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HomeMy WebLinkAbout214-128 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. cQL - Icalg Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: /9oIor Items: ❑ Maps: Grayscale Items: /Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: '] BY: Date:ca/D.1 /1/45.— /s/ m P Project Proofing` BY: (Maria-) Date: ca/(17116-. /s/ (111° Scanning Preparation a x 30 = b 0 + 13 =TOTAL PAGES3 (Count does not include coy sheet) BY: Maria Date: a S /s/ 71 Production Scanning Stage 1 Page Count from Scanned File: 11.. (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Illik Date: g JJJ/ g:-/ /5' IIF/s/ ID Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc O .n O • , p N LL L.L. • co ISI I, . 0 . E E 0 • > N ON co o i v . LL a X s N N O O aO Z \ 'C >, >, OJth J C 0 0 a >. >. aN � m as J J C a) a) J J M _U NI C C C c j C C o 5 >- @ U co M M UCOUcn CL LL it U it it O cp co co it it T N 0 0 0 N N 0 0 > 0 0 > > > W a) 0 0 -o H 2 2 HE 2 2 H 0 0 c c g g Zas j WLU W Z N to U) N LO to W W LL LL N 10 u...7 > O O D C O O O O O O O O O O O O Q N a) > N �0 7) J J Q. 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( H E ° o rn -- 0 LL E O o E d c c ¢ a z w 3 3 0 a c0 0 0 c ° 0 0 EAU FEB a 4 21115 RECEIVED Letter of Transmittal Date: DATA LOGGED OGCG BAKER February 3, 2015 .2,,/6ENDESR HUGHES -__ -- ---_-_ ______ I To: r From: State of Alaska, AOGCC i Jesse Salyer 333 West 7th Ave, Suite 100 Baker Hughes INTEQ Anchorage, Alaska 99501 795 East 94th Avenue Anchorage,Alaska 99515 Please find enclosed the final well data for the following well(s): Well: 2M-32L1 2 1 4 1 2 5 2 5 3 5 1 M-332L1-01 2. 1 4 1 2 8 2 5 3 5 e Enclosed for each well(s): 1 hardcopy print of final logs • 2MD, 5MD & TVDSS 1 compact disk containing final field data • CGM • PDF • SURVEY • TIFF • LAS RECEIVED STATE OF ALASKA 0 C T 1 5 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: •Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: September 18,2014• 214-128/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 September 14,2014• 50-103-20186-61 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: w•t=a•14( Surface: 114'FSL,96'FEL,Sec.28,T11N, R8E, UM September 16,2014 • Kgs.) 2M-32L1-01 . SKS Top of Productive Horizon: '8. KB(ft above MSL): 146'RKB 15.Field/Pool(s): 2013'FSL, 1301'FEL, Sec.5,T1ON,R8E,UM GL(ft above MSL): 105'AMSL Kuparuk River Field • Total Depth: 9.Plug Back Depth(MD+TVD): 431'FNL, 1756'FEL,Sec. 8,T1ON, RO8E, UM 15650'MD/6220'TVD Kuparuk River Oil Pool. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-487744 y- 5948986 Zone-4 15650'MD/6220'TVD • ADL 25586,25590,25589 . TPI: x-481264 y- 5940340 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-480810 y- 5937897 Zone-4 none 2672,2676 18.Directional Survey: Yes ❑✓ , 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) 1479'MD/1396'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 13458'MD/6237'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 42' 121' 42' 121' 24" 227 sx PF C 9.625" 47# L-80 41.5' 4515' 41.5' 2701' 12.25" 670 sx PF E,840 sx Class G 7" 26# J-55 39.7' 12988' 39.7' 6057' 8.5" 150 sx Class G 5" 18# L-80 12657' 13385' 5828' 6349' 8.5" 75 sx Class G 2.375" 4.6# L-80 12982' 15650' 6053' 6220' 3" slotted liner 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 13008' 12567'MD/5770'TVD, 12983'-15650'MD 6053'-6220'TVD i t J14tPLE t1. 12657'MD/5828'TVD , 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. �� Was hydraulic fracturing used during completion? Yes No \Ta DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ••^ - none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) October 2,2014 oil producer Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/6/2014 24.0 Test Period--> 1179 1133 209 176% 476 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 201 psi 24-Hour Rate-> 1179 - 1133 - 209 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 un-- 2/4//5" CONTINUED ON REVERSE , fiA4 kI Zo'I'S- Submm original only //.5 RBDMJAN - 6 2015 G 29. GEOLOGIC MARKERS(List all formations and mai ;ncountered) 30. FORMATION TESTS NAME MD TVD Well tested' Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1479' 1396' needed,and submit detailed test information per 20 AAC 25.071 Top Kuparuk A3 13458' 6237' Kuparuk A3 15650' 6220' N/A Formation at total depth. Kuparuk A3 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Burke @ 265-6097 Email Jason.Burke@conocophillips.com Printed Name 'D.Venhaus / Title CTD Engineering Supervisor �l j Signature �ijij, f/Jj Lis� Phone 263-4372 Date / """ i�' /(f. lr o6 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 t KUP PROD 2M-32L1-01 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,Illi;;- Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(kKB) -Act Btm(ftKB) Ctentnttull5 a 501032018661 KUPARUK RIVER UNIT PROD 98.85 13,544.88 15.650.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) •'Rig Release Date 2M-32L1-01,10/7/20142.51:46 PM SSSV:ISOLATION VLV 125 12/24/2013 Last WO: 41.01 11/21/1992 Vertical schematic(actual) Annotation Depth(NKR) End Date Annotation Last Mod By End Date Last Tag'. Rev Reason:ADD LATERALS L1,L1-01,GLV haggea 10/7/2014 0/0,PULLED CATCHER/HOLEFINDER HANGER 39.7 j Casing Strings Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(WD)... Wt/Len(I...Grade Top Thread LINER 1.1-01 23/8 1.995 12,981.8 15,650.0 6,220.4 4.60 L-80 STL Liner Details Nominal ID Top(kKB) Top(WD)(kKB) Top Ieel(°) Item Des Corn (in) 12,981.8 6,052.9 43.58 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.920 Perforations&Slots .AA/CONDUCTOR;42.0-121.0- ✓t..n..safts. Shot Dens Top(TVD) Btm(TVD) (shots/f Top(Po(B) Btm(kKB) (Po(B) (kKB) Zone Date t) Type Com BARRIER VLV;3.506.2 12,982.6 15549.6 6,053.4 6,220.4 A-3,2M-32L1- 9/17/2014 SLOTS Slotted Liner 41 01 Notes:General&Safety • End Date Annotation 9/6/2014 NOTE:ADD LATERALS L1,L1-01 GAS LIFT;4,243.4 g- SURFACE;41.5.4,514.6- i. GAS LIFT;7,541.2 GAS LIFT;10.011.1 g GAS LIFT,11,673.5II GAS LIFT;12,484.1III LOCATOR;12.540.0- SEAL ASSY;12,541.01 PBR;12,543. %9 PACKER;12.566.9 _�.� SO THREADS;72,578 4 p(D, 6,.� DO THREADS;12,614.9 /NV NIPPLE;12.6249 XO THREADS;12,626.5 V b-� ;4,I Ir 1 i II PRODUCTION;39.7-12,987.8 • I WLEG;13,007.5 LINER;12,657.1-13,385.0 SLOTS;12,982.6.75.649.6 LINER L1431;12.981.8.15,650.0 V , °° -I I I N II II Co 0,6 II I I Co Il I I co co L co N 11 rn II r- •• 000 NM N ni o - ccoo IIII CLQ= II M a) ❑ °O a J }, 1 II Jia 11 NCGI- c- o o cc �° m II co -.--, IP 11 E- N� � O p II = ❑ 11 co co NI— H II Nm l— b.) 11 er-I N N II II ' 7r660 II 11 01.0 _ I � co c7 M I 11 o� �� N CO -N II II r-iM of d u) �� II 11 m g 0)2 g N N II Ii r — > g d p II II m M N c � ca �•� - II 1I �- � v > I—f a) II J iB a.D-, Ud Y� II N ca I II CO "-' cn E CO Q 0) II I I .� ❑ >. = .J r- a C I N m 1- 1O ❑m U� O as ` 11 O Q p co°° O CO Q- c c \\` O CO rnrn U XX i=i= ` N• NN N NM E rk II • rr ,-p r o0 :..1 xx 4 c AA ch Ac.; to Eo- in 1 i i i i i -Y /A ,,' 13 - et I I I I n I I �' 0 1 '/� C3 t_ 0 c i., n U 1 / M 1 2 :ou CNIp O pa) a) p O _Q r L 0 00 in cin ❑ 6 Nrn cnp ;,--)� p `o1 It `? � En m 00 N � � v It 0) EN * CO C0N o0 a) CON N CL (BN 00c0 r 10 0 N = O (a � ❑ c- v 0) C ' _ U C) Y Q ,- 2 Cog KUP PROD 2M-32 ConocoPhillips t 1` Well Attributes Max Angle&MD TD Alaska,Inc. ' Wellbore APIIUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) cmrr,,,,., ; 501032018600 KUPARUK RIVER UNIT PROD 71.25 9,399.90 13,385.0 ••• Comment I12S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2M-32,10/720142;49.00 PM ' SSSV:ISOLATION VLV 125 12/24/2013 Last WO: 6/12/2014 41.01 11/21/1992 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .................................................._......._.._.._._... ___... ..Last Tag:SLM 13,209.0 8/23/2014 Rev Reason:ADD LATERALS L1,L1-01,GLV haggea 10/7/2014 HANGER;39.1 I C/O,PULLED CATCHER/HOLEFINDER Casing Strings Casing Description OD(in) ID(in) Top((tKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread • m CONDUCTOR 16 15.062 420 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 'illi SURFACE 95/8 8.681 41.5 4,514.6 2,701.3 47.00 L-80 AB-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen)t...Grade Top Thread PRODUCTION 7 6.276 39.7 12987.8 6,057.2 26.00 J-55 BTC .-A-A.,CONDUCTOR;420-121.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW L1 7 6.276 13,164.0 13,186.0 6,202.0 ` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 5 4.276 12,657.1 13,385.0 6,349.0 18.00 L-80 LTC BARRIER VLV;3,506.2 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°l Item Des Com (in) - 12,657.1 5,828.0 49.35 PACKER TIW LINER PACKER 4.276 GAS LIFT;4.2434 13 3 12,667.9 5,835.1 49.36 HANGER TIW LINER HANGER 5.000 F--• Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection O TUBING WO (UPPER) 31/2 2.992 39.1 12,562.7 5,766.8 9.30 L-80 EUE I Completion Details SURFACE;41.5-4,514.6-i TopftKB TopD ftKB To Incl Item Des Com Nominal to ( ) (TVD) ) P ('I on) 39.1 39.1 0.00 HANGER TUBING HANGER 2.992 - 3,506.3 2,347.8 68.83 BARRIER VLV BAKER ORBIT-5 BARRIER VALVE(ISOLATION) 2.835 GAS LIFT;7,541.2 -H 12,540.0 5,752.2 50.29 LOCATOR BAKER LOCATOR SUB 2.990 12,541.0 5,752.8 50.24 SEAL ASSY SEAL ASSY 3-ft STICK UP ABOVE THE TOP OF THE 2.990 PBR Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection GAS LIFT;10,011.1 -- TUBING WO (LOWER) 3 1/2 2.992 12,544.0 13,008.5 6,072.2 9.30 L-80 IBT_M Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(") Item Des Com (In) GAS SFr;11,673.5- LI 12,544.0 5,754.7 50.10 PBR BAKER 80/40 POLISH BORE RECEPTACLE 2.992 12,566.9 5,769.5 49.63 PACKER BAKER FHL RETREIVABLE PACKER 2.992 12,624.9 5,807.1 49.83 NIPPLE X-NIPPLE 2.813 13,007.5 6,071.5 43.27 WLEG SPECIAL CLEARANCE(4.15"O.D.)WLEG 3.020 GAS UFT;12.484.1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top incl Top(ftKB) (ftKB) (") Des Corn Run Date ID(in) - 13,160.0 6,182.8 42.86 WHIPSTOCK BAKER 3.5"x 5"Gen 2 Retrievable Whipstock.Set 8/25/2014 3 degrees ref of high side.Two PIP tags installed at LOCATOR;12,540.0 °r 13167.35'. SEAL ASSY:12541.0, l Perforations&Slots PBR;12,543.9 Shot Dens ^\ Top(ND) Btm(ND) (shotslf PACKER;12,566.9 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 13,172.0 13,192.0 6,191.6 6,206.4 A-3,2M-32 1/1/1993 4.0 (PERF SWS 33/8"PPG Guns; 180 deg.ph;OR 26 deg. XO THREADS;12,578.4 M. F/High Side 13,192.0 13,197.0 6,206.4 6,210.1 A-3,2M-32 1/1/1993 4.0 IPERF SWS 33/8"PPG Guns; XO THREADS;12,614.9 C 180 deg.ph;OR 22 deg. NIPPLE;12.624.9 Iti, F/High Side t= XO THREADS;12,626.5 MI Mandrel Inserts St aft °n Top(TVD) Valve Latch Port Size TRO Run t N,-r. Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com , 1 4,243.4 2,607.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,341.0 9/24/2014 2 7,541.2 3,797.4 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,357.0 9/24/2014 I 3 10,011.1 4,643.7 CAMCO KBMG 1 GAS LIFT OV BK 0250 0.0 9/24/2014 4 11,673.5 5,291.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 ' 0.000 0.0 6/12/2014 _ k 5 12,484.1 5,716.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/12/2014 Notes:General&Safety PRODUCTION;39.7-12.997.9 J End Date Annotation • 3/9/2011 NOTE:-DOUBLE 0-RING ON TREE CAP'" 9/6/2014 NOTE:ADD LATERALS L1,L1-01 WLEG;13,007.5 SLOTS;12,982.6-15,649.6 LINER L1-01;12981.8-15,650.0 Y, WHIPSTOCK 13,160.0 i 4 1- IPERF;13,172.0-13,192.0• WINDOW L1;13,164.013,186.0 IPERF;13.1920-13,197.0 LINER;12.67.1-13,305.0 - 2M-32 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 8/20/2014 TAGGED @ 13197' SLM. IN PROGRESS 8/21/2014 GAUGE TBG &SET 2.81"XX PLUG @ 12624' RKB; PULLED GLVS &SET DV'S @ 4243' &7541' RKB. IN PROGRESS 8/22/2014 PULL OV @ 10011' RKB; CIRC OUT W/INHIB SW W/DSL U-TUBE FP; SET DV @ 10011' RKB. LRS ON LOCATION DOING MIT'S. ((SEE ATTACHMENTS FOR PASSING MITIA& MITT RESULTS)) IN PROGRESS 8/23/2014 PULL CATCHER& XX PLUG @ 12624' RKB; DRIFT TBG W/2.63"x20' BAKER WHIPSTOCK DRIFT& TAG FILL @ 13209' SLM; CLOSE ORBIT VALVE AND PERFORM DDT ON TBG (GOOD); OPEN ORBIT VALVE & DRIFT WHIPSTOCK BACK THRU W/NO PROBLEMS. READY FOR E-LINE. 8/25/2014 SET BAKER 3 1/2"X 5" GEN 2 RETRIEVABLE WHIPSTOCK. TOP OF TRAY AT 13160'. WHIPSTOCK SET 3 DEGREES LEFT OF HIGH SIDE. CCL-TOP OF WHIPSTOCK= 15'. CCL STOP DEPTH 13145'. TWO PIP TAGS INSTALLED IN WHIPSTOCK AT 13167.35'. JOB COMPLETE. 8/27/2014 MEASURE BHP @ 13155' RKB (3677 PSI). JOB COMPLETE ((READY FOR BPV)) 8/28/2014 (PRE-CTD): TREE TEST. DDT'S: SV-FAILED. SSV-PASSED. MV-PASSED. POSITIVE PRESSURE TESTS: SV-PASSED. SSV-PASSED. MV-PASSED. POST RIG WELL WORK 9/23/2014 RAN 2.60" MAGNET TO TOP OF LINER© 12,982' RKB (RECOVERED METAL SHAVINGS) ; MEASURED BHP @ 12,982' RKB (3876 PSI); SET CATCHER/COLLAR STOP HOLEFINDER @ 10,184' SLM. IN PROGRESS 9/24/2014 PULLED DV'S @ 10,011', 7541', &4244' RKB; SET GLV'S @ 7541'&4244' RKB; SET OV @ 10,011' RKB; (GOOD TUBING TEST) PULLED CATCHER/HOLEFINDER @ 10,080' SLM. JOB COMPLETE. ConocoPhiIIips Time Log & Summary WelNiew Web Reporting Report Well Name: 2M-32 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 9/1/2014 12:00:00 AM Rig Release: 9/18/2014 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/31/2014 24 hr Summary Stab coil in injector, ND BOP stack,secure stack and wellhead. Finish RD on 2K-09. Move rig to 2M-Pad, MIRU CDR2. 08:00 09:00 1.00 0 0 MIRU MOVE CTOP P PJSM, R/U stabbing cable, Install grapple, pull test and stab coil into injector, R/D stabbing equipment. 09:00 10:00 1.00 0 0 MIRU MOVE CTOP P PJSM-Install inner reel iron, bulkhead, CTES counter. 10:00 12:00 2.00 0 0 MIRU MOVE RURD P Complete RD from 2K-09, ND BOP stack,secure BOP stack for move, secure wellhead, load with metanol, prep for move to 2M-Pad. 12:00 13:00 1.00 0 0 MIRU MOVE RURD P Complete RD,continue prep for rig move to 2M-Pad. 13:00 15:00 2.00 0 0 MIRU MOVE MOB P Peak trucks on location,pull subs off 2K-09, clean&inspect wellhead/work area. 15:00 18:00 3.00 0 0 MIRU MOVE MOB P Move Rig from 2K-09 to 2M-32. 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Arrive on 2M pad, Crew change, PJSM Prep well site and spot up, berm cellar, R/U PUTZ,steam. electrical inter tie,pre spud checklist. 39/01/2014 NU BOP. Perform initial BOP tests, Install CTC, UQC and test, Load reel. 00:00 03:30 3.50 0 0 MIRU WHDBO NUND P Accept rig @ 00:00, Nipple up BOPE equipment,MP line,all tree flange bolts checked and tightened, fill stack,shell test. 03:30 15:00 11.50 0 0 MIRU WHDBO BOPE P Begin BOP test,250/4000,2500 annular,test witness waived by Chuck Sheve,AOGCC at 08:25 on 08/31/2014 15:00 17:45 2.75 0 0 MIRU WHDBO MPSP P PJSM. Load BPV lubricator,pull BPV, LD lubricator. 17:45 19:39 1.90 0 0 MIRU WHDBO PRTS P PJSM.Test PDL's,and tiger tank line. 19:39 00:00 4.35 0 0 SLOT WELLPF CTOP P PJSM. Install CTC,counters, MU UQC, load coil and PT CTC, inner reel valve. 09/02/2014 Complete reel equipment tests,Tested Orbit valve per procedure, MU BHA#1, Begin milling window at 13,164' 00:00 00:45 0.75 0 0 SLOT WELLPF SFTY P Pre spud,with Orbit valve overview. 00:45 03:15 2.50 0 0 SLOT WELLPF PRTS P Pressure test inner reel iron,stripper, CTC. Page 1 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 05:45 2.50 0 0 PROD1 WHPST DHEQ P PJSM-testing down hole orbit valve. Initial tubing 1187 psi, open/close control lines 0/0 psi. 1)Bleed SITP from 1187 to 850 psi, unable to bleed WH down.ORBIT valve open. 2)SITP 1184 psi,pressure up CLOSE side, returns at 1800 psi, recovered 65.5cc, Max CL 3500 psi. Bled WH down to 782 psi and held, 406 psi and held, 14 psi and held 5 min.ORBIT valve closed. 3)SITP 14 psi,pressure TBG to 900 psi, pressure up OPEN side, returns at 1700 psi,TBG equilized to 1191 psi at 2500 psi pump pressure, recovered 65.5cc,Max CL 3500 psi, unable to bleed WH down, ORBIT valve open. 4)SITP 1180 psi, pressure up CLOSE side, returns at 1700 psi, recovered 65.5cc, Max CL 4000 psi. Bled WH down to 806 psi and held, 378 psi and held,6 psi and held 30 min.ORBIT valve closed. 5)Open/Close sides both bled to 0 psi, monitor both sides from one guage for thermal expansion. 05:45 07:15 1.50 0 75 PROD1 WHPST PULD P MU window milling BHA#1 07:15 07:45 0.50 75 75 PROD1 WHPST SFTY P Pre spud,with Orbit valve overview with day crew 07:45 08:30 0.75 75 75 PROD1 WHPST DHEQ P Pressure up tbg to 1400 psi, pressure up on OPEN side of DH isolation valve,4000 psi max on control line,65.5cc fluid return, DH valve fully open, unable to bleed tubing down, Orbit valve is fully open. 08:30 11:18 2.80 75 13,000 PROD1 WHPST TRIP P TIH with BHA#1, .6°AKO motor and window mill assembly, clean through 2.835"ID Orbit DH isolation valve. 11:18 11:30 0.20 13,000 13,075 PROD1 WHPST DLOG P Log K1 marker, +19 correction. 11:30 12:51 1.35 13,075 13,164 PROD1 WHPST DISP P Swap hole over to 9.6 ppg milling fluids, PUW 29k, RBIH, pumps off tag top of whipstock at 13,165'. 12:51 22:00 9.15 13,164 13,182 PROD1 WHPST WPST P 13,164'Begin milling pinch point 1 fph as per Baker rep, 1.35 bpm at 4108 psi, CWT 6.5k,WOB.4k, 22:00 00:00 2.00 13,182 13,182 PROD1 WHPST DRLG P Start drilling ahead in formation 09/03/2014 Complete milling window 00:00 00:30 0.50 13,182 13,186 PROD1 DRILL WPST P 13182',Continue milling window, 1.35bpm at 4100psi, BHP 4086, WHP 13, IA 708, OA 67 Page 2 of 14 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:30 02:15 1.75 13,186 13,186 PROD1 DRILL REAM P 13186.2',TD rate hole, ream window area as per plan. 13155'-13175', reaming passes 30°of milled TF. 02:15 02:30 0.25 13,186 13,040 PROD1 DRILL REAM P Dry drift window area,Tag bottom twice at 13183', PUH and tie in to verify depth. PUH to tie in depth. 02:30 02:45 0.25 13,040 13,058 PROD1 DRILL DLOG T 13040',Tie into the K1 marker no correction, looks like we are on depth. **"*Note:Thinking it might be cuttings in the 5inch. 02:45 03:30 0.75 13,058 13,186 PROD1 DRILL REAM T RIH,tag TOWS 2k,continue in hole, PUH,overpull 5k, backream up, PUH to 12960'inside the 3-1/2, RBIH at 90fpm to try and clean the 5inch, ream down at milled TF, continue RIH, pumping 5bbls high vis sweep. 03:30 04:00 0.50 13,186 13,186 PROD1 DRILL REAM P Tag TD 13186', PUH chasing sweep to the tubing tail 13000'. RBIH 04:00 04:15 0.25 13,186 13,186 PROD1 DRILL REAM P Dry drift window area clean to bottom 13186.2'. 04:15 06:57 2.70 13,186 75 PROD1 DRILL TRIP P 13,186', TOOH with BHA#1, no problem through Orbit valve at 3,506'. 06:57 07:42 0.75 75 75 PROD1 DRILL OWFF P On surface, 1700 psi on both sides of Orbit valve manifold, bleed residule pressure of CL,200 cc return from both sides,pressure up Closed side to 4000 psi,65 cc fluid return on non-active side indicating full closure of valve per procedure, bled tubing down in 200 psi increments to 0 psi, monitor well 30 min.,good, left 1000 psi on active side(Closed)and 0 psi on non-active side(Open) 07:42 08:30 0.80 75 0 PROD1 DRILL PULD P PJSM-LD BHA#1, both mills 2.79 no-go,2.80"go,normal wear,top two magnets full of metal,bottom half of lowest magnet half full. 08:30 09:18 0.80 0 72 PROD1 DRILL PULD P PJSM-MU build section BHA#2, 2.3°AKO motor with Bi-center bit. 09:18 10:00 0.70 72 72 PROD1 DRILL SVRG P Service choke, injector and reel. 10:00 11:30 1.50 72 4,960 PROD1 DRILL TRIP P Open up to well, pressure up tubing to 900 psi,open Orbit valve per procedure,TIH with BHA#1 11:30 12:06 0.60 4,960 5,565 PROD1 DRILL RGRP T Counter on injector gave out, bearings frooze up,change out counters, reset to digital 12:06 13:30 1.40 5,567 12,980 PROD1 DRILL TRIP P Continue TIH with BHA#2 13:30 13:42 0.20 12,980 13,010 PROD1 DRILL DLOG P Log K1 marker, +16 correction. 13:42 15:27 1.75 13,010 13,130 PROD1 DRILL DISP P Swap hole over to drilling fluids 8.9 ppg PwrPro 15:27 18:57 3.50 13,130 1,000 PROD1 DRILL CIRC T Losing Returns,discuss with town team,decide to POOH to clean up hole. Page 3 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:57 20:57 2.00 1,000 72 PROD1 DRILL CIRC T Still no change in returns,open B8, looks like we have full returns, looks like we have a plug in surface lines between B4 and B3,circulate out metal debirs,well debris,brillo pad debris from coil, and rubber chucks, function close the orbit valve, continue pulling to surface,with full returns flushing surface lines, retireveing addtional brillo pad debris from coil. ****Note: Closed Orbit Valve, recovered 2 oz of fluid. 20:57 21:42 0.75 72 3,450 PROD1 DRILL CIRC T Perform jog at 150'by RIH at 100fpm down to 250',then POOH to surface, RBIH to 3450',circulate bottoms up with full returns, looks like we have some more debris in choke flush lines,open Orbit valve. ****Note: Open Orbit valve, recovered 2oz of fluid. 21:42 00:00 2.30 3,450 10,937 PROD1 DRILL CIRC T RIH, pumping lbpm at2200psi, IA 564, OA 88 09/04/2014 Finished milling window and rate hole down to 13186', M/U and RIH with the build BHA,displaced well to drilling fluid.Circulated to clean wellbore. 00:00 00:36 0.60 10,937 13,025 PROD1 DRILL CIRC T ****Note: Lost 22bbls of PwrPro and 16bbls of FloPro to formation during displacement. Continue RIH, pumping lbpm at 2200psi, BHP 3419,WHP 364, IA 632, OA 70 00:36 00:51 0.25 13,025 13,052 PROD1 DRILL CIRC T 13025,Tie into the K1 marker correction of plus 3.5' 00:51 01:00 0.15 13,052 13,150 PROD1 DRILL CIRC T Continue RIH, BHP 3827,WHP 393, IA 638, OA 69 01:00 01:12 0.20 13,150 13,186 PROD1 DRILL TRIP P Close EDC, RIH through window 01:12 07:33 6.35 13,186 13,420 PROD1 DRILL DRLG P 13186', OBD 1.5bpm at 3223psi, BHP 3805,WHP 211, IA 609, OA 68 07:33 10:36 3.05 13,420 72 PROD1 DRILL TRIP P 13,420', End of build and turn,wiper up hole, PUW 28k,open EDC in 5" liner, continue TOOH,jog at 3,600', jog at 500'. 10:36 11:51 1.25 72 0 PROD1 DRILL PULD P On surface, PJSM- Close DH Orbit valve(65.5 cc fluid return), lay down BHA#2 11:51 12:48 0.95 0 72 PROD1 DRILL PULD P PJSM-MU Drilling BHA#3, .5+0 AKO motor with Bi-center bit, surface test tool. 12:48 15:18 2.50 72 13,000 PROD1 DRILL TRIP P TIH with BHA#3,Open DH Orbit valve(65.5 cc fluid return), IA 540, OA 57 15:18 15:30 0.20 13,000 13,060 PROD1 DRILL DLOG P Log K1 marker,-.5'correction, PUW 27k. Page 4 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 15:39 0.15 13,060 13,160 PROD1 DRILL TRIP P Continue TIH with BHA#3 15:39 15:45 0.10 13,160 13,205 PROD1 DRILL DLOG P Log RA marker, marker at 13,168.5', top of whipstock at 13,161' 15:45 15:51 0.10 13,205 13,420 PROD1 DRILL TRIP P Continue TIH with BHA#3 15:51 18:00 2.15 13,420 13,620 PROD1 DRILL DRLG P 13,420', OBD 1.43 bpm at 3426 psi, BHP 3920,WHP 266, IA 689, OA 58 18:00 18:18 0.30 13,620 13,620 PROD1 DRILL WPRT P 13620',Wiper up hole to 13200', PUW 28k, RIW7k 18:18 20:18 2.00 13,620 13,820 PROD1 DRILL DRLG P 13620', BOBD 1.41bpm at 3140psi, BHP 3937,WHP 245, IA 778, OA 63 20:18 21:03 0.75 13,820 13,820 PROD1 DRILL WPRT P 13820',Wiper up hole to 13212', PUW 30k, RIW 21:03 22:48 1.75 13,820 14,020 PROD1 DRILL DRLG P 13820', BOBD 1.5bpm at 3350psi, BHP 3988,WHP 251, IA 828, OA 63 22:48 23:36 0.80 14,020 13,010 PROD1 DRILL WPRT P 14020',Wiper up hole for a tie in, PUW 30k 23:36 23:51 0.25 13,010 13,147 PROD1 DRILL WPRT P 13147', PUH into the casing,jet the 5inch liner up to 13010', RIH to tie in depth. ****Note: Perform Pressure Survey at window Annullar Pressure 3915psi, BHI/ECD 12.53 23:51 00:00 0.15 13,147 13,204 PROD1 DRILL DLOG P 13190',Tie into the RA marker correction of plus 2.5' 09/05/2014 Drilled the Build section from 13186'-13420'. M/U lateral assy.with 1.5°AKO motor and rebuild Hughes bit. 00:00 00:24 0.40 13,204 14,020 PROD1 DRILL WPRT P 13204', Continue wiper in hole. RIW 8k 00:24 03:24 3.00 14,020 14,220 PROD1 DRILL DRLG P 14020', BOBD 1.5bpm at 3400psi, BHP 4059,WHP 257, IA 299, OA 64 03:24 04:18 0.90 14,220 14,220 PROD1 DRILL WPRT P 14220',Wiper up hole to 13425'. PUW 30.5k ****Note: 14135'over pull 1.5k on DHWOB 04:18 07:45 3.45 14,220 14,281 PROD1 DRILL DRLG P 14220', BOBD 1.5bpm at 3470psi, BHP 4026,WHP 259, IA 335, OA 64, slow drilling 10-20 fph to 14,277', drilling picked up to 80 fph,to 14,281', BHP fluctuating, 07:45 09:45 2.00 14,281 14,190 PROD1 DRILL DRLG T PUH,several attempts at lower pump rate and speeds, unable to get back to bottom,getting back gas infused mud,take 20 bbls to TT, attempt to get back to bottom, losing returns when poking bit into fault, PU 37k at 14,277', returns come back,mud cleaned up, RBIH confer with town, same results at 14,274'. 09:45 11:30 1.75 14,281 13,100 PROD1 DRILL WPRT T 14,274' Wiper trip to window for BHP survey, PUW 27k,clean up 5"liner, RBIH for survey at window,sample at bottoms up, nothing unusual. 11:30 11:48 0.30 13,100 13,100 PROD1 DRILL DLOG T 13,100', Perform Pressure Survey at window,Annular Pressure 4000 psi, BHI/ECD 12.83 Page 5 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:48 12:27 0.65 13,100 14,272 PROD1 DRILL WPRT T 13,100, Wiper back in hole 12:27 16:00 3.55 14,272 72 PROD1 DRILL TRIP T 14,272', Sat down 2.7k, annular and returns fell off, PUW 33k,call from town to plug back.TOOH for anchored billet assembly. 16:00 17:15 1.25 72 0 PROD1 DRILL PULD T PJSM-Close Orbit valve, holding, LD BHA#3 17:15 19:15 2.00 0 73 PROD1 STK PULD T PJSM-MU anchored billet assembly BHA#4 19:15 21:00 1.75 73 73 PROD1 STK RGRP T Replace leaking hose on gooseneck, and tighten sadle clamp bolt on reel stand. 21:00 00:00 3.00 73 11,660 PROD1 STK TRIP T RIH,with plug back BHA#4/ Aluminum Open Hole Anchored Billet 70 fpm,slowing down 20 fpm passing jewlery. ***"Note: Open Orbit Valve,2 oz of fluid retrieved 39/06/2014 Drilled the L1 build section from 14020',to 14281'. 00:00 00:30 0.50 11,660 13,025 PROD1 STK TRIP T 11660', Continue RIH with Open Hole Anchored billet. 00:30 00:45 0.25 13,025 13,063 PROD1 STK DLOG T 13025',Tie into the K1 marker _ correction of minus 2'. PUW 30k 00:45 01:15 0.50 13,063 13,935 PROD1 STK TRIP T Continue RIH 01:15 01:30 0.25 13,935 13,935 PROD1 STK WPST T 13935',at 180 Deg low side w/ anchors set at 150 degrees. Pressure up on pump to 4300psi set Open hole anchored billet.Set down _ 4k, 01:30 04:09 2.65 13,935 73 PROD1 STK TRIP T POOH 04:09 04:30 0.35 73 73 PROD1 STK SFTY T Check well for flow, PJSM for UD billet setting BHA#4 04:30 05:15 0.75 73 0 PROD1 STK PULD T L/D BHA#4 05:15 05:45 0.50 0 72 PROD1 STK PULD T MU drilling BHA#5, .5°+AKO motor with new Bi-center bit. 05:45 06:15 0.50 72 72 PROD1 STK SVRG T Check reel shims,crew change out, PJSM 06:15 07:03 0.80 72 72 PROD1 STK PULD T MU BHA to coil,stab on injector, test tool,pressure up tubing to SITP, open Orbit valve(2.2 fluid ounces return) 07:03 09:33 2.50 72 13,030 PROD1 STK TRIP T TIH with BHA#5 09:33 09:48 0.25 13,030 13,070 PROD1 STK DLOG T Log K1 marker,-3.5'correction, PUW 23k. 09:48 10:15 0.45 13,070 13,936 PROD1 STK TRIP T Continue TIH,dry tag top of billet at 13,936', PUW 29k. 10:15 12:00 1.75 13,936 13,940 PROD1 STK KOST T 13,935', Start time milling billet at 1,2,5 FPH, 180°ROHS: 1.5 bpm @ 3608 psi, BHP 4017 psi,WHP 240, IA 109, OA 62. Page 6of14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 13,940 13,957 PROD1 STK KOST T Start drilling at 10,20 and 45 fph to 13960". PUH to drift billet, PUW 30.5k, RBIH,drift looks good. Note: Rig on High Line at 12:50. 13:00 22:00 9.00 13,957 14,135 PROD1 DRILL DRLG T 13,957' BOBD 1.5 bpm at 3829 psi, BHP 4017,WHP 264, IA 182,OA 61 22:00 22:15 0.25 14,135 14,135 PROD1 DRILL WPRT T 14135',Wiper up hole to 13975', PUW 28k 22:15 00:00 1.75 14,135 14,177 PROD1 DRILL DRLG T 14135', BOBD 1.51bpm at 3829psi, BHP 4043,WHP 260, IA 341,OA 63 09/07/2014 Kicked off of billet,drilled from 14281'to 14643' 00:00 06:15 6.25 14,177 14,281 PROD1 DRILL DRLG T OBD, 1.51bpm at 3823psi, BHP 4057,WHP 261, IA 350,OA 64. **"Note: New mud at the bit 14223'. 06:15 09:36 3.35 14,281 14,335 PROD1 DRILL DRLG P 14,281', OBD, 1.47 bpm at 3513 psi, BHP 4045 psi,WHP 376, IA 382, OA 63 09:36 10:36 1.00 14,335 13,020 PROD1 DRILL WPRT P 14,335',Wiper up hole, PUW 31k, couple passes in 5"liner to clean up. 10:36 10:48 0.20 13,020 13,060 PROD1 DRILL DLOG P Log K1 marker, +3.5'correction. 10:48 11:33 0.75 13,060 14,335 PROD1 DRILL WPRT P 13,060', Wiper in hole. 11:33 19:33 8.00 14,335 14,535 PROD1 DRILL DRLG P 14,335', BOBD, 1.50 bpm at 3553 psi, BHP 4026 psi,WHP 347, IA 353,OA 60 19:33 20:18 0.75 14,535 14,535 PROD1 DRILL WPRT P 14535',Wiper up hole to 13975'. PUW 31k 20:18 00:00 3.70 14,535 14,643 PROD1 DRILL DRLG P 14535', BOBD 1.5bpm at 3520psi, BHP 4070,WHP 349, IA 461,OA 63 39/08/2014 Drilled L1 lateral from 14643'to 15135', 00:00 03:51 3.85 14,643 14,735 PROD1 DRILL DRLG P OBD 14643', 1.5bpm at 3520psi, BHP 4093,WHP 360, IA 469,OA 63 03:51 04:18- 0.45 14,735 13,990 PROD1 DRILL WPRT P 14,735', Wiper up hole, PUW 30k 04:18 04:45 0.45 13,990 14,735 PROD1 DRILL WPRT P 13,990', Wiper in hole. 04:45 12:54 8.15 14,735 14,935 PROD1 DRILL DRLG P 14,735', OBD 1.5 bpm at 3553 psi, BHP 4090,WHP 327, IA 487,OA 63 12:54 13:54 1.00 14,935 13,020 PROD1 DRILL WPRT P 14,935',Wiper up hole, PUW 32k, slight 1k overpull at billet 13,935', couple passes in 5"liner to clean up. 13:54 14:06 0.20 13,020 13,060 PROD1 DRILL DLOG P Log K1 marker, +3.5'correction. 14:06 15:06 1.00 13,060 14,935 PROD1 DRILL WPRT P 13,060', Wiper in hole, clean down through billet 15:06 18:21 3.25 14,935 15,135 PROD1 DRILL DRLG P 14,935', OBD 1.5 bpm at 3702 psi, BHP 4073,WHP 304, IA 482, OA 61 Page 7 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:21 23:36 5.25 15,135 72 PROD1 DRILL TRIP T 15,135', TOOH for anchored billet, PUW 31k,overpull 4k at 14,179'and 14,146', 1k at billet 13,935', open EDC,two passes in 5"to clean up, TOOH. Choke plugged off,shut down pumps,close Orbit valve(2.2 fl oz recovered)bypass choke and jog to 530',TOOH, lots of aluminum/metal shavings across shaker. 23:36 00:00 0.40 72 0 PROD1 DRILL PULD T At surface,PJSM-LD BHA#5 09/09/2014 Out of target, Set anchored billet @ 13631, Drill by billet and drill ahead 00:00 01:30 1.50 0 0 PROD1 DRILL PULD T Continue L/D BHA#5, ****Note: SimOps replace saddle clamp on reel,and replace counter rollers on horses head. 01:30 02:00 0.50 73 PROD1 DRILL BOPE P Function Test BOPE equipment 02:00 04:00 2.00 0 73 PROD1 STK PULD T M/U Open hole anchored billet BHA# 5, Make up INJH to well, ****Note:SimOps pull choke apart to clear debris from well. ****Note: Open Orbit valve,992 psi WHP 04:00 07:30 3.50 73 13,040 PROD1 STK WPST T RIH,with Anchored billet BHA#6, 70fph slowing to 20 fph for jewelry. 07:30 07:45 0.25 13,040 13,058 PROD1 STK DLOG T 13040',Tie into the K1 marker correction of minus 6', PUW 30k 07:45 08:15 0.50 13,058 13,630 PROD1 STK TRIP T Continue RIH,set down at 13246' 3.1k, PUH to try again PUW 32k, set down again at 13259', PUH PUW 31k, RIH clean to setting depth 13630'. 08:15 08:30 0.25 13,630 13,100 PROD1 STK WPST T 13630', pressure up to set Anchored Billet sheared at 4450psi,set down 3k. 08:30 11:00 2.50 13,100 73 PROD1 STK TRIP T 13100',Open EDC, POOH 11:00 12:30 1.50 73 0 PROD1 STK PULD T PJSM-for L/D BOT setting tools BHA#6, "***Note:Function Orbit Valve closed recovered 2 oz of hydraulic fluid. 12:30 13:54 1.40 0 72 PROD1 STK PULD T PJSM-M/U kickoff/drilling BHA#7 ****Note: SimOps inspect saddle clamp on reel and service INJH ****Note: Function Orbit Valve open recovered 2oz of hydraulic fluid. 13:54 16:24 2.50 72 13,050 PROD1 STK TRIP T RIH with kickoff BHA#7 drilling assembly, Page 8 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:24 16:39 0.25 13,050 13,063 PROD1 STK DLOG T 13050',tie into the K1 marker correction of minus 4', PUW 29k BHP 3936,WHP 443, IA 98, OA 54 16:39 17:03 0.40 13,063 13,630 PROD1 STK TRIP T Continue RIH to bottom 17:03 18:27 1.40 13,630 13,633 PROD1 STK KOST T Dry tag TOB @ 13631.840', PUH Pump onlie @ 1.5 BPM @ 3506 PSI FS, Start time milling billet @ 13631' 18:27 18:45 0.30 13,633 13,638 PROD1 STK MILL T Speed up to 15-20 FPH 18:45 19:21 0.60 13,638 13,660 PROD1 DRILL DRLG T Drill ahead, 1.5 BPM @ 3510 PSI FS, BHP=3995 19:21 19:27 0.10 13,660 13,660 PROD1 DRILL WPRT T Wiper trip up past billet and dry drift, Clean pass up and down past billet, PUW=30K 19:27 22:15 2.80 13,660 13,763 PROD1 DRILL DRLG T 13660', Drill ahead, 1.5 BPM @ 3525 PSI FS, BHP=4000 22:15 22:27 0.20 13,763 13,763 PROD1 DRILL WPRT T BHA Wiper, PUW=30K 22:27 00:00 1.55 13,763 13,805 PROD1 DRILL DRLG T 13763', Drill ahead, 1.48 BPM @ 3525 PSI FS, BHP=4010 09/10/2014 Drill L1 Lateral to 14256 00:00 09:15 9.25 13,805 14,030 PROD1 DRILL DRLG T 13805', Drill Ahead, 1.48 BPM @ 3525 PSI FS, BHP=4010 09:15 10:15 1.00 14,030 14,030 PROD1 DRILL WPRT T 14030',Wiper up hole13220', PUW 32 10:15 12:30 2.25 14,030 14,067 PROD1 DRILL DRLG T 14030', BOBD 1.5bpm at 3596psi, BHP 4056,WHP 254, IA 417, OA 61 12:30 12:45 0.25 14,067 14,067 PROD1 DRILL WPRT T BHA wiper, PUW=33K 12:45 20:45 8.00 14,067 14,230 PROD1 DRILL DRLG T 14067', Drill ahead, 1.5 BPM @ 3578 PSI FS, BHP=4028 20:45 22:45 2.00 14,230 14,230 PROD1 DRILL WPRT T Wiper trip#3,pump 5 X 5 Sweeps Chase up through window to 13015', Slight overpull in 5"@ 13150'.Jog 5" liner waiting for bottoms up. Observed out density up.2 as material came to surface. No plugging.Tie into K1 for+5' correction. Clean trip back to bottom 22:45 00:00 1.25 14,230 14,256 PROD1 DRILL DRLG T 14230', Drill ahead, 1.5 BPM @ 3650 PSI FS, BHP=4050 09/11/2014 Drill L1 Lateral to 15129, Perform mud swap to 9.3PPG 00:00 03:00 3.00 14,256 14,290 PROD1 DRILL DRLG T 14256', Drill ahead 03:00 08:45 5.75 14,290 14,430 PROD1 DRILL DRLG T 14290', new 9.3PPG at bit, 1.5 BPM @ 3580 PSI FS, BHP=4032, System #2 8.9 PPG out at 1531'Drilled, .8% drill solids 08:45 10:15 1.50 14,430 14,430 PROD1 DRILL WPRT T 14430',Wiper up hole to 13660', PUW 30K 10:15 15:30 5.25 14,430 14,650 PROD1 DRILL DRLG T 14430', BOBD 1.5bpm at 3400psi, BHP 4063,WHP 275, IA 531, OA 60 ****Note: Orbit Valve 2300psi on the active side and 750psi on the non-active side. Page 9 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:30 1.00 14,650 14,650 PROD1 DRILL WPRT T 14650',Wiper up hole to 13670', PUW 29k 16:30 18:06 1.60 14,650 14,840 PROD1 DRILL DRLG T 14650', BOBD 1.5 bpm at 3550psi, BHP 4100,WHP 272, IA 559, OA 60 18:06 20:18 2.20 14,840 14,840 PROD1 DRILL WPRT T Wiper trip to window and 5"tubing jet, PUW=30K, Perform jog in 5".Tie into RA for+5.5, RBIH to drill 20:18 22:06 1.80 14,840 15,040 PROD1 DRILL DRLG T 14840', Drill, 1.48 BPM @ 3430 PSI FS, BHP=4060 22:06 23:06 1.00 15,040 15,040 PROD1 DRILL WPRT T Wiper trip to 14300, PUW=30K 23:06 00:00 0.90 15,040 15,129 PROD1 DRILL DRLG T 15040', Drill, 1.49 BPM @ 3480 PSI FS, BHP=4105 09/12/2014 Call L1 TD early @ 15841', Pump sweeps and jet 5"section.Trip out laying in liner running pill 00:00 01:36 1.60 15,129 15,240 PROD1 DRILL DRLG T 15129', Drill ahead, 1.49 BPM @ 3480 PSI FS 01:36 02:30 0.90 15,240 15,240 PROD1 DRILL WPRT P Wiper trip 14,300, PUW=31K, Off problem time at 15135' 02:30 06:00 3.50 15,240 15,440 PROD1 DRILL DRLG P 15240', Drill, 1.48 BPM @ 3560 PSI FS, BHP=4105 06:00 07:30 1.50 15,440 13,020 PROD1 DRILL WPRT P 15440',Wiper up hole for tie in and jet 5inch chasing sweep, PUW 31, 07:30 08:30 1.00 13,020 11,500 PROD1 DRILL WPRT P Perform jog below tubing tail, RBIH to 13140', Open EDC, bring both pumps on to 2.3bpm at 4250psi and jet liner and tubing up to 11500'. Aluminum and clay balls in bottoms up sample. 08:30 08:54 0.40 11,500 13,050 PROD1 DRILL WPRT P RBIH,pumping 1.9bpm at 3600psi, BHP 3554,WHP 35, IA 609, OA 59 08:54 09:09 0.25 13,050 13,068 PROD1 DRILL DLOG P 13050',Tie into the K1 marker correction of plus 11.5' 09:09 10:09 1.00 13,068 15,440 PROD1 DRILL WPRT P Continue wiper in hole. RIW 5k 10:09 13:09 3.00 15,440 15,640 PROD1 DRILL DRLG P 15440', BOBD 1.5bpm at 3450psi, BHP 4079,WHP 184, IA 562,OA 59 13:09 14:09 1.00 15,640 15,640 PROD1 DRILL WPRT P 15640',Wiper up hole to 15000'. PUW 31k 14:09 16:39 2.50 15,640 15,840 PROD1 DRILL DRLG P 15640', BOBD 1.5bpm at 3450psi, BHP 4182,WHP 217, IA 586, OA 60 16:39 18:39 2.00 15,840 13,020 PROD1 DRILL WPRT P 15840,TD L1 lateral,perform wiper to the 5 1/2,chasing 10x10 sweep. PUW 34K 18:39 19:15 0.60 13,020 13,180 PROD1 DRILL WPRT P Open EDC and make second recip of 5"at max pump rate 2.3 BPM 19:15 19:21 0.10 13,180 13,210 PROD1 DRILL DLOG P Close EDC and run through window, Log RA for+6.5'correction 19:21 20:39 1.30 13,210 15,841 PROD1 DRILL WPRT P RIH to confirm TD,Tag up© 15841, Clean trip to TD 20:39 00:00 3.35 15,841 3,650 PROD1 DRILL TRIP P Trip out of hole laying in 9.3 PPG beaded liner running pill,50BBIs, Paint EOP flags @ 13300&10600' 09/13/2014 Run L1 completion to 158441,TOL=13461, Start full BOPE Test.Witness waived by Jeff Jones,AOGCC 00:00 01:00 1.00 3,650 50 PROD1 DRILL TRIP P Trip out continued Page 10 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 50 0 PROD1 DRILL PULD P At surface,Close Orbit valve,bleed off well and monitor for flow, PJSM lay down BHA#7, R/U floor to run liner """"Note:Close Orbit Valve, 1060 psi WHP 02:30 03:30 1.00 0 0 COMPZ CASING SVRG T Position reel to swap out saddle bolts,Saddle bolts to flared to remove from saddle clamps. Change out reel saddle clamps 03:30 07:30 4.00 0 2,424 COMPZ CASING PUTB P PJSM, P/U BHA#8, Non ported bullnose, 74jts Slotted Tubing, , Liner top billet 07:30 08:30 1.00 2,424 2,424 COMPZ CASING PUTB P M/U BHI tools, and BOT GS. Strip down onto well,test quick test sub o-rings. 08:30 11:30 3.00 2,424 13,041 COMPZ CASING RUNL P RIH,with L1 liner completion with, BOT GS """"Note: Open Orbit Valve, 980 psi WHP 11:30 12:30 1.00 13,041 15,841 COMPZ CASING RUNL P Correct to the 10600'EOP flag-17.3' 12:30 12:45 0.25 15,841 15,841 COMPZ CASING RUNL P 15841', set down at 15683'and 15699', PUW 37k, Set liner on bottom at 15841'.bring pump and to release from liner 1.2bpm at 3000psi, PUW 29k 12:45 15:45 3.00 15,841 42 COMPZ CASING TRIP P POOH, close orbit valve with 1069 psi tubing pressure 15:45 16:30 0.75 42 0 COMPZ CASING PUTB P L/D BHA#8 16:30 19:30 3.00 0 0 PROD2 WHDBO RURD P Stab INJH,displace coil to fresh water, prep for BOP test,Crew change,valve check list, grease choke manifold, Service tree 19:30 00:00 4.50 0 0 PROD2 WHDBO BOPE P Full BOPE Test,Witnes waived by Jeff Jones,AOGCC 39/14/2014 Complete full BOPE test,M/U BHA#9 and kick off LTB @ 13458, Drill to 13947 00:00 05:00 5.00 0 0 PROD2 STK BOPE P Continue full BOPE Test,Witness waived by Jeff Jones,AOGCC 05:00 06:00 1.00 0 0 PROD2 STK CTOP P Stab on injector and roll fresh water out of coil to 9.3 PPG PowerPro 06:00 07:15 1.25 0 72 PROD2 STK PULD P PJSM, M/U, L1-01 Lateral BHA#9 07:15 10:45 3.50 72 13,040 PROD2 STK TRIP P RIH,with kickoff/drilling BHA#9 """"Note: Open Orbit valve,980 psi on well. 10:45 11:00 0.25 13,040 13,058 PROD2 STK DLOG P 13040',Tie into the K1 marker correction of minus 6.5'. 11:00 11:30 0.50 13,058 13,458 PROD2 STK TRIP P 13059', continue RIH,dry tag TOB at 13458', PUW 31k Page 11 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 14:00 2.50 13,458 13,485 PROD2 STK KOST P 13458', Start milling off of billet at 13457', 1.5bpm at 3600psi, BHP 4000,WHP 155 13460', Looks like we are kicked off. 14:00 14:15 0.25 13,485 13,485 PROD2 STK REAM P 13485', PUH to drift billet area clean, RBIH 14:15 18:09 3.90 13,485 13,660 PROD2 DRILL DRLG P 13485', BOBD 1.5bpm at 3480psi, BHP 3989,WHP 146, IA 268, OA 50 ****Note: New mud at the bit 13550' 18:09 19:39 1.50 13,660 13,660 PROD2 DRILL WPRT P Wiper trip up through 5"tubing, PUW=28K,Tie into RA for+2' correction 19:39 21:57 2.30 13,660 13,860 PROD2 DRILL DRLG P 13660', Drill, 1.56 BPM @ 3440 PSI FS, BHP=3985 21:57 22:39 0.70 13,860 13,860 PROD2 DRILL WPRT P 13860',Wipe to 13190, PUW=28K 22:39 00:00 1.35 13,860 13,947 PROD2 DRILL DRLG P 13860', Drill, 1.57 BPM @ 3450 PSI FS, BHP=3990 X9/15/2014 Drill L1-01 lateral 13947 to 15180, perform Mud swap 00:00 01:18 1.30 13,947 14,060 PROD2 DRILL DRLG P 13947', Drill 1.57 BPM @ 3450 PSI FS, BHP=3990 01:18 02:12 0.90 14,060 14,060 PROD2 DRILL WPRT P Wiper to 13,195, PUW=28K 02:12 04:30 2.30 14,060 14,260 PROD2 DRILL DRLG P 14060, Drill ahead, 1.56 BPM @ 3540 PSI FS, BHP=4020 04:30 05:30 1.00 14,260 14,260 PROD2 DRILL WPRT P Wiper trip up into 5"with 5 X 5 sweeps and tie in, PUW=29K 05:30 05:45 0.25 14,260 14,260 PROD2 DRILL DLOG P 13180',Tie into the RA marker correction of plus 4.5' 05:45 06:30 0.75 14,260 14,260 PROD2 DRILL WPRT P 13205',Wiper back in hole, 06:30 08:30 2.00 14,260 14,460 PROD2 DRILL DRLG P 14260', BOBD 1.5bpm at 3450psi, BHP 4000,WHP 219, IA 532, OA 53 08:30 09:30 1.00 14,460 14,460 PROD2 DRILL WPRT P 14460',Wiper up hole 13480', PUW 30 09:30 12:00 2.50 14,460 14,660 PROD2 DRILL DRLG P 14460', BOBD 1.5bpm at 3450psi, BHP 4035,WHP 215, IA 531,OA 53 12:00 13:00 1.00 14,660 14,660 PROD2 DRILL WPRT P 14660',Wiper up hole to 13499', PUW 28k 13:00 15:00 2.00 14,660 14,860 PROD2 DRILL DRLG P 14660', BOBD 1.5bpm at 3450psi, BHP 4082,WHP 180, IA 553, OA 52 15:00 16:30 1.50 14,860 14,860 PROD2 DRILL WPRT P 14860',Wiper up hole. PUW 31, Pull above whipstock and jet 5inch liner up to 13000'. 16:30 16:45 0.25 14,860 14,860 PROD2 DRILL DLOG P 13180',Tie into the RA marker correction of plus 6'. 16:45 18:00 1.25 14,860 14,860 PROD2 DRILL WPRT P 13201', Continue wiper in hole. RIW 8k 18:00 20:30 2.50 14,860 15,060 PROD2 DRILL DRLG P 14860', BOBD 1.5bpm at 3550psi, BHP 4026,WHP 189, IA 561, OA 52 20:30 22:00 1.50 15,060 15,060 PROD2 DRILL WPRT P 15060',Wiper up hole to 13560', PUW 29k RIW 5k 22:00 00:00 2.00 15,060 15,180 PROD2 DRILL DRLG P 15060', BOBD 1.5bpm at 3500psi, BHP 4034,WHP 110, IA 601,0A 62 ****Note: New mud at 15070' Page 12 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/16/2014 24 hr summary Drill L1-01 to called TD @ 15,650', pump 10 bbl to/hi vis sweep.TOOH,lay in 50 bbl beaded liner pill. Found damaged coil @ 1,000',TOOH.Start cutting 2,200'of coil. 00:00 01:24 1.40 15,180 15,260 PROD2 DRILL DRLG P 15180', Drill Ahead, 1.5bpm at 3500PSI FS, BHP=4034 01:24 02:06 0.70 15,260 15,260 PROD2 DRILL WPRT P Wiper to 13760', PUW=30K 02:06 05:41 3.59 15,260 15,460 PROD2 DRILL DRLG P 15260', Drill, 1.56 BPM @ 3640 PSI FS, BHP=4088 05:41 07:02 1.35 15,460 15,460 PROD2 DRILL WPRT P Wiper to 13172', PUW 31k 07:02 07:21 0.33 15,460 15,460 PROD2 DRILL DLOG P Jet into 5",Tie into RA tag, plus 9.5' correction 07:21 08:51 1.50 15,460 15,460 PROD2 DRILL DRLG P Drill ahead, GEO>90 degrees 08:51 12:27 3.60 15,460 15,650 PROD2 DRILL DRLG P 15460', Drill, 1.54 BPM @ 3800 PSI, BHP=4150 PSI 12:27 14:01 1.57 15,660 13,170 PROD2 DRILL WPRT P 15650,TD L1-01 lateral, perform wiper to the 5 1/2, chasing 10x10 sweep. PUW 31.5K 14:01 14:29 0.47 13,170 13,145 PROD2 DRILL WPRT P Open EDC and make second pass of 5"at max rate 2 BPM 14:29 14:34 0.09 13,145 13,135 PROD2 DRILL WPRT P Close EDC and run through window 14:34 14:41 0.13 13,135 13,206 PROD2 DRILL DLOG P Tie into RA tag, plus 4'correction 14:41 15:57 1.28 13,206 15,650 PROD2 DRILL WPRT P Tag bottom,confirm TD depth of 15650' 15:57 19:57 4.00 15,650 1,000 PROD2 DRILL DISP P POOH laying in beads, at 1,000' found damaged coil,take pictures of damaged coil send to town. Paint EOP flags @ 10400'and 12800'. 19:57 20:57 1.00 1,000 0 PROD2 DRILL DISP P Continue out of hole to surface,close Orbit valve,test valve,good test. Decision made from town to cut 2,200'coil. 20:57 21:27 0.50 0 0 PROD2 DRILL PULD P PJSM. LD BHA#9. Remove BHI upper QC. 21:27 23:56 2.49 0 0 COMPZ DRILL CTOP T Prep for pipe cutting operations. PJSM.Start cutting 2,200'coil. 09/17/2014 Finish cutting 2,200'of coil. Troubleshoot E-Line continuity issue, pump slack management. Rehead E-Line/coil connector and test. Run L1-01 liner assembly to set depth @ 15,650', release from liner. Displace well with seawater,start freeze protect with diesel,freeze protect in progress. 00:00 03:30 3.50 0 0 COMPZ CASING CTOP T Finish cutting coil,Cut 2200'of coil for fatigue management. 03:30 04:20 0.84 0 0 COMPZ CASING CTOP T PJSM. Test E-Line, unable to establish continuity,troubleshoot E-Line. Call-out rig electrican. 04:20 08:29 4.16 0 0 COMPZ CASING CTOP T E-line continuity good, inspecting injector head and investigating wear spot on coil. Ruled out mechanical errors:checked gripper blocks and chains. No debri in injector. Believe to be an operational error from a brief snubbing situation. Page 13 of 14 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 08:29 12:29 4.00 0 0 COMPZ CASING CTOP T Pump Slack, rehead E-line/coil connector, Pull test 35k, rehead UQC, E-line had bad flow sub, installed new flow stub,pressure test CTC to 4k 12:29 16:53 4.40 0 2,667 COMPZ CASING PUTB P PJSM, P/U BHA#10, Non ported bullnose,84jts Slotted Tubing, shorty deployment sleeve. 16:53 17:47 0.90 2,667 2,725 COMPZ CASING PULD P PJSM. MU BHA#10 17:47 21:17 3.50 2,725 15,650 COMPZ CASING RUNL P TIH w/L1-01 liner assembly,weight check above window 30K,continue in hole to set depth,tag bottom 15,650', PUW=31K, RBIH, stack 3K down, release from liner, PUW=25K, PUH reset counter to GS depth 12,968'. 21:17 23:17 2.00 15,650 6,060 COMPZ CASING DISP P Displace well to seawater while tripping 23:17 23:59 0.70 6,060 3,650 COMPZ WELLPF FRZP P PJSM. PT LRS surface equipment, start pumping diesel down coil for freeze protect,while POOH. 09/18/2014 Freeze protect with diesel from 2,500'. LD BHA#10. Set FMC BPV, ND BOP stack, secure wellhead, load with methanol. RDMO CDR2AC. 00:00 01:15 1.25 3,650 53 COMPZ CASING FRZP P Complete freeze protect from 2,500'. At surface, 1290 WHP, close Orbit valve, bleed off wellhead. 01:15 02:00 0.75 53 0 COMPZ CASING PULD P PJSM. LD BHA#10 02:00 03:15 1.25 0 0 DEMOB WHDBO MPSP P PJSM. PT FMC BPV lubricator, reopen Orbit valve. Set BPV, LD lubricator. 03:15 09:00 5.75 0 0 DEMOB WHDBO NUND P Flush and purge coil, blow down CT reel and rig lines to tiger tank. RD MP line and misc. lines in cellar. ND BOPE and secure,secure wellhead, load with methanol. 09:00 12:00 3.00 0 0 DEMOB WHDBO DMOB P Continue to prep rig for move to 2T-Pad-RIG RELEASE 12:00 Page 14 of 14 iii W Noloor z gzt ca 0 0_ 0 0 w tn 1 as w ce .Q a 1— >, _ Q (nz w co S _ a) — O � � > oa = a V L> _ . - NLO 4-1 L .0 J N E L L N ch Q O O QQM0 CO w, n V 0 � YY � � m 0 N. 1 Z a LIN F c,, v 3 iNil : m o .c CO ao 2 O O y C.. 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I!) 10 10 10 c0 10 CO N co- c0 t0 to N CO VE O N d d N rn 2A-t25 RECEIVED SEP 1 8 2014 Letter of Transmittal MIS AOGCC BAKER Date: DATA LOGGED September 17, 2014 O1 HUGHES K.BENDE To: From: Meredith Guhl Yosha Ragbirsingh/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): 2M-32L1PB1 2_4-6s q 2M-32L1PB2 2A 5 2M- L1 2.-4(%53 A 2M-32L1-01 2.'!-- (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 return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager1.� Yosha.Ragbirsingh@BakerHughes.com ` ./ r I 0 N X X ^T n v C E C = CDcn CD ED j -0 0 r1 3 —■ "'1 0 p N 0) 0 CD � _ opjE � •n n 0 °' -0 (1) C O 0 n m.- —•z- -0I, Ei curi ....• S ic - .5- • cp Z M su QD to CD 0 73 ,:,.. , ® M 33 > CID rn o � 0 ±G) li m 0 e- ni j 0 0 01 im doin In N e .t ,t oe = (e co cIL • CD co co c W W N C 'y 6 N ID rt. _ = L O 9 N = 3 O A N 0 C T N O (O 7 5 N O (n n 0 '' CO `° 3 v Dt ' Z n o ' N 7 0 f0 O .. O D ^' o o (°D0 'oco CO m 3 m 0 coco 5 C.) 3 'o O` N N N - C C O r co co W N co N N D Z C N W W W ! 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G A A A A A A A A A A A A '< 1 i 0 0 ii o Z O 3 co 1, D 0 00 o_ 1 0 i o' 00 G =3 i A 3 pro 214-2z pr-0 Z14 —I ZSS> Ferguson, Victoria L (DOA) From: Eller,J Gary <J.Gary.Eller@conocophillips.com> Sent: Wednesday,August 27, 2014 9:27 AM To: Ferguson,Victoria L(DOA) Cc: Ohlinger,James J;Venhaus, Dan E; Burke,Jason Subject RE:2M-32L1(PTD 214-125);2M-32L1-01(PTD 214-128) Attachments: 2M-32 TCR Sheet for WSakl5.pdf;W Sak 15 wellbore Schematic.pdf Follow Up Flag: Follow up Flag Status: Completed Victoria—Attached is the approved TCR worksheet for the close approach of 2M-32L1 to the P&A'd West Sak River State 15 well (PTD 179-99, API 50-103-20013). There is no HSE risk associated with a collision as CTD would encounter the well below the 7" cement retainer that was used to plug the perfs (see attached schematic). The only consequence is financial, which the TCR sheet assesses as a tolerable financial risk. -Gary From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent:Tuesday, August 26, 2014 4:28 PM To: Eller, J Gary Subject: [EXTERNAL]FW: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) From: Ferguson, Victoria L (DOA) Sent: Tuesday, August 26, 2014 1:48 PM To: Ohlinger, James J (James.J.Ohlinger@conocophillios.com) Subject: RE: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) Do you have more information on WSak 15 from the anti-collision report. What is the status of the well? Not clear where the wellbore trajectory is for this well. PTD#? Thanx, Victoria From: Ferguson, Victoria L(DOA) Sent: Tuesday, August 26, 2014 9:54 AM To: Ohlinger, James J (James.J.Ohlinger@conocophillips.com) Subject: FW: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) From: Ferguson, Victoria L(DOA) Sent: Tuesday, August 26, 2014 9:52 AM To:jason.burke@conocophillips.com Subject: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) Jason, Please provide a wellbore schematic for each of these PTDs. pro 214-115- 07-D 2 -1 zg Ferguson, Victoria L (DOA) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Thursday, August 28, 2014 10:02 AM To: Ferguson, Victoria L(DOA) Cc: Venhaus, Dan E; Burke, Jason Subject: Mud Weight& Formation Pressure at 2M-32 (PTDs 214-125 &214-128) Victoria-Thanks for getting those KRU 2M-32 drilling permits (214-125 &214-128)approved yesterday. Yesterday we got an updated static BHP on well 2M-32 which showed that the formation pressure has come down significantly over the last 2 months. On June 24 the well measured a static pressure of 3903 psi (12.2 ppg EMW)whereas on August 27 it measured 3678 psi (11.4 ppg EMW). That drop in pressure is no accident: we've been producing the well for the last couple of months in order to bring down the formation pressure in the area, and yesterday's BHP survey shows that we were successful. The drop in formation pressure does allow us to make some design changes in the drilling program that I wanted to make you aware of. The write-up for the drilling permits indicated that we would hold 12.5 ppg EMW at the window to maintain formation overbalance. We'd like to reduce that to a target EMW of 12.0 ppg held at the window. It's operationally a little easier and it reduces the chance of breaking down the formation and experiencing lost returns. We would not be looking to change our BOP test pressure of 4000 psi or the weight of our emergency kill weight fluid, and we'll still plan to use the new Baker Hughes deployment valve to isolate the formation while picking up slotted liner. But we will reduce our planned mud weight from 9.4 ppg to 8.9 ppg to bring that target pressure down to 12.0 ppg. And as is typical with our CTD managed pressure drilling techniques, if we encounter increasing formation pressure while drilling we can manage that with a combination of increased choke pressure or increased mud weight. Please let me know if you have any questions on this. Thanks again! J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 1 7...c:(3-1,- 77,2,z, n_, ,,,, _ ,__,_ 'rte ?-�- Wil/ 1 VW: r -z __ `_ - - --- 333 'IJest Se vc-HI, Aver uc Anchorage Alaska 99501 35/2 \`:�� N I:4 rl I1 917 779 lI z,i 3 D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-32L1-01 ConocoPhillips Alaska, Inc. Permit No: 214-128 Surface Location: 114' FSL, 96' FEL, SEC. 28, T11N, R8E, UM Bottomhole Location: 557' FNL, 1780' FEL, SEC. 8, T10N, R8E, UM Dear Mr. Venhaus: 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 Permit No. 192-104, API No. 50-103- 20186-00-00. 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 AOGCC 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 AOGCC 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 0 Daniel T. Seamount, Jr. '� Commissioner DATED this day of August, 2014. i w STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 19 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC la Type of Work 1 b Proposed Well Class Development-Oil Q• Service-Winj ❑ Single Zone EA lc Specify if well is proposed for: Drill ❑ • Lateral ❑✓ 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 I_I Blanket - U Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-180 . K12L.,_ 2M-32L1-01• 3 Address 6.Proposed Depth: 12. Field/Pool(s). P.O. Box 100360 Anchorage,AK 99510-0360 MD: 15750'' TVD: 6110' • Kuparuk River Field` 4a Location of Well(Governmental Section). 7.Property Designation(Lease Number) Surface. 114'FSL,96'FEL,Sec.28,T11N,R8E, UM ' ADL 25586,255901,Q5c6c1 Kuparuk River Oil Pool Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date 1930'FSL, 1387'FEL,Sec.5,T1ON, R8E,UM 2672,2676 9/1/2014 Total Depth' 9.Acres in Property: 43lt13 14 Distance to 557'FNL, 1780'FEL,Sec.8,T1ON, RO8E, UM 2500 7< 2,A Nearest Property 8500 4b.Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL: 146 feet 15 Distance to Nearest Well Open Surface:x- 487744 y- 5948986 Zone- 4• GL Elevation above MSL 105 feet to Same Pool 2M-34,1930 16.Deviated wells Kickoff depth 13375 ft. 17 Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle , 100.6° deg Downhole:4399 psig , Surface'3781 psig - 18 Casing Proram Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 3" 2.375" 4.7# L-80 ,ST-L 2750' 13000' 6037' 15750' 6110' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redd!and Re-Entry Operations) Total Depth MD(ft) Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft). Junk(measured) 13385' 6349' none 13295' 6214' none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 227 sx PFC 121' 121' Surface 4473' 9.625" 670 sx PFE,840 sx Cl G 4515' 2701' Intermediate 12948' 7" 150 sx Class G 12988' 6057' Production 728' 5" 75 sx Class G 13385' 6349' Perforation Depth MD(ft): Perforation Depth TVD(ft): 13172'-13197' 6192'-6210' _ 20 Attachments Property Plat ❑ BOP Sketch II Drilling Prograrr a Time v Depth Plot- Shallow Hazard Analysis [i Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requir ments Q 21.Verbal Approval. Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jason Bur{$@'a) -6097 Email Jason.Burke@cop.com Printed NamD. Ve us Title CTD Engineering Supervisor Signature Phone 263-4372 Date g - I sr'" Commission Use Only Permit to Drill API Number Permit Approval" M� See cover letter Number 02 1 y - '�a`, 50- 1 V3- ,ZQ g(4, - 1-00 I Date: x I.J 1 h II Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbedm thane,gas hydrates,or gas contained in shales Other: By p 1-e 5 71 fo 4 OG d p5 , Samples req'd. Yes ❑ No [V Mud log req'd. Yes❑ No Er H2S measures: Yes g No ❑ Directional svy req'd: Yes LTJ No❑ Spacing exception req'd: Yes ❑ No Lr I Inclination-only svy req'd: )Yes❑ No 21 e)litAPPROVED BY THE t�/ `� �J/' q- Form by CO MI i rl kiCAMILON Date: 2 ( T'Form 10-401(ReviselO/20l /Z���spermit is 91°I -r d of approval(20 AAC 25.005(g)) 0-r7/7 ConocoPhillips RECEIVED Alaska AUG 19 2014 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 13, 2014 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a two lateral well out of the Kuparuk well 2M-32 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in September 2014. The CTD objective will be to drill two laterals (2M-32L1 & 2M-32L1-01), targeting the A3 sand interval/This well will be classified as a development well. Attached to this application are the following documents: — Permit to Drill Application Form 10-401 for 2M-32L1 &2M-32L1-01 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, 411101PrAgllP ason :urke Coiled Tubing Drilling Engineer 907-231-4568 Kuparuk CTD Laterals NABOASALA A Mina .I jt -. &Wells 2M-32L1 & L1-01 �/I 1 Application for Permit to Drill Document 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 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 3 (Requirements of 20AAC 25.005(c)(6)) 3 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 AAC 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 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 5 Pressure Deployment of BHA 6 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. Attachments 7 Attachment 1: Directional Plans for 2M-32L1 & L1-01 7 Attachment 2: Current Well Schematic for 2M-32 7 Attachment 3: Proposed Well Schematic for 2M-32L1 &L1-01 7 Page 1 of 7 JRIGINAL 8/18/2014 PTu Application: 2M-32L1 & L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2M-32L1 & L1-01. All laterals will be classified as "Development- Oif'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 2M-32L1 & L1-01. 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 to 4000 psi. Using the maximum formation pressure in the area of 4399 psi in the 2M-35, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3781 psi. 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)) A static bottom hole pressure of 2M-32 in June 2014 indicated a reservoir pressure of 3903 psi or 12.2 ppg equivalent mud weight. The maximum down hole pressure in the 2M-32 pattern is at 2M-35 with 4399 psi. It is not expected that reservoir pressure as high as 2M-35 will be encountered while drilling the 2M-32 laterals because of faulting to the east. Using the 2M-35 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3781 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed on the 2M-32, so the drilling fluid will need to be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 2M-32 laterals will be high pressures in the fault blocks. Managed pressure drilling will be used to reduce this risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AA C 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 7 ORIGINAL 8/18/2014 PTD Application: 2M-32L1 & L1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Name MD MD TVDSS TVDSS Liner Details 2M-32L1 13,375' 16,050' 6,091' 6,126' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 2M-32L1-01 13,000' 15,750' 6,037' 6,110' 2%", 4.7#, L 80, ST-L slotted liner; ran into the 5" liner. Existing Casing/Liner Information Category OD Weight Grade Conn. Top MD Btm Top Btm Burst Collapse (PO) MD TVD TVD psi psi Conductor 16" 62.50 H-40 Welded 42' 121' 0' 121' 1640 630 Surface 9-5/8" 47 L-80 AB-MOD 41.5' 4,514' 0' 2,701' 6870 4760 Casing 7" 26 J-55 BTC 40' 12,987' 0' 6,057' 4980 4330 Liner 5" 18 L-80 LTC 12,657' 13,385 5,683' 6,349' 10140 10500 Tubing 31/2" 9.3 L-80 EUE 39' 12,562' 0' 5,767' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not 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 Power-Pro mud (9.4 ppg) - Drilling operations: Chloride-based Power-Pro mud (9.4 ppg)/This mud weight will not hydrostatically overbalance the reservoir pressure; we will maintain over balance conditions using MPD practices described below. - Completion operations: 2M-32 contains a new style deployment valve. This valve will allow the deployment of tool strings and liner without pumping kill weight fluid. However, in the case the valve will not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 13.0 ppg K-Formate completion fluid in order to provide formation over-balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes (-282 bbl) of at least 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. Page 3 of 7 CflIGINAL 8/18/2014 PT. Application: 2M-32L1 & L1-01 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 an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of the minimum of 12.5 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and expected draw down reservoir pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. L(S2 1y ) Pressure at the 2M-32 Window(13,160' MD, 6183' TVD) U PD Pumps On (1.5 bpm) e, Pumps Off � A-sand Formation Pressure (12.2 ppg) 3922 psi 1 3922 psi Mud Hydrostatic (9.4 ppg) 3022 psi 3022 psi _ Annular friction (i.e. ECD, 0.075 psi/ft) 987 psi 0 psi Mud + ECD Combined 4009 psi 3022 psi (no choke pressure) (overbalanced (underbalanced —87 psi) —900 psi) Target BHP at Window(12.5 ppg) 4019 psi 1I-360 4019 psi Choke Pressure Required to Maintain 10 psi �ti' 997 psi Target BHP rAC 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 AA C 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AA C 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)) Page 4 of 7 ORIGINAL 8/18/2014 PTL, Application: 2M-32L1 & L1-01 Summary of Operations Background Well 2M-32 is a Kuparuk A-sand development well equipped with 31/2"tubing and a 5"liner. Two laterals from well 2M-32 will be drilled to the south side of parent well 2M-32 to access reserves in an adjacent fault block. These laterals will target the A3 sand. A mechanical whip-stock will be placed in the 5" liner at the planned kickoff point. The 2M-32L1 lateral will exit through the 5"liner at 13160' MD and all subsequent laterals will be drilled off of this lateral. The laterals will be completed with 2-%" slotted liner. The final liner will be run with the top located inside the 31/2"tubing at 13,000' MD. Pre-CTD Work 1. RU slickline—Dummy off GLM and obtain a SBHP 2. RU E-line—Set 3.5"x 5"whip-stock at 13,160'. 3. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2M-32L1 Lateral(A3 sand - South) i. Mill 2.80"window at 13160' MD ii. Drill 2.74"x 3.0"bi-center lateral to TD of 16050' MD iii. Run 2%" slotted liner with an aluminum billet from TD up to 13375' MD 3. 2M-32L1-01 Lateral (A3 sand-South) i. Kick off of the aluminum billet at 13375' MD ii. Drill 2.74"x 3.0" bi-center lateral to TD of 15750' MD iii. Run 2%" slotted liner into the tubing tail at 13000' MD 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pu11 BPV 2. Obtain static BHP. Install GLV. 3. Turn over to production Page 5 of 7 0 . 1GINAL 8/18/2014 PTk Application: 2M-32L1 & L1-01 Pressure D ployment of BHA The planned ! ottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. 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 slick-line lubricator can be used. This pressure control equipment listed 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. - 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 observed, only in reverse. Liner Running - The 2M-32 has a new down hole deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalancing fluid (13.0 ppg K- Formate) prior to running liner. 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%" rams will 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. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plan - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Page 6 of 7 0 I G I N A L 8/18/2014 PTL, Application: 2M-32L1 & L1-01 - MWD directional, resistivity, and gamma ray will be run over the entire openhole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance _ 2M-32L1 8770' 2M-32L1-01 8500' - Distance to Nearest Well within Pool (heel measured to offset well) Lateral Name Distance Well 2M-32L1 2600' 2M-34 2M-32L1-01 1930' 2M-34 16. Attachments Attachment 1: Directional Plans for 2M-32L1 & L9-01 Attachment 2: Current Well Schematic for 2M-32 Attachment 3: Proposed Well Schematic for 2M-32L1 & L1-01 Page 7 of 7 ORIGINAL 8/18/2014 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-32 2M-32L1-01 Plan: 2M-32L1-01_wp04 Standard Planning Report 12 August, 2014 r' 1 BAKER HUGHES ORIGINAL .- ri_ ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2M-32 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site: Kuparuk 2M Pad North Reference: True Well: 2M-32 Survey Calculation Method: Minimum Curvature Wellbore: 2M-32L1-01 Design: 2 M-32 L 1-01_wp04 Project Kuparuk River Unit,North Slope Alaska,United States 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 2M Pad Site Position: Northing: 5,948,985.89 usft Latitude: 70°16'18.578 N From: Map Easting: 487,859.45 usft Longitude: 150°5 53.484 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.09° Well 2M-32 Well Position +N/-S 0.00 usft Northing: 5,948,986.10 usft Latitude: 70°16'18.579 N +E/-W 0.00 usft Easting: 487,744.38 usft Longitude: 150°5'56.834 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.10 usft Wellbore 2M-32L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BG G M2014 11/1/2014 18.98 80.84 57,564 Design 2M-32L1-01_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 13,375.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (") -105.10 0.00 0.00 211.79 8/12/2014 5:55:25PM Page 2 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2M-32 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-32:105.1+40.9 @ 146.Oousft(2M-32) Site: Kuparuk 2M Pad North Reference: True Well: 2M-32 Survey Calculation Method: Minimum Curvature Wellbore: 2M-32L1-01 Design: 2M-32L1-01_wp04 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 13,375.00 92.93 173.26 6,090.60 -8,909.34 -6,642.10 0.00 0.00 0.00 0.00 13,485.00 100.63 173.26 6,077.62 -9,017.74 -6,629.29 7.00 7.00 0.00 0.00 13,635.00 99.54 183.87 6,051.27 -9,165.15 -6,625.62 7.00 -0.73 7.07 95.00 13,755.00 94.09 190.31 6,037.02 -9,283.27 -6,640.35 7.00 -4.54 5.37 130.00 13,855.00 87.51 192.70 6,035.61 -9,381.19 -6,660.28 7.00 -6.58 2.39 160.00 14,005.00 84.85 182.52 6,045.63 -9,529.33 -6,680.09 7.00 -1.78 -6.79 255.00 14,105.00 89.81 177.58 6,050.28 -9,629.16 -6,680.17 7.00 4.96 -4.94 315.00 14,205.00 89.81 184.58 6,050.61 -9,729.08 -6,682.05 7.00 0.00 7.00 90.00 14,305.00 86.97 178.18 6,053.41 -9,828.95 -6,684.46 7.00 -2.84 -6.40 246.00 14,405.00 83.50 172.08 6,061.72 -9,928.18 -6,676.01 7.00 -3.48 -6.10 240.00 14,555.00 90.29 180.10 6,069.86 -10,077.40 -6,665.85 7.00 4.53 5.35 50.00 14,655.00 92.45 186.77 6,067.47 -10,177.13 -6,671.83 7.00 2.16 6.66 72.00 14,755.00 90.04 193.34 6,065.30 -10,275.51 -6,689.28 7.00 -2.40 6.58 110.00 14,955.00 87.63 207.14 6,069.38 -10,462.66 -6,758.27 7.00 -1.20 6.90 100.00 15,255.00 87.79 186.12 6,081.50 -10,748.28 -6,843.57 7.00 0.05 -7.01 270.00 15,485.00 86.35 202.18 6,093.33 -10,970.27 -6,899.51 7.00 -0.62 6.98 95.50 15,750.00 86.54 183.59 6,109.90 -11,226.97 -6,958.22 7.00 0.07 -7.01 270.00 8/12/2014 5.55:25PM Page 3 COMPASS 5000.1 Build 61 O1G1NAL Fr ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2M-32 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site: Kuparuk 2M Pad North Reference: True Well: 2M-32 Survey Calculation Method: Minimum Curvature Wellbore: 2M-32L1-01 Design: 2M-32L1-01_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 13,375.00 92.93 173.26 6,090.60 -8,909.34 -6,642.10 11,071.91 0.00 0.00 5,940,088.47 481,088.45 TIP/KOP 13,400.00 94.68 173.26 6,088.94 -8,934.11 -6,639.17 11,091.42 7.00 0.00 5,940,063.70 481,091.34 13,485.00 100.63 173.26 6,077.62 -9,017.74 -6,629.29 11,157.29 7.00 0.00 5,939,980.07 481,101.08 Start?dls 13,500.00 100.54 174.32 6,074.86 -9,032.40 -6,627.69 11,168.91 7.00 95.00 5,939,965.41 481,102.65 13,600.00 99.83 181.40 6,057.16 -9,130.69 -6,624.03 11,250.53 7.00 95.20 5,939,867.12 481,106.15 13,635.00 99.54 183.87 6,051.27 -9,165.15 -6,625.62 11,280.65 7.00 96.45 5,939,832.67 481,104.51 3 13,700.00 96.60 187.38 6,042.14 -9,229.18 -6,631.93 11,338.40 7.00 130.00 5,939,768.66 481,098.10 13,755.00 94.09 190.31 6,037.02 -9,283.27 -6,640.35 11,388.82 7.00 130.49 5,939,714.58 481,089.59 4 13,800.00 91.13 191.39 6,034.97 -9,327.42 -6,648.81 11,430.80 7.00 160.00 5,939,670.45 481,081.06 13,855.00 87.51 192.70 6,035.61 -9,381.19 -6,660.28 11,482.55 7.00 160.05 5,939,616.70 481,069.50 5 13,900.00 86.70 189.65 6,037.88 -9,425.28 -6,668.99 11,524.61 7.00 -105.00 5,939,572.63 481,060.72 14,000.00 84.94 182.86 6,045.18 -9,524.36 -6,679.86 11,614.55 7.00 -104.85 5,939,473.59 481,049.69 14,005.00 84.85 182.52 6,045.63 -9,529.33 -6,680.09 11,618.90 7.00 -104.35 5,939,468.61 481,049.44 6 14,100.00 89.56 177.82 6,050.25 -9,624.16 -6,680.37 11,699.66 7.00 -45.00 5,939,373.79 481,049.01 14,105.00 89.81 177.58 6,050.28 -9,629.16 -6,680.17 11,703.80 7.00 -44.77 5,939,368.79 481,049.20 7 14,200.00 89.81 184.23 6,050.59 -9,724.09 -6,681.67 11,785.28 7.00 90.00 5,939,273.87 481,047.55 14,205.00 89.81 184.58 6,050.61 -9,729.08 -6,682.05 11,789.72 7.00 89.98 5,939,268.89 481,047.16 8 14,300.00 87.12 178.50 6,053.15 -9,823.96 -6,684.60 11,871.71 7.00 -114.00 5,939,174.02 481,044.46 14,305.00 86.97 178.18 6,053.41 -9,828.95 -6,684.46 11,875.87 7.00 -113.84 5,939,169.03 481,044.59 9 14,400.00 83.67 172.39 6,061.16 -9,923.26 -6,676.68 11,951.94 7.00 -120.00 5,939,074.72 481,052.21 14,405.00 83.50 172.08 6,061.72 -9,928.18 -6,676.01 11,955.77 7.00 -119.53 5,939,069.79 481,052.88 10 14,500.00 87.79 177.17 6,068.94 -10,022.44 -6,667.16 12,031.22 7.00 50.00 5,938,975.53 481,061.58 14,555.00 90.29 180.10 6,069.86 -10,077.40 -6,665.85 12,077.26 7.00 49.61 5,938,920.57 481,062.80 11 14,600.00 91.26 183.10 6,069.25 -10,122.38 -6,667.11 12,116.15 7.00 72.00 5,938,875.60 481,061.46 14,655.00 92.45 186.77 6,067.47 -10,177.13 -6,671.83 12,165.18 7.00 72.04 5,938,820.86 481,056.65 12 14,700.00 91.37 189.73 6,065.97 -10,221.64 -6,678.28 12,206.40 7.00 110.00 5,938,776.37 481,050.13 14,755.00 90.04 193.34 6,065.30 -10,275.51 -6,689.28 12,257.99 7.00 110.10 5,938,722.52 481,039.05 13 14,800.00 89.49 196.44 6,065.48 -10,319.00 -6,700.84 12,301.04 7.00 100.00 5,938,679.06 481,027.41 14,900.00 88.29 203.34 6,067.42 -10,412.95 -6,734.84 12,398.81 7.00 99.99 5,938,585.17 480,993.27 14,955.00 87.63 207.14 6,069.38 -10,462.66 -6,758.27 12,453.41 7.00 99.85 5,938,535.50 480,969.76 14 15,000.00 87.64 203.98 6,071.24 -10,503.22 -6,777.67 12,498.10 7.00 -90.00 5,938,494.98 480,950.30 15,100.00 87.67 196.98 6,075.34 -10,596.76 -6,812.60 12,596.01 7.00 -89.87 5,938,401.50 480,915.21 15,200.00 87.74 189.97 6,079.36 -10,693.87 -6,835.87 12,690.81 7.00 -89.58 5,938,304.44 480,891.78 15,255.00 87.79 186.12 6,081.50 -10,748.28 -6,843.57 12,741.11 7.00 -89.30 5,938,250.05 480,884.01 15 15,300.00 87.49 189.26 6,083.36 -10,792.83 -6,849.58 12,782.15 7.00 95.50 5,938,205.52 480,877.92 15,400.00 86.86 196.24 6,088.29 -10,890.18 -6,871.61 12,876.50 7.00 95.37 5,938,108.21 480,855.74 15,485.00 86.35 202.18 6,093.33 -10,970.27 -6,899.51 12,959.28 7.00 95.03 5,938,028.17 480,827.71 8/12/2014 5:55:25PM Page 4 COMPASS 5000.1 Build 61 ORIGINAL y Er ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2M-32 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site: Kuparuk 2M Pad North Reference: True Well: 2M-32 Survey Calculation Method: Minimum Curvature Wellbore: 2M-32L1-01 Design: 2M-32L1-01_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (0) (°) (usft) (usft) (usft) (usft) (°/100usft) (0) (usft) (usft) 16 15,500.00 86.35 201.13 6,094.29 -10,984.19 -6,905.03 12,974.01 7.00 -90.00 5,938,014.27 480,822.16 15,600.00 86.39 194.11 6,100.63 -11,079.25 -6,935.22 13,070.71 7.00 -89.93 5,937,919.27 480,791.82 15,700.00 86.48 187.10 6,106.86 -11,177.29 -6,953.57 13,163.72 7.00 -89.49 5,937,821.27 480,773.31 15,750.00 86.54 183.59 6,109.90 -11,226.97 -6,958.22 13,208.39 7.00 -89.05 5,937,771.60 480,768.58 Planned TD at 15750.00 8/12/2014 5:55:25PM Page 5 COMPASS 5000.1 Build 61 ORIGINAL IF/ ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2M-32 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site: Kuparuk 2M Pad North Reference: True Well: 2M-32 Survey Calculation Method: Minimum Curvature Wellbore: 2M-32L1-01 Design: 2M-32L1-01_wp04 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2M-32L1-01_T5 0.00 0.00 6,105.00 -9,530.861,133,207.77 5,937,611.00 1,620,822.00 70°0'52.704 N 141°1'7.373 W -plan misses target center by 1139831.87usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Point 2M-32L1-01_Fault3_V 0.00 0.00 6,097.00 -9,418.821,133,225.59 5,937,723.00 1,620,840.00 70°0'53.766 N 141°1'6.389 W -plan misses target center by 1139849.66usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Polygon Point 1 6,097.00 0.00 0.00 5,937,723.00 1,620,840.00 Point 2 6,097.00 1.00 1.00 5,937,721.74 1,620,840.64 2M-32L1_Faultl 0.00 0.00 0.00 -7,805.541,133,909.03 5,939,335.00 1,621,526.00 70°1'8.437 N 14V 0'40.097 W -plan misses target center by 1140549.91 usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Rectangle(sides W506.00 H1.00 D0.00) 2M-32L1-01_T2 0.00 0.00 6,045.00 -7,907.271,133,467.15 5,939,234.00 1,621,084.00 70°1'8.094 N 141°0'53.081 W -plan misses target center by 1140091.84usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Point 2M-32L1-01_Fault4 0.00 0.00 0.00 -9,534.871,133,196.77 5,937,607.00 1,620,811.00 70°0'52.681 N 141°1'7.702 W -plan misses target center by 1139836.97usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Rectangle(sides W485.00 H1.00 D0.00) 2M-32L1-01_Fault3 0.00 0.00 0.00 -9,418.821,133,225.59 5,937,723.00 1,620,840.00 70°0'53.766 N 141°1'6.389 W -plan misses target center by 1139865.75usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Rectangle(sides W735.00 Ii1.00 D0.00) 2M-32L1-01 Faultl 0.00 0.00 0.00 -7,928.271,133,465.19 5,939,213.00 1,621,082.00 70°1'7.893 N 141°0'53.226 W -plan misses target center by 1140105.94usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Rectangle(sides W745.00 H1.00 D0.00) 2M-32L1-01_Faultl_V 0.00 0.00 6,046.00 -7,928.271,133,465.19 5,939,213.00 1,621,082.00 70°1'7.893 N 14V 0'53.226 W -plan misses target center by 1140089.85usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Polygon Point 1 6,046.00 0.00 0.00 5,939,213.00 1,621,082.00 Point2 6,046.00 1.00 1.00 5,939,211.96 1,621,082.96 2M-32L1-01_Polygon 0.00 0.00 0.00 -7,046.601,133,208.72 5,940,095.00 1,620,827.00 70°1'16.830 N 141°0'56.747 W -plan misses target center by 1139850.75usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Polygon Point 1 0.00 0.00 0.00 5,940,095.00 1,620,827.00 Point2 0.00 -1,499.59 -260.51 5,938,595.99 1,620,564.07 Point 3 0.00 -2,169.01 -469.41 5,937,926.97 1,620,354.11 Point4 0.00 -2,346.85 -366.10 5,937,748.98 1,620,457.12 Points 0.00 -2,795.94 205.72 5,937,299.01 1,621,028.15 Point6 0.00 -2,069.67 321.51 5,938,025.02 1,621,145.11 Point7 0.00 -1,043.21 535.81 5,939,051.02 1,621,361.06 Point 8 0.00 -452.78 754.84 5,939,641.04 1,621,581.03 Point9 0.00 -91.58 852.24 5,940,002.04 1,621,679.00 Point 10 0.00 0.00 0.00 5,940,095.00 1,620,827.00 2M-32L1-01_Fault2 0.00 0.00 0.00 -8,326.311,133,469.83 5,938,815.00 1,621,086.00 70°1'4.020 N 141°0'54.793 W -plan misses target center by 1140110.24usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Rectangle(sides W735.00 H1.00 D0.00) 2M-32L1-01_T3 0.00 0.00 6,061.00 -8,302.301,133,470.80 5,938,839.00 1,621,087.00 70°1'4.252 N 14V 0'54.663 W -plan misses target center by 1140095.13usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Point 2M-32L1-01_T1 0.00 0.00 6,035.00 -7,720.201,133,495.85 5,939,421.00 1,621,113.00 70°1'9.869 N 14V 0'51.467 W -plan misses target center by 1140120.75usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Point 2M-32L1-01_T4 0.00 0.00 6,097.00 -9,421.801,133,232.59 5,937,720.00 1,620,847.00 70°0'53.727 N 141°1'6.203 W -plan misses target center by 1139856.66usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) 8/12/2014 5:55:25PM Page 6 COMPASS 5000.1 Build 61 ORIMIAL ret- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2M-32 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site: Kuparuk 2M Pad North Reference: True Well: 2M-32 Survey Calculation Method: Minimum Curvature Wellbore: 2M-32L1-01 Design: 2M-32L1-01_wp04 -Point 2M-32L1-01_T6 0.00 0.00 6,110.00 -9,619.901,133,186.91 5,937,522.00 1,620,801.00 70°0'51.869 N 141°1'8.345 W -plan misses target center by 1139811.05usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Point 2M-32L1_Polygon 0.00 0.00 0.00 -6,996.031,133,554.68 5,940,145.00 1,621,173.00 70°1'16.816 N 141°0'46.705 W -plan misses target center by 1140196.79usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Polygon Point 1 0.00 0.00 0.00 5,940,145.00 1,621,173.00 Point2 0.00 -541.43 -224.11 5,939,603.99 1,620,948.03 Point3 0.00 -1,072.64 277.83 5,939,072.02 1,621,449.06 Point4 0.00 -2,781.36 -46.33 5,937,364.00 1,621,122.15 Point5 0.00 -3,056.48 496.18 5,937,088.02 1,621,664.15 Point6 0.00 -1,184.36 1,045.09 5,938,959.06 1,622,216.06 Point? 0.00 0.00 0.00 5,940,145.00 1,621,173.00 2M-32L1-01_Fault2_V 0.00 0.00 6,062.00 -8,326.31 1,133,469.83 5,938,815.00 1,621,086.00 70°1'4.020 N 141°0'54.793 W -plan misses target center by 1140094.15usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Polygon Point 1 6,062.00 0.00 0.00 5,938,815.00 1,621,086.00 Point2 6,062.00 1.00 1.00 5,938,814.15 1,621,087.13 2M-32L1-01_Fault4_V 0.00 0.00 6,105.00 -9,534.871,133,196.77 5,937,607.00 1,620,811.00 70°0'52.681 N 141°1'7.702 W -plan misses target center by 1139820.88usft at 13600.00usft MD(6057.16 TVD,-9130.69 N,-6624.03 E) -Polygon Point 1 6,105.00 0.00 0.00 5,937,607.00 1,620,811.00 Point2 6,105.00 1.00 1.00 5,937,605.85 1,620,811.83 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 15,750.00 6,109.90 2-3/8" 2.375 3 000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 13,375.00 6,090.60 -8,909.34 -6,642.10 TIP/KOP 13,485.00 6,077.62 -9,017.74 -6,629.29 Start 7 dls 13,635.00 6,051.27 -9,165.15 -6,625.62 3 13,755.00 6,037.02 -9,283.27 -6,640.35 4 13,855.00 6,035.61 -9,381.19 -6,660.28 5 14,005.00 6,045.63 -9,529.33 -6,680.09 6 14,105.00 6,050.28 -9,629.16 -6,680.17 7 14,205.00 6,050.61 -9,729.08 -6,682.05 8 14,305.00 6,053.41 -9,828.95 -6,684.46 9 14,405.00 6,061.72 -9,928.18 -6,676.01 10 14,555.00 6,069.86 -10,077.40 -6,665.85 11 14,655.00 6,067.47 -10,177.13 -6,671.83 12 14,755.00 6,065.30 -10,275.51 -6,689.28 13 14,955.00 6,069.38 -10,462.66 -6,758.27 14 15,255.00 6,081.50 -10,748.28 -6,843.57 15 15,485.00 6,093.33 -10,970.27 -6,899.51 16 15,750.00 6,109.90 -11,226.97 -6,958.22 Planned TD at 15750.00 8/12/2014 5:55:25PM Page 7 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2M Pad 2M-32 2M-32L1-01 2M-32L1-01_wp04 Travelling Cylinder Report 11 August, 2014 BAKER HUGHES ORIGINAL I/. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.O0usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01_wp04 Offset TVD Reference: Offset Datum Reference 2M-32L1-01_wp04 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 13,375.00 to 15,750.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,770.91 usft Error Surface: Elliptical Conic Survey Tool Program Date 8/11/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 13,375-00 15,750.00 2M-32L1-01_wp04(2M-32L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ("I (") 15,750 00 6,255.90 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 (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 2M Pad 2M-32-2M-32L1-2M-32L1_wp07 13,375.00 13,375.00 0.00 10.21 -7.46 FAIL-Minor 1/10 2M-34-2M-34-2M-34 13,755.00 14,325.00 1,231.78 410.13 874.43 Pass-Major Risk Kuparuk W.Sak W SAK 15-W SAK 15-W SAK 15 13,494.54 5,325.00 933.20 1.55 932.98 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 2 of 9 COMPASS 5000.1 Build 61 ~ORIGINAL • ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2M Pad- 2M-32-2M-32L1-2M-32L1_wp07 Offset Site Error: 0.00 usft Survey Program: 50-GYD-CT-CMS,12600-OCT-MS,13157-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft 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 +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°I (usft) (usft) (usft) (usft) (usft) (usft) 13,375.00 6,236.59 13,375.00 6,236.59 0.00 72.23 173.26 -8,909.34 -6,642.10 2-11/16 0.00 10.21 -7.46 FAIL-Moor 1/10,CC,ES,SF 13,399.83 6,234.95 13,400.00 8,235.41 3.38 72.24 72.64 -8,933.70 -6,636.76 2-11/16 2.49 10.21 -3.21 FAIL-Minor 1/10 13,423.99 6,232.63 13,425.00 6,234.39 3.41 72.25 71.60 -8,957.01 -6,627.81 2-11/16 8.77 10.07 3.16 Pass-Minor 1/10 13,447.81 6,229.64 13,450.00 6,233.47 3.42 72.25 69.35 -8,980.00 -6,618.04 2-11/16 16.07 9.94 10.71 Pass-Minor 1/10 13,471.27 6,226.04 13,475.00 6,232.64 3.42 72.26 67.24 -9,002.69 -6,607.57 2-11/16 24.28 9.82 19.14 Pass-Minor 1/10 13,494.06 6,221.95 13,500.00 6,231.91 3.42 72.27 66.25 -9,025.05 -6,596.41 2-11/16 33.44 9.83 28.40 Pass-Minor 1/10 13,515.86 6,217.97 13,525.00 6,231.28 3.43 72.27 67.45 -9,047.07 -6,584.58 2-11/16 43.80 10.03 38.63 Pass-Minor 1/10 13,536.85 6,214.20 13,550.00 6,230.74 3.43 72.28 69.25 -9,068.72 -6,572.09 2.11/18 55.37 10.22 49.99 Pass-Minor 1/10 13,556.98 6,210.63 13,575.00 6,230.30 3.44 72.29 71.29 -9,089.98 -6,558.95 2.11/18 68.09 10.40 62.46 Pass-Minor 1/10 13,576.17 6,207.27 13,600.00 6,229.96 3.44 72.30 73.38 -9,110.83 -6,545.17 2-11/16 81.92 10.58 76.02 Pass-Minor 1/10 13,594.40 6,204.12 13,625.00 8,229.72 3.45 72.30 75.43 -9,131.26 -6,530.77 2-11/16 96.79 10.75 90.84 Pass-Minor 1/10 13,611.65 6,201.18 13,650.00 8,229.57 3.46 72.31 77.41 -9,151.24 -6,515.75 2-11/16 112.66 10.91 106.25 Pass-Minor 1/10 13,627.88 6,198.46 13,675.00 6,229.52 3.48 72.31 79.28 -9,170.76 -6,500.13 2-11/16 129.46 11.05 122.82 Pass-Minor 1/10 13,643.56 6,195.88 13,700.00 6,229.58 3.59 72.32 80.92 -9,189.80 -6,483.93 2-11/16 147.12 11.20 140.28 Pass-Minor 1/10 13,658.69 6,193.56 13,725.00 6,229.81 3.78 72.32 82.36 -9,208.35 -6,467.17 2-11/16 165.53 11.35 158.50 Pass-Minor 1/10 13,672.92 6,191.55 13,750.00 6,230.20 3.97 72.33 83.72 -9,226.39 -6,449.87 2-11/16 184.63 11.49 177.43 Pass-Minor 1/10 13,686.23 6,189.80 13,775.00 6,230.77 4.15 72.33 84.98 -9,243.90 -6,432.04 2-11/16 204.38 11.61 197.02 Pass-Minor 1/10 13,700.00 6,188.14 13,800.00 6,231.51 4.33 72.33 86.22 -9,260.88 -6,413.70 2-11/16 224.74 11.73 217.23 Pass-Minor 1/10 13,710.17 6,187.02 13,825.00 6,232.41 4.48 72.33 87.21 -9,27729 -6,394.86 2-11/16 245.66 11.82 238.02 Pass-Minor 1/10 13,720.82 6,185.92 13,850.00 8,233.49 4.63 72.33 88.18 -9,293.13 -6,375.55 2-11/16 267.12 11.92 259.35 Pass-Minor 1/10 13,730.81 6,184.99 13,875.00 8,234.74 4.77 72.33 89.06 -9,308.39 -6,355.79 2-11/18 289.05 11.99 281.18 Pass-Minor 1/10 13,739.73 6,184.20 13,900.00 8,236.10 4.90 72.33 89.87 -9,32322 -6,335.71 2-11/16 311.33 12.07 303.36 Pass-Minor 1/10 13,750.00 6,183.38 13,925.00 6,237.32 5.05 72.34 90.72 -9,338.52 -6,315.98 2-11/16 333.42 12.14 325.35 Pass-Minor 1/10 13,759.17 6,182.73 13,950.00 8,238.37 5.18 72.34 91.38 -9,354.41 -6,296.71 2-11/16 355.23 1220 347.08 Pass-Minor 1/10 13,770.83 6,182.03 13,975.00 6,239.25 5.34 72.34 91.94 -9,370.88 -6,277.92 2-11/16 378.72 12.27 368.47 Pass-Minor 1/10 13,782.93 6,18107 14,000.00 6,239.95 5.51 72.34 92.52 -9,387.89 -6,259.62 2-11/16 397.85 12.34 389.52 Pass-Minor 1/10 13,795.44 6,18107 14,025.00 6,240.48 5.68 72.34 93.12 -9,405.45 -6,241.83 2-11/16 418.61 12.40 410.19 Pass-Minor 1/10 13,808.33 6,180.84 14,050.00 6,240.83 5.86 72.35 93.73 -9,423.53 -6,224.57 2-11/16 439.00 12.46 430.47 Pass-Minor 1/10 13,821.58 6,180.81 14,075.00 6,241.00 6.04 72.35 94.37 -9,442.11 -6,207.85 2-11/16 459.00 12.52 450.37 Pass-Minor 1/10 13,835.01 6,180.98 14,100.00 6,241.02 622 72.36 95.02 -9,461.05 -6,191.52 2-11/16 478.74 12.58 470.00 Pass-Minor 1/10 13,850.00 8,181.41 14,125.00 6,241.03 6.42 72.36 95.70 -9,479.57 -6,174.74 2-11/16 498.90 12.62 490.07 Pass-Minor 1/10 13,889.90 6,182.29 14,150.00 6,241,03 6.65 72.37 95.19 -9,497.58 -6,157.40 2-11/16 519.50 12.65 510.59 Pass-Minor 1/10 13,909.60 6,184.45 14,175.00 6,241.04 7.07 72.37 92.97 -9,515.35 -6,139.81 2-11/16 539.79 12.64 530.85 Pass-Minor 1/10 13,958.71 6,187.64 14,200.00 6,241.04 7.51 72.37 90.31 -9,533.61 -6,122.74 2-11/16 558.88 12.60 549.94 Pass-Minor 1/10 14,009.09 6,191.98 14,225.00 6,241.04 8.05 72.38 87.42 -9,552.39 -6,106.24 2.11/18 576.44 12.52 567.56 Pass-Minor 1/10 14,044.01 6,194.47 14,250.00 6,241.05 8.45 72.39 86.07 -9,571.66 -6,090.31 2-11/16 592.68 12.44 583.80 Pass-Minor 1/10 14,081.82 6,195.97 14,275.00 6,241.05 8.92 72.39 84.47 -9,591.41 -6,074.99 2-11/16 607.79 12.33 598.95 Pass-Minor 1/10 14,105.00 6,196.28 14,300.00 6,241.06 921 72.40 83.45 -9,611.62 -6,060.27 2-11/16 621.77 1228 612.93 Pass-Minor 1/10 14,121.94 6,196.34 14,325.00 6,241.06 9.43 72.41 84.73 -9,632.26 -6,046.17 2-11/16 635.19 12.36 626.22 Pass-Minor 1/10 14,133.86 6,196.38 14,350.00 6,241.07 9.58 72.42 85.65 -9,853.33 -6,032.72 2-11/16 648.30 12.44. 639.22 Pass-Minor 1/10 14,150.00 6,196.43 14,375.00 6,241.10 9.79 72.43 86.85 -9,674.80 -6,019.91 2-11/16 661.11 12.52 651.91 Pass-Minor 1/10 14,150.00 6,196.43 14,400.00 6,241.24 9.79 72.44 86.92 -9,696.65 -6,007.76 2-11/16 673.62 12.58 864.33 Pass-Minor 1/10 14,169.70 6,196.49 14,425.00 6,241.50 10.05 72.45 88.34 -9,718.85 -5,996.27 2.11/18 885.88 12.66 876.27 Pass-Minor 1/10 14,181.66 6,196.53 14,450.00 6,241.86 10.20 72.47 89.22 -9,741.39 -5,985.46 2-11/16 697.45 12.73 687.96 Pass-Minor 1/10 14,200.00 6,196.59 14,475.00 6,242.34 10.44 7248 90.52 -9,764.24 -5,975.33 2-11/16 708.95 12.79 699.38 Pass-Minor 1/10 14,211.34 6,196.64 14,500.00 6,242.93 10.59 72.50 90.49 -9,787.38 -5,965.90 2-11/16 720.00 12.84 710.37 Pass-Minor 1/10 14,340.99 6,201.70 14,525.00 6,243.62 12.13 72.52 82.88 -9,810.80 -5,957.18 2-11/16 728.66 12.58 719.47 Pass-Minor 1/10 14,405.00 6,207.72 14,550.00 6,244.43 12.93 72.54 7929 -9,834.47 -5,949.17 2-11/18 733.78 12.46 724.81 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 3 of 9 COMPASS 5000.1 Build 61 ORIGINAL 4.4 ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2M Pad- 2M-32-2M-32L1-2M-32L1_wp07 Offset Site Error: 0.00 usft Survey Program: 50-GYD-CT-CMS,12600-GCT-MS,13157-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0,00 usft 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 +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (") (usft) (usft) (usft) (usft) (usft) (usft) 14,426.02 6,209.93 14,575.00 6,245.34 13.20 72.56 80.45 -9,858.36 -5,941.88 2-11/16 737.89 12.49 728.82 Pass-Minor 1/10 14,440.38 6,211.24 14,600.00 6,246.36 13.38 72.58 81.26 -9,882,46 -5,935.32 2-11/16 741.86 12.53 732.50 Pass-Minor 1/10 14,450.00 6,212.02 14,625.00 6,247.49 13.50 72.60 81.81 -9,908.75 -5,929.49 2-11/16 745.06 12.57 735.81 Pass-Minor 1/10 14,489.17 8,213.37 14,650.00 6,248.72 13.74 72.63 82.81 -9,931.19 -5,924.40 2-11/16 748.01 12.60 738.68 Pass-Minor 1/10 14,483.58 8,214.20 14,675.00 6,250.06 13.92 72.66 83.55 -9,955.77 -5,920.06 2-11/16 750.58 12.63 741.18 Pass-Minor 1/10 14,500.00 8,214.94 14,700.00 6,251.50 14.12 72.68 84.38 -9,980.47 -5,916.46 2.11/18 752.76 12.66 743.30 Pass-Minor 1/10 14,512.41 6,215.35 14,725.00 6,253.05 14.28 72.71 84.97 -10,005.26 -5,913.61 2-11/16 754.53 12.69 745.01 Pass-Minor 1/10 14,526.81 8,215.69 14,750.00 6,254.69 14.47 72.75 85.64 -10,030.12 -5,911.52 2-11/16 755.90 12.72 746.33 Pass-Minor 1/10 14,550.00 6,215.87 14,775.00 6,256.38 14.76 72.78 86.77 -10,055.02 -5,910.18 2-11/16 756.96 12.74 747.35 Pass-Minor 1/10 14,555.00 6,215.86 14,800.00 6,257.97 14.83 72.81 86.92 -10,079.96 -5,909.60 2-11/16 757.43 12.77 747.78 Pass-Minor 1/10 14,568.68 6215.75 14,825.00 6,259.46 15.01 72.85 87.71 -10,104.92 -5,909.77 2-11/16 757.60 12.81 747.92 Pass-Minor 1/10 14,581.84 6,215.59 14,850.00 6,260.85 15.18 72.89 88.46 -10,129.86 -5,910.71 2-11/16 757.40 12.84 747.69 Pass-Minor 1/10 14,600.00 6,215.25 14,875.00 6262.13 15.42 72.93 89.56 -10,154.77 -5,912.39 2.11/18 756.86 12.87 747.12 Pass-Minor 1/10 14,600.00 6,215.25 14,900.00 6,263.31 15.42 72.98 89.43 -10,179.62 -5,914.83 2-11/16 755.98 12.90 746.22 Pass-Minor 1/10 14,621.28 6,214.70 14,925.00 6,264.38 15.70 73.02 90.74 -10,204.39 -5,918.03 2-11/16 754.59 12.92 744.82 Pass-Minor 1/10 14,634.41 6,214.27 14,950.00 6,265.34 15.87 73.07 91.50 -10,229.06 -5,921.97 2-11/16 752.92 12.94 743.13 Pass-Minor 1/10 14,650.00 6,213.68 14,975.00 8,266.19 16.08 73.12 92.43 -10,253.60 -5,926.65 2-11/16 750.88 12.96 741.10 Pass-Minor 1/10 14,655.00 6,213.47 15,000.00 8,286.94 16.14 73.17 92.63 -10,277.99 -5,932.08 2-11/16 748.51 12.97 738.72 Pass-Minor 1/10 14,674.36 6,212.72 15,025.00 6,267.57 16.39 73.22 93.82 -10,302.21 -5,938.24 2-11/16 745.68 12.99 735.90 Pass-Minor 1/10 14,687.90 6,212.29 15,050.00 6,268.09 16.57 73.27 94.62 -10,326.24 -5,945.14 2-11/16 742.51 13.00 732.74 Pass-Minor 1/10 14,700.00 6,211.97 15,075.00 6,268.50 16.73 73.33 95.33 -10,350.04 -5,952.75 2-11/16 738.97 13.01 729.21 Pass-Minor 1/10 14,715.01 6,211.86 15,100.00 6,268.80 16.92 73.39 96.25 -10,373.61 -5,961.08 2.11/18 735.04 13.01 725.30 Pass-Minor 1/10 14,728.61 6,211.48 15,125.00 6,269.02 17.09 73.44 97.09 -10,397.07 -5,969.73 2-11/16 731.16 13.01 721.43 Pass-Minor 1/10 14,750.00 6,211.31 15,150.00 6,269.23 17.36 73.49 98.45 -10,420.76 -5,977.71 2-11/16 728.43 12.99 718.72 Pass-Minor 1/10 14,755.00 6,211.30 15,175.00 6,269.44 17.43 73.54 98.75 -10,444.68 -5,984.95 2-11/16 726.69 13.00 716.98 Pass-Minor 1/10 14,769.54 6,211.31 15,200.00 6,269.66 17.61 73.59 99.74 -10,468.82 -5,991.47 2-11/18 726.17 12.99 716.47 Pass-Minor 1/10 14,782.98 6,211.36 15,225.00 6,269.87 17.78 73.64 100.65 -10,493.14 -5,997.24 2.11/18 726.81 12.99 717.11 Pass-Minor 1/10 14,800.00 6,211.48 15,250.00 6,270.08 17.99 73.70 101.83 -10,517.63 -6,002.27 2.11/18 728.63 12.98 716.94 Pass-Minor 1/10 14,800.00 8,211.48 15,275.00 6,270.33 17.99 73.75 101.84 -10,542.18 -6,006.95 2.11/18 731.27 12.99 721.56 Pass-Minor 1/10 14,823.08 6,211.74 15,300.00 6,270.74 18.28 73.81 103.42 -10,566.59 -6,012.33 2.11/18 733.40 12.97 723.71 Pass-Minor 1/10 14,836.42 8,211.94 15,325.00 6,271.30 18.45 73.88 104.32 -10,590.83 -6,018.42 2.11/18 735.32 12.96 725.64 Pass-Minor 1/10 14,850.00 6,212.19 15,350.00 6,272.03 18.62 73.95 105.23 -10,614.87 -6,025.24 2.11/18 736.89 12.94 727.24 Pass-Minor 1/10 14,863.10 6,212.46 15,375.00 6,272.91 18.78 74.02 106.10 -10,638.69 -6,032.77 2-11/18 738.13 12.92 728.51 Pass-Minor 1/10 14,876.44 6,212.77 15,400.00 6,273.94 18.94 74.09 106.97 -10,662.27 -6,041.01 2-11/16 739.04 12.90 729.44 Pass-Minor 1/10 14,900.00 6,213.42 15,425.00 6,275.13 19.23 74.16 108.51 -10,685.59 -6,049.95 2-11/16 739.73 12.84 730.21 Pass-Minor 1/10 14,900.00 6,213.42 15,450.00 6,276.48 19.23 74.24 108.46 -10,708.62 -6,059.58 2-11/16 739.84 12.83 730.33 Pass-Minor 1/10 14,916.44 6,213.94 15,475.00 6,277.87 19.43 74.31 109.52 -10,731.51 -6,069.53 2.11/18 740.11 12.79 730.66 Pass-Minor 1/10 14,929.75 6,214.40 15,500.00 6,279.02 19.59 74.38 110.39 -10,754.68 -6,078.85 2-11/16 741.44 12.75 732.03 Pass-Minor 1/10 14,950.00 6,215.18 15,525.00 6,279.92 19.83 74.45 111.75 -10,778.11 -6,087.51 2-11/16 743.92 12.69 734.57 Pass-Minor 1/10 14,979.24 6,216.38 15,550.00 6,280.57 20.15 74.51 110.51 -10,801.80 -6,095.49 2-11/16 747.32 12.75 737.88 Pass-Minor 1/10 15,255.00 6,227.50 15,575.00 6,280.97 23.13 74.58 92.01 -10,825.70 -8,102.79 2-11/16 746.73 12.99 737.00 Pass-Minor 1/10 15,268.05 6,228.02 15,600.00 6,281.11 23.29 74.65 92.93 -10,849.81 -6,109.39 2-11/16 742.88 12.99 733.13 Pass-Minor 1/10 15,281.17 6,228.55 15,625.00 6,281.05 23.45 74.73 93.87 -10,874.11 -6,115.29 2-11/16 740.13 13.00 730.36 Pass-Minor 1/10 15,300.00 6,229.36 15,650.00 6,280.89 23.69 74.80 95.22 -10,898.57 -6,120.44 2-11/16 738.57 13.00 728.78 Pass-Minor 1/10 15,300.00 6,229.36 15,675.00 6,280.64 23.69 74.87 95.32 -10,923.17 -6,124.86 2-11/16 738.14 13.02 728.31 Pass-Minor 1/10 15,320.75 6,230.29 15,700.00 6,280.30 23.95 74.95 96.82 -10,947.90 -6,128.52 2-11/16 738.75 13.02 728.90 Pass-Minor 1/10 15,333.89 6,230.91 15,725.00 6,279.86 24.12 75.03 97.83 -10,972.72 -6,131.44 2-11/16 740.59 13.03 730.70 Pass-Minor 1/10 15,350.00 6,231.69 15,750.00 8,279.33 24.33 75.10 99.05 -10,997.62 -6,133.60 2-11/16 743.58 13.04 733.66 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 4 of 9 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9©146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2M Pad- 2M-32-2M-32L1-2M-32L1_wp07 Offset Site Error: 0.00 usft Survey Program: 50-GYD-CT-CMS,12600-GCT-MS,13157-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft 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 +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) F) (usft) (usft) (usft) (usft) (usft) (usft) 15,350.00 6,231.69 15,775.00 6,278.73 24.33 75.19 9920 -11,022.55 -6,135.42 2-11/16 747.39 13.06 737.42 Pass-Minor 1/10 15,372.88 6232.85 15,800.00 6278.13 24.62 75.27 100.88 -11,047.41 -6,137.96 2-11/16 750.65 13.06 740.66 Pass-Minor 1/10 15,385.83 6,233.53 15,825.00 6,277.54 24.79 75.38 101.90 -11,072.19 -6,141.25 2-11/16 753.68 13.05 743.66 Pass-Minor 1/10 15,400.00 6,234.29 15,850.00 6,276.94 24.97 75.45 102.99 -11,096.85 -6,145.30 2-11/16 756.34 13.05 746.30 Pass-Minor 1/10 15,400.00 6,234.29 15,875.00 6,276.35 24.97 75.54 103.15 -11,121.38 -6,150.10 2-11/16 758.81 13.06 748.73 Pass-Minor 1/10 15,424.67 6,235.68 15,900.00 6,275,76 25.28 75.64 104.94 -11,145.74 -6,155.65 2-11/16 760.56 13.03 750.49 Pass-Minor 1/10 15,437.61 6,236.43 15,925.00 6,275.17 25.44 75.73 105.95 -11,169.93 -6,161.94 2-11/16 762.13 13.01 752.05 Pass-Minor 1/10 15,450.00 6,237.17 15,950.00 6,274.59 25.60 75.83 106.92 -11,193.92 -6,168.96 2.11/18 763.33 12.99 753.25 Pass-Minor 1/10 15,463.47 6,237.99 15,975.00 6,274.01 25.77 75.93 107.97 -11,217.67 -6,176.72 2-11/16 764-16 12.97 754.10 Pass-Minor 1/10 15,476.40 6,238.79 16,000.00 6,273.43 25.93 76.03 108.97 -11,241.19 -6,185.19 2-11/16 764.63 12.94 754.57 Pass-Minor 1/10 15,609.29 6,247.21 16,025.00 6,272.86 27.41 76.14 101.53 -11,264.43 -6,194.39 2-11/16 764.07 13.09 753.80 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 5 of 9 COMPASS 5000.1 Build 61 ORIGINAL i ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01 wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2M Pad- 2M-34-2M-34-2M-34 Offset Site Error: 0.00 usft Survey Program: 173-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 usft 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 +14)S +E1-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (") (usft) (usft) (usft) (usft) (usft) (usft) 13,652.88 6,194.43 14,225.00 5,401.73 3.71 152.32 -126.38 -8,983.89 -7,530.09 5 1,218.68 385.92 878.77 Pass-Major Risk,CC 13,678.38 6,190.81 14,250.00 5,408.39 4.04 152.61 -124.09 -9,003.32 -7,544.34 5 1,221.77 392.04 877.55 Pass-Major Risk 13,705.17 6,187.56 14,275.00 5,415.00 4.41 152.90 -121.80 -9,022.75 -7,558.62 5 1,225.01 398.27 876.34 Pass-Major Risk 13,733.27 6,184.76 14,300.00 5,421.56 4.81 153.19 -119.50 -9,042.17 -7,572.93 5 1,228.35 404.65 875.09 Pass-Major Risk 13,755.00 6,183.02 14,325.00 5,428.08 5.12 153.48 -117.64 -9,061.57 -7,587.28 5 1,231.78 410.13 874.43 Pass-Major Risk,ES,SF 13,773.34 6,181.90 14,350.00 5,434.55 5.37 153.77 -116.59 -9,080.97 -7,601.67 5 1,235.43 413.10 876.45 Pass-Major Risk 13,788.22 6,181.28 14,375.00 5,440.96 5.58 154.06 -115.65 -9,100.36 -7,616.08 5 1,239.38 415.62 878.64 Pass-Major Risk 13,800.00 6,180.96 14,400.00 5,447.33 5.74 154.35 -114.82 -9,119.74 -7,630.53 5 1,243.63 417.75 881.02 Pass-Major Risk 13,818.75 6,180.80 14,425.00 5,453.65 6.00 154.64 -113.85 -9,139.11 -7,645.02 5 1,248.14 420.71 883.94 Pass-Major Risk 13,834.39 6,180.96 14,450.00 5,459.92 6.21 154.93 -112.99 -9,158.48 -7,659.54 5 1,252.92 423.27 887.04 Pass-Major Risk 13,850.00 6,181.41 14,475.00 5,466.15 6.42 155.22 -112.15 -9,177.83 -7,674.09 5 1,257.96 425.83 890.41 Pass-Major Risk 13,855.00 6,181.61 14,500.00 5,472.40 6.49 155.51 -111.59 -9,197.17 -7,688.64 5 1,263.25 427.12 893.77 Pass-Major Risk 13,870.43 6,182.32 14,525.00 5,478.66 6.66 155.80 -112.13 -9,216.51 -7,703.19 5 1,268.76 424.59 900.22 Pass-Major Risk 13,879.37 6,182.76 14,550.00 5,484.94 6.76 156.09 -112.25 -9,235.84 -7,717.75 5 1,274.62 423.36 905.84 Pass-Major Risk 13,900.00 6,183.88 14,575.00 5,491.23 6.98 156.38 -113.12 -9,255.17 -7,732.31 5 1,280.91 419.43 914.45 Pass-Major Risk 13,900.00 6,183.88 14,600.00 5,497.55 6.98 156.67 -112.66 -9,274.49 -7,746.86 5 1,287.24 420.11 918.79 Pass-Major Risk 13,900.00 6,183.88 14,625.00 5,503.88 6.98 156.96 -112.20 -9,293.80 -7,761.42 5 1,294.01 420.79 923.61 Pass-Major Risk 13,900.00 6,183.88 14,650.00 5,510.22 6.98 157.25 -111.76 -9,313.10 -7,775.99 5 1,301.23 421.47 928.88 Pass-Major Risk 13,922.85 6,18528 14,675.00 5,516.59 7.19 157.54 -112.75 -9,332.40 -7,790.55 5 1,308.36 416.64 939.30 Pass-Major Risk 13,931.29 6,185.84 14,700.00 5,522.97 7.27 157.83 -112.84 -9,35169 -7,805.11 5 1,315.99 415.20 947.04 Pass-Major Risk 13,950.00 6,187.15 14,725.00 5,529.37 7.44 158.12 -113.58 -9,370.98 -7,819.68 5 1,324.00 411.06 957.79 Pass-Major Risk 13,950.00 6,187.15 14,750.00 5,535.80 7.44 158.40 -113.13 -9,390.25 -7,834.25 5 1,332.09 411.69 964.07 Pass-Major Risk 13,950.00 6,187.15 14,775.00 5,542.30 7.44 158.68 -11268 -9,409.49 -7,848.83 5 1,340.57 412.32 970.77 Pass-Major Risk 13,950.00 6,187.15 14,800.00 5,548.88 7.44 158.95 -112.24 -9,428.70 -7,863.41 5 1,349.43 412.94 977.86 Pass-Major Risk 13,972.19 6,188.84 14,825.00 5,555.53 7.67 159.23 -113.18 -9,447.88 -7,877.99 5 1,358.18 407.66 990.55 Pass-Major Risk 13,980.10 6,189.48 14,850.00 5,562.26 7.75 159.51 -11324 -9,467.04 -7,892.59 5 1,367.39 406.11 1,000.13 Pass-Major Risk 14,000.00 6,191.18 14,875.00 5,569.06 7.95 159.78 -114.03 -9,486.16 -7,907.18 5 1,376.97 401.11 1,013.46 Pass-Major Risk 14,000.00 6,191.18 14,900.00 5,575.93 7.95 160.06 -113.59 -9,505.25 -7,921.79 5 1,386.54 401.71 1,021.38 Pass-Major Risk 14,003.25 6,191.47 14,925.00 5,582.88 7.99 160.34 -113.35 -9,524.31 -7,936.39 5 1,396.46 401.38 1,030.56 Pass-Major Risk 14,014.88 6,192.47 14,950.00 5,589.90 8.12 160.62 -113.47 -9,543.34 -7,951.01 5 1,406.60 399.47 1,040.34 Pass-Major Risk 14,027.47 6,193.42 14,975.00 5,597.00 826 160.89 -113.60 -9,562.34 -7,965.62 5 1,416.91 397.49 1,050.06 Pass-Major Risk 14,039.78 6,194.23 15,000.00 5,604.17 8.40 161.17 -113.71 -9,581.31 -7,980.25 5 1,427.39 395.51 1,060.00 Pass-Major Risk 14,050.00 6,194.79 15,025.00 5,611.41 8.52 161.45 -113.73 -9,600.25 -7,994.87 5 1,438.03 393.94 1,070.00 Pass-Major Risk 14,063.56 6,195.40 15,050.00 5,618.74 8.69 161.72 -113.89 -9,619.16 -8,009.49 5 1,448.82 391.65 1,080.50 Pass-Major Risk 14,075.03 6,195.79 15,075.00 5,626.14 8.83 162.00 -113.97 -9,638.04 -8,024.11 5 1,459.78 389.77 1,091.07 Pass-Major Risk 14,205.00 6,19661 15,100.00 5,633.63 10.51 162.28 -107.98 -9,656.88 -8,038.73 5 1,471.01 421.34 1,070.26 Pass-Major Risk 14,224.39 6,196.76 15,125.00 5,641.19 10.74 162.55 -108.75 -9,675.70 -8,053.35 5 1,480.49 416.92 1,083.64 Pass-Major Risk 14,231.38 6,196.86 15,150.00 5,648.84 10.83 162.83 -108.73 -9,694.49 -8,067.96 5 1,490.34 415.67 1,094.03 Pass-Major Risk 14,250.00 6,197.26 15,175.00 5,656.57 11.05 163.11 -109.44 -9,713.25 -8,082.57 5 1,500.56 411.21 1,108.25 Pass-Major Risk 14,250.00 6,197.26 15,200.00 5,664.37 11.05 163.39 -108.99 -9,731.97 -8,097.18 5 1,510.77 411.79 1,117.06 Pass-Major Risk 14,250.00 6,197.26 15,225.00 5,672.26 11.05 163.66 -108.54 -9,750.67 -8,111.79 5 1,521.29 412.38 1,126.21 Pass-Major Risk 14,250.00 6,197.26 15,250.00 5,680.23 11.05 163.94 -108.10 -9,769.33 -8,126.39 5 1,532.11 412.96 1,135.69 Pass-Major Risk 14,250.00 6,197.26 15,275.00 5,688.27 11.05 164.22 -107.66 -9,787.96 -8,140.98 5 1,543.24 413.55 1,145.48 Pass-Major Risk 14,271.90 6,197.93 15,300.00 5,696.39 11.31 164.49 -108.58 -9,806.57 -8,155.58 5 1,554.21 407.90 1,161.83 Pass-Major Risk 14,278.42 6,198.18 15,325.00 5,704.57 11.38 164.77 -108.55 -9,825.15 -8,170.16 5 1,565.61 406.58 1,174.01 Pass-Major Risk 14,300.00 6,199.15 15,350.00 5,712.81 11.63 165.05 -109.44 -9,843.71 -8,184.74 5 1,577.44 400.72 1,191.47 Pass-Major Risk 14,300.00 6,199.15 15,375.00 5,721.11 11.63 165.32 -109.02 -9,862.26 -8,199.32 5 1,589.12 401.27 1,201.94 Pass-Major Risk 14,300.00 6,199.15 15,400.00 5,729.46 11.63 165.60 -108.61 -9,880.78 -8,213.88 5 1,601.08 401.83 1,212.72 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 6 of 9 COMPASS 5000.1 Build 61 ORIGINAL WA ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2M Pad- 2M-34-2M-34-2M-34 Offset Site Error: 0,00 usft Survey Program: 173-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 usft 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 ON/-6 +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usff) F) (usft) (usft) (use) (usft) (usft) )usft) 14,305.00 6,199.41 15,425.00 5,737.88 11.69 165.88 -108.50 -9,899.28 -8,228.44 5 1,613.31 400.86 1,225.40 Pass-Major Risk 14,305.00 6,199.41 15,450.00 5,746.36 11.69 166.15 -108.09 -9,917.76 -8,242.99 5 1,625.75 401.41 1,236.70 Pass-Major Risk 14,305.00 6,199.41 15,475.00 5,754.90 11.69 166.43 -107.69 -9,936.21 -8,257.53 5 1,638.46 401.96 1,248.28 Pass-Major Risk 14,322.59 6,200.43 15,500.00 5,763.55 11.91 166.70 -108.30 -9,954.63 -8,272.05 5 1,651.11 397.38 1,265.52 Pass-Major Risk 15,050.00 6,219.30 15,525.00 5,772.32 20.86 166.98 -85.15 -9,973.02 -8,286.54 5 1,659.21 516.46 1,157.58 Pass-Major Risk 15,050.00 6,219.30 15,550.00 5,781.22 20.86 167.25 -84.82 -9,991.37 -8,301.00 5 1,663.60 517.15 1,160.66 Pass-Major Risk 15,050.00 6,219.30 15,575.00 5,790.28 20.86 167.52 -84.48 -10,009.67 , -8,315.42 5 1,668.30 517.84 1,164.06 Pass-Major Risk 15,050.00 8,219.30 15,600.00 5,799.56 20.86 167.80 -84.14 -10,027.90 -8,329.80 5 1,673.27 518.53 1,167.74 Pass-Major Risk 15,067.75 8,220.03 15,625.00 5,809.07 21.04 168.07 -84.98 -10,046.05 -8,344.12 5 1,678.25 516.43 1,174.04 Pass-Major Risk 15,075.14 6,220.33 15,850.00 5,818.80 21.12 168.34 -85.13 -10,064.13 -8,358.38 5 1,683.48 515.89 1,179.15 Pass-Major Risk 15,082.47 6,220.63 15,675.00 5,828.74 21.19 168.61 -85.26 -10,082.14 -8,372.58 5 1,688.90 515.30 1,184.49 Pass-Major Risk 15,100.00 6,221.34 15,700.00 5,838.88 21.37 168.88 -86.07 -10,100.10 -8,386.72 5 1,694.57 512.82 1,191.91 Pass-Major Risk 15.100.00 6,221.34 15,725.00 5,849.21 21.37 169.15 -85.70 -10,117.99 -8,400.79 5 1,700.23 513.48 1,196.33 Pass-Major Risk 15.100.00 6,221.34 15,750.00 5,85974 21.37 169.41 -85.32 -10,135.83 -8,414.79 5 1,706.14 514.13 1,201.02 Pass-Major Risk 15,100.00 6,221.34 15,775.00 5,870.45 21.37 169.68 -84.94 -10,153.63 -8,428.69 5 1,712.28 514.78 1,205.96 Pass-Major Risk 15,118.08 6,222.08 15,800.00 5,881.34 21.57 169.94 -85.77 -10,171.41 -8,442.49 5 1,718.36 511.96 1,214.17 Pass-Major Risk 15,125.00 6,222.36 15,825.00 5,892.40 21.65 170.21 -85.85 -10,189.15 -8,456.20 5 1,724.87 511.21 1,220.66 Pass-Major Risk 15,131.85 6,222.63 15,850.00 5,903.71 21.72 170.46 -85.91 -10,206.82 -8,469.79 5 1,731.11 510.43 1,227.31 Pass-Major Risk 15,150.00 6,223.36 15,875.00 5,915.43 21.92 170.72 -86.73 -10,224.32 -8,483.27 5 1,737.77 507.16 1,236.61 Pass-Major Risk 15,150.00 6,223.36 15,900.00 5,927.55 21.92 170.98 -86.31 -10,241.63 -8,496.62 5 1,744.32 507.78 1,242.05 Pass-Major Risk 15,150.00 8,223.36 15,925.00 5,940.06 21.92 171.24 -85.88 -10,258.77 -8,509.84 5 1,751.06 508.40 1,247.69 Pass-Major Risk 15,150.00 6,223.36 15,950.00 5,952.82 21.92 171.49 -85.45 -10,275.80 -8,522.97 5 1,758.03 509.00 1,253.58 Pass-Major Risk 15,150.00 6,223.36 15,975.00 5,965.75 21.92 171.74 -85.02 -10,292.75 -8,536.03 5 1,765.24 509.60 1,259.74 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 7 of 9 COMPASS 5000.1 Build 61 ORIGINAL a/f1 ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk W.Sak- W SAK 15-W SAK 15-W SAK 15 Offset Site Error: 0.00 usft Survey Program: 6410-BLIND Rule Assigned:Minor 1/10 Offset Well Error: 0.00 uWft 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 +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) lush) (°) (usft) (usft) (usft) (usft) (usft) (usft) 13,494.54 6,221.86 5,325.00 5,325.00 3.42 1,717.90 -178.73 -8,870.78 -6,764.61 2-11/16 933.20 1.55 932.98 Pass-Minor 1/10,CC,ES,SF 13,499.33 6220.98 5,300.00 5,300.00 3.42 1,709.58 -178.52 -8,870.78 -6,764.61 2-11/16 957.58 1.54 957.36 Pass-Minor 1/10 13,504.09 6220.12 5,275.00 5,275.00 3.42 1,701.27 -178.30 -8,870.78 -6,764.61 2-11/16 981.97 1.54 981.75 Pass-Minor 1/10 13,508.82 6219.25 5250.00 5,250.00 3.43 1,692.96 -178.08 -8,870.78 -6,764.61 2-11/16 1,006.37 1.53 1,006.14 Pass-Minor 1/10 13,513.52 6,218.40 5225.00 5,225.00 3.43 1,684.64 -177.85 -8,870.78 -6,764.61 2-11/16 1,030.77 1.53 1,030.55 Pass-Minor 1/10 13,518.19 6,217.55 5200.00 5,200.00 3.43 1,676.33 -177.82 -8,870.78 -6,764.61 2-11/16 1,055.19 1.53 1,054.96 Pass-Minor 1/10 13,522.84 6,216.71 5,175.00 5,175.00 3.43 1,668.02 -177.38 -8,870.78 -6,764.61 2-11/16 1,079.61 1.53 1,079.38 Pass-Minor 1/10 13,527.46 6,215.88 5,150.00 5,150.00 3.43 1,659.70 -177.15 -8,870.78 -6,764.61 2-11/16 1,104.03 1.53 1,103.81 Pass-Minor 1/10 13,532.06 6,215.06 5,125.00 5,125.00 3.43 1,651.39 -176.91 -8,870.78 -8,784.61 2-11/16 1,128.47 1.54 1,128.24 Pass-Minor 1/10 13,536.62 6,214.24 5,100.00 5,100.00 3.43 1,643.08 -176.66 -8,870.78 -6,764.61 2-11/16 1,152.91 1.54 1,152.68 Pass-Minor 1/10 13,541.16 6,213.43 5,075.00 5,075.00 3.43 1,634.76 -176.42 -8,870.78 -6,764.61 2-11/16 1,177.35 1.55 1,177.13 Pass-Minor 1/10 13,545.67 6,212.63 5,050.00 5,050.00 3.43 1,626.45 -178.17 -8,870.78 -6,764.61 2-11/16 1,201.81 1.56 1,201.58 Pass-Minor 1/10 13,550.15 6,211.83 5,025.00 5,025.00 3.44 1,618.14 -175.94 -8,870.78 -6,764.61 2-11/16 1,226.26 1.58 1,226.04 Pass-Minor 1/10 13,554.61 6,211.04 5,000.00 5,000.00 3.44 1,609.82 -175.68 -8,870.78 -6,764.61 2-11/16 1,250.73 1.59 1,250.50 Pass-Minor 1/10 13,559.04 6,210.26 4,975.00 4,975.00 3.44 1,601.51 -175.43 -8,870.78 -6,764.61 2-11/16 1,275.20 1.61 1,274.97 Pass-Minor 1/10 13,563.44 6,209.49 4,950.00 4,950.00 3.44 1,593.19 -175.18 -8,870.78 -6,764.61 2-11/16 1,299.67 1.63 1,299.45 Pass-Minor 1/10 13,567.81 6,208.72 4,925.00 4,925.00 3.44 1,584.88 -174.93 -8,870.78 -6,764.61 2-11/16 1,324.15 1.65 1,323.93 Pass-Minor 1/10 13,572.15 6,207.97 4,900.00 4,900.00 3.44 1,576.57 -174.67 -8,870.78 -6,764.61 2-11/16 1,348.64 1.67 1,348.41 Pass-Minor 1/10 13,576.47 6,207.21 4,875.00 4,875 00 3.44 1,568.25 -174.42 -8,870.78 -8,764.61 2-11/16 1,373.13 1.69 1,372.90 Pass-Minor 1/10 13,580.76 6,206.47 4,850.00 4,850.00 3.44 1,559.94 -174.17 -8,870.78 -6,784.61 2-11/16 1,397.62 1.72 1,397.39 Pass-Minor 1/10 13,585.03 6,205.73 4,825.00 4,825.00 3.44 1,551.63 -173.92 -8,870.78 -6,764.61 2-11/16 1,422.12 1.74 1,421.89 Pass-Minor 1/10 13,589.26 6,205.00 4,800.00 4,800.00 3.45 1,543.31 -173.66 -8,870.78 -6,764.61 2-11/16 1,446.62 1.77 1,446.40 Pass-Minor 1/10 13,593.47 6,204.28 4,775.00 4,775.00 3.45 1,535.00 -173.41 -8,870.78 -8,764.61 2-11/16 1,471.13 1.80 1,470.90 Pass-Minor 1/10 13,597.65 6,203.56 4,750.00 4,750.00 3.45 1,526.69 -173.16 -8,870.78 -6,764.61 2-11/16 1,495.64 1.83 1,495.42 Pass-Minor 1/10 13,601.80 6,202.86 4,725.00 4,725.00 3.45 1,518.37 -172.91 -8,870.78 -6,764.61 2-11/16 1,520.16 1.86 1,519.93 Pass-Minor 1/10 13,605.93 6,202.15 4,700.00 4,700.00 3.45 1,510.06 -172.65 -8,870.78 -6,764.61 2-11/16 1,544.68 1.89 1,544.45 Pass-Minor 1/10 13,610.03 6,201.46 4,675.00 4,675.00 3.45 1,501.75 -172.40 -8,870.78 -6,764.61 2-11/16 1,569.20 1.92 1,588.98 Pass-Minor 1/10 13,614.10 6,200.77 4,650.00 4,650.00 3.46 1,493.43 -172.15 -8,870.78 -6,764.61 2-11/16 1,593.73 1.95 1,593.50 Pass-Minor 1/10 13,618.14 6,200.09 4,625.00 4,625.00 3.46 1,485.12 -171.90 -8,870.78 -6,764.61 2-11/16 1,618.26 1.98 1,618.04 Pass-Minor 1/10 13,622.16 6,199.41 4,600.00 4,600.00 3.47 1,476.81 -171.65 -8,870.78 -6,764.61 2-11/16 1,642.80 2.02 1,642.57 Pass-Minor 1/10 13,626.15 6,198.75 4,575.00 4,575.00 3.47 1,468.49 -171.40 -8,870.78 -6,764.81 2-11/16 1,667.34 2.05 1,667.11 Pass-Minor 1/10 13,630.11 6,198.09 4,550.00 4,550.00 3.49 1,460.18 -171.16 -8,870.78 -6,764.61 2-11/16 1,691.88 2.08 1,691.65 Pass-Minor 1/10 13,634.05 6,197.43 4,525.00 4,525.00 3.51 1,451.87 -170.91 -8,870.78 -6,764.61 2.11/18 1,716.43 2.12 1,716.20 Pass-Minor 1/10 13,635.00 6,197.27 4,475.00 4,475.00 3.51 1,435.24 -170.98 -8,870.78 -6,764.61 2.11/18 1,765.54 2.13 1,765.32 Pass-Minor 1/10 13,635.00 6,197.27 4,500.00 4,500.00 3.51 1,443.55 -170.91 -8,870.78 -6,764.61 2-11/16 1,740.98 2.13 1,740.75 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 8 of 9 COMPASS 5000.1 Build 61 DIRIGINAL tra— ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-32 Project: Kuparuk River Unit TVD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Reference Site: Kuparuk 2M Pad MD Reference: 2M-32:105.1+40.9 @ 146.00usft(2M-32) Site Error: 0.00usft North Reference: True Reference Well: 2M-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2M-32L1-01 Database: EDM Alaska Prod Reference Design: 2M-32L1-01_wp04 Offset TVD Reference: Offset Datum Reference Depths are relative to 2M-32:105.1+40.9 @ 146.00usft(2M Coordinates are relative to:2M-32 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:-0.10° Ladder Plot 1800- �. I I I - I I I I I I I I I J J _J ____ h_0 I I „ I I 1 1350 I I 1 Qf► O I I 0co _I J J _J J ._ N I I I (I) I I N 0 I I 900 I 1 o I N J J J ____J J I U N 11/ 450— 1 I I _. .. ... .._ _- J J J ____J ____ J I I 0 I I 0 3000 6000 9000 12000 15000 18000 Measured Depth LEGEND $ 2M-32,2M-32L1,2M-32L1 wp07V0 2M-34,2M-34,2M-34 V2 -e- WSAK 15,WSAK 15,WSAK 15 V1 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/11/2014 9:51:42AM Page 9 of 9 COMPASS 5000.1 Build 61 ORGI \ AL vs (i) ��NttO�1��F8P-1c �OOi V N(`O') `J, nOm04QlMo)Ufl1l Un N-M O)m m m c O m m In< O co. 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A 0 CD U f AA h O11 O a „ iQ aL IL__ _ Now. III � o 0 0 M o N 2 to 2 L9 E fir) - 0 CO zo rn a)v- m co _.i - CON Q <-- '<- N N (V X -C in I�v0 t` @� iv, co _7.. N O N 7 Q r c0 d 9 L co c0 2 O N Ferguson, Victoria L (DOA) From: Eller,J Gary <J.Gary.Eller@conocophillips.com> Sent: Wednesday,August 27, 2014 1:58 PM To: Ferguson,Victoria L(DOA) Subject: RE:2M-32L1(PTD 214-125);2M-32L1-01(PTD 214-128) Victoria—Sorry for so much turmoil on this set of drilling permits Please let me know when you get a Commissioner's signature and I can come by to pick them up. Thanks for your help. -Gary From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Wednesday, August 27, 2014 9:29 AM To: Eller, J Gary Subject: [EXTERNAL]RE: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) Thanx,that's what I needed- From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Wednesday, August 27, 2014 9:27 AM To: Ferguson, Victoria L(DOA) Cc: Ohlinger, James J; Venhaus, Dan E; Burke,Jason Subject: RE: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) Victoria—Attached is the approved TCR worksheet for the close approach of 2M-32L1 to the P&A'd West Sak River State 15 well (PTD 179-99, API 50-103-20013). There is no HSE risk associated with a collision as CTD would encounter the well below the 7" cement retainer that was used to plug the perfs (see attached schematic). The only consequence is financial, which the TCR sheet assesses as a tolerable financial risk. -Gary From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent:Tuesday, August 26, 2014 4:28 PM To: Eller,J Gary Subject: [EXTERNAL]FW: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) From: Ferguson, Victoria L(DOA) Sent: Tuesday,August 26, 2014 1:48 PM To: Ohlinger,James J (Jaures.J.Ohlinger@conocophillins.com) Subject: RE: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) Do you have more information on WSak 15 from the anti-collision report. What is the status of the well? Not clear where the wellbore trajectory is for this well. PTD#? Thanx, Victoria From: Ferguson, Victoria L(DOA) Sent:Tuesday, August 26, 2014 9:54 AM To: Ohlinger,James.3 (James.].Ohlinger@conocophillips.com) Subject: FW: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) 1 Froth: Ferguson,Victoria L(DOA) Sent:Tuesday, August 26, 2014 9:52 AM To: iason.burke@conocophillips.com Subject: 2M-32L1(PTD 214-125); 2M-32L1-01(PTD 214-128) Jason, Please provide a wellbore schematic for each of these PTDs. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria.ferqusonAalaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 2 WEST SAK _ 4/ER STATE #15 CURRENT t_ _LBORE DIAGRAM • . 1 ,... . • . + . AAAA • + . :to, • • www • • w w •A �" ,r • • . • w w • • w w • w w • w w • w • . • r ; . w • w w • • w • • w . . • • . A • A • • i • 2 • 110 r4k/0/14:.:.:.:.:4:4:A:.:.:.:• ` r .r�• _Pj •w•••.A •. . ..- r .:a: 16" CSA 731 • 0010-3/41' n�4, . 468 bpf '�� •••"A; A•. A::"•A iia 65# H40 �slAVIV. rsr�ji•�p :A r7ilrir• fr`y • yrx;✓ � 414A.illi,BirAlri. . 21 CEMENT PLUG IN 7", 300.500 I' FP; "'ik24 4c7 j'.. ,:. r •S• EST CMT TOP @ 1981' . '';,4 �:•1•:'I•. . ' '(•` „' �'_'. • r- AS. UPPER FO COLLAR @ 2020' lir . - ; A IP .1 zjiiii iirl,:..:..: :..:...:..:..:.f..:. :. ,rat A rf, �1 ia4i.. • Sa. � . • ��r ; , •:.7i.. ;Y • 10.3/4" CSA 2225' '`,lri. •...`. 'y'' 45.5# K55 BTC it i.:±...:.1:. ... '.1.:.. :. LOWER FO COLLAR @ 2603' ▪ • '4'V ...I•I• • i• .1 [ 88 DESEL ::i•: :Iw'::1' ':":17":U : Ti. El FF B 5 1991 ::I Alaska.Oil& Gas108 PPG CALCIUM CHLORIDE• . : _ „,,.2: Cons. Commission .:. ' :. :.: Anchorage VI ARCTIC PACK � .••r: 1 .4 PP MU '•• •:r: :.�.-:',. • I fa;a a,a 1.1 ;k410,1111; TOP OF CMT ABOVE RETAINER @ 6010' TOP OF RETAINER @ 6070' t 1;'3i'f' S'i:ti O �1i• •isiii�,1i x ii• Np . PERFS: 6164-6178',1i.4 " EE KUPARUK TOP @ 6164' ,24r1114YS)44 6184-6207', 6186-6222'222' I • •rir r ' bj� •. itret PERFS SQUEEZED W/300 SX G r r I� r rrr� �I� r 3i • 441}' 7” CSA 6392' • t • 1a. / • �'• 261 K55 BTC, ..0382 bpt L- J 8-1/2' HOLE TD @ 8410' .0702 bpf ARCO Alaska, Inc. West Sak River State #15 • 1800' FSL, 1600' FEL, SEC. 5, T1ON, R8E, UM STRAIGHT HOLE/VERTICAL WELLApla 50-103.20013, PERMIT 79-99 LRC 1-21-91 ConocoPhillipsConoc ips Alaska, Inc Drilling Anti-Collision Management Alaska A Tolerable Collision Generic name of scenario: Collision with the abandoned W SAK 15 well while drilling 2M-32L1. Risk Worksheet Description: (Be specific.Include all factors which affect either the cost of col'ision or the cost of reducing the risk) based on Rev.1-29 Jul 99 Lateral 2M-32L1 wp07 fails major risk anti-collision scan against well W SAK 15 between 13,343' MD and 13,360'MD. CTR-CTR distance is 122'.Well W SAK 15 has been completely Use this sheet to describe a well interference scenario where ORA abandoned. may be applicable.Check first that the scenario really is different The 2M-32L1 will be building for a landing point in the A sand,the collision risk is in the 7,casing from those described on existing worksheets. below the cement retainer. Prepared by: JasofrBurke/ Authorized by: Do the consequences Are the (STOP ] r:o of collision include a ()Yes Oro risk to personnel or the consequences of collision Major risk environment? • o List all the consequences of 0Yes collision and the necessary remedial action: Cost of Collision - There in no HSE risk associated with a collision with the abandoned W SAK 15 well while drilling the 2M-32L1 lateral. There is an economic risk due to the $450,000 potential for an openhote sidetrack. The cost of collision is based on 2 days needed to accomplish a sidetrack,lateral isolation,and resume drilling. How could the probability of collision or the severity Estimate the total cost of C= $450,000 of the consequences be reduced?How might this collision impact the drilling operation? Cost: Is there a practical way One- to substantially reduce (to ro Estimate the NPV of the planned well either the probability of collision or the severity V= $15,500,000 of the consequences? • Accepting a finite risk of collision will reduce the NPV of the planned well.What reduction,as a fraction of the total NPV,are you prepared to tolerate?(Guideline=0.05) j - f F= 0.05 Estimate the total cost of substantially reducing V= $0 the risk V F 1 C= 1.722222222 Given the uncertainty in the above estimates,by how many times must the savings made from not reducing the risk outweigh he risk itself?(Guideline=20) M = 20 ► close approach tolerances need not F= 1 /M= 0.05 P Tolerable Collision Risk = be set OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: I - 3 1.( -U ( PTD: `Development Service Exploratory _Stratigraphic Test Non-Conventional FIELD: )4A,,,f) < K011— POOL: � �J�1 I4J14 0:1 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER I/ MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. J / —/0'1 , API No. 50- /03 - 9. h3C2_ -Co - 00 . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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