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210-114
New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 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. c 1 Q - I 4_ Well History File Identifier Organizing(done) ❑ Two-sided 1 III III ❑ Rescan Needed II IIIIIUI I III RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: 1y cale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner oor Quality Originals: p 1 OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria ) Date: a /s/7J/L Project Proofing 11311111 11 III BY: aria ) Date: a 71 4 /s/ rv1f Scanning Preparation I x 30 = 30 + = TOTAL PAGES sei does not include cover sheet)( )'J • BY: Maria Date: _ /s/ Production Scanning I ( Stage 1 Page Count from Scanned File: 1-1-0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: kES NO BY: a .. Date: � 11 111.- /s/ vid F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 111 BY: Maria Date: Is/ Scanning is complete at this point unless rescanning is required. 1311111 1111 ReScanned 1 11111111111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked II llhIIIIllhIIII 19/99/9(111 1AI II Hictnni it Cns,cr Pnnc rinr. I a j C 1 9 . o r N I 4' 2 0 co 3 O N N Z a O co....(0 U` o fie N U 1 c co ceo° U` C7 O a a rt Ix O 4? E 2-0m O in m E coma a Cl. g 2 2 p Z � j 0 U O F-Q 0 ma a 2 2 1- a a a � Y. o v Q To C N o 0 0 0 0 0 0 o 0 a0 >.6 o 0 0 0 0 0 0 ■ J U I O N N N N N N N N U O Q O N N N N N N N Z_ E c N 2 �- N c c C c C c C c C C C E '� N N N w N N N N N 0 0 m c = = a s a a 0. 0. a 0. a a a a Y OU O O 0 0 0 0 0 0 0 0 0 E N J c :D U O- a P_) O. N N N co co N N N M M M f) O M M r) U) IC) CO M M to t IC) 0) y Z Z a. .. v v v oo ao v v v CO ao ao ao „ a 7. cr, CD E J , MI I t o n o 0 o u) u) u) v) u) u) N Z 1i O '•4 a`g'o `O co o o 0) v v v v v v �,. 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C° -° AA o o8 o3o 08 o eo � cn , -° * , m3 m -. -I � ..{ 3K IC 3 i co � eaD 3 o -0'D a•co o o. = -n-°.to • m • 3. = r 0 51 < m ° o Q m m (D T v - d co -CD - -0 M a D. ▪ 3 r-(5. » -n . �' . � .--> to O . r a C CD CD m -1 SD Q - C , a _ v• m < Q O g„•= . m - m - m , ez Qm s •O t0 if N O Q � O — Co O cr En (7 O O 7 Z o w a _ a o a a c D cr - CD s - o m C C 3. a' •- r c CD o y •- O m Cn — CD N 7 CD N -' °- N o tli Nom°• O n - O O N co o CD N ' �7 0 O Q C CD O n Q ° d CD c a_ a• O O O CD 0 Cn 8 Z• o ,`< o _77 < -, CT CD • d Q TI'°CD 0 C in c. 0 w ca a 0 - Q ° - o `° CD CD W ev k�J Om\ I� 1 a co Company ConocoPhillips, Alaska, Inc. Well Name 3A-17AL1 PB1 Date 11/22/2010 ES nocoPhillips Alaska Greater Kuparuk Area*** Data Distribut RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy i'rinr, Christine Mahnken 1 Graphic image file 1 Dish*/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM /TIFF LIS 'fir and on Tucker, NR T State of Alaska; DNR, Div. of Oil and Gas 1 Disc 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS DS Engineer / Rig Foreman TOTAL Hardcopy Prints 4 Graphic Image File 4 2l c u 6C) l Page 1 of 4 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil 0 . Gas ❑ SPLUG ❑ Other El Abandoned El Suspended El 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development • • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test El 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: October 11,2010 210-114/ ' 3.Address: 6.Date Spudded: /, 13.API Number: r P.O.Box 100360,Anchorage,AK 99510-0360 , September014 /f'I1'/ 50-029-22691-60/50-029-22691-70 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 663'FSL,785'FEL,Sec.7,T12N, R9E,UM October 1,2010 3A-17AL1 /3A-17AL1 PB1 Top of Productive Horizon: 8. KB(ft above MSL): 82'RKB 15.Field/Pool(s): 1391'FNL,2450'FEL,Sec. 17,T12N, R9E, UM GL(ft above MSL): 40'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2532'FNL,3341'FEL,Sec. 17,T12N, R9E,UM 7362'MD/6006'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-507663 • y- 5997044 • Zone-4 • 9432'MD/6069'TVD • ADL 25631,25632 TPI: x-511287 y- 5994995 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-510401 y- 5993853 Zone-4 nipple @ 508'MD/508'TVD 2564,2565 18.Directional Survey: Yes III No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1465'MD/1445'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 7838'MD/6107'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 121' Surf. 121' 24" 212 sx AS I 7.625" 29.7# L-80 Surf. 3821' Surf. 3306' 9.875" 1020 sx AS III,340 sx Class G 5.5"x 3.5" 15.5#/9.3# L-80 Surf. 7782' Surf. 6334' 6.75" 190 sx Class G 2.375" 4.6# L-80 7411'• 9430' ' 6045' 6069' 3" slotted liner • 24.Open to production or injection? Yes is 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" 7272' none slotted liner for 3A-17AL1 7488'-8396'MD 6095'-6119'TVD _ ;Ct ' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 8398'-9431'MD 6119'-6069'ND J! , DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1* r,..� slotted liner for 3A-17AL1PB1 ;' 7840'-8046'MD 6106'-6098'TVD ,M 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) October 17,2010 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/19/2010 12 hours Test Period--> 984 338 963 24 Bean 421 Flow Tubing Casing Pressure Calculated .OIL-BBL .GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 179 psi 269 24-Hour Rate-> 1805 760 1893 23.5 deg. 28. CORE DATA Conventional Core(s)Acquired? Yes El No is Sidewall Cores Acquired? Yes ❑ No 0 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 NONE RECEIVED Ni i l\/ 0 R 7010 RBDMS NOV 05 20. ;_,,� a&�a�Cons.Co on Form 10-407 Revised 12/2009 CONTINUED ON REVERSE r r lit original or]hc ((i L, 74 /�HY/e) iel'0 , /, 6 28. GEOLOGIC MARKERS(List all formations and market.0ncountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1465' 1445' needed,and submit detailed test information per 20 AAC 25.071. A-2 sand 8472' 6120' Bottom A-2 sand 8768' 6079' Top A-3 sand 7838' 6107' Bottom A-3 sand 8768' 6079' 3A-17AL1PB1 Total depth 8853' 6064' N/A Formation at total depth: Kuparuk A3 sand 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,definitive directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact/ Jill Long @ 263-4093 Printed Nam V. awv Title: Alaska Wells Manager VV (1(0.5(10�r -1 Signature Phone 265-6306 Date OP Z• 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 0 0 o :r N d a @ a 0 0° o n ro 0 m ° > o J O N N 0 ,7 m C Yd a - / L A d o (;) ;0',702 E N E I «R V N O Q O `� 1CO o c m I ar'm . C o E a J©cn L 0 11\. 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C U O)��ll T Q O Q N v d 1 J Q 0 N Q Q F o CO KU P 3A-17AL1 ConocoPhillip5 r Well At�ribfttes JMax Angle&M D TD Alaska.)Ik' ^'<VI Wellborn APUUWI Field Name Well Status Inc!(3 IMD(ftKB) Act Blrn(ftKB) � 500292269160 KUPARUK RIVER UNIT PROD 9,430 0 Comment H2S(ppm) Dab Annotation End Date KB-Grd(ft) Rig Release Date .�„�„g+pJlC171,L1, tq8, ge4,_ SSSV:NIPPLE 220 3/15/2009 Last WO: 41 00 9/2/1996 iC.A A nobtion Depth(kK8) Entl Data Annotat on Last Mod By End Date Last Tag I Rev Reason-SIDEI RACK WELL w/LATERALS I Imosbor 10/12/2010 I Casing Strings 1 Casing Description String 0... IString ID .Top(ftKB) Set Depth(f.--Set Depth(TVD) String Wt...String.. String Top Thrd HANGER,37 LINER AL7 23/8 1.995 7,409.5 9,430.0 4.60 L-80 STL Liner Details Top(ND) Top Mcl Natal..Top Depth �' I Top(Rat) (k(B) (•) Item Deset_pl lion Comment ID(in) CONDUCTOR, I 7,409.5 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 40-121 Ir 8,395 51 Perforations DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 NIPPLE,508 1111P --- - - ---- lions&Slots Shot -- -------"� Top(TVD) She(TVD) Dens Top(RKBLehn MUM_ (ftKB) (RKB) Zone Date I(eh-- T Cwnmam GAS 2.562 7,488.0 8,396.0 A-4,A-3, 10/2/2010 32.0 SLOT Slotted I p'pe-0.125"x2.5' 4 3A-17AL1 circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends 8,398.0 9,431.0 A-3,A-2,A-3, 10/2/2010 32.0 SLOT Slotted pipe-0.125"x2.5^C 4 A-4,3A-17AL1 circumferential adjacent rows,3' centers staggered 18 deg,3' SURFACE. ,a, non-slotted ends 39-3,821 Notes Generale Safety GAS LIFT, _ End Date _.- Annotation 4,236 10/12/2010 'NOTE:WELL SIDETRACKED,3A-17A,AL7 ALI,AL2,AL2-01 GAS 5,25UFT,_ 0 GAS 6,114 LIFT, yarl GAS LIFT,8,753 @' @__. I . [ 1 GAS LIFT, 7,198 t[ 71 NIPPLE,7,251 , SEAL Ass,' 7,258 WHIPSTOCK 4 1 (AL25 7,396 ' SLOT, 7,388-7,420 tt WHIPSTOCK, - I� 1 7,412 ■ PRODUCTION 5.5'%3.5', 35-1,782 SLOT, 7,488-8,398 SLOT, Mandrel Details 7,497-9,249 - ITop Depth'' Top Port ' SLOT, 1 Stn (TVD) Ind OD Valve Latch Sian TRO Run 8,398-9,431 AL2-01, Top ftKB (ftKB) ('I Make Model (in LINERAL2-01, 1 _ 2. ) ) Sery Type -1 .00 (psi)0 Run/010 Com... 7,381-9,250 I 1 2,961.6 BST A;X 1 GAS LIF I urav T-1 0.000 0.0 8/20/2070 2 4,235.5 BST A I X 1 GAS LIFT DMY T-1 0.000 0.0 9/14/1996 3 5,254.5 BST AIX 1 GAS LIFT GLV T-1 0.156 1,335.0 11/30/1996 Note t 4 6,114.3 BST AIX 1 GAS LIFT DMV T-1 0.000 0.0 9/14/1996 I 5 6,752.7 BST AIX 1 GAS LIFT DMY T-1 0.000 0.0 8/22/2010 6 7,197.8 BS f A I X 1 GAS LIFT DMY T-1 0.000 0.0 2/4/2007 LINER AL1, II 7,410.9,430 TO(3A-17AL15 9,430 l ll 411 au 41 IX LIZ!we 0 __ is 0 O. co co �LLI OC VI 1 Q 1— >, O. j Z aw •.�... 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O O O O O O O O O O O O O O O O O tM U) 0 0 0 0 0 0 0 0 0 M O C L Q^ O c, ..1- N- O M co O <,:1 ,4 OO .- V no CO (O O .- Loco ,- ,1- N- O M co O U) o l0 _ 0 C T v C) O O O .- `- .- .- N M M M V V V V U) U) U) CO (D (O r r n N- CO 0 fl. m .0 0) Cl r co co co co W co co CO CO CO CO CO CO CO CO CO CO OD OD CO CO CO CO CO M O CO OD CV E 4 v 0 m a) 3 S3 Q to O Cl) o C- Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:15 15:30 1.25 1,414 7,200 COMPZ CASING TRIP P RIH pumping .3 bpm.Two guide plates sheered off backside of Injector cart.-Driller slowing down for flag and the injector weight spiked by 10K.(surface weight)when the plates bolts sheared off. 15:30 17:00 1.50 7,200 7,200 COMPZ CASING CTOP T Troubleshooting-Injector centered over well, RIH with less reel tension to watch the difference. POOH 200 ft pipe looked good, RIH-no problems. 30K P/U. 17:00 17:45 0.75 7,200 8,785 COMPZ CASING TRIP P RIH-flag-5.4'correction. RIH tagged up @ 8789'-TOB @ 7412'-Could be stuck in window with Billet.Work pipe with Max. P/U of 35K.Worked it 5 times.Stop&pump.4 bpm to try and move billet.Start Moving up hole 35K surface weight&-10K on BHA. 17:45 21:00 3.25 8,785 1,415 COMPZ CASING TRIP T P/U 300ft for hand-over-RIH one more time to see if anything changed. RIH and tagged same spot 5 times at slower speeds, no luck tagging same spot @ 8788'POOH to inspect Al. Billet. 21:00 23:00 2.00 1,415 1,415 COMPZ CASING PULD T At surface. PJSM to make down liner running tools. Stand back running tools to inspect. Small amount of drill cuttings and metal shavings at FVS union,but no major materials packed off around tools. Nor any marks or scratches on the running tools or billet to indicate hang up in window. Did, however, consider the likelihood of harsh shoulder at knuckle joint hanging up at window. Discussed with CTD Engineer to re-run liner assembly minus the knuckle joint,and also changing the FVS to one without a C-plate slot. PJSM for change of scope. Reconfigured BHA and made up to liner string for second liner run. 23:00 00:00 1.00 1,415 4,386 COMPZ CASING RUNL T RIH. 09/27/2010 Ran the A-lateral liner with aluminum liner top billet;TOB 8008'. Layed down liner running tools and picked up AL1-lateral drilling BHA with 1.1-deg AKO. Kicked off liner top billet at 8008',40-deg right of high side. Drilled ahead AL1-lateral to 8507'. 00:00 00:30 0.50 4,386 7,319 COMPZ CASING RUNL T Continue RIH liner assembly BHA, minus the knuckle joint,and changing the FVS to one without a C-plate slot. Stop at flag(7319.3') and correct to 7313.68'. Continue RIH. 00:30 00:45 0.25 7,313 7,428 COMPZ CASING RUNL T Continue to RIH liner assembly. 00:45 01:30 0.75 7,428 9,382 COMPZ CASING RUNL T RIH into open hole. Page 7 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:30 01:45 0.25 9,382 9,382 COMPZ CASING RUNL P Tag TD. Perform weight check. RIH to bottom. Release liner. 01:45 02:15 0.50 9,382 7,175 COMPZ CASING RUNL P PUH for logging run-tie-in. Stop at 8545. Change EOP depth to 7175.13'. 02:15 02:30 0.25 7,175 7,209 COMPZ CASING RUNL P RIH logging to tie-in gamma. (-2' correction.) Makes sense with 9381.5 versus 9380'TD. ***Estimated Top of Liner is 8010".*** 02:30 04:00 1.50 7,209 37 COMPZ CASING RUNL P POOH circulating completion fluid (12-ppg K-Formate). 04:00 04:30 0.50 37 37 COMPZ CASING RUNL P Tag up. Monitor well for flow/no-flow. PJSM for lay-down liner running tools and pick-up drilling BHA. Prep to PU/LD tools. 04:30 05:00 0.50 37 0 COMPZ CASING PULD P Lay down liner running BHA 05:00 06:00 1.00 0 71 PROD2 STK PULD P Pick up drilling BHA.with 1.1 AKO and re-run Bicenter. 06:00 09:30 3.50 71 8,008 PROD2 STK TRIP P RIH-tie in-8ft,Sit @ 7380 and circulate out KWF.Good 1:1 returns during entire process.Close EDC& RIH. Dry tag TOB @ 8008'. 09:30 12:30 3.00 8,008 8,030 PROD2 STK KOST P P/U weight 28K,bring pumps online @ 40 right.Start milling 8007.5'Al. returns to surface @ 8008'.Milled as per procedure,with no stalls. Increase drilling ROP @ 8017'to 8030'.27K P/U clean drift through billet. 12:30 15:30 3.00 8,030 8,160 PROD2 DRILL DRLG P Drilling ahead-1.43 bpm,3600, BHP 3930, ECD 12.5, ROP 60,WOB 2.4K,Ct weight 8K. 15:30 16:30 1.00 8,160 8,160 PROD2 DRILL WPRT P P/U weight 29K -billet looked clean. 16:30 18:45 2.25 8,160 8,310 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm,3950, ECD 12.6, ROP 66,WOB 2.3,Ct weight 10K. 18:45 20:00 1.25 8,310 8,310 PROD2 DRILL WPRT P Wiper trip. PUW 28k#. Pulled up to 7447'. Set down through 8168'. Pulled back up through 8168'and RBIH. Smooth second time through. 20:00 21:45 1.75 8,310 8,460 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm,3950, ECD 12.8, ROP 85,WOB 1.8,Ct weight 10K. 21:45 23:30 1.75 8,460 8,460 PROD2 DRILL WPRT P Wiper trip with tie-in. PUW 28k#. PUH to 7437'. RIH logging the RA marker(7437-7458')and determine (+1')correction. RIH and set down 8171'. Pulled up and run in slow past 8171'with slight bobble. Pulled back up through to clean up area and RBIH. Slight bobble down through again. 23:30 00:00 0.50 8,460 8,507 PROD2 DRILL DRLG P Drilling ahead-1.4 bpm,3950, ECD 12.8, ROP 94,WOB 1.8,Ct weight 10K. 09/28/2010 Drilled AL-1 Lateral to 8853.Stuck on wiper trip @ 8484.Work free. POOH for FCO BHA Page 8 of 20 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 01:15 1.25 8,507 8,600 PROD2 DRILL DRLG P Continue drilling ahead-1.4 bpm, 3950, ECD 12.8, ROP 74,WOB 1.8, Ct weight 10K. 01:15 02:45 1.50 8,600 8,600 PROD2 DRILL WPRT P Wiper trip. PUW 28k#. Pulled up to 7450'. Set down through 8172'. Pulled back up to 8125'and RBIH, this time smooth down through. Added drum of clay guard to mud system. 02:45 04:30 1.75 8,600 8,760 PROD2 DRILL DRLG P Continue drilling ahead-1.4 bpm, 3950, ECD 12.8, ROP 91,WOB 1.6, Ct weight 10K. (Performed fire drill on rig 03:30. 100%correct responses, rig and third-party personnel.) 04:30 06:30 2.00 8,760 8,760 PROD2 DRILL WPRT P Wiper trip. PUW 28k#. Pulled up to 7445'. No set downs,slow pump rate to 1 bpm near troubled area. 06:30 07:00 0.50 8,760 8,853 PROD2 DRILL DRLG P Drilling ahead-Start pumping new mud. Shaker bolt sheared off bracket.Wiper trip 60ft early. 07:00 08:00 1.00 8,853 7,400 PROD2 DRILL WPRT T POOH-Wiper trip for shaker problems,taking old mud returns to Tiger tank. New mud @ surface, bypass shakers&take into Shaker pit.TF drag from 8150'-8138'2K overpull. 08:00 09:00 1.00 7,400 5,000 PROD2 DRILL WPRT P Pull up through window.trap pressure&open EDC.Wipe up the cased hole.Shaker back operational. Noticed more cutting rolling over shaker while doing wiper in cased hole-current depth 5000'. 09:00 10:00 1.00 5,000 2,200 PROD2 DRILL WPRT P Continue wiping up to 2200',cutting cleaned up around 2800'. 10:00 10:30 0.50 2,200 2,400 PROD2 DRILL CIRC P 2200' slug of shale cutting came across shaker&plugged off choke. Flush chokes,circulate&cleaned up remaining shale-RIH. 10:30 12:00 1.50 2,400 8,495 PROD2 DRILL TRIP P RIH-Tie in @ window with-2 ft correction.-continue RIH,tagged up hard @ 8595' 12:00 14:00 2.00 8,495 8,495 PROD2 DRILL CIRC T Stacked @ fault section. Pump pressure increased to 4800.Torqued into it. Differential 2000 psi.Worked the string 7 tiems, circ.3300,diff 1500.Try to roll tool. Bit stuck. Depths WOB 7K=8495'/WOB- 17K 8484' Cycle pipe up/down 8 times,pump rate.5 bpm, pressure 3300 psi. Page 9 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:00 15:00 1.00 8,495 8,495 PROD2 DRILL CIRC T Attempted trapping pressure on CT and pumping down backside to 4000 psi BHP.Attempted to pull.Able to rotate HOT. Max.pull-62K surface/-17K WOB Max.push-11K Surface/+8K WOB No luck. 15:00 15:15 0.25 8,495 8,483 PROD2 DRILL CIRC T Pump back down threw CT- increase pump rate to 1 bpm,Circ. 4500psi-BHP Bore 6300 psi, Pulled 60K into and as we relaxed to RIH is popped free. Total of 56 cycles-CT life&cycles Y Y in a good spot 50 bbls loss to formation during process 15:15 16:15 1.00 8,480 7,400 PROD2 DRILL TRIP T POOH to inspect BHA following MPD-all corns working to BHA. Starting getting oily returns when POOH 7500'-Returns to U.Get above window and Circ.out oily returns.7 bbls. 16:15 18:15 2.00 7,400 0 PROD2 DRILL TRIP T POOH pumping through EDC. 18:15 21:27 3.20 0 0 PROD2 DRILL PULD T At Surface, PJSM, Pressure un deploy BHA#9 Blow down and break down. Bit had minor chipping on teeth and two plugged ports. No other apparent damage to BHA 21:27 21:45 0.30 0 0 PROD2 DRILL BOPE P Bi Weekly BOPE Function test 21:45 23:45 2.00 0 62 PROD2 DRILL PULD T PJSM, Deploy BHA#10,Surface test tool Open EDC 23:45 00:00 0.25 62 200 PROD2 DRILL TRIP T Trip in well following MP Schedule 09/29/2010 Ran Fill Clean out to 8050. Run PB1 Liner to 8046 TOL Billet @ 7840 P/U Drill By BHA, Dry Tag Billet @ 7838.Trough and time drill by 00:00 01:45 1.75 200 7,190 PROD2 DRILL TRIP T Continue in well 01:45 01:57 0.20 7,190 7,225 PROD2 DRILL DLOG T Log Tie in for a-8.5.Shut EDC 01:57 03:21 1.40 7,225 8,050 PROD2 DRILL TRIP T Clean run through window,Clean trip past billit Get down to 8050, Pump Lo Hi Sweeps,Chase up hole 03:21 03:33 0.20 8,050 7,430 PROD2 DRILL DLOG T 7430, Log RA Marker on Whipstock +3'correction 03:33 04:03 0.50 7,430 7,440 PROD2 DRILL TRIP T RIH to lay in beaded liner running pill 04:03 06:03 2.00 7,440 62 PROD2 DRILL TRIP T 8050 POOH laying in Beaded pill followed by KWF 12.0 PPG PUW=30k Paint EOP Flags @ 7700'(Orange) &7100'(red) Page 10 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:03 07:33 1.50 62 0 PROD2 DRILL PULD T Flow-check-lay down BHA @ surface. 07:33 08:33 1.00 0 0 PROD2 STK PULD T prepare rig floor for liner&safety meeting 08:33 10:33 2.00 0 268 PROD2 STK WPST T Pressure test CT connector to 4K- good. P/U 6 joints of liner,Anchor billet&Coiltrac. 10:33 12:33 2.00 268 8,046 PROD2 STK WPST T RIH with EDC open pumping.3bpm. -6.4'correction. P/U weight 28K, Close EDC. RIH 12:33 13:03 0.50 8,046 7,840 PROD2 STK WPST T Orient 175 R-bring pumps online. WOB-1.3K,pump up to 3400 psi, good set,WOB 6K. P/U weight 29K. TOB=7840' 13:03 16:03 3.00 7,840 62 PROD2 STK TRIP T POOH laying in KWF.Ct @ surface -flo-check. 16:03 17:03 1.00 62 0 PROD2 STK PULD T Lay down BHA#11 17:03 17:33 0.50 0 72 PROD2 STK PULD T P/U BHA#12 1.1 degree motor Bi-Center bit 17:33 19:15 1.70 72 7,210 PROD2 STK TRIP T RIH 19:15 19:21 0.10 7,210 7,402 PROD2 STK DLOG T Tie In-9'correction 19:21 21:51 2.50 7,402 7,402 PROD2 STK CIRC T Pump 20 BBI pill,circ out KWF 21:51 22:03 0.20 7,402 7,838 PROD2 STK TRIP T 9.8 Drilling fluid around, RIH to trough /time mill off billet 22:03 23:03 1.00 7,838 7,837 PROD2 STK KOST T 7838', Dry tag TOB,start troughing up hole 150L 1 FPM PUW=29K 1.4 BPM @ 3178 BHP=3890 23:03 00:00 0.95 7,837 7,838 PROD2 STK KOST T 7837.6 Saw WOB start time drilling 1.4 BPM @ 3170 BHP=3797 09/30/2010 Time drill by Billet @ 7838, Drill towards planned TD @-9400' 00:00 01:06 1.10 7,838 7,841 PROD2 STK KOST T Time Milling(cont) 01:06 01:30 0.40 7,841 7,845 PROD2 DRILL DRLG T 7841 Start drilling ahead @ 10 FPH 1.41 BPM @ 3069 BHP=3793 01:30 01:45 0.25 7,845 7,848 PROD2 DRILL DRLG T 7845, Drill ahead 20 FPH 01:45 01:57 0.20 7,848 7,860 PROD2 DRILL DRLG T 7848 Drilling ahead @ 44 FPH 01:57 02:07 0.18 7,860 7,860 PROD2 DRILL WPRT T 7860 Mini wiper to check side track area Looks clean 02:07 03:31 1.40 7,860 7,990 PROD2 DRILL DRLG T 7860', Drill ahead 1.45 BPM @ 3252 FS, 150L TF BHP=3892 03:31 04:16 0.75 7,990 7,990 PROD2 DRILL WPRT T 7990 Wiper to window PUW=28k 04:16 06:29 2.23 7,990 8,290 PROD2 DRILL DRLG T 7990'Drill Ahead 1.44 BPM @ 3195PSi FS BHP=3880 ROP=120 FPH 06:29 06:44 0.25 8,140 8,140 PROD2 DRILL WPRT T 8140'Wiper up to 7450 Wt28k Page 11 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:44 07:44 1.00 8,140 8,290 PROD2 DRILL DRLG T 8140'Drill Ahead 1.43 BPM @ 3377 PSI BHP=3744 ROP 120'FPH 07:44 08:29 0.75 8,290 8,290 PROD2 DRILL WPRT T 8290'Wiper up to 7440' WT off BTM 28k Tie in pass from 7445 to 7460' +1 08:29 10:14 1.75 8,290 8,440 PROD2 DRILL DRLG T 8290'Drill Ahead 1.4 BPM @ 3450 PSI BHP=4300 PSI ROP 120'FPH 10:14 11:14 1.00 8,440 8,440 PROD2 DRILL WPRT T 8440'Wiper up to 7453' 11:14 13:14 2.00 8,440 8,590 PROD2 DRILL DRLG T 8440'Drilling ahead 1.45 BPM @ 3600 PSI BHP=4528 PSI ROP 120 FPH 13:14 14:29 1.25 8,590 8,590 PROD2 DRILL WPRT T 8590'wiper up to 7438' 14:29 15:59 1.50 8,590 8,740 PROD2 DRILL DRLG T 8590'Drill Ahead 1.4 BPM @ 3850 PSI BHP 4742 PSI ROP 120 FPH 15:59 17:29 1.50 8,740 8,740 PROD2 DRILL WPRT T 5 bbls Low/5 bbls high pill at bit 8740'wiper up to 7442' Log down for tie in(-1/2') 17:29 18:59 1.50 8,740 8,890 PROD2 DRILL DRLG T Drilling Ahead 1.44 BPM @ 3559 PSI FS BHP=3977 18:59 20:44 1.75 8,890 8,890 PROD2 DRILL WPRT P 8890'Wiper to window PUW=29K 20:44 22:13 1.49 8,890 9,040 PROD2 DRILL DRLG P 8890', Drill Ahead 1.41 BPM @ 3320 PSI FS BHP=3981 22:13 23:58 1.75 9,040 8,520 PROD2 DRILL WPRT P Wiper to window, PUW=28K Midnight Depth 8520 10/01/2010 TD well @ 9432,Wiper trip to surface, RBIH,tie in for-4.5 correction,Tag @ 9432. POOH laying in Liner running pill/KWF, Pick up lower liner section 00:00 00:18 0.30 8,520 9,040 PROD2 DRILL WPRT P 8050 Continue wiper trip 00:18 01:54 1.60 9,040 9,190 PROD2 DRILL DRLG P 9040 Drill Ahead, Pump Lo Hi Sweep 1.40 BPM @ 3301 FS BHP=3981, ECD=12.8 01:54 03:12 1.30 9,190 7,445 PROD2 DRILL WPRT P Wiper trip to window with tie in PUW=28K 03:12 03:18 0.10 7,445 7,460 PROD2 DRILL DLOG P Log RA Marker-.5'correction 03:18 04:18 1.00 7,460 9,190 PROD2 DRILL WPRT P Head back to bottom 04:18 06:15 1.96 9,190 9,340 PROD2 DRILL DCSG P 9190, Drill Ahead 1.42BPM @ 3450 FS RIW=8K BHP=3990 ROP=100 FPH 06:15 08:45 2.50 9,340 9,340 PROD2 DRILL WPRT P 9340' Wiper trip up to 7455' 29k pu wt off btm. RIH back to BTM. 08:45 09:45 1.00 9,340 9,432 PROD2 DRILL DRLG P 9340'Drill Ahead 1.41 BPM @ 3600 PSI FS BHP=4658 09:45 14:00 4.25 9,432 100 PROD2 DRILL WPRT P Gamma not looking good.Get call from town to stop drilling.TD @ 9432'Pump 5 bbs Lo/10 HI Vis sweep pill.Wiper up to surface. Page 12 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:00 15:30 1.50 100 7,200 PROD2 DRILL TRIP P RBIH 15:30 15:45 0.25 7,200 7,300 PROD2 DRILL DLOG P Log for Tie in -4.5'. 15:45 17:00 1.25 7,300 9,432 PROD2 DRILL TRIP P RBIH,close EDC @ 7402' Tag TD @ 9432 17:00 17:30 0.50 9,432 9,432 PROD2 DRILL CIRC P Circulating Beaded liner pill down coil 17:30 20:18 2.80 9,432 71 PROD2 DRILL TRIP P Trip out of well laying in beaded liner running pill/KWF Paint EOP flags @ 7200,6200 EOP 20:18 21:48 1.50 71 0 PROD2 DRILL PULD P Lay down BHA#12. Blow down and break down. Prep to run liner 21:48 22:15 0.45 0 0 COMPZ CASING PUTB P PJSM, P/U AL1 lower section of liner Indexing guide shoe,32 joints slotted liner Shorty deployment sleeve Perform safety joint drill 22:15 23:06 0.85 0 0 COMPZ CASING SFTY T Hand Injured on rig/transport to medic/Stand down 23:06 23:59 0.89 0 0 COMPZ CASING SFTY T Stand down 10/02/2010 Run AL1 Liner in two sections BOL 9430'TOL @7411, RIH with Upper Whipstock 00:00 05:00 5.00 0 0 COMPZ CASING SFTY T Suspend ops for injury investigation 05:00 08:00 3.00 0 0 COMPZ CASING PUTB P PJSM-P/U liner. 08:00 10:30 2.50 0 9,432 COMPZ CASING RUNL P RIH W/liner run#1.Get pu wt of 30k. Rih down AL1 lat, smooth all the way to tag up 9432'. Pump off liner w/no problem-POOH 10:30 11:30 1.00 9,432 9,432 COMPZ CASING DLOG P Stop @ 8210'. Re-set bit depth to 7175'. Log down to RA marker, TOWS @ 7413'. PUH,paint flag. 11:30 13:15 1.75 9,432 0 COMPZ CASING TRIP P POOH to Surface. 13:15 17:00 3.75 0 0 COMPZ CASING PULD P OOH.Conduct Un-deploy safety meeting.Stab off well, LD BHA. Load up AL1 Liner#2 17:00 18:24 1.40 0 7,238 COMPZ CASING RUNL P RIH W/AL1 Liner Run#2 18:24 19:18 0.90 7,238 7,229 COMPZ CASING RUNL P Stop and correct to flag,-8.3' PUW=29k 19:18 19:33 0.25 8,396 7,247 COMPZ CASING RUNL P 8396',Tag up, Pump off liner, 1.3 BPM @ 39K PUW=26K TOL=7410 Remove Liner lenth from counters PUH to 7170 and tie in 19:33 19:39 0.10 7,247 7,198 COMPZ CASING DLOG P 7170,Tie in,-.5'correction calling TOL 7410 19:39 21:24 1.75 7,198 65 COMPZ CASING TRIP P Continue out of well 21:24 21:39 0.25 65 65 COMPZ CASING SFTY P PJSM/Flo test well 21:39 22:33 0.90 65 0 COMPZ CASING PULD P Lay down BHA#14 Liner running tool 22:33 23:51 1.30 0 70 PROD3 RPEQP1PULD P P/U BHA 15 Upper whipstock Surface test tool,tag up and set depth Open EDC Page 13 of 20 SITATIE LIEF a IL /i / SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-17AL1 ConocoPhillips Alaska, Inc. Permit No: 210-114 Surface Location: 663' FSL, 785' FEL, SEC. 7, T12N, R9E, UM Bottomhole Location: 2871' FSL, 3200' FEL, SEC. 17, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3A-17A, Permit No 210- 113, API 50-029-22691-01. 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. incerely, Daniel T. Seamount, Jr. Chair DATED this3/ day of August, 2010. cc: Department of Fish 8; Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECENED STATE OF ALASKA i-t ! 0 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska a 7.n Gs;Cam.Commission 20 AAC 25.005 A;iCii+lftagO la.Type of Work: , Proposed Well Class: Development-Oil lg ' Service-Winj El Single Zone ,lc.Specify if well is proposed for: Drill ❑ Re-drill MI 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: In Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 ' 3A-17AL1 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): ' P.O.Box 100360 Anchorage,AK 99510-0360 MD:9200' TVD: 6000' * Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:663'FSL,785'FEL,Sec.7,T12N,R9E,UM. ADL 25631;25632 . Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: Top of Kuparuk:4219.95 FSL,2653.2'FEL,Sec.17,T12N, R9E,UM 2564,2565 9/5/2010 Total Depth: 9.Acres in Property: 14.Distance to TD:2871'FSL,3200'FEL,Sec. 17,T12N,R9E,UM 2560 Nearest Property: 22650' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 82 feet 15.Distance to Nearest Well Open Surface:x- 507663 y- 5997044 . Zone- 4 GL Elevation above MSL: 41 feet to Same Pool: 3A-07,1200' 16.Deviated wells: Kickoff depth: 7700' ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 104° deg. Downhole:4560 psig Surface:3957 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2.375" 4.7# L-80 ST-L 1788 7412 5963 9200 6000 slotted liner \••• OIC ‘t \ I 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft). Effective Depth ND(ft): Junk(measured) 7785' 6336' 7717' 6283' Casing Length Size Cement Volume MD ND Conductor/Structural 81' 16" 212 sx AS I 121' 121' Surface 3782' 7.625" 1020 sx AS III,340 sx CI G 3821' 3306' Intermediate Production 7747' 5.5"x 3.5" 190 sx Class G 7782' 6334' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7347'-7370',7380'-7390',7474-7504' 5995-6013',6020'-6028',6094-6117' 20.Attachments: Property Plat❑ BOP Sketch 151 Drilling Program Eg Time v.Depth Plot❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program In 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 1 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 1/4,- Printed Name V. Cawvey Title Alaska Wells Manager ,,` �+ Signature jigX, ,,1 , Phon.265-6306 Date {,(/ 1 1/kJ V '( Commission Use Only l�1 Permit to Drill API Number: / Ty. Permit A proval See cover letter Number: 2 l L)l! V 50- p72 • 2 Z 7 1--4t --1 Date: $��' I O for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m hone,gas hydrates,or gas contained in shales: lir PP Y P P 9 Y 9 YQ00 /0 5� /,j0 P c S f Samples req'd: Yes ❑ o L`7 Mud log req'd: Yes ❑ No Et Other: n / H2S measures: Yes Of o ❑ Directional svy req'd: Yes [ No ❑ -k Z co to S /f h n t �5 c.,..:...,) 89/3 APPROVED BY THE COMMISSION !�� Q DATE: ,COMMISSIONER Form 1U-4U1 (1-‹lit///LOW) This permit is valid or 2 months from the date of approval( AAC 25.005(g)) ,pbmlt in Duplicate PZ7/0 f ro L%/'1r, ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 18, 2010 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill 4 lateral sidetracks out of Kuparuk Well 3A-17 using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 3A-17 as early as September 12, 2010. The CTD objective is to drill four lateral sidetracks (3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01); targeting the A2 and A3-sands to access reserves away from the parent wellbore, across isolating faults. Two laterals each will be drilled from two separate casing exits in the 3.5" liner. Attached to this application are the following documents: — Permit to Drill Application Forms for 3A-17A, 3A-17AL1, 3A-17AL2, and 3A-17AL2-01 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic — Sundry Application—Plug perforations If you have any questions or require additional information please contact me at 907-263-4093. Sincerel Jill Long Coiled T ing Drilling Enginee Permit to Drill Summary of Operations KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Laterals Coiled Tubing Drilling Well History and Objective Well 3A-17 was originally drilled and completed as an A-sand producing, single completion well in September 1996. The A sands were perforated and fracture stimulated in October/November 1996. The well operated as an A-only producer until 1999 when the C and B sands were perforated in June of that year. Production from 3A-17 has historically been lower than expected. The reservoir in the surrounding area is highly faulted and seismic data confirms the current wellbore position is not optimal. The purpose of the CTD project is to drill four CTD sidetracks in the A2 and A3 sands away from the parent • wellbore and across faults that are believed to be isolating. The new reservoir locations should result in improved sweep efficiency and oil recovery for the pattern. Perforations in the parent wellbore are planned to be plugged prior to CTD rig arrival however the lateral footage drilled in the immediate vicinity of parent well will recover the existing perforations. Operational Outline Pre-Rig Work Remaining 1. Changeout all gas lift valves to dummy valves and caliper the 3.5" liner below the tubing tail. 2. Set a cast iron bridge plug above the A sand perforations(and below the lower CTD kickoff point). 3. Perforate the 3.5" liner across the kickoff point locations 4. Set the lower whipstock at—7412' MD 5. Cement squeeze the B and C sand perforations, cleaning out to the top of the whipstock 6. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Lower Window a. Mill a 2.74"window exit with high-side orientation off of the whipstock previously cemented in place at—7412' MD b. 3A-17A Lateral i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL1 lateral c. 3A-17AL1 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand 44A- ii. Load well with kill weight fluid. Run 2%" slotted liner with a shorty deployment sleeve on top rI-0 from TD to just inside the window 3. Upper Window a. Set a 3.5" Monobore whipstock at—7395' MD and mill a 2.74"window exit with high-side orientation off of the whipstock set at—7395' MD b. 3A-17AL2 Lateral i. Drill 2.70"x 3" bi-center lateral in the A2 sand ii. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 3A-17AL2-01 lateral c. 3A-17AL2-01 Lateral i. Drill 2.70"x 3" bi-center lateral in the A3 sand ii. Load well with kill weight fluid. Run 2%"slotted liner with a shorty deployment sleeve on top from TD to inside the 3.5" liner above the window. 4. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 1 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 Operational Details Hazards — Shale stability is a potential problem, particularly in the build section when crossing Fault#1. — Drilling into over-pressured zones is a potential hazard in 3A-17. Nearby injecting well 3A-10 has a . bottomhole pressure of—4600 psi but is expected to be fault isolated from the planned laterals. Choke pressure will be maintained while drilling, both for maintaining well control and borehole stability. — Well 3A-17 has 130 ppm H2S as measured on 02/16/10. Well 3A-08 is located 16' to the right side and 3A- 09 is 59' to the left side of the 3A-17 surface location. The H2S measured in 3A-08 is 200 ppm (12/18/09) and 3A-09 is 120 ppm (1/2/09). The maximum H2S level on the pad is 260 ppm from well 3A-16 (12/19/09). All H2S monitoring equipment will be operational. Fluids Program — Chloride-based Biozan brine (8.6 ppg)will be used for window milling operations. — Chloride-based Flo-Pro mud (9.8 ppg)for drilling operations. — Due to the high reservoir pressures, 13.1 ppg Potassium Formate will be used for running completions. Disposal — No annular injection on this well. — Class I I 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 Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 3A-17A 7700' 9150' 6038' 6032' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3A-17AL1 7412' 9200' 5963' 6000' 2%", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 9250' 6043' 6085 2W, 4.7#, L-80, ST-L solid/slotted liner; 3A-17AL2 7600' aluminum billet on top. 3A-17AL2-01 7380' 9300' 5939' 6060' 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 0 121 0 121 1640 630 Surface 7%" 29.7 L-80 BTC-Mod 0 3821 0 3306 6890 4790 Casing 5 %" 15.5 L-80 LTC-Mod 0 7254 0 5922 7000 4990 Liner 3 %" 9.3 L-80 EUE-8rd Mod 7254 7782 5922 6334 10160 10540 Tubing 3 '/2" 9.3 L-80 EUE-8rd Mod 0 7267 0 5932 10160 10540 Directional Planning — See attached directional plans for each of the three laterals. — 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 Lateral Name Distance 3A-17A 22650' 3A-17AL2 21450' 3A-17AL1 22650' 3A-17AL2-01 21450' Page 2 of 3 8/18/2010 PTD Applications KRU 3A-17A, 3A-17AL1, 3A-17AL2, 3A-17AL2-01 - Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well Lateral Name Distance Well 3A-17A 1200' Toe measured to 3A-07 3A-17AL2 1200' Toe measured to 3A-07 3A-17AL1 1200' Toe measured to 3A-07 3A-17AL2-01 1200' Toe measured to 3A-07 Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Reservoir Pressure — The most recent static BHP survey in well 3A-17 was taken August 12, 2010. The reservoir pressure was measured at 3800 psi at 7426' MD/ 6056' TVD, corresponding to 12.1 ppg EMW. This is also the highest expected pressure in the targeted fault block. — The highest pressure from any of the surrounding wells that could potentially be anticipated is 4560 psi at 6628' MD/6065'TVD (in nearby injector 3A-10). Well Control — Two well bore volumes (-161 bbl) of KWF will be within a short drive to the rig during drilling operations. In this situation, a"welibore volume" is defined as the tubing volume plus the volume of the longest lateral. — 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 4000 psi. Maximum surface pressure anticipated while sidetracking out of 3A-17 is 3957 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the maximum reservoir pressure from all nearby wells: 4560 psi at 6628' MD/6065' TVD (in nearby injector 3A-10). — The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 9.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. Page 3 of 3 8/18/2010 0 N 0 0 a, p L > j y O A 0 J FO CO W ch N / N Q N _ r Q 01 o b a 'JO O. I NNr C J m 2O I d f0 ° 'E o 11 y I m 11 y IiN v Q I-J W o II o v m g v-, N III II Z V N(��� II II O d g N O ,O On 5 2 W N E II II 0 0 0 m I • O \ 0 m I U \ U (V U m m U on \\1 N (V CI N N \ A A A A m i 0 I N / oo 1 (7 V a U I I o m ad I N p O co 0 1 UW O 0Lo �p 0 D_M a o Q r U � - m 2 � m U-D o cO r d d CD r-- a) wp @ a:, o ° X N n \U) 02 n o U) Q �=N r N U .a \ • m d I I o c0 V J N L % CO / o �� Q / °O 3 I I L I N r N Z I 3 J I r a 2 I z m I a b I y I ti J I Q m r J O N Li \ I U O ^O 2 O v W O co II d N r J 0 C N m NI N Q I—J II N [— -JO < CO ConocoPh illi s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3A Pad 3A-17 3A-17AL1 Plan: 3A-17AL1_wp03 Standard Planning Report 16 August, 2010 BAKER HUGHES 't►-` ConocoPhillips If/- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17AL1 Design: 3A-17AL1_wp03 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3A Pad Site Position: Northing: 5,996,860.05ft Latitude: ,24'9.520 N From: Map Easting: 507,712.01 ft Longitude: 149°56'14.019 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.06 ° Well 3A-17 Well Position +N/-S 0.00 ft Northing: 5,997,044.46 ft Latitude: 70°24'11.335 N +E/-W 0.00 ft Easting: 507,662.81 ft Longitude: 149°56'15.455 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 40.40ft - Wellbore 3A-17AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 8/11/2010 17.03 79.83 57,388 Design 3A-17AL1 w 03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,700.00 Vertical Section: Depth From(TVD) +N/-S +E/.W Direction (ft) (ft) (ft) r) -40.40 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) (°) (°1 (ft) (ft) (ft) (°/100ft) (°/100ft) (1100ft) (1 Target 7,700.00 95.78 169.89 6,038.42 -1,928.30 3,645.77 0.00 0.00 0.00 0.00 7,730.00 100.45 172.63 6,034.19 -1,957.64 3,650.28 18.00 15.56 9.14 30.00 7,770.00 103.98 179.06 6,025.72 -1,996.60 3,653.13 18.00 8.82 16.06 60.00 7,800.00 103.92 184.62 6,018.48 -2,025.69 3,652.19 18.00 -0.21 18.55 90.00 7,890.00 103.63 201.30 5,996.91 -2,110.54 3,632.66 18.00 -0.32 18.53 89.00 7,980.00 91.07 190.97 5,985.39 -2,196.02 3,608.05 18.00 -13.96 -11.48 220.00 8,030.00 91.21 181.97 5,984.40 -2,245.64 3,602.42 18.00 0.29 -18.00 271.00 8,180.00 91.99 208.97 5,980.14 -2,388.82 3,562.81 18.00 0.52 18.00 88.00 8,305.00 93.75 231.43 5,973.81 -2,483.57 3,482.77 18.00 1.41 17.97 85.00 8,455.00 88.83 257.99 5,970.37 -2,547.02 3,348.42 18.00 -3.28 17.71 100.00 8,605.00 83.98 231.37 5,979.95 -2,610.36 3,214.32 18.00 -3.23 -17.75 259.00 8,675.00 87.77 243.42 5,985.00 -2,647.89 3,155.61 18.00 5.41 17.21 73.00 8,975.00 88.69 189.40 5,995.01 -2,880.38 2,984.21 18.00 0.31 -18.01 270.00 9,200.00 89.00 229.90 5,999.73 - -3,071.83 2,875.22 18.00 0.14 18.00 90.00 8/16/2010 2:00:21PM Page 2 COMPASS 2003.16 Build 69 10-' ConocoPhillips F/- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17AL1 Design: 3A-17AL1_wp03 I Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,700.00 95.78 169.89 6,038.42 -1,928.30 3,645.77 565.08 0.00 0.00 5,995,120.10 511,310.19 3A-17A 7,730.00 100.45 172.63 6,034.19 -1,957.64 3,650.28 591.11 18.00 30.00 5,995,090.76 511,314.73 2 7,770.00 103.98 179.06 6,025.72 -1,996.60 3,653.13 626.75 18.00 60.00 5,995,051.81 511,317.62 3 7,800.00 103.92 184.62 6,018.48 -2,025.69 3,652.19 654.40 18.00 90.00 5,995,022.72 511,316.71 4 7,890.00 103.63 201.30 5,996.91 -2,110.54 3,632.66 740.81 18.00 89.00 5,994,937.86 511,297.27 5 7,900.00 102.25 200.12 5,994.67 -2,119.65 3,629.21 750.56 18.00 -140.00 5,994,928.74 511,293.83 7,980.00 91.07 190.97 5,985.39 -2,196.02 3,608.05 829.56 18.00 -140.27 5,994,852.36 511,272.75 6 8,000.00 91.13 187.37 5,985.01 -2,215.76 3,604.86 849.20 18.00 -89.00 5,994,832.62 511,269.58 8,030.00 91.21 181.97 5,984.40 -2,245.64 3,602.42 878.11 18.00 -89.07 5,994,802.74 511,267.17. 7 8,100.00 91.62 194.56 5,982.66 -2,314.76 3,592.38 946.49 18.00 88.00 5,994,733.62 511,257.20 1 8,180.00 91.99 208.97 5,980.14 -2,388.82 3,562.81 1,026.20 18.00 88.31 5,994,659.53 511,227.71 8 8,200.00 92.30 212.56 5,979.39 -2,405.99 3,552.59 1,045.84 18.00 85.00 5,994,642.35 511,217.51 8,300.00 93.69 230.53 5,974.13 -2,480.43 3,486.64 1,138.34 18.00 85.13 5,994,567.85 511,151.65 8,305.00 93.75 231.43 5,973.81 -2,483.57 3,482.77 1,142.62 18.00 86.08 5,994,564.71 511,147.77 9 8,400.00 90.66 248.26 5,970.13 -2,531.07 3,400.98 1,215.23 18.00 100.00 5,994,517.13 511,066.05 8,455.00 88.83 257.99 5,970.37 -2,547.02 3,348.42 1,248.19 18.00 100.65 5,994,501.13 511,013.50 10 8,500.00 87.30 250.03 5,971.90 -2,559.39 3,305.22 1,274.59 18.00 -101.00 5,994,488.71 510,970.32 8,600.00 84.13 232.26 5,979.43 -2,607.29 3,218.23 1,349.35 18.00 -100.73 5,994,440.73 510,883.39 8,605.00 83.98 231.37 5,979.95 -2,610.36 3,214.32 1,353.58 18.00 -99.39 5,994,437.66 510,879.48, 11 8,675.00 87.77 243.42 5,985.00 -2,647.89 3,155.61 1,408.92 18.00 73.00 5,994,400.07 510,820.82 12 8,700.00 87.78 238.91 5,985.97 -2,659.94 3,133.74 1,427.72 18.00 -90.00 5,994,388.00 510,798.96 8,800.00 87.94 220.90 5,989.73 -2,724.03 3,057.60 1,513.99 18.00 -89.83 5,994,323.84 510,722.90 I 8,900.00 88.31 202.90 5,993.03 -2,808.53 3,005.01 1,611.38 18.00 -89.15 5,994,239.29 510,670.40 8,975.00 88.69 189.40 5,995.01 -2,880.38 2,984.21 1,686.02 18.00 -88.55 5,994,167.43 510,649.67 I 13 9,000.00 88.69 193.90 5,995.58 -2,904.85 2,979.16 1,710.74 18.00 90.00 5,994,142.95 510,644.65' 9,100.00 88.79 211.90 5,997.79 -2,996.57 2,940.42 1,810.17 18.00 89.90 5,994,051.20 510,606.00 9,200.00 89.00 229.90 5,999.73 -3,071.83 2,875.22 1,903.19 18.00 89.50 5,993,975.89 510,540.89 TD at 9200.00 8/16/2010 2.00:21 PM Page 3 COMPASS 2003.16 Build 69 ti•' ConocoPhillips F/,'- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Welibore: 3A-17AL1 Design: 3A-17AL1_wp03 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3A-17A Fault 1 0.00 0.00 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 70°23'58.344 N 149°54'23.542 W -plan misses target center by 6050.80ft at 7900.00ft MD(5994.67 ND,-2119.65 N,3629.21 E) -Polygon Point 1 0.00 -1,319.88 3,820.22 5,995,728.63 511,484.00 Point2 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 Point 3 0.00 -2,782.46 3,242.74 5,994,265.60 510,908.08 Point 4 0.00 -2,151.56 3,407.37 5,994,896.61 511,072.05 3A-17AL1 t2 0.00 0.00 6,002.00 -2,096.76 3,637.40 5,994,951.64 511,301.99 70°23'50.705 N 149°54'28.909 W -plan misses target center by 1.51ft at 7874.66ft MD(6000.54 ND,-2096.53 N,3637.72 E) -Point 3A-17A,AL1 Fault 2 0.00 0.00 0.00 -2,315.40 3,274.13 5,994,732.65 510,938.99 70°23'48.556 N 149°54'39.552 W -plan misses target center by 5975.12ft at 8432.03ft MD(5970.06 ND,-2541.45 N,3370.69 E) -Polygon Point 1 0.00 -2,315.40 3,274.13 5,994,732.65 510,938.99 Point2 0.00 -2,510.91 3,779.99 5,994,537.67 511,445.00 3A-17AL1 t5 0.00 0.00 5,975.00 -2,580.41 3,259.86 5,994,467.65 510,924.99 70°23'45.950 N 149°54'39.974 W -plan hits target center -Point 3A-17AL1 11 0.00 0.00 6,038.00 -1,928.76 3,645.57 5,995,119.64 511,309.99 70°23'52.357 N 149°54'28.667 W i -plan hits target center -Point 3A-17A,AL1 Polygon 0.00 0.00 0.00 -1,764.62 3,531.73 5,995,283.63 511,196.00 70°23'53.972 N 149°54'31.999 W -plan misses target center by 6001.4011 at 7980.00ft MD(5985.39 TVD,-2196.02 N,3608.05 E) -Polygon Point 1 0.00 -1,764.62 3,531.73 5,995,283.63 511,196.00 Point2 0.00 -1,937.80 3,697.58 5,995,110.64 511,362.01 Point 3 0.00 -2,422.73 3,576.09 5,994,625.64 511,241.03 Point 4 0.00 -2,623.49 3,311.87 5,994,424.63 510,977.04 Point 5 0.00 -2,760.25 3,049.71 5,994,287.61 510,715.05 Point 6 0.00 -3,316.14 2,883.15 5,993,731.61 510,549.07 Point 7 0.00 -3,195.89 2,633.25 5,993,851.59 510,299.08 Point 8 0.00 -2,596.98 2,788.84 5,994,450.60 510,454.04 Point9 0.00 -2,401.54 3,384.09 5,994,646.63 511,049.03 Point 10 0.00 -2,051.67 3,554.45 5,994,996.64 511,219.01 3A-17AL1 t4 0.00 0.00 5,970.00 -2,546.51 3,352.90 5,994,501.65 511,017.99 70°23'46.283 N 149°54'37.248 WI -plan hits target center -Point 3A-17AL1 t3 0.00 0.00 5,979.00 -2,405.70 3,552.07 5,994,642.64 511,216.99 70°23'47.667 N 149°54'31.412 W -plan hits target center -Point 3A-17AL1 t6 0.00 0.00 6,000.00 -3,072.06 2,875.31 5,993,975.66 510,540.98 70°23'41.116 N 149°54'51.243 W -plan hits target center -Point 3,821.00 3,223.24 7 5/8" 7-5/8 9-7/8 9,200.00 5,999.73 2 3/8" 2-3/8 3 8/16/2010 2:00.21 PM Page 4 COMPASS 2003.16 Build 69 Noe' ConocoPhillips FA..-- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3A-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-17 @ 82.00ft(Rowan 245) Site: Kuparuk 3A Pad North Reference: True Well: 3A-17 Survey Calculation Method: Minimum Curvature Wellbore: 3A-17AL1 Design: 3A-17AL1_wp03 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,700.00 6,038.42 -1,928.30 3,645.77 TIP/KOP 3A-17A 7,730.00 6,034.19 -1,957.64 3,650.28 2 7,770.00 6,025.72 -1,996.60 3,653.13 3 7,800.00 6,018.48 -2,025.69 3,652.19 4 7,890.00 5,996.91 -2,110.54 3,632.66 5 7,980.00 5,985.39 -2,196.02 3,608.05 6 8,030.00 5,984.40 -2,245.64 3,602.42 7 8,180.00 5,980.14 -2,388.82 3,562.81 8 8,305.00 5,973.81 -2,483.57 3,482.77 9 8,455.00 5,970.37 -2,547.02 3,348.42 10 8,605.00 5,979.95 -2,610.36 3,214.32 11 8,675.00 5,985.00 -2,647.89 3,155.61 12 8,975.00 5,995.01 -2,880.38 2,984.21 13 9,200.00 5,999.73 -3,071.83 2,875.22 TD at 9200.00 8/16/2010 2:00:21PM Page 5 COMPASS 2003.16 Build 69 r El�W� s 8 Q z $ m 8 $ a M ^ 1 a o . r - ' i r N a F 1 M f, o - • 3sgg i Q 'g -__ - - - - M3 s - °i . a , 8 1 n 1 G / m e. 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Ui 11111111■MINA\/%■■■• \7/ li i :, -. . fl &iP1 8 -E- E131- ,f i % . iltillIMAP14111 7:. .< a l\I�\M�I\\I■ x s /\_�I•\■■►\ _/I 2 z,,n M I//�//\■\■■\� e u e 31 prillop o PPP - F, 5a¢ °- 8 F 8 (ui/g OSI)(4)i[uoN/(-)quoS ce ce 0 g Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N • Lubricator Riser Annular/ Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator J • above BHA rams i 1 Choke 1 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip(BHA) Kill ><.J L'_ L —_,,,.. 1 f Blind/Shear 2" Pipe/Slip(CT) Choke 2 i Swab Valves l MIL Wing Valves IiVC4 Tree Flow Cross # Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi 0 Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union TRANSMITTAL LETTER CHECKLIST WELL NAME K/at f7 4 L PTD# Z I t 1 t Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: KL'1 et. k. lJ e- r- POOL: e� t V ��% v i ( cm 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 KR L{ 54 / 7L c/ (If last two digits in Permit No. 2/C//3 ,API No. 50-Oat) - z ' / - . 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. Rev: 1/11/2008 iii 1 To a) O) 0 a) a co .co a) 0 _ @ c Q .c U a) a a a) 2 _. 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