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213-023
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. 2J 3 - L Well History File Identifier Organizing (done) ❑ Two-sided I ❑ Rescan Needed I I III III RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: /GreyscaIe Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: a ta U / Li. . /s/ Ca r Project Proofing I III BY: Maria Date: c ag i L/ /s/ nq f Scanning Preparation I x 30 = no +.),�` = TOTAL PAGES 51+ BY: (Count does not include cover sheet) 0 ` Date: ! /s/ Production Scanning I I III Stage 1 Page Count from Scanned File: .4S (Count does include coy eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date:a 1 '�a /s/ rvi 1 Stage I If NO in stage 1, page(s) discrepancies were f nd: YES NO 1 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I ReScanned I 111111011111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111 111111 0 i �; I � I; o I T > f0 ,� M II E D. / Z .Z/ o , _ as N c0 en j E Q N Z r>.. N U iN co � ? N cn '>q 5 / .� w • °y .-N 1 > = ) > 0) Q C a) a) ip u) U c f- N O z ` Z n + g n Ce m a U - m Q c o o m m a 2 2 o c CO a) 2 O O O - I g 2 � m a ° N� i U U J 'o T m as a 0) J O 0 � a) n n O O _ O O N 1 O c 13� Z a o- U p 0 c = n. 0) CI. 0) a) O D ? N III a0 E O a� a� 2.7 m m ,' Q /Z 1 1 i No QQ c a) a) m ct — N m rn o ° c�n� O a E I' co in U m m p >. ct :° o m p > uJ Et Q E p �CL 2 c F-2' 2: V m a) m p • U Y > o 0 0 0 o ENE m p as W a i as 0 ao a v v Cl) Z o) IX U O c c c c c o a> vi 0 CO W Z J 2 2 n a a a a m CO 0 0 U p OUO O O 0 0 E E Z ! o O 2 N 0 0 0 N O y H Q CO 7 N O O co O co J O' m J 0. . 0 O Z w, = 0 � CL cn O 2 0) U U M co /zl I!; CIlao^o v v v v N 11C I— CAIN n � N- N- I O5-11. n a) U 0�0 U m c /< J CO CL r . > Q o I o I I- 6 R 0. .7 H o 0 o 0 0 ° o Z M J � U U U !0 co id = N m Z p in f° �! .-- 07 CO .E c a) E YN C m fn U) 0 CL < its ' 1 N d c c o ` .d Q Y c m c ici o= O I `111k\! 0 p Z o J v, w �' ^ 0 I >,., w? w > > 0 2 p£ I Z U to N li�' cu Z O co a) N a) >. 4) 1 a) c c c c E E o 0 0 o ca c /Q l� z0 E z a) 0 c c c co CO >- >- } o p z o ... t O W / g / T NNNN O 0 d a+ W E 0 CO 0 c00 c00 C > I CO y O N rC O 0 '.o2 W O Z N N N N _N W O d rC 0 Q 0 CO a+ n N `) a) E CL D o C 0O 0 c O o a m co Z 1- c c m I s v Q o '" c 0 / w LL d rn ta w 5 a 0 J 0 0 O � v' o E E a o 3 o ° ° °w 3 ? v a 0 0 , 0 _ RECEIVED ,a`- PRINT DISTRIBUTION LIS 1 Y 1 ® 2013 BAKER HUGHES AOGCC COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) 2N3—Dz_ WELL NAME 1G-10BL2 RUN NUMBER �^7 (mandatory) L2 -G0 Z. FIELD Kuparuk BH SALESMAN Anyanwu,Okechukwu(OKEY) (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) 1 STATE Alaska PAGE OF (mandatory) LOG DATE: March 31,2013 TODAYS DATE: 5/10/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD - FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Or PHIN I S #OF COPIES #OF COPIES 1 1 ConocoPhillips Alaska,Inc. I 1 I I I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I i I i I I I I Christine Mahnken � 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I 1 I 1 I I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I I 1 I 1 I I I I Glenn Fredrick 3800 Center Point Drive,Suite 101) 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 THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil El , Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ i lb.Well Class: ✓ 20AAC 25.105 20AAC 25.110 Development 1111, Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: J 5.Date Comp.,Susp., ✓ 12.Permit to Drill Number: ✓ ConocoPhillips Alaska, Inc. or Aband.: April 1,2013 213-023/ 3.Address: 6.Date Spudded: ✓ 13.API Number: ✓ P.O.Box 100360,Anchorage,AK 99510-0360 March 29,2013 50-029-21003-61 4a.Location of Well(Governmental Section): i 7.Date TD Reached: ✓ 14.Well Name and Number: v Surface: 386'FSL,793'FWL,Sec.29,T12N,R10E,UM March 31,2013 1G-10BL2 Top of Productive Horizon: 8. KB(ft above MSL): 94'RKB 1 15.Field/Pool(s): ✓ 412'FNL,2625'FEL,Sec.32,T12N,R10E, UM GL(ft above MSL): 63'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): ', 455'FNL,2637'FEL,Sec.32,T12N,R10E, UM 10020'MD/6581'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): j 10.Total Depth(MD+ND): ✓ 16.Property Designation: '✓ Surface: x-540572 y- 5981035 Zone-4 10020'MD/6581'ND ADL 25640 TPI: x-542441 y- 5980247 Zone-4 11.SSSV Depth(MD+ND): `/17.Land Use Permit Total Depth: x-542430 y- 5980204 Zone-4 nipple @ 523'MD/523'ND 2571 18.Directional Survey: Yes EI 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) 1668'MD/1599'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7897'MD/6639'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 39' 116' 39' 116' 24" 212 sx CS II 10.75" 45.5# K-55 _ 37' 2350' 37' 2185' 13.5" 930 sx AS III,250 sx AS I 7" 26# K-55 35' 6290' 35' 5441' 8.75" 850 sx Class G,250 sx AS I 2.375" 4.7# L-80 7466' 10020' 6482' 6581' 3" slotted liner 24.Open to production or injection? Yes El No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): V. SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6151' 6149'MD/5305'ND slotted liner from 7628'-10019'MD 6627'-6581'ND K rY 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. CONIPLETI 1N , RECEIVED Was hydraulic fracturing used during completion? Yes El Nola 5.14711.+i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ..i.......I.LEL.( APR 3 0 2013 none AOGCC 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) shut-in 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. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No is If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 DMS MAY - 1201 - CONTINUED QED N REVERSE ,/f � � riginal only i ��` 73l 13 �., G 5 � 29. GEOLOGIC MARKERS(List all formations and ma. encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Ell Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface j briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1668' 1599' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A6 9975' 6584' Kuparuk B 10020' 6581' N/A Formation at total depth: Kuparuk B 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kai Starck @ 263-4093 Email: Kai.Starck(a)conocophillios.com Printed Name Lamar G antt Title: Coiled Tubing Drilling Supervisor Signature XLX:IIVIA. Phone 263-4021 Date /241/i 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 10/2012 • KUP 1G-10BL2 MIL ComaRhi nj swetii. Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Inc'(°) MD(ftKB) Act Btm(ftKB) Alaska'Inc. 500292100361 KUPARUK RIVER UNIT PROD 10,020.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date Well COnrp:MULTIPLE LATERALS-1G100L24/2120132:41:44 PM SSSV:NIPPLE 240 8/14/2012 Last WO: 31.18 9/7/1983 Schematic-Actual 'Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM Rev Reason:SIDETRACK/LATERALS osborl Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(TVD)... String Wt...String...String Top Thrd HANGER,26 414. a" LINER BL2 2 3/8 1.992 7,465.6 10,020.0 4.60 L-80 ST L (Off Main Wellbore) Liner Details Top Depth (TVD) Top Inc! Nomi... 1 ' Top(ftKB) (ftKB) (') Rem Description Comment ID(in) 7,465.6 DEPLOY BAKER SEAL BORE DEPLOYMENT SLEEVE 1.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(BOB)Btm(ftKB) (ftKB) MB) Date (oh... Type Comment 7,628.0 10,019.0 A-5,A-4,1G-10A 3/31/2013 32.0 SLOTS Slotted pipe-0.125"x2.5"Co)4 CONDUCTOR, circumferential adjacent rows,3" 39-116 centers staggered 18 deg,3' non-slotted ends NIPPLE.523 Notes:General&Safety End Date Annotation 1 4/2/2013 NOTE:WELL SIDETRACKED TO'B',BL1,BL2(BL2 OFF MAIN WELLBORE) SURFACE. 37-2,350 GAS LIFT. 2,396 GAS LIFT, 3,865 GAS LIFT, 4,242 GAS LIFT, 11=. 4,756 GAS LIFT. 6.095 NIPPLE,6,141 --- LOCATOR. 6.146 // f SEALS,6,150 PRODUCTION Pod SIT'A', • 35-6290 CMT SOZ. - - 7,310-7,330 CMT 502, 7,330.7,340 CMT SOZ, 7,352-7,356 CMT SOZ, 7,366-7,374 ,Ip 1 WHIPSTOCK 7,462 WINDOW BL2, tar. 7.482-7.490 Mandrel Details Top Depth Top' Port 5... (ND) Intl OD Valve Latch Size TRO Run N...Top(RKB) (ftKB) (') Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 2,396.3 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/13/2013 10:30 2 3,664.8 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/27/2013 3:30 3 4,242.3 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/28/1996 '8:30 4 4,755.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/27/2013 9:00 5 6,095.0 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0,1/28/2013 11:30 LINER A. 6,142-7.906 SLOTS._ 7.628-10,019 LINER 912 (OR Male Wellbore), 7,46&70,0,020 0 TD(7G101302 10,020 11 1 1 11 Y CC rn 3 rp V N Q O Z N 0 N c V V N ✓ E a Q t O ti) _N CO O CD co CO c CO O�1 Z m C) M Y O O J O ,CO V �O\ r �CO\ Y W /�1 m tOp O V O V �Y� �� O th o E CC 1:3 CO c E O., @_)-(5 ��`` ru I con N .Q E (6 O_ 2i O V Q W O c N O-cN a)0 m ' m c D _ td N O_cB� E€O O O I Q U W 2 •a = OLW Tc O O O O LL 2 0 m Nm O O 0 c Cn Q O O O O \ I E E . 0 C * N 0 aN� J RS co N f6 U(6 O i M I U of 0 U ri O Sw m N CV N N N Y N'611515 NY I ‘-- (6 cco c6 ca a)co 00 M M M M M m J corn (nm ;'\ N• O M 3 III m E � II � o � o � E 1 @� . � W .. 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C o m 0 O m co co co co m co Ol N D CD O Z to 1. n n Iri LL ri ri CO i i ri Q • N• N c u d u 3 m a • m C u m u m 'C O m V N m O m ^ . O CO O Q Q. N w N N O C O. CO o ° a m m m Q m a O — t a ✓ 0 R o R rn o m a m o o D m r m CO m O J >> ❑ F 2 Z N ❑ W •r 0 0 7 V CD CO Q CO m m N CO 0 0 11 1 8 1 T T O C. n m O2 OQa Z $ + 0 rn N CO CI CO Q O CO O to CO Q O Z CO 1[) n C1 6 6 ti o M O 6 t- f/ = 0 0 0 o m a 01 m a in m m ❑ N 10 I0 In Q 'Cr V Q Q Q Q > — to to to to to m to to to to m co- p- 1` N CO a Q 0 m M N to a to O Q CD Q 0 m Q N CO O N ❑ - O a co O O m a m OOD 01`O aaa CO C m v m tO lO IO 6 to t0 tO t0 an in IO F m to to to m to m m m m 0303 U C R N CO N CO Q r 0 Q N IO m m m R -C Cl CO N N t0 O CO Q 1` h CO CO Q D -p N CV a t0 N M tD O) .- V 6 6 in as N .-. 03003 (003 m m m to W W to o. d CO Q o �Q aL, c� • Y_ Y • U t- 0 0 0 m Q CO CO 0 p t7 CO r m 01 = O R CO r CO CO. CO CO r m CO O Q CO IO LC/ awl o > > 0 U't C� c rn Si rn rn Si Si rn �i rn rn rn rn O a U O co N N co N a CV N N N N a- CO a m to 6 to to 6 6 Iti tci 6 N o T ❑ O N O m Q I,- O CO m CO Cal �} C ` - co a a 1� m m m co a m Ot O O R •;-' O C T E tT a a a a a a a a a a t] t C') U E o m m v a` in 3 3 o rn I co --- i v 1G-10A Well Work Summary ,DATE , SUMMARY 1/26/2013 TAGGED @ 7765' SLM. MEASURED BHP @ 7300' RKB: 2630 PSI. GAUGED TBG TO 2.79"TO 6141' RKB. DRIFTED WITH 17.3'x 2.625" DUMMY WHIPSTOCK TO 6770'SLM. SET 2.75"CA-2 PLUG @ 6141' RKB; PT TBG AGAINST PLUG&DRAW DOWN TESTED, PASSED. IN PROGRESS. 1/27/2013 SET AVA CATCHER ON PLUG @ 6141' RKB. PULLED GLVs FROM 4755', 3664', &2396' RKB. SET DVs @ SAME. ATTEMPTED PULL OV @ 6095' RKB. IN PROGRESS. 1/28/2013 PULLED OV @ 6095' RKB. LOADED WELL WITH 185 BBL DSL TAKING RETURNS OFF IA TO PRODUCTION. COMBO MITT x IA 2500 PSI, PASSED. SET DV @ 6095' RKB. MIT IA 2500 PSI, PASSED. PULL AVA CATCHER @ 6141' RKB. IN PROGRESS. 1/29/2013 PULLED CA-2 PLUG @ 6141' RKB. READY FOR E-LINE. 1/31/2013 PERFORMED CALIPER SURVEY WITH 24-ARM MIT. LOGGED FROM 7650'TO SURFACE. 2/1/2013 PERFORMED GYRO SURVEY WITH GYRODATA GYRO TOOLS. LOGGED SURVEY FROM 7600'TO SURFACE. 2/15/2013 (PRE-CTD): RIG WORK-T POT(PASSED), T PPPOT(PASSED), IC POT(PASSED), IC PPPOT(PASSED). SV(PASSED), SSV(PASSED), MV(INCONCLUSIVE). IN PROGRESS. 2/16/2013 (PRE-CTD) MITOA(DID NOT CATCH PRESSURE), PT& DDT ON SV(PASSED), SSV (PASSED), MV(PASSED), RE-ENERGIZE OC PO"Y" SEAL 2/17/2013 (PRE-CTD): RIG WORK-SCLD (SUSPECTED TO BE—858') 2/27/2013 SET CATCHER @ 2505' SLM. PULLED DV @ 2396' RKB & REPLACED WITH OV. PULLED CATCHER. READY FOR DHD. 2/28/2013 (PRE-CTD) OA NFT-FAILED WOULD NOT BLEED TO OPSI. 3/1/2013 PERFORMED RADIAL CEMENT BOND LOG AND SBHP WITH PRESSURE MEMORY GAUGE. FOUND GOOD CEMENT BOND OVER ZONE OF INTEREST AT 7300'-7600'. FOUND ESTIMATED TOP OF CEMENT @ 6160'. SBHPS FOUND 2723 PSI AND 160 DEGF AT 7500'. 2682 PSI AND 159 DEGF AT 7386' 3/2/2013 (AC EVAL)OA DD TEST- FAILED ON GAS PASSES W/O GAS 3/3/2013 SET 2.75" D CAT SV @ 6141' RKB. PULLED OV @ 2396' RKB. CIRC'D OUT 85 BBL DSL. SET DV @ 2396' RKB. ATTEMPTED MIT TBG 2500 PSI.. OPERATIONS SUSPENDED FOR HIGH WINDS. IN PROGRESS. 3/4/2013 MIT IA 2500 PSI, PASSED. TESTED TBG AGAINST HOLEFINDER 2500 PSI, PASSED. PULLED CAT SV @ 6141' RKB. READY FOR CTU. 3/7/2013 Pumped 15 bbl 15.8 ppg class"G" neat, squeezed 9 bbls to perfs 7,318-ft to 7,644-ft RKB, achieved 1200 psi squeeze pressure,washed tubing down to 7,240-ft, POOH jetting tubing, freeze protect, trapped 500 psi at surface. Stand back CTU for night. 3/8/2013 Weather delayed start. Conduct weekly BOP test 250/4,000 psi. Remove snow from surface lines and equipment. Job in progress. 3/9/2013 Milled "D" nipple out to 2.80". Tagged TOC at 7,370-ft CTMD, 52-ft below top perf. Established injection rate of 1,050 psi at.5 bpm. Return in AM for repeat cement job. 3/10/2013 Pumped 10 bbl 15.8 ppg class"G" neat, squeezed '3 bbls to perfs 7,318-ft to 7,370-ft RKB, achieved 1200 psi squeeze pressure, washed tubing down to 7,200-ft, POOH jetting tubing, freeze protect, trapped 500 psi at surface. Stand back CTU for night. 3/11/2013 Milled cement in liner from 7,181-ft to 7,510-ft with 2.7"x 3" Bi-center mill. Test tubing to 1,200 psi. RDMO. Ready for Slickline. 3/12/2013 TAG TOC @ 7503' SLM/—7526' RKB. MITT TO 1475 PSI ( PASS ) . DRIFT TO TAG DEPTH WITH DMY WHIPSTOCK DRIFT. READY FOR E-LINE TO SET WHIPSTOCK. 3/15/2013 Set 3 1/2" Baker Monobore Whipstock with TOWS at 7482' at an orientation of 140 ROHS ConocoPhillips Time Log & Summary We//view Web Reporting Report rF7� �'i Well Name: 1G-10 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/17/2013 12:00:00 PM Rig Release: 4/1/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/16/2013 24 hr Summary RDMO from 1H-19, move rig to 1 G-10 18:00 00:00 6.00 MIRU MOVE MOB P Move rig from 1H-19 to 1G-10 03/17/2013 Mobilize rig from 1H-19 to 1G-10.Spot rig&RU.Start BOPE testing at 12:00pm. State Waived witness by John Crisp. Rig Accept 12:00pm 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Mobilize rig from 1H pad to 1G pad. Tarp down and plywood around wellhead, Spot rig modules. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P RU Putz,berm up around cellar, RU interconnect,steam, landings,load pits 11.8ppg completion fluid, 13.1ppg Formate and used 9.6ppg FP. Spot tiger tank, RU hardline to rig from tiger tank. 12:00 22:00 10.00 0 0 MIRU WHDBO BOPE P Perform initial BOPE 250/4,000 psi, annular 2,500 psi.John Crisp (AOGCC)waived witness of test 15:45. Rig Accept: 12:00 22:00 00:00 2.00 0 0 MIRU WHDBO BOPE P BOPE test complete with 0 failures. Continue operations servicing Bowen connections on stack, Riser and PDL's, PT PDL's and Tiger tank line. 03/18/2013 PU/MU/RIH BHA 1. Displace well to 9.6ppg used FP. Dry tag TOWS 7481'. Mill window including rat hole down to 7501'. Backream window. POOH 00:00 02:00 2.00 0 0 MIRU WHDBO BOPE P Continue operations servicing Bowen connections on stack, Riser and PDL's, Fill reel with H20,PT tiger tank liner and inner reel valve, stripper. 02:00 05:00 3.00 0 0 MIRU WHDBO BOPE P Pull BPV. Debris on top BPV. 05:00 05:59 0.99 0 0 MIRU WHDBO BOPE P Pressure test PDL's, Inspect CTC, and CT.Service injector head and reel. 05:59 05:59 0.01 0 0 SLOT WELLPF DISP P 05:59 06:14 0.25 0 0 PROD1 WHPST SFTY P Crew change, PJSM 06:14 07:59 1.75 0 0 PROD1 WHPST PULD P PU/MU BHA1,surface test,open EDC. 07:59 08:59 1.00 0 0 PROD1 WHPST TRIP T RIH w/milling assembly,counter issue,troubleshoot problem. 08:59 11:08 2.15 0 7,450 PROD1 WHPST TRIP P RIH with BHA#1, log tie-in,-17.5' correction,continue in hole. Page 1 of 13 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 11:08 12:08 1.00 7,450 7,481 PROD1 WHPST CIRC P Swap over to 9.6 ppg mud.Close EDC,weight check 34K, RIH to tag WS, PU 34K. RBIH,stall. 12:08 13:53 1.75 7,481 7,482 PROD1 WHPST MILL P Start time milling as per well plan, tool face 140R,pumping 1.44 bpm @ 3,880 psi, BHP 4,410 psi, DHWOB .5K. 13:53 20:05 6.20 7,482 7,488 PROD1 WHPST MILL P Start auto-driller milling, 1.44 bpm @ 3,882 psi, BHP 4,450 psi, DHWOB= 1.4K. 20:05 22:05 2.00 7,488 7,501 PROD1 WHPST DRLG P Start drilling rathole to 8,501'. 1.44 bpm @ 3,750, BHP 4,450 psi, DNWOB=2.4K. 22:05 23:59 1.90 7,501 7,476 PROD1 WHPST REAM P Make several reaming passes. 1 pass up and down at 140 TF. Additional passes 170 TF, 110 TF up,all passes down at 140 TF. 03/19/2013 Finished milling 2.80 OD window, Displace well to 9.5ppg Flo-Pro. POOH. Undeployed Milling BHA.M/U Build section BHA with a 2.3°AKO motor with a bi-center bit. RIH 00:00 00:30 0.50 7,476 7,500 PROD1 WHPST REAM P 2 additional reaming passes at 140 TF up and down milling off consistent motorwork at 7481'=TOWS.Two additional passes milled off area. PU above TOWS 00:30 00:45 0.25 7,475 7,500 PROD1 WHPST REAM P Drift window without pumps,holding MP.Window looked good. 00:45 02:30 1.75 7,500 0 PROD1 WHPST TRIP P POOH following MP schedule 02:30 02:45 0.25 0 0 PROD1 WHPST SFTY P At surface, PJSM 02:45 04:30 1.75 0 0 PROD1 WHPST PULD P Undeploy BHA 1 04:30 05:15 0.75 0 0 PROD1 WHPST PULD P LD BHA 05:15 06:00 0.75 0 0 PROD1 DRILL PULD P Deploy BHA 2 06:00 06:30 0.50 0 0 PROD1 DRILL SFTY P Crew change PJSM 06:30 07:30 1.00 0 0 PROD1 DRILL PULD P Cont.to Deploy 07:30 08:00 0.50 62 7,140 PROD1 DRILL TRIP P RIH,w/EDC open 08:00 08:15 0.25 7,140 7,140 PROD1 DRILL DLOG P Tie in depth to K1 minus 18.5' correction 08:15 09:15 1.00 7,140 7,500 PROD1 DRILL TRIP P RIH, Drift window with build BHA. Drift good, PUH above window 09:15 10:30 1.25 7,500 7,501 PROD1 DRILL TRIP P Displace well to 9.5ppg FP 10:30 17:15 6.75 7,501 7,618 PROD1 DRILL DRLG P RIH Drill ahead, 1.5bpm,3950 ctp, 44 whp,3962 bhp, 16k ctw 17:15 17:30 0.25 7,618 7,150 PROD1 DRILL WPRT P Rework directional plan. Out of spec surveys.Tuff drilling. Pull wiper trip early DD reowrk directional plan. Shoot surveys to compare. PU to K1 marker to tie in depth. 17:30 17:45 0.25 7,150 7,178 PROD1 DRILL DLOG P Log Tie into the K1 marker correction of-5ft. RIH and Log RA marker 7487' (7481'TOWS) 17:45 18:30 0.75 7,178 7,618 PROD1 DRILL WPRT P Wiper back in hole RIW 17.8k Page 2 of 13 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:30 00:00 5.50 7,618 7,759 PROD1 DRILL DRLG P 7618'-BOBD 1.48bpm at 3800psi, BHP 3959,WHP 31,Coil Surface Weight +15k, IA 631,OA 33 03/20/2013 Finished landing the build section at 8010ft. POOH. Undeployed build BHP, Deployed the B lateral BHA with Rib Steer. RIH 00:00 01:30 1.50 7,759 7,790 PROD1 DRILL DRLG P OBD 1.48bpm at 3800psi, BHP 4028,WHP 43, 16k coil surface Weight, IA 696,OA 35 01:30 01:45 0.25 7,790 7,500 PROD1 DRILL WPRT P 7790ft-Wiper up to the bottom of window 01:45 02:00 0.25 7,500 7,790 PROD1 DRILL WPRT P 7500ft-Wiper back in hole RIW 18k 02:00 04:30 2.50 7,790 7,940 PROD1 DRILL DRLG P 7790ft-BOBD 1.40bpm at 3750psi, BHP 4022,WHP 46, 16k coil surface weight, IA 701,OA 35 04:30 05:45 1.25 7,940 7,572 PROD1 DRILL WPRT P Wiper up to 7573ft PUW 38k 05:45 06:15 0.50 7,572 7,940 PROD1 DRILL WPRT P Wiper back in hole RIW 18k 06:15 10:15 4.00 7,940 8,010 PROD1 DRILL DRLG P BOBD 1.49 bpm, 4.35 ctp, Stacking WOB at 7955',sticky PU 42k for BHA wiper.Cont.drilling 10:15 12:15 2.00 8,010 0 PROD1 DRILL TRIP P Land Build section. POOH 12:15 12:45 0.50 0 0 PROD1 DRILL SFTY P At surface. PJSM 12:45 14:15 1.50 0 0 PROD1 DRILL PULD P Undeploy BHA 14:15 15:15 1.00 0 0 PROD1 DRILL SVRG P Service injector head,reel L/W, MP choke,and stripper. 15:15 16:45 1.50 0 0 PROD1 DRILL PULD P Deploy BHA 3 16:45 18:00 1.25 69 7,165 PROD1 DRILL TRIP P RIH 18:00 18:15 0.25 7,165 7,190 PROD1 DRILL DLOG P Tie into the K1 correction of-20ft. 18:15 19:00 0.75 7,190 8,010 PROD1 DRILL TRIP P Continue tripping in hole. RIW 18k 19:00 20:30 1.50 8,010 8,160 PROD1 DRILL DRLG P OBD 1.43bpm at 3750psi, BHP 3998,WHP 31, 15k coil surface weight,ROP 75fph, IA 154,OA 45 20:30 20:45 0.25 8,160 8,020 PROD1 DRILL WPRT P Wiper trip up to start Madd Pass 20:45 21:30 0.75 8,020 7,500 PROD1 DRILL DLOG P Start Madd Pass from 8020ft-7500ft 21:30 22:00 0.50 7,500 8,160 PROD1 DRILL WPRT P Wiper back in hole. RIW 18 22:00 23:45 1.75 8,160 8,310 PROD1 DRILL DRLG P 8160ft-BOBD 1.41 bpm at 3636psi, BHP 4000,WHP 39, 14k coil surface weight. IA 502, OA 47 23:45 00:00 0.25 8,310 8,141 PROD1 DRILL WPRT P Wiper trip to window. PUW 34k 03/21/2013 Drilled the"B"lateral until we inadvertantly faulted through the A5/A6 into the B1. Drilled further for Geo's. Decide to POOH for anchored billet. 00:00 00:30 0.50 8,141 8,310 PROD1 DRILL WPRT P Continue wiper trip 00:30 02:30 2.00 8,310 8,460 PROD1 DRILL DRLG P OBD 1.40bpm at 3650psi, BHP 4109,WHP 116, 13k surface coil weight, 1.8wob, ROP 70fph, IA 582, OA 48 02:30 03:00 0.50 8,460 7,505 PROD1 DRILL WPRT P Wiper up to the window for a tie in. PUW38 Page 3 of 13 it Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode _ T Comment 03:00 03:15 0.25 7,505 7,526 PROD1 DRILL DLOG P Tie into RA marker correction of- 2.5ft. 03:15 03:45 0.50 7,526 8,460 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 03:45 05:45 2.00 8,460 8,610 PROD1 DRILL DRLG P BOBD 1.41 bpm at 3650psi, BHP 4091,WHP 113,WOB 1.6k, ROP 85 fph, 14k coil surface weight,IA 572, OA 48 05:45 06:30 0.75 8,610 8,610 PROD1 DRILL WPRT P Wiper trip 500' . PUW 37k 06:30 09:45 3.25 8,610 8,760 PROD1 DRILL DRLG P Drill Ahead 1.45 bpm,4013 ctp,4084 bhp,74 whp, 14k ctw 09:45 10:15 0.50 8,760 8,000 PROD1 DRILL WPRT P Wiper trip 750'. PUW 10:15 10:30 0.25 8,000 8,760 PROD1 DRILL WPRT P RBIH 10:30 15:30 5.00 8,760 8,910 PROD1 DRILL DRLG P Drill Ahead 1.43 bpm,4000 ctp, 50 whp,4130 bhp, 13k ctw. Start preparing for mud swap.Multiple faulting into an uncertain formation. Possibly the A5/A6 8890'.Cont. drilling for data to wiper trip 8010'. 15:30 16:15 0.75 8,910 7,907 PROD1 DRILL WPRT P Wiper trip 38K weight break back to 32k, PUH slowly.Trucks on location pits ready Swap out mud system. 16:15 17:00 0.75 7,907 8,910 PROD1 DRILL WPRT P Wiper back in hole to drill ahead to search for fault. 17:00 20:00 3.00 8,910 8,940 PROD1 DRILL DRLG P BOBD 1.45bpm at 3830psi, BHP 4145,WHP 253,WOB 2.7k,ROP 10-15fph, 12k coil surface weight. 20:00 22:30 2.50 8,940 0 PROD1 DRILL TRIP T POOH 22:30 22:45 0.25 0 0 PROD1 DRILL SFTY T Tag up and space out for Undeploying drilling BHA. PJSM. SIMOPS w/changing out reel motor 22:45 00:00 1.25 0 0 PROD1 DRILL PULD T Start Undeploying BHA 03/22/2013 POOH, Undeployed drilling BHA(RSM). Replace reel motor.M/U and RIH with anchored billet and set TOB at 8650ft 00:00 01:30 1.50 0 0 PROD1 STK PULD T M/U and deploy BHA#4 Aluminum Anchored Billet 01:30 02:30 1.00 0 0 PROD1 STK CTOP T Finish replacing and test new reel motor. ******Nabors Reel Motor Swap out ******** ***Nabors on 1 hour Rig Repair Rate*** 02:30 03:15 0.75 0 0 PROD1 STK SVRG P Service INJH at surface. 03:15 03:45 0.50 0 0 PROD1 STK PULD T Finish deploying BHA 03:45 06:30 2.75 0 7,150 PROD1 STK TRIP T RIH with Anchored Billet 06:30 06:45 0.25 7,150 7,150 PROD1 STK DLOG T Tie into K1 correction of-20'.Close EDC.Weight check.34k puw. 06:45 07:30 0.75 7,150 8,662 PROD1 STK TRIP T Cont RIH Page 4 of 13 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 07:30 07:45 0.25 8,662 8,662 PROD1 STK WPST T Billet on depth 8662. PU string weight.Online with pumps setting OH anchored billet with single slip at 160 ROHS,8650 TOB.3800 psi 07:45 09:45 2.00 8,662 0 PROD1 STK TRIP T POOH 09:45 10:00 0.25 0 0 PROD1 STK SFTY T At surface. PJSM 10:00 11:30 1.50 0 0 PROD1 STK PULD T Undeploy BHA 4 11:30 12:00 0.50 0 0 PROD1 STK BOPE T PU test joint,function test BOPE 12:00 12:30 0.50 0 0 PROD1 STK SFTY T Nabors Crew change. PJSM 12:30 14:30 2.00 0 0 PROD1 STK PULD T Deploy BHA 5 14:30 16:30 2.00 72 7,150 PROD1 STK TRIP T RIH 16:30 16:45 0.25 7,150 7,178 PROD1 STK DLOG T Tie in depth to K1 marker correction of-20.5'. 16:45 17:30 0.75 7,178 8,653 PROD1 STK TRIP T RIH 17:30 18:00 0.50 8,653 8,653 PROD1 STK TRIP T Dry tag TOB at 8652.5ft. PUW 36k 18:00 20:30 2.50 8,653 8,655 PROD1 STK MILL T Start time milling 20:30 21:00 0.50 8,655 8,690 PROD1 DRILL DRLG T Drilling Ahead 21:00 21:15 0.25 8,690 8,640 PROD1 DRILL WPRT T Dry drift billet area clean 21:15 21:30 0.25 8,640 8,690 PROD1 DRILL WPRT T Wiper back in hole past billet 21:30 23:00 1.50 8,690 8,790 PROD1 DRILL DRLG T OBD 1.40bpm at 3650psi, BHP 4134,WHP 158,WOB 1.5k, ROP 90fph, 14k coil surface weight, IA 217,OA 52 23:00 23:15 0.25 8,790 8,665 PROD1 DRILL WPRT T Wiper up to the bottom of billet 8665ft 23:15 23:30 0.25 8,665 8,790 PROD1 DRILL WPRT T Wiper back on bottom. RIW 18k 23:30 00:00 0.50 8,790 8,857 PROD1 DRILL DRLG T BOBD 1.40bpm at 3650psi, BHP 4110,WHP 130,WOB 1.8k, ROP 91fph, 13k coil surface weight, IA 249,OA 53 03/23/2013 Drilled"B"lateral section as per plan 00:00 01:30 1.50 8,857 8,940 PROD1 DRILL DRLG T OBD 1.40bpm at 3650psi. BHP 4104,WOB 2.3k, ROP 40fph 01:30 01:45 0.25 8,940 8,665 PROD1 DRILL WPRT P Wiper up to the bottom of billet 01:45 02:00 0.25 8,665 8,940 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 02:00 04:30 2.50 8,940 9,090 PROD1 DRILL DRLG P BOBD 1.40bpm at 3650psi, BHP 4107,WHP 121,WOB 1.6k, ROP 88fph, IA 303,OA 53 04:30 05:00 0.50 9,090 7,510 PROD1 DRILL WPRT P Wiper to the window for tie in. PUW 34k 05:00 05:15 0.25 7,510 7,525 PROD1 DRILL DLOG P Tie into the RA marker correction of- 4ft 05:15 05:45 0.50 7,525 9,090 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 05:45 07:15 1.50 9,090 9,169 PROD1 DRILL DRLG P BOBD 1.4bpm at 3650psi, BHP 4113psi Page 5 of 13 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:15 08:00 0.75 9,170 8,780 PROD1 DRILL WPRT P Wiper trip back to 8780'(390'). early for Geo.32k puw.stay below billet. 08:00 08:15 0.25 8,780 9,170 PROD1 DRILL WPRT P RBIH 08:15 10:30 2.25 9,170 9,320 PROD1 DRILL DRLG P Drill ahead 1.5 bpm,4262 ctp,92 whp,4138 bhp, 14k ctw 10:30 11:15 0.75 9,320 8,686 PROD1 DRILL WPRT P Wiper trip back to Billet 8686'.33k puw.634' 11:15 11:30 0.25 8,686 9,320 PROD1 DRILL WPRT P RBIH 40fpm 11:30 13:45 2.25 9,320 9,470 PROD1 DRILL WPRT P Drill Ahead 1.5 bpm,4300 ctp,89 whp,4194 bhp, 10k ctw. 13:45 14:45 1.00 9,470 7,487 PROD1 DRILL WPRT P Wiper trip back to window 33k puw 14:45 15:00 0.25 7,487 7,487 PROD1 DRILL DLOG P Log RA marker,-8'correction 15:00 16:00 1.00 7,487 9,470 PROD1 DRILL WPRT P RBIH 16:00 17:30 1.50 9,470 9,620 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm,4340 ctp, 111 whp,4185 bhp, 13k ctw 17:30 18:00 0.50 9,620 9,000 PROD1 DRILL WPRT P Wiper trip, PUW 33 18:00 18:30 0.50 9,000 9,620 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 18:30 20:30 2.00 9,620 9,775 PROD1 DRILL DRLG P BOBD-1.44bpm at 3927psi, BHP 4223,WHP 135,WOB 2.6k, ROP 70fph 20:30 21:00 0.50 9,770 8,700 PROD1 DRILL WPRT P Wiper up to 8700ft, PUW 36k 21:00 21:30 0.50 8,700 9,770 PROD1 DRILL WPRT P Wiper back in hole. RIW 16k 21:30 23:00 1.50 9,770 9,935 PROD1 DRILL DRLG P BOBD-1.44bpm at 3961 psi, BHP 4695,WHP 131, ROP 100fph, IA 564,OA 54 23:00 00:00 1.00 9,935 7,715 PROD1 DRILL WPRT P Wiper up to window for tie in. PUW 35k 03/24/2013 Drilled"B"Lateral to TD 10543ft.Pulled a wiper to the swab. 00:00 00:15 0.25 7,715 7,510 PROD1 DRILL WPRT P Continue wiper from 9935ft. 00:15 00:30 0.25 7,510 7,570 PROD1 DRILL DLOG P Tie into RA marker correction of- 45ft 00:30 00:45 0.25 7,570 7,440 PROD1 DRILL WPRT P Pull up into the casing and replace Injector head. 00:45 01:00 0.25 7,440 7,440 PROD1 DRILL SVRG P Replace Injector head counter 01:00 01:15 0.25 7,440 7,510 PROD1 DRILL WPRT P RBIH to tie in. 01:15 01:30 0.25 7,510 7,528 PROD1 DRILL DLOG P Tie into RA marker. no correction 01:30 02:30 1.00 7,528 9,935 PROD1 DRILL WPRT P Contiue wiper in hole. RIW 18k 02:30 04:45 2.25 9,923 10,085 PROD1 DRILL DRLG P BOBD-1.40bpm at 3900psi, BHP 4218,WHP 66,WOB 1.6k, ROP 100fph 04:45 05:15 0.50 10,085 9,000 PROD1 DRILL WPRT P Wiper up to 9000'. PUW 34k 05:15 06:00 0.75 9,000 10,085 PROD1 DRILL WPRT P Wiper back in hole. RIW. 06:00 06:30 0.50 10,085 10,117 PROD1 DRILL DRLG P Drill ahead 1.46 bpm,4326 ctp,211 whp,4329 bhp, 7k ctw 06:30 06:39 0.15 10,117 10,117 PROD1 DRILL WPRT P Depth counter stopped working PU of bottom,found loose wire. Reset depth to CTES. RBIH Page 6 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:39 06:48 0.15 10,117 10,132 PROD1 DRILL DLOG P Ream down 150 fph,logging hole data, 06:48 07:48 1.00 10,132 10,235 PROD1 DRILL DRLG P Cont drilling 1.45 bpm,4315 ctp,214 whp,4307 bhp, 7-9k ctw. 07:48 09:03 1.25 10,235 10,235 PROD1 DRILL WPRT P Wiper trip back to 8925'.35k PUW 09:03 11:03 2.00 10,235 10,385 PROD1 DRILL DRLG P Drill ahead 1.45 bpm, 4300 ctp,210 whp,4308 bhp, 9k ctw.Monitor depth tracking on BHI counter with CTES counter. Exact match.cont drilling. Pump low/high sweeps. 11:03 12:15 1.20 10,385 10,385 PROD1 DRILL WPRT P Wiper trip 500'chasing sweeps. 33k PUW 12:15 15:00 2.75 10,385 10,543 PROD1 DRILL DRLG P Drill ahead. 15:00 18:30 3.50 10,543 72 PROD1 DRILL WPRT P pump sweep,TD lateral @ 10543'. 33k off btm.Wiper up to the swabs. 18:30 20:00 1.50 72 7,150 PROD1 DRILL WPRT P Wiper back in hole 20:00 20:15 0.25 7,150 7,180 PROD1 DRILL DLOG P Tie into the K1 correction of-13ft. 20:15 22:00 1.75 7,180 10,540 PROD1 DRILL WPRT P Continue wiper in hole. 22:00 22:15 0.25 10,540 10,540 PROD1 DRILL TRIP P Tag TD at 10540ft, PUH and Paint EOP flag Yellow at 8999.9ft. 22:15 00:00 1.75 10,540 5,190 PROD1 DRILL TRIP P POOH laying in 11.8ppg completion fluid with alpine beads up to window. Paint EOP flag White at 5899.8ft. 03/25/2013 Ran liner in B lateral to 10,540'setting the anhored billet at 9159'. kicked off billet, started drilling BL1 lateral. 00:00 01:15 1.25 5,190 72 PROD1 DRILL TRIP P Continue POOH 01:15 01:30 0.25 72 72 PROD1 DRILL SFTY P OOH,Check well for flow. PJSM for LD drilling tools. 01:30 02:00 0.50 72 0 PROD1 DRILL PULD P Laydown BHA 02:00 02:15 0.25 0 0 PROD1 DRILL SVRG P Tighten reel bolts on reel saddles. Prep Rig floor for running liner. 02:15 02:45 0.50 0 100 COMPZ CASING PUTB P M/U"B"liner 02:45 03:00 0.25 100 100 COMPZ CASING SFTY P BOPE Drill with rig crew. Drill Time 1min 32sec. 03:00 05:00 2.00 100 1,440 COMPZ CASING PUTB P Continue M/U"B"liner assy. • 05:00 08:00 3.00 1,440 10,540 COMPZ CASING RUNL P RIH-with 41 jts of slotted liner for "B"lateral completion with Anchored billet.Open EDC.See first flag 7340' -13',close EDC. CIH,see second flag 100'off BTM,good.Tag up @ 10540. Pull up for pick up wt,40.5k. Run back down, 10539.38,2.4 k WOB. Pressure up coil to 4000 psi, shear running tool. Pick-off,35k liner gone. 08:00 10:45 2.75 10,540 0 COMPZ CASING RUNL P POOH pumping mininum rate down coil to keep hole full. 10:45 11:30 0.75 0 0 COMPZ CASING PUTB P Tagged up.Watch for no flow. Conduct PJSM for BHA change out. Page 7 of 13 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 11:30 15:30 4.00 0 0 PROD2 STK SVRG P Service injector, replace pack offs. Chanhe out checjs.Coil has a flat spot just above the coil connector. Decide to cut coil to just above flat spot&re-head. 15:30 16:15 0.75 0 0 PROD2 STK PULD P Pre-Job, Pu drilling BHA. 16:15 18:15 2.00 72 7,140 PROD2 STK TRIP P RIH 18:15 18:30 0.25 7,140 7,140 PROD2 STK DLOG P Log K-1,for a-13'correction. 18:30 19:45 1.25 7,140 7,452 PROD2 STK CIRC P RIH to just above window 7452'. Pump 9.5 flo-pro drilling down coil circulating&recovering the completion fluid. 19:45 20:15 0.50 7,452 9,160 PROD2 STK TRIP P Close EDC, RIH 20:15 22:30 2.25 9,160 9,170 PROD2 STK KOST P Tag TOB @ 9160'. Kick off billet, time milling, Have several stalls. Pick up 100'&try again.apperars to be slip sticking. 22:30 23:30 1.00 9,170 9,195 PROD2 DRILL DRLG P Drill Ahead 1.38bpm at 3759psi. BHP 4632 23:30 23:45 0.25 9,195 9,150 PROD2 DRILL WPRT P PUH and drift billet area. 23:45 00:00 0.25 9,150 9,195 PROD2 DRILL WPRT P RBIH-Billet area clean 03/26/2013 Drilled 9195 to 10225',Swapped mud @ 10225 00:00 01:15 1.25 9,195 9,325 PROD2 DRILL DRLG P BOBD-1.40bpm at 4015psi, BHP 4173,WHP 47,WOB 1.5, ROP 01:15 01:30 0.25 9,325 9,180 PROD2 DRILL WPRT P Wiper up to bottom of billet 9170ft 01:30 01:45 0.25 9,180 9,325 PROD2 DRILL WPRT P Wiper back in hole. RIW 16k 01:45 03:30 1.75 9,325 9,475 PROD2 DRILL DRLG P BOBD 1.43bpm at 3923psi. BHP 4131,WHP 39,WOB 1.5k ROP 100fph 03:30 04:00 0.50 9,475 9,180 PROD2 DRILL WPRT P Wiper to the billet PUW 34k 04:00 04:30 0.50 9,180 9,475 PROD2 DRILL WPRT P Wiper back in hole. RIW 15k 04:30 06:15 1.75 9,475 9,625 PROD2 DRILL DRLG P BOBD-1.40bpm at 3960psi, BHP 4160,WHP 38, CTW 11k 06:15 07:15 1.00 9,625 7,510 PROD2 DRILL WPRT P Wiper up fora tie in. PUW 36k 07:15 07:30 0.25 7,510 7,550 PROD2 DRILL DLOG P Tie into RA marker correction of+1' 07:30 08:30 1.00 7,550 9,625 PROD2 DRILL WPRT P Wiper back in hole. RIW 16k 08:30 11:00 2.50 9,625 9,775 PROD2 DRILL DRLG P BOBD-1.40bpm at 3923psi, BHP 4054,WHP 40,CWT 12k 11:00 11:30 0.50 9,775 8,700 PROD2 DRILL WPRT P Wiper up hole. PUW 36k 11:30 12:00 0.50 8,700 9,775 PROD2 DRILL WPRT P Wiper back in hole. RIW 12:00 14:00 2.00 9,775 9,925 PROD2 DRILL DRLG P BOBD-1.40bpm at 3963, BHP 4109,WHP 40, CTW 12k, IA 457, OA 63 14:00 14:30 0.50 9,925 8,700 PROD2 DRILL WPRT P Wiper up hole. PUW 36k 14:30 15:30 1.00 8,700 9,925 PROD2 DRILL WPRT P Wiper back in hole. RIW 15k Page 8 of 13 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 15:30 17:18 1.80 9,925 10,075 PROD2 DRILL DRLG P BOBD-1.4bpm at 3964psi,BHP 4220 ,WHP 110, IA 485 ,OA 64 17:18 20:12 2.90 10,075 10,075 PROD2 DRILL WPRT P Wiper to window with tie in, PUW=35K no correction at tie in 20:12 22:54 2.70 10,075 10,225 PROD2 DRILL DRLG P 10075', Drill Ahead, 1.4 BPM @ 3750 PSi FS, BHP=4220 22:54 00:00 1.10 10,225 9,732 PROD2 DRILL WPRT P 10225 wiper to 9200',Swap Mud. Midnight 9732 RIH 03/27/2013 TD well @ 10393',Wiper to swab, Pump liner Pill and 12.2 Completion fluid. Run Lower BL1 liner 10392 to 8540 00:00 00:18 0.30 9,732 10,225 PROD2 DRILL WPRT P Continue wiper from 10225' 00:18 02:54 2.60 10,225 10,392 PROD2 DRILL DRLG P 10225',Drill Ahead, 1.44 BPM @ 4050 PSi FS,(New Mud), BHP=4200 02:54 06:30 3.60 10,392 0 PROD2 DRILL WPRT P 10392',Call TD,Pump 10-10 sweeps and chase to swab valves. PUW=35K 06:30 08:00 1.50 0 7,150 PROD2 DRILL WPRT P RIBIH,continue wiper in hole. 08:00 08:15 0.25 7,150 7,181 PROD2 DRILL DLOG P Tie into the K1 marker correction of 0 ft. 08:15 10:00 1.75 7,181 10,392 PROD2 DRILL WPRT P RIH 10:00 13:00 3.00 10,393 0 PROD2 DRILL TRIP P Confirm TD 10393', POOH laying in 11.8ppg completion fluid with alpine beads. Paint EOP flag at 8471.72' Yellow.5571.78'White. 13:00 13:30 0.50 0 0 PROD2 DRILL SFTY P Conduct PJSM for laying down drilling BHA while flow checking well. 13:30 14:15 0.75 0 0 PROD2 DRILL PULD P LD Drilling BHA 14:15 14:45 0.50 0 0 PROD2 DRILL SVRG P Service top drive and prep rig floor for liner ops 14:45 15:00 0.25 0 0 COMPZ CASING SFTY P Conduct PJSM for M/U liner 15:00 15:30 0.50 0 0 COMPZ CASING PUTB P M/U 59 jts of slotted liner-BOPE drill while tripping in with tubing drill time was 2mins 45sec. 15:30 16:00 0.50 0 189 COMPZ CASING PUTB P Rabbit failed to go through pipe. Switch out joint,and try and retrieve rabbit. 16:00 19:00 3.00 189 1,896 COMPZ CASING PUTB P continue M/U liner,Make up to coil and surface test.Strip on well 19:00 19:45 0.75 1,896 1,896 COMPZ CASING RGRP T Working CTES Issues to ensure coil fatigue operational 19:45 21:21 1.60 1,896 7,395 COMPZ CASING TRIP P Trip in well 21:21 21:27 0.10 7,395 7,399 COMPZ CASING DLOG P Tie in to EOP flag for-13.2, PUW=39K 21:27 22:15 0.80 7,399 8,985 COMPZ CASING TRIP P RIH with liner 22:15 22:21 0.10 8,985 9,000 COMPZ CASING DLOG P Tie in to K1 Marker,for no correctiom 22:21 23:03 0.70 9,000 10,392 COMPZ CASING TRIP P Continue in with liner, No correction at lower flag drive by 23:03 00:00 0.95 10,392 7,744 COMPZ CASING TRIP P Tag @ 10392„ PUW=45K with liner, set back down, Pumps on @ 1.25 BPM, PUW=38K. Liner released POOH Page 9 of 13 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 03/28/2013 24 hr Summary Complete running BL1 Liner BOL=10392,TOL=7901,Complete full BOPE Test.Test witnes waived By Bob Nobel,AOGCC 00:00 02:00 2.00 7,744 41 COMPZ CASING TRIP P Continue out of well Paint EOP flags @ 7700 and 6700 02:00 02:36 0.60 41 0 COMPZ CASING PULD P At surface, Flow check well, PJSM lay down BHA on dead well 02:36 04:00 1.40 0 630 COMPZ CASING PUTB P PJSM, Start making up BL1 Upper liner section, Ported bullnose,20 jts slotted liner and anchored billet. Held Safety joint drill 3 Minutes good test 04:00 06:00 2.00 630 630 COMPZ CASING PULD P P/U,M/U,and scribe BHI tools onto liner assy. 06:00 08:00 2.00 630 7,401 COMPZ CASING RUNL P RIH-w/20jts of slotted and anchored billet. IA 0,OA 61 08:00 08:15 0.25 7,401 7,401 COMPZ CASING DLOG P Correct to EOP Flag correction of- 14'. 08:15 08:45 0.50 7,401 8,140 COMPZ CASING RUNL P Continue RIH with liner 08:45 09:00 0.25 8,140 8,154 COMPZ CASING DLOG P Gamma tie into RA marker correction of+2'. 09:00 09:15 0.25 8,154 8,541 COMPZ CASING RUNL P Continue in hole with upper liner section 09:15 11:00 1.75 8,541 0 COMPZ CASING RUNL P POOH circulating pipe displacement. 11:00 11:15 0.25 0 0 COMPZ CASING SFTY P Conduct PJSM-UD liner running tools while performing a flow check. 11:15 12:15 1.00 0 0 COMPZ CASING PULD P Blow down and UD BHI and BOT BHA. 12:15 13:15 1.00 0 0 COMPZ CASING PULD P R/D liner running eqiupment. 13:15 14:45 1.50 0 0 PROD3 DRILL BOPE P Prep to start BOP tesing. 14:45 15:30 0.75 0 0 PROD3 DRILL BOPE P Conduct PJSM-BOPE Testing- grease tree 15:30 23:00 7.50 0 0 PROD3 DRILL BOPE P Start BOPE testing,Test witness waived by Bob Nobel,AOGCC 23:00 23:48 0.80 0 0 PROD3 DRILL PULD P PJSM, P/U BHA#10 Drill By BHA with .7°motor, Hyc Bicenter with test cutters 23:48 00:00 0.20 0 0 PROD3 DRILL SVRG P Tool in hole,servicing injector 03/29/2013 Trip in and Kick off liner top Billet @ 7897, Drill ahead to 8960 00:00 00:30 0.50 0 72 PROD3 STK PULD P Make up coil to BHA and surface test 00:30 02:24 1.90 72 7,155 PROD3 STK TRIP P Trip in in casing,EDC Open 02:24 02:36 0.20 7,155 7,192 PROD3 STK DLOG P Log K1 for-14' 02:36 03:48 1.20 7,192 7,450 PROD3 STK CIRC P Swap well back to 9.5 PPG Flo Pro 03:48 04:06 0.30 7,450 7,898 PROD3 STK TRIP P Close EDC, PUW=34.6K,Trip in to find billet,Clean trip through window, Dry tag billet @ 7897.56 04:06 04:54 0.80 7,898 7,897 PROD3 STK MILL P PUH, Bring pumps on @ 1.4 BPM@ 4000 PSI FS, BHP=4047,See DHWOB and diff press @ 7897.0 04:54 05:30 0.60 7,897 7,900 PROD3 STK MILL P Stacking out, Pick up and reset, Milling Billet. Seem to be off of billet. Page 10 of 13 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:30 06:00 0.50 7,900 7,940 PROD3 DRILL DRLG P Drilling Ahead 06:00 06:15 0.25 7,940 7,885 PROD3 DRILL WPRT P PUH and dry drift billet area. 06:15 06:30 0.25 7,885 7,940 PROD3 DRILL WPRT P RIH past billet clean. 06:30 07:15 0.75 7,940 8,040 PROD3 DRILL DRLG P Drilling Ahead 1.41 bpm at 4030psi. BHP 4041,WHP 4,WOB 1.4k, ROP 130fph. IA 24,OA 65 07:15 07:45 0.50 8,040 7,530 PROD3 DRILL WPRT P Wiper up to 7530', PUW 33k 07:45 08:15 0.50 7,530 8,040 PROD3 DRILL WPRT P Wiper back in hole. RIW 18k 08:15 09:30 1.25 8,040 8,190 PROD3 DRILL DRLG P BOBD-1.41bpm at 4030psi, BHP 4030,WHP 5. 09:30 10:00 0.50 8,190 7,530 PROD3 DRILL WPRT P Wiper up to 7530ft. PUW 33k 10:00 10:30 0.50 7,530 8,190 PROD3 DRILL WPRT P Wiper back in hole. RIW 18k 10:30 11:30 1.00 8,190 8,340 PROD3 DRILL DRLG P BOBD-1.41bpm at 4030psi. BHP 4032,WHP 5, IA 73,OA 66. 11:30 12:00 0.50 8,340 7,510 PROD3 DRILL WPRT P Wiper up to tie into the RA marker 12:00 12:15 0.25 7,510 7,551 PROD3 DRILL DLOG P Tie into RA marker correction of+1' 12:15 12:45 0.50 7,551 8,340 PROD3 DRILL WPRT P Wiper back in hole. RIW 16k 12:45 14:00 1.25 8,340 8,490 PROD3 DRILL DRLG P BOBD-1.43bpm at 4051psi, BHP 4117,WHP 91,WOB 1.5k, ROP 14:00 14:30 0.50 8,490 7,915 PROD3 DRILL WPRT P Wiper up to 7930'. PUW 33k 14:30 15:00 0.50 7,915 8,490 PROD3 DRILL WPRT P Wiper back in hole. RIW 16k 15:00 16:00 1.00 8,490 8,640 PROD3 DRILL DRLG P BOBD-1.40bpm at 4060psi. BHP 4037,WHP 20, IA 170,OA 66 16:00 16:30 0.50 8,640 7,915 PROD3 DRILL WPRT P Wiper up to 7930'. PUW 33k 16:30 17:15 0.75 7,915 8,640 PROD3 DRILL WPRT P Wiper back in hole. RIW 16k 17:15 18:15 1.00 8,640 8,773 PROD3 DRILL DRLG P BOBD 1.36bpm at 4053', BHP 4121, WHP 92,WOB 1.6k, ROP 140fph. 18:15 18:21 0.10 8,773 8,773 PROD3 DRILL WPRT P Lost pump prime starting sweeps down hole. PUH then stacked out on way back in 18:21 19:15 0.90 8,773 8,773 PROD3 DRILL WPRT P Stuck just off bottom,Able to maintain full circulation,Work pipe. Circulate sweeps around to surface 19:15 19:27 0.20 8,773 8,773 PROD3 DRILL WPRT P Work Pipe,Trap pressure and let pipe hole relax, Pull free at 59K 19:27 20:21 0.90 8,773 7,510 PROD3 DRILL WPRT P Wipe to window 20:21 20:27 0.10 7,510 7,526 PROD3 DRILL DLOG P Log RA Marker for-.5'correction 20:27 20:57 0.50 7,526 8,773 PROD3 DRILL WPRT P Wiper trip back to bottom 20:57 22:27 1.50 8,773 8,925 PROD3 DRILL DRLG P 8773 Drill ahead, 1.4 BPM @ 3700 PSI FS, BHP=4080 22:27 23:39 1.20 8,925 8,925 PROD3 DRILL WPRT P Wiper to Billet 7990, PUW=34K 23:39 00:00 0.35 8,925 8,960 PROD3 DRILL DRLG P 8925', Drill Ahead, 1.4 BPM @ 3740 PSi FS, BHP=4110 03/30/2013 Drilled 8960 to 9840 00:00 01:12 1.20 8,960 9,075 PROD3 DRILL DRLG P Drill ahead 1.4 BPM @ 3750PSI FS, BHP=4140 Page 11 of 13 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 01:12 02:30 1.30 9,075 9,075 PROD3 DRILL WPRT P Wiper to 7940, PUW=35K 02:30 04:30 2.00 9,075 9,225 PROD3 DRILL DRLG P 9075', Drill ahead, 1.44 BPM @ 3900 PSI FS, BHP=4140, RIW-16K New mud at bit @ 9178, 1445'on old system.6% DS 04:30 05:30 1.00 9,225 7,510 PROD3 DRILL WPRT P 9225 wiper to window with tie in. PUW=34K, BHP=4130,WHP=115 05:30 05:45 0.25 7,510 7,525 PROD3 DRILL DLOG P Tie into RA marker NO correction. 05:45 06:30 0.75 7,525 9,225 PROD3 DRILL WPRT P Wiper back in hole. RIW 15k 06:30 07:30 1.00 9,225 9,375 PROD3 DRILL DRLG P BOBD-1.48bpm at 4085psi, BHP 4142,WHP 109, IA 511, OA 69 07:30 08:15 0.75 9,375 8,000 PROD3 DRILL WPRT P Wiper up to 7930', PUW 34k 08:15 09:00 0.75 8,000 9,375 PROD3 DRILL WPRT P Wiper back in hole. RIW 09:00 13:30 4.50 9,375 9,525 PROD3 DRILL DRLG P 9375ft-BOBD 1.40bpm at 3950psi. BHP 4130,WHP 92, IA 588,OA 70 13:30 14:00 0.50 9,525 8,350 PROD3 DRILL WPRT P Wiper up hole, PUW 33 14:00 14:30 0.50 8,350 9,525 PROD3 DRILL WPRT P Wiper back in hole. RIW 16 14:30 17:54 3.40 9,525 9,675 PROD3 DRILL DRLG P BOBD-1.46bpm at 3960psi, BHP 4130,WHP 66, IA 634,OA 70 17:54 19:00 1.10 9,675 7,510 PROD3 DRILL WPRT P Wiper up hole. PUW 33k 19:00 19:06 0.10 7,510 7,526 PROD3 DRILL DLOG P Log tie into RA marker for no correction 19:06 20:12 1.10 7,526 9,675 PROD3 DRILL WPRT P Wiper back in hole. RIW 20:12 22:06 1.90 9,675 9,825 PROD3 DRILL DRLG P 9675', Drill ahead, 1.4 BPM @ 3790 PSI FS, BHP=4160 22:06 23:48 1.70 9,825 9,825 PROD3 DRILL WPRT P Wiper to billet 7925', PUW=33K 23:48 00:00 0.20 9,825 9,840 PROD3 DRILL DRLG P 9825', Drill Ahead, 1.4 BPM @ 3800 PSI FS, BHP=4230 03/31/2013 TD well @ 10020',Condition Hole, run BL2 liner to bottom TOL=7465, BOL=10020 00:00 02:12 2.20 9,840 9,975 PROD3 DRILL DRLG P 9840', Drill ahead 02:12 04:12 2.00 9,975 9,975 PROD3 DRILL WPRT P 9975',Wiper to billet 7925', PUW=32K, BHP=4200, Clean trip out and in 04:12 05:30 1.30 9,975 10,020 PROD3 DRILL DRLG P 9975', Drill Ahead, 1.4 BPM @ 3850 PSI FS, BHP=4137 05:30 08:30 3.00 10,020 72 PROD3 DRILL WPRT P Pump 10x10,TD BL2 lateral 10020ft. Wiper to the swab. PUW 33 08:30 10:00 1.50 72 7,150 PROD3 DRILL WPRT P At surface. RBIH to tie into the K1. 10:00 10:15 0.25 7,150 7,168 PROD3 DRILL DLOG P Tie into the K1 correction of minus 2'. 10:15 11:45 1.50 7,168 10,020 PROD3 DRILL WPRT P Continue tripping in hole to confirm TD10020ft 11:45 15:00 3.25 10,020 0 PROD3 DRILL TRIP P PUH laying in 11.8ppg completion fluid with 2ppb alpine beads, Paint EOP Flags @ 7300&4800' 15:00 15:45 0.75 0 0 PROD3 DRILL PULD P Conduct PSJM to UD Drilling BHA. 15:45 16:21 0.60 0 0 COMPZ CASING PULD P PJSM, Prep floor to run liner Page 12 of 13 s Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:21 19:45 3.40 0 2,554 COMPZ CASING PUTB P M/U BHA#11, Non ported bullnose, 76 Jts 2 3/8"slotted,5 jts 2 3/8" solid,and long deployment sleeve 19:45 20:45 1.00 2 554 2 598 COMPZ CASING PULD P 9 5 5 R/D floor from liner running,P/U Coil track, M/U to liner,M/U to coil and surface test tool 20:45 22:09 1.40 2,598 7,398 COMPZ CASING TRIP P Trip in with liner, EDC closed 22:09 22:15 0.10 7,398 7,398 COMPZ CASING DLOG P Tie into 4300'EOP flag for-11.4' correction, PUW=38K 22:15 22:51 0.60 7,398 9,680 COMPZ CASING TRIP P Continue in well,clean trip through window 22:51 23:03 0.20 9,680 9,705 COMPZ CASING DLOG P Log K1 marker for+5 correction, BOT counter has quit working after starting in hole continue to bottom 23:03 23:57 0.90 9,705 10,020 COMPZ CASING TRIP P Run liner to bottom, PUW=56K Can get numbers to work out between CTS and injector counter, Pump on @ 1.4 BPM @ 4K PSI, PUW=35K. Trip up hole to confirm tie in, remove liner length from counters 2554.37' 23:57 00:00 0.05 7,130 7,145 COMPZ CASING DLOG P 7130 log tie into K1 correction of+ 5ft 04/01/2013 Land liner, Roll well to seawater and Freeze protect to 2500'.Set BPV,flush rig RDMO 00:00 00:06 0.10 7,145 7,165 COMPZ CASING DLOG P Tieing into K1 marker for-1', BOL=10020,TOL=7465, 00:06 00:12 0.10 7,165 7,450 COMPZ CASING TRIP P RBIH to circulate seawater around 00:12 01:12 1.00 7,450 7,450 DEMOB WELLPF CIRC P Roll well to seawater,recover Bromide completion fluid 01:12 02:36 1.40 7,450 2,500 DEMOB WELLPF TRIP P POOH on seawater, PUW=33.5K 02:36 03:00 0.40 2,500 2,500 DEMOB WELLPF FRZP P Freeze protect well with Diesel 03:00 03:48 0.80 2,500 30 DEMOB WELLPF TRIP P Open EDC, POOH chasing diesel out of coil with seawater 03:48 06:00 2.20 30 0 DEMOB WELLPF PULD P At surface, PJSM, PUD BHA#11, Liner running tools 06:00 06:15 0.25 0 0 DEMOB WHDBO NUND P Conduct PJSM with FMC and rig crew for setting BPV. 06:15 08:45 2.50 0 0 DEMOB WHDBO NUND P Set BPV 3inch Type H 08:45 09:00 0.25 0 0 DEMOB WHDBO NUND P Conduct PJSM-swapping coil over to fresh water and flushing surface lines. 09:00 11:45 2.75 0 0 DEMOB WHDBO NUND P Conduct PJSM-RDMO 11:45 12:00 0.25 0 0 DEMOB WHDBO NUND P XXXXX RIG RELEASE 12:00 NOON XXXX Page 13 of 13 Letter of Transmittal WARM 3 BAKER Date: HUGHES April 3, 2013 L0 0,A To: From: Christine Mahnken Carl Ulrich/Michael Soper 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): 1G-10B , , 13 1G-10BL1 2,(3 a Z 2 1G-10BL2 1G-10BPB1 � - U) � ;, 1 3 ). (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of re m..1 . � r Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich @BakerHughes.com %, or T� y4•e\�����j,��� THE STATE Alaska Oil and Gas °fALASIc:A Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue o "F� Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt Coiled Tubing Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1G-10BL2 ConocoPhillips Alaska, Inc. Permit No: 213-023 Surface Location: 386' FSL, 793' FWL, SEC. 29, T12N, R10E, UM Bottomhole Location: 572' FNL, 2600' FWL, SEC. 32, T12N, R10E, UM Dear Mr. Gantt: 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 1G-10B, Permit No 213-021, API 50-029-21003-02-00. 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, GI-e—t-0 Cathy . Foerster Chair DATED this day of February, 2013. . RECEIVED STATE OF ALASKA FEB 1 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL �,,M�o;h ®GCG 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil 0• Service-Winj ❑ Single Zone 1c.Specify if well is proposed for: Drill ❑ • Lateral 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ 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• 1G-10BL2• 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10100'• TVDSS: 6464'• Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:386'FSL,793'FWL,Sec.29,T12N, R10E,UM• ADL 25640 . Kuparuk River Oil Pool• Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1042'FSL, 1228'FEL,Sec.29,T12N,R10E,UM 2571 3/18/2013 Total Depth: 9.Acres in Property: 14.Distance to ■ 572'FNL,2600'FWL,Sec.32,T12N,R10E, UM • 2560 Nearest Property: 10665' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: - 94 feet 15.Distance to Nearest Well Open Surface:x- 540572 y- 5981035 Zone- 4• GL Elevation above MSL: • 31 feet to Same Pool: 1G-11,1865' 16.Deviated wells: Kickoff depth: 7900. ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 104°, deg Downhole:3907 psig Surface:3383 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" 2.375" 4.7# L-80 ST-L 2630' 7470' 6482' 10100' 6554' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 7906 6864 none 7815 6789 none Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16" 116' 116' 212 sx CS II Surface 2313' 10.75 2350' 2185' 930 sx AS III,250 sx AS I Intermediate Production 6255' 7" 6290' 5441' 850 sx Class G,250 sx AS Liner 1764' 3.5" 7906' 6868' 396 sx Class G Perforation Depth MD(ft): Perforation Depth TVD(ft): 7318-7340, 7352-7358, 7366-7374, 7614-7644 6354-6373, 6384-6389, 6396-6403, 6613-6639 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Kai Starck @ 263-4093 Email Kai.Starcki conocop li .com Printed Name Lamar Gantt Title Coiled Tubing Drilling Supervisor j Signature *OJyLu.t.. (), 4'\ tiAA, _ Phone:263-4021 Date 71/`-//3 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 2 1 ; L 3 50- G y — `�'00 3—61—00 I Date: � A.\ 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: ✓❑' Other: t3 C r to5f to +6 cc pS/ Samples req'd: Yes ❑ No Q Mud log req'd: Yes El No Z' H2S measures: Yes 21 No ❑ Directional svy req'd: Yes ✓r No❑ I� Spacing exception req'd: Yes ❑ No 2 Inclination-only svy req'd: Yes❑ No 21 AgPRovED V THE / Approved by: ) COMMi6SION COMMISSION Date: Z —ZS Form 10-401(Revd 10/2012) This permit is valid for 24 menthsl Mom the date Ofapproval(20 AAC 25.005(g)) \�� LP. 2/13 � t '1, RECEIVE 1►� FEB 15 2? ConocoPhillips Alaska AOGCC P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 14,2013 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete 1G-10B, 1G- 10BL1 and 1 G-10BL2 from Kuparuk well 1G-10A(PTD#196-140). Coiled tubing drilling (CTD)operations are scheduled to begin March 18, 2013 using the Nabors CDR2-AC rig. Producer 1G-10B is part of a development concept to increase throughput in an unswept A-sand pattern. The planned 1H-19A injector to the east will increase sweep efficiency to this new producer. Prior to commencing CTD operations all of the original A and C-sand perforations will be squeezed. There will be a cement plug left at 7510' above the A-sand perforations. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A and C-sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 7482' MD. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary — Permit to Drill application forms for 1G-10B, 1G-10BL1 and 1G-10BL2 — Directional plans for 1G-10B, 1G-10BL1 and 1G-10BL2 — Current wellbore schematic — Proposed wellbore schematic after CTD operations — 10-403 to plug perforations in the 1G-10A If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, Kai Starck ConocoPhillips Alaska Coiled Tubing Drilling Specialist e Kuparuk CTD Laterals NABORS ALASKA Drilling j; J &Wells 1G-10B, 1 G-10BL1 and 1 G-10BL2 Application for Permit to Drill Document flC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) '' '• 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 2 (Requirements of 20 AAC 25.005(c)(6)) 2 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 MC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 MC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) Error! Bookmark not defined. (Requirements of 20 AAC 25.402) Error!Bookmark not defined. 17. Construction of Injection Wells Error! Bookmark not defined. (Requirements of 20 AAC 25.412) Attachment 1: Directional Plans for 3C-11A,3C-11AL1 6 Attachment 2: Current Well Schematic for 3C-11 6 Attachment 3: Proposed Well Schematic for 3C-11 CTD Laterals 6 Page 1 of 6 February 14,2013 PTD Application for KRU 1G-10B, BL1, BL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) There are three proposed laterals described in this document: KRU 1G-10B, 1G-10BL1 and 1G-10BL2. 1G- 10A. The B sidetrack will be drilled off the motherbore and the BL1 and BL2 laterals will be drilled off the B sidetrack. All three will be classified as"Development-Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The 1G-10B sidetrack is planned to target the Kuparuk A4 sand to north of the existing well. The 1 G-10BL1 lateral is planned to target the Kuparuk A3 sand to the north of the existing well. The 1 G-10BL2 lateral is planned to target the A4 sand to the southwest of the existing well. See the attached 10-401 forms for surface and subsurface coordinates of each of the 1G-10 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP)schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4000 psi. Using a maximum potential formation pressure of 4022 psi, the maximum potential surface pressure is 3383 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure"section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The latest 1G-10A SBHP taken 1/13 was 2630 psi for an 8.1 EMW from the C3/C4 and the A4/A5 sands. The 1G-10B and BL1 laterals will be approaching 1G-07 producer which had the latest SBHP in October 2012 showing 2557 psi for the A sand, 7.5 EMW. 1H-03 water injector to the east has a current BHP of 3907, 12.1 EMW and is the highest pressure in the area. It is not expected that pressures as high as 1H-03 will be encountered during the drilling operations due to offset distance. Using the 1H-03 formation pressure as the maximum possible in 1G-10B,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3383 psi. • Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled and there has been no gas or Ml injection in the area Potential Causes of Hole Problems(Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 1G-10B laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target of 11.8 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 1G-10B laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Page 2 of 6 o`, " -- February 14,2013 PTD Application for KRU 1G-10B, BL1, BL2 New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD IG-10B 8930' 10,380' 6582' 6594' 2'h , 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1G-10BL1 7895' 10,400' 6640' 6624' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top • 1G-10BL2 7470' 10,100' 6482' 6554' 23/", 4.7#, L-80, ST-L slotted liner; • Deployment sleeve on top Existing Casing/Liner Information Weight Top Btm Top Btm Burst Collapse Category OD (ppfl Grade Connection MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 39' 116' 0' 116' Surface 10-3/4 45.5 K-55 BTC 37.1' 2350' 0' 2185' 3580 2090 Casing 7" 26 K-55 BTC 35.1' 6290' 0' 5441' 4980 4320 Liner 3'/2" 9.3 L-80 IBT 6142' 7906' 5305' 6868' 10,160 10,530 Tubing 3%" 9.3 J-55 AMB-EUE 26 6151' 0' 5315' 6990 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.5 ppg) - Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.5 ppg). This mud weight alone will hydrostatically overbalance formation pressure in the 1G-10A motherbore. MPD practices described below will increase the overbalance to enhance shale stability. - Completion operations: The well will be loaded with 11.8 ppg sodium bromide completion fluid in order to maintain pressure over-balance while picking up liner. - Emergency Kill Weight fluid: Two well bore volumes(-200 bbl)of 12 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections,while at the same time providing pressure over- balance to the formation. In the 1 G-10 laterals we will target a constant BHP of 11.8 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Page 3 of 6 February 14,2013 PTD Application for KRU 1G-10B, BL1, BL2 Pressure at the 1G-10B Window(7482' MD, 6393' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (8.1 ppg) 2692 psi 2692 psi Mud Hydrostatic(9.5 ppg) 3158 psi 3158 psi Annular friction (i.e. ECD, 0.090 psi/ft) 711 psi 0 psi Mud + ECD Combined 3869 psi 3158 psi (no choke pressure) (overbalanced (overbalanced . 1231 psi) 466 psi) • Target BHP at Window(11.8 ppg) 3923 psi 3923 psi Choke Pressure Required to Maintain 54 psi 765 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1G-10 was originally completed in 1984 as a C1-sand producer. In 1996 it was sidetracked and 1G-10A was an A-sand producer until 1999 when the C3 and C4 intervals were perforated and stimulated with a small fracture treatment. The well continued as an A and C sand dual producer until October 2012 when it was shut in due to low productivity and freezing issues. The C-sand perforations will be cement squeezed with a cement plug left over the A-sand perforations. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A- sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 7482' MD. A mechanical whipstock will be placed in the 3%" liner at the planned kickoff point. The 1G-10B sidetrack will exit the 3W casing at 7482' MD and target the A4 sand to the north of the existing well with a 2918' lateral. The hole will be completed with a 2%"slotted liner to the TD of 10,380' MD with an aluminum billet at 8930' MD. The 1 G-10BL1 lateral will kick off from the aluminum billet at 8930' MD and will target the A3 sand north of the existing well with a 1465' lateral. The hole will be completed with a 2%"slotted liner to the TD of 10,400' MD with an aluminum billet at 7895' MD. L„) I\ <r � 5xr Page 4 of 6 February 14,2013 PTD Application for KRU 1G-10B, BL1, BL2 The 1G-10BL2 lateral will kick off from the aluminum billet at 7895' MD and will target the A4 sand southwest of the existing well with a 2200' lateral. The hole will be completed with a 2%"slotted liner to the TD of 10,100' MD with a liner top deployment sleeve at 7470' MD, inside the 3%" liner. Pre-CTD Work 1. MIRU slickline. Dummy all GLMs. 2. MIRU e-line, perform CBL 3. OPTIONAL-Pending results of CBL-MIRU e-line, perforate 3-1/2" liner at 7480-7490. To ensure good cement isolation at the window from the C1. 4. Perform injectivity test into open A&C-sand perfs. 5. MIRU coiled tubing. Cement squeeze the open perforations and lay in cement in the 3-1/2" liner, leaving the cement top in the 3-1/2" liner at 7290'. 6. Coiled tubing. Mill 2.75" Camco D nipple at 6141'to 2.80" 7. Mill cement from 7290'to 7510'with a bi-center bit. This will leave a cement plug 100' above the A-sand perforations. 8. MIRU slickline. Run whipstock dummy inside 3'/2"liner. 9. Prep site for Nabors CDR2-AC, including setting BPV G 5 I P 9 9 f"�b�' fo lJ-G /� N t, t}-OUCC zf Rig Work c,dvar,cc 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE, test. 2. 1G-10B Sidetrack(A4 sand, North) pur4- f(7-1O7' a. Set whipstock at 7482' MD with 140 ROHS orientation 194.-1,4-0 b. Mill 2.80"window through 3%" liner c. Drill 2.70"x 3" bi-center lateral to TD of 10,380' MD PTD tc.z.- 03 d. Run 2%" slotted liner with an aluminum billet from up to 8930'__ 2 i 3-0 z1 3. 1G=10131-1-Lateral (A3 sand, north) a. Kick off of the aluminum billet at 8930' MD pro 14 6d 43 1 b. Drill 2.70"x 3" bi-center lateral to TD of 10,400' MD 213-0 12 c. Run 2%" slotted liner with an aluminum billet from TD up to 7895' MD 4. 1G-10BL2 Lateral (A4 sand, south) p i-n ILI!o BL-L. a. Kick off of the aluminum billet at 7895' MD 2` 3 _o 2-3 b. Drill 2.70"x 3" bi-center lateral to TD of 10,100' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7470' MD inside the 3%2" liner 5. Freeze protect. Set BPV, ND BOPE. 6. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP, Install gas lift valves 3. Put well on production Pressure Deployment of BHA The planned bottomhole assemblies(BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. Page 5 of 6 ` February 14,2013 PTD Application for KRU 1G-10B, BL1, BL2 — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize,internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running — Fluid of sufficient density to over-balance the formation will be used to provide well control. See the "Drilling Fluids"section for more details. — While running 2%"slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — 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. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 10-10B 11 11,245' 748' 1G-07 1 G-10 B L1 04 11,150' 744' 1G-07 1G-10BL2 05 10,665' 1865' 1G-11 Attachment 1: Directional Plans for 1G-10B, 1G-10BL1 and 1G-10BL2 Attachment 2: Current Well Schematic for 1G-10A Attachment 3: Proposed Well Schematic for 1G-10B CTD Laterals Page 6 of 6 February 14,2013 II N N 3 c° I II g o° Z o ( z iD Q'c I Q ° o v m ‘-' .1110 o Qv o_ N th ° II � � V' c I-- in N M m M Y cvi Y E ED Ct m �_ a co o w N�Y (f7 V (O r (O CO y N g © i1YO II Y o " © mod m c -o o E my E c E win.,- 0 cg in 3 E E _a N t H c o) ://p N -6 C N 0`oC R) Q CO 0) @ -a 0 as or m a W 0 4' C N Q'C lL awe m Co L m p ° (i. 2 0 v a co I o o o o. i U° U as co as as as P U of U U U r) o =°co ?' g 1 m N N CVm CV N Y N oYY Q. U •� ,-Y 7 7 m coot O o _ 11 M M MCC M co (Y] J (OM a. (V d /„.--- � ` cE 22 I ° 2° 2 CL c N oco liY Er,- Iii , 1 L.-- i \ , II 11 • +, /r IIT • +... , Y r �I o \iii IC. I� 1 o ° I v I 6 °'N o o I � ry�O c �� v rn(Al• (n ° in° I "NO O � -') n N2 0a� N I t(0 N N o � t-L *t O Y p ) 3 t _ (o (n CL It LZ..1`- It g N M O 6)N ' -c I 'c (7 u) N -I. N N (0 7 - o v aU N „., co Qo .- N M O O N V ti Q °c J O °°T Q 0 0 ORIGIN! �- r ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1G Pad 1G-10 1 G-10BL2 Plan: 1 G-10BL2_wp05 Standard Planning Report 12 February, 2013 r' 1 BAKER HUGHES ■ap-' ConocoPhillips or its affiliates Ird'' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1G-10 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site: Kuparuk 1G Pad North Reference: True Well: 1G-10 Survey Calculation Method: Minimum Curvature Wellbore: 1 G-10BL2 Design: 1 G-10BL2_wp05 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 1G Pad Site Position: Northing: 5,981,540.78ft Latitude: 70°21'37.826 N From: Map Easting: 540,089.12ft Longitude: 149°40'27.705 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.31 ° Well 1G-10 Well Position +N/-S 0.00 ft Northing: 5,981,034.77 ft Latitude: 70°21'32.824 N +E/-W 0.00 ft Easting: 540,572.19 ft Longitude: 149°40'13.660 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1G-10BL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BG G M2011 12/31/2012 16.00 79.98 57,385 Design 1G-10BL2_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,895.17 Vertical Section: Depth From(TVD) +Nl-S +E/-W Direction (ft) (ft) (ft) C) 0.00 0.00 0.00 220.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +El-W Rate Rate Rate TFO (ft) (1 (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (`/100ft) (°) Target 7,895.17 103.94 271.70 6,549.35 448.87 3,090.99 0.00 0.00 0.00 0.00 8,030.00 91.24 276.28 6,531.58 458.23 2,957.98 10.00 -9.42 3.39 160.00 8,162.00 93.48 263.26 6,526.13 457.70 2,826.39 10.00 1.70 -9.86 280.00 8,262.00 90.85 272.91 6,522.34 454.37 2,726.64 10.00 -2.63 9.66 105.00 8,562.00 91.99 242.92 6,514.74 392.34 2,436.72 10.00 0.38 -10.00 272.50 9,062.00 91.28 192.91 6,499.52 10.45 2,139.30 10.00 -0.14 -10.00 270.00 9,287.00 91.18 215.41 6,494.64 -193.48 2,047.82 10.00 -0.04 10.00 90.00 9,537.00 91.07 190.41 6,489.65 -421.89 1,951.28 10.00 -0.04 -10.00 270.00 9,662.00 98.54 180.34 6,479.16 -545.64 1,939.58 10.00 5.97 -8.05 307.00 9,762.00 92.73 188.53 6,469.33 -644.73 1,931.86 10.00 -5.80 8.19 125.00 9,982.00 89.92 210.36 6,464.17 -850.85 1,859.08 10.00 -1.28 9.92 97.00 10,100.00 89.92 198.56 6,464.33 -958.07 1,810.31 10.00 0.00 -10.00 270.00 2/12/2013 12:34:03PM Page 2 COMPASS 2003.16 Build 69 b--- ConocoPhillips or its affiliates ,f' Conoco Phillips Planning Report HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1G-10 Company: ConocoPhillips(Afaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site: Kuparuk 1G Pad North Reference: True Well: 1G-10 Survey Calculation Method: Minimum Curvature Wellbore: 1 G-10BL2 Design: 1 G-10BL2_wp05 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (*) (ft) (ft) (ft) (ft) (°/100$) (°) (ft) (ft) 7,895.17 103.94• 271.70 6,549.35 448.87 3,090.99 -2,330.71 0.00 0.00 5,981,500.33 543,660.40 TIP/KOP 7,900.00 103.48 271.87 6,548.21 449.02 3,086.30 -2,327.81 10.00 160.00 5,981,500.45 543,655.71 8,000.00 94.07 275.28 6,532.96 455.21 2,987.79 -2,269.23 10.00 160.04 5,981,506.11 543,557.18 8,030.00 91.24 276.28 6,531.58 458.23 2,957.98 -2,252.38 10.00 160.56 5,981,508.97 543,527.35 Start 10 DLS 8,100.00 92.44 269.38 6,529.33 461.68 2,888.15 -2,210.13 10.00 -80.00 5,981,512.04 543,457.51 8,162.00 93.48 263.26 6,526.13 457.70 2,826.39 -2,167.39 10.00 -80.22 5,981,507.73 543,395.78 3 8,200.00 92.49 266.93 6,524.15 454.46 2,788.59 -2,140.60 10.00 105.00 5,981,504.28 543,358.00 8,262.00 90.85 272.91 6,522.34 454.37 2,726.64 -2,100.72 10.00 105.19 5,981,503.86 543,296.06 4 8,300.00 91.01 269.12 6,521.73 455.05 2,688.66 -2,076.82 10.00 -87.50 5,981,504.33 543,258.08 8,400.00 91.42 259.12 6,519.59 444.82 2,589.34 -2,005.14 10.00 -87.56 5,981,493.56 543,158.82 8,500.00 91.79 249.13 6,516.78 417.51 2,493.31 -1,922.50 10.00 -87.77 5,981,465.74 543,062.95 8,562.00 91.99 242.92 6,514.74 392.34 2,436.72 -1,866.84 10.00 -88.06 5,981,440.26 543,006.50 5 8,600.00 91.98 239.12 6,513.42 373.95 2,403.50 -1,831.40 10.00 -90.00 5,981,421.69 542,973.39 8,700.00 91.93 229.12 6,510.00 315.45 2,322.63 -1,734.60 10.00 -90.13 5,981,362.76 542,892.84 8,800.00 91.82 219.11 6,506.72 243.78 2,253.14 -1,635.04 10.00 -90.47 5,981,290.73 542,823.75 8,900.00 91.65 209.11 6,503.69 161.13 2,197.16 -1,535.74 10.00 -90.80 5,981,207.78 542,768.23 9,000.00 91.43 199.11 6,500.99 70.00 2,156.38 -1,439.72 10.00 -91.11 5,981,116.44 542,727.95 9,062.00 91.28 192.91 6,499.52 10.45 2,139.30 -1,383.12 10.00 -91.38 5,981,056.80 542,711.19 6 9,100.00 91.27 196.71 6,498.68 -26.27 2,129.59 -1,348.75 10.00 90.00 5,981,020.03 542,701.68 9,200.00 91.24 206.71 6,496.48 -119.04 2,092.65 -1,253.94 10.00 90.08 5,980,927.08 542,665.25 9,287.00 91.18 215.41 6,494.64 -193.48 2,047.82 -1,168.10 10.00 90.30 5,980,852.41 542,620.82 7 9,300.00 91.18 214.11 6,494.37 -204.15 2,040.41 -1,155.16 10.00 -90.00 5,980,841.69 542,613.47 9,400.00 91.16 204.11 6,492.33 -291.39 1,991.83 -1,057.10 10.00 -90.03 5,980,754.20 542,565.37 9,500.00 91.10 194.11 6,490.35 -385.74 1,959.14 -963.81 10.00 -90.23 5,980,659.68 542,533.19 9,537.00 91.07 190.41 6,489.65 -421.89 1,951.28 -931.08 10.00 -90.43 5,980,623.50 542,525.54 8 9,600.00 94.85 185.36 6,486.40 -484.18 1,942.65 -877.81 10.00 -53.00 5,980,561.17 542,517.24 9,662.00 98.54 180.34 6,479.16 -545.64 1,939.58 -828.75 10.00 -53.26 5,980,499.69 542,514.50 9 9,700.00 96.35 183.47 6,474.24 -583.30 1,938.32 -799.10 10.00 125.00 5,980,462.04 542,513.45 9,762.00 92.73 188.53 6,469.33 -644.73 1,931.86 -747.88 10.00 125.41 5,980,400.57 542,507.32 10 9,800.00 92.27 192.30 6,467.67 -682.06 1,925.00 -714.87 10.00 97.00 5,980,363.21 542,500.66 9,900.00 90.99 202.23 6,464.83 -777.40 1,895.36 -622.80 10.00 97.16 5,980,267.73 542,471.55 9,982.00 89.92 210.36 6,464.17 -850.85 1,859.08 -543.20 10.00 97.45 5,980,194.09 542,435.66 11 10,000.00 89.92 208.56 6,464.20 -866.52 1,850.22 -525.51 10.00 -90.00 5,980,178.37 542,426.90 10,100.00 89.92 198.56 6,464.33 -958.07 1,810.31 -429.72 10.00 -90.00 5,980,086.61 542,387.48 TD at 10100.00 2/12/2013 12:34:03PM Page 3 COMPASS 2003.16 Build 69 ',yr-' ConocoPhillips or its affiliates Ir1,.._ ConocoPhillips Planning Report BAKER Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1G-10 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 10-10A:@ 94.17ft(1G-10A:) Site: Kuparuk 1G Pad North Reference: True Well: 10-10 Survey Calculation Method: Minimum Curvature Wellbore: 1 G-10BL2 Design: 1 G-10BL2_wp05 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (1 (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1G-1OBL2_T3 0.00 0.00 6,455.00 -805.27 1,983.08 5,980,240.33 542,559.41 70°21'24.901 N 149°39'15.686 W -plan misses target center by 92.56ft at 9900.00ft MD(6464.83 TVD,-777.40 N,1895.36 E) -Point 1G-10BL2_Fault2 0.00 0.00 0.00 -365.98 1,936.46 5,980,679.32 542,510.41 70°21'29.222 N 149°39'17.046 W -plan misses target center by 6475.31ft at 9769.58ft MD(6468.98 TVD,-652.21 N,1930.69 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 1G-10BL2_Faultl 0.00 0.00 0.00 566.69 2,565.59 5,981,615.29 543,134.42 70°21'38.393 N 149°38'58.643 W -plan misses target center by 6518.28ft at 8590.67ft MD(6513.75 TVD,378.66 N,2411.54 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 1G-10BL2_T1 0.00 0.00 6,520.00 566.69 2,565.59 5,981,615.29 543,134.42 70°21'38.393 N 149°38'58.643 W -plan misses target center by 124.16ft at 8400.00ft MD(6519.59 TVD,444.82 N,2589.34 E) -Point 1G-10BL2_T2 0.00 0.00 6,481.00 -365.98 1,936.46 5,980,679.32 542,510.41 70°21'29.222 N 149°39'17.046 W -plan misses target center by 28.68ft at 9488.92ft MD(6490.56 TVD,-375.03 N,1961.94 E) -Point 10-10B CTD Polygon_S 0.00 0.00 0.00 919.18 3,217.58 5,981,971.27 543,784.42 70°21'41.857 N 149°38'39.575 W -plan misses target center by 6552.97ft at 8030.00ft MD(6531.58 TVD,458.23 N,2957.98 E) -Polygon Point 1 0.00 919.18 3,217.58 5,981,971.27 543,784.42 Point2 0.00 607.07 1,868.75 5,981,651.89 542,437.44 Point 3 0.00 -981.33 1,485.19 5,980,061.59 542,062.52 Point4 0.00 -1,193.00 2,102.12 5,979,853.29 542,680.53 Point 5 0.00 -47.78 2,240.28 5,980,999.12 542,812.47 Point6 0.00 174.20 2,290.48 5,981,221.35 542,861.46 Point7 0.00 542.94 3,465.59 5,981,596.42 544,034.44 Point 8 0.00 919.31 3,217.58 5,981,971.40 543,784.42 1G-10B CTD Polygon_N 0.00 0.00 0.00 919.14 3,224.58 5,981,971.27 543,791.42 70°21'41.857 N 149°38'39.370 W -plan misses target center by 6553.25ft at 8030.00ft MD(6531.58 TVD,458.23 N,2957.98 E) -Polygon Point 1 0.00 919.14 3,224.58 5,981,971.27 543,791.42 Point 2 0.00 542.69 3,486.59 5,981,596.28 544,055.44 Point 3 0.00 337.28 2,999.43 5,981,388.26 543,569.45 Point4 0.00 1,299.42 2,247.51 5,982,346.21 542,812.40 Point 5 0.00 3,082.22 2,695.13 5,984,131.24 543,250.32 Point 6 0.00 2,891.45 3,208.16 5,983,943.27 543,764.32 Point7 0.00 1,914.61 2,970.89 5,982,965.25 543,532.37 Point 8 0.00 1,095.35 2,816.48 5,982,145.25 543,382.41 Point 9 0.00 919.14 3,224.58 5,981,971.27 543,791.42 111.17 17.00 16" 16 24 2,345.17 2,081.53 10 3/4" 10-3/4 13-1/2 6,296.17 5,351.69 7" 7 8-1/2 7,948.17 6,538.84 7" 7 8-1/2 10,100.00 6,464.33 2 3/8" 2-3/8 3 2/12/2013 12:34:03PM Page 4 COMPASS 2003.16 Build 69 rt I ConocoPhillips or its affiliates Ira' Conoco Phillips Planning Report BAKER HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1G-10 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site: Kuparuk 1G Pad North Reference: True Well: 1G-10 Survey Calculation Method: Minimum Curvature Wellbore: 1G-10BL2 Design: 1 G-10BL2_wp05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (ft) (ft) (ft) (ft) Comment 7,895.17 6,549.35 448.87 3,090.99 TIP/KOP 8,030.00 6,531.58 458.23 2,957.98 Start 10 DLS 8,162.00 6,526.13 457.70 2,826.39 3 8,262.00 6,522.34 454.37 2,726.64 4 8,562.00 6,514.74 392.34 2,436.72 5 9,062.00 6,499.52 10.45 2,139.30 6 9,287.00 6,494.64 -193.48 2,047.82 7 9,537.00 6,489.65 -421.89 1,951.28 8 9,662.00 6,479.16 -545.64 1,939.58 9 9,762.00 6,469.33 -644.73 1,931.86 10 9,982.00 6,464.17 -850.85 1,859.08 11 10,100.00 6,464.33 -958.07 1,810.31 TD at 10100.00 2/12/2013 12:34:03PM Page 5 COMPASS 2003.16 Build 69 Conoco Phillips Conoco Phillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1G Pad 1G-10 1G-1 OBL2 1G-10BL2_wp05 Travelling Cylinder Report 12 February, 2013 0 R ,A L. ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit TVD Reference: 1G-10A:@ 94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site Error: 0.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Welibore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset TVD Reference: Offset Datum Reference 1G-10BL2_wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,895.17 to 10,100.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,200.58ft Error Surface: Elliptical Conic Survey Tool Program Date 2/12/2013 From To (ft) (ft) Survey(Welibore) Tool Name Description 95.17 6,295.17 Boss Gyro(1G-10) BOSS-GYRO Sperry-Sun BOSS gyro multishot 6,390.00 7,422.00 MWD(1G-10A) MWD MWD-Standard 7,422.00 7,895.17 1G-10B_wp11(1G-10B) MWD MWD-Standard 7,895.17 10,100.00 1G-10BL2_wp05(1G-10BL2) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 111.17 111.17 16" 16 24 7,948.17 6,633.01 7" 7 8-1/2 6,296.17 5,445.86 7" 7 8-1/2 2,345.17 2,175.70 103/4" 10-3/4 13-1/2 10,100.00 6,558.50 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 1G Pad 1G-09-1 G-09-1 G-09 Out of range 1G-10-1G-10-1G-10 7,896.74 7,300.00 598.18 117.00 497.16 Pass-Major Risk 1G-10-1G-10A-1 G-10A 7,900.00 7,275.00 419.59 92.20 360.27 Pass-Major Risk 1G-10-1G-10B-1G-10B_wp11 7,900.00 7,900.00 0.08 0.95 -0.52 FAIL-Major Risk 1G-10-1G-10BL1-1G-10BL1_wp04 7,900.00 7,900.00 0.08 0.88 -0.52 FAIL-Major Risk 1G-11-1G-11-1G-11 Out of range 1 G-12-1 G-12-1 G-12 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/12/2013 11:32:29AM Page 2 of 9 COMPASS 2003.16 Build 69 - ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit TVD Reference: 1G-10A:@ 94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site Error: 0.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Weilbore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-10-1G-10-1G-10 Offset Site Error: 0.00 ft Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth *W-S +EI-W Hole Size Centre Distance Deviation ON Iff) NO Ift) (ft) NN (°) ON (ft) (ff) (ft) Ift) ON 7,896.74 6,64114 7,300.00 6,352.33 34.64 4.88 -28.83 961.38 3,177.78 0.65 598.18 117.00 497.16 Pass-Major Risk,CC,ES,SF 7,910.70 6,639.97 7,275.00 6,330.72 34.65 4.73 -29.85 959.09 3,165.42 0.85 605.36 116.59 505.77 Pass-Major Risk 7,923.86 6,637.27 7,250.00 6,309.04 34.65 4.59 -30.93 958.79 3,153.18 0.65 613.14 116.18 515.03 Pass-Major Risk 7,936.28 6,634.97 7,225.00 6,287.30 34.64 4.45 -32.04 954.47 3,141.07 0.65 621.54 115.77 524.93 Pass-Major Risk 7,950.00 8,632.73 7,200.00 6,265.49 34.64 4.31 -33.11 952.13 3,129.06 0.65 630.57 115.35 535.44 Pass-Major Risk 7,959.03 6,631.41 7,175.00 6,243.64 34.64 4.18 -34.35 949.79 3,117.15 0.85 640.20 114.97 546.62 Pass-Major Risk 7,969.50 6,630.06 7,150.00 6,221.75 34.64 4.04 -35.52 947.45 3,105.30 0.65 650.45 114.59 558.39 Pass-Major Risk 7,979.40 6,628.94 7,125.00 6,199.83 34.63 3.90 -36.70 945.10 3,093.51 0.65 66129 114.21 570.75 Pass-Major Risk 7,988.78 6,628.03 7,100.00 6,177.87 34.63 3.77 -37.87 942.76 3,081.79 0.65 672.72 113.83 583.70 Pass-Major Risk 8,000.00 6,627.13 7,075.00 6,155.86 34.63 3.63 -38.94 940.44 3,070.17 0.65 684.77 113.45 597.19 Pass-Major Risk 8,005.99 6,626.74 7,050.00 6,133.77 34.64 3.50 -40.17 938.14 3,058.70 0.65 697.42 11310 611.38 Pass-Major Risk 8,013.84 6,626.31 7,025.00 6,111.59 34.64 3.37 -41.31 935.86 3,047.39 0.65 710.68 112.74 626.11 Pass-Major Risk 8,021.24 6,628.00 7,000.00 6,089.33 34.64 3.24 -42.42 933.62 3,036.23 0.85 724.53 112.46 641.41 Pass-Major Risk 8,030.00 6,625.75 6,975.00 6,067.00 34.64 3.12 -43.45 931.38 3,025.21 0.65 738.93 112.20 657.18 Pass-Major Risk 8,034.96 6,625.64 6,950.00 6,044.61 34.64 2.99 -45.23 929.16 3,014.32 0.65 753.84 112.22 673.52 Pass-Major Risk 8,041.73 6,625.47 6,925.00 6,022.18 34.65 2.87 -47.14 926.94 3,003.55 0.85 769.23 112.35 690.27 Pass-Major Risk 8,050.00 6,825.26 6,875.00 5,977.06 34.65 2.62 -50.27 922.52 2,982.40 0.65 801.41 112.27 725.16 Pass-Major Risk 8,050.00 6,625.26 6,900.00 5,999.64 34.65 2.74 -49.15 924.72 2,992.90 0.65 785.09 112.56 707.41 Pass-Major Risk 8,062.16 6,624.90 6,850.00 5,954.41 34.66 2.50 -52.57 920.35 2,972.06 0.65 818.12 112.73 742.97 Pass-Major Risk 8,068.97 6,624.68 6,825.00 5,931.68 34.66 2.39 -54.28 918.20 2,961.87 0.65 835.25 112.84 761.30 Pass-Major Risk 8,075.78 6,624.44 6,800.00 5,908.88 34.66 2.27 -55.94 916.07 2,951.85 0.65 852.77 112.94 779.97 Pass-Major Risk 8,082,62 6,624.20 6,775.00 5,886.03 34.67 2.15 -57.56 913.94 2,941.93 0.65 870.62 113.07 798.91 Pass-Major Risk 8,089.52 6,623.93 6,750.00 5,863.18 34.67 2.04 -59.15 911.77 2,932.07 0.65 888.72 113.19 818.08 Pass-Major Risk 8,100.00 6,623.50 6,700.00 5,817.36 34.68 1.81 -61.86 907.31 2,912.51 0.85 925.67 113.21 857.08 Pass-Major Risk 8,100.00 6,623.50 6,725.00 5,840.27 34.68 1.92 -61.06 909.56 2,922.26 0.65 907.09 113.50 837.41 Pass-Major Risk 8,110.57 6,623.03 6,675.00 5,794.42 34.69 1.70 -63.72 905.02 2,902.82 0.65 944.46 113.52 876.75 Pass-Major Risk 8,117.69 6,622.70 6,650.00 5,771.47 34.70 1.59 -65.18 902.68 2,893.20 0.85 963.46 113.61 896.65 Pass-Major Risk 8,124.87 6,622.35 6,625.00 5,748.49 34.70 1.47 -66.63 900.30 2,883.65 0.65 982.65 113.70 916.70 Pass-Major Risk 8,132.10 6,621.98 6,600.00 5,725.49 34.71 1.36 -68.04 897.86 2,874.17 0.65 1,002.02 113.78 936.90 Pass-Major Risk 8,139.40 6,621.80 6,575.00 5,702.48 34.72 1.25 -69.44 895.38 2,864.71 0.65 1,021.55 113.86 957.22 Pass-Major Risk 8,150.00 6,621.01 6,550.00 5,679.48 34.73 1.14 -71.15 892.88 2,855.24 0.65 1,041.22 114.07 977.62 Pass-Major Risk 8,154.33 6,620.76 6,525.00 5,656.48 34.74 1.03 -72.18 890.35 2,845.76 0.65 1,061.01 113.98 998.16 Pass-Major Risk 8,162.00 6,620.30 6,500.00 5,633.49 34.74 0.92 -73.54 887.80 2,836.27 0.65 1,080.93 114.04 1,01877 Pass-Major Risk 8,176,85 6,619.45 6,475.00 5,610.52 34.77 0.81 -72.55 885.23 2,826.76 0.65 1,100.93 113.63 1,039.33 Pass-Major Risk 8,191.32 6,618.72 6,450.00 5,587.55 34.79 0.69 -71.61 882.64 2,817.24 0.65 1,120.98 113.18 1,059.94 Pass-Major Risk 8,205.30 6,618.10 6,425.00 5,564.58 34.81 0.58 -70.73 880.05 2,807.70 0.65 1,141.07 112.70 1,080.59 Pass-Major Risk 8,218.81 6,617.59 6,400.00 5,541.63 34.83 0.47 -69.89 877.43 2,798.14 0.85 1,161.21 112.19 1,101.28 Pass-Major Risk 8,231.82 6,617.17 6,375.00 5,518.68 34.86 0.36 -69.11 874.80 2,788.58 0.65 1,181.41 111.68 1,122.03 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/12/2013 11:32:29AM Page 3 of 9 COMPASS 2003.16 Build 69 `- Conoco Phillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit TVD Reference: 1G-10A:©94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site Error: 0.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Welibore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-10-1G-10A-1G-10A Offset Site Error: 0.00 ft Survey Program: 95-BOSS-GYRO,6390-MWD Rule Assigned:Major Risk Offset Well Error. 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +WS •E/-W Hole Size Centre Distance Deviation IS) (ft) Off) OH ON (ft) 11 IS) NH )ftl UN ON UN 7,900.00 6,642.38 7,275.00 6,315.09 34.66 0.00 -51.36 697.53 3,171.07 0.50 419.59 92.20 360.27 Pass-Major Risk,CC,ES,SF 7,912.25 6,63564 7,250.00 6,293.09 34.65 050 -51.83 702.69 3,160.36 0.50 437.74 92.23 379.20 Pass-Major Risk 7,922.74 6,637.49 7,225.00 6,27157 3455 050 -52.34 707.83 3,149.71 0.50 456.20 92.25 398.42 Pass-Major Risk 7,932.77 6,635.60 7,200.00 6,249.03 3454 050 -52.82 71357 3,139.13 0.50 47551 92.27 417.95 Pass-Major Risk 7,950.00 6,632.73 7,150.00 6,204.91 3454 0.00 -53.76 723.93 3,118.27 0.50 513.69 92.30 457.95 Pass-Major Risk 7,950.00 6,632.73 7,175.00 6,226.97 34.64 0.00 -5257 718.43 3,128.65 0.50 494.27 92.27 437.73 Pass-Major Risk 7,960.27 6,631.24 7,125.00 6,182.82 34.64 050 -54.10 729.48 3,107.96 0.50 533.47 92.33 478.28 Pass-Major Risk 7,968.70 6,630.16 7,100.00 6,16058 34.64 050 -54.50 73450 3,09764 0.50 553.39 92.35 498.77 Pass-Major Risk 7,976.82 6,629.22 7,075.00 6,138.49 34.63 0.00 -54.92 739.85 3,087.29 0.50 573.42 92.37 519.37 Pass-Major Risk 7,984.63 6,628.42 7,050.00 6,116.26 34.63 0.00 -55.33 744.63 3,076.91 0.50 593.56 92.40 540.07 Pass-Major Risk 8,000.00 6,627.13 6,975.00 6,049.52 3453 0.00 -56.73 758.51 3,04553 050 65456 92.47 603.17 Pass-Major Risk 8,000.00 6,627.13 7,00050 6,071.75 3453 0.00 -56.12 75357 3,056.08 050 63428 92.44 581.85 Pass-Major Risk 8,000.00 6,627.13 7,02550 6,094.00 3453 0.00 -55.46 74924 3,066.51 050 61351 92.40 56079 Pass-Major Risk 8,013.14 6,626.34 6,950.00 6,027.30 3454 0.00 -56.86 763.17 3,035.15 050 67570 92.49 624.22 Pass-Major Risk 8,01957 8,826.06 6,925.00 6,005.12 3454 0.00 -57.19 76758 3,024.64 050 696.64 92.51 64550 Pass-Major Risk 8,030.00 6,625.75 6,90050 5,982.96 34.64 0.00 -57.36 77254 3,014.08 050 717.76 92.53 66751 Pass-Major Risk 8,032.97 6,625.68 6,875.00 5,960.84 34.64 0.00 -58.16 777.46 3,003.48 0.50 738.97 92.75 688.70 Pass-Major Risk 8,041.53 6,625.48 6,850.00 5,938.75 34.65 0.00 -59.49 782.34 2,992.84 0.50 760.30 93.32 710.39 Pass-Major Risk 8,05050 6,62526 6,825.00 5,916.67 34.65 0.00 -60.76 78726 2,982.19 0.50 781.72 93.88 732.13 Pass-Major Risk 8,05858 6,625.00 6,800.00 5,894.61 34.65 0.00 -62.02 79223 2,971.53 050 80324 94.43 75353 Pass-Major Risk 8,067.25 6,624.73 6,77550 5,872.56 3456 0.00 -63.23 79725 2,960.87 050 82454 94.97 775.78 Pass-Major Risk 8,075.81 6,624.44 6,750.00 5,850.52 34.66 0.00 -64.42 802.30 2,950.20 0.50 846.51 95.50 797.67 Pass-Major Risk 8,084.40 6,624.13 6,725.00 5,828.52 34.67 0.00 -65.58 807.33 2,939.46 0.50 868.20 96.01 819.56 Pass-Major Risk 8,093.03 6,623.79 6,700.00 5,806.54 3458 0.00 -66.73 812.32 2,92853 0.50 889.91 96.50 841.45 Pass-Major Risk 8,100.00 6,623.50 6,675.00 5,784.60 34.68 0.00 -67.69 817.27 2,917.72 0.50 911.63 96.90 863.34 Pass-Major Risk 8,110.35 6,623.04 6,650.00 5,762.69 3459 0.00 -68.97 82224 2,906.76 050 933.38 97.47 88521 Pass-Major Risk 8,118.95 6,822.64 6,62550 5,74038 34.70 0.00 -70.05 827.30 2,895.83 0.50 955.22 97.93 907.15 Pass-Major Risk 8,127.49 6,622.22 6,600.00 5,718.88 34.71 0.00 -71.10 832.47 2,884.94 0.50 977.14 98.38 929.16 Pass-Major Risk 8,135.94 6,621.78 6,575.00 5,696.99 34.72 0.00 -72.13 837.75 2,874.07 0.50 999.13 98.80 95122 Pass-Major Risk 8,15050 6,621.01 6,550.00 5,675.10 34.73 0.00 -73.72 843.05 2,863.23 0.50 1,021.21 99.45 97329 Pass-Major Risk 8,152.65 6,620.85 6,525.00 5,653.18 34.73 0.00 -74.11 848.32 2,852.42 0.50 1,043.29 99.60 995.46 Pass-Major Risk 8,162.00 6,620.30 6,500.00 5,631.25 34.74 0.00 -75.19 853.56 2,841.62 0.50 1,065.43 10052 1,017.63 Pass-Major Risk 8,174.53 6,619.57 6,475.00 5,609.28 34.76 0.00 -74.02 858.70 2,830.87 050 1,08750 10050 1,039.76 Pass-Major Risk 8,188.83 6,618.83 6,45050 5,587.02 34.78 0.00 -72.73 863.04 2,820.34 0.50 1,109.70 99.92 1,061.87 Pass-Major Risk 8,202.78 6,61820 6,425.00 5,564.46 34.80 0.00 -71.54 866.36 2,810.11 0.50 1,131.71 99.81 1,083.96 Pass-Major Risk 8,21626 6,617.68 6,400.00 5,541.62 3453 0.00 -70.47 888.67 2,80020 050 1,153.59 9957 1,106.00 Pass-Major Risk 8,229.19 6,617.25 6,375.00 5,518.59 34.85 0.00 -69.51 869.93 2,790.57 0.50 1,175.31 99.47 1,127.93 Pass-Major Risk 8,241.79 6,61651 6,350.00 5,495.50 34.87 0.00 -6855 870.12 2,780.98 050 1,196.71 9921 1,14951 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/12/2013 11:32:29AM Page 4 of 9 COMPASS 2003.16 Build 69 e--- ConocoPhillips or its affiliates ConoCOPhlIllps Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit TVD Reference: 1G-10A:@ 94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site Error: O.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-10-1G-10B-1G-10B_wp11 Onset site Error: 0.009 Survey Program: 95-BOSS-GYRO,6390-MOOD,7422-MOOD Rule Assigned:Major Risk Offset Well Error. 0.00 6 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- CeMre to No Go Allowable Warning Depth Depth Depth Depth Azimuth clg S +E/-W Hole Size Centre Distance Deviation (n) (tt) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (H) (ft) (ft) 7,900.00 6,642.38 7,900.00 6,642.36 027 0.01 -9.50 449.10 3,08621 0.45 028 0.95 -0.52 FAIL-Major Risk,CC,ES,SF 7,900.00 6,642.38 7,275.00 6,315.09 0.27 0.00 -51.36 697.53 3,171.07 0.45 419.59 2.02 418.79 Pass-Major Risk 7,912.25 6,63924 7,250.00 6,29329 0.27 0.00 -51.83 70229 3,160.36 0.45 437.74 224 436.82 Pass-Major Risk 7,922.74 6,637.49 7,225.00 6,271.07 0.27 0.00 -52.34 707.83 3,149.71 0.45 456.20 2.45 455.18 Pass-Major Risk 7,924.80 6,637.09 7,925.00 6,636.51 0.27 0.07 -8.31 452.97 3,062.35 0.45 3.04 1.23 2.10 Pass-Major Risk 7,932.77 6,635.60 7,200.00 6,249.03 027 0.00 -52.82 713.07 3,139.13 0.45 47521 2.65 47329 Pass-Major Risk 7,948.76 6,632.92 7,95200 6,631.07 0.27 0.13 -6.99 461.27 3,039.44 0.22 10.19 1.25 9.14 Pass-Major Risk 7,950.00 6,632.73 7,150.00 6,204.91 0.27 0.00 -53.76 723.93 3,118.27 0.45 513.69 3.02 512.40 Pass-Major Risk 7,950.00 6,632.73 7,175.00 6,22627 0.27 0.00 -52.97 718.43 3,128.65 0.45 49427 297 492.98 Pass-Major Risk 7,960.27 6,63124 7,125.00 6,18222 0.28 0.00 -54.10 729.48 3,107.96 0.45 533.47 223 532.09 Pass-Major Risk 7,968.70 6,630.16 7,100.00 6,160.68 0.28 0.00 -54.50 734.80 3,097.64 0.45 553.39 3.42 551.93 Pass-Major Risk 7,971.24 6,629.85 7,975.00 6,626.35 0.28 0.17 -5.23 473.71 3,018.32 0.22 21.28 1.51 19.90 Pass-Major Risk 7,976.82 6,629.22 7,075.00 6,138.49 0.28 0.00 -54.92 739.85 3,087.29 0.45 57242 3.59 571.89 Pass-Major Risk 7,984.63 6,628.42 7,050.00 6,116.26 0.29 0.00 -55.33 744.63 3,076.91 0.45 593.56 3.76 591.97 Pass-Major Risk 7,991.71 6,627.78 8,000.00 6,623.04 029 0.21 -2.62 489.80 2,999.52 022 35.82 1.76 34.16 Pass-Major Risk 8,000.00 6,627.13 6,975.00 6,049.52 0.30 020 -56.73 75821 3,04523 0.45 65426 4.15 653.26 Pass-Major Risk 8,00020 6,627.13 7,000.00 6,071.75 020 020 -56.12 753.87 3,056.08 0.45 634.28 4.10 63227 Pass-Major Risk 8,000.00 6,627.13 7,02520 6,094.00 020 020 -55.46 749.24 3,066.51 0.45 61321 4.05 61220 Pass-Major Risk 8,009.66 6,626.53 8,025.00 6,62122 021 023 0.00 50921 2,98327 0.22 53.43 2.00 51.51 Pass-Major Risk 8,013.14 6,626.34 6,95020 6,027.30 0.31 0.00 -56.86 763.17 3,035.15 0.45 675.70 4.41 673.90 Pass-Major Risk 8,01927 6,626.06 6,92520 6,005.12 0.32 0.00 -57.19 767.88 3,02424 0.45 696.64 4.56 694.82 Pass-Major Risk 8,025.48 6,625.86 8,050.00 6,620.80 0.32 025 2.16 530.19 2,970.40 0.22 73.06 224 70.92 Pass-Major Risk 8,030.00 6,625.75 6,900.00 5,982.96 0.33 020 -57.36 77224 3,014.08 0.45 717.76 478 715.91 Pass-Major Risk 8,03227 6,625.68 6,875.00 5,960.84 0.33 020 -58.16 777.46 3,003.48 0.45 738.97 4.88 737.11 Pass-Major Risk 8,03825 6,625.54 8,075.00 6,62020 024 025 2.37 551.94 2,958.08 0.22 93.37 2.40 91.11 Pass-Major Risk 8,041.53 6,625.48 6,850.00 5,938.75 024 0.00 -59.49 78224 2,992.84 0.45 760.30 5.05 758.30 Pass-Major Risk 8,050.00 6,625.26 6,825.00 5,916.67 025 0.00 -60.76 787.26 2,982.19 0.45 78172 221 77921 Pass-Major Risk 8,050.00 6,625.26 8,10200 6,620.67 0.35 0.26 221 574.19 2,946.69 0.22 114.54 2.51 112.21 Pass-Major Risk 8,058.68 6,625.00 6,80200 5,894.61 0.36 0.00 -62.02 792.23 2,971.53 0.45 80324 5.38 801.01 Pass-Major Risk 8,060.12 6,62426 8,125.00 6,620.87 0.36 026 1.59 598.77 2,935.97 0.22 13623 262 133.95 Pass-Major Risk 8,067.25 6,624.73 6,77200 5,872.56 0.37 0.00 -6323 797.25 2,960.87 0.45 824.84 5.53 82220 Pass-Major Risk 8,069.26 6,624.67 8,150.00 6,621.03 0.38 0.25 1.09 61924 2,925.64 022 158.53 2.74 156.12 Pass-Major Risk 8,075.81 6,624.44 6,750.00 5,850.52 028 0.00 -64.42 80220 2,950.20 0.45 846.51 5.68 844.07 Pass-Major Risk 8,077.56 6,624.38 8,175.00 6,621.16 0.39 0.25 0.57 642.48 2,915.71 0.22 181.09 2.86 178.69 Pass-Major Risk 8,084.40 6,624.13 6,725.00 5,828.52 0.40 200 -65.58 807.33 2,939.46 0.45 86820 5.81 86526 Pass-Major Risk 8,08529 6,624.10 8,200.00 6,621.24 0.40 225 0.04 66529 2,906.17 0.22 203.99 298 20120 Pass-Major Risk 8,091.90 6,623.84 8,22200 6,621.29 0.41 0.23 -0.47 688.86 2,897.05 0.22 227.17 3.10 224.90 Pass-Major Risk 8,09323 6,623.79 6,700.00 5,806.54 0.41 020 -6673 81222 2,92823 0.45 889.91 292 887.28 Pass-Major Risk 8,100.00 6,623.50 6,87200 5,78420 0.42 0.00 -6729 817.27 2,917.72 0.45 911.63 206 908.90 Pass-Major Risk 8,100.00 6,623.50 8,250.00 6,621.30 0.42 022 -1.15 71229 2,888.32 0.22 250.63 227 248.11 Pass-Major Risk 8,10020 6,623.50 8,275.00 6,621.27 0.42 0.21 -1.04 735.87 2,880.01 0.22 274.32 232 271.80 Pass-Major Risk 8,108.52 6,623.13 8,300.00 6,621.20 0.43 0.19 -1.83 759.59 2,872.11 0.22 298.17 3.50 295.45 Pass-Major Risk 8,110.35 6,623.04 6,650.00 5,762.69 0.43 0.00 -6297 82224 2,906.76 0.45 933.38 6.36 93023 Pass-Major Risk 8,11322 6,62221 8,325.00 6,621.09 0.43 0.17 -225 783.31 2,86421 0.22 322.11 3.63 31929 Pass-Major Risk 8,117.93 6,622.69 8,350.00 6,620.95 0.44 0.15 -228 806.88 2,855.89 0.22 345.98 3.77 34327 Pass-Major Risk 8,11825 6,622.64 6,825.00 5,740.78 0.44 0.00 -7025 82720 2,895.83 0.45 95522 629 95228 Pass-Major Risk 8,122.66 6,622.46 8,375.00 6,620.76 0.45 0.13 -3.12 83021 2,847.17 0.22 36938 3.91 366.78 Pass-Major Risk 8,127.40 6,622.22 8,400.00 6,620.54 0.46 0.11 -3.57 85329 2,838.04 022 393.51 4.05 390.42 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/12/2013 11:32:29AM Page 5 of 9 COMPASS 2003.16 Build 69 • `-- ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project Kuparuk River Unit TVD Reference: 1G-10A:@ 94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site Error: O.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Welibore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset ND Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-10-1G-10B-1G-10B_wp11 Offset Site Error: 010 ft Survey Program: 95-BOSS-GYRO,6390-MWD,7422-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 0 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface• Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +WS +E/-W Hole Size Centre Distance Deviation HD (ff) lffl (80 (ff) ON (°I (ff) (ft) (f) (ft) (ft) (ft) 8,127.49 6,622.22 6,600.00 5,718.88 0.46 0.00 -71.10 832.47 2,88414 0.45 977.14 6.83 974.08 Pass-Major Risk 8,13217 6,62118 8,42510 6,620.09 0.46 0.09 -4.05 87676 2,82818 0.22 41722 4.19 41415 Pass-Major Risk 8,135.94 6,621.78 6,575.00 5,696.99 0.47 0.00 -72.13 837.75 2,874.07 145 999.13 7.06 995.97 Pass-Major Risk 8,136.57 6,821.75 8,450.00 6,619.21 0.47 0.08 -4.56 899.89 2,819.25 0.22 440.96 4.33 437.70 Pass-Major Risk 8,15010 6,621.01 6,550.00 5,675.10 0.49 0.00 -7172 84315 2,86323 0.45 1,021.21 7.40 1,017.88 Pass-Major Risk 8,150.00 6,621.01 8,47510 6,617.89 0.49 0.08 -616 92218 2,809.75 0.22 484.89 4.64 461.38 Pass-Major Risk 8,150.00 6,62111 8,500.00 6,616.15 0.49 0.09 -6.19 94612 2,80020 022 488.55 4.70 48512 Pass-Major Risk 8,150.00 6,821.01 8,525.00 6,613.98 0.49 0.11 -6.35 96910 2,790.59 0.22 512.29 4.77 50875 Pass-Major Risk 8,152.65 6,620.85 6,525.00 5,653.18 0.49 0.00 -74.11 848.32 2,852.42 0.45 1,043.29 7.50 1,039.93 Pass-Major Risk 8,153.14 6,620.82 8,550.00 6,611.38 0.49 0.14 -6.88 991.91 2,780.93 0.22 536.07 4.89 532.47 Pass-Major Risk 8,156.96 6,620.60 8,575.00 6,608.36 0.50 0.19 -7.50 1,014.74 2,771.21 0.22 559.85 5.03 556.19 Pass-Major Risk 8,162.00 6,620.30 6,500.00 5,631.25 0.51 0.00 -75.19 853.56 2,841.62 145 1,065.43 7.73 1,061.96 Pass-Major Risk 8,162.00 6,620.30 8,600.00 6,604.91 0.51 0.25 -8.27 1,037.50 2,761.45 0.22 583.62 5.19 579.90 Pass-Major Risk 8,174.53 6,619.57 6,475.00 5,60928 0.53 0.00 -74.02 858.70 2,830.87 0.45 1,087.80 7.94 1,084.00 Pass-Major Risk 8,188.83 6,618.83 6,450.00 5,587.02 0.55 0.00 -72.73 863.04 2,820.34 0.45 1,109.70 8.14 1,105.95 Pass-Major Risk 8,202.78 6,618.20 6,425.00 5,564.46 018 0.00 -71.54 866.36 2,810.11 0.45 1,131.71 8.32 1,127.81 Pass-Major Risk 8,216.26 6,617.68 6,400.00 5,541.62 0.60 0.00 -70.47 868.67 2,80120 015 1,153.59 8.48 1,149.55 Pass-Major Risk 8,22919 6,617.25 6,375.00 5,518.59 0.62 0.00 -69.51 869.93 2,790.57 0.45 1,175.31 8.88 1,171.13 Pass-Major Risk 8,241.79 6,616.91 6,350.00 5,495.50 014 0.00 -68.65 870.12 2,780.98 0.45 1,196.71 9.83 1,192.40 Pass-Major Risk 8,262.00 6,61611 8,625.00 6,601.41 0.68 0.35 1.49 1,060.28 2,751.78 0.22 606.62 6.39 601.83 Pass-Major Risk 8,262.00 6,616.51 8,650.00 6,598.25 0.68 0.45 1.27 1,083.22 2,742.35 0.22 629.31 148 624.46 Pass-Major Risk 8,274.61 6,616.32 8,675.00 6,595.41 0.70 0.56 -0.18 1,106.30 2,733.17 0.22 65214 6.70 647.27 Pass-Major Risk 8,279.05 6,616.25 8,700.00 6,592.91 0.70 0.66 -0.77 1,129.51 2,72423 0.22 675.09 6.83 670.42 Pass-Major Risk 8,283.21 6,616.18 8,725.00 6,590.75 0.71 0.79 -129 1,152.85 2,715.55 022 698.33 6.99 693.39 Pass-Major Risk 8,287.10 6,616.12 8,750.00 6,588.92 0.72 0.92 -1.75 1,176.32 2,707.11 022 721.75 7.15 716.65 Pass-Major Risk 8,300.00 6,615.90 8,775.00 6,587.42 0.74 1.06 -3.10 1,199.89 2,69813 0.22 745.46 7.46 740.08 Pass-Major Risk 8,300.00 6,615.90 8,800.00 6,586.26 0.74 1.19 -3.11 1,223.58 2,691.01 0.22 769.10 7.54 763.69 Pass-Major Risk 8,300.00 6,615.90 8,825.00 6,585.28 0.74 1.36 -3.11 1,24738 2,68145 0.22 792.95 7.65 787.51 Pass-Major Risk 8,300.00 6,61190 8,850.00 6,584.41 0.74 1.53 -319 1,271.32 2,67128 0.22 816.97 7.75 811.52 Pass-Major Risk 8,30010 6,615.90 8,875.00 6,583.66 0.74 1.69 -3.07 1,295.38 2,669.52 022 841.16 7.85 835.69 Pass-Major Risk 8,300.00 6,615.90 8,900.00 6,583.02 0.74 1.86 -3.05 1,319.55 2,663.17 0.22 885.50 7.95 860.01 Pass-Major Risk 8,30100 6,615.90 8,925.00 6,582.50 0.74 2.05 -3.01 1,34182 2,657.22 0.22 889.96 8.06 884.46 Pass-Major Risk 8,300.00 6,615.90 8,950.00 6,582.09 0.74 224 -298 1,36820 2,651.68 0.22 914.52 8.17 909.02 Pass-Major Risk 8,300.00 6,615.90 8,975.00 6,581.79 0.74 2.43 -2.94 1,392.66 2,646.56 0.22 939.18 828 933.67 Pass-Major Risk 8,300.00 6,61190 9,000.00 6,581.61 0.74 2.63 -2.89 1,417.21 2,641.84 0.22 963.92 8.40 951140 Pass-Major Risk 8,30010 6,61190 9,025.00 6,581.54 0.74 2.84 -184 1,441.84 2,637.54 0.22 988.72 8.52 98320 Pass-Major Risk 8,300.00 6,615.90 9,050.00 6,581.59 0.74 3.04 -2.79 1,46614 2,633.66 022 1,013.57 8.63 1,008.06 Pass-Major Risk 8,300.00 6,615.90 9,075.00 6,581.75 0.74 3.26 -2.73 1,49110 2,630.19 0.22 1,038.46 8.75 1,032.96 Pass-Major Risk 8,300.00 6,615.90 9,100.00 6,582.02 0.74 3.47 -2.67 1,516.11 2,627.14 0.22 1,063.38 8.87 1,057.90 Pass-Major Risk 8,316.58 6,615.59 9,125.00 6,582.41 0.77 3.69 -4.29 1,54016 2,624.51 0.22 1,087.96 9.29 1,081.86 Pass-Major Risk 8,316.96 6,615.58 9,150.00 6,582.91 0.77 3.92 -426 1,565.86 2,622.30 0.22 1,112.90 9.43 1,106.71 Pass-Major Risk 8,317.18 6,615.58 9,175.00 6,583.53 0.77 4.14 -4.21 1,590.79 2,620.50 0.22 1,137.86 9.56 1,131.58 Pass-Major Risk 8,317.19 6,615.58 9,225.00 6,585.10 0.77 4.60 -4.07 1,640.71 2,618.18 022 1,187.77 9.83 1,181.37 Pass-Major Risk 8,317.25 6,615.58 9,200.00 6,584.26 0.77 4.37 -4.15 1,615.74 2,619.13 0.22 1,162.82 9.69 1,156.47 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/12/2013 11:32:29AM Page 6 of 9 COMPASS 2003.16 Build 69 - ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project Kuparuk River Unit TVD Reference: 1G-10A:@ 94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site Error: 0.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-10-1G-10BL1-1G-10BL1_wp04 Offset Site Error: 0.0011 Survey Program: 95-BOSS-GYRO,6390-M1ND,7422-MWD,8930-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 8 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +EI-W Hole Size Centre Distance Deviation (n) (ff) (ft) IS) (C) ON 11 (ft) (e) tftl Iff) Ift) (ff) 7,900.00 6,642.38 7,900.00 6,642.36 027 0.01 -9.50 449.10 3,086.31 0.45 0.08 0.88 -0.52 FAIL-Major Risk,CC,ES,SF 7,900.00 6,642.38 7,275.00 6,315.09 0.27 0.00 -51.36 697.53 3,171.07 0.45 419.59 1.97 418.79 Pass-Major Risk 7,912.25 6,639.64 7,250.00 6,293.09 0.27 0.00 -51.83 702.69 3,160.36 0.45 437.74 2.20 436.62 Pass-Major Risk 7,922.74 6,637.49 7,225.00 6,271.07 0.27 0.00 -52.34 707.83 3,149.71 0.45 456.20 2.41 455.18 Pass-Major Risk 7,924.80 6,637.09 7,925.00 6,636.51 0.27 0.07 -8.31 452.97 3,062.35 0.45 3.04 1.15 2.10 Pass-Major Risk 7,93277 6,635.60 7,200.00 6,249.03 027 0.00 -52.82 713.07 3,139.13 0.45 475.01 2.61 473.89 Pass-Major Risk 7,94836 6,632.92 7,950.00 6,631.07 0.27 0.13 -6.99 461.27 3,039.44 0.22 10.19 1.20 9.13 Pass-Major Risk 7,950.00 6,632.73 7,150.00 6,204.91 027 0.00 -53.76 723.93 3,118.27 0.45 513.69 2.99 512.40 Pass-Major Risk 7,950.00 6,632.73 7,175.00 6,226.97 027 0.00 -52.97 718.43 3,128.65 045 49427 2.94 492.98 Pass-Major Risk 7,960.27 6,631.24 7,125.00 6,182.82 028 0.00 -54.10 729.48 3,107.96 0.45 533.47 3.20 532.09 Pass-Major Risk 7,968.70 6,630.16 7,100.00 6,160.68 0.28 0.00 -54.50 734.80 3,097.64 0.45 553.39 3.38 551.93 Pass-Major Risk 7,971.24 6,629.85 7,975.00 6,626.35 0.28 0.17 -5.23 473.71 3,018.32 0.22 21.28 1.45 19.90 Pass-Major Risk 7,976.82 6,629.22 7,075.00 6,138.49 028 0.00 -54.92 739.85 3,087.29 0.45 573.42 3.55 571.89 Pass-Major Risk 7,984.63 6,628.42 7,050.00 6,11626 0.29 0.00 -55.33 744.63 3,076.91 0.45 593.56 3.72 591.97 Pass-Major Risk 7,991.71 6,627.78 8,000.00 6,623.04 0.29 021 -2.62 489.80 2,999.52 0.22 35.82 1.72 34.16 Pass-Major Risk 8,000.00 6,627.13 6,975.00 6,049.52 0.30 0.00 -56.73 758,51 3,045.63 0,45 654,96 4.11 653.26 Pass-Major Risk 8,000.00 6,627.13 7,000.00 6,071.75 0.30 0.00 -56.12 753.87 3,056.08 0.45 634.28 4.06 632.57 Pass-Major Risk 8,000.00 6,627.13 7,025.00 6,094.00 0.30 0.00 -55.46 74924 3,066.51 0.45 613191 4.02 612.20 Pass-Major Risk 8,009.66 6,626.53 8,025.00 6,621.32 0.31 0.23 0.00 509.01 2,983.67 022 53.43 1.98 51.51 Pass-Major Risk 8,013.14 6,626.34 6,950.00 6,027.30 0.31 0.00 -56.86 763.17 3,035.15 0.45 675.70 4.37 673.90 Pass-Major Risk 8,019.67 6,626.06 6,925.00 6,005.12 0.32 0.00 -57.19 767.88 3,024.64 0.45 696.64 4.53 694.82 Pass-Major Risk 8,025.48 6,625.86 8,050.00 6,620.80 0.32 0.25 2.16 530.19 2,970.40 022 73.06 222 70.92 Pass-Major Risk 8,030.00 6,625.75 6,900.00 5,982.96 0.33 0.00 -57.36 772.64 3,014.08 0.45 717.76 4.75 715.91 Pass-Major Risk 8,032.97 6,625.68 6,875.00 5,960.84 0.33 0.00 -58.16 777.46 3,003.48 0.45 738.97 4.84 737.11 Pass-Major Risk 8.038.85 6,625.54 8,075.00 6,620.60 0.34 025 2.37 551.94 2,958.08 022 93.37 2.38 91.11 Pass-Major Risk 8,041.53 6,625.48 6,850.00 5,938.75 0.34 0.00 -59.49 782.34 2,992.84 0.45 760.30 5.01 758.30 Pass-Major Risk 8,050.00 6,625.26 6,825.00 5,916.67 0.35 0.00 -60.76 787.26 2,982.19 0.45 781.72 5.18 779.61 Pass-Major Risk 8,050.00 6,625.26 8,100.00 6,620.67 0.35 0.28 2.01 574.19 2,946.69 0.22 114.54 2.49 112.21 Pass-Major Risk 8,058.68 6,625.00 6,800.00 5,894.61 0.36 0.00 -62.02 792.23 2,971,53 0.45 803.24 5.34 801.01 Pass-Major Risk 8,060.12 6,624.96 8,125.00 6,620.87 0.36 026 1.59 596.77 2,935.97 0.22 136.33 2.60 133.95 Pass-Major Risk 8,067.25 6,624.73 6,775.00 5,872.56 0.37 0.00 -6323 797.25 2,960.87 0.45 824.84 5.50 822.50 Pass-Major Risk 8,069.26 6,624.67 8,150.00 6,621.03 0.38 0.25 1.09 619.54 2,925.64 0.22 158.53 2.75 156.12 Pass-Major Risk 8,075.81 6,624.44 6,750.00 5,850.52 0,38 0.00 -64.42 802.30 2,950.20 0.45 846.51 5.64 844.07 Pass-Major Risk 8,077.56 6,624.38 8,175.00 6,621.16 0.39 0.25 0.57 642.48 2,915.71 0.22 181.09 2.89 178.69 Pass-Major Risk 8,084.40 6,624,13 6,725.00 5,828.52 0.40 0.00 -65.58 807.33 2,939.46 0.45 86820 5.78 865.66 Pass-Major Risk 8,085.09 6,624.10 8,200.00 6,621.24 0.40 025 0.04 665.59 2,906.17 022 203.99 3.03 201.60 Pass-Major Risk 8,091.90 6,623.84 8,225.00 6,62129 0.41 0.23 -0.47 688.86 2,897.05 0.22 227.17 3.17 224.90 Pass-Major Risk 8,093.03 6,623.79 6,700.00 5,806.54 0.41 0.00 -66.73 812.32 2,928.63 0.45 889.91 5.88 887.26 Pass-Major Risk 8,100.00 6,623.50 6,675.00 5,784.60 0.42 0.00 -67.69 81727 2,917.72 0.45 911.63 6.03 908.90 Pass-Major Risk 8,100.00 6,623.50 8,250.00 6,621.30 0.42 0.22 -1.15 712.29 2,888.32 0.22 250.63 3.34 248.11 Pass-Major Risk 8,100.00 6,823.50 8,275.00 6,621.27 0.42 0.21 -1.04 735.87 2,880.01 022 274.32 3.39 271.80 Pass-Major Risk 8,108.52 6,623.13 8,300.00 6,62120 0.43 0.19 -1.83 759.59 2,872.11 022 298.17 3.58 295.45 Pass-Major Risk 8,110.35 6,623.04 6,650.00 5,762.69 0.43 0.00 -68.97 82224 2,906.76 0.45 933.38 6.33 930.53 Pass-Major Risk 8,11122 6,62291 8,325.00 6,621.09 0.43 0.17 -225 783.31 2.864.21 022 322.11 3.71 31929 Pass-Major Risk 8,117.93 6,62269 8,350.00 6,620.95 0.44 0.15 -2.68 806.88 2,855.89 022 345.98 3.85 343.07 Pass-Major Risk 8,118.95 6,622.64 6,625.00 5,740.78 0.44 0.00 -70.05 827.30 2,895.83 0.45 955.22 6.57 952.26 Pass-Major Risk 8,122.66 6,622.46 8,375.00 6,620.76 0.45 0.13 -3.12 830.31 2.847.17 0.22 369.78 3.98 36638 Pass-Major Risk 8,127.40 6,622.22 8,400.00 6,620.54 0.46 0.11 -3.57 853.59 2,838.04 022 393.51 4.12 390.42 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/12/2013 11:32:29AM Page 7 of 9 COMPASS 2003.16 Build 69 - ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project Kuparuk River Unit TVD Reference: 1G-10A:@ 94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-1OA:) Site Error: O.0Oft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-10-1G-10BL1-1G-10BL1_wp04 Offset Site Error: 0.00 ft Survey Program: 95-BOSS-GYRO,6390-MWD,7422-MWD,8930-MWO Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolf ace+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +WS +EJ-W Hole Size Centre Distance Deviation HO (ft) (ft) (ft) (ff) (n) 11 (ft) (ff) (ft) (ff) (ft) (ft) 8,127.49 6,62222 6,600.00 5,718.88 0.46 0.00 -71.10 832.47 2,884.94 0.45 977.14 6.80 974.08 Pass-Major Risk 8,132.07 6,621.98 8,425.00 6,620.09 0.46 0.09 -4,05 876.78 2,828.68 0.22 417.22 4.26 414,05 Pass-Major Risk 8,135.94 6,621.78 6,575.00 5,696.99 0.47 0.00 -72.13 837.75 2,874.07 0.45 999.13 7.03 995.97 Pass-Major Risk 8,136.57 6,621.75 8,450.00 6,61921 0.47 0.08 -4.56 899.89 2,819.25 022 440.96 4.40 437.70 Pass-Major Risk 8,150.00 6,621.01 6,550.00 5,675.10 0.49 0.00 -73.72 843.05 2,863.23 0.45 1,021.21 7.37 1,017.88 Pass-Major Risk 8,150.00 6,621.01 8,475.00 6,617.89 0.49 0.08 -6.06 922.98 2,809.75 0.22 464.89 4.71 461.38 Pass-Major Risk 8,150.00 6,621.01 8,500.00 6,616.15 0.49 0.09 -6.18 946.02 2,800.20 0.22 488.55 4.77 485.02 Pass-Major Risk 8,150.00 6,621.01 8,525.00 6,613.98 0.49 0.11 -6.35 969.00 2,790.59 022 51229 4.84 508.75 Pass-Major Risk 8,152.65 6,620.85 6,525.00 5,653.18 0.49 0.00 -74.11 848.32 2,852.42 0.45 1,043.29 7.47 1,039.93 Pass-Major Risk 8,153.14 6,620.82 8,550.00 6,611.38 0.49 0.14 -6.88 991.91 2,780.93 022 536.07 4.97 532.47 Pass-Major Risk 8,156.96 6,620.60 8,575.00 6,608.36 0.50 0.19 -7.50 1,014.74 2,771.21 022 559.85 5.10 556.19 Pass-Major Risk 8,162.00 6,620.30 6,500.00 5,631.25 0.51 0.00 -75.19 853.56 2,841.62 0.45 1,065.43 7.71 1,061.96 Pass-Major Risk 8,162.00 6,620.30 8,600.00 6,604.91 0.51 0.25 -827 1,037.50 2,761.45 022 583.62 5.26 579.90 Pass-Major Risk 8,174.53 6,619.57 6,475.00 5,609.28 0.53 0.00 -74.02 858.70 2,830.87 0.45 1,087.60 7.91 1,084.00 Pass-Major Risk 8,188.83 6,618.83 6,450.00 5,587.02 0.55 0.00 -72.73 863.04 2,820.34 0.45 1,109.70 8.12 1,105.95 Pass-Major Risk 8,202.78 6,618.20 6,425.00 5,564.46 0.58 0.00 -71.54 866.36 2,810.11 0.45 1,131.71 8.30 1,127.81 Pass-Major Risk 8,216.26 6,617.68 6,400.00 5,541.62 0.60 0.00 -70.47 868.67 2,800.20 0.45 1,153.59 8.45 1,149,55 Pass-Major Risk 8,229.19 6,617.25 6,375.00 5,518.59 0.62 0.00 -69.51 869.93 2,790.57 0.45 1,175.31 8.85 1,171.13 Pass-Major Risk 8,241.79 6,616.91 6,350.00 5,495.50 0.64 0.00 -68.65 870.12 2,780.98 0.45 1,196.71 9.81 1,192.40 Pass-Major Risk 8,262.00 6,616.51 8,625.00 6,601.41 0.68 0.35 1.49 1,060.28 2,751.78 0.22 606.62 6.39 601,83 Pass-Major Risk 8,262.00 6,616.51 8,650.00 6,598:25 0.68 0.45 1.27 1,083.22 2,742.35 0.22 629.31 6.46 624.46 Pass-Major Risk 8,274.61 6,616.32 8,675.00 6,595.41 0.70 0.56 -0.18 1,106.30 2,733.17 0.22 652.04 6.73 847.27 Pass-Major Risk 8,279.05 6,616.25 8,700.00 6,592.91 0.70 0.66 -0,77 1,129.51 2,724.23 0.22 675.09 6.87 670.42 Pass-Major Risk 8,283.21 8,616.18 8,725.00 6,590.75 0.71 0.79 -129 1,152.85 2,715.55 0.22 698.33 7.03 693.39 Pass-Major Risk 8,287.10 6,616.12 8,750.00 6,588.92 0.72 0.92 -1.75 1,176.32 2,707.11 0.22 721.75 7.18 716.65 Pass-Major Risk 8,300.00 6,615.90 8,775.00 6,587.42 074 1.06 -3,10 1,199.89 2,698.93 0.22 745.46 7.51 740,08 Pass-Major Risk 8,300.00 6,615.90 8,800.00 6,586.26 074 1.19 -3.11 1,223.58 2,691.01 0.22 769.10 7.59 763.69 Pass-Major Risk 8,300.00 6,615.90 8,825.00 6,585.28 0.74 1.38 -3.11 1,247.38 2,683.45 0.22 792.95 7.69 787.51 Pass-Major Risk 8,300.00 6,615.90 8,850.00 6,584.41 0.74 1.53 -3.09 1,271.32 2,676.28 022 816.97 7.78 811.52 Pass-Major Risk 8,300.00 6,615.90 8,875.00 6,583.66 0.74 1.69 -3.07 1,295.38 2,669.52 0.22 841.16 7.88 835.69 Pass-Major Risk 8,300.00 6,615.90 8,900.00 6,583.02 0.74 1.86 -3.05 1,319.55 2,663.17 0.22 865.50 7.98 860.01 Pass-Major Risk 8,300.00 6,615.90 8,925.00 6,582.50 074 2.05 -3.01 1,343.82 2,657.22 022 889.96 8.09 884.46 Pass-Major Risk 8,300.00 6,615.90 8,950.00 6,58229 074 2.18 -2.96 1,368.17 2,651.55 022 914.49 8.14 908.52 Pass-Major Risk 8,300.00 6,615.90 8,975.00 6,582.83 0.74 2.27 -2.87 1,392.51 2,645.90 0.22 939.02 8.15 933.05 Pass-Major Risk 8,300.00 6,615.90 9,000.00 6,584.14 0.74 2.36 -274 1,416.83 2,640.25 022 963.53 8.18 957.54 Pass-Major Risk 8,300.00 6,615.90 9,025.00 6,586.21 074 2.46 -2.57 1,441.10 2,634.61 022 987.98 8.17 981.99 Pass-Major Risk 8,316.00 6,615.60 9,050.00 6,588.66 0.77 2.56 -4.01 1,465.41 2,629.35 0.22 1,012.12 8.47 1,006.00 Pass-Major Risk 8,317.21 6,615.58 9,075.00 6,591.10 0.77 2.68 -3.96 1,489.88 2,624.84 0.22 1,036.70 8.52 1,030.58 Pass-Major Risk 8,318.12 6,615.56 9,100.00 6,593.54 0.77 238 -3.88 1,514.48 2,621.08 0.22 1,061.38 8,55 1,055.27 Pass-Major Risk 8,318.56 6,615.55 9,225.00 6,605.60 0.77 3.45 -3.22 1,638.55 2,613.68 0.22 1,185.48 8.71 1,179.45 Pass-Major Risk 8,318.74 6,615.55 9,125.00 6,595.98 0.77 2.91 -3.79 1,539.17 2,618.08 022 1,086.14 8,59 1,080.04 Pass-Major Risk 8,318.98 6,615.55 9,200.00 6,60321 078 3.30 -3.39 1,613.67 2,613.64 0.22 1,160.65 8,68 1,154.60 Pass-Major Risk 8,319.08 6,615.54 9,150.00 6,598.40 078 3.03 -3.67 1,563.95 2,615.84 022 1,110.95 8.62 1,104.87 Pass-Major Risk 8,319.16 6,615.54 9,175.00 6,600.81 0.78 3.17 -3.54 1,588.79 2,614.36 0.22 1,135.80 8.66 1,129.73 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation I 2/12/2013 11:32:29AM Page 8 of 9 COMPASS 2003.16 Build 69 1 ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit TVD Reference: 1G-10A:@ 94.17ft(1G-10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G-10A:@ 94.17ft(1G-10A:) Site Error: 0.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1G-10BL2 Database: EDM Alaska Prod v16 Reference Design: 1G-10BL2_wp05 Offset TVD Reference: Offset Datum Reference Depths are relative to 1G-10A:@ 94.17ft(1G-10A:) Coordinates are relative to:1G-10 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.31° Ladder Plot I I I I I I 1200 I I ■ I I J J J J J ___ l900- --------_ C ; o 1 o I, 0) I CO a) C 600— -- 0 o m C Q) o 300 - 1 1 1 1 .1 J ___ _ ___ _. _. _ J _I 1 I I I I 0 1 I 1 I 0 1500 3000 4500 6000 7500 9000 Measured Depth LEGEND 46- 1G-10,1G-10,1G-10 V2 -4- 1 G-10,1 G-108,1 G-10B_wp11 VO -$ 1G-10,1G-10A,1G-10AV0 1G-10,1G-10BL1,1G-10BL1 wp04V0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/12/2013 11:32:29AM Page 9 of 9 COMPASS 2003.16 Build 69 0 , d d , ..i.ri , : r";a - 8 im 07. a s M m 8 a , C pp it Oil' -- e 0_ o eldill 6'..w . „: Ii C m_ t v zi WWII��- n I I I N O F pp n fp P 3. _s g w rIIIIIIIIW ‘‘ ‘, '' ', z ..--.- P cot I i - q m _ 6 °c6 u d d "6 M °o F0M c c w a - - 0 0 o g g a° O N 0 o a n v a M •^ g n 4 4 C 25 w 3 m = N m v~ (Ui/8 OM(+)quotd/(-)glnos r oi $ N Y ~ g E o G aa E o a° ^ ¢ a r _ a �r0tin' '..g.,A lr n 9-5 N tr "1-9 V P m , ?a m o 0 000 0 ma °0.0°0,0000°00 °o,0 _ v o — m r oo. 300. 98,88,888888 s c-"3 p00088;8OO6.8;8;O 7. v [yaq ca C Q .. n zO ,t-ciq PIAW.Wc4 6- \ Ci y ry O.2 o v � ^ vi �4 �`°M�� 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IIN■nl`U(d\•+'.tr/t,■■.I o./H■n■■\qq/w■■■■n /N\■■m■■ -I M I.US■I=ZI m �IN:NNN .a_ I .:: ■11■■■■■\BNI\ma��:: sae:�n•.:wH::B■ l /U\Um■■ O MMM W ._ 1..... ■ ■pm /U ... ■■■■\ - ■■pt■ ■IIH■/Hp..' r����qq.s l$1/ U■, ■U■ is lINIF I Mir;m:::::m Imo- 1-p :1 llm■,::nl8 llW.milr II 1 ■: ■ ;. + ,IIIIS■.w.nn n N sums■■t■ ■ \Um �. t■m ■I ■/■I.\n11 �i��"' ■■m `i �■■� p .Y■ w 1•!m�/ ' �■pnp■ppHq■■rSr �wwwm� mmw ¢8 9 $ f \/nu\\\//aO:.i\rgmN\\// - CV • /II\NNUrd■4R. 1k1�11� Nm■■w \■r1\/ T r i pid EVIU MENAMEM:oMv:EM:::::a m°.� I Ui r:ammasi ira ii ��ilin��i i i TRANSMITTAL LETTER CHECKLIST WELL NAME K2w IG—IcOJBL,2 PTD# a/302,3 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: K G y.u .�A. POOL: / 4( � o Check Box for 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 _ /<i k 1G- -/0�3 (If last two digits in Permit No. .2/SO 2( ,API No. 50-02,9 - al Oo3 -0.z-00. 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 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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