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212-088
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ai a- 6 g "WeII History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Date: _ `j /s/ U (J Project Proofing BY: Date: illaolizt. /s/ 7 Scanning Preparation I x 30 = 3o + az =TOTAL PAGES 5 BY: Maria Date: ' l/go/it/ (Count does not include cover sheet) /s/ ' r ` Production Scanning Stage 1 Page Count from Scanned File: ...c3(Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria ..) Date: j ! caO `q- isii11/1 to Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked II 7/8/2014 Well HistoryFile Cover Pae 20140708.doc 9 _ C a) J 0 ui) I.° N 4•a) N + Q < < ►, w to cc > E rn� D a a / Z/ V Z N �( r 0 co a)w coo, CO a r >- r N0 ° 1 m , a 2E o °L� a m o D E = ai N9 �I c 00 0 0 c a w0 c) g c u co co o EI- w—T• aa)i �.�0 C. 0 c ! a 0 N ,I T m E w>E 2 °aE 0 E 0L ° o '!I Z Z V 'OC)) a) > 2ccaa Dna) ao #v I a ° o II a u) 1 c 2CCa 1-110 2�CC 20 0 + 0 o Til I a ITos 2 c O N N N N N O O f0 O O .0 a U U J ,Z O In o 4, N N N N N /> I M M M M > D J N N N N M ) U E co co co co n c Q Q � a) Z / Z 3 I 2 c c c c c E -- Cl) iii - o 0 0 0 0 0 0 E r r IX 0 � / C li Q m to o co co co co co ` 0 ii � UI Z N 0 ENE m p w 7 ö m a c t o) a) rn rn o to Z - rn Ce O I , N N- N- co) N- N CD co ii E W Z o y , ° V ZU / I cu m m O. Z +o c7 O „ ?? 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O 6 c CC � C � , 1I ON a co E Chi• o U 1 Q co O F— N N I- N z O 1 5 N co • N a' n I Iii (/) a o ii► Q a 0 I— Y a) Qz E d U E co z m • coL co 2:3 CCIMI N I 3 v 74- N Q. w CI O V O c w to '= a E ii i 0 0 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION A!I r 2 ; WELL COMPLETION OR RECOMPLETION REPORT AND LOG la Well Status Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1-1,WeII'Class: i rl -;5;,,i 20AAC 25.105 20AAC 25 110 Development ❑ Fzxploratory ❑ GINJ ❑ WINJ ❑I WAG ❑ WDSPL ❑ No.of Completions: Service ❑, Stratigraphic Test❑ 2 Operator Name 5.Date Comp,Susp., 12.Permit to Drill Number. ConocoPhillips Alaska, Inc. orAband.: July 23,2012 212-088/ 3 Address: 6.Date Spudded. 13 API Number P.O. Box 100360,Anchorage,AK 99510-0360 July 18,2012 50-029-21157-64 4a Location of Well(Governmental Section): 7.Date TD Reached: 14 Well Name and Number: Surface: 5111'FNL,551'FEL,Sec.23,T11N,RO9E,UM July 22,2012 2D-05L1-02 Top of Productive Horizon: 8. KB(ft above MSL): . 126'RKB 15.Field/Pool(s): 46'FSL, 1935'FWL,Sec. 13,T11N,RO9E,UM GL(ft above MSL): 79.4'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 4528'FNL,3032'FEL,Sec. 13,T11N,RO9E,UM 10011'MD/6157'TVD Kuparuk River Oil Pool 4b Location of Well(State Base Plane Coordinates,NAD 27). 10 Total Depth(MD+TVD): 16.Property Designation: Surface: x-529214 y- 5954367 Zone-4 10018'MD/6158'TVD ADL 25653 TPI: x-531675 y- 5959534 Zone-4 ii SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-531985 y- 5960241 Zone-4 1888'MD/1764'TVD 2579 18 Directional Survey: Yes ❑., No❑ 19 Water Depth,if Offshore 20.Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 3934'MD/3233'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071): 22 Re-drill/Lateral Top Window MD/TVD GR/Res 7845'MD/6128'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 35' 116' 35' 116' 24" 224 sx Coldset II 9.625" 36# J-55 35' 3823' 35' 3159' 12.25" 1075 sx AS III,685 sx Class G 7" 26# _ J-55 33' 7971' 33' 6345' 8.5" 625 sx Class G 2.375" 4.7# L-80 7620' 10011' 6027' 6157' 3" slotted liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. __ TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 7110' none slotted liner 7624'-10015'MD 6028'-6158'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. r "IY1ZION ' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none I0.,;6741' _ 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired' Yes ❑ No ❑✓ Sidewall Cores Acquired' Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summanze lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE 4'1)0' ElDMS AUG 2 3 2012 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only ORIGINAL �e)'z Y',� e 28. GEOLOGIC MARKERS(List all formations and m. .encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 3934' 3233' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk River 7845' 6128' Kuparuk A4 8537' 6143' Kuparuk A4 8619' 6135' Kuparuk A4 9216' 6132' N/A Formation at total depth: Kuparuk A4 30 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger©265-1102 Printed Nam Gantt Title: Wells Supervisor Signature -+o.-U..6 Phone 263-4021 Date Z/ 2 ZZ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 ..p1. P KUP 2D-05L1-02 Conocoilli W.5 Well Attributes Max Angle&MD TD Alaska,,Inc ""ss*" Wellbore APWWI Field Name Well Status not C) MD(1U(B) Act Btm(ftKB) co,,,L„R,Ikp, 500292115764 KUPARUK RIVER UNIT PROD 10,015.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "•" Well Contig.-2D-0SLt-02724120122'.19:37 PM SSSV:LOCKED OUT Last WO: 46.60 9/20/1984 Schematic-Actual Annotation Depth(ROB) End Date 'Annotation Last Mod...End Date Last Tag: Rev Reason:LATERALS ninam 7/24/2012 tS, Casing Strings Casing Description String O... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd � LINER L1-02 23/8 1.992 7,619.0 10,011.1 4.70 L-80 STL HANGER,33 1 Liner Details 'Top Depth (TVD) Top Incl Nomi... III Top(ftKB) (BOB) C) Item DescriptionComment ID(in) \ 7,619.0 DEPLOY DEPLOYMENT SLEEVE"SHORTY" 1 992 8,200.7 DEPLOY DEPLOYMENT SLEEVE"SHORTY' 1.992 IIIII CONDUCTOR, II Perforations&Slots 35116 Shot Top(TVD) Btm(TVD) Dens Top(RIM)Btnl(RKB) (MB) (ftKB) Zone Date (ah-- Type Comment .=,. 7,620 8,190 7/22/2012 32.0 SLOTS SAFETY VLV. 1,888 8,202 10,011 7/22/2012 32.0 SLOTS Notes:General&Safety End Date Annotation GAS LIFT, 7/24/2012 NOTE:ADDED LATERALS L1,L1-01,L1-02 2,091 ppp. 7/24/2012 NOTE:LATERAL 2D-05L1-02 OFF MAIN WELLBORE(See Multi-Lat Drawing) II II SURFACE. J L. 35-3,833 /A� FISH,4,210 -- _L GAS 4LIFT. .228 GAS LIFT, 5,739 GAS LIFT, 6.860 GAS LIFT. 7.337 MBR,7.383 PACKER,7,397 ')',l:£31vAt=.'-w GAS LIFT, .1-14 7,436 GAS LIFT, 3 7.502 PERF, 7,5347,5478 ri GAS LIFT. 7,605 TBG Punches, 7,616 LOCATOR. 7,622 PACKER.7.624 MILLOUT, 7,626 NIPPLE.7.639 WHIPSTO7,63CK, 9 SOS,7,643 Mandrel Details IPERF, Top Depth Top Port 7,678-7,688 (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (RKB) (°) Make Model (in) Sery Type Type (in) (psl) Run Date Com... 1 2,091.4 1,918.6 40.81 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28J1994 7,700-77422 4,227.6 3,438.0 45.02 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 SLOTS, 7,620-8,190, 3 5,739.4 4,538.2 41.42 MMH FMHO 1 GAS UFT DMY BK2 0.000 0.0 9/2&1994 PRODUCTI 333-797N, \ 4 6,859.9 5,389.5 38.93 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 12/17/2006 5 7,336.5 5,777.8 30.07 OTIS OVAL 1 1/2 GAS LIFT DMY RO 0.000 0.0 10/2/1989 6 7,435.7 5,863.9 28.69 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/27/2008 7 7,502.4 5,922.5 27.97 MMH FMHO 1 INJ DMY BTM 0.000 0.0 6/3/2012 SLOTS. 8 7,605.2 6,014.4 27.09 MMH FMHO 1 INJ DMY BRO...0.000 0.0 10/14/2004 8,202-to,ott LINER L1-02. 7,6t9-10,011 TD (2D-05L1-02), 10.015 N O N o 0 N_ m CoCC cO Yz T7-') U) LL co c -c p 3 p �h.1 I-- oro C — V V r in o 00 N- rn .o V � = o o u E O _� v 9 ii N O N N CO p p CV OF Q Y O Q Q^ N O p r O V - V p r O) mN co 2 ^\'C oro co Y cc ao a) Q m 1 a- Y H `" Via) ns Q � .� o � aU mr E m c °' co N M C r Y M O)N N > r O - N- c 0 CO (o W N g g- r a r Cn D -6 V O �` C �1 Jw R m a) V O V Yo o N LL d (0 Q Q v L O N 4— p Q) N Q I .-- W C V E C M m O) _m co u_ m 2 m O O 2 a3 CY, N N N (V a) a) (V a) N C N N �c ‘• '--;;, Y Y Y --Y9 i `- co co i (0 O 7 i UO ti M M M m m co m m F- A M Q O 0.O H III 1 1 , i,'ills ,,. 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CO CD O CO O I, C) M VCO r- V1,, O N V0) O co v) aN- W 0N M N CO CD I- 0) N CD CD 6 0) 0 0 C- O V Q N N N N N N N N N CO CO CO CO CO CO CO CO CO M C) E `� O O 00000 O O O O O O O O O 0 0 0 0 0 0 00 (O (O O (O O CD cci coO tO CO coO O CO CO co- CD O co- co- CO (D co- -; co co I,- N N- 00 CO CO (D U) V CO O N N- CO O V N- C) N V u) c- V M CO CO CO CD CO O CO O I"- C) CO V CO V I,- CO N CV) O E N C) V CO N- 03 0 N N C) L 00 ,- N V u) N V CO O N- U - V Cr V V V V V V co co co 0 0 u) CO CO CO CO CO CO CO CO co 0 C O O N O O O (O co-- fD (O tD O t0 N (D (O O CD tD O O O (Ti (O 00 - .. u) R :.-• _ C V CO V (n N V CO CO 0 C) CO CO O 0) 0 O CO 0 (n O M oo co CO Q D 'O co CD V V N- u) C) O In O N- N N- O N N CO CO u) O N t0 (O (/) N •C y C) N V O 4 O CO O 4 O V O N 4 1: O 0 1: O 0 (O I- V V (� - 1-c° (V] N CO 0 .- c- N N N CO CO CO V V V V !X!) ] CO a E o •_ -Y Y _ 0 (♦i ID ID ID .- 0 0 O V co V N ,- 0 N (O N O C) CO u) N- CO 00 CO C O. n 0 0 0 f.7 7 O V O N N". V (O 7 7 N N 0) u) CO O O O I.- N M CO 0 7 7 r 00 <5 co h o N- I` CO O co co N u) 00 CO O O .- V N 0) cO ) U Y Y C C3IU C3ID c C CO CO CO 03 00 0) 0) oz) co co aD co co co co oD co oo co co a) a) co a) a AS VC)O O COO N N V COC) 0) I` COM a N N COM C) COC) CO COO (n N O N O �'. O N co t` O O O C V C) V O (O u7 CO u) u) N V CO CO V u7 O T .. CD (O (n (n u) CO O (n O O O V (n u) N u) u) O (n O u) (n N- O C C Q V n 0 CO O O N (O 0) N (O 03 V r O CO CD O N u7 N- r- N co j, O c 2 g COCO C) V v v V (n co. co co O CO n ti t` co CO co. W co. O co. O OO. co co C) of O co 0) ai on ai m m co co m m co ai co ai co ai m o O V E o m m 3 M tiav� 3 � Q _ rn Q ConocoPhiIIips Time Log & Summary We'Mew Web Reporting Report Well Name: 2D-05 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 7/5/2012 11:00:00 AM Rig Release: 7/23/2012 11:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07/04/2012 24 hr Summary Excempt rig move Start at 21:00 HRS. 21:00 00:00 3.00 MIRU MOVE NUND P Excempt Rig Move from 2K-14 to 2D-05. 07/05/2012 Move rig to 2D pad,MIRU. ****Rig Accept at 11:00 hrs**** Complete BOPE Test.Witness waived by John Crisp,AOGCC 00:00 11:00 11.00 0 0 MIRU MOVE MOB P 05:00 Arrive on location.Spot Sub& Mud Module over well.Spot shop, Rig up hard line&cellar. Rig up scaffolding after secondary containment put down. 11:00 15:30 4.50 0 0 MIRU MOVE NUND P ***RIG Accept.*** NU BOP's on Stack. Repair hydraulic seals on lower two bonnets.Grease the Tree. IA=268/ OA=35 psi. 15:30 16:30 1.00 0 0 MIRU WHDBO BOPE P PJSM-Begin BOPE testing 250 low /4000 psi High.***Waived by John Crisp*** Troubleshoot remote valve operations of hydraulic lines. refill stack&lines. 16:30 18:00 1.50 0 0 MIRU WHDBO BOPE P Start test number 1. 18:00 00:00 6.00 0 0 MIRU WHDBO BOPE P Complete BOPE Test,Had to grease and retest C-15 07/06/2012 Trim 2200'coil, Head Up, RIH,mill cement 7522 to 7590 00:00 00:15 0.25 0 0 MIRU WHDBO PRTS P Pressure test TT Line to 1500 PSI 00:15 02:00 1.75 0 0 MIRU WHDBOOTHR P FMC on location, PJSM, R/U and Pull BPV, R/D lubricator and load out 02:00 05:00 3.00 0 0 MIRU RIGMNTCTOP P PJSM, R/U Pump in sub on bottom of injector, R/U CT Cutter and cut— 2200'CT 05:00 08:00 3.00 0 0 MIRU RIGMNT CTOP P Crew change PJSM for cutting pipe. Currently 800'into cutting. 08:00 09:00 1.00 0 0 MIRU RIGMNT CTOP P Done Cutting 2200ft of Coil.RD cutting equipment. Setup to perform slackmanagement.(Install external CTC to prevent pipemovement upward, boot end of eline.) 09:00 11:30 2.50 0 0 MIRU RIGMNTCTOP P Line up pumps and perform slack. Test Inner reel iron and pac off.Good test.30ft, Found wire.Good test on eline.Crew change 11:30 13:30 2.00 0 0 MIRU RIGMNTCTOP P Install CTC, Pull test to 35K. Head up BHI UQ. Page 1 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:30 14:30 1.00 0 0 MIRU RIGMNT SFTY P Plan Foward meeting with rig crew 2D-05.Well OPS for 2F-11 included. 14:30 16:00 1.50 0 62 PROD1 WHPST PULD P PJSM, Line up to check well head pressure,WHP Opsi.MU BHA.9 AKO 2.80 D331 16:00 17:48 1.80 62 7,420 PROD1 WHPST TRIP P RIH with EDC open pumping .9 bpm 17:48 18:18 0.50 7,420 7,493 PROD1 WHPST DLOG P Log K-1 Marker for-14'correction 18:18 18:30 0.20 7,493 7,522 PROD1 WHPST TRIP P RIH and tag TOC @ 7522, Pull up hole,PUW=31 K,Continue rolling well to 2 PPB Biozan 18:30 18:48 0.30 7,499 7,521 PROD1 WHPST CIRC P Biozan all around,S/D Pumps and close EDC, Pumps online 1.5 BPM @ 2700 PSI FS,trip in to mill cement 18:48, 19:30 0.70 7,521 7,545 PROD1 WHPST MILL P 7521',See WOB and Diff pressure, TF=20 ROHS, initial ROP=40 to 50 FPH @ 1500 Lbs WOB 19:30 19:54 0.40 7,545 7,548 PROD1 WHPST MILL P 7540', ROP @ 22 FPM,WOB=1.47, 1.48 BPM,Good cement at shaker 19:54 20:00 0.10 7,548 7,548 PROD1 WHPST MILL P 7548',Stall, PUW=36K,ROP was down to 15-18 FPH,Clean P/U, Bring pumps online, RBIH to mill 20:00 21:15 1.25 7,548 7,565 PROD1 WHPST MILL P 7548', Mill, 1.45 BPM @ 2725 PSI FS, ROP=12-14 FPH @ 1.55K WOB 21:15 22:57 1.70 7,565 7,585 PROD1 WHPST MILL P 7565', ROP=12-14 FPH with 2K WOB, 1.46 BPM,300 PSI Differential 22:57 23:27 0.50 7,585 7,585 PROD1 WHPST MILL P 7585,Stall in GLM area multiple times, PUW=40K off bottom with pumps off, Dragging 31K. Bring pumps online, 1.45 BPM @ 2700 PSI FS, RBIH to mill. 23:27 23:57 0.50 7,585 7,590 PROD1 WHPST MILL P Unable to get past, roll TF to 210, get past and roll back to 20R at 7585.9 23:57 00:00 0.05 7,590 7,590 PROD1 WHPST MILL P 7590.2 Stall, PUW=36K Midnight Depth 7590.2 07/07/2012 Mill Cement pilot Hole to 7670, Run Dummy Whipstock,R/U and RIH with E-line tools 00:00 00:45 0.75 7,590 7,594 PROD1 WHPST MILL P Continue milling pilot hole, ROP=10-12FPH @ 1.5K WOB 00:45 01:15 0.50 7,594 7,596 PROD1 WHPST MILL P Stalls, PUW=37K, Roll TF to 180 to get by,roll back to 7594.7 01.15 02:51 1.60 7,596 7,606 PROD1 WHPST MILL P Stalls @ 7596.1 roll TF to get back on bottom. 1.47 BPM @ 2700 PSI 02:51 03:39 0.80 7,606 7,615 PROD1 WHPST MILL P 7606.2,Stall, PUW=36K,7607.4' 03:39 04:15 0.60 7,615 7,614 PROD1 WHPST MILL P 7614.6,Stall, DHWOB=1.7, PUW=34K,stalled three times at same spot, roll TF down to pass, stalled @ 120R, 180,210, 04:15 04:45 0.50 7,614 7,460 PROD1 WHPST WPRT P Wipe to TOC,Add 776 to Biozan, Multiple overpulls on trip up, Hung up at 7548,work free Page 2 of 15 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 04:45 05:03 0.30 7,460 7,614 PROD1 WHPST WPRT P 776 close to mill,trip in hole, 1.5 BPM @ 2840 PSI FS, RIW=13.5K, trip down to 7575 see some bobbles, PUH to 7510,Clean up past 7548 05:03 06:03 1.00 7,614 7,616 PROD1 WHPST MILL P 7614',Clean trip to bottom, 1.47 BPM @ 2730 PSI FS, lightly touch and stall. Right in area of tubing punches 06:03 06:33 0.50 7,616 7,623 PROD1 WHPST MILL P Crew change,Continue milling-1.50 bpm,3200, BHP 3350, ROP 12, WOB 1.5K,Ct weight 14K. Stall at 7623'-P/U weight 30K 06:33 07:03 0.50 7,623 7,623 PROD1 WHPST WPRT P Wiper up past TOC-Tie in zero. 07:03 09:33 2.50 7,623 7,655 PROD1 WHPST MILL P Mill ahead-1.40 bpm,2900, BHP 3307, ROP 12-14,WOB 1.6, Ct weight 15K.Small ROP loss @ 7628'. Increase ROP @ 7629' WOB gain&ROP drop @ 7639' 09:33 11:03 1.50 7,655 7,670 PROD1 WHPST MILL P Stall P/U 30K-drilling ahead-1.40 bpm,2800, BHP 3263, ROP 12, WOB 1.7K,CT weight 14.5K. 11:03 12:03 1.00 7,450 7,670 PROD1 WHPST WPRT P P/U weight 30K-wipe up&tie in with zero correction, RIH-pump 20 bbls used flo-pro sweep on bottom. POOH for dry drift. 12:03 12:33 0.50 7,670 7,500 PROD1 WHPST FIT P Dry drift looked clean-very small DH weight bobble @ 7640'.Static test. 12:33 14:33 2.00 7,500 62 PROD1 WHPST TRIP P Test Expro's encoder for camera run, good test, POOH pumping 2#Bio. 14:33 15:03 0.50 62 0 PROD1 WHPST PULD P OOH, Check well for flow, Unstab Injector Head, LD Milling BHA#1, OOH with tools,Gauge bit«« 2.79 ODnogo-2.80ODgo»»> 15:03 16:33 1.50 0 71 PROD1 WHPST PULD P MU Jetting Assy.Jet BOPE and Choke. PJSM P/U Dummy WS BHA. 16:33 18:18 1.75 71 7,460 PROD1 WHPST TRIP P RIH pumping.3bpm. 18:18 18:30 0.20 7,460 7,481 PROD1 WHPST DLOG P Log Gamma tie in to K-1 for-16' correction, PUW=30.5K @.3 BPM 18:30 18:48 0.30 7,481 7,670 PROD1 WHPST TRIP P RIH to drift pilot hole down to 7670 clean trip running in cement to bottom 18:48 20:42 1.90 7,670 69 PROD1 WHPST TRIP P Trip out of hole PUW=31.5 off bottom with.45 BPM 20:42 21:42 1.00 69 0 PROD1 WHPST PULD P At surface, Flo Check well, PJSM Lay down dummy whipstock BHA 21:42 00:00 2.30 0 0 PROD1 EVALWE ELOG P PJSM with HES E-line services, R/U E-Line and run Multi Finger Imaging Tools 07/08/2012 Complete E-Line caliper run,set whipstock, Run Expro camera 00:00 02:30 2.50 0 7,669 PROD1 EVALWE ELOG P Run Multi Finger Imaging tool on HES E-Line,Tagged TD @ 7669 02:30 03:30 1.00 7,669 0 PROD1 EVALWE ELOG P At Surface with E-Line caliper, PJSM to lay down/Rig down E-Line Page 3 of 15 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 03:30 05:00 1.50 0 72 PROD1 WHPST PULD P PJSM, P/U 3 1/2 Mono Bore whipstock with cement slips, No Kick pad or fishing neck. Make up to Coil Track and surface test tool string 05:00 07:30 2.50 72 7,649 PROD1 WHPST TRIP P RIH pumping.3bpm with EDC open. Tie in K-1,Minus 13ft correction. RIH to 7649.53' 07:30 08:00 0.50 7,649 7,649 PROD1 WHPST WPST P Close EDC-WOB zero,CT string weight 19.8K. HS-pressure up to 4100psi.WOB 2.2K,set down 4K WOB. Paint flag for camera run-7650'/ EOP 7578' 08:00 09:30 1.50 7,649 7,630 PROD1 WHPST CIRC P P/U 20' and rig up LRS to circulate Clean SW for camera run, 1.5 times wellbore volume. POOH pumping clean SW,tie in zero correction. Flag EOP 7402' 09:30 11:30 2.00 7,630 62 PROD1 WHPST TRIP P POOH laying in SW-total pumped 140 bbls. 150 bbls left for camera run. 11:30 12:30 1.00 62 0 PROD1 WHPST PULD P Flow check, PJSM-lay down BHA. 12:30 13:30 1.00 0 11 PROD1 WHPST PULD P PJSM for rigging up camera BHA& cables.Test E-line,found a bad cable from Putz to camera panel. Repair jumper line. 13:30 14:00 0.50 11 11 PROD1 WHPST SFTY P pre-spud meeting with Gary crew. 14:00 16:30 2.50 11 7,413 PROD1 WHPST TRIP P RIH pumping.5 bpm.View is quite murky through filtered water. Correction minus 10ft at flag. RIH 20 fpm 16:30 17:00 0.50 7,413 7,639 PROD1 WHPST CIRC P RIH 20 fpm,pumping 1 bpm. Poor view due to Bio once we stung out of WS.Get to WS and jet clean fluid. Increase pump rate to 2 bpm. 17:00 18:30 1.50 7,639 7,639 PROD1 WHPST DLOG P Ran out of SW, use clean vac truck and take on 100 bbls clean fresh water. Log the camera up while transfering water. P/U weight 30K. 18:30 20:30 2.00 7,639 7,639 PROD1 WHPST DLOG P Image cleared up while waiting on water/crew change. Log up.5 FPM to 7625 clouded up,Start fresh water down coil 1 BPM, RBIH to 7639 20:30 23:30 3.00 7,639 11 PROD1 WHPST TRIP P Made multiple passes up and down. Last pass up-POOH 23:30 00:00 0.50 11 0 PROD1 WHPST PULD P PJSM, Lay down Expro Camera, 07/09/2012 Finish Camera Run, Mill Window 00:00 00:30 0.50 0 0 PROD1 WHPST PULD P Lay down Expo camera and load out Page 4of15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:00 1.50 0 73 PROD1 WHPST PULD P PJSM, P/U BHA#5,window milling BHA, .6 degree motor,new 2.80 window mill and new 2.80 string reamer,Test E-Line, Hook up to coil track and surface test tool.Change out pack offs 02:00 03:48 1.80 73 7,460 PROD1 WHPST TRIP P Trip In EDC Open 03:48 04:00 0.20 7,460 7,485 PROD1 WHPST DLOG P Log Gamma tie in for-14'correction 04:00 04:12 0.20 7,485 7,500 PROD1 WHPST CIRC P Complete circulating coil to used 9.8 Flo Pro-8 BBIs,Close EDC, PUW=32.5K,pumps off 04:12 04:24 0.20 7,500 7,638 PROD1 WHPST TRIP P Trip in to whipstock,Min rate through pilot hole,S/D pumps for dry tag,Set down @ 7624.9. PUH,should not be whipstock, PUW=35K. Bring pumps on @.75 BPM, RIH small bobble @ 7625',TT,Continue in,S/D pump and dry tag TOWS @ 7639' 04:24 05:54 1.50 7,638 7,639 PROD1 WHPST MILL P PUH-PUW=33K, Pumps on @ 1.4 BPM @ 2670 PSI FS,480 PSI Diff, RIW=17.3K,feather in from 7634, Call pinch point @ 7638.8.Work to keep WOB and Diff up for 1st.6 foot to keep mill in MCA. 05:54 07:54 2.00 7,639 7,642 PROD1 WHPST MILL P PJSM-crew change-continue milling,good metal returns over shaker.Mid point,motor increase WOB decrease. 07:54 14:54 7.00 7,642 7,660 PROD1 WHPST MILL P Continue milling as per procedure. Exit @ 7643'.Sample at 7644'- 25%metal, 10%cement,30% sand,35%siltstone. Increase ROP @ 7645 ft to 5ft per hour. Increasing formation sand accorss shaker. 14:54 15:54 1.00 7,660 7,660 PROD1 WHPST REAM P Perform backreaming passes.P/U weight 29K. First HS, 15 ROHS, 15 LOHS. Looked clean.Shut down pumps dry drift.Clean POOH min. rate. 15:54 17:54 2.00 7,660 78 PROD1 WHPST TRIP P POOH holding MPD 17:54 19:54 2.00 78 0 PROD1 WHPST PULD P Crew change, PJSM lay down BHA #5 window milling, Both mills @ 2.79 No Go 19:54 22:06 2.20 0 0 PROD1 DRILL PRTS P PJSM, PT ODS PDL,change out upper QTS Section,unable to get test on it, Change out Tiger tank line and PT. PT PDL to 2000 high. Flush MP Choke,service Injector 22:06 23:42 1.60 0 62 PROD1 DRILL PULD P PJSM, P/U BHA#6, Build section with 2.4 Degree motor and Re Run Bi Center,Make up to coil track and surface test tool 23:42 00:00 0.30 62 1,700 PROD1 DRILL TRIP P RIH with EDC closed 07/10/2012 Drilled Build section to 8090',tripped for lateral drilling BHA Page 5 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 01:54 1.90 1,700 7,450 PROD1 DRILL TRIP P Trip in hole cont., EDC Closed 01:54 02:06 0.20 7,450 7,467 PROD1 DRILL DLOG P Log tie into K-1 for a-15'Correction 02:06 02:30 0.40 7,467 7,510 PROD1 DRILL TRIP P trip into 7520.open EDC and circ hole to 9.4 PPG Flo Pro 02:30 02:45 0.25 7,510 7,660 PROD1 DRILL TRIP P Trip into Drill,Clean trip through window down to TD 02:45 04:45 2.00 7,660 7,735 PROD1 DRILL DRLG P 7660' Drill Ahead, 1.35 BPM @ 3112 PSI FS, Diff Press=407, Near Bit Inc @ 29.33.Max dogleg so 49-50 degrees. 04:45 05:15 0.50 7,735 7,739 PROD1 DRILL DRLG P Do a mini wiper due to surface stacking-drill ahead 1.45 bpm, 3340, BHP 3720, ECD 12, ROP 30, WOB 2K,Ct weight 12K.Still stacking-wipe to window. P/U weight 29K. 05:15 09:42 4.45 7,739 7,890 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm,3500, BHP 3750, ROP 130,WOB 1.7K,CT weight 14K, Landed @ 5992'TVD, high 40's doglegs. 09:42 10:00 0.30 7,890 7,890 PROD1 DRILL WPRT P 7890ft Wiper to the window.TVD 5990.33ft, PUW 31 K, ECD 12.1, BHP 3712, IA 555psi,OA 331 psi. 10:00 12:06 2.10 7,890 8,040 PROD1 DRILL DRLG P 7890ft Back on bottom drilling,FS 3313psi 1.46 bpm, 1.7 WOB. BHP 3780 12:06 12:36 0.50 8,040 8,040 PROD1 DRILL WPRT P Wiper to the window,33K PUW 12:36 13:54 1.30 8,040 8,090 PROD1 DRILL DRLG P Continue drilling ahead, 1.45 BPM, 3823 BHP,3320 CTP, 13:54 16:12 2.30 8,090 48 PROD1 DRILL TRIP P 8090ft TD Build Section Average Dogleg 49.5 degrees, ECD 12.1, POOH for laterial BHA. Following MPD Schedule for Tripping OOH, BHP 3767, IA 600,OA 362,WHP 33, PU through window and cement pilot hole while pumping.3 bpm. Open EDC at TOC Puming 1.5bpm, Continue to POOH 16:12 20:36 4.40 0 0 PROD1 DRILL PULD P PJSM,PUD Build BHA#5, PD BHA#6 Lateral Section with 0.8 Degree AKO. 20:36 22:36 2.00 0 7,460 PROD1 DRILL TRIP P RIH 22:36 23:12 0.60 7,460 7,690 PROD1 DRILL DLOG P Tie in,minus 15.5',29.5K PUW, close EDC, 14K RIW, Log RA at 7646' 23:12 23:30 0.30 7,690 8,090 PROD1 DRILL TRIP P Continue RIH, 14K RIW 23:30 00:00 0.50 8,090 8,103 PROD1 DRILL DRLG P Drilling, 1.4 BPM,3420 CTP,3780 BHP. Resistivity is unusually high 07/11/2012 Drill L1 Lateral Section 00:00 03:12 3.20 8,103 8,240 PROD1 DRILL DRLG P Drilling, 1.4 BPM,3420 CTP,3780 BHP. 03:12 05:42 2.50 8,240 8,240 PROD1 DRILL WPRT P Wiper with MAD pass to the window, 30K PUW Page 6 of 15 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 05:42 07:00 1.30 8,240 8,390 PROD1 DRILL DRLG P Drilling Ahead, ROP 90-150fph, WOB average 1.2k-1.6k, BHP 3853, ECD 12.3 07:00 08:00 1.00 8,390 8,390 PROD1 DRILL WPRT P Wiper trip to the window, PUW 32K 08:00 09:00 1.00 8,390 8,540 PROD1 DRILL DRLG P Drilling Ahead, IA 615,OA 345, Pits 368, ECD 12.3 09:00 10:30 1.50 8,540 8,540 PROD1 DRILL WPRT P Wiper to the window, PUW 33K,Tie in to RA,Minus 4ft 10:30 12:00 1.50 8,540 8,690 PROD1 DRILL DRLG P Drilling Ahead, ROP 146fph,WOB average 1.5k, BHP 3880, ECD 12.3 12:00 13:00 1.00 8,690 8,690 PROD1 DRILL WPRT P Wiper to the window, PUW 36K 13:00 15:00 2.00 8,690 8,840 PROD1 DRILL DRLG P Drilling ahead,CTP 3364, BHP 3867 15:00 16:30 1.50 8,840 8,840 PROD1 DRILL WPRT P Wiper to the window, PUW 34K 16:30 18:42 2.20 8,840 8,990 PROD1 DRILL DRLG P Drill Ahead CTP 3380, 1.46 bpm, BHP 3850 18:42 19:48 1.10 8,990 7,670 PROD1 DRILL WPRT P Pump 5 low/5 high. Wiper to the window, PUW 34k,5k Over pull at 8888ft 19:48 20:00 0.20 7,670 7,685 PROD1 DRILL DLOG P Tie in correction of+1.5ft 20:00 20:42 0.70 7,685 8,990 PROD1 DRILL WPRT P Wiper Back into hole, RIW 15.5k 20:42 22:12 1.50 8,990 9,140 PROD1 DRILL DRLG P Continue drilling ahead, 1.45 BPM, 3350 CTP,3860 BHP with 70 WHP 22:12 00:00 1.80 9,140 9,140 PROD1 DRILL WPRT P Pump 5 low/5 high,Wiper to the window,34K PUW 07/12/2012 Drilled lateral to TD at 9860',wiper to surface 00:00 01:36 1.60 9,140 9,290 PROD1 DRILL DRLG P Drill Ahead CTP 3400, 1.45 BPM, BHP 3900,8K RIW 01:36 03:00 1.40 9,290 9,290 PROD1 DRILL WPRT P Pump 5 low/5 high,wiper to 8500' 03:00 03:54 0.90 9,290 9,368 PROD1 DRILL DRLG P Drill Ahead CTP 3400, 1.45 BPM, BHP 3900,8K RIW 03:54 06:12 2.30 9,368 9,440 PROD1 DRILL DRLG P Losing returns, 1.49 BPM in, 1.2 BPM out,over pulls coming up, Back to full returns after pulling up hole to 9100', resume drilling 06:12 07:24 1.20 9,440 9,440 PROD1 DRILL WPRT P Wiper to window with sweeps,Saw no overpull @ 9370 area 07:24 07:36 0.20 7,665 7,686 PROD1 DRILL DLOG P Tie In correction of Plus 1.5ft 07:36 08:36 1.00 7,686 9,440 PROD1 DRILL WPRT P Wiper back to bottom,RIW 8K, Perform Mud swap with new 9.4ppg 08:36 10:30 1.90 9,440 9,552 PROD1 DRILL DRLG P Drill Ahead,CTP 3388, 1.50 bpm, BHP 3895, RIW 8k 10:30 11:42 1.20 9,552 7,660 PROD1 DRILL WPRT P Stacking weight,can't achieve WOB, Wiper to the window with sweeps,PUW 10k over 11:42 12:42 1.00 7,660 9,552 PROD1 DRILL WPRT P Wiper back in hole, RIW 16K 12:42 14:42 2.00 9,552 9,710 PROD1 DRILL DRLG P Drill Ahead,CTP 3200, BHP 3800, RIW 4k 14:42 15:42 1.00 9,710 8,699 PROD1 DRILL WPRT P 1000ft Wiper with 5low/5high sweep, 15:42 16:42 1.00 8,699 9,710 PROD1 DRILL WPRT P Wiper back to Bottom, RIW 11K Page 7of15 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 16:42 18:48 2.10 9,710 9,860 PROD1 DRILL DRLG P Drill Ahead CTP 3400, 1.5fpm, BHP 3866 18:48 22:06 3.30 9,860 0 PROD1 DRILL WPRT P TD,pump sweeps and start wiper to the swab valve,34k PUW 22:06 00:00 1.90 0 7,480 PROD1 DRILL WPRT P Tag stripper,zero depth and RIH 07/13/2012 Layed in 12.2 ppg liner running pill and completion fluid. Ran 62 joints slotted liner and a liner top aluminum billet at 7759'. Function test BOP. 00:00 00:18 0.30 7,448 7,490 PROD1 DRILL DLOG P Tie-in to K1,Minus 14ft 00:18 01:36 1.30 7,490 9,861 PROD1 DRILL WPRT P Continue RIH 01:36 04:48 3.20 9,861 0 PROD1 DRILL DISP P Lay in 12.0 liner running pill and completion fluid while POOH, Paint EOP Flag 7600ft, Paint another flag at 5400 EOP. 04:48 05:24 0.60 0 0 PROD1 DRILL SFTY P Check well for no-flow. Crew changeout, PJSM for laying down BHA 05:24 06:42 1.30 0 0 PROD1 DRILL PULD P Lay down drilling BHA#7 06:42 08:00 1.30 0 0 COMPZ CASING CTOP P Prep Rig Floor for MU Liner and running tools 08:00 08:30 0.50 0 2,142 COMPZ CASING PUTB P PJSM,MU 62 Joints of 2 3/8 4.7ppf slotted liner, BOPE Saftey joint drill (Time 1 min 30sec),Surface Test BHI tools 08:30 12:42 4.20 2,142 2,142 COMPZ CASING RUNL P RIH with liner, BHA#8 12:42 14:00 1.30 7,541 7,541 COMPZ CASING DLOG P Correct to 5400ft EOP correction of minus 13.5ft, PUW 33.5k 14:00 15:54 1.90 7,541 9,861 COMPZ CASING RUNL P Continue RIH, Liner on BTM 9860ft, pressure up, PUW 30k Release from liner 15:54 16:06 0.20 9,861 7,530 COMPZ CASING DLOG P Tie into RA for confirming depth of LT -no correction 16:06 18:00 1.90 7,530 0 COMPZ CASING RUNL P POOH, Remove liner length of liner left in hole 18:00 18:18 0.30 0 0 COMPZ CASING SFTY P PJSM for laying down BHA 18:18 18:48 0.50 0 0 COMPZ CASING PUTB P Lay down liner running BHA 18:48 19:18 0.50 0 0 PROD2 WHDBO BOPE P Function test BOP 19:18 20:00 0.70 0 0 PROD2 STK PULD P MU drilling BHA,2.3 motor and bicenter bit 20:00 22:06 2.10 0 7,450 PROD2 STK TRIP P RIH 22:06 22:24 0.30 7,450 7,490 PROD2 STK DLOG P Tie in,-14'correction 22:24 23:24 1.00 7,490 7,759 PROD2 STK DISP P Circulate out completion fluid 23:24 00:00 0.60 7,759 7,759 PROD2 STK KOST P RIH,tag top of billet at 7759'and start time milling, 1.5 BPM,3200 CTP,3720 BHP,WOC 07/14/2012 Drilled L1-01 build section,tripped for motor adjust and drilled L1-01 lateral section to 8560' 00:00 02:42 2.70 7,759 7,769 PROD2 STK KOST P Continue time milling off billet Page 8 of 15 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 02:42 04:12 1.50 7,769 7,915 PROD2 DRILL DRLG P Drilling formation, 1.5 BPM,3220 CTP,3700 BHP, 15K RIW. at 7810 PUH to drift billet with pump shut down then resume drilling. 04:12 04:42 0.50 7,915 7,915 PROD2 DRILL WPRT P Wiper to the window,29K PUW 04:42 05:42 1.00 7,915 8,010 PROD2 DRILL DRLG P Continue drilling, 1.5 BPM,3300 CTP,3750 BHP, 15K RIW 05:42 06:00 0.30 8,010 7,484 PROD2 DRILL TRIP P TD Build Section 8010ft, POOH, Open EDC above the window 06:00 08:00 2.00 7,484 0 PROD2 DRILL CTOP P OOH,PJSM Undeploying Build section BHA#9 2.3 AKO 08:00 10:18 2.30 0 0 PROD2 DRILL CTOP P Tools LD,MU motor and RR HCC 10:18 12:42 2.40 0 0 PROD2 DRILL CTOP P PJSM, Deploy lateral BHA#10,.80 AKO 12:42 14:42 2.00 0 7,478 PROD2 DRILL TRIP P RIH with lateral BHA#10 14:42 15:00 0.30 7,478 7,770 PROD2 DRILL DLOG P PUW 29.5k,Tie into K1 marker correction of minus 14.5ft,close EDC 15:00 15:12 0.20 7,770 8,010 PROD2 DRILL TRIP P Continue Running to Bottom, RIHW 15k, RIH past billet at 7760ft 70L Clean 15:12 16:48 1.60 8,010 8,160 PROD2 DRILL DRLG P Drill Ahead, 1.5bpm,CTP 3375, BHP 3729, Pit Vol 350 bbls 16:48 17:42 0.90 8,160 7,700 PROD2 DRILL DLOG P Wiper trip to window with MAD Pass from 8020 to 7745, PUW=30K. BHP=3760 17:42 18:00 0.30 7,700 8,160 PROD2 DRILL WPRT P Wiper back in hole, 15K RIW 18:00 19:42 1.70 8,160 8,310 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3200 CTP,3730 BHP 19:42 20:24 0.70 8,310 8,310 PROD2 DRILL WPRT P Wiper to the billet,30K PUW 20:24 22:00 1.60 8,310 8,460 PROD2 DRILL DRLG P Continue drilling ahead, 1.47 BPM, 3300 CTP,3760 BHP, 15K RIW 22:00 22:36 0.60 8,460 7,670 PROD2 DRILL WPRT P Wiper to the window,30K PUW 22:36 22:42 0.10 7,670 7,690 PROD2 DRILL DLOG P Tie-in, +1'correction 22:42 23:06 0.40 7,690 8,460 PROD2 DRILL WPRT P Wiper back in hole 23:06 00:00 0.90 8,460 8,560 PROD2 DRILL DRLG P Continue drilling ahead, 1.47 BPM, 3300 CTP,3780 BHP, 15K RIW 07/15/2012 Drilled L1-01 lateral to 9533' 00:00 00:06 0.10 8,560 8,574 PROD2 DRILL DRLG P Continue drilling ahead, 1.47 BPM, 3400 CTP,3780 BHP, 15K RIW 00:06 00:30 0.40 8,574 8,574 PROD2 DRILL DRLG P Losing some returns, 1.45 in/1.1 out. BHP down to 3720, PUH 200',31K PUW. 00:30 00:54 0.40 8,574 8,610 PROD2 DRILL DRLG P Continue drilling ahead, 1.45 BPM (1.3 out),3400 CTP, 3785 BHP, 15K RIW 00:54 01:42 0.80 8,610 8,610 PROD2 DRILL WPRT P Wiper trip to 8050',30K PUW, 16K RIW 01:42 03:54 2.20 8,610 8,760 PROD2 DRILL DRLG P Continue drilling ahead, 1.4 BPM (1.3 out),3400 CTP,3740 BHP, 15K RIW, Lost 36bbls to formation Page 9 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:54 04:36 0.70 8,760 7,670 PROD2 DRILL WPRT P Wiper to the window,29K PUW 04:36 04:48 0.20 7,670 7,690 PROD2 DRILL DLOG P Tie-in,+1' 04:48 05:30 0.70 7,690 8,760 PROD2 DRILL WPRT P Wiper back in hole, RIW 9.2K 05:30 07:18 1.80 8,760 8,910 PROD2 DRILL DRLG P Drilling ahead, 1.36bpm(1.2bpm out),CTP 3368, BHP 3730,27 bbls lost to formation 07:18 08:06 0.80 8,910 7,800 PROD2 DRILL WPRT P Wiper trip to 7800ft, PUW 29.5K 08:06 08:42 0.60 7,800 8,910 PROD2 DRILL WPRT P Wiper back in hole, RIW 15K 08:42 10:42 2.00 8,910 9,010 PROD2 DRILL DRLG P Drilling ahead, 1.46 bpm(1.29bpm out),CTP 3300, BHP 3730, 10:42 12:00 1.30 9,010 7,760 PROD2 DRILL WPRT P Survey wiper, PUH 29.5k, DD states that he can't get clean surveys on bottom,wiper to the window, Consult with town desision was made to get _IFR correction. 12:00 12:12 0.20 7,760 7,792 PROD2 DRILL DLOG P Tie in correction of-.5ft 12:12 13:06 0.90 7,792 9,010 PROD2 DRILL WPRT P Wiper back in hole, RIW 15K, Shooting survey's during TIH, Magnetics came in clean 13:06 14:48 1.70 9,010 9,160 PROD2 DRILL DRLG P Drilling Ahead, 1.45bpm(1.33bpm out),CTP 3500, BHP 3818,lossing 13 bbls per hour to formation 14:48 15:30 0.70 9,160 7,800 PROD2 DRILL WPRT P Wiper to 7800ft, PUW 32k 15:30 16:18 0.80 7,800 9,160 PROD2 DRILL WPRT P Wiper back in hole, RIW 14.5K, Start new mud down hole. 16:18 18:48 2.50 9,160 9,310 PROD2 DRILL DRLG P Drilling Ahead, CTP 3450(1.5bpm in and 1.3bpm out)BHP 3838 18:48 19:36 0.80 9,310 7,670 PROD2 DRILL WPRT P Wiper to the window,30K PUW 19:36 19:48 0.20 7,670 7,690 PROD2 DRILL DLOG P Tie-in, +1.5'correction 19:48 20:36 0.80 7,690 9,310 PROD2 DRILL WPRT P Wiper back in hole, 15K RIW 20:36 22:06 1.50 9,310 9,460 PROD2 DRILL DRLG P Continue drilling ahead, 1.5 BPM in , 1.34 BPM out,3450 CTP,3767 BHP 22:06 23:18 1.20 9,460 9,460 PROD2 DRILL WPRT P Wiper trip to 8600',30K PUW, 14K RIW 23:18 00:00 0.70 9,460 9,533 PROD2 DRILL DRLG P Continue drilling ahead, 1.4 BPM in , 1.24 BPM out, 3300 CTP,3767 BHP 07/16/2012 Drilled L1-01 lateral to TD at 9910',long wiper trip and layed in12.0 ppg liner running pill and completion fluid, losing 10 bbls per hour to formation. 00:00 01:12 1.20 9,533 9,610 PROD2 DRILL DRLG P Continue drilling ahead, 1.4 BPM in , 1.24 BPM out,3300 CTP,3767 BHP 01:12 02:06 0.90 9,610 6,770 PROD2 DRILL WPRT P Wiper to the window, 30K PUW 02:06 02:18 0.20 6,770 6,790 PROD2 DRILL DLOG P Tie-in, +1'correction 02:18 03:12 0.90 6,790 9,610 PROD2 DRILL WPRT P Wiper back in hole, 16K RIW 03:12 05:36 2.40 9,610 9,760 PROD2 DRILL DRLG P Continue drilling ahead, 1.4 BPM in, 1.24 BPM out,3300 CTP,3767 BHP 05:36 06:36 1.00 9,760 8,800 PROD2 DRILL WPRT P Pump low/high vis sweeps. Wiper trip 06:36 07:12 0.60 8,800 9,760 PROD2 DRILL WPRT P Wiper back into hole, RIW 10k Page 10 of 15 1 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 07:12 09:12 2.00 9,760 9,847 PROD2 DRILL DRLG P Drilling Ahead,CTP 3310(1.48bpm in, 1.35bpm out)BHP 3845 09:12 09:24 0.20 9,847 9,550 PROD2 DRILL WPRT P Encountered slow ROP and not getting weight on bit.Wiper to clean hole 09:24 09:36 0.20 9,550 9,847 PROD2 DRILL WPRT P Wiper back down to bottom 09:36 11:36 2.00 9,847 9,910 PROD2 DRILL DRLG P Drilling Ahead, (1.48bpm in, 1.35bpm out)BHP 3820 11:36 14:36 3.00 9,910 0 PROD2 DRILL WPRT P TD L1-01 lateral,Chase, 30k PUW, 101ow/10high sweep OOH,Wiper to swab,Tag up and rezero depth 14:36 16:12 1.60 0 7,465 PROD2 DRILL WPRT P Wiper back in hole, lost 84 bbls since 6am 16:12 16:24 0.20 7,465 7,492 PROD2 DRILL DLOG P Tie in to K1 marker,Correction of- 15ft 16:24 18:06 1.70 7,492 9,910 PROD2 DRILL WPRT P Continue wiper in hole, RIW 15K 18:06 21:06 3.00 9,910 0 PROD2 DRILL DISP P Tag TD and lay in 12.0 ppg liner running pill and completion fluid. Paint EOP flags at 21:06 21:30 0.40 0 0 PROD2 DRILL SFTY P Check well for no flow, PJSM 21:30 22:12 0.70 0 0 PROD2 DRILL PULD P Lay down drilling BHA 22:12 00:00 1.80 0 0 COMPZ CASING PUTB P PU non-ported shoe,61 joints slotted liner and liner top aluminum billet. 07/17/2012 PU liner,PU BHA#11 RIH with Liner,Tie in to flag correction of-13'.9596ft tag PUW 31K,Work pipe, Pulled 55K,MU 30bbls of beads.Close choke&pump beads down past liner,RIH with liner to TD 9910'.Start testing BOP's State waived witnessing Chuck Scheve. 00:00 01:30 1.50 0 2,050 COMPZ CASING PUTB P Continue to pick up liner string 01:30 02:36 1.10 2,050 2,103 COMPZ CASING PUTB P MU Inteq liner running BHA 02:36 04:06 1.50 2,103 7,503 COMPZ CASING RUNL P RIH,still losing 10+bph 04:06 04:54 0.80 7,503 9,348 COMPZ CASING RUNL P Correct to flag,-13',Continue in hole, clean pass through window and billet @ 7760' 04:54 05:30 0.60 9,348 9,575 COMPZ CASING RUNL P Set down @ 9348', PUW=55K work liner,get moving down,pushing-3K 05:30 06:00 0.50 9,575 9,550 COMPZ CASING RUNL P Work pipe,popped free,Atempt to latch, PU Can't get it to grab. PUH and pump to fill hole.Crew Change, Discuss plan forward. 06:00 06:18 0.30 9,550 9,720 COMPZ CASING RUNL P Wash up and down to free GS of debris.Tag BHA, Liner moving down hole slowly 06:18 06:42 0.40 9,720 9,750 COMPZ CASING RUNL P PU&pump to bring BHP up to 3800psi,shut pump off,work pipe, Push liner down some more,Top of billet 18ft below the bottom of window 06:42 07:18 0.60 9,750 9,767 COMPZ CASING RUNL P PU&pump to bring BHP up to 3750psi,Shut pump off and work pipe. Push liner down some more. Make up 30 bbl pill with beads 07:18 07:54 0.60 9,767 9,767 COMPZ CASING RUNL P Start 30bbls pill down the coil.Work pipe, No movement.Top of Billet is 65ft below the Bottom of window. Page 11 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:54 08:42 0.80 9,767 9,783 COMPZ CASING RUNL P Still pumping 30 bbls beaded pill down coil,Work pipe, liner moved down some more. PU to 25K coil weight,park coil. 08:42 12:00 3.30 9,783 9,910 COMPZ CASING RUNL P Continue pumping beads down liner at.25 BPM,work pipe and moved liner down to TD at 9910' 12:00 13:30 1.50 9,910 7,600 COMPZ CASING DISP P Tie in to RA for zero correction, displace 12.0 ppg from well with flo-pro. Lost total of 202 bbls of NaBr. 13:30 15:30 2.00 7,600 0 COMPZ CASING RUNL P POOH 15:30 17:30 2.00 0 0 COMPZ CASING PUTB P Un-deploy liner running BHA 17:30 18:48 1.30 0 0 PROD3 DRILL SVRG P Service rig,choke manifold,tree, flush stack,surface lines 18:48 20:30 1.70 0 0 PROD3 DRILL SVRG P Contiue to prep for BOPE test, Remove BHI checks for testing inner reel valve,Grease tree valves 20:30 00:00 3.50 0 0 PROD3 WHDBO BOPE P PSJM,Start BOPE test#1 07/18/2012 Finish BOP test, RIH with Build BHA#12, Kick off of billet(7850')Drill build as per plan 00:00 06:00 6.00 0 0 PROD3 WHDBO BOPE P Continue BOPE test.Changed out R2 Valve and retest 06:00 06:30 0.50 0 0 PROD3 STK SFTY P Crew changeout and PJSM 06:30 09:48 3.30 0 0 PROD3 STK PULD P MU and deploy BHA#12 for drilling L1-02 build section 09:48 11:48 2.00 0 7,350 PROD3 STK TRIP P RIH 11:48 12:12 0.40 7,450 7,490 PROD3 STK DLOG P Tie into K1,-15'correction. 28K PUW 12:12 12:36 0.40 7,490 7,845 PROD3 STK TRIP P Close EDC and continue RIH, 16K RIW 12:36 15:54 3.30 7,845 7,855 PROD3 STK KOST P Dry tag billet and start time milling, 1.55 BPM,3300 CTP,3690 BHP with 65 WHP 15:54 16:24 0.50 7,855 7,918 PROD3 DRILL DRLG P Drilling ahead, 1.5 BPM,3200 CTP, 3700 BHP. 1:1 returns. At 7885' drifted the billet dry,continue drilling ahead 16:24 18:24 2.00 7,918 7,970 PROD3 DRILL DRLG P Drilliing Ahead 1.55 bpm CTP 3302, BHP 3740 WHP 121. Drilling in ankerite, 18:24 20:18 1.90 7,970 7,994 PROD3 DRILL TRIP P TD build section as per DD and Geo. Open EDC POOH 20:18 22:18 2.00 7,994 0 PROD3 DRILL PULD P OOH, PJSM for Undeploying build BHA#12. 22:18 22:30 0.20 0 0 PROD3 DRILL PULD P R1 float valve sub not holding between the motor and the HOT. PJSM,for change of scope.Make call for verification of plan forward. Agreed to close EDC to isolate R1 float valve sub. Proceed forward with undeploying. 22:30 00:00 1.50 0 0 PROD3 DRILL PULD P BHA#12 OOH,MU lateral BHA#13 Page 12 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/19/2012 24 hr Summary Drill ahead in section,TD build(7994'),Trip OOH for lateral BHA#13.Trouble area in ankerite 7947'work area with coil,continued to BTM. Drill ahead 00:00 01:54 1.90 0 0 PROD3 DRILL PULD P Loading PDL,perpairing to deploy Lateral BHA#13 01:54 04:12 2.30 0 7,947 PROD3 DRILL TRIP P RIH with Lateral BHA#13 04:12 05:12 1.00 7,947 7,994 PROD3 DRILL TRIP P Tag @ 7947', PUH 31K-RIW 16K, work pipe past ankerite pumping 1.5bpm @ 40fpm. 05:12 07:36 2.40 7,994 8,170 PROD3 DRILL DRLG P Drilling ahead,CTP 3400, BHP 3738 07:36 08:30 0.90 8,170 7,690 PROD3 DRILL DLOG P Wiper trip with MAD pass,Tie-in, 08:30 08:54 0.40 7,690 8,170 PROD3 DRILL WPRT P Wiper back in hole, 15K RIW,stack some weight at 7946'without stopping 08:54 10:30 1.60 8,170 8,322 PROD3 DRILL DRLG P Continue drilling, 1.55 BPM,3700 CTP, 3820 BHP 10:30 11:12 0.70 8,322 8,322 PROD3 DRILL WPRT P Pump sweeps. Wiper to 7870',29K PUW 11:12 13:12 2.00 8,322 8,470 PROD3 DRILL DRLG P Drilling ahead, 1.5 BPM,3700 CTP, 3840 BHP 13:12 14:36 1.40 8,470 8,470 PROD3 DRILL WPRT P Pump sweeps,wiper trip to the window,30K PUW, 16K RIW 14:36 16:30 1.90 8,470 8,620 PROD3 DRILL DRLG P Drilling ahead, 1.5 BPM,3700 CTP, 3840 BHP 16:30 17:12 0.70 8,620 7,500 PROD3 DRILL WPRT P Wiper to the window,29K PUW 17:12 18:00 0.80 7,500 7,500 PROD3 DRILL SFTY P Safety stand down. Open EDC and Circulate at 1.5 bpm 18:00 18:42 0.70 7,670 7,687 PROD3 DRILL DLOG P Close EDC,Tie in to RA marker Plus 1ft correction 18:42 18:54 0.20 7,687 8,620 PROD3 DRILL WPRT P Wiper back in hole, RIW 11.8K 18:54 23:06 4.20 8,620 8,770 PROD3 DRILL DRLG P Drilling Ahead,CTP 3470, BHP 3833 23:06 00:00 0.90 8,770 7,900 PROD3 DRILL WPRT P Wiper to 7900ft, PUW 31K 07/20/2012 Drill L1-02 lateral to 9666' 00:00 00:24 0.40 7,900 8,770 PROD3 DRILL WPRT P Continue wiper in hole, RIW 11k 00:24 01:48 1.40 8,770 8,920 PROD3 DRILL DRLG P Drilling Ahead,CTP 3613, BHP 3869 01:48 02:30 0.70 8,920 7,669 PROD3 DRILL WPRT P Wiper to window, PUW 31K 02:30 03:18 0.80 7,669 8,920 PROD3 DRILL WPRT P Wiper back in hole, RIW 14K 03:18 04:42 1.40 8,920 9,070 PROD3 DRILL DRLG P Drilling Ahead,CTP 3550, BHP 3860 04:42 06:18 1.60 9,070 9,070 PROD3 DRILL WPRT P Wiper up to 8000', PUW 31K 06:18 09:36 3.30 9,070 9,211 PROD3 DRILL DRLG P Continue drilling, 1.46 BPM, 3600 CTP,3877, BHP,WOC 09:36 10:36 1.00 9,211 7,670 PROD3 DRILL WPRT P Pump Sweeps. Wiper to the window,30K PUW 10:36 10:48 0.20 7,670 7,690 PROD3 DRILL DLOG P Tie-in,+.5' 10:48 11:36 0.80 7,690 9,211 PROD3 DRILL WPRT P Wiper back in hole, 16K RIW, start new mud down coil 11:36 13:48 2.20 9,211 9,370 PROD3 DRILL DRLG P Continue Drilling, 1.5 BPM,3350 CTP,3870 BHP with 120 WHP Page 13of15 Time Logs _ Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 13:48 14:54 1.10 9,370 9,370 PROD3 DRILL WPRT P Wiper to 8300',31K PUW, 15K RIW 14:54 16:12 1.30 9,370 9,545 PROD3 DRILL DRLG P Continue Drilling, 12K RIW, 1.5 BPM,3350 CTP,3900 BHP with 120 WHP 16:12 17:12 1.00 9,545 7,670 PROD3 DRILL WPRT P Wiper to the window,30K PUW 17:12 17:24 0.20 7,670 7,690 PROD3 DRILL DLOG P Tie-in, +1' 17:24 18:30 1.10 7,690 9,545 PROD3 DRILL WPRT P Wiper back in hole, 18K RIW 18:30 19:06 0.60 9,545 9,611 PROD3 DRILL DRLG P Drilling Ahead, 1.42bpm,CTP 3350, BHP 3911 19:06 19:42 0.60 9,611 9,511 PROD3 DRILL WPRT P BHA wiper stacking weight 19:42 00:00 4.30 9,511 9,666 PROD3 DRILL DRLG P Drilling Ahead,CTP 3350 07/21/2012 Drill L1-02 lateral to TD 00:00 01:30 1.50 9,666 9,672 PROD3 DRILL DRLG P Drilling Ahead,CTP 3350, BHP 3905 01:30 01:36 0.10 9,672 9,572 PROD3 DRILL WPRT P BHA wiper PUW 35k 01:36 01:42 0.10 9,572 9,672 PROD3 DRILL WPRT P Wiper back down to bottom, RIW 3K 01:42 05:30 3.80 9,672 9,695 PROD3 DRILL DRLG P Drilling Ahead, 1.4 bpm,CTP 3300 05:30 07:00 1.50 9,695 9,695 PROD3 DRILL WPRT P wiper trip to 8500', 33K PUW 07:00 11:30 4.50 9,695 9,845 PROD3 DRILL DRLG P Continue drilling, 1.5 BPM,3500 CTP,3940 BHP, 11:30 12:36 1.10 9,845 7,670 PROD3 DRILL WPRT P Wiper trip to the window 12:36 12:48 0.20 7,670 7,690 PROD3 DRILL DLOG P Tie-in,zero correction 12:48 14:00 1.20 7,690 9,845 PROD3 DRILL WPRT P Wiper back in hole 14:00 18:00 4.00 9,845 10,015 PROD3 DRILL DRLG P Continue drilling, 1.5 BPM,3550 CTP, 3960 BHP, 18:00 21:30 3.50 10,015 0 PROD3 DRILL WPRT P TD,Wiper to the swab 21:30 23:06 1.60 0 9,664 PROD3 DRILL TRIP P Wiper back in hole 23:06 23:18 0.20 7,460 7,476 PROD3 DRILL DLOG P Tie in minus 15.5'correction 23:18 00:00 0.70 7,476 8,815 PROD3 DRILL TRIP P Continue to RIHTB 07/22/2012 Wiper to swab, RIH to TD 10018', Lay in 12.0 ppg liner running pill and completion fluid.MU and run first section of liner to TD. POOH. MU second liner section and run to TD. POOH. LD liner running BHA. 00:00 00:54 0.90 8,815 10,018 PROD3 DRILL TRIP P Continue in hole. 00:54 04:30 3.60 10,018 0 PROD3 DRILL TRIP P Tag Bottom 10018', Lay in 12.0 ppg liner running pill&completion fluid, Paint EOP flags at 5700ft and 8100ft. POOH 04:30 06:00 1.50 0 0 PROD3 DRILL PULD P Tag up at surface, Perform flow check,No Flow, PJSM,for LD lateral BHA#13 06:00 06:30 0.50 0 0 COMPZ CASING SFTY P Crew changeout, PJSM for liner operations 06:30 10:12 3.70 0 1,855 COMPZ CASING PUTB P MU 54 Joints of liner,Safety joint drill while second joint was being made up,2:10 until well was secured. Page 14 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:12 11:36 1.40 1,855 7,555 COMPZ CASING RUNL P RIH 11:36 12:42 1.10 7,555 10,018 COMPZ CASING RUNL P Correct to EOP flag,-11.4',31K PUW,20K RIW,-5K WOB 12:42 13:00 0.30 10,018 7,424 COMPZ CASING RUNL P Set liner at TD and pump to release, 1.4 BPM,3600 CTP,WOB went to 0. PUH 13:00 13:12 0.20 7,424 7,450 COMPZ CASING DLOG P Log K1,-2.5',Top of liner was left at 8205.1' 13:12 15:00 1.80 7,450 0 COMPZ CASING RUNL P POOH, paint EOP flag at 6900' 15:00 15:24 0.40 0 0 COMPZ CASING SFTY P PJSM for BHA and liner 15:24 16:00 0.60 0 0 COMPZ CASING PUTB P Lay down liner running BHA 16:00 18:00 2.00 0 626 COMPZ CASING PUTB P MU upper liner string and Inteq tools 18:00 19:06 1.10 626 7,000 COMPZ CASING RUNL P RIH 19:06 19:12 0.10 7,000 8,200 COMPZ CASING RUNL P EOP flag 5400',correction of-14' 19:12 19:24 0.20 8,200 7,433 COMPZ CASING RUNL P Set liner at 8200',pump off of liner lost 2K lbs, PUH to tie in 19:24 19:30 0.10 7,433 7,450 COMPZ CASING DLOG P Tie in to the K1 marker,correction of plus 1', Liner top is at 7619' 19:30 21:00 1.50 7,450 7,600 DEMOB WELLPF DISP P Swap hole over to SW 21:00 23:00 2.00 7,600 0 DEMOB WELLPFTRIP P POOH with liner running BHA#15 23:00 23:18 0.30 0 0 DEMOB WELLPF FRZP P Freeze protect well from 2500' 23:18 23:30 0.20 0 0 DEMOB WELLPF SFTY P PJSM for Undeploying liner running BHA#15 23:30 00:00 0.50 0 DEMOB WELLPF PULD P Undeploy BHA, 766 WHP Shut Swab,Tools OOH, RD tools, Prep for Inhibiting surface iron. 07/23/2012 Circulate corrosion inhibitor through surface equipment,Set BPV, RDMO. Rig released at 11:00. 00:00 01:30 1.50 0 0 DEMOB WELLPF PUTB P Continue to LD liner running BHA #15 01:30 04:00 2.50 0 0 DEMOB WHDBO DMOB P Prepare and Pump Corrosion Inhibitor through rig lines and BOPE. 04:00 04:18 0.30 0 0 DEMOB WHDBO SFTY P PJSM 04:18 06:00 1.70 0 0 DEMOB WHDBO NUND P Install BPV 06:00 11:00 5.00 0 0 DEMOB WHDBO DMOB P Blow down coil and surface equipment, RDMO ***Rig Release is 11:00*** Page 15 of 15 \2-0t� PRINT BAKER N LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2D-05L1;05L1-01; 05L1-02 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF _ (mandatory) LOG DATE: July 13,2012 TODAYS DATE: 8/21/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY D FIELD FINAL (digital il ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Oh NHiN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 I 1 I T NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 !Christine 1 I 1 I I i Christine Mahnken 1333 West 7th Ave,Suite 100 'Anchorage,Alaska 99501 • i t 3 !BP I 1 I 1 I I Petrotechnical Data Center,MB33 ,David Douglas 1900 East Benson Blvd iAnchorage,Alaska 99508 4'Chevron/KRU REP I 1 I 1 1 Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 1 Brandon Tucker,NRT State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 l TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Letter of Transmittal Frig BAKER Date: RECEIVED July 30, 2012 RE HUGHES JUL 312012 To: From: AOGCC Christine Mahnken Carl Ulrich/Sachin Gandra AOGCC Baker Hughes 1NTEQ 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): 2D-05L1 a L 2D-05L1-01 0. ) � © 8' CD-05L1-02 (3) Total prints ' 1 ` v ET l 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. Sachin Gandra, Baker Hughes, Project Engineer r(\ . ' Sachin.Gandra@BakerHughes.com A Carl.Ulrich, Baker Hughes, Survey Manager ` 411M/)� Carl.Ulrich@BakerHughes.com SEAN PARNELL, GOVERNOR T ALASKA COMMISSION OIL AND G& 333 W 7th AVENUE,SUITE 100 CONBIERVA �L ®1 ® MISSIION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Lamar Gantt FAX (907)276-7542 Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, 2D-05L1-02 ConocoPhillips Alaska, Inc. Permit No: 212-088 Surface Location: 5111' FNL, 551' FEL, Sec. 23, T11N, RO9E, UM Bottomhole Location: 4587' FNL, 3163' FEL, Sec. 13, T11N, RO9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 2D-05, Permit No 212- 088, API 50-029-21157-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission 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 a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ter.% r Cathy/P. Foerster Chair, Commissioner DATED this 0 day of July, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a Type of Work: k lb.Proposed Well Class: Development-Oil ❑ Service-Winj ❑✓ , Single Zone ❑✓ 1 c.Specify if well is proposed for Drill ❑ Re-drill❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2 Operator Name 5. Bond LJ Blanket . u Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 2D-05L1-02 3.Address: 6 Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9900' • TVDSS: 5990' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number) Surface:5111'FNL,551'FEL,Sec.23,T11N,RO9E, UM ADL 25653 Kuparuk River Oil Pool • Top of Productive Horizon. 8.Land Use Permit: 13.Approximate Spud Date: 1308'FNL,3896'FEL,Sec.24,T11N, RO9E,UM 2579 7/16/2012 Total Depth: 9.Acres in Property: 14 Distance to 4587'FNL,3163'FEL,Sec. 13,T11N, RO9E,UM 2560 Nearest Property 25520' 4b.Location of Well(State Base Plane Coordinates-NAD 27). 10.KB Elevation above MSL: • 126 feet 15 Distance to Nearest Well Open Surface:x- 529214 - y- 5954367 • Zone- 4 GL Elevation above MSL:n ya eetG-Z�o Same Pool 2Z-08,695' 16 Deviated wells. Kickoff depth: 7840' ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle 95' deg Downhole:2990 psig Surface: 3826 psig 18 Casing Program. Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 ST-L 2285' 7615' 5895' 9900' 5990' slotted/solid liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft). Plugs(measured) Effective Depth MD(ft). Effective Depth ND(ft). Junk(measured) 7990' 6363' 7718' 6114' 4210' Casing Length Size Cement Volume MD TVD Conductor/Structural 81' 16" 224 sx CS II 116' 116' Surface 3798' 9.625" 1075 sx ASIII,685 sx Class G 3823' RECEIVED Intermediate Production 7938' 7" 625 sx Class G 7971' .JU42' 7 ,} G , j'�C Perforation Depth MD(ft): Perforation Depth TVD(ft): AOGCC 7534'-7578',(7678'-7688',7700'-7742'-squeezed) 5949'-5988',6078'-6087',6098'-6136' 20.Attachments Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25 050 requirements ❑ 21.Verbal Approval Commission Representative Date. 6/Wt. 22 I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-110265,6 Printed Name L. Gantt Title Wells Supervisor Signature f / ' 5t.tvillt- Phon 263-4021 Date G7 // 2_ Commission Use Only Permit to Dnll API Number: Permit Approv I See cover letter ) Number 2 1 2— J 50- C 2? 2l / ;- 7 46''Date. 1 1�t I1 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbem thane,gas hydrates,or gas contained in shales' i'0 a a ps r B b p -t'cs 't- Samples req'd: Yes ❑ No Mud log req'd: Yes El No g Other: H2S measures: Yes Al No ❑ Directional svy req'd: Yes [vr No ❑ M tr rectus red rh1,r, 1 -�j , UL(� RO' ED BY TH COMMISSION DAT _4-I ,.r- • 711/i•�"-��' ' `�(� MISSIONER i" Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)Y Sin-�t in Duplicate t�L ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 20, 2012 JUNCEI VE� Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 2Q 12 333 West 7th Anchorage, AlaskauSuite 100 995014OGC Dear Commissioner: 1, ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a tri-lateral out of the Kuparuk Well 2D-05 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in mid-July 2012. The CTD objective will be to drill tri-laterals (2D-05L1, 2D- 05L1-01, 2D-05L1-02), targeting the A sand intervals. The original A-sand perforations will have been cemented off before CTD operations commence, as per Sundry 312-209. Attached to this application are the following documents: — Permit to Drill Application Form for 2D-05L1, 2D-05L1-01, 2D-05L1-02 — Detailed Summary of Operations — Proposed Schematic — Directional Plans If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James J. Ohlinger Coiled Tubing Drilling Engineer Kuparuk CTD Laterals f15lfA 2D-05L1 , 2D-05L1-01 , and 2D-05L1-02 CNAOOAK. Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(C)(6)) 3 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids Program 4 (Requirements of 20 AAC 25.005(c)(8)) 4 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 AAC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 AAC 25.005(c)(12)) 5 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 8 Attachment 1: Directional Plans for 2D-05L1,2D-05L1-01, and 2D-05L1-02 8 Attachment 2: Current Well Schematic for 2D-05 8 Attachment 3: Proposed Well Schematic for 2D-05L1,2D-05L1-01, and 2D-05L1-02 8 Page 1 of 8 6/20/2012 PTD Application: 2D-05L1, 2D-05L1-01, and 2D-05L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2D-05L1, 2D-05L1-01, and 2D-05L1-02. All three of these laterals will be classified as"Service"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand'package in the Kuparuk reservoir. Location at Surface 5111' FNL, 551' FEL, Sec 23, T11N, RO9E, UM NAD 1927 RKB Elevation 126 AMSL Northings: 5,954,367 Eastings: 529,214 Pad Elevation 79.4 AMSL 2D-05L1 Location at Top of Productive Horizon 1210' FNL, 3859' FEL, Sec 24, T11N, RO9E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7,775' Northings: 5,958,276 Eastings: 531,167 Total Vertical Depth, SS: 5,998' Location at Total Depth 2909' FNL, 3569' FEL, Sec 24, T11N, RO9E, UM NAD 1927 Measured Depth, RKB: 9,860' Northings: 5,956,578 Eastings: 531,465 Total Vertical Depth, SS: 5,966' 2D-05L1-01 Location at Top of Productive Horizon 1146' FNL, 3851' FEL, Sec 24, T11N, RO9E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7,840' Northings: 5,958,340 Eastings: 531,175 Total Vertical Depth, SS: 6,002' Location at Total Depth 2558' FNL, 4425' FEL, Sec 24, T11N, RO9E, UM NAD 1927 _ Measured Depth, RKB: 9,880' Northings: 5,956,926 Eastings: 530,608 Total Vertical Depth, SS: 5,950' 2D-05L1-02 Location at Top of Productive Horizon (Kuparuk) 1308' FNL, 3896' FEL, Sec 24, T11N, RO9E, UM NAD 1927 Measured Depth, RKB: 7,637' Northings: 5,958,180 Eastings: 531,131 Total Vertical Depth, SS: 5,916' Location at Total Depth 4587' FNL, 3163' FEL, Sec 13, T11N, RO9E, UM NAD 1927 Measured Depth, RKB: 9,900' Northings: 5,960,182 Eastings: 531,854 Total Vertical Depth, SS: 5,990' Page 2 of 8 " x 6/20/2012 PTD Application: 2D-05L1, 2D-05L1-01, and 2D-05L1-02 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 4000 psi. (Using the maximum pressure in the area of 4410 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3826 psi. See the"Drilling Hazards Information and Reservoir Pressure"section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 2D-05 in June 2012 indicated a reservoir pressure of 2990 psi or 9.4 ppg equivalent mud weight. The maximum downhole pressure in the 2D-05 pattern is at injector 2D-07 with 4410 psi.. It is not expected that reservoir pressure as high as 2D-07 well will be encountered while drilling the 2D-05 laterals because of offset distance and faulting. Using the 2D-07 pressure as the maximum possible in 2D- 05,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3826 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 2D pad does have some wells on miscible gas injection (MI) so encountering MI gas is a possibility. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 2D-05 laterals will be crossing a fault into an over pressurized reservoir block. The surrounding injectors have been shut in to bring the reservoir pressure down. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(1), thru-tubing drilling operations need not perform additional formation integrity tests. 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 2D-05L1 7775' 9860' 5998' 5966' 23/",4.7#, L-80, ST-L slotted liner; aluminum billet on top. 2D-05L1-01 7840' 9880' 6002' 5950' 2'/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 2D-05L1-02 7615' 9900' 5895' 5990' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. Page 3 of 8 r i I A L 6/20/2012 PTD Application: 2D-05L1, 2D-05L1-01, and 2D-05L1-02 Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 35' 116' 0' 116' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 35' 3833' 0' 3165' 3520 2020 Casing 7" 26.0 J-55 BTC 33' 7971' 0' 6345' 4980 4330 Tubing 3-1/2 " 9.3 J-55 EUE 8rd-mod 33' 7625' 0' 6030' 6,990 7,400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine (9.4 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.4 ppg). While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 2D-05 contains a subsurface safety valve (SSSV) that has been locked out. The well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-173 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 11.8 ppg will be initially targeted at the window based on the recent static bottom hole pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 4 of 8 6/26/2012 PTD Application: 2D-05L1, 2D-05L1-01, and 2D-05L1-02 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background The CTD laterals from well 2D-05 will target Kuparuk A-sands by improving throughput and recovery in the area. Approximately 6,388 ft of total CTD hole will be drilled from well 2D-05. The productive intervals will be completed with slotted liners. The scope of this project is to drill two CTD injection laterals to the east and one CTD injection lateral to the west, all in the A4 sands. The two laterals to the east will go north and south and will support CTD producer 2D-06B and potentially producer 2Z-12A. The lateral to the west will turn south to support producer 2D-03. Prior to drilling, the existing A-sand perfs in 2D-05 will be squeezed with cement to provide a means to kick out of the 7" casing. This will permanently abandon only the Kuparuk A-sand. The C-sand perfs will still be accessible via the single selective. After plugging off the existing A-sand perfs with cement, a pilot hole will be drilled through the cement to 7670' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2D-05L1 sidetrack will exit the 7" casing at 7637' MD. The 2D-05 CTD sidetrack is planned to spud in Q3 of 2012 with the Nabors CDR2-AC rig. Once drilled, the CTD laterals will be flowed back within ten days following the sidetrack completion. The well will be put on injection after flow back to support the offset producers. Pre-Rig Work (As per Sundry 312-209) 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T & IC. 3. MIT-IA, MIT-OA. 4. RU slickline. Tag fill. Get updated static BHP survey. 5. Pressure test tubing to confirm that the C sand straddle has integrity. 6. RU coil. Mill out D-nipple at 7621' RKB to 2.80" ID. 7. RU coil. Plug A-sand perfs with cement from —7852' up to the tubing tail perfs at 7616' MD. 8. RU slickline. Tag top of cement and pressure test. RD slickline. 9. Prep site for Nabors CDR2-AC, including setting BPV Page 5 of 8 6/26/2012 PTD Application: 2D-05L1, 2D-05L1-01, and 2D-05L1-02 Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE,test. 4bpOpj; DD P tt5 f 2. 2D-05L1 Sidetrack(A4 sand, south) Nat! 4dLa CG a. Drill 2.80" high-side pilot hole through cement to 7670' MD. I Yt$pC'G to pfp b. Drift pilot hole with whipstock dummy c. Set whipstock at 7637' MD with high-side orientation. d. Mill 2.80"window at 7637' MD. e. Drill 2.70"x 3" bi-center lateral to TD of 9860' MD f. Run 2'/"slotted liner with an aluminum billet from TD up to 7775' MD 3. 2D-05L1-01 Lateral (A4 sand, west) a. Kick off of the aluminum billet at 7775' MD b. Drill 2.70"x 3" bi-center lateral to TD of 9880' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 7840' MD 4. 2D-05L1-01 Lateral (A4 sand, north) a. Kick off of the aluminum billet at 7840' MD b. Drill 2.70"x 3"bi-center lateral to TD of 9900' MD c. Run 2%"slotted liner from TD up to 7615' MD, up inside the 3'/"tubing tail 5. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Flow well to clean up 5-7 days 4. Return to injection Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using 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 slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment,the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Page 6 of 8 °* j6/20/2012 ... ki 1 ...' • PTD Application: 2D-05L1, 2D-05L1-01, and 2D-05L1-02 Liner Running — The 2D-05 CTD laterals will be displaced to an overbalancing fluid (12 ppg Na-Br) prior to running liner. See the"Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 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 2D-05L1 21575 2D-05L1-01 24650 2D-05L1-02 25520 — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 2D-05L1 1146 2D-07 2D-05L1-01 1365 2D-05 2D-05L1-02 695 2Z-08 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 2D-05L1: 2D-07 is 1,146'from the toe of 2D-05L1. Structurally the 2D-05L1 lateral will be north and east of 2 large sealing faults. 2D-07 is an injector with 3-1/2"tubing in 7"production casing with perforations in the A- sand and C-sand selective interval. The Ann-ComM status of 2D-07 is"Normal"and passed MIT-T, MIT-IA, T- POT, and T-PPPOT in 2010. 2D-06BL1 will be—1,050' East of the 2D-05L1 lateral and in the same zone(this is one of the wells that 2D-05 will support). 2D-06BL1 is a CTD sidetrack from 2008 and has a Normal Ann-Comm status. 2D-06BL1 is completed with 2-3/8"slotted liner from TD with the top inside of the 3-1/2" production tubing. 2D-05L1-02: 2Z-08 is 695'from the toe of 2D-05L1-02. 2Z-08 is an injector with 3-1/2"tubing in 7" production casing with perforations in the A-sand and C-sand selective interval. Classified as a"Problem"well with IAxOA comm, packoffs failed testing in 2001 and will monitor OA for waiver evaluation. 2Z-08 passed an MIT-IA in 08/2011 and an MIT-OA in 05/2012. 2Z-12A is 1,065'from the toe of 2D-05L1-02. 2Z-12A is a producer with"Normal"well status. The completion consists of 7"production casing and a 3-1/2" liner producing from perforations in the A and C sand intervals. Page 7 of 8 f.8 r, 6/20/2012 PTD Application: 2D-05L1, 2D-05L1-01, and 2D-05L1-02 17. Attachments Attachment 1: Directional Plans for 2D-05L1, 2D-05L1-01, and 2D-05L1-02 Attachment 2: Current Well Schematic for 2D-05 Attachment 3: Proposed Well Schematic for 2D-05L1, 2D-05L1-01, and 2D-05L1-02 Page 8 of 8 6/20/2012 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2D Pad 2D-05 2D-05L1-02 Plan: 2D-05L1-02_wp13 Standard Planning Report 12 June, 2012 r i�1 BAKER HUGHES Iv' ConocoPhillips or its affiliates «� ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2D-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level ' Project: Kuparuk River Unit MD Reference: 2D-05 @ 126.00ft Site: Kuparuk 2D Pad North Reference: True Well: 2D-05 Survey Calculation Method: Minimum Curvature Wellbore: 2D-05L1-02 Design: 2D-05L1-02_wp13 Project Kuparuk River Unit 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 2D Pad Site Position: Northing: 5,954,045.13ft Latitude: 70°17'7.882 N From: Map Easting: 529,129.90ft Longitude: 149°45'51.288 W' Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.22 ° Well 2D-05 Well Position +N/-S 0.00 ft Northing: 5,954,367.10 ft ' Latitude: 70°17'11.046 N +E/-W 0.00 ft Easting: 529,214.16 ft • Longitude: 149°45'48.797 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 79.40 ft Wellbore 2D-05L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength j r) (°) (nT) BGGM2012 7/25/2012 15.98 79.87 57,348 I Design 2D-05L1-02_wp13 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,840.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -79.40 0.00 0.00 25.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°1100ft) (°/100ft) (°/100ft) (°) Target 7,840.00 92.51 353.45 6,001.59 3,965.80 1,976.38 0.00 0.00 0.00 0.00 7,870.00 88.96 354.07 6,001.21 3,995.62 1,973.12 12.00 -11.82 2.08 170.00 7,910.00 85.29 357.17 6,003.21 4,035.44 1,970.07 12.00 -9.18 7.73 140.00 7,940.00 84.07 0.57 6,006.00 4,065.30 1,969.48 12.00 -4.07 11.34 110.00 8,010.00 85.58 8.86 6,012.32 4,134.71 1,975.21 12.00 2.16 11.85 80.00 8,125.00 95.36 18.62 6,011.38 4,246.15 2,002.46 12.00 8.50 8.48 45.00 8,235.00 91.18 31.16 6,005.08 4,345.54 2,048.60 12.00 -3.79 11.41 108.00 8,435.00 91.08 55.17 6,001.08 4,490.32 2,184.40 12.00 -0.05 12.00 90.00 8,985.00 90.44 349.16 5,992.85 4,971.92 2,380.58 12.00 -0.12 -12.00 270.00 9,460.00 90.24 46.17 5,989.78 5,406.07 2,518.85 12.00 -0.04 12.00 90.00 9,900.00 89.75 353.37 5,989.84 5,805.65 2,662.45 12.00 -0.11 -12.00 269.50 6/12/2012 1:48:26PM Page 2 COMPASS 2003.16 Build 69 ►-' ConocoPhillips or its affiliates Iir ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2D-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2D-05 @ 126.00ft Site: Kuparuk 2D Pad North Reference: True Well: 2D-05 Survey Calculation Method: Minimum Curvature Wellbore: 2D-05L1-02 Design: 2D-05L1-02_wp 13 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/_W Section Rate Azimuth Northing Easting (ft) (°1 (°1 (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) • 7,840.00 92.51 353.45 6,001.59 3,965.80 1,976.38 4,429.49 0.00 0.00 5,958,340.16 531,174.93 TIP/KOP 7,870.00 88.96 354.07 6,001.21 3,995.62 1,973.12 4,455.14 12.00 170.00 5,958,369.96 531,171.55 2 7,900.00 86.21 356.39 6,002.47 4,025.48 1,970.63 4,481.15 12.00 140.00 5,958,399.81 531,168.95 7,910.00 85.29 357.17 6,003.21 4,035.44 1,970.07 4,489.94 12.00 139.90 5,958,409.76 531,168.35 3 7,940.00 84.07 0.57 6,006.00 4,065.30 1,969.48 4,516.75 12.00 110.00 5,958,439.62 531,167.64 4 8,000.00 85.36 7.68 6,011.53 4,124.85 1,973.78 4,572.54 12.00 80.00 5,958,499.18 531,171.71 8,010.00 85.58 8.86 6,012.32 4,134.71 1,975.21 4,582.08 12.00 79.34 5,958,509.05 531,173.10� 5 8,100.00 93.24 16.49 6,013.25 4,222.38 1,994.94 4,669.88 12.00 45.00 5,958,596.79 531,192.49 8,125.00 95.36 18.62 6,011.38 4,246.15 2,002.46 4,694.59 12.00 44.92 5,958,620.58 531,199.91 6 8,200.00 92.53 27.18 6,006.22 4,315.00 2,031.55 4,769.29 12.00 108.00 5,958,689.53 531,228.74 8,235.00 91.18 31.16 6,005.08 4,345.54 2,048.60 4,804.17 12.00 108.59 5,958,720.13 531,245.66 7 8,300.00 91.17 38.97 6,003.75 4,398.69 2,085.90 4,868.11 12.00 90.00 5,958,773.42 531,282.76 8,400.00 91.11 50.97 6,001.75 4,469.30 2,156.43 4,961.90 12.00 90.16 5,958,844.30 531,353.00 8,435.00 91.08 55.17 6,001.08 4,490.32 2,184.40 4,992.78 12.00 90.40 5,958,865.43 531,380.891 8 8,500.00 91.07 47.37 5,999.85 4,530.95 2,235.05 5,051.01 12.00 -90.00 5,958,906.25 531,431.38 8,600.00 91.02 35.37 5,998.03 4,605.85 2,301.01 5,146.76 12.00 -90.15 5,958,981.40 531,497.04', 8,700.00 90.92 23.36 5,996.33 4,692.83 2,349.95 5,246.28 12.00 -90.37 5,959,068.56 531,545.63 8,800.00 90.78 11.36 5,994.85 4,788.09 2,379.74 5,345.20 12.00 -90.57 5,959,163.92 531,575.05 8,900.00 90.61 359.36 5,993.63 4,887.46 2,389.07 5,439.20 12.00 -90.75 5,959,263.32 531,583.99 8,985.00 90.44 349.16 5,992.85 4,971.92 2,380.58 5,512.17 12.00 -90.89 5,959,347.74 531,575.18 9 9,000.00 90.44 350.96 5,992.74 4,986.69 2,377.99 5,524.46 12.00 90.00 5,959,362.50 531,572.53 9,100.00 90.43 2.97 5,991.98 5,086.37 2,372.71 5,612.56 12.00 90.01 5,959,462.14 531,566.86 9,200.00 90.40 14.97 5,991.26 5,184.96 2,388.26 5,708.50 12.00 90.10 5,959,560.79 531,582.03 9,300.00 90.35 26.97 5,990.61 5,278.17 2,423.98 5,808.06 12.00 90.19 5,959,654.12 531,617.38 9,400.00 90.28 38.97 5,990.06 5,361.91 2,478.29 5,906.92 12.00 90.27 5,959,738.07 531,671.36 9,460.00 90.24 46.17 5,989.78 5,406.07 2,518.85 5,964.08 12.00 90.34 5,959,782.38 531,711.75 10 9,500.00 90.20 41.37 5,989.63 5,434.95 2,546.51 6,001.94 12.00 -90.50 5,959,811.37 531,739.29 9,600.00 90.08 29.37 5,989.39 5,516.35 2,604.29 6,100.13 12.00 -90.52 5,959,892.98 531,796.74 9,700.00 89.97 17.37 5,989.34 5,607.98 2,643.87 6,199.91 12.00 -90.55 5,959,984.76 531,835.97 9,800.00 89.85 5.37 5,989.49 5,705.84 2,663.55 6,296.91 12.00 -90.55 5,960,082.68 531,855.26 • 9,900.00 89.75 353.37 5,989.84 - 5,805.65 2,662.45 6,386.91 12.00 -90.53 5,960,182.48 531,853.77 TD at 9900.00 6/122012 1:48:26PM Page 3 COMPASS 2003.16 Build 69 \ l11/4:, i11a 1,.., �.' ConocoPhillips or its affiliates (f ConocoPhillips Planning Report RHES Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2D-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2D-05 @ 126.00ft Site: Kuparuk 2D Pad North Reference: True Well: 2D-05 Survey Calculation Method: Minimum Curvature Wellbore: 2D-05L1-02 Design: 2D-05L1-02_wp 13 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2D-05L1_Major NS C 0.00 0.00 5,990.00 6,227.48 2,330.52 5,960,602.97 531,520.25 70°18'12.289 N 149°44'40.844 W -plan misses target center by 536.76ft at 9900.00ft MD(5989.84 TVD,5805.65 N,2662.45 E) -Polygon Point 1 5,990.00 6,227.48 2,330.52 5,960,602.97 531,520.25 Point 2 5,990.00 3,396.64 1,687.60 5,957,769.94 530,888.39 Point 3 5,990.00 2,027.50 1,947.38 5,956,401.95 531,153.46 Point4 5,990.00 3,396.64 1,687.60 5,957,769.94 530,888.39 2D-05L1-02_T2 0.00 0.00 6,004.00 4,412.20 2,107.43 5,958,787.02 531,304.23 70°17'54.437 N 149°44'47.363 W -plan misses target center by 7.67ft at 8324.81ft MD(6003.24 TVD,4417.56 N,2102.00 E) -Point 2D-05L1-02_T3 0.00 0.00 5,995.00 4,815.83 2,211.02 5,959,191.01 531,406.24 70°17'58.406 N 149°44'44.340 W -plan misses target center by 171.21ft at 8776.08ft MD(5995.18 TVD,4764.77 N,2374.44 E) -Point 2D-05L1-02_T4 0.00 0.00 5,990.00 5,259.07 2,415.76 5,959,634.99 531,609.24 70°18'2.765 N 149°44'38.367 W -plan misses target center by 1.15ft at 9279.19ft MD(5990.74 TVD,5259.42 N,2414.95 E) -Point 2D-05L1-02_T5 0.00 0.00 5,990.00 5,760.82 2,745.75 5,960,137.98 531,937.24 70°18'7.698 N 149°44'28.741 W -plan misses target center by 80.21ft at 9854.17ft MD(5989.66 TVD,5759.95 N,2665.55 E) -Point 2D-05L1-02_T1 0.00 0.00 6,008.00 3,971.65 1,981.71 5,958,346.03 531,180.23 70°17'50.104 N 149°44'51.032 W -plan misses target center by 8.89ft at 7845.15ft MD(6001.39 TVD,3970.92 N,1975.80 E) -Point 2D-05L1-02_Polygon 0.00 0.00 126.00 3,998.59 1,741.78 5,958,372.03 530,940.23 70°17'50.370 N 149°44'58.025 W -plan misses target center by 5879.76ft at 7870.00ft MD(6001.21 TVD,3995.62 N,1973.12 E) -Polygon Point 1 126.00 3,998.59 1,741.78 5,958,372.03 530,940.23 Point 2 126.00 3,839.23 2,093.21 5,958,214.05 531,292.24 Point 3 126.00 5,827.24 3,188.94 5,960,206.11 532,380.13 Point4 126.00 6,235.33 2,132.40 5,960,610.05 531,322.12 Point 5 126.00 3,998.59 1,741.78 5,958,372.03 530,940.23 2D-05L1-02_Faultl 0.00 0.00 6,004.00 4,420.20 1,850.44 5,958,794.02 531,047.23 70°17'54.516 N 149°44'54.855 W -plan misses target center by 209.32ft at 8203.64ft MD(6006.06 TVD,4318.23 N,2033.22 E) -Polygon Point 1 6,004.00 4,420.20 1,850.44 5,958,794.02 531,047.23 Point 2 6,004.00 4,312.40 2,318.08 5,958,688.05 531,515.24 2D-05L1-02_Fault2 0.00 0.00 5,995.00 4,851.96 1,922.12 5,959,226.01 531,117.24 70°17'58.762 N 149°44'52.762 W -plan misses target center by 447.23ft at 8456.80ft MD(6000.66 TVD,4503.17 N,2202.00 E) -Polygon Point 1 5,995.00 4,851.96 1,922.12 5,959,226.01 531,117.24 Point2 5,995.00 4,778.58 2,539.90 5,959,155.04 531,735.24 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,823.00 3,030.95 9 5/8" 9-5/8 12-1/4 9,900.00 5,989.84 2-3/8" 2-3/8 3 6/12/2012 1:48:26PM Page 4 COMPASS 2003.16 Build 69 �•' ConocoPhillips or its affiliates V/." ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2D-05 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2D-05 @ 126.00ft Site: Kuparuk 2D Pad North Reference: True Well: 2D-05 Survey Calculation Method: Minimum Curvature Wellbore: 2D-05L1-02 Design: 2D-05L1-02_wp13 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,840.00 6,001.59 3,965.80 1,976.38 TIP/KOP 7,870.00 6,001.21 3,995.62 1,973.12 2 7,910.00 6,003.21 4,035.44 1,970.07 3 7,940.00 6,006.00 4,065.30 1,969.48 4 8,010.00 6,012.32 4,134.71 1,975.21 5 8,125.00 6,011.38 4,246.15 2,002.46 6 8,235.00 6,005.08 4,345.54 2,048.60 7 8,435.00 6,001.08 4,490.32 2,184.40 8 8,985.00 5,992.85 4,971.92 2,380.58 9 9,460.00 5,989.78 5,406.07 2,518.85 10 9,900.00 5,989.84 5,805.65 2,662.45 TD at 9900.00 6/12/2012 1:48:26PM Page 5 COMPASS 2003.16 Build 69 F=M / Ihly1iI * 0 0 N C O � l O 8 oo O to N CC2 �\ n b I N O O \ 8 C 11 \1 1 \I 1II 1 M b 8 0 P N \ \\ \ I1 I II r' NE0 S \ N ' 1 11 1 1 II 1 °" I \ 1 I I 1 I I u '1 \ I 1 I I I I p O p .p p 1 \\ 1 II l i O 8 \ 1\ I I 1 1 0 2 W 2 ‘\+ '\ I 1 II I I I 0 N N ----'1 Z. F o o 2_ I 1\ 1 \\ ' o + __- R s ��o N \ ifU en IenilhL olirI IMI Z~g�m 1 1111 p �mE,U -�!Mk. N �O r b 0 .Op O N N O Q ' 0 I J O _ 4L O • O O• O O O r....CD ON^ N \J J9 0 < `i p O o o p W O 2 N i O o cD O v a o 0 0 0 m 8 O o 0 0 0 0 0 0 0 0 „� N W e e e N h N o e v v 8 m m ♦+ m .• ~ (u!R3 ON)(+)upaN/(-)ulnog 71 `m O O w a 3 -0 Nu iPaq O o ' S 6v 0 i_i Q Sp O m ssl M ZO_ m 1 N SSa N N v 75 At lq 1- O +QiCO)tG[VR: (V tV OtC N >44-vQWWv2mM NN0 o0 0 r Sr �c 0 C V q J a e ............ a N - igIO..:!= OOOm 4 LL O O O.O..... r K N NO O H �Q—mQ 0,3 v- CO N Y Y 4 99. ^ 0 m.... 0000000000 o aa44N 0'0000000000 v Y Y m =00:2. NcEiita+ Z Jp ON.... .I NI NIcic l(.I -2:.:(02.1 O I � �+�i�OWN4SW um'i,mv -� QN34 0 ^ �00g�0Oo�'�0r�nn°� 8�p 1 ...I 0' i- O)O)O)O cna W, NNN 4 o j r O Z co p p N N F' 0 Z.�p.In1cc��D��llpCp,N.AQ4 H2 0s�M�O�ppf0 a J W +Cm m.;r 3WN� __ -_ ? .. Q CN (n O���ONmmpppp -N C9111� .I.,,,,,7t7O---, N ,c6N_vi,,m,„ Ooo800 O8 2 u M m m M OD u0 m m US U, I per^ In N-N-I\\D Nm I'sm N-N- I '9 �� v,o �nmm ��c-� q �� r p a Z"- mrnr�mm mm Qln C N C mgR16-.. �O4tll� .088888888888 mpm pm p�....` pppdp�p8i pm ` pS b v �O 30 00000000000 N O r VONT O t� o• N O h W6 ............Qpf h h N \00 \8 N 9 b 9 1 -N-N-N-000000w,CD \o/ ane eeg ueaw 1 (yc7Q Am1�mD � Utu r,\ RD A A L , :;� ,.. uuda gai a awl V `, KUP 2D-05 ConocoPlliIIips '-' Well Attributes Max Angle&MD TD Alaska,Inc. i,' Wellbore API/UWI Field Name Well Status Incl I) MD(ROB) Act Btm(RKB) w�ocw,nl,ps 500292115700 KUPARUK RIVER UNIT INJ 46.80 3,700.00 7,990.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date Wel tonna:-2D-os.1229ao11 e:aoo2 AM SSSV:LOCKED OUT Last WO: 46.60 9/20/1984 Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,842.0 12/28/2011,Rev Reason:GLV C/O,TAG ninam 12/29/2011 Casing Strings Casing Description String O._ String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 35.0 116.0 116.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String Wt...String... String Top Thrd SURFACE 95/8 8.921 34.9 3,832.9 3,165.2 36.00 J-55 BTC HANGER,33 r Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(WD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 33.0 7,971.2 6,345.3 26.00 J-55 BUTT Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd t TUBING 31/2 2.992 32.7 7,625.5 6,031.0 9.30 J-55 EUE8RD Completion Details Top Depth (WD) Top Incl Noml... CONDUCTOR, Top(MB) MB) et Item Description Comment ID(in) 35-118 32.7 32.7 0.40 HANGER FMC GEN III TUBING HANGER 3.500 1,870.2 1,751.6 39.78 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 7/26/94) 2.810 7,365.5 5,801.7 30.38 PBR BAKER PBR 3.000 SAFETY 1,870 _ 7,379.2 5,813.4 30.14 PACKER BAKER FHL HYD SET RETRIEVABLE PACKER 3.000 7,521.8 5,938.3 27.76 BLAST RING 2.992 7,604.2 6,012.2 27.11 LOCATOR BAKER LOCATOR SUB w/5'SEALS 2.992 GAS LIFT, 7,606.0 6,013.8 27.08 PACKER BAKER FB-1 PERMANENT PACKER 4.000 2,074 7,608.5 6,016.0 27.04 MILL MILL OUT EXTENSION 2.992 7,621.5 6,027.4 26.82 NIPPLE CAMCO D NIPPLE NO GO 2.750 I 7,624.9 6,030.4 26.76 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 7626'during SWS(PROF on 2.992 08/23/08 SURFACE, -� 1114. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 363,833 Top Depth ppp (TVD) Top Incl FISH,4,210 - Top(RKB) (ftKB) (°) Description Comment Ran Date ID(ie) GAS LIFT, 4,210 3,427.0 45.11 FISH STAINLESS STEEL BAND FROM HOLEFINDER APPROX 11/30/2008 0.000 4,210 3/4":x9"x 1/16" r 7,616 6,022.6 26.91 TBG Punches TUBING PUNCHES shot w/2"HSD GUN HJ CHARGES 1/28/2007 2.992 GAS LIFT, 1 1/28/2007 5,722 1 Perforations&Slots GAS LIFT, yj` Shot 6,842 1 Top(WD) Btm(WD) Dens Top(MB)Btm(RKB) (ftKB) (RKB) Zone Date Oh- Type Comment 7,534 7,578 5,949.1 5,988.2 C-4,UNIT B, 9/28/1984 12.0 IPERF Dresser Atlas GAS LIFT, 2D-05 7.319 `� 7,678 7,688 6,077.7 6,086.6 A-5,2D-05 9/28/1984 4.0 IPERF Dresser Atlas 7,700 7,742 6,097.5 6,135.6 A-4,2D-05 9/28/1984 4.0 IPERF Dresser Atlas PBR,7.368 Notes:General&Safety End Date Annotation PACKER.7,379 4/7/2001 NOTE:BROKE OFF LATCH WHEN ATTEMPTED TO PULL DMY 4- 7/30/2010 NOTE:TAGGED OBSTRUCTION @ 6864' GAS LIFT, 9/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 7,418 MMM GASLIF,485 T,_ `I 7 I PERF, 1 I 7,5347,578 ilk GAS LIFT. i. 7,587 EJ LOCATOR. J, 1=t 7,6047,604 _ C PACKER,7,805 MILL,7,609 TOG Punches, 7,618 NIPPLE,7,621 ;`) 'r [ l SOS,7,625 -+- Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Sian TRO Run IPERF, 111 ■ Ste Top(MB) (RKB) (°1 Make Model (in) Sery Type Type (in) (psI) Run Date Corn... 7,678-7,688 1 2,073.6 1,906.9 40.77 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 2 4,209.9 3,426.9 45.11 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 3 5,721.6 4,525.4 41.31 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/28/1994 IPERF, 4 6,842.2 5,376.7 39.98 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 12/17/2006 7,700-7,742 5 7,318.8 5,762.0 31.21 OTIS HP Round 1 1/2 GAS LIFT DMY RO 0.000 0.0 10/2/1989 6 7,418.0 5,847.2 28.89 MMH MMH 1 INJ DMY BK 0.000 0.0 11/27/2008 7 7,484.7 5,905.5 28.17 MMH MMH 1 INJ CV INT 0.000 0.0 12/28/2011 8 7,587.5 5,996.6 27.06 MMH MMH 1 INJ DMY BRO...0.000 0.0 10/14/2004 PRODUCTION. r. {-- NA 33.7,9909,,,,, .- TD(2D-06). • ✓S \1 7,990 --c--.)- co 0 Y o co eC co Z 2 Co Y 0 - - b 17) •o- CO C-- 1"-- ._ CO E Cr .E.' 1--- -c •cr Er) 0 a E 2 •:r --- cz, 0 al Lf) ----- E0 CC 0 o it o L._ a ,- _ -- 4 ,- 6 o ,, a) a - b r"- b c•1 CV I— • ° Cri &I 4 0 4 - co 0 l'- . . ,---- -,-_-_- b c3) ,-_,..,-- co 03 '19n; CO 0 I I " I I N- C ‘..., C Y IT C O 1 El ......N- Y c " . . . . ft = I- C\I c En b Ca Co Co 0.0 © DcD CO g CO N- E 1-- .c Z . 00 .. „ . . ,._ 01 > co u) co I-- ,,, ,--- 0)csi c.: U) I-- r-- C 0iz‘'-'-• CO C 0 CD a . 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I 0 1 © ,if fy ,, 0 n. co a) 121- 1— cu o _c u) co .4 co co 1---- u) ,-- a) c a = _ 'Co in r,-- g al IR: CL C - ,': " 0 al c0 7;1 -c cn LO I-0 CO Lf CO 4-- ,_ v.) = f; -3 e y -1 y a) In eC a) . co 1.11 0 U f:t 0_ ENI r-- CC) •—• COI _C V) CO CO 'CO 0 CK C a I I I - cr) 1 _ c\i co E0 .C)o co cn 1--- . . , . 2 co , in 01 Li-) 0 N-. . , r--. CO 3• — • a CO g C' Zo a $ a C. 11 E cp 6 a__.._.. 6 1 I CV F- --,.. CV ORGIN 1 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Tuesday, July 03, 2012 9:46 AM To: 'Ohlinger, James J' Cc: Schwartz, Guy L (DOA) Subject: RE: 2D-05 Procedure James, You have verbal approval to proceed with the outlined steps below. We expect to have the PTDs for the three laterals approved today. Thank you, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria ferguson©alaska goy From: Ferguson, Victoria L(DOA) Sent: Monday, July 02, 2012 4:42 PM To: 'Ohlinger, James J' Cc: Schwartz, Guy L(DOA) Subject: RE: 2D-05 Procedure These steps are a part of the permit to drill. I will be in touch with you tomorrow morning concerning the status of the permit to drill. From: Ohlinger, James J Jmailto:James.J.Ohlinger@conocophillips.com] Sent: Monday, July 02, 2012 4:15 PM To: Ferguson, Victoria L(DOA) Cc: Schwartz, Guy L (DOA) Subject: FW: 2D-05 Procedure Mrs. Ferguson —are the following steps in red allowed to proceed under the Sundry 312-209? Please let me know if you need anything else or clarification. Sundry 1.MIRII Nabor.('DR2-AC rig using 2'. coil tubing. 2.NU 7-1 16- ROI'F and test. 1.Drill 2.80'' high-side pilot hole through cement to 7670' MD 4.Drift pilot hole with whipstock dununv 5 RU F-Line for Caliper of pilot hole 1 6.Set \\hipstocl. at 7637' MD vv ith high-side orientation. 7.MU EXPRO(downhole) Camera on C'I K E-line Adapter Drilling Permit 8.Mill 2.80"window at 7637' MD. 9.2D-05L1 Sidetrack(A4 sand,south) a. Drill 2.70"x 3"bi-center lateral to TD of 9860' MD b. Run 2%"slotted liner with an aluminum billet from TD up to 7775' MD 10. 2D-05L1-01 Lateral(A4 sand,west) c. Kick off of the aluminum billet at 7775' MD d. Drill 2.70"x 3"bi-center lateral to TD of 9880' MD e. Run 23/8"slotted liner with an aluminum billet from TD up to 7840' MD 11. 2D-05L1-02 Lateral(A4 sand,north) f. Kick off of the aluminum billet at 7840' MD g. Drill 2.70"x 3"bi-center lateral to TD of 9900' MD h. Run 2%"slotted liner from TD up to 7615' MD, up inside the 31/2"tubing tail James OFiinger Senior CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-854-2414 cell 2 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL ��LETTER CHECKLIST /�S WELL NAME l'�l�-Lt z D '-c c L( "- PTD# 2, G-2-L- -0 ‘ Development _' Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ISL 1 e Z-°-e--,5 POOL: /Z - -- L Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well / ( Z_Z) (If last two digits in �C API number are Permit No./��/�_ ,API No. 50- I� ?- ,(7z, between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 (n D m • D gD a -I : , 71 a 0 r a CO(G 3 p ,. C) p d o d p a o co CD N f.g (D0 N 3.O a) y 7 O) Cr. O N p N co NCO i N C) 3 0 co 0 O O( D : O (D 0 (D Is.. CO CO J O) O1 A Co N 0 (O Co J O) cn A W N 0 CO Co N N N N :,. . o W W Co W CO CO W Co j CO N) N) N N) N N N N N N -, . a) Ut A COW N) 0 CO Co -.I O) 01 A Co N - V 3 es iv N ,.X.., C) Cn C/) 0 m K 0 * C) CO CO 0 =, D =. 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