floors to run liner. 0.0 0.0 00:00 00:21 1/20/2016 1/20/2016 5.00 COMPZ3 CASING PUTB P PJSM-MU bull nose,pup jt,97 jts 0.0 2,809.8 00:21 05:21 slotted,shorty deployment sleeve. 1/20/2016 1/20/2016 1.25 COMPZ3 CASING PULD P PJSM-MU L1-02 liner assmbly to 2,809.8 2,854.1 05:21 06:36 BHA#10,MU to CoilTrak,surface test. 1/20/2016 1/20/2016 2.00 COMPZ3 CASING RUNL P RIH w/L1-02 slotted liner completion, 2,854.1 7,654.0 06:36 08:36 97 jts,shorty deployment,and non- ported bullnose. 1/20/2016 1/20/2016 0.25 COMPZ3 CASING RUNL P 7,654 ft.Correct to the EOP flag plus 7,654.0 7,654.0 08:36 08:51 0.4 ft.PUW 32k 1/20/2016 1/20/2016 1.00 COMPZ3 CASING RUNL P Continue RIH w/liner 7,654.0 10,345.0 08:51 09:51 1/20/2016 1/20/2016 0.25 COMPZ3 CASING RUNL P 10,345 ft.Tie into the K1 marker 10,345.0 10,552.0 09:51 10:06 correction of zero. Page 12/13 Report Printed: 2/2/2016 aerations Summary (with Timelog laths) ,rhe r -- - �a 3Q-13 coAhiiiaps *s., Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/20/2016 1/20/2016 0.25 COMPZ3 CASING RUNL P 10,550 ft.PUW 34k,Set down 4k, 10,552.0 7,742.0 10:06 10:21 bring pump up 1.3 bpm at 4300 psi, 1.2 bpm returns,release liner,PUW 28k. 1/20/2016 1/20/2016 2.00 COMPZ3 CASING TRIP P 7,742 ft.Line up and displace well to 7,742.0 2,500.0 10:21 12:21 seawater,while POOH 1/20/2016 1/20/2016 1.50 COMPZ3 CASING FRZP P 2,500 ft.PJSM with rig crew and Little 2,500.0 44.2 12:21 13:51 Red Services,FP well with diesel. 1/20/2016 1/20/2016 1.50 COMPZ3 CASING PULD P At surface,PJSM,with rig team, PUD 44.2 0.0 13:51 15:21 and LD liner setting tools 1/20/2016 1/20/2016 4.65 DEMOB WHDBOP RURD P Install nozzle,stab INJH,and flush 0.0 0.0 15:21 20:00 surface lines with inhibitor.Blow down coil,surface lines and TT line. 1/20/2016 1/20/2016 2.50 DEMOB WHDBOP MPSP P Valve crew onsite,bring in lubricator 0.0 0.0 20:00 22:30 and equipment.PJSM-Lubricate in BPV,SITP 930 psi,rig down,off load lubricator and equipment. 1/20/2016 1/21/2016 1.50 DEMOB WHDBOP NUND P PJSM-ND BOPE Equipment.RD 0.0 0.0 22:30 00:00 cellar.Prep shop for move. ' Rig Release 00:00 on 01/21/2016 Page 13/13 Report Printed: 2/2/2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-13L1-02 50-029-21664-62 Baker Hughes INTEQ Definitive Survey Report HUGHES 20 January,2016 • i ConocoPhillips //%l s ConocoPhilli BAKER ConocoPhillips Definitive Survey Report HY6NE5 g Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-13 t project: Kuparuk River Unit TVD Reference: 30-13 @ 60.00usft(3Q-13) 1 "Site: Kuparuk 3Q Pad MD Reference: 30-13 @ 60.00usft(3Q-13) Well: 3Q-13 North Reference: True Wellborn: 3Q-13 Survey Calculation Method: Minimum Curvature ,Design: 13Q-13 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ,Well 30-13 Well Position +N/-S 0.00 usft Northing: 6,025,789.31 usft Latitude: 70°28'53.925 N +E/-W 0.00 usft Easting: 516,299.52 usft Longitude: 149°52'0.528 W F Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3Q-13L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (°) (nT) BGGM2015 3/1/2016 18.51 81.05 57,493 Design 3Q-13L1-02 Audit Notes: i "Version: 1.0 Phase: ACTUAL lie On Depth: 8,750.22 Vertical Section: Depth From(TVD): +Nl-S +E!.W Direction (usft) (vaft) (dam) rt 60.00 0.00 0.00 225.00 Survey Program Date 1/20/2016 From To Survey Survey (usft) (usft) Survey(Wellbore) . Tool Name Description Start Date End Date 100.00 7,700.00 3Q-13(3Q-13) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/15/2001 kkk 7,745.00 8,140.90 3Q-13L1PB1(3Q-13L1PB1) MWD MWD-Standard 1/4/2016 1/8/2016 8,150.00 8,750.22 3Q-13L1(3Q-13L1) MWD MWD-Standard 1/9/2016 1/12/2016 E i 875400 10,512.87 3Q-13L1-02(3Q-13L1-02) MWD MWD Standard 1/17/2016 1/19/2016 i 1f2012016 3:01:52PM Page 2 COMPASS 5000.1 Build 74 • • ConocoPhillips IrdiII ConocoPhillips Definitive Survey Report BAKER iES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3D-13 Project: Kuparuk River Unit TVD Reference: 3Q-13 @ 60.00usft(3Q-13) Site: Kuparuk 30 Pad MD Reference: 3Q-13 @ 60.O0usfl(3Q-13) $Well: 3Q-13 North Reference: True ( i Wellbore: 3Q-13 Survey Calculation Method: Minimum Curvature 1 Design: 3Q-13 Database: EDM Alaska NSK Sandbox 3 Survey. Map Map Vertical MD Inc Azi ND TVDSS +11(-S +EI-W DLS Northing Easting Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) ((sft) (usft) (ft) (ft) (°I100') (ft) 8,750.22 92.80 232.04 6,291.24 6,231.24 -4,567.99 -1,957.91 6,021,217.50 514,351 82 9.37 4,614.50 MWD(3) TIP 8,754.00 92.54 231.54 6,291.07 6,231.07 -4,570.32 -1,960.87 6,021215.16 514,348.86 14.90 4,618 25 MWD(4) KOP 1 8,785.22 96.77 227.00 6,288.53 6,228.53 -4,590.61 -1,984.44 6,021,194.82 514,325.33 19.84 4,649.27 MWD(4) "s 8,815.47 96.77 222.58 6,284.96 6,224.96 -4,611.93 -2,005.60 6,021,173.46 514,304.23 14.51 4,679.30 MWD(4) 8,845.32 96.46 220.30 6,281.52 6,221.52 -4,634.15 -2,025.23 6,021,151.19 514,284.65 7.66 4,708.89 WD(4) i M 8,875.14 94.98 217.50 6,278.55 6,218.55 -4,657.24 -2,043.85 6,021,128.07 514,266.08 10.58 4,738.39 MWD(4) 8,905.47 90.21 217.12 6,277.18 6,217.18 -4,681.33 -2,062.21 6,021,103.94 514,247.77 15.78 4,768.41 MWD(4) 8,935.22 90.58 216.34 6,276.97 6,216.97 -4,705.18 -2,080.01 6,021,080.06 514,230.03 2.90 4,797.85 MWD(4) 8,965.39 88.40 218.33 6,277.24 6,217.24 -4,729.16 -2,098.30 6,021,056.04 514,211.79 9.78 4,827.74 MWD(4) ti 8,995.34 88.53 221.80 6,278.04 6,218,04 -4,752.07 -2117.57 6,021,033.09 514,192.58 11.59 4,857,57 MWD(4) l 9,025.22 88.34 222.26 6,278.86 6,218.86 -4,774.26 -2,137.57 6,021,010.86 514,172.63 1.67 4,887.40 MWD(4) I 9,055.19 90.98 219.26 6,279.04 6,219.04 -4,796.95 -2,157.13 6,020,988.12 514,153.12 13.33 4,917.28 MWD(4) 9,085.14 94.24 216.69 6,277.67 6,217.67 -4,820.53 -2,175.53 6,020,964.51 514,134.77 13.85 4,946.97 MWD(4) 1 9,115.23 95.07 212.49 6,275.23 6,215.23 -4,845.21 -2,192.56 6,020,939.79 514,117.80 14.18 4,976.46 MWD(4) 9,145.52 93.81 209.52 6,272.89 6,212.89 -4,871.10 -2208.11 6,020,913.87 514,102.31 10.62 5,005.75 MWD(4) 9,175.52 92.64 206.63 6,271.20 6,211.20 -4,897.52 -2,222.20 6,020,887.42 514,088.27 10.38 5,034.41 MWD(4) 9,205.40 93.38 208.32 6,26963 6,209.63 1{923.99 -2,235,97 6,020,860.92 514,074.57 6.17 5,062.86 MWD(4) t 9,235.08 93.44 211.93 6,267.86 6,207.86 -4,949.61 -2,250.84 6,020,835.27 514,059.76 12.14 5,09149 MWD(4) S k 9,265.23 91.57 214.77 6,266,55 6,206.55 -4,974.77 -2267.39 6,020,810.08 514,043,26 11.27 5,120.98 MWD(4) 9,295.20 90.80 217.51 6,265.93 6,205.93 -4,998.97 -2285.06 6,020,785.85 514,025.64 9.49 5,150.59 MWD(4) i 9,325.59 90.64 219.76 6,265.54 6,205.54 -5,022.70 -2304.04 6,020,762.07 514,006.72 7.42 5,180.79 MWD(4) j 9,355.44 89.57 216.42 6,265,49 6,205.49 -5,046.19 -2,322.45 6,020,738.55 513,988,37 11.75 5,210.41 MWD(4) 9,385.36 89.57 213.83 6,265,71 6,205.71 -5,070.66 -2,339.66 6,020,714.04 513,971.21 8.66 5,239.89 MWD(4) 9,420.57 89.17 210.16 6,266.10 6,206.10 5,100.51 -2,358.31 6,020,684.15 513,952.62 10.48 5,274.19 MWD(4) 9,450.30 90.18 207.42 6,266.27 6,206.27 -5,126.57 -2,372.63 6,020,658.07 513,938.37 9.82 5,302.73 MWD(4) 9,480.57 90.49I. 207.82 6,266.09 6,206.09 -5,153.39 -2,386.66 6,020,631.22 513,924.39 1.67 5,331.62 MWD(4) 9,510.42 90.98 210.76 6,265.71 6,205.71 -5,179.42 -2,401.26 6,020,605.16 513,909.85 9.98 5,360.35 MWD(4) 9,540.28 92.18 213.58 6,264.89 6,204.89 -5,204.66 -2417.15 6,020,579.87 513,894.02 10.26 5,389.45 MWD(4) I 9,570.26 93.84 215.76 6,263.31 6,203.31 -5,229.30 -2,434.18 6,020,555.21 513,877.04 9.13 5,418.90 MWD(4) 9,600.58 93 35 217 53 6,261.41 6,201.41 -5,253.58 -2,452.24 6020 530 90 513,859 04 6.05 5,448.84 MWD(4) a 1,20#,2016 3:01:52P11 Page 3 COMPASS 5000.1 Build 74 y • s ConocoPhillips Mill ConocoPhillips Definitive Survey Report SES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-13 Project Kuparuk River Unit TVD Reference: 3Q-13 @ 60.00usft(3Q-13) Site: Kuparuk 3Q Pad MD Reference: 3Q-13 @ 60.00usft(3Q-13) Well: 3Q-13 North Reference: True Wellbore: 30-13 Survey Calculation Method: Minimum Curvature 1 Design: 3Q-13 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi IVO TVDSS +NI-S +El-W DLS Northing Easting Section Survey Tool Name Annotation (haft) (1 (°) ittet) (usff) (usft) (haft) (ft) (e) (1100, Int 9,630.72 92.40 220.79 6,259.90 6,199.90 -5,27691 -2,471.25 6,020,507 52 513840.09 1125 5,478.78 MWD(4) eI 9,660.54 91.57 219.70 6,258.87 6,198.87 -5,299.66 -2,490.50 6,020,484 73 513820.88 459 5,508.48 MWD(4) I 9,690.36 91.57 216.20 6,258.05 6,198.05 -5,323.16 -2,508.83 6,020,461.19 513802.61 11.73 5,538.06 MWD(4) 9,720.46 91.51 212.19 6,25724 6,197.24 -5,348.05 -2,525.74 6,020,436.28 513,785.76 13.32 5,567.60 MWD(4) 9,750.70 91.84 208.22 6,256.35 8196.35 -5,374.16 -2,540.94 6,020410.13 513,770.61 1317 5,596.82 MWD(4) 9,780.58 9157 209.28 6,255.47 6,195.47 -5,400.35 -2555.31 6,020,383.92 513,756.31 3.66 5,62550 MWD(4) 9,810.48 91.87 213.68 6,254.57 6,194.57 -5425.83 -2570.91 6,020,358.40 513,740.76 14.74 5,65455 MWD(4) I. 9,840.52 90.98 215.69 6,253.82 6,193.82 -5,450.52 -2588.00 6,020,333.67 513,723.73 7.32 5,684.09 MWD(4) 9,870.46 91.14 220.25 6,25327 6,193.27 -5,474.11 -2,606.41 6,020,310.04 513,705.37 1524 5,713.79 MWD(4) 1 9,900.53 90.28 222.38 6,252.89 6,19289 -5,496.70 -2,626.26 6,020,287.42 513685.57 7.64 5,743.80 MWD(4) $ F $ e 9,930.58 91.26 224.67 6,252.49 6,192.49 -5,518.48 -2,646.95 6,020,265.59 513,664.93 829 5,773.83 MWD(4) e 9,960.55 90.31 228.58 6,25208 6,19208 -5,539.06 -2,668.73 6,020,244.97 513643.20 13.42 5,803.78 MWD(4) 9,990.40 91.29 231.04 6,251.66 6,191.66 -5,558.32 -2,691.53 6,020,225.66 513,620.45 887 5,833.52 MWD(4) g 10,020.62 91.57 231.25 6,250.91 6,190.91 -5,57727 -2715.05 6,020,206.66 513596.96 1.16 5,663.56 MWD(4) 10,050.40 89.39 228.42 6,250.66 6,190.66 -5,596.47 -2737.81 6,020,187.41 513574.25 11.99 5,89323 MWD(4) eee 10,080.47 90.52 224.52 6,250.68 6,190.68 -5,617.18 -2,759.60 6,020,166.66 513,552.51 13.50 5,923.28 MWD(4) I10,110.17 89.82 221.49 6,250.59 6,190.59 -5,638.90 -2,779.86 6,020,144.90 513,532.30 10.47 5,95296 MWD(4) f@@@i 10,140.37 90.95 218.32 6,250.39 6,190.39 -5,66206 -2,799.23 6,020,121.70 513,512.98 11.14 5,983.03 MWD(4) & 10,170.11 91.53 215.20 6,249,75 6,188.75 -5,685.88 -2,817.02 6,020,097.84 513495.25 10.67 6,012.46 MWD(4) e 10,200.32 91.20 212.49 6,249.03 6,189.03 -5,710.96 -2,833.84 6,020,072.73 513,478.48 9.03 6,042.08 MWD(4) € 10,230.13 91.66 209.51 6,248.28 6,188.28 -5,736.50 -2,849.18 6,020,047.15 513,463.19 10.11 6,071.00 MWD(4) & 10,260.14 92.00 207.08 6,247.32 6,187.32 -5,76291 -2,863.40 6,020,020.72 513,449.04 817 6,099.72 MWD(4) 10289.95 91.14 204.63 6,246.51 6,186.51 -5,789.72 -2,876.40 6,019,993.88 513,436.10 8.71 6,127.87 MWD(4) s 10,320.11 90.98 204.48 6,245.95 6,185.95 -5,817.15 -2,888.93 6,019,966.43 513,423.63 0.73 6,156 13 MWD(4) 10,350.07 94.58 207.14 6,244.50 6,184.50 -5,844.08 -2,901.95 6,019,939.47 513,410.67 14.93 6,184.38 MWD(4) 10,380.08 96.37 210.24 6,241.63 6,181.63 -5,870.28 -291629 6,019,913.24 513,396.39 11.89 6,213.05 MWD(4) 10410.07 9544 21209 6,238.55 6,178.55 -5,89581 -2931.73 6,013887.68 513,381.01 6.88 6242.01 MWD(4) 10,440.29 9264 214.01 6,236.42 6,176.42 -5,921.07 -2948.16 6,019,862.38 513,364.63 11.23 6271.50 MWD(4) s 10,470.31 89.54 215.28 6,235.85 6,175.85 -5,945.76 -2965.23 6,019,837.66 513,34762 11.16 6301.02 MWD(4) 10,500.01 87.97 217.04 6,236.49 6,176.49 -5,969.73 -2,982.74 6,019,813.65 513,330.16 7.94 6,330.36 MWD(4) 8 ' 10 512 87 88 04 218.78 6,236 94 6,176.94 -5,979.87 2,990.64 6,019,80350 513 322 29 13.53 6343 11 MWD(4) 11I0/2016 3:01:52PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips p11111 ConocoPhillips Definitive Survey Report BAKERHUGHES y Company:. ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-13 Project: Kuparuk River Unit TVD Reference: 3Q-13 @ 60.00usft(3Q-13) '''.Site: Kuparuk 3Q Pad MD Reference: 3Q-13 @ 60.00usft(3Q-13) Wept:,: 3Q-13 North Reference: True t tNel)bdra; `r 3Q-13 Survey Calculation Method: Minimum Curvature peetry; 130-13 Database: EDM Alaska NSK Sandbox t Map Map Vertical MO Inc Azi NO TVDSS +NIS +EI-Mt NorthingEasting DCS Section lusft)' O O tush) (usft) (usft) (usft) (ft) (ftsti (°rloo) (h) Survey Tool Name Annotation 1055200 8804 218.78 623828 6,17828 -601036 301513 601977296 513,297 86 000 638199 PROJECTED to TD 1/202016 3:01:52PM Page 5 COMPASS 5000.1 Build 74 IPECEWED JAN 22 2016 ®GCC Letter of Transmittal BAKER Date: DATA LOGGED HUGHES January 21, 2016 L/9 izo,C. M.K.BENDER 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): 3Q-13L1PB1 21 5 2 2 12 57 0 1 3Q-13L1 2 1 5-2-2 1 2 6 7 0 0 3Q-13L1-01 21 5 2 2 3 2 6 7 0 2 Z 3Q-13L1-02 21 5 2 2 4 2 6 7 0 3 (4) 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com • • C'V M N c) LC) H CV N W ON z `IY; gmg2 0 ul o V N ul 6-1 CI j d N a I C L ca O O. cn ca 0 0 W a Q I— >1 0 Z 0 LEL = a, 0 0 Q. 70 C u o = }i._ /, O •- ac1 N C O N _ as O ki R M N . 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G iG 0 —'D- C) Q . 00 z q) LO (,1 -. Q U d G U — �� tt 0) G U i V @ Q 'E o w w N (11 ,L, U " a V Q m 0 K :t:. , e o 0 ? N J i- 2 z U) 0 W V <.?0 M 0 E o z N N m N ❑ N v N m Q N Y 0 S N m N U 0 C N Q Co9 D U .N @ Q v1 :L d• ' 0 /� d Y 3.f. 8 2 2 SII O co co ,- .- .- o S U Y Y UM' MU' G °_ m O h 0 V o 0 O N CO 2 N C d ❑ N Nco V a 11 _ .o ) m o 0 0 E c ai m 'y c) v a in 3 0 to o • • OF Th. i • ‘v. )\ I//Z�,� THE STATE Alaska Oil and Gas Of Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 T h` Main: 907.279.1433 110X-17;4, ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Daniel Venhaus CTD Supervisor ConocoPhillips Alaska,Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-13L1-02 ConocoPhillips Alaska, Inc. Permit No: 215-224 Surface Location: 2283' FNL, 2037' FEL, SEC. 17, T13N, R9E, UM Bottomhole Location: 2990' FNL, 5163' FEL, SEC. 20, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 186-176, API No. 50-029- 21664-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P Foerster Chair DATED this 41 day of December, 2015. RECEIVED STATE OF ALASKA Al,A OIL AND GAS CONSERVATION COMMON DEC 15 2015 PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: l h. Proposed Well Class Exploratory-Gas ❑ Service- WAG 0 • Service-DisptP 1c.Specify if well is proposed for: Drill ❑ Lateral'0 Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone [ Coalbed Gas 0 Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ p 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. #86$B-2.6•.2.7.375` NO v,t4) 3Q-13L1-02 3.Address: 6. Proposed Depth: 12.Field/Pool(s): PO Box 100360 Anchorage,AK 99510-0360 MD: 10575'• TVD: 6211' . Kuparuk River Field/. 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk Oil Pool Surface: 2283'FNL,2037'FEL,Sec.17,T13N,R9E,UM • ADL 25512 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 727'FNL,3563'FEL,Sec.20,T13N,R9E, UM ALK 2553 1/1/2016 Total Depth: 9.Acres in Property: 7348 14.Distance to Nearest Property: 2990'FNL,5163'FEL,Sec.20,T13N,R9E,UM 2,543cr 4514 14060' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL(ft): . 60' 15.Distance to Nearest Well Open Surface: x-516300 y-6025789 Zone-4 • GL Elevation above MSL(ft): • 42' to Same Pool: 1265' (3M-13) 16.Deviated wells: Kickoff depth: . 8650 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 93 degrees Downhole: 4509 psi . Surface: 4022 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing , Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3.25" 2-3/8" 4.6# L-80 ST-L 2821' 7745 6249' 10575' 6211' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 8168' 6195' none 8083'MD 6502'TVD None Casing Length Size Cement Volume MD TVD Conductor/Structural 115' 16" 1875#Poleset 115' 115' Surface 4325' 9-5/8" 1200 sx ASI I I&300 sx Class G 4325' 3713' Intermediate Production 8168' 7" 300 sxs Class G&175 sx AS I 8168' 6567' Liner Perforation Depth MD(ft): 7743'-7755',7760'-7784'&7790'- Perforation Depth TVD(ft): 6247'-6256',6259'-6277'&9282'-6310' 7828' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: D 22. I hereby certify that the foregoing is true and the procedure approved herein will not o rke be deviated from without prior written approval. Conta iason.burkecop.com Email Printed Name Daniel Venhaus Title CTD Supervisor Signature Phone 907-263-4372 Date /2--/`T`"15 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: pJ5_ aQZj 50- Dag— .V 6o6a1-6a.—QQ Date: 1 0,...) ) requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: Other:Bop t-t- t to ,J-G o p 5 19 Samples req'd: YesNo al Mud log req'd:Yes❑ No Er 4-1,7n vi ar pre Vt va tl fr' ftS 1-- f� 25-00,�5 t 9 H2S measures: Yes No❑ Directional svy req'd:Yes V No❑ / 51 a tC .frtr It Z'55 c'd M/T - /A Spacing exception req'd: Yes ❑ No E ' Inclination-only svy req'd:Yes❑ No d req.u/'red of Ft-cr. s sl-et b r i r ? C c� 11-3 Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:/2._Z3 —/5'- V` 12 23/is 1'143 /1 I4$rr RitisGlift4A„E 'y / Submit Form and Form 10-401(Revised 11/2015) TF[s J from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate A Iz/3//� • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 9, 2015 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 • Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applicatiops for permits to drill a tri-lateral out of the KRU 3Q-13 using the coiled tubing drilling rig, Nabors CDR2-AC.✓✓The work is scheduled to begin mid-January 2016. The CTD objective will be to drill three laterals(3Q-13L1, L1-01 & L1-02), targeting the Kuparuk A-sand intervals. Note the current A sand perforations will be open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401)for 3Q-13L1, L1-01 & L1-02 — Detailed Summary of Operations — Directional Plans for 3Q-13L1, L1-01 & L1-02 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-263-6097. Sincerely, Jason Burke Coiled Tubing Drilling Engineer 0 • 0Kupay ruk CTD Laterals M° .5 ". 3Q-13L1, L1-01 & L1-02 ~' Application for Permit to Drill Document Znc 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 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 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 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 3Q-13L1, 3Q-13L1-01 &3Q-13L1-02 7 Attachment 2: Current Well Schematic for 3Q-13 7 Attachment 3: Proposed Well Schematic for 3Q-13L1, 3Q-13L1-01 &3Q-13L1-02 7 Page 1 of 7 June 30,2015 S i PTD Application: 3Q-13L1, L1-01 & L1-02. 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3Q-13L1, L1-01 &L1-02. All laterals will be classified as "Development—Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3Q-13L1, L1-01 &L1-02. . 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 4500 psi. Using the maximum formation pressure in the area of 4509 psi in 3M-13 (i.e. 14.2 ppg EMW), the maximum potential surface pressure in 3Q-13, assuming a gas gradient of 0.1 psi/ft,would be 4022 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)) The formation pressure in KRU 3Q-13 was measured to be 3135 psi (11.9 ppg EMW) on 10/21/2015. However the pressure is expected to decline to less than 11.8 ppg by the spud date. The maximum downhole pressure in the 3Q-13 vicinity is to the southwest in the 3M-13 injector at 4509 psi (14.2 ppg EMW) measured in November 2015. Due to a large fault between the 3M-13 and the 3Q-13, that high pressure is not expected during operations. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Offset injection wells to 3Q-13 are under active MI gas injection. If significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems is 1 large fault crossing. Managed pressure drilling (MPD)will be / used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3Q-13 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 December 9, 2015 S PTD Application: 3Q-13L1, L1-01 & L1-02. 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 3Q-13L1 8990' 10575' 6188' 6195' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3Q-13L1-01 8650' 10575' 6249' 6175' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3Q-13L1-02 7740' 10575' 6015' 6210' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (PO MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 38' 115' 0' 115' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 37' 4325' 0' 3713' 3520 2020 Production 7" 26.0 J-55 BTC 34' 8168' 0' 6567' 4980 4330 Liner 5-1/2" 14.0 H-40 STC 7680' 7770' 6140' 6444' 3110 2620 Tubing 3-1/2" 9.3 L-80 8rd EUE 38' 7680' 0' 6140' 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 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 A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.7 ppg) — Drilling operations: Chloride-based PowerVis mud (9.5 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The 3Q-13 contains a downhole deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with an overbalanced completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". Page 3 of 7 December 9,2015 S PTD Application: 3Q-13L1, L1-01 & L1-02. In the 3Q-13 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. 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 3Q-13 Window(7745' MD, 6189' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(11.5ppg) 3737 psi 3737 psi Mud Hydrostatic(9.5 ppg) 3087 psi 3087 psi Annular friction (i.e. ECD, 0.060 psi/ft) 465 psi 0 psi Mud+ ECD Combined 3552 psi 3087 psi (no choke pressure) (underbalanced (underbalanced —185 psi) —650 psi) Target BHP at Window(11.8 ppg) 3834 psi 3834 psi Choke Pressure Required to Maintain Target BHP 283 psi 747 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 AA C 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 for a land based 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. 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Summary of Operations Background Well KRU 3Q-13is a Kuparuk A-sand injection well equipped with 31/2"tubing and 5 'h"big tail pipe kick out joint. Three laterals will be drilled to the southwest of the parent well with the laterals targeting the Al, A2 and A3 sands. A thru-tubing whip-stock will be set inside the 51/4"liner at the planned kickoff point of 7745' MD to drill all 3 laterals. The 3Q-13L1 southwestern lateral will exit through the 51/4"liner at 7745' MD and TD at 10,575' MD, targeting the Al sand. It will be completed with 2%"slotted liner from TD up to 8990' MD with an aluminum billet for kicking off the 3Q-13L1-01 lateral. Page 4 of 7 December 9,2015 I a PTD Application: 3Q-13L1, L1-01 & L1-02. The 3Q-13L1-01 will drill southwest to a TD of 10575' MD targeting the A3 sand. It will be completed with 2%"slotted liner from TD up to 8650' MD with an aluminum billet for kicking off the 3Q-13L1-02 lateral. The 3Q-13L1-02 will turn east and drill to a TD of 10575' MD targeting the A2 sands. It will be completed with 2%"slotted liner from TD up to 7740' MD,back into the 5 1/2"liner and completed with a deployment sleeve. Pre-CTD Work 1. RU Slickline:Dummy all gas lift valves and obtain an A-sand SBHP, drift a dummy whip-stock to TD. 2. RU E-line: Set Baker Hughes 31/2"x 51/2"thru-tubing whip-stock at 7745' MD 3. Perform injection test 4. Pump degradable plug for temporary parent bore isolation 5. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3Q-13L1 Lateral(Al sand southwest) a. Mill 2.80"window at 7745' MD. b. Drill 3.25"bi-center lateral to TD of 10575' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 8990' MD. 3. 3Q-13L1-01 Lateral(A3 sand southwest) a. Kick off of the aluminum billet at 8990' MD. b. Drill 3.25"bi-center lateral to TD of 10575' MD. c. Run 2%"slotted liner from TD up to 8650' MD 4. 3Q-13L1-02 Lateral(A2 sand southwest) / a. Kick off of the aluminum billet at 8650' MD. b. Drill 3.25"bi-center lateral to TD of 10575' MD. c. Run 2%"slotted liner from TD back into the liner at 7740' MD 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Pre-produce for less than 30 days v'' 3. Return to injection. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using 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 Page 5 of 7 December 9, 2015 • s PTD Application: 3Q-13L1, L1-01 & L1-02. 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 — The 3Q-13 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalance completion fluid (as detailed in Section 8"Drilling Fluids Program") prior to running liner. — 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). 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 3Q-13L1 14060' Page 6 of 7 December 9, 2015 • S PTD Application: 3Q-13L1, L1-01 & L1-02. 3Q-13L1-01 14060' 3Q-13L1-02 14060' — Distance to Nearest Well within Pool Lateral Name Distance Well 3Q-13L1 3M-13 1265' 3Q-13L1-01 3M-13 1265' 3Q-13L1-02 3M-13 1265' 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 3M-13& 3Q-07 are within 1/4-mile of the 3Q-13L1, L1-01 & L1-02 wells 3Q-13(mother bore) Injector • The well is completed with 3.5" 9.3#L-80 tubing, 5.5" 14.0#H-40 liner and 7"26#J-55 production casing. The last MIT-IA was completed on 4/10/15 and passed at 3000 psi. • Classified as a"Normal Well" • A-sand perforations (open):A3: 7743'—7755' MD,A2: 7760'—7784' &Al: 7790'—7828' MD • Well was recently worked over on 11-27-15, new tubing was run and an down hole deployment valve was installed 3M-13(producer),—1265' away from 3Q-13L1, L1-01 & L1-02 lateral to southwest • Well is classified as a troubled well due to T x IA leak at 3634' • Well has a surface casing patch 7' 7"from surface • Well is completed with 7"26#J-55 production casing, 3 'h" 9.3#L-80 tubing and a 4.5"x 3.5" scab liner from 5590'—9015' MD • Packers located at 9002' &9181' MD the lowest most which is located less than 200' from the top of the perforations • A/C sand perforations from 9269--9379' MD • Production casing was cemented with 350 sxs Class'G' & 175 sx AS I 3Q-07 (producer),—1275' away from 3Q-13L1, L1-01 & L1-02 lateral to northwest • 30-07 currently producing from the Kuparuk A&C sand intervals • Classified as a waivered well due to IA x OA communication • Waivered with passing MIT-OA and fluid level. • Well is completed with 7"26#J-55 production casing and 2-7/8" 6.5#L-80 tubing • A/C-sand perforations: 8732'—8830' MD • Packer at 8619 ' MD,which is less than 200'from the perforations • Production casing was cemented with 100 sx 50/50 'G' 12.0 ppg and 200 sx'G' 15.8 ppg 17. Attachments Attachment 1: Directional Plans for 3Q-13L1, 3Q-13L1-01 & 3Q-13L1-02 Attachment 2: Current Well Schematic for 3Q-13 Attachment 3: Proposed Well Schematic for 3Q-13L1, 3Q-13L1-01 & 3Q-13L1-02 Page 7 of 7 December 9,2015 0 0 i. ! / B ( 2 ) ! !4 -g\\ )} ! ! 8 §�, , E ! - - IA F; - i E ) / ) § m # ) 0 0 | B « » a 08 , m I / } b£ $£ gs ( ( ; | ;\ 3. � k 2E rk re k( 14. ( r.".0' \ /` §-5 r I) ! a gk ! .. \ zu- ti ..co 2 o ) } #! : > W CG $ƒ )\% j c I < 1- qk 1 § 2 I /} , j . ko /, 2▪2 // § § § ( 7 f 7 I § ; , i } k ■ § § § F, / 2 § o Ln 2 o ! !!-?, # § • • Project:Kuparuk River Unit Noon IS 51- WELLBOREDETAILS:30-13L1 Onnnncn OFD WTCN Wait" Site:Kuparuk 30 Patl .patIgFidelParent Welhore:30-13 CO Onale(WEIRderenw:Well 3613.True Werth Well:30139enp 574930.T Te on MD:7700.00 VodWe(1VD)Relerenw:3013060.COus4(3Q13) BAKER Section Roerercx SW.(0.00N.00o r Wellbore:30-13L1 (30-13Date 05) CQnO��f I1��I�ps PIan:3D-13L1_wp03(30-1300-13L1) Abdel is Meamminepth Relerencc 30.I31§60.00ufl(90.13) HUGHES Celaetion Method Minorum Curvature 4550'`p'7��'.� .�M7iGSiiiC: _ _ 'Al.01,3,F o i 'a`ci1 -� illeAU 3900 .. 1:117441"1-,,- 9D--;- '4111" '1 • — i r —- M .___- �Z7R" .1 *: fin 7e3'''''' 1 3250 _s,:.:�1: `�.-� _ ._._ _ -.-•r, _ ` Y +.,-, 1951 a, ' 130. .............a,_...... , • 650 K— P '' - i .,... 'bo- sismatil _650F l-� � .-- ., _ ����..1. :�..... _ _ r , i _1300 *2 lilif iu _— — %'�w� -'r,A' 1e C ____ 1 `t _ aCC fi ,,--,..,,,-;_-...A S' -1950 ma oe - E ' r 6,,,lni1r. i . 1r1% - .2600 si b -3250 -_._ ----No _ '--3900#'' 'Pp "� I P _'ii � _ oul .�--5200) � V -- — —' -- �9iajft 10-.11 _. -''` -Aro., , ri. _-- 1 __ OK45, c.3a,1t ie,l 911'. ri 7150 gj .- - 7800 Rye i s v �EM, ' ,-.,,m,..,-,-;.t.; _, -i ,°e� : � 3: i+.4 f ern L 1 - 84501 ' / _ _ 1 —'t 1F< ,,D3n•. i ,r�'I' , *W�' 3 :a .t i 9750 ` tt fr-C C�"11Nr!W _ � i' TeLiT -10400 , _. ��Mf/f Y r ,� CAII I r,: n- .3V 1b3 04 -11050-14r4°'''''-'„,... ..F l.` \ `. .; ` \ —'. 1,13. <1 z, a rb 1 41 .. }` t '- \`� „ _— >Y4+2 3N-Y-1 \ .. E.a B 1 Ri Pn �t I -11700 � _ E,4 � ° .C��a.'�.� 1 1 i4,c 1 R..:.er xet kFf ' -�, -12350 4, Jz i ..:i _. - .�63064(F '..:1-......=•,...:__:5" y; 44 30-13. n r ,tra ir..�. - giverw - ,. I_:;_i -13650-13000-12350-11700-11050-10400-9750-9100-8450-7800-7150-6500-5850-5200-4550-3900-3250-2600-1950-1300 -650 0 6510 1300 1950 2600 3250 3900 4550 5200 5850 6500 7150 7800 8450 9100 9750 10400 West(-)/East(+)(650 usft/in) PhillipS Co : . ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-13 3Q-13L1-02 Plan: 3Q-13L1-02_wp01 Standard Planning Report 04 December, 2015 BAKER HUGHES • Baker Hughes INTEQ • .EE. ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3Q-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-13 @ 60.00usft(3Q-13) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-13 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-13L1-02 Design: 3Q-13L1-02_wp01 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 3Q Pad Site Position: Northing: 6,025,873.14 usft Latitude: 70°28'54.757 N From: Map Easting: 515,959.89 usft Longitude: 149°52'10.513 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.12 ° Well 3Q-13 Well Position +N/-S 0.00 usft Northing: 6,025,789.31 usft Latitude: 70°28'53.925 N +E/-W 0.00 usft Easting: 516,299.52 usft Longitude: 149°52'0.528 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3Q-13L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 3/1/2016 18.51 81.05 57,493 Design 3Q-13L1-02_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,650.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 225.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 8,650.00 89.28 225.17 6,249.67 -4,517.26 -1,888.05 0.00 0.00 0.00 0.00 8,720.00 92.43 221.42 6,248.62 -4,568.19 -1,936.04 7.00 4.50 -5.36 310.00 8,790.00 90.75 216.81 6,246.68 -4,622.46 -1,980.17 7.00 -2.40 -6.58 250.00 8,920.00 89.98 225.88 6,245.84 -4,719.95 -2,065.96 7.00 -0.59 6.98 94.80 9,000.00 89.01 231.40 6,246.54 -4,772.79 -2,125.98 7.00 -1.21 6.89 100.00 9,220.00 89.05 216.00 6,250.29 -4,931.35 -2,277.49 7.00 0.02 -7.00 270.00 9,340.00 89.93 207.64 6,251.36 -5,033.22 -2,340.70 7.00 0.74 -6.96 276.00 9,590.00 90.24 225.14 6,250.98 -5,233.68 -2,488.44 7.00 0.12 7.00 89.00 9,790.00 90.83 211.15 6,249.10 -5,390.57 -2,611.66 7.00 0.30 -6.99 272.50 9,890.00 92.40 204.33 6,246.28 -5,478.99 -2,658.16 7.00 1.57 -6.83 283.00 9,990.00 92.38 211.33 6,242.10 -5,567.29 -2,704.78 7.00 -0.02 7.01 90.00 10,190.00 93.16 225.33 6,232.39 -5,723.61 -2,828.35 7.00 0.39 7.00 86.50 10,290.00 93.13 218.32 6,226.90 -5,797.97 -2,894.89 7.00 -0.02 -7.01 270.00 10,390.00 93.48 225.32 6,221.13 -5,872.33 -2,961.42 7.00 0.34 7.00 87.00 10,575.00 93.39 238.29 6,210.00 -5,986.27 -3,106.24 7.00 -0.05 7.01 90.00 12/4/2015 2:30:52PM Page 2 COMPASS 5000.1 Build 74 I,, Baker Hughes INTEQ • 'dial !hips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3Q-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-13 @ 60.00usft(3Q-13) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-13 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-13L1-02 Design: 3Q-13L1-02_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 8,650.00 89.28 225.17 6,249.67 -4,517.26 -1,888.05 4,529.24 0.00 0.00 6,021,268.37 514,421.56 TIP/KOP 8,700.00 91.53 222.49 6,249.32 -4,553.32 -1,922.67 4,579.22 7.00 -50.00 6,021,232.24 514,387.02 8,720.00 92.43 221.42 6,248.62 -4,568.19 -1,936.04 4,599.18 7.00 -50.02 6,021,217.35 514,373.69 Start 7 dls 8,790.00 90.75 216.81 6,246.68 -4,622.46 -1,980.17 4,668.76 7.00 -110.00 6,021,162.98 514,329.68 3 8,800.00 90.69 217.51 6,246.55 -4,630.43 -1,986.21 4,678.67 7.00 94.80 6,021,155.00 514,323.66 8,900.00 90.10 224.49 6,245.86 -4,705.85 -2,051.77 4,778.36 7.00 94.81 6,021,079.45 514,258.27 8,920.00 89.98 225.88 6,245.84 -4,719.95 -2,065.96 4,798.36 7.00 94.86 6,021,065.32 514,244.11 4 9,000.00 89.01 231.40 6,246.54 -4,772.79 -2,125.98 4,878.16 7.00 100.00 6,021,012.35 514,184.21 5 9,100.00 89.02 224.40 6,248.26 -4,839.78 -2,200.12 4,977.96 7.00 -90.00 6,020,945.20 514,110.23 9,200.00 89.04 217.40 6,249.96 -4,915.31 -2,265.54 5,077.63 7.00 -89.88 6,020,869.54 514,044.98 9,220.00 89.05 216.00 6,250.29 -4,931.35 -2,277.49 5,097.41 7.00 -89.76 6,020,853.48 514,033.07 6 9,300.00 89.64 210.43 6,251.21 -4,998.25 -2,321.28 5,175.69 7.00 -84.00 6,020,786.49 513,989.42 9,340.00 89.93 207.64 6,251.36 -5,033.22 -2,340.70 5,214.14 7.00 -83.94 6,020,751.48 513,970.09 7 9,400.00 90.01 211.84 6,251.39 -5,085.30 -2,370.45 5,272.01 7.00 89.00 6,020,699.34 513,940.45 9,500.00 90.13 218.84 6,251.27 -5,166.82 -2,428.26 5,370.54 7.00 89.00 6,020,617.70 513,882.82 9,590.00 90.24 225.14 6,250.98 -5,233.68 -2,488.44 5,460.37 7.00 89.01 6,020,550.71 513,822.80 8 9,600.00 90.27 224.44 6,250.94 -5,240.78 -2,495.49 5,470.37 7.00 -87.50 6,020,543.60 513,815.77 9,700.00 90.57 217.45 6,250.21 -5,316.26 -2,560.98 5,570.05 7.00 -87.50 6,020,467.98 513,750.45 9,790.00 90.83 211.15 6,249.10 -5,390.57 -2,611.66 5,658.43 7.00 -87.55 6,020,393.57 513,699.93 9 9,800.00 90.99 210.47 6,248.95 -5,399.16 -2,616.79 5,668.13 7.00 -77.00 6,020,384.97 513,694.83 9,890.00 92.40 204.33 6,246.28 -5,478.99 -2,658.16 5,753.83 7.00 -77.01 6,020,305.06 513,653.63 10 9,900.00 92.40 205.03 6,245.86 -5,488.07 -2,662.33 5,763.20 7.00 90.00 6,020,295.97 513,649.48 9,990.00 92.38 211.33 6,242.10 -5,567.29 -2,704.78 5,849.23 7.00 90.03 6,020,216.66 513,607.22 11 10,000.00 92.42 212.03 6,241.68 -5,575.79 -2,710.02 5,858.96 7.00 86.50 6,020,208.15 513,601.99 10,100.00 92.83 219.03 6,237.10 -5,657.04 -2,768.04 5,957.43 7.00 86.53 6,020,126.79 513,544.16 10,190.00 93.16 225.33 6,232.39 -5,723.61 -2,828.35 6,047.15 7.00 86.85 6,020,060.09 513,484.00 12 10,200.00 93.16 224.63 6,231.84 -5,730.67 -2,835.41 6,057.14 7.00 -90.00 6,020,053.01 513,476.95 10,290.00 93.13 218.32 6,226.90 -5,797.97 -2,894.89 6,146.78 7.00 -90.04 6,019,985.59 513,417.63 13 10,300.00 93.17 219.02 6,226.35 -5,805.77 -2,901.13 6,156.71 7.00 87.00 6,019,977.78 513,411.41 10,390.00 93.48 225.32 6,221.13 -5,872.33 -2,961.42 6,246.40 7.00 87.04 6,019,911.09 513,351.27 14 10,400.00 93.48 226.02 6,220.52 -5,879.30 -2,968.56 6,256.38 7.00 90.00 6,019,904.10 513,344.15 10,500.00 93.44 233.03 6,214.48 -5,944.05 -3,044.44 6,355.83 7.00 90.04 6,019,839.19 513,268.41 10,575.00 93.39 238.29 6,210.00 -5,986.27 -3,106.24 6,429.37 7.00 90.47 6,019,796.85 513,206.71 Planned TD at 10575.00 12/4/2015 2:30:52PM Page 3 COMPASS 5000.1 Build 74 • Baker Hughes INTEQ • ConocoPhifli �E Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3Q-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-13 @ 60.00usft(30-13) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-13 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-13L1-02 Design: 30-13L1-02_wp01 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") 10,575.00 6,210.00 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/-W (usft) (usft) (usft) (usft) Comment 8,650.00 6,249.67 -4,517.26 -1,888.05 TIP/KOP 8,720.00 6,248.62 -4,568.19 -1,936.04 Start 7 dls 8,790.00 6,246.68 -4,622.46 -1,980.17 3 8,920.00 6,245.84 -4,719.95 -2,065.96 4 9,000.00 6,246.54 -4,772.79 -2,125.98 5 9,220.00 6,250.29 -4,931.35 -2,277.49 6 9,340.00 6,251.36 -5,033.22 -2,340.70 7 9,590.00 6,250.98 -5,233.68 -2,488.44 8 9,790.00 6,249.10 -5,390.57 -2,611.66 9 9,890.00 6,246.28 -5,478.99 -2,658.16 10 9,990.00 6,242.10 -5,567.29 -2,704.78 11 10,190.00 6,232.39 -5,723.61 -2,828.35 12 10,290.00 6,226.90 -5,797.97 -2,894.89 13 10,390.00 6,221.13 -5,872.33 -2,961.42 14 10,575.00 6,210.00 -5,986.27 -3,106.24 Planned TD at 10575.00 12/4/2015 2'3O52PM Page 4 COMPASS 5000.1 Build 74 • 4110 ConocoPhillips Fait. C011ocoPtulhpS Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-13 Project: Kuparuk River Unit TVD Reference: 3Q-13 @ 60.00usft(30-13) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-13 @ 60.00usft(3Q-13) Site Error: 0.00 usft North Reference: True Reference Well: 3Q-13 Survey Calculation Method: Minimum Curvature Well Error 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3Q-13L1-02 Database: EDM Alaska ANC Prod Reference Design: 3Q-13L1-02_wp01 Offset TVD Reference: Offset Datum Reference 3Q-13L1-02_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,650.00 to 10,575.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,251.50 usft Error Surface: Elliptical Conic Survey Tool Program Date 12/4/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,700.00 3Q-13(3Q-13) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,700.00 8,650.00 3Q-13L1_wp03(3Q-13L1) MWD MWD-Standard 8,650.00 10,575.00 3Q-13L1-02_wp01 (3Q-13L1-02) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C") 10,575.00 6,270.00 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 3Q Pad 3Q-05-3Q-05-3Q-05 Out of range 3Q-06-3Q-06A-3Q-06A Out of range 3Q-06-3Q-06AL1-3Q-06AL1 Out of range 3Q-07-3Q-07-3Q-07 Out of range 3Q-13-3Q-13L1-3Q-13L1 wp03 8,650.00 8,650.00 0.00 0.27 -0.27 FAIL-Minor 1/10 3Q-13-3Q-13L1-01-3Q-13L1-01_wp01 8,650.00 8,650.00 0.00 0.27 -0.22 FAIL-Minor 1/10 3Q-14-3Q-14A-3Q-14A Out of range 3Q-14-3Q-14AL1-3Q-14AL1 Out of range 3Q-14-3Q-14AL2-3Q-14AL2 Out of range 3Q-22-3Q-22-30-22 Out of range Offset Design Kuparuk 3Q Pad- 3Q-13-3Q-13L1-30-13L1_wp03 Offset Site Error. 0.00 usft ' Survey Program: 100-BOSS-GYRO,7700-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset ToaBace+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth ON/-S +E1-W Hole Size Centre Distance Deviation (usft) (use) (use) (usft) (usft) (usft( (1 (usft) (usft) )") (usttl (usft) (usft( 8,650.00 6,309.67 8,650.00 6,309.68 0.00 0.00 59.76 -4,517.26 -1,888.05 2-11/16 0.00 0.27 -0.27 FAIL-Minor 1/10 CC,ES,SF 8,674.98 6,309.74 8,675.00 6,309.90 0.07 0.09 -32.44 -4,534.62 -1,906.04 2-11/16 0.68 0.52 0.20 Pass-Minor 1/10 8,699.85 6.309.32 8,700.00 6,309.96 0.15 0.18 -34.00 -4,551.43 -1,924.54 2-11/16 2.73 0.71 2.06 Pass-Minor 1/10 8,724.50 6,308.44 8,725.00 6,309.84 0.21 0.27 -35.62 -4,567.70 -1,943.53 2-11/16 6.12 0.86 5.27 Pass-Minor 1/10 8,748.99 6.307.57 8,750.00 6,309.40 0.28 0.36 -39.92 -4,584.02 -1,962.46 2-11/16 10.00 1.00 9.00 Pass-Minor 1/10 8,773.37 6,306.95 8,775.00 6,308.55 0.35 0.44 -45.47 -4,600.82 -1,980.95 2-11/16 13.85 1.12 12.73 Pass-Minor 1/10 8,797.93 6,306.58 8,800.00 6,307.28 0.42 0.52 -50.35 -4,618.07 -1,999.00 2-11/16 17.68 1.22 16.46 Pass-Minor 1/10 8,823.32 6,306.30 8,825.00 6,305.60 0.50 0.61 -52.81 -4,635.76 -2,016.58 2-11/18 20.53 1.30 19.23 Pass-Minor 1/10 8,848.86 6,306.08 8,850.00 6,303.50 0.57 0.69 -55.79 -4,653.88 -2,033.68 2-11/16 22.11 1.36 20.76 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/4/2015 3:33:19PM Page 2 COMPASS 5000.1 Build 74 . • Project Kuparok River Unit • 944,...,,0",."°e'"s'1. WELLBORE DETAILS:30-1301.02 REFERENCE 8840+0050+ Site:Kuparuk 3Q Pad d CnebaUBLE)Raleeaa Wd3R13.TivaNa9 � Well:3Q-13 T/ "-nervs,ra Parent ie on MD:3Q-13L1 �IReeence Wellbore:JQ-13L1-02 (Wll'(1 s'°wC^-sTesi°r,r Tie on MD:5850.00 RAM 3�� ((�'3(,�, ]j ORa evas° Mean SealexA sramryslRieeKa:sd-(aoov,o.aoEl �Fl � 14Vt41--1 Al�1l� Wellbore: (3Q-1343Q-13L1-02) reaDate MM. lecoRcros Meearedoecm Reiemw:3013i3600)A113013) Catdaan Mnm HUGHES WELL DETAILS: 3Q-13 -34 I■■■■■■■■■■■■■am•••u +N/-S +E/-W Northing Easting Latitude Longitude -3600 111111111111111111111111t11111111111 0.00 0.00 6025789.31 516299.52 70°28'53.925 N 149°52'0.528 W .3000 1111111111111111111111rllg11111111111 Sec MD Inc Ali TVDSS +N/-S .5/-W Dleg TFace VSect Annotation 1 8650.00 89.28 225.17 6249.67 -4517.26 -1888.05 0.00 0.00 4529.24 TIP/KOP -40002 8720.00 92.43 221.42 6248.62 ■■■••■■•■ , 3 8790.00 90.75 216.81 6246.68 68.19 14 7.00 310.00 4599.18 tart7dls -4622.46 -1980.17 7.00 250.00 4668.76 3 -4200 •■••■•••■■,��' �■•■r 4 8920.00 89.98 225.88 6245.84 -4719.95 -2065.96 7,00 94.80 4798.36 4 111111111111111111.2.�11��1111111 5 9000.00 89.01 231.40 6246.54 -4772.79 -2125.98 7.00 100.00 4878.16 5 9-4400 1111111111111111� 111111111 6 9220.00 89.05 216.00 6250.29 -4931.35 -2277.49 7.00 270.00 a � � 5097.41 6 7 9340.00 89.93 207.64 6251.36 -5033.22 -2340.70 7.00 276.00 5214.14 7 7-4.r 1 8 9590.00 90.24 225.14 6250.98 -5233.68 -2488.44 7.00 89.00 5460,37 8 0 ■■■■■EEEF,rwgg3Q-13i �■.■, 9 9890.00 90.83 211.150 6249.102 -5390.57 -2611.66 7.00 272.50 5756.83 9 I-4a 1 ■■..■■■12����■■■■■., 10 9890.00 92.40 204.33 6246.28 -5478.99 -2658.16 7.00 283.00 5753,83 10 + ,/ 11 9990.00 9238 21133 6242,10 -556729 -2704.78 7.00 90.00 5849.23 11 srrl 12 10190.00 93.16 225.33 6232.39 -5723.61 -2828.35 7.00 86.50 6047.15 12 0 11111111 �EI■®�11111111111 13 10290.00 93.13 218.32 6226,90 -5797.97 -2894.89 7.00 270.00 6146.78 13 z 5211 4 14 10390.00 93.48 225.32 6221,13 -5872.33 -2961.42 7.00 87.00 6246.40 14 �` .■■� IN11111111111111111111111 15 10575.00 93.39 238.29 6210.00 -5986.27 -3106.24 7.00 90.00 6429.37 Planned TDatl0575,00 0-5.1 1111 r 11 i��.�M111111111111111111111 -5858 I■u11iAM/■11■■■■■■■■1 111111111E11®1111■■■■■111 -62"11111■iIENEMEN1111■■■11■111 I......manzz-02 •••••••••••• -4000-3800-3600-3400-3200-3000-2800-2600-2400-2200-2000-1800-1600-1400-1200-1000 -800 -600 -400 West(-)/East(+)(200 usft/in) 5780 5865 - a sl 1'- [• 5950 4 q 4 !A n .:i d t.2, ❑ 6035''' 0.). b A a e'ri In - 3Q-133Q-13.1-01 00 I 6120 E. TI SKOP 43 6205 Q _ 1 .,3813138 311 6290 � - l ' 11 12 13 14 Planned ID at 19575 0e � Star7 dla 4 5 r 7 8 9 1( 3Q-133Q-13.1-112 Ii) 6375 4) ] 7 6460 �' 3Q-13/3(J3 6545 6630 3Q-1:0_F1410 3r}13L-F1Wt2 3Q-1 L_FaWtl Mean Sea L64.1 3570 3655 3740 3825 3910 3995 4080 4165 4250 4335 4420 4505 4590 4675 4760 4845 4930 5015 5100 5185 5270 5355 5440 5525 5610 5695 5780 5865 5950 6035 6120 6205 6290 6375 6460 6545 6630 6715 6800 Vertical Section at 225.00°(85 usft/in) 0 • KUP INJ 3Q-13 ConocoP it ips �` wet Attributes Max s MD TD ,!1Otb PWW rTalililnU �WlE6oia1 $4"es 110111_ 2,09062,96 411l8im)01511k.":)$ ... .3729 664_.: KT1riSREiYR11$A#33k1T 743 a4 .?. 3 1127-.0 kl.a3': ... t;s!R•'Raalt 1123:557: Pale .4nastltoa £M0WD KG-6n6 fMI Rtg Ra4mm/colt 19511-9.7/00 727.. ..2777 :..,1,.. 42.5' . 55 2222.. t--•-.. -< 22224:119x;5911101, Cosi/410KB4 Ent DM. 00:11011101 12033122 ay &4015e .r,.32.1 7^94;_6 2:'s. Row Ross,.17.3SICeD :F"vim' 1523,2915 It:',1;II Cassng Strtn9s Coon Csesnpncr. 00$31111 110/1111 Top4011081 Sat coots{1I1781 S1£85111)114422.W55.111 is.10330. T6p123N210 ICL/ TO?. '5 '5052 3 3 7529. 62.50 44.49 115.1011/ Casing G 0115101 004114 401.11 22p 301201 Sot 0001:1108 3910451114190/..-WSYan.41. Grua Teo TIUMo 2-L115422 9 0x2 2 755 .17 1 713 9 53.013 3.55 6T£ ..91 gC Ipikr OD 4104 ID 4114 Top 410451 Set CWtl4365, 540941041564...Wtlt.an.II... Too-Mond101, Tood tiv._.i.v..n v..v.n_.�/ .s- f2J_2IO^i 5276 34,3 9.924 559.7.2 29.5,23-.15 013 �u Tubing Strbrgs Il 7 2,9;CsmOstor Strtn4 Ms...10401 Top 411118) Sot Depth III 91 044511147VD1 4.-.W143sA14 Grads Top 00011011011 .2 2-7+52 3425 7.5E5: 6,127,7 9363.557 0463..3 I Completion Details 0S..'ac2022 If23,120 ` n4,1-5,2 T05.1051 125 T."Ci:TIKEI TCC 150-1 001 296 .:1 al34.i� 31, '3 1�-,_er 'wV2u4:•. z:-g_ - ; 7.551.2 5'12 5 4'.2' x:355", _.s.. b1�^ :7969II Sc,4 5"+ 4'..E" .r_.a.b 539135'++ 27 Soo.. c 5'7wc _. Tu51 g 105101 tlna [51084 Etalffi 1111) dross/Swot s1 coots;rc._es0 ,511,41041; Wt;9314 13000 �rop cormaels0R 2 Y:v. 7:5€5 5 7 7 0 4.597 3 10 29.-20 540 275 P == Completion Details L4Tv+,ir.ro1M LM.i,SOB l . Top Y2KE7 132 T.. .111,5, 1 F 11.4;' /tier Get ?',579 __� {1116 5.1 14 4'; _.e' .E'T<. 5901£' 1.623 - S"'^95 4'.77 a 3 574 PER 3-223-2 5'445 4'..54 .00 1 os coo.o 747-ru;,1,,f,:3;..2,-g. 3515 11 , � ..,b .r 2 5. , 4•.44 Lh .... 7 13.20 xr S+.6: _ .a_. =34: 4':.+13 _ 5.277 ..74-2 e 4 Goer In Hole(WSretine ren vat#:Hugs.vato+es,pumps.fists,etc.) l r 1V2.. 1;: o 10p43105x mos, Dm _1T Run 011 124Ki IA .'!061110 59997'3-':94034 ;272975 2.963 wow.--eem,..LSE, ill Perforations&Mats GN.e 4 lap)TVO1 51.7.41/51';'' {912,100 555 023283 811015110) 70110®t 1905: 3 .v Date Ii Ty50 7.743.'3 7.755.0•. 5,547.1 92%.1 0-3,30-13 _:42003 4.3 95A.E13F 0+a•am-a✓nrte'.4230 11AK 7.784.; 5.755.9_ 9277.: h-2.30-13 32.._.330 4.: 5.7E _ 3II 7 793 3 . 11 7,828.0 £,:52.3 6,217.5 R-1,30--13 3 29 7737 4.3 515 5 _.. J 1191.01:a.+'a9YTpc411 Mandrel Inserts II 1 aOP l op{TW; 'valve Latton Polt Sys TRO Run 19 105010EO HONES 100. M.;e 3,2'.71: Scan Typo Typo 011) 4514 Run Dols Com 47,47, RK 1.500Ile-2.220.55 2 4.222.7 71:7,4 '.,.1 S Damm RK 1.530' 11/22/2015 lit Y 293'S {,5`7.7 1.3E.,,,, 30,3 Dumm 'RK 1.500 `1522/27.:5 Y 4 4 51131 9 5.2...'""22ryr-c .3 Damm RK .ssn 2;2:15 lilt 3332 5 7.3992.5, 5 74'..5 D.om.yes ".73 - Dorms RK 5.500 17/2927I 5 .55' ^?'2."5 ' Y _ 7 M.7 4 6757.3n..5 51.4D. 3.5'1 8121 '._509 12-20'5 7. - - taWi lodes_Genera:&Safety ;. r E 2019 1,ct11cn MI .,.15:777 ..521-75 V.EI.1_.,-,__so.:r_s.mas=s_s r- A. R=04:7,Y110.0.;7110P* 0 I Psicr,,Ol 12OE-lin 9_1 L • • 3Q-13 Proposed CTD Sidetrack 3Q-13 Proposed CTD Schematic Modified by JAB 11 15 AB... t 3-1/2"9.3#L-80 EUE 8rd,AB-Mod tubing to surface 3-1/2"Camco MMM gas lift mandrels:2690',4323', "` '�" 5551',6401'&7062' 3-1/2"Baker Orbit deployment valve at 3509'MD Note:2.835"min ID,no nipple profile 3-1/2"SOV @ 7502' Packer 7565'MD 3-1/2"X-nipple 7606'MD(2.812"min ID) 16"62.59 11-40 shoe @ 115'MD 5-1/2"Big Tail Pipe configuration 7681'-7770'MD I 9-5/8"369 J-55 shoe @ 4325'MD 7680'MD 1 Crossover 3-1/2'to 5-1/7'liner Vented/Ported for installation a47 Ilia 1101 7745'proposed TOWS depth I 3Q-131_1-01,Planned TD=10,575'MD ',....,_,.::�`�` 2%"slotted liner with billet at 8650' ‘ \ :/ '�♦-, -• --- 7743-7828' 1 \\ 30-131_1,Planned TD=10,575'MD ♦ 2%"slotted liner with billet at 8990' _______________ 30-13L1-02,Planned TO=10,575'MD 2W slotted liner 7670'-10,585' 7"260 J-55 shoe 02 8168'MD • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: IR(1,. 3Q - /31,1 PTD: Q15-01./ _Development ✓ Service Exploratory Stratigraphic Test Non-Conventional FIELD: ky,,,t,i<RIVE,f— POOL: KIA706ftV4.,? X #1 a) 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 existin well Permit LATERAL No. /g(, - / , API No. 50-0a9 - GG - CM- OO. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • 0 Iii 7 w , CA p o a , U1 N a0 0• j. ca. • c a3. , C L, , �'. C) 3. L To E , I CO C 0 c `* o. c. O Z �, .CO 2 w' cocCO uy E O a )ai a o Ul' o of U O C V. a >, c 3 a) a = a) °, v' c c y, a o a� o o 3. ° ZZ; ° N a >. ami o°f a o. 0. 3. C, 1._ N, M•, U) O� n;, a). gip. O 3'. N. o' ° _o .. 3, co a) d _a c c w. oa a) rn a c ▪ CD `�� .0 ate) o 4 �; �� a 0. i� • E cc) r. a) V a E N 0 _ Z, >• '� O• O. C. C y. a o. �. di y. c E. E, a p rn m. E 2• D'. I - - 1.0 ri; c'. r). a E' a m' �� �'� �'� CC N co .. c. M. 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