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211-082
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. zI L - Q g 02,Well History File Identifier Organizing (done) /1wo-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: Color Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: 42Date: 7/ JJIL /s/ Pie Project Proofing ri'if BY: Date: /s/ Scanning Preparation 4 x 30 = (P0 + / q = TOTAL PAGES '79 (Count does not include cover sheet) BY: aria Date: 7 a j//if /s/ rn,� Production Scanning Stage 1 Page Count from Scanned File: O (Count does include covers et) Page Count Matches Number in Scanning Preparation: YES NO BY: `I Date: 7/ i1 J t+ /s/ 04 F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES ( NO ) TOTAL PAGES: Digital version appended by: Meredith Michel Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s! Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc I 1 0 1 m � co Jco E J co ...,.. a_ I1 1 co w A, c c I co a) 0a1-2,- 6 a a`> a o131 co E )n co N as E d N a C7 C7 y4 Z 1 U ❑• >❑ w ❑ dl�i 1 1 a I co c Q mo v z_ 0 o a .> 5 `) (/) o N N N N N N c, >¢ o Et ,- ,- 0) 0) a) a) U > ❑ J 0) 0)) m a o) a) 4 z E c co 1 ch c = = a a a) a) a a) E I—� N N -co pU 0 0 0 0 O O o 0 IL Q c ! 0 v i m a 0 0 0 0 0 0 0 co J▪ 0 : : : :co n n n } } I,- Om J W co c . ` I fx 0 C co L. O O N z U Cl) n- to (0 (O c0 0 C0 '' 111 0 U o d a") v) Z oof zo Q a z o O . , .! o J a ra I R = '� aN of zl � �o I 81i 8 U oE. 5 Nv) 1 a) OO E a co O V N in ID J Co V N 0 E O> J Q ! co Q N I— coO. ` O 1 N — Z N Z n 5 G/ W co• N c > > I t V) a N t Q Y `s 1001 Ha) Q C a ZI co .4 i, .. 0 z o W aTi aTi > > '> '> • 0 E J Z ,N V) N N )C .D CC!) In N 0' W K 2' Z 0 � m m c c c c a) O O ,O O O O a) I ! C R a) a) 7 3 7 7 C m " o coo 1 C Z a Q c -o c c ., Z c o y 1 c !Tic/Z.) z 1 T < Z r CO W G Z N 0 }}t �} 3 N CL O p d p m Ua. co d' ca YO u c y in z m 0 �• co n ❑ g \ ` aio a. I d z Lu o o o? a o ' a .ca) 0y 0 y 02 o. a o 0 0 ❑ m O oca) 0 d 0H N QU ¢dU 0 I re JGLU d 1 _ 232 r�� BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes WELL NAME 31-I-12AL1 RUN NUMBER FIELD Kuparuk BH SALESMAN Woods,Jim (mandate (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandato LOG DATE: 08/23/2011 TODAYS DATE: 4/10/2011 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) 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 nNKiN t S #OF COPIES #OF COPIES v v v v v v 1 ConocoPhillips Alaska,Inc. 1 1 NSK Wells Aide,NSK 69 I ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP 1 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 STATE OF ALASKA A • �. ALA; OIL AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Rug Ferforations r Perforate r Other F., Convert Prod to Injector Alter Casing r Rill Tubing r Stimulate-Frac r Waiver IT Time Extension r- Change Approved Program r Operat.Shutdow n r Stimulate-Other r" Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ConocoPhillips Alaska, Inc. Development Fi, Exploratory r ' 211-082-0 3.Address: 6.API Number: Stratigraphic r Service r" P. O. Box 100360,Anchorage,Alaska 99510 - 50-103-20088-60 "00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25531 ` _. 3H-12AL1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):,, none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7710 feet Plugs(measured) None true vertical 6090 feet Junk(measured) None Effective Depth measured 7710 feet Packer(measured) 6684 true vertical 6090 feet (true vertucal) 5878 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 115 115 . SURFACE 3069 9.625 3104 2986 PRODUCTION 7189 7 7225 LINER AL1 361 2.375 7710 90 RECEIVED i V MAR 16 2012 Perforation depth: Measured depth: 7361'-7697' True Vertical Depth: 6097'-6091' i ,\,aS"Cil &has Cons.Commission h Tubing(size,grade,MD,and TVD) 3.5,J-55,6682 MD,5876 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6684 MD and 5878 ND 1 SSSV-CAMCO TRMAXX @ 1804 MD and 1804 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 299 153 650 425 181 Subsequent to operation 3797 1050 1532 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r ; Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ IT f SUSP r SPLUG r 17.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: 311-339 Contact Bob Christensen/ Darrell Humphrey Printed Name i R...ert i Christensen Title NSK Production Engineering Specialist Signature // ' Phone:659-7535 Date .3// M5 MAR 19 20t 3/2 D Form 10-404 Revised 11 2� �z___ Submit Original Only 3H-12AL1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/05/12 Commenced WAG EOR Injection L l ConocoPhillips Well Attributes KUP 3H-12AL1 Max Angle&MD TD • Alaska IncWellbore APIIUWI Field Name Well Statue Incl(°) MO(RKB) Act atm (1tKB) ,,,,,,,,,,,l„ 501032008860 KUPARUK RIVER UNIT SVC 8,454.0 Comment H2S(ppm) Date Annotation End Date KB{3rd(R) Rig Release Date ... Well Coate.-3H-128L1.9162011 2:43:29 PM —SSSV:TRDP Last WO: 42.01 1/4/1988 Schematic'.ActualAnnotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,681.0 8/1/2011 Rev Reason:ADD SIDETRACKS ninam 9/8/2011 r Casing Strings #. Casing Description String 0... String ID...Top(I0(81 Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd HANGER.35 LINER AL1 2 3/8 1.992 7,350.0 7,710.6 4.70 L-80 STL Liner Details Top Depth (TVD) Top Incl Nomi... IIITop(91081 (RKB) (°) Item Description Comment ID(In) II 7,350.0 Perforations&SlotsBILLET OH ANCHORED BILLET 1.000 CONDUCTOR, 36115 Shot Top(TVD) Btm(TVD) Dene Top DIKED Btm MKS) (RKB) (1188) Zone Dab (ah... Type Comment SAFETY vw, o1, 7,361 7,697 8/24/2011 32.0 SLOTS Alternating solid/slotted pipe- 1,804 0.125'x2.5"@ 4 dreumferential I adjacent rows,3"centers staggered 18 deg,3'non-slotted ends i Ii GAS LIFT, 2 SBC 111 I SURFACE 35-3 104 GAS LIFT. a 4081 i GAS LFT t 5 211 1 MMI I PERF 5.895-5.899 GAS LIFT 6.026 GAS LIFT, S559 NIPPLE,6620 SEAL ASSY, 8,67 - PEW.8,6711 PACKER,8,684 tIIIIMMIN NIPPLE.8.723 a- Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Sloe TRO Run ---1 Stn Top(MB) MKS) P) Make Model (in) Sere Type Type (int (psi) Run Dab .. Com. SOS,6,7x6 (PERF, 1 2,584.1 2,553.5 28.44 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2011 6,8 WHIPSTOCK.6 2 4,087.3 3,791.4 34.71 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2011 PRODUCTION. ■ 3 5,210.8 4,693.2 36.92 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/172011 725 4 6,026.4 5,347.6 36.42 CAMCO MMG 1 12 GAS LIFT'DMY RK 0.000- 0.0 6/172011 5 6,559.2 5,777.3 36.09 CAMCO MMG [1 12 GAS LIFT DMY RK 0.000 0.0 7/2/2011 SLOTS. 7,3131207 1111111. LINER AL1, 7,350.7,711 TD(3H-12AL1), 8,454 CW-7 /IT a - a a O SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMDIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Jeremy Mardambek Production Engineer ConocoPhillips Alaska, Inc. 0$ X' P.O. Box 100360 a t Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-12AL1 Sundry Number: 311-339 Dear Mr. Mardambek: 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 rd DATED this 3 day of November, 2011. Encl. (A I "ECEIVED' 1 l N ,40v 0 2 2011 STATE OF ALASKA .1� ALASKA OIL AND GAS CONSERVATION COMMISSION V APPLICATION FOR SUNDRY APPROVALWaska Oil &Gas Cons.ComniSSion 20 MC 25.280 Ile lOri! 0 1.Type of Request: Abandon n Rug for Redrifl n Perforate New Pool f Repair well n Change Approved Program r Suspend n Plug Perforations r Perforate r Pull Tubing n Time Extension n Operational Shutdown n Re-enter Susp.Weil n Stimulate f Alter casing n Other:Convert prod to Injector p; • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhiilips Alaska,Inc. Development f , Exploratory r 211-082-0 • 3.Address: Stratigraphic n Service r 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20088-60 ' 7.1f 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 j 3H-12AL1 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25531 ` Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(n): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7710 - 6090 7710' 6090' Casing Length ' Size MD ND Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3069 9.625 3104' 2986' PRODUCTION 7200' 7 7225' 6314' LINER AL1 361 2.375 7710' 6090' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7361'-7697' 6097'-6091' 3.5 L-80 6682 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER FHL PACKER MD=6684 TVD=5878 SSSV MD=1804 ND=1804 12.Attachments: Description Summary of Proposal 17, 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Development n Service (J • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/4/2011 Oil n Gas n WDSPL 1"1 Suspended n 16.Verbal Approval: Date: WINJ n GINJ n WAG 17, , Abandoned n Commission Representative: GSTOR n SPLUG n 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jeremy Mardambek i 659-7871 Printed Name Jeremy Mardambek Title: CPF3 Production Engineer Signature Phone: Date 11/0 i I Commission Use Only Sundry Number: I 1 ..33 q Conditions of approval: Notify Commission so that a representative may witness Plug Integrity n BOP Test n Mechanical Integrity Test Location Clearance n Other: Subsequent Form Required: /4) —y p APPROVED BY / /j ( Approved by: .I/ COMMISSIONER THE COMMISSION Date: L I F rm 10-403 Revise. 1 Submit in Duplicate I I� Dns Novo 4 in ,,_z_r, OR I G l N A L 1.2` `, LIP ;H-12AL1 COnocoPh llips - y Well Attributes_ - Max Angle&MD TO Alaska.Inc. .AB, Wellbore APPUWI ',Field- N me (Well Stat Incl(') IMO(HMI) Act Btm(ftKB)8 454.0 Lcx+nclxPhnkas 501032008860 KUPARUK RIVER UNIT SVC , ' Comment H2S(ppm) Data Annotation End Date KB-Grd(ft) RigRelease Date _ ..__)54608 F.l9.-_�tk12A0 L4/8129'I.1.3;43 R9 PM __.:... SSSV'TRDP �... _ _Last WO: 42.01 1/4/1988 _ g .AcyaL,,._ Annotation" Depth MKS) (End Dale (Annotation Last Mod...End Date Last Tag'SLM 6,681 0 8/1/2011 Rev Reason'ADD SIDETRACKS 11 mem 9/8!2011 Casing Strings Casing Description String 0... Sb ng ID..Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String_.Sting Top Thrd it HANGER,35 ,^; LINER AL1 _.-L 2318_._ 1.992 -...7,350.01-7,710.6 I -_--__� 4.70 L-80 � STL itltitlsts,I:iwa �'�'. Liner Details Top Depth (ND) Top Incl Noma... Top(ftK6) (ftK6) I') Item Description Comment ID(in) 7,3500 BILLET OH ANCHORED BILLET 1.000 CONDUCTOR, 36.115 Perforations&Slots I Shot Top(TVD) Btm(TVD) Dens Top MKS)Bbn(ftKB) MKS) (ftKB) Zone Date (eh.-- Type Comment SAFETY nLV, 7,361 7,697 8/24/2011 32.0 SLOTS Alternating solid/slofted pipe- 1,804 *47 0.125"x2.5'@ 4 circumferential I. adjacent rows,3"centers staggered 18 deg,3'non-slotted ends , GASLIFT, '•`- 2.566 ,.. % 11 1 SURFACE,.-. .( 35-3,10a • GAS LIFT - 4,087 I GAS LIFT, 5,211 (PERF. 8,885.5,898 eYu- „ -. GAS LIFT, 6.026 II GAS LIFT. 6,559 lit t NIPPLE.6,620— -'1`' 1 1,. SEAL ASSY,_ t• -i PBR,8.871 --_-- PACKER.6,664 NIPPLE,6,723 .Mandrel Details_ L W P ,A A `` MA Top Depth Top Pant ' (TVD) loot OD Valve Latch SW TRO Run SOS,6,756-----... ... Sin Top (ftK6) (") Make Model lin) Sery Type Type _ lin) (Pei) Run Dab a Cn..._ I.6 - DMY RK 0.000 0.0 6!172011 6,832 ERF. -_-- 3,797 434. CAMCO MMG 1 1/2 GAS LIFT — 846 WHIPSTOCK, 2 4,0873DMY RK 0.000 0.06!17/2011 PRODUcraN, 1 _r451_, el 3 5,210 8 4,693.2 36.92 CAMCO MMG 1 1/2 GAS LIFT rDMY RK 0.000 0.0 6/17/2011 35-7.225 -'..r. --- .-----"_- - - --- - ---- 4 6,026.4 5,347.6 36.42 CAMCO MMG 1 1/2 GAS LIFT 'DMY RK 0.000 0.0 6/17/2011 5 6,559.2 5,777.3 36.09 CAMCO MMG 1 1/2 GAS LIFT ';DMY RK 0.000 0.0 7/2/2011 SLOTS,_ ^" 7.361-7.697 - -. - --� 7,NERALi, 11 7,35127,71) TO(3H-116,454 8,45a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION la.Well Status: a.�J WELL CaOs �MPLETIOSPLUG �N OhR Rer ❑ECOaMPLndoned❑ETIOuNenRded EPORT IAND LOG �I l Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ WAG ❑ WDSPL ❑ No.of Completions: Service 0 Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August 27,2011 211-082/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 August 22,2011 50-103-20088-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1207'FNL,281'FWL,Sec. 12,T12N, R8E,UM August 23,2011 3H-12AL1 Top of Productive Horizon: 8.KB(ft above MSL): • 76'RKB 15.Field/Pool(s): 1358'FSL, 1162'FWL,Sec. 1,T12N, R8E, UM GL(ft above MSL): . 34'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1091'FSL,689'FWL,Sec. 1,T12N, R8E, UM 7710'MD/6090'TVD • Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-498655 y- 6000451 Zone-4 7710'MD/6090'TVD -ADL 25531 TPI: x-499535 y- 6003015 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-499062 y- 6002748 Zone-4 1804'MD/1804'TVD • 2657 18.Directional Survey: Yes ❑✓ No El 19.Water Depth,if Offshore: 20.Thickness of Permafrost MDITVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1983'MD/1983'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 6861'MD/6022'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 245 sx AS I 9.625" 36# J-55 36' 3104' 36' 2986' 12.25" 1300 sx AS III,400 sx Class G,90 sx AS I 7" 26.0# J-55 36' 7225' 36' 6314' 8.5" 320 sx Class G,175 sx AS I 2.375" 4.7# L-80 7350' 7710' 6088' 6090' 3" slotted liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6682' 6684'MD/5878'TVD 7361'-7697'MD 6097'-6091'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. :;v. -i;r0, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED '.. : '/1 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting for facility hook-up Date of Test Hours Tested Production for .OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> ' 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No E If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED' NONE SEP 2 0 2011 RBDMS SEP 2 0 2011 j�; _ Alaska Oil &Gas Cons. Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE At1 h tioriginal only f•Zr•:/d," V 6 28. GEOLOGIC MARKERS(List all formations and markers e. ,tered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes E No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1983' 1983' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk Al 6940' 6079' N/A Formation at total depth: Kuparuk Al 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: Jame Ohlinger @ 265-1102 •D. 9//3// Printed Nam L Gan syr Title: CTD Engineering Supervisor Signature GLXfn 1j Q Phone 265-6306 Date qy / Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 KUP 3H-12AL1 C�4Phi lips Wel t r tes Max Angle&MD TD _— B( f�{tiS'i+.B , Wellbore API/UW1 [Field Name Well( Status Incl(') IMO(COB) Act Bim(ftKB) torx.rcmnins.. 501032008860 KUPARUK RIVER UNIT 11 SVC 8,454.0 Comment H2S(ppm) Date An otation End Date KB-Grd(ft) Rig Release Oct. - SSSV TRDP l Last WO 42.01 1 1/4/1988 (ftKB Depth __ Wel an6p'-X 12147,_9/0/7Q Schematic-/AduaL..7.2.19,2$.?DA._,.- Annotation ( End Date [Annotation I Last Mod...(End b Da �'�'^ _ �_�. _ ll ) Last Tag:SLM 6,681 0 8/1/2011 Rev Reason:ADD SIDETRACKS ninam I 9/8/2011 l Casing Strings s y Casing Description Strng 0... String ID...[Top(MB) Set Depth(1...Set Depth(ND) I String Wt..'Siring...String Top Thrd HANGER,35 3 LINER AL1 __-.. .I 23/8_-_ 1.992 73500 [Set I 1 4.70 I L80I STL ..-._-. r; . yr o:Liner Details Top Depth (ND) Top Incl 11 Nomi... Top(ftKB) (ftKB) (') Item Description Comment ID(in) 7,350.0 BILLET 10H ANCHORED BILLET 1.000 CONDU O gOR, Perforations&Slots Shot Top(TVD) Btm(IVO) Dens Top(ftKB) BUn(MB) (ftKB) (11KB) Zone Date (eh-. Type Comment _ SAFETY VLV, - 7,361 7,697 8/24/2011 32.0 SLOTS Alternating solid/slotted pipe- 1,804 _ 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends • II GAS LIFT, 2.584 II ill SURFACE, I 35-3,101 l" GAS LIFT, -_- 4.087 J. I., I GAS 111-1 5.21 -.ti;.-. IPERF, 5,895-5,899 _ lji. - ' GAS LIFT. 6,026 1:, , 1I it GAS LIFT. -- 6.555 it i NIPPLE,6,620 — AIL j1 -..---- SEAL _SEAL ASSY, Ii_.-.-A CPO-N., _... -- . PBR,6,671 ...'1 PACKER,6,884 --- 1 NIPPLE,6.723-- - .p• �..`` "f 7.111 .✓** 1 d "`,.e6'dn y«, : Top Depth Top Port (TVO) Incl OD Valve Latch Si.. TRO Run SOS,6.756 Stn Top MKS) MKS) (1 Make Model (in) Say Type Type (ln) (psi Run Dabs Can,.. IPERF, - -! 1 2,584.1 2,553.5 28.44 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2011 6,832-6,846 2 4087.3 3,791.4 34.71 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/17/2011 6.854 WHIPSTOCK, PRODUCTION, 3 5,210.8 4,693.2 36.92 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/17/2011 35-7,2254 6,026.4 5,347.6 36.42 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/17/2011 5 6,559.2 5,777.3 36.09.CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 7/2/2011 SLOTS, 7,361-7,697 7, LINER356-7,7AL11t, TD(3!41281.1),\ 8,451 M u') W i` I M O N co m co I CO- "'CN N t I C I N N I 0_C 'I r) O_, ;1 NI M •I U 11 co 11 II co C j n 0 m O U Ln C 11 O N o) 1 co I ^' I I M V C O , 1 :� _I iij Q a�D J N (I N _c O n 1 I C .I I I = o c N� II '; CO 0-1 (0^II 'I o- R —1 N In < M V N_c N-) 5( c0 R •-• C '' 1), I (p = N m dc vU) ao MOJ 1) Is M I ( II N N.p ) ,, 1 I J N O ) I I Qr N _c 1. C .. II II N N ,I' ,11 I 1 a c CO O J .I II 11 1 ;' II 1, II 1 .II '1 .. .I .. .. _ 1, II V �\ • .. 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N N N N N N N N N N N N CO Cl) 0 00 0 CO 0 CO 0 NM U) N C) CO CO r U) 00 V CO CO CO r N r 0 O • CO O U) Q aO N r ,- a) U) a) co V N N r N V r r CO N .- r r N N .- V v U) 0) O a0 O r 0 M O O N- (O U) V M N N O O 7 Q h 0 0 0 r OD V 0 v'"-. 0)) C) 0))QD O). O O O O 0 0 0 0 0 0 .606o 0. 0 0 0 0 0 0 0 0 0 O O > `� N U) U) U) 0 0 OO 0 (O co 0 OD 0 (O OD OO (O (O co (O (O (O OD co cc 0 (O (O f0 co F- O) U) O 0 O CO 0 0) 0 NU) CO U) N O) (0 (D r U) (O V (O 0 CO r N r O O • a0 O co V co N r a) a) U) Q N N r N V r N- a0 N r r N (V Q O U) 0 V 0 M N g OD 0 M N O 0) 0 cO r OD 2 r O M Q Q `., M N O U 0 w N N Q OO OO a) O O 0) 0) O) a) a) a) a) 0 0 c0 W a0 a0 0 a) a) a) a) a) a) a) O) C 0 . 0 0 0 0 '- '- 00000 0 0 0 0 0 O O O O O 0 0 0 0 0 O O - F- `- (O (O co- (D (O CO Or (D 0 0 OO 0 0 0 0 co OD OD 0 co0 (O 0 0 co 0 co (O tD 0 Y v) cz +' Cr) CO 0 V0) CO OO CO U) 0 r N CO 0 N Q Q CO CO 0 U) OD O CO CO CO O Q -O r (O O Q N M Q M Q OD U) U) V (O M V M M M M M M CO N .- OD a? V V V -r N CO .-� r r 0 M CO U) (O aD U) a0 U) N 0 OO O V co M6 V O OD 0) 0 V I� r (1 N d N or Q N N N N N O 0 r CD V co co N O O O 0) O 0 0 .- O CO co M M M M M M N N N N N N N N N N N N N N (V N N N a. L Q- ' CO o Y •— O - N N N U) r CO m U) OO CO U1 0) N V OD N 0 CO 0 0 V CO r N N 0 C) CO M C d 03 .,- _ V U) V r N c`; 0 N- N 0 CO CD UI r U) CO N- 0 0 N- N r 0 r CO N CO a) V V Cl., 0 n n 2 = S C°.� (M') M m v (°o r IC rn rn rn rn rn rn rn rn rn rn rn m m (0 OQD OBD 0) rn rn rn CO" •)a2 U Y Y (h (� CO0) 0 rNV 0 0 coM coM UO to N 0 C) V 0 0 Q (� U) COM r N COM N a) N N V 0 d' 0 >. y) ^ O O r Q V V CO CO V CO 0 CO U) V V V CO U) U) V co co Q V U) 0 CD 0 O N O 0 0 0 0 0 O O O O O O O O O O O O O O O 0 0 0 0 0 O O () C C . (a U, O C >. 0 (D CO 6) N U) ao Q r O CO CO O) N UOD Q N- 0 CO CO 'a N U) CO V N- r •- aDaO CO- O? CD CD. O ' `- .- .- NNN CO MM V. .1.- ca NU) CP, O (Orp, a 0 EO °' m o D m m cD co n r r r r r r r r (� rr r r r (- r r r O U ) 0 )U 0 U 0 cn 3H-12 Well Summary DATE SUMMARY 7/2/11 ASSIST VLV CREW W/ PULLING BPV, REPLACE SOV @ 6559' RKB W/ DV, PERFORM PASSING MIT IA TO 2500 PSI, PULL CATCHER @ 6703' SLM. IN PROGRESS. 7/3/11 BAIL MUD OFF CA-2 PLUG @ 6723' RKB, PULL PRONG FROM PLUG, ATTEMPT TO PULL PLUG BODY. IN PROGRESS 7/4/11 PULL 2.75"CA-2 PLUG BODY @ 6723' RKB, TAG @ 6895' SLM, MEASURE BHP @ 6900' RKB, GRADIENT @ 6780' RKB. READY FOR E-LINE. 7/5/11 SHOT 2" HSC LOADED WITH 5' OF JRC BH 6.7g CHARGES 6 SPF 60 DEG PHASE. TOP SHOT @ 6705'. SHOT INTERVAL 6705'-6710'. LOGGED TUBING JEWELRY TO 200'. LRS FOLLOW UP INJECTION TEST: PUMPED 140 BBL DIESEL DOWN TUBING AT 1.5 BPM @ 2500 PSI. 7/9/11 RIH TO MILL NIPPLE, PLLUGGED TOOLS W/ROCKS, PIG CT, RETURN IN MORNING 7/10/11 RIH TO MILL NIPPLE, MILL FOR 8HRS, RAN OUT OF PIPE CYCLES, POOH TO CUT PIPE, IN PROGRESS 7/11/11 FINISH MILLING NIPPLE, RETOOL FOR FCO, HARD TAG @ 6878'CTMD, COULD NOT WASH THROUGH, POOH, IN PROGRESS 7/13/11 MILL OUT FILL FROM 6900'TO 7000' CTMD, CIRCULATE CLEAN, PREP FOR SQUEEZE, IN PROGRESS 7/14/11 HARD TAG @6878' CTMD, POSSIBLE CASING DAMAGE, CALL ENGINEER CALIPER REQUESTED,CONTACT SLICKLINE, IN PROGRESS 7/14/11 DRIFTED TBG/CSG WITH 5'x 2" BAILER. LOCATED TBG TAIL @ 6723' SLM, 6755' RKB. TAGGED @ 6969'SLM, EST. 7001' RKB. LOGGED CALIPER SURVEY f/—7000'TO 6250' RKB. RECOVERED GOOD DATA. COMPLETE. 7/26/11 Performed required weekly BOPE testing. Swapped out failed micro-motion (3-hr NPT). Attempted cement squeeze pumping 34-bbl of 17-ppg cement. Layed in cement from just above intitial tag at 7000' up to 3.5" tubing at 6507'with 1:1 returns prior to closing choke. Pumped remainder of cement with closed choke but squeeze pressure not obtained throughout. Pumped ball and ran back in from 4450' to 6966' pumping away all cement. Ordered out 30-bbl 17-ppg cement, as well as quantity of CemNET for minimum 15-bbl, for load and testing tonight, and pumping tomorrow. CTU and Cement Van remain rigged up on location for morning re-start. 7/27/11 ATTEMP TO SQUEEZE 33 BBL 17 PPG CMT WITH 1 LB PER BBL CEM NET FIBER ADDITVE, LAY CEMENT IN FROM 6970'TO 6500'ATTEMPED 1 SQUEEZE WITH NO RESULTS. PUSHED ALL CEMENT AWAY, POH TO 1500' PROBLEMS WITH INJECTOR, OUT HOLE, TRAP 1850 PSI WHP, FP, UNIT DN DUE TO INJ PROBLEMS, 4 HR NPT, 7/28/11 DRIFT TBG W/2.29". TAG TOC @ EST. 6966' RKB. ATTEMPTED INJECTION TEST, TBG PRESSURED UP TO 2250 PSI AFTER .02 BBLS. COMPLETE. 7/30/11 PERFORM CEMENT SQEEZE WITH 16.2 BBL 17 PPG NEAT CEMENT, RIH AND HRD TAG @ 6954 CTMD, CORRECTED DEPTH TO 6966 RKB, CONDITIONED WELL BORE WITH SW, LAYED IN 10 BBL CEMENT FROM 6966'TO 6705', SQUEEZED APPROX 4.2 BBL BEHIND PIPE, WASHED ALL REMAINING CEMENT TO SURFACE, WH FP, IN PROGRESS, 8/1/11 TAG TOC w/SAMPLE BAILER @ 6686' SLM, LOCATE X-NIPPLE w/X-LINE TOOL @ 6586'SLM, TAG TOC @ 6681' SLM, SET BPV w/VALVE CREW, RDMO ConocoPhillips Time Log & Summary We/Mew Web Reporting Report Well Name: 3H-12 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/2/2011 3:00:00 PM Rig Release: 8/28/2011 6:00:00 AM Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 08/02/2011 24 hr Summary Mobilized rig from 3H-10 to 3H-12.Accept rig at 15:00. MIRU Stabbed pipe, pumped slack management, cut 80'of coil. 04:00 15:00 11.00 MIRU MOVE MOB P Move rig from 3H-10 to 3H-12. Ru equip. 15:00 00:00 9.00 MIRU WHDBO NUND P Accept rig @ 15:00.Continue rigging up.Stab pipe,fluid pack coil with SW, pump slack management.Test &chart inner reel valve&stripper. Cut coil 80'of coil. 08/03/2011 Tested BOPE,test waived by John Crisp.Tagged TOC at 6710'MD. Swap well to Seawater W/2 PPB Biozan. Mill 2.80"pilot hole in cement from 6710 to tight spot @ 6843'MD. 00:00 09:00 9.00 MIRU WHDBO BOPE P Finish up cutting coil, rehead while starting BOPE test.Test waived by John Crisp. 09:00 11:00 2.00 MIRU WHDBO BOPE P Pull BPV 11:00 12:00 1.00 MIRU WHDBO BOPE P Pressure test PDI and tiger tank line to 2500 PSI 12:00 13:00 1.00 PROD1 WHPST PULD P MU milling BHA,strip on well to establish space-out for pressure deployment, 1.9'down from tag up. 13:00 14:48 1.80 0 6,530 PROD1 WHPST TRIP P RIH, displace wellbore fluids to tiger tank with seawater 14:48 16:00 1.20 6,530 6,710 PROD1 WHPST DLOG P Tie into GR,+30',tag cement at 6710'. PUH and log CCL to verify jewelry. 16:00 16:24 0.40 6,710 6,710 PROD1 WHPST TRIP P continue circulating well to biozan 16:24 21:15 4.86 6,710 6,808 PROD1 WHPST MILL P Start milling cement. 1.5 BPM, 3450 CTP, 3180 BHP,with WOC, 10.55 ECD. 21:15 23:45 2.50 6,808 6,843 PROD1 WHPST MILL P Stall @ 6808'. Down on pump, PUH @ 35k. Back on line,ease back down to 6808'1.5 BPM, 3450 CTP, 3294 BHP, 10.77 ECD. ROP 19. 23:45 23:59 0.24 6,843 6,843 PROD1 WHPST MILL P Stall @ 6843'. Down on the pump. Try again&stall again. 08/04/2011 Continued milling cement pilot hole @ 6843'.Slow milling from 6843'to 6848'with multiple stalls.Trip OOH for D331 mill with gauge cutters&adjust motor to.6. Mill at average ROP of.6 from 6848 to 6853. 00:00 01:30 1.50 6,843 6,847 PROD1 WHPST MILL P Working mill @ 6843'have several stalls.Make tool face changes...210/280/90/make it by @ 140 tool face. Ease back to 20 right. 1.5 BPM 3400 CTP.WOB @ 1.5, ROP @ 8.8 @ 6845'. Page 1 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:30 3.00 6,847 6,848 PROD1 WHPST MILL P Stall out @ 6847'. PU @ 35k. RBIH @ 20 right,went by 6843'with no problem.Stall again @ 6847.13. Change tool face to 150 R,stall again @ same depth.Try time drilling,still having muliple stalls. 04:30 05:30 1.00 6,848 6,848 PROD1 WHPST MILL P Continue time milling @ 6848.4 1.5 BPM,3400 CTP. 05:30 09:00 3.50 6,848 6,848 PROD1 WHPST MILL P Ream down at 6 FPH at 210 then 150 from 6840'to 6848' 09:00 10:54 1.90 6,848 0 PROD1 WHPST TRIP T POOH for mill and motor adjust 10:54 11:12 0.30 6,848 PROD1 WHPST SFTY P Flow check, PJSM 11:12 12:30 1.30 0 0 PROD1 WHPST PULD T Lay down motor and mill, mill came out 2.80 go/2.79 no-go. PU new 2.80"D331 mill with guage cutters 2.81 go/2.80"no-go. Adjust motor to.6 deg. 12:30 14:24 1.90 0 6,715 PROD1 WHPST TRIP T RIH 14:24 14:54 0.50 6,715 6,757 PROD1 WHPST DLOG T Tie in to K1, +14' 14:54 16:42 1.80 6,757 6,848 PROD1 WHPST MILL P Tag cement at 6848'. Ream up and down at 180,210 and 150 degrees at 1 FPM from 6838'to 6848' 16:42 22:00 5.30 6,848 6,853 PROD1 WHPST MILL P Milling cement, 1.5 BPM, 3050 CTP 22:00 00:00 2.00 6,853 6,853 PROD1 WHPST MILL P ROP @.6 Sample at the shakers showing 80%fine metal shavings. Discuss with engineer,geo,&DD. Keep a real close eye on samples for any changes. Continue Milling at 6853' 08/05/2011 Attempt to mill cement pilot hole, unable to get past tight spot @ 6853'. PU 2.80"craylola mill, ream up/down passes from 6830 to 6852 @ 210, 180,145, &240 TF @ 18 FPH. 00:00 01:00 1.00 6,853 6,854 PROD1 WHPST MILL P Milling @ 6853'. ROP @.3.TF @ 210 deg 1.5 BPM CTP 3200,WOB 2.73. 01:00 05:30 4.50 6,854 6,854 PROD1 WHPST MILL P Real slow going. Have had 8 stalls. Have to push to get by tight spots to get back to bottom. Samples are showing 50/50 metal shavings/cement. 05:30 08:42 3.20 6,854 6,854 PROD1 WHPST MILL P Ream up and down at 17 FPH, 150 TF 08:42 10:18 1.60 6,854 0 PROD1 WHPST TRIP T POOH' 10:18 10:42 0.40 0 0 PROD1 WHPST SFTY T Flow check, PJSM 10:42 12:45 2.05 0 0 PROD1 WHPST PULD T Lay down motor and mill,Mill came out 2.80 go/2.79 no-go. PU .6 deg motor and weatherford carbide crayola mill,2.80 go/2.79 no-go 12:45 14:15 1.50 0 6,725 PROD1 WHPST TRIP T RIH 14:15 14:30 0.25 6,725 6,755 PROD1 WHPST DLOG T Tie-in, +15' Page 2 of 20 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode TComment 14:30 00:00 9.50 6,854 6,840 PROD1 WHPST MILL T Tag bottom at 6855.8 with 2K WOB, PUH to 6853'and come online with pump at 1.5 BPM,3400 CTP, ream up and down at 210, 180, 145,&240 TF @ 18 FPH 08/06/2011 Mill cement pilot hole from 6854'to 6930'.TOOH for dummy whipstock drift. 00:00 00:45 0.75 6,840 6,852 PROD1 WHPST MILL T @ 6840', Continue reaming down @ 240 TF @ 18 FPH. 1.5 BPM 3068 CTP. 00:45 02:03 1.30 6,852 6,830 PROD1 WHPST MILL T Pass up,0 TF @ 18 FPH 02:03 03:48 1.75 6,830 0 PROD1 WHPST TRIP T Shut down pump. Open EDC, circulate POOH to surface 03:48 04:18 0.50 0 0 PROD1 WHPST SFTY P Flow check, PJSM. 04:18 05:18 1.00 0 0 PROD1 WHPST PULD T Swap out mills. lay down crayola mill (2.80 no go/2.79 go.PU D331 mill with side gauge cutters.Check out coil life @ 6850 area, 14% 05:18 07:06 1.80 0 6,725 PROD1 WHPST TRIP T RIH W/BHA#4, D331 mill w/side cutters. 07:06 07:24 0.30 6,725 6,853 PROD1 WHPST DLOG T Tie-in, +16',close EDC, 31K PUW, 14K RIW 07:24 10:30 3.10 6,853 6,866 PROD1 WHPST MILL P Tag at 6853.4'and start milling at 20 ROHS, 1.5 BPM,3200 CTP. Note: Looks like we accidentally exited the 7"casing at 6854'MD. 10:30 19:00 8.50 6,866 6,930 PROD1 WHPST MILL P Swap well to 10.3 flo-pro system, 1.4 BPM at 3700 freespin.Continue milling at 20 ROHS, 1.5 BPM 3660 CTP 19:00 20:00 1.00 6,930 6,737 PROD1 WHPST DLOG P PUH to 6823'. RIH @ min rate take surveys to bottom. PUH to 6737' 20:00 20:15 0.25 6,737 6,930 PROD1 WHPST TRIP P RIH,dry drift to bottom with no problems. 20:15 21:00 0.75 6,930 6,930 PROD1 WHPST DLOG P PUH to 6925',tie in for-2 correction. Run CCL log from 6763'to 6930' 21:00 23:00 2.00 6,930 0 PROD1 WHPST TRIP P TOOH to surface 23:00 23:45 0.75 0 0 PROD1 WHPST SFTY P No flow test&PJSM. Bleed down 20 psi, built back up to 300 PSI.repeat several times.Open choke,flowing at.1 for 5 minutes. Shut in SSSV, bleed down held at 0 psi. 23:45 00:00 0.25 0 0 PROD1 WHPST PULD P Undeploy BHA#4 08/07/2011 Cut 150'of coil. RU E-line, run GyroData log from 6600'to TD@ 6930'. Data sent to Inteq well planner in town. 00:00 05:00 5.00 0 0 PROD1 WHPST SLPC P Continue laying down BHA#4. Prep to cut coil. Reverse circulate for minor slack management prior to cutting coil. Cut coil, install CTC& pull test. Re-head Inteq&test. 05:00 07:00 2.00 0 0 PROD1 WHPST PULD P MU BHA#5, Dummy whipstock with USR 07:00 07:48 0.80 0 0 PROD1 WHPST TRIP T Tool shorted while RIH, PUH,shut in and flow check Page 3 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code ' Subcode T Comment 07:48 08:12 0.40 0 0 PROD1 WHPST SFTY T PJSM 08:12 11:12 3.00 0 0 PROD1 WHPST PULD T Pull injector off well and trouble shoot Inteq tools. Pulled out of e-line head. Rehead and PT. 11:12 15:30 4.30 0 0 PROD1 WHPST ELNE T MIRU HES e-line unit 15:30 16:00 0.50 0 0 PROD1 WHPST SFTY T PJSM with HES and Gyro-Data personnel 16:00 21:00 5.00 0 0 PROD1 WHPST ELNE T MU gyro-data tools and RIH with e-line. Log&tie in at 6600'down to 6930'W/CCL&gyro tool. POOH to surface. 21:00 23:00 2.00 0 0 PROD1 WHPST ELNE T E-line out of the hole. PJSM, RD E-line. 23:00 00:00 1.00 0 0 PROD1 WHPST PULD T PJSM. Decided not to run USR tool. Lay down BHA that was staged in the PDL. Re-configure BHA and pick up. 08/08/2011 Run whipstock dummy drift to 6890',window clean.Set anchored aluminum billet w/RA tag(10 deg LOHS) @ 6880'.Tagged TOB billet @ 6880.23',start time drilling for kick off. 00:00 02:15 2.25 0 0 PROD1 WHPST PULD P Continue picking up BHA#6. Dummy whip stock drift. PJSM for PD. Pressure deploy BHA#6 dummy drift. 02:15 02:30 0.25 0 0 PROD1 WHPST TRIP T Attempt to pump&RIH W/BHA#6. Unable to pump. Look at check list, suspect double valve ball valves are closed. 02:30 03:30 1.00 0 0 PROD1 WHPST PULD T PJSM. Undeploy to check out BHA, ball valves were closed. open ball valves and pressure deploy. 03:30 05:12 1.70 0 6,710 PROD1 WHPST TRIP P RIH W/BHA#6(dummy whipstock) 05:12 05:30 0.30 6,710 6,768 PROD1 RPEQP1DLOG P Tie-in, 05:30 06:30 1.00 6,768 6,750 PROD1 RPEQP1TRIP P Continue RIH,drift through window was clean with 1K WOB at 6867'and less than 1K at 6890'. PUH through "window"was clean. 06:30 08:12 1.70 6,750 0 PROD1 RPEQP1TRIP P POOH 08:12 09:42 1.50 0 0 PROD1 RPEQP1PULD P Undeploy BHA#6 09:42 11:00 1.30 0 0 PROD1 RPEQPI SVRG P Injector maintenence and rig service while waiting on BOT 11:00 12:30 1.50 0 0 PROD1 RPEQP1PULD P Deploy BHA#7,Anchored aluminum billet with RA. 12:30 14:06 1.60 0 6,715 PROD1 RPEQP1TRIP P RIH 14:06 14:18 0.20 6,715 6,767 PROD1 RPEQP1DLOG P Tie-in, +26' 14:18 14:42 0.40 6,767 6,891 PROD1 RPEQP1WPST P Close EDC, RIH 6891,stacked 5K, oriented to 10 deg. LOHS. pressure up to 4400 CTP to set. PUH at 28K 14:42 16:42 2.00 6,891 0 PROD1 RPEQP1TRIP P Close EDC, POOH 16:42 17:00 0.30 0 0 PROD1 RPEQP1SFTY P PJSM 17:00 18:00 1.00 0 0 PROD1 RPEQP1PULD P Undeploy billet running BHA Page 4 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:30 0.50 0 0 PROD1 DRILL SFTY P Change out&pressure deploy PJSM. 18:30 20:30 2.00 0 0 PROD1 DRILL PULD P Pick up BHA#8, pressure deploy. 20:30 22:30 2.00 0 6,710 PROD1 DRILL TRIP P RIH W/BHA#8 22:30 22:45 0.25 6,710 6,880 PROD1 DRILL DLOG P Tie in+18'correction, RIH tag billet @ 6880.39 22:45 00:00 1.25 6,880 6,881 PROD1 DRILL DRLG P Pick up,pump on line @ 1.44 BPM 3436 CTP FS.Start time drilling(1 FPH)@ 6879.60' 08/09/2011 Function tested BOPE.Kicked off billet @ 6880'. Drilled build to 7195'. Drilled ahead in 3H-12A to 7360'. 00:00 01:30 1.50 6,881 6,915 PROD1 DRILL DRLG P Continue kicking off the billet @ 6881' 1.42 BPM 3348 CTP Drill down to 6915'. 01:30 01:45 0.25 6,915 6,915 PROD1 DRILL WPRT P PUH up past billet,drift down, pumps at min, looks good. 01:45 05:54 4.15 6,915 7,060 PROD1 DRILL DRLG P Drill ahead 1.41 BPM 3500 CTP, ROP 30, BHP 3921 PSI. 05:54 06:12 0.30 7,060 6,725 PROD1 DRILL WPRT P Wiper to TT for tie-in,28K PUW 06:12 06:42 0.50 6,725 6,920 PROD1 DRILL DLOG P Tie-in to K1, +1', Log RA in billet at 6883' 06:42 06:54 0.20 6,920 7,060 PROD1 DRILL WPRT P Wiper back to bottom, 15K RIW 06:54 13:00 6.10 7,060 7,195 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3440 CTP,4000 BHP with WOC 13:00 14:54 1.90 7,195 0 PROD1 DRILL TRIP P End of build, POOH 14:54 15:12 0.30 0 0 PROD1 DRILL SFTY P PJSM 15:12 16:30 1.30 0 0 PROD1 DRILL PULD P Undeploy BHA#8 16:30 17:00 0.50 0 0 PROD1 DRILL BOPE P Function test BOP 17:00 19:00 2.00 0 0 PROD1 DRILL PULD P Deploy BHA#9 19:00 20:45 1.75 0 6,720 PROD1 DRILL TRIP P RIH W/Drilling BHA 20:45 20:54 0.15 6,720 6,768 PROD1 DRILL DLOG P Tie into K-1 +22.5 20:54 21:15 0.36 6,768 7,195 PROD1 DRILL TRIP P RIH to BTM 21:15 23:15 2.00 7,195 7,360 PROD1 DRILL DRLG P Drill ahead 1.40 BPM 3739 CTP. BHP @ 3900 PSI, ECD 12.52 23:15 23:59 0.74 7,360 6,900 PROD1 DRILL DLOG P PUH 26k off BTM. Mad pass from 7200'to 6870' 08/10/2011 Drilled ahead in lateral 3H-12A from 7360'to 8520. 00:00 00:15 0.25 6,900 6,870 PROD1 DRILL DLOG P Continue MAD pass to 6870'. 00:15 00:30 0.25 6,870 7,360 PROD1 DRILL TRIP P RBIH 00:30 02:00 1.50 7,360 7,510 PROD1 DRILL DRLG P Drill ahead. 1.5 BPM 3884 CTP BHP,3923 PSI, ECD 12.61 02:00 02:45 0.75 7,510 7,510 PROD1 DRILL WPRT P Wiper up to 6900'. RBIH 02:45 04:45 2.00 7,510 7,660 PROD1 DRILL DRLG P Drill ahead 1.5 BPM 3700 CTP, 3925 BHP, 12.62 ECD 04:45 05:00 0.25 7,660 6,900 PROD1 DRILL WPRT P Pull Wiper 05:00 05:12 0.20 6,900 6,930 PROD1 DRILL DLOG P Tie in,-3' Page 5 of 20 Time Logs Date From %To Dur S.Depth E. Death Phase Code Subcode T Comment 05:12 05:27 0.25 6,930 7,660 PROD1 DRILL WPRT P Wiper back in hole, 14K RIW 05:27 07:21 1.90 7,660 7,810 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM,3700 CTP,3985 BHP with WOC 07:21 08:27 1.10 7,810 7,810 PROD1 DRILL WPRT P Wiper to the billet,26K PUW 08:27 09:51 1.40 7,810 7,960 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM, 3750 CTP,3960 BHP with WOC 09:51 11:09 1.30 7,960 7,960 PROD1 DRILL WPRT P Wiper to billet,27K PUW 11:09 13:27 2.30 7,960 8,110 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM,3750 CTP,3980 BHP with WOC 13:27 14:21 0.90 8,110 6,900 PROD1 DRILL WPRT P Wiper to the billet,26K PUW 14:21 14:39 0.30 6,900 6,925 PROD1 DRILL DLOG P Tie-in, 14:39 15:09 0.50 6,925 8,110 PROD1 DRILL WPRT P Wiper back inhole, 14K RIW 15:09 17:27 2.30 8,110 8,260 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3750 CTP,4010 BHP with WOC 17:27 19:12 1.75 8,260 8,260 PROD1 DRILL WPRT P Pull wiper,27k off btm&smooth. wiper up to 6915'. RBIH 19:12 20:27 1.25 8,260 8,410 PROD1 DRILL DRLG P Drill ahead. 1.4 BPM 3839 CTP, 4028 BHP, 13.00 ECD 20:27 22:27 2.00 8,410 8,410 PROD1 DRILL WPRT P Pull wiper, RBIH to BTM. 22:27 00:00 1.55 8,410 8,520 PROD1 DRILL DRLG P Drill ahead 1.43 BPM 3900 CTM, BHP 4043 PSI, ECD 13.07 08/11/2011 Swap to 9.8 drilling mud. Drilled ahead to 9140' 00:00 00:15 0.25 8,520 8,540 PROD1 DRILL DRLG P Continue drilling to 8540' 00:15 01:30 1.25 8,540 6,930 PROD1 DRILL WPRT P Pull wiper,dirty trucks on location for mud swap. RBIH,Tie in for a-5 correction. 01:30 02:30 1.00 6,930 8,540 PROD1 DRILL TRIP P RBIH, Pump 5 bbls hi/lo vis sweep. Swap mud to 9.8 system.Time it to have new mud to the bit©TD. 02:30 04:30 2.00 8,540 8,621 PROD1 DRILL DRLG P Drill ahead.Still have old mud on backside. 1.41 BPM,4052 CTP, 4047 BHP.WHP 106. Get new mud all around.Open choke full open. 1.4 BPM 3981 CTP, BHP 4034, ECD 13.0. Harder drilling starting at -8615' 04:30 04:45 0.25 8,621 8,621 PROD1 DRILL WPRT P Short wiper up,27k off BTM. RBIH 04:45 06:24 1.65 8,621 8,690 PROD1 DRILL DRLG P Drill ahead. Slow ROP of 6.2.get w/ Geo. 1.40 BPM 3971 CTP, BHP 4059, ECD 13.09. @ 8625'ROP picked up to 48 FPH. 06:24 08:36 2.20 8,690 8,690 PROD1 DRILL WPRT P Wiper to billet, Circulating pressure is up about 100 psi, 1.4 BPM at 3900 CTP and freespin differential pressure is 520 PSI at the BHA. 26K PUW 08:36 11:18 2.70 8,690 8,840 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3850 CTP,4050 BHP with WOC 11:18 13:36 2.30 8,840 8,840 PROD1 DRILL WPRT P Wiper to the billet,27K PUW 13:36 16:30 2.91 8,840 8,981 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3850 CTP,4050 BHP with WOC Page 6 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T < Comment 16:30 19:15 2.75 8,981 8,981 PROD1 DRILL WPRT P Wiper to the billet,26K PUW RBIH, tie in for-7'correction. 19:15 21:45 2.50 8,981 9,140 PROD1 DRILL DRLG P Drill ahead 1.41 BPM,4041 CTP, BHP 4108, ECD 13.18 21:45 23:59 2.24 9,140 8,000 PROD1 DRILL WPRT P Wiper to billet,28k off BTM, RBIH 08/12/2011 Drilled ahead to TD @ 9535'. Pull wiper to swab valve.TIH back to TD, lay in liner beads up through cement pilot hole.Tag up, attempt to get SSSV to hold. 00:00 00:30 0.50 8,000 9,140 PROD1 DRILL WPRT P Continue RBIH from wiper trip. 00:30 02:45 2.25 9,140 9,291 PROD1 DRILL DRLG P Drill ahead 1.40 BPM,4135 CTP, BHP 4110, ECD 13.23 02:45 05:24 2.65 9,291 9,291 PROD1 DRILL WPRT P Pull wiper to the billet. RBIH. 05:24 08:00 2.60 9,291 9,440 PROD1 DRILL DRLG P Drill ahead, 1.4 BPM,3950 CTP, 08:00 09:54 1.90 9,440 6,900 PROD1 DRILL WPRT P Wiper to the billet 09:54 10:06 0.20 6,900 6,930 PROD1 DRILL DLOG P Tie-in, -11' 10:06 11:18 1.20 6,930 9,440 PROD1 DRILL WPRT P Wiper back in hole 11:18 13:12 1.90 9,440 9,535 PROD1 DRILL DRLG P Continue driling, 1.4 BPM,3850 CTP,4150 BHP. TD lateral. 13:12 16:54 3.70 9,535 0 PROD1 DRILL WPRT P Wiper to the swab valves, pumped low and high vis sweeps,26K PUW. Clean trip in open hole,clean past billet and through window. 16:54 20:30 3.60 0 9,535 PROD1 DRILL WPRT P Wiper back in hole. Send liner pill down in time to be at the bit @ TD. 20:30 23:30 3.00 9,535 0 PROD1 DRILL DISP P Tag TD, Liner beads at the bit, PUH laying beads up past window& cement pilot hole to-6432'TOOH to surface. All fluids 9.8 ppg. 23:30 00:00 0.50 0 0 PROD1 DRILL OWFF P Conduct pre job.Shut SSSV,watch for no flow. No good.Trouble shoot. 08/13/2011 Unable to SSSV to hold for liner run. RBIH&layed in 12.8 liner pill&KWF to surface.Attempt to run liner W/anchored billet but stacked out @ 8680'.Tripping out with liner assembly. 00:00 00:45 0.75 0 0 PROD1 DRILL OWFF T SSSV still not holding. Discuss options. 00:45 02:30 1.75 0 1,804 PROD1 DRILL TRIP T Pump MP while RIH to SSSV @ 1804'. Open ECD,wash acrossed SSSV.Check EDC location to ensure it's washing the valve.Wash valve numerous times-Pull up above valve. Dump SSSV again,bleed thru choke fast,WHP goes down but bounces back up. Repeat a couple time still no good. Estimate 6 bbls bleed back over all the SSSV tests. Call town.Get the 12.5 ppg KWF weighted up to 12.8 ppg. 02:30 04:30 2.00 1,804 6,400 PROD1 DRILL TRIP T RIH while mud is being weighted up. Have another liner bead pill made up as well. 04:30 07:06 2.60 6,400 7,100 PROD1 DRILL TRIP T Wait for liner pill and KWF 07:06 07:24 0.30 7,100 7,150 PROD1 DRILL DLOG T Tie-in to K1 marker Page 7 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:24 08:54 1.50 7,150 9,535 PROD1 DRILL TRIP T RIH to TD 08:54 11:54 3.00 9,535 0 PROD1 DRILL TRIP T Lay in 12.8 PPG liner pill and KWF to surface while POOH 11:54 12:18 0.40 0 0 PROD1 DRILL SFTY P PJSM for laying down drilling BHA, watch for no flow. All good. 12:18 13:18 1.00 0 0 PROD1 DRILL PULD P lay down drilling BHA 13:18 13:48 0.50 0 0 COMPZ CASING SVRG P Injector maintenence 13:48 14:18 0.50 0 0 COMPZ CASING SFTY P PJSM for liner operations 14:18 19:45 5.45 0 0 COMPZ CASING PUTB P RU for liner operations. MU liner,51 joints slotted with anchor billet attached. 19:45 22:15 2.50 0 8,680 COMPZ CASING RUNL P RIH W/liner&anchored billet. Get the anchor billet past the window with no problem.Seeing some swings in the open hole,stacked weight @ 8680'PU WT. @ 43k. Reluctant to work pipe down because of anchor billet attached. 22:15 00:00 1.75 8,680 5,500 COMPZ CASING RUNL T Prepare to POH. Having issues with the torque adjust on the panel.Slack off wt, able to get moving up-TOOH. Get EDC back up into the tubing but unable to open the EDC due the heavy weight below the BHA. Have to trickle in KWF down the backside to keep hole full. Note:A Call was made for the electrian&mechcanic to look at injector. 08/14/2011 Repaired injector drive shaft&replaced drive motor.(10 hours billable rig repair time)Set liner(lower section) @ 9235'top at 8530'. Picking up liner for upper section. 00:00 01:15 1.25 5,500 0 COMPZ CASING TRIP T Continue POOH to surface. 01:15 01:45 0.50 0 0 COMPZ CASING SFTY T PJSM,check for no flow. 01:45 03:00 1.25 0 0 COMPZ CASING PUTB T No flow at surface. Lay down BHA. Lay down Anchored billet&3 joints of liner. Install safety joint. 03:00 13:00 10.00 0 0 COMPZ CASING RGRP T Inspect injector for torque problem. Found drive shaft damaged. Make repairs. Changed out drive motor. *"'10 Hours billable rig repair time 13:00 13:30 0.50 0 0 COMPZ CASING PUTB T RU for liner operations 13:30 13:54 0.40 0 0 COMPZ CASING SFTY T PJSM 13:54 15:54 2.00 0 0 COMPZ CASING PUTB T Lay down 27 joints of liner,this will leave 21 joints,704'of liner and shoe 15:54 16:30 0.60 0 749 COMPZ CASING PUTB T MU BHA, injector to well Page 8 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 19:30 3.00 749 9,235 COMPZ CASING RUNL T RIH W/lower liner section, tie into K-1 for a+22.5'correction. continue RIH get past 9235'. PUH&get good PU WT. Stop @ 9235',short of TD as per decision from town. Up on pump, pump off liner,-10k, looks good. TOL=8530', BOL=9235'. 19:30 21:45 2.25 9,235 0 COMPZ CASING TRIP P TOOH to surface, keeping hole full. 21:45 22:15 0.50 0 0 COMPZ CASING SFTY P Tagged up. PJSM.Watch for flow. 22:15 00:00 1.75 0 0 COMPZ CASING PUTB P Well is dead. lay down BHA and start picking up liner, 21 jts. 08/15/2011 Set upper liner @ 8532', placing anchored billet @ 7821'.Test BOP,test waived by Chuck Sheve on 08-14-11 at 12:00.Started picking up kick off BHA. 00:00 01:15 1.25 0 772 COMPZ CASING PUTB P Continue picking up liner, BHA& Anchored billet. 01:15 03:30 2.25 772 8,533 COMPZ CASING RUNL P RIH W/liner run#2(BHA 12)stop @ flag.6772'on counter+27.62' correction.Weight check of 28.5k. RBIH, lower section top should be at 8530', orient to 165 deg.ease down, not seeing wt on bit until 8532.5'pick up to neural wt. Pump up Coil to 4200 psi,set anchor. Pick up 2'& re-tag stack 2k. Looks good. 03:30 06:00 2.50 8,533 0 COMPZ CASING TRIP P TOOH up past window. adjust bit depth.TOOH to surface circulating KWF. 06:00 06:30 0.50 0 0 COMPZ CASING SFTY P OOH,conduct PJSM and change out with day crew. 06:30 08:00 1.50 0 0 COMPZ CASING PULD P Get BOT tools broken off. Lay down BHA. 08:00 10:00 2.00 0 0 PROD2 DRILL SVRG P Grease tree,prep for BOP test 10:00 22:00 12.00 0 0 PROD2 DRILL BOPE P Start testing BOP. State witnessing waived by Chuck Sheve on 8-14-2011 at 12:00. 22:00 23:00 1.00 0 0 PROD2 DRILL RGRP P Service injector&fix leaky Koomy line. 23:00 00:00 1.00 0 0 PROD2 DRILL PULD P Pick up. BHA. Check out hole fill, pump.5 bbls to fill hole. 08/16/2011 Sidetrack AL3 lateral 7816'at 165 LOHS TF. Drill to 7994'.Orienter failure. POOH to swap out BHA's 00:00 00:30 0.50 0 0 PROD2 STK PULD P Continue picking up BHA. 00:30 02:30 2.00 0 6,830 PROD2 STK TRIP P RIH W/Kick off BHA#13,open EDC Send spacer and 9.8 drilling mud down coil to time out to bit for mud swap. 02:30 03:30 1.00 6,830 6,830 PROD2 STK CIRC P Have spacer close to the bit. Pump @.35 BPM 2000 psi CTP,4113 BHP, 13.44 ECD. Ease rate up to 1.25 BPM. Get 9.8 all around. Page 9 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 6,830 7,816 PROD2 STK TRIP P Continue RIH,tie in for+22.5 correction.Tag TOB @ 7816'Pick up 10'.Annular @ 4182 @.86 BPM W/ full open choke. PUH slowly to cir out KWF out of the open hole. getting 11.0 mud over the shakers, Annular tailing off 1.29 BPM 3700 CTP,4166 BHP. 05:00 09:30 4.50 7,816 7,821 PROD2 STK KOST P Time mill on billet 09:30 12:30 3.00 7,821 7,960 PROD2 DRILL DRLG P Drilling ahead 12:30 14:00 1.50 7,960 7,960 PROD2 DRILL WPRT P Wiper trip-26K 14:00 14:30 0.50 7,960 7,985 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,4100 psi, BHP 4097, ECD 13.1, ROP 70, WOB 1.7K,CT weight 9K,differential 700psi.7985'Having TF problems with BHA,keeps rolling to lowside on bottom.Tried locking it in on HS but still rolling:Possible magnetic interference. 14:30 15:30 1.00 7,985 7,985 PROD2 DRILL WPRT T P/U slowly to check end stops on BHA&pull above billet to stop& check Orientator comms.Tool tested fine with MWD. P/U weight check- clean. RIH to try drill again. 15:30 15:45 0.25 7,985 7,994 PROD2 DRILL DRLG P Drilling ahead-inititally no issues- 1.40 bpm,4000 psi, BHP 4108, ECD 13.2, ROP 90,WOB 1.4K.Once differential and WOB increased the TF started to fall to Lowside. 15:45 18:00 2.25 7,994 0 PROD2 DRILL TRIP T POOH for BHA swap. P/U weight 25K. 18:00 18:30 0.50 0 0 PROD2 DRILL SFTY T Crew change,At surface, PJSM 18:30 20:30 2.00 0 0 PROD2 DRILL PULD T Undeploy BHA 20:30 21:30 1.00 0 0 PROD2 DRILL PULD T Swap out complete BHA 21:30 23:00 1.50 0 0 PROD2 DRILL PULD T Deploy BHA 14. 23:00 00:00 1.00 72 PROD2 DRILL TRIP T RIH,taking returns to Tiger Tank to swap out mud 38/17/2011 CIO complete BHA. RIH,Swap out mud. Drill ahead AL3 lateral 7994'to 8547'. 00:00 00:30 0.50 5,000 6,720 PROD2 DRILL TRIP T RIH 00:30 00:45 0.25 6,720 6,720 PROD2 DRILL DLOG T Tie in depth+19'correction 00:45 01:06 0.35 6,720 6,850 PROD2 DRILL CIRC T Circ. new mud around 01:06 01:51 0.75 6,850 7,994 PROD2 DRILL TRIP T Close EDC RIH to drill, new to surface ***BHI back to billable rate***** 01:51 05:21 3.50 7,994 8,140 PROD2 DRILL DRLG P Orienter holding TF. Drill Ahead 3620 CTP, 3994 BHP, 11K CTW, 05:21 07:51 2.50 8,140 8,140 PROD2 DRILL WPRT P Wiper trip-P/U weight 27K.Town discussion on fault&formation. Page 10 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T` Comment 07:51 12:51 5.00 8,140 8,290 PROD2 DRILL DRLG P Drilling ahead-1.43 bpm, 3680, BHP 3995,WHP 150, ECD 12.8, ROP 55, WOB 1.8K,CT weight 9K. Hit slow ROP 8178'. Clay/shale in returns 12:51 14:36 1.75 8,290 8,290 PROD2 DRILL WPRT P Wiper trip-P/U weight 27K. 14:36 19:21 4.75 8,290 8,440 PROD2 DRILL DRLG P Drilling ahead-1.42 bpm,3800, BHP 4030, ROP 30,WHP 150, ECD 13, CT weight 8K. 19:21 20:51 1.50 8,440 8,440 PROD2 DRILL WPRT P Wiper trip to window,27K PUW 20:51 21:06 0.25 8,440 8,440 PROD2 DRILL DLOG P Tie in depth to RA marker-8' correction 21:06 22:21 1.25 8,440 8,440 PROD2 DRILL WPRT P RBIH to drill 22:21 00:00 1.65 8,440 8,547 PROD2 DRILL DRLG P Drilling ahead-1.42 bpm, 3800, BHP 4030, ROP 30,WHP 150, ECD 13, CT weight 8K. 08/18/2011 Drill AL3 Lateral. Perform mud swap. 00:00 00:45 0.75 8,547 8,590 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm, BHP 4030, WHP 150, ECD 13,CT weight 8K. 00:45 03:00 2.25 8,590 8,590 PROD2 DRILL WPRT P Wiper trip back to window,28K PUW 03:00 04:30 1.50 8,590 8,642 PROD2 DRILL DRLG P Drilling ahead-1.4 BPM, BHP 4058, ECD 13.07, CT weight 6-8K. 04:30 04:51 0.35 8,642 8,642 PROD2 DRILL WPRT P Pump high vis sweep.Once out bit, PU BHA wiper slow ROP,27K PUW 04:51 09:21 4.50 8,642 8,670 PROD2 DRILL DRLG P Drilling ahead-1.4 BPM, BHP 4079, ECD 13.1,CT weight-5K.Weight check of 27K. ROP 5fph. 09:21 13:21 4.00 8,670 8,740 PROD2 DRILL DRLG P Pump 60 bls of extra bromide mud with total of 4%of lubes.Small change in weight transfer-P/U weight 25K-clean to bottom. Drilling ahead-1.50 bpm, 3960, BHP 4080, ECD 13.1, ROP 15,WOB 2K, CT weight 1.1K. 13:21 15:51 2.50 8,740 8,740 PROD2 DRILL WPRT P Wiper trip-P/U weight 27K-Seen weight loss/bobbles through shale section @ 8680'-RIH to TD&wipe back through section. P/U 26K to 8600'.Very small weight bobble @ 8680' 15:51 17:30 1.65 8,740 8,790 PROD2 DRILL DRLG P Drilling ahead-1.50 bpm,4130, BHP 4111, ROP 15,WOB 2K,Ct weight 1K.-Set up for mud swap with 4% lubes&2%Klaystop. 17:30 18:30 1.00 8,790 8,819 PROD2 DRILL DRLG P New mud-1.50 bpm,4000, BHP 4070, ECD 13, ROP 80,WOB 1.7K, CT weight 11K,WHP 80 18:30 19:00 0.50 8,819 8,819 PROD2 DRILL WPRT P PU 28K PUW,geo wiper 19:00 20:00 1.00 8,819 8,890 PROD2 DRILL DRLG P Drilling ahead-1.50 bpm,4000, BHP 4080, 8K CTW,13.1 ECD, 130 WHP 20:00 22:36 2.60 8,890 8,890 PROD2 DRILL WPRT P Wiper trip to window 26K PUW 22:36 23:09 0.55 8,890 8,939 PROD2 DRILL DRLG P Drilling ahead-1.50 bpm,4000, BHP 4080, 8K CTW, 13.1 ECD, 130 WHP Page 11 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:09 00:00 0.85 8,939 9,010 PROD2 DRILL DRLG P PU weight check,26K. Drill ahead- 1.50 bpm,4000, BHP 4080,5-6K CTW, 13.1 ECD, 130 WHP, 08/19/2011 Drill AL3 lateral to TD 9532'. Pump low/high sweeps, POOH to swab valves. Small dimples in CT from 8600- 8350'. 00:00 00:30 0.50 9,010 9,040 PROD2 DRILL DRLG P Drill ahead-1.50 bpm,4000, BHP 4080,5-6K CTW, 13.1 ECD, 130 WHP 00:30 03:15 2.75 9,040 9,040 PROD2 DRILL WPRT P Wiper trip to window,26K PUW 03:15 06:00 2.75 9,040 9,190 PROD2 DRILL DRLG P Drill ahead-1.50 bpm,4000, BHP 4080, 5-6K CTW, 13.1 ECD, 130 WHP 06:00 08:30 2.50 9,190 6,765 PROD2 DRILL WPRT P Wiper trip-P/U weight 26K. Pull into cased hole. 08:30 09:00 0.50 6,765 6,765 PROD2 DRILL CIRC P Pull into cased hole and repair injector counter(BHI depth control) Open EDC and circulate. Open EDC 09:00 11:00 2.00 6,765 9,190 PROD2 DRILL TRIP P RIH-tie in to RA marker.-oft correction. RIH-noticed light marks on pipe from 8400'-8600'Looks like items stuck in gripper blocks during a wiper trip. 11:00 16:00 5.00 9,190 9,355 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,4110, BHP 4175, ECD13.2, ROP 60 WOB, 2.2K, Ct weight 4K. 16:00 19:30 3.50 9,355 9,355 PROD2 DRILL WPRT P Pump Low/high sweep-wiper trip 27K,Tie in depth to RA marker-1' correction 19:30 21:15 1.75 9,355 9,450 PROD2 DRILL DRLG P Drilling ahead-1.42 bpm,3950 CTP, BHP 4113, ECD13.2, Ct weight 4-5K. 21:15 22:45 1.50 9,450 9,488 PROD2 DRILL DRLG P Pump low high sweeps 10brls.Cont. Drilling ahead 22:45 23:15 0.50 9,488 9,488 PROD2 DRILL WPRT P Hard Stall 9488'.. PU pull heavy 35K. RBIH stacking out cannot get back to bottom. PUH to 9200'. RBIH to drill, Losing returns.25 BPM 23:15 23:45 0.50 9,488 9,532 PROD2 DRILL DRLG P Drilling ahead-1.42 bpm,4000 CTP, BHP 4100, ECD13.2,Ct weight 4-5K. Losses getting better. Losing .10 BPM 23:45 00:00 0.25 9,532 9,532 PROD2 DRILL DRLG P Pump 10bbrls low/high sweeps.TD AL3 Lateral. POOH to swab valves 27K PUW. 08/20/2011 Wiper trip to swab valves, RBIH lay in liner running pill(12.5ppg K-formate)with beads up to window. Completion KWF(12.5ppg K-formate)up to surface. PU/MU AL3 liner, RIH, unable to get liner past 9056'. Injector head unable to POOH. Diagnose problem. 00:00 03:45 3.75 9,532 0 PROD2 DRILL WPRT P POOH to swab valves 03:45 07:15 3.50 0 9,532 PROD2 DRILL TRIP P Tag up, Correct depth.-2.5' correction. RBIH.Started seeing 6- 8K weight loss&light set downs from 9200'to TD @ 9532' Page 12 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:15 08:15 1.00 9,532 8,500 PROD2 DRILL WPRT P P/U weight 28K-increase pump rate to 1.40 bpm,Wipe up 1000'to clean up lower section.Shakers cleaned up. 08:15 08:45 0.50 8,500 9,532 PROD2 DRILL WPRT P RIH-start pumping liner pill down. CT weight 10K. Slight weight bobbles near TD,cleaner than first pass. 08:45 11:45 3.00 9,532 71 PROD2 DRILL TRIP P POOH P/U weight 29K-laying in KWF liner pill followed by KWF. EOP flags 7200'&4500'.Good KWF around at 1000'from surface. 11:45 12:15 0.50 71 71 PROD2 DRILL SFTY P PJSM for laying down BHA-flow check of well. 12:15 13:15 1.00 71 0 PROD2 DRILL PULD P Lay down BHA. Bi-center bit Different serial number than on BHI spreadsheet. 13:15 14:45 1.50 0 0 COMPZ CASING RGRP P Top up the well with 1/2 bbl. Set up rig floor, Service Top drive&injector 14:45 17:15 2.50 0 2,145 COMPZ CASING PUTB P PJSM for P/U liner. P/U 25 jnts slotted,2 solid, 38 slotted with Liner top billet.Safety joint drill. 17:15 18:00 0.75 2,145 2,145 COMPZ CASING PULD P P/U BHA 18:00 18:30 0.50 2,145 2,145 COMPZ CASING SFTY P MU safety joint.Crew Change, PJSM 18:30 19:30 1.00 2,145 2,145 COMPZ CASING PULD P MU BHA to liner and CT 19:30 20:30 1.00 2,145 6,706 COMPZ CASING RUNL P RIH 20:30 20:45 0.25 6,706 6,725 COMPZ CASING RUNL P Correct depth to EOP flag. 18' Correction. Record up and down weights.28K up, RIH 16K.Cont. RIH. 20:45 22:30 1.75 6,725 8,782 COMPZ CASING RUNL P 50 FPM,Stack out 8782'-10K CTW, 9K WOB, PU 50K CTW,-15K WOB, RIH 35,20 FPM. Unable to get down. PU RIH 60FPM.Stack out 8860'. PU 46K CTW,20K WOB. Stack out 8874', PU 100'. RIH 65 FPM,Stack out 8912. PU RIH 60-70 FPM Stack out 8923', 8943,9010, 9038,9044,9050, 9056. 22:30 00:00 1.50 9,056 9,056 COMPZ CASING RUNL P Injector unable to POOH. Look into problem 08/21/2011 Repair drive shaft on injector head.Attempt to pull liner out of hole, Unsuccessful. Disconnect off liner POOH. BOL=9049.68.TOL=6868.17.At surface inspect injector head. Pull test to 60K. Cut 200'CT. 00:00 06:00 6.00 9,056 9,050 COMPZ CASING RUNL T Diagnose Injector problem. Continous pumping across the top with KWF to keep the hole full.Total of 5 bbls losses since 23:00 hrs. Page 13 of 20 Time Logs, Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 9,050 9,050 COMPZ CASING RUNL T Continue troubleshooting Injector Pulling problems.The head will not hold a P/U weight of 20K or over, then the chains free-spin(release). Liner=TD 9050' Bottom of solid=8211' Top of Solid=8151' Top of billet=6868' EOP=6824' TOW=6850 BOW=6854 Anc Billet=6880' 07:00 11:00 4.00 9,050 9,050 COMPZ CASING RUNL T Injector problems is the front right angle drive motor shaft is sheared. The back one is fine(this is the one that was changed out two weeks ago). 11:00 12:00 1.00 9,050 9,053 COMPZ CASING RUNL T Set to move pipe to check liner movement&test injector-Free point 29K 9048'-Max. P/U 44K(-13K on BHA-9045')-RIH Max push 10K WOB(9053') Liner not moving-Down max-9053' (WOB 10K) Up CTweight 48K(WOB-16.5K) depth 9045' Nuetral string weight depth=9048' (WOB 0) Conference call to town. Liner not moving and max.weight on BHA. 12:00 13:00 1.00 9,053 6,720 COMPZ CASING TRIP T Decision to release liner-RIH downweight 4K. Increase pump rate to 1.2 bpm. Release the liner-P/U 27K.Tie in @ 6720'-6ft correction. RIH&tag TOL to ensure depth. ***Nabors back on billable time*** 13:00 15:30 2.50 6,720 62 COMPZ CASING TRIP T TOL 6862'-9044'BOL-POOH slowly monitoring injector. 15:30 16:00 0.50 62 62 COMPZ CASING SFTY T PJSM for laying down BHA-conduct no-flow test.46 bbls of formate lost to formation for liner run. 16:00 17:00 1.00 0 0 COMPZ CASING PULD T Lay down BHA&close swab valves. 17:00 17:30 0.50 0 0 COMPZ CASING BOPE P Weekly function test of BOPE stack. 17:30 18:00 0.50 0 0 COMPZ CASING CTOP T Remove BHI upper quick, install pull test plate. Pull test injector to 60K 18:00 18:30 0.50 0 0 COMPZ CASING CTOP T Set up to cut 200ft of coil. 18:30 19:30 1.00 0 0 COMPZ CASING CTOP P Cut 200'CT 19:30 20:30 1.00 0 0 COMPZ CASING CTOP P MU CT drilling head 20:30 20:45 0.25 0 0 COMPZ CASING CTOP P Pull test connector 35K 20:45 21:15 0.50 0 0 COMPZ CASING CTOP P Pressure test connector 4100psi, finish heading up drilling head. Change stripper rubber Page 14 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:15 22:30 1.25 0 0 PROD3 STK PULD P PU/MU BHA 16(2.4 AKO) 22:30 00:00 1.50 62 6,000 PROD3 STK TRIP P RIH 08/22/2011 PU/MU/RIH BHA 16(2.4 AKO w/o USR). Swap well back to drilling mud. KOTB 6862'.Swap out drilling mud. Drill AL1 lateral build section to 7250'. POOH. Undeploy BHA 16, Deploy BHA 17 00:00 00:15 0.25 6,000 6,725 PROD3 STK TRIP P Tie in depth+13'correction 00:15 02:15 2.00 6,725 6,750 PROD3 STK DISP P Displace KWF OOH. Unable to get returns. PUH to 6625'.Spacer pill start exiting EDC. Start to get returns. RIH slowly to 6750'. Displace to FP 90 bbrls of KWF lost to formation. 02:15 02:24 0.15 6,750 6,861 PROD3 STK TRIP P Close EDC. RIH dry tag TOB 02:24 02:33 0.15 6,861 6,861 PROD3 STK KOST P Tag TOB no pumps 6861.98'PU 25K PUW 02:33 03:18 0.75 6,861 6,862 PROD3 STK KOST P Start milling 1 FPH 6861.29'1.37 BPM in, 1.25 BPM out,3282 CTP, 3805 BHP, 15K CTW, 1.6K WOB, 12.3 ECD,wide open choke. .10 BPM losses 03:18 04:18 1.00 6,862 6,863 PROD3 STK KOST P Start to get aluminum in cuttings 6861.89'Cont milling 1 FPH 04:18 04:33 0.25 6,863 6,894 PROD3 STK KOST P Increase ROP 2 FPH, .27K WOB, 3323 CTP,3830 BHP, 1.36 BPM in, 1.27 out 04:33 04:48 0.25 6,894 6,865 PROD3 STK KOST P Increase ROP 3 FPH, .52K WOB, 3323 CTP,3830 BHP, 1.36 BPM in, 1.27 out. Blow down MP choke of aluminum. 04:48 05:03 0.25 6,865 6,866 PROD3 STK KOST P Increase ROP 5 FPH, .80K WOB, 3378 CTP,3834 BHP, 1.35in, 1.30 out. 05:03 05:24 0.35 6,866 6,869 PROD3 STK KOST P Increase to 10 FPH.Stack 2.5K WOB, No motor work.Shut down pumps,trap pressure, PU 26K PUW. RIH dry tag at 6865.5'. PU 26K, online with pumps. RIH.start to see WOB w/o motor work 6865.3'. 05:24 07:54 2.50 6,869 6,736 PROD3 STK KOST P P/U into cased hole and open EDC- dispace vac truck to swap mud. Discuss with town plan forward.Vac truck arrived on location 07:54 08:54 1.00 6,736 6,869 PROD3 STK KOST P Start pumping new mud-new mud at bit trap pressure&close EDC. RIH to TOW min. rate.Offline until 6858' 6857'-WOB 1.4K TF 210 ROHS 6858-WOB.6K TF 280 ROHS- bring pumps up to min. rate 6859'-increase pump rate to 1.35 bpm,WOB zero. RIH Slowly(50fph) 6866'WOB 1.2K No motor work, WOB dropped off to zero 6866.5' 6869.3'motor work-Start milling at 10 fph. Page 15 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T` Comment 08:54 09:54 1.00 6,869 6,898 PROD3 STK KOST P Milling 10 fph, 1.35 bpm, 3460, BHP 3860, ECD 12.6,WHP 160,CT weight 15K,WOB 1.5K-Good formation cuttings to surface-no Al. shavings. KOTB-drill additional 20 ft. 09:54 10:24 0.50 6,898 6,898 PROD3 STK KOST P P/U weight 23K.WOB-0.6K off bottom. into cased hole. Slow to min. rate @ 6870' WOB-0.6K Slight weight drags @ 6867',6864'( geometry binding) Slight increase in pressure @ 6856' Clean up to 6830'-RIH pumps off @ 10 fpm.-SLight weight bobbles near window exit. 10:24 15:54 5.50 6,898 7,160 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,3530, BHP 3930, ECD 12.6,WHP 130,WOB 1.8K, ROP 20,Ct weight 15K.A few difficult TF reactions when first drilling but smoothed out after 20 ft. 15:54 16:24 0.50 7,160 7,160 PROD3 DRILL WPRT P Wiper trip-P/U weigth 28K-Clean up to billet. RIH. 16:24 17:54 1.50 7,160 7,250 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,3540, BHP 3930, ECD 12.6, ROP 70,WOB 1.6K,Ct weight 14K. 17:54 20:09 2.25 7,250 7,250 PROD3 DRILL TRIP P TD build. POOH 20:09 20:24 0.25 7,250 0 PROD3 DRILL SFTY P At surface. PJSM 20:24 21:39 1.25 0 0 PROD3 DRILL PULD P Undeploy BHA.Tag up pulling BHA above swabs with high AKO bend. (2.4 AKO).Close bag to centralize BHA.Open bag, PUH with SL slowly, until BHA is above swabs. 21:39 23:39 2.00 0 0 PROD3 DRILL PULD P MU new BHA, (USR, 1 deg AKO w/ B7 Bi-center) 23:39 00:00 0.35 0 0 PROD3 DRILL PULD P Deploy BHA 17 X8/23/2011 Drilled AU lateral to TD at 7710' 00:00 01:30 1.50 72 6,725 PROD3 DRILL TRIP P RIH 01:30 01:45 0.25 6,725 6,725 PROD3 DRILL DLOG P Tie in depth to K1. +12'correction 01:45 02:30 0.75 6,725 7,250 PROD3 DRILL TRIP P RIH to drill,small weight bobble going through window due to TF orientation of window vs.TOB KO. Cont. RIH log RA markers to assure which to use on wuiper trip tie in. Did see the RA marker in#1 billet. Formation marker for tie in 6813' picked up.Cont. RIH 02:30 04:30 2.00 7,250 7,410 PROD3 DRILL DRLG P Drill Ahead 1.4 in, 13K CTW,3517 CTP, 3912 BHP, 12.5 ECD. 04:30 05:30 1.00 7,410 7,410 PROD3 DRILL WPRT P Wiper trip-P/U 26K.MADD pass 7260-6940'. 05:30 08:00 2.50 7,410 7,560 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm, 3870, BHP4000, ECD 12.8, ROP 60,WON 1.8K,Ct weight 14K. Page 16 of 20 Time Logs Date From 'To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:00 10:15 2.25 7,560 7,560 PROD3 DRILL WPRT P Wiper trip-P/U weight 27K. 10:15 11:15 1.00 7,560 7,710 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM,3835 CTP, 4000BHP, 11-12K CTW, 12.8 ECD. wide open choke 11:15 12:45 1.50 7,710 6,750 PROD3 DRILL WPRT P TD lateral PU 100'26K. RBIH pumping low/high 10/10 out CT, Chase pills to window. 12:45 13:00 0.25 6,750 6,750 PROD3 DRILL DLOG P PU into casing.Tie in depth to K1 marker-2'.Talk with town on next operation. 13:00 15:00 2.00 6,750 0 PROD3 DRILL WPRT P POOH to swab valves 15:00 18:00 3.00 0 7,710 PROD3 DRILL WPRT P RBIH, no increase amount of cuttings at surface.Cuttings continued over shakers while RIH down to window. 18:00 20:42 2.70 7,710 0 PROD3 DRILL WPRT P POOH laying in liner pill and KWF, paint EOP flags at 7200 and 6300' 20:42 21:12 0.50 0 0 PROD3 DRILL SFTY P PJSM,check for no-flow 21:12 22:06 0.90 0 0 PROD3 DRILL PULD P Lay down drilling BHA 22:06 00:00 1.90 0 COMPZ CASING PUTB P PU liner string with anchored aluminum billet 08/24/2011 Ran liner in AL1 lateral and set anchored liner top billet at 7350'. Drilled off billet and continued drilling AL2 lateral. 00:00 01:48 1.80 421 6,721 COMPZ CASING RUNL P RIH with liner 01:48 02:30 0.70 6,721 7,710 COMPZ CASING RUNL P Correct to flag,+13',27K PUW, 18 K RIW, close EDC and continue RIH 02:30 04:30 2.00 7,710 0 COMPZ CASING RUNL P Set anchor at 340 deg orientation, 3900 psi to set. Liner top at 7350'. POOH 04:30 04:48 0.30 0 COMPZ CASING SFTY P PJSM,check for no-flow 04:48 05:48 1.00 0 0 COMPZ CASING PUTB P Lay down liner running BHA 05:48 06:18 0.50 0 0 PROD4 STK SFTY P Crew change, PJSM 06:18 06:48 0.50 0 0 PROD4 STK PULD P PUMU BHA 19(.8 AKO 12deg DLS). 06:48 08:48 2.00 72 6,730 PROD4 STK TRIP P RIH 08:48 09:03 0.25 6,730 6,743 PROD4 STK DLOG P Tie in depth+13'correction 09:03 10:33 1.50 6,743 6,743 PROD4 STK DISP P Circulate well to Flo-Pro 10:33 10:48 0.25 6,743 7,349 PROD4 STK TRIP P New mud to surface, RIH to ST AL2 Lateral 10:48 11:33 0.75 7,349 7,349 PROD4 STK TRIP P Dry tag TOB 7349.81'. PU 26K 11:33 13:18 1.75 7,349 7,351 PROD4 STK KOST P ST AL2 Lateral setting auto driller to .5 FPH increasing to 1 FPH 3300 CTP, 120 MP choke, 16K CTW, 1.3 in, 1.3 out Large amount of aluminum across shakers 13:18 13:48 0.50 7,351 7,352 PROD4 STK KOST P Increase ROP 2 FPH 3350 CTP, 150 MP choke, 15K CTW, 1.4 BPM in, 1.4 BPM out. Page 17 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:48 14:18 0.50 7,352 7,353 PROD4 STK KOST P Increase ROP to 3 FPH 3350 CTP, 150 MP choke, 15K CTW, 1.4 BPM in, 1.4 BPM out. 14:18 14:45 0.45 7,353 7,358 PROD4 STK KOST P Increase ROP 10 FPH 3350 CTP, 150 MP choke, 15K CTW, 1.4 BPM in, 1.4 BPM out. 14:45 15:15 0.50 7,358 7,375 PROD4 STK KOST P Increase ROP to 25 FPH 15:15 15:24 0.15 7,375 7,385 PROD4 STK KOST P Increase ROP to Drilling rate 15:24 15:36 0.20 7,385 7,385 PROD4 STK KOST P PU drift ST.24K PUW. Drift looks good. RIH to drill 15:36 18:06 2.50 7,385 7,510 PROD4 DRILL DRLG P Drill Ahead 14K CTW,3384 CTP, 125 MP choke, 12.6 ECD, 1.4 BPM. 18:06 18:48 0.70 7,510 7,510 PROD4 DRILL WPRT P Wiper to the window,24K PUW, 14K RIW 18:48 20:36 1.80 7,510 7,660 PROD4 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP,3965 BHP, 150 WHP. Increase rate to 1.6 BPM,3800 CTP, 3950 BHP, 100 WHP 20:36 21:30 0.90 7,660 7,660 PROD4 DRILL WPRT P Wiper to the window,24K PUW, 14K RIW 21:30 22:54 1.40 7,660 7,810 PROD4 DRILL DRLG P Continue drilling, 1.6 BPM, 3770 CTP, 3970 BHP, 100 WHP 22:54 23:36 0.70 7,810 6,930 PROD4 DRILL WPRT P Wiper to the window,24K PUW 23:36 23:42 0.10 6,930 6,950 PROD4 DRILL DLOG P Tie-in, -1' 23:42 00:00 0.30 6,950 7,810 PROD4 DRILL WPRT P Wiper back in hole, 15K RIW 08/25/2011 Drilled to TD at 8454'and killed well with 12.5 PPG KWF 00:00 01:48 1.80 7,810 7,960 PROD4 DRILL DRLG P Continue drilling AL2 lateral, 1.6 BPM, 3800 CTP,4000 BHP,80 WHP 01:48 03:00 1.20 7,960 7,960 PROD4 DRILL WPRT P Wiper to the window,25K PUW 03:00 05:45 2.75 7,960 8,140 PROD4 DRILL DRLG P Continue drilling, 1.6 BPM, 3800 CTP,4000 BHP,WOC 05:45 07:15 1.50 8,140 8,140 PROD4 DRILL WPRT P Wiper trip to window 26K PUW 07:15 09:30 2.25 8,140 8,290 PROD4 DRILL DRLG P Cont. Drilling 11K CTW, 1.5K WOB, 3771 CTP,4022 BHP 09:30 11:15 1.75 8,290 8,290 PROD4 DRILL WPRT P Wiper trip to window,26K PUW 11:15 14:00 2.75 8,290 8,410 PROD4 DRILL DRLG P Cont. Drilling 11K CTW, 1.5K WOB, 3771 CTP,4022 BHP 14:00 14:15 0.25 8,410 8,455 PROD4 DRILL DRLG P Pump low/high sweeps 14:15 17:15 3.00 8,455 0 PROD4 DRILL WPRT P TD AL2 lateral. POOH to swab valves chasing sweeps 17:15 20:30 3.25 0 8,454 PROD4 DRILL WPRT P RBIH 20:30 23:00 2.50 8,454 0 PROD4 DRILL DISP P Lay in liner pill and KWF 23:00 23:42 0.70 0 0 PROD4 DRILL PULD P Lay down drilling BHA 23:42 00:00 0.30 0 0 PROD4 DRILL SFTY P PJSM,check for no-flow 38/26/2011 Ran liner in AL2. Liner top at surface??? 00:00 00:18 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations Page 18 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:18 02:30 2.20 0 1,183 COMPZ CASING PUTB P Rig up for liner operations and PU 34 joints slotted liner 02:30 04:42 2.20 1,183 8,458 COMPZ CASING RUNL P RIH,correct depth at flag,6767.4 to 6782.91, 15.5'correction. 28K PUW, 16K RIW,-3.7 WOB. Tag bottom,pump at 1.2 BPM,4000 CTP, release liner. 04:42 07:12 2.50 8,458 0 COMPZ CASING RUNL P POOH 07:12 08:57 1.75 0 0 COMPZ CASING PUTB P Flow check, PJSM, LD BHA 08:57 10:57 2.00 0 0 COMPZ CASING PUTB P PJSM, RU for liner Ops. PU 14jnts slotted,4 joints solid,with Baker Seal Bore Assembly. 10:57 12:57 2.00 658 6,800 COMPZ CASING RUNL P RIH 12:57 13:12 0.25 6,800 7,315 COMPZ CASING RUNL P Tie in depth to EOP flag. +12.6' correction.28.5K PUW. RIH,2nd EOP flag, no correction. 13:12 13:57 0.75 0 6,688 COMPZ CASING RUNL P Tag TOL#1, Pump off liner 3500psi , 29K PUW.0 WOB.Open EDC, remove liner length from bit depth. TOL=7315 13:57 15:42 1.75 6,688 6,688 COMPZ CASING DISP P Circulate well to Seawater 15:42 17:54 2.20 6,688 0 COMPZ CASING RUNL P POOH,freeze protect well 2100'MD to surface 17:54 18:30 0.60 0 0 COMPZ CASING SFTY P PJSM for undeploy BHA,Crew change 18:30 19:12 0.70 0 0 COMPZ CASING PUTB P Undeploy BHA, 1400 WHP 19:12 23:30 4.30 0 0 COMPZ CASING PUTB T Slick line parted when opening deployment rams,(After further investigation it was determined that the liner string was still attached) toolstring dropped to no-go. Changed out PDL. Unable to move BHA,while working slickline on second PDL line parted again. Attempted to close SSSV which did not work 23:30 00:00 0.50 0 0 COMPZ CASING PUTB T Load pits to kill well 08/27/2011 Ran liner,displace well to seawater and diesel freeze protect 00:00 01:30 1.50 0 0 COMPZ CASING CIRC T Bullhead 12.5 ppg KWF, 100 Bbls. Well is dead. 01:30 01:42 0.20 0 0 COMPZ CASING SFTY T PJSM 01:42 04:18 2.60 0 658 COMPZ CASING PUTB T Remove PDL, PU BHA, liner sting is still there... Call out for another GS from BOT The nose of the GS was getting wedged inside the seal bore on the deployment sleeve. Ground down the nse to allow clearence inside sealbore 04:18 04:36 0.30 658 658 COMPZ CASING SFTY T PJSM 04:36 05:06 0.50 658 658 COMPZ CASING PUTB T PU liner running BHA. Page 19 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:06 05:36 0.50 658 658 COMPZ CASING CIRC T Circulate coil to KWF 05:36 07:36 2.00 658 6,758 COMPZ CASING RUNL T RIH 07:36 07:51 0.25 6,758 6,759 COMPZ CASING RUNL T Tie in depth to EOP flag.+11' correction.Close EDC,Weight check.28K PUW. DHWOB-3.7K, change DHWOB to-2.34K weight of liner. RIH 18K RIHW,-1.6K DHWOB while RIH 07:51 08:03 0.20 6,759 7,315 COMPZ CASING RUNL T RIH to TOL#1, in open hole, 0 K DHWOB, 16K CTW 08:03 08:09 0.10 7,315 7,315 COMPZ CASING RUNL T Tag TOL#1 @ 7315.69'. 16K CTW, 2.2K DHWOB. 08:09 08:24 0.25 7,315 6,700 COMPZ CASING RUNL T Release off liner,4300 CTP,28K PUW. DHWOB 0. PU 50',28K PUW, DHWOB 0. RIH, RIHW 18K, OK DHWOB. Liner released.Open EDC.Circ. across top to minimize losses. 08:24 09:24 1.00 6,700 2,200 COMPZ CASING RUNL T POOH 09:24 09:39 0.25 2,200 2,200 COMPZ CASING OWFF T Stop flow check well 09:39 10:39 1.00 2,200 0 COMPZ CASING RUNL T Cont. POOH 10:39 10:54 0.25 0 0 COMPZ CASING OWFF T At surface,flow check. PJSM, 10:54 11:24 0.50 0 0 COMPZ CASING PULD T LD BHA, Liner gone 11:24 11:54 0.50 0 0 COMPZ CASING PULD T PU BHA 23, Nozzle run 11:54 13:54 2.00 22 6,600 COMPZ CASING TRIP T RIH 13:54 14:54 1.00 6,600 2,150 COMPZ CASING TRIP T POOH displacing well to seawater 14:54 15:24 0.50 2,150 2,150 COMPZ CASING TRIP T Wait on LRS for freeze protect 15:24 15:54 0.50 2,150 2,150 COMPZ CASING FRZP T RU LRS 15:54 16:24 0.50 2,150 0 COMPZ CASING FRZP T POOH 16:24 16:39 0.25 0 0 COMPZ CASING SFTY T At Surface. PJSM 16:39 18:00 1.35 0 0 COMPZ CASING PULD T LD Tools, 18:00 18:24 0.40 0 0 DEMOB WHDBO SFTY P PJSM, crew change out 18:24 23:12 4.80 0 0 DEMOB WHDBO NUND P RU and set BPV. After roofing the seal three times,went for a different plg and got a good set. 23:12 00:00 0.80 0 DEMOB WHDBO CIRC P Circulate corrosion inhibitor through coil and surface equipment 08/28/2011 Circulate corrosion inhibitor in coiled tubing and rig down for move, rig released at 06:00 00:00 01:24 1.40 DEMOB WHDBO CIRC P Continue circulating corrosion inhibitor through coiled tubing and surface equipment 01:24 02:54 1.50 DEMOB WHDBO DMOB P Blow down coiled tubing and rig 02:54 04:24 1.50 DEMOB WHDBO DMOB P Unstab CT from injector for injector maintenance. 04:24 06:00 1.60 DEMOB WHDBO DMOB P RDMO, Rig Released at 0600 Page 20 of 20 Letter of Transmittal rdi1111 BAKER August ICI, 2ol l HUGHES To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3H-12A 3H-12APB1 3H-12AL1 3H-12AL2 3H-12AL3 (5) 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 inP lace of return mail. Sachin Gandra, Baker Hughes Operations Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes Survey Manager Carl.Ulrich@BakerHughes.com ITAla tnizu ind„ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gnatt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-12AL1 ConocoPhillips Alaska, Inc. Permit No: 211-082 (revised) Surface Location: 1207' FNL, 281' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 406' FSL, 431' FWL, SEC. 1, T12N, R8E, UM Dear Mr. Gnatt: 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 3H-12A, Permit No 211- 081, API 50-103-20088-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. S f Chair DATED thisl day of August, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 e i;;,-v la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑✓ • Single Zone ❑✓ . lc.Specify if well is proposed for: Drill ❑ Re-drill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 3H-12AL1 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9510'• TVDSS: 5961' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1207'FNL,281'FWL,Sec. 12,T12N,R8E, UM . ADL 25531 , Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1561'FSL,913'FWL,Sec. 1,T12N, R8E, UM • 2657 , 8/21/2011 Total Depth: 9.Acres in Property: 14.Distance to 406'FSL,431'FWL,Sec. 1,T12N,R8E,UM 2560 - Nearest Property: 6350' , 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 76 feet 15.Distance to Nearest Well Open Surface:x- 498655 y- 6000451- Zone- 4 GL Elevation above MSL: 40 feet to Same Pool: 3H-10B,1000' 16.Deviated wells: Kickoff depth: 6862 - ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 94° - deg Downhole:3205 psig . Surface:2615 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) RECE 3" 2.325" 4.7# L-80 ST-L 1450' 7300' 5995' 9510' 5961' slotted lirtgr, �i HU(1Z4 2011 kd.0u&baa C°ac Co 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operation h�{ ff�� /Iflir//SS/Qn Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Ju�nKieaatked) 7298' 6373 7144' 6249' 7030', 7032', 7036' Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 245 sx AS I 115' 115' Surface 3069' 9.625" 1300 sx AS III,400 sx Class G, 3104' 2986' Intermediate top job 90 sx AS I Production 7190' 7" 320 sx Class G, 175 sx AS I 7225' 6314' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 6832'-6846',6880'-6890',6904'-6914',6934'-6954' 5998'-6009',6037'-6045',6056-6064',6080'-6096' 20.Attachments: Property Plat❑ BOP Sketch❑✓ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 2 21.Verbal Approval: Commission Representative: Guy Schwartz Date: 8/22/2011 Cd.fl 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 /..f 0'I Printed Name AAA�L.�Gantt Title CTD Engineering Supervisor / "(�Signature w . ie -q i 1/�1 Phon 263-4021 Date /Z3/,/ Commission Use Only Permit to Drill1 API Number: y/ /� Permit Approv I See cover letter Number: 2_1 I • r! 50-/ ' L V ��l'' Date: I ', 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: RIF 3Sao r s'- 2OP 7 CI Samples req'd: Yes No L� Mud log req'd: Yes ❑ No Other: A-2.,S210 /lye -12-; e- 1 H2S measures: Yes Ts/No ❑ Directional svy req'd: Yes M.7- No I]�1 _ O r it) i 41.4 . 51�'P ! j,, / • , APPROVED BY THE COMMISSION 3I // DATE: vi re i r ,•••• ,COMMISSIONER Form 10-401 (Revised 7/ 009) This permit is vali•��2 0 tI• • •proval(20 AAC 25.005(g)) Submit in Duplicate ,S ' 12f/( % </ 75,:'+11 ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 4bep August 23, 2011 40G 2�r I rf T < JC Commissioner-State of Alaska 144 wit$�8d Alaska Oil &Gas Conservation Commission 333 East 7th Avenue Suite 100 Z # Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a revised Permit to Drill application for previously permitted coiled tubing drilling (CTD) lateral 3H-12AL1 (PTD#211-082). This revised application is being submitted because the actual kickoff point depth deviated from the permitted wejjpjan by more than 500'. The permitted kickoff point was 7400' MD and the actual kickoff point was 6862' MD. The reason for the deviation was due to difficulties encountered while running liner on the previous lateral, 3H-12AL3. s`Q g.Lz.er Verbal approval was requested from the State was via voicemail as well as an email on Sunday, August 21. The Commission granted verbal approval to continue with uninterrupted drilling operations on Monday, August 22, 2011. —.- Attached to this application are the following documents that explain the proposed job operations: — Revised Permit to Drill Application Form for 3H-12AL1 — Updated Wellbore Schematic — Updated Directional Plan — Original 3H-12 CTD Summary of Operations — Addendum#1: 3H-12AL3 Addendum-submitted 8/15/11 — Addendum#2: 3H-12AL1 Addendum If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, Jill g ConocoPhillips Alaska Coiled Tubing Drilling Engineer Permit to Drill Summary of Operations KRU 3H-12A, 3H-12AL1, and 3H-12AL2 Laterals Coiled Tubing Drilling Overview: Well 3H-12 is currently completed in both the A and C sand, without a selective completion equipped with 3W tubing and 7" production casing. Three proposed A-sand CTD laterals will increase injection and reservoir exposure for the offset planned 3H-10 CTD production laterals. Prior to drilling, the existing C and A-Sand perfs in 3H-12 will be squeezed with cement to provide a means to kick out of the 7" casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 6,930' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 3H-12A sidetrack will exit the 7" casing at 6,880' MD and will target the A2 sand south of the existing well with a 2,570' lateral. The hole will be completed with a 2%"slotted liner to the TD of 9,450' MD with an aluminum billet at 7,400' MD. The 3H-12AL1 lateral will kick off from the aluminum billet at 7,400' MD and will target the Al sand beneath the 3H-12A lateral with a 1,350' lateral. The hole will be completed with a 2%" slotted liner to the TD of.8;750'MD with an aluminum billet at 7,300' MD. %C/C) , " The 3H-12AL2 lateral will kick off from the aluminum billet at 7,300' MD and will target the A3 sand south of the existing well with a 2,200' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9,500' MD with the final liner top located inside the 3W tubing at 6,710' MD. Operational Outline Pre-Rig Work • Slickline: Pull CA2 Plug, DCR-1 shear valve and replace w/dummy,tag fill, obtain SBHP • E-line: Caliper/GR/CCL • E-line: Perforate the 3V2"tubing tail • Coil: Mill the D-nipple • Coil: Lay/squeeze cement plug • Slickline: Tag TOC and PT to 1500 psi. • Prepare well site for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU BOPE and test. Pull BPV 2. Mill cement pilot hole. 3. Set top of whipstock at 6,880' MD. 4. Mill 2.80"window at 6,880'. 5. 3H-12A Sidetrack a. Drill a 2.70"x 3"bi-center lateral to a TD of 9,450' MD b. Run the 23/8" slotted liner with an aluminum liner top billet from TD to 7,400' MD. 6. 3H-12AL1 Lateral � � '.. a. Kick off of the aluminum liner top billet at X7;400' MD b. Drill a 2.70"x 3" bi-center lateral to a TD of-8;770-"MD/yam s it c. Run the 2%" slotted liner with an aluminum libillet from TD to 7,300' MD. Page 2 of 7 ORIGINAL August 12,2011 Permit to Drill Summary of G,_.ations Cont. KRU.,._-12A,3H-12AL1,and 3H-12AL2 7. 3H-12AL2 Lateral 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 9,500' MD c. Run the 2%" slotted liner from TD to 6,710' MD, inside the 3-1/2" tubing tail of the mother-bore. Mud Program • Chloride-based Biozan brine (8.9 ppg) for milling operations, and chloride-based Flo-Pro mud (-V9.70 ppg) for drilling operations. • 3H-12 does have a TRMAXX —CMT-SR-5 SSSV that can be utilized for liner running operations, however will depend on reservoir pressure stabilization. May use an 11.9 ppg NaBr as a completion fluid to maintain a consistent pressure on the openhole. 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 3H-12A 7,400 9,450 2%", 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3H-12AL1 7,300 8,750 2%", 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3H-12AL2 6,710 9,500 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 0 115 1,640 630 Surface _ 9 b/8" 36 J-55 0 3,103 3,520 2,020 Casing 7 " 26 J-55 0 7,225 4,980 4,330 Tubing 3 '/" 9.3 L-80 0 6,663 10,160 10,540 Tubing 3 '/" 9.3 J-55 6,691 6,757 6,990 7,400 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 2615 psi assuming a gas gradient to surface based on the potential pressure from the combined A and C-sand interval that measured 3205 psi at 5900' TVDss. • The annular preventer will be tested to 250 psi and 2500 psi. Page3of7 ORIGINAL August 12,2011 Permit to Drill Summary of Gr__ations Cont. KRU 12A,3H-12AL1,and 3H-12AL2 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 3H-12A 6,350' 3H-12AL1 6,350 • 3H-12AL2 6,350' • Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset 3H-12A 1000' 3H-10B 3H-12AL1 1000' 3H-10B 3H-12AL2 1000' 3H-10B Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. Reservoir Pressure A combined zone SBHP was obtained on this well. The C and A Sand SBHP as of 5/31/11 was 3205 psi at a depth of 5900' TVDss which is equivalent to a 10.4 ppg EMW. The well has been shut in since then to reduce reservoir pressure for CTD operations. Hazards • 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. • 3H-16 had the maximum H25 level at 625 ppm on the 3H pad as measured on Oct. '09. All H25 . monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 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. The SSSV in well 3H-12 is operable for liner running operations, so the well may or may not be loaded with completion fluid prior to running slotted liner depending on maintaining a stable bottom hole pressure with potential losses to formation/faults. 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 7 OR I G l N }A L August 12, 2011 Permit to Drill Summary of(., .ations Cont. KRU.,..-12A,3H-12AL1,and 3H-12AL2 Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 3205 psi 3205 psi Mud Hydrostatic(9.70 ppg) 3006 psi 3006 psi Annular Friction 654 psi 0 psi Mud +Annular Friction 3660 psi 3006 psi (no choke pressure) (overbalanced (underbalanced -455 psi) -199 psi) Target Pressure (11.8 ppg) 3660 psi 3660 psi Choke Pressure Required 0 psi 654 psi to Maintain 13.1 ppg Example: Using the 3H-12 SBHP from May '11 with a reservoir pressure of 3205 psi at 5900 TVDss (10.4 ppg EMW). While drilling and circulating at 1.5 bpm with 2" e-coil, head from the 9.70 mud (3006 psi), plus an estimated 654 psi of annular friction (assuming friction of 95 psi/1000 ft)will provide 3660 psi BHP (11.8 ppg EMW) and will be overbalanced to the reservoir. More pressure can be applied to overbalance the reservoir. When circulation is shut down, the mud will be underbalanced to the reservoir pressure. However maintaining -654 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 3H-12 CTD laterals. The distances noted are the closest proximity between these wellbores and any point along the planned CTD laterals. - 3H-10B (active producer) - Currently a waivered well (7/15/2009) with IAxOA communication that was sidetracked in 2011 as a rotary setup for CTD operations. Well 3H-10B is a Kuparuk C-sand and A- sand production well equipped with 4%" tubing and 4%2" production liner. There are four proposed A- sand CTD laterals to increase reservoir exposure and offset the planned 3H-12 CTD injection laterals. Prior to rig arrival, a 4'/" mechanical whipstock will be set at the planned kickoff point of 6045' MD in 3H-10B. After setting the whipstock we will down-squeeze around the whipstock to permanently abandon the A-sand and C-sand perfs. - 3H-13A (active producer) - Currently a waivered well (1/20/2004) with IAxOA communication that was sidetracked in 1997. Perforations in the C and A sands through a 3-1/2" liner, from a 7" production casing. The last pressure was 2068 PSI (AC) in December 2009. There is a large fault interpreted to be sealing based on seismic between 3H-13A and 3H-12. Pressure data would suggest the fault is sealing also. Page 5 of 7 ORIGINAL August 12, 2011 KRU 3H-12AL3 — Coiled Tubing Drilling P /a.*•. Addendum to Summary of Operations (Addendum #1) / ""q.<< All general information relating to the CTD drilling program at 3H-12 outlined in previously submitted PTD Summary of Operations is relevant to 3H-12AL3 as well. The updated information that is lateral specific is noted below. Summary of Operations Additional lateral, 3H-12AL3, is being added to the 3H-12 coiled tubing drilling (CTD) program after the drilling of 3H-12A has taken place. While drilling 3H-12A, geologic complexity was encountered which caused the CTD team to reconsider how the planned 3H-12AL2 should be drilled. In order to minimize potential risks associated with keeping a faulted/shale section open for an extended amount of time, the objectives of the 3H-12AL2 lateral will now be met by drilling two laterals instead of only one. , ZO.µ, asie The 3H-12AL3 lateral will kick off from an aluminum billet at-? MD from the 3H-12A lateral and target the A2/A3 sands with a 2025' lateral. The hole will be completed with a 2%' slotted liner to the TD of 9375' MD with an aluminum billet at-7350' MD. Drilling operations will then proceed with the next lateral, 3H-12AL2. Remaining Work 1. 3H-12AL3 Lateral a. Kick off of the aluminum billet at 7820' MD b. Drill 2.70" x 3" bi-center lateral to TD of 9375' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7350' / 7j b•' - d 2. Drill and complete 3H-12AL2 as previously permitted G ec Z M 3. Drill and complete 3H-12AL1 as previously permitted Casing Program 3H-12AL3: 2%", 4.7#, L-80, ST-L slotted/solid liner from 7820' MD to 9375' MD Directional - See attached directional plan: 3H-12AL3. - 3H-12AL3: -6350' to property line, -1000' to well 3H-10 All general information relating to the CTD drilling program at 3H-12 outlined in the previously submitted PTD Summary of Operations is relevant to 3H-12AL3 as well. The updated information that is lateral specific is noted below. Page 6 of 7 ORIGINAL August 12, 2011 Revised KRU 3H-12AL1 — Coiled Tubing Drilling Addendum to Summary of Operations (Addendum #2) Summary of Operations The 3H-12AL3 liner was unable to reach the planned set depth. When it was determined that the liner would go no further, attempts were made to pull it out of the hole. The liner had become stuck though and would not move. This placed liner was across the permitted kickoff point for 3H-12AL1 (7400' MD) requiring a new kickoff to be determined. A kickoff was possible from the top of the stuck liner (an aluminum billet at a depth of 6862' MD); however, the kickoff deviated from the permitted kickoff depth for 3H-12AL1 by 538'. Because of this deviation a new, revised PTD was required. The reservoir targets and objectives of the 3H-12AL1 lateral remained as originally permitted; the only change was the kickoff from a shallower depth. After drilling and completion operations are complete on 3H-12AL1, drilling of the next lateral, 3H-12AL2, will begin. Remaining Work 1. 3H-2AL1 Lateral a. Kick off of the aluminum billet at 6862' MD ✓ b. Drill 2.70"x 3" bi-center lateral to TD at—9510' MD wr c. Run 2%" slotted liner with an aluminum billet from TD up to —7300' MD ✓ 2. Drill and complete 3H-12AL2 as previously permitted Casing Program 3H-12AL1: 2%", 4.7#, L-80, ST-L slotted/solid liner from 7300' MD to TD at-9510' MD Directional — See attached directional plan: 3H-12AL1. — 3H-12AL1: —6350' to property line, —1000' to well 3H-10B AL4-ttc✓C LA, cJ Or:1(i w, Orle.t_ i) 3N-Iz�4 2) 311 - ( 2_ AL 3 31 3H- 11 Al-- I `f) 31-1-!Z A1-2 Page 7 of 7August 23,2011 ORIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N I I Lubricator Riser Annular Blind/Shear 2" Pipe/Slip (CT) Pump into Lubricator ►�/ L\ /D< / above BHA rams 1 L Choke 1 li 2-3/8"Pipe/Slip(BHA) I Choke Equalize Manifold i 2-3/8" Pipe/Slip(BHA) , I Kill ►>40C� L�.I � L ► Blind/Shear I' 2" Pipe/Slip(CT) l' 'I r Choke 2 II Swab Valves ' I Wing Valves �� 141 Tree Flow Cross 0 Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi XI 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, CO62 Union ORIGINAL Q N co Q O N M '-C r _ , i M , \-,-: 11 p V r U N J N 2 cK up 0 N M .0. E V N ` o\ ` 4-, ,„> 0 (.3 43 E--- . . \ %. . y 0 — . . \ . . (9 m a 0 r� co Um E��7-N 0 Z 92 at N U N v u m - X ° 0- 0 M O w o N Z m 2 0 N 0 m 0 LL 0? 0 , , I 2 2 x 2 a 2- 2 0 2 Ce O O N V N ch U t0 I I l't t . U N•E co I�., co co. N N u) c6 co co tom (Om COU f0 L �� t,� i �C U U Tfax Y, I Et Y yc z ter o 1-.- -i 9 .. a) ,- Es 1-- 11I III III III o I g o °' 0 o 0 0 0 0 0 0 TO D. M N U o f °-(0 a• (0 a(0 0, Ua CD - -0 • "O • V , V , 0 O N C- G C- C- .0 L (0 N N N— c0 V m cn h CO n M aD N o FICO °m Q co Q 0 Q CO 0 T.- V I I C9 M 4t CO C•/) CV OD N Cfl I- CO 6 , ORIGINAL . . ConocoPhilli _.. Alas ca ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H-12 3H-12AL1 Plan: 3H-12AL1_wp08 Standard Planning Report 22 August, 2011 Ira 11-11 BAKER HUGHES ORIGINAL r' ConocoPhillips or its affiliatesFS ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL1_wp08 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 3H Pad Site Position: Northing: 6,000,110.73ft Latitude: 70°24'41.531 N From: Map Easting: 498,655.44ft Longitude: 150°0'39.416 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 3H-12 Well Position +N/-S 0.00 ft Northing: 6,000,450.51 ft Latitude: 70°24'44.873 N +E/-W 0.00 ft Easting: 498,655.38 ft Longitude: 150°0'39.420 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 3H-12AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 8/1/2011 16.50 79.91 57,367 Design 3H-12AL1_wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,860.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 200.00 8`22/2011 10:02:38AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL 1.7". ConocoPhillips or its affiliates VA' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3 H-12AL 1_wp08 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) 0100ft) (°) Target 6,860.00 33.45 7.75 5,944.19 2,515.15 897.01 0.00 0.00 0.00 0.00 6,862.00 33.57 7.66 5,945.85 2,516.24 897.16 6.49 6.00 -4.50 -22.53 6,892.00 38.02 345.74 5,970.28 2,533.49 895.98 45.00 14.84 -73.05 280.00 6,922.00 47.66 331.74 5,992.30 2,552.30 888.42 45.00 32.11 -46.67 310.00 6,952.00 60.47 326.48 6,009.88 2,573.04 875.91 45.00 42.72 -17.55 340.00 7,050.00 104.57 326.48 6,022.32 2,652.07 823.56 45.00 45.00 0.00 0.00 7,150.00 90.05 283.40 6,009.01 2,706.84 744.07 45.00 -14.53 -43.08 255.00 7,250.00 90.03 238.40 6,008.94 2,691.42 647.85 45.00 -0.01 -45.00 270.00 7,350.00 90.14 226.40 6,008.79 2,630.52 568.76 12.00 0.10 -12.00 270.50 7,450.00 85.47 215.33 6,012.63 2,555.10 503.49 12.00 -4.66 -11.07 247.00 7,560.00 90.06 202.94 6,016.94 2,459.29 450.11 12.00 4.17 -11.26 290.00 7,675.00 90.53 189.15 6,016.34 2,349.04 418.41 12.00 0.41 -11.99 272.00 7,775.00 91.77 201.09 6,014.32 2,252.70 392.38 12.00 1.23 11.94 84.00 7,925.00 94.76 218.87 6,005.72 2,123.49 317.90 12.00 1.99 11.85 80.00 8,095.00 98.28 198.64 5,986.21 1,976.28 237.00 12.00 2.07 -11.90 281.00 8,170.00 89.28 198.64 5,981.27 1,905.44 213.11 12.00 -12.00 0.00 180.00 8,270.00 91.37 210.46 5,980.71 1,814.65 171.64 12.00 2.08 11.82 80.00 8,450.00 92.01 188.86 5,975.34 1,646.22 111.47 12.00 0.36 -12.00 272.00 8,650.00 87.79 212.49 5,975.71 1,460.46 41.38 12.00 -2.11 11.82 100.00 8,800.00 84.21 194.80 5,986.26 1,323.98 -18.43 12.00 -2.39 -11.79 258.00 8,950.00 90.53 177.92 5,993.20 1,175.67 -34.90 12.00 4.21 -11.25 290.00 9,075.00 91.28 162.94 5,991.21 1,052.78 -14.18 12.00 0.61 -11.99 273.00 9,275.00 98.01 186.07 5,974.79 855.84 4.97 12.00 3.36 11.56 73.00 9,510.00 88.75 212.78 5,960.69 636.94 -72.50 12.00 -3.94 11.37 108.00 8/22/2011 10:02:38AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ✓ ConocoPhillips or its affiliates Ira' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL1_wp08 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (1 (o) (ft) (ft) (ft) (ft) (°/100ft) (`) (ft) (ft) 6,860.00 33.45 7.75 5,944.19 2,515.15 897.01 -2,670.26 0.00 0.00 6,002,965.24 499,552.75 TIP 6,862.00 - 33.57 7.66 5,945.85 2,516.24 897.16 -2,671.34 6.49 -22.53 6,002,966.34 499,552.90 KOP 1 6,892.00 38.02 345.74 5,970.28 2,533.49 895.98 -2,687.15 45.00 -80.00 6,002,983.59 499,551.73 Start of 45DLS 6,900.00 40.42 341.49 5,976.48 2,538.34 894.55 -2,691.22 45.00 -50.00 6,002,988.44 499,550.30 6,922.00 47.66 331.74 5,992.30 2,552.30 888.42 -2,702.24 45.00 -46.70 6,003,002.40 499,544.17 4 6,952.00 60.47 326.48 6,009.88 2,573.04 875.91 -2,717.45 45.00 -20.00 6,003,023.14 499,531.66 5 7,000.00 82.07 326.48 6,025.20 2,610.72 850.95 -2,744.32 45.00 0.00 6,003,060.81 499,506.72 7,050.00 104.57 326.48 6,022.32 2,652.07 823.56 -2,773.80 45.00 0.00 6,003,102.16 499,479.34 6 7,100.00 97.85 304.57 6,012.49 2,686.74 789.37 -2,794.68 45.00 -105.00 6,003,136.83 499,445.15 7,150.00 90.05 283.40 6,009.01 2,706.84 744.07 -2,798.08 45.00 -109.32 6,003,156.94 499,399.86 7 7,200.00 90.04 260.90 6,008.97 2,708.70 694.42 -2,782.85 45.00 -90.00 6,003,158.82 499,350.221 7,250.00 90.03 238.40 6,008.94 2,691.42 647.85 -2,750.69 45.00 -90.02 6,003,141.55 499,303.65 8 7,300.00 90.08 232.40 6,008.89 2,663.04 606.71 -2,709.95 12.00 -89.50 6,003,113.18 499,262.51 7,350.00 90.14 226.40 6,008.79 2,630.52 568.76 -2,666.41 12.00 -89.51 6,003,080.66 499,224.56 Start of 12DLS 7,400.00 87.79 220.87 6,009.69 2,594.36 534.28 -2,620.63 12.00 -113.00 6,003,044.51 499,190.07 7,450.00 85.47 215.33 6,012.63 2,555.10 503.49 -2,573.21 12.00 -112.90 6,003,005.26 499,159.28 10 7,500.00 87.54 209.69 6,015.68 2,513.03 476.68 -2,524.51 12.00 -70.00 6,002,963.20 499,132.47 7,560.00 90.06 202.94 6,016.94 2,459.29 450.11 -2,464.93 12.00 -69.66 6,002,909.48 499,105.89 11 7,600.00 90.23 198.14 6,016.84 2,421.85 436.08 -2,424.94 12.00 -88.00 6,002,872.04 499,091.85 7,675.00 90.53 189.15 6,016.34 2,349.04 418.41 -2,350.48 12.00 -88.01 6,002,799.24 499,074.17 12 7,700.00 90.85 192.13 6,016.04 2,324.48 413.79 -2,325.82 12.00 84.00 6,002,774.68 499,069.55 7,775.00 91.77 201.09 6,014.32 2,252.70 392.38 -2,251.05 12.00 84.04 6,002,702.91 499,048.13 13 7,800.00 92.29 204.04 6,013.44 2,229.63 382.80 -2,226.09 12.00 80.00 6,002,679.85 499,038.54 7,900.00 94.28 215.90 6,007.69 2,143.30 333.02 -2,127.94 12.00 80.10 6,002,593.53 498,988.76 7,925.00 94.76 218.87 6,005.72 2,123.49 317.90 -2,104.16 12.00 80.79 6,002,573.74 498,973.63 14 8,000.00 96.41 209.98 5,998.40 2,061.99 275.74 -2,031.95 12.00 -79.00 6,002,512.25 498,931.46 8,095.00 98.28 198.64 5,986.21 1,976.28 237.00 -1,938.16 12.00 -79.87 6,002,426.55 498,892.71 15 8,100.00 97.68 198.64 5,985.52 1,971.59 235.42 -1,933.21 12.00 -180.00 6,002,421.86 498,891.13 8,170.00 89.28 198.64 5,981.27 1,905.44 213.11 -1,863.42 12.00 -180.00 6,002,355.72 498,868.81 16 8,200.00 89.91 202.18 5,981.48 1,877.33 202.65 -1,833.42 12.00 80.00 6,002,327.62 498,858.35 8,270.00 91.37 210.46 5,980.71 1,814.65 171.64 -1,763.92 12.00 79.97 6,002,264.95 498,827.33 17 8,300.00 91.49 206.86 5,979.96 1,788.34 157.26 -1,734.27 12.00 -88.00 6,002,238.64 498,812.95 8,400.00 91.85 194.86 5,977.03 1,695.10 121.74 -1,634.51 12.00 -88.09 6,002,145.42 498,777.41 8,450.00 92.01 188.86 5,975.34 1,646.22 111.47 -1,585.06 12.00 -88.44 6,002,096.54 498,767.14 18 8/22/2011 10:02:38AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL r.' ConocoPhillips or its affiliates rril, ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL1_wp08 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) C) C) (ft) (ft) (ft) (ft) (°l100ft) (°) (ft) (ft) 8,500.00 90.96 194.77 5,974.05 1,597.31 101.24 -1,535.61 12.00 100.00 6,002,047.65 498,756.90 8,600.00 88.84 206.58 5,974.23 1,503.92 66.01 -1,435.80 12.00 100.15 6,001,954.27 498,721.65 8,650.00 87.79 212.49 5,975.71 1,460.46 41.38 -1,386.54 12.00 100.13 6,001,910.82 498,697.02 19 8,700.00 86.55 206.61 5,978.18 1,417.04 16.77 -1,337.31 12.00 -102.00 6,001,867.40 498,672.40 8,800.00 84.21 194.80 5,986.26 1,323.98 -18.43 -1,237.83 12.00 -101.71 6,001,774.36 498,637.19 20 8,900.00 88.40 183.53 5,992.73 1,225.64 -34.27 -1,140.00 12.00 -70.00 6,001,676.03 498,621.33 8,950.00 90.53 177.92 5,993.20 1,175.67 -34.90 -1,092.83 12.00 -69.27 6,001,626.07 498,620.69 21 9,000.00 90.84 171.93 5,992.60 1,125.89 -30.48 -1,047.57 12.00 -87.00 6,001,576.29 498,625.10 9,075.00 91.28 162.94 5,991.21 1,052.78 -14.18 -984.43 12.00 -87.07 6,001,503.18 498,641.39 22 9,100.00 92.16 165.81 5,990.46 1,028.71 -7.45 -964.13 12.00 73.00 6,001,479.12 498,648.11 9,200.00 95.58 177.34 5,983.69 930.20 7.16 -876.56 12.00 73.09 6,001,380.62 498,662.71 9,275.00 98.01 186.07 5,974.79 855.84 4.97 -805.93 12.00 73.87 6,001,306.27 498,660.50 23 9,300.00 97.07 188.94 5,971.51 831.27 1.73 -781.74 12.00 108.00 6,001,281.70 498,657.26 9,400.00 93.18 200.34 5,962.55 735.10 -23.42 -682.75 12.00 108.38 6,001,185.54 498,632.09 9,500.00 89.15 211.65 5,960.51 645.40 -67.17 -583.50 12.00 109.40 6,001,095.85 498,588.34 9,510.00 88.75 212.78 5,960.69 . 636.94 -72.50 -573.73 12.00 109.63 6,001,087.40 498,583.00 TD 8/22%2011 10:02:38AM Page 5 COMPASS 2003.16 Build 69 RIGINAL • ConocoPhillips or its affiliates ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL1_wp08 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3H-12AL1_T3(copy)] 0.00 0.00 6,009.00 2,609.54 554.45 6,003,059.69 499,210.24 70°25'10.538 N 150°0'23.161 W -plan misses target center by 4.72ft at 7375.07ft MD(6008.99 TVD,2612.80 N,551.03 E) -Point 3H-12AL1_14(copy)' 0.00 0.00 6,017.00 2,489.52 460.46 6,002,939.70 499,116.24 70°25 9.357 N 150°0'25.918 W -plan misses target center by 3.27ft at 7528.31ft MD(6016.60 TVD,2488.07 N,463.36 E) -Point 3H-12AL1_T9 0.00 0.00 5,991.00 1,262.34 -20.40 6,001,712.73 498,635.21 70°24'57.288 N 150°0'40.018 W -plan misses target center by 10.18ft at 8861.46ft MD(5991.10 TVD,1263.94 N,-30.45 E) -Point 3H-12AL1_T5(copy) 0.00 0.00 6,017.00 2,363.50 410.47 6,002,813.70 499,066.23 70°25 8.118 N 150°0'27.383 W -plan misses target center by 10.34ft at 7662.81ft MD(6016.45 TVD,2361.05 N,420.50 E) -Point 3H-12AL1_T8(copy) 0.00 0.00 5,974.00 1,620.39 106.55 6,002,070.72 498,762.22 70°25'0.810 N 150°0'36.295 W -plan hits target center -Point 3H-12AL1_T10 0.00 0.00 5,985.00 942.32 6.65 6,001,392.73 498,662.20 70°24'54.141 N 150°0'39.225 W -plan hits target center -Point 3H-12A lats Fault 2(c 0.00 0.00 -76.00 2,242.43 -2.55 6,002,692.71 498,653.23 70°25'6.927 N 150°0'39.494 W -plan misses target center by 6070.47ft at 8170.00ft MD(5981.27 ND,1905.44 N,213.11 E) -Polygon Point 1 -76.00 2,242.43 -2.55 6,002,692.71 498,653.23 Point 2 -76.00 2,209.49 289.49 6,002,659.72 498,945.24 Point 3 -76.00 2,107.58 682.55 6,002,557.75 499,338.24 Point 4 -76.00 2,209.49 289.49 6,002,659.72 498,945.24 3H-12A,AL1,AL2 Pol 0.00 0.00 -76.00 2,879.64 1,029.45 6,003,329.67 499,685.24 70°25'13.193 N 150°0'9.231 W -plan misses target center by 6032.66ft at 6860.00ft MD(5944.19 ND,2515.15 N,897.01 E) -Polygon Point 1 -76.00 2,879.64 1,029.45 6,003,329.67 499,685.24 Point 2 -76.00 3,004.49 325.35 6,003,454.64 498,981.24 Point 3 -76.00 535.09 -330.14 6,000,985.60 498,325.37 Point 4 -76.00 448.14 -60.10 6,000,898.61 498,595.37 Point 5 -76.00 2,580.51 595.48 6,003,030.65 499,251.26 Point 6 -76.00 2,425.56 875.54 6,002,875.67 499,531.27 3H-12A lats Fault 3(c 0.00 0.00 -76.00 1,634.33 -263.48 6,002,084.73 498,392.22 70°25'0.947 N 150°0'47.145 W -plan misses target center by 6060.40ft at 8583.17ft MD(5973.94 ND,1519.10 N,73.27 E) -Polygon Point 1 -76.00 1,634.33 -263.48 6,002,084.73 498,392.22 Point 2 -76.00 1,576.40 73.57 6,002,026.74 498,729.22 Point 3 -76.00 1,316.67 1,328.75 6,001,766.81 499,984.23 Point4 -76.00 1,576.40 73.57 6,002,026.74 498,729.22 3H-12AL1_T11 0.00 0.00 5,968.00 812.30 -1.33 6,001,262.73 498,654.19 70°24'52.862 N 150°0'39.459 W -plan misses target center by 1.28ft at 9319.40ft MD(5969.25 ND,812.30 N,-1.63 E) -Point 311-12AL1_12(copy)' 0.00 0.00 6,028.00 2,700.58 739.45 6,003,150.69 499,395.24 70°25'11.433 N 150°0'17.736 W -plan misses target center by 20.32ft at 7154.40ft MD(6009.00 ND,2707.78 N,739.78 E) -Point 3H-12AL1_T6(copy) 0.00 0.00 6,002.00 2,098.46 299.50 6,002,548.71 498,955.23 70°25'5.511 N 150°0'30.638 W -plan misses target center by 1.01ft at 7956.30ft MD(6002.93 ND,2098.61 N,299.13 E) -Point 3H-12AL1_T1 (copy)i 0.00 0.00 6,005.00 2,610.59 851.47 6,003,060.68 499,507.24 70°25'10.548 N 150°0'14.451 W _plan missestaraet center by 20.12ft at 6993.10ft MD(6024.06 ND,2605.04 N.854.71 E) 8/22/2011 10:02:38AM Page 6 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates ConocoPhilkps Planning Report BAKER Alaska. HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL1_wp08 Point 3H-12AL1 T7(copy) 0.00 0.00 5,979.00 1,824.42 177.53 6,002,274.71 498,833.22 70°25'2.816 N 150°0'34.214 W -plan misses target center by 1.97ft at 8258.64ft MD(5980.95 TVD, 1824.50 NI, 177.28 E) -Point 3H-12A lets Fault 1 (t 0.00 0.00 -76.00 3,052.63 884.41 6,003,502.68 499,540.25 70°25'14.895 N 150°0' 13.484 W -plan misses target center by 6044.14ft at 6860.00ft MD(5944.19 TVD,2515.15 N,897.01 E) -Polygon Point 1 -76.00 3,052.63 884.41 6,003,502.68 499,540-25 Point 2 -76.00 2,783.59 812.47 6,003,233.68 499,468-27 Point 3 -76.00 2,271.49 633.57 6,002,721.66 499,289.29 Point 4 -76.00 2,783.59 812.47 6,003,233.68 499,468.27 3H-12AL1 T12 0.00 0.00 5,961.00 637.28 -72.31 6,001,087.74 498,583.19 70°24'51.141 N 150°0'41.540 W -plan hits target center -Point 115.00 39.00 16" 16 20 3,021.99 2,844.26 9 5/8" 9-5/8 13-1/2 6,800.00 5,895.57 6" 7 7 9,510.00 5,960.69 2-3/8" 3 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 6,860.00 5,944.19 2,515.15 897.01 TIP 6,862.00 5,945.85 2,516.24 897.16 KOP 6,892.00 5,970.28 2,533.49 895.98 Start of 45DLS 6,922.00 5,992.30 2,552.30 888.42 4 6,952.00 6,009.88 2,573.04 875.91 5 7,050.00 6,022.32 2,652.07 823.56 6 7,150.00 6,009.01 2,706.84 744.07 7 7,250.00 6,008.94 2,691.42 647.85 Start of 12DLS 7,350.00 6,008.79 2,630.52 568.76 9 7,450.00 6,012.63 2,555.10 503.49 10 7,560.00 6,016.94 2,459.29 450.11 11 7,675.00 6,016.34 2,349.04 418.41 12 7,775.00 6,014.32 2,252.70 392.38 13 7,925.00 6,005.72 2,123.49 317.90 14 8,095.00 5,986.21 1,976.28 237.00 15 8,170.00 5,981.27 1,905.44 213.11 16 8,270.00 5,980.71 1,814.65 171.64 17 8,450.00 5,975.34 1,646.22 111.47 18 8,650.00 5,975.71 1,460.46 41.38 19 8,800.00 5,986.26 1,323.98 -18.43 20 8,950.00 5,993.20 1,175.67 -34.90 21 9,075.00 5,991.21 1,052.78 -14.18 22 9,275.00 5,974.79 855.84 4.97 23 9,510.00 5,960.69 636.94 -72.50 TD 8/22/2011 10:02::38AM Page 7 COMPASS 2003.16 Build 69 ORIGINAL 1 I I_ __ rt __-t- — -8 C4 I CI iZ x M O I Q I -4/1 4/l 4. � . _- -_ 1 g o iCO �s s�N S'- •",..8^-`-' , /11;141/44 0 V, [ ilkI `'�- I I II MINN*, i Z.-.Q / / ' / 1 0.1 / I J I . 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SAA ttpp VO, m mmm Mmr�A N Z p 2 O N 8 m Q N a O,r Q a b V N N M a h N N N O F N '°E °' ,o MBgr 2g.l Ntie Cryjw p Ud = a8�ogwmmooi8rnmamwrnmmrnrnrnm f 11.1-i Ny2 W s. 48 88888.880888888888880888 tWNS 'iN.% 45gcryH2a '12r Q W ppmmpOm - - 88 dY 0 %a i? m ar NMv�Amr mrnorNMe g O (l1rNm,....FmmrrrrrrrrrrNNNNN O 8 S I r S 1M c c N 4--- p N v om C v p 0.r- N ilml _'� O pp r 1 - N N O M p /` N r ., F df.oe5 " 'E' .3, e/ Q r c� N g p d N /M \\ N m V J g.-3?! i / / / / / - '-°'° A c U € �� - \' 0 i ,i .� �t m 8av � 0 \ A a N !1 0 N 8 c° 0 0 ON O O O 'I' 2- , __.._.O s'v O O O O O" 0 8 00 8 ON O > 5f ........ — -— — N N N O > pQ • u N 1,1 1, I ` '1 \ a m / / / 1 / j i 4 1 � ov 0 ma 11r 1 1 `\ \ \ \ - m m� % LL �RS• M a ` M % / / 2, m. 3 N E Q•• \ \ \ -„,., • ,\lk: U m m o iil. .,.,� ,tto n. ,A ./ , } .r o 1 S CI_ a OO O M r N V cN E ORIGINAL ,, I ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-12 Project: Kuparuk River Unit TVD Reference: 3H-12 @ 76.00ft(3H-12) Reference Site: Kuparuk 3H Pad MD Reference: 3H-12 @ 76.00ft(3H-12) Site Error: 0.00ft North Reference: True Reference Well: 3H-12 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3H-12AL1 Database: EDM Alaska Prod v16 Reference Design: 3H-12AL1_wp08 Offset TVD Reference: Offset Datum 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 3H Pad 3H-10-3H-10-3H-10 Out of range 3H-10-3H-10B-3H-10B 9,491.47 6,000.00 784.18 182.56 605.64 Pass-Major Risk 3H-10-3H-10C-3H-10C 9,491.47 6,000.00 784.18 182.79 605.46 Pass-Major Risk 3H-10-3H-10CL1 -3H-10CL1 9,491.47 6,000.00 784.18 182.79 605.46 Pass-Major Risk 3H-10-3H-10CL2-3H-10CL2 9,491.47 6,000.00 784.18 182.79 605.46 Pass-Major Risk 3H-10-3H-10CL2-01 -3H-10CL2-01 9,491.47 6,000.00 784.18 182.79 605.46 Pass-Major Risk 3H-10-3H-10CL2-02-3H-10CL2-02 9,491.47 6,000.00 784.18 182.79 605.46 Pass-Major Risk 3H-10-3H-10CPB1 -3H-10CPB1 9,491.47 6,000.00 784.18 182.79 605.46 Pass-Major Risk 3H-11 -3H-11 -3H-11 Out of range 3H-11 -Plan:3H-11A-3H-11A(wp05) Out of range 3H-12-3H-12-3H-12 6,875.00 6,875.00 0.48 89.60 -85.11 FAIL-Major Risk 3H-12-3H-12A-3H-12A 6,874.96 6,875.00 0.63 0.46 0.22 Pass-Minor 1/10 3H-12-3H-12AL3-3H-12AL3 6,874.96 6,875.00 0.63 0.63 0.07 Pass-Major Risk 3H-12-3H-12APB1 -3H-12APB1 6,874.96 6,875.00 0.63 0.75 -0.08 FAIL-Major Risk 3H-13-3H-13-3H-13 Out of range 3H-13-3H-13A-3H-13A Out of range 3H-14-3H-14-3H-14 Out of range 3H-14-3H-14A-3H-14A Out of range 3H-14-3H-14APB1 -3H-14APB1 Out of range 3H-14-3H-14B-3H-14B Out of range 3H-14-3H-14BL1 -3H-14BL1 Out of range 3H-14-3H-14BL2-3H-14BL2 Out of range 3H-14-3H-14BL3-3H-14BL3 Out of range 3H-14-3H-14BL4-3H-14BL4 Out of range 3H-15-3H-15-3H-15 Out of range 3H-17-3H-17-3H-17 Out of range 3H-18-3H-18-3H-18 Out of range 3H-19-3H-19-3H-19 Out of range 3H-20-3H-20-3H-20 Out of range 3H-21 -3H-21 -3H-21 Out of range 3H-23-3H-23-3H-23 Out of range 3H-23-3H-23A-3H-23A Out of range 3H-24-3H-24-3H-24 Out of range 3H-25-3H-25-3H-25 Out of range 3H-25-3H-25A-3H-25A Out of range 3H-25-3H-25APB1 -3H-25APB1 Out of range 3H-25-3H-25APB2-3H-25APB2 Out of range 3H-28-3H-28-3H-28 Out of range 3H-28-3H-28A-3H-28A Out of range 3H-28-3H-28APB1 -3H-28APB1 Out of range 3H-32-3H-32-3H-32 Out of range 3H-32-3H-32PB1 -3H-32PB1 Out of range 3H-33-3H-33-3H-33 Out of range 3H-33-3H-33A-3H-33A Out of range 3H-33-3H-33AL1 -3H-33AL1 Out of range 3H-33-3H-33AL1 PB1 -3H-33AL1 PB1 Out of range 3H-33-3H-33AL2-3H-33AL2 Out of range 3H-33-3H-33AL2-01 -3H-33AL2-01 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/21/2011 7:10:16PM Page 3 of 19 COMPASS 2003.16 Build 69 ORIGINAL Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, August 22, 2011 8:42 AMpr;((t oviZ To: 'Long, Jill W z) AL3 Subject: RE: Changes to Approved PTD 211-082 3) A L I My mistake... 3H-12AL1 is lateral that I was referring to . 4) A LZ Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long, Jill W [mailto:Jill.W.Long@conocophillips.com] Sent: Monday, August 22, 2011 8:40 AM To: Schwartz, Guy L(DOA) Subject: RE: Changes to Approved PTD 211-082 Thanks Guy. Just to confirm though, this revision is for the 3H-12AL1 lateral. The liner we had trouble getting down was the one for 3H-12AL3. Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, August 22, 2011 8:37 AM To: Long, Jill W Subject: RE: Changes to Approved PTD 211-082 74- g,Z z r c Jill, AZ- You have verbal approval to move the lateral kickoff point for 3H-12AL-5-"as described below. Submit a revised 401 PTD within 3 business days. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long, Jill W [mailto:JilI.W.Long@conocophillips.com] Sent: Sunday, August 21, 2011 5:06 PM To: Schwartz, Guy L (DOA) Subject: Changes to Approved PTD 211-082 8/22/2011 Page 2 of 2 Guy- The purpose of this email is to follow up to the voicemail I just left you on your cell phone. ConocoPhillips requests verbal approval to drill the previously permitted 3H-12AL1 lateral by kicking off from a depth that deviates from the permitted wellplan by more than 500'. Last night we experienced issues getting the 3H-12AL3 liner all the way to TD. The plan was to pull the liner out and attempt to re-run but injector issues prohibited pulling the liner out. Once the injector issues were resolved, the liner was unable to be moved up or down. Because of that, the billet for the kickoff for the next lateral (3H- 12AL1) is 538'shallower than the permitted depth. The permitted kickoff depth was 7400'and the new kickoff will be at 6862'. A new PTD application to document this change will be submitted within the required 3 calendar days. If you have questions please give me a call on my cell phone. Otherwise, I will plan to speak with you tomorrow morning (Monday, August 22). Thank you Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 8/22/2011 TRANSMITTAL LETTER CHECKLIST , WELL NAME l'% 3/-( - /2/ / / (72- e 1-)/51 PTD# 2 / ( CF)' __.2_ / G/ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ./ -"-/-/-</e_._ 7‹.../ '3r POOL: kC - e' `� /0-e---/— 1' / Circle Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment,of existing well / /11. ( 3/( ' (2d7 , (If last two digits in Permit No.-74 Z--)R.)/ ,API No. 50/C 3-:2--(-C--)A7 -0/ . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approviip a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 i y cn D a, O .g cn D a - r2 „ -3 o r coc -n a 3 0 m o 0 -1 V,o ( 3' 0 "P., 3. r- 3 m ,.< co 0 O 3.o au °� 3' y 0 m cn O cO 17.3 I co m coo d `a (N0 0 0 � XI O c' 0 0 0 o I o co - -, - I -i o n W W - CO W CO CO W - CO CON N N N N N N - N CD -, -i . . . . . CO CO V O CT A CO N -, -. m CO CO V 0) O, A CO N -. 0 CO CO V 0) Ot A W N 0 CO CO O, (n A W N -. 0 V .O m CD O 'cn 'cn 0 b IM o ;* 'n 03 'W .°. v D , D n n n n n 0 'a D * n b - O O = 0 * * * C r 1 Z ,< n o D CDCD - o 0O c) m. 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(7,• O_ co KJ e a _ �0. O D :N W W W O IX CI) 7c m CD 7 0 CO �33 a 0 N W N N N < • o c o O * 2 O O n y D o W_ CD 3 m (o o o a' X o 7rC4 n -ca K a ,chi a (0 a L g N 0 ' y 0, 0 a C -0 a O p 0 �_ 'co �0 ,0 :NCll N c '0 '0 0 '� 'Q Z N 0 = N a s cn ° ° v m 'o o '5 `< = 0•. (0 O 'C O, d O ,? O (D 7 7 y W �y Zr).‘ o N A o o < •a m m y m0 • m o o v v D 3 ac0.o mm K * O 0 O C I- C 0. 0 3 *. °- ° v a 0 i0 t0 '(/+ 0c'D- m v = v, o �, m m rn w- 5. CT I * m g m - 4- ; o z S' v o (D 0- " A Cp • nCO F, ET, oo co 3 0 O 3 co(17 m o. 5-'" °°, 0 2 _. v 0) CD Kn D• ° ° c - = r r O j f(Q m 3 o O o'C° * 3 ,= - 0 CD v F 0- -I • CD ° v Dp o (o o 41- o c° vc _ c o r 3 r -, 0 • o <0 0 `� a7 n 2 c 7 : p (o a N i v o m - m ❑El sirma o [ic ansEff.,\\ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gnatt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-12AL1 ConocoPhillips Alaska, Inc. Permit No: 211-082 Surface Location: 1207' FNL, 281' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 406' FSL, 431' FWL, SEC. 1, T12N, R8E, UM Dear Mr. Gnatt: 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 3H-12A, Permit No 211- 081, API 50-103-20088-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, aniel T. Seamount, Jr. 71.4 Chair DATED this day of July, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) C V STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION UN '' 9 ?_1111' PERMIT TO DRILL 20 AAC 25.005 fk;ani;a cif C2�A CMS.t)minlission Ata nn 1 a.Type of Work: t 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ • Single Zone ❑� • 10.Specify if well i5 pthpb52Cr16 Drill ❑ Re-drill 2 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas Cl Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: iJ Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. - Bond No. 59-52-180 / 3H-12AL1 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:8750' . TVDSS: 6003' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1207'FNL,281'FWL,Sec. 12,T12N, R8E,UM • ADL 25531 Kuparuk River Oil Pool _ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1561'FSL,913'FWL,Sec. 1,T12N,R8E,UM 2657 7/21/2011 Total Depth: 9.Acres in Property: 14.Distance to 406'FSL,431'FWL,Sec. 1,T12N, R8E,UM 2560 Nearest Property: 6350' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: •76 feet 15.Distance to Nearest Well Open Surface:x- 498655 • y- 6000451 • Zone- 4 GL Elevation above MSL: 40 feet to Same Pool: 3H-10B,1000' 16.Deviated wells: Kickoff depth: 7400'. ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 94° deg Downhole:3205 psig • Surface:2615 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.325" 4.7# L-80 ST-L 1450' 7300' 5995' 8750' 6003' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 7298' 6373 7144' 6249' 7030', 7032', 7036' Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 245 sx AS I 115' 115' Surface 3069' 9.625" 1300 sx AS III,400 sx Class G, 3104' 2986' Intermediate top job 90 sx AS I Production 7190' 7" 320 sx Class G, 175 sx AS I 7225' 6314' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 6832'-6846',6880'-6890',6904'-6914',6934'-6954' 5998'-6009',6037'-6045',6056'-6064',6080'-6096' 20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 Printed Name L. Gantt Title CTD Engineering Supervisor Signature dUl/VkllA �C t14�( t I Phon 263-4021 Date �ize/f/ 4 Commission Use Only Permit to Drill __ API Number: Permit Approval See cover letter / „ ,e_'--)c., Number: _2 (C F 50-/LE� , J Date: tY 1,1 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed mane,gas hydrates,or gas contained in shales: Ile 3.5.00 psi_ &V' I'S4— Samples req'd: Yes CI No et Mud log req'd: Yes ❑ No g7 Other: A2 S-as rs` Ann re-3,(_(. H2S measures: Yes ET No ❑ Directional svy req'd: Yes a No ❑ — U t• n. - d/oer•r ;•o4•. l..t CcG.e i'� "'f 1't[ • Z� A- µ I T” I-c t,.,1,-,..se . 2 A 7// APPROVED BY THE COMMISSION DATE: `� ,COMMISSIONER_ Form 10-401 (Revised 7/2009) This permit is valid f.r 21itis Nat f pproval(20 AAC 25.005(9)) Submit in Duplicate>,� i 0 2 O 10 LO I a„ aa; h: _ a a; .‘,41.c H a'': xi . In 0 J�; d-. 1.„,„4-'"---, V., aye N �\: 1..: re 0 a,< fin F'' S 0' a dr n J 6, J, /� I i. -'t4344 I 14 Stei-- a�.. CO a� ._€-=, >ff) 0 ; )_ a,ly o to- op co 1.2Coo Q CD a d 0 ::. mu °' 'n --- '411-.4*r .._ g 92 co X N: CO:10 O N O, x b N. Q �. LL1: aa; iI Q�-.. U.N V.Cf] co 3 N - M. _ Z m�: O 4t?a J'; C7 00 d' Jy, CC— 2. 0N fid] 0�: OP 0 �; -, U E CNO CSO N N` d. ✓.." co co ,'J c0 on CO m' 0 0 CO- Q.- AA i V V Y �ysJe-,,r'l I JI II y: " — i � _ �� xy,. v,`� is '+.t „3-'4* ¢�er__ , _ , � Ley 'v�'e,K4�.'� .3 i W as- U) B p — I— ii III //��,� as o 11:: ECt . a a0 a C0 :f0-CO a a a a IDo a fA 1= C C "C L N o .c cn `V2 wo yM , an a rn rn p. �C (.0> 0 CO4t 00 CV Q p Q p Q CO: II CO CD M CO in N E m oa ORIGINAL Permit to Drill Summary of Operations KRU 3H-12A, 3H-12AL1, and 3H-12AL2 Laterals Coiled Tubing Drilling Overview: Well 3H-12 is currently completed in both the A and C sand,without a selective completion equipped with 3%" tubing and 7" production casing. Three proposed A-sand CTD laterals will increase injection and reservoir exposure for the offset planned 3H-10 CTD production laterals. Prior to drilling,the existing C and A-Sand perfs in 3H-12 will be squeezed with cement to provide a means to kick out of the 7" casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 6,930' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 3H-12A sidetrack will exit the 7"casing at 6,880' MD and will target the A2 sand south of the existing well with a 2,570' lateral. The hole will be completed with a 2%"slotted liner to the TD of 9,450' MD with an aluminum billet at 7,400' MD. The 3H-12AL1 lateral will kick off from the aluminum billet at 7,400' MD and will target the Al sand beneath the 3H-12A lateral with a 1,350' lateral. The hole will be completed with a 2%" slotted liner to the TD of 8,750' MD with an aluminum billet at 7,300' MD. The 3H-12AL2 lateral will kick off from the aluminum billet at 7,300' MD and will target the A3 sand south of the existing well with an 2,200' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9,500' MD with the final liner top located inside the 31/2"tubing at 6,710' MD. Operational Outline Pre-Rig Work • Slickline: Pull CA2 Plug,DCR-1 shear valve and replace w/dummy, tag fill, obtain SBHP • E-line: Caliper/GR/CCL • E-line: Perforate the 3'/2"tubing tail • Coil: Mill the D-nipple • Coil: Lay/squeeze cement plug • Slickline: Tag TOC and PT to 1500 psi. • Prepare well site for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU BOPE and test. Pull BPV 2. Mill cement pilot hole. 3. Set top of whipstock at 6,880' MD. 4. Mill 2.80"window at 6,880'. 5. 3H-12A Sidetrack a. Drill a 2.70"x 3"bi-center lateral to a TD of 9,450' MD b. Run the 23/4" slotted liner with an aluminum liner top billet from TD to—7,400' MD. 6. 3H-12AL 1 Lateral 4.4° a. Kick off of the aluminum liner top billet at 7,400' MD P, b. Drill a 2.70"x 3"bi-center lateral to a TD of 8,750' MD c. Run the 23/4"slotted liner with an aluminum liner top billet from TD to—7,300' MD. PrP Page 2 of 5 'tet 7\ ! r‘ irs,, I A 6/27/2011 Permit to Drill Summary of Operations Cont. KRU 3H-12A,3H-12AL1,and 3H-12AL2 7. 3H-12AL2 Lateral 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 9,500' MD c. Run the 2%" slotted liner from TD to 6,710' MD, inside the 3-1/2" tubing tail of the mother-bore. Mud Program • Chloride-based Biozan brine (8.9 ppg)for milling operations, and chloride-based Flo-Pro mud (-9.70 ppg) for drilling operations. • 3H-12 does have a TRMAXX—CMT-SR-5 SSSV that can be utilized for liner running operations, however will depend on reservoir pressure stabilization. May use an 11.9 ppg NaBr as a completion fluid to maintain a consistent pressure on the openhole. 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 3H-12A 7,400 9,450 2%', 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3H-12AL1 7,300 8,750 2%", 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3H-12AL2 6,710 9,500 2%",4.7#, L-80, ST-L slotted Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppt) MD MD psi psi Conductor 16" 62 H-40 0 115 1,640 630 Surface 9 5/8" 36 J-55 0 3,103 3,520 2,020 Casing 7 " 26 J-55 0 7,225 4,980 4,330 Tubing 3 '/2" 9.3 L-80 0 6,663 10,160 10,540 Tubing 3'/2" 9.3 J-55 6,691 6,757 6,990 7,400 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 2615 psi assuming a gas gradient to surface based on the potential pressure from the combined A and C-sand interval that measured 3205 psi at 5900'TVDss. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: Page 3 of 5 6/27/2011 ORIGINAL Permit to Drill Summary of Operations Cont. KRU 3H-12A,3H-12AL1,and 3H-12AL2 • 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 3H-12A 6,350' 3H-12AL1 6,350 3H-12AL2 12,250' • Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset 3H-12A 1000' 3H-10B 3H-12AL1 1000' 3H-10B 3H-12AL2 1000' 3H-10B Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. Reservoir Pressure A combined zone SBHP was obtained on this well. The C and A Sand SBHP as of 5/31/11 was 3205 psi at a depth of 5900' TVDss which is equivalent to a 10.4 ppg EMW. The well has been shut in since then to reduce reservoir pressure for CTD operations. Hazards • 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. • 3H-16 had the maximum H2S level at 625 ppm on the 3H pad as measured on Oct. '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. The SSSV in well 3H-12 is operable for liner running operations, so the well may or may not be loaded with completion fluid prior to running slotted liner depending on maintaining a stable bottom hole pressure with potential losses to formation/faults. 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 6/27/2011 Permit to Drill Summary of Operations Cont. KRU 3H-12A,3H-12AL1,and 3H-12AL2 Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 3205 psi 3205 psi Mud Hydrostatic(9.70 ppg) 3006 psi 3006 psi Annular Friction 654 psi 0 psi Mud +Annular Friction 3660 psi 3006 psi (no choke pressure) (overbalanced (underbalanced —455 psi) —199 psi) TargetPressure (11.8 ppg) 3660 psi 3660 psi Choke Pressure Required 0 psi 654 psi to Maintain 13.1 ppg Example: Using the 3H-12 SBHP from May'11 with a reservoir pressure of 3205 psi at 5900 TVDss (10.4 ppg EMW). While drilling and circulating at 1.5 bpm with 2"e-coil, head from the 9.70 mud (3006 psi), plus an estimated 654 psi of annular friction (assuming friction of 95 psi/1000 ft)will provide 3660 psi BHP (11.8 ppg EMW) and will be overbalanced to the reservoir. More pressure can be applied to overbalance the reservoir. When circulation is shut down, the mud will be underbalanced to the reservoir pressure. However maintaining —654 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 3H-12 CTD laterals. The distances noted are the closest proximity between these wellbores and any point along the planned CTD laterals. — 3H-10B (active producer) — Currently a waivered well (7/15/2009) with IAxOA communication that was sidetracked in 2011 as a rotary setup for CTD operations. Well 3H-10B is a Kuparuk C-sand and A- sand production well equipped with 4'/z' tubing and 41/2" production liner. There are four proposed A- sand CTD laterals to increase reservoir exposure and offset the planned 3H-12 CTD injection laterals. Prior to rig arrival, a 4W mechanical whipstock will be set at the planned kickoff point of 6045' MD in 3H-10B. After setting the whipstock we will down-squeeze around the whipstock to permanently abandon the A-sand and C-sand perfs. — 3H-13A (active producer) — Currently a waivered well (1/20/2004) with IAxOA communication that was sidetracked in 1997. Perforations in the C and A sands through a 3-1/2" liner, from a 7" production casing. The last pressure was 2068 PSI (AC) in December 2009. There is a large fault interpreted to be sealing based on seismic between 3H-13A and 3H-12. Pressure data would suggest the fault is sealing also. Page 5 of 5 '" [� 6/27/2011 f P l n l y i Conochilhi Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H-12 3H-12AL1 Plan: 3H-12AL1_wp04 Standard Planning Report 14 June, 2011 BAKER HUGHES Ur GIN L lir ConocoPhillips la" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL 1_wp04 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3H Pad Site Position: Northing: 6,000,110.73ft Latitude: 70°24'41.531 N From: Map Easting: 498,655.44ft Longitude: 150°0'39.416 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 3H-12 i Well Position +N/-S 0.00 ft Northing: 6,000,450.51 ft Latitude: 70°24'44.873 N +EI-W 0.00 ft Easting: 498,655.38 ft Longitude: 150°0'39.420 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 3H-12AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2011 8/1/2011 16.50 79.91 57,367 Design 3H-12AL1_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,400.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 200.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) Target 7,400.00 89.42 252.69 5,994.81 2,767.96 629.85 0.00 0.00 0.00 0.00 7,470.00 79.56 249.06 6,001.52 2,745.18 564.11 15.00 -14.08 -5.19 200.00 7,540.00 77.74 238.51 6,015.34 2,714.92 502.62 15.00 -2.60 -15.07 259.00 7,674.58 91.00 223.18 6,028.59 2,630.63 399.44 15.00 9.85 -11.39 310.00 7,899.00 92.38 189.53 6,021.77 2,432.52 301.28 15.00 0.62 -14.99 272.80 8,049.00 91.82 212.04 6,016.19 2,293.28 248.43 15.00 -0.38 15.01 91.00 8,339.00 93.94 168.53 6,000.89 2,015.16 197.88 15.00 0.73 -15.00 273.80 8,439.00 90.47 183.13 5,997.03 1,915.79 205.11 15.00 -3.47 14.61 103.00 8,569.00 88.44 202.53 5,998.27 1,789.65 176.38 15.00 -1.56 14.92 96.00 8,750.00 88.62 175.37 6,003.00 1,612.59 148.50 15.00 0.09 -15.00 270.00 6114/2011 11:43:55AM Page 2 COMPASS 2003.16 Build 69 ' • -Iv- ConocoPhillips Fr- ConocoPhillips _ConocoPhtdhips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL1_wp04 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) 7,400.00 89.42 252.69 5,994.81 2,767.96 629.85 -2,816.45 0.00 0.00 6,003,218.08 499,285.67 TIP/KOP 7,470.00 79.56 249.06 6,001.52 2,745.18 564.11 -2,772.56 15.00 -160.00 6,003,195.31 499,219.92 2 7,500.00 78.73 244.55 6,007.18 2,733.58 537.03 -2,752.40 15.00 -101.00 6,003,183.72 499,192.85 7,540.00 77.74 238.51 6,015.34 2,714.92 502.62 -2,723.10 15.00 -100.15 6,003,165.07 499,158.44 3 7,600.00 83.60 231.58 6,025.07 2,681.01 454.17 -2,674.66 15.00 -50.00 6,003,131.17 499,109.98 7,674.58 91.00 223.18 6,028.59 2,630.63 399.44 -2,608.61 15.00 -48.87 6,003,080.81 499,055.26 4 7,700.00 91.18 219.37 6,028.11 2,611.54 382.68 -2,584.93 15.00 -87.20 6,003,061.72 499,038.50 7,800.00 91.85 204.38 6,025.44 2,526.89 330.05 -2,487.38 15.00 -87.27 6,002,977.09 498,985.85 7,899.00 92.38 189.53 6,021.77 2,432.52 301.28 -2,388.86 15.00 -87.67 6,002,882.73 498,957.07 5 7,900.00 92.38 189.68 6,021.72 2,431.54 301.11 -2,387.88 15.00 91.00 6,002,881.75 498,956.90 8,000.00 92.04 204.68 6,017.84 2,336.35 271.68 -2,288.37 15.00 91.01 6,002,786.57 498,927.45 8,049.00 91.82 212.04 6,016.19 2,293.28 248.43 -2,239.94 15.00 91.59 6,002,743.51 498,904.20 6 8,100.00 92.31 204.40 6,014.35 2,248.40 224.35 -2,189.54 15.00 -86.20 6,002,698.65 498,880.12 8,200.00 93.14 189.40 6,009.57 2,153.11 195.40 -2,090.09 15.00 -86.48 6,002,603.36 498,851.15 8,300.00 93.76 174.39 6,003.51 2,053.63 192.10 -1,995.48 15.00 -87.19 6,002,503.90 498,847.83 8,339.00 93.94 168.53 6,000.89 2,015.16 197.88 -1,961.31 15.00 -88.10 6,002,465.44 498,853.60 7 8,400.00 91.84 177.44 5,997.81 1,954.76 205.31 -1,907.10 15.00 103.00 6,002,405.04 498,861.02 8,439.00 90.47 183.13 5,997.03 1,915.79 205.11 1,870.40 15.00 103.45 6,002,366.07 498,860.82 8 8,500.00 89.51 192.23 5,997.04 1,855.40 196.96 -1,810.87 15.00 96.00 6,002,305.69 498,852.66 8,569.00 88.44 202.53 5,998.27 1,789.65 176.38 -1,742.05 15.00 96.00 6,002,239.95 498,832.07 9 8,600.00 88.45 197.88 5,999.11 1,760.58 165.68 -1,711.07 15.00 -90.00 6,002,210.88 498,821.36 8,700.00 88.53 182.87 6,001.76 1,662.53 147.73 -1,612.79 15.00 -89.87 6,002,112.85 498,803.40 8,750.00 88.62 175.37 6,003.00 • 1,612.59 148.50 -1,566.12 15.00 -89.48 6,002,062.91 498,804.15 TD 6/14%2011 11:43:55AM Page 3 COMPASS 2003.16 Build 69 i ` i 'a.,<1 i i a .i L. ConocoPhillips t111C3C<3PhIllI ? Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3H-12AL1 wp04 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3H-12AL1_T3 0.00 0.00 5,997.00 1,919.43 232.52 6,002,369.71 498,888.22 70°25 3.751 N 150°0'32.602 W -plan misses target center by 27.22ft at 8435.22ft MD(5997.06 TVD,1919.57 N,205.30 E) -Point 3H-12A,AL1,AL2 Pol 0.00 0.00 -76.00 2,879.64 1,029.45 6,003,329.67 499,685.24 70°25'13.193 N 150°0'9.231 W -plan misses target center by 6084.97ft at 7400.00ft MD(5994.81 TVD,2767.96 N,629.85 E) -Polygon Point 1 -76.00 2,879.64 1,029.45 6,003,329.67 499,685.24 Point 2 -76.00 3,004.49 325.35 6,003,454.64 498,981.24 Point 3 -76.00 535.09 -330.14 6,000,985.60 498,325.37 Point 4 -76.00 448.14 -60.10 6,000,898.61 498,595.37 Point 5 -76.00 2,580.51 595.48 6,003,030.65 499,251.26 Point 6 -76.00 2,425.56 875.54 6,002,875.67 499,53127 3H-12A lats Fault 1 0.00 0.00 -76.00 3,052.63 884.41 6,003,502.68 499,540.25 70°25'14.895 N 150°0'13.484 W -plan misses target center by 6082.81ft at 7400.00ft MD(5994.81 TVD,2767.96 N,629.85 E) -Polygon Point 1 -76.00 3,052.63 884.41 6,003,502.68 499,540.25 Point 2 -76.00 2,783.59 812.47 6,003,233.68 499,468.27 Point 3 -76.00 2,271.49 633.57 6,002,721.66 499,289.29 Point 4 -76.00 2,783.59 812.47 6,003,233.68 499,468.27 3H-12AL1_T4 0.00 0.00 6,003.00 1,614.40 172.56 6,002,064.72 498,828.22 70°25'0.751 N 150°0'34.360 W -plan misses target center by 24.18ft at 8748.55ft MD(6002.97 TVD,1614.03 N,148.38 E) -Point 3H-12A lats Fault 3 0.00 0.00 -76.00 1,634.33 -263.48 6,002,084.73 498,392.22 70°25'0.947 N 150°0'47.145 W -plan misses target center by 6091.24ft at 8640.27ft MD(6000.20 TVD,1721.68 N,155.37 E) -Polygon Point 1 -76.00 1,634.33 -263.48 6,002,084.73 498,392.22 Point 2 -76.00 1,576.40 73.57 6,002,026.74 498,729.22 Point 3 -76.00 1,316.67 1,328.75 6,001,766.81 499,984.23 Point 4 -76.00 1,576.40 73.57 6,002,026.74 498,729.22 3H-12AL1_T1 0.00 0.00 6,028.00 2,595.52 390.43 6,003,045.70 499,046.24 70°25 10.400 N 150°0'27.971 W -plan misses target center by 16.17ft at 7709.54ft MD(6027.90 TVD,2604.09 N,376.73 E) -Point 3H-12A lats Fault 2 0.00 0.00 -76.00 2,242.43 -2.55 6,002,692.71 498,653.23 70°25 6.927 N 150°0'39.494 W -plan misses target center by 6084.12ft at 8396.34ft MD(5997.94 TVD,1958.42 N,205.13 E) -Polygon Point 1 -76.00 2,242.43 -2.55 6,002,692.71 498,653.23 Point 2 -76.00 2,209.49 289.49 6,002,659.72 498,945.24 Point 3 -76.00 2,107.58 682.55 6,002,557.75 499,338.24 Point 4 -76.00 2,209.49 289.49 6,002,659.72 498,945.24 3H-12AL1_T2 0.00 0.00 6,015.00 2,249.46 186.47 6,002,699.71 498,842.23 70°25'6.996 N 150°0'33.952 W -plan misses target center by 35.40ft at 8109.99ft MD(6013.94 TVD,2239.26 N,220.35 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') (") 6,880.00 5,960.50 3 1/2" 3-1/2 4-1/2 8,750.00 6,003.00 2-3/8 2-3/8 3 6/14/2011 11:43:55AM Page 4 COMPASS 2003.16 Build 69 ORtGNA ,, yr- ConocoPhillips Fr,' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-12 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-12 @ 76.00ft(3H-12) Site: Kuparuk 3H Pad North Reference: True Well: 3H-12 Survey Calculation Method: Minimum Curvature Wellbore: 3H-12AL1 Design: 3 H-12AL 1_wp04 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,400.00 5,994.81 2,767.96 629.85 TIP/KOP 7,470.00 6,001.52 2,745.18 564.11 2 7,540.00 6,015.34 2,714.92 502.62 3 7,674.58 6,028.59 2,630.63 399.44 4 7,899.00 6,021.77 2,432.52 301.28 5 8,049.00 6,016.19 2,293.28 248.43 6 8,339.00 6,000.89 2,015.16 197.88 7 8,439.00 5,997.03 1,915.79 205.11 8 8,569.00 5,998.27 1,789.65 176.38 9 8,750.00 6,003.00 1,612.59 148.50 TD 6/14'2011 11:43:55AM Page 5 COMPASS 2003.16 Build 69 IP W• 1 _8 8 `�� _ DO R rc j 8 Z O 4liviiifti . . I w §8§g E, iI I .. 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TRANSMITTAL LETTER CHECKLIST WELL NAME ) PTD# Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: - POOL: Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a newwellborese ent of existing well J��2/ ( l / it—7 �f (If last two digits in Permit No. 7_//6.)V,API No. 50-/0-3- �'-Ti "�- �'J/. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to 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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