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211-012
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. cQ 1 ._ - Dia Well History File Identifier Organizing (done) /Two-sided III 111111 IHi VIII ❑ Rescan Needed III 11111111 1111111 RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: ❑ Other, No/Type: ther Items Scannable by a Large Scanner L©,gs ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: AM Date: 11 I /s/ P Project Proofing III IJIIIIIIH 11111 BY: (Maria Date: ( / l4 /s/ nip Scanning Preparation a x 30 = 10 0 + ti3/ = TOTAL PAGES___ (Count does not include cover sheet) BY: AZ. Date: 6/7 ) / /s/ Y 11 Production Scanning II 1111 II I I 111 II 111 Stage 1 Page Count from Scanned File: (Count does include cover sheet) 9 Page Count Matches Number in Scanning Preparation: YES NO BY: 40 Date: (C)/(11 `L� is, (14 P 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. III IIII II I II II 1liii ReScanned II I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III 111111 o -.- A oLL m m 2 d v, 1 c N -CT-) O o) 0 c CL CG 0 ceu_ I Csi 0 0 _ c m E �~ v) co E a a xs o 2o 2 2 =g _ >O z U 2 2 F- O U .i Y. coU 1 c o y 0 0 a) >_ Z Q. C) N N N N N N Z N w (��(1 Q o re to 0 0 0 0 ZE M M CC) U) CC) C[) C Q iii 2 c — c c c c c C E E d Y = = a) Cl) N N Cl) a a+ a Y 0U 0 0 0 0 0 0 o 0 ce Q C (� ED_ co w 0. N N N N N N O d U) 7 a) r N N N N N N jq (:::coQ t aoo aco opoa0o aco c)) LL U N N co CO CD COQ1CD Cs- W zJ d > U 0 o > 0 CD co Z c e CC a $ ' ° 1- Q rez ° c `� U) 0 J o. o co = m CL 0 ) o o)y o 0 0 , E N o ZI J U U U U) T ci cc r G N a) U) a) Oa a) O)<a M E Ti. o (. N LoN U s 01 co c J = 1 i Q 9 0 H < I a. F- _ co G NC W cc c..) > > a) v Cl) a 0 N Q a Y o N Q o a • Z I U w w wwE W N > > > > >Z gillQd U oOZ w v 1) _ N E J U) U) a) Cl) m a) m 0 Uu m C C z , g C c c c c c =a) a) o ° O o O o • o E coca) y > > > > c 0 co y Z Q 0 c c v c R Z o) E O /tel >, N O J w N d .o• ,FO H{�L/ CO pH v y E N C Q"'""ecc------GGG ° N w W 0 Z N d 0O } d CL E. u. Z iI ra o a) Q J Z z ami u cam• iii c °) c4 Z W °) \, 0 O o N ami m R E 5 . VI J m \� ` � o V p ; o- o 8 E E o. y D a m rncgo a 0 0 0 o m O r ca) 0 0 2 2 0 f- g 3 0 1_>.[cc W J J J W Q 0 <CC 0 0 -- STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other ,, Prod to WINJ J • Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat.Shutdow n r Perforate r Re-enter Suspended Well r2. Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 211-012-0 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r -50-029-21444-61 ... 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25631,25632 ` 3A-0711h Ire _ Lt :' 9.Field/Pool(s): / Kuparuk River Field/Kuparuk River Oil Pool OA/ O LD 10.Present Well Condition Summary: Af jottill ' &Ga�� Total Depth measured 9252 feet Plugs(measured) N Alia. v90/ true vertical 6105 feet Junk(measured) No P#14 �//ss/00 Effective Depth measured 8411 feet Packer(measured) 6791,6923,6955 true vertical 6085 feet (true vertucal) 5916,6020,6046 Casing Length Size MD ND Burst Collapse L1-01 LINER 841 2.625 9252 6105 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 8411-9252 True Vertical Depth: 6085-6105 Tubing(size,grade,MD,and ND) 3.5, L80,6978 MD,6046 ND Packers&SSSV(type,MD,and ND) PACKER-FHL PACKER @ 6791 MD and 5916 ND PACKER-BAKER"F-1"PRODUCTION PACKER @ 6923 MD and 6020 ND SHOE-5 1/2", 15.5#, L-80 MULE SHOE JOINT WITH WEARSOX @ 6955 MD and 6046 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 4 481 519 1950 258 Subsequent to operation 3071 350 2461 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service p Stratigraphic r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations GSTOR r WINJ I 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 311-144 Contact Darrell Humphrey/Bob Christesen Printed Name Bob C 'stensen Title Production Engineering Specialist 111 Signature Phone:659-7535 Date s Form 10-404 Revised 10/2010 RBDMS JUN 0 9 2011 Submit Original Only 3A-07L1-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/07/11 REPLACED DV @ 6706' RKB w/5/16"OV, COMPLETE. 05/09/11 BRUSH AND FLUSH TBG TO 6898'SLM, SET 2.81 XX PLUG IN X NIPPLE @ 6812' RKB, PULL OV F/STA# 1 AND REPLACE W/DV @ 6706' RKB, PREFORM MITT&MITIA BOTH PASSED. JOB IN PROGRESS 05/10/11 PULLED AVA CATCHER AND XX PLUG FROM "X" NIPPLE @ 6812' RKB 05/12/11 Commenced Water Injection • o.1I�t� KUP 3A-07L1-01 ConocoPhilips " ` & I Attributes 1 .Angle&MD TO Wellbore APIAIWI Field Name Well Statue Incl(•) MD(MB) Act Btm(ftKB) Alaska,Inc. 500292144461 KUPARUK RIVER UNIT INJ 105.22 7,370.11 9,252.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well cont9:-3Aa7L1-ot,5/15/2011 t43.37 PM —SSSV:TRDP Last WO: 1/6/2011 36.48 10/25/1985 Sclrmebc-Aciuel Annotation Depth INKS) End Dab Annotation Last Mod..End Date Last Tag:SLM Rev Reason:GLV C/O Imosbor 5/15/2011 Casing Strings • Casing Description String 0... String ID...Top(WEI) Set Depth(I...Set Depth(TVD)... String Wt..String... String Top Thrd L1-01 LINER 23/8 1.995 8,411.2 9,252.0 6,105.1 4.70 L-80 STL HANGER,29 Liner Details Top Depth (TVD) Top Incl Nomi... p Top 41K8) (nK8) 11 Item Deacriptbn Comment ID tint 8,411.2 6,084.8 89.45 BILLET OH anchored Billet 1.995 Perforations&Slots • shot Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(RKB) (RKB1 (MB) Zone Oct. tsh... Type Comment Il 8,422.0' 9,251.0 6,084.6 6,105.1 2/25/2011 32.0 Slots Alternating solid/slotted pipe- 0.125"X2.5"@ 4 circumferential I adjacent rows,3"centers staggered CONDUCTOR 18 deg,3'non-slotted ends Notes:General&Safety • End Date Annotation SAFETY VLV. 3/9/2011 NOTE:View Schematic w/Alaska Schematic9.O 1.779 3/9/2011 NOTE:NEW CTD LATERALS L1,L1-01,L1-02 SURFACE, -J ' 31-3,176 GAS LIFT I - 6.706 i SEAL ASSY, / y 6,761 Li } r PBR,6,768 J • PACKER,6,791 IMMI.10 NIPPLE.6,813 GAS LIFT 6.866 le /PERF, 6.888-6.922 SEAL ASSY, 6,921 PACKER,8,923 58E.6.925 • SHOE.6.955 L,WINDOW, Mandrel Details 6.9824,987\ Top Depth Top Port PRODUCTION. \ (TVD) Incl OD Valve Latch Size TRO Run 24-7,281 _ Stn Top MKS) MKS) (°) Make Model lin) Sere Type Type (in) (psi) Run Date Cont... 1 6,706.4 5,847.2 35.63 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/9/2011 slots, 2 6,866.1 5,975.8 37.87 CAMCO KBMG 1 GAS LIFT'DMY BKS 0.000 0.0 1/4/2011 7294-9203 Sob, 8,4225,251 L1 LINER, 7285-9.204 * 1 L1-01LINER.82 8N 1 I 8.411-9.-9.TD • (3A-07L1431), • 9,252 -- IA BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes ,_nda«or; WELL NAME 3A-07L1; -01; -02 RUN NUMBER FIELD Kuparuk BH SALESMAN Woods,Jim ,u;, .,ci;,) landpo ,) COUNTY North Slope Borough BH DISTRICT Alaska (;n anc-ator•,1 ;:,ancator;t STATE Alaska PAGE OF na hlaic't LOG DATE: TODAYS DATE: 6/5/2011 jrnardaiory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. mandaiory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD (digital FINAL digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur PHIN i S #OF COPIES #OF COPIES 1 'ConocoPhillips Alaska,Inc. I 1 1 I 1 I I NSK Wells Aide,NSK 69 IATTN:MAIL ROOM 700 G Street, 'Anchorage,AK 99501 2 AOGCC I I 1 I 1 I I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 t)-11 ' 01( O' 3 3 3 SBP 1 1 I 1 I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd ! p� t a a.O t' !Anchorage,Alaska 99508 I " V 4 Chevron/KRU REP I 1 I 1 :,, tA ' f,, 0 Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 ao99 5 r 1 'O i 5 Brandon Tucker,NRT I I 1 X1243 01 'A o ° ' �9471 �' (State of Alaska;DNR,Div.of Oil and Gas �' 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 I TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 0 4 4 0 0 0 sirgyE ELAzgA SEAN PARNELL, GOVERNOR �T �+ ALASKA OIL AND GAS333333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Darrell R. Humphrey Wells Engineer /►-� 1 ConocoPhillips Alaska, Inc. Alt- V P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-07L1-01 Sundry Number: 311-144 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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 Z day of May, 2011. Encl. STATE OF ALASKA ' } ALASKA \ND GAS CONSERVATION COMMISSION , APPLICA 1 ION FOR SUNDRY APPROVALS i'� 20 AAC 25.280 1.Type of Request: Abandon T Rug for Redrill r Perforate New Pool r Repair w el r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate f Alter casing Other:Prod to WINJ 17- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. Development C , Exploratory r 211-012-0 • 3.Address: Stratigraphic r Service r 6.API Number. P.O.Box 100360,Anchorage,Alaska 99510 50-029-21444-61 • 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 �._ 3A-07L1-01 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25631,25632' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9252 6105 8411' 6085' Casing Length Size MD ND Burst Collapse L1-01 LINER 841 2.375 9252' 6105' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8411-9252 6085-6105 3.5 L80 6978 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-FHL PACKER MD=6791 TVD=5916 PACKER-BAKER"F-1"PRODUCTION PACKER MD=6923 TVD=6020 SHOE-5 1/2", 15.5#,L-80 MULE SHOE JOINT WITH WEARSOX MD=6955 TVD=6046 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch r Evloratory r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2011 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: Darrell Humphrey/Bob Christesen Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature ��,,` Phone:659-7535 Date (-t-Z,Sj. t t Commission Use Only 11 Sundry Number.'ll I '(Lig Conditions of approval: Notify Commission so that a representative may witnessIRECErva✓✓✓✓ i Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearrannce�lr" G9 Other: N o f..5 rh rte.Ta r -(4 w,•-Fh ems' /_/ / ' ` 1 �A- APR FS �E £ "e-es,'7 r:/of s`-9-`'uS Alaska Oil&fos Cons.Commission Subsequent Form Required: ! a _ ' J�ncfla!�e APPROVED BY /y[_ r 11 Approved by: ��y/ COMMISSIONER THE COMMISSION Date: ` J Rl4DMS MAY 021011 F' Yzi•/( :� zr -2.7 %i Form 10-403 Revised 1/2010 ,\0 R I G I N A L Submifin Duplicate `v Y/s/, J 3A-07L1-01 DESCRIPTION SUMMARY OF PROPOSAL i3A-07 ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3A-07 from Oil Production service to Water Injection service. Well 3A-07 was produced to reduce formation pressure prior to CTD drilling. CTD has been completed in the Kuparuk formation The 16"Conductor was cemented with 150sx AS II (104' and/ 104'bid). The 9-5/8"Surface casing (3176' and /3086'tvd)was cemented with 1000sx AS III and 350sx Class G. The 7" Production casing (7281' and/ 6295'tvd)was cemented with 125sx Healy Fly Ash and 300sx Class G and 175 sx AS I The top of the Kuparuk C was found at 6888' and/5993'tvd. The top of the Kuparuk Cl was found at 6908' and/6009'tvd. The top of the Kuparuk B was found at 6021' and/6019'tvd. The top of the Kuparuk A was found at 6973' and/6059'tvd. The injection tubing/casing annulus is isolated via FHL packer 6.151"OD x 2.930" ID located @ 6791' and/ 5916'tvd. An MIT-IA was last performed on 58/9/09; 4 year State waived MITIA- passed. Initial T/I/0=2775/675/360, pressured up IA with 1.3 bbls diesel. T/I/0=2825/2000/550, 15 min T/I/O=2825/1880/550, 30 min T/I/O= 2825/1860/550. Bled IA Final T/I/O=2825/640/380 KUP 3A-07L1-01 o COt1000PILlli' ell Attributes Max Angle&MD TD . Alaska IncWellbore APINWI Field Name Well States Incl(°) MD(Po(B) Act Btm(DNB) LonowH.ldps 500292144461 KUPARUK RIVER UNIT PROD 105.22 7,370.11 9,252.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Dote ••• Well lAntl9:-3A-073-01, (t7/jQ1116928 PM -Annotation TROP --_Last WO: 1/6/2011 36.48 10/25/1985 ScMnatls-�fit Annotation Depth(5KB) End Date Annotation Last Mod.. End Date Last Tag:SLM I I I Rev Reason:GLV C/O I Imosbor 14/17/2011 Casing Strings Casing Description String 0... string ID...Top(RKB) Set Depth(l...set Depth(TVD)...String Wt...String... String Top Thrd L1-01 LINER 23/8 1.995 8,411.2 I 9,252.0 6,105.1 4.70 I L-80 I STL "ANGER,29 Liner Details I Top Depth VDI (iND) Top incl Nomi... 111 Top 411.2 (RKB) (°) Item Description Comment ID(In) 8,411.2 6,084.8 89.45 BILLET OH anchored Billet D(in) Perforations&Slots shot Top(TVD) Btm(TVD) Dene 1111 Top(NAB) Btm(DAB) (RKB) (RBB) Zone Dote (oh-. Type Comment 8,422.0 9,251.0• 6,084.6 6,105.1 2/25/2011 32.0 Slots 1Altemating solid/slotted pipe- 0.125'12.5"s,4 circumferential CONDUCTOR._� • adjacent rows,3"centers staggered 31-1a 18 deg,3'non-slotted ends IIII Notes:General&Safety End Date _ Annotation SAFETY VLV, 3/9/2011 NOTE:View Schematic w/Alaska Schematic9.0 1.779 i 3/9/2011 NOTE:NEW CTD LATERALS L1,L1-01,L1-02 SU31-3,17RFACE.6— .. __.J l GAS LIFT, C 6,706 SEAL ASSY, 6.761 ll { PER,6,786-- PACKER,6,791 • NIPPLE,6,613 GAS LIFT 6 (PERF. 6,888-6,922 SEAL ASSY, 6,SY, PACKER,6,923 56E.6,925 L••=2 SHOE,6,955 LI WINDOW, Mandrel Details 6,9828,987 Top Depth Top Port PRODUCTION, (TVD) Incl OD Vales Lekh Size TRO Run 24-7281 Stn Top(DAB) (BNB) 11 Make Model (in) Sere Type Type (in) (pal) Run Date Com... 1 6,706.4 5,847.2 35.63 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 4/7/2011 Slots, 2 6,866.1 5,975.8 37.87 CAMCO KBMG 1 GAS LIFT DMV BK-5 0.000 0.0 1/4/2011 7.294-9,203 Sots, 13122-9,251 LI LINER, 7,285-9,2111 t . 1 I L1UN LINER.N I I 11,1411-0,TD 1 (3A-07L1-01), 4e 9.252 RECEIVED APR 2 7 2011 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 ConocoPh• s �41askd Qty&f Cons.Dern 11SSiofl PO Box 196105 Anchorage AK 99519-6105 pS Anchor Phone:(907)659-7535 Fax:659-7314 April 25,2011 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7`h Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3A-07, 3A-07L1, 3A-07L1-01, 3A-07L1-02 from Oil Production service to Water Injection service. The well was produced to reduce formation pressure prior to CTD drilling. CTD was completed in the Kuparuk formation on March 03, 2011. Conversion to Injection service is required due to potential reservoir depletion. Enclosed you will find 10-403 applications for Sundry Approval for ConocoPhillips Alaska, Inc. for 3A-07, 3A-07L1, 3A-07L1-01, 3A-07L1-02 (PTD 185-223,211-211- 0,211-012-0,211-028-0). If you have any questions regarding this matter,please contact myself or Robert D. Christensen at 659-7535. Sincerely,EL-A^ k '‘ \NPeal Darrell R. Humphrey Attachments Sundry application Well schematic _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March',2011 211-012/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 February 20,2011 50-029-21444-61 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 623'FSL,774'FEL,Sec.7,T12N,R9E, UM February 24,2011 3A-07L1-01 Top of Productive Horizon: 8.KB(ft above MSL): 73'RKB 15.Field/Pool(s): 1554'FNL, 1471'FWL,Sec. 17,T12N,R9E,UM GL(ft above MSL): 31'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 512'FNL, 1047'FWL,Sec. 17,T12N,R9E,UM 8411'MD/6085'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-507673 y- 5997005 Zone-4 9252'MD/6105'TVD ADL 25631,25632 TPI: x-509929 y- 5994830 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 509500 y- 5995871 Zone-4 1779'MD/1779'TVD 2564,2565 18.Directional Survey: Yes 2 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) 2560'MD/2547'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 6950'MD/6042'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 31' 104' 31' 104' 24" 185 sx AS II 9-5/8" 36# _ J-55 31' 3176' 31' 3086' 12.25" 1000 sx AS III,350 sx Class G 7" 26# J-55 31' 7281' 31' 6295' 8.5" 125 sx Healy Fly ash,300 sx CI G,175 sx AS I 2-3/8" 4.7# L-80 8411' ' 9252' . 6085' 6105' 3" slotted liner t/ 24.Open to production or injection? Yes Q 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) ti g 3.5" 6997' 6791'MD/5916'ND,6923'MD/6020'ND 6888'-6922'MD 5993'-6020'TVD r;y C ,. 6990'-7010'MD 6073'-6088'TVD 4.24.LL1 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 7024'-7060'MD 6099'-6126'TVD ' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7118'-7128'MD 6171'-6178'N * D /' 1 '. w s.�w slotted liner from 8411'-9252'MD 6085'-6105'TVD 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period-> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 2 Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+ND 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 ,hAR 6 zQ'H A1a4e Oil&Gas Cons.Gunnison Form 10-407 Revised 12pEIDMS MAR 2 9 201f CONTINUED ON REVERSE - p Submit original only 6 , 28. GEOLOGIC MARKERS(List all formations and marks. ,icountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 2 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 2560' 2547' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A2 7285' 6116' Kuparuk A3 7450' 6084' Kuparuk A3 8685' 6084' Kuparuk A3 8825' 6098' Kuparuk A3 8890' 6106' 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: James Ohlinger @ 265-1102 090. 3472/// Printed Nam J.V.Ca ey Title: Alaska Wells Manager Signature � Phone 265-6306 Date 5/ fZdi f INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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' , II - IC VI(03 1II \ r 1 Io 2 o co0 m m co N CO y 64 b 1 _2c3 LO k g _ co co m 2 J y O O N I n U p O x C Q 09 M EC N lf�a.� #- ,-0"2., 0 (N J Gni- 1-@, O 6)V ~ r- c-) OD W 7- 1-.'U IN 0 Q M KUP 3A-07L1-01 • COfOCOPhIilrps " wen AVALVtes Max Angle&MD TD ��skii.Inc. , './ W Ilbore APUUWI IF Id Name IWall StatusIncl() ND(8KB) Act Bim(RKB) c.oncxetivl40* -tFIY 500292144461 KUPARUK RIVER UNIT PROD 105.22 7,370.11 9,252.0 Comment 1IH2S(ppm) Date Annotation IE d Date KB-OM(ft) Rig Release Date SSSV•TRDP 1 1_- on Last WO: 1/6/2011 I.-__3648 10/25/1985 WV9i,9Pn4 3f1 D,2;li A2'7,.8114'1144 P4-' _, Annotation I Depth Oki) End Date IMnotati --- Last Nod End Date Last Tag:SLM Rev Reason:OC UPDATES Imosbor 3/23/2011 Casing Strings Casing Description String 0... Strng ID Top(ftK8) Sat Depth(f...Set Depth(TVD) "String Wt...Str tri g..Sng Top ThirdLt 01 LINER 23/8 'String 1995 ._8411 2 92520. 1 6,105.1 1 4.70....1 L-80 ._ STL HANGER.29— --.___( Liner Details_ Top Depth__. I (TVD) Top Inel N mi... +' Top(ftK8) (8KB) (') Item Description Comment ID(in) 8,411.2 6,084 8 89 45 BILLET OH anchored Billet 1.995 Perforations&Slots ( shot Top)TVD) Btm(TVD) Dens IS TopjftKB) Ban(SKB) (11K6) (66KB) Zone Date (ch-. Type Comment 8,422.0 9,251.0 6,084.6 6,105.1 2/25/2011 32.0 Slots Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered CONDUCTOR, 31-104 , 18 deg,3'non-slotted ends I Motes:General.&Safety,` End Date Annotation 3/9/2011 NOTE:View Schematic in/Alaska Schematic9.0 SAFETY WV. .... 1,779 ;- 3/9/2011 NOTE:NEW CTD LATERALS L1,L1-01,L1-02 111 II II SUR31-3,17FACE,6 I 1 i- GAS LIFT, 6,706 SEAL ASSY, 6,761 _ 1 PBR,6,768 PACKER,6,791 --- Wiiiii I NIPPLE,6,813_—__ ��.....: • _p ,,AS l IF 1. __. 6,866 IPERF.— �: 6,888-6,922 SEAL ASSY,6,921 - I PACKER,6,923 .., — - - WE,6,925 -- IF SHOE,6.955— __ LI WINDOW, 8,982-6,987 Top Depth Top ----_—�- Pent PRODUCTION. -__ fIVD) Incl 00 Volvo Latch alas TRO Run 24.7,261 l Stn Top MKS) !ftK8) (') Make Model (In) Sty Type TYP. (In) (peg Run Dale Com_ 1 6,706.4 5,847.2 35.63 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/152011 sou, 2 6,866.1 5,975.8 37.87 CAMCO KBMG 1 GAS LIFT DMY BKS 0.000 0.0 1/4/2011 7,2949.203 Slots, 8,422-9,251 LI LINER, 7,285.9.204 ......f'- .t::........�. I 8 1 1 L1-01 LINER, I i 8,411-9,252\ 1 TD (Y1-On 6,252 3A-07 Pre and Post Rig Work DATE SUMMARY 1/14/11 PULLED BALL AND ROD FROM 6813' RKB.IN PROGRESS 1/15/11 REPLACED 1" SOV WITH DV @ 6706' RKB.PULLED RHC PLUG BODY @ 6813' RKB.MITIA PASSED 1/26/11 DRIFTED TBG WITH DUMMY WHIPSTOCK/SETTING TOOL ASS'Y TO 7000' SLM. NO PROBLEMS. READY FOR E/L. 1/29/11 PERFORMED CORRELATION LOG WITH GAMMA/CCL FROM A DEPTH OF 7000'TO 6650'. 2/4/11 PRE CTD PT SV, MV,SSV( PASSED) DDT SV, SSV( PASSED ) DDT SSSV& MV INCONCLUSIVE DUE TO LOW TUBING PRESSURE) 3/6/11 ASSIST VALVE CREW, PULLED BPV. GAUGED TBG TO 2.64"; TAGGED LINER TOP @ 6916' SLM, 6918' RKB. MEASURED BHP @ 6918' RKB: 3094 PSI. COMPLETE. ConocoPhiIIips Time Log & Summary Weiview Web Reporting Report Well Name: 3A-07 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 2/11/2011 6:00:00 PM Rig Release: 3/3/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/10/2011 24 hr Summary Rig Move 18:00 22:00 4.00 MIRU MOVE MOB P Continue to rig down and prepare for rig move. 22:00 22:30 0.50 MIRU MOVE MOB P Start WellView... 22:30 23:30 1.00 MIRU MOVE MOB T Trucks had delayarriving of to location due to spine road being closed for a disabled vehicle. 23:30 00:00 0.50 MIRU MOVE MOB P Trucks arrived begin moving off well. 02/11/2011 Continue moving rig,Spot on 3A-07&swap out reels. 00:00 05:00 5.00 MIRU MOVE MOB P Rig off 2X-18 well&drive rig to Y junction. 05:00 07:00 2.00 MIRU MOVE MOB T Sit at Y junction for field crew change. 07:00 12:00 5.00 MIRU MOVE MOB P Travel to 3A-pad 12:00 21:00 9.00 MIRU MOVE MOB P On location, Rig Up on well.****Rig Accept at 18:00 HRS*** 21:00 00:00 3.00 SURPRI WELLPF CTOP T Reel Swap.-Get old reel ready for transport. Remove spacer flangers. 02/12/2011 Complete reel swap&Start BOPE testing. 00:00 02:30 2.50 SURPRI WELLPF CTOP P PJSM for lowering old reel&P/U new reel into rig.Spot trucks& perform task. 02:30 05:30 3.00 SURPRI WELLPF CTOP T Install spacer flanges and start taking on SW into pits.Continue rigging up in cellar. 05:30 06:00 0.50 SURPRI WELLPF CTOP P Set reel into cradle,start working on inner reel iron. 06:00 18:00 12.00 SURPRI WELLPF CTOP P Crew change, Start on inner reel iron ,make up pressure bulkhead.Test E-line. Remove stuffing box and replace brass. continue cellar rig up Bring on fluids.Continue mud pump assembly.Complete post rig move checklist. 18:00 19:00 1.00 SURPRI WELLPF CTOP P Clean up rig floor&set up to stab pipe. 19:00 22:00 3.00 SURPRI WELLPF CTOP P Secure pipe with stabbing sling and remove banding from string. Stab pipe. 22:00 00:00 2.00 MIRU WHDBO BOPE P PJSM-Start BOP testing. 02/13/2011 Complete Initial BOPE test to 3500 psi. Pump slack&cut 10ft of CT to locate cable. Head up CT connections&test. Pull BPV and deploy dummy whipstock BHA. Page 1 of 15 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 0 0 MIRU WHDBO BOPE P Continue with BOPE testing 06:00 06:30 0.50 0 0 MIRU WHDBO BOPE P Crew chng. Status rig,valve alignment checklist. 06:30 08:30 2.00 0 0 MIRU WHDBO BOPE P PJSM, Fill coil, reverse circulate for slack mgmt, PT Inner reel valve, End BOPE Test 08:30 10:00 1.50 0 0 MIRU WHDBO BOPE P PJSM,M/U FMC lubricator, Pull BPV, R/D Lubricator 10:00 12:30 2.50 0 0 MIRU WHDBO CTOP P Test wire insulation and continuity. Install CTC and pull test to 30K. Install UQC.""Cut back 10 ft to locate cable*" 12:30 13:00 0.50 0 0 MIRU WHDBO SFTY P Hold Pre Spud meeting with rig team 13:00 14:00 1.00 0 0 MIRU WHDBO PRTS P Pressure test UQC to 4K, PDL to 2.5K, 1.5KTiger tank line Bleed off and blow down 14:00 15:30 1.50 0 0 MIRU WHDBO OWFF P Bleed off well in steps while cleaning rig areas. Initial WHP=270.Well would bleed to zero but pressure back up tried three times.got down to 150. Prep to load PDL 15:30 15:45 0.25 0 0 PROD1 RPEQP1SFTY P Safety meeting, Load PDL and Dummy Whipstock Pressure deploy 15:45 17:00 1.25 0 0 PROD1 RPEQP1PULD P PD BHA#1 Dummy Whipstock 17:00 18:00 1.00 0 0 PROD1 RPEQP1 EQRP T Valve R-8 not allowing us to bleed off PDL. Pull tools out of well to circulate through system to try locate problem. Found soft rag in line that came over shaker. 18:00 19:00 1.00 0 0 PROD1 RPEQP1SFTY P Crew change-PJSM&valve check list to deploy BHA. 19:00 20:00 1.00 0 0 PROD1 RPEQP1PULD P Deploy Dummy whipstock BHA 20:00 21:30 1.50 0 0 PROD1 RPEQP1 CTOP T Problems when last initial comms check with BHA.Strip off injector and start troubleshooting E-line/BHA problems. BHA checked good.Start troubleshooting Flo-sub back to CT connector-good check. 21:30 00:00 2.50 0 PROD1 RPEQP1 CTOP T Problem seems to be in the reel or pressure bulk head.Start by checking the junction box& collector. No luck. Decide to first reverse the polarity before pulling the bulkhead.Stab back on BHA. 02/14/2011 Dummy Whipstock run pumping SW. Surface pressure 150 psi,shut in SSSV-passed. RIH&set TOWS @ 6978'HS. P/U 2.80"window mill with.6 AKO motor.Start milling window @ 6983'. Page 2 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 71 PROD1 RPEQPI CTOP T Stabbed Injector back on and reversed the polarity of the wiring in the MWD office.Good test, potentially ground and positive crossed while hooking up initial reel bulkhead. Complete stripping down injector and prepare to RIH. End NAD Downtime 01:00 03:00 2.00 71 7,000 PROD1 RPEQP1TRIP P ECD closed start RIH with EDC closed pumping through WS drift taking returns to tiger tank. SSSV has 4500 psi on line while starting in hole.Tie in @ 6760'+9ft. 03:00 05:30 2.50 7,000 72 PROD1 RPEQP1TRIP P Increase pump rate to 1.5 bpm to circulate out well bore fluid with SW. Out rate 1.1 bpm. P/U weight 36K. POOH. 05:30 06:00 0.50 72 72 PROD1 RPEQPI SFTY P CT @ surface-monitor well-still flowing 150 psi on well when shut in. Shut in SSSV to test it.Good test no flo at pits. PJSM for laying down BHA 06:00 07:00 1.00 72 0 PROD1 RPEQP1 PULD P lay down Dummy WS BHA. 07:00 07:30 0.50 0 0 PROD1 RPEQPI PULD P Bring whipstock into pipe shed and assemble 07:30 08:30 1.00 0 75 PROD1 RPEQPI PULD P PJSM, P/U whipstock,set in well, M/U Coil track surface test 08:30 10:00 1.50 75 6,770 PROD1 RPEQP1TRIP P Run in well, EDC open 10:00 10:15 0.25 6,770 6,810 PROD1 RPEQPI DLOG P Log tie in, +4'correction 10:15 10:30 0.25 6,810 6,930 PROD1 RPEQP1TRIP P Trip into 6930,Shut EDC 10:30 10:48 0.30 6,930 6,990 PROD1 RPEQP1WPST P 6990.0 Set whipstock @ High Side. Tool shifted @ 2500PS1 10:48 14:03 3.25 6,990 6,399 PROD1 RPEQP1TRIP T 6399, H2S alert from shaker sensor, S/I well and evac rig As soon as well S/I All sensors went to zero, Head count taken made notifications. Plan forward to circulate bottoms up to TT after load of SW arrives 14:03 15:33 1.50 6,399 6,900 PROD1 RPEQPI CIRC P Seawater on loc. PJSM. Bring on seawater pump 1.5 tubing volume(50 BBIs)bring returns back in one small H2S burp then cleaned up.Start out of well 15:33 17:33 2.00 6,900 71 PROD1 RPEQPI TRIP P Trip out of well 17:33 18:33 1.00 72 72 PROD1 RPEQPI SFTY P Shut in SSSV-Flow check.Crew change 18:33 19:33 1.00 72 72 PROD1 RPEQP1 PULD P Lay down BHA-P/U milling BHA with new 2.80"string&window mill with.6 AKO motor. 19:33 20:03 0.50 72 72 PROD1 RPEQPI SFTY P Pre-spud meeting with night crew. Page 3 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:03 22:03 2.00 72 6,900 PROD1 WHPST TRIP P Pump open SSSV-RIH with milling BHA pumping through EDC Tie in @ 6790'+2.5 ft correction. Pumping Milling fluid to swap out SW. 22:03 22:33 0.50 6,900 6,900 PROD1 WHPST CIRC P Phase 3 called on all access roads. Stop operations before milling. Continue to circulate Milling fluid from B/U. Called to verify spine&access road to 3A-pad(pioneer access)still open. Confirmed Phase 2 access to 3A-pad&spine road. 22:33 23:03 0.50 6,900 6,983 PROD1 WHPST MILL P B/U with 9.0#milling fluid 1.40 bpm in&.7 bpm out. Stop pumping and close EDC. RIH and dry tag @ 6983'. Choke wide open. Clean magents on shaker. IA=60/ OA 150 23:03 23:15 0.20 6,983 6,983 PROD1 WHPST MILL P P/U weight 34K,bring pumps online @ 1.40 bpm,3900(free spin), BHP 3460. rate out.9 bpm. 23:15 00:00 0.75 6,983 6,984 PROD1 WHPST MILL P Start seeing motor work-1.40 bpm, 3940 psi, BHP 3500, ECD 11.3, WHP-0,WOB.5,Ct weight 19K. rate out.90 bpm.Time drill first 1ft of window. 02/15/2011 Complete window milling with 10'of rat hole,back ream 30 deg left and right of HS, RIH HS. Drift window with no pumps. POOH, PU BHA#4(2.4 AKO). RIH.pump 10 bbrls high vis pill followed by new 9.7ppg Flo-Pro performing mud swap. RIH through window clean. Drill build section 7000'to 7155'. POOH.Total losses to formation last 24hrs, 142 bbls 9.1ppg FloPro SF milling fluid,56 bbls 9.7 ppg FloPro SF. 198 bbls. TOW=6982', BOW=6987', RA=6984' 00:00 01:00 1.00 6,984 6,985 PROD1 WHPST MILL P Milling-1.40 bpm,3900, BHP 3540, ECD 11.4,WHP 0,WOB 1.3K,Ct weight 17K, ROP 1fph. rate out 1 bpm. Set auto drill starting 1.5' into window.6984.7'.WOB not to exceed 2K.20 bbl losses last hour. 01:00 02:30 1.50 6,985 6,986 PROD1 WHPST MILL P Good metal shavings over shakers. 1.40 bpm,3910, BHP 3540, ECD 11.4,WOB 1.9K,Ct weight 15K, ROP 1 fph, 1.1 bpm returns. Keeping WOB at 2K or below. 12 bbl losses last hour. 02:30 04:30 2.00 6,986 6,986 PROD1 WHPST MILL P Potentially touching 7"-WOB 2K and ROP.7 fph. 6986.2'-WOB 2K, ROP.5 fph, 1.40 bpm,3850 psi,CT weight 15K. rate out 1.1bpm. 12 bbls losses last hour. 04:30 05:30 1.00 6,986 6,987 PROD1 WHPST MILL P Very light medal shaving over shakers-Increase ROP to 1 fph, WOB 2K. No stalls all night.. 05:30 06:00 0.50 6,987 6,987 PROD1 WHPST MILL P Increase to 1.5 bpm,4100, BHP 3570, ECD 11.5, ROP.7,WOB 2.2K. Page 4 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:18 3.30 6,987 6,988 PROD1 WHPST MILL P Crew change, Losses are at 9 BPH, continue milling 09:18 11:54 2.60 6,988 6,999 PROD1 'WHPST DRLG P Milling formation 11:54 13:30 1.60 6,999 6,999 PROD1 WHPST MILL P Back ream window at 1 FPM, 0, 30L,30R. Ream down at 0 and 1 FPM. Drift with pump down,clean window. 13:30 15:12 1.70 6,999 0 PROD1 WHPST TRIP P POOH 15:12 15:48 0.60 0 0 PROD1 WHPST PULD P Swap out BHA 15:48 16:30 0.70 0 0 PROD1 DRILL PULD P PU drilling BHA for build section 16:30 18:30 2.00 0 6,760 PROD1 DRILL TRIP P RIH 18:30 18:45 0.25 6,760 6,760 PROD1 DRILL DLOG P Tie in depth to K1 marker. +4.5' 18:45 19:30 0.75 6,760 6,760 PROD1 DRILL CIRC P Circulate 100 LSRV pill,chasing with new mud. Holding 11.8 ECD. 19:30 19:36 0.10 6,760 7,000 PROD1 DRILL TRIP P Close EDC, RIH through window without any weight bobbles. 19:36 23:06 3.50 7,000 7,155 PROD1 DRILL DRLG P Drill Ahead 10-50 FPH, 3880 CTP, 15K CTW, 3718 BHP, 11.8 ECD, 1.4 BPM in, 1.12 BPM out, 1K-2K WOB. 23:06 00:00 0.90 7,155 0 PROD1 DRILL TRIP P Land build section. POOH 02/16/2011 Undeploy BHA#4, Deploy BHA#5(1.4 AKO w/Resistivity)RIH,Drill 20 deg build section 7155'to 8055'. 137 bbls,Total losses for last 24hours. 00:00 01:00 1.00 3,000 0 PROD1 DRILL TRIP P Cont. POOH 01:00 01:15 0.25 0 0 PROD1 DRILL SFTY P At surface, PJSM 01:15 02:45 1.50 0 0 PROD1 DRILL PULD P Undeploy BHA#4 02:45 03:15 0.50 0 0 PROD1 DRILL PULD P MU BHA#5(1.4 AKO with resistivity) 03:15 03:30 0.25 0 0 PROD1 DRILL SFTY P PJSM 03:30 04:15 0.75 0 0 PROD1 DRILL PULD P Deploy BHA#5 04:15 06:15 2.00 72 6,700 PROD1 DRILL TRIP P RIH 06:15 07:09 0.90 6,700 7,155 PROD1 DRILL DLOG P Tie in,+10'. Inspect depth encoders, all good, log RA at 6984' 07:09 09:33 2.40 7,155 7,305 PROD1 DRILL DRLG P Tag and start drilling, 1.36 BPM, 3700 CTP,3746 BHP, 15K RIW 09:33 09:57 0.40 7,305 7,040 PROD1 DRILL DLOG P MAD pass,29K PUW 09:57 10:15 0.30 7,140 7,305 PROD1 DRILL WPRT P Wiper in hole 10:15 12:15 2.00 7,305 7,455 PROD1 DRILL DRLG P Drilling, 1.36 BPM, 3720 CTP,3766 BHP, 14K RIW 12:15 12:51 0.60 7,455 7,455 PROD1 DRILL WPRT P Wiper to window 12:51 15:09 2.30 7,455 7,605 PROD1 DRILL DRLG P Drilling, 1.36 BPM,3730 CTP,3770 BHP, 14K RIW 15:09 15:27 0.30 7,605 7,020 PROD1 DRILL WPRT P Wiper to winidow, 29K PUW 15:27 15:39 0.20 7,020 7,050 PROD1 DRILL DLOG P Tie in to RA,-1' 15:39 16:03 0.40 7,050 7,605 PROD1 DRILL WPRT P Wiper in hole, 15K RIW • Page 5 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:03 17:45 1.70 7,605 7,755 PROD1 DRILL DRLG P Drilling, 1.35 BPM,3800 CTP,3845 BHP, 14K RIW 17:45 18:45 1.00 7,755 7,755 PROD1 DRILL WPRT P Wiper to window,29K PUW 18:45 20:45 2.00 7,755 7,905 PROD1 DRILL DRLG P Drilling, 1.35 BPM in, 1.1 BPM out, 3950 CTP,3865 BHP, 14K RIW 20:45 21:30 0.75 7,905 7,905 PROD1 DRILL WPRT P Wiper to window,29K PUW 21:30 23:30 2.00 7,905 8,055 PROD1 DRILL DRLG P Drilling, 1.35 BPM in, 1.1 BPM out, 4050 CTP,3880 BHP, 14K RIW 23:30 00:00 0.50 8,055 8,055 PROD1 DRILL WPRT P Wiper to window,29K PUW 02/17/2011 Drill 20 deg build section 8055'to 8430'. POOH, Undeploy BHA 5, Deploy BHA 6(PDS caliper). RIH,Caliper log 8425'to 6950'TOWS. POOH.84 bbls,Total losses for last 24 hours. 00:00 00:45 0.75 8,055 6,984 PROD1 DRILL WPRT P Wiper to window,29K PUW 00:45 01:00 0.25 6,984 6,984 PROD1 DRILL DLOG P Tie in depth to RA marker-1.5' correction. 01:00 01:45 0.75 6,984 8,055 PROD1 DRILL WPRT P RIH 01:45 04:15 2.50 8,055 8,205 PROD1 DRILL DRLG P Drilling, 1.35 BPM in, 1.1 BPM out, 4050 CTP, 3880 BHP, 14K RIW 04:15 05:27 1.20 8,205 8,205 PROD1 DRILL WPRT P Wiper to window,29K PUW 05:27 08:06 2.65 8,205 8,355 PROD1 DRILL DRLG P Drilling, 1.35 BPM in, 1.2 BPM out, 3800CTP,3900 BHP, 14K RIW 08:06 08:48 0.70 8,355 7,000 PROD1 DRILL WPRT P Wiper to window,29K PUW 08:48 09:00 0.20 7,000 7,060 PROD1 DRILL DLOG P Tie in,-1' 09:00 09:36 0.60 7,060 8,355 PROD1 DRILL WPRT P Wiper back in hole, 15K RIW 09:36 11:36 2.00 8,355 8,430 PROD1 DRILL DRLG P Drilling, 1.35 BPM in, 1.2 BPM out, 3800CTP, 3900 BHP, 14K RIW 11:36 14:06 2.50 8,430 0 PROD1 DRILL TRIP P Pump low-vis/high-vis sweeps and POOH 14:06 15:06 1.00 0 0 PROD1 DRILL PULD P Undeploy BHA 15:06 16:45 1.65 0 0 PROD1 DRILL PULD P PJSM, PU BHA for caliper run 16:45 18:15 1.50 0 0 PROD1 DRILL PULD P Deploy BHA 18:15 20:00 1.75 59 6,758 PROD1 DRILL TRIP P RIH 20:00 20:15 0.25 6,758 6,758 PROD1 DRILL DLOG P Tie in depth to K1 marker+7' correction. 20:15 21:45 1.50 6,758 8,425 PROD1 DRILL TRIP P RIH to TD 21:45 23:24 1.65 8,425 6,700 PROD1 DRILL DLOG P Fingers open on caliper 948pm,wait 12 minutes, PUH 22 FPM,22:00, 30K PUW 23:24 00:00 0.60 6,700 4,000 PROD1 DRILL TRIP P Fingers retracted, POOH 02/18/2011 Drill L1 lateral 8430'to 9040'. 111 bbls,Total losses for last 24 hours. 00:00 01:00 1.00 4,000 0 PROD1 DRILL TRIP P POOH 01:00 03:00 2.00 0 0 PROD1 DRILL PULD P PJSM, Undeploy BHA 6, ,All fingers intacted. Data looks good from memory tool. 03:00 04:18 1.30 0 0 PROD1 DRILL PULD P MU and Deploy BHA 7 04:18 05:54 1.60 71 6,760 PROD1 DRILL TRIP P RIH Page 6 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:54 06:42 0.80 6,760 6,980 PROD1 DRILL DLOG P Tie-in, +6', log CCL,close EDC 06:42 07:42 1.00 6,980 8,430 PROD1 DRILL TRIP P Continue RIH 07:42 09:48 2.10 8,430 8,580 PROD1 DRILL DRLG P Drilling, 1.33 BPM, 3950 CTP,3920 BHP, 12K RIW 09:48 11:48 2.00 8,580 8,580 PROD1 DRILL WPRT P Wiper to window,29K PUW 11:48 13:48 2.00 8,580 8,728 PROD1 DRILL DRLG P Conrtinue drilling, 1.34 BPM,3950 CTP,3920 BHP, 12K RIW 13:48 15:42 1.90 8,728 8,728 PROD1 DRILL WPRT P Wiper trip, 31K PUW 15:42 18:27 2.75 8,728 8,880 PROD1 DRILL DRLG P Conrtinue drilling, 1.32 BPM,3920 CTP,3924 BHP, 12K RIW 18:27 21:00 2.55 8,880 8,880 PROD1 DRILL WPRT P Wiper trip, 31K PUW,Tie in depth to RA marker 21:00 00:00 3.00 8,880 9,040 PROD1 DRILL DRLG P Conrtinue drilling, 1.32 BPM,3950 CTP,3984 BHP, 12K RIW 02/19/2011 TD L1 lateral 9200'. Pump low/high sweeps chasing to surface. RBIH to TD. Lay in liner running pill to window. POOH displacing well to 12ppg KWF(Sodium Bromide). PU/MU 58jnts with liner top billet. RIH releasing liner on bottom 9208'TOL 7285'.. POOH.45 bbls 9.7ppg Flo-Pro,62 bbls 12 ppg Sodium Bromide KWF,Total Losses for last 24 hours 107bbls. 00:00 02:30 2.50 9,040 9,040 PROD1 DRILL WPRT P Wiper trip to window,29K PUW 02:30 05:00 2.50 9,040 9,200 PROD1 DRILL DRLG P Conrtinue drilling, 1.32 BPM,4200 CTP,4041 BHP, 12K RIW 05:00 08:00 3.00 9,200 0 PROD1 DRILL WPRT P TD,pump low/high sweeps,wiper to the swab 08:00 09:30 1.50 0 6,770 PROD1 DRILL WPRT P Wiper back in hole 09:30 09:48 0.30 6,770 6,800 PROD1 DRILL DLOG P Tie in, +8' 09:48 10:42 0.90 6,800 9,200 PROD1 DRILL WPRT P Continue RIH 10:42 13:42 3.00 9,200 0 PROD1 DRILL DISP P Lay in liner pill to window, KWF to surface, paint EOP flag's at 7200' and 4900' 13:42 14:00 0.30 0 0 PROD1 DRILL SFTY P PJSM for laying down BHA,flow check well 14:00 14:42 0.70 0 0 PROD1 DRILL PULD P Lay down BHA 14:42 15:12 0.50 0 0 COMPZ CASING PUTB P Rig up floor for liner operations 15:12 15:30 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations 15:30 17:30 2.00 0 0 COMPZ CASING PUTB P PU 58 joints slotted liner 17:30 18:00 0.50 0 0 COMPZ CASING SFTY P Crew change, PJSM 18:00 19:00 1.00 1,964 6,857 COMPZ CASING PUTB P MU coiltrac BHA and injector to well 19:00 20:15 1.25 6,857 6,864 COMPZ CASING RUNL P RIH,Tie into EOP flag,+7' correction. Record up weight 29.5K PUW, 20:15 21:30 1.25 6,864 9,209 COMPZ CASING RUNL P Rlh to TD,5K set down billet running through window. 21:30 21:45 0.25 9,209 9,209 COMPZ CASING RUNL P Tag TD. Liner on bottom.Online with pumps 4200psi. PUH to release off liner,29K PUW, PUH to above window 21:45 22:15 0.50 9,209 6,758 COMPZ CASING RUNL P Remove liner depth PUH to K1 marker to tie in depth. Page 7of15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:15 22:30 0.25 6,758 6,758 COMPZ CASING DLOG P Tie in depth to K1 marker, +.5' correction 22:30 00:00 1.50 6,758 0 COMPZ CASING RUNL P POOH 02/20/2011 Perform BOPE Function Test, RIH BHA 9(1.4 AKO)Displace well back to 9.7ppg old Flo-Pro.Sidetrack L1-01 Lateral 7285'. Drill 20deg build 7290-76042.Swap out old 9.7ppg to new 9.5ppg Flo-Pro.56bbls of 9.7ppg Flo-Pro,20bbls 12ppg Soium Bromide KWF,Total losses for last 24 hours,76 bbls. 00:00 00:15 0.25 0 0 COMPZ CASING SFTY P PJSM,monitor well for flow 00:15 00:45 0.50 0 0 COMPZ CASING PULD P LD BHA 8, 00:45 01:00 0.25 0 0 PROD2 DRILL BOPE P PJSM, Perform Function Test on BOPE. 01:00 02:00 1.00 0 0 PROD2 STK PULD P PU BHA 9(1.4 AKO, Hycalog Razor bit) 02:00 03:45 1.75 72 6,795 PROD2 STK TRIP P RIH 03:45 04:00 0.25 6,790 6,795 PROD2 STK DLOG P Tie in depth to K1 marker.+5' correction. RIH 04:00 06:12 2.20 6,758 6,950 PROD2 STK CIRC P Displace well to Flo-Pro 06:12 08:36 2.40 6,950 7,293 PROD2 STK KOST P Dry tag billet then start milling at 1 FPH, 1.4 BPM,4050 CTP,3820 BHP, 15K RIW,20 ROHS. Increase V to 2FPH at 7286.0',3 FPH at 7287', 1-(d0110 FPH at 7288'. consistent motor work and WOB throughout 08:36 09:30 0.90 7,293 7,315 PROD2 STK KOST P Drilling formation, 1.4 BPM,4000 CTP, 3806 BHP, 14K RIW 09:30 09:42 0.20 7,315 7,315 PROD2 STK KOST P Drift billet,28K PUW at.3 BPM, 17.5K RIW at 0 BPM,clean both ways 09:42 14:54 5.20 7,315 7,435 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,4000 CTP,3820 BHP, 14:54 15:39 0.75 7,435 7,435 PROD2 DRILL WPRT P Wiper to the window,29K PUW, 17K RIW 15:39 20:39 5.00 7,435 7,543 PROD2 DRILL DRLG P Drilling, 1.3 BPM,4100 CTP,3823 BHP,Stacking weight stalling. 20:39 22:09 1.50 7,543 7,543 PROD2 DRILL WPRT P Wiper Trip to window 27K PUW, start taking returns to tiger tank for mud swap.9.5ppg Flo-Pro 22:09 22:39 0.50 7,543 7,560 PROD2 DRILL DRLG P Drill Ahead, 1.3 BPM, 1.2 BPM out 3750 CTP,3860 BHP, Mud at bit only. 22:39 00:00 1.35 7,560 7,604 PROD2 DRILL DRLG P Drilling Ahead 30-50 FPH, 1.3 BPM in, 1.2 BPM out,3750 CTP,3650 BHP, Ratty drilling 02/21/2011 Drill L1-01 Lateral,7604-7766',(20deg build). Ratty drilling,stalling.Maximum ROP 30 FPH.POOH BHA 9, Swap motors, RIH BHA 10. Ratty drilling,stalling slower ROP's. POOH,swap out entire BHA and bit to Hughes Christensen, Pressure test CTC, Inspect check valves. RIH Total losses last 24 hours 24bbls 9.5ppg Flo-Pro Page 8 of 15 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 7,604 7,628 PROD2 DRILL DRLG P Drilling Ahead 20-30 FPH, 1.3 BPM in, 1.2 BPM out, 3850 CTP,3730 BHP, Ratty drilling,stalling, Unable to drill past 30 FPH,Stalling. In good sands, in good sand as per Geo. Possible bit balling,seems to be Bit related. Possible aluminum on Bit. Try running in slow,fast. Not drilling. 02:00 02:30 0.50 7,628 7,000 PROD2 DRILL WPRT P PUH to window,28K PUW 02:30 02:36 0.10 7,000 6,925 PROD2 DRILL WPRT P PU through window into 4"ID tubing. Online with pumpsl.5 BPM picking up hole slow 6960 to 6940'. Attempting to clean up bit. 02:36 03:06 0.50 6,925 6,925 PROD2 DRILL WPRT P RIH to drill 03:06 03:36 0.50 7,628 7,647 PROD2 DRILL DRLG P Drill Ahead,same parameters, ratty drilling,unable to exceed 20-30 FPH. Geo assured we are in A3. Lower pump rate 1.3 BPM 03:36 06:24 2.80 7,647 0 PROD2 DRILL TRIP P POOH to inspect bit 06:24 08:42 2.30 0 0 PROD2 DRILL PULD P Change out moter, rerun bit 08:42 10:24 1.70 0 6,820 PROD2 DRILL TRIP P RIH 10:24 10:36 0.20 6,820 6,850 PROD2 DRILL DLOG P Tie-in,+5' 10:36 11:00 0.40 6,850 7,647 PROD2 DRILL TRIP P Continue RIH, 17K RIW 11:00 14:12 3.20 7,647 7,746 PROD2 DRILL DRLG P Tag bottom and start drilling, 1.34 BPM,3850 CTP,3770 BHP. Stalls with<2K WOB 14:12 15:00 0.80 7,746 7,746 PROD2 DRILL WPRT P Stacking surface weight with continued stalls and low ROP,29K PUW, 16K RIW 15:00 16:00 1.00 7,746 7,766 PROD2 DRILL DRLG P Continue to"attempt"to drill ahead. 1.32 BPM,3750 CTP,3740 BHP 16:00 18:30 2.50 7,766 0 PROD2 DRILL TRIP P POOH,29K PUW 18:30 20:30 2.00 0 0 PROD2 DRILL PULD P PJSM, Undeploy BHA 20:30 21:30 1.00 0 0 PROD2 DRILL PULD P MU new BHA 21:30 22:30 1.00 0 0 PROD2 DRILL SVRG P Grease Tree valves, Pressure test Coil Tubing Connector 4000psi. Inspect check valves.All pass 22:30 00:00 1.50 0 0 PROD2 DRILL PULD P PJSM, Deploy 11 02/22/2011 Drill L1-01 20 deg build to 7766 to 8370'. POOH. Undeploy BHA 11, Deploy BHA 12(.8 deg AKO). RIH, Drill L1-01 lateral 8370 to 8520'. 50bbls 9.5 ppg Flo-Pro,Total losses for last 24 hours. 00:00 01:30 1.50 72 6,770 PROD2 DRILL TRIP P RIH 01:30 01:45 0.25 6,770 6,770 PROD2 DRILL DLOG P Tie in depth with K1 marker 01:45 02:15 0.50 6,770 7,766 PROD2 DRILL TRIP P Close EDC, RIH to drill 02:15 04:00 1.75 7,766 7,920 PROD2 DRILL DRLG P Drill Ahead, 120-150 FPH.3940 CTP, 16K CTW, 1.5-2K WOB,3745 BHP 04:00 05:00 1.00 7,920 7,920 PROD2 DRILL WPRT P Wiper Trip to Window,28.5K PUW Page 9 of 15 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05:00 07:00 2.00 7,920 8,070 PROD2 DRILL DRLG P Drill Ahead, 118 FPH.3980 CTP, 16K CTW, 1-1.5K WOB,3746 BHP 07:00 07:54 0.90 8,070 8,070 PROD2 DRILL WPRT P Wiper to the window,29K PUW 07:54 09:42 1.80 8,070 8,220 PROD2 DRILL DRLG P Drill Ahead, 1.3 BPM, 3800 CTP, 3826 BHP, 16K RIW. 09:42 10:24 0.70 8,220 7,015 PROD2 DRILL WPRT P Wiper to window 10:24 10:36 0.20 7,015 7,050 PROD2 DRILL DLOG P Tie-in,+4.5' 10:36 11:06 0.50 7,050 8,220 PROD2 DRILL WPRT P Wiper back in hole 11:06 12:24 1.30 8,220 8,370 PROD2 DRILL DRLG P Drill Ahead, 1.3 BPM,3800 CTP, 3826 BHP, 16K RIW. 12:24 14:54 2.50 8,370 0 PROD2 DRILL TRIP P POOH for motor adjustment,29K PUW 14:54 18:54 4.00 0 0 PROD2 DRILL PULD P Undeploy BHA#11,deploy BHA #12 18:54 20:39 1.75 0 6,798 PROD2 DRILL TRIP P RIH 20:39 20:54 0.25 6,798 6,798 PROD2 DRILL DLOG P Tie in depth tto K1 Marker+5' correction 20:54 21:45 0.85 6,798 8,370 PROD2 DRILL TRIP P RIH to drill 21:45 23:00 1.25 8,370 8,468 PROD2 DRILL DRLG P Drill Ahead, 1.36 BPM in 1.2 BPM out,4000 CTP, 3906 BHP, 16K RIW. 23:00 23:21 0.35 8,468 8,468 PROD2 DRILL WPRT P Loosing prime on pump. Mud aerated. PUH 33K PUW 23:21 23:51 0.50 8,468 8,520 PROD2 DRILL DRLG P Drill Ahead, 1.36 BPM in 1.2 BPM out,4250 CTP, 3913 BHP, 16K RIW. 23:51 00:00 0.15 8,520 8,520 PROD2 DRILL WPRT P Wiper trip to window 29K PUW 02/23/2011 Drill L1-01 lateral 8520 to 9147'. Phase 3 called, Pick up into cased hole and circulate. 00:00 01:45 1.75 8,520 8,520 PROD2 DRILL WPRT P Wiper trip 01:45 03:30 1.75 8,520 8,670 PROD2 DRILL DRLG P Drill Ahead, 1.36 BPM in 1.2 BPM out,4250 CTP, 3913 BHP, 16K RIW. 03:30 05:15 1.75 8,670 8,670 PROD2 DRILL WPRT P Wiper trip to window 29K PUW 05:15 08:03 2.80 8,670 8,819 PROD2 DRILL DRLG P Drill Ahead, 1.39 BPM,4150 CTP, 3940 BHP, 16K RIW. Started to stack weight last 5'of drilling. 08:03 10:03 2.00 8,819 8,819 PROD2 DRILL WPRT P Wiper to window,29K PUW. 10:03 12:57 2.90 8,819 8,970 PROD2 DRILL DRLG P Drill Ahead, 1.37 BPM,4180 CTP, 3950 BHP, 15K RIW. 12:57 14:57 2.00 8,970 8,970 PROD2 DRILL WPRT P Wiper to window,29K PUW, over pull at 8814'with no motor work, RBIH and come through with no over pull,continue wiper trip. 14:57 17:57 3.00 8,970 9,120 PROD2 DRILL DRLG P Drill ahead. Lost returns at 8990, choke had been closed in to hold 180 WHP while RIH on wiper and forgot to open up, BHP was 9140 PSI. Opened choke and returns at 1 BPM, 1.3 BPM pump rate. 3950 CTP, 3940 BHP. Continue drilling ahead 17:57 20:27 2.50 9,120 9,120 PROD2 DRILL WPRT P Wiper trip to window, 30K PUW Page 10 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:27 21:00 0.55 9,120 9,147 PROD2 DRILL DRLG P Drill Ahead 1.3 BPM in, 1 BPM out, 3950 BHP,4000 CTP 21:00 23:30 2.50 9,147 6,970 PROD2 DRILL CIRC T Phase 3 called, PU to cased hole. 15 FPM, 23:30 00:00 0.50 6,970 6,970 PROD2 DRILL CIRC T Open EDC,continue to circulate, PUH every 15 minutes assuring pipe free,waiting on weather 02/24/2011 Wait on Phase 3 weather(midnight to 6am). Drill L1-01 Lateral 9147 to 9252'TD.Wiper trip to swab valves, RBIH to TD,lay in liner running pill to window, Displace 12ppg KWF,window to surface. PU 25jnts slotted liner with OH anchored billet.Total losses last 24 hours 77bbls FLo-Pro. 00:00 06:30 6.50 6,970 6,970 PROD2 DRILL CIRC T Wait on Weather 06:30 07:30 1.00 6,970 6,770 PROD2 DRILL CIRC T Phase 1 conditions,waiting on fluids 07:30 07:39 0.16 6,770 6,793 PROD2 DRILL DLOG T Tie in to K1, +3' 07:39 08:39 1.00 6,793 9,147 PROD2 DRILL WPRT T RIH 08:39 10:51 2.20 9,147 9,252 PROD2 DRILL DRLG P 1.3 BPM, 3950 CTP,3960 BHP, 15K RIW, losing 15-20 Bbls/hour 5 Bbls low/10 Bbls high vis sweeps. 10:51 14:09 3.30 9,252 0 PROD2 DRILL WPRT P TD,wiper to the swab,29K PUW 14:09 15:39 1.50 0 6,770 PROD2 DRILL WPRT P RBIH 15:39 15:51 0.20 6,770 6,790 PROD2 DRILL DLOG P Tie into K1,+4' 15:51 17:03 1.20 6,790 9,252 PROD2 DRILL WPRT P Close EDC and continue RIH, 17K RIW 17:03 20:30 3.45 9,252 0 PROD2 DRILL DISP P Lay in liner running pill, KWF and POOH,28K PUW, paint flags at 8300'EOP and 6000'EOP 20:30 20:45 0.25 0 0 PROD2 DRILL OWFF P At surface, Flow check, PJSM 20:45 21:45 1.00 0 0 PROD2 DRILL PULD P LD BHA 21:45 22:30 0.75 0 0 COMPZ CASING PUTB P PJSM, Prepare floor to PU liner, Service injector head 22:30 23:12 0.70 0 0 COMPZ CASING PUTB P PU 25 jnts liner with OH anchored billet 23:12 23:27 0.25 0 0 COMPZ CASING PUTB P #14 jnt. Perform BOP drill while running liner. PU safety joint,MU with people in place.5 minutes. Hold discussion. 23:27 23:59 0.54 0 0 COMPZ CASING PUTB P Continue running liner 02/25/2011 Set liner on bottom with OH anchored billet,9252'.TOB 8411'. POOH above window,circulating KWM across top,performing weight checks.wait on weather.65bbls KWM Total losses last 24hours. Shut down phase 3. 00:00 01:30 1.50 0 0 COMPZ CASING PUTB P Conitnue running liner 01:30 03:30 2.00 902 6,896 COMPZ CASING RUNL P RIH 03:30 03:45 0.25 6,901 6,950 COMPZ CASING RUNL P Tie into EOP flag+5'correction, RIH to TOW. Record up and down weights.Offline with pumps,open bleeder on pumps,Close EDC.20K RIW,29K PUW 03:45 04:51 1.10 6,950 9,255 COMPZ CASING RUNL P RIH to TD Page 11 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:51 05:06 0.25 9,255 9,252 COMPZ CASING RUNL P Tag TD 9255.43,3.5K WOB. PU 30K CTW, 1.5K WOB. Orient TF 160 ROHS.Close bleeders on pump, online with pumps setting OH anchor releasing off liner. 3100psi CTP3.5K WOB, RIH set down weight 5K. Good set. 05:06 06:06 1.00 9,252 6,950 COMPZ CASING RUNL P POOH above window and circulate. Phase 3 06:06 00:00 17.90 6,950 6,950 COMPZ CASING CIRC T Phase 3,wait on weather 02/26/2011 Wait on weather. POOH, Undeploy L1-02 Liner BHA. Perform Bi-Weekly BOPE test.Waived by State. (Matt Herrera) 00:00 10:00 10.00 6,797 6,797 COMPZ CASING CIRC T Wait on weather 10:00 14:42 4.70 6,797 6,790 COMPZ CASING CIRC T Circulate well to flo-pro 14:42 16:12 1.50 6,790 0 COMPZ CASING TRIP P POOH, 16:12 16:36 0.40 0 0 COMPZ CASING SFTY P PJSM for undeployment 16:36 20:00 3.40 0 0 COMPZ CASING PUTB P Undeploy liner running BHA 20:00 21:00 1.00 0 0 PROD3 DRILL CIRC P Flush stack/choke valves,Grease, and prepare for BOP test 21:00 00:00 3.00 PROD3 DRILL BOPE P Bi-Weekly BOPE test ***Waived by Chuck Sheve**** 02/27/2011 Complete BOPE test. (0 Failures). RIH Sidetrack for L1-02 lateral,drill ahead 8411 to 8750'.49bbls Total losses last 24 hours. 00:00 06:00 6.00 0 0 PROD3 DRILL BOPE P BOPE testing BOP testing complete 9hrs 06:00 06:30 0.50 0 0 PROD3 DRILL SFTY P Crew change PJSM • 06:30 07:48 1.30 0 0 PROD3 DRILL BOPE P Testing inner reel valve, install checks in UQC, 07:48 08:00 0.20 0 0 PROD3 STK SFTY P PJSM for deployment of BHA 08:00 10:00 2.00 0 0 PROD3 STK PULD T Deploy drilling BHA 10:00 11:42 1.70 0 6,770 PROD3 STK TRIP T RIH 11:42 12:00 0.30 6,770 6,790 PROD3 STK DLOG T Tie in to K1,+5' 12:00 12:42 0.70 6,790 8,413 PROD3 STK TRIP T Close EDC and continue RIH 12:42 15:24 2.70 8,413 8,445 15ROD3 STK KOST T Tag billet at 8413'and start time milling at 1 FPH, 1.4 BPM,4000 CTP, 3850 BHP, losing.1 BPM returns. 1 FPH for first foot,2 FPH 4/•,02— for next foot, 3 FPH for next foot, 10 FPH for next five feet,then drill ahead 15:24 15:36 0.20 8,445 8,445 PROD3 STK KOST T PUH and drift billet 15:36 16:48 1.20 8,445 8,560 PROD3 DRILL DRLG T Drill ahead, 1.4 BPM,4000 CTP, 3830 BHP 16:48 18:48 2.00 8,560 8,560 PROD3 DRILL WPRT T Wiper to the window,29K PUW Page 12 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:48 21:30 2.70 8,560 8,710 PROD3 DRILL DRLG T Drill ahead, 1.4 BPM,4000 CTP, 3840 BHP 21:30 22:45 1.25 8,710 8,710 PROD3 DRILL WPRT T Wiper to the window,29K PUW 22:45 00:00 1.25 8,710 8,750 PROD3 DRILL DRLG T Drill ahead, 1.4 BPM,4000 CTP, 3850 BHP 02/28/2011 8750'to 9300'TD.Wiper trip to swab valves, RBIH to TD lay in liner running pill, POOH. 00:00 01:00 1.00 8,750 8,860 PROD3 DRILL DRLG T Drill ahead, 1.4 BPM,4000 CTP, 3860 BHP 01:00 03:15 2.25 8,860 8,860 PROD3 DRILL WPRT T Wiper trip to window 29K PUW,Tie in depth with RA marker-1' correction. 03:15 05:00 1.75 8,860 9,010 PROD3 DRILL DRLG T Drill ahead, 1.4 BPM,4000 CTP, 3860 BHP 05:00 06:36 1.60 9,010 6,950 PROD3 DRILL WPRT T Wiper trip to window 29K PUW, 06:36 07:36 1.00 6,950 6,950 PROD3 DRILL SVRG T Need to reboot choke computer, pull up into cased hole and test chokes 07:36 09:00 1.40 6,950 9,010 PROD3 DRILL WPRT T Wiper back in hole 09:00 10:54 1.90 9,010 9,160 PROD3 DRILL DRLG T Drilling, 1.3 BPM,3800 CTP,3880 BHP, losing<2 BPH 10:54 13:42 2.80 9,160 9,160 PROD3 DRILL WPRT T Wiper to window,30K PUW 13:42 16:00 2.30 9,160 9,300 PROD3 DRILL DRLG T Drilling, 1.35 BPM,4100 CTP,3940 BHP, 16:00 20:00 4.00 9,300 0 PROD3 DRILL WPRT T TD! Pump low/high sweeps and Wiper to the swabs. 20:00 21:30 1.50 0 6,758 PROD3 DRILL WPRT T RBIH 21:30 21:45 0.25 6,758 9,300 PROD3 DRILL DLOG T Tie into K1 marker, RIH to TD 21:45 23:45 2.00 9,300 7,000 PROD3 DRILL TRIP T Pump liner pill to bit, Lay in liner running pill,9300'to 7000' 23:45 00:00 0.25 7,000 0 PROD3 DRILL TRIP T POOH Paint EOP flag 5671' 03/01/2011 Run final liner completion strings from 9300'-6917'(TOL). 00:00 02:00 2.00 0 1,780 PROD3 DRILL TRIP T Cont. POOH 02:00 02:15 0.25 1,780 1,780 PROD3 DRILL CIRC T Flush SSSV through EDC 02:15 02:30 0.25 1,700 1,700 PROD3 DRILL OWFF T PU above SSSV. Close SSSV and bleed of well.test good 02:30 03:00 0.50 1,700 0 PROD3 DRILL TRIP T POOH 03:00 03:15 0.25 0 0 PROD3 DRILL OWFF T PJSM,flow check well 03:15 04:15 1.00 0 0 PROD3 DRILL PULD T LD BHA 04:15 04:45 0.50 0 0 COMPZ CASING PUTB T Prep floor for running liner 04:45 05:03 0.30 0 0 COMPZ CASING SFTY T PJSM, PU liner 05:03 08:03 3.00 0 1,243 COMPZ CASING PUTB T PU 36 Joints liner and Coiltrack BHA 08:03 09:48 1.75 1,243 6,843 COMPZ CASING RUNL T RIH,correct to EOP flag,+4 09:48 11:03 1.25 6,843 9,302 COMPZ CASING RUNL T Continue RIH Page 13 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:03 12:18 1.25 9,302 6,936 COMPZ CASING RUNL T Setdown @ 9304. PUH to Neutral weight @ 9302' Punp 1.25 BPM @ 4100PSI PUH Liner released DHWOB @ 600Lbs Trip Out 12:18 12:48 0.50 6,936 8,129 COMPZ CASING RUNL T 6336(8134 with liner)had overpull— ' 50'above widow. Looks like might have liner, RBIH and set down on DHWOB.Going back to bottom (added liner back in to bit depth 1198.09) 12:48 13:54 1.10 9,304 6,775 COMPZ CASING RUNL T 9304 in compression, Pump off liner, Start OOH 13:54 15:54 2.00 6,775 44 COMPZ CASING TRIP T At K-1 tie in,subtract out liner left in well,Tie in for+2.5'correction. BOL=9306 TOL Lower segment 8107.9 Paint EOP Flags @5700&6800 POOH 15:54 16:54 1.00 44 0 COMPZ CASING PULD T At surface,Close SSSV,flo check well, Pull BHA#15 from well 16:54 21:00 4.10 0 1,237 COMPZ CASING PUTB P PJSM, P/U ported sub and 36 Joints of slotted liner 21:00 23:30 2.50 1,237 8,108 COMPZ CASING TRIP P RIH pumping through EDC @.3 bpm.Correction+3.5 ft correction. RIH weight 17K-P/U weight 30K. Set down 3K @ 8108'. 23:30 00:00 0.50 8,108 6,760 COMPZ CASING TRIP P Pump rate 1.35 bpm,4200 psi, P/U weight 26K. Pull up to K-1 tie in point and start pumping SW.+3 ft correction. TOL=6917' 03/02/2011 Set BPV-thaw out Tiger tank line&pump corrossion inhibitor through rig and coil. Purge, unstab pipe and RDMO.***Rig release at midnight**** 00:00 03:30 3.50 6,760 48 COMPZ CASING TRIP P POOH pumping Sea-water up to 2500'then pump heated diesel for freeze protect. 03:30 05:00 1.50 48 0 COMPZ CASING PULD P PJSM- Pressure undeploy BHA, Unload PDL's Coil track to pipe shed 05:00 07:00 2.00 0 0 DEMOB WHDBO NUND P Set BPV, Final SITP=600 07:00 07:30 0.50 0 0 DEMOB WHDBO CTOP P M/U Nozzle and stab back on well to circulate inhibitor 07:30 16:00 8.50 0 0 DEMOB WHDBO CTOP T Line to tiger tank frozen, Iron in wheel room frozen, Break down backside iron and bring in.Steam lines in wheel room NAD Downtime starts 16:00 16:30 0.50 0 0 DEMOB RIGMNT CIRC P PJSM/Perform Valve checklist Pumping getting returns to tiger tank PT Backside line End NAD Downtime 16:00 16:30 18:30 2.00 0 0 DEMOB RIGMNT CIRC P Start inhibitor procedure Page 14 of 15 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:30 23:30 5.00 0 0 DEMOB RIGMNT CTOP P Crew change-PJSM blowing down rig&CT string for rig down process &unstabbing CT string. break down hard line and rig iron. 23:30 00:00 0.50 0 0 DEMOB WHDBO BOPE P RDMO-Rig release @ midnight. Page 15 of 15 Letter of Transmittal r' I BAKER Date: March 11, 2011 HUGHES To: From: Christine Mahnken Carl Ulrich/Tai Sturdivant AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3A-07L1 3A-07L1-01 3A-07L1-02 (3) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Tai Sturdivant, Baker Hughes Drilling Applications Engineer Tai.Sturdivant@bakerhughes.com Carl.Ulrich, Baker Hughes Survey Manager Carl.Ulrich@bakerhughes.com /i-- 00-6/ 0 j-Dar—ara Page 1 of 1 Schwartz, Guy L (DOA) p7--) 2<(-o/ L_ From: Schwartz, Guy L (DOA) Sent: Wednesday, February 16, 2011 10:06 AM To: 'Ohlinger, James J' Subject: RE: 3A-07 H2S alarm Thanks James.... As per 20 AAC 25.065 (a) you have reported a H2S incident of>20 ppm . This email notification fulfills that requirement and will be filed in out rig folder for CDR2-AC. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ohlinger, James J mailto:James.J.Ohlin er Conoco hilli s.com � 9 P P l Sent: Tuesday, February 15, 2011 2:02 PM To: Schwartz, Guy L (DOA) Subject: 3A-07 H2S alarm (Feb. 14th, 10:48am)While starting to pull out of the hole after setting the whipstock on 3A-07 (6978' set depth), the H2S alarm at the shaker activated. 28 ppm was detected and the return line was shut. The rig was evacuated and once all the sensors were zero, operations circulated seawater around and out to the tiger tank. Attached are the operation reports. Please give me a call if you have any questions or need further information or documentation. James Ohlinger CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-748-1051 cell 2/16/2011 0 [F ALLa SEAN PARNELL,GOVERNOR ALASKA OIL ANI) GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 J. V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-07L1-01 ConocoPhillips Alaska, Inc. Permit No: 211-012 Surface Location: 623' FSL, 774' FEL, SEC. 07, T12N, R9E, UM Bottomhole Location: 609' FNL, 1176' FWL, SEC. 17, T12N, R9E, 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 3A-07, Permit No 185- 223, API 50-029-21444-00. Injection should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. 5�f- Chair DATED this day of February, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) iltfLer.,1v 4;4? STATE OF ALASKA IAN 8 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL " �i"`i R og Calcis,ez^ t"fssian 20 AAC 25.005 Kill,;11F4E la.Type of Work: ' 1b.Proposed Well Class: Development-Oil ❑ Service-Winj ✓❑ * Single Zone ❑ . 1c.Specify if well is proposed for: Drill ❑ Re-drill❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Service-WAG Service-Dis Shale Gas ❑ Exploratory Re entry ❑ ❑ ❑ P ❑ 2.Operator Name: 5. Bond: U Blanket Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 3A-07L1-01 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9250' ' TVD: 6078' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:623'FSL,774'FEL,Sec.7,T12N,R9E,UM ' ADL 25631,25632 . Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1410'FNL, 1483'FWL,Sec. 17,T12N,R9E,UM 2564,2565 2/7/2011 Total Depth: 9.Acres in Property: 14.Distance to 609'FNL, 1176'FWL,Sec. 17,T12N, R9E, UM 2560 Nearest Property: 22350' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: - 73 feet 15.Distance to Nearest Well Open Surface:x- 507673 w y- 5997005- Zone- 4 GL Elevation above MSL: - 41 feet to Same Pool: 3A-17AL2-01 ,780' 16.Deviated wells: Kickoff depth: 7300' ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 103' deg Downhole:3633 psig - Surface:3040 psig 18.Casing Prosram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data). 3" 2.375" 4.7# L-80 ST-L 2330' 6920' 5945' 9250' 6078' slotted liner ✓ ,A3 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) 7325' 6328' 7191' 6225' Casing Length Size Cement Volume MD ND Conductor/Structural 104' 2 16" 185 sx AS II 104' 104' Surface 3146' 9.625" 1000 sx AS III,350 sx Class G 3176' 3086' Intermediate Production 7257' 7" 125 sx Healy fly ash, 7281' 6295' Liner 300 sx Class G,175 sx AS I Perforation Depth MD(ft): Perforation Depth TVD(ft): 6888'-6922',6990'-7010',7024'-7060',7118'-7128' 5993'-6020',6073'-6088',6099'-6126',6171'-6178' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: !//7/I/ 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 a. Printed Name J. V. Cawve Title Alaska Wells Manager Signature 70— Phon 265-6306 Date ?fr.... ' t Commission Use Only Permit to Drill API Numbe. Permit Appro I See cover letter zO z-9-i I �'i! l- '` Number: I — 50- Hate: �, , 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 4 3s-00 fisi. i6QP 77,7z Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No Other: H2S measures: Yes [ 1" No ❑ Directional svy req'd: Yes R. No ❑ AA — LW-/m.�Jte o lap nc.-- 'dr• g.. Ace-0✓ • Y/ 4A-1/ 10 /i Mir /�— C _ �j APPROVED THE COMMISSION ` / DAT ', ., � ` • ,COMMISSIONER Z7/// Form 10-401 (Revised 7/2009) This permit is al 2 o z rkfniih, of approval(20 AAC 25.005(g)) 6.0, Submit in Duplicate / a.e.. /-X-/( 1404 ‘ Permit to Drill Summary of Operations KRU 3A-07L1, and 3A-07L1-01 Laterals Coiled Tubing Drilling Overview: Well 3A-07 was originally drilled and completed in Nov. 1985 as a selective single A&C sand gas lift producer. It remained on production for 5 years and was then converted to injection. This well has had a steady injection history, primarily on seawater injection. It was shut-in in March 2010 when it was chosen as a candidate for a CTD sidetrack. The well was flowed back for 5-6 months to allow the pattern to de-pressure. The well is going through a rig work over with the objective to pull the entire selective completion including the 2 %"tubing tail, and recompleting it with an all 3 '/2" selective completion and set it up for a CTD sidetrack. This well will be sidetracked with two laterals in the A2 & A3 sands to provide injection support for 3A-17 and protect approximately 698 MBOE of resources at risk. The sidetrack will utilize a thru-tubing whipstock to mill through the 5-1/2"tubing tail and 7"casing. The top of the whipstock is planned for 6,980' MD. The first CTD lateral will kick off in the A5/4 and land in the A2 sand,then make a long horizontal turn (270°turn from motherbore)to obtain several cross cuts of the A2. The second lateral will kick off from 3A-07AL1 around 7,300'to acquire footage in the A3. The 3A-07L1 is planned for a 2-3/8"slotted liner with a liner-top aluminum billet for the KOP for the L1-01 lateral at—7,300' MD. The 3A-07L1-01 will be completed with 2-3/8"slotted liner from TD to—6,920'MD in the original well bore, above the F-1 packer at 6,925'. Operational Outline Pre-Rig Work • Slickline: Dummy whipstock drift • E-Line: Set 3-1/2"x 5-1/2"Thru-tubing whipstock • O: Set BPV, prepare Wellsite for rig arrival Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU BOPE and test 2. Mill 2.80"window at 6,974' in the 5-1/2' tubing tail & 7"casing 3. 3A-07L1 Lateral a. Drill a 2.70"x 3"bi-center lateral to a TD of 9,150' MD b. Run the 2%" slotted liner to TD with an aluminum liner top billet at--730.0' 1.i1 4. 3A-07L1-01 Sidetrack a. Kick off of the aluminum liner top billet at 7,300' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 9,250' MD c. Run the 2%" slotted liner from TD up to 6,920' (inside the 3-1/2"tubing, above the F-1 Packer) 5. ND stack, Set BPV 6. RDMO Page 2 of 5 1/13/2011 fl ! ! GjNAL Permit to Drill Summary L. operations Cont. Kr._JA-07L1,and 3A-07L1-01 Post-Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Mud Program • Chloride-based Biozan brine (8.9 ppg) for milling operations, and chloride-based Flo-Pro mud (-9.70 ppg) for drilling operations. • 3A-07 will have a 3-1/2" TRMAXX-CMT-SR-5 SSSV, therefore a completion fluid will not be utilized to kill the well for liner running. 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. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD 3A-07L1 7,300 9,150 2'/.",4.7#, L-80, ST-L slotted Unanchored aluminum billet 3A-07L1-01 6,920 9,250 2%",4.7#, L-80, ST-L slotted Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 62 H-40 0 104 1,640 630 Surface 9°18" 36 J-55 0 3176 3,520 2,020 Casing 7" 26 J-55 0 7281 4,980 4,330 Tubing 3 1/2" 9.3 L-80 0 6925 10,160 10,540 Tubing 5'/:" 14 H-40 6935 7000 3,110 2,620 Well Control: • Two well bore volumes 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 is 3040 psi assuming a gas gradient to surface based on the potential pressure from the C-sand interval that measured 3633 psi at 5933'ND. • The annular preventer will be tested to 250 psi and 2500 psi. Page 3 of 5 11 1/17/2011 r a Permit to Drill Summary of Operations Cont. KRU 3A-07L1,and 3A-07L1-01 Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 3A-07L1 22,350' 3A-07L1-01 22,350' • Distance to Nearest Well within Pool(toe measured to offset well) Lateral Name Distance Offset 3A-07L1 780' 3A-17AL2-01 3A-07L1-01 780' 3A-17AL2-01 Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. , Reservoir Pressure Recent separate zone SBHP's were obtained on this well. The A-Sand SBHP as of 10/12/10 was 3301 psi at a depth of 5933' ND which is equivalent to a 10.7 ppg EMW. The C-Sand SBHP as of 11/22/10 was 3633 psi at a depth of 5933'ND which is equivalent to an 11.7 ppg EMW. The C-sand pelf interval will be behind the 3-1/2"tubing straddle. Hazards • Pressure is expected to increase along wellbore. Maintain sufficient ECD to overbalance. A 9.7 ppg mud system and annular friction will supply enough pressure to overbalance the expected reservoir pressure. Choke pressure can be applied to if higher pressures are encountered as we near the surrounding injectors. • Well 3A-07 has 15 ppm H2S as measured on Dec. '90, 3A-16 had the maximum H2S level at 260 ppm on the 1B pad as measured on Dec. '09. All H2S monitoring equipment will be operational. -- Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by - using 9.70 ppg drilling fluid in combination with annular friction losses and if needed applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the 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 located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 3A-07 will have an SSSV, so the well will not have to be loaded with completion fluid 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 charts show the different pressure parameters in both"pumps on"and"pumps off"conditions. Page 4 of 5 1/13/2011 g, l t / i s 1 L. ............._...._._.____ Permit to Drill Summary of Operations Cont. KRU 3A-07L1,and 3A-07L1-01 Drilling Conditions: Pressure at the Window Using MPD(FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 3301 psi 3301 psi Mud Hydrostatic(9.70 ppg) 3022 psi 3022psi Annular Friction 663 psi 0 psi Mud+Annular Friction 3685 psi 3022 psi (no choke pressure) (overbalanced (underbalanced —384 psi) —279 psi) Target Pressure(11.8 ppg) 3677 psi 3677 psi Choke Pressure Required to Maintain 11.8 ppg 0 psi 650 psi Example: Using the 3A-07 SBHP from Oct. '10 with a reservoir pressure of 3301 psi at 5933 TVDss(10.7 ppg EMW). While drilling and circulating at 1.5 bpm with 2"e-coil, head from the 9.70 mud (3022 psi), plus an estimated 663 psi of annular friction(assuming friction of 95 psi/1000 ft)will provide 3685 psi BHP(11.8 ppg EMW)and overbalance the reservoir by—326 psi. When circulation is shut down,the mud will be underbalanced to the reservoir pressure. However maintaining—650 psi at surface when the pumps are shut down will maintain a constant 11.8 ppg EMW to promote wellbore stability. Quarter-Mile Injection Review The following wells lay within one-quarter mile of the proposed 3A-07 CTD laterals. The distances noted are the closest proximity between these wellbores and any point along the planned CTD laterals. — 3A-04 (active injector) —This wellbore is located —1480' to the southwest of laterals 3A-07L1 and 3A-07 L1-01. This well is a 3-1/2"x 7"completion with perforations in both the A and C sands. The C-sand interval is within a packer/straddle with an AVA BPC sleeve for isolation or access. — 3A-17 (active producer) — This well has recently been sidetracked with CDR2-AC and completed 5 laterals in the A-sand, and is the offset producer for the 3A-07 injection laterals. The original B and C-sand perforations were cement squeezed during the CTD pre-rig work. Lateral Center-Center Distance • 3A-17 1396' • 3A-17A 875' • 3A-17AL1 783' • 3A-17AL1PB1 808' • 3A-17AL2 1396' • 3°-17AL2-01 1396' Page 5 of 5 1/14/2011 5 0 p J; Q Q I ~ 89 ♦ m _ m m 9 co Y �n--- 7 o 7 0 m um IV X m - z. m O m ce W, Vm Y aci) si— E2 N [V o a m2a _w 0 em E 'm J m y m 0 W m 2 a W X , Co O m (0 N•''''.1 I\IJ LL / / a co / / I r a) IuhIiF, oXII: \ 1 O . III 1\ III II I 0 0 I o m N mm N m aft, CO (V a) N O O O V 2 _2 ascki Zi. x ° < f E 0 J N g 1,0 ^ N J d o ^a I I Q M 3A-07 Proposed pre-CTD RWO setup 16"62#H-40 shoe 104'MD ® TRMAXX-CMT-SR-5 SCSSV-1779.5'MD MIN ID=2.813""X"Profile 9-5/8"36#J-55 shoe 3176'MD KBMG-6706'MD 3-112"EUE"PB R" -6791'MD Baker"FHL"Retrievable PackerEWE . C-sand perfs 2.813"X Nipple-6813'MD 6888'-6922'MD KBMG-6866'MD 6922.5'MD Baker"F-1"Packer w/Seal Bore Extension If" 6929'MD /0 0 0 4 Crossover 5"SBE to 5-1/2"liner Vented for installation 6955'MD 4 ♦ 5-1/2"Liner Jt 5-1/2"14#H-40 6974-6'TOWS "6"OD special clearance connections 3-1/2"x 5-1/2"TTWS I -42'of 5-1/2"liner Wearsox 6"OD,every 2.5-3.0'along the (13'Long) pipe Bevel/shoe on bottom A-sand perfs 6997'MD 6990'-7128'MD _ F = Bottom of 5-1/2"liner 7"26#J-55 shoe @ 7281'MD \ 5 I N. F ' . Casing OR Tubing OR Drilling Detail Well: 3A-07 3A-07Ji5~Selective Completion Date: 1/4/2010 ConocoPhillips Rig: Nordic 3 Alaska,Inc, Depth Jt Number Joints Well Equipment Description and Comments Length Tops Pugo1 _. . _ • - .������� Top of String or Top of Flange ORKB Parker 141 28.65 FMC Gen 4 Tubing Hanger .50 28.65 3 1/2", 8.3#, L,80 EUE 8rd Pup Joint 2.58 29.15 Jtx213to213 1 Jts 3 1/2", 9.3#. L-80 EUE 8rd Tubing 31.20 31.73 3 1/2", 9.3#, L'80 EUE 8rd Space Out Pup 4A0.07'.8.06'.O.33'.4.10' 26.02 02.93 Jts 159 to 212 54Jte 3 1/2", 9.3#. L-80 EUE 8rd Tubing 1079.82 89.55 3 1/2", 9.3#. L-80 EUE 8rd Pup Joint 10.11 1768.37 TRMAXX-CMT-SR-5 SCSSV W/2.813" 'X' PROFILE 4.03 1779.48 3 1/2", 9.3#. L-80 EUE 8rd Pup Joint 10.16 1783.51 Jtx2to158 157Jto 3 1/2'', 9.3#. L-80 EUE 8rd Tubing 4902.51 1793.67 3 1/2'', 8.3#, L,80 EUE 8rd Pup Joint 10.22 0690.18 ConnooKBMGProduction Mandrel w/SOV 7.01 6708.40 3 1/2'', 0.3#, L'80 EUE 8rd Pup Joint 10.05 6713.41 Jta1 to 1 1 Jts 3 1/2", 9.3#. L,80 EUE 8rd Tubing 31.30 6723.48 3 1/2'', 0.3#, L-80 EUE 8rd Pup Joint 6.19 6754.76 22.21-ft Baker 80-40 Seal Assembly w/7-ft spaceout 7.33 6760.95 20' "PBR"Polish Bore Receptacle 23.06 676828 FHL Packer 7.32 6791.34 3 1/2" 9.3# L-80 EUE 8rd Pu* Joint 4.08 0788.86 3 1/2", 9.3#, L-80 EUE 8rd Pup Joint 10.18 080275 HES "){" Nipple with RHC Plug in place ' - ', ' ; 1.82. 6812.93 3 1/2", 9.3#. L,8O EUE8nd Pup Joint 10i08 0014.55 3 1/2", 9.3#, L-80 EUE 8rd Tubing '- 31.32 6824.64 3 1/2", 8.3#, L-80 EUE 8rd Pup Joint ' � ��''�^~ 10.16 6855.96 ��`�^~- (�onnoo KBMG Injection Mandrel �4 . 7.02 6866.12 3 1/2", 9.3#. L-80 EUE 8rd Pup Joint 10.21 6873.14 3 1/2", 8.3#, L-80 EUE 8rd Tubing 31.21 6883.35 3 1/2", 9.3#, L-80 EUE8nd Pup Joint 6.20 8914.58 7.124tGBH - 22Bonded Seal assy. 1' Space Out Above String Weight. 1.77 0920.78 Baker"F-1" Production Packer 2.49 6922.53 Baker 80-40 Seal Bore Extension 3.97 0925.02 Ported Cross over Coupling 1.74 6828.99 5 1/2", 15.5#, L-80 Cross over pup (5 1/2 BTC x 8rd ST-C) 24.32 693073 5 1/2", 15.5#, L-80 Mule Shoe j,uintwithVVeoraox 41.95 8955.05 6997.00 Remarks: 59 SS bands Up Wt 87K DnWt 82K Block Wt 35K Supeivisors:Randy Do/cater/Mike Freeborn OR ! GINM ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3A Pad 3A-07 3A-07L1-01 Plan: 3A-07L1-01_wp02 Standard Planning Report 11 January, 2011 Ein BAKER HUGHES ORIGINAL -- ,- ConocoPhillips 14 a ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-07 @ 73.00ft(3A-07) Site: Kuparuk 3A Pad North Reference: True Well: 3A-07 Survey Calculation Method: Minimum Curvature Wellbore: 3A-07L1-01 Design: 3A-07L 1-01_wp02 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3A Pad Site Position: Northing: 5,996,860.05ft Latitude: 70°24'9.520 N From: Map Easting: 507,712.01 ft Longitude: 149°56'14.019 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.06° Well 3A-07 Well Position +N/-S 0.00 ft Northing: 5,997,004.90 ft Latitude: 70°24'10.945 N +E/-W 0.00 ft Easting: 507,673.26 ft Longitude: 149°56'15.150 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 3A-07L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) 11 (nT) BGGM2010 2/14/2011 16.75 79.88 57,353 Design 3A-07L1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,300.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 339.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) 1°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,300.00 92.69 172.51 6,036.14 -2,033.50 2,264.85 0.00 0.00 0.00 0.00 7,340.00 99.60 176.56 6,031.86 -2,073.06 2,268.64 20.00 17.29 10.12 30.00 7,370.00 102.56 181.88 6,026.09 -2,102.48 2,269.05 20.00 9.85 17.74 60.00 7,440.00 102.18 196.21 6,011.02 -2,169.81 2,258.33 20.00 -0.54 20.47 90.00 7,510.00 89.99 203.15 6,003.60 -2,235.17 2,234.90 20.00 -17.41 9.93 150.00 8,210.00 89.81 343.15 6,006.27 -2,205.55 1,697.32 20.00 -0.03 20.00 90.30 8,490.00 88.57 11.13 6,010.31 -1,928.70 1,683.49 10.00 -0.44 9.99 92.70 8,590.00 78.57 11.13 6,021.50 -1,831.33 1,702.65 10.00 -10.00 0.00 180.00 8,870.00 83.20 33.34 6,066.41 -1,577.30 1,806.86 8.00 1.65 7.93 80.00 8,939.00 88.72 33.34 6,071.27 -1,519.82 1,844.67 8.00 8.00 0.00 0.00 9,250.00 88.84 8.45 6,078.00 -1,231.61 1,954.69 8.00 0.04 -8.00 270.00 1/11/2011 2:22:53PM Page 2 COMPASS 2003.16 Build 69 OR ! G ! NAL ' ConocoPhillips t.iTI ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-07 @ 73.00ft(3A-07) Site: Kuparuk 3A Pad North Reference: True Well: 3A-07 Survey Calculation Method: Minimum Curvature Wellbore: 3A-07L1-01 Design: 3A-07L1-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/_W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,300.00 92.69 172.51 6,036.14 -2,033.50 2,264.85 -2,710.09 0.00 0.00 5,994,973.93 509,939.97 TIP/KOP 7,340.00 99.60 176.56 6,031.86 -2,073.06 2,268.64 -2,748.37 20.00 30.00 5,994,934.38 509,943.80 2 7,370.00 102.56 181.88 6,026.09 -2,102.48 2,269.05 -2,775.99 20.00 60.00 5,994,904.96 509,944.24 3 7,400.00 102.49 188.02 6,019.58 -2,131.64 2,266.53 -2,802.31 20.00 90.00 5,994,875.80 509,941.75 7,440.00 102.18 196.21 6,011.02 -2,169.81 2,258.33 -2,835.01 20.00 91.33 5,994,837.62 509,933.59 4 7,500.00 91.74 202.18 6,003.75 -2,225.95 2,238.76 -2,880.40 20.00 150.00 5,994,781.48 509,914.08 7,510.00 89.99 203.15 6,003.60 -2,235.17 2,234.90 -2,887.63 20.00 150.73 5,994,772.25 509,910.23 5 7,600.00 89.90 221.15 6,003.69 -2,311.06 2,187.20 -2,941.38 20.00 90.30 5,994,696.32 509,862.61 7,700.00 89.81 241.15 6,003.94 -2,373.46 2,109.71 -2,971.87 20.00 90.28 5,994,633.84 509,785.20 7,800.00 89.74 261.15 6,004.33 -2,405.60 2,015.56 -2,968.13 20.00 90.23 5,994,601.61 509,691.08 7,900.00 89.71 281.15 6,004.82 -2,403.60 1,916.08 -2,930.61 20.00 90.15 5,994,603.51 509,591.62 8,000.00 89.70 301.15 6,005.34 -2,367.69 1,823.30 -2,863.84 20.00 90.06 5,994,639.32 509,498.80 8,100.00 89.74 321.15 6,005.83 -2,302.22 1,748.38 -2,775.87 20.00 89.95 5,994,704.71 509,423.83 8,200.00 89.80 341.15 6,006.24 -2,215.07 1,700.38 -2,677.31 20.00 89.85 5,994,791.80 509,375.75 8,210.00 89.81 343.15 6,006.27 -2,205.55 1,697.32 -2,667.32 20.00 89.77 5,994,801.31 509,372.67 End of DLS 20 8,300.00 89.39 352.14 6,006.90 -2,117.73 1,678.09 -2,578.44 10.00 92.70 5,994,889.11 509,353.36 8,400.00 88.94 2.14 6,008.35 -2,017.99 1,673.11 -2,483.54 10.00 92.64 5,994,988.83 509,348.27 8,490.00 88.57 11.13 6,010.31 -1,928.70 1,683.49 -2,403.91 10.00 92.49 5,995,078.12 509,358.56 7 8,500.00 87.57 11.13 6,010.65 -1,918.90 1,685.42 -2,395.45 10.00 -180.00 5,995,087.93 509,360.48 8,590.00 78.57 11.13 6,021.50 -1,831.33 1,702.65 -2,319.86 10.00 -180.00 5,995,175.51 509,377.62 End of DLS 10 8,600.00 78.71 11.93 6,023.48 -1,821.72 1,704.61 -2,311.60 8.00 80.00 5,995,185.11 509,379.57 8,700.00 80.22 19.92 6,041.79 -1,727.27 1,731.58 -2,233.09 8.00 79.84 5,995,279.58 509,406.44 8,800.00 81.92 27.84 6,057.34 -1,637.03 1,771.56 -2,163.16 8.00 78.38 5,995,369.86 509,446.32 8,870.00 83.20 33.34 6,066.41 -1,577.30 1,806.86 -2,120.06 8.00 77.15 5,995,429.61 509,481.56 9 8,900.00 85.60 33.34 6,069.34 -1,552.36 1,823.27 -2,102.65 8.00 0.00 5,995,454.57 509,497.94 8,939.00 88.72 33.34 6,071.27 -1,519.82 1,844.67 -2,079.95 8.00 0.00 5,995,487.13 509,519.31 10 9,000.00 88.72 28.46 6,072.63 -1,467.50 1,875.98 -2,042.32 8.00 -90.00 5,995,539.47 509,550.56 9,100.00 88.75 20.45 6,074.84 -1,376.57 1,917.33 -1,972.25 8.00 -89.89 5,995,630.44 509,591.81 9,200.00 88.80 12.45 6,076.97 -1,280.76 1,945.62 -1,892.95 8.00 -89.71 5,995,726.26 509,620.00 9,250.00 88.84 8.45 6,078.00 -1,231.61 1,954.69 -1,850.31 8.00 -89.54 5,995,775.42 509,629.02 TD 1/11/2011 2:22:53PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Fel al ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-07 @ 73.00ft(3A-07) Site: Kuparuk 3A Pad North Reference: True Well: 3A-07 Survey Calculation Method: Minimum Curvature Wellbore: 3A-07L1-01 Design: 3A-07L1-01_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3A-07L1-01 t2 0.00 0.00 6,067.00 -1,569.29 1,832.32 5,995,437.65 509,507.00 70°23'55.510 N 149°55'21.475 W -plan misses target center by 16.93ft at 8890.64ft MD(6068.56 TVD,-1560.15 N,1818.15 E) -Point 3A-07L1,L1-01 Fault 0.00 0.00 0.00 -1,346.90 1,477.52 5,995,659.66 509,152.01 70°23'57.697 N 149°55'31.867 W -plan misses target center by 6041.39ft at 8500.00ft MD(6010.65 TVD,-1918.90 N,1685.42 E) -Polygon Point 1 0.00 -1,346.90 1,477.52 5,995,659.66 509,152.01 Point 2 0.00 -2,409.56 3,065.64 5,994,598.73 510,741.06 3A-07L1-01 t3 0.00 0.00 6,078.00 -1,231.38 1,954.68 5,995,775.65 509,629.01 70°23'58.832 N 149°55'17.887 W -plan hits target center -Point 3A-07L1-01 KOP 0.00 0.00 6,036.00 -2,033.78 2,264.88 5,994,973.65 509,940.00 70°23'50.940 N 149°55'8.807 W -plan hits target center -Point 3A-07L1,L1-01 Polyg 0.00 0.00 0.00 -1,900.63 2,140.00 5,995,106.65 509,815.00 70°23'52.250 N 149°55'12.464 W -plan misses target center by 6013.37ft at 7500.00ft MD(6003.75 TVD,-2225.95 N,2238.76 E) -Polygon Point 1 0.00 -1,900.63 2,140.00 5,995,106.65 509,815.00 Point 2 0.00 -1,958.88 2,390.97 5,995,048.67 510,066.00 Point 3 0.00 -2,698.60 2,023.21 5,994,308.64 509,699.04 Point4 0.00 -2,266.98 1,431.57 5,994,739.61 509,107.02 Point 5 0.00 -832.24 1,851.01 5,996,174.64 509,524.94 Point 6 0.00 -1,347.46 2,024.53 5,995,659.65 509,698.97 Point 7 0.00 -2,125.33 1,811.75 5,994,881.64 509,487.01 Point 8 0.00 -2,305.50 1,965.59 5,994,701.65 509,641.02 Point 9 0.00 -2,151.68 2,165.76 5,994,855.66 509,841.01 3A-07L1-01 t1 0.00 0.00 6,004.00 -2,225.76 2,238.67 5,994,781.66 509,913.99 70°23'49.052 N 149°55'9.577 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 9,250.00 6,078.00 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,300.00 6,036.14 -2,033.50 2,264.85 TIP/KOP 7,340.00 6,031.86 -2,073.06 2,268.64 2 7,370.00 6,026.09 -2,102.48 2,269.05 3 7,440.00 6,011.02 -2,169.81 2,258.33 4 7,510.00 6,003.60 -2,235.17 2,234.90 5 8,210.00 6,006.27 -2,205.55 1,697.32 End of DLS 20 8,490.00 6,010.31 -1,928.70 1,683.49 7 8,590.00 6,021.50 -1,831.33 1,702.65 End of DLS 10 8,870.00 6,066.41 -1,577.30 1,806.86 9 8,939.00 6,071.27 -1,519.82 1,844.67 10 9,250.00 6,078.00 -1,231.61 1,954.69 TD 1/11/2011 2.22:53PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL 0 Wss t oml m M law* 7. _$ t si rgo N Q 4 / 8 N X N O ,N p Q i O O r DD - / 4N "w Q \ / N h N tel wg W e 4 • 8 0 R .' s 8.6 E ti.ittivio. .011111111114r1/0 .,9 2 limy 3 =s : 5 IN M o 8 M -8 s Hy 4 4 [h Q Q T O O C- p 9 9 `. g .W 4. 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Q. > CO • I- 0 M N rV +� N S O ( Vi ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3A Pad 3A-07 3A-07L1-01 3A-07L1-01_wp02 Travelling Cylinder Report 11 January, 2011 kfiq H BAKER HUGHES OiflGINAL 0 ,v,. ConocoPhillips rifil ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Reference 3A-07L1-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,300.00 to 9,250.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,117.70ft Error Surface: Elliptical Conic Survey Tool Program Date 1/10/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 6,900.00 3A-07(3A-07) GCT-MS Schlumberger GCT multishot 6,900.00 7,300.00 3A-07L1wp06(3A-07L1) MWD MWD-Standard 7,300.00 9,250.00 3A-07L1-_01_wp02(3A-07L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (1 (") 9,250.00 6,151.00 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3A Pad 3A-01 -3A-01 -3A-01 Out of range 3A-02-3A-02-3A-02 Out of range 3A-03-3A-03-3A-03 Out of range 3A-03-3A-03A-3A-03A Out of range 3A-03-3A-03B-3A-03B Out of range 3A-03-3A-03B-3A-03B wp04 Out of range 3A-04-3A-04-3A-04 Out of range 3A-05-3A-05-3A-05 Out of range 3A-06-3A-06-3A-06 Out of range 3A-07-3A-07-3A-07 8,833.51 6,825.00 330.80 5.91 330.58 Pass-No Errors 3A-07-3A-07L1 -3A-07L1_wp06 7,324.95 7,325.00 1.13 0.29 0.85 Pass-No Errors 3A-08-3A-08-3A-08 Out of range 3A-11 -3A-11 -3A-11 Out of range 3A-17-3A-17-3A-17 Out of range 3A-17-3A-17A-3A-17A 7,550.00 8,875.00 874.69 174.93 710.08 Pass-Major Risk 3A-17-3A-17AL1 -3A-17AL1 7,550.00 8,900.00 783.12 174.74 617.67 Pass-Major Risk 3A-17-3A-17AL1 P61 -3A-17AL1PB1 7,540.62 8,853.00 808.00 173.90 643.27 Pass-Major Risk 3A-17-3A-17AL2-3A-17AL2 Out of range 3A-17-3A-17AL2-01 -3A-17AL2-01 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 2 of 10 COMPASS 2003.16 Build 69 J a- ConocoPhillips pi,;fi ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3A Pad- 3A-07-3A-07-3A-07 Offset Site Error: 0.00 ft Survey Program: 100-OCT-MS Rule Assigned:No Errors Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +W-S +E1-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 8,821.52 6,133.29 6,325.00 5,547.87 35.39 0.00 26.28 -1,532.98 1,791.60 0.22 591.69 5.88 591.47 Pass-No Errors 8,821.52 6,133.29 6,350.00 5,567.36 35.39 0.00 27.72 -1,542.88 1,803.73 0.22 571.36 5.88 571.13 Pass-No Errors 8,821.57 6,133.30 6,300.00 5,528.40 35.39 0.00 24.95 -1,523.03 1,779.46 0.22 612.35 5.88 612.13 Pass-No Errors 8,821.57 6,133.30 6,375.00 5,586.88 35.39 0.00 29.26 -1,552.72 1,815.85 0.22 551.39 5.88 551.16 Pass-No Errors 8,821.66 6,133.31 6,275.00 5,508.96 35.39 0.00 23.70 -1,513.04 1,767.34 0.22 633.31 5.88 633.09 Pass-No Errors 8,821.68 6,133.31 6,400.00 5,606.43 35.39 0.00 30.91 -1,562.52 1,827.97 0.22 531.82 5.88 531.60 Pass-No Errors 8,821.80 6,133.33 6,250.00 5,489.52 35.39 0.00 22.53 -1,503.02 1,755.22 0.22 654.55 5.88 654.33 Pass-No Errors 8,821.86 6,133.34 6,425.00 5,626.00 35.39 0.00 32.69 -1,572.26 1,840.09 0.22 512.70 5.88 512.48 Pass-No Errors 8,821.97 6,133.35 6,225.00 5,470.10 35.39 0.00 21.45 -1,492.95 1,743.12 0.22 676.04 5.88 675.82 Pass-No Errors 8,822.15 6,133.37 6,450.00 5,645.61 35.39 0.00 34.61 -1,581.93 1,852.23 0.22 494.09 5.88 493.86 Pass-No Errors 8,822,18 6,133.38 6,200.00 5,450.68 35.39 0.00 20.43 -1,482.86 1,731.03 0.22 697.77 5.88 697.54 Pass-No Errors 8,822.42 6,133.41 6,175.00 5,431.28 35.39 0.00 19.47 -1,472.73 1,718.95 0.22 719.69 5.88 719.47 Pass-No Errors 8,822.54 6,133.43 6,475.00 5,665.24 35.39 0.00 36.68 -1,591.52 1,864.37 0.22 476.03 5.88 475.81 Pass-No Errors 8,822.68 6,133.45 6,150.00 5,411.90 35.39 0.00 18.58 -1,462.56 1,706.87 0.22 741.81 5.88 741.58 Pass-No Errors 8,822.96 6,133.48 6,125.00 5,392.54 35.39 0.00 17.73 -1,452.37 1,694.78 0.22 764.08 5.89 763.86 Pass-No Errors 8,823.04 6,133.49 6,500.00 5,684.91 35.39 0.00 38.91 -1,601.03 1,876.52 0.22 458.60 5.89 458.38 Pass-No Errors 8,823.26 6,133.52 6,100.00 5,373.19 35.39 0.00 16.94 -1,442.15 1,682.69 0.22 786.52 5.89 786.29 Pass-No Errors 8,823.57 6,133.56 6,075.00 5,353.86 35.39 0.00 16.19 -1,431.89 1,670.59 0.22 809.09 5.89 808.86 Pass-No Errors 8,823.63 6,133.57 6,525.00 5,704.61 35.39 0.00 41.31 -1,610.49 1,888.66 0.22 441.87 5.89 441.64 Pass-No Errors 8,823.89 6,133.61 6,050.00 5,334.56 35.39 0.00 15.48 -1,421.62 1,658.48 0.22 831.78 5.89 831.56 Pass-No Errors 8,824.22 6,133.65 6,025.00 5,315.28 35.39 0.00 14,81 -1,411.32 1,646.35 0.22 854.60 5.89 854.37 Pass-No Errors 8,824.29 6,133.66 6,550.00 5,724.36 35.39 0.00 43.90 -1,619.89 1,900.77 0.22 425.89 5.89 425.66 Pass-No Errors 8,824.55 6,133.70 6,000.00 5,296.02 35.39 0.00 14.17 -1,400.99 1,634.20 0.22 877.51 5.89 877.29 Pass-No Errors 8,824.92 6,133.74 5,975.00 5,276.78 35.39 0.00 13.56 -1,390.63 1,622.06 0.22 900.53 5.89 900.31 Pass-No Errors 8,825.03 6,133.76 6,575.00 5,744.15 35.39 0.00 46.67 -1,629.24 1,912.85 0.22 410.75 5.89 410.53 Pass-No Errors 8,825.32 6,133.80 5,950.00 5,257.57 35.39 0.00 12.99 -1,380.20 1,609.92 0.22 923.64 5.89 923.41 Pass-No Errors 8,825.77 6,133.86 5,925.00 5,238.39 35.39 0.00 12.45 -1,369.71 1,597.80 0.22 946.83 5.89 946.61 Pass-No Errors 8,825.86 6,133.87 6,600.00 5,763.98 35.39 0.00 49.65 -1,638.54 1,924.90 0.22 396.57 5.89 396.34 Pass-No Errors 8,826.26 6,133.92 5,900.00 5,219.23 35.39 0.00 11.94 -1,359.16 1,585.68 0.22 970.10 5.89 969.88 Pass-No Errors 8,826.73 6,133.98 6,625.00 5,783.85 35.39 0.00 52.83 -1,647.81 1,936.92 0.22 383.45 5.89 383.22 Pass-No Errors 8,826.78 6,133.99 5,875.00 5,200.09 35.39 0.00 11.46 -1,348.58 1,573.59 0.22 993.45 5.89 993.23 Pass-No Errors 8,827.30 6,134.06 5,850.00 5,180.93 35.39 0.00 11.00 -1,337.98 1,561.51 0.22 1,016.89 5.89 1,016,66 Pass-No Errors 8,827.62 6,134.10 6,650.00 5,803.72 35.39 0.00 56.23 -1,657.08 1,948.92 0.22 371.52 5.90 371.30 Pass-No Errors 8,827.83 6,134.13 5,825.00 5,161.77 35.39 0.00 10,56 -1,327.36 1,549.46 0.22 1,040.40 5.90 1,040.18 Pass-No Errors 8,828.36 6,134.20 5,800.00 5,142.61 35.39 0.00 10.15 -1,316.73 1,537.43 0.22 1,063.99 5.90 1,063.76 Pass-No Errors 8,828.54 6,134.22 6,675.00 5,823.61 35.39 0.00 59.83 -1,666.36 1,960.90 0.22 360.91 5.90 360.69 Pass-No Errors 8,828.89 6,134.27 5,775.00 5,123.43 35.39 0.00 9.75 -1,306.10 1,525.43 0.22 1,087.64 5.90 1,087.42 Pass-No Errors 8,829.41 6,134.34 5,750.00 5,104.24 35.39 0.00 9.38 -1,295.47 1,513.44 0.22 1,111.36 5.90 1,111.13 Pass-No Errors 8,829.47 6,134.35 6,700.00 5,843.51 35.39 0.00 63.64 -1,675.64 1,972.85 0.22 351.74 5.90 351.52 Pass-No Errors 8,830.41 6,134.47 6,725.00 5,863.43 35.39 0.00 67.62 -1,684.93 1,984.77 0.22 344.11 5.90 343.89 Pass-No Errors 8,831.13 6,134.56 6,900.00 6,002.51 35.39 0.00 97.27 -1,753.16 2,066.09 0.22 340.68 5.90 340.19 Pass-No Errors 8,831.31 6,134.59 6,750.00 5,883.36 35.39 0.00 71.76 -1,694.25 1,996.63 0.22 338.12 5.90 337.89 Pass-No Errors 8,832.17 6,134.70 6,775.00 5,903.32 35.39 0.00 76.02 -1,703.59 2,008.44 0.22 333.85 5.91 333.63 Pass-No Errors 8,832.63 6,134.76 6,875.00 5,982.85 35.39 0.00 93.23 -1,742.61 2,054.81 0.22 335.49 5.91 335.27 Pass-No Errors 8,833.00 6,134.81 6,800.00 5,923.29 35.39 0.00 80.36 -1,712.96 2,020.20 0.22 331.38 5.91 331.16 Pass-No Errors 8,833.41 6,134.86 6,850.00 5,963.09 35.39 0.00 89.03 -1,732.39 2,043.40 0.22 332.18 5.91 331.96 Pass-No Errors 8,833.51 6,134.87 6,825.00 5,943.24 35.39 0.00 84.72 -1,722.51 2,031.86 0.22 330.80 5.91 330.58 Pass-No Errors,CC,ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 3 of 10 COMPASS 2003.16 Build 69 ORG1NAL ConocoPhillips ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3A Pad- 3A-07-3A-07L1 -3A-07L1_wp06 Offset Site Error: 0.00 ft Survey Program: 100-GCT-MS,6900-MWD Rule Assigned:No Errors Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Welibore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-Vy Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 7,324.95 6,107.03 7,325.00 6,108.02 0.08 0.05 -33.45 -2,058.37 2,267.02 0.22 1.13 0.29 0.85 Pass-No Errors,CC,ES,Sf 7,349.66 6,103.17 7,350.00 6,107.07 0.10 0.11 -29.33 -2,083.35 2,267.02 0.22 4.48 0.29 4.20 Pass-No Errors 7,374.24 6,098.17 7,375.00 6,106.30 0.14 0.16 -22.62 -2,108.23 2,264.85 0.22 9.23 0.28 8.96 Pass-No Errors 7,399.12 6,092.77 7,400.00 6,105.73 0.17 0.22 -15.69 -2,132.84 2,260.53 0.22 14.47 0.28 14.21 Pass-No Errors 7,424.16 6,087.38 7,425.00 6,105.34 0.21 0.27 -9.11 -2,156.99 2,254.08 0.22 19.84 0.27 19.57 Pass-No Errors 7,449.90 6,082.08 7,450.00 6,105.15 0.26 0.33 -4.03 -2,180.48 2,245.56 0.22 25.18 0.27 24.91 Pass-No Errors 7,477.07 6,078.25 7,475.00 6,105.16 0.30 0.39 -3.49 -2,203.15 2,235.04 0.22 29.48 0.26 29.21 Pass-No Errors 7,504.72 6,076.64 7,500.00 6,105.39 0.35 0.44 -5.50 -2,224.82 2,222.59 0.22 32.60 0.27 32.34 Pass-No Errors 7,531.29 6,076.61 7,525.00 6,105.84 0.41 0.50 -6.60 -2,245.32 2,208.31 0.22 35.26 0.28 34.99 Pass-No Errors 7,557.97 6,076.63 7,550.00 6,106.50 0.47 0.55 -5.99 -2,264.51 2,192.30 0.22 38.30 0.29 38.01 Pass-No Errors 7,585.10 6,076.66 7,575.00 6,107.37 0.53 0.60 -4.21 -2,282.23 2,174.70 0.22 41.58 0.30 41.29 Pass-No Errors 7,612.68 6,076.71 7,600.00 6,108.45 0.59 0.64 -1.44 -2,298.34 2,155.63 0.22 44.99 0.31 44.69 Pass-No Errors 7,640.70 6,076.77 7,625.00 6,109.72 0.65 0.68 2.17 -2,312.74 2,135.24 0.22 48.43 0.32 48.12 Pass-No Errors 7,669.16 6,076.84 7,650.00 6,111.06 0.71 0.72 6.38 -2,325.31 2,113.68 0.22 51.75 0.32 51.44 Pass-No Errors 7,698.04 6,076.93 7,675.00 6,112.17 0.76 0.75 10.88 -2,335.96 2,091.10 0.22 54.69 0.31 54.38 Pass-No Errors 7,727.32 6,077.03 7,700.00 6,113.04 0.81 0.79 15.62 -2,344.62 2,067.67 0.22 57.21 0.31 56.91 Pass-No Errors 7,756.94 6,077.15 7,725.00 6,113.66 0.85 0.82 20.56 -2,351.22 2,043.57 0.22 59.28 0.29 58.99 Pass-No Errors 7,786.86 6,077.27 7,750.00 6,114.03 0.90 0.85 25.68 -2,355.71 2,018.99 0.22 60.87 0.27 60.59 Pass-No Errors 7,817.02 6,077.41 7,775.00 6,114.14 0.96 0.89 30.93 -2,358.05 1,994.11 0.22 61.94 0.26 61.68 Pass-No Errors 7,847.34 6,077.55 7,800.00 6,114.01 1.02 0.92 36.30 -2,358.23 1,969.12 0.22 62.50 0.26 62.26 Pass-No Errors 7,877.76 6,077.71 7,825.00 6,113.68 1.08 0.96 41.81 -2,356.24 1,944.21 0.22 62.56 0.27 62.33 Pass-No Errors 7,908.19 6,077.86 7,850.00 6,113.17 1.14 0.99 47.43 -2,352.10 1,919.57 0.22 62.12 0.30 61.90 Pass-No Errors 7,938.57 6,078.02 7,875.00 6,112.48 1.20 1.01 53.15 -2,345.83 1,895.38 0.22 61.19 0.33 60.97 Pass-No Errors 7,968.81 6,078.18 7,900.00 6,111.61 1.24 1.03 58.93 -2,337.48 1,871.84 0.22 59.77 0.36 59.55 Pass-No Errors 7,998.86 6,078.33 7,925.00 6,110.57 1.27 1.05 64.77 -2,327.12 1,849.12 0.22 57.88 0.38 57.66 Pass-No Errors 8,028.65 6,078.49 7,950.00 6,109.37 1.28 1.05 70.66 -2,314.83 1,827.39 0.22 55.55 0.41 55.32 Pass-No Errors 8,058.14 6,078.63 7,975.00 6,108.17 1.28 1.04 76.75 -2,300.70 1,806.82 0.22 52.88 0.43 52.65 Pass-No Errors 8,087.29 6,078.77 8,000.00 6,107.18 1.26 1.03 83.23 -2,284.82 1,787.54 0.22 50.01 0.44 49.79 Pass-No Errors 8,116.06 6,078.90 8,025.00 6,106.41 1.24 1.01 90.19 -2,267.33 1,769.71 0.22 47.00 0.45 46.77 Pass-No Errors 8,144.42 6,079.03 8,050.00 6,105.85 1.20 0.99 97.72 -2,248.35 1,753.46 0.22 43.89 0.45 43.66 Pass-No Errors 8,172.35 6,079.14 8,075.00 6,105.52 1.15 0.97 105.96 -2,228.03 1,738.91 0.22 40.76 0.45 40.54 Pass-No Errors 8,199.83 6,079.24 8,100.00 6,105.41 1.10 0.95 115.05 -2,206.53 1,726.18 0.22 37.73 0.44 37.50 Pass-No Errors 8,226.18 6,079.33 8,125.00 6,105.60 1.06 0.94 123.22 -2,184.00 1,715.35 0.22 35.10 0.42 34.88 Pass-No Errors 8,252.03 6,079.48 8,150.00 6,106.17 1.02 0.94 130.06 -2,160.64 1,706.50 0.22 33.55 0.41 33.32 Pass-No Errors 8,277.87 6,079.68 8,175.00 6,107.11 0.98 0.95 136.09 -2,136.61 1,699.69 0.22 33.02 0.40 32.80 Pass-No Errors 8,303.69 6,079.94 8,200.00 6,108.42 0.95 0.96 140.97 -2,112.10 1,69497 0.22 33.42 0.40 33.19 Pass-No Errors 8,329.49 6,080.25 8,225.00 6,109.87 0.92 0.96 145.22 -2,087.35 1,691.80 0.22 34.17 0.40 33.94 Pass-No Errors 8,355.27 6,080.61 8,250.00 6,111.24 0.91 0.97 149.66 -2,062.49 1,689.49 0.22 34.70 0.39 34.48 Pass-No Errors 8,381.01 6,081.02 8,275.00 6,112.51 0.89 0.97 154.29 -2,037.57 1,688.04 0.22 35.03 0.39 34.80 Pass-No Errors 8,406.69 6,081.48 8,300.00 6,113.68 0.88 0.97 159.15 -2,012.60 1,687.46 0.22 35.17 0.38 34.94 Pass-No Errors 8,432.30 6,081.99 8,325.00 6,114.76 0.87 0.97 164.27 -1,987.63 1,687.75 0.22 35.13 0.37 34.91 Pass-No Errors 8,457.82 6,082.55 8,350.00 6,115.74 0.87 0.97 169.68 -1,962.68 1,688.90 0.22 34.96 0.36 34.73 Pass-No Errors 8,483.25 6,083.15 8,375.00 6,116.62 0.86 0.97 175.42 -1,937.78 1,690.92 0.22 34.67 0.34 34.44 Pass-No Errors 8,509.42 6,084.13 8,400.00 6,117.40 0.85 0.97 179.14 -1,912.96 1,693.80 0.22 34.07 0.33 33.83 Pass-No Errors 8,535.87 6,086.29 8,425.00 8,118.07 0.83 0.97 -179.47 -1,888.25 1,697.54 0.22 32.51 0.33 32.27 Pass-No Errors 8,562.13 6,089.65 8,450.00 6,118.64 0.82 0.97 -179.96 -1,863.68 1,702.14 0.22 29.89 0.33 29.64 Pass-No Errors 8,588.07 6,094.13 8,475.00 6,119.11 0.81 0.98 177.07 -1,839.29 1,707.58 0.22 26.26 0.33 26.02 Pass-No Errors 8,612.81 6,098.96 8,500.00 6,119.48 0.80 0.99 172.85 -1,815.10 1,713.87 0.22 22.27 0.34 22.03 Pass-No Errors CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 4 of 10 COMPASS 2003.16 Build 69 • ,:,,,; , ., ,,, 1 ConocoPhillips . ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3A Pad- 3A-07-3A-07L1 -3A-07L1_wp06 Offset Site Error: 0.00ft Survey Program: 100-GOT-MS,6900-MWD Rule Assigned:No Errors Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +W-S +EI-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 8,637.54 6,103.65 8,525.00 6,119.74 0.79 1.01 166.38 -1,791.14 1,720.99 0.22 18.64 0.34 18.42 Pass-No Errors 8,662.35 6,108.20 8,550,00 6,119.90 0.79 1.03 156.47 -1,767.43 1,728.94 0.22 15.63 0.35 15.40 Pass-No Errors 8,687.22 6,112.60 8,575.00 6,119.81 0.78 1.06 141.87 -1,744.01 1,737.67 0.22 13.46 0.36 13.23 Pass-No Errors 8,712.11 6,116.83 8,600.00 6,119.31 0.78 1.09 122.44 -1,720.87 1,747.11 0.22 12.58 0.36 12.35 Pass-No Errors 8,737.03 6,120.89 8,625.00 6,118.40 0.79 1.11 102.09 -1,698.04 1,757.25 0.22 13.47 0.37 13.24 Pass-No Errors 8,761.98 6,124.77 8,650.00 6,117.09 0.81 1.14 85.83 -1,675.55 1,768.09 0.22 16.03 0.37 15.81 Pass-No Errors 8,786.97 6,128.48 8,675.00 6,115.49 0.84 1.18 75.04 -1,653.42 1,779.61 0.22 19.71 0.38 19.48 Pass-No Errors 8,812.13 6,132.02 8,700.00 6,114.18 0.89 1.21 69.12 -1,631.65 1,791.83 0.22 23.62 0.38 23.39 Pass-No Errors 8,821.52 6,133.29 6,325.00 5,547.87 0.90 0.00 26.28 -1,532.98 1,791.60 0.22 591.69 5.88 591.47 Pass-No Errors 8,821.52 6,133.29 6,350.00 5,567.36 0.90 0.00 27.72 -1,542.88 1,803.73 0.22 571.36 5.88 571.13 Pass-No Errors 8,821.57 6,133.30 6,300.00 5,528.40 0.90 0.00 24.95 -1,523.03 1,779.46 0.22 612.35 5.88 612.13 Pass-No Errors 8,821.57 6,133.30 6,375.00 5,586.88 0.90 0.00 29.26 -1,552.72 1,815.85 0.22 551.39 5.88 551.16 Pass-No Errors 8,821.66 6,133.31 6,275.00 5,508.96 0.90 0.00 23.70 -1,513.04 1,767.34 0.22 633.31 5.88 633.09 Pass-No Errors 8,821.68 6,133.31 6,400.00 5,606.43 0.90 0.00 30.91 -1,562.52 1,827.97 0.22 531.82 5.88 531.60 Pass-No Errors 8,821.80 6,133.33 6,250.00 5,489.52 0.90 0.00 22.53 -1,503.02 1,755.22 0.22 654.55 5.88 654.33 Pass-No Errors 8,821.86 6,133.34 6,425.00 5,626.00 0.90 0.00 32.69 -1,572.26 1,840.09 0.22 512.70 5.88 512.48 Pass-No Errors 8,821.97 6,133.35 6,225.00 5,470.10 0.90 0.00 21.45 -1,492.95 1,743.12 0.22 676.04 5.88 675.82 Pass-No Errors 8,822.15 6,133.37 6,450.00 5,645.61 0.90 0.00 34.61 -1,581.93 1,852.23 0.22 494.09 5.88 493.86 Pass-No Errors 8,822.18 6,133.38 6,200.00 5,450.68 0.90 0.00 20.43 -1,482.86 1,731.03 0.22 697.77 5.88 697.54 Pass-No Errors 8,822.42 6,133.41 6,175.00 5,431.28 0.90 0.00 19.47 -1,472.73 1,718.95 0.22 719.69 5.88 719.47 Pass-No Errors 8,822.54 6,133.43 6,475.00 5,665.24 0.90 0.00 36.68 -1,591.52 1,864.37 0.22 476.03 5.88 475.81 Pass-No Errors 8,822.68 6,133.45 6,150.00 5,411.90 0.91 0.00 18.58 -1,462.56 1,706.87 0.22 741.81 5.88 741.58 Pass-No Errors 8,822.96 6,133.48 6,125.00 5,392.54 0.91 0.00 17.73 -1,452.37 1,694.78 0.22 764.08 5.89 763.86 Pass-No Errors 8,823.04 6,133.49 6,500.00 5,684.91 0.91 0.00 38.91 -1,601.03 1,876.52 0.22 458.60 5.89 458.38 Pass-No Errors 8,823.26 6,133.52 6,100.00 5,373.19 0.91 0.00 16.94 -1,442.15 1,682.69 0.22 786.52 5.89 786.29 Pass-No Errors 8,823.57 6,133.56 6,075.00 5,353.86 0.91 0.00 16.19 -1,431.89 1,670.59 0.22 809.09 5.89 808.86 Pass-No Errors 8,823.63 6,133.57 6,525.00 5,704.61 0.91 0.00 41.31 -1,610.49 1,888.66 0.22 441.87 5.89 441.64 Pass-No Errors 8,823.89 6,133.61 6,050.00 5,334.56 0.91 0.00 15.48 -1,421.62 1,658.48 0.22 831.78 5.89 831.56 Pass-No Errors 8,824.22 6,133.65 6,025.00 5,315.28 0.91 0.00 14.81 -1,411.32 1,646.35 0.22 854.60 5.89 854.37 Pass-No Errors 8,824.29 6,133.66 6,550.00 5,724.36 0.91 0.00 43.90 -1,619.89 1,900.77 0.22 425.89 5.89 42566 Pass-No Errors 8,824.55 6,133.70 6,000.00 5,296.02 0.91 0.00 14.17 -1,400.99 1,634.20 0.22 877.51 5.89 877.29 Pass-No Errors 8,824.92 6,133.74 5,975.00 5,276.78 0.91 0.00 13.56 -1,390.63 1,622.06 0.22 900.53 5.89 900.31 Pass-No Errors 8,825.03 6,133.76 6,575.00 5,744.15 0.91 0.00 46.67 -1,629.24 1,912.85 0.22 410.75 5.89 410.53 Pass-No Errors 8,825.32 6,133.80 5,950.00 5,257.57 0.91 0.00 12.99 -1,380.20 1,609.92 0.22 923.64 5.89 923.41 Pass-No Errors 8,825.77 6,133.86 5,925.00 5,238.39 0.91 0.00 12.45 -1,369.71 1,597.80 0.22 946.83 5.89 946.61 Pass-No Errors 8,825.86 6,133.87 6,600.00 5,763.98 0.91 0.00 49.65 -1,638.54 1,924.90 0.22 396.57 5.89 396.34 Pass-No Errors 8,826.26 6,133.92 5,900.00 5,219.23 0.91 0.00 11.94 -1,359.16 1,585.68 0.22 970.10 5.89 969.88 Pass-No Errors 8,826.73 6,133.98 6,625.00 5,783.85 0.91 0.00 52.83 -1,647.81 1,936.92 0.22 383.45 5.89 383.22 Pass-No Errors 8,826.78 6,133.99 5,875.00 5,200.09 0.91 0.00 11.46 -1,348.58 1,573.59 0.22 993.45 5.89 993.23 Pass-No Errors 8,827.30 6,134.06 5,850.00 5,180.93 0.91 0.00 11.00 -1,337.98 1,561.51 0.22 1,016.89 5.89 1,016.66 Pass-No Errors 8,827.62 6,134.10 6,650.00 5,803.72 0.91 0.00 56.23 -1,657.08 1,948.92 0.22 371.52 5.90 371.30 Pass-No Errors 8,827.83 6,134.13 5,825.00 5,161.77 0.91 0.00 10.56 -1,327.36 1,549.46 0.22 1,040.40 5.90 1,040.18 Pass-No Errors 8,828.36 6,134.20 5,800.00 5,142.61 0.92 0.00 10.15 -1,316.73 1,537.43 0.22 1,063.99 5.90 1,063.76 Pass-No Errors 8,828.54 6,134.22 6,675.00 5,823.61 0.92 0.00 59.83 -1,666.36 1,960.90 0.22 360.91 5.90 360.69 Pass-No Errors 8,828.89 6,134.27 5,775.00 5,123.43 0.92 0.00 9.75 -1,306.10 1,525.43 0.22 1,087.64 5.90 1,087.42 Pass-No Errors 8,829.41 6,134.34 5,750.00 5,104.24 0.92 0.00 9.38 -1,295.47 1,513.44 0.22 1,111.36 5.90 1,111.13 Pass-No Errors 8,829.47 6,134.35 6,700.00 5,843.51 0.92 0.00 63.64 -1,675.64 1,972.85 0.22 351.74 5.90 351.52 Pass-No Errors 8,830.41 6,134.47 6,725.00 5,863.43 0.92 0.00 67.62 -1,684.93 1,984.77 0.22 344.11 5.90 343.89 Pass-No Errors CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 5 of 10 COMPASS 2003.16 Build 69 I C i N A ConocoPhillips ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3A Pad- 3A-07-3A-07L1 -3A-07L1_wp06 Offset Site Error: 0.00 ft Survey Program: 100-GCT-MS,6900-MWD Rule Assigned:No Errors Offset Well Error 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Tooiface+ Offset Welibore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +py.S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (n) (ft) C) (ft) (ft) (ft) (ft) (ft) (ft) 8,831.13 6,134.56 6,900.00 6,002.51 0.92 0.00 97.27 -1,753.16 2,066.09 0.22 340.68 5.90 340.19 Pass-No Errors 8,831.31 6,134.59 6,750.00 5,883.36 0.92 0.00 71.76 -1,694.25 1,996.63 0.22 338.12 5.90 337.89 Pass-No Errors 8,832.17 6,134.70 6,775.00 5,903.32 0.92 0.00 76.02 -1,703.59 2,008.44 0.22 333.85 5.91 333.63 Pass-No Errors 8,832.63 6,134.76 6,875.00 5,982.85 0.92 0.00 93.23 -1,742.61 2,054.81 0.22 335.49 5.91 33527 Pass-No Errors 8,833.00 6,134.81 6,800.00 5,92329 0.92 0.00 80.36 -1,712.96 2,020.20 0.22 331.38 591 331.16 Pass-No Errors 8,833.41 6,134.86 6,850.00 5,96309 0.93 0.00 89.03 -1,732.39 2,043.40 0.22 332.18 5.91 331.96 Pass-No Errors 8,833.51 6,134.87 6,825.00 5,943.24 0.93 0.00 84.72 -1,722.51 2,031.86 0.22 330.80 591 330.58 Pass-No Errors 8,837.46 6,135.38 8,725.00 6,113.25 0.93 1.25 66.03 -1,610.27 1,804.75 0.22 27.34 0.39 27.11 Pass-No Errors 8,862.93 6,138.56 8,750.00 6,112.68 0.98 1.28 64.60 -1,589.29 1,818.34 0.22 30.68 0.39 30.46 Pass-No Errors 8,888.70 6,141,38 8,775.00 6,112.49 1.02 1.32 63.40 -1,568.75 1,832.59 0.22 33.53 0.40 33.30 Pass-No Errors 8,914.67 6,143.31 8,800.00 6,112.47 1.05 1.37 63.92 -1,548.70 1,847.52 0.22 35.88 0.40 35.65 Pass-No Errors 8,940.63 6,144.31 8,825.00 6,112.53 1.07 1.38 65.10 -1,528.70 1,862.51 0.22 37.44 0.41 37.21 Pass-No Errors 8,964.91 6,144.85 8,850.00 6,112.64 1.07 1.39 64.29 -1,508.18 1,876.79 0.22 38.42 0.42 38.20 Pass-No Errors 8,989.15 6,145.39 8,875.00 6,112.82 1.06 1.37 63.45 -1,487.18 1,890.35 0.22 39.35 0.42 39.13 Pass-No Errors 9,013.37 6,145.93 8,900.00 6,113.06 1.06 1.36 62.59 -1,46572 1,903.17 0.22 40.24 0.43 40.01 Pass-No Errors 9,037.54 6,146.46 8,925.00 6,113.35 1.06 1.35 61.70 -1,443.82 1,915.23 0.22 41.07 0.43 40.84 Pass-No Errors 9,061.69 6,147.00 8,950.00 6,113.71 1.07 1.34 60.80 -1,421.52 1,926.52 0.22 41.84 0.44 41.62 Pass-No Errors 9,085.80 6,147.53 8,975.00 6,114.13 1.08 1.34 59.88 -1,398.85 1,937.03 0.22 42.57 0.44 42.34 Pass-No Errors 9,109.88 6,148.05 9,000.00 6,114.60 1.09 1.34 58.96 -1,375.82 1,946.75 0.22 43.23 0.45 43.01 Pass-No Errors 9,133.94 6,148.57 9,025.00 6,115.13 1.11 1.35 58,02 -1,35246 1,955.65 0.22 43.84 0.45 43.62 Pass-No Errors 9,157.96 6,149.09 9,050.00 6,115.73 1.14 1.36 57.09 -1,328.82 1,963.74 0.22 44.40 0.45 44.18 Pass-No Errors 9,181.96 6,149.60 9,075.00 6,116.37 1.17 1.38 56.16 -1,304.90 1,971.00 0.22 44.90 0.45 44.68 Pass-No Errors 9,205.92 6,150.10 9,100.00 6,117.08 1.20 1.41 55.23 -1,280.75 1,977.41 0.22 45.35 0.45 45.12 Pass-No Errors 9,229.87 6,150.59 9,125.00 6,117.84 1.24 1.44 54.30 -1,256.39 1,982.99 0.22 45.73 0.45 45.51 Pass-No Errors CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 6 of 10 COMPASS 2003.16 Build 69 r I1..\ i ConocoPhillips ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3A Pad- 3A-17-3A-17A-3A-17A Offset Site Error: 0.00ft Survey Program: 50-GYD-CT-CMS.7298-MWD,7415-MWD Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +W-S +El-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 7,445.33 6,082.94 8,425.00 6,110.09 34.74 26.13 105.80 -2,499.35 3,322.59 0.44 1,114.21 171.55 954.31 Pass-Major Risk 7,450.00 6,082.06 8,450.00 6,111.31 34.74 26.12 106.12 -2,510.11 3,300.06 0.44 1,095.90 171.53 935.98 Pass-Major Risk . 7,450.00 6,082.06 8,475.00 6,112,95 34.74 26.11 105.86 -2,519.48 3,276.95 0.44 1,076.85 171.87 916.74 Pass-Major Risk 7,461.84 6,080.12 8,500.00 6,114.75 34.75 26.10 107.01 -2,527.70 3,253.41 0.44 1,057.08 171.32 897.26 Pass-Major Risk 7,475.00 6,078.46 8,525.00 6,115.39 34.76 26.09 108.29 -2,535.62 3,229.71 0.44 1,037.32 170.78 877.78 Pass-Major Risk 7,475.00 6,078.46 8,550.00 6,114.43 34.76 26.09 108.23 -2,543.44 3,205.98 0.44 1,017.46 171.11 857.60 Pass-Major Risk 7,475.00 6,078.46 8,575.00 6,112.72 34.76 26.08 108.20 -2,551.24 3,182.29 0.44 997.83 171.45 837.63 Pass-Major Risk 7,484.93 6,077.56 8,600.00 6,111.19 34.76 26.09 109.25 -2,559.50 3,158.75 0.44 978.63 171.26 818.41 Pass-Major Risk 7,491.62 6,077.11 8,625.00 6,109.70 34.77 26.09 109.95 -2,569.08 3,135.71 0.44 960.55 171.31 800.17 Pass-Major Risk 7,500.00 6,076.75 8,650.00 6,107.83 34.77 26.09 110.84 -2,580.26 3,113.44 0.44 943.98 171.35 783.42 Pass-Major Risk 7,506.69 6,076.62 8,675.00 6,105.49 34.78 26.10 111.60 -2,592.54 3,091.79 0.44 928.62 171.54 767.75 Pass-Major Risk 7,510.00 6,076.60 8,700.00 6,103.06 34.78 26.10 112.06 -2,606.16 3,070.97 0.44 914.85 171.90 753.50 Pass-Major Risk 7,518.19 6,076.60 8,725.00 6,100.72 34.78 26.11 113.83 -2,621.23 3,051.17 0.44 902.93 172.11 741.46 Pass-Major Risk 7,525.00 6,076.61 8,750.00 6,098.44 34.79 26.11 115.33 -2,637.63 3,032.45 0.44 893.00 172.44 731.22 Pass-Major Risk 7,525.00 6,076.61 8,775.00 6,096.16 34.79 26.11 115.47 -2,655.27 3,014.88 0.44 885.15 172.97 722.70 Pass-Major Risk 7,535.40 6,076.61 8,800.00 6,093.66 34.79 26.11 117.71 -2,674.02 2,998.54 0.44 879.30 173.33 716.51 Pass-Major Risk 7,550.00 6,076.62 8,825.00 6,091.19 34.80 26.11 120.79 -2,693.82 2,983.49 0.44 875.81 173.80 712.58 Pass-Major Risk 7,550.00 6,076.62 8,850.00 6,089.39 34.80 26.12 120.91 -2,714.56 2,969.65 0.44 874.06 174.36 710.13 Pass-Major Risk,CC 7,550.00 6,076.62 8,875.00 6,088.38 34.80 26.12 120.97 -2,736.21 2,957.21 0.44 874.69 174.93 710.08 Pass-Major Risk,ES,SF 7,559.86 6,076.63 8,900.00 6,088.16 34.80 26.12 122.96 -2,758.87 2,946.68 0.44 877.96 175.51 712.77 Pass-Major Risk 7,575.00 6,076.65 8,925.00 6,088.85 34.81 26.12 125.94 -2,782.53 2,938.68 0.44 884.64 176.22 71875 Pass-Major Risk 7,575.00 6,076.65 8,950.00 6,089.13 34.81 26.12 125.93 -2,806.80 2,932.71 0.44 893.45 176.69 727.02 Pass-Major Risk 7,575.00 6,076.65 8,975.00 6,089.22 34.81 26.13 125.93 -2,831.51 2,929.00 0.44 904.95 177.15 738.00 Pass-Major Risk 7,575.00 6,076.65 9,000.00 6,088.93 34.81 26.14 125.95 -2,856.33 2,925.96 0.44 917.57 177.60 750.08 Pass-Major Risk 7,587.17 6,076.66 9,025.00 6,088.15 34.81 26.16 128.43 -2,881.00 2,922.02 0.44 929.57 178.29 761.25 Pass-Major Risk 7,600.00 6,076.68 9,050.00 6,086.97 34.81 26.17 131.07 -2,905.34 2,916.46 0.44 940.74 179.11 771.42 Pass-Major Risk 7,600.00 6,076.68 9,075.00 6,085.61 34.81 26.17 131.16 -2,929.27 2,909.38 0.44 950.64 179.64 780.66 Pass-Major Risk 7,600.00 6,076.68 9,100.00 6,084.69 34.81 26.18 131.21 -2,952.75 2,900.86 0.44 959.73 180.20 789.08 Pass-Major Risk 7,600.00 6,076.68 9,125.00 6,084.68 34.81 26.18 131.22 -2,975.83 2,891.25 0.44 968.30 180.79 797.01 Pass-Major Risk 7,613.93 6,076.71 9,150.00 6,085.12 34.81 26.18 133.97 -2,998.29 2,880.31 0.44 975.62 181.76 803.21 Pass-Major Risk 7,625.00 6,076.73 9,175.00 6,085.65 34.81 26.18 136.16 -3,020.23 2,868.33 0.44 982.52 182.73 808.98 Pass-Major Risk 7,625.00 6,076.73 9,200.00 6,086.42 34.81 26.18 136.11 -3,041.83 2,855.76 0.44 98907 183.36 814.89 Pass-Major Risk 7,625.00 6,076.73 9,225.00 6,087.82 34.81 26.18 136.04 -3,062.75 2,842.15 0.44 99501 184.02 82019 Pass-Major Risk 7,635.71 6,076.76 9,250.00 6,089.03 34.81 26.18 138.11 -3,082.64 2,827.08 0.44 999.54 185.04 823.56 Pass-Major Risk 7,650.00 6,076.79 9,275.00 6,089.03 34.81 26.18 140.96 -3,101.39 2,810.56 0.44 1,002.96 186.24 82549 Pass-Major Risk 7,650.00 6,076.79 9,300.00 6,089.38 34.81 26.18 140.95 -3,119.23 2,793.05 0.44 1,005.21 186.94 827.04 Pass-Major Risk 7,650.00 6,076.79 9,325.00 6,090.31 34.81 26.18 140.90 -3,135.89 2,774.44 0.44 1,006.46 187.67 827.58 Pass-Major Risk 7,650.00 6,076.79 9,350.00 6,091.69 34.81 26.21 140.82 -3,151.13 2,754.67 0.44 1,006.49 188.38 826.96 Pass-Major Risk 7,663.34 6,076.83 9,375.00 6,093.15 34.80 26.30 143.40 -3,166.04 2,734.66 0.44 1,006.35 189.52 825.46 Pass-Major Risk 7,664.44 6,076.83 9,380.00 6,093.44 34.80 26.32 143.61 -3,169.02 2,730.66 0.44 1,006.40 189.69 825.33 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 7 of 10 COMPASS 2003.16 Build 69 : \ ,! G1. [ ConocoPhillips ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error. 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3A Pad- 3A-17-3A-17AL1 -3A-17AL1 Offset Site Error: 0.00ft Survey Program: 50-GYD-CT-CMS,7298-MWD,7415-MWD,7838-MWD Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Well bore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +W-S +E/-w Hole Size Centre Distance Deviation (R) (8) (R) (8) (R) (ft) C) (ft) Oft (ft) (R) (ft) (ft) 7,425.00 0087.20 8,375.00 6,118.59 34.72 26.21 101.70 -2,433.87 3,333.25 0.22 1,106.98 171.79 947.31 Pass-Major Risk 7,433.68 6,085.36 8,400.00 6,119.16 34.73 26.20 103.58 -2,450.28 3,314.40 0.22 1,092.90 171.06 934.05 Pass-Major Risk 7,440.00 6,084.02 8,425.00 6,119.76 34.73 26.19 104.87 -2,466.07 3,295.03 0.22 1,078.53 170.70 920.12 Pass-Major Risk 7,440.00 6,084.02 8,450.00 6,120.20 34.73 26.18 104.61 -2,480.28 3,274.47 0.22 1,062.86 171.09 904.20 Pass-Major Risk 7,450.00 6,082.06 8,475.00 6,120.44 34.74 26.16 105.60 -2,492.69 3,252.79 0.22 1,045.80 170.64 887.31 Pass-Major Risk 7,450.00 6,082.06 8,500.00 6,120.35 34.74 26.15 105.41 -2,503.00 3,230.02 0.22 1,027.31 171.01 868.55 Pass-Major Risk 7,461.40 6,080.18 8,525.00 6,119.51 34.75 26.14 106.63 -2,511.61 3,206.57 0.22 1,007.71 170.51 849.08 Pass-Major Risk 7,467.05 6,079.40 8,550.00 6,117.31 34.75 26.13 107.24 -2,519.08 3,182.82 0.22 987.60 170.47 828.82 Pass-Major Risk 7,475.00 6,078.46 8,575.00 6,113.46 34.76 26.12 108.21 -2,525.15 3,158.89 0.22 966.95 170.30 808.01 Pass-Major Risk 7,475.00 6,078.46 8,600.00 6,108.96 34.76 26.12 108.37 -2,529.57 3,134.70 0.22 945.60 170.62 786.18 Pass-Major Risk 7,475.00 6,078.46 8,625.00 6,104.23 34.76 26.12 108.56 -2,532.68 3,110.35 022 923.80 170.91 763.91 Pass-Major Risk 7,486.97 6,077.41 8,650.00 6,099.57 34.76 26.13 110.06 -2,536.57 3,086.11 0.22 902.36 170.62 742.36 Pass-Major Risk 7,500.00 6,076.75 8,675.00 6,094.99 34.77 26.14 111.61 -2,542.36 3,062.23 0.22 882.22 170.45 722.08 Pass-Major Risk 7,500.00 6,076.75 8,700.00 6,090.46 34.77 26.15 111.87 -2,550.11 3,038.90 0.22 863.33 170.88 702.57 Pass-Major Risk 7,506.40 6,076.62 8,725.00 6,085.99 34.78 26.16 112.78 -2,559.77 3,016.29 0.22 846.10 171.14 684.86 Pass-Major Risk 7,510.00 6,076.60 8,750.00 6,081.61 34.78 26.17 113.43 -2,571.31 2,994.56 0.22 830.71 171.54 668.83 Pass-Major Risk 7,517.99 6,076.60 8,775.00 6,077.35 34.78 26.19 115.33 -2,584.65 2,973.86 0.22 817.32 171.86 655.08 Pass-Major Risk 7,525.00 6,076.61 8,800.00 6,073.62 34.79 26.20 117.01 -2,599.54 2,954.13 0.22 805.91 172.31 643.16 Pass-Major Risk 7,525.00 6,076.61 8,825.00 6,070.64 34.79 26.21 117.23 -2,615.88 2,935.46 0.22 796.59 172.92 633.03 Pass-Major Risk 7,536.07 6,076.61 8,850.00 6,068.40 34.79 26.22 119.62 -2,633.65 2,918.02 0.22 789.42 173.45 625.36 Pass-Major Risk 7,550.00 6,076.62 8,875.00 6,066.63 34.80 26.22 122.54 -2,652.79 2,902.05 0.22 784.91 174.12 620.21 Pass-Major Risk 7,550.00 6,076.62 8,900.00 6,065.05 34.80 26.23 122.66 -2,673.40 2,888.01 0.22 783.12 174.74 617.67 Pass-Major Risk,CC,ES,E 7,550.00 6,076.62 8,925.00 6,063.42 34.80 26.23 122.78 -2,695.29 2,876.07 0.22 784.57 175.33 618.39 Pass-Major Risk 7,562.50 6,076.63 8,950.00 6,061.68 34.80 26.23 125.40 -2,718.12 2,866.03 0.22 788.55 176.08 621.58 Pass-Major Risk 7,575.00 6,076.65 8,975.00 6,060.06 34.81 26.23 128.00 -2,741.74 2,858.04 0.22 795.40 176.89 627.51 Pass-Major Risk 7,575.00 6,076.65 9,000.00 6,058.76 34.81 26.23 128.07 -2,766.09 2,852.57 0.22 805.05 177.39 636.54 Pass-Major Risk 7,575.00 6,076.65 9,025.00 6,057.77 34.81 26.23 128.11 -2,790.91 2,849.88 0.22 817.83 177.85 648.76 Pass-Major Risk 7,585.70 6,076.66 9,050.00 6,056.78 34.81 26.23 130.28 -2,815.88 2,849.56 0.22 832.82 178.54 662.96 Pass-Major Risk 7,590.32 6,076.67 9,075.00 6,056.28 34.81 26.24 131.20 -2,840.79 2,851.53 0.22 849.96 179.05 679.51 Pass-Major Risk 7,600.00 6,076.68 9,100.00 6,056.25 34.81 26.25 133.10 -2,865.62 2,854.41 0.22 868.09 179.70 696.90 Pass-Major Risk 7,600.00 6,076.68 9,125.00 6,056.65 34.81 26.26 133.03 -2,890.52 2,856.49 0.22 885.76 180.03 714.23 Pass-Major Risk 7,600.00 6,076.68 9,150.00 6,057.40 34.81 26.27 132.95 -2,915.50 2,856.56 0.22 902.33 180.37 730.44 Pass-Major Risk 7,600.00 6,076.68 9,175.00 6,058.30 34.81 26.28 132.87 -2,940.40 2,854.51 0.22 917.67 180.76 745.39 Pass-Major Risk 7,613.15 6,076.71 9,200.00 6,059.42 34.81 26.28 135.40 -2,965.03 2,850.46 0.22 931.42 181.62 758.21 Pass-Major Risk 7,625.00 6,076.73 9,225.00 6,060.10 34.81 26.29 137.71 -2,989.15 2,843.95 0.22 943.69 182.53 769.44 Pass-Major Risk 7,625.00 6,076.73 9,250.00 6,060.74 34.81 26.29 137.65 -3,012.60 2,835.34 0.22 954.20 183.02 779.45 Pass-Major Risk 7,625.00 6,076.73 9,275.00 6,061.60 34.81 26.29 137.59 -3,035.35 2,825.01 022 963.55 183.56 788.26 Pass-Major Risk 7,625.00 6,076.73 9,300.00 6,062.50 34.81 26.29 137.53 -3,057.17 2,812.87 0.22 971.56 184.15 795.69 Pass-Major Risk 7,639.77 6,076.77 9,325.00 6,063.38 34.81 26.29 140.42 -3,077.59 2,798.49 0.22 977.13 185.34 799.89 Pass-Major Risk 7,650.00 6,076.79 9,350.00 6,064.44 34.81 26.29 142.40 -3,096.63 2,782.33 0.22 981.21 186.42 802.76 Pass-Major Risk 7,650.00 6,076.79 9,375.00 6,065.82 34.81 26.29 142.32 -3,114.46 2,764.87 0.22 983.91 187.07 804.86 Pass-Major Risk 7,650.00 6,076.79 9,400.00 6,067.32 34.81 26.29 142.23 -3,131.89 2,747.01 0.22 986.67 187.68 807.06 Pass-Major Risk 7,662.11 6,076.82 9,425.00 6,068.82 34.80 26.29 144.56 -3,149.32 2,729.15 0.22 989.73 188.79 808.84 Pass-Major Risk 7,663.66 6,076.83 9,432.00 6,069.24 34.80 26.29 144.85 -3,154.20 2,724.15 0.22 990.70 189.01 809.57 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 8 of 10 COMPASS 2003.16 Build 69 f"t. tR, f I S `p /~-r ,t lam• ConocoPhillips Nal ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit ND Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset ND Reference: Offset Datum Offset Design Kuparuk 3A Pad- 3A-17-3A-17AL1 PB1 -3A-17AL1PB1 Onset Site Error: 0.00ft Survey Program: 50-GYD-CT-CMS,7298-MWD,7415-MWD,8008-MWD Rule Assigned:Major Risk Offset Well Error. 0.006 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +W-S +EI-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) IM 7,450.00 6,082.06 8,425.00 6,055.97 34.74 26.23 109.08 -2,500.24 3,319.10 0.44 1,111.53 170.51 950.52 Pass-Major Risk 7,450.00 6,082.06 8,450.00 6,057.31 34.74 26.21 108.85 -2,514.01 3,298.28 0.44 1,095.72 170.93 934.40 Pass-Major Risk 7,461.74 6,080.14 8,475.00 6,058.36 34.75 26.19 110.06 -2,526.33 3,276.56 0.44 1,078.75 170.40 917.66 Pass-Major Risk 7,475.00 6,078.46 8,500.00 6,058.83 34.76 26.17 111.40 -2,537.34 3,254.12 0.44 1,061.02 169.88 900.18 Pass-Major Risk 7,475.00 6,078.46 8,525.00 6,058.27 34.76 26.16 111.36 -2,547.29 3,231.20 0.44 1,042.57 170.29 881.30 Pass-Major Risk 7,475.00 6,078.46 8,550.00 6,056.42 34.76 26.14 111.39 -2,556.42 3,208.00 0.44 1,023.89 170.70 862.16 Pass-Major Risk 7,484.89 6,077.56 8,575.00 6,053.69 34.76 26.12 112.57 -2,564.38 3,184.47 044 1,004.64 170.51 842.81 Pass-Major Risk 7,490.18 6,077.20 8,600.00 6,050.92 34.77 26.11 113.27 -2,570.91 3,160.50 0.44 984.66 170.62 822.53 Pass-Major Risk 7,500.00 6,076.75 8,625.00 6,049.10 34.77 26.10 114.38 -2,576.40 3,136.18 0.44 964.13 170.55 801.88 Pass-Major Risk 7,500.00 6,076.75 8,650.00 6,048.67 34.77 26.10 114.43 -2,581.12 3,111.64 0.44 943.11 170.92 780.45 Pass-Major Risk 7,505.22 6,076.64 8,675.00 6,049.46 34.78 26.10 114.94 -2,58565 3,087.07 0.44 922.10 171.09 759.25 Pass-Major Risk 7,510.00 6,076.60 8,700.00 6,050.94 34.78 26.10 11536 -2,591.59 3,062.84 0.44 902.06 171.31 739.00 Pass-Major Risk 7,510.00 6,076.60 8,72500 6,052,84 34.78 26.11 115.28 -2,59943 3,039.18 0.44 883.53 171.73 720.11 Pass-Major Risk 7,519.04 6,076.60 8,750.00 6,054.94 34.78 26.12 116.99 -2,608.82 3,016.11 0.44 866.32 171.88 702.99 Pass-Major Risk 7,525.00 6,076.61 8,775.00 6,056.94 34.79 26.13 11809 -2,619.49 2,993.59 0.44 850.51 172.23 687.01 Pass-Major Risk 7,525.00 6,076.61 8,800.00 6,059.02 34.79 26.13 117.98 -2,631.53 2,971.79 0.44 836.32 172.77 672.34 Pass-Major Risk 7,534.45 6,076.61 8,825.00 6,061.14 34.79 26.13 119.75 -2,643.85 2,950.14 0.44 822.72 173.25 658.47 Pass-Major Risk 7,539.95 6,076.61 8,850.00 6,063.25 34.79 26.13 120.73 -2,656.17 2,928.49 0.44 809.55 173.83 644.88 Pass-Major Risk 7,540.62 6,076.61 8,853.00 6,063.51 34.79 26.13 120.85 -2,657.65 2,925.89 0.44 808.00 173.90 643.27 Pass-Major Risk,CC,ES, CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46:50PM Page 9 of 10 COMPASS 2003.16 Build 69 ConocoPhillips Vaal ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-07 Project: Kuparuk River Unit TVD Reference: 3A-07 @ 73.00ft(3A-07) Reference Site: Kuparuk 3A Pad MD Reference: 3A-07 @ 73.00ft(3A-07) Site Error: 0.00ft North Reference: True Reference Well: 3A-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3A-07L1-01 Database: EDM Alaska Prod v16 Reference Design: 3A-07L1-01_wp02 Offset TVD Reference: Offset Datum Reference Depths are relative to 3A-07 @ 73.00ft(3A-07) Coordinates are relative to:3A-07 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.06° Ladder Plot I 1 1200 I I I I I I I € I t I I I 1 I I I I I I I 1 1 I I I I I 900 c I 1 I g(15 I I ii I __J __J __J J J '.i d I I I C17 I I I I I I aa) 600 C.) 2 I I I € I 4Y I I 6 I C_.) I I 1 I I I 1 300 I I € I € I • I I I 1 € 1 I 1 I I 1 i I I I 1 I 1 I I 1 1 I t I I I I I 0 1500 3000 4500 6000 7500 9000 M easured Depth LEGEND 3A-07,3A-07.3407 V3 3A-17,3A-1743A-1 7AV0 3A-17.3417AL1 P B1.3A-1 7AL1P B 1\A m 3A-07,3A-07L1,3A-07L1wp06 VD 3A-17,3A-17AL1.3A-17AL1\O CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/11/2011 1:46.50PM 2RtGINAL Page 10 of 10 COMPASS 2003.16 Build 69 r Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing '1.0. — Lubricator 1 1 Itiwo Riser Annular Blind/Shear 2"Pipe/Slip (CT) / /Pump into Lubricator - above BHA rams �ii� Ji\' ivmnk Choke 1 'I 2-3/8"Pipe/Slip(BHA) I' Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) ' ' \ J _ Kill ►i �✓ i I - Blind/Shear I 2"Pipe/Slip (CT) . Choke 2 •'Swab Valves . ■Wing Valves Tree Flow Cross 0 Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union IG ! "//‘ Lcv A N.) A _ 1 , - -..„ - ,, ,1 . _ _ _ C.--.1 • • 1`.... I lig:ti i '1 C) 'Cr 4... - - — ".. LI') Ce) 1 I ' D er) f L GP ' C ) c:=7, ICD C_) •c-x=> 11.-C) ` . . . . = _ _ . , . 0 1 W no - a• 4--, (f) c — --.... C ) 5 0 g . _ I g . g , —I _ - 1%.- 0 1 . - - ...._. et, . (J) _ 03 - . . . h-1-4. ___,. ..,.... ,, . ———— —NI. mmmmm NMI mmmmmmm _C r--- c=_—) a.C> . = — 0 - (./.) - . C.= (---) . C--, _ ,,,-.,, .. , . 1 1.,.A.44-e- IP 111 WIPP 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST / WELL NAME 1<Iz1.-� 3/1 - .. 1 PTD# ! l 1 2- Developmenty Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 1 c-r l� L iLl�l POOL: lt,l- Gc 6i( Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore s gment of existing well /'f211 rJ 7 , (If last two digits in rmit No./ S-2.33,API No. 50-CO - 1/�� . API number are i2 e between 60-69) ould continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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