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211-035
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aA t - 035 Well History File Identifier Organizing (done) ❑ Two-sided II II' II 111 11111 ❑ Rescan Needed II 1111111 1111111 7RE AN DIGITAL DATA OVERSIZED (Scannable) C or Items: ❑ Diskettes, No. ❑ Ma : Greyscale Items: ❑ Other, No/Type: ther Items Scannable by a Large Scanner 1,03s ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other::BY: Maria Date: ill /s/ r'viP Project Proofing II 111/111111 11111 m P BY: c Maria Date: a► l ii. /s/ Scanning Preparation a x 30 = 0 + i15 = TOTAL PAGES 7ST (Count does not incudecover sheet)7J ..Ji1f. BY: ria Date: /s/ Production Scanning IIIIIIIIIIIII 11111 Stage 1 Page Count from Scanned File: 7 (Count does include cover eet) Page Count Matches Number in Scanning Pre aration: YES NO BY: Maria Date: 71 D.. I /s/ 04 ID Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II 11111111111111 Re Scanned I H1111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111111 III In o 76 0 m o 0o m a LL E) z t o ma Ni el 0N p c . Q �,1"I 0i0 O J u- 6 t ! Ei� d �N co a a O� c a) g o 2 2o z 2 o O p 0 . m LL U a co c 2 2 1- 2U0 a0 o -0 0 0 , LL 0 0 0 0 0 0 0 J N y V N N N N N N O 0) ix CO CO CO CO CO CO ✓ Q J N N N N _ 1, z co (O (0 (0 (n ([) C 0 QQ 2 2 X E ci I . 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I • o I; I E E!i) .� ..) t .0 .0 i s a (a 0 > > > y �_ I coNI Z l c c c c .0-. to Q p ! ca Z w E a l a (A j ZO J « yoj a � ,� F- Z Z m o ~ ' f- `0 a0) 2E c m N 0 w W O Z CD p N P o E E E 0 u. to i a' p (O O O v °)v �� \\ - Q lto Zr Wa' Z w c p , ' c O o L y 0 0 c E = a H J ,J ` U Q U II T.� E Q a`� p C7 H p, D rn j, 0 0 o ° n p y O D z c a2i o o a , cc 0 ~ 3 -IoI- J J J W Ce w 3 < 3 0 4t CL 1 0 10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil O Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test LI 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: May 14,2011 211-035/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 May 4,2011 50-103-20118-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 219'FNL,94'FEL,Sec. 11,T1ON,R8E,UM May 9,2011 2K-19AL1 Top of Productive Horizon: 8.KB(ft above MSL): 154'RKB 15.Field/Pool(s): 1573'FSL,2084'FEL,Sec. 10,T1ON,R8E,UM GL(ft above MSL): 118.5'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1180'FSL, 1135'FWL,Sec. 10,T1ON, R8E, UM Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498310 y- 5938085 Zone-4 13181'MD/6307'TVD ADL 25588,25589 TPI: x-491044 y- 5934602 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-488983 y- 5934212 Zone-4 1798'MD/1726'TVD 2674,2675 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1400'MD/1379'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 11055'MD/6303'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 Surf. 115' Surf. 115' 24" 170 sx AS II 9.625" 36# J-55 Surf. 3789' Surf. 2898' 12.25" 1200 sx AS III,450 sx Class G 7" 26# J-55 Surf. 10557' Surf. 6508' 8.5" 450 sx Class G 2.375" 4.7# L-80 10064' , 13180' s 6213' 6307' 3" slotted liner 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 10084' 10016'MD/6185'TVD slotted liner from 10064'-13180'MD 6213'-6307'TVD ,p_. 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. I 03:14i'. 'N DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ill r 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) May 23,2011 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/29/2011 18 hours Test Period--> 947 1298 147 176 Bean 687 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 240 psi 1133 24-Hour Rate-> 1155 1827 194 24 deg. 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 2 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 descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVE ' NONE ai IN 91 11: RBDMS JUN 07 ZO11 Nati 011& GOA Cern.Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Ancli?f e1Qe Submit original only 28. GEOLOGIC MARKERS(List all formations and markers er.__.ntered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes E 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 1400' 1379' needed,and submit detailed test information per 20 AAC 25.071. A4 11055' 6303' N/A Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Eller @ 263-4172 Printed Name L.Gantt ri Title: Alaska Wells Supervisor Signature TetAliILV\ � dikPh Phone ,266-6396 Z6,,3-4621 Date 6/2"r+ 1 I Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 . . ƒ a) \ I oD ( \ ra / . ;) CO [ f 7 II N- tO zo k 1.0 f /// _;} _ 11 ) ` - \ to §)\ I� / §- \A |� a�� \ 0 ) -o 0- �u \ k�\ ,) L > f ! / . . � |� 2 CO ; 67 \/ \j \ % �� ) j ;� %f ƒ7 § \ HO - 6q 03 03 / § 2 §z @ & d ✓ A r= CO_ \ , `,- {\ 1 ) !� }�. 2\ k 77' § e o_ . i \g _¥ \ � � 4 ! iiiiii I ... ,,,i ji, r = I F ..-r. I��� .� ]' _ _ ® = j c o .c iii \g \n ©_ $ E b u) § 2 ,- %2 ® /\ \| \\ \} \ \ \\ c04 o 2.\\ \]9 2\ /9 / \\ «\ J# KUP 2K-19ALI 14"..M0'`` -- - - Ct>CiC3COPI11I1�15 , Well Attributes _ Max Angle&MD TD Al8y.k ,If K; ,",4 9Yf" j,1(k Wellbore APWWI - Field Name IWO!Sttus Ind() IMD(ORB) Act Btm(ORB) _t.. ra+Y+cd^m1z 501032011860 KUPARUK RIVER UNIT PROD 100.48 11,505.51 13 180.0 Comment 1125(ppm) Date Annotation End Dab [KB-Gard(ft) Rig R.Yase Date - SSSV:TRDP 90 1/17/2010 Last WO: 3999 11/14/1989 -,_ Annotation�.yy�,- Last Mod...End Dale LastTaq [ _ Rev Reason:SIDETRACK A&AL1 I Imosbor 15/16/2011 : j, Casing Strings HANGER,31 ----- 1, ! l„�, ' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Sot Depth(TVD)...String Wt...String...'String TopThrd , < LINER ALI 1 2 3/8 1 995. 10,064 0J_ 13,180.0 1 6,306 7 I 4.60 L-80 , STL Liner Details p Top Depth (TVD) Top Incl Mend... ''. Top(SKS) (flKB) (*) Nem Description Comment ID(in) -'«190211081111111 10,064.0 6,212.5 54.23 DEPLOY Shorty deployment sleeve 1.750 coNDuc7oR, Ali 11,098.8 6,303.8 86.06 DEPLOY Shorty deployment sleeve 1.750 35-115 Notes_General&Safety -— End Date Annotation 4/17/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SAFETY VLV. 1,798 —- 5/16/2011 NOTE:WELL SIDETRACKED TO A&AL1(AL1 sidetracked off main wellbore) III GAS LIFT, 2,675 fl SURFACE, 35-3,789 i : ,';',:.: I GAS LIFT. 5,531/ :,;._. III GAS LIFT. 7.062 GAS LIFT,_ 7,833 GAS LIFT, _. 8,577 GAS LIFT, 9,298 F.. 1 GAS LIFT, 9,959 PBA,10,003 PACKER, 10,016 Fr' NIPPLE.10,052 Ilk SOS,10,083 PLOT,10,070-- - APERF, 10,157-10.159- - WHIPSTOCI(, 1 10,170 r RPERF, 10,172-10,182A APERF, 10,169-10,189 :: 1 CEMENT PLUG,10,070 I/r,..I.z Mandrel Details Top T Depth Top Port ....___— (TVD) Incl OD Valve Latch Size TRO Run Sin Top(flKB) (flKB) (1 Make Modm (in) gery Type Type (in) (Psi) Run Date Cam... II 1 2,674.9 2,329.4 56.08 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 i I I i 2 5,529.7 3,800.4 58,91 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 3 7,061.6 4,615.1 57.95 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/26/2011 1 PRODUCTION 4 7,833.2 5,023.6 58.58 MERLA TMPD 1 GAS UFT DMY BK 0.000 0.0 5/3/1990 33-10'557 5 8,576.8 5,412.8 58.71 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/27/2011 i!ii 6 9,298.5 5,789.3 58.71 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/24/2003 7 9,959.4 6,152.5 55.91 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/27/2011 LINER AL1, t 4 10,084-13.180 1 1 TD rd(-19AL1), 13,180 1 4. w Nu z W. qi2ettz 0 v c i ca 0 - 0. coOC W . <, u) Z — „ D -0 c OV R Nr. 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CO of Lri \ o Y Y 0.1N N ..---' CO 0o Co O) O) 00 CO COI,- n CO CO 0- 0 `0, V co C) o co C) � O) O CO O /1t N N N CO O N — CD V CD N T .. .. to Ln In a a a Ln a a Ln � r- C Q7 a r- LO CO V N- O M (O O N CO n - UO UO Cn O) O. co. O O O 0. -Q O) d S` N N N N N CM M M M M M M O v 0 d u) o Cl) (e • ConocoPhitlips Time Log & Summary We/iview Web Reporting Report Well Name: 2K-19 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 4/22/2011 11:00:00 PM Rig Release: 5/14/2011 8:00:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 04/21/2011 24 hr Summary Move rig from 1 E, MIRU 00:00 13:00 13.00 MIRU MOVE MOB P Travel to 2K-19 13:00 17:00 4.00 MIRU MOVE MOB P Remove jeeps,spot rig over well, spot pit module 17:00 23:00 6.00 MIRU WHDBO NUND P RU, nipple up BOP, call pad operator to pump open the SSV,grease tree valves ****RIG ACCEPT***** 23:00 00:00 1.00 MIRU WHDBO BOPE P Test BOP. State witness waived by John Crisp. 04/22/2011 Test BOP,state witnessing waived by John Crisp. All passed except inner reel valve which was replaced and then successfully tested. PU cement milling BHA. 00:00 11:00 11.00 0 0 MIRU WHDBO BOPE P Continue with BOP testing. Complete test @ 11:00 execept for inner reel valve. Replaced valve R-3 11:00 11:30 0.50 0 0 MIRU WHDBO OTHR P Test rig ESD on gen and Hi-Line, restore all systems after test. All Good 11:30 14:00 2.50 0 0 MIRU WHDBO BOPE P R/U and Pull BPV, Lay down Lubricator 14:00 15:12 1.20 0 0 MIRU WHDBO PULD P P/U injector, Remove checks in upper quick connect, M/U Nozzle, stab on, Check out tiger tank line 15:12 18:30 3.30 0 0 MIRU WHDBO BOPE P Fill coil with seawater,Test and chart inner reel valve 18:30 21:30 3.00 0 0 MIRU WHDBO BOPE T Trouble shoot, replace inner reel valve and retest ***3 Hours Nabors Billable Downtime*** 21:30 22:00 0.50 0 0 MIRU WHDBO PRTS P Test PDL 22:00 22:18 0.30 0 0 PROD1 WHPST SFTY P PJSM for PU BHA 22:18 00:00 1.70 0 0 PROD1 WHPST PULD P Makeup pilot hole BHA with used 2.80"D331 mill(smooth gauge)and 0.9 deg motor 04/23/2011 Milled pilot hole from 9993'to 10200', reamed transition area from 10075'to 10095'. Ran dummy WS 00:00 02:30 2.50 0 9,993 PROD1 WHPST TRIP P RIH,circulate FP to TT,swap well to Biozan. 9900'Wt.check, 37K PUW, 18K RIW 02:30 05:30 3.00 9,993 10,064 PROD1 WHPST MILL P 9993'uncorrected depth,tag cement and start milling 20 Deg ROHS, 1.4 BPM,2900 CTP, —20 FPH Page 1 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code SUbcode T Comment 05:30 11:06 5.60 10,064 10,154 PROD1 WHPST MILL P Stalled 3 times total,time mill with 1.5K WOB for 1'then got going ahead @—20 FPI. 1.3 BPM @ 3300PSI FS. (Note: Stall area appears to be where made contact with 7"casing.) 11:06 12:36 1.50 10,154 10,170 PROD1 WHPST MILL P Got enough character from gamma to reset depth+16.5'correction, Continue milling cement 12:36 13:06 0.50 10,170 10,200 PROD1 WHPST MILL P Mill down to 10200', Call TD for cement pilot hole. PUW=40K, Pull up hole,circ bottoms up 13:06 13:18 0.20 10,200 10,026 PROD1 WHPST DLOG P 9990',tie into K-1 marker for 0' correction 13:18 13:48 0.50 10,026 10,162 PROD1 WHPST TRIP P RIH to dry drift transition area saw increase in WOB @ 10082-10087 13:48 17:24 3.60 10,162 10,093 PROD1 WHPST REAM P 10093 to 10075 Back ream this transition area per program. Back reamed 5 times Started @ 1400 lbs DHWOB dry, last dry pass quick blip down to 900 lbs. Perform No flow test,good test. POOH. 17:24 19:54 2.50 10,093 0 PROD1 WHPST TRIP P POOH 19:54 20:12 0.30 0 0 PROD1 WHPST SFTY P PJSM 20:12 21:12 1.00 0 0 PROD1 WHPST PULD P Lay down motor and mill,mill guaged 2.80"go,2.79"no-go. PU dummy WS. 21:12 21:48 0.60 0 0 PROD1 RPEQP1SVRG P Injector head maintenance 21:48 00:00 2.20 0 PROD1 RPEQP1TRIP P RIH 04/24/2011 Ran Dummy WS to 10199'. Ran whipstock and set at 10170'top of whipstock. Started milling window. 00:00 02:42 2.70 10,200 0 PROD1 RPEQP1TRIP P Clean run to 10200'with dummy WS, POOH 02:42 02:54 0.20 0 0 PROD1 RPEQP1SFTY P PJSM for BHA 02:54 03:30 0.60 0 0 PROD1 RPEQPI PULD P Lay down dummy WS, PU WS 03:30 04:00 0.50 0 0 PROD1 RPEQP1SVRG P Service injector 04:00 06:15 2.25 0 9,800 PROD1 RPEQP1TRIP P RIH with whipstock 06:15 06:33 0.30 9,800 10,000 PROD1 RPEQP1TRIP P Close EDC before going below TOC, 06:33 07:33 1.00 10,000 10,185 PROD1 RPEQP1DLOG P Wt Chk, PUW=40K,Tie into formation marker, PUH to 9980 re run log,peak not well defined, RIH to 10100 and log,Tie in for a+11.5 07:33 08:09 0.60 10,150 10,185 PROD1 RPEQP1DLOG P Log CCL 10050 to 10185,correlate results 08:09 08:18 0.15 10,185 10,181 PROD1 RPEQP1WPST P Pull up to set depth 10180.55,TOW @ 10170 orient to high side TF. Set whipstock @ 4030PSI,Set down 3K, l000ks all!good 08:18 10:36 2.30 10,181 88 PROD1 RPEQP1TRIP P Trip out of well, PUW=36K 10:36 10:48 0.20 88 88 PROD1 RPEQP1SFTY P PJSM/No Flo check Page 2 of 22 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 10:48 12:36 1.80 88 78 PROD1 RPEQP1PULD P Lay down Whipstock running tool, BHA#3 P/U Window milling BHA 12:36 15:06 2.50 78 10,100 PROD1 WHPST TRIP P Trip in well with window mill BHA#4 Start 9.7 ppg used Flopro mud down coil 15:06 15:12 0.10 10,100 10,133 PROD1 WHPST DLOG P Log Gamma tie in, +10.5' PUW=39K 15:12 15:30 0.30 10,133 10,172 PROD1 WHPST TRIP P Close EDC, RIH and dry tag PUH 10' and start pumps 15:30 22:00 6.50 10,172 10,176 PROD1 WHPST MILL P 10172.1 call pinch point,start time milling 1'/Hr 1.35 bpm @ 3800 psi FS 22:00 00:00 2.00 10,176 10,177 PROD1 WHPST MILL P Stacking weight with minimal motor work, 3.5k wob,40-60 psi motor work. PU a few times and resume with same result. 1.35 bpm,4000 CTP, 12K RIW 04/25/2011 Milled window at 10172', milled rat hole to 10193',tripped for drilling assembly,drilled build section of 2K-19A to 10430'. Losing 15-20 bbls/hour. 00:00 02:00 2.00 10,177 10,179 PROD1 WHPST MILL P Continue window milling. 1.35 BPM, 4000CTP, 12K RIW, having to stack 3.5K WOB to maintain motor work. Continue at 1 FPH 02:00 04:00 2.00 10,179 10,183 PROD1 WHPST MILL P WOB decreased to 400,40 PSI motor work. Increase ROP to 2 FPH. 04:00 05:45 1.75 10,183 10,193 PROD1 WHPST MILL P Continue milling formation at-6 FPH 05:45 06:30 0.75 10,193 10,190 PROD1 WHPST REAM P PUH and make three reaming passes 06:30 06:36 0.10 10,190 10,160 PROD1 WHPST REAM P Dry Drift window in and out. Looks good 06:36 09:36 3.00 10,160 0 PROD1 WHPST TRIP P Trip out for build section BHP 09:36 11:06 1.50 0 0 PROD1 WHPST PULD P PJSM, Lay dowm window milling BHA#4 2.80 go, 2.79 No-Go both mills 11:06 11:42 0.60 0 62 PROD1 DRILL PULD P P/U Build section BHA#5.2.3 degree motor Bi Center Bit Surface test tool,tag stripper, reset counters 11:42 15:00 3.30 62 10,095 PROD1 DRILL TRIP P RIH, EDC Shut Tagged up GLM @ 7828(7833),90R to get through 15:00 15:18 0.30 10,095 10,121 PROD1 DRILL DLOG P 10095',tie in for+10.0 15:18 15:48 0.50 10,121 10,193 PROD1 DRILL TRIP P trip in to pass through window,clean pass through window Pull up to circ new mud down coil, PUW=40K 15:48 16:24 0.60 9,950 10,193 PROD1 DRILL CIRC P 9950',Open EDC and circulate 50 BBIs 8.6PPG Flo Pro Shut down,shut EDC, RIH to drill 16:24 18:24 2.00 10,193 10,264 PROD1 DRILL DRLG P 10193, Clean pass through window, Drill Ahead 1.4 BPM @ 3720 PSI FS 8.6PPG mud not all the way to surface BHP=3850 Page 3 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:24 20:54 2.50 10,264 10,281 PROD1 DRILL DRLG P Into ankerite, 1.4 BPM, 3600 CTP, 3K WOB with 100 PSI motor work. After discussion with geologists decided to go down. 20:54 21:54 1.00 10,281 10,343 PROD1 DRILL DRLG P Through ankerite and drilling ahead, 1.4 BPM,3600 CTP, 3800 CTP 21:54 23:00 1.10 10,343 10,430 PROD1 DRILL DRLG P Started losing returns, leveled out at -18 BPH, lowered pump rate to 1.3 BPM, BHP was 3700, no improvment in losses,drilling ahead 23:00 00:00 1.00 10,430 6,900 PROD1 DRILL TRIP P POOH for rib steer BHA,following MPD tripping schedule 04/26/2011 Deploy rib steer motor BHA#6. Drill A lateral 10430-10490. Unable to drill, POOH. PU BHA#7. (.8 AKO motor). Drill A Lateral 10490-10640'. Last 24hr loses=247bbrls 00:00 01:36 1.60 6,900 0 PROD1 DRILL TRIP P Continue POOH for BHA swap, following MPD tripping schedule 01:36 01:54 0.30 0 0 PROD1 DRILL SFTY P PJSM for Undeploy/deploy BHA 01:54 04:48 2.90 0 0 PROD1 DRILL PULD P Undeploy build BHA, Deploy RSM BHA 04:48 07:12 2.40 0 9,980 PROD1 DRILL TRIP P RIH with rib steer BHA 07:12 07:48 0.60 9,980 10,128 PROD1 DRILL DLOG P Tie in to formation, K-1, +10' 07:48 08:06 0.30 10,128 10,190 PROD1 DRILL TRIP P RIH through window 08:06 08:12 0.10 10,190 10,209 PROD1 DRILL DLOG P Log RA marker @ 10178,TOWS 10172 08:12 08:27 0.25 10,209 10,430 PROD1 DRILL TRIP P Trip in hole to drill 08:27 09:27 1.00 10,430 10,488 PROD1 DRILL DRLG P 10430, Drill Ahead 1.38 BPM @ 3780 PSI FS BHP=3810 09:27 10:27 1.00 10,488 10,490 PROD1 DRILL DRLG P Drilling Ahead, start losing returns, Wt checks good 36K PUW. Ratty drilling 10:27 11:27 1.00 10,490 10,490 PROD1 DRILL DRLG P Unable to get weight transfer to bit, stalling. Bore pressure increasing possible packing off instead of stalling. Losing returns, but pickups clean. Try several times to drill past. Decide to change to conventional BHA in case it's a problem with the RSM. PUH to window 36K PUW 11:27 12:12 0.75 10,490 9,863 PROD1 DRILL DLOG P MAD pass 10435-10195'. PU into casing 12:12 14:42 2.50 9,863 0 PROD1 DRILL TRIP T Open EDC, POOH 14:42 14:57 0.25 0 0 PROD1 DRILL SFTY T At surface, PJSM 14:57 18:57 4.00 0 0 PROD1 DRILL PULD T Undeploy BHA 6, Inspect EDC, check valve in UQC-all looks good. Deploy BHA 7,.(0.8 AKO with same Hughes Bi-Center Bit) 18:57 19:27 0.50 0 0 PROD1 DRILL SFTY T Crew change, PJSM 19:27 21:27 2.00 0 9,980 PROD1 DRILL TRIP T RIH Page 4 of 22 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:27 21:42 0.25 9,980 9,980 PROD1 DRILL DLOG T Tie in depth with gamma+10' correction 21:42 21:57 0.25 9,980 10,490 PROD1 DRILL TRIP T RIH to Drill 21:57 00:00 2.05 10,490 10,640 PROD1 DRILL DRLG P On bottom drilling,same situtation. Bore pressure increasing, losing returns. PUH length of BHA, 36K. RIH pinch MP choke placing 50psi on WH try to Drill.Get by trouble spot at 10,488'without additonal packoff or losses. Drill Ahead 80-100FPH, 1.3 in, .98 out.2K WOB,3990 BHP. 04/27/2011 Drill A Lateral 10460-11575'. 204 bbrls= Losses past 24 hours 00:00 00:30 0.50 10,640 10,640 PROD1 DRILL WPRT P Wiper trip to window 00:30 02:00 1.50 10,640 10,790 PROD1 DRILL DRLG P Drill Ahead 100FPH,2K WOB, 1.3 in, 1.1 out. 12 ECD,3860 BHP 02:00 02:30 0.50 10,790 10,790 PROD1 DRILL WPRT P Wiper trip to window 02:30 04:00 1.50 10,790 10,940 PROD1 DRILL DRLG P Drill Ahead 100-150 FPH,2K WOB, 1.3 in, 1.1 out, 12.1 ECD,3880 BHP 04:00 05:00 1.00 10,940 10,940 PROD1 DRILL WPRT P Wiper trip to window with tie-in(+1' correction). 05:00 08:00 3.00 10,940 11,090 PROD1 DRILL DRLG P Drill ahead 100-150FPH, 1.3 BPM in, 1.1 out, 12.3 ECD,4173 3943 BHP 08:00 09:15 1.25 11,090 11,090 PROD1 DRILL WPRT P Wiper trip(#1)up to 10210'. 09:15 11:15 2.00 11,090 11,240 PROD1 DRILL DRLG P Drill ahead 34-92-fph. Mud rates: 1.38-bpm in; 1.19-bpm out.4050-psi CTP;4600-psi BHP. 9.5k#pipe wt; 2k#WOB. 11:15 12:30 1.25 11,240 11,240 PROD1 DRILL WPRT P Wiper trip(#2)up to 10212'. 12:30 15:45 3.25 11,240 11,390 PROD1 DRILL DRLG P Drill ahead 47-92-fph. Mud rates: 1.38-bpm in; 1.20-bpm out.4140-psi CTP;4532-psi BHP. 7.2k#pipe wt; 2.9k#WOB. 15:45 16:45 1.00 11,390 10,190 PROD1 DRILL WPRT P Wiper trip(#3)with tie-in. (+1' correction). 16:45 17:00 0.25 10,190 10,219 PROD1 DRILL DLOG P Log RA marker. 17:00 17:45 0.75 10,219 11,240 PROD1 DRILL WPRT P RBIH to drill. 17:45 21:30 3.75 11,390 11,540 PROD1 DRILL DRLG P Drill Ahead 1.38 BPM in, 1.23 out, 4050 CTP, 1-2K WOB, 10K CTW 21:30 23:00 1.50 11,540 11,540 PROD1 DRILL WPRT P Wiper trip to window,34K PUW 23:00 00:00 1.00 11,540 11,575 PROD1 DRILL WPRT P Drill Ahead, 1.38 BPM in 1.22 out, 4046 CTP,2K WOB,5-6K CTW 04/28/2011 Drill A Lateral 11575-12440'. Perform mud swap. Past 24 hour losses 138 bbrls.Avg./hour losses past 24 hrs 5-6 bbrls. Total Losses for Lateral 658 bbrls. 00:00 02:30 2.50 11,575 11,688 PROD1 DRILL DRLG P Drilling Ahead 40-50 FPH, 1.38 BPM in, 1.22 out,4150 CTP, 6-8K CTW 02:30 04:30 2.00 11,688 11,688 PROD1 DRILL WPRT P Wiper trip back to window, 34K PUW Page 5 of 22 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 04:30 07:15 2.75 11,688 11,840 PROD1 DRILL DRLG P Drill Ahead 1.37 BPM in, 1.26 out, 4000 CTP, 1-2K CTW,2-3K WOB, 12.3 ECD 07:15 08:22 1.13 11,840 10,195 PROD1 DRILL WPRT P Wiper trip(#3)with tie-in(36k#off bottom). 08:22 08:29 0.13 10,195 10,215 PROD1 DRILL DLOG P Log RA tag. (0.0'correction). 08:29 09:29 1.00 10,215 11,840 PROD1 DRILL WPRT P RBIH. RIW of 12-14k#from 11600-11800'. 09:29 12:14 2.75 11,840 11,990 PROD1 DRILL DRLG P Drill ahead 65-fph. Mud rates: 1.40-bpm in; 1.25-bpm out.4200-psi CTP;3975-psi BHP. 8.1k#pipe wt; 1.7k#WOB. 12:14 13:29 1.25 11,990 11,990 PROD1 DRILL WPRT P Wiper trip(#1)up to 10215'. (37k# off bottom). RIW 12k#through 11800-11990'. 13:29 15:14 1.75 11,990 12,140 PROD1 DRILL DRLG P Drill ahead 100-fph. Mud rates: 1.40-bpm in; 1.25-bpm out.4275-psi CTP;3990-psi BHP. 1.9k#pipe wt; 1.5k#WOB. 15:14 17:59 2.75 12,140 12,140 PROD1 DRILL WPRT P Wiper trip(#2)up to 10212'. (37k# off bottom). Swap out mud 17:59 19:44 1.75 12,140 12,290 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM in, 1.25 out, 4000 CTP,-2K CTW, 1-2K WOB 19:44 22:29 2.75 12,290 12,290 PROD1 DRILL WPRT P Wiper Trip to window,38K PUW, intial PU.Weight breaks back to 34K.Tie in depth to RA marker, 0 Correction 22:29 23:59 1.50 12,290 12,440 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM in, 1.25 out. 4000 CTP,80 WHP, 3965 BHP,-2K CTW, 12.4 ECD 04/29/2011 Drill A Lateral 12440-12614'.TD A Lateral 12614'.Wiper trip to swab valves. RBIH to TD, POOH laying in liner running pill to build section.(10400). Displace well to 12ppg KWF 10400'to surface. Perform BOPE function test.Total losses past 24 hours=86 bbrls, Cum losses for lateral=744 bbrls 00:00 02:30 2.50 12,440 12,440 PROD1 DRILL WPRT P Wiper Trip back to window,36K _ PUW 02:30 04:00 1.50 12,440 12,546 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM in, 1.3 out,-3K CTW, 1-2K WOB,4000 CTP, 3966 BHP, 12.5 ECD. Pump 50bbrl lube pill 6%,attempt to minimize stacking surface weight. 04:00 04:30 0.50 12,546 12,546 PROD1 DRILL DRLG P PUH, stacking-7K CTW,without weight transfer, PU/RIH attempting to drill. 6%lube pill did not help stacking. 04:30 07:30 3.00 12,546 12,546 PROD1 DRILL WPRT P Unable to drill,Stacking-10K, Pull wiper trip to window. 36K PUW (8k# RIW just before back on bottom.) 07:30 09:00 1.50 12,546 12,614 PROD1 DRILL DRLG P Drill ahead 60-fph. Mud rates: 1.40-bpm in; 1.24-bpm out.4100-psi CTP;4018-psi BHP. 0-1.5k#pipe wt; 1.1k#WOB. Page 6 of 22 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 09:00 09:45 0.75 12,614 12,614 PROD1 DRILL DRLG P Stacking out again with no WOB. Attempt BHA wipers but unable to get back doen. PUH a couple hundred foot and attempt to RBIH. Unable to RBIH;stacking above with no WOB. PUH a couple hundred foot and try again. RBIH to bottom to attempt drilling. 09:45 10:15 0.50 12,614 12,614 PROD1 DRILL DRLG P On bottom again but unable to drill. PUH and time out low/high vis sweep to be at bit when back on bottom. Pump low/high sweep and pull swab wiper. 10:15 14:45 4.50 12,614 148 PROD1 DRILL WPRT P TD Lateral,Chase sweeps with wiper trip to swabs. 14:45 17:00 2.25 148 9,990 PROD1 DRILL WPRT P RBIH from surface 17:00 17:15 0.25 9,990 9,990 PROD1 DRILL DLOG P Tie in depth-7'correction 17:15 18:30 1.25 9,990 12,612 PROD1 DRILL WPRT P RIH to TD 18:30 19:00 0.50 12,612 12,612 PROD1 DRILL WPRT P Tag TD PU start pumping beads. Recip CT pumping beads to bit 19:00 23:00 4.00 12,612 10,300 PROD1 DRILL TRIP P POOH displace liner pill TD to landing point 10300', Displace KWF to surface POOH. 23:00 23:15 0.25 10,300 0 PROD1 DRILL OWFF P At surface, PJSM, Monitor well for flow 23:15 23:45 0.50 0 0 PROD1 DRILL PULD P LD lateral drilling BHA 23:45 00:00 0.25 0 0 PROD1 DRILL BOPE P Function test BOPE 04/30/2011 PU/MU Lower half"A"Liner. RIH setting on bottom 12612'. POOH. PU/MU"A"liner upper half. RIH,tag at 10755'.Stuck.Attempt to get free. 00:00 01:00 1.00 0 0 COMPZ CASING PUTB P RU floor to MU liner 01:00 03:15 2.25 0 0 COMPZ CASING PUTB P PU/MU 26 jnts of slotted Liner 03:15 06:45 3.50 903 12,614 COMPZ CASING RUNL P RIH 06:45 07:15 0.50 12,614 10,880 COMPZ CASING RUNL P Tag TD with liner segment#1. Set down 5k#surface, 1.44k#WOB. Come online pump 1.4-bpm, 4400-psi CTP. PUH 31k#off bottom. No pull shown on WOB. All good. Stop and come offline pumping. Pump across top up to window. PUH. Liner placed 11,756'-12614'. 07:15 07:45 0.50 9,970 9,990 COMPZ CASING DLOG P Stop and correct depth to omit liner length. Tie-in. (-6'correction). 07:45 10:30 2.75 9,990 71 COMPZ CASING TRIP P POOH stopping at 9343.8'to flag pipe for OH. 10:30 10:45 0.25 71 71 COMPZ CASING SFTY P At surface, check well for flow. Conduct PJSM for lay down tools. Confirm no-flow again. 10:45 11:00 0.25 71 0 COMPZ CASING PULD P Lay down liner running tools. 11:00 11:15 0.25 0 0 COMPZ CASING SFTY P PJSM for making up liner. Page 7 of 22 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:15 12:15 1.00 0 0 COMPZ CASING PUTB P Make up liner segment#2 into hole for liner run. 19 jnts of solid liner,3 jnts of slotted liner, plus anchor-billet. 12:15 13:15 1.00 0 0 COMPZ CASING PUTB P Pick up liner segment#2. 13:15 14:00 0.75 0 751 COMPZ CASING PULD P Pick up anchor-billet, PU MWD, hang in slips. Skid Injector over well and make up tools. Make up to well, open rams and and tag stripper. 14:00 14:15 0.25 751 751 COMPZ CASING RUNL P Test MWD. Open EDC. 14:15 16:30 2.25 751 10,755 COMPZ CASING RUNL P RIH liner segment#2(BHA#9). 16:30 17:00 0.50 10,755 10,755 COMPZ CASING RUNL P Stopped at flag to correct depth. Calculate 18.8'correction. RIH to log RA marker for depth control. 17:00 18:00 1.00 10,755 10,755 COMPZ CASING RUNL T Stack weight-12K, unable to RIH. Attempt pull up a45k but unable to move. Stuck with shoe at 10755'. Total liner length=690.12'(Bull Nose to top of billet). OH anchor=10073.88'in well. 4' below TT in cement pilot hole. Aluminum billet is straddling tubing tail. EDC=10019'in wellbore. Note:Openhole anchor is limiting options. Cannot push or pull too much or will prematurely set permanent anchor in the cement pilot hole, leaving blank liner across the window and most of the productive interval. 18:00 22:00 4.00 10,755 10,755 COMPZ CASING CIRC T Pump KWF down backside equalizing diff. psi on BHA. .45 BPM, 368 WHP, PU 50K,-14K WOB.Still stuck. Discuss with Town,order mineral out from KIC. While waiting, mix up 6%lube pill in 8.6 ppg mud. 22:00 00:00 2.00 10,755 10,755 COMPZ CASING CIRC T Open EDC circ.5 BPM,4000 BHP, 13 ECD,5 bbl lube pill through EDC. Once displaced out EDC, close EDC, bullhead 3 bbl down backside displacing lube pill around BHA,try to pull free. Still stuck. 05/01/2011 Upper Section"A"Lateral liner with OH anchored billet stuck at 10755'bit depth.Multiple attempts to pull free.Swap well back to Flo-Pro,Spot 10bbrls mineral oil around liner and let soak 30 min. Pull free 50K. POOH, LD liner utilizing SSSV. Deploy BHA 10(.8 AKO w/DS331 mill. RIH to TOL#1,(11754')cleanout run. Dress cement pilot hole in transition/build section. RBIH, Lay in liner running pill TOL#1 to Tubing Tale (10071'). POOH Total Losses KWF=198 brls Total Losses FP=63 brls Total Losses well FP=807 brls Page 8 of 22 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 00:15 0.25 10,755 10,755 COMPZ CASING CIRC T 6%Lube pill displaced around liner. PU attempt to pull free.50K PUW, -14K WOB, RIH 7K CTW,8K WOB, No Luck Setting Tool limits with 15%Safety factor 13K Set down 20K PU 00:15 04:30 4.25 10,755 10,755 COMPZ CASING CIRC T Relax CT to neutral weight 21K CTW, Open EDC. Circulate well from 12.0 ppg KWF to 8.6 ppg Flo-Pro. 04:30 05:00 0.50 10,755 10,755 COMPZ CASING CIRC T Flo-Pro back to surface.Offline with pumps, close EDC, Line up and pump down backside with Flo-Pro attempt to pull free. No luck. Open EDC. 05:00 07:45 2.75 10,755 10,755 COMPZ CASING CIRC T Load mineral oil in pits. Circ 10-bbl mineral oil down CT through open EDC. Chase mineral oil with drilling mud. Spot mineral oil in well just outside tool. Close EDC and pump down the backside to move mineral oil down to liner portion in the open hole. 07:45 08:30 0.75 10,755 10,755 COMPZ CASING OWFF T Allow time for mineral oil to soak around liner/openhole interface. 08:30 09:00 0.50 10,755 9,999 COMPZ CASING PULL T Pull free with 48.8k#surface weight and-12.5k#WOB. PUH pumping down backside. 09:00 11:30 2.50 9,999 1,700 COMPZ CASING PULL T Open EDC. POOH BHA#9. 33k# pick up weight from 9999'. 11:30 12:00 0.50 1,700 1,700 COMPZ CASING OWFF T Stop at 1700'to close SSSV and perform drawdown test. Bleed down WHP in two iterations with no pressure increase and confirmed no-flow at surface. Watched well for +5-min and confirmed no flow. 12:00 12:30 0.50 1,700 781 COMPZ CASING PULL T POOH. No-flow check good. 12:30 12:45 0.25 781 781 COMPZ CASING SFTY T PJSM for laying down liner. Confirm no flow again. 12:45 13:45 1.00 781 0 COMPZ CASING PULD T Lay down BHA. 13:45 15:45 2.00 0 0 COMPZ CASING PUTB T Lay down liner. Cannot find any marks on liner or anchor-billet to indicate where we were stuck. 15:45 16:00 0.25 0 0 COMPZ CASING SFTY T PJSM for picking up tools and injector maintenance. 16:00 16:30 0.50 0 0 COMPZ CASING SVRG T Perform injector maintenance. 16:30 17:30 1.00 0 0 COMPZ CASING PULD T PU clean out BHA(BHA#10)with 0.8-deg AKO and 2.74"D331. 17:30 17:45 0.25 62 62 COMPZ CASING PULD T Check MWD tools and open EDC. 17:45 19:45 2.00 62 9,990 COMPZ CASING TRIP T RIH 19:45 20:00 0.25 9,990 10,000 COMPZ CASING DLOG T Tie in depth+8'correction Page 9 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:00 2.00 10,000 11,754 COMPZ CASING FCO T RIH to top of liner segment#1. Hole in good shape-no trouble getting to bottom. 22:00 00:00 2.00 11,754 11,754 COMPZ CASING WPRT T Lightly tag TOL#1 (11754.19'), Pump 10 bbrls Low/High vis pill chasing back to window. Dress cement pilot hole with 180 deg TF (10150-10071)at 5'/min.Clean-did not see any motor work. RBIH to TOL segment#1 at 11754.19'. 05/02/2011 PU/MU liner#2 utilizing SSSV. RIH releasing on depth, 11755',TOL#2 11071'. POOH, Undeploy BHA 11, Deploy BHA 12(1.0 AKO,with DS 331 mill). RIH,dress cement pilot hole. 00:00 03:00 3.00 10,755 1,800 COMPZ CASING TRIP T POOH displace liner running pill to tubing tale, POOH 03:00 04:15 1.25 1,800 0 COMPZ CASING TRIP T Close SSSV,flow check, POOH 04:15 04:45 0.50 0 0 COMPZ CASING SFTY T At surface, PJSM Monitor well for flow 04:45 06:30 1.75 0 0 COMPZ CASING PULD T LD cleanout BHA 10 06:30 06:45 0.25 0 0 COMPZ CASING SFTY T PJSM for picking up liner. 06:45 07:30 0.75 0 0 COMPZ CASING PUTB T Make up liner segment#2 minus the anchor-billet for liner run. 07:30 07:45 0.25 0 81 COMPZ CASING PUTB T Pick up liner segment#2. 07:45 08:00 0.25 81 729 COMPZ CASING PULD T PU MWD, hang in slips. Skid Injector over well and make up tools. Make up to well,open rams and and tag stripper. Make correction to depth for liner. 08:00 08:45 0.75 729 729 COMPZ CASING PULD T Tag up. Test MWD. Open EDC. Pressure up well. Close EDC. Open SSSV. 08:45 10:45 2.00 729 10,020 COMPZ CASING RUNL T RIH liner segment#2(BHA#11). 10:45 11:00 0.25 10,020 10,029 COMPZ CASING DLOG T Stop at flag. (Correction+9.4'). Weight check 35k#. Come offline pump. Close EDC. 11:00 11:15 0.25 10,029 10,755 COMPZ CASING RUNL T RIH with liner 11:15 11:40 0.42 10,755 11,754 COMPZ CASING RUNL P Continue RIH with liner 11:40 11:44 0.08 11,754 11,755 COMPZ CASING RUNL P Tag lightly and set down 3.5k# WOB. Came online 1.33-bpm 4300-psi Circ Pressure. Pull up out of liner with 32k#off bottom. TOL at 11,070'MD. 11:44 12:04 0.34 11,755 10,849 COMPZ CASING TRIP P PUH. 12:04 12:13 0.16 10,164 10,189 COMPZ CASING DLOG P Stop and correct depth to reflect having left liner at depth. RIH to log RA marker. (0.0'correction). 12:13 14:28 2.25 10,189 0 COMPZ CASING TRIP P POOH. 14:28 14:43 0.25 0 0 COMPZ CASING TRIP P Tag stripper. Open EDC. 14:43 14:58 0.25 0 0 COMPZ CASING SFTY P PJSM for pressure undeploying liner running BHA#11. 14:58 16:28 1.50 0 0 COMPZ CASING PULD P Undeploy liner BHA#11. Page 10 of 22 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:28 17:58 1.50 0 0 PROD2 STK PULD T Deploy clean-out run BHA#12 17:58 18:28 0.50 0 0 PROD2 STK PULD T Crew change, PJSM, Perform injector maintenance. 18:28 20:28 2.00 0 55 PROD2 STK PULD T Undeploy BHA#12,change configuration of BHA as per town. Pull out string reamer,change AKO from 0.8 to 1.0 deg. Deploy BHA. 20:28 22:43 2.25 55 9,990 PROD2 STK TRIP T RIH, EDC closed(concern of Alpine beads strung out in wellbore). 22:43 22:58 0.25 9,990 9,990 PROD2 STK DLOG T Tie in depth with gamma,+10.5' correction 22:58 23:58 1.00 9,990 10,085 PROD2 STK REAM T Dress Pilot hole: Differential 330psi, CTP 3850psi, Free Spin RIH,5 FPM to 10085',HS TF,Backream HSTF to 10064 1 FPM. 50psi increase motor work, 10085'on RIH, Clean on backream 34K PUW RIH,5 FPM to 10090',HS TF,Backream LS TF to 10064 1 FPM. 50psi increase motor work, 10085'on RIH,Clean on backream 34K PUW 05/03/2011 Dress cement pilot hole from 10,060-10,095 with 2.79"D331. Run dummy drift through pilot&Window- clean. Set OH Anchored billet from 11,070'-11,054'. POOH.24 hour losses=50 bbls Page 11 of 22 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T' Comment 00:00 06:15 6.25 10,060 10,094 PROD2 STK REAM T Dress Pilot Hole: Free spin diff psi 330, 3900 CTP psi. *RIH at 5 fpm to 10087'at HS TF. Backream 90L TF to 10063'at 1 fpm. 50 psi increase motor work, 10080-10085'on RIH,50 psi increase backream. 34K PUW *RIH at 5 fpm to 10088'at HS TF. Backream 90R TF to 10062'at 1 fpm. 50psi increase motor work, 10080'-10085'on RIH,30psi increase backream. 34K PUW *RIH at 3 fpm to 10091'at 20R TF. Backream 160L TF at 1 fpm to 10061'. 70psi increase motor work, 10081'-10086'on RIH,40psi increase on backream. 34K PUW *RIH at 3 fpm to 10092'at 20R TF. Backream 170L at 1 fpm to 10060'. 45psi increase motor work, 10081'-10086'on RIH, 15 psi increase on backream 10075-10071'. At tubing tail observe 30psi increase. *RIH at 3 fpm to 10093'at 20R TF. Backream 150L TF at 1 FPM to 10059'. 50psi increase motor work, 10081-10086'on RIH, 15psi increase on backream to 10075'. *RIH at 3 fpm to 10094'at 20R TF. Backream 140L at 1 fpm to 10058'. 45psi increase motor work, 10081-10083'on RIH, Clean on backream. *RIH at 3 fpm to 10095'at 20R TF. Backream 160R TF at 1 fpm to 10057'. 40psi increase motor work, 10081-10084'on RIH. Clean on backream. *RIH at 3 fpm to 10096'at HS TF. Backream 160L TF at 1 fpm to 10056'. 50psi increase motor work, 10082-10085'on RIH,Clean on backream 06:15 06:30 0.25 10,094 10,055 PROD2 STK REAM T PUH to 10055'. Dry drift transition 10055-10190'. Observed 350#WOB down through 10085'and-170# picking up through 10085'. 06:30 08:45 2.25 10,055 0 PROD2 STK TRIP T POOH. 08:45 09:00 0.25 0 0 PROD2 STK PULD T At surface. Space out 1.9'. Open EDC. 09:00 09:15 0.25 0 0 PROD2 STK SFTY T Conduct PJSM for undeploy BHA #12. 09:15 10:00 0.75 0 0 PROD2 STK PULD T Undeploy reaming BHA#12. Perform injector maintenance. 10:00 10:15 0.25 0 0 PROD2 STK SFTY T PJSM to deploy drift run for anchored billet(BHA#13). Page 12 of 22 Time Logs Date From To Dur S. Death E.Death Phase Code Subcode T Comment 10:15 11:45 1.50 0 0 PROD2 STK PULD T Deploy BHA#13. Close EDC. Continue injector maintenance. 11:45 12:50 1.09 0 9,999 PROD2 STK TRIP T RIH drift BHA(BHA#13). 12:50 12:59 0.16 9,999 10,026 PROD2 STK DLOG T Log RA marker(+9.0'correction). Weight check:31 k#. 12:59 13:14 0.25 10,026 10,161 PROD2 STK TRIP, T Drift 10,026.23'through 10,161.2'. Looked good. 13:14 16:29 3.25 10,161 0 PROD2 STK TRIP T POOH. 16:29 16:44 0.25 0 0 PROD2 STK SFTY T At surface, PJSM 16:44 18:14 1.50 0 0 PROD2 STK PULD T Undeploy drift BHA 18:14 19:59 1.75 0 77 PROD2 STK PULD T Deploy BHA#14 with Anchor-Billet& BOT J-setting sleeve. 19:59 22:59 3.00 77 9,990 PROD2 STK TRIP T RIH with EDC open pumping.3 bpm hoplding MPD.Weight check 37K, Close EDC&tie in with+9.5 ft. RIH to 11070'Tag TOL 22:59 23:29 0.50 11,070 11,054 PROD2 STK ANCR T Orient 190 ROHS. Bring pumps up to 4700 psi.Set Billet WOB increased to 12K. P/U weight 38K, pump.8 bpm while POOH. Top of billet at 11,054'MD. 23:29 23:59 0.50 11,054 9,500 PROD2 STK TRIP T Pull through window HS, re-set counter. POOH following MPD. 05/04/2011 POOH laydown BHA#14, notcied damaged pipe above CT connector.Cut off 15 ft of CT, re-head. P/U BHA# 15 with 1.0 AKO&RR Bi-center for KO. KOTB @ 11, 054'. Initial problems with slip sticking and pressures. Continue drilling build section after successfull billet exit. 77 bbl losses for 24hours. 00:00 02:00 2.00 9,500 60 PROD2 STK TRIP T POOH following MPD 02:00 04:00 2.00 60 0 PROD2 STK PULD T PJSM-Undeploy BHA#14.Small indents noticed in pipe at surface on bottom side. Inspect injector chains for debris. 04:00 06:00 2.00 0 0 PROD2 STK SLPC T Found a couple of small shims and pieces of CT stringers in chains. Inspect CT above coil connector and found gouges in pipe from chains during deployments.Cut off damaged CT,total of 15ft. Start heading up CTC. 06:00 06:30 0.50 0 0 PROD2 STK SFTY T Crew change PJSM 06:30 08:00 1.50 0 0 PROD2 STK SLPC T Head up CTC and BHI drilling head, Pull test and psi test CTC 08:00 10:00 2.00 0 0 PROD2 STK SLPC T Head did not test, Rehead CTC and BHI drilling head, Pull test and psi test.40K,4500psi 10:00 11:30 1.50 0 0 PROD2 STK PULD P Deploy BHA 15(1.0 AKO with Hughes rerun Bi-center) 11:30 14:00 2.50 62 9,990 PROD2 STK TRIP P RIH 14:00 14:15 0.25 9,990 9,990 PROD2 STK DLOG P Tie in depth+8'correction 14:15 14:45 0.50 9,990 11,055 PROD2 STK TRIP P RIH to ST 14:45 15:00 0.25 11,055 11,055 PROD2 STK TRIP P Dry tag TOB. 11054.6' Page 13 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code ` Subcode T Comment 15:00 18:00 3.00 11,055 11,054 PROD2 STK KOST P 1 fph for 1'. Stall several times due to slip sticking. Dry tag TOB once again. 10053.5'.Try to start milling, pump 6%lube pill, no change. 18:00 20:00 2.00 11,054 11,055 PROD2 STK KOST P Start to get weight transfer to bit, Start milling,pressures slightly higher than normal, 1.40 bpm, 3880psi, BHP 4240,WHP 0..-WOB transfer problems after 2 ft drilled,Al. Shavings to surface.3 tries with slip sticking. Do a 100ft wiper.Overpull 25ft up. 20:00 20:45 0.75 11,055 10,070 PROD2 STK WPRT T P/U 100ft-overpull-40K.Start working string P/U weight 45K- possibly getting differentially stuck. losing returns,Trap WHP before coming down on pump to 400 psi. Popped free-continue to wiper pumping 1.3 bpm, circ 3900 psi, .9 bpm out,WHP 0, BHP 4300,open choke to zero. Still pulling heavy. Annular bled down to 4000 psi, Rate out 1.30 bpm.Circ press 3600 psi. normal pressures after 10,480ft. 20:45 21:30 0.75 10,070 11,056 PROD2 STK WPRT T Wiped into cased hole-10,030'- During wiper had heavy blobs of slick pill roll over the shakers with Al. Shavings suspended in viscious pill. RIH,clean drift through cement& window.Tie into PIP tag+1ft correction. 21:30 22:48 1.30 11,056 11,070 PROD2 STK KOST P Milling ahead-much better WOB& pressures-1.35 BPM,3600, BHP 3980, ECD 12.4,WOB.8K,CT weight 14K,smooth milling. Increase speed @ 11059'. Drillling ahead additional 30 ft. 22:48 23:12 0.40 11,070 11,085 PROD2 STK KOST P Started to get light cement over shakers-possibly from clean out runs.-IA=390/OA=300, PH= 9.7,density of sample=11.4. Continue drilling ahead to 11085'- Drift Billet-clean. Returns cleaning up. 23:12 00:00 0.80 11,085 11,139 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,3800, BHP 3980, ECD 12.4, ROP 80,WOB 1.6k,CT weight 12K, returns 1.25 bpm. 05/05/2011 BOP test state witness waived by Lou Girmaldi. Deploy BHA#15-RSM with 2.73"Braised Bi-center.46 bbls losses for 24 hours. 00:00 01:00 1.00 11,139 11,210 PROD2 DRILL DRLG P Drilling ahead 01:00 02:15 1.25 11,210 11,210 PROD2 DRILL WPRT P Wiper trip 35K off bottom 02:15 04:15 2.00 11,210 11,355 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,3890, BHP 4030, ECD 12.6, ROP 80,WOB 1.8K, Ct weight 12K Page 14 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 08:15 4.00 11,355 0 PROD2 DRILL WPRT P Wiper trip-36K, Min. pump rate through window&cement pilot. Open EDC above pilot&POOH for BHA change and BOPE test. 08:15 08:30 0.25 0 0 PROD2 DRILL SFTY P At surface, PJSM. 08:30 10:30 2.00 0 0 PROD2 DRILL PULD P Undeploy lateral BHA#14 10:30 12:00 1.50 0 0 PROD2 DRILL SVRG P Prepare for BOPE test,Grease rig valves and tree valves 12:00 18:00 6.00 0 0 PROD2 DRILL BOPE P Test BOPE.Witness waived by Lou Grimaldi. 18:00 22:00 4.00 0 0 PROD2 DRILL BOPE P BOPE test completed. No failures. 22:00 23:00 1.00 0 0 PROD2 DRILL CIRC P Circulate flo-pro through CT string. Flush MP choke system as grease and debris plugged it off. 23:00 00:00 1.00 0 68 PROD2 DRILL PULD P Deploy BHA#15 with RSM& Hughes bi-center bit. 05/06/2011 Drilled ahead AL1 lateral.83 bbl losses for 24 hours. 00:00 00:30 0.50 68 68 PROD2 DRILL PULD P Complete deploying BHA#15 00:30 04:00 3.50 68 11,357 PROD2 DRILL TRIP P RIH pumping.5 bpm following MPD. Stop pumping, close EDC.Tie in @ 10,000 ft with+9 ft correction. P/U weight 36K. Clean drift throug cement&window, pump.3 bpm through build. Empty single pit of old mud for mud swap on bottom. 04:00 05:00 1.00 11,357 11,400 PROD2 DRILL DRLG P Drilling ahead-start pumping new mud-1.35 bpm,3800psi, BHP 4010, ECD 12.5, ROP 80, CT weight 7K, WOB2K, rate out 1.25 bpm. 05:00 07:45 2.75 11,400 11,515 PROD2 DRILL DRLG P Drilling ahead-new mud around- 1.40 bpm, 3850, BHP 3900, ECD 12.2, ROP 20,WOB 2.4K,Ct weight 6K, rate out 1.33 bpm. 07:45 09:15 1.50 11,515 11,515 PROD2 DRILL WPRT P Wiper trip to window, 36K PUW, MADD pass 11380-11060'. 09:15 10:45 1.50 11,515 11,560 PROD2 DRILL DRLG P Drill ahead, 1.35 BPM in, 1.27 BPM out,4000 CTP,3900 BHP, 12.2 ECD, 2K WOB,8-9K CTW. 10:45 12:15 1.50 11,560 11,560 PROD2 DRILL WPRT P BHAwiper36KPUW 12:15 14:30 2.25 11,560 11,665 PROD2 DRILL DRLG P Drill ahead, 1.35 BPM in, 1.27 BPM out,4000 CTP,3900 BHP, 12.2 ECD, 2K WOB,8-9K CTW. 14:30 16:30 2.00 11,665 11,665 PROD2 DRILL WPRT P Wiper trip to window 16:30 19:00 2.50 11,665 11,815 PROD2 DRILL DRLG P Drill ahead, 1.35 BPM in, 1.27 BPM out,4000 CTP,3900 BHP, 12.2 ECD,2K WOB,8-9K CTW. 19:00 21:00 2.00 11,815 11,815 PROD2 DRILL WPRT P Wiper trip-P/U weight 38K.Tie in-1 ft correction 21:00 23:00 2.00 11,815 11,965 PROD2 DRILL DRLG P Drilling ahead-1.38 bpm,3720, BHP 3900, ECD 12.3, ROP 80,WOB 1.7K, CT weight 6K, rate out 1.30 bpm. 23:00 00:00 1.00 11,965 11,965 PROD2 DRILL WPRT P Wiper trip-P/U weight 36K Page 15 of 22 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05/07/2011 24 hr Summary Continue drilling ahead on AU lateral with RSM&2.73"Bi-center. Having weight transfer issues,pump 5/5 low/high sweeps and wiper trips every 100'instead of 150'.74 bbl losses for 24 hours. 00:00 01:30 1.50 11,965 11,965 PROD2 DRILL WPRT P Wiper trip. Losing roughly 4 to 5 bbls/hour. 01:30 03:30 2.00 11,965 12,100 PROD2 DRILL DRLG P Drilling ahead-1.37bpm,3680, BHP 3950, ECD 12.4, ROP 90,WOB 1.4, CT weight 8K, rate out 1.30 bpm. Drilling depth of 12,090'notice clayballs over shakers in samples. Started to stack weight last 5ft. P/U 40K-broke over for wiper. 03:30 06:00 2.50 12,100 12,100 PROD2 DRILL WPRT P Wiper trip to window-37K-clean wiper. Losing 4 bbls/hour. 06:00 07:30 1.50 12,100 12,193 PROD2 DRILL DRLG P Drill Ahead 1.34 BPM in, 1.26 BPM out,4080 CTP,4000 BHP,7-8K CTW, 1-2K WOB, 12.5 ECD 07:30 07:36 0.10 12,193 12,193 PROD2 DRILL WPRT P Stacking CT surface weight, lose motor work and WOB. PU BHA wiper 40K PUW. 07:36 08:06 0.50 12,193 12,219 PROD2 DRILL DRLG P Drill Ahead 1.34 BPM in, 1.26 BPM out,4100 CTP,4000 BHP,5-6K CTW, 1.5K WOB, 12.5 ECD 08:06 09:36 1.50 12,219 12,219 PROD2 DRILL WPRT P Stacking CTW.41K PUW,CTW breaks back to 34K. Pump low/high vis sweeps. Unable to get back to bottom,stacking. PUH to 11400' wiping through sump in A4 silt. Increase lubes in high vis sweeps 2%776,2%Low Torq. Wiper to 11400'did a lot of good-improved weight transfer and reduced annular pressure by 100 psi. Able to get back to drilling. 09:36 10:15 0.65 12,219 12,265 PROD2 DRILL DRLG P Drill Ahead 10K CTW,3900 CTP, 3950 BHP,90 FPH 10:15 13:00 2.75 12,265 12,265 PROD2 DRILL WPRT P Wiper trip to window,39K PUW, chasing Low/High sweeps Out of OH,Tle in depth to RA marker-4' correction. 13:00 14:45 1.75 12,265 12,365 PROD2 DRILL DRLG P Drill Ahead 10K CTW, 3900 CTP, 3950 BHP, 90 FPH 14:45 17:15 2.50 12,365 12,365 PROD2 DRILL WPRT P Wiper trip 37K PUW,chasing low/High sweeps. Begin making wiper trips every 100'due to overpulls &trying to packoff. 17:15 19:00 1.75 12,365 12,465 PROD2 DRILL DRLG P Drill Ahead 10K CTW, 3900 CTP, 3950 BHP, 90 FPH, Pump Low/high prior to 100'drilled. 19:00 21:30 2.50 12,465 12,465 PROD2 DRILL WPRT P Wiper trip chasing sweep-P/U weight 36K, Hold 50 psi on choke during wiper to hold recommended MPD. Page 16 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 23:00 1.50 12,465 12,527 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm, 3800, BHP 3990,WHP 0, ECD 12.6, ROP 70, WOB 1.6,CT weight 7K. Pump sweeps @ 12520'-weight stacking. Losing prime, BHA wiper-could not RIH due to weight stacking. P/U 44K, broke over to 36K.Wiper while sweep is coming around. 23:00 00:00 1.00 12,527 12,527 PROD2 DRILL WPRT P Wiper up to 11,200 ft, noticed annular dropped from 3920 to 3800' during wiper. RIH clean @ 14K CT weight. 05/08/2011 Continue to drill AL1 lateral.Mud swap with 1200ft on system. POOH for agitator BHA due to WOB&CT weight transfer.33 bbl losses for 24hours. _ 00:00 00:30 0.50 12,527 12,527 PROD2 DRILL WPRT P Wiper trip from 11,200ft 00:30 02:00 1.50 12,527 12,591 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm, 3700, BHP 4010, ECD 12.6, ROP 80,WOB 1.6, CT weight 8K. Lo-vis sweep at bit @ 12580'.WOB&ROP increase for a brief time and then stacked out. 02:00 05:00 3.00 12,591 12,591 PROD2 DRILL WPRT P Wiper trip 37K P/U&prepare pits for Mud swap.Tie in with-4 ft correction.Mud swap at the end of the wiper with 1200 ft on old system. 05:00 08:00 3.00 12,591 12,737 PROD2 DRILL DRLG P Drilling ahead-new mud at bit-1.40 bpm, 3880, BHP 4030, ECD 12.5, ROP 88,WOB 1K, CT weight 6K. 08:00 11:15 3.25 12,737 12,737 PROD2 DRILL WPRT P Wiper trip to window 41K PUW 11:15 11:45 0.50 12,737 12,760 PROD2 DRILL DRLG P Drilling ahead-new mud at bit-1.40 bpm, 3880, BHP 4030, ECD 12.5, ROP 88,WOB 1K,CT weight 6K. 11:45 12:15 0.50 12,760 12,760 PROD2 DRILL WPRT P Stacking, PU Pump low/high sweeps. 12:15 12:45 0.50 12,760 12,781 PROD2 DRILL DRLG P Drill Ahead,2-3K CTW,Stacking 12:45 13:15 0.50 12,781 12,781 PROD2 DRILL WPRT P PU,40K, BHA wiper,Sweeps at bit. RIH to drill 13:15 13:24 0.15 12,781 12,791 PROD2 DRILL DRLG P Drill Ahead, Ribs off on RSM to get drilling, 1.4 in, 1.3 out, 1K WOB,6K CTW, 3380 CTP,3980 BHP 13:24 13:33 0.15 12,791 12,791 PROD2 DRILL WPRT P Stacking PUH,41K. Building Low sweeps 13:33 14:48 1.25 12,791 12,870 PROD2 DRILL DRLG P Drill ahead,3K CTW,3897 CTP, 3960 BHP 14:48 19:30 4.70 12,870 12,870 PROD2 DRILL WPRT P Stacking, PU,41K PUW. POOH to PU agitator 19:30 21:30 2.00 12,870 68 PROD2 DRILL PULD P PJSM-undeploy RSM BHA#16 Page 17 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 23:30 2.00 0 78 PROD2 DRILL PULD P Pressure deploy BHA#17 with 2-1/8" agitator&2.73"Bi-center.Apply 900 psi prior to opening the rams, and observed an increase in injector weight to 22K(pipe tension). BHA still communicating but decision to Undeploy BHA to change EDC. Injector 1/4"gap is noticed below the pack off-connecting to the riser. Note:Appears that there was some kind of movement in the stripper/Bowen connection. Applying WH pressure(900 psi)was acting upon the stripper to put the BHA in tension. 23:30 00:00 0.50 78 0 PROD2 DRILL PULD T PJSM-Undeploy BHA& troubleshoot 1/4"gap under pack-off assembly. ***0.5 hour billable rig repair rate*** 05/09/2011 Deploy BHA#18 with agitator&2.73"bi-center bit. Had downtime with injector risers&weight transfer at surface. RIH&TD AU lateral @ 13,180ft. Pull wiper to swab valves.80 bbls lost to formation 24/hours. 00:00 01:00 1.00 0 0 PROD2 DRILL PULD T Undeploy BHA to replace EDC& inspect 1/4"gap below pack-off assembly.lay BHA down out of the way. 01:00 03:30 2.50 0 0 PROD2 DRILL RGRP T Screw the threads back up into the pack off assembly. Inspect CT& pack off rubbers.Stab on well&test. Move injector back to run&test. 03:30 06:00 2.50 0 78 PROD2 DRILL PULD T Deploy BHA#18 with 2 1/8" agitator, 0.8 deg Xtreme motor& 2.73"bi-center. Injector back on well, zero weight indicator&tighten bottom 7"riser bowen above annular. Weights look better. ***6 hour billable rig repair rate*** 06:00 09:00 3.00 78 10,000 PROD2 DRILL TRIP P RIH 09:00 09:06 0.10 10,000 10,000 PROD2 DRILL DLOG P Tie in depth with gamma,+10' correction 09:06 10:36 1.50 10,000 12,870 PROD2 DRILL TRIP P RIH to drill 10:36 13:36 3.00 12,870 13,030 PROD2 DRILL DRLG P Drill Ahead 1.3 in, 1.2 out, 3940 CTP,4000 BHP, 50-70 FPH,5-8K CTW 13:36 17:06 3.50 13,030 13,030 PROD2 DRILL WPRT P Chase low/high sweeps back to window 17:06 20:36 3.50 13,030 13,180 PROD2 DRILL DRLG P Drill Ahead 1.3 in, 1.2 out, 3940 CTP,4000 BHP,50-70 FPH,5-8K CTW. Pump low/high sweep on bottom. TD lateral at 13,180'. 20:36 00:00 3.40 13,180 8,000 PROD2 DRILL WPRT P Wiper trip P/U weight 39K.pump second sweep at window to flush cased hole while tripping to swab valves. Page 18 of 22 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05/10/2011 24 hr summary Wiper trip to swab valves, Lay in beaded liner running pill, lay in KWF to surface. BHA pulled off coil at surface.Start BHA recovery ops 00:00 02:00 2.00 8,000 68 PROD2 DRILL TRIP P Trip to swab valves to clean out cased hole, light to med cuttings while POOH.Open EDC at surface. No significant cuttings at surface. 02:00 06:00 4.00 68 13,180 PROD2 DRILL TRIP P Reset counters-RIH following MPD pumping 1.2 bpm through EDC.Tie in+8.5 ft.Close EDC-RIH 06:00 11:00 5.00 13,180 0 PROD2 DRILL DISP P POOH laying in Liner running pill, and 12.0 ppg NaBr KWF to surface 11:00 14:00 3.00 0 0 PROD2 DRILL RGRP T While tagging up at surface the injector applied—85K pounds of pull to the coiled tubing and pulled the coil connector out of the pipe. The driller did not recognize that the BHA had been lost and continued pulling OOH, pulling the coiled tubing out of the injector chains. Secure CT, RD injector. **"Start nabors downtime,first 5.5 hours are billable, next 7.5 hours are non-billable*** 14:00 16:00 2.00 0 0 PROD2 DRILL SLKL T Slick line crew on location. PJSM for RU,spot equipment. Rig crew remove Pack offs&stuffing box 16:00 18:30 2.50 0 0 PROD2 DRILL SLKL T R/U Slick Line. Hold additional PJSMs with incoming night crew 18:30 19:30 1.00 0 0 PROD2 DRILL SLKL T PJSM-P/T S/L Lubricator 19:30 22:45 3.25 0 10,114 PROD2 DRILL SLKL T RIH with 3 1/2 GR spear pulling tool, 3 1/2 Bait sub, overshot with 1.55 grapple,Set down and jar down @ 10114'SLM PUH and oil jars fired @ 10086, PUW=1450 after engaging _ fish.700Lbs before, POOH 22:45 23:09 0.40 10,114 0 PROD2 DRILL SLKL T PJSM while flow checking well. Pull S/L lubricator and catch fish in C-Plate Stand back slick line equipment 23:09 00:00 0.85 0 0 PROD2 DRILL PULD T Lay down BHA#18.All tools recovered except upper E-Line anchor mandrel(2"long x 0.75" diameter) 05/11/2011 Recovered all BHA componets except for e-line anchor in Upper Quick Connect. Replace injector skates, Fish for E-Line anchor with slickline.Test repairs to injector 00:00 00:30 0.50 0 0 PROD2 DRILL PULD T Complete Blow down/lay down BHA #18 ***Continue nabors downtime,24 hours of non-billable rig repair time*** 00:30 12:30 12.00 0 0 PROD2 DRILL RGRP T Begin injector skate R&R 12:30 14:54 2.40 0 0 PROD2 DRILL RGRP T Injector repairs completed, restab CT Page 19 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:54 15:12 0.30 0 0 PROD2 DRILL SFTY T PJSM,slickline operations 15:12 16:18 1.10 0 0 PROD2 DRILL SLKL T MIRU Haliburton slickline 16:18 16:36 0.30 0 0 PROD2 DRILL SLKL T Function test BOP rams. Check for fish on top of closed swab valve, no luck 16:36 19:36 3.00 0 10,160 PROD2 DRILL SLKL T PT lubricator, RIH with 2.60 magnet, Recip through all GLM 19:36 20:06 0.50 10,160 0 PROD2 DRILL SLKL T At surface, No fish on magnet. reconfig magnet to double knuckle to allow magnet to get into belly down GLM's 20:06 21:36 1.50 0 3,000 PROD2 DRILL SLKL T PT lubricator, RIH. Get down to 3000', unable to continue in hole, POOH to repack stuffing box 21:36 22:36 1.00 3,000 0 PROD2 DRILL SLKL T At surface replace slick line packing, 22:36 00:00 1.40 0 7,000 PROD2 DRILL SLKL T PT Lubricator, RIH with double knuckle 2.6"magnet 05/12/2011 Run magnet on slickline to recover E-Line Anchor, No Fish after two runs. Perform slack management,M/U BHA#19 FCO and RIH 00:00 01:30 1.50 7,000 10,160 PROD2 DRILL SLKL T Continue to run double knuckle 2.60" magnet to 10160', POOH ***Continue nabors downtime,3 hours of non-billable rig repair time*** 01:30 01:54 0.40 10,160 0 PROD2 DRILL SLKL T Slickline at surface, No fish on magnets 01:54 03:00 1.10 0 0 PROD2 DRILL SLKL T Rig down Slickline unit 03:00 04:15 1.25 0 0 PROD2 DRILL SLPC P PJSM-Prep for slack mgmt,test wire-good test,boot wire,stab on ***Nabors back on regular rig rates*** 04:15 05:15 1.00 0 0 PROD2 DRILL SLPC P Circ coil to water, Unstab and ensure wire is up in coil, line up and reverse circ coil 05:15 08:03 2.80 0 0 PROD2 DRILL SLPC P Reverse circulate to pump slack,cut coil to find wire.Cut 98'(+22'cut previously=-120'entered in cerberus) 08:03 10:48 2.75 0 0 PROD2 DRILL SLPC P Test e-line. Install CTC and pull test. 10:48 11:48 1.00 0 0 PROD2 DRILL SFTY P Safety meeting to discuss recent incidents. 11:48 13:18 1.50 0 0 PROD2 DRILL CIRC P PT CTC and UQC,circulate coil back to KWF 13:18 15:00 1.70 0 0 PROD2 DRILL PULD T MU FCO assembly with 0.8 deg. motor and 2.74"D331 mill 15:00 17:30 2.50 0 5,356 PROD2 DRILL TRIP T RIH with FCO assembly 17:30 19:00 1.50 5,356 5,356 PROD2 DRILL SFTY P Hold 2010 end-of-year results meeting with Dan Venhaus with day and night crews. Pre-tower meeting in Dog house with incoming night crew 19:00 20:00 1.00 5,356 9,985 PROD2 DRILL TRIP T Continue trip in well Page 20 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:06 0.10 9,985 10,011 PROD2 DRILL DLOG T Log gamma tie in for+16.5' correction 20:06 22:21 2.25 10,011 10,000 PROD2 DRILL CIRC T PUH and circulate well to 8.6 ppg Flopro mud. Lost 15 bbl of 12.0 ppg KWF during recovery. 22:21 00:00 1.65 10,000 12,807 PROD2 DRILL FCO T RIH for FCO, Good pass through window No problem past billet @ 11054 Midnight Depth 12807 05/13/2011 Run FCO BHA to TD, Pump sweeps,condition hole, Lay in beaded liner pill/KWF while tripping out. M/U and run lower liner section to 13180' 00:00 00:15 0.25 12,807 13,177 PROD2 DRILL FCO T Continue running to bottom 00:15 02:39 2.40 13,177 10,190 PROD2 DRILL FCO T Clean run to bottom @ 13177. Sweeps at mill, Chase to window PUW=46K. Had slight overpull @ 10,546' 02:39 02:45 0.10 10,190 10,206 PROD2 DRILL DLOG T Log RA marker for no correction 02:45 04:15 1.50 10,206 13,168 PROD2 DRILL FCO T Run back to bottom,clean trip. hole looks good 04:15 08:42 4.45 13,168 0 PROD2 DRILL TRIP T POOH laying in beaded liner pill followed by KWF. Paint EOP Flags @ 10,900 and 7900 08:42 08:54 0.20 0 0 PROD2 DRILL SFTY P PJSM 08:54 10:06 1.20 0 0 PROD2 DRILL PULD P Lay down BHA 10:06 11:54 1.80 0 0 COMPZ CASING PUTB P Rig up floor for liner operations. Start PU liner string 11:54 12:24 0.50 0 0 COMPZ CASING SFTY P Crew change out, PJSM 12:24 15:12 2.80 0 2,125 COMPZ CASING PUTB P Continue PU liner string,63 Joints slotted liner. 15:12 16:54 1.70 2,125 2,125 COMPZ CASING PULD P MU coiltrac tools and injector. While MU quick connect on coiltrac tools a lower connection backed off. Move injector, pull coiltrac tools up and re-torque connections. 16:54 19:24 2.50 2,125 9,898 COMPZ CASING RUNL P RIH with liner 19:24 20:00 0.60 9,898 9,898 COMPZ CASING SVRG P Stop and test/troubleshoot injector brakes 20:00 20:30 0.50 9,898 10,009 COMPZ CASING RUNL P RIH to flag depth, Make +16.1' correction 20:30 22:15 1.75 10,009 13,181 COMPZ CASING RUNL P Continue running liner to bottom @ 13181,set down 2500 Lbs. PUW=35K, Pump off deployment sleeve, POOH. 22:15 22:30 0.25 13,181 10,192 COMPZ CASING DLOG P Remove Liner length left in hole, -2081.23,tie into RA marker for a -1.5'correction, BOL=13180',TOL lower section=11098.7 Page 21 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 10,192 5,400 COMPZ CASING TRIP P POOH, Keeping hole full across the top, Paint EOP flags @ 9000& 10000 Midnight depth 5400' 05/14/2011 Complet running liner, F/P well, RDMO, Rig Release 20:00 00:00 01:30 1.50 5,400 140 COMPZ CASING TRIP P Continue tripping out of well 01:30 01:36 0.10 140 78 COMPZ CASING TRIP P PJSM, Raise injector,bring CTC to surface 01:36 01:54 0.30 78 0 COMPZ CASING PULD P Lay down BHA#20 AL1 Lower liner section running tools 01:54 04:54 3.00 0 0 COMPZ CASING PUTB P PJSM, P/U AU Liner Upper section 04:54 05:54 1.00 0 0 COMPZ CASING PULD P PJSM, P/U Coil track,M/U to liner 05:54 06:18 0.40 0 1,078 COMPZ CASING SFTY P Crew change and PJSM 06:18 09:54 3.60 1,078 11,100 COMPZ CASING RUNL P RIH, correct to EOP flag, +14.4'. Weight check, 37K PUW(-6K WOB). Continue RIH. Set liner and PUH to log K1. Liner top at 10064'. 09:54 11:00 1.10 11,100 10,000 DEMOB WELLPF DISP P Displace KWF with SW 11:00 13:18 2.30 10,000 0 DEMOB WELLPF FRZP P POOH. FP from 2500'with diesel. 13:18 14:06 0.80 0 0 DEMOB WELLPF PULD P Lay down liner running BHA 14:06 15:36 1.50 0 0 DEMOB WHDBO NUND P Set BPV 15:36 17:06 1.50 0 0 DEMOB WHDBO DMOB P Blow down coil and surface lines 17:06 20:00 2.90 0 DEMOB WHDBO DMOB P Nipple down, rig down, move out ***Rig Release 20:00****** Page 22 of 22 2K-19A Well Summary DATE SUMMARY 5/17/11 GAUGED TBG TO 2.75" TO LINER ,JP @ 10065' RKB. IN PROGRESS. 5/18/11 MEASURED BHP @ 10000' RKB: 3509 PSI. SET CATCHER @ 10065' RKB. PULLED DV @ 9298', SET OV @ 9298' RKB. IN PROGRESS. 5/19/11 PULLED DVs @ 8576', 7833', 7061', 5529' RKB. SET GLVs @ 8576', 7833', 7061' RKB. IN PROGRESS. 5/20/11 PULLED DV @ 2674' RKB. SET GLVs @ 5529', 2674' RKB. PULLED CATCHER @ 10065' RKB. COMPLETE. Letter of Transmittal BAKER Date: May 16, 2011 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): 2K-19A 2K-19AL1 (2) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files SEC d Roy 1 8 2fl1t. Alaska OI&Geg Cow COMIliSSION Amway Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes Operations Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes Survey Manager Carl.Ulrich@BakerHughes.com 00I o3 -- s [E Cm a SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS333333 W.7th AVENUE,SUITE 100 CONSERVATION CO IIIISSIO1 ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager Q � ConocoPhillips Alaska, Inc. I l P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-19AL1 ConocoPhillips Alaska, Inc. Permit No: 211-035 (revised) Surface Location: 219' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 1198' FSL, 1167' FWL, SEC. 10, T1ON, R8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 2K-19A, Permit No 211- 034, API 50-103-20118-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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, 0 / Daniel T. Seamount, Jr. _ A Chair DATED this 'S day of May, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips (a. Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 2, 2011 RECEIVED Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission MAY 92 'al', 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil&Gas Cent.Gornmjssjon knCjt®r&ge Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a revised version of the Permit to Drill (PTD) application for the Kuparuk 2K-19AL1 lateral (PTD#211-035).'Verbal approval for continued drilling operations on this lateral was granted by the AOGCC on April 29, 2011. The revision to the PTD is needed because the 2K-19AL1 lateral had to be kicked off more than 500' away from the original proposed depth due to geologic complexity while drilling . the 2K-19A motherbore. The geologic objective of 2K-19AL1 is unchanged, as is the anticipated formation pressure, assessment of drilling risks, distance to offset wells and unit boundaries, BOPE configuration, etc. ,, Attached to this application are the following documents that explain the proposed job operations: — Revised Permit to Drill Application Form for 2K-19AL1 — Proposed Wellbore Schematic — Directional Plan — Copy of e-mail of 4/29/11 authorizing continued drilling operations If you have any questions or require additional information please contact me at my office 907-263-4172. Si cerely, Gary Eller ConocoPhi Alaska Coiled Tubing Drilling Engineer E� STATE OF ALASKA ECE1VED \� ALASKA OIL AND GAS CONSERVATION COMMISSION � 4,AY `' . 1)1 PERMIT TO DRILL `' x 20 AAC 25.005 �� �p cons. ,i1 i�11SS�0A la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single ZonI4'1c.Specifry if wel i p osed for: C`,�� d Drill ❑ Re-drill❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed GasC Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ 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 • 2K-19AL1 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 13137' . TVD: 6118' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:219'FNL,94'FEL,Sec. 11,T1 ON,R8E, UM - ADL 25588,25589• Kuparuk River Oil Pool , Top of Productive Horizon: 8.Land Use Permit: '13.Approximate Spud Date: 1430'FSL, 1919'FWL,Sec. 10,T10N, R8E, UM 2674,2675 5/3/2011 Total Depth: 9.Acres in Property: 14.Distance to 1198'FSL, 1167'FWL,Sec. 10,T10N, R8E, UM 2560 Nearest Property: 11400 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:/.,-1h/feet 15.Distance to Nearest Well Open Surface:x- 498310 y- 5938085' Zone- 4 GL Elevation above MSL://f/I f et y Io Same Pool: 2K-27,2100' 16.Deviated wells: Kickoff depth: 11055 ft. 17.Maximum Anticipated Pressures i�i� p p psig(see 20 AAC 25.035) Maximum Hole Angle: 100° deg. Downhole:4078 psig Surface:3512 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2.375" 4.7# L-80 ST-L 3077' 10060' 6210' 13137' 6118' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 10659' 6576' 10500' 6474' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 170 sx AS II 115' 115' Surface 3754' 9.625" 1200 sx AS III,450 sx Class G 3789' 2898' Intermediate Production 10524' 7" 450 sx Class G 10557' 6508' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 10169'-10189', 10210'-10250' 6259'-6271',6285'-6309' 20.Attachments: Property Plat❑ BOP Sketch 10 Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Guy Schwartz Date:4/29/2011 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 \it_ Printed Na V. Cawvey Title Alaska Wells Manager Signature �, Phon 265-6306 Date 572/ / z6) Commission Use Only Permit to Drill API umber: Permit Apprqtval See cover letter r: ,27/(\34 , Number /'\F-' : 7r 3"� -//��j- 1-e _,Date: 3 10 II for other requirements Conditions of approval: If box is checked,wellmaynot be used to explore for,test,or produce coalbed metha e,gas hydrates,or gas contained in shales: ,. f500/As,:/As,: /Joe k.3•� Samples req'd: Yes 0/No 1-- Mud log req'd: Yes ❑ No [7I Other: i"Z s—ao pS� Alin"4.4- /e y 12S measures: Yes [+'J No 0 Directional svy req'd: Yes 2( No ❑ Fr (om) Ai glirS / 5 /// 1 / DATE: / � APPROVED BY THE COMMISSION ��� ` Aetf2pproval ,COMMISSIONER Form 0-401 (Revised 7/2009) This permit is valid fdr L► nC 20 AAC 25.005(g)) Sub it in Duplicate't�.AP `.� r S'Y•/( rn / J 't Allsup-Drake, Sharon K From: Schwartz, Guy L(DOA)[guy.schwartz@alaska.gov] Sent: Friday,April 29, 2011 10:00 AM To: Eller, J Gary Cc: Gantt, Lamar L Subject: RE:Approval to Change KOP in 2K-19AL1 (211-035) Gary, Per our conversation, please submit a revised PTD application for 2K-19AL1 (PTD 211-035). You have verbal approval to proceed with 2K-19AL1 as we discussed and is outlined below. The new well trajectory will include the new proposed kickoff point at 11055'and the"possible" new BHL target if you think you can replace AL2 lateral. Please get the revised to the Commission by Monday(next working day)as stated in 20 AAC 25.005(a) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller,3 Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Friday,April 29, 2011 9:20 AM To: Schwartz,Guy L(DOA) Cc: Gantt, Lamar L Subject: Approval to Change KOP in 2K-19AL1 (21-035) Guy—Good morning. As we discussed earlier, I'd like to change the planned KOP of the 2K-19AL1 lateral (211-035) in order to better contact the Kuparuk A4 pay. We want to move our KOP to 11,055' MD instead of the original plan of 12,350' MD. Proposed TD would remain unchanged. As is common with these Kuparuk CTD laterals,the map view will be practically identical to what was previously proposed— we should remain within 100'of the original approved well plan. The attached slides perhaps better show what I'm describing. The first slide shows a geologic cross- section for the 2K-19A sidetrack plus the AL1 and AL2 laterals in dashed lines. The second slide shows our current geologic interpretation and well status. By moving the AL1 kickoff point to 11,055' MD,we pick up a significant amount of A4 pay that was missed with the'A'sidetrack. It's possible (but not at all certain)that we can meet our geologic objectives with this AL1 lateral such that we won't need to drill the AL2 lateral, but that remains to be seen. I think the bottom line is whether we can amend the 2K-19AL1 KOP via verbal approval or whether a new PTD is needed. If a new PTD is required,then we'll need AOGCC authorization to continue uninterrupted drilling operations over the weekend until I can provide you with a written PTD. Please call if we need to discuss any of this. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 5/2/2011 ORtGINAL sk < J \ \kV% h � . Cr— 1, � 3 A i II T Z l6 N a N "ClM 1 N I- 1n M Jfh V r- 0 0 N 0 h— M c n (V p m c OK a .n ° c M II ,n o E U m "' c5 to Q11 0 rx as N © v Q IIti i v Y O- Q MCC U -L v o Q- C/ mcowY (0 ; E p ce Q o II aN `' 'E \ Q al Ol CO y.+ Y p 0 H o 2 n. N W v: -c o I o m x Z dX NN . W ,a U + + O� _, � _O \ N N N-0 N N zN m2 °' YY N W a� N R N N D ch M M p m co 0"1 M LL p O K U * g Q 0O o / a 0 0. O p 1 �� - I O Y V •os� I. Lo •en ORIGINAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19AL1 Plan: 2K-19AL1_wp04 Standard Planning Report 29 April, 2011 viuI BAKER HUGHES II O ! G1N/LL r' t ConocoPhillips IT/,1- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature . Wellbore: 2K-19AL1 Design: 2K-19AL1_wp04 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 2K Pad Site Position: Northing: 5,938,600.18 ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-19 Well Position +NI-S 0.00 ft Northing: 5,938,085.20 ft Latitude: 70°14'31.454 N +EI-W 0.00 ft Easting: 498,310.27 ft Longitude: 150°0'49.127 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118.50ft Wellbore 2K-19AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength F (0) (°) (nT) BGGM2010 4/15/2011 16.64 79.76 57,334 I Design 2K-19AL1_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,040.56 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -118.50 0.00 0.00 260.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (°/100ft) (°/1OOft) (°/100ft) (°) Target 11,040.56 92.95 280.89 6,149.62 -3,487.34 -7,252.90 0.00 0.00 0.00 0.00 11,055.00 92.48 279.41 6,148.94 -3,484.80 -7,267.10 10.74 -3.25 -10.25 -107.60 11,135.00 83.46 282.70 6,151.77 -3,469.49 -7,345.47 12.00 -11.28 4.11 160.00 11,235.00 83.60 270.62 6,163.08 -3,457.99 -7,443.98 12.00 0.14 -12.08 270.00 11,355.00 91.94 258.86 6,167.76 -3,468.98 -7,563.06 12.00 6.95 -9.80 305.00 11,425.00 92.90 253.34 6,164.80 -3,485.77 -7,630.93 8.00 1.37 -7.89 280.00 11,545.00 99.64 257.29 6,151.69 -3,516.01 -7,746.21 6.50 5.62 3.29 30.00 1 11,805.00 89.76 257.29 6,130.39 -3,572.95 -7,998.68 3.80 -3.80 0.00 180.00 12,055.00 91.58 264.57 6,127.47 -3,612.34 -8,245.35 3.00 0.72 2.91 76.00 12,395.00 91.56 257.77 6,118.14 -3,664.50 -8,581.00 2.00 0.00 -2.00 270.00 12,531.40 90.00 260.00 6,116.27 -3,690.80 -8,714.81 2.00 -1.15 1.64 124.98 13,137.00 89.69 247.89 6,117.94 -3,857.96 -9,295.71 2.00 -0.05 -2.00 268.50 4/29/2011 5:07.23PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL Iv" ConocoPhillips Fait ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19;@ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL1 Design: 2K-19AL1_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 11,040.56 92.95 280.89 6,149.62 -3,487.34 -7,252.90 7,748.28 0.00 0.00 5,934,599.83 491,057.32 TIP 11,055.00 92.48 279.41 6,148.94 -3,484.80 -7,267.10 7,761.82 10.74 -107.60 5,934,602.38 491,043.12 KOP 11,100.00 87.41 281.26 6,148.99 -3,476.73 -7,311.35 7,804.00 12.00 160.00 5,934,610.45 490,998.87 11,135.00 83.46 282.70 6,151.77 -3,469.49 -7,345.47 7,836.35 12.00 160.00 5,934,617.70 490,964.76 3 11,200.00 83.52 274.85 6,159.15 -3,459.65 -7,409.24 7,897.44 12.00 -90.00 5,934,627.56 490,900.99 11,235.00 83.60 270.62 6,163.08 -3,457.99 -7,443.98 7,931.36 12.00 -89.11 5,934,629.23 490,866.26 4 11,300.00 88.11 264.24 6,167.78 -3,460.90 -7,508.69 7,995.60 12.00 -55.00 5,934,626.33 490,801.56 11,355.00 91.94 258.86 6,167.76 -3,468.98 -7,563.06 8,050.54 12.00 -54.54 5,934,618.26 490,747.19 End of 12DLS 11,400.00 92.56 255.32 6,165.99 -3,479.02 -7,606.88 8,095.44 8.00 -80.00 5,934,608.23 490,703.37 11,425.00 92.90 253.34 6,164.80 -3,485.77 -7,630.93 8,120.29 8.00 -80.14 5,934,601.49 490,679.33 Ribsteer 11,500.00 97.12 255.80 6,158.25 -3,505.65 -7,702.92 8,194.65 6.50 30.00 5,934,581.63 490,607.33 11,545.00 99.64 257.29 6,151.69 -3,516.01 -7,746.21 8,239.08 6.50 30.21 5,934,571.28 490,564.04 7 11,600.00 97.55 257.29 6,143.47 -3,527.97 -7,799.26 8,293.40 3.80 -180.00 5,934,559.33 490,511.00 11,700.00 93.75 257.29 6,133.62 -3,549.86 -7,896.32 8,392.78 3.80 -180.00 5,934,537.46 490,413.95 11,800.00 89.95 257.29 6,130.38 -3,571.85 -7,993.80 8,492.60 3.80 -180.00 5,934,515.50 490,316.47 11,805.00 89.76 257.29 6,130.39 -3,572.95 -7,998.68 8,497.59 3.80 -180.00 5,934,514.40 490,311.59 8 11,900.00 90.45 260.05 6,130.21 -3,591.61 -8,091.81 8,592.56 3.00 76.00 5,934,495.76 490,218.46 12,000.00 91.18 262.97 6,128.79 -3,606.37 -8,190.70 8,692.50 3.00 76.01 5,934,481.02 490,119.58 12,055.00 91.58 264.57 6,127.47 -3,612.34 -8,245.35 8,747.37 3.00 76.05 5,934,475.07 490,064.93 9 12,100.00 91.58 263.67 6,126.23 -3,616.95 -8,290.10 8,792.23 2.00 -90.00 5,934,470.47 490,020.19 12,200.00 91.57 261.67 6,123.48 -3,629.71 -8,389.24 8,892.08 2.00 -90.02 5,934,457.73 489,921.06 12,300.00 91.57 259.67 6,120.74 -3,645.92 -8,487.87 8,992.03 2.00 -90.08 5,934,441.54 489,822.43 12,395.00 91.56 257.77 6,118.14 -3,664.50 -8,581.00 9,086.97 2.00 -90.13 5,934,422.99 489,729.31 10 12,400.00 91.51 257.85 6,118.00 -3,665.56 -8,585.88 9,091.96 2.00 124.98 5,934,421.93 489,724.42 12,500.00 90.36 259.49 6,116.37 -3,685.21 -8,683.92 9,191.92 2.00 124.98 5,934,402.31 489,626.40 12,531.40 90.00 260.00 6,116.27 -3,690.80 -8,714.81 9,223.31 2.00 125.01 5,934,396.72 489,595.50 11 12,600.00 89.96 258.63 6,116.30 -3,703.52 -8,782.22 9,291.91 2.00 -91.50 5,934,384.02 489,528.10 12,700.00 89.91 256.63 6,116.40 -3,724.94 -8,879.90 9,391.82 2.00 -91.50 5,934,362.62 489,430.43 12,800.00 89.86 254.63 6,116.60 -3,749.76 -8,976.76 9,491.52 2.00 -91.50 5,934,337.83 489,333.57 12,900.00 89.81 252.63 6,116.89 -3,777.94 -9,072.70 9,590.90 2.00 -91.49 5,934,309.67 489,237.63 13,000.00 89.76 250.63 6,117.28 -3,809.46 -9,167.60 9,689.83 2.00 -91.49 5,934,278.18 489,142.73 13,100.00 89.70 248.63 6,117.75 -3,844.26 -9,261.34 9,788.19 2.00 -91.48 5,934,243.40 489,048.99 13,137.00 89.69 247.89 6,117.94 - -3,857.96 -9,295.71 9,824.42 2.00 -91.47 5,934,229.71 489,014.62 TD 4/29/2011 5:0723PM Page 3 COMPASS 2003.16 Build 69 ORG ! NAL ConocoPhillips 'r ConocoPhillips Planning Report BAI Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. -JVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL1 Design: 2K-19AL1 wp04 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-19A Polygon 0.00 0.00 0.00 -3,476.86 -6,478.13 5,934,610.14 491,832.00 70°13'57.232 N 150°3'57.366 W -plan misses target center by 6198.25ft at 11040.56ft MD(6149.62 TVD,-3487.34 N,-7252.90 E) -Polygon Point 1 0.00 -3,476.86 -6,478.13 5,934,610.14 491,832.00 Point 2 0.00 -3,634.84 -6,350.07 5,934,452.15 491,960.02 Point 3 0.00 -3,727.89 -6,512.06 5,934,359.14 491,798.02 Point4 0.00 -3,668.98 -6,838.11 5,934,418.12 491,472.02 Point 5 0.00 -3,551.16 -7,528.21 5,934,536.08 490,782.01 Point 6 0.00 -3,738.46 -8,559.27 5,934,349.03 489,751.01 Point 7 0.00 -3,743.58 -8,983.31 5,934,344.01 489,327.01 Point 8 0.00 -3,570.71 -9,526.41 5,934,516.98 488,784.01 Point 9 0.00 -3,378.68 -9,482.46 5,934,708.98 488,828.00 Point 10 0.00 -3,526.53 -8,880.36 5,934,561.01 489,430.00 Point 11 0.00 -3,467.33 -8,199.30 5,934,620.06 490,111.01 Point 12 0.00 -3,329.16 -7,632.29 5,934,758.08 490,677.99 Point 13 0.00 -3,476.86 -6,478.13 5,934,610.14 491,832.00 2K-19AL1 T5 0.00 0.00 6,117.00 -3,598.32 -8,666.38 5,934,489.18 489,643.95 70°13'56.015 N 150°5 0.947 W -plan misses target center by 82.07ft at 12465.73ft MD(6116.71 TVD,-3678.79 N,-8650.25 E) -Point 2K-19AL1 Polygon 0.00 0.00 0.00 -3,506.30 -8,604.40 5,934,581.18 489,705.95 70°13'56.921 N 150°4'59.149 W -plan misses target center by 6119.38ft at 12486.58ft MD(6116.48 TVD,-3682.73 N,-8670.72 E) -Polygon Point 1 0.00 -3,506.30 -8,604.40 5,934,581.18 489,705.95 Point 2 0.00 -3,728.29 -8,480.33 5,934,359.18 489,829.96 Point 3 0.00 -3,916.43 -8,919.32 5,934,171.16 489,390.97 Point4 0.00 -3,955.55 -9,334.35 5,934,132.13 488,975.97 Point 5 0.00 -3,689.53 -9,373.43 5,934,398.14 488,936.95 Point 6 0.00 -3,506.30 -8,604.40 5,934,581.18 489,705.95 2K-19AL1 T3 0.00 0.00 6,142.00 -3,464.14 -7,818.31 5,934,623.16 490,491.97 70°13'57.344 N 150°4'36.308 W -plan misses target center by 66.47ft at 11604.66ft MD(6142.86 TVD,-3528.99 N,-7803.76 E) -Point 2K-19AL1 T2 0.00 0.00 6,166.00 -3,486.09 -7,605.27 5,934,601.16 490,704.97 70°13'57.130 N 150°4'30.118 W -plan misses target center by 7.25ft at 11400.36ft MD(6165.97 ND,-3479.11 N,-7607.23 E) -Point 2K-19AL1 T4 0.00 0.00 6,130.00 -3,538.20 -8,074.32 5,934,549.17 490,235.96 70°13'56.613 N 150°4'43.745 W -plan misses target center by 49.41ft at 11872.35ft MD(6130.38 ND,-3586.65 N,-8064.62 E) -Point 2K-19AL1 T1 0.00 0.00 6,165.00 -3,488.06 -7,458.26 5,934,599.16 490,851.98 70°13'57.112 N 150°4'25.845 W -plan misses target center by 30.07ft at 11250.73ft MD(6164.68 ND,-3458.03 N,-7459.62 E) -Point 2K-19AL1 T6 0.00 0.00 6,118.00 -3,848.47 -9,296.41 5,934,239.20 489,013.93 70°13'53.548 N 150°5'19.245 W -plan misses target center by 9.06ft at 13134.14ft MD(6117.93 ND,-3856.89 N,-9293.06 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,789.00 2,758.29 9 5/8" 9-5/8 12-1/4 13,137.00 6,117.94 2-3/8" 2-3/8 3 4/29/2011 5:07:23PM Page 4 COMPASS 2003.16 Build 69 ORtGINAL �.' ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL1 Design: 2K-19AL1_wp04 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/-W (ft) (ft) (ft) (ft) Comment 11,040.56 6,149.62 -3,487.34 -7,252.90 TIP 11,055.00 6,148.94 -3,484.80 -7,267.10 KOP 11,135.00 6,151.77 -3,469.49 -7,345.47 3 11,235.00 6,163.08 -3,457.99 -7,443.98 4 11,355.00 6,167.76 -3,468.98 -7,563.06 End of 12DLS 11,425.00 6,164.80 -3,485.77 -7,630.93 Ribsteer 11,545.00 6,151.69 -3,516.01 -7,746.21 7 11,805.00 6,130.39 -3,572.95 -7,998.68 8 12,055.00 6,127.47 -3,612.34 -8,245.35 9 12,395.00 6,118.14 -3,664.50 -8,581.00 10 12,531.40 6,116.27 -3,690.80 -8,714.81 11 13,137.00 6,117.94 -3,857.96 -9,295.71 TD 4/2912011 5:07.23PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL Conoco Phillips ConocoPhiiii iiiips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19AL1 2K-19AL1_wp04 Travelling 1i��w���uylinder Report 29 April, 2011 1r BAKER FIUGHIES ORIGINAL .... ConocoPhillips 13".illConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-19 Project: Kuparuk River Unit TVD Reference: 2K-19 @ 154.00ft(Nordic 1) Reference Site: Kuparuk 2K Pad MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site Error: 0.00ft North Reference: True Reference Well: 2K-19 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-19AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-19AL1_wp04 Offset TVD Reference: Offset Datum Reference 2K-19AL1_wp04 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 11,040.56 to 13,137.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,510.15ft Error Surface: Elliptical Conic Survey Tool Program Date 4/29/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 40.00 10,160.00 2K-19 GyroData(2K-19) GYD-CT-CMS Gyrodata cont.casing m/s 10,172.00 11,040.56 2K-19A Rig Survey(2K-19A) MWD MWD-Standard 11.040.56 13,137.00 2K-19AL1_wp04(2K-19AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( ) C) 3,789.00 2,912.29 9 5/8" 9-5/8 12-1/4 13,137.00 6,271.94 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 2K Pad 2K-13-2K-13AL1 -2K-13AL1_wp03 Out of range 2K-19-2K-19A-2K-19A 11,050.00 11,050.00 0.00 0.55 -0.39 FAIL-Minor 1/10 2K-27-2K-27-2K-27 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/29/2011 4:39:59PMPage 2 of 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips S/' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-19 Project: Kuparuk River Unit TVD Reference: 2K-19 @ 154.00ft(Nordic 1) Reference Site: Kuparuk 2K Pad MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site Error: 0.00ft North Reference: True Reference Well: 2K-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-19AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-19AL1_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-19-2K-19A-2K-19A Offset Site Error: 0.00ft Survey Program: 40-GYD-CT-CMS,10172-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +e/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) r) (ft) (ft) (ft) (ft) (ft) (ft) 11,050.00 6,303.16 11,050.00 6,303.16 0.09 0.05 82.09 -3,485.64 -7,262.17 0.22 0.00 0.55 -0.39 FAIL-Minor 1/10,CC,ES,S 11,074.98 6,302.47 11,075.00 6,302.19 0.11 0.17 -140.38 -3,481.89 -7,286.87 0.22 0.58 0.77 -0.07 FAIL-Minor l/10 11,099.78 6,302.98 11,100.00 6,301.31 0.17 0.31 -136.35 -3,479.34 -7,311.72 0.22 3.12 0.97 2.30 Pass-Minor 1/10 11,124.15 6,304.65 11,125.00 6,300.73 0.24 0.44 -136.66 -3,478.13 -7,336.68 0.22 7.62 1.14 6.64 Pass-Minor 1/10 11,148.52 6,307.31 11,150.00 6,300.37 0.31 0.58 -138.42 -3,478.21 -7,361.67 0.22 13.76 1.26 12.65 Pass-Minor 1/10 11,173.39 6,310.14 11,175.00 6,299.27 0.38 0.71 -139.40 -3,479.43 -7,386.61 0.22 20.35 1.36 19.15 Pass-Minor 1/10 11,198.49 6,312.98 11,200.00 6,297.88 0.46 0.85 -140.93 -3,482.05 -7,411.44 0.22 27.16 1.41 25.90 Pass-Minor 1/10 11,223.99 6,315.85 11,225.00 6,296.66 0.55 0.99 -143.03 -3,485.71 -7,436.14 0.22 33.65 1.43 32.35 Pass-Minor 1/10 11,250.37 6,318.65 11,250.00 6,296.26 0.64 1.14 -145.13 -3,489.28 -7,460.87 0.22 38.48 1.44 37.17 Pass-Minor 1/10 11,277.52 6,320,73 11,275.00 6,296.63 0.74 1.29 -147.22 -3,491.93 -7,485.73 0.22 40.75 1.45 39.45 Pass-Minor 1/10 11,304.83 6,321,93 11,300.00 6,297.40 0.84 1.44 -148.77 -3,493.30 -7,510.67 0.22 40.33 1.46 39.08Pass-Minor l/10 11,331.79 6,322.22 11,325.00 6,298.50 0.94 1.60 -149.37 -3,493.36 -7,535.65 0.22 37.29 1.46 36.10 Pass-Misr 1/10 11,357.84 6,321.66 11,350.00 6,299.97 1.05 1.76 -148.16 -3,492.04 -7,560.56 0.22 31.70 1.47 30.55 Pass-Minor 1/10 11,382.20 6,320.75 11,375.00 6,301.62 1.15 1.92 -141.86 -3,489.41 -7,585.37 0.22 24.48 1.46 23.26Pass-Minor l/10 11,405.50 6,319.74 11,400.00 6,303.47 1.25 2.09 -124.09 -3,485.65 -7,610.01 0.22 17.22 1.43 15.98 Pass-Minor 1/10 11,427.78 6,318.65 11,425.00 6,305.86 1.34 2.26 -83.57 -3,481.15 -7,634.49 0.22 13.92 1.44 12.61 Pass-Minor 1/10 11,450.03 6,317.23 11,450.00 6,308.86 1.43 2.43 -42.47 -3,476.49 -7,658.86 0.22 18.71 1.44 18.49 Pass-Minor 1/10 11,472.55 6,315.28 11,475.00 6,311.91 1.53 2.61 -22.19 -3,472.33 -7,683.32 0.22 27.49 1.44 27.25 Pass-Minor 1/10 11,495.65 6,312.78 11,500.00 6,314.74 1.63 2.79 -11.24 -3,469.37 -7,707.98 0.22 36.46 1.44 36.19 Pass-Minor 1/10 11,519.19 6,309.69 11,525.00 6,317.00 1.74 2.97 -4.10 -3,467.40 -7,732.80 0.22 44.90 1.43 44.61 Pass-Minor 1/10 11,543.09 6,306.01 11,550.00 6,318.20 1.85 3.16 0.76 -3,465.96 -7,757.73 0.22 52.82 1.41 52.51 Pass-Minor 1/10 11,567.19 6,302.13 11,575.00 6,317.97 1.96 3.34 2.77 -3,464.93 -7,782.70 0.22 60.03 1.39 59.70 Pass-Minor 1/10 11,591.68 6,298.58 11,600.00 6,316.35 2.08 3.53 2.99 -3,464.49 -7,807.64 0.22 66.25 1.37 65.91 Pass-Minor 1/10 11,616.44 6,295.39 11,625.00 6,313.95 2.21 3.73 2.48 -3,464.90 -7,832.52 0.22 71.34 1.38 71.00 Pass-Minor 1/10 11,641.44 6,292.58 11,650.00 6,311.29 2.33 3.92 1.79 -3,466.49 -7,857.33 0.22 75.15 1.39 74.80Pass-Minor l/10 11,666.62 6,290.17 11,675.00 6,308.85 2.46 4.11 1.26 -3,469.40 -7,882.03 0.22 77.65 1.41 77.30 Pass-Mirror 1/10 11,691.89 6,288.17 11,700.00 6,306.37 2.59 4.30 0.69 -3,473.70 -7,906.53 0.22 78.69 1.42 78.34 Pass-Minor 1/10 11,717.17 6,286.59 11,725.00 6,303.80 2.73 4.49 0.01 -3,479.36 -7,930.74 0.22 78.27 1.43 77.92 Pass-Minor 1/10 11,742.37 6,285.44 11,750.00 6,301.46 2.88 4.67 -0.62 -3,486.28 -7,954.65 0.22 76.56 1.42 76.21 Pass-Minor 1/10 11,767.45 6,284.71 11,775.00 6,299.78 3.02 4.85 -0.90 -3,494.42 -7,978.22 0.22 73.66 1.41 73.32 Pass-Minor 1/10 11,792.35 6,284.39 11,800.00 6,298.89 3.16 5.03 -0.68 -3,503.85 -8,001.35 0.22 69.53 1.39 69.20 Pass-Minor 1/10 11,817.21 6,284.43 11,825.00 6,297.59 3.30 5.20 -0.49 -3,514.43 -8,023.96 0.22 63.99 1.40 63.67 Pass-Minor 1/10 11,842.03 6,284.46 11,850.00 6,296.18 3.46 5.37 0.16 -3,525.76 -8,046.20 0.22 57.36 1.41 57.07 Pass-Minor 1/10 11,866.75 6,284.40 11,875.00 6,295.12 3.61 5.54 1.28 -3,536.95 -8,068.53 0.22 50.69 1.42 50.41 Pass-Minor 1/10 I 11,891.62 6,284.27 11,900.00 6,294.31 3.76 5.72 2.72 -3,547.07 -8,091.37 0.22 44.91 1.43 44.66 Pass-Minor 1/10 11,916.67 6,284.06 11,925.00 6293.47 3.92 5.91 4.05 -3,555.83 -8,114.77 0.22 40.25 1.43 40.01 Pass-Minor 1/10 11,941.85 6,283.77 11,950.00 6,293.50 4.09 6.10 6.57 -3,563.26 -8,138.64 0.22 36.88 1.43 36.64 Pass-Minor 1/10 11,967.09 6,283.40 11,975.00 6,293.86 425 6.30 9.70 -3,569.60 -8,162.81 0.22 34.44 1.42 34.21 Pass-Minor 1/10 11,992.38 6,282.94 12,000.00 6,294.07 4.42 6.51 12.63 -3,574.92 -8,187.24 0.22 32.73 1.42 32.49 Pass-Misr 1/10 12,017.69 6,282.40 12,025.00 6,293.63 4.60 6.73 14.31 -3,579.15 -8,211.87 0.22 31.59 1.40 31.36 Pass-Minor 1/10 12,043.03 6,281.79 12,050.00 6,292.55 4.78 6.95 14.49 -3,582.18 -8,236.66 0.22 31.09 1.39 30.86 Pass-Minorl/10 12,068.04 6,281.11 12,075.00 6,291.50 4.96 7.18 13.50 -3,583.92 -8,261.57 0.22 31.62 1.37 31.39 Pass-Minor 1/10 12,092.66 6,280.43 12,100.00 6,290.06 5.13 7.41 10.53 -3,584.27 -8,286.53 0.22 33.51 1.34 33.28 Pass-Minor 1/10 12,117.06 6,279.76 12,125.00 6,288.75 5.32 7.64 7.39 -3,583.25 -8,311.47 0.22 37.02 1.31 36.79 Pass-Minor 1/10 12,141.15 6,279.10 12,150.00 6,287.67 5.50 7.89 4.59 -3,580.87 -8,336.33 0.22 42.15 1.26 41.92 Pass-Minor 1/10 12,164.80 6,278.45 12,175.00 6,286.83 5.67 8.13 2.25 -3,577.10 -8,361.02 0.22 48.91 1.21 48.67 Pass-Minor 1/10 12,188.05 6,277.81 12,200.00 6,286.18 5.85 8.37 0.38 -3,572.37 -8,385.56 0.22 56.84 1.15 56.60 Pass-Minor l/10 12,211.24 6,277.17 12,225.00 6,285.54 6.03 8.62 -1.13 -3,567.87 -8,410.14 0.22 64.79 1.08 64.53 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/2912011 4:39:59PM Page 3 of 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-19 Project: Kuparuk River Unit TVID Reference: 2K-19 @ 154.00ft(Nordic 1) Reference Site: Kuparuk 2K Pad MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site Error: 0.00ft North Reference: True Reference Well: 2K-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-19AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-19AL1_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-19-2K-19A-2K-19A Offset Site Error: 0.00 ft Survey Program: 40-GYD-CT-CMS,10172-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +EI-w Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (`) (ft) (ft) (ft) (ft) (ft) (ft) 12,234.67 6,276.53 12,250.00 6,285.16 6.21 8.87 -2.12 -3,564.58 -8,434.92 0.22 71.80 0.98 71.54 Pass-Minor 1/10 12,258.30 6,275.88 12,275.00 6,284.17 6.39 9.12 -3.38 -3,562.44 -8,459.81 0.22 77.85 0.85 77.58 Pass-Minor 1/10 12,282.11 6,275.23 12,300.00 6,283.14 6.58 9.37 -4.49 -3,561.59 -8,484.77 0.22 82.85 0.66 82.57 Pass-Minor 1/10 12,306.10 6,274.57 12,325.00 6,282.37 6.77 9.62 -5.29 -3,562.20 -8,509.74 0.22 86.65 0.35 86.36 Pass-Minor 1/10 12,330.23 6,273.91 12,350.00 6,281.74 6.96 9.87 -5.90 -3,564.34 -8,534.64 0.22 89.16 0.35 88.87 Pass-Minor 1/10 12,354.44 6,273.25 12,375.00 6,281.20 7.16 10.12 -6.38 -3,567.89 -8,559.38 0.22 90.48 0.35 90.19 Pass-Minor 1/10 12,378.67 6,272.58 12,400.00 6,280.49 7.36 10.37 -6.91 -3,572,62 -8,583.92 0.22 90.81 0.35 90.52 Pass-Minor 1/10 12,403.37 6,271.92 12,425.00 6,279.80 7.56 10.61 -7.08 -3,578.55 -8,608.19 0.22 90.10 0.35 89.81 Pass-Minor 1/10 l 12,428.93 6,271.33 12,450.00 6,279.27 7.77 10.84 -6.48 -3,586.08 -8,632.02 0.22 87.65 0.35 87.37 Pass-Minor 1/10 12,454.22 6,270.87 12,475.00 6,278.94 7.98 11.07 -5.71 -3,595.18 -8,65529 0.22 83.39 0.35 83.12 Pass-Minor 1/10 12,479.23 6,270.55 12,500.00 6,278.81 8.19 11.29 -4.77 -3,605.22 -8,678.19 0.22 77.98 0.35 77,72 Pass-Minor 1/10 12,504.21 6,270.35 12,525.00 6,278.88 8.40 11.51 -3.70 -3,615.05 -8,701.18 0.22 72.63 0.35 72.39 Pass-Minor 1/10 12,529.36 6,270.28 12,550.00 6,279.04 8.62 11.73 -2.66 -3,623.77 -8,724.60 0.22 68.28 0.35 68.04 Pass-Minor 1/10 12,549.14 6,270.28 12,570.35 6,279.00 8.79 11.92 -2.69 -3,630.12 -8,743.93 0.22 65.45 0.35 65.22 Pass-Minor 1/10 1 1 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/29/2011 4:39:59PM Page 4 of 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ler ConocoPhiiiips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-19 Project: Kuparuk River Unit TVD Reference: 2K-19 @ 154.00ft(Nordic 1) Reference Site: Kuparuk 2K Pad MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site Error: 0.00ft North Reference: True Reference Well: 2K-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-19AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-19AL1_wp04 Offset TVD Reference: Offset Datum Reference Depths are relative to 2K-19 @ 154.00ft(Nordic 1) Coordinates are relative to:2K-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:-0.02° Ladder Plot I I I I 100 - I I I I I 1 I I I I 1 I I I I I 1 I I I I I I I I I I J J J J J1\ J I I I I I 1 I 1 1 I I I 1 1 1 I I I I I 1 1 1 1 75 ' _ I I I I I I 1 1 0 1 I I 1I I 66 1 I 1 I ii m 1 I I 1 I /, f7 ID J J J J J "-f - J ai I I I 1 I I GO 1 1 I 1 I I ai I 1 1 1 I I I I 1 I C. 50 I I I I I 1 f I U I I I I I I te-. 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L._ Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, April 29, 2011 10:00 AM To: 'Eller, J Gary' Cc: Gantt, Lamar L Subject: RE: Approval to Change KOP in 2K-19AL1 (211-035) Gary, Per our conversation, please submit a revised PTD application for 2K-19AL1 (PTD 211-035). You have verbal approval to proceed with 2K-19AL1 as we discussed and is outlined below. The new well trajectory will include the new proposed kickoff point at 11055' and the"possible" new BHL target if you think you can replace AL2 lateral. Please get the revised to the Commission by Monday (next working day) as stated in 20 AAC 25.005 (a) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Friday, April 29, 2011 9:20 AM To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L Subject: Approval to Change KOP in 2K-19AL1 (21-035) Guy—Good morning. As we discussed earlier, I'd like to change the planned KOP of the 2K-19AL1 lateral (211- 035) in order to better contact the Kuparuk A4 pay. We want to move our KOP to 11,055' MD instead of the original plan of 12,350' MD. Proposed TD would remain unchanged. As is common with these Kuparuk CTD laterals, the map view will be practically identical to what was previously proposed—we should remain within 100' of the original approved well plan. The attached slides perhaps better show what I'm describing. The first slide shows a geologic cross-section for the 2K-19A sidetrack plus the AL1 and AL2 laterals in dashed lines. The second slide shows our current geologic interpretation and well status. By moving the AL1 kickoff point to 11,055' MD, we pick up a significant amount of A4 pay that was missed with the 'A' sidetrack. It's possible(but not at all certain)that we can meet our geologic objectives with this AL1 lateral such that we won't need to drill the AL2 lateral, but that remains to be seen. I think the bottom line is whether we can amend the 2K-19AL1 KOP via verbal approval or whether a new PTD is needed. If a new PTD is required, then we'll need AOGCC authorization to continue uninterrupted drilling operations over the weekend until I can provide you with a written PTD. Please call if we need to discuss any of this. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 4/29/2011 l� O 0 0 0 CI O 0 0 M _ _ O .A Cs C(7 O 0 lt' 0 0 117 V CSN m 0 0- M Ms- ^0^ _ C O Cs V ' Cs O O 0 g2 N _ - M C !V _ _ .- co J oM Q -L o 01 o "' " c o - t • ' M N Y � rN. 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O 0 0 0 Co_ N " ( a vi � NP. co.(D a 3. 32 — TW (.0 'CL y 't ' D /1:3 O n 'N CD 'y CD N N (D W OD m li jCON v O ( O0U 'W 'p N D ' ( . z Z z '-i,5OA 'Og0p .0 ' ' '0 ' 7 7 '' S 'O c' El' 70 y ; � ' ) aa 7Fww W ;m u (" 3 F 3 0 N -. ; , oD y co _ (D D CO N ,N 'N '0.•. QO y O n .0 n( 3 co • co to V _ a ,CTO z° y p a O y N O a' m O V 0 S' p p > O x O ° C o 7 N me . -p CD CD p y c r- • - 00 _< .c CO c n 0. CO Cl) 'p '•0 '• ^•' cc (C) 0 � 7 . CD V . a ,y .y _. N 3 Ft 3 0 O y c 'p ,6 n . co ° 'a o m - . O co3 m ° I o '� f ° u)• m co a 'y = a = < r W p CD y '� m • c � CD o .aa 3 o - � a o p c o Q 3 0 m a CO v-D ov c-) T. 0) m c m -°o Q y a _ o' c 3 o . � . 0 (I) 7 N m -0 CD O o o co cnN cu El Ei Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 4:36 PM To: 'Eller, J Gary' Cc: Davies, Stephen F (DOA) Subject: RE: Correction on KRU 2K-19 CTD PTDs(PTD 211-035) Gary, The permits have already been circulated here... I will add your statement to the well files. Thanks for updating us with the most current information. Hopefully, if the MI injection has truly been that recent(first gas injection in pattern) you will not see MI gas that quickly in the tighter A sand target zone wellbore. Of course , if MI has been injected for quite awhile all bets are off!!! Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Wednesday, March 09, 2011 4:23 PM To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L; Ohlinger, James J Subject: Correction on KRU 2K-19 CTD PTDs Guy— I wanted to make you aware of an error that I made in the paperwork accompanying the drilling permits for the proposed KRU 2K-19 CTD laterals. In the Hazards section on page 4 of the summary document dated February 28, 2011 that accompanied the drilling permits, I stated that"there has been no MI gas injection in the vicinity of 2K-19, so it is unlikely that an influx will yield significant quantities of gas". That statement was incorrect. Well 2K-13, immediately to the north of 2K-19, has recently been on MI gas injection, and therefore it is likely that any influx taken during the drilling of the 2K-19 CTD laterals would contain significant quantities of gas. I have already made the correction on my own written drilling procedure. Please contact me if you have any questions. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 3/9/2011 sift:J[ 1 oF ALAsEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-19AL1 ConocoPhillips Alaska, Inc. Permit No: 211-035 Surface Location: 219' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 1264' FSL, 1213' FWL, SEC. 10, T1ON, R8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 2K-19A, Permit No 211- 034, API 50-103-20118-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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, Daniel T. Seamount, Jr. Chair DATED this day of March, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 2 2011 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil&Gas Cons.Commission la.Type of Work: • lb.Proposed Well Class: Development-Oil ❑. Service-Winj El Single Zone ❑✓ . lc.Specify if AlIgiglialp for: Drill ❑ Re-drill ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2K-19AL1 . 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13100' • TVD: 6108' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:219'FNL,94'FEL,Sec. 11,T1ON,R8E,UM • ADL 25588,25589 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1430'FSL, 1919'FWL,Sec. 10,T1ON,R8E,UM 2674,2675 4/15/2011 Total Depth: 9.Acres in Property: 14.Distance to 1264'FSL, 1213'FWL,Sec. 10,T1ON, R8E,UM 2560Nearest Property: 11400 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:/5-7./ p8feet 15.Distance to Nearest Well Open Surface:x- 498310 y- 5938085 Zone- 4 GL Elevation above MSL: r-,,�Beet to Same Pool: 2K-27,2100' • 16.Deviated wells: Kickoff depth: 12350 .ft. 17.Maximum Anticipated Pressures•in psig(see 20 AAC 25.035) Maximum Hole Angle: 97° deg Downhole:4078 psig • Surface:3512 psig . 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1500' 11600' 6135' 13100' 6108' slotted liner t/ 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 10659' 6576' 10500' 6474' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 170 sx AS II 115' 115' Surface 3754' 9.625" 1200 sx AS III,450 sx Class G 3789' 2898' Intermediate Production 10524' 7" 450 sx Class G 10557' 6508' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 10169'-10189', 10210'-10250' 6259'-6271',6285'-6309' 20.Attachments: Property Plat❑ BOP Sketch❑✓ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172��J S(‘)1‘ Printed Name V. Cawvey Title Alaska Wells Manager Signature Phon 265-6306 Date 3 zij,I Commission Use Only Permit to DrillAPI Number: 1 I Permit Approval See cover letter Number: �' �� 50-/ �" /�L�/ - r`1„ Date: Jio/i ( forotherrequirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbe, me/ ne,gas hydrates,or gas contained in shales: 12/4f$2 C /0.g. Bo? 1 s r Samples req'd: Yes El No L 4 Mud log req'd: Yes ❑ No 2/ Other:e 2S06 / sc... ANh w,tc.+, T sf( Sreasures: Yes P/No ❑ Directional svy req'd: Yes [y/ No ❑ ,,// �— APPROVED BY THE COMMISSION FA D `, DATr�`. I ['''' ,COMMISSIONER Form 10-401 Revised 7/2009) This permit is vhliaf f ticislfr the da a of approval AAC 25.005(g)) Submit in Du hcate— ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECEIVED February 28, 2011A 211 Commissioner-State of Alaska Masks Oil&Gas Cons.Commission fission Alaska Oil &Gas Conservation Commission Anchor° 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill applications for three coiled tubing drilling (CTD) laterals out of Kuparuk well 2K-19 (PTD# 189-109) using the Nabors CDR2-AC coiled tubing drilling rig. The objective is to drill three producing A-sand laterals: 2K-19A, 2K-19AL1, and 2K-19AL2. Work is scheduled to begin in April 2011. Also included is the sundry for plugging the existing 2K-19 perfs with cement in order to perform these CTD sidetracks. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 2K-19A, 2K-19AL1, 2K-19AL2 — Proposed &Current Wellbore Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — 10-403 for plugging the existing 2K-19 wellbore with cement If you have any questions or require additional information please contact me at my office 907-263-4172. Sincerely, Gary Eller Conoco fillips Alaska Coiled Tubing Drilling Engineer KRU 2K-19A, AL1, AL2 —Coiled Tubing Drilling Summary of Operations: Well 2K-19 is a Kuparuk A-sand production well equipped with 31/2"tubing and 7"production casing. Three proposed A-sand CTD laterals will increase reservoir exposure and offset the planned 2K-13 CTD injection laterals. Prior to drilling,the existing A-Sand perfs in 2K-19 will be squeezed with cement to provide a means to kick out of the 7"casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 10,220' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2K-19A sidetrack will exit the 7"casing at 10,170' MD and will target the A4 sand west of the existing well with a 3030' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,200' MD with an aluminum billet at 12,350' MD. The 2K-19AL1 lateral will kick off from the aluminum billet at 12,350' MD and will target the A4 sand west of the existing well with a 750' lateral. The hole will be completed with a 23/" slotted liner to the TD of 13,100' MD with an aluminum billet at 11,600' MD. The 2K-19AL2 lateral will kick off from the aluminum billet at 11,600' MD and will target the A4 sand west of the existing well with an 850' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,450' MD with the final liner top located just inside the 31/2"tubing at 10,060' MD. CTD Drill and Complete 2K-19 Laterals: April 2011 Pre-CTD Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. RU slickline. Obtain updated static BHP on A-sand. Dummy off all GLMs. RD slickline. 3. RU e-line. Perf holes in 31/2"tubing tail at 10,070' MD. RD e-line. 4. RU coil. Mill out XN-nipple in tubing tail to 2.80"ID. Plug the A-sand perfs with cement up to 10,070' MD. RD coil. 5. RU slickline. Tag top of cement. RD slickline. 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. 2K-19A Sidetrack(A4 sand,west) a. Drill 2.80"high-side pilot hole through cement to 10,220 MD'. b. Drift pilot hole with whipstock dummy c. Set whipstock at 10,170' MD with high-side orientation. d. Mill 2.80"window with high-side orientation at 10,170' MD. e. Drill 2.70"x 3"bi-center lateral to TD of 13,200' MD f. Run 2%"slotted liner with an aluminum billet from TD up to 12,350' 3. 2K-19AL1 Lateral(A4 sand,west) 4 a. Kick off of the aluminum billet at 12,350' MD -rh. pr; b. Drill 2.70"x 3"bi-center lateral to TD of 13,100' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 11,600' 1` 4. 2K-19AL2 Lateral (A4 sand,west) a. Kick off of the aluminum billet at 11,600' MD b. Drill 2.70"x 3"bi-center lateral to TD of 12,450' MD c. Run 2%"slotted liner from TD up to 10,060' MD, up inside the 31/2"tubing tail 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Page 2 of 4 f It IA February 28, 2011, FINAL KRU 2K-19A, AL1, AL2 - Coiled Tubing Drilling Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg)for milling operations, and chloride- based Flo-Pro mud(8.6 ppg)for drilling operations. We will have to kill the well with weighted brine in order to deploy 2%"slotted liner in the three laterals. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class H drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2K-19A: 2%", 4.7#, L-80, ST-L slotted/solid liner from 12,350' MD to 13,200' MD • 2K-19ALI: 2%",4.7#,L-80, ST-L slotted/solid liner from 11,600' MD to 13,100' MD✓ • 2K-19AL2: 2%",4.7#,L-80, ST-L slotted/solid liner from 10,060' MD to 12,450' MD Existing Casing/Liner Information Surface: 9%", J-55, 36 ppf Burst 3520 psi Collapse 2020 psi Production: 7", J-55,26 ppf Burst 4980 psi Collapse 4320 psi Logging • MWD directional,resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 2K-19 was taken November 2010. The A-sand reservoir pressure was measured at 2355 psi at 10,050' MD, 6050' SSTVD, corresponding to 7.3 ppg EMW. We generally expect to encounter increasing pressure as laterals are drilled away from the mother well. Well Control: • • Two well bore volumes(-230 bbl)of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2"coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum potential surface pressure in 2K-19 is 3512 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 4078 psi at 6122' TVD taken in offset injection well 2K-13 in January 2011, corresponding to 12.8 ppg formation pressure. • The annular preventer will be tested to 250 psi and 2500 psi. Page 3 of 4 n1 r ?, „e, 1February 28,2011, FINAL litU . s` KRU 2K-19A, AL1, AL2 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 2K-19A,plan#3 2. 2K-19AL1, plan#2 3. 2K-19AL2,plan#2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 2K-19 CTD laterals(A,AL1 &AL2): 11,400' to property line,—2100' to well 2K-27 Hazards • Shale stability is the most significant problem expected due to somewhat low reservoir pressure and the significant number of fault crossings expected. It will be mitigated by directional planning to minimize exposure to the worst shales and by applying MPD pressure to maintain hole stability. • There has been no MI gas injection in the vicinity of 2K-19, so it is unlikely that an influx will yield significant quantities of gas. • Well 2K-19 has 90 ppm measured 1-12S as of January 2010. Well 2K-18 is located 25' to the right side and 2K-20 is 25' to the left side of the 2K-19 surface location. Neither well has any measured 112S since they are both injectors. The maximum H25 level on the pad is 400 ppm from well 2K-27 (1/13/09). All H25 monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. Well 2K-19 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 2382 psi at 10,170' MD(6275' TVD),or 7.3 ppg EMW. • Expected annular friction losses while circulating: 1017 psi(assuming annular friction of 100 psi/1000 ft due to the 31/2"tubing) • Planned mud density of 8.6 ppg equates to 2806 psi hydrostatic bottom hole pressure at 6275' TVD. Mud hydrostatic pressure alone is expected to be sufficient to overbalance formation pressure. • While circulating 8.6 ppg mud, bottom hole circulating pressure is estimated to be 3823 psi or 11.7 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 2K-19. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability, but not necessarily for well control. • When circulation is stopped, 1000 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. Page 4 of 4 f iNI a t February 28,2011, FINAL r KUP 2K-19 C( o� (l �e ; Weil Attributes Max.An91e-&MD -TD Al3SKd G 1,7: '''s TalhOx Wellbore APWWI Reid Name Iw II Status Incl(1 MD(ftKB) Act Btm(ftKB) ' 501032011800 KUPARUK RIVER UNIT _II PROD 60.35 3,700.00 _10659.0 taatOmli _ -" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Darts "' SSSV:TRDP 200 1/13/2009 Last WO I 39.99 11/14/1989 w ncon6n:_zK_ge 3l2L29luke33331- (ftKB) _- - s_ _ _Y _ .. Sewn tic.gGupL,.:_ �� Annotation Depth(ftKB) End Drte Annotation Last Mod By EM Date Last Tag:SLM 10,346.0 2/14/2010 Rev Reason:PERFORATIONS I Imosbor 3/2/2010 Casing'Strings Y e,_: �. String OD String ID Set Depth Set Depth(TVD) String Wt String . 0,,,..,a 85.m,"1 -f , .--- Casino Desorption_ (in) (in) _ Top(FMB) (ftKB) (ftKB) (barn) Grade String Top Thrd 1 CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 CONDUCTOnR SURFACE 95/8 8.765 0.0 3,789.0 2,897.5 36.00 J-55 s _ PRODUCTION 7 6.151 0.0 10,557.0 6,508.0 26.00 J-55 Tubing Stnngs ... '- =` rax Safety valve, String OD Siring ID Set Depth '4 Set Depth(TVD) String Wt String Vin T bion Desmiption (in) On) Top(ftKB) MKS) (KB) (lbs/ft) Grade String Top Thrd TUBING 3 12 2.992 0.0 10,084.0 6,209.0 9.30 J-55 EUE8rdABMOD Other In Holez:(AII JeweIry Tubing Run&Retnevable;Fishetc_)_ Top Depth (TVD) Top Ind GAS LIFT, ;y- Top(1KB) 668) (.3 Deurlption Comment Run Date ID(in) 2,675 = 1,798 1,721.8 33.62 Safety Valve Camco TRDP-1ASSA 5/3/1990 2.812 2,675 2,317.5 56.05 GAS LIFT MERLA/TMPD/1/GLVBK/.125/1350/Comment STA 1 9/21/2003 2.875 •',5,.1 5,530 3,784.8 58.98 GAS LIFT MERLA/TMPD/1/GLVBK/.156/1363/Comment STA 2 9212003 2.875 SURFACE, 3,789 ;^ 7,062 4,598.8 57.84 GAS UFT MERLA/TMPD/1/GLVBK/.156/1341/Comment STA 3 9/21/2003 2.875 7,833 5,007.4 5773 GAS LIFT MERLA/TMPD/1/DMY/BK///Comment:STA 4 5/3/1990 2.875 ti, 8,577 5,397.1 58.70 GAS UFT MERLA/TMPD/1/GLVBK/.188/1355/Comment STA5 9/21/2003 2.875 GAS LIFT, 5,7 9,298 732 57.98 GAS UFT CAMCO/MMG-2/1.5/DMY/RK///Comment STA 6 9/24/2003 2.921 5' 9,959 6,136.9 55.24 GAS UFT CAMCO/MMG-2/1.5/OV/RK/.25//Comment STA 7 5/14/2009 2.921 10,003 6,163.4 55.48 PBR Baker'80.40'w/10'Stroke PBR 5/3/1990 3.000 10,016 6,170.5 55.28 PACKER Baker'HB'RETRIEVABLE PACKER 5/3/1990 2.890 GAS LIFT, 10,052 6,190.6 54.76 NIPPLE Otis'XN'Nipple NO GO w/2.81"POLISHED BORE 5/3/1990 2.750 - 10,083 6,208.4 54.30 SOS Baker 5/3/1990 2.992 10,084 6,209.0 54.29 TTL --- 5/3/1990 2.992 Perforations&.Slots__ GAS LIFT, Shot-- 7,833Top(ND) Btrn(TVD) --- Dens --2iM Top(ftKB) Bhn(ftKB) (ftKB) (ftKB) Zone Date (9h... Type Comment 10,169 10,189 6,259.4 6,271.4 A-4,2K-19 3/1/2010 6.0 APERF 2.5"Millenium HMX charges,60 '544, degree phase 10,210 10,250 6,285.3 6,309.1 A-5,2K-19 5/1/1990 4.0 IPERF 180 deg.Phasing;4.5"HLS Casing GAS LIFT, Guns Notes.Geneial&LSafetyn i- , ._.. -_ End Date Annotation 10/24/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION 9/24/2009 NOTE:Repair SURF CSG of 9 5B"hanger,weld 38"sleeve W/10".500 wall API SL-X65 pipe - ,y' GAS IFT,_ li 9,298 f GAS LIFT, 9,959 ii: , ' PBR,10,003 PACKER _ �_ 10,0161 Iiii • NIPPLE,10,052 1 ` X SOS,10,083 TIL,10,080 APERF. 10,189-10,189 IPERF, Fs 10,210.10,250 as ioss es. PRODUCTION, 10,557 TD,10.659 ORIGINAL - Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing , Lubricator Riser Annular/ Blind/Shear 2" Pipe/Slip (CT) Pump into ams -< L> / above BHA rams �/ ` L� 1 r I ' Choke 1 2-3/8" Pipe/Slip(BHA) ` Choke Equalize Manifold 2-3/8" Pipe/Slip(BHA) Kill ,>4�J r><I>i<_1` L . ► r Blind/Shear 2" Pipe/Slip (CT) 1 r Choke 2 i Swab Valves Ali_ Wing Valves ieii-oi Tree Flow Cross 4 Surface Safety Valve BOPE: 7-1/16", 5M psi,TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union 0l " ! , y Np p LL a 2 W CV 0 0 N NJ<- < 0 V aN O N H T^ p 2 0 to Nv J N Q< 0 CON O 0 m to to II o m o CC p 'n o _ m 'o o E D N V l K VCO ti in 6 Y. II I p 2 71 M re co / ag vCl B o. N m O mal N o a O oco co 1— x W o o 1 Q co Q co � � Civ 0 L m O d o O.m E. C mr CO aX8 8� x N NE at E ito N C mU rn U to c%) O$1 0 _p N N ,)o] N N `i N m W Y MI R < d G M M co ONi m m C%) ty c O_ p U pp<� 2 QlY/ O 4AM immool i co' bb efial1 13 /��,,•.Hill U - 13 f1 I 7\i" m M III I L I N C p 0 a d ai m O O c n E w o ca _ o t 0 0 a� w. �Y I o- '= a 2 o. �Nqmm o to"CO' <p op vc b N O Ct O o 2 p v on m co N��1 ` a ' mo �� Q< �c N.,- r"..-@ 1�@ io Np " iORIGINAL ConocoPhilli Alas-Ka ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19AL1 Plan: 2K-19AL1_wp02 Standard Planning Report 25 February, 2011 BAKER lU HES ORIGINAL 1.-- ConocoPhillips (1' ConocoP'hillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL1 Design: 2K-19AL1_wp02 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 2K Pad I Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-19 Well Position +N/-S 0.00 ft Northing: 5,938,085.20 ft Latitude: 70°14'31.454 N +EI-W 0.00 ft Easting: 498,310.27 ft Longitude: 150°0'49.127 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118.50ft Wellbore 2K-19AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2010 4/15/2011 16.64 79.76 57,334 Design 2K-19AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,350.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -118.50 0.00 0.00 257.00 • Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°1100ft) (0/100ft) (°1100ft) (0) Target 12,350.00 92.79 262.15 6,136.92 -3,626.46 -8,544.45 0.00 0.00 0.00 0.00 12,380.00 89.67 260.35 6,136.28 -3,631.03 -8,574.09 12.00 -10.40 -6.00 210.00 12,410.00 87.87 257.23 6,136.92 -3,636.86 -8,603.51 12.00 -6.00 -10.40 240.00 12,440.00 87.88 253.62 6,138.04 -3,644.40 -8,632.52 12.00 0.01 -12.01 270.00 12,470.00 89.68 250.51 6,138.68 -3,653.63 -8,661.05 12.00 6.01 -10.39 300.00 12,545.00 97.46 245.98 6,134.01 -3,681.34 -8,730.50 12.00 10.38 -6.03 330.00 12,645.00 93.24 234.70 6,124.65 -3,730.54 -8,816.85 12.00 -4.22 -11.28 250.00 12,815.00 91.30 255.02 6,117.84 -3,802.31 -8,969.82 12.00 -1.14 11.96 95.00 13,100.00 92.48 289.22 6,108.15 -3,791.94 -9,250.24 12.00 0.41 12.00 87.50 2125.2011 11:37:47AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL 1,-' ConocoPhillips r/' ConocoPhi1hps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL1 Design: 2K-19AL1 wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (1 e) (ft) (ft) (ft) (ft) (1100ft) (') (ft) (ft) 12,350.00 92.79 262.15 6,136.92 -3,626.46 -8,544.45 9,141.24 0.00 0.00 5,934,461.01 489,765.86 TIP/KOP 12,380.00 89.67 260.35 6,136.28 -3,631.03 -8,574.09 9,171.14 12.00 -150.00 5,934,456.46 489,736.22 2 12,400.00 88.47 258.27 6,136.60 -3,634.74 -8,593.74 9,191.12 12.00 -120.00 5,934,452.75 489,716.57 12,410.00 87.87 257.23 6,136.92 -3,636.86 -8,603.51 9,201.12 12.00 -119.97 5,934,450.63 489,706.81 3 12,440.00 87.88 253.62 6,138.04 -3,644.40 -8,632.52 9,231.08 12.00 -90.00 5,934,443.10 489,677.80 4 12,470.00 89.68 250.51 6,138.68 -3,653.63 -8,661.05 9,260.96 12.00 -60.00 5,934,433.87 489,649.27 5 12,500.00 92.79 248.71 6,138.03 -3,664.08 -8,689.16 9,290.69 12.00 -30.00 5,934,423.43 489,621.16 12,545.00 97.46 245.98 6,134.01 -3,681.34 -8,730.50 9,334.86 12.00 -30.04 5,934,406.19 489,579.81 6 12,600.00 95.17 239.76 6,127.95 -3,706.26 -8,779.13 9,387.84 12.00 -110.00 5,934,381.28 489,531.19 12,645.00 93.24 234.70 6,124.65 -3,730.54 -8,816.85 9,430.06 12.00 -110.69 5,934,357.01 489,493.47 7 12,700.00 92.65 241.28 6,121.82 -3,759.64 -8,863.40 9,481.96 12.00 95.00 5,934,327.92 489,446.92 12,800.00 91.48 253.23 6,118.20 -3,798.20 -8,955.39 9,580.28 12.00 95.34 5,934,289.38 489,354.92 12,815.00 91.30 255.02 6,117.84 -3,802.31 -8,969.82 9,595.25 12.00 95.77 5,934,285.28 489,340.50 8 12,900.00 91.72 265.22 6,115.59 -3,816.87 -9,053.42 9,679.98 12.00 87.50 5,934,270.74 489,256.91 13,000.00 92.15 277.22 6,112.20 -3,814.75 -9,153.15 9,776.69 12.00 87.77 5,934,272.88 489,157.18 13,100.00 92.48 289.22 6,108.15 -3,791.94 -9,250.24 9,866.16 12.00 88.18 5,934,295.71 489,060.10 TD 2/25/2011 11:37:47AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site: Kuparuk 2K Pad North Reference: True Well: 2K-19 Survey Calculation Method: Minimum Curvature Wellbore: 2K-19AL1 Design: 2K-19AL1_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (1 (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-19AL1 t1 0.00 0.00 6,137.00 -3,667.33 -8,698.37 5,934,420.18 489,611.94 70°13'55.336 N 150°5'1.874 W -plan hits target center -Point 2K-19A,AL2 Fault#2 0.00 0.00 0.00 -2,377.01 -7,624.51 5,935,710.13 490,685.99 70°14'8.038 N 150°4'30.709 W -plan misses target center by 6330.03ft at 12350.00ft MD(6136.92 TVD,-3626.46 N,-8544.45 E) -Polygon Point 1 0.00 -2,377.01 -7,624.51 5,935,710.13 490,685.99 Point 2 0.00 -3,514.21 -7,946.23 5,934,573.12 490,364.04 Point 3 0.00 -3,853.22 -7,867.13 5,934,234.13 490,443.06 Point 4 0.00 -3,514.21 -7,946.23 5,934,573.12 490,364.04 2K-19AL1 t2 0.00 0.00 6,108.00 -3,791.46 -9,250.42 5,934,296.19 489,059.93 70°13'54.109 N 150°5 17.910 W -plan hits target center -Point 2K-19AL1 Polygon 0.00 0.00 0.00 -3,506.30 -8,604.40 5,934,581.18 489,705.95 70°13'56.921 N 150°4'59.149 W r -plan misses target center by 6132.36ft at 12661.58ft MD(6123.74 TVD,-3739.88 N,-8830.52 E) -Polygon Point 1 0.00 -3,506.30 -8,604.40 5,934,581.18 489,705.95 Point 2 0.00 -3,728.29 -8,480.33 5,934,359.18 489,829.96 Point 3 0.00 -3,916.43 -8,919.32 5,934,171.16 489,390.97 Point 4 0.00 -3,955.55 -9,334.35 5,934,132.13 488,975.97 Point 5 0.00 -3,689.53 -9,373.43 5,934,398.14 488,936.95 Point 6 0.00 -3,506.30 -8,604.40 5,934,581.18 489,705.95 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name 3,789.00 2,758.29 9 5/8" 9-5/8 12-1/4 13,100.00 6,108.15 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates ,, 1/V44 , Depth Depth +N/-S +El-W G�, 411 wa 1 ' � � a x (ft) (ft) (ft) (ft) Comment 'n � sr+ k. 12,350.00 6,136.92 -3,626.46 -8,544.45 TIP/KOP 12,380.00 6,136.28 -3,631.03 -8,574.09 2 12,410.00 6,136.92 -3,636.86 -8,603.51 3 12,440.00 6,138.04 -3,644.40 -8,632.52 4 12,470.00 6,138.68 -3,653.63 -8,661.05 5 12,545.00 6,134.01 -3,681.34 -8,730.50 6 12,645.00 6,124.65 -3,730.54 -8,816.85 7 12,815.00 6,117.84 -3,802.31 -8,969.82 8 13,100.00 6,108.15 -3,791.94 -9,250.24 TD 212512011 11;37;47AM Page 4 COMPASS 2003.16 Build 69 OR ! 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[O(10 OA (0(0 CO 40 t0 ON b.- . .N .t, -,. 6,,, N. .. ...•-. . ., ..., ,126 ccrn TR V "m NNNN(�CV Z m cop N ..r-- oa`43 NM V 0 01 (Tx OS) uidaQ patuaA an.u, ..0rt 0. S n888888888 OWO ss.0pONNpNppp8 (11 L' N N N N N N 4 N M C N 10 f S (n N M Q..N o-a 0 Q' 1 SV �.t 1 \,,,,,,, ' ' hi:0 \ • I e \ I Vit NN I I �+8 i j K 1 ''[.; o i I I j Y s§g' I 25 t z 1 1 I I I B ,, v � 3 9> 1 1 0 j -MO I 1 a i < /-1 200 ,,+ 1 I I °(9 3 a, 1 I I ao I 1 I I 1 Y p,p51, N� C I 8 0 N o I Y 15 o pp2 3 a I 11\ e\11111 i i 1 iiI 1 ili I i ....0,78; s_.,tt' \ . IF i 1 i ..§ . I 1 4 I : -I 1 8 I II n m W >' 1 I Y I. E'''.4 0 o Y Y o ! a. a. Y Y . 3 1 a )r' t 8 N I I _ a a .. j �.. 19h I I 1 8 I O 1 'S Ei 1... b. b b' bii ' g g r r m 3 0 8 o v o�oP (II I/4 00Z) (+)'1 oN/(-)uanos �04110 Z g 0 0 IUORIGINAL N ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-19 2K-19AL1 2K-19AL1_wp02 Travelling Cylinder Report 28 February, 2011 r' . BAKER HUGHES ORIGiNAL ConocoPhillips r1 ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-19 Project: Kuparuk River Unit TVD Reference: 2K-19 @ 154.00ft(Nordic 1) Reference Site: Kuparuk 2K Pad MD Reference: 2K-19 @ 154.00ft(Nordic 1) Site Error: 0.00ft North Reference: True Reference Well: 2K-19 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-19AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-19AL1_wp02 Offset TVD Reference: Offset Datum Reference 2K-19AL1_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer(WARNING:There is hidden tight data in this project Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 12,350.00 to 13,100.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,506.45ft Error Surface: Elliptical Conic Survey Tool Program Date 2/23/2011 ,...-- ._�_ r „M From To ",-.u' , ,.,"i .._ (ft) (ft) Survey(Wellbore) Tool Name Description 40.00 10,160.00 2K-19 GyroData(2K-19) GYD-CT-CMS Gyrodata cont.casing m/s 10,160.00 12,350.00 2K-19A_wp03(2K-19A) MWD MWD-Standard 12,350.00 13,100.00 2K-19AL1_wp02(2K-19AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (••) 3,789.00 2,912.29 9 5/8" 9-5/8 12-1/4 13,100.00 6,262.15 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 2K Pad 2K-19-2K-19A-2K-19Awp03 12,350.00 12,350.00 0.00 0.37 -0.22 FAIL-No Errors 2K-19-2K-19AL2-2K-19AL2_wp02 12,364.15 12,425.00 264.81 168.73 96.31 Pass-Major Risk 2K-27-2K-27-2K-27 Out of range 2K-27-2K-27-2K-27(wp02) Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/28/2011 10:51:29AM Page 2 of 5 COMPASS 2003.16 Build 69 ORIGINAL OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME / e((( /. ( �- l PTD# Z / Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 6,(f. ,„_,7t.c__l�' fG�—r POOL: ! (f j Circle Appropriate Letter I 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 wellbo,_re seegmt of existing well / rC , v If last two digits in T w API numberare Permit No. 2J fly- ,API No. 50-/6 - 'l/y 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 perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ma 0 r- v -na f cm 3 D m O Da o o p a e I-- 0 � 3co y r 0 3.o W W 3 W oa o m co W C 2.3 o W C ° C>t JJ p N 0 N D) N 0 0 0 .S 7 p p a, O o N _- m O, 0303030303 W W W W W N N N N N N N N N N - - CO 00 .1 0) (31 A W N S 0 co oo .1 0) 01 A W N -+ 0 CO CO .I 0) 01 A Co.) N -, 0 CO CO 0) Cn A W N - 0 v O 0) CO o '13 k :e �* 0 CO bo D �, D �. 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