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212-154
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 directinspection of the file. 2I a - Ls 14- Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESC OVERSIZED: NOTES: or Items: Gra scale Items: ❑ Ms : Lo s: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: t ell I CAP if /s/ vvir Project Proofing I BY: Maria Date: ` a. a /s/ Scanning Preparation I x 30 = 30 + .(7 = TOTAL PAGES ;"---6/ (Count does not include cover sheet) BY: Maria Date: I ! $ l /s/ Production Scanning • Stage 1 Page Count from Scanned File: bo (Count does include cover heet) Page Count Matches Number in Scannin Pre aration: YES NO BY: AM Date: i 0,,,, t S / /s/ (,/Vlf 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 Michel 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 7/8/2014 Well History File Cover Page_20140708.doc r\ JV co 0 a aco Z rZ /Z CsI zeV II c ll- > >-• > N 1 1 •- 4 ? I' />- m a c H LA 1� N fl _a a) a)Z u) Im v) J o o a) o H O C x 7 J • ? o E C7 C9 cc C7 co r 0_ m C7 m /Q ° Em rn L U m > r m OQ J pW OV lm y '° a)Ce Q E ' E2 2 a O U tu /� d j "' N N N cc cc ccN N d To co A J Y co > N N N N N E c/> E co o Jco m W 2 - 43 co co v cn Z - ai a ami Cl) 0) I VCe 0 CO E mW zJ -. C C C C C 22n a a a a '13 d y - a) as 0 a co HU V O 0 0 0 0 0 0 0 - J ca u; wZ � c g g g 3 mx o) yrn• o ECQ R N M c7 co el N) -o .—.o u) O o 7 CLo co O a) 0 0 C (y C I / ZI c t CO CO CO N- m a) G 0 1 a r` r- N- co cD w N — i a) N o 0 0 0 r E a U = U Z • F.- . I r11 o• z CJ 0Q ca � aO Ew IO a) O O O cs) J 2 U U U To Cl) N CZ N — L'' 1 11 II) Z D w2 / O) ca > a) • ce a) a) E CO O V'N C E J N Y 'tm a) c ) w aQIlk Cn Ce co CO C- C O Q C I - f0 1 lib Y g I,I ,I I c ,U a) II I O a NI a r zI �) 0Ail 1 < z ELu w w w • aa) co EU o > > '> '> a 2 a O J Ct N co N Z co Irk Z 7 0 N ur N 7 fn IX CL CC — C `' Tu 'c c c c --- cu --- co , 7 E II,O O O O O C /z C I ) i) v 0 _ `?i / cD 2 z > > > a, o :'co } >- >- j p, C C C a C E •1111 p c In > o J of m I Y N 3d o O dN p OO WGZ W C >O NQ „ co a) Owa) mO Oo E E z Yix . c6 co m 0 it HcaN- LL � Z - - N fZ — 0 ca — c° j p Q � w p i3 a) J ai o c° Ccoo el WLL yo) 0 o u ai' Ce z oE a15 0 a c o! acE E 0 a LL O a W O J0oa) A TJ J C WQ J 0 /- I ? U dO 0 0 7 / 1/ 1 STATE OF ALASKA 111 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status. Oil ❑✓ r Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class 20AAC 25 105 20AAC 25.110 Development ❑ • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No of Completions: •4 if) Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp,Susp., t[130 ,Q 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband' Noveber'2Q,2012 212-154/ ' 3.Address: 6 Date Spudded: 13 API Number P.O.Box 100360,Anchorage,AK 99510-0360 November 9,2012 • 50-029-22728-60 i 4a Location of Well(Governmental Section) 7 Date TD Reached: 14 Well Name and Number Surface: 68'FNL, 1749'FEL,Sec.33,T11 N,RO9E, UM November 12,2012 ' 2F-19AL1• Top of Productive Horizon. 8. KB(ft above MSL): 129'RKB• 15 Field/Pool(s): 2153'FNL,2592'FEL,Sec.3,T1ON,RO9E, UM GL(ft above MSL): 96.8'AMSL. Kuparuk River Field• Total Depth 9.Plug Back Depth(MD+ND) 856'FSL,2722'FEL,Sec.3,T1ON,RO9E, UM 13647'MD/6128'TVD . Kupuruk River Oil Pool. 4b Location of Well(State Base Plane Coordinates,NAD 27): 10 Total Depth(MD+TVD): 16 Property Designation. , Surface: x-517483 y- 5948815 Zone-4 13647'MD/6128'TVD , ADL 25657,25666 TPI: x-521953 y- 5941462 Zone-4 11.SSSV Depth(MD+ND) 17 Land Use Permit 1 Total Depth: x-521834 y- 5939192 Zone-4 nipple @ 513'MD/513'TVD • 2583,2587 18.Directional Survey Yes E• 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) 1650'MD/1602'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071): 22.Re-dnll/Lateral Top Window MDTTVD GR/Res 11679'MD/6104'TVD • 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 42' 121' 42' 121' 24" 260 sx AS I 7.625" 29.7# L-80 41' 4711' 41' _ 3222' 9.875" 261 sx ASLW,1220 sx Class G,60 sx AS I 5.5" 15.5# L-80 39' 10635' 39' 5877' 6.75" 100 sx Class G 3.5" 9.2# L-80 10019' 11150' 5430' 6394' 4.75" 132 sx Class G 2.375" 4.7" L-80 11325' 13647' 6086' 6128' 3" slotted liner 24 Open to production or infection? Yes ❑ No a 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/TVD) 3.5" 10019'MD 10019'MD/5430'ND slotted liner from 11328'-13647'MD 6086-6128'ND 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC ' Was hydraulic fracturing used during completion? Yes❑ No E I; ..."_: DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED :< 12-N RECEIVED JAN 1 8 2013 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) I�OGCV pre-produced injector 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 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 summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descnptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071 REIMS JAN 2 8 201 e NONE Form 10-407 Revised 10/2012 CONTINUED ON REVERSE — Submit original only 111 29. GEOLOGIC MARKERS(List all formations and markers encountered) 30. FORMATION TESTS NAME MD TVD Well tested? Yes 0 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 1650' 1602' needed,and submit detailed test information per 20 AAC 25.071 Kuparuk A4 11679' 6104' Kuparuk A4 13647' 6128' N/A Formation at total depth: Kuparuk A4 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 263-4093 Email: James.J.Ohlinaer(ilconocophillips.com 02742 Printed Name Lamar Gantt Title: CTD Supervisor `�f �, //„//3 Signature �fjry�� Cv Phone 263-4021 Date 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 ND 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 10/2012 0 . KUP i 2F-19AL1 • ConocoPhillips ' maw Well Attributes Max Angle&MD TD Alaska I Wellbore APINIWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(RKB) 500292272860 KUPARUK RIVER UNIT PROD 94.86 11,115.45 13,645.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Con6p.-2F-19AL1,1/11/2013 21020 PM SSSV:NIPPLE 55 10/16/2006 Last WO: 5/25/1997 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW/SET PATCH osborl 1/10/2013 HANGER,27 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(TVD)...String Wt...String... String Top Thrd 9 LINER AL1 23/8 1.995 11,327.5 13,647.0 6,128.2 4.70 L-80 STL Liner Details 'Top Depth (ND) Top Incl Nomi... Top(ftKB) (RKB) (°) Item DescriptionComment ID(in) • 11,327.5 6,085.9 89.91 BILLET LINER TOP BILLET 1.000 Perforations&Slots Shot Top IND) BtmTVD ( ) Dens Top(ftKB)Btm(MB) (MB) (ftKB) Zone Date Intl... Type Comment CONDUCTOR. r 11,336.5 13,646.6 6,085.9 6,128.1 A-4,2F-19AL1 11/12/2012 32.0 SLOTS 42-121 1+lotes:General&Safety End Date Annotation NIPPLE,513 11/30/2012 NOTE:WELL SIDTRACKED,ADDED LATERALS AL1,AL2,AL3 11/30/2012 NOTE:LATERAL 2F-19AL1 OFF 2F-19AL3(See Multi-tat Drawing) GAS LIFT 3.335 .I..' i j .: D ii SURFACE, Al L 41-4,711 11111 GAS LIFT. 1 7.601 IN lir PACKER,9,350 _ PATCH,9.353 III! PACKER,9,359 1 AV GAS LIFT, • 9,943 NIPPLE.9.996 IME LOCATOR, 10,004 Mil TOR. PBR,10,005 ANCHOR, 10019 • 1117 PRODUCTION,0,676 • I. 39-1 Elh• WHIPSTOCK. 70,720 WINDOW•A•, Mandrel Details 10,790-10,800 LINER Top Depth Top Port SEPost 2012 Sidetrack, trock, (TVD) Intl OD Valve Latch Size TRO Run 70,1137 Stn Top(ftKB) MKS)) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... SLOTS, 10.e75-11650 1 3,334.9 2,637.7 63.18 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 10/16/2012 8:00 11407-12513 2 7,600.7 4,374.1 66.37 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 9/25/2012 9:00 LINER AL2, 10777-11,950 + 3 9,943.3 5,383.1 52.82 BST AXT 1 GAS LIFT DMY Ti 0.000 0.0 9/26/2012 4:00 SLOTS, 1 + 11,336-t3,647 LINER AL3, 614 ,096-12.513 TO(2F-19AL1), 1 S 13,645 LINER ALI, 11,327-13,647 be LINER A. 11,661-14,400 MI .I I II 2 C] Ch vow p a V co 2 in co `� < co 67 • Qpm Iil //::: 'a J p a) -o Q H CO No 0 0 Lops Ct co OCo 7 Q CV M 00 Q O -a ti m 0 03r- ,n - _ ca co C co r' a@`) r i', M ;� M E chI2C co p p f° (d �' c8i co � E rn in a0 moo cr D_ 0_ -Jp = (B �M r' a) O I� O O • M Q F- CO V II a) ©N O� N O 0) �O 0 Y o 0 cv) c me � m mc co' E � -6- YY �7 U O rn coO " C Y 0_ O_ CO Cl -- n 00 co CC is (13 a) a) 0 ' n. O O m °' _c_ W co Ill 0)Q O �t O O �- c W aci (9 _c o o c�i rJ tJ m dU U o f c co c c c -J p 0 © t a) � 0 O , � = in u) < H O ? 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O C 0 C "•' M M M M M M M co- C] M co- M co- M M M M Q O. d Of d LI p •�: : d d y O 0 O in 3 3 0 y 1 2F-19 ^ -Rig Well Work Summary DATE SUMMARY 9/23/12 (PRE-CTD): SCLD (IN PROGRESS) CURRENT OA FL @ 426' 9/24/12 RECOVERED LOST JD & PULLED GLV @ 7600' RKB. IN PROGRESS. 9/25/12 SET DV @ 7600' RKB. PT TBG & IA TRACKING. PULLED DV& SET NEW @ SAME. IA STILL TRACKING. IN PROGRESS. 9/26/12 RAN HOLE FINDER, PREMATURELY SET, AND OBTAIN GOOD TEST TBG. @ 8661' SLM ( STA#2 GLM @ 7600' RKB ). REPLACED DV @ 9943' RKB W/TBG X IA STILL TRACKING. RAN HOLE FINDER AND SET ONTOP OF THE CATCHER @ 9995' RKB WITH FAILED TEST. LEAK DETECT UP WITH THE LAST FAILING TEST @ 9450' SLM AND PASSING TEST @ 9240' SLM (ABOVE GLM#3 @ 9943' RKB ). UNABLE TO ESTABLISH LLR. READY FOR E-LINE. 10/2/12 (PRE-CTD): SCLD (IN PROGRESS) OA FL @ 912'.. 10/6/12 SCLD- PASSED; OA FL @ 1074FT. 10/16/12 PULLED GLV @ 3334' RKB. SET DV @ SAME. PULLED CATCHER @ 9992' RKB. PULLED CA-2 PLUG @ 9996' RKB. DRIFT FOR CIBP WITH 2.73", 3' OF WB &2.72"TO 10,813' SLM. READY FOR E-LINE. 10/17/12 MITIA(FAILED)TO 3000 PSI, LLR IA @ 11 GPM. 10/20/12 PERFORMED LEAK DETECT. IDENTIFIED TxIA LEAK IN TUBING COLLAR AT 9361' CORRELATED TO TUBING TALLY. LOCATED LEAK PUMPING 0.2 BPM DOWN IA THROUGH LEAK TO FORMATION. SET TOP OF HALLIBURTON BRIDGE PLUG AT 10811'. CCL TO TOP OF PLUG OFFSET 8.4', CCL STOP DEPTH 10802.6'. 10/21/12 SET TOP OF WHIPSTOCK AT 10790' ORIENTED AT+9.1 DEG ROHS. CCL TO TOWS OFFSET 19.1', CCL STOP DEPTH 10770.9'. RA PIP TAG SET AT 10797'. 10/22/12 Performed injectivity test to 1500 psi; after.61 bbls pressured up and held tight. Attempted to bleed off tubing for no-flow test, unable to bleed below 500 psi. See attached pump report 10/25/12 SET 2.75" CA-2 PLUG @ 9996' RKB. SET AVA STYLE CATCHER ON TOP OF PLUG @ 9995' RKB. BLEED DOWN TBG & IA. IA WENT ON A VAC &TBG DOWN TO A WHISPER. TURN OVER TO DHD. IN PROGRESS. 10/25/12 (PRE-CTD) BLED T& IA TO OPSI. FOR BPV. 2F-19 Post Rig Well Work Summary 11/26/12 Developed leak at lubricator quick connect while running in hole. Bled tubing to zero and pulled out of hole to repair leak. In progress. 11/27/12 ENCOUNTER HEAVY FLUID @ 1250' SLM. REAL SLOW GOING DOWN TO 1500' SLM WHERE PICK-UP WEIGHT WAS 1100#AT 39 FPM. JOB SUSPENDED. 12/1/12 RIH WITH 2.25 JSN TO 9970' CTMD, CIRCULATE DRILLING MUD OOH WITH S/D, JOB COMPLETE 12/4/12 MOVE UNIT& EQUIPMENT TO 2F-19 12/5/12 PULLED AVA CATCHER FROM 9959' SLM, PULLED PRONG FROM CA-2 @ 9963' SLM, PULLED CA-2 PLUG BODY @ 9964' SLM, ACQUIRED REAL-TIME SBHP STOPS WHILE POOH WITH PLUG AS PER PROGRAM 12/6/12 BRUSH/FLUSH TUBING FROM 9200'TO 9400' SLM, DRIFT TBG W/20' DUMMY PATCH TO 9500' SLM, LDFN 12/7/12 TIE IN AND SET 3 1/2"WFD LOWER ER PACKER WITH DIGITAL SL, CENTER ELEMENT SET @ 9372' MD, SET TEST TOOL IN LOWER PACKER @ 9345' SLM, PERFORMED CMIT TxIA 2500PSI ***PASSED***, LDFN 12/13/12 SET 22.3' x 2.74"WEATHERFORD PATCH AND UPPER ER PACKER @ 9350' RKB. MITIA( FAILED )WILL TROUBLESHOOT IN A.M. SET 3 1/2 ER TEST TOOL @ 9350' RKB. MITT TO 2500 PSI ( PASSED ) . IN PROGRESS. 12/14/12 MITIA AND DRAW DOWN TEST FAILED ON IA. MITT( PASSED ). PULLED ER TEST TOOL @ 9350' RKB. LAY DOWN EQUIPMENT DUE TO COLD WEATHER. IN PROGRESS. 12/16/12 PULLED UPPER PATCH ASS'Y FROM 9350' RKB. SNAP-LATCH WAS NOT ENGAGED. RAN TEST TOOL TO LOWER ER PACKER @ 9372' RKB AND CMIT TO 2500 PSI PASSED ) . WILL RETURN TO RE-SET PATCH ( IN PROGRESS ). 12/23/12 SET 19.84'WEATHERFORD UPPER PACKER & SPACER ASSEMBLY @ 9349' RKB. IN PROGRESS. 12/25/12 SET 3-1/2" ER TEST TOOL IN --ATHERFORD PATCH © 9349' RKB. MI G, PASSED. ATTEMPTED MIT I. .ILED. IN PROGRESS. 12/26/12 (AC EVAL) MITIA TO 2500 PSI; FAILED DUE TO LOSS OF 500 PSI IN 30 MI .. 1/3/13 PULLED 3 1/2 ER TEST TOOL FROM UPPER PATCH ASSEMBLY @ 9349' RKB, PULLED UPPER ER PATCH ASSEMBLY @ SAME STINGER SEAL LIGHTLY DAMAGED SNAP LATCH NOT SHEARD. CMIT TxIA PASS. IN PROGRESS. 1/8/13 BRUSHED LOWER ER PACKER @ 9372' RKB ( RECOVERED STINGER SEAL ) SET 22.3' x 2.74"WEATHERFORD PATCH AND UPPER ER PACKER © 9350' RKB. IA DRAWDOWN TEST TO 50 PSI ( PASSED ) . MITIA TO 2500 PSI ( PASSED ) SET CATCHER SUB @ 9350' RKB. IN PROGRESS 1/9/13 PULLED DV @ 7601' RKB AND SET OV. PULLED DV @ 3335' RKB AND SET GLV. PULLED CATCHER FROM 9320' SLM. JOB COMPLETE. Time Log & Summary ConocoPhitlips We/Mew Web Reporting Report Well Name: 2F-19 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 10/28/2012 10:00:00 AM Rig Release: 11/20/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/28/2012 24 hr Summary MIRU on 2F-19. Reel swap, BOPE test 250 low/4700 psi High. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Move from 2F-11 to 2F-19.Spot modules. 06:00 10:00 4.00 0 0 MIRU MOVE RURD P PJSM-rig up hard lines,steam lines and set down cribbing around the rig. 10:00 12:30 2.50 0 0 MIRU WELLPF CTOP P ***Rig Accept** PJSM for unstabing Coil.Set up rig floor and unstab CT from injector. 12:30 14:30 2.00 0 0 MIRU WELLPFCTOP P Secure reel, peak on location. Remove iron from inside of reel. 14:30 16:00 1.50 0 0 MIRU WELLPFCTOP P PJSM with Peak drivers. Start offloading reel from rig. Reel loaded out. 16:00 18:00 2.00 0 0 MIRU WELLPFCTOP P Swap reel spacer hubs on new work string. 18:00 19:30 1.50 0 0 MIRU WHDBO NUND P PJSM Complete nipple up. Hammer up tree.Complete post rig move checklist 19:30 23:00 3.50 0 0 MIRU WELLPFCTOP P Reconfigure test joint and safety joint,Grease rig valves in prep for BOPE Test,Complete cellar rig up. Get Koomy online. Fluid pack rig 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE P Start full BOPE Test,Witness waived by Lou Grimaldi,AOGCC 10/29/2012 Complete BOPE Test, R/U S/L to Pull plug 00:00 09:00 9.00 0 0 MIRU WHDBO BOPE P Continue BOPE Test,Witness waived by Lou Grimaldi,AOGCC. C-16 failed test. Replace valve and re-test. Pass.Tested alarms. 09:00 11:30 2.50 0 0 MIRU WHDBO SEQP P Valve checklist, R/U&Pressure test PDL/Tiger tank lines.2500 psi. Little bit of ice slush in TT line. Pump 25 bbls to TT to warm up the line. 11:30 12:30 1.00 0 0 MIRU WHDBO MPSP P PJSM-pull BPV. IA=0/OA 630 psi. 12:30 16:30 4.00 0 0 SLOT WELLPF SLKL P PJSM-start bringing in SL equipment&set up rig floor. Rig up SL. Pressure test to 2500 psi. 16:30 18:30 2.00 0 9,980 SLOT WELLPF SLKL P Open swab valves-RIH for catcher sub. POOH. Lay down catcher at surface. 18:30 19:00 0.50 0 9,995 SLOT WELLPF SLKL P RIH-stop 50'above CA plug. Pressure up Wellhead to 1500 psi- started to leak off-IA pressure tracking tubing pressure.equalized at 1400 psi. Bump up to 1700 psi. Did not get the plug. Page 1 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 19:30 0.50 9,995 0 SLOT WELLPF SLKL P Bleed down pressure POOH. Install split skirt tool. 19:30 00:00 4.50 0 9,995 SLOT WELLPF SLKL P RIH-Stop prior to plug. Pressure up to 1700psi.Good indication of latch- pressure bled down 200 psi. POOH. Equalize sub at surface. RIH for plug body. First run failed, P/U spangs. RIH sheared off pins. POOH Set heavier pins-RIH. 10/30/2012 Preform SL Mgmt, Head up BHI 00:00 01:00 1.00 9,995 0 SLOT WELLPF SLKL P Slickline on surface with plug 01:00 02:45 1.75 0 0 SLOT WELLPF PULD P PJSM, R/D and load out slickline equipment 02:45 04:45 2.00 0 0 SLOT WELLPF CTOP P PJSM, R/U grapple to end of coil, pull test grapple, pull coil into injector 04:45 06:00 1.25 0 0 SLOT WELLPF CTOP P Seal end of wire,Stab on and fill coil 06:00 07:00 1.00 0 0 SLOT WELLPF PRTS P Pressure test inner reel iron, pressure bulkhead,and stuffing box. Pressure bulkhead seeping after 3 minutes on HP test. Bleed down and tighten packoff element,Get good test. 07:00 09:00 2.00 0 0 SLOT WELLPF CTOP P Perform Slack Mgmt,Cut 25'to find wire cut a total of 30',test wire good test 09:00 13:00 4.00 0 0 SLOT WELLPF CTOP P Dress coil and install CTC, Pull test to 40K, Head up E-Line to UQC test wire and UQC,All good, PT connector to 4K 13:00 14:00 1.00 0 0 SLOT WELLPF SFTY P Perform Pre Spud with day crew (Corder) 14:00 15:00 1.00 0 0 SLOT WELLPF SFTY P Flow check well,500 PSI WHP, IA=470. Bleed off to TT and monitor, PJSM 15:00 16:36 1.60 0 73 PROD1 WELLPF PULD P P/U BHA#1,2.74 Dimond window mill, new 2.74 string reamer, .6° motor, 10'pup,M/U to coil and surface test tools, Strip on and set counters. Inspect packoffs 16:36 19:45 3.15 73 10,660 PROD1 WHPST TRIP P Trip in hole with BHA#1 19:45 20:00 0.25 10,660 10,680 PROD1 WHPST DLOG P 10660ft start tie in correction of-8ft 20:00 20:30 0.50 10,680 10,645 PROD1 WHPST SFTY P Pre-Spud with crew while swapping fluid over in tubing to power-vis. Moving coil up hole. 20:30 20:45 0.25 10,645 10,685 PROD1 WHPST MILL P Bring returns back in side.Trip in hole to 10685ft. Close EDC 20:45 21:00 0.25 10,685 10,790 PROD1 WHPST MILL P Dry Tag TOWS at 10790.3ft. RIW 16k, PUW 37k 21:00 00:00 3.00 10,790 10,792 PROD1 WHPST MILL P 10789.7ft Start Milling window- 1.48bpm at 3400 psi FS. 10/31/2012 Finish milling 2.741D window, Ream window area, POOH and MU Build BHA 00:00 03:45 3.75 10,792 10,796 PROD1 WHPST MILL P 10792.2ft Milling Window-1.42bpm at 3400psi FS. Page 2 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 05:51 2.10 10,796 10,800 PROD1 WHPST MILL P 10795.8ft release brake, mill formation ahead at 2fph 05:51 08:03 2.20 10,800 10,811 PROD1 WHPST MILL P Drill Ahead in rathole, 1.45 BPM @ 3450 PSI FS, BHP=3950 08:03 09:21 1.30 10,811 10,811 PROD1 WHPST REAM P Ream window per procedure, PUW=34K, BHP=3955 09:21 12:27 3.10 10,811 55 PROD1 WHPST TRIP P Trip out, PUW=34K, 12:27 14:03 1.60 55 0 PROD1 WHPST PULD P At surface. PJSM, Lay down BHA#1 14:03 15:33 1.50 0 0 PROD1 DRILL SVRG P Service injector,reel,tighten reel hub bolts,and top drive link tilt, reconfig motor 15:33 17:03 1.50 0 62 PROD1 DRILL PULD P PJSM. P/U BHA#2 with 2.4°motor and RR Hughes Bi Center,Make up coil and strip on well,surface test tool,tag up and set counters 17:03 17:15 0.20 62 10,660 PROD1 DRILL TRIP P RIH-Open EDC pumping.30 bpm 17:15 20:15 3.00 10,660 10,683 PROD1 DRILL DLOG P 10660ft-Tie into K1 correction of -17ft.Close EDC 20:15 20:30 0.25 10,683 10,812 PROD1 DRILL TRIP P RIH-ECD closed 20:30 23:00 2.50 10,812 10,938 PROD1 DRILL DRLG P 10812ft Tag bottom-Drill Ahead in Build section as per Geo and DD. 1.41 bpm at 3460psi. BHP 3965. WHP 129. IA-1438,OA-420 23:00 23:30 0.50 10,938 10,775 PROD1 DRILL TRIP P 10938ft POOH-TD build section. PUW 33k. BHP 4032.WHP 105. IA 1437,OA 426. 23:30 00:00 0.50 10,775 7,960 PROD1 DRILL TRIP P 10775ft Open EDC.Circulate 1.43 bpm while POOH. 11/01/2012 TD build section/Drill lateral section 00:00 02:00 2.00 7,960 0 PROD1 DRILL TRIP P Continue to trip out of hole. EDC open.pumping 1.43 bpm using the MP tripping schedule. 02:00 02:15 0.25 0 0 PROD1 DRILL SFTY P PJSM-OOH space out 1.9ft 02:15 04:45 2.50 0 0 PROD1 DRILL PULD P Tools OOH-MU BHA#3.45°AKO w/HYC bit 2.7x3(SS#A145576)and install into PDL 04:45 06:30 1.75 0 72 PROD1 DRILL PULD P PJSM-Deploy lateral BHA#3 with .45°Motor and Hycalog rebuild bi center,Make up to coil and surface test 06:30 08:54 2.40 72 10,650 PROD1 DRILL TRIP P Trip in hole EDC open 08:54 09:18 0.40 10,650 10,715 PROD1 DRILL DLOG P Log Tie in for-18'correction,Shut EDC, PUW=34K 09:18 09:42 0.40 10,715 10,938 PROD1 DRILL TRIP P RIH to log RA Marker, RA @ 10795.5,TOWS=10789 clean pass through window,Continue in to drill. 09:42 13:12 3.50 10,938 11,080 PROD1 DRILL DRLG P 10837', Drill Ahead, 1.4 BPM @ 3480 PSI FS, BHP=3980 13:12 14:00 0.80 11,080 11,080 PROD1 DRILL WPRT P Wiper trip to window with MADD Pass 14:00 15:54 1.90 11,080 11,230 PROD1 DRILL DRLG P 11080', Drill Ahead, 1.4 BPM @ 3450 PSI FS, BHP=3950,Wide Open Choke Page 3 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:54 16:18 0.40 11,230 11,230 PROD1 DRILL WPRT P Wiper to window, PUW=36K 16:18 19:30 3.20 11,230 11,380 PROD1 DRILL DRLG P 11230', Dril Ahead, 1.4 BPM @ 3430 PSI FS, BHP=3993,Wide open choke 19:30 19:45 0.25 11,380 10,815 PROD1 DRILL WPRT P 11380ft-Wiper to the window for a tie in. PUW 33k. 19:45 20:00 0.25 10,815 10,839 PROD1 DRILL DLOG P 10815ft-Tie into RA marker no correction. 20:00 20:15 0.25 10,839 11,380 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 20:15 23:00 2.75 11,380 11,530 PROD1 DRILL DRLG P 11380ft-BOBD 1.41 bpm at 3400psi. BHP 3960.WHP 20 open choke. IA 1342, OA 445. 23:00 23:30 0.50 11,530 10,839 PROD1 DRILL WPRT P 11530ft-Wiper to the window PUW 37k 23:30 00:00 0.50 10,839 11,530 PROD1 DRILL WPRT P 10839ft-Wiper back in hole RIW 15k 11/02/2012 Drill Lateral section as per plan 00:00 03:15 3.25 11,530 11,680 PROD1 DRILL DRLG P 11530ft-BOBD 1.42 bpm at 3400psi. BHP 3968.WHP 24 w/open choke. IA 1340,OA 449.WOB 2.6k ROP 45fph 03:15 04:00 0.75 11,680 10,810 PROD1 DRILL WPRT P 11680ft-Wiper to the window. PUW 38k 04:00 04:30 0.50 10,810 11,680 PROD1 DRILL WPRT P 10810ft-Wiper back in hole. RIW 15k 04:30 07:54 3.40 11,680 11,830 PROD1 DRILL DRLG P 11680ft-BOBD 1.42 bpm at 3212psi. BHP 3934,WHP 24 open choke. IA 1301,OA 454. RIW 15k 07:54 11:24 3.50 11,830 72 PROD1 DRILL WPRT P 10830,Wiper trip up through the tubing, PUW=42K, Dragging 38K, Come through window,open EDC. Come up to swab valve.Additional cutting at-2200'on way out 11:24 14:24 3.00 72 10,660 PROD1 DRILL WPRT P Tag up and set counters,Trip in 14:24 14:48 0.40 10,660 10,697 PROD1 DRILL DLOG P Log K-1,Geo not happy with first pass, relog interval at 2 FPM, make -8'correction,Close EDC, PUW=35K 14:48 15:36 0.80 10,697 10,831 PROD1 DRILL WPRT P Continue wiper in hole to drill 15:36 16:06 0.50 11,850 11,850 PROD1 DRILL DRLG P 11830', Drill Ahead, 1.42 BPM @ 3305 PSI FS, BHP=3960, RIW=15.3 16:06 16:18 0.20 11,850 11,850 PROD1 DRILL WPRT P Mini wiper for pick up weight, PUW=36, Dragging 35K 16:18 23:30 7.21 11,850 11,980 PROD1 DRILL DRLG P 11850', Drill Ahead 1.4 BPM @ 3350 PSI FS, RIW=15K, BHP=3970 23:30 23:59 0.49 11,980 11,330 PROD1 DRILL WPRT P 11980ft-Wiper to the window. PUW 36k 11/03/2012 Drilled A Lateral section 00:00 00:30 0.50 11,330 10,840 PROD1 DRILL WPRT P 11330ft-Continue wiper to the window. PUW 35k. 00:30 01:00 0.50 10,840 11,980 PROD1 DRILL WPRT P 10840ft-Wiper back in hole. RIW 14k Page 4 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:00 3.00 11,980 12,130 PROD1 DRILL DRLG P 11980ft-BOBD 1.42bpm at 3320psi. BHP 4021.WHP 136. IA 1385,OA 470. 04:00 05:00 1.00 12,130 10,840 PROD1 DRILL WPRT P 12130ft-Wiper#2 to the window. PUW 39k 05:00 05:30 0.50 10,840 12,130 PROD1 DRILL WPRT P 10840ft-Wiper back in hole. RIW 15k 05:30 09:00 3.50 12,130 12,280 PROD1 DRILL DRLG P 12130ft-BOBD 1.42bpm at 3379psi. BHP 4454.WHP 136. IA 1424, OA 454. 09:00 10:00 1.00 12,280 10,810 PROD1 DRILL WPRT P 12280ft-Wiper up to the window. PUW 39.5 10:00 10:15 0.25 10,810 10,854 PROD1 DRILL DLOG P 10810ft-Tie into RA marker. Correction of-1ft. RIW 14k 10:15 11:00 0.75 10,854 12,280 PROD1 DRILL WPRT P 10854ft-Wiper back in hole. RIW 14k. 11:00 15:00 4.00 12,280 12,430 PROD1 DRILL DRLG P 12280ft-BOBD 1.43bpm at 3440psi. BHP 4475.WHP 134. IA 1418,OA 473. 15:00 16:00 1.00 12,430 11,091 PROD1 DRILL WPRT P 12430ft-Wiper to the window. PUW 39k 16:00 16:30 0.50 11,091 12,430 PROD1 DRILL WPRT P 10810ft-Wiper back in hole. RIW 14k 16:30 21:00 4.50 12,430 12,580 PROD1 DRILL DRLG P 12430ft-BOBD 1.43bpm at 3372psi. BHP 4548.WHP 138. IA 1422,OA 451.Start Mud Swap with new 9.3 Power-Vis. 21:00 22:00 1.00 12,580 10,830 PROD1 DRILL WPRT P 12580ft-New Mud at the bit.Wiper to the window. PUW 39k 22:00 23:00 1.00 10,830 12,580 PROD1 DRILL WPRT P 10830ft-Wiper back in hole. RIW 23:00 00:00 1.00 12,580 12,650 PROD1 DRILL DRLG P 12580ft-BOBD 1.46bpm at 3480. BHP 4056.WHP 145. IA 1410,OA 474. 11/04/2012 Drilled the A lateral as per Geo and DD 00:00 01:30 1.50 12,650 12,730 PROD1 DRILL DRLG P 12650ft-OBD 1.47bpm at 3477psi. BHP 4133.WHP 207. IA 1441,OA 473.WOB 2.5k, ROP 50 fph. 01:30 02:00 0.50 12,730 10,810 PROD1 DRILL WPRT P 12730ft-Wiper up to the window for a tie in. 02:00 02:15 0.25 10,810 10,846 PROD1 DRILL DLOG P 10810ft-Tie in to RA marker correction of+2.5ft. 02:15 03:15 1.00 10,846 12,730 PROD1 DRILL WPRT P 10846ft-Wiper back in hole RIW 16k 03:15 06:03 2.80 12,730 12,880 PROD1 DRILL DRLG P 12730ft-BOBD 1.40bpm at 3347bpm. BHP 4135 WHP 85. IA 1357,OA 475.WOB 2.3. ROP 37 06:03 08:03 2.00 12,880 12,880 PROD1 DRILL WPRT P Wiper to 11332, PUW=39K 08:03 10:45 2.70 12,880 13,030 PROD1 DRILL DRLG P 12880', Drill Ahead, 1.4 BPM @ 3535 PSI FS. BHP=4090, WHP=190, 10:45 12:33 1.80 13,030 13,030 PROD1 DRILL WPRT P Wiper to 11647, PUW=39K, Hole in good shape. No overpulls or setdowns 12:33 14:33 2.00 13,030 13,180 PROD1 DRILL DRLG P 13030', Drill ahead, 1.43 BPM @ 3570 PSI FS, BHP=4155,WHP=190 Page 5 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:33 15:45 1.20 13,180 10,810 PROD1 DRILL WPRT P 13180',Wiper to window with tie, PUW=39K 15:45 16:03 0.30 10,810 10,835 PROD1 DRILL DLOG P Log RA Marker for+3.5'correction 16:03 18:30 2.45 10,835 13,180 PROD1 DRILL WPRT P Continue wiper trip to bottom 18:30 21:00 2.50 13,180 13,330 PROD1 DRILL DRLG P 13180ft-BOBD 1.4bpm at 3374. BHP 4187.WHP 203. IA 1458,OA 484.WOB 2.3k, ROP 100fph 21:00 22:00 1.00 13,330 10,840 PROD1 DRILL WPRT P 13330ft- Wiper to the window. PUW 39k 22:00 23:45 1.75 10,840 13,330 PROD1 DRILL WPRT P 10840ft-Wiper back in hole. RIW 15k 23:45 00:00 0.25 13,330 13,330 PROD1 DRILL DRLG P 13330ft-BOBD 1.44bpm at 3500psi. BHP 4200.WHP 188. IA 1457,OA 484.WOB 2k, ROP 75. 11/05/2012 Drilled A lateral as per plan 00:00 01:00 1.00 13,330 13,480 PROD1 DRILL DRLG P 13330ft-OBD 1.44bpm at 3500psi. BHP 4205.WHP 188. IA 1456,OA 484.WOB 2k, ROP 75fph 01:00 02:30 1.50 13,480 10,840 PROD1 DRILL WPRT P 13480ft-Wiper up to the window. PUW 38k 02:30 03:30 1.00 10,840 13,480 PROD1 DRILL WPRT P 10840ft-Wiper back in hole. RIW 15k 03:30 07:00 3.50 13,480 13,630 PROD1 DRILL DRLG P 13480ft-BOBD 1.45bpm at 3570psi. BHP 4201.WHP 166. IA 1432,OA 473.WOB 2.6k. ROP 8fph 07:00 08:48 1.80 13,630 10,810 PROD1 DRILL WPRT P Wiper,36k off btm. 08:48 09:00 0.20 10,810 10,840 PROD1 DRILL DLOG P Log RA for+3.5' 09:00 10:54 1.90 10,840 10,632 PROD1 DRILL WPRT P Continue wiper trip back to bottom, RIW=14K 10:54 13:00 2.10 13,630 13,780 PROD1 DRILL DRLG P 10632', Drill Ahead, 1.44 BPM @ 3600 PSI FS, BHP=4195 13:00 14:30 1.50 13,780 13,780 PROD1 DRILL WPRT P Wiper trip to 12642, PUW=39K, BHP=4245 14:30 17:48 3.30 13,780 13,930 PROD1 DRILL DRLG P 13780', Drill Ahead, 1.4 BPM @ 3575 PSI FS, BHP=4200, RIW=6K, DHWOB=1.6 17:48 21:35 3.79 13,930 10,840 PROD1 DRILL WPRT P Wiper to window, PUW=40K, BHP=4265,WHP=135, Lost string weight @ 13500, 3 to 5K surface weight.At full pump rate 21:35 23:59 2.41 13,930 13,948 PROD1 DRILL DRLG P 13930', Drill Ahead, 1.4 BPM @ 3625 PSI FS, BHP=4240, RIW=4.3K with 1.7K DHWOB,WHP=126 11/06/2012 Drill A lateral to 13900'. POOH.Swap out mud motor, Drill Bit, PU agitator. RIH. Drill A lateral. Swap out drilling mud. 1495'on old mud system, .7%Drill Solids. 00:00 01:00 1.00 13,948 13,948 PROD1 DRILL DRLG P 13948ft-OBD 1.45bpm at 3650psi. BHP 4190.WHP 200. IA 1476. OA 486. Page 6 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:45 0.75 13,948 13,900 PROD1 DRILL WPRT P 13948ft-Pick up off bottom. Noticed Differential changed off bottom. Pump 5X5 sweep. Found rubber pieces on shaker. Determined motor may be giving up. Discuss with town drilling team and decided to POOH to change motor,bit, pick up aggitator and perform function test. 01:45 04:00 2.25 13,900 10,723 PROD1 DRILL TRIP T 13900ft-POOH chasing sweep to surface. 04:00 06:00 2.00 10,723 500 PROD1 DRILL TRIP T 10723ft-Open EDC jetting tubing at 1.8bpm at 3555psi while POOH 06:00 06:30 0.50 500 0 PROD1 DRILL SFTY T 500ft-Continue POOH, PJSM- Undeploying BHA 06:30 09:00 2.50 0 0 PROD1 DRILL PULD T Oft-At surface begin undeploying BHA 09:00 11:00 2.00 0 0 PROD1 DRILL SVRG P Tools OOH. Bit Grade 2/1 MU lateral BHA#4 swap rig over to gen power for highline maintenance. Perform INJH maintenance,clean out both sumps.Check reel hub bolts and check inner reel iron.Service levelwind. 11:00 11:30 0.50 0 0 PROD1 WHDBO BOPE P Surface-Function test BOPE 11:30 13:30 2.00 0 0 PROD1 DRILL PULD T Surface-PJSM deploy lateral drilling BHA#4 13:30 16:15 2.75 0 10,660 PROD1 DRILL TRIP T Surface-Surface Test BHI tools and aggitator. RIH A lateral BHA New.45°AKO motor Aggitator(43hrs) New HYC Razor-edge bit SS# A142290(SRRE3408M-B6) 16:15 16:45 0.50 10,660 10,703 PROD1 DRILL DLOG T 10660ft-Tie into K1 marker correction of-17.5ft 16:45 18:30 1.75 10,703 13,947 PROD1 DRILL TRIP T 10703ft-Contine RIHTB 18:30 20:00 1.50 13,947 14,036 PROD1 DRILL DRLG P Drill Ahead 1.35 bpm,4019 ctp,4210 bhp, 1.36 wob, 5k ctw 20:00 20:30 0.50 14,036 14,090 PROD1 DRILL DRLG P Swap out mud 14,065'new mud at bit. Drill Ahead, 1.38 bpm,3750 ctp 20:30 21:30 1.00 14,090 12,250 PROD1 DRILL WPRT P Wiper trip 36k puw 21:30 23:00 1.50 12,250 14,090 PROD1 DRILL WPRT P RBIH 23:00 00:00 1.00 14,090 14,192 PROD1 DRILL DRLG P Drill Ahead 1.35 bpm,3750 ctp,4210 bhp, 1.36 wob,6k ctw,200 whp 11/07/2012 TD"A"Lateral 14400'.Wiper trip to swab valves. RBIH, layin 12.4ppg Formate completion fluid. No Flow check failed. RBIH to displace well to 13.1ppg Formate. 00:00 01:45 1.75 14,192 14,240 PROD1 DRILL DRLG P Drill Ahead 1.35 bpm,3750 ctp,4210 bhp, 1.36 wob,6k ctw,200 whp 01:45 02:15 0.50 14,240 12,900 PROD1 DRILL WPRT P Wiper trip 37k puw,back to 12900' 02:15 02:45 0.50 12,900 14,240 PROD1 DRILL WPRT P RBIH 02:45 05:45 3.00 14,240 14,400 PROD1 DRILL DRLG P Drill Ahead 1.35 bpm,3750 ctp,4210 bhp, 1.36 wob,6k ctw,200 whp Page 7 of 20 111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 09:15 3.50 14,400 10,750 PROD1 DRILL WPRT P 14400ft-TDA lateral. Pump 10x10 sweep wiper to the swab. 09:15 11:30 2.25 10,750 0 PROD1 DRILL WPRT P 10750ft-Open EDC.Continue wiper to the swab. 11:30 14:00 2.50 0 10,660 PROD1 DRILL WPRT P Oft-Zero counters/RBIH 14:00 14:15 0.25 10,660 10,754 PROD1 DRILL DLOG P 10660ft-Tie into K1 marker correction of-17ft.Close EDC 14:15 17:15 3.00 10,754 14,400 PROD1 DRILL WPRT P 10754ft- Continue RIH to TD to verify TD. 17:15 21:15 4.00 14,400 0 PROD1 DRILL TRIP P 14400ft-POOH laying in 12.4ppg completion fluid with beads to window,without beads to surface. Paint EOP flag 8600'. 21:15 21:45 0.50 0 0 PROD1 DRILL OWFF P At surface.Monitor well for 30 minutes. PJSM 21:45 23:00 1.25 0 0 PROD1 DRILL PULD P No flow check failed. Prepare to RBIH to window to displace well to 13.1 ppg Formate 23:00 00:00 1.00 0 0 PROD1 DRILL TRIP T RBIH, Prepare 13.1ppg formate with lubes and LSRV. 11/08/2012 Displace well to 13.1ppg Formate. No Flow test pass. PU/MU/RIH first section"A"Liner 60jnts 2 3/8"STL slotted tubing. Release on bottom 14400'.TOL-12390'. POOH. 00:00 01:00 1.00 5,000 8,234 PROD1 DRILL TRIP T Start pumping 13.1ppg down CT to bit to displace well. EDC open. 01:00 01:30 0.50 8,234 10,650 PROD1 DRILL TRIP T Cont. RIH 01:30 02:15 0.75 10,650 10,650 PROD1 DRILL DLOG T Tie in depth to K1 marker+34' correction 02:15 05:15 3.00 10,700 0 PROD1 DRILL TRIP T 13.1ppg at EDC. pump 15bbrls above. POOH 05:15 05:45 0.50 0 0 PROD1 DRILL TRIP T At surface, PJSM,Monitor well for flow. No flow 05:45 06:45 1.00 0 0 PROD1 DRILL PULD P Surface-PJSM unstab INJH. L/D Drilling BHA. Blow down tools. Fill the hole. 06:45 08:15 1.50 0 0 COMPZ CASING SVRG P PJSM-R/U rig floor to run completion. 08:15 10:00 1.75 0 0 COMPZ CASING PUTB P Joint#2, Kick while running tubing drill. 10:00 10:15 0.25 0 0 COMPZ CASING PUTB P Continue P/U tubing 10:15 15:15 5.00 0 0 COMPZ CASING PUTB P Surface-Test BHI tools, RIH BHA#5 Baker GS spear 60jts of slotted 2 3/8 liner 15:15 18:30 3.25 2,053 10,652 COMPZ CASING RUNL P RIH with first section"A"Liner 18:30 19:45 1.25 10,652 14,400 COMPZ CASING RUNL P Record up wt. 35k and 20k down weight.Correct depth to EOP flag -29'.Cont.to RIH with liner.second EOP flag came in+4.4'. Do not change the depth Page 8 of 20 111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:45 1.00 14,400 10,715 COMPZ CASING RUNL P Tag 14400.93'. PU 45k,-6k wob, Online with pumps 3700psi, 1.1 bpm, PU to release off liner.36k puw, -2.8k wob. Liner relased. POOH, pumping across the top to keep hole full. Remove liner length from bit depth. 20:45 21:15 0.50 10,715 10,715 COMPZ CASING OWFF P Stop above window, monitor well for flow 21:15 21:30 0.25 10,715 10,640 COMPZ CASING DLOG P No Flow pass. PUH to K1,tie in depth.+4'correction. Paint EOP flag 9600' 21:30 00:00 2.50 10,640 COMPZ CASING RUNL P POOH 11/09/2012 PU/MU/RIH second section"A"liner 2ljnts with OH anchored billet.Set atop liner#1 at 12390'.TOB 11679'. PU/MU/RIH Drilling BHA. Displace well to 9.3ppg drill mud. Sidetrack off billet for AU lateral at 11679'. 00:00 00:30 0.50 0 0 COMPZ CASING OWFF P At Surface, PJSM,Montior well for flow. Pass 00:30 01:00 0.50 0 0 COMPZ CASING PUTB P LD BHA 01:00 01:30 0.50 0 0 COMPZ CASING SVRG P Prepare floor to PUTB 01:30 02:00 0.50 0 0 COMPZ CASING PUTB P PU/MU 2ljnts 2 3/8"Slotted Liner, OH anchored billet with Coiltrack 02:00 02:15 0.25 0 0 COMPZ CASING SFTY P Drill kick while PUTB.2min 20sec. 02:15 03:15 1.00 0 0 COMPZ CASING PUTB P Cont. PUTB 03:15 06:00 2.75 0 10,395 COMPZ CASING RUNL P RIH 06:00 06:15 0.25 10,395 10,373 COMPZ CASING RUNL P 10395ft-Correct to Flag-22ft. correct depth to 10373ft, PUW 32k 06:15 06:30 0.25 10,373 10,752 COMPZ CASING RUNL P 10752ft-Close EDC, PUW 33k 06:30 07:00 0.50 10,752 12,086 COMPZ CASING RUNL P 12086ft-Set down-5k, PU and try to work through. 07:00 07:15 0.25 12,086 12,108 COMPZ CASING RUNL P 12108ft-Made it through at 50fpm no pump. 07:15 07:30 0.25 12,108 12,391 COMPZ CASING RUNL P 12108ft-Contine to RIHTB 07:30 07:45 0.25 12,391 12,391 COMPZ CASING RUNL P 12391ft-Tag top of first liner section PUW 39k, RBIH and set down 3k at 12391 ft Bring pump up to shear at 3900psi Set down 3k,leaving top of Billet at 11679ft 07:45 08:15 0.50 12,391 11,450 COMPZ CASING RUNL P POOH 08:15 10:45 2.50 11,450 0 COMPZ CASING RUNL P 11450ft-Correct depth after liner release from 11450ft-711.84ft to 10738.21ft.Continue OOH 10:45 12:15 1.50 0 0 COMPZ CASING RUNL P Surface-Perform 30min flow check, PJSM for LD liner running BHA. 12:15 14:00 1.75 0 0 PROD2 STK SVRG P Surface- Tools OOH,service INJH, MU kick off BHA. 14:00 16:15 2.25 0 10,660 PROD2 STK TRIP P Stab INJH and RIH AL 1 lateral BHA .7°AKO motor 2.7 HYC DuraForce Bit(A156395) Page 9 of 20 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 16:30 0.25 10,660 10,684 PROD2 STK DLOG P 10660ft-Tie into K1 Marker correction of-25ft 16:30 20:30 4.00 10,684 10,765 PROD2 STK KOST P 10684ft-RIH to TOB,Troubled area with liner run looked good. Displace well to 9.3ppg Power Pro drilling mud.Mud all around. PUH to window 20:30 21:00 0.50 10,765 10,765 PROD2 STK OWFF P Record Static BHP. Start: 663 WHP,3888 BHP, 12.86 ECD Stop:30min 705 WHP,3875 BHP, 12.81 ECD 21:00 21:30 0.50 10,765 10,679 PROD2 STK TRIP P RIH, Dry tag TOB, PU 35K 21:30 21:45 0.25 10,679 11,679 PROD2 STK KOST P Slowly RIH,Sidetrack off Billet, 1.45 bpm,3378 ctp off bottom, 14k ctw, 3978 bhp, 120 whp. 21:45 22:15 0.50 11,679 11,679 PROD2 STK KOST P Start Milling Billet 11678.5'. 1.46 bpm,3470 ctp, 144 whp,3985 bhp, 17k ctw, Follow milling schedule: 1 fph for 1' 2 fph for 1' 3 fph for 1' 3 fph for 1' 10 fph for 5' 20 fph for 2' 22:15 23:00 0.75 11,679 11,680 PROD2 STK KOST P Aluminum cuttings at the shakers, cont.milling 23:00 00:00 1.00 11,680 11,680 PROD2 STK KOST P Keep ROP at 1 fph after first foot drilled.WOB not drilling off as well as wanted. 1.56K WOB 11/10/2012 Complete sidetrack for AL1 lateral at 11679', 120 ROHS. Drill AL1 lateral 00:00 00:30 0.50 11,680 11,681 PROD2 STK KOST P Increase ROP 1.5 fph 00:30 00:45 0.25 11,681 11,682 PROD2 STK KOST P INcrease ROP 2.5 fph 00:45 01:03 0.30 11,682 11,687 PROD2 STK KOST P Increase to 10 fph 01:03 01:18 0.25 11,687 11,689 PROD2 STK KOST P Increase to 20 fph 01:18 02:00 0.70 11,689 11,730 PROD2 DRILL DRLG P Drill ahead 1.46 bpm, 3565 ctp, 15k ctw,3986 bhp, 02:00 02:15 0.25 11,730 11,730 PROD2 DRILL DRLG P Drift sidetrack w/o pumps, PUW 34k, looks good. 02:15 03:45 1.50 11,730 11,830 PROD2 DRILL DRLG P Drill ahead 1.46 bpm,3565 ctp, 15k ctw,3986 bhp, 03:45 04:15 0.50 11,830 10,840 PROD2 DRILL WPRT P Wiper trip back to window 36K PUW 04:15 04:45 0.50 10,840 11,830 PROD2 DRILL WPRT P RBIH 04:45 07:30 2.75 11,830 11,980 PROD2 DRILL DRLG P 11830ft-BOBD 1.45bpm at 3250psi. BHP 4015.WHP 165. IA 1378psi, OA 483psi.WOB 3k, ROP 60fph 07:30 08:30 1.00 11,980 10,850 PROD2 DRILL WPRT P 11980ft-Wiper to the window. PUW 39k 08:30 09:00 0.50 10,850 11,980 PROD2 DRILL WPRT P 10850ft-Wiper back in hole. RIW 15k Page 10 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 11:30 2.50 11,980 12,130 PROD2 DRILL DRLG P 11980ft-BOBD 1.48 bpm at 3394psi. BHP 3998,WHP 146. IA 1357psi,OA 485psi.WOB 2.5k ROP 68fph 11:30 12:30 1.00 12,130 10,810 PROD2 DRILL WPRT P 12130ft-Wiper to the window. PUW 39k,we are seeing fault number 2 every wiper. 12:30 12:45 0.25 10,810 10,843 PROD2 DRILL DLOG P 10810ft-Tie into the RA marker correction of-1ft 12:45 13:15 0.50 10,843 12,130 PROD2 DRILL WPRT P 10843ft-Continue wiper in hole. RIW 15k,we are seeing fault number 2 every wiper. 13:15 15:15 2.00 12,130 12,280 PROD2 DRILL DRLG P 12130ft-BOBD 1.49bpm at 3374psi. BHP 4029,WHP 148. IA 1367psi, OA 494psi.WOB 2k, ROP 70 fph 15:15 16:15 1.00 12,280 10,973 PROD2 DRILL WPRT P 12280ft-Wiper up to the window. PUW 38k 16:15 17:00 0.75 10,973 12,280 PROD2 DRILL WPRT P 10973ft-Wiper back in hole. RIW 10k 17:00 19:00 2.00 12,280 12,430 PROD2 DRILL DRLG P 12280ft-BOBD 1.50bpm at 3414psi. BHP 4074.WHP 144. IA 1403psi, OA 494.WOB 2k ROP 19:00 19:30 0.50 12,430 11,450 PROD2 DRILL WPRT P Wiper trip back to window 38K PUW. Increase weights 11900'40-42K. Cont Picking up to window. 19:30 20:00 0.50 11,450 12,430 PROD2 DRILL WPRT P RBIH, looked good. 20:00 20:30 0.50 11,450 11,380 PROD2 DRILL DLOG P MADD pass 11450-11380'.To compare gamma logs. Log up. 20:30 22:45 2.25 12,430 12,580 PROD2 DRILL DRLG P Drill ahead 1.4 bpm,3669 ctp, 174 whp,4063 bhp, 10k ctw 22:45 00:00 1.25 12,580 10,500 PROD2 DRILL WPRT P Wiper trip 39k PUW.Chase 5x5 low/high sweeps. Large increase of cuttings once sweeps at surface. Decision to continue to pick up to 9500'.Open EDC pump full rate when RBIH to Top of Window performing JOG. 10,500 PROD2 DRILL WPRT P 11/11/2012 Drill AL1 lateral. Pick up weights on wiper trips gradually increasing. Pull extended wiper trip up to 9500', performing JOG to clean hole. Swap out 9.3ppg drilling mud to 9.6ppg. Increase LSRV 45K. BOPE test 24hr notice sent by email and waived. 00:00 01:00 1.00 10,000 9,500 PROD2 DRILL WPRT P Conitune wiper trip up to 9500'.40 fpm 01:00 01:24 0.40 9,500 10,750 PROD2 DRILL WPRT P Open EDC. RBIH pumping max rate 70 fpm,.to TOWS performing JOG. Blow down Micro Motion and MP choke while RIH with open choke. Maintain MP with rate. 01:24 01:39 0.25 10,750 10,815 PROD2 DRILL DLOG P Close EDC. RIH, Log RA marker+.5' correction. 01:39 02:30 0.85 10,815 12,580 PROD2 DRILL WPRT P RIH to drill 02:30 03:00 0.50 12,580 12,600 PROD2 DRILL DRLG P Drill Ahead 1.5 bpm,3640 ctp,4060 bhp, 10k ctw, 150 whp Page 11 of 20 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:15 1.25 12,600 12,730 PROD2 DRILL DRLG P Start sending new mud for mud swap. Swap 9.3ppg out to 9.6ppg. Old mud system: 1325'.... .6%DS 04:15 05:30 1.25 12,730 10,840 PROD2 DRILL WPRT P Wiper trip to window,36k puw. Shales looked good. 05:30 06:30 1.00 10,840 12,730 PROD2 DRILL WPRT P 10840ft-Wiper back in hole. RIW 13k 06:30 08:00 1.50 12,730 12,880 PROD2 DRILL DRLG P 12730ft-BOBD 1.47bpm at 3364psi. BHP 4058,WHP 206. IA 1435,OA 500.WOB 1.7k, ROP 90fph. Drill to 12880 ft. 08:00 09:30 1.50 12,880 10,843 PROD2 DRILL WPRT P 12880ft-Wiper trip to window,36k puw. Shales looked good. 09:30 11:00 1.50 10,843 12,880 PROD2 DRILL WPRT P 10843ft-Wiper back in hole. RIW 13k 11:00 12:30 1.50 12,880 13,030 PROD2 DRILL DRLG P 12880ft-Drill Ahead 1.5 bpm,3840 ctp,4060 bhp, 10k ctw, 25 whp 12:30 14:00 1.50 13,030 10,840 PROD2 DRILL WPRT P Wiper trip to window, 36k puw. Shales looked good. 14:00 14:15 0.25 10,840 10,874 PROD2 DRILL DLOG P 10850ft-Tie into the RA correction+ 2.5ft. 14:15 15:30 1.25 10,874 13,030 PROD2 DRILL WPRT P 10840ft-Wiper back in hole. RIW 13k 15:30 17:30 2.00 13,030 13,180 PROD2 DRILL DRLG P 13030ft-BOBD 1.48bpm at 3464psi. BHP 4124,WHP 209. IA 1437,OA 502.WOB 1.5k, ROP 66fph. 17:30 20:30 3.00 10,840 13,180 PROD2 DRILL WPRT P Wiper trip to window 40K PUW.22 fpm. Increase to 40 fpm on bottoms up. 20:30 21:45 1.25 13,180 13,330 PROD2 DRILL DRLG P Drill ahead 1.4 bpm,3726 ctp,4064 bhp,6k ctw, 21:45 23:15 1.50 13,330 10,837 PROD2 DRILL WPRT P Wiper trip to window 41k puw,22 fpm. Bottoms up increase POOH speed to 40fpm to window. 23:15 00:00 0.75 10,837 12,500 PROD2 DRILL WPRT P RBIH 11/12/2012 TD AL1 lateral at 13647'. POOH to swab valves. RBIH. laying 13.1 KWf with beads from TD to window,w/o beads to surface. Start BOPE test 2300hrs.Witness waived by:Jeff Jones 00:00 00:30 0.50 12,500 13,330 PROD2 DRILL WPRT P Cont. RIH 00:30 01:45 1.25 13,330 13,470 PROD2 DRILL DRLG P Drill ahead 1.48 bpm,3888 ctp,5k ctw, 170 whp, 01:45 02:15 0.50 13,470 12,480 PROD2 DRILL WPRT P Wiper trip 1000'to 12480'.chasing 5x5 sweeps 38K PUW 02:15 02:30 0.25 12,480 13,180 PROD2 DRILL WPRT P RBIH 02:30 03:00 0.50 13,180 13,480 PROD2 DRILL WPRT P Stack out trying to get to bottom. PU 43k.Cont to RIH,Adjust RIH speed, working to bottom. 03:00 04:45 1.75 13,480 13,630 PROD2 DRILL DRLG P Drill ahead 1.6 bpm,4052 ctp,4151 bhp, 110 whp,4k ctw, 1.6k wob, 90-100fph 04:45 09:15 4.50 13,645 0 PROD2 DRILL WPRT P TD AL1 lateral 13645'. POOH 24fpm to window,chasing 10x10 low/hi sweeps. Drill 15'further displacing sweeps out bit Page 12 of 20 41110 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:30 0.25 0 500 PROD2 DRILL WPRT P Oft(Surface)-Perform jog,Tag up, RIH at 50fpm. 09:30 09:45 0.25 500 0 PROD2 DRILL WPRT P 500ft-POOH 09:45 12:15 2.50 0 10,660 PROD2 DRILL WPRT P Tag up and rezero depth.Open EDC and RIH to verify depth. 12:15 12:30 0.25 10,660 10,684 PROD2 DRILL DLOG P 10660ft-Tie into K1 Marker correction of-22ft 12:30 14:15 1.75 10,684 13,647 PROD2 DRILL WPRT P 10684ft-Continue wiper in hole. Stop above window and close EDC. 14:15 16:15 2.00 13,647 8,372 PROD2 DRILL WPRT P 13647ft-Tag Bottom at 13647ft. PUW 39k. POOH Laying in 13.1 KW w/beads.BHP 4043.WHP 430. IA 1148psi,OA 501psi. 16:15 16:30 0.25 8,372 8,371 PROD2 DRILL TRIP P 8371ft-Paint EOP flag White in color. 16:30 19:30 3.00 8,371 0 PROD2 DRILL TRIP P 8371ft-Continue to POOH 19:30 20:00 0.50 0 0 PROD2 DRILL SFTY P At surface, PJSM. Monitor well for flow 20:00 21:00 1.00 0 0 PROD2 DRILL PULD P LD BHA 21:00 23:00 2.00 0 0 PROD2 DRILL SVRG P Prepare for BOPE test. Displace CT to fresh water. Flush stack,choke and grease tree valves, remove check valves,. 23:00 00:00 1.00 0 0 PROD2 DRILL BOPE P PJSM,Start BOPE testing 11/13/2012 BOPE test.0 Failures. PU/MU/RIH AU liner,69jnts of 2 3/8"Slotted liner with liner top billet. Release on bottom 13647'.TOB-11327'. POOH, Rehead CTC and BHI drilling head. PU/MU/RIH drilling BHA. 00:00 06:00 6.00 0 0 PROD2 DRILL BOPE P Cont. BOPE testing 06:00 07:30 1.50 0 0 PROD2 DRILL BOPE P Circulate and condition KWF. Displace CT back to 13.1# K-formate. Blow down test pumps. M/U safety joint;perform valve checklist. Open well and flow check; no flow. 07:30 07:45 0.25 0 0 COMPZ CASING SFTY P PJSM for running liner. 07:45 08:15 0.50 0 0 COMPZ CASING PUTB P PU/MU 2-3/8"ST-L slotted liner assembly. 08:15 08:21 0.10 0 0 COMPZ CASING SFTY P Perform"Kick While Tripping"drill. (2.5-min response time). 08:21 10:51 2.50 0 2,310 COMPZ CASING PUTB P PU/MU 2-3/8"ST-L slotted liner assembly. 10:51 10:57 0.10 2,310 2,310 COMPZ CASING SFTY P PJSM for liner running BHA 10:57 12:03 1.10 2,310 2,363 COMPZ CASING PUTB P PU/MU liner running BHA&service injector. Surface test tools and strip over BHA. Make up CT. 12:03 15:15 3.20 2,363 12,880 COMPZ CASING TRIP P RIH liner pumping 0.3 BPM KWF. 15:15 15:51 0.60 12,880 13,647 COMPZ CASING TRIP P Start stacking weight. PU 52k#. RBIH. Stack weight again;continue to work down. Stack to-10k and pop passed 13241'. Speed to 15-fpm w/4k down. RIH. Page 13 of 20 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:51 15:57 0.10 13,647 0 COMPZ CASING TRIP P Reach TD 13647, pumped up 1.14-bpm,3800-psi. Release liner; PU 33k#. 15:57 18:57 3.00 0 0 COMPZ CASING TRIP P POOH. 18:57 19:27 0.50 0 0 COMPZ CASING SFTY P At surface. PJSM.Monitor well for flow 19:27 20:27 1.00 0 0 COMPZ CASING PUTB P LD BHA. 20:27 22:27 2.00 0 0 PROD3 DRILL CTOP P Service Injector Head,checked packoffs(good), Cut Coil 15'. MU CTC pull test 35K, pressure test 4000psi, Rehead BHI drilling head. 22:27 22:45 0.30 0 0 PROD3 STK SFTY P PJSM 22:45 23:15 0.50 0 0 PROD3 STK PULD P PU/MU Drilling BHA 23:15 00:00 0.75 72 3,500 PROD3 STK TRIP P RIH 11/14/2012 Swap well back to 9.6ppg drill mud.Sidetrack off of billet at 11325'. Drill AL3 lateral. 00:00 02:00 2.00 3,500 10,656 PROD3 STK TRIP P Cont. RIH 02:00 02:15 0.25 10,656 10,656 PROD3 STK DLOG P Tie in depth to K1 -6.5 correction. CLosed EDC 02:15 03:45 1.50 10,656 11,327 PROD3 STK CIRC P RIH just above TOB. PUH slowly swapping hole back to 9.6ppg drill mud. 03:45 04:15 0.50 11,324 11,324 PROD3 STK KOST P RIH dry tag billet at 11325'PU 36k. Online with pumps 1.45 bpm, 3500 off bottom CTP, 14.5k RIHW,4000 BHP, RIH lfpm to start sidetrack. 04:15 06:45 2.50 11,324 11,335 PROD3 STK KOST P Start sidetrack 11324.76'as per program: 1.48 bpm,3630 ctp,90 whp, 18k ctw 1 fph for 1' 2 fph for 1' 3 fph for 1' 10 fph for 5' 20 fph for 2' 06:45 09:09 2.40 11,335 11,366 PROD3 STK KOST P Drill ahead AL3 Lateral 80-fph; 1k# WOB; 1.48-bph; 3692-psi CTP; 118-psi WHP. Encounter something hard at 13351';limit push so as not to create excessive micro-dog-leg at KO. Drill ahead slow to try to get through hard spot before disconnect passes billet. 09:09 09:45 0.60 11,366 11,366 PROD3 STK KOST P PU to 11277'to drift KO. Saw-500# WOB up through billet at 0.3-bpm. Drifted clean down through billet dry. RBIH. 09:45 10:45 1.00 11,366 11,441 PROD3 DRILL DRLG P Drill ahead AL3 Lateral 49-fph; 1.2k# WOB; 1.48-bph; 3993-psi CTP; 100-psi WHP. Ratty drilling 11375; suspect fault.0.2-bpm losses taper to 0.07-bpm by 11400'. Good drilling and minimal losses after 11412'. Page 14 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 14:00 3.25 11,441 11,441 PROD3 DRILL WPRT P Perform wiper trip into tubing. Circulate in tubing and reciprocate pipe while. Service choke. Tie in (+1'correction). RBIH. 14:00 15:48 1.80 11,441 11,541 PROD3 DRILL DRLG P Drill ahead AL3 Lateral 22-fph; 1.2k# WOB; 1.48-bph;3760-psi CTP; 100-psi WHP. Encountering survey issues possibly due to magnetic bias from laterals below. Check shots above pass QA/QC. Troubleshooting IIFR data. Decide to pull wiper trip early while examining survey. 15:48 18:18 2.50 11,541 11,541 PROD3 DRILL WPRT P Wiper to 10850';9-fpm. 18:18 19:18 1.00 11,541 11,690 PROD3 DRILL DRLG P Drill Ahead 1.46 bpm, 3842 ctp,4018 bhp, 12k ctw, 19:18 20:18 1.00 11,690 10,830 PROD3 DRILL WPRT P Wiper trip to window,37k puw 20:18 00:00 3.70 11,690 11,826 PROD3 DRILL DRLG P Drill Ahead 1.44 bpm,3700 ctp,4018 bhp, 12k ctw, 11/15/2012 Drill AL3 lateral to 12212'. POOH to swap out Survey package in drilling BHA. RBIH,cont drilling AL3 lateral. 00:00 00:15 0.25 11,826 11,840 PROD3 DRILL DRLG P Drill Ahead 1.44 bpm, 3700 ctp,4018 bhp, 12k ctw, 00:15 01:00 0.75 11,840 10,820 PROD3 DRILL WPRT P Wiper trip to window 37k puw,Tie in depth to RA marker-.5'correction 01:00 01:30 0.50 10,820 11,840 PROD3 DRILL TRIP P RBIH 01:30 03:15 1.75 11,840 11,990 PROD3 DRILL DRLG P Drill Ahead 1.44 bpm, 3695 ctp,4030 bhp, 11 k ctw,90 whp 03:15 04:00 0.75 11,990 10,830 PROD3 DRILL WPRT P Wiper trip to window 37k puw, Chasing 5x5 sweeps 04:00 04:30 0.50 10,830 11,990 PROD3 DRILL WPRT P RBIH, increase of cuttings with bottoms up sweeps 04:30 06:15 1.75 11,990 12,140 PROD3 DRILL DRLG P Drill Ahead 1.45 bpm,3791,68 whp, 12k ctw,4055 bhp, 1.86 wob. Time 5-bbl each, low/hi visc sweeps around coil for wiper trip. 06:15 07:15 1.00 12,140 10,840 PROD3 DRILL WPRT P Wiper trip#2 with sweeps out bit; PUW 37k#. 07:15 07:51 0.60 10,840 12,140 PROD3 DRILL WPRT P RBIH. Swap mud to new 9.6# PowerPro system(1800'on old system with 0.8%DS;50k LSRV). 07:51 08:27 0.60 12,140 12,212 PROD3 DRILL DRLG P Drill ahead avg 120-fph ROP; 3770-psi CTP;4000-psi BHP; 1.49-bpm; 1.9k#WOB; 170-psi WHP. 08:27 10:51 2.40 12,212 11,234 PROD3 DRILL TRIP T PU for surveys. Three sequential check-shots outside QA/QC spec. Import new IIFR to troubleshoot possible interference. Shots still outside spec. Decide to trip out for drill-package swap. 10:51 13:45 2.90 11,234 31 PROD3 DRILL TRIP T Trip out for tools. Pull slow through window into tubing. Stop 10756; open EDC. POOH. Tagged up; space out. 13:45 14:03 0.30 31 31 PROD3 DRILL SFTY T PJSM for pressure un-deploy/deploy. Page 15 of 20 s Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:03 15:33 1.50 31 0 PROD3 DRILL PULD T PUD BHA#9. 15:33 17:00 1.45 0 31 PROD3 DRILL PULD T PD BHA#10. 17:00 19:15 2.25 31 10,600 PROD3 DRILL TRIP T RIH BHA#10. 19:15 19:30 0.25 10,600 10,600 PROD3 DRILL DLOG T Log K1 for depth correlation.Spot check surveys.All looks good. 19:30 20:45 1.25 10,600 12,212 PROD3 DRILL TRIP T RIH to drill 20:45 23:30 2.75 12,212 12,361 PROD3 DRILL DRLG P Drill Ahead 1.46 bpm,3673 ctp, 130 whp,4040 bhp, 12.5k ctw, 23:30 00:00 0.50 12,361 11,325 PROD3 DRILL WPRT P Wiper trip to window 36k puw.chase 5x5 sweeps up hole. Increase of cuttings on Bottoms sweep of sweep 11/16/2012 TD AL3 lateral 12515'. Pull wiper trip to swab valves. RBIH to TD. Lay in 13.1 ppg KWF with beads to window, w/o beads to surface. PU/MU/RIH AL3 liner,42jnts 2 3/8"slotted liner with liner top billet.Tag 12512'. Release liner on bottom.TOB 11098'. 00:00 00:30 0.50 11,325 10,840 PROD3 DRILL WPRT P Small over pull and pressure increase pulling thru billet. Have seen this everytime thru the billet. Do not see anything RBIH thru billet. Hole looks good. Cont. up hole wiping hole to window 00:30 01:15 0.75 10,840 12,361 PROD3 DRILL WPRT P RBIH,All looked good 01:15 03:30 2.25 12,361 12,515 PROD3 DRILL DRLG P Drill Ahead 1.43 bpm,3800 ctp, 180 whp,4070 bhp, 13k ctw, pump sweeps 5 x 5 03:30 04:00 0.50 12,515 11,800 PROD3 DRILL WPRT P Planned wiper trip 1000'.35K PUW. chasing 5 x 5 sweeps 04:00 07:18 3.30 11,800 0 PROD3 DRILL WPRT P Geo called TD.Cont. POOH to swab valves. Large increase of cuttings on BU sweeps.Cont.to POOH to swab valves. 07:18 09:48 2.50 0 10,665 PROD3 DRILL WPRT P BHA back at surface. In/out jog to 505'. Power up and open EDC. RBIH cleaning hole 1.2-bpm. 09:48 10:06 0.30 10,665 10,699 PROD3 DRILL DLOG P Log GR tie-in(-26.5'correction). Wt chk: 31k#. Close EDC. 10:06 11:06 1.00 10,669 12,513 PROD3 DRILL WPRT P RIH. Drift clean past billet. Circulate completion fluid around to time it at bit when confirming TD tag. Tag TD at 12,513'. 11:06 15:12 4.10 12,513 37 PROD3 DRILL TRIP P POOH laying in beaded liner pill to window(13.1#Formate with Alpine Beads). Lay in 13.1#Formate to surface. Paint 10900'EOP flag for TD(yellow). Paint 9200'EOP flag for window(white). Continue OOH. 15:12 15:42 0.50 37 37 PROD3 DRILL OWFF P At surface. Watch well for 30-min flow check. 15:42 15:54 0.20 37 37 PROD3 DRILL SFTY P PJSM for laying down drilling BHA. 15:54 16:24 0.50 0 0 PROD3 DRILL PULD P Lay down drilling BHA#10. 16:24 16:54 0.50 0 0 COMPZ CASING SVRG P Prepare floor for PU liner Page 16 of 20 S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:54 17:09 0.25 0 0 COMPZ CASING SFTY P PJSM 17:09 20:09 3.00 0 0 COMPZ CASING PUTB P PU/MU AL3 liner.42 jnts slotted liner 20:09 22:09 2.00 1,459 10,500 COMPZ CASING RUNL P RIH 22:09 22:18 0.15 10,500 10,500 COMPZ CASING DLOG P Tie in depth to EOP flag,-26' correction 22:18 23:03 0.75 10,500 12,512 COMPZ CASING RUNL P Record up and down weights 36k up, 20k RIW. Close EDC, RIH to TD 23:03 23:12 0.15 12,512 12,512 COMPZ CASING RUNL P Tag TD 12512, Pick up 43K,-5k wob. RBIH 12512'.set down 3k wob. Online with pumps 1 bpm, 3800 ctp, pick to release off liner.36k puw. Liner released. PUH. Remove liner length out of bit depth. 23:12 00:00 0.80 10,512 7,200 COMPZ CASING RUNL P POOH 11/17/2012 Drill AL2 lateral. Pump low/high sweeps as needed,wiper trips back to window every 150'drilled or as needed. 00:00 01:45 1.75 7,200 0 COMPZ CASING RUNL P Cont. POOH 01:45 02:00 0.25 0 0 COMPZ CASING SFTY P At surface,Monitor well for flow, PJSM 02:00 02:30 0.50 0 0 COMPZ CASING PUTB P LD BHA 02:30 03:00 0.50 0 0 PROD4 DRILL SVRG P Service inj. head, reel and flush/blow down MP choke. 03:00 03:30 0.50 0 0 PROD4 STK PULD P PU drilling BHA 03:30 06:00 2.50 71 10,700 PROD4 STK TRIP P RIH BHA#12. 06:00 06:15 0.25 10,700 10,701 PROD4 STK DLOG P Log GR tie-in;-32.5'correction. 06:15 06:30 0.25 10,701 11,060 PROD4 STK TRIP P RIH. 06:30 08:30 2.00 11,060 10,863 PROD4 STK TRIP P Finish swapping wellbore over to mud. 08:30 08:36 0.10 10,863 11,060 PROD4 STK TRIP P RBIH. 08:36 08:48 0.20 11,060 11,095 PROD4 STK TRIP P Dry tag. 08:48 11:42 2.90 11,095 11,105 PROD4 STK KOST P PU and come online pumps 1.45-bpm. Begin time drilling 11094.6'; 3650-psi CTP;3950-psi BHP;0.3-0.5k#WOB;Tool Face 30L. Time drill: 1-fph for 1' 2-fph for 1' 3-fph for 1' 10-fph for 5' 20-fph for 2' 11:42 12:00 0.30 11,105 11,125 PROD4 STK KOST P Drilling: 1.45-bpm; 1.6k#WOB; 3775-psi CTP;3950-psi BHP;57-fph. 12:00 12:15 0.25 11,125 11,125 PROD4 STK KOST P Drift up through billet to 11035': observe 2000#overpull on CT pulling up past billet pumping min rate. Drift clean down through dry. 12:15 15:39 3.40 11,125 11,280 PROD4 DRILL DRLG P Drill ahead: 1.43-bpm; 1.7k#WOB; 3790-psi CTP;3964-psi BHP; 100-fph. Page 17 of 20 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:39 15:57 0.30 11,280 10,835 PROD4 DRILL WPRT P Wiper trip(No. 1)to 10835'. Observe similar 1-2k#overpull up through billet at min rate. Drifts clean down through dry. (Flushed and blew down choke while pump off during drift.) 15:57 16:15 0.30 10,835 11,280 PROD4 DRILL WPRT P RBIH 16:15 19:00 2.75 11,280 11,430 PROD4 DRILL DRLG P Drill ahead: 1.42-bpm;2.0k#WOB; 4000-psi CTP;3950-psi BHP; 19:00 19:15 0.25 11,430 10,830 PROD4 DRILL WPRT P Wiper trip#2 to window,37k puw 19:15 19:30 0.25 10,830 11,430 PROD4 DRILL WPRT P RBIH 19:30 22:00 2.50 11,430 11,625 PROD4 DRILL DRLG P Drill ahead: 1.42-bpm;2.0k#WOB; 3945-psi CTP;4012-psi BHP; 13k CTW,92psi WHP 22:00 22:30 0.50 11,625 10,800 PROD4 DRILL WPRT P Wiper trip to window,37k PUW 22:30 22:48 0.30 10,800 10,800 PROD4 DRILL DLOG P Log RA marker to tie in depth.-1' correction 22:48 23:03 0.25 10,800 11,625 PROD4 DRILL WPRT P RBIH 23:03 00:00 0.95 11,625 11,712 PROD4 DRILL DRLG P Drill ahead: 1.42-bpm; 1-2#WOB; 3900-psi CTP;4013-psi BHP; 13k CTW,80psi WHP 11/18/2012 TD AL2 lateral 11950'. Encountered losses.5-1.25 bpm last 20'drilled. Pull heavy 50k off bottom.Wiper trip 15-20fpm to swab valves managing pressure. RBIH, lay in liner running pill(13.1ppg formate with beads)from 11910'to 10700'. 13.1 Formate w/o beads to surface. PU/MU AL2 liner(32jnts 2 3/8"Slotted and 3jnts 2 3/8" 511 Hydril) 00:00 00:30 0.50 11,712 11,775 PROD4 DRILL DRLG P Drill ahead: 1.42-bpm; 1-2#WOB; 3900-psi CTP;4013-psi BHP; 13k CTW,80psi WHP 00:30 01:15 0.75 11,775 10,830 PROD4 DRILL WPRT P Wiper trip back to window, chasing 5x5 sweeps.38K PUW 01:15 02:00 0.75 10,830 11,775 PROD4 DRILL WPRT P RBIH 02:00 04:30 2.50 11,775 11,950 PROD4 DRILL DRLG P Drill ahead: 1.43-bpm; 1-2#WOB; 4000-psi CTP;4013-psi BHP; 13k CTW,50psi WHP 04:30 09:42 5.20 11,950 127 PROD4 DRILL WPRT P TD Lateral 11950'.Start loosing returns 11930'. 1 bpm.Tough to manage Pressure. Pull heavy 50k. POOH to swab valves chasing sweeps.Cont.to close choke to manage pressure. Pull 10-15 fpm. Pick up weight 36-38k.Cont to POOH 4000 psi MP. loosing 1 bpm. 09:42 09:54 0.20 127 490 PROD4 DRILL WPRT P In/out jog. 09:54 10:06 0.20 490 32 PROD4 DRILL WPRT P PU to tag up. 10:06 13:24 3.30 72 10,665 PROD4 DRILL WPRT P Tag. Re-set depth. RIH. 13:24 13:54 0.50 10,665 10,700 PROD4 DRILL DLOG P Log K-1 Tie-in;-32.5'correction. Static test;408-psi WHP;3679-psi BHP. 13:54 14:24 0.50 10,700 11,900 PROD4 DRILL WPRT P RIH. 14:24 15:24 1.00 11,900 11,900 PROD4 DRILL WPRT P Reach 11909'. Recip pipe momentarily to get liner pill to bit. Page 18 of 20 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:24 19:00 3.60 11,900 0 PROD4 DRILL TRIP P POOH laying in beaded liner pill to window(13.1#Formate with Alpine Beads). Lay in 13.1#Formate to surface. Paint 10600' EOP flag for TD(yellow). Paint 9500'EOP flag for window(white). Continue OOH. 19:00 19:15 0.25 0 0 PROD4 DRILL SFTY P At surface, PJSM,Monitor well for flow 19:15 19:45 0.50 0 0 PROD4 DRILL PULD P LD BHA 19:45 20:45 1.00 0 0 COMPZ CASING SVRG P Prepare floor to run liner 20:45 00:00 3.25 0 COMPZ CASING PUTB P PU/MU AL2 liner 11/19/2012 Land AL2 liner 11950'. Swap well to SW.6%safelube and Freeze Protect.Slickline set CA-2 plug 9995'.Set BPV. Rig Down 00:00 03:00 3.00 12 8,000 COMPZ CASING RUNL P RIH 03:00 03:06 0.10 8,000 8,000 COMPZ CASING RUNL P Start pumping across top to minimze losses. 03:06 03:12 0.10 10,746 10,716 COMPZ CASING RUNL P Tie in depth to-30'correctionEOP flag. Record up and down weights 20k RIW,38k PUW. 03:12 03:42 0.50 10,716 11,952 COMPZ CASING RUNL P RIH to TD 03:42 04:00 0.30 11,952 11,952 COMPZ CASING RUNL P Tag TD 11952'. PU 42k PUW.-5k WOB. RBIH 4k WOB.Online with pumps release liner on bottom. 1 BPM 4000psi CTP, PU 35K PUW. -1K WOB>Liner released. PU 30' remove liner from bit depth. ***AL2 liner top is at 10,777.*** 04:00 06:30 2.50 10,760 10,760 DEMOB WELLPF CIRC P Swap well to seawater.6%Safelube added.50%return rate. Pump 10brI spacer for Formate recovery. 06:30 09:18 2.80 10,760 5 DEMOB WELLPF TRIP P POOH. Start diesel around to reach tool as it reaches 2500'for freeze protect. 09:18 09:30 0.20 5 7 DEMOB WELLPF TRIP P Tagged up;space out. 09:30 09:48 0.30 7 7 DEMOB WELLPF SFTY P PJSM for pressure un-deploy BHA #13. 09:48 11:18 1.50 7 0 DEMOB WELLPF PULD P Pressure un-deploy BHA#13. 11:18 11:36 0.30 0 0 DEMOB WELLPF SFTY P PJSM for rigging up HES Slickline. 11:36 14:24 2.80 0 0 DEMOB WELLPF SLKL P Rig up HES Slickline. 14:24 16:54 2.50 0 0 DEMOB WELLPF SLKL P RIH slickline to drift to nipple at 9995'. 16:54 17:24 0.50 0 0 DEMOB WELLPF SLKL P OOH with drift no/go BHA. RIH with CA-2 plug BHA. 17:24 17:54 0.50 0 0 DEMOB WELLPF SLKL P Set CA-2 plug 9995'. POOH 17:54 18:09 0.25 0 0 DEMOB WELLPF SLKL P At Surface w/SL. Bleed off well Flow check 10 minutes,Good Test. 18:09 19:09 1.00 0 0 DEMOB WELLPF SLKL P RIH set Catcher atop CA-2 plug. 19:09 20:09 1.00 0 0 DEMOB WELLPF SLKL P POOH RD Slickline unit Page 19 of 20 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:09 21:09 1.00 0 0 DEMOB WHDBO BOPE P Set BPV 21:09 22:09 1.00 0 0 DEMOB WHDBO DMOB P Flush stack and CT with inhibitor. 22:09 23:09 1.00 0 0 DEMOB WHDBO DMOB P Purge CT and rig. 23:09 00:00 0.85 0 0 DEMOB WHDBO DMOB P RD, Prepare rig to move 11/20/2012 00:00 06:00 6.00 0 0 DEMOB WHDBO DMOB P ND/RD Prepare to move rig ***Rig Release 6 am*** 06:00 12:00 6.00 0 DEMOB MOVE MOB P Prepare to move rig Page 20 of 20 { ri&1111 BAKER PRINT DISTRIBUTION U ON LI ST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2F-19AL1 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: November 12,2012 TODAYS DATE: 12/10/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD (FIELD FINAL digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur t'IlIN 16 #OF COPIES #OF COPIES v v v v v v 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAILROOM 700 G Street, Anchorage,AK 99501 ,l 2 AOGCC 1 1 Christine Mahnkenll rr .�.,_,. 333 West 7th Ave,Suite 100 o�). o (sl Anchorage,Alaska 99501 3 BP 1 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 I — Glenn Fredrick • i 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 -_.._____.._ 5 Brandon Tucker,NRT I I 1 I I I 1. State of Alaska;DNR,Div.of Oil and Gas .. 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 . Iz ,- i >' -( Letter of Transmittal rpu BAKER Date: December 3, 2012 HUGHES To: From: Christine Mahnken Carl Ulrich/Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): -1 .. '-19AL12..'V 2F-19AL2 7,k2,-k% 2F-19AL3 2.‘2'15(g (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes, Project Engineer / RAA,<LD Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com OF F„, •• V w� s,, THE STATE Alaska Oil and Gas ��`� �'”' °f Conservation Commission - ____ - ALAS *R , GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA., Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 L. Gantt CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F-19AL1 ConocoPhillips Alaska, Inc. Permit No: 212-154 Surface Location: 68' FNL, 1749' FEL, SEC. 33, T11N, RO9E, UM Bottomhole Location: 100' FSL, 2493' FWL, SEC. 3, T1ON, RO9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 2F-19A, Permit No 212-153, API 50-029-22728-01. Production should continue to be reported as a function of the original API number stated above. ConocoPhillips Alaska, Inc. request for a variance from the requirements of 20 AAC 25.412(b) which requires the isolation packer to be within 200 ft of injection interval is Approved. As proposed the packer will be approximately 770 ft from injection interval. Cement inspection logs indicate that the casing is well bonded in the interval from just above the packer to injection zone and will provide adequate confinement of the fluids into the desired zone. Additionally, MIT's of both the Inner annulus ( IA ) and Tubing/Liner to a depth of 10750' and are required before injection commences. 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. 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, (3/4, '71..6,7 4.......____ Cathy P. Foerster Chair DATED this i day of October, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA OCT 0 9 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work: lb Proposed Well Class: Development-Oil ❑ Service-Win) Q. Single Zone ❑✓ • 1 c.Specify if well is proposed for. Drill ❑ Lateral 2 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Rednll ❑ Re-entry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5 Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 • 2F-19AL1 • 3.Address: 6.Proposed Depth. 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 14430' • TVDSS: 6005' • Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:68'FNL, 1749'FEL,Sec.33,T11N,RO9E, UM • ADL 25657,25666 Kuparuk River Oil Pool • Top of Productive Horizon. 8 Land Use Permit: 13.Approximate Spud Date. 1915'FNL,2641'FEL,Sec.3,T1ON, RO9E,UM 2583,2587 10/27/2012 • Total Depth 9.Acres in Property 14.Distance to 100'FSL,2493'FWL,Sec.3,T1ON, RO9E,UM 2560 Nearest Property 2750' • 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 129 feet 15.Distance to Nearest Well Open Surface:x- 517483 • y- 5948815 ' Zone- 4 GL Elevation above MSL: • 96.8 feet to Same Pool: 2F-19PB1 ,97' , 16.Deviated wells. Kickoff depth: 11940 ft. • 17 Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle. 96' deg Downhole:4839 psig • Surface:4238 psig • 18.Casing Program. Specifications _t _ 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 3330' 11100' 5958' 14430' 6005' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Rednll and Re-Entry Operations) Total Depth MD(ft). Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft) Junk(measured) 11152 6338 11051 6302 Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 260 sx AS I 121' 121' Surface 4670' 7.625" 261 sx ASLW,1220 sx Class G, 4711' 3222' Intermediate 60 sx ASI Production 10594' 5.5" 100 sx Class G 10635' 5877' Liner 1130' 3.5" 132 sx Class G 11150' 6336' Perforation Depth MD(ft): Perforation Depth ND(ft): 10760'-10874' 6044'-6144' 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. \Q(CI(VZ- 22. V222. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 Email J.Gary.Eller@conocophillips.co Printed Name . L. G8 d4 Title CTD Supervisor Signature L�_/ 1� 4Phone Date \qiik'Z Commission Use Only Permit to Drill API Number: :4iPermit Approval See cover letter Number 2 /z_ Icc./ 50_019_22_72E—6-C-)- Date rN I for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coal methane,gas hydrates,or gas contained in shales: [V� Other: *L/7Oo t5� �p go fes I- Samples req'd: Yes V No L Mud log req'd: Yes❑ No g *ySbo/s•- ,4,„,j...., T:d-I12S measures: Yes No r❑i Directional svy req'd: Yes[✓f No ,❑/ Spacing a ption req'd: Yes ❑ No L�'J Inclination-only svy req'd: Yes❑ No L' -la t-;*144-e_ op r - a. �e. k i/A-t0 Z. - auT 11.-Zr P R V BY THE 7 Approved by: �T� �,�c�� MMISSJONER� ç r �CM SIGNDATE /D 1 € ` W �Form 10-401 R�ised 10/2012) This permit is valid for 24 mont sm tie date of approval(20 AAC 25.005(g)) `J1 ments in Duplicate ✓ . RECEIVED ConocoPhillips Alaska OCT 0 9 2012 P.O. BOX 100360 /� ,r1 G A C ANCHORAGE,ALASKA 99510-0360 AOGCC October 8, 2012 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete 2F-19A, 2F-19AL1, and 2F-19AL2 from Kuparuk well 2F-19 (PTD# 196-201). The current 2F-19 wellbore is designated as a"Development— Oil'well. It is ConocoPhillips' intention that the 2F-19 coiled tubing drilling (CTD) laterals serve as"Service— Water Injection"wells even though they will initially be produced for some months. ConocoPhillips requests a variance from the packer placement requirements of 20 AAC 25.412(b)so that the 2F-19 CTD laterals may ultimately serve as water injection wells. CTD operations are scheduled to begin October 27, 2012 using the Nabors CDR2-AC rig. The objective of the CTD project is to improve Kuparuk A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. Drilling the coiled tubing laterals will require permanently plugging the A-sand perforations in the 2F-19 mother bore, but there is insufficient room to plug the perfs in accordance with 20 AAC 25.112(c)(1). ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in a manner that allows the CTD sidetrack to take place. Once all CTD operations are completed then a 10-407 will be submitted to classify the original 2F-19 completion as 'Abandoned'. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary, including mechanical assessment and quarter-mile review required for injection wells — Permit to Drill application forms (3) for 2F-19A, 2F-19AL1, and 2F-19AL2 — Directional plans (3) for 2F-19A, 2F-19AL1, and 2F-19AL2 — Current wellbore schematic — Schematic of 2F-19PB1 and 2F-19PB2 from 1997 — Proposed wellbore schematic — 10-403 application form (1)to plug perforations in 2F-19 — Summary of plugging operations for the 10-403 If you have any questions or require additional information please contact me at my office 907-263-4172. Sin rely, J. G7tyElle Conoc• hillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORS ALASKA bWenSCD A &wells 2F-19A, 2F-19AL1, & 2F-19AL2 Drilling Program Summary 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 6 Liner Running 6 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 & Mechanical Assessment (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 Attachment 1: Directional Plans for 2F-19A,AL1, &AL2 8 Attachment 2: Current Well Schematic for 2F-19 8 Attachment 3: Proposed Well Schematic for 2F-19 CTD Laterals 8 Page 1 of 8 O R I I , L October 8,2012 PTD Applicatioi. for KRU 2F-19A, AL1,& AL2 1. Well Name and Classification (Requirements of 20 AAC 25.0050 and 20 AAC 25.005(b)) There are three proposed sidetracks/laterals described in this document: KRU 2F-19A, 2F-19AL1, and 2F- 19AL2. These laterals will exit from the 2F-19 motherbore. All will be classified as"Service- Winj'wells . following a period of pre-production. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A4 and A5 sands in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates of each of the 2F-19 laterals. 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 4700 psi. Using a maximum potential formation pressure of 4839 psi, the maximum potential surface pressure is 4238 psi assuming a gas gradient of 0.1 psi/ft. 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)) Welt 2F-1,9 has a static BHP from August 2012 that measured 3824 psi at 10,821' MD, 6039' TVD for an EMW (12.2 pp0. Since we are drilling south away from any other existing wells, our expectation is that we will i counteysimilar or reduced formation pressure while drilling the 2F-19 CTD laterals. Maximum potential formation pressure is based on the May 2012 pressure measurement from the 2F-14 injector to the north, which had an estimated formation pressure of 4862 psi at 6039' TVD for a gradient of 15.)5 ppg. This estimate comes from an extrapolated surface pressure measurement since a tubing obstruction prevents measurement of a bottomhole pressure in 2F-14. In well 2F-19 this equates to a maximum potential formation pressure of 4839 psi (10,780' MD, 6011' TVD) and a maximum potential surface pressure of 4238 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled. 2F pad is currently a water-only injection pad, although in years past it has had miscible gas injectant. It is possible but unlikely that an influx can produce a significant amount of gas since MI has not been injected in the area for several years. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 2F-19 laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target bf 12.4 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 2F-19 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. Page 2 of 8 nI r October 8, 2012 1101 I PTD Applicatioi. for KRU 2F-19A, AL1,& AL2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 2F-19A 11,940' 13,925' 5948' 5969' 23/", 4.7#, L 80, ST-L slotted liner; aluminum billet on top /2F-19AL1 11,100' 14,430' 5958' 6005' 23/8", 4.7#, L-80, ST-L slotted liner; • aluminum billet on top 2F-19AL2 10 785' 11 900' 5895' 5923' 23/8", 4.7#, L 80, ST-L slotted liner up inside 3%" liner Existing Casing/Liner Information Category OD Wt Grade Cxn Top Btm Top Btm Burst Col. (ppf) MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0' 121' 0' 121' Surface Csg 7%" 29.7 L-80 BTC 0' 4711' 0' 3222' 6890 4790 Prod Csg 5W 15.5 L-80 LTC-Mod 0' 10,635' 0' 5877' 7000 4990 Liner 3W 9.3 L-80 IBT-Mod 10,019' 11,150' 5429' 6336' 10,160 10,530 Tubing 3W 9.3 L-80 EUE 0' 10,019' 0' 5429' 10,160 10,530 8rd-Mod 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is 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 or used drilling mud (-9.3 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.3 ppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 2F-19 motherbore, but overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 2F-19 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.4 ppg (or greater) completion fluid in order to maintain pressure over-balance while, picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-170 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 2F-19 laterals we will target a constant BHP of 12.4 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain Page 3 of 8 ORIGINAL October 8,2012 PTD Application. , for KRU 2F-19A, AL1,& AL2 overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Pressure at the 2F-19A Window(10,790' MD, 6011' TVD, 5880' SSTVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.2 ppg) 3813 psi 3813 psi Mud Hydrostatic (9.3 ppg) 2907 psi 2907 psi Annular friction (i.e. ECD, 0.085 psi/ft) 917 psi 0 psi Mud + ECD Combined 3824 psi 2907 psi (no choke pressure) (overbalanced (underbalanced —10 psi) —910 psi) Target BHP at Window (12.4 ppg) 3876 psi 3876 psi Choke Pressure Required to Maintain 50 psi 970 psi Target BHP 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 Well KRU 2F-19 is an NC-sand producer that has been shut in for several months due to problems with sand production from possible casing damage adjacent to the A-sand perforations. Three CTD laterals will be drilled south of 2F-19 to increase reservoir exposure and improve waterflood sweep in the A5 and A4 sands. Following a lengthy period of pre-production, the 2F-19 CTD laterals will be converted to water injection service. The liner-top packer in 2F-19 is 771' above the planned window exit, which is substantially greater than the 200' allowed for wells equipped for water injection service. There is no means to deepen the packer placement inside the 3'/2" liner. ConocoPhillips requests a variance from the requirements of 20 AAC 'Y 25.412(b) regarding packer placement to allow 2F-19 to be converted to water injection service. A permanent plug will be set in the 3'/2" liner at 10,811' to isolate the existing A-sand perfs, and then a mechanical whipstock will be placed at the planned kickoff point of 10,790' MD. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 10,790' MD. Page 4 of 8 Q r ` I I t L October 8, 2012 PTD Applicatioi. for KRU 2F-19A, AL1,& AL2 After setting the bridge plug and whipstock, we will perform an injectivity test into the open C-sand perfs at 10,760'-770'. Our expectation is that the C-sand is tight and that we will not be able to establish injection. However, if we are able to establish injection then we will use coiled tubing to perform a cement squeeze on all open perfs. Either way, all existing 2F-19 perforations will be isolated or rendered unproductive prior to ✓ performing the CTD sidetrack. A tubing leak has recently been detected in 2F-19 at±9350' MD. We have conducted a risk assessment and concluded that CTD managed pressure drilling operations can be safely conducted despite the tubing communication. However, an extra barrier from the formation is required during rig mobilization and demobilization. Prior to rig mobilization we will perform a no-flow test at the conclusion of pre-CTD plugging operations to confirm that barrier. Prior to demobilization we will install a positive plug in the D-nipple at 9995' MD, followed by a no-flow test. The tubing leak will be repaired after the CTD rig has departed. The 2F-19A sidetrack will exit the 3%2" liner at 10,790' MD and will target the A4 sand south of the existing well with a 3135' lateral. The hole will be completed with a 2%"slotted liner to the TD of 13,925' MD with an aluminum billet at 11,940' MD. The 2F-19AL1 lateral will kick off from the aluminum billet at 11,940' MD and will target the A5 sand south of the existing well with a 2490' lateral. The hole will be completed with a 2%"slotted liner to the TD of 14,430' MD with an aluminum billet at 11,100' MD. The 2F-19AL2 lateral will kick off from the aluminum billet at 11,100' MD and will also target the A5 sand south of the existing well with an 800' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,900' MD with the final liner top located inside the 3%' liner at 10,785' MD. Pre-CTD Work 1. MIRU slickline. Dummy all GLMs. Run whipstock dummy inside 3'/2' liner. 2. MIRU e-line. Set permanent plug inside 3'/" liner at 10,811' above all A-sand perfs. 3. Set monobore whipstock at 10,790' MD with 10° ROHS orientation. 4. Perform injectivity test into open C-sand perfs. If unable to establish injection into C-sand perfs, proceed to step#5. a. OPTION: If able to establish injectivity into C-sand perfs, then MIRU coiled tubing. Cement whipstock in place, simultaneously squeezing all open perfs. Clean out cement down to the top of the whipstock at 10,790'. b. MIRU slickline. Tag top of cement and pressure test. 5. Perform no-flow test. If well does not pass a no-flow test, have slickline set a positive plug in the 2.75" D-nipple at 9995' prior to rig mobilization. 6. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2F-19A Sidetrack (A4 sand, south) a. Mill 2.74"window through 3'/2" liner at 10,790' MD b. Drill 2.70" x 3" bi-center lateral to TD of 13,925' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 11,940'. Over-balancing completion fluid will have been circulated in place to serve as a barrier to formation pressure while picking up slotted liner. 3. 2F-19AL1 Lateral (A5 sand, south) a. Kick off of the aluminum billet at 11,940' MD b. Drill 2.70" x 3" bi-center lateral to TD of 14,430' MD • c. Run 2%"slotted liner with an aluminum billet from TD up to 11,100'. Over-balancing completion ../(1/1:1 fluid will have been circulated in place to serve as a barrier to formation pressure while picking up slotted liner. n� Page 5 of 8 ! f October 8,2012 1 It F ] p PTD Applicatioi,. for KRU 2F-19A, AL1,&AL2 4. 2F-19AL2 Lateral (A5 sand, south) a. Kick off of the aluminum billet at 11,100' MD b. Drill 2.70"x 3" bi-center lateral to TD of 11,900' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 10,785' inside the 3W liner. Over- balancing completion fluid will have been circulated in place to serve as a barrier to formation pressure while picking up slotted liner. 5. Freeze protect. 6. MIRU slickline. Set a positive plug in the 2.75" D-nipple at 9995'. Perform no-flow test. RD slickline. 7. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. MIRU slickline. Pull plug at 9995'. Install gas lift design and patch the hole at—9350' MD. Perform static BHP survey. 3. Put on pre-production for several months prior to submitting a 10-403 application and performing an MIT-IA to convert to water 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 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 conducted in reverse. Liner Running — Since 2F-19 is not equipped with a SSSV, fluid of sufficient density to over-balance the formation will be used to provide well control while picking up slotted 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%" pipe rams provide secondary well control while running 2%" liner. Page6of8 nr"1 i r'% , �, I A October 8, 2012 r + s , <, t t L E �G t. L. PTD Application.. for KRU 2F-19A, AL1,& AL2 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)) — There are no other affected owners — Please see attached directional plans for each lateral. — 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 and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 2F-19A 08 3250' 97' 2F-19PB1 2F-19AL1 03 2750' 97' 2F-19PB1 • 2F-19AL2 02 5325' 97' 2F-19PB1 16. Quarter Mile Injection Review & Mechanical Assessment (for injection wells only) (Requirements of 20 AAC 25.402) The only wells that lie within %4-mile of the proposed 2F-19 CTD laterals are the 2F-19 motherbore and the two plugbacks, 2F-19PB1 and 2F-19PB2, that occurred during the original drilling of 2F-19 in 1997. The casing and cementing of 2F-19 is described below. Its perforations will be permanently plugged as part of this CTD sidetrack proposal. Also described are the plugging methods and isolation of the two plugbacks that ensure that injected fluids remain in the authorized intervals. See the attached schematic of the 1997 plugbacks for clarification. 2F-19 Mother Bore Well 2F-19 was drilled and completed in 1997. The 51/2", 15.5 ppf, L-80, BTC-Mod production casing was set at 10,635' MD in the upper Kalubik Shale and cemented in place with 22 bbl of 15.8 ppg Class G cement. The 5W shoe was subsequently drilled out, and two attempts were made to drill and case 43/" hole but both instances failed to get 3W liner run to TD. Those failed attempts have been designated 2F-19PB1 (TD at 11,191', 4/1/97) and 2F-19PB2 (TD at 10,871', 4/18/97). A bridge plug was set at 10,288' and then a whipstock was set in the 5'/z" casing at 10,260'. A window was cut there and an FIT performed to 13.8 ppg EMW before 43/4" hole was drilled to a TD of 11,152' on 5/21/97. 3W OD, 9.3 ppf, L-80, IBT-Mod liner was placed across the entire Kuparuk sand interval and cemented in place with 28 bbl of 15.8 ppg class G cement. A Schlumberger Cement Bond Log was run in the 3W liner on 6/5/97 and showed good to excellent cement quality from 11,028' to 10,292'. From 10,292' to the top of the liner at 10,019' it is less consistent but there are still several intervals where there is good quality cement across the 5W lap. A separate Schlumberger Cement Mapping Tool run on 5/2/97 in the 5W casing showed generally good cement from the sidetrack depth of 10,260' up to —9800' MD. More recently, a passing combo-MIT to 3000 psi was performed on 8/28/12 which confirms the integrity of the 5W production casing and liner-top packer down to 10,019'. The 3W tubing has a hole at —9350' MD and will have to be repaired prior to converting the well to water injection. There has not been a recent pressure test of the 3'/" liner, although a 24-arm caliper of 8/23/12 showed that the liner was in good condition from a corrosion standpoint. A shallow leak in the 7%" surface casing has very recently been repaired (sundry approval 312- 258), but there are indications that an open shoe on the 7%" casing will prevent getting an MIT-OA. Page 7 of 8 October 8, 2012 PTD Applicatioi., for KRU 2F-19A, AL1,& AL2 2F-19PB1 and PB2 The PB1 and the PB2 both fully penetrated the Kuparuk interval. The 2F-19PB1 was squeezed with 15 bbl of 17.0 ppg, class G cement at a depth of 10,686 on 4/12/97. Although they achieved 2200 psi squeeze pressure, they did not find any hard cement when they drilled out. A second 15 bbl, 17.0 ppg balanced cement plug was laid in from 10,642' and squeezed to 3300 psi, and they ultimately kicked off from that plug at 10,631' to drill what would become 2F-19PB2. An 18 bbl abandonment plug of 15.8 ppg class G cement was squeezed into the PB2 below a cement retainer at 10,500' in the 5'W'casing. Although water injected into the 2F-19 CTD laterals can make its way to the 2F-19PB1 and PB2 wellbores, there is no significant potential for migration of fluids out of the Kuparuk interval. The 5'/2" casing was set in the upper Kalubik shale, and the CMT log of 5/2/97 plus the 14.0 ppg FIT when they drilled out the 5%" shoe both attest to the adequacy of the cement isolation external to the 5W casing. A cement retainer and a bridge plug adequately isolate the inside of the 5%", as does the 3'/" liner, liner-top packer, and cement that were ultimately part of the 2F-19 completion. Attachment 1: Directional Plans for 2F-19A, AL1, &AL2 Attachment 2: Current Well Schematic for 2F-19 Attachment 3: Proposed Well Schematic for 2F-19 CTD Laterals Page 8 of 8 October 8,2012 't I ;� d. 2F-19PB1 & 2F-19PB2 Final Schematic (1997) • •"Ail Depths aro reference Nordic 2 RKB • 4 i 5''/"liner-top packer at 10,019' MD • , Window in 5'/2" liner 10,260'-10,270' MD Bridge Plug®+1-10,281' 'L Top Cement Pl '0+1-10,440' sk,� t: f`' Retainer if.+1-10,500' f '_ .. tip.Y..' 6 5"15.5#L-80 i P 10,626'MD ttg"�rr.,•t•�f'> :�=„•; Nordic RK8 {3 • %:ifCSEt. Ali` '__1,`P §s121• .•,., a,2 - at lTb : Catnent rx ns Sidetrack 4-3/4'open `` ;.' hole section with TD ® Original 4-3/4 open 10,871'MD hole section with TD rel 2F-19 TD at 11,152' MD 11,191'MD 3'/2” liner 10,019-' 11,150' MD 2F-19PB2 2F-19PB1 _._..._. 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Q , .N-1 . alar_ 1 �OOOOOOCCGC2 \ \ Q O O W u 01- aa oZ m E r ▪ 031 3 NmN-,.7,2,1g1 LL JNC H N Q _ ^ Z A��O S.... mrDMlmo 0WW N�OI�ON8-,2092,2p O. pJUoDO v-M UD m O M m rgTwo "8 rWc4c9c9c4mrnmB Umm0 ympp� ON �R¢¢ On .^VMV,.,..mmamMgmmm mN Q Coo .yOnci1�00V G �1.-1 0 - aaml-mNatoa mN C, Z N O.OmO((��MMpp, CN01" WNI�0, pRR 8m80000COM y >> p 8 p �� ?O 00000000000 O 8 8 8 8 000 . r n 8 �O 8 �GGOInOU)0000 h N H N O N iQD W V e-me-M.- OP , v� \D b . \O . 0 .-N N N N N M OD M V 0 N �ana�eeg ueay� O (u/8 56)gpdo Ieo�aan anlO +O co.-NM,MUJ lit,, 1 .. r %:m-. L.. ConocoPhilhi ps Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2F Pad 2F-19 2F-19AL1 Plan: 2F-19AL1_wp03 Standard Planning Report 28 September, 2012 BAKER HUGHES ConocoPhillips or its affiliates IC" . ConocoPhillips Planning Report SNR laska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-19 • Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level • Project: Kuparuk River Unit MD Reference: 2F-19 @ 129.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-19 Survey Calculation Method: Minimum Curvature • Wellbore: 2F-19AL1 Design: 2F-19AL 1_wp03 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 2F Pad Site Position: Northing: 5,949,341.83ft Latitude: 70°16'21.978 N From: Map Easting: 517,392.55ft Longitude: 149°51'33.576 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.13° Well 2F-19 Well Position +N/-S 0.00 ft Northing: 5,948,815.19 ft ' Latitude: 70°16'16.796 N +El-W 0.00 ft Easting: 517,483.07 ft • Longitude: 149°51'30.976 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: • 96.80 ft Wellbore 2F-19AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2011 11/1/2012 15.98 79.89 57,368 Design 2F-19AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,940.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -96.80 0.00 0.00 180.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (1 (°) (ft) (ft) (ft) 0100ft) (°l100ft) (°/100ft) (°) Target 11,940.00 89.16 189.47 5,947.48 -7,942.12 4,466.21 0.00 0.00 0.00 0.00 12,010.00 96.06 190.69 5,944.30 -8,010.93 4,453.98 10.00 9.85 1.74 10.00 12,110.00 89.21 197.99 5,939.70 -8,107.59 4,429.26 10.00 -6.85 7.30 133.00 12,385.00 89.30 170.48 5,943.36 -8,379.19 4,409.15 10.00 0.03 -10.00 270.00 12,610.00 87.86 192.95 5,949.01 -8,602.57 4,402.48 10.00 -0.64 9.98 93.90 12,835.00 88.02 170.43 5,957.21 -8,825.88 4,395.90 10.00 0.07 -10.01 270.00 13,110.00 88.25 197.94 5,966.34 -9,097.37 4,376.01 10.00 0.08 10.01 90.00 13,410.00 87.73 167.93 5,977.12 -9,393.37 4,360.81 10.00 -0.17 -10.00 268.50 13,710.00 88.03 197.95 5,988.46 -9,689.35 4,345.60 10.00 0.10 10.01 90.00 14,010.00 88.30 167.94 5,998.29 -9,985.38 4,330.39 10.00 0.09 -10.00 270.00 14,430.00 90.07 209.90 6,004.54 -10,391.02 4,266.69 10.00 0.42 9.99 88.00 9/28/2012 2:49:09PM Page 2 COMPASS 2003.16 Build 69 O , A ! GI1V? L- •Ie✓ ConocoPhillips or its affiliates 111.4', ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-19 @ 129.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-19 Survey Calculation Method: Minimum Curvature Wellbore: 2F-19AL1 Design: 2F-19AL1_wp03 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +EI-W Section Rate Azimuth Northing Easting (ft) (0) (°) (tt) (ft) (ft) (ft) (1100ft) C) (ft) (ft) 11,940.00 ' 89.16 189.47 5,947.48 -7,942.12 4,466.21 7,942.12 0.00 0.00 5,940,884.25 521,967.27 TIP/KOP 12,000.00 95.07 190.51 5,945.27 -8,001.15 4,455.81 8,001.15 10.00 10.00 5,940,825.21 521,957.01 12,010.00 96.06 190.69 5,944.30 -8,010.93 4,453.98 8,010.93 10.00 10.04 5,940,815.42 521,955.20 Start 10 DLS 12,100.00 89.89 197.26 5,939.62 -8,098.06 4,432.28 8,098.06 10.00 133.00 5,940,728.26 521,933.71 12,110.00 89.21 197.99 5,939.70 -8,107.59 4,429.26 8,107.59 10.00 133.34 5,940,718.72 521,930.71 3 12,200.00 89.22 188.98 5,940.94 -8,195.01 4,408.29 8,195.01 10.00 -90.00 5,940,631.26 521,909.95 12,300.00 89.25 178.98 5,942.28 -8,294.63 4,401.35 8,294.63 10.00 -89.88 5,940,531.63 521,903.24 12,385.00 89.30 170.48 5,943.36 -8,379.19 4,409.15 8,379.19 10.00 -89.74 5,940,447.10 521,911.23 4 12,400.00 89.20 171.98 5,943.56 -8,394.01 4,411.43 8,394.01 10.00 93.90 5,940,432.29 521,913.55 12,500.00 88.53 181.96 5,945.54 -8,493.72 4,416.71 8,493.72 10.00 93.88 5,940,332.60 521,919.06 12,600.00 87.92 191.95 5,948.65 -8,592.81 4,404.63 8,592.81 10.00 93.68 5,940,233.49 521,907.21 12,610.00 87.86 192.95 5,949.01 -8,602.57 4,402.48 8,602.57 10.00 93.37 5,940,223.72 521,905.08 5 12,700.00 87.89 183.94 5,952.36 -8,691.44 4,389.29 8,691.44 10.00 -90.00 5,940,134.83 521,892.09 12,800.00 87.98 173.93 5,955.98 -8,791.23 4,391.14 8,791.23 10.00 -89.66 5,940,035.06 521,894.18 12,835.00 88.02 170.43 5,957.21 -8,825.88 4,395.90 8,825.88 10.00 -89.30 5,940,000.42 521,899.02 6 12,900.00 88.03 176.93 5,959.45 -8,890.41 4,403.04 8,890.41 10.00 90.00 5,939,935.91 521,906.31 13,000.00 88.10 186.94 5,962.82 -8,990.17 4,399.67 8,990.17 10.00 89.78 5,939,836.16 521,903.17 13,100.00 88.23 196.94 5,966.03 -9,087.83 4,379.01 9,087.83 10.00 89.44 5,939,738.46 521,882.74 13,110.00 88.25 197.94 5,966.34 -9,097.37 4,376.01 9,097.37 10.00 89.12 5,939,728.92 521,879.77 7 13,200.00 88.03 188.94 5,969.27 -9,184.77 4,355.12 9,184.77 10.00 -91.50 5,939,641.48 521,859.08 13,300.00 87.85 178.94 5,972.87 -9,284.34 4,348.26 9,284.34 10.00 -91.21 5,939,541.90 521,852.45 13,400.00 87.74 168.93 5,976.72 -9,383.58 4,358.81 9,383.58 10.00 -90.85 5,939,442.70 521,863.23 13,410.00 87.73 167.93 5,977.12 -9,393.37 4,360.81 9,393.37 10.00 -90.46 5,939,432.91 521,865.25 8 13,500.00 87.76 176.94 5,980.67 -9,482.42 4,372.64 9,482.42 10.00 90.00 5,939,343.89 521,877.29 13,600.00 87.85 186.94 5,984.50 -9,582.17 4,369.26 9,582.17 10.00 89.64 5,939,244.15 521,874.14 13,700.00 88.02 196.95 5,988.12 -9,679.81 4,348.60 9,679.81 10.00 89.26 5,939,146.47 521,853.71 13,710.00 88.03 197.95 5,988.46 -9,689.35 4,345.60 9,689.35 10.00 88.90 5,939,136.93 521,850.73 9 13,800.00 88.06 188.94 5,991.54 -9,776.74 4,324.71 9,776.74 10.00 -90.00 5,939,049.50 521,830.04 13,900.00 88.14 178.94 5,994.86 -9,876.32 4,317.85 9,876.32 10.00 -89.69 5,938,949.91 521,823.41 14,000.00 88.28 168.94 5,997.99 -9,975.58 4,328.39 9,975.58 10.00 -89.36 5,938,850.68 521,834.19 14,010.00 88.30 167.94 5,998.29 -9,985.38 4,330.39 9,985.38 10.00 -89.05 5,938,840.89 521,836.21 10 14,100.00 88.63 176.93 6,000.70 -10,074.47 4,342.23 10,074.47 10.00 88.00 5,938,751.84 521,848.25 14,200.00 89.04 186.93 6,002.74 -10,174.27 4,338.86 10,174.27 10.00 87.76 5,938,652.04 521,845.12 14,300.00 89.48 196.92 6,004.03 -10,271.98 4,318.23 10,271.98 10.00 87.56 5,938,554.30 521,824.72 14,400.00 89.94 206.91 6,004.54 -10,364.63 4,280.96 10,364.63 10.00 87.43 5,938,461.56 521,787.67 •14,430.00 90.07 209.90 6,004.54 ' -10,391.02 4,266.69 • 10,391.02 10.00 87.37 5,938,435.15 521,773.46 TD at 14430.00 9/28/2012 2::49:09PM Page 3 COMPASS 2003.16 Build 69 0 I-) 1 Er -, ,, rk a % ,.,d ConocoPhillips or its affiliates VPP" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-19 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-19 @ 129.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-19 Survey Calculation Method: Minimum Curvature Wellbore: 2F-19AL1 Design: 2F-19AL1_wp03 Targets Target Name -hiUmiss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2F-19AL1_T3 0.00 0.00 5,979.00 -9,458.58 4,317.27 5,939,367.60 521,821.87 70°14'43.759 N 149°49'25.448 W -plan misses target center by 53.35ft at 13469.00ft MD(5979.45 TVD,-9451.55 N,4370.15 E) -Point 2F-19AL1_T2 0.00 0.00 5,957.00 -8,821.55 4,322.75 5,940,004.59 521,825.87 70°14'50.024 N 149°49'25.278 W -plan misses target center by 71.62ft at 12820.76ft MD(5956.71 TVD,-8811.82 N,4393.71 E) -Point 2F-19AL1_T1 0.00 0.00 5,943.00 -8,344.73 4,415.87 5,940,481.57 521,917.87 70°14'54.713 N 149°49'22.562 W -plan misses target center by 11.37ft at 12351.27ft MD(5942.94 TVD,-8345.78 N,4404.55 E) -Point 2F-19AL1_T5 0.00 0.00 6,009.00 -10,384.64 4,310.12 5,938,441.63 521,816.87 70°14'34.651 N 149°49'25.671 W -plan misses target center by 35.64ft at 14400.00ft MD(6004.54 TVD,-10364.63 N,4280.96 E) -Point 2F-19AL1_T4 0.00 0.00 6,000.00 -9,984.61 4,311.05 5,938,841.62 521,816.87 70°14'38.585 N 149°49'25.637 W -plan misses target center by 18.87ft at 14005.42ft MD(5998.15 TVD,-9980.90 N,4329.45 E) -Point 2F-19 Polygon 0.00 0.00 6,011.00 -6,896.03 4,164.21 5,941,929.54 521,662.87 70°15'8.962 N 149°49'29.857 W -plan misses target center by 1090.67ft at 11940.00ft MD(5947.48 TVD,-7942.12 N,4466.21 E) -Polygon Point 1 6,011.00 -6,896.03 4,164.21 5,941,929.54 521,662.87 Point2 6,011.00 -6,977.94 4,120.02 5,941,847.54 521,618.88 Point 3 6,011.00 -7,204.44 4,329.53 5,941,621.55 521,828.89 Point4 6,011.00 -7,481.65 4,411.90 5,941,344.56 521,911.90 Point 5 6,011.00 -7,740.74 4,438.32 5,941,085.55 521,938.92 Point 6 6,011.00 -8,194.29 4,222.27 5,940,631.55 521,723.94 Point7 6,011.00 -8,956.27 4,176.53 5,939,869.54 521,679.98 Point 8 6,011.00 -9,984.43 4,201.20 5,938,841.54 521,707.03 Point 9 6,011.00 -10,664.47 4,188.65 5,938,161.54 521,696.06 Point 10 6,011.00 -10,609.16 4,492.81 5,938,217.55 522,000.06 Point 11 6,011.00 -9,985.00 4,450.22 5,938,841.55 521,956.03 Point 12 6,011.00 -9,107.01 4,496.22 5,939,719.56 521,999.98 Point 13 6,011.00 -8,245.09 4,570.19 5,940,581.56 522,071.94 Point 14 6,011.00 -7,835.19 4,632.12 5,940,991.56 522,132.92 Point 15 6,011.00 -7,443.28 4,688.02 5,941,383.56 522,187.90 Point 16 6,011.00 -7,116.92 4,544.75 5,941,709.56 522,043.89 Point 17 6,011.00 -6,856.14 4,214.31 5,941,969.54 521,712.87 Point 18 6,011.00 -6,896.03 4,164.21 5,941,929.54 521,662.87 2F-19AL1 Fault#1 0.00 0.00 5,998.00 -9,918.04 4,070.17 5,938,907.62 521,575.86 70°14'39.241 N 149°49'32.639 W -plan misses target center by 249.57ft at 13915.44ft MD(5995.36 TVD,-9891.74 N,4318.34 E) -Polygon Point 1 5,998.00 -9,918.04 4,070.17 5,938,907.62 521,575.86 Point2 5,998.00 -9,944.57 4,304.13 5,938,881.64 521,809.86 Point 3 5,998.00 -9,978.18 4,567.08 5,938,848.64 522,072.86 Point 4 5,998.00 -9,944.57 4,304.13 5,938,881.64 521,809.86 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 103.00 -26.00 16" 20-3/8 20-3/8 4,693.00 3,085.41 7-5/8" 7-5/8 9-7/8 14,430.00 6,004.54 2-3/8" 2-3/8 3 9/28/2012 2:49:09PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates FS- . ConocoPhillips Planning Report Alaska BAKER HES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-19 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-19 @ 129.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-19 Survey Calculation Method: Minimum Curvature Wellbore: 2F-19AL1 Design: 2F-19AL1_wp03 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 11,940.00 5,947.48 -7,942.12 4,466.21 TIP/KOP 12,010.00 5,944.30 -8,010.93 4,453.98 Start 10 DLS 12,110.00 5,939.70 -8,107.59 4,429.26 3 12,385.00 5,943.36 -8,379.19 4,409.15 4 12,610.00 5,949.01 -8,602.57 4,402.48 5 12,835.00 5,957.21 -8,825.88 4,395.90 6 13,110.00 5,966.34 -9,097.37 4,376.01 7 13,410.00 5,977.12 -9,393.37 4,360.81 8 13,710.00 5,988.46 -9,689.35 4,345.60 9 14,010.00 5,998.29 -9,985.38 4,330.39 10 14,430.00 6,004.54 -10,391.02 4,266.69 TD at 14430.00 9/28/2012 2:49:09PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2F Pad 2F-19 2F-19AL1 2F-19AL1_wp03 Travelling Cylinder Report 04 October, 2012 a r r�1 BAKER HUGHES Baker Hughes INTEQIra- . ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-19 Project: Kuparuk River Unit TVD Reference: 2F-19 @ 129.00ft Reference Site: Kuparuk 2F Pad MD Reference: 2F-19 @ 129.00ft Site Error: 0.00ft North Reference: True Reference Well: 2F-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-19AL1 Database: EDM Alaska Prod v16 Reference Design: 2F-19AL1_wp03 Offset TVD Reference: Offset Datum Reference 2F-19AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 11,940.00 to 14,430.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,639.78ft Error Surface: Elliptical Conic Survey Tool Program Date 9/28/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 60.00 10,160.00 2F-19 Gyro(2F-19PB1) GYD-CT-CMS Gyrodata cont.casing m/s 10,175.00 10,758.18 2F-19(MWD)(2F-19) MWD MWD-Standard 10,758.18 11,940.00 2F-19A_wp08(2F-19A) MWD MWD-Standard 11,940.00 14,430.00 2F-19AL1_wp03(2F-19AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ("I (") 103.00 103.00 16" 20-3/8 20-3/8 4,693.00 3,214.41 7-5/8" 7-5/8 9-7/8 14,430.00 6,133.54 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2F Pad 2F-19-2F-19A-2F-19A_wp08 11,950.00 11,950.00 0.13 0.60 -0.38 FAIL-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/4/2012 10:36:54AM Page 2 of 5 COMPASS 2003.16 Build 69 Baker Hughes INTEQ rdii ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-19 Project: Kuparuk River Unit TVD Reference: 2F-19 @ 129.00ft Reference Site: Kuparuk 2F Pad MD Reference: 2F-19 @ 129.00ft Site Error: 0.00ft North Reference: True Reference Well: 2F-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-19AL1 Database: EDM Alaska Prod v16 Reference Design: 2F-19AL1_wp03 Offset TVD Reference: Offset Datum Reference Depths are relative to 2F-19 @ 129.00ft Coordinates are relative to:2F-19 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.13° Ladder Plot I 80 I _J J ..- ._ J C 60 I 0 1 I I (Q 1 as I d J J _1 _ N I U) I 1 1 w 40— _ I U 0 C a) 20- 1 1 1 I 1 1 1 — I I 1 I 1 I I 0 I I I 0 2500 5000 7500 10000 12500 15000 Measured Depth LEGEND 2F-19,2E 19A,2F-19A_wp08 V0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/4/2012 10:36:54AM Page 5 o/5 COMPASS 2003.16 Build 69 ORIGIN.a!1- L 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 CHECKLISTi7-1 WE LL NAME _ee- ( Z k - 7 - I PTD# 2--t 2 /..cc-/ / Development '� Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: g et (2±".,..k POOL: s ( i L/ /O0-c_c / Check Box or 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 xisting well / _Le l/L 2 r /? , (If last two digits in Permit No. Z[Z i 5-5 ,API No. 50-6 2C- 7—Z 726 -G'I. API number are 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. 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