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210-058
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. Q 1 0 - 05B Well History File Identifier Organizing (done) Two-sided I I111111 11111 ❑ Rescan Needed 1 III III RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: 7yscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: 1 OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: . BY: Maria Date: 13 D I /s/ u Project"ect Proofin III I 11111 Proofing BY: left Date: ' 3 D I tt /s/ f li Scanning Preparation ` ' x 30 = 30 + 5• = TOTAL PAGES 5� (Count does not include cover sheet) 01 F BY: uf- Date: 0 /s/ Production Scanning II 1111111111111 Stage 1 Page Count from Scanned File: 5 2 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date://30//1.1— /s/ NI f 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. I 1111 II I ReScanned AMIN I BY: Maria Date: /s/ Comments about this file: Quality Checked III llIIIIIIIlII 19/99/9!111 \A/cll 1-lictnn,Filc Cnvcr Pnnc rinn I O C !O 2 C . co (_'1+ ai N — N I N y 0. ° 0 1 10 i z° I z U �� p p ° I a Ts °- o 0 0 > 0 0 0 0 1 Z U y V j N N N N j_)/1 U C1 o M M M M Z J ao co co aD C E Q = 2 - C C C C C C Y xx o w a m a) E ., I— g y OU O O O O O O E 0 CO 2 to x 2 Q a g as o:0) 0) 0) 0) 0) 10 0 y m z z CL J U Nio 0 0 0 0 0 p od `e 1.11 E J Ce 1 i C A (N O O O 0 0 Z to W 0 ✓ 0 q , U d o Z C a re o Q w z° _ co C t c I' N o CL- O u) ji o ° o 0 o c >, E c l i ZI J U U U o s to 2 o N n N O E a J N ' LO U E i N J a CO < 4 I— ,- a 0 • ° w C� z o R C j am aai m he • a) ! in Q 0 ) N Q I— 4 Q I � c z a o z v) 4',... 4' w Z. > > > > d U O N N N 0 m M 2 Z E I J 0 N CO 0 0 o) co CC Q Q Q Z 2 C C C C C C y a) 0 0 o o 0 0 in I E 7 7 7 .7 a) N C coo 1 Q' Z -o -13 c c 0 0 r I to to p Z I o y a`� i Cr) E O 111 CO J 0 y - ( ,2 H z Q m O a Z L C W ° Z N yO } ''\1!{.. d CL O o a) N O H O 10a .+ Z. d L. �. '>cC • a)I Z 0 0 V C J Q o W Z a �. .a 0 a) Z o P • C• O p p .2 r I ce Z W U I \ U p O o P as a) o P. Ty E a a N J \ U a ' a I N J pC 3 ° 0 c , J ="!", I W J J W a a� Q v . STATE OF ALASKA ALASKA uIL AND GAS CONSERVATION COMMISSKAN1 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Plug Frforations r Stimulate r Other [] PROD to WINJ Alter Casing r Pull Tubing r Perforate New Rol r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well - 2.Operator Name: 4.Current Well Status: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r ' 210-058 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 - 50-029-21331-61-00 7.Property Designation: 8.Well Name and Number: ADL 25635 1 R-06AL2 9.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 10915 feet Plugs(measured) None true vertical 6759 feet Junk(measured) None Effective Depth measured 10915 feet Packer(measured) 8435,8909 true vertical 6759 feet (true vertucal) 6266,6628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 12 4659 3694 0 0 WINDOW"A" 12 8 8832 8832 0 0 PRODUCTION 9244 7 9279 6729 0 0 "A"LINER 785 2.625 10245 6759 0 0 0 0 0 Perforation depth: Measured depth: Slots:9354-9486;9488-10914 True Vertical Depth: 6723-6725;6725-6759 RECEIVED ED Tubing(size,grade,MD,and TVD) 3.5,J-55, 8931 MD,6640 ND DEC 0 1 2010 Packers&SSSV(type,MD,and ND) PACKER-BAKER'FHL'PACKER .) 8435 MD• 6266 ND Alaska On & Gas Cons.Commission PACKER-BAKER'FB-1'PACKER • :•S• MD and 6628 ND Anchorage SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 429 1195 109 1500 159 Subsequent to operation 1089 700 1864 13.Attachments 14.Well Class after proposed work: o ' Copies of Logs and Surveys run Exploratory r Development r Service 17 �/ 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations !� GSTOR r WINJ ; WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 310-333 Contact Bob Christensen/Darrell Humphrey Printed Name i - 'be 4, Chri to sen Title Production Engineering Specialist Signature iff ______ - _ Phone:659-7535 Date y RBDMS DEC 01 2010 d i fz Form 10-404 Revised 10/2010 �y o Submit Original Only ..._.__ .._. . . 1 R-06AL2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary • Pre Produced Injector turned to Water Injection service 10/28/10 TAG LINER TOP @ 8781' RKB. PERFORMED 30 MINS SBHPS @ 8500'RKB= 1943 PSI, 145 DEG F. 15 MIN GRADIENT STOP @= 1938 PSI. 10/29/10 SET 3.5"WEATHERFORD WRP@ 8455' USING 1-11/16"SHORTY LONGSTROKE SETTING TOOL. CCL-ME=15.7'CCL STOP DEPTH-8439.3' 10/30/10 DEPLOYED 2.75 AVA CATCHER SUB ONTOP OF WRP @ 8455' RKB. PULLED GLV'S @ 2043',4326',6285', 7615'RKB AND SET DVS. PULLED OV @ 8381' RKB AND LEFT POCKET OPEN FOR CIRC OUT. 10/31/10 CIRC OUT TBG X IA. SET DV @ 8381' RKB. MIT TBG TO 2500 PSI. PASSED. MIT-IA TO 3000 PSI-PASS: IN PROGRESS. 11/01/10 PULLED CATCHER SUB AND WRP @ 8455'RKB. 11/27/10 Commenced Water Injection service KUP 1 R-06AL2 ConocoPhillips /° �r Attributes Field Name Well Status noax Angle&MD TMD lm(Rxe)t L.monwalhp: 500292133161 KUPARUK RIVER UNIT INJ 94.88 10,480.31 10,915.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date ... Well Conrig -1 R-06AL2,10/31/20 10 1 0.03:15 AM SSSV:TRDP Last WO: 37.61 5/15/1985 Schemare-Actual Annotation Depth(RKB) End Date Annotation Lest Mod...End Date Last Tag: Rev Reason:GLV C/O,SET PLUG/CATCHER Imosbor 10/31/2010 Casing Strings a HANGER,33 .:I Casing Description String 0... String ID...Top(MB) Set Depth(r..Set Depth(TVD)...String Wt...String... String Top Thrd WINDOW AL2 8 6.000 8,802.0 8,814.0 6,561.8 Y 39 t. - Casing Description String 0... String ID...Top(FMB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd AL2 LINER 23/8 1.995 9,344.1 10,915.0 4.43 L-80 STL Liner Details CONDUCTOR, I Top Depth 38-110 (TVD) Top Inc! Nom'... 0 Top(RKS) (t B) I') Item Description Comment ID(In) 9,344.1 6,723.3 91.00 Anchor billet Anchored billet 1.000 r—7 9,978.1 6,748.8 91.14 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 SAFETY VLV, 1, Hole Wireline retrievable plugs,valves,pumps,fish,etc.) r i Other In Top Depth GAS LIFT, tj (TVD) Top Intl 2,OH f Top(FMB) (RKB) 11 Description Comment Run Date ID(in) 8,800.5 6,552.1 35.66 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 7/5/2010 1.000 GAS LIFT, removed 4,328 J Perforations&Slots SURFACE, - Shot 371639 Top(TVD) Blm(TVD) Dens Top(ftKB) Btm(ftKB) (RK8) (RKB) Zone Date (oh... Type Comment GAS LIFT. 9,354.0 9,486.0 6,723.1 6,724.5 7/12/2010 32.0 SLOT Alternating solid/slotted pipe- 5,631 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered OAS LIFT. 18 deg,3'non-slotted ends 6,285 9,488.0 10,914.0 6,724.7 6,758.7 7/12/2010 32.0 SLOT Alternating solid/slotted pipe- GAS LIFT. r 0.125"72.5"@ 4 circumferential 6.762 1 adjacent rows,3"centers staggered r18 deg,3'non-slotted ends GAS LIFT,_ 77� Notes:General&Safety End Date Annotation GAS LIFT, 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 7,515 7/19/2010 NOTE:WELL SIDETRACK 1R AL1,AL1-01,AL2,AL2-01 GAS 6,061 LIFT, 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT. 8,381 PBR,8.121 PACKER,8,435 CATCHER, II 8.154 Mika-I PLUG,8,455 %% ell GASIFr3, ', 8L,17 IL. GAS LIFT, 8,545 IMI IM INI WHIPSTOCK, 8.801 OT, SLOT, 8,782-8,818 I WINDOW AL2, 8,802-8,814 WHIPSTOCK\ ; 8.819 \ PRODUCTION. 359,279 SLOT, 9,354-9,486 SLOT, 9,100-10.209 SLOT, 9150.10 SLOT, Mandrel Details 9,188-10,911 I lop Depth Top Port AL2-01 LINER, (TVD) Inc' OD Valve Latch Size TRO Ron 8,781-10,823 Stn Top(RKB) IRKS) ('1 Meke Model lin) Sera Type Type tin) (pal) Run Oste Com... 2 2,040.8 1,963.6 33.06 CAMCOKBUG 1 GAS LIFT DMY BK 10/30/2010 4,326.0 3,449.3 43.06 CAMCO KBUG 1 GAS LIFT 'DMY BK 0.000 0.0 10/30/2010 I 3 5,630.9 4,355.6 49.21 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1967 4 6,285.1 4,787.6 48.27 CAMCO 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 AL2 LINER, 5 6,762.2 5,103.9 48.28 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,31410915 _ TD(1RA6AL2), 6 7,198.2 5,396.447.03 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 10.915 81.1A1 LINER, 7 7,615.3 5,683.7 46.14 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 8815-11805 8' 8,060.9 5,995.744.90 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 I I 1 9 8,381.1 6,225.9 42.60 CAMCO KBUG 1 1/2 PROD DMY rd 120 0.000 0.0 10/30/2010 10 8,473.5 6,294.9 40.49 CAMCOMMG-2 1 1/2 PROD OPEN 0.000 0.0 11/21/1993 • KUP 1 R-06AL2 • Conoco✓Phillips Alaska.Inc. KB-Grtl(R) Rip Release Dab ••• Well Conn(.-1 R-06AAL2,1073172010 10.03:45 AM 37.61 5/15/1985 Schematic.Asks)! HANGER,33 1' saes • • CONDUCTOR,i I [1 ILI 38-710 SAFETY VLV, A o l 1,908 GAS LT, 2.04IF1 GAS IFT, 1 4L,326 SU37-4,RFACE, J I. 659 GAS LIFT, ,641 GAS LIFT, 6,285 GAS LIFT, 8,762 GAS LIFT, 7,198 GAS LIFT, 7,515 GAS LIFT, 6061 GAS UFT, 8,381 PBR,8,021 1 PACKER,5035 CATCHER, 8,454 illf PLUG,8,055 GAS LIFT, 8,473 GAS LIFT, f 8,545 In - MI MI IIIII - 1. WHIPSTOCK, I • L 1 i SLOT, 87828,848 WINDOW AL2, • 8,8028,814 WHIPSTOCK, I 8 PRODUCT8ION19 , %9.279 ■ t SLOT, 354-9 486 SLOT, 9,100-10,209 SLOT, 9,150-10,822 Mandrel Details SLOT, 9,488-10,974 Top Depth Top Port AL2-01 LINER, (TVD) I ncl OD Valve Latch Size 'FRO Run 6,781-10,823 $b Top(19(8) (RKB) I') Make Model (In) Sera Type Type (in) (psi) Run Dab Com...\ MI 11 8,544.5 6,349.5 39.15 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 12 8,890.3 6,616.8 52.78 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 AL2 LINER, 9,344-10,915 TD(1 R-06AL2), 10,915 AL1-01 LINER, IIF'. 8,815-11,605 1 11 0 ASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONT ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. Q j P.O. B:g695 10 Re: Kuparuk River Field, Kuparuk Oil Pool, 1R-06AL2 Sundry Number: 310-333 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this / day of October, 2010. Encl. EG1 D •' ,, (0 STATE OF ALASKA /e, �t 0 }per ALASK _ AIL AND GAS CONSERVATION COMMISSk.�J S F P 2 . 2010 1 o APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska 61&ON COL rr lsssion 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Aram r I Suspend r Rug Perforations r Perforate r Pill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate Alter casing g r Other: PROD to WINJ F.- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p . Exploratory r 210-058 ' 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21331-61 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1R-06AL2 • 9.Property Designation: 10.Field/Pool(s): ADL 25635 Kuparuk River Field/Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD/141): Total Depth (ft): Effective Depth M ): Effective Depth TV ): A Plugs(measured): Junk(measured): jc'li gno4�fi,l'. ,+G2 'Jr1 .4°>l0.9i<-1 q,,4f' C 6 /e-`1' Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 4622 12 4659' 3694' WINDOW"A" 12 8 8832' 8832' PRODUCTION 9244 7 9279' 6729' "AL2"LINER 1571 2.625 10915' 6759' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:9354-9486;9488-10914 6723-6725;6725-6759 3.5 J-55 8931 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER'FHL'PACKER MD=8435 TVD=6266 PACKER-BAKER'FB-1'PACKER MD=8909 TVD=6628 SAFETY VLV-CAMCO TRDP-1A SSSV MD=1908 TVD=1850 12.Attachments: Description Sunmary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service p Y 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/15/2010 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Printed Name Robert D. Christensen Title: Production Engineering Specialist Signature Phone:659-7535 Date ()7/.2 7-7//e) Commission Use Only Sundry Number: ')D-533 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test FrLocation Clearance r Other: Subsequent Form Required: / 0 •4/0 ( APPROVED BY /D /CL// ,l Approved by: �/ COMMISSIONER THE COMMISSION Date: (J M QC 0:4 11' 1, �� /.Sr 1L:. :4, rC, Form 10-403 Revised /2010 �3 R I L I I\I� L /d•`'/O Sub41;W Du li t 1 R-06AL2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 1 R-06AL2 (PTD 210-058)from Oil Production service to Water Injection service. Well 1 R-06AL2 (CTD Sidetrack)was completed in the Kuparuk formation on July 19, 2010 as a pre-producing injector with initial production commencing on July 25, 2010. Conversion to Injection service is required due to potential reservoir depletion. The 16"Conductor was cemented with 215sx of CS II. The 9-5/8"Surface casing (4659' and/3694'tvd)was ° cemented with 1390sx Permafrost E and 425sx PF C. The 7" Production casing (9279' and/6729'tvd)was cemented with 510 sx Class"G"and 250sx PFC. The top of the Kuparuk B sand was found at 8820' and/6568'tvd. The top of the Kuparuk A3 sand was found at 10248' and/6670'tvd. The injection tubing/casing annulus is isolated via Baker FHL Packer located @ 8435' and/6266'tvd. • . KUP 1R-06AL2 ConocoPhillips Well Attributes Max An le&MD TD AI,1,n,1111, Wellbore APIIUWI Field Name Well Status Inch(°) MO(f6(B) Pct She(RKB) (nnocciPn,lho 500292133161 KUPARUK RIVER UNIT INJ Comment H2S(ppm) Date Annotation End Date KB-lord(R) Rig Release Date • Well Conte.-1R-O6AL2 7212011112 04.20 PM —SSSV:TRDP Last WO: 37.61 5/15/1985• Schematic-Actual Annotation Depth(HI(B) End Oats An notation Last Mod...End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 HANGER,33 Casing Strings I Casing Description String 0... String ID...Top(868) Set Depth(f...Set Depth(TVD)...String Wt...String...'String Top Thrd WINDOW AL2 8 6.000 8,802.0 8,814.0 Casing Description String 0... String ID...Top(ftKB) Set Depth(6...Set Depth(TVD) . String Wt...String...Stang Top Thrd CONDUCTOR, I I AL2 LINER 2 3/8 1.995 9,344.1 10,915.0 4.43 L-80 SR 38-110 O Liner Details Top Depth t (TVD) Top Inch None... SAFETY�90V9 r Top(FMB) MB) 1°) Item Description Comment ID(in) 9,344.1 Anchor billet Anchored billet 1.000 OAS LIFT, oat 9,978.1 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 GAS LIFT, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 4,326 Top Depth (TVD) Top Intl SURFACE, Top(6868) (RK8) 1°) Description Comment Run Date ID in 37-4,859 8,800 WHIPSTOCK BOT 3.5"morobore WS w/retrieval tang/4-deg ram 7/5/2010 1.000 GAS LIFT, P 5,831 removed EMI GAS LIFT, 6,286 1N- Perforations&Slots GAS LIFT, Shot B762 ME ' Top(TVO) Btm(TVD) Dens OM Top(RK8) Btm(RK8) MKS) (tti(B) Zone Date leh..• Type Comment GAS LIFT, 9,354 9,486 7/12/2010 32.0 SLOT Alternating solid/slotted pipe- 7,198 4 circumferential 1E 0.125"x2.5" GAS uFT, adjacent rows,3"centers staggered 7.615 ,Itr1_ 18 deg,3'non-slotted ends GAS LIFT,1 9,488 10,914 7/12/2010 32.0 SLOT Alternating solid/slotted pipe- 8,081 GAS LIFT y 0.125"12.5"@ 4 circumferential 8381,_. T • adjacent rows,3"centers staggered 18 deg,3'non-slotted ends PBR.8,421 --- PACKER,8.435 Notes:General&Safety _ End Date Annotation Ilk GAS LIFT, 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED e.473 L 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, 8,545 - WHIPSTOCK, 8,801 WINDOW AL2, • 8,8028,814 WHIPSTOCK, 6,819 WINDOW'A', ° 6,820-8,832 T GAS LIFT i ir---- - MMG,LIFO LOCATOR. f PACKER,8,909 r SBE,8.913 r Clan,8,921 /y..�1\ NIPPLE,8,924 ( 4 SOS,8,931— -- V� FISH,9.145' -- 4 PRODUCTION. Mandrel Details 59.279 Top Depth Top Port (TVD) Intl OD Valve Latch Site TRO Run Stn Top(FMB) (RKB) (°) Make Model (In) Sera Type Type (In) (Pei) Run Date Com... ■ SLOT, 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 4.3549.448 2 4,326.0 CAMCO'KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 721/2010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 sl-or. 4 6,285.1 CAMCO'KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7/21/2010 9,n1t0,244 5 6,7622 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987' 6 7,198.2 CAMCO'KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 9,4eL10,014 7 7,615.3 CAMCO'KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7212010 'A'LINER, 8 8,060.9 CAMCO'KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 a,4e010.245 9 8,381.1 CAMCO'KBUG 1 1/2 PROD OV rdo20 0.188 0.0 7212010 AL2 LINER, 9,34410,915\ 10 8,473.5 CAMCO'MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993' TO(1 R-06AL2), 10,940 VA Ill MI BiZ meow agi hos aviz ri3C° __ -:,--.: i•-i - 7 4 , . 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(/) 0 0 Z ,c.0 I, ‹C (..) 62 - < C.) r) ama. ocLa oc..9oa mu) an ct 0 I— I STATE OF ALASKA • ALASK IL AND GAS CONSERVATION COMMIS`_.1N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other pi' Pre-Prod Inj Alter Casing Pull Tubing <30 days 9 r 9 r F�rforate New Fbol r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Current Well Status: \.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-058 3.Address: \.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r • 50-029-21331-61 7.Property Designation: 8.Well Name and Number: ADL 25635 \1 R-06AL2 9. Field/Pool(s): \, Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 10915 feet Plugs(measured) None true vertical 6759 feet Junk(measured) None Effective Depth measured 10915 feet Packer(measured) 8435,8909,8921 true vertical 6759 feet (true vertucal) 6266,6628,6634 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 9.625 4659 3694 0 0 PRODUCTION 9244 7 9279 6729 0 0 Slotted Liner 1571 2.375 10915 6759 0 0 RECEIVED 1 1 Perforation depth: Measured depth: Slotted 9354-9486;9488-1091A AUG 1 2010 True Vertical Depth: 6723-6725;6725-6759 Alaska Ell&Gas Cans.Commission Tubing(size,grade,MD,and ND) 3.5,J-55,8931 MD,6640 ND nCilifag6 Packers&SSSV(type,MD,and ND) PACKER-BAKER'FHL' PACKER @ 8435 MD and 6266 ND PACKER-BAKER'FB-1'PACKER @ 8909 MD and 6628 ND SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 781 3029 760 1267 164 13.Attachments 14.Well Class after proposed work: \ Copies of Logs and Surveys run Exploratory r Development r Service 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WAG r GASINJ r WI J r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell Humphrey Printed Name Robert . . Christensen Title Production Engineering Specialist Signature / ` it Phone:659-7535 Date © !`/`el Aof) Form 10-404 Revised 7/2009 / RBDAAS AUG 1� 2010 " �/L-/o Submit Original Only 1 R-06AL2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/20/10 MEASURED BHP @ 8500' MD: 3154 PSI. SET CATCHER. PULLED DV @ 8381' RKB, SET 3/16"OV @ SAME. PULLED DVs @ 7615' &6285' RKB, SET GLVs @ SAME. IN PROGRESS 07/21/10 PULLED DVs @ 4326'&2041' RKB. SET GLVs @ SAME. BLED IA TO CONFIRM GLVs SET. PULLED CATCHER. COMPLETE. 07/25/10 OPEN WELL- RETURN TO SERVICE KUP 1 R-06AL2 4. ConocoPhillips Oen Attributes Max Angle&MD TD 1,ItiM.1 III: Well bore API/UWI Field Name Well Status I ncl(") MD((MB) Act!Urn(BNB) L«ncarah,ps 500292133161 KUPARUK RIVER UNIT INJ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Gunfi9..-1 R-06AL2,7/212010 12:44:20 PM _SSSV:TRDP Last WO: 37.61 5/15/1985 __ _ Schematic-Ptlual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date _ Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 MANGER,33 Casing Strings �� �i WINDOW W A Description String 0... String ID..Top,80. Set Depth(/.. Set Depth(TVD)..String WL..String...String Top Thrd WINDOW AL2 8 6.000 8,802.0 8,814.0 Cuing Description String 0... String ID..Top(RKB) Set Depth(f...Set Depth(TVD)..String Wt...String...String Top Pled CONDUCTOR, AL2 LINER 23/8 1.995 9,344.1 10,915.0 4.43 L-80 STL 3a„0 Liner Details Top Depth (TVD) Top Inc! Nomi... ETV L Top(R (KB) B) (°) Item Description Comment ID(In) MIN 9,344.1 Anchor billet Anchored billet 1.000 GAS LIFT, L — 2,041 I 9,978.1 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 GAS LIFT, r■ ... Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth •J 1� (TVD) Top Intl SURFACE, Top(IIKB) VOW 1°I Description Comment Run Dab ID(In) GAS LIFT, 8,800 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 7/5/2010 1.000 5631 removed GAS B 295 Perforations&Slots Shot GAS LIFT, Top(TVD) Btm(TVD) Dens 8783 Top(Itl(B) etm(RKB) (RKB) (RKB) Zone Dab ph... Type Comment GAS LIFT, 9,354 9,486 7/122010 32.0 SLOT Alternating sdid/slotted pipe- 7,198 0.125"x2.5"@ 4 circumferential GAS LIFT, adjacent rows,3"centers staggered 7,615 18 deg,3'non-slotted ends GAS LIFT, 9,488 10,914 7/12/2010 32.0 SLOT Alternating solid/slotted I (5,061 9 PPe- 0.125"x2.5"@ 4 circumferential GAS LIFT. adjacent rows,3"centers staggered 8.381 f 18 deg,3'non-slotted ends PeR 8,421 PACKER,5435 Notes:General&Safety ® End Date Annotation GAS LIFT, 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 6 e,473 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, 8,545 I I • WHIPSTOCK, 8.801 WINDOW AU. • • 8,502-6,814 WHIPSTOCK, ILFF 8519 WINDOW'A", • 8,820-8.832 GAS LIFT ii MMG,8,890 LOCATOR, frr{ 8,908 PACKER,8,909 \ SBE,8,913 / CIBP,8,921- si♦-4•11111 NIPPLE,8,924 SOS.8.931 FISH,9,145 —4 PRODUCTION, 1 Mandrel Details 35-9,279 Top Depth Top I I Port I (TVD) Inc! OD Valve Latch Side TRO Run Stn Top(RKB) IRKS) (°I Make Model (In) Sery Type Type (In) (psi) Run Date Com... SLOT, 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 A354.5488 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.07212010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 sL,2M Or. 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7212010 9,471.10 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY 'BK 0.000 0.011/10/1987 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY 'BK 0.000 0.0 6/30/1985 9,485 OL91/ 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7212010 ./1.LINER, 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.011/10/1987 9.460-10,245 9 8,381.1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 721/2010 AL2 LINER, 9,344-10,915\ 10 8,473.5 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 TD O R-06AL2), 10,940 • • KUP 1 R-06AL2 ConocoPPhillips • Al,itil.,i 41,. laroceth I pc KB-Grd(N) Rig Release Date ••• WN-Cono..-1R-06AL2 7212 2 01014420 PM 37.51 5/15/1985 Schematic-Actual HANGER,33 CONDUCTOR, 11 I 35-110 SAFETY VLV, � , 1.908 IF GAS LIFT, 2,041 GAS LIFT, 4,326 SURFACE, i, GAS LIFT, 5,631 C GAS LIFT, i 6,285 GAS LIFT, ff 6,762 GAS LIFT, BE 7,198 it GAS LIFT, ■ 7,615 7 r GAS LIFT, r t 8,061 T GAS LIFT. 8,381 PBR,8,421 iij PACKER,8,435 as GAS LIFT, i 8,473 GAS LIFT, 6 8,545 I r 1 WHIPST ''n\\OCK, \ 8,801 WINDOW AL2. • 8,802A,814 WHIPSTOCK, 1 \ • 8,619 WINDOW NV. 8.8208.832 1 1 GAS 088 LIFT M GA 90 LOCATOR, 8,908 PACKER.8,909 SHE,8,913 •f---C EA CIBP,8,921 NIPPLE,8,924 - I I SOS.8,931 - — FISH,9,145 -4 PRODUCTION, etalls 36-9,279 ` Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (In) Sane Type Type (in) (psi) Run Data Com... SLOT. 11 8,544.5 CAMCO MMG-2 1 12 PROD DMY RK 0.000 0.05/21/2010 9,354-9,488 12 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN 0.000. 0.05/21/2010 SLOT, 9,Q7-10,2M SLOT, 9.488-10914 'A'LINER, 9,460-10,245 AL2 LINER, 9,344-10,915 TD(1 R-06AL2), 10,940 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil El Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Cla 20AAC 25.105 20AAC 25.110 Development Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service L. Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: July 19,2010 210-0580/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 July 6,2010 50-029-21331-61 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 272'FNL,222'FEL,Sec. 19,T12N,R10E, UM • July 12,2010 • 1 R-06AL2 . Top of Productive Horizon: 8. KB(ft above MSL): 84'RKB 15.Field/Pool(s): 1176'FSL,902'FWL,Sec. 19,T12N,R10E,UM GL(ft above MSL): AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2434'FNL, 1284'FWL,Sec. 19,T12N, R10E,UM 10915'MD/6759'TVD Kuparuk River Oil Pool• 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-539470 • y- 5990930 • Zone-4 • 10915'MD/6759'ND • ADL 25635 TPI: x-535794 y- 5987080 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-536168 y- 5988752 Zone-4 1908'MD/1850'ND 2560 18.Directional Survey: Yes 0 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) 1550'MD/1527'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 8802'MD/6553'ND 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. 110' Surf. 110' 24" 215 sx CS II 9.625" 36# J-55 Surf. 4659' Surf. 3694' 12.25" 1390 sx Permafrost E,425 sx PF C 7" 26# J-55 Surf. 9278' Surf. 6975' 8.5" 510 sx Class G,250 sx PFC 2.375" 4.7# L-80 9344' 10915' 6723' 6759' 3" slotted liner 24.Open to production or injection? Yes 0 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 8932' 8435'MD/6266'ND slotted liner from 9344'-10914'MD 6723'-6759'ND 8909'MD/6628'ND `"'"# rrr��'''' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 44,4° none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) July 25,2010 pre-produced injector-flowback in progress Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/31/2010 16 hours Test Period--> 389 2317 459 209% _ 5952 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 165 psi 1263 24-Hour Rate-> 584 3476 689 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 . Sidewall Cores Acquired? Yes ❑ No ig 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. RECEIVED NONE AUG 0 4 2010 Alaska el Si Gas nn cc,Com Commission Form 10-407 Revised 12/1DMS AUG 0.4 20 CONTINUED ON REVERSES"ubhnRr�lal only kr5s6 ,A1> It • 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1550' 1527' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk B Sand 8893' 6601' Top Kuparuk A Sand 9101' 6679' N/A Formation at total depth: Kuparuk A3 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: Gary Eller @ 263-4172 Printed Na V.Cawv Title: Alaska Wells Manager Signature Phone 265-6306 Date e/ 3 ro Sharon All up-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 Time.Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:30 04:30 1.00 11,605 8,800 COMPZ CASING TRIP P p/U weight 38K,Set back down, bring pump up to 1.2 bpm, disconnect off liner-P/U weight 26K. come up 20 ft and set up to pump down backside while POOH to window. Liner segment#1 set 10209'- 11605'. 04:30 07:18 2.80 8,800 0 COMPZ CASING TRIP P POOH Pumping 11.5 ppg KWF down the CT. NOTE:Inteq counter slipped-400' while POOH. Counter wheel showed wear-replaced. 07:18 08:18 1.00 0 0 COMPZ CASING PULD P LD BHA. 08:18 11:30 3.20 0 0 COMPZ CASING PUTB P PJSM. PU liner segment#2- indexing shoe,34 jnts slotted,9 jnts solid,4'pup,shorty deployment sleeve. 11:30 11:54 0.40 0 0 COMPZ CASING PULD P MU BHA#17 onto liner. 11:54 14:54 3.00 0 8,820 COMPZ CASING RUNL P RIH with liner segment#2. Bobble at 9060'but otherwise run to bottom without trouble. 14:54 15:06 0.20 8,820 8,820 COMPZ CASING TRIP P Circulate to release liner. Liner segment#2 set 8814'-10209'. POH. 15:06 15:12 0.10 8,820 8,350 COMPZ CASING DLOG P Tie into K1 marker, +8'correction. Top of liner(corrected)=8822'. 15:12 17:18 2.10 8,350 0 COMPZ CASING TRIP P POH. 17:18 17:48 0.50 0 0 COMPZ CASING PULD P PJSM, LD BHA#17. 17:48 19:30 1.70 0 71 PROD4 RPEQP1PULD P PU whipstock BHA#18 19:30 22:00 2.50 71 8,800 PROD4 RPEQP1TRIP P Open EDC-RIH slowly the first 300 ft,Start pumping. 3bpm, RIH 60 fpm.Tie in @ 8350.Corection+8ft. Weight check-27K. RIH to 8815' P/U to 8810'26K, HS orientation. IA -300 OA"0" 22:00 22:30 0.50 8,800 8,800 PROD4 RPEQP1WPST P Close EDC-Bring pumps up to 1 bpm,3600 psi,Setting tool pressure drop to 1500 psi. Set down 3K WOB.Top of WS set @ 8800.55'- Good set 22:30 00:00 1.50 8,800 83 PROD4 RPEQP1TRIP P POOH laying in KWF. 07/06/2010 Mill 3.5"window exit from 8802.0 to 8808.0. POOH, Perform BOPE Function test, RIH with 7"exit BHA,Tag @ 8807.2 00:00 01:00 1.00 83 0 PROD4 RPEQP1 PULD P Ct @ surface-flow check well. Lay down WS BHA. 01:00 01:30 0.50 0 73 PROD4 WHPST PULD P P/U Milling BHA.Open EDC. 01:30 03:30 2.00 73 8,780 PROD4 WHPST TRIP P RIH pumping.3 bpm.Tie in correction+8 ft. 03:30 04:30 1.00 8,780 8,802 PROD4 WHPST CIRC P Circulate B/U to recover KWM. 04:30 05:00 0.50 8,802 8,802 PROD4 WHPST MILL P Stop pumping,Close EDC. Dry tag TOWS @ 8802.2', P/U start pumping 1.45 bpm,3600 psi free spin. Page 20 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code' Subcode T` Comment 05:00 09:00 4.00 8,802 8,805 PROD4 WHPST MILL P RIH slowly from 8801.5'-motor work detected @ 8802'. Start milling-1.45 bpm,3750psi, BHP 3970psi,WOB.8K,Ct weight 7.4K,Auto drill set up-1fph. Seeing cement in the sample by 2.2'into it. 09:00 11:00 2.00 8,806 8,805 PROD4 WHPST MILL P See spike in motor work @ 8805.6'; walked through and see increase of ROP,decrease in pump pressure (-3700 psi).Appear to have exited tubing.Mud pump#2 leaking out cap, PUH clean and bring pump#1 online and begin working pumps in tandem. RBIH and ease back down to 8805',see motor work again where we left it @ 8805.6.Window area appears clean. 11:00 13:00 2.00 8,807 8,807 PROD4 WHPST MILL P At 8806.75'. Pumping 1.44 BPM, 3870 psi, BHP=3948 psi.WOB _ 2.55k, ROP set @ 0.8 fph. 13:00 14:30 1.50 8,807 8,808 PROD4 WHPST MILL P At 8808'. Begin PUH @ 1'fpm for reaming passes through window to top of whipstock. Pumping 1.45 bpm, 3965 psi,3958 psi BHP.Good clean passes with little to no motor work. 14:30 16:45 2.25 8,808 0 PROD4 WHPST TRIP P Open EDC&POOH following MPD. 16:45 18:45 2.00 0 0 PROD4 WHPST PULD P PJSM,Close EDC,Tag up, UnDeploy BHA#19 18:45 19:45 1.00 0 0 PROD4 WHPST BOPE P Blow down stack, Perform Bi-weekoly BOPE Function test 19:45 21:15 1.50 0 0 PROD4 WHPST PULD P PJSM, P/U BHA#20,2 degree fixed bend Weatherford motor with 2.80"fat radius mill 2.81 go 2.80 NoGo 21:15 23:27 2.20 0 8,360 PROD4 WHPST TRIP P Trip in well with BHA#20 23:27 23:42 0.25 8,360 8,389 PROD4 WHPST DLOG P Log Gamma tie in,+6.5'.Close EDC RIH to mill 7"caseing exit PUW=28K, RIW=10K with no pumps 23:42 00:00 0.30 8,389 8,807 PROD4 WHPST TRIP P 8807.8, Dry tag window, PUH and roll on pumps 1.4 BPM @ 3800PSI FS 8807.2 600lbs WOB,40 PSI Motor work 07/07/2010 Complete Dual String window. P/U Build section BHA, Drill Ahead 00:00 03:45 3.75 8,808 8,810 PROD4 WHPST MILL P 8807.2',Milling 7"casing exit per program 03:45 06:45 3.00 8,810 8,812 PROD4 WHPST MILL P 8809.5.Motor work and WOB dropped off. Possible 7"exit,2.3' down from contact point.Continue @ 1 FPH Page 21 of 33 Time Logs Date From To Dur S.Depth_E. Depth_Phase Code Subcode T Comment 06:45 07:45 1.00 8,812 8,812 PROD4 WHPST MILL P Getting better WOB transfer 2-3K. ROP 1 fph,CT weight 8K.Cement with fine medal shavings in returns. P/U due to no movement and WOB 4K,stacking out. 1.45 bpm,3570psi, BHP 3952, ROP 1.1 fph,WOB 4K, CT weight 8.8K,differential 625 07:45 11:15 3.50 8,812 8,820 PROD4 WHPST MILL P P/U clean 30K, RIH 4 fpm.WOB 3.7K @ 8812.1', Better motor work. Popped through @ 8812.70' WOB dropped to 1K.Start time milling down to 8820' ROP 2 fph,then 5 fph. Formation in returns. 11:15 12:45 1.50 8,820 8,820 PROD4 WHPST REAM P Start backreaming from 8815'to 8800'as per procedure. No motor work detected.Total of 3 passes @ 1 fpm.Shut down pumps-dry run- Clean. 12:45 15:45 3.00 8,820 74 PROD4 WHPST TRIP P Open EDC&POOH, P/U weight 29K. 15:45 17:15 1.50 74 0 PROD4 WHPST PULD P CT @ surface. Undeploy BHA.Mill came out 2.79"No-go 17:15 19:00 1.75 0 0 PROD4 DRILL SVRG P Service Injector,Gripper block bolt broken. E-Z out Crew change, Prep to cut coil,then got call from town changing their mind. 19:00 21:00 2.00 0 0 PROD4 DRILL PULD P PJSM, Deploy BHA#21 with 2.4 degree motor bend with re-run Hughs with cheetah cutters,Surface test good Open EDC 21:00 23:00 2.00 0 8,340 PROD4 DRILL TRIP P RIH 23:00 23:15 0.25 8,340 8,365 PROD4 DRILL DLOG P Gamma Tie in log, +6.5', Close EDC PUW=28K, RIW=10K 23:15 23:27 0.20 8,365 8,819 PROD4 DRILL TRIP P RIH to drill 23:27 00:00 0.55 8,820 8,838 PROD4 DRILL DRLG P Slight bobble @ 8809,Tag @ min rate 8819.1 PUH, Line up on new mud 1.45 BPM@ 3500 PSI BHP=3960 8838 Midnight Depth 07/08/2010 RIH with 2.45 Degree motor drilled 8838 to 8870. High DLS POOH,dial down to 2.2. Drill build 8870 to 9255. POOH for RibSteer 00:00 01:00 1.00 8,838 8,870 PROD4 DRILL DRLG P Drill ahead from Midnight-Mud swap. 01:00 01:30 0.50 8,870 8,350 PROD4 DRILL WPRT T Higher then anticipated DLS Avg 53 degrees Pull off bottom to crunch numbers explore alternatives Pull up through window to log K-1 Marker 01:30 01:45 0.25 8,350 8,381 PROD4 DRILL DLOG P Log K-1 to tie in RA marker 01:45 01:57 0.20 8,381 8,820 PROD4 DRILL TRIP P Trip in well to log RA Page 22 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:57 02:03 0.10 8,820 8,833 PROD4 DRILL DLOG P Log RA to Tie in marker, RA is at 8808.0 TOW=8802 02:03 04:03 2.00 8,833 0 PROD4 DRILL TRIP T POOH to dial down motor angle 04:03 06:03 2.00 0 0 PROD4 DRILL PULD T At Surface, PJSM. Undeploy BHA #21 06:03 08:03 2.00 0 62 PROD4 DRILL PULD T Deploy BHA#22 with a 2.2 AKO instead of 2.45 AKO. 08:03 10:33 2.50 62 8,860 PROD4 DRILL TRIP T Open EDC-RIH following MPS.Tie +6.5',stop pumping close EDC-RIH through window,slight bobble @ 10 fpm. @ 8809'. 10:33 13:33 3.00 8,870 9,020 PROD4 DRILL DRLG P Bring pumps online.drilling ahead- 1.42 bpm,3300 psi, BHP 3910psi, ROP 40,WOB 1.7K,CT weight 8K, returns 1.38 bpm. ECD 11.6 13:33 14:03 0.50 9,020 9,020 PROD4 DRILL WPRT P Wiper trip-P/U weight 30K-Had weight transfer issues going back down,pumping 0.3 bpm, P/U and re-orientate down @ 8914'. 14:03 17:03 3.00 9,020 9,104 PROD4 DRILL DRLG P Drilling ahead-1.40 bpm,3600 psi, BHP 3990, ECD 11.7, ROP 40, WOB 2.5K,Ct weight 7K. 17:03 20:03 3.00 9,104 9,170 PROD4 DRILL DRLG P Quick P/U 30K,due to weight transfer&ROP. Drilling ahead. 20:03 20:33 0.50 9,170 9,170 PROD4 DRILL WPRT P Wiper trip to window PUW=34k Overpulls @ 9091 and 8900 20:33 22:45 2.20 9,170 9,251 PROD4 DRILL DRLG P Drill Ahead 1.45 BPM @ 3822 FS RIW=7K, ROP 60-40 FPH BHP=4065 22:45 23:09 0.40 9,251 9,255 PROD4 DRILL DRLG P Lost motor work and WOB, P/U and have to run back in and dial up traction pressure.46K off bottom. Perform BHA Wiper, ROP 10-15 FPH continue to drill ahead 23:09 00:00 0.85 9,255 7,238 PROD4 DRILL TRIP P 9255, Drilling break looks like back up out of Ankorite.Trip out for RibSteer PUW=32K 07/09/2010 RIH w/RibSteer drill to 9464, POOH to inspect BHA. 00:00 01:30 1.50 7,238 0 PROD4 DRILL TRIP P Continue out of well for RibSteer 01:30 03:00 1.50 0 0 PROD4 DRILL PULD P PJSM,At surface, Undeploy BHA #22 Bit came out with 3 out of 4 nozzles plugged off Connector to lower quick packed with clay MBT up to 0.25 03:00 04:15 1.25 0 68 PROD4 DRILL PULD P PJSN, Deploy BHA#23 Ribsteer with rebuilt Hughes Bi-Center with Cheetah cutters Page 23 of 33 Time Logs Date ' From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:15 06:45 2.50 68 9,255 PROD4 DRILL TRIP P RIH following MPS-tie in with+6.5'. Close EDC-RIH through window 20 fpm-saw about 2K weight resistance but no tag. RIH pumping mina rate to bottom,clean all the way down. 06:45 10:45 4.00 9,255 9,350 PROD4 DRILL DRLG P Drilling ahead-1.45 bpm,3600 psi, BHP 4055, ECD 11.7,ROP 20, WOB 3.17,CT weight 6K. Drilling in/out of Ankerite. Needing to set down 3K+to get through harder Ankerite stringers then 1.5K in faster ROP areas. 10:45 11:45 1.00 9,350 9,350 PROD4 DRILL DLOG P Wiper trip&MADD pass. P/U weight clean @ 29K. 9200'&9105'slight weight drag and small pressure spike POOH. 11:45 13:45 2.00 9,350 9,422 PROD4 DRILL DRLG P Drilling ahead-erratic drilling from 9375'Motor work,quick drill off. ROP 30-50.CT weight 9K,WOB 2K, 1.45 bpm,3800 psi, BHP 4085, ECD 11.8 13:45 14:45 1.00 9,422 8,600 PROD4 DRILL WPRT P Weight check-heavy motor work and no WOB. P/U weight 35K, lots of motor dP.Wiper up to window to clean up hole. Bore and differntial pressure increased during wiper. Slow POOH due to possible packing off @ bit. Mix up Hi-lo sweeps. 14:45 15:15 0.50 8,600 8,600 PROD4 DRILL CIRC P Pull into cased hole,slight 1K drag at window and differential pressure dropped off to nearly normal. P/U 300'pumping through bit,stop open EDC and circ. B/U. Heavy thick returns to surface. 15:15 15:45 0.50 8,600 9,422 PROD4 DRILL TRIP P Increase clay stop to 3%and add drillzone to to-vis sweep for bit balling.Close EDC-RIH. Pump Low/High sweeps with drill zone. Quick weight check before TD. P/U weight 28K-clean. 15:45 16:39 0.90 9,422 9,464 PROD4 DRILL DRLG P Drilling ahead-1.40 bpm,3700psi, BHP 4000, ECD 11.7,WOB 2K,Ct weight 10K, ROP 50,ratty drilling. 9460'- P/U 40'clean 31K. 16:39 18:09 1.50 9,464 9,464 PROD4 DRILL CIRC T Packed off above the bit again, P/U weight 32K,Circ press.4100 psi. Seems like bit balling again. P/U and pump low/high sweeps. 18:09 19:39 1.50 9,464 8,550 PROD4 DRILL WPRT T Wipe to window. Differential pressure high, Bore pressure 4700 to 5200. Pull up through window and pump 5 BBI sweep of drill zone to clear bit. No pressure change through window or after sweep 19:39 21:39 2.00 8,550 0 PROD4 DRILL TRIP T Open EDC and pull to surface to check BHA Bit, FVS, Page 24 of 33 Time Logs Date From To Dur S.Depth'E.Depth Phase Code Subcode T Comment 21:39 22:39 1.00 0 0 PROD4 DRILL PULD T PJSM, Undeply BHA#23 22:39 00:00 1.35 0 0 PROD4 DRILL PULD T L/D BHA found RSM output shaft dropped 1.7 inches. Bit @ 1-1 with two plugged nozzles on nose 07/10/2010 Drill from 9464 to 9600.Circ pressure high,swap mud, POOH to diagnose High pressure, Ball valve partialy shut.Swap out DBV. RIH and drill to 9960 00:00 01:00 1.00 0 0 PROD4 DRILL PULD T Finish testing BHA#24 and load into PDL 01:00 02:00 1.00 0 0 PROD4 DRILL PULD T PJSM, Deploy BHA#24 into well, Surface test 02:00 04:00 2.00 0 8,350 PROD4 DRILL TRIP T RIH 04:00 04:09 0.15 8,350 8,386 PROD4 DRILL DLOG T Tie into formation for a+7'correction 04:09 04:45 0.60 8,386 9,464 PROD4 DRILL TRIP T Trip in well to drill Good pass through window tight spot @ 9112. No setdown 04:45 07:15 2.50 9,464 9,600 PROD4 DRILL DRLG P 9464'Drill Ahead 1.2 BPM @ 4090 FS ROP=50 to 70 FPH @ 2K WOB Circ pressure up to 4300psi.Quick weight check-32K, By pass filters- no change-screens clean. Possible BHA ball valves or old mud. 07:15 08:15 1.00 9,600 8,780 PROD4 DRILL WPRT T Wiper trip due to stall&no working limits. P/U weight 35K. 1.20 bpm, 4300 psi, BHP 4080, ECD 11.7. Pull into cased hole to diagnose Downhole-surface pressures. 08:15 08:45 0.50 8,780 8,780 PROD4 DRILL CIRC T Open EDC-Bring pumps up to check old mud rate vs new mud rate. Old-1.3 bpm=4350 psi New 1.3 bpm=4100 psi(38 bbl pumped)-continue pumping new mud,chase old mud out&POOH to inspect BHA. 08:45 11:15 2.50 8,780 68 PROD4 DRILL TRIP T POOH-new mud in system.CT at surface-Circulate 1.2 bpm to check pressure-4160 psi. 11:15 14:00 2.75 68 0 PROD4 DRILL PULD T Break off BHA-check upper CT connector and ball valves. Lower ball valve was 1/2 closed. Undeploy BHA to replace ball valves. 14:00 14:30 0.50 0 0 PROD4 DRILL SVRG P Injector maintainence. 14:30 15:30 1.00 0 68 PROD4 DRILL PULD T Deploy BHA, Surface test,Tag stripper check pressures 15:30 17:15 1.75 68 8,350 PROD4 DRILL TRIP T Circ 1.3 bpm=3000 psi, RIH with EDC open pumping .45 bpm. 17:15 17:27 0.20 8,350 8,376 PROD4 DRILL DLOG T Gamma tie in for a+6'correction Close EDC, RIH to drill 17:27 17:57 0.50 8,376 9,599 PROD4 DRILL TRIP T Trip in well to Drill,good pass through window 17:57 19:33 1.60 9,600 9,760 PROD4 DRILL DRLG P 9599'Drill Ahead 1.48 BPM @ 3707 PSI FS RIW=9.4K BHP=4150 Page 25 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:33 20:48 1.25 9,760 9,760 PROD4 DRILL WPRT P Wiper trip to window PUW=33K 1.48 BPM@ 3707 FS BHP=4107 20:48 22:18 1.50 9,760 9,910 PROD4 DRILL DRLG P 9760'Drill Ahead 1.50 BPM @ 3700 PSI FS BHP=4102 22:18 23:31 1.22 9,910 9,910 PROD4 DRILL WPRT P 9910 Wipe to window PUW=32K Good clean wiper out and in 23:31 23:59 0.48 9,910 9,960 PROD4 DRILL DRLG P 9910, Drill Ahead 1.5 BPM @ 3650 PSI FS BHP=4105 Midnight Depth 9960 07/11/2010 Drill from 9960 to 10786, Lost 18 BBIs 9.4 to formation 00:00 01:00 1.00 9,960 10,060 PROD4 DRILL DRLG P Drilling ahead 1.5 BPM @ 3650 PSI FS BHP=4105 01:00 01:33 0.55 10,060 8,825 PROD4 DRILL WPRT P Wipe to window with tie into RA Marker 01:33 01:48 0.25 8,825 8,847 PROD4 DRILL DLOG P 8825, Log RA marker,-1'correction continue wiper trip 01:48 02:18 0.50 8,847 10,060 PROD4 DRILL WPRT P Wipe to bottom Good clean wiper trip,No over pulls or setdowns 02:18 03:51 1.55 10,060 10,210 PROD4 DRILL DRLG P 10060', Drill ahead 1.5 BPM @ 3675 PSI FS BHP=4130 03:51 05:15 1.40 10,210 10,210 PROD4 DRILL WPRT P 10210',wipe to window PUW=33k, BHP=4181 Clean wiper in and out 05:15 07:15 2.00 10,210 10,360 PROD4 DRILL DRLG P 10210', Drill ahead 1.5 BPM @ 3700PSI FS RIW=12K BHP=4146 07:15 08:45 1.50 10,360 10,360 PROD4 DRILL WPRT P Wiper trip-31K,clean all the way- slight drag from 9197-9107'. 08:45 11:15 2.50 10,360 10,510 PROD4 DRILL DRLG P Back on bottom drilling-Start turning up to stay in A-4. 1.46 bpm, 4000psi, BHP 4152, ECD 12, ROP _ 90,WOB 2.4,CT weight 7K. 11:15 13:45 2.50 10,510 10,510 PROD4 DRILL WPRT P Wiper trip-35K off bottom.Clean wiper-tie in(-1 ft correction) 13:45 16:15 2.50 10,510 10,620 PROD4 DRILL DRLG P Back on bottom drilling-1.45 bpm, 3800psi, BHP 4180, ECD 12.2, ROP 60,WOB 2.4K,Ct weight 5K. 16:15 17:00 0.75 10,620 10,660 PROD4 DRILL DRLG P Started stacking weight-BHA wiper -36K off bottom.Continue drilling ahead-1.45 bpm,4000 psi, BHP 4230psi, ECD 12.2, ROP 60,WOB 2.4,CT weight 2K. 17:00 19:12 2.20 10,660 10,660 PROD4 DRILL WPRT P Wiper trip to window PUW=36K, BHP=4191 Good wiper. lost surface weight in Shales from 10475 to bottom. RBIH 19:12 21:42 2.50 10,660 10,784 PROD4 DRILL DRLG P 10660', Drill ahead 1.48 BPM @ 3700PSI FS BHP=4234 WOB=1.9K RIW=-3K Page 26 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:42 22:27 0.75 10,784 10,784 PROD4 DRILL DRLG P 10784'Stack out Can't get restarted drilling Pull 48K to get moving up, Pump Lo Ho Sweep Clean up to 10450 above shaley area that took most of surface weight. RBIH to drill 22:27 22:39 0.20 10,784 10,786 PROD4 DRILL DRLG P 10784 Attempt to drill ahead Surface weight-10 tag bottom @ multiple speeds Call full wiper 22:39 23:33 0.90 10,786 8,825 PROD4 DRILL WPRT P Wipe to window PUW=37K Pump to-hi sweeps coming off bottom 23:33 23:39 0.10 8,825 8,844 PROD4 DRILL DLOG P Log RA marker+1.5'due to overpull and working pipe 23:39 00:00 0.35 8,844 9,615 PROD4 DRILL WPRT P RBIH to Drill 9615'Midnight Depth 07/12/2010 TD Lateral @ 10915, LAy in beaded pill, Kill well,M/U and run liner to 10303. POOH with liner 00:00 00:36 0.60 9,615 10,786 PROD4 DRILL WPRT P On Wiper trip back to bottom. Shales from 10475 Taking away surface weight. Into-8 to-10 getting on bottom to drill 00:36 02:00 1.40 10,786 10,915 PROD4 DRILL DRLG P 10787,took a few tries to get drilling ahead Got it going 15FPM to bottom then keep feeding pipe stay above 100 FPH got surface weight back 1.5 BPM @ 3986 PSI FS, WOB=1.6K RIW=3K BHP=4284 02:00 02:24 0.40 10,915 10,915 PROD4 DRILL WPRT P Wipe footage just drilled while Lo-Hi going down coil PUW=34k Dragging a little heavy 3 to 4K PUH to 10640 RIH to sweep from bottom 02:24 03:54 1.50 10,915 8,825 PROD4 DRILL WPRT P Lo Hi at nozzle,sweeping off bottom, PUW36, Dragging weight 36-38 03:54 04:00 0.10 8,825 8,844 PROD4 DRILL DLOG P Log RA tie in+1, RIH to lay in liner running pill 04:00 05:15 1.25 8,844 10,915 PROD4 DRILL WPRT P Wipe to bottom to lay in beaded liner pill 05:15 06:15 1.00 10,915 7,800 PROD4 DRILL TRIP P Trip out of well laying in Beaded Pill PUW=38 Corrected TD=10915 06:15 08:30 2.25 7,800 68 PROD4 DRILL TRIP P POOH pumping KWF -Stop @ 7100 to flag pipe. KWF&CT @ surface. 08:30 09:00 0.50 68 0 PROD4 DRILL SFTY P No flow check&safety meeting. 09:00 09:30 0.50 0 0 PROD4 DRILL PULD P Lay down BHA-Get liner running tools ready. Inspect&service injector. 09:30 13:00 3.50 0 1,473 COMPZ CASING PUTB P Start P/U liner.44 joints in total. Page 27 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 13:00 15:30 2.50 1,473 10,287 COMPZ CASING TRIP P RIH pumping.3bpm. EDC closed. 8572'-Correct depth +5.7 ft. Weight check 29K.Smooth through the window. WOB started increasing as the EOP went through window.Starting to push from 10,210'. 15:30 16:00 0.50 10,287 10,300 COMPZ CASING TRIP T Stacking out, P/U weight 48K @ surface-5K WOB.Worked it down to 10,300'. P/U and dragging from 48K-57K.Worked it 3 more times with no success.Weight back to normal @ 9600' 16:00 18:00 2.00 10,300 1,478 COMPZ CASING TRIP T POOH pumping KWF. 18:00 22:00 4.00 1,478 0 COMPZ CASING PULL T Tag up and space out,Close EDC and hold PJSM L/D BHA#26 L/D Liner 22:00 23:30 1.50 0 0 COMPZ CASING CIRC P Roll KWF out of coil and stack, Flush stack. Pull checks out of quick connect,Change packoffs, Test inner reel valve and pack offs 23:30 00:00 0.50 0 0 COMPZ CASING BOPE P Start Full BOPE Test Test witness waived by Chuck Sheeve 07/13/2010 Test BOPE, repair injector,pump slack and cut coiled tubing for pipe life management 00:00 06:00 6.00 0 0 COMPZ CASING BOPE P BOPE Test,Test witness waived by Chuck Sheeve,AOGCC. Procedure steps 1 -through 9 completed.All good.250&3500 psi. 06:00 09:00 3.00 0 0 COMPZ CASING BOPE P BOP test Completed 250 low-3500 high. Function tested alarms, drawdown test&check Koomey pressures. 09:00 10:30 1.50 0 0 COMPZ CASING SLPC P Set up to pump slack back into CT prior to injector repairs. Calibrate Micro Motions with fresh water. Pump slack, Blow down coil. 10:30 12:00 1.50 0 0 COMPZ CASING RGRP T PSJM, Rig up and unstab coil ***Start Nabors rig repair time 12:00 20:00 8.00 0 0 COMPZ CASING RGRP T PJSM, Remove packoff assembly, Skate R&R 20:00 22:00 2.00 0 0 COMPZ CASING RGRP T Install packoff assembly. Stab coil. ***End Nabors rig repair time for today(11.5 hours billable repair time) 22:00 00:00 2.00 0 0 COMPZ CASING SLPC P Cut 1100'of coil for pipe life management 07/14/2010 Completed coil cutting operations, rehead coil. Run cleanout assembly to TD, lay in liner running pill and displace well back to KWF. MU 29 joints slotted liner and RIH. 00:00 02:00 2.00 0 0 COMPZ CASING SLPC P Continue cutting coiled tubing for pipe life management Page 28 of 33 Time Logs Date From To " Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:30 2.50 0 0 COMPZ CASING SLPC P Install CTC,pull test to 30K,rehead E-line,pressure test. Install new pack-offs and make up lubricator and pressure test. 04:30 04:42 0.20 0 0 COMPZ CASING SFTY T PJSM 04:42 05:12 0.50 0 0 COMPZ CASING PULD T PU clean out BHA,#27 05:12 06:12 1.00 0 0 COMPZ CASING DISP T Displace coil to KWF through open EDC 06:12 07:42 1.50 0 8,340 COMPZ CASING TRIP T RIH 07:42 07:48 0.10 8,340 8,367 COMPZ CASING DLOG T Log Gamma tie in for+9'correction 07:48 07:54 0.10 8,367 8,790 COMPZ CASING TRIP T Trip in to window 07:54 09:54 2.00 8,790 8,790 COMPZ CASING CIRC T Circulate/Recover 11.8 KWF 09:54 10:54 1.00 8,790 10,913 COMPZ CASING WPRT T Close EDC,Trip in well,Clean pass through window Clean trip to bottom. Nothing @ 10300 or 10787 RIW+6 to 8K at bottom 10:54 12:24 1.50 10,913 8,850 COMPZ CASING WPRT T Wipe up hole with tool face down 180 degree PUW=33K 1.41 BPM @ 3215, BHP=4298 Clean trip to window, No overpulls or motorwork 12:24 13:54 1.50 8,850 10,913 COMPZ CASING WPRT T RIH to pump lo hi sweeps 13:54 14:54 1.00 10,913 8,820 COMPZ CASING WPRT T Lo-Hi sweeps coming out on bottom, Chase to window and Tie into RA marker 90L TF PUW=35k 14:54 15:00 0.10 8,820 8,837 COMPZ CASING DLOG T Log RA marker 15:00 16:30 1.50 8,837 10,900 COMPZ CASING WPRT T RIH to lay in beaded liner running pill 16:30 19:00 2.50 10,900 0 COMPZ CASING TRIP T POOH laying in beads, Paint EOP flag @ 9800(9862.34) Paint 7700'EOP Flag(7762.34) continue OOH on 11.8 KWF 19:00 20:00 1.00 0 0 COMPZ CASING PULD T Lay down BHA#27, RU for liner ops 20:00 20:12 0.20 0 0 COMPZ CASING SFTY T PJSM for liner 20:12 22:12 2.00 0 983 COMPZ CASING PUTB T PU 29 joints liner, inteq tools, 'Eller profile bulinose" 22:12 00:00 1.80 983 COMPZ CASING RUNL T RIH,0.3 BPM 07/15/2010 Ran liner in AL2 in two sections with an anchored billet at 9344'. RIH with drilling BHA and circulated out KWF,tripped for a failed orienter. 00:00 01:00 1.00 8,683 10,916 COMPZ CASING RUNL T Correct to EOP flag,+12',26K PUW, 14K RIW,-3.5K WOB,continue RIH Page 29 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T. Comment 01:00 04:00 3.00 10,916 0 COMPZ CASING RUNL T Smooth run in hole with no set downs. Release from liner with 1.5 BPM 4500 CTP. POOH pumping down backside,tie in at RA for-3' correction. Circulate down coil whil continue POOH. Paint flag at 8000 EOP. 04:00 06:00 2.00 0 0 COMPZ CASING PUTB P Lay down liner running BHA, RU for liner ops, PU liner string and anchored billet 06:00 07:24 1.40 0 696 COMPZ CASING PUTB P P/U Coil track,M/U FVS,Scribe, stab on,surface test,strip down injector,Open rams,Tag up, set counters 07:24 09:12 1.80 696 8,665 COMPZ CASING TRIP P Trip in well with AL2 liner second run, BHA#29 09:12 09:54 0.70 8,665 9,981 COMPZ CASING TRIP P Correct+10 at flag,close EDC, PUW=30K 09:54 10:18 0.40 9,981 9,380 COMPZ CASING TRIP P Tag @ 9982 with 3.5K WOB, PUW=31 K Set back down to 9978 w 1.7K WOB, Release Liner POOH 10:18 12:18 2.00 9,380 8,746 COMPZ CASING TRIP P 9380, reset counter to bottom of TS -634', Open EDC Continue Out of well 12:18 13:03 0.75 8,746 0 COMPZ CASING PULD P PJSM,At surface, Flow check Lay down liner running tools BHA #29 13:03 14:18 1.25 0 72 PROD5 DRILL PULD P P/U Drill by BHA#30 Surface test,Tag up and set counters 14:18 15:48 1.50 72 8,350 PROD5 DRILL TRIP P RIH with BHA#30 15:48 16:00 0.20 8,350 8,392 PROD5 DRILL DLOG P Log Gamma tie in for a+8.5' correction, RIH to window to displace KWF 16:00 16:12 0.20 8,392 8,760 PROD5 DRILL TRIP P RIH to above window Circ out KWF 16:12 18:30 2.30 8,760 8,760 PROD5 DRILL CIRC P Circ out KWF trying to maintain 1 for 1,starting at.3 BPM 18:30 21:00 2.50 8,760 0 PROD5 DRILL TRIP T Toolface indicator not working properly. Pulled up hole to 8200'and it appeared to begin working,further checks indicate it is in fact not accurate. POOH. 21:00 22:00 1.00 0 0 PROD5 DRILL PULD T Undeploy BHA#30 22:00 23:30 1.50 0 0 PROD5 DRILL PULD T deploy BHA#31. Had trouble with the jib arm for PDL not returning to center,spent about 20 minutes checking it out then it started working again? Mechanic will trouble shoot during day shift. 23:30 00:00 0.50 0 2,406 PROD5 DRILL TRIP T RIH 07/16/2010 Kicked off aluminum billet at 9344',drilled to 9505'and tripped for RSM,continue drilling AL2-01 lateral 00:00 01:30 1.50 2,406 8,350 PROD5 DRILL TRIP T Continue RIH Page 30 of 33 KU P 1 R-06AL2 Conoc©Phillip5 ' n Angle 8 MD w 11 ales Max TD Wellbore APUUWi [Field Name Well Status Intl C) MD(ftKB) Act Btm(ftKB) , ! 5002.92133161 �KUPARUK RIVER UNIT lINJ L-Comment Tag - H2S(per) Rev Reason:SIDETRACKS End Date 1KB-103 .6 Rig Release/19 Date vaal conrg 7R-0§! 2j1lRU1412:40,2o N, SSSV TRDP 1 rata- Last WO ..3761 _ 5/15/1985 Sdsfinet AFL___ w4^A notation !Depth(ftKB) [End Date 'Annotation rL t Mod.. End Data II. SIDETRACKS,GLV C/O ll Imosbor 7/21/2010_ HAVGEk.33 I Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt...String...String Top Thrd '' " '' '' 'v'S WINDOW AL2 8 6 000 8802.0 8,814 0 Casing Descdption String 0... String ID...Top(RKB) Set Depth(t...Set Depth(ND) Siring Wt...String String Top Thrd CONDUCTOR, AL2 LINER 2 3/8 1.995 9,344.1 10,915.0 4.43 L-80 STL 38-110 Liner Details-_ ,:::..' ; a. . .y Top Depth SAFETY VLV, - (TVD) Top Intl Norm... t.sm Top(ftKB) (ftKB) C) Item Description Comment ID On) 9,344.1 Anchor billet Anchored billet 1.000 GAS LIFT, 2,041 9,978.1 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 GAS LIFT, ' �- Other In Hole reline retrievable plugs,valves,pumps,fish,etc.) 4'326 '� Top Depth [: (ND) Top Inc! SURFACE, :[�.. TW B) (RKB) (°) Description Comment Run Dab ID(in) 37-4,659 .: ----. - _. GAS LIFT * 8,800 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 7/5/2010 1.000 5,631- removed GAS LIFT, 6,285 mow. Perforations&Slots _ -... Shot --_- GAS LIFT, .. Top(TVD) Btm(TVD) Dens 6,762 T.. ftKB Bbn ftKB (ftKB) (ftKB) Zone Date (ah... Comment GAS LIFT, ft 9,354 9,486 7/12/2010 32.0 SLOT Alternating solid/slotted pipe-- 7,198 0.125'x2.5"@ 4 circumferential GAS LIFT, adjacent rows,3"centers staggered 7919 , 18 deg,3'non-slotted ends GASeI�, s' 9,488 10,914 7/12/2010 32.0 SLOT Alternating solid/slotted pipe- paw 0.125"x2.5"@ 4 circumferential GAS LIFT, adjacent rows,3"centers staggered 6'381 18 deg,3'non-slotted ends PBR,8,421 - Notes:General&Safety - _--- - -- - PACKER,8,435 __- - y Olt End Date Annotation GAS LIFT, 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED Ilk 8,473 ,' ____ -_______ _ ._ -. _ 7/21/2010 NOT E-View Schematic w/Alaska Schematic9.0 lir GAS LIFT, �411r.'[.F -._ 8,545 ... - -. ir ciii:: ii.ii . WHIPSTOCK, 8,801 WINDOW AL2, 4 • 8,802-8,814 WHIPSTOCK, 8K, 8, k • WINDOW•A•, 8,820-8,832 I GAS LIFT___._.. MMG,8890 ' IrL LOCATOR,... 8,908 PACKER,8,909-- - `F S8E,8,913 l J- Ill CIBP,8.921- NIPPLE,8,924-. IPW'' SOS,8,931 f4''/' FISH,9,145 IV PRODUCTION, ,Mandrel Details -; 35-9,279 Top Depth Top I Port (TVD) Inc! OD Valve Latch SM. TRO Run SLOT. S-?1 26 8 (nKe) (°) CAMCO Model (in) Sam Type_ TYPs (in) (Pa!) Run Mb Can... KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7212010 9'39' KBUG 1 GAS LIFT GLV BK 0.156 1,333.07212010 ,'' sL244 - 5 4 6,285.1 CAMCO KBUG 1 GAS LIFT 6,762.2 CAMCO KBUG 1 GAS LIFT DMY- BK 0.000 1,319.0 0.0 1/21/10/1987 3 5,630.9 CAMCO KBUG I GAS LIFT DMY BK 0.000 0.0 11/10/1987 x,471-tn,zu t 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 SLOT, 9,488-10,914 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7212010 I "A.LINER, 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,460-10,245 -, 9 8,381.1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 7/21/2010 AL2 LINER, - 9,344-10,915 10 8,473.5 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 TD(1 R-06AL2), I 10,940 KU P 1 R-06AL2 ConoeoPhillips g Alaska. ; Lce14411n,`'"i ano 1 KB-Crd(R) Rig Release Deb 37.61 5/15/1985 Well C f9 1s R 1e6mALa2]/2 A r f 20 l 0'2 44 20 PM - HANGER.33 - .1 CONDUCTOR. I rI 36-110 SAFETY VLV. 1,908 GAS LIFT, 2,041 GAS LIFT,_ SURFAC, . 37-4,65E9_ .4* GAS LIFT, 5,631 GAS LIFT, 6,285 AWL GAS LIFT, 6,762 GAS LIFT, I^'`"- � 7,198 L GAS 1_1.:;1" ._ 5 -y GAS LIFT, 8,061 GAS LIFT, --_ 8,381 y d P138,8,421- j 1 PACKER,8,435'-- R :' GAS LIFT 4. 8,473 GAS LIFT, B 8,545 .. .::+ter.."+;.. NIAV I WHIPSTOCK,_ 8,801 WINDOW AL2, 8,802-8,814 WHIPSTOCK, 8,819 WINDOW'0', 0,820-8,632 a GAS LIFT MUG,8,890 - ._. LOCATOR, 8,908 PACKER,8,909 '- SDE,8,913 GAP,8,921 NIPPLE,8,924 VW I SOS.8,931 --_- FISH,9,145 PRODUCTION, Mandrel Details 35-9.278 _-___.. Top Depth Top ... _.._. -_ Pod (TVD) Inc! OD Valve Latch Sloe TRO Run Stn Top jftKo) (ftKH) (') Make Model (in) Sere Type Type (in) (psi) Run Date Com... SLOT, _. 8,544-5 CAMCO MMG 2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 9.354-9.486 8,890.3 CAMCO MMG-2 1 1f2 PROD OPEN 0.000 0.0 5/21/2010 SLOT, 9,471-10,244 SLOT, 9,488-10,914 'A'LINER, 9,46010,245 AL2 LINER, 9,344-10,915 10,940 e. u1 N N p_q �mp,– N N o m N- <O - m `< 07 o? 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EITERE E SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COmIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Von Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1R-06AL2 ConocoPhillips Alaska, Inc. Permit No: 210-058 Surface Location: 272' FNL, 222' FEL, Sec. 19, T12N, R10E, UM Bottomhole Location: 2531' FNL, 1245' FWL, Sec. 19, T12N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 1R-06A, Permit No. 210- 056, API 50-029-21331-01. 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. As ince ely, Daniel T. Seamount, Jr. Chair DATED this 17 day of May, 2010. 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 MAY 0 6 2010 PERMIT TO DRILL y�kao�&G�� 20 AAC 25.005 �,�.,.. la.Type of Work: , lb.Proposed Well Class: Development-Oil ❑ Service-Winj 0 • Single Zone Q . 1c.Specify if well is p ooposed for: Drill ❑ Re-drill II 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 ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 1R-06AL2 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11050'• - TVD: 6631' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:272'FNL,222'FEL,Sec. 19,T12N, R10E,UM ADL 25635 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1041'FSL, 1086'FWL,Sec. 19,T12N,R10E,UM 2568 6/10/2010 Total Depth: 9.Acres in Property: 14.Distance to 2532'FNL, 1245'FWL,Sec. 19,T12N,R10E, UM 2560 Nearest Property: 19500' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 84 feet 15.Distance to Nearest Well Open Surface:x- 539470 y- 5990930 Zone- 4 GL Elevation above MSL: 41 feet to Same Pool: 1R-08,1050' 16.Deviated wells: Kickoff depth: 8791 • ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98.5" deg Downhole:3115 psig Surface:2545 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 1800' 9250' 6630' 11050' 6631' slotted liner • 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9303' 6998' 9188' 6890' 9145' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 215 sx CS II 110' 110' Surface 4575' 9.625" 1390 sx PF E,425 sx PF C 4659' 3694' Intermediate Production 9194' 7• 510 sx Class G,250 sx PF C 9278' 6975' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8582'-8588',8692'-8742',8860'-8867',8976'-8984',8994'-9024',9028'-9038' 6379'-6383',6465'-6505',6801'-6607',6700'-6707',6716-6741',6745'-6754' 20.Attachments: Property Plat❑ BOP Sketch Q Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch Cl Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: S/J'`0 22. I hereby certify that the foregoing is true and correct. Contact J. G.Eller @ 263-4172 V Printed Name V. Cawve Title Alaska Wells Manager R Signature Phon 265-6306 Date 5 151‘0 (VW_6e t lia- 414.11A Al Com fission Use Only Permit to Drill ` API Number: Permit Appro al See cover letter Number: Z / 6 j 50-( 1q "2 13 5 L-6 t-O6 Date: P 11 I 1 O for other requirements Conditions of approval: -If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: LJ 1.-• 3soo Ps Bo �;57 Samples req'd: Yes ❑ No Q� Mud log req'd: Yes ❑ No 2- Other: r A n A7$) H2S easures: Yes ©- No ❑ Directional svy req'd: Yes [✓7 No ❑ -0•ZSad s� /` n (,hc i,,t 6(e f of. s m �ti RA:Oa 41 4/o ZB — /i oC{ t�C✓'n /0 / APPROVED BY THE((COMMISSION DATE: i���` ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is va g• o t •: 'hi d t • approval(20 AAC 5.005(g)) Submit in Duplicate c/rJ!—( /•P . /p er,-/c ,14 /2 KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Summary of Operations: Well 1R-06 is a Kuparuk A-sand and C-sand injection well equipped with 3'/2"tubing x 7"casing.Four proposed A-sand CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling,the existing C-sand perfs in 1R-06 will be squeezed with cement and the A-Sand perfs will be plugged with a bridge plug. After squeezing the existing C-sand perfs with cement, a mechanical whipstock will be placed in the 31/2" tubing at the first kickoff point. The 1 R-06A sidetrack will make a 2-string exit through the 31/4"tubing and 7" casing at 8819' MD. It will target the A3 sand south of the existing well with a 2881' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,700' MD with a liner top aluminum billet at 9350' MD. The 1R-06AL1 lateral will kick off from the aluminum billet at 9350' MD and will target the A4 sand south of the existing well with a 2250' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 11,600' MD with the final liner top located just inside the 3'/2"tubing at 8814' MD. The 1R-06AL2 lateral will make another 2-string exit through the 3'/2"tubing and 7"casing at 8791' MD via a second mechanical whipstock placed in the 3'/2"tubing. It will target the A3 sand north of the existing well with a 2259' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,050' MD with a liner top aluminum billet at 9250' MD. The 1R-06AL2-01 lateral will kick off from the aluminum billet at 9250' MD and will target the A4 sand north of the existing well with a 1500' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,750' MD with the final liner top located just inside the 3'/2"tubing at 8780' MD. CTD Drill and Complete 1R-06: June 2010 Pre-Rig Work 1. Test packoffs—T&IC. 2. Positive pressure and drawdown tests on master valve& swab valve 3. Load tbg&IA. MIT-IA. MIT-OA. 4. Obtain updated static BHP on A-sand& C-Sand 5. Permanently lock out the SCSSV at 1908' MD 6. Set 31/2"CIBP at 8920' MD to plug off A-sand perfs 7. Shoot squeeze perfs thru the 3'h"tubing and 7"casing at 8791' & 8819' ELM 8. Lay in cement on top of CIBP isolating A-sand. Squeeze the C-sand perfs with cement. 9. RU slickline. Tag cement top. Pressure test cement squeeze. 10. Drill out cement from the 3'/2"tubing to 8920' using special clearance bi-center bit 11. Run whipstock dummy 12. Run slimhole CBL to evaluate C-sand squeeze 13. Prep site for Nabors CDR2-AC. ! M AL May Page 2 of 5 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1 R-06A Lateral(A3 sand, south) a. Mill 2.80"2-string window with high-side orientation at 8819' MD. b. Drill 2.70"x 3"bi-center lateral to TD of 11,700' MD. c. Run 2%"slotted liner with an aluminum liner-top billet from TD up to 9350' 3. 1 R-06AL 1 Lateral(A4 sand, south) a. Kick off of the aluminum billet at 9350' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11,600' MD. c. Run 2%"slotted liner from TD up to 8814' MD,up inside the 7"casing 4. 1R-06AL2 Lateral(A3 sand,north) a. Set 31/2"monobore whipstock in 3V2"tubing at 8791' MD with high-side orientation. b. Mill 2.80"2-string window with high-side orientation at 8791' MD. 4.; r ct . Drill 2.70"x 3"bi-center lateral to TD of 11,050' MD. • ° d. Run 2%"slotted liner with an aluminum liner-top billet from TD up to 9250' 5. 1R-06AL2-01 Lateral (A4 sap.,nort a. Kick off of the aluminum billet at 9250' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,750' MD. c. Run 2%"slotted liner from TD up to 8780' MD,up inside the 31/2"tubing 6. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Obtain static BHP 2. Run GLVs 3. Flow back well to the system for clean up prior to putting on injection 4. Conduct MIT-IA 5. Put well on injection 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. Because the SCSSV installed in 1R-06 will be locked out,we will have to kill the well to deploy 2%"slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1R-06A: 2%",4.7#,L-80, ST-L slotted/solid liner from 9350' MD to 11,700' MD • 1R-06AL1: 2%",4.7#,L-80, ST-L slotted/solid liner from 8814' MD to 11,600' MD • 1R-06AL2: 2%",4.7#,L-80, ST-L slotted/solid liner from 9250' MD to 11,050' MD • 1R-06AL2-01: 2%",4.7#,L-80, ST-L slotted/solid liner from 8780' MD to 10,750' 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 Page 3 of 5 I (,' May 5,2010, FINAL 1 \01 r' ` KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Well Control: • Two well bore volumes(-205 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 3500 psi. Maximum potential surface pressure in 1R-06 is 2545 psi assuming a gas gradient to surface and maximum potential • formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity,which is 3115 psi at 6490 SSTVD(i.e.9.3 ppg)from 1R-08 to the • north in September 2009. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 1R-06A,plan#4 2. 1R-06AL1,plan#3 3. 1R-06AL2,plan#2 4. 1R-06AL2-01, plan#2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 1R-06 CTD southern laterals(A&AL1): 18,550' to property line,—870' to well 1G-08 • 1R-06 CTD northern laterals(AL2 &AL2-01): —19,500' to property line, 1050' from well 1R-08 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 1R-06 was taken April 2010 after several months of shut-in. The measured A-sand reservoir pressure was 2998 psi at 6571' SSTVD, corresponding to 8.7 ppg EMW. We generally expect to encounter similar pressure as the laterals are drilled away from the mother well. Hazards • Lost circulation is usually not particularly troublesome in the A-sand,but it is a possibility in 1R-06 because of the generally low formation pressure in this area. • Shale stability is a potential problem,particularly in the build section where the A6 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70°hole angle,and by holding a constant pressure on the formation throughout drilling operations. • Well 1R-06 has no measured H2S since it is an injection well. Well 1R-05 is located 60' to the right side . and 1R-07 is 60' to the left side of the 1R-06 surface location. Well 1R-05 has 40 ppm H2S and 1R-07 has 25 ppm H2S, both being measured on 8/6/09. The maximum H2S level on the pad is 150 ppm from well 1R-20(8/15/05). All H2S monitoring equipment will be operational. Page 4 of 5 kG1 ' ' f I May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling 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 utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. 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. The SSSV in well 1R-06 will be locked out, so the well will have to be killed prior to running 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 2933 psi at 8819' MD(6483' SSTVD),or 8.7 ppg EMW. • Expected annular friction losses while circulating: 882 psi(assuming annular friction of 100 psi/1000 ft due to the 3'/z"tubing) • Planned mud density of 8.6 ppg equates to 2899 psi hydrostatic bottom hole pressure at 6483' SSTVD • While circulating 8.6 ppg mud,bottom hole circulating pressure is estimated to be 3781 psi or 11.2 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 1R-06. 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,—880 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Quarter-Mile Injection Review The following wells lie within one-quarter mile of the proposed 1R-06 CTD laterals. • 1R-06 motherbore(injector). This well is a selective completion in the Kuparuk A-sand and C-sand. The A-sand perfs will be isolated with a cast iron bridge plug in the tubing tail and the C-sand perfs will be squeezed with cement. • 1R-06 CTD southern laterals(A&AL 1): • 1R-05 (active producer). This wellbore is located-1335' to the northeast of wells 1R-06A and 1R- 06AL1. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. • 1 G-08 (plugged& sidetracked producer)—This abandoned wellbore is located—873' to the southeast of wells 1R-06A and 1R-06AL1. The Kuparuk interval was abandoned in June 2004 with a balanced cement plug placed on top of a 7"retainer prior to being sidetracked. • 1R-06 CTD northern laterals (AL2&AL2-01): • 1R-08 (active injector)—This wellbore is located—1055' to the north of wells 1R-06AL2 and 1R- 06AL2-01. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. Page 5 of 5 ORIGINAL May 5,2010, FINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N Lubricator Riser Annular� Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator Pj�� J L above BHA rams %ice i >. 4 Choke 1 2-3/8" Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip(BHA) I Kill 1>4�II/< L>d L . _4-0401_ 1 r Blind/Shear 2" Pipe/Slip(CT) Choke 2 i Swab Valves Wing Valves i Q Tree Flow Cross 1 r Surface Safety Valve BOPE: 7-1/16", 5M psi,TOT Choke Line: 2-1/16", 5M psi 0 Master Valve Kill Line: 2-1/16", 5M psi T� Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union O \ 1GI \JAL o .--- 1 < o a',.. - 11:.■2 11 11 3-,.;. '_,--2 r° 0,-) •.,72 `,2--' ,,,. a, •• ' ° 1_,011 ,'.) 74,oil .,:,, D a,z■ r i- .. • . . " . . . . . , -J • • • , • • • .: ■ , • • • ' ' • • . . 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Well Attnbutes Max An•le-&MD TD - r Wellbore APW WI Field Name Well Status blcl(") MD(ftKB) Act Bt.(ftKB) �''iqs jnC, 500292133100 I KUPARUK RIVER UNIT I INJ 60.30 3,100.00 9,303.0 tmOCOPhAlhpS "" Comment H2S(ppm) Date Annotation End Data KB-Grd(ft) Rig Release Date Well COn6q:-1R-06,a27/�Q108.68s9 AN- SSSV:TRDP _ Last WO: 37.61 5/15/1985 Schematic-Actual " -"'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,986.0 4/22/2010 Rev Reason:Tag,Pull Plug/Gauges/Leak Imosbor 4/27/2010 4 -c4 • .> to. most Casing Strings CONDUCTOR, String OD String ID Set Depth Set Depth(TVD) String WI Sting • 110 Casing Description (in) (in) Top(ftKB) (ftKB) (MB) (Ibs/ft) Grade String Top Thrd • CONDUCTOR 16 15.062 0.0 110.0 110.0 65.00 1440 WELDED SAFETY VLV, SURFACE 9 5/8 8.765 0.0 4,659.0 3,693.3 36.00 J-55 1,908 PRODUCTION 7 6.151 0.0 9,278.0 6,974.8 26.00 J-55 GAS LIFT, Tubinq Strings _ 2,041 String OD String ID • Set Depth Set Depth(TVD) String Wt String Tubing Description (in) (in) Top(68KB) (ftKB) (ftKB) (Ibs ft) Grade String Top Thrd TUBING 31@ 2.992 0.0 8,932.0 6,662.6 9.30 J-55 EUE8RD GAS LIFT.4,328 _ Other In Hole(All Jewelry:Tubinq Run Retrievable,Fish,etc.) Top Depth (TVD) Top Intl SURFACE, Top(ftKB) (ftKB) (') Description Comment Run Date ID(in) 1,908 1,850.2 29.48 SAFETY VLV Camco TRDP-1A'(NOT Locked Out) May hang up 5/21/1995 2.812 toolstring if control line pressure bleeds down. GAS LIFT 2,041 1,963.4 33.00 GAS UFT CAMCO/KBUG/1/DMY/BK///Comment STA 1 11/9/1987 2.875 4,326 3,449.4. 43.26 GAS UFT CAMCO/KBLJG/1/DMY/BK///Comment STA2 11/10/1987 2.875 GAS LIFT, 5,631 4,355.8 49.37 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA 3 11/10/1987 2.875 6,285 ,q- 6,285 4,787.5 4827 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA 5 6/30/1985 2.875 6,762 5,103.8 48.32 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA 5 11/10/1987 2.875 . GAS LIFT, 6,762 - 7,198 5,396.3 47.03 GAS LIFT CAMCO/KBLJG/1/DMY/BK///Comment STA 6 6/30/1985 2.875 ilt7,615 5,683.6 46.05 GAS LIFT CAMCO/KBUG/1/DMYBKI//Comment STA 7 11/10/1987 2.875 GAS LIFT, _ 8,061 5,995.8 44.95 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA 8 11/10/1987 2.875 7,198 8,381 6,225.8 42.60 GAS LIFT CAMCO/MMG-2/1.5/DMY/RK///Comment STA 9 11/10/1987 2.922 8,421 6,255.8 41.30 PBR Baker PBR 6/30/1985 3.000 GAS LIFT,7,615 Ir 8,435 6,266.1 41.09 PACKER Baker'FHL'PACKER 6/3011985 3.000 8,473 6,294.6 40.50 PRODUCTION CAMCO/MMG-2/1.5JDMY/RK///Comment STA 10 11/21/1993 2.992 8,544 6,349.1 39.40 PRODUCTION CAMCO/MMG-211.5/DMY/RK///Comment STA 11 11/21/1993 2.992 GAS LIFT, 6,061 8,890 6,626.0 33.19 PRODUCTION CAMCO/MMG-2/1.5/DMY/RK/.25//Comment STA 12 4/21/2002 2.992 ,' 8,909 6,643.9 32_57 PACKER Baker'FB-1'PACKER 6/30/1985 4.000 8,924 6,656.0 31.85 NIPPLE Camco'D'Nipple NO GO 6/30/1985 2.750 GAS LIFT, 8,381 - 8,931 6,661.7 31.51 SOS Camco 6/30/1985 2.992 8,932 6,662.6 31.46 TTL 6/30/1985 2.992 PBR.8.421 9,145 6,852.0 22.94 FISH 1 1/2"GLV Valve Dropped;Could Still be in Tubing String 3/15/1986 Perforations&Slots .�_rss Shot PACKER,6,4354 Top(TVD) Btm(TVD) Dans Top(ftKB) Ben(ftKB) (ftKB) (ftKB) Zone Date (oh_. Type Comment 8,582 8,588 6,378.5 6,383.1 C-4,1R-06 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase PRODUCTION, 8,692 8,742 6,465.0 6,505.0 C-1,UNIT B, 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase 8,473 .'r 1R-06 1_` 8,860 8,867 6,601.4 6,607.1 UNIT B,1R-06 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase PRODUCTION, ��t_ 8,976 8,984 6,699.6 6,706.6 A-4,1R-06 6/30/1985 4.0 IPERF 4"HJ II Csg Gun'90 deg.ph e'er 8,994 9,024 6,715.3 6,741.2 A-3,15-06 6/30/1985 4.0 IPERF 4"HJ II Csg Gun'90 deg.ph 9,028 9,038 6,744.8 6,753.9 A-3,1R-06 6/30/1985 4.0 IPERF 4"HJ II Csg Gun'90 deg.ph IPERF, 8,582.8,588 ->y Notes:General&Safety End Date Annotation _ 4/23/2010 NOTE:Suspect Tubing leak between 8572'&8868' IPERF.8,692.8,742 -- IPERF, . .r 8,860-8,867 PRODUCTION, 8.890 iti PACKER,8,909 I NIPPLE.8.924 mu_ SOS,8,931 nl,8,932 it I .. - IPERF, 8,976-8,984 -- . =r IPERF, "- _ - 8,994-9,024 - _ IPERF, 9,028.9,038 FISH,9,145 PRODUCTION, 9,278 p'" 19 a q-1 g i 7O,9.303 fi, fg $ \I 4 ; @ 4,L. A' N ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1R Pad 1R-06 1 R-06AL2 Plan: 1 R-06AL2_wp02 Standard Planning Report 30 April, 2010 nes BAKER HUGHES r ORIGINAL ConocoPhillips as ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1R-06©84.00ft(1R-06) - Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature _ Wellbore: 1 R-06AL2 Design: 1 R-06AL2_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 rSIte Kuparuk 1R Pad Site Position: Northing: 5,991,050.01 ft Latitude: 70°23'11.370 N From: Map Easting: 539,829.93ft Longitude: 149°40'33.803 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.31 ° Well 1 R-06 I Well Position +N/-S 0.00 ft Northing: 5,990,930.21 ft Latitude: 70°23'10.210 N +E/-W 0.00 ft Easting: 539,469.74 ft Longitude: 149°40'44.368 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1 R-06AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2009 7/1/2010 17.20 79.85 57,390 Design 1 R-06AL2_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,700.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) Cl 0.00 0.00 0.00 3.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/S +E/-W Rate Rate Rate TFO (ft) (°) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) (1100ft) (0) Target 8,700.00 37.42 231.68 6,387.34 -3,932.40 -3,470.12 0.00 0.00 0.00 0.00 8,791.00 35.83 231.86 6,460.37 -3,965.99 -3,512.77 1.75 -1.75 0.20 176.21 8,811.00 43.83 231.86 6,475.71 -3,973.90 -3,522.83 40.00 40.00 0.00 0.00 8,881.00 68.33 231.86 6,514.48 -4,009.50 -3,568.17 35.00 35.00 0.00 0.00 8,951.00 81.76 253.14 6,532.70 -4,040.10 -3,627.81 35.00 19.19 30.40 60.00 9,071.00 64.05 293.26 6,569.20 -4,035.82 -3,739.24 35.00 -14.76 33.44 120.00 9,351.71 93.60 30.69 6,640.10 -3,806.32 -3,799.14 35.00 10.53 34.71 90.00 9,476.71 93.48 45.72 6,632.34 -3,708.56 -3,722.20 12.00 -0.10 12.02 90.00 9,551.71 91.42 54.49 6,629.13 -3,660.56 -3,664.76 12.00 -2.74 11.69 103.00 9,776.71 89.99 27.52 6,626.30 -3,492.34 -3,518.51 12.00 -0.63 -11.98 267.20 10,106.71 81.44 348.71 6,651.91 -3,173.20 -3,472.35 12.00 -2.59 -11.76 256.50 10,316.71 90.14 12.45 6,667.54 -2,965.49 -3,470.01 12.00 4.14 11.30 71.00 10,466.71 92.13 30.34 6,664.55 -2,826.43 -3,415.53 12.00 1.33 11.93 83.50 10,566.71 92.09 18.33 6,660.85 -2,735.55 -3,374.42 12.00 -0.05 -12.01 270.00 10,816.71 91.81 348.32 6,652.16 -2,488.96 -3,360.09 12.00 -0.11 -12.01 270.00 11,050.00 98.45 15.64 6,630.92 -2,259.09 -3,352.44 12.00 2.85 11.71 75.30 4/30/2010 12:16:05PM Page 2 COMPASS 2003.16 Build 69 iNI I A . ConocoPhillips - ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL2 Design: 1 R-06AL2_wp02 • Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map DePth Inclination Azimuth System +N/.S +EJ_W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) lft) (ft) (ft) (°rlOOft) (°) (ft) (ft) 8,700.00 37.42 231.68 6,387.34 -3,932.40 -3,470.12 -4,108.62 0.00 0.00 5,986,979.94 536,020.761 TIP 8,791.00 35.83 231.86 6,460.37 -3,965.99 -3,512.77 -4,144.40 1.75 176.21 5,986,946.13 535,978.30', KOP 8,800.00 39.43 231.86 6,467.49 -3,969.38 -3,517.09 -4,148.01 40.00 0.00 5,986,942.71 535,973.99 8,811.00 43.83 231.86 6,475.71 -3,973.90 -3,522.83 -4,152.82 40.00 0.00 5,986,938.17 535,968.27 End DLS 40 8,881.00 68.33 231.86 6,514.48 -4,009.50 -3,568.17 -4,190.75 35.00 0.00 5,986,902.33 535,923.13 4 8,900.00 71.76 237.92 6,520.97 -4,019.75 -3,582.78 -4,201.75 35.00 60.00 5,986,892.00 535,908.58 8,951.00 81.76 253.14 6,532.70 -4,040.10 -3,627.81 -4,224.43 35.00 57.93 5,986,871.42 535,863.65 I 5 9,000.00 73.57 268.58 6,543.22 -4,047.77 -3,674.86 -4,234.55 35.00 120.00 5,986,863.50 535,816.65 I 9,071.00 64.05 293.26 6,569.20 -4,035.82 -3,739.24 -4,225.99 35.00 116.67 5,986,875.11 535,752.22 6 9,100.00 64.48 304.52 6,581.83 -4,023.23 -3,762.06 -4,214.60 35.00 90.00 5,986,887.58 535,729.33 9,200.00 72.02 341.45 6,619.99 -3,950.28 -3,816.05 -4,144.58 35.00 85.10 5,986,960.23 535,674.96 9,300.00 85.71 14.39 6,639.79 -3,853.88 -3,818.88 -4,048.46 35.00 70.96 5,987,056.61 535,671.63 9,351.71 93.60 30.69 6,640.10 -3,806.32 -3,799.14 -3,999.93 35.00 64.38 5,987,104.27 535,691.12 End DLS 35 9,400.00 93.58 36.50 6,637.07 -3,766.19 -3,772.48 -3,958.47 12.00 90.00 5,987,144.53 535,717.56 9,476.71 93.48 45.72 6,632.34 -3,708.56 -3,722.20 -3,898.29 12.00 90.36 5,987,202.42 535,767.53 8 9,500.00 92.84 48.45 6,631.06 -3,692.73 -3,705.17 -3,881.58 12.00 103.00 5,987,218.34 535,784.47 9,551.71 91.42 54.49 6,629.13 -3,660.56 -3,664.76 -3,847.34 12.00 103.15 5,987,250.72 535,824.70 9 9,600.00 91.13 48.70 6,628.06 -3,630.58 -3,626.95 -3,815.42 12.00 -92.80 5,987,280.90 535,862.36 9,700.00 90.50 36.72 6,626.63 -3,557.24 -3,559.25 -3,738.64 12.00 -92.93 5,987,354.59 535,929.66 9,776.71 89.99 27.52 6,626.30 -3,492.34 -3,518.51 -3,671.70 12.00 -93.10 5,987,419.70 535,970.05 10 9,800.00 89.34 24.81 6,626.44 -3,471.44 -3,508.24 -3,650.29 12.00 -103.50 5,987,440.65 535,980.21 9,900.00 86.58 13.12 6,630.01 -3,377.10 -3,475.82 -3,554.39 12.00 -103.48 5,987,535.14 536,012.13 10,000.00 83.95 1.37 6,638.29 -3,278.43 -3,463.25 -3,455.19 12.00 -103.07 5,987,633.87 536,024.18 10,100.00 81.59 349.51 6,650.92 -3,179.72 -3,471.10 -3,357.03 12.00 -102.09 5,987,732.53 536,015.81 10,106.71 81.44 348.71 6,651.91 -3,173.20 -3,472.35 -3,350.58 12.00 -100.60 5,987,739.04 536,014.52 11 10,200.00 85.21 359.32 6,662.78 -3,081.20 -3,481.96 -3,259.21 12.00 71.00 5,987,830.98 536,004.43 10,300.00 89.42 10.57 6,667.48 -2,981.87 -3,473.34 -3,159.56 12.00 69.76 5,987,930.35 536,012.52 10,316.71 90.14 12.45 6,667.54 -2,965.49 -3,470.01 -3,143.03 12.00 69.23 5,987,946.74 536,015.77 12 10,400.00 91.26 22.38 6,666.53 -2,886.13 -3,445.11 -3,062.48 12.00 83.50 5,988,026.22 536,040.24 10,466.71 92.13 30.34 6,664.55 -2,826.43 -3,415.53 -3,001.31 12.00 83.62 5,988,086.07 536,069.51 13 10,500.00 92.13 26.35 6,663.31 -2,797.16 -3,399.74 -2,971.25 12.00 -90.00 5,988,115.42 536,085.14 10,566.71 92.09 18.33 6,660.85 -2,735.55 -3,374.42 -2,908.40 12.00 -90.15 5,988,177.16 536,110.14 14 10,600.00 92.08 14.34 6,659.64 -2,703.63 -3,365.06 -2,876.04 12.00 -90.00 5,988,209.13 536,119.32', 10,700.00 92.01 2.33 6,656.06 -2,604.93 -3,350.60 -2,776.72 12.00 -90.15 5,988,307.89 536,133.26 10,800.00 91.84 350.32 6,652.69 -2,505.37 -3,357.00 -2,677.63 12.00 -90.58 5,988,407.40 536,126.34 10,816.71 91.81 348.32 6,652.16 -2,488.96 -3,360.09 -2,661.40 12.00 -90.98 5,988,423.80 536,123.16 15 10,900.00 94.31 358.01 6,647.71 -2,406.49 -3,369.99 -2,579.56 12.00 75.30 5,988,506.21 536,112.83 4/30/2010 12:16:05PM 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 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL2 Design: 1 R-06AL2_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) (') (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 11,000.00 97.14 9.73 6,637.70 -2,307.40 -3,363.31 -2,480.26 12.00 75.82 5,988,605.32 536,118.99 11,050.00 98.45 15.64 6,630.92 . -2,259.09 -3,352.44 -2,431.45 12.00 76.99 5,988,653.68 536,129.60 1 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/S +E/-W Northing Easting -Shape r) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1R-06AL2 t1 0.00 0.00 6,641.00 -3,830.23 -3,810.97 5,987,080.30 535,679.41 70°22'32.531 N 149°42'35.880 W' -plan hits target center -Point 1 1 R-06AL2 t2 0.00 0.00 6,627.00 -3,447.85 -3,498.91 5,987,464.29 535,989.42 70°22'36.293 N 149°42'26.754 W -plan hits target center -Point 1 R-06 AL2,AL2-01 Pi 0.00 0.00 0.00 -3,970.82 -3,513.68 5,986,941.29 535,977.41 70°22'31.150 N 149°42'27.179 W -plan misses target center by 6387.60ft at 8700.00ft MD(6387.34 TVD,-3932.40 N,-3470.12 E) -Polygon Point 1 0.00 -3,970.82 -3,513.68 5,986,941.29 535,977.41 Point 2 0.00 -4,153.34 -3,800.67 5,986,757.28 535,691.42 Point 3 0.00 -3,962.83 -3,894.68 5,986,947.27 535,596.41 Point 4 0.00 -3,752.81 -3,893.58 5,987,157.28 535,596.40 Point 5 0.00 -2,168.47 -3,542.26 5,988,743.29 535,939.32 Point 6 0.00 -2,240.23 -3,206.60 5,988,673.31 536,275.32 Point 7 0.00 -3,970.82 -3,513.68 5,986,941.29 535,977.41 1 R-06AL2 t4 0.00 0.00 6,643.00 -2,356.43 -3,369.12 5,988,556.26 536,113.43 70°22'47.028 N 149°42'22.971 W I -plan hits target center -Point 1R-06 AL2,AL2-01 H. 0.00 0.00 0.00 -2,168.50 -3,542.15 5,988,743.26 535,939.43 70°22'48.875 N 149°42'28.037 W -plan misses target center by 6626.81ft at 8700.00ft MD(6387.34 TVD,-3932.40 N,-3470.12 E) -Polygon Point 1 0.00 -2,168.50 -3,542.15 5,988,743.26 535,939.43 Point 2 0.00 -2,240.26 -3,206.49 5,988,673.28 536,275.44 Point 3 0.00 -3,970.85 -3,513.57 5,986,941.27 535,977.52 Point 4 0.00 -2,240.26 -3,206.49 5,988,673.28 536,275.44 1R-06AL2 t3 0.00 0.00 6,667.00 -3,005.92 -3,477.57 5,987,906.28 536,008.42 70°22'40.639 N 149°42'26.136 W -plan hits target center -Point 1R-06AL2 t5 0.00 0.00 6,631.00 -2,258.51 -3,352.60 5,988,654.26 536,129.43 70°22'47.991 N 149°42'22.489 W -plan hits target center -Circle(radius 1,500.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (') (") 11,050.00 6,630.92 2-3/8" 2-3/8 3 4/30/2010 12:16:05PM Page 4 COMPASS 2003.16 Build 69 ORIGtNAL ConocoPhillips ler ConocoPhillips Planning Report BAKER Alaska. HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL2 Design: 1 R-06AL2_wp02 I Plan Annotations I Measured Vertical Local Coordinates Depth Depth +N/S +E/-W 1 (ft) (ft) (ft) (ft) Comment 8,700.00 6,387.34 -3,932.40 -3,470.12 TIP 8,791.00 6,460.37 -3,965.99 -3,512.77 KOP 8,811.00 6,475.71 -3,973.90 -3,522.83 End DLS 40 8,881.00 6,514.48 -4,009.50 -3,568.17 4 8,951.00 6,532.70 -4,040.10 -3,627.81 5 9,071.00 6,569.20 -4,035.82 -3,739.24 6 9,351.71 6,640.10 -3,806.32 -3,799.14 End DLS 35 9,476.71 6,632.34 -3,708.56 -3,722.20 8 9,551.71 6,629.13 -3,660.56 -3,664.76 9 9,776.71 6,626.30 -3,492.34 -3,518.51 10 10,106.71 6,651.91 -3,173.20 -3,472.35 11 10,316.71 6,667.54 -2,965.49 -3,470.01 12 10,466.71 6,664.55 -2,826.43 -3,415.53 13 10,566.71 6,660.85 -2,735.55 -3,374.42 14 10,816.71 6,652.16 -2,488.96 -3,360.09 15 I 11,050.00 6,630.92 -2,259.09 -3,352.44 TD I 1 4/30/2010 12:16:05PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL a t A0141:i e N C - N a N I h h N C o -I 0 % ' X 8 8 _ ^ o ■N 1 I O -r z gf 2 rf Q s— 0 g Kyot .Q \ S. _s" ?' ,L •-6.. 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BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 5, 2010 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits permit to drill applications for four lateral sidetracks out of Kuparuk Well 1R-06 (PTD# 185-071) using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 1R-06 in June 2010. The CTD objective is to drill four A-sand lateral sidetracks (1R-06A, 1 R-06AL1, 1 R-06AL2, and 1R-06AL2-01). The original wellbore perforations will be plugged with cement and a bridge plug prior to CTD operations(Sundry application is attached). Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 1 R-06A, 1 R-06AL1, 1 R-06AL2, 1 R-06AL2-01 — Proposed &Current Wellbore Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — Sundry application for plugging the KRU 1R-06 motherbore If you have any questions or require additional information please contact me at my office 907-263-4172. S cerely, Gary Eller ConocoP • • Alaska Coiled Tubing Drilling Engineer Cd O CO O O ty ►` r a pj 8 41'! * ii'1 o N ��c'il ri\. c ufa___LE):, r n i 00 0 CA tp J p ' O e- ,...1 � r �. mm co r r W CD O Q )(,,/,,,,k) 9. O " 1 - 1 M j c- Q r� o X O 4 r . .. o v CA E c?'-'-'.1.'";--. °‘'.'n',- 9r M CO fr �r CJ 1` O + VJ O r WI \� `( Cr) OD O N X q` ! r d r T O r L k . . ,g M N :�, CSI O� g l P T .T 'NNI1/44, \ _ 4:: ' ''' . .14,,L; e.si:. n CO c:" 'Ic. r i! Tf CO 1iV/ ; c..\\\, \\15\i 5., C3 4 . ::../ l . it,, O co I+. d` r 1 8 cG n o x \ J O r 1 fi G r I M — r C.0 M cse M CA Oe-y„ d CO 'sk O q i!r 6 p cp O Q co M r r r $� ti) t O N T CO gg pm N p �- t Ni O g r r t O $G ` O T SJ' r 6f CA to O o 0 o-'r .t N ° § r co CO O r) >. CO �' 0 ova re) r �d M O M p 1 r r ,. — p !CO cr I' 3 T r O Ox �3 � n p N 0 C1_—' Y Min r g r r 0 eo $ 3 II N t d c r r_ yY — C V1 T r O p, cr)'.-i.._____..7-"& M $ # £\ O �` llr !?'�. g9 A r U t7 , $J�y� 11•. 9 f / ,$ V n G r! \ ,; • r M_ i9 Q co r c,l 6 a� $ \ . - LA uOy a r r T' Ci r r es �ie�$ .~``r�.\.14 a-1 t it .- TRANSMITTAL LETTER CHECKLIST WELL NAME L /'- =‘,4 C-- 2- PTD# 2_w �5 Development Service Exploratory Stratigraphic Test Non-Conventional Well ,4� FIELD: ,� 1 GL 1 � ��[ POOL: �- 1-( L Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well _ -x)64 If last two digits in API number are Permit No.Z-/L�©51, ),API No. 50-0Z - 7/ I. 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. 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