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212-048
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. 41c:Q - 0 if Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: o r Items: ❑ Ma s: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: `/ // /s/ Project Proofing BY: 40110Date: l f /if /s/ rillp Scanning Preparation I x 30 = 30 + = TOTAL PAGES (Count does not include cover sh et) 01 BY: Maria Date: I //Spit /s/ Production Scanning Stage 1 Page Count from Scanned File: 50 (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: 411M Date: t r J ! /s/ VV 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 .ate: /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 r o N ILL / 1 Q/Q / 11 n !a Z Z Z a o Z c } } } N f6 u N LL N I11 eg O 0 / OI N y Ti ✓ �' ~Ct. to Q I _ 0 N O) < `\ o a) m 0 - u) o Z` I Zj > _ + L .c O I 11 LI U d a o 0 LL 7,2- < m Q N co a N d a C N i� co I U U I - (�o p 15 o w Z_ \{ l 0 %- � N a° E CO ac) / < /Z N C am o CO L 0o E >- >- } R n u) m 0 0 < y o OCA 2 2 ~ U 75 N 0 O �-. a) y it d = C SIN NNNN aye a l6 1 a W J U N N N N N m N 7 Q Q 1 0 N y'N N N N N N Z Ul a Ce p n n n co .? co 1E U E , W 0 1 C c c c c iN ; 1ocou • J 2 2, a a a . a a) v) a U V O 00!0 0 0 0 0 E Z r 1 ce Iu ui «) U Illt 10 dN I 'MMMM yO a) _ N 0 o co a E =a n111 m1 o UiI c� M c / Zc ti; n n n o mN5 r O II, rnNlrn rn rn rn O p nU E1 a 11 ) Q 0 o E / Z J ~ U Viz° rI Q c N / I E.- oW Jo00 _ �� = Z Cl � U U 0 i0 y co c N a) CI in co f `1 CO CL co J b7 N Ln 1.0 C g E 1 Y tie c Z' 0 ai O) N Cn re Q co 0 co C C C , d C 'J 1 - O Q O m f0 Co Y 0 ° a r - \ IIIII pZ o / Z1 w wL ww . 2 a) .�Q O) CC N IA V) V) 2 Q Z = 0 a) N N N CO d 3 co E -2o o .o .o 0 /a �'- �� �a o z uup') �' z; 7 7 7 7 0 1 w i� D o ` , ai } >- r ' o 0 Z o y ` o I E o c / co p J O d M I p W, O 1 m o 1 f= w u .3 E 0 N _ w E a m N O 0 w W Z N d W • O N �O Q c w y a a) Q c I aa)) LL g € '�3 E E j z co m y ;� D rn ! CL � 01LL •w N z 0 ~ co 1 a) 2 M 0 O 8 y J (I) Q o o I c W LL a) _ Z W J O 0 v m m o 5 Q w O a o E a • o c7 � H a -- a a o) o) rn a - LL E o o E E O. ICL ; o H 3 ra w J J 0 Q 0 a 0 0 0 7 / / 1 / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class. 20AAC 25 105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: June 4,2012 , 212-048/ - 3.Address. 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 May 31,2012 • 50-103-20147-62 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2538'FNL,220'FEL,Sec.23,T12N,RO8E,UM June 3,2012 i 3G-22AL2-01 Top of Productive Horizon 8. KB(ft above MSL): c 3 ' B/J 15.Field/Pool(s): 2631'FNL, 1509'FEL,Sec.27,T12N,RO8E,UM GL(ft above MSL): AMSL'- F ' ' Kuparuk River Field Total Depth 9.Plug Back Depth(MD+TVD): 2584'FSL, 1551'FEL,Sec.27,T12N, RO8E,UM 11386'MD/5853'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD). 16.Property Designation. Surface: x-498160 ' y- 5988561 - Zone-4 ..11390'MD/5853'TVD . ADL 25547,25549 ' TPI: x-491594 y- 5983192 Zone-4 11.SSSV Depth(MD+TVD) 17 Land Use Permit Total Depth: x-491552 y- 5983128 Zone-4 1906'MD/1784'ND 2661,2663 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) 1600'MD/1539'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22 Re-drill/Lateral Top Window MD/TVD GR/Res,CBL 9628'MD/5903'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 216 sx AS I 9.625" 36# J-55 36' 4042' 36' 2947' 12.25" 950 sx AS III,550 sx Class G 7" 26# J-55 36' 9764' 36' 6076' 8.5" 200 sx Class G 4.5" 12.6# L-80 9150' 9611' 5734' 5994' 6.125" 21 bbls 15 8 cement 2.375" 4.6# L-80 9410' 11386' 5882' 5853' 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" 9177' 9126'MD/5720'ND 9411-11385'MD 5882'-5853'ND slotted liner 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED (� I .COWIE 'SI t iii. RECEIVED_ ¢ � 24. JUy 2 i 2012 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) /�OG gas lift oil /� Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Penod-> Flow Tubing Casing Pressure Calculated 'OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ , Sidewall Cores Acquired' Yes ❑ No E. If Yes to eitherquestion,list formations and intervals cored(MD+TVD of topand bottom of each),and summarize lithologyandpresence 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 P ) P NONE RBDMS JUN 2 7 2012 4w Form 10-407 Revised 12/2009 1/1--- /1 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS(List all formations and r. s encountered): 29. FORMATION TESTS NAME MD TVD Well tested" Yes 2 No• If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1600' 1539' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A3 9666' 5898' Kuparuk C 9753' 5880' Kuparuk A3 9897' 5878' Kuparuk C 9948' 5878' Kuparuk A3 10239' 5872' Kuparuk C 11003' 5864' Kuparuk A3 11193' 5859' Kuparuk C 11313' 5860' N/A Formation at total depth: Kuparuk C • 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ql er @ 265-1102 Printed Nam L. ntt _ Title: CTD Supervisor / Signature t11'Y Lv\ r tl# Phone 263-4021 Date (�/24/r INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 A', KUP 3G-22AL2-01 Conoco.Phillips 1= Well AttributesI/UMax Angle&MD TD Inc Wellbore APWI Field Name Well Status Incl(°) MD(RKB) Act Btm(SLOB) Alaska. C0110u.161169- pa 501032014762 KUPARUK RIVER UNIT PROD •"" Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ••• Well Canfi9:-3G-22AL2-01,6/20/20122:30'46 PM SSSV:TRDP 110 11/3/2010 Last WO: 37.11 10/30/1990 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,472.0 11/22/2011 Rev Reason:ADD SIDETRACKS ninam 6/20/2012 HANGER,24lilt 1 Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER AL2-01 23/8 1.992 9,410.5 11,386.0 4.70 L-80 STL Liner Details Top Depth (TVD) Top Incl Nomi... CONDUCTOR, I Top(RKB) IRKS) (') Item Description Comment ID(in) 36-115 1 9,410.5 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.900 10,380.2 DEPLOY DEPLOYMENT SLEEVE 1.900 SAFETY 9LV. ,J �� 1.907 �1 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens GAS LIFT, Top(RKB)Btm IRKS) (RKB) (RKB) Zone Date (eh-- Type Comment 3,160 — 9,417 10,380 6/4/2012 32.0 SLOTS SLOTTED LINER 10,381 11,386 6/4/2012 32.0 SLOTS SLOTTED LINER Notes:General&Safety End Date Annotation SURFACE, 6/20/2012 NOTE:LATERAL 3G-22AL2-01 OFF MAIN WELLBORE A(See Multi-lat Drawing) 354.042 6/20/2012 NOTE:WELL SIDETRACKED:ADDED LATERALS AL1,AL2,AL2-01(See Multi-lat Drawing) GAS LIFT, 5,446 GAS LIFT,_ _ p 7.133 l hlGAS LIFT,_. J _ 8,328 MIN GAS LIFT, _ 9.033 NIPPLE.9,093 11 Ir LOCATOR, 9.135 y` ` 0 SEAL ASSY, _ ) ' 9,140 I � WLEG,9.177 -- WINDOW, 9.412-9.417 WHIPSTOCK, 9,418 BILLET.9,550 SCAB LINER. 9,1289,611 PRODUCTION, 35-9,764 SLOTS, 9,417-10,380 SLOTS. 9,656-10,288 SLOTS, e.e00-10.490 _ Mandrel Details L Top Depth Top I Port I SLOTS. . (TVD) Incl OD Valve Latch Size TRO Run 10.381-11,388 WI Sin Top OMB) (RKB) (°) Make Model (in) Sery Type Type UN (psi) Run Date Com... SLOTS, 10,290-11,702 _ 1 3,160.1 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,217.0 6/17/2012 • 10.49iiiOn .TS. 2 5,445.5 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1209.0 6/172012 10,801-070941 3 7,1332 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,198.0 6/16/2012 LINER AL2-01, 9,410-11,3661 ' 4 8,328.3 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1, 187.0 6/15/2012 LINER ALI, (_ 9,589-11,774 1 5 9,032.9 CAMCO MMG 1 12 GAS LIFT OV RK 0.250 0.0 6/17/2012 e uommi LINER AL2, 9,8SLD SLOTTED LINER A. 10,590-17,9411 TD (3G-22A 191 11.969 o ;_ § g[ \ CO rsi \\(N—© Na� ) CO §p)f .1-- Z-Lo \\ / © ® \ q} __ \/ CC 2 §j/ § ( \ )} mg} $ c - ; \ X \ E� - \0/ - ( co ) \} Si ; - ) ) 7 cllgzo \ )/q ] { A 2 / {& E." \e �2u § ] _ ci \ § \ §j} / -01: 3cog a=2 • - — $b = k\ , j© j j / \ §§) § \ } } ) . P_' ,)110, H0 ) c R i \ Z,,I,\ , ‘C*vl ,bLOi § 2\ § \\ 2\ . 2) i' ar �• /«©®©r . � . � . 1 lInn t . : . , . . . . § .\ ' d M ,4 « • 2 « m z< ^I— -, \ CD 0 . . . . . ! 1/3 i „ i ,i i i i; C - H 01 jg .— -0/ H / % IL \; \/ \ w . 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(; (' C• 0 4) N m N 6 (O M N O 6 6 o6 O 6 O N N N O O 4) r O N .- V 6 (O Z lye 0 Y Y c') (o (o m m m m m m o m m rn co co co m co m m co m com rn m co m CO m co m m m - a. P O co V r U, V � (07 M m M T N .4 M MNV O 0 N CD N m O LMn O N g O O O m m4O NO >. hi' 6 0 0 0 O O O o O O O O O N N O O 4 f 6.- N 6 O O O O O N (n 4 O N ❑ _� O N (D co ,- V i- rO co co co N 4) n O C N- m N (O N 4co V 1-- o co V m '"CRS aC >. C 4 N 4) (O CD 0 r t` CO CO m m m m O O O N N N COM M M FOO. d .. , 0 £ O y c 0 0 0 0 0 0 0 0 o O 0 0 CO.. 0 0 0 0 0 .- .- V d N U a N 0 N O 1, 3G-22 Pre Rig Well Work DATE SUMMARY 2/6/12 ASSISTED VALVE CREW PULLING BPV. DRIFTED TBG WITH 2.79" GAUGE & SAMPLE BAILER; ENCOUNTER THICK DRILLING MUD @ 9105' SLM. IN PROGRESS. 2/7/12 SET CATCHER. PULLED SOV @ 9032' RKB& REPLACED W/DV. MITIA TO 2500 PSI, PASS. PULL CATCHER. COMPLETE 2/9/12 CIRCULATED OUT DRILLING MUD FROM TBG. DISPLACED WITH SEAWATER AND FREEZE PROTECTED TO 2500'ND. JOB COMPLETE. 2/10/12 TAGGED @ 9442' SLM WITH 2.79" GAUGERING.RAN 2.62" OD X 17.3' OAL DUMMY WHIPSTOCK DRIFT WITH NO PROBLEMS.READY FOR ELINE. 2/12/12 LOGGED CEMENT BOND LOG AND GAMMA/CCL CORRELATION FROM A TAG DEPTH OF 9480'-9000'. RIGGED DOWN AND TURNED WELL OVER TO DSO. 4/25/12 PRE-CTD--PT/DT ON ALL VALVES, SV(PASSED), SSV(PASSED), MV(PASSED), SSSV (PASSED} ConocoPhillips Time Log & Summary Wel'view Web Reporting ^e p o rt Well Name: 3G-22 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 5/16/2012 10:00:00 AM Rig Release: 6/5/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/15/2012 24 hr Summary RDMO 1 E-05 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Move Off 1 E pad @ 12:00 to 3G-22 05/16/2012 MIRU, BOPE test 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Arrive on 3G-22, R/D Jeeps,Spot Rig, Sub and shop _ 03:00 06:00 3.00 0 0 MIRU MOVE MOB P R/D Jeeps, Spot Rig, Sub and shop 06:00 10:00 4.00 0 0 MIRU MOVE MOB P Rig Up, Putz,steam,water, power, test rig emergency shut down test, go to high line power 10:00 11:00 1.00 0 0 MIRU WHDBO NUND P Accept rig @ 10:00, Nipple up stack 11:00 21:30 10.50 0 0 MIRU WHDBO BOPE P Start BOPE Test,witness waived by Matt Herrera,AOGCC. Changed out top set blind shears. 21:30 23:00 1.50 0 0 MIRU WHDBO BOPE P Pull BPV 23:00 00:00 1.00 0 0 MIRU WHDBO SLPC P Remove CTC, pump slack,test inner reel valve and tiger tank line 05/17/2012 Cut coil for pipe management, rehead, run whipstock and set at 9416',start milling window 00:00 04:00 4.00 0 0 MIRU WHDBO SLPC P Cut 300'CT for pipe life management, Found wire at 30'. Install CTC Attemp to pull test CTC, unable to pull past 20K on Injector 04:00 06:30 2.50 0 0 MIRU WHDBO PRTS P Inspect and pressure test PDL's,TT Line 06:30 07:00 0.50 0 0 MIRU WHDBO RGRP P Complete injector drive shaft replacement, Pull test CTC to 38K 07:00 07:45 0.75 0 0 MIRU WHDBO CTOP P Head up upper Quick connect 07:45 08:00 0.25 0 0 MIRU WHDBO PRTS P Pressure test UQC to 4K 08:00 09:15 1.25 0 75 PROD1 RPEQPI PULD P PJSM, P/U whipstock BHA#1, M/U to coil track,Surface test tool,tag up and set counter 09:15 11:30 2.25 75 9,255 PROD1 RPEQPITRIP P RIH, EDC Open, on Seawater, returns to TT 11:30 11:54 0.40 9,255 9,245 PROD1 RPEQPI DLOG P Log GR tie in for-16', PUW=38K 11:54 12:36 0.70 9,245 9,429 PROD1 RPEQPITRIP P Trip in to set depth of 9428.98, TOWS 9416 Oriented to high side, Shut EDC Pumps on @.5 BPM see tool shift @ 2500 PSI, set down on whipstock—3K looks good, PUH to 9400 Circulate mud around Page 1 of 15 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:36 15:06 2.50 9,429 71 PROD1 RPEQP1TRIP P 9.7 PPG milling fluid 10 BBIs out, trip out for window milling BHA first run. 15:06 16:12 1.10 71 73 PROD1 WHPST PULD P PJSM, Stand back coil track BHA #1 whipstock setting tools, M/U BHA #2,window milling first run.2.80 window mill,2.79 string mill, .6 degree AKO motor,Service Injector, inspect packoffs 16:12 18:42 2.50 73 9,280 PROD1 WHPST TRIP P Trip in well, EDC open 18:42 19:00 0.30 9,280 9,300 PROD1 WHPST DLOG P Tie-in,-17' 19:00 00:00 5.00 9,300 9,424 PROD1 WHPST MILL P Close EDC, 34K PUW, 17K RIW, tag WS at 9419.1'and start time milling. 1.5 BPM, 3500 CTP, 3680 BHP 05/18/2012 Milled window at 9419'and rat hole to 9437'. 00:00 02:00 2.00 9,424 9,424 PROD1 WHPST MILL P Continue milling window, ream window, 3 times up and down. Drift window with pump down. 02:00 05:00 3.00 9,424 0 PROD1 WHPST TRIP P POOH. Overpull at 9190 bit depth, orient low side to pass. There is a 0.125"lip at the XO on the pup joint that would be at the WLEG/Muleshoe at this depth. 05:00 06:30 1.50 0 0 PROD1 WHPST PULD P Change out motor and mills,Well started to flow while pulling toolstring,Shut swab valves and opened MP line to monitor WHP. 730 PSI WHP after 30 minutes(6:30) 06:30 07:15 0.75 0 0 PROD1 WHPST PULD P Pull QTS and install pressure cap. Open up against closed choke, Shut SSSV and monitor for flow 07:15 07:57 0.70 0 72 PROD1 WHPST PULD P SSSV pass No Flo test. P/U BHA#3 1.2 Degree Motor,2.80 Fat radius Mill and 2.79 String reamer, Make up coil and surface test,Tag up and set counters 07:57 10:15 2.30 72 9,275 PROD1 WHPST TRIP P Pressure up WHP, open SSSV, RIH 10:15 10:27 0.20 9,275 9,300 PROD1 WHPST DLOG P Log K-1 for-19'correction, Close • EDC, PUW=33K 10:27 10:45 0.30 9,300 9,424 PROD1 WHPST TRIP P Trip in to dry tag 7"casing, Light tag <1000lbs DHWOB 10:45 11:03 0.30 9,424 9,416 PROD1 WHPST CIRC P PUH, Pumps on @ 1.5 BPM, getting ready to start milling out density drop. light gas.divert to TT., Pumped 15 BBIs, Out density back in range bring returns in 11:03 18:30 7.45 9,416 9,427 PROD1 WHPST MILL P Mill window per procedure, High side TF, 1.53 BPM @ 3615PS1 FS, BHP=3708,Wide Open Choke, See motor work @ 9423.9,Start time schedule from here. Page 2 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:30 21:06 2.60 9,427 9,430 PROD1 WHPST MILL P Started stacking weight with no additional motor work. Increased WOB to 5.2K and started getting motor work., continued at 1 FPH 21:06 23:36 2.50 9,430 9,437 PROD1 WHPST MILL P Drilling formation, 1 FPH to 9431.5 then drill ahead. 23:36 00:00 0.40 9,437 9,437 PROD1 WHPST REAM P Ream window 05/19/2012 Drilled build section to 9825', Drilled lateral to 9968' 00:00 01:24 1.40 9,437 9,411 PROD1 WHPST REAM P Continue reaming passes,dry drift clean 01:24 02:06 0.70 9,411 9,411 PROD1 WHPST OWFF P Shut in well for static BHP. Initial shut in pressure was 750 WHP and 3773 BHP. After 10 min. bled downpressure to 450 WHP and 3570 BHP. After 30 min. Final pressure was 770 WHP and 3755 BHP(12.54 ECD),TVD of DPS was 5775. 02:06 04:36 2.50 9,411 0 PROD1 WHPST TRIP P POOH using MPD tripping schedule for 12.5 ECD at the window,Overpull at 9190'bit depth,orient low side to pass.There is a 0.125"lip at the XO on the pup joint that would be at the WLEG/Muleshoe at this depth. Jet SSSV. 04:36 04:54 0.30 0 0 PROD1 WHPST SFTY P Shut SSSV, PJSM while monitoring well 04:54 05:24 0.50 0 0 PROD1 WHPST PULD P Lay down milling BHA 05:24 06:09 0.75 0 62 PROD1 DRILL PULD P MU drilling BHA#4 for build section, 2.3 degree motor and RR hycalog bit, Make up Coil and surface test tool,equalize SSSV, pump open 06:09 08:51 2.70 62 9,255 PROD1 DRILL TRIP P RIH with EDC open 08:51 09:09 0.30 9,255 9,437 PROD1 DRILL DLOG P Log K-1 tie in for-18',Trap pressure and shut EDC, 09:09 09:27 0.30 9,437 9,438 PROD1 DRILL TRIP P Trip in to drill, RIW=15.4, PUW 32.5K @ 9396 09:27 11:12 1.75 9,438 9,590 PROD1 DRILL DRLG P 9438', Drill Ahead 1.4 BPM @ 3450 PSI FS, BHP=3790 11:12 12:00 0.80 9,590 9,590 PROD1 DRILL WPRT P 9590',Wiper trip to window with tie in to K-1 for+.5"correction, Log RA @ 9424.0 Official TOWS=9417 (9416.65) 12:00 13:36 1.60 9,590 9,740 PROD1 DRILL DRLG P 9590', Drill Ahead, 1.46 BPM @ 3460 PSI FS, BHP=3787 13:36 14:06 0.50 9,740 9,740 PROD1 DRILL WPRT P 9740,Wiper to window,puw=34K 14:06 15:06 1.00 9,740 9,825 PROD1 DRILL DRLG P 9740', Drill Ahead, 1.45 BPM @ 3520 PSI FS, BHP=3912 15:06 18:06 3.00 9,825 0 PROD1 DRILL TRIP P 9825 End of Build/Turn,trip out for RSM, PUW=33K,Open EDC Above window,Avg DLS 42.3 18:06 18:42 0.60 0 0 PROD1 DRILL SFTY P Crew change out, Monitor well for no flow, PJSM Page 3 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:42 19:42 1.00 0 0 PROD1 DRILL PULD P Lay down build BHA,MU lateral BHA with RSM and rebuild Hughes bi-center 19:42 21:54 2.20 0 9,250 PROD1 DRILL TRIP P RIH 21:54 22:12 0.30 9,250 9,280 PROD1 DRILL DLOG P Tie-in,-18' 22:12 22:30 0.30 9,280 9,825 PROD1 DRILL TRIP P Continue RIH, 16K RIW 22:30 00:00 1.50 9,825 9,968 PROD1 DRILL DRLG P Drilling ahead, 1.4 BPM, 3500 CTP, 3825 BHP with 70 WHP 05/20/2012 Drilled"A"lateral to 11075' 00:00 00:06 0.10 9,968 9,975 PROD1 DRILL DRLG P Continue drilling lateral, 1.45 BPM, 3600 CTP, 3868 BHP with 74 WHP 00:06 01:12 1.10 9,975 9,440 PROD1 DRILL DLOG P MAD pass build section, 32K PUW 01:12 01:36 0.40 9,440 9,975 PROD1 DRILL WPRT P Wiper back in hole 01:36 02:54 1.30 9,975 10,125 PROD1 DRILL DRLG P Continue drilling lateral, 1.45 BPM, 3600 CTP, 3868 BHP with 74 WHP 02:54 03:42 0.80 10,125 10,125 PROD1 DRILL WPRT P Wiper to window 03:42 05:30 1.80 10,125 10,275 PROD1 DRILL DRLG P Continue drilling lateral, 1.45 BPM, 3600 CTP, 3868 BHP with 74 WHP 05:30 06:45 1.25 10,275 10,275 PROD1 DRILL WPRT P Pumped sweeps. Wiper to the window,with tie in for+3' 06:45 07:51 1.10 10,275 10,425 PROD1 DRILL DRLG P 10275', Drill Ahead, 1.41 BPM @ 3630 PSI FS, BHP=3910 with 85 PSI WHP 07:51 09:15 1.40 10,425 10,425 PROD1 DRILL WPRT P Wiper to window with sweeps, PUW=32K 09:15 10:45 1.50 10,425 10,575 PROD1 DRILL DRLG P 10425', Drill Ahead, 1.41 BPM @ 3610 PSI FS, BHP=3918, WHP=100, RIW=14.6 10:45 12:27 1.70 10,575 10,575 PROD1 DRILL WPRT P Wiper to window with sweeps, PUW=32.5k 12:27 13:54 1.45 10,575 10,725 PROD1 DRILL DRLG P 10575' Drill Ahead, 1.4 BPM @ 3600 PSI FS, BHP=3933,WHP=90 PSI 13:54 15:30 1.60 10,725 10,725 PROD1 DRILL WPRT P 10725',Wiper to window with sweeps and tie in, PUW=34K,Correct+2' 15:30 . 17:00 1.50 10,725 10,875 PROD1 DRILL DRLG P 10725', Drill ahead, 1.43 BPM @ 3609 PSI FS, BHP=3920,WHP=70 PSI 17:00 19:06 2.10 10,875 10,875 PROD1 DRILL WPRT P Wiper to 3.5"Tubing, PUW=34K 19:06 22:00 2.90 10,875 11,075 PROD1 DRILL DRLG P Continue drilling, 1.42 BPM,3600 CTP, 3918 BHP, 10K RIW,swap mud 22:00 00:00 2.00 11,075 PROD1 DRILL WPRT P Wiper to window,34K PUW 05/21/2012 Drilled"A"Lateral to 11960 00:00 01:00 1.00 11,075 11,225 PROD1 DRILL DRLG P Continue drilling, 1.46 BPM, 3550 CTP, 3990 BHP, 12K RIW 01:00 02:12 1.20 11,225 9,450 PROD1 DRILL WPRT P Wiper to the window, 33K PUW 02:12 02:24 0.20 9,450 9,585 PROD1 DRILL DLOG P Tie in,+4' 02:24 03:18 0.90 9,585 11,225 PROD1 DRILL WPRT P Wiper back in hole Page 4 of 15 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 03:18 04:42 1.40 11,225 11,375 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM,3600 CTP,3950 BHP with 135 WHP, 04:42 07:24 2.70 11,375 11,375 PROD1 DRILL WPRT P Wiper to the window and up to 3 1/2 07:24 08:48 1.40 11,375 11,525 PROD1 DRILL DRLG P 11375',drill ahead, 1.5 BPM @ 3820 PSI FS, BHP=3924 08:48 11:00 2.20 11,525 11,525 PROD1 DRILL WPRT P Wiper to window with sweeps, PUW=32.5K, RIW=12K @ 10250', RIW=9K @ 11050' 11:00 13:00 2.00 11,525 11,675 PROD1 DRILL DRLG P 11525',Drill ahead, 1.5 BPM @ 360 PSI FS, BHP=3975,WHP=130 13:00 16:00 3.00 11,675 11,675 PROD1 DRILL WPRT P 11675 Wiper trip to window with sweeps and tie in, PUW=35.5K, Correction,+2' 16:00 17:30 1.50 11,675 11,825 PROD1 DRILL DRLG P 11675', Drill Ahead, 1.4 BPM @ 3410 PSI FS, BHP=3990, WHP=170,RIW=8.7K 17:30 20:24 2.90 11,825 11,825 PROD1 DRILL WPRT P Wiper to the window 20:24 00:00 3.60 11,825 11,960 PROD1 DRILL DRLG P Continue drilling,-2K RIW, 1.4 BPM, 4020 BHP,sliding issues,pump sweeps. Also increased lubricants to 2%each. No measurable benefit observed. 05/22/2012 TD"A"Lateral 11969'.Wiper Trip back to tubing tail. RBI,lay in liner running pill in OH, POOH.Close SSSV, PU/MU/RIH 40jnts slotted liner with OH anchered billet.Set 11941.3 BOL, 10650'TOB, HS. BOPE Function test 00:00 00:42 0.70 11,960 11,971 PROD1 DRILL DRLG P Continue drilling,pump sweeps 00:42 02:12 1.50 11,971 9,150 PROD1 DRILL WPRT P Wiper to the tubing tail,33K PUW 02:12 02:30 0.30 9,150 9,300 PROD1 DRILL DLOG P Tie in to K1,+1.5' 02:30 03:54 1.40 9,300 11,969 PROD1 DRILL WPRT P Wiper back in hole 03:54 07:24 3.50 11,969 48 PROD1 DRILL TRIP P Trip out of hole laying in beaded liner running pill,PUW=35K.Paint EOP flags @ 10400 and 7900' 07:24 08:24 1.00 48 0 PROD1 DRILL PULD P At surface, PJSM,Shut SSSV and flow check well, Lay down RSM BHA #5 08:24 09:24 1.00 0 0 COMPZ CASING OTHR P Service injector while rigging up floor for tubing pick up 09:24 09:54 0.50 0 0 COMPZ CASING SFTY P PJSM 09:54 10:18 0.40 0 0 COMPZ CASING PUTB P Run 40 joints slotted liner 10:18 10:48 0.50 0 0 COMPZ CASING SFTY P Safety joint drill and post drill review 10:48 13:42 2.90 0 1,400 COMPZ CASING PUTB P Continue running liner,MU anchored billet and injector 13:42 16:00 2.30 1,400 9,312 COMPZ CASING RUNL P RIH 16:00 17:30 1.50 9,312 11,942 COMPZ CASING RUNL P Correct to flag,-17.8',close EDC, 34K PUW, 15K RIW,-5K WOB 17:30 20:45 3.25 11,941 0 COMPZ CASING RUNL P Orient anchor highside,set anchor, TOWS at 10590'. POOH 20:45 21:00 0.25 0 0 COMPZ CASING RUNL P At surface,Close SSSV,Monitor well for flow,PJSM 21:00 22:00 1.00 0 0 COMPZ CASING RUNL P LD BHA#6 Page 5 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 23:30 1.50 0 0 PROD2 STK SVRG P Service Injector head and reel. Perform Function test on BOP, reset computers for new lateral. 23:30 00:00 0.50 0 2,500 PROD2 STK TRIP P RIH 05/23/2012 KO anchored billet 40 LOHS, Drill"AL1"lateral. Swap out drilling mud. Increase lubes 2/2. 00:00 01:30 1.50 2,500 9,250 PROD2 STK TRIP P Cont RIH 01:30 01:45 0.25 9,250 9,250 PROD2 STK DLOG P Tie in depth,-19.5' 01:45 02:30 0.75 9,250 10,590 PROD2 STK TRIP P Cont RIH 02:30 05:00 2.50 10,590 10,603 PROD2 STK KOST P KO billet at 1' FPH for 1' 2'FPH for 1' 3' FPH for 1' 5'FPH for 2' 10 FPH for 5' 20'FPH for 5'assuring past anchor 05:00 05:18 0.30 10,603 10,625 PROD2 DRILL DRLG P Drill Ahead 05:18 06:48 1.50 10,625 10,740 PROD2 DRILL DRLG P Drift billet kick off, clean continue drilling ahead, 1.4 BPM, 3600 CTP, 3950 BHP, 100 WHP 06:48 08:42 1.90 10,740 10,740 PROD2 DRILL WPRT P Wiper trip to window,32K PUW, some over pull and motor work at 10200 to 10170 up and down 08:42 10:12 1.50 10,740 10,890 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3700 CTP, 3950 BHP, 10K RIW 10:12 12:18 2.10 10,890 10,890 PROD2 DRILL WPRT P Wiper to window,34K PUW. Over pull and motor work at 10175 coming up,stalled motor, RIH and work free then continued PUH. 12:18 13:30 1.20 10,890 11,040 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3700 CTP, 3950 BHP, 10K RIW 13:30 14:42 1.20 11,040 9,440 PROD2 DRILL WPRT P Wiper to window, 34K PUW, held low side TF and 20 FPM from 10250' to 10125', some overpull with motor work at 10178'to 10140' 14:42 14:54 0.20 9,440 9,480 PROD2 DRILL DLOG P Tie-in, +4.5' 14:54 15:48 0.90 9,480 11,040 PROD2 DRILL WPRT P Wiper back in hole 15:48 17:18 1.50 11,040 11,190 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3700 CTP, 3960 BHP,6K RIW 17:18 19:36 2.30 11,190 11,190 PROD2 DRILL WPRT P Wiper to the window, pull heavy 10220- 10120'. Orient LS. Max pull 48K,with motor work. Did not see anything thru this area going down 19:36 20:36 1.00 11,190 11,250 PROD2 DRILL DRLG P Drill Ahead start swapping out mud, stacking weight, PU/RIH attempt to drill, 20:36 23:00 2.40 11,250 11,340 PROD2 DRILL DRLG P New mud around, Drill ahead 1.4 BPM, 1.7 WOB, 3882 CTP, Continued stacking, Increase lubes in drilling mud to 2/2 23:00 00:00 1.00 11,340 11,340 PROD2 DRILL WPRT P Wiper trip to window 34K PUW, Orient LS PU thru 10120-10220.4K overpull,250psi motor work.much better LS Page 6of15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/24/2012 24 hr Summary Drill"AL1"Lateral to TD 11782'.Wiper Trip back to TT, RBIH, lay in liner running pill. POOH. 00:00 01:00 1.00 11,340 11,340 PROD2 DRILL WPRT P Continue wiper trip.Orient HS going thru 10120-10220. Looked good. 01:00 03:00 2.00 11,340 11,490 PROD2 DRILL DRLG P Drill Ahead 1.45 BPM,3950 CTP, -4K CTW, 1.6 WOB, 166 WHP,3981 BHP 03:00 04:00 1.00 11,490 9,440 PROD2 DRILL WPRT P Wiper trip to window,Orient LS thru 10170 area. Looked good,small amount of motor work and 3K over pull 04:00 04:15 0.25 9,440 9,440 PROD2 DRILL DLOG P Tie in depth+1'correction 04:15 05:30 1.25 9,440 11,490 PROD2 DRILL WPRT P RBIH 05:30 08:24 2.90 11,490 11,640 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3650 CTP,3980 BHP, 130 WHP 08:24 10:54 2.50 11,640 11,640 PROD2 DRILL WPRT P Pump sweeps,wiper to the window 10:54 15:18 4.40 11,640 11,783 PROD2 DRILL DRLG P Continue drilling, 1.43 BPM,3700 CTP,3980 BHP, 140 WHP,8K RIW 15:18 19:18 4.00 11,783 11,783 PROD2 DRILL WPRT P TD"AL1"Lateral,Wiper to TT;35K PUW.Tie in depth-.5'. RBIH, Condition hole,during"I Believe" Presentation with D&W manager (Shon). 19:18 23:00 3.70 11,783 0 PROD2 DRILL TRIP P Tag TD. 11782'. POOH laying in liner running pill in OH. Paint EOP flags 10471.8 and 8071', 23:00 23:15 0.25 0 0 PROD2 DRILL SFTY P At surface.Close SSSV,monitor well for flow. PJSM. 23:15 23:45 0.50 0 0 PROD2 DRILL PULD P LD BHA 7. 23:45 00:00 0.25 0 0 COMPZ CASING SVRG P Prep floor to run liner 05/25/2012 PU/MU/RIH/Release"AL1"lower liner BOL-11782'.TOL-10497'. POOH. PU/MU/RIH upper"AL1"liner with anchored billet. Set 170 deg.TOB-9589. POOH. 00:00 00:15 0.25 0 0 COMPZ CASING SVRG P Cont preping floor 00:15 02:30 2.25 0 0 COMPZ CASING PUTB P PU"AL1"Liner 02:30 04:15 1.75 1,321 9,338 COMPZ CASING RUNL P RIH 04:15 04:21 0.10 9,338 9,338 COMPZ CASING DLOG P Tie in depth to EOP flag-17',record up and down weights,33K up, 14K RIW 04:21 05:36 1.25 9,338 11,782 COMPZ CASING RUNL P Continue to RIH to TD,tag TD and pump off liner 05:36 08:36 3.00 !11,782 0 COMPZ CASING RUNL P POOH 08:36 09:06 0.50 !0 0 COMPZ CASING SFTY P PJSM while monitoring well for flow 09:06 12:00 2.90 0 0 COMPZ CASING PUTB P Lay down BHA, MU lower liner sting 12:00 12:30 0.50 0 0 COMPZ CASING SFTY P Crew change,PJSM 12:30 14:00 1.50 0 968 COMPZ CASING PUTB P Continue run liner,MU BHA and injector Page 7 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:00 14:48 0.80 968 968 COMPZ CASING SVRG P Work on Expro Choke panel ***Nabors 1 hour billable rig repair rate*** 14:48 16:48 2.00 968 9,268 COMPZ CASING RUNL P RIH 16:48 18:00 1.20 9,268 10,497 COMPZ CASING RUNL P Correct to flag, close EDC,31K PUW, 16K RIW,-4K WOB Continue RIH 18:00 18:15 0.25 10,497 10,497 COMPZ CASING RUNL P Orient to 170 Deg.and set anchor., Billet at 9590'. POOH 18:15 18:30 0.25 10,497 10,497 COMPZ CASING RUNL P Crew change 18:30 18:45 0.25 10,497 9,373 COMPZ CASING RUNL P Cont. POOH. 18:45 19:45 1.00 9,373 9,373 COMPZ CASING RUNL P Stop and circulate bottoms up. 19:45 20:45 1.00 0 COMPZ CASING RUNL T Work on Expro choke panel 20:45 22:45 2.00 9,373 0 COMPZ CASING RUNL P POOH, unable to get Expro panel powered up. 22:45 23:00 0.25 0 0 COMPZ CASING SFTY P At surface. PJSM 23:00 00:00 1.00 0 0 COMPZ CASING PUTB P LD BHA 9 05/26/2012 KO anchored billet for"AL2"lateral. Drift successful, drill ahead.Tag billet on first wiper trip. Unable to dress billet successful. POOH, PU/MU/RIH anchored billet with 1 jnt of slotted liner. Set single slip on anchored billet 345 deg TF. 9550'TOB. POOH 00:00 02:00 2.00 0 0 PROD3 DRILL SVRG T Work on Expro panel ***Nabors 2 hrs billable rig repair rate*** 02:00 03:00 1.00 0 0 PROD3 STK PULD P PU BHA 10 03:00 05:42 2.70 72 9,275 PROD3 STK TRIP P RIH 05:42 06:06 0.40 9,275 9,589 PROD3 STK DLOG P Tie-in,-18', 06:06 09:06 3.00 9,589 9,620 PROD3 STK KOST P Tag billet at 9589'and start milling, 1.45 BPM,3700 CTP,3840 BHP. 31K PUW, 15K RIW,drift window dry. 09:06 11:00 1.90 9,620 9,740 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM , 3600 CTP,3820 BHP, 130 WHP, 14K RIW 11:00 12:00 1.00 9,740 9,589 PROD3 DRILL WPRT P Wiper to the window,at 9630 bit depth WOB went from 0 to-500. On trip back in tagged at the top of the billet. Tried 200 and 270 deg TF with no pump. tried 200 TF with 0.15 BPM and saw motor work with tag 12:00 14:06 2.10 9,589 9,589 PROD3 STK KOST T attempted to drill past billet,2-3 FPH with no motor work or WOB. Went down to 9595'. PUH and attempt to drift,tagged up at 9589' 14:06 16:24 2.30 9,589 0 PROD3 STK TRIP T POOH 16:24 16:42 0.30 0 0 PROD3 STK SFTY T PJSM, monitor well for no-flow 16:42 17:42 1.00 0 0 PROD3 STK PULD T Lay down drilling BHA, Page 8 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:42 18:12 0.50 0 0 PROD3 STK SFTY T Crew change, PJSM 18:12 19:12 1.00 0 0 PROD3 STK PULD T PU/MU anchored billet with 1 jnt slotted liner 19:12 21:45 2.55 0 9,310 PROD3 STK TRIP T RIH 21:45 22:00 0.25 9,310 9,310 PROD3 STK DLOG T Tie in depth-21'correction. Record up weight 32K. 22:00 22:18 0.30 9,310 9,595 PROD3 STK TRIP T RIH setting depth 22:18 22:30 0.20 9,595 9,595 PROD3 STK WPST T Anchored Billet on depth 9595'bit depth.5'past placing slots across AU billet.4100 psi anchor set.Set down 2K WOB.looked good. 22:30 00:00 1.50 9,595 3,000 PROD3 STK TRIP T POOH 05/27/2012 KO anchored billet 315 deg TF for"AL2"Lateral. Drill build/turn section of"AL2"Lateral. Landed 9723'.POOH PU/MU/RIH BHA 13(RSM). Drill"AL2"Lateral. 00:00 00:45 0.75 3,000 0 PROD3 STK TRIP T Cont.to POOH 00:45 01:00 0.25 0 0 PROD3 STK SFTY T At surface,flow check, PJSM 01:00 02:00 1.00 0 0 PROD3 STK PULD T LD BHA 11, PU/MU BHA 12(ldeg AKO, Bi-Center bit),Service Injector head,Change stripper rubber. 02:00 03:00 1.00 0 0 PROD3 STK SFTY T Shut down for Pre Spud Meeting 03:00 05:00 2.00 0 9,270 PROD3 STK TRIP T RIH 05:00 05:18 0.30 9,270 9,550 PROD3 STK DLOG T Tie-in,-17.5',close EDC, 05:18 08:42 3.40 9,550 9,580 PROD3 STK KOST T Tag billet and start time milling, 1.4 BPM,3600,3835 BHP, 120 WHP, 15K RIW. Milling was normal and continued drilling ahead,drifted billet clean. 08:42 09:54 1.20 9,580 9,690 PROD3 DRILL DRLG T Continue drilling ahead, 1.4 BPM, 3650 CTP,3840 BHP, 130 WHP 09:54 10:24 0.50 9,690 9,690 PROD3 DRILL WPRT Wiper to the window,billet drifted clean 10:24 11:06 0.70 9,690 9,723 PROD3 DRILL DRLG Continue drilling ahead, 1.4 BPM, 3650 CTP,3840 BHP, 130 WHP 11:06 13:36 2.50 9,723 0 PROD3 DRILL TRIP - Landed build/turn, POOH 13:36 14:00 0.40 0 0 PROD3 DRILL SFTY - PJSM while watching for no flow 14:00 15:12 1.20 0 0 PROD3 DRILL PULD - Lay down BHA#12, PU BHA#13 for drilling AL2 lateral 15:12 17:18 2.10 0 9,270 PROD3 DRILL TRIP - RIH 17:18 17:30 0.20 9,270 9,300 PROD3 DRILL DLOG Tie in,-21'correction 17:30 18:00 0.50 9,300 9,731 PROD3 DRILL TRIP - Continue RIH 18:00 20:30 2.50 9,731 9,875 PROD3 DRILL DRLG - Drill Ahead 1.4 BPM,3550 CTP, 3841 BHP,282 WHP 20:30 21:00 0.50 9,875 9,875 PROD3 DRILL WPRT - Wiper Trip to window 32K PUW 21:00 23:15 2.25 9,875 10,025 PROD3 DRILL DRLG - Drill Ahead 1.4 BPM,3775 CTP, 3889 BHP, 144 WHP 23:15 00:00 0.75 10,025 10,025 PROD3 DRILL WPRT P Wiper trip to window 32K PUW Page 9 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05/28/2012 24 hr Summary Drill"AL2"Lateral,swapped mud system. 00:00 02:00 2.00 10,025 10,175 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM,3775 CTP, 3889 BHP, 144 WHP 02:00 03:00 1.00 10,175 10,175 PROD3 DRILL WPRT P Wiper trip to window 32K PUW,tie in depth to RA marker. +3'correction 03:00 04:30 1.50 10,175 10,325 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM, 3900 CTP, 3888 BHP,65 WHP 04:30 05:30 1.00 10,325 10,325 PROD3 DRILL WPRT P Wiper trip 800'. 05:30 07:06 1.60 10,325 10,475 PROD3 DRILL DRLG P Continue drilling, 1.4 BPM,3800 CTP, 3950 BHP 07:06 08:06 1.00 10,475 10,475 PROD3 DRILL WPRT P Wiper to the window 08:06 09:42 1.60 10,475 10,640 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3630 CTP, 3940 BHP, 65 WHP 09:42 10:18 0.60 10,640 9,440 PROD3 DRILL WPRT P Wiper to the window,32K PUW, pumped sweeps and started mud swap 10:18 10:30 0.20 9,440 9,470 PROD3 DRILL DLOG P Tie-in, +3' 10:30 11:12 0.70 9,470 10,640 PROD3 DRILL WPRT P Wiper back in hole 11:12 12:36 1.40 10,640 10,790 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3700 CTP,3950 BHP,140 WHP, 12:36 13:54 1.30 10,790 10,790 PROD3 DRILL WPRT P Wiper to the window, 13:54 15:24 1.50 10,790 10,940 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3700 CTP,3950 BHP,140 WHP, 15:24 16:48 1.40 10,940 10,940 PROD3 DRILL WPRT P Wiper to the window,33K PUW 16:48 18:18 1.50 10,940 11,091 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3600 CTP, 3960 BHP,140 WHP, 18:18 20:18 2.00 11,091 11,091 PROD3 DRILL WPRT P Wiper trip to window 32K PUW.Tie in depth+5'correction 20:18 22:18 2.00 11,091 11,240 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM,3926 CTP, 167 WHP,3975 BHP 22:18 00:00 1.70 11,240 11,240 PROD3 DRILL WPRT P Wiper trip to window.35K PUW 05/29/2012 TD AL2 lateral 11782',Wiper to window, RIH&lay in a liner pill. POOH jetting to the swab valves.Close SSSV, lay down BHA&start P/U 45 jnts of slotted Liner, run#1. 00:00 02:06 2.10 11,240 11,390 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM, 3817 CTP, 3960 BHP, 10K CTW, 02:06 03:12 1.10 11,390 11,390 PROD3 DRILL WPRT P Wiper trip back to 10400'.35K PUW 03:12 05:12 2.00 11,390 11,540 PROD3 DRILL DRLG P Continue drilling ahead, 1.44 BPM, 3780 CTP,4010 BHP,160 WHP, 05:12 06:12 1.00 11,540 9,445 PROD3 DRILL WPRT P Wiper to the window,33K PUW 06:12 06:24 0.20 9,445 9,475 PROD3 DRILL DLOG P Tie-in, +4.5' 06:24 07:24 1.00 9,475 11,540 PROD3 DRILL WPRT P Wiper back in hole 07:24 09:54 2.50 11,540 11,690 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3800 CTP,4010 BHP,130 WHP, 11K RIW. Weight transfer issues, pump sweeps and 100'wiper. 09:54 11:24 1.50 11,690 11,690 PROD3 DRILL DRLG P Wiper trip back to 10560'.34K PUW 11:24 13:54 2.50 11,690 11,782 PROD3 DRILL DRLG P Drill ahead, 1.44 BPM, 3780 CTP, 4010 BHP,110 WHP Page 10 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:54 16:24 2.50 11,782 11,782 PROD3 DRILL WPRT P Call TD, Pump sweeps 10/10 Low/Hi. PUH/RBIH pumping seeps to bit. POOH to TT 9160'. chasing sweeps OOH.32K PUW 16:24 16:39 0.25 11,782 11,782 PROD3 DRILL DLOG P Tie in depth 16:39 18:09 1.50 11,782 11,782 PROD3 DRILL WPRT P RBIH to TD 18:09 21:45 3.60 11,782 72 PROD3 DRILL TRIP P POOH laying in liner pill,clean through window,pump 1.3 bpm while POOH. Flag EOP. 10,200&7800'. 21:45 23:00 1.25 72 0 PROD3 DRILL PULD P Tag up, Dump SSSV-15 minute flow check. Pre-job for laying down BHA. lay down BHA 7 set up rig floor for liner run 23:00 00:00 1.00 0 COMPZ CASING PUTB P PJSM-P/U 45 joints of slotted liner. 05/30/2012 Run&Set liner from 11782'-9630'.Anchored billet set 345 TF at 4500 psi. POOH,fill reel with fresh water& flush the stack. BOPE test waived by Matt Herrera. 00:00 02:00 2.00 500 1,537 COMPZ CASING PUTB P Complete P/U 45 jnts of liner& Coiltrack assembly. Open SSSV. 02:00 05:00 3.00 1,537 11,779 COMPZ CASING RUNL P RIH pumping .3 bpm, EDC is closed. Stop at EOP flag,correction-54 ft. Weight check-35K,-7K WOB. RIH pumping .2 bpm.Tag bottom.11,744+35ft flag depth correction=11779' 05:00 05:45 0.75 11,779 9,400 COMPZ CASING RUNL P Weight 37K,WOB-3.7K. Pump 1.3 bpm, release liner P/U weight 32K, -1.2K WOB.TOL= 10,284'.Set up and pump down backside while POOH to window.Tie in at window. 05:45 06:00 0.25 9,400 9,400 COMPZ CASING DLOG P Tle in depth+3'Correction 06:00 08:00 2.00 9,400 0 COMPZ CASING RUNL P POOH 08:00 08:15 0.25 0 0 COMPZ CASING SFTY P At surface, PJSM,flow check 08:15 09:15 1.00 0 0 COMPZ CASING PUTB P LD BHA 14 09:15 09:45 0.50 0 0 COMPZ CASING SVRG P Prep floor to run liner,service inj. head and reel. 09:45 11:36 1.85 0 0 COMPZ CASING PUTB P PU 19jnts slotted liner with anchored billet 11:36 12:51 1.25 715 8,600 COMPZ CASING RUNL P RIH 12:51 13:06 0.25 8,600 8,600 COMPZ CASING DLOG P Tie in depth to EOP flag.-20' correction. Record up weight 31K PUW. Close EDC 13:06 14:21 1.25 8,600 10,283 COMPZ CASING RUNL P RIH 14:21 14:36 0.25 10,283 10,283 COMPZ CASING RUNL P Tag TOL#1 10283'. PU for up weight.33K PUW. RBIH tag.Orient 345 TF. Set anchor.4500 psi. Estimated TOB 9629'. 14:36 16:51 2.25 10,283 0 COMPZ CASING RUNL P POOH 16:51 17:51 1.00 0 0 COMPZ CASING SFTY P At surface, PJSM, Montitor well for flow. Lay down BHA Page 11 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:51 20:00 2.15 0 0 COMPZ WHDBO CIRC P Crew change-valve checklist.Pump fresh water through CT string,flush stack and lines. Grease tree. 20:00 00:00 4.00 0 0 PROD4 WHDBO BOPE P Zero Micro Motions.**Start BOPE testing**Waived by Matt Herrera. Low 250 High 4000psi. Completed up to test 7. No failures. Set up pumping down MPD. 05/31/2012 Complete BOPE test. P/U BHA#16 with.7 AKO&3"Bi-center. KOTB from 9629'. Drill AL2-01 Lateral. 00:00 04:00 4.00 0 0 PROD4 WHDBO BOPE P Continue with BOP testing. Pumping down MP line. BOP test complete. No failed tests. Pumped less than a 1/2 bbl down MP line during test. Close SSSV. 04:00 05:00 1.00 0 0 PROD4 WHDBO CIRC P Install CV, Pump flo-pro through reel. 05:00 06:30 1.50 0 0 PROD4 STK PULD P Make up BHA#16. 06:30 08:30 2.00 72 9,250 PROD4 STK TRIP P RIH 08:30 08:45 0.25 9,250 9,250 PROD4 STK DLOG P Tie in depth to K1,-15.5'correction. Wt.check 32K PUW 08:45 09:00 0.25 9,250 9,630 PROD4 STK TRIP P RIH 09:00 09:15 0.25 9,630 9,630 PROD4 STK KOST P Dry tag TOB 9628.5'. PU online with pumps. Slowly RIH to start KO 09:15 10:00 0.75 9,630 9,629 PROD4 STK KOST P Start to see motor work 9628.3. KO billet 45 LOHS, 15 K CTW,400 WOB, 1.4 BPM, 3650 CTP,88 WHP,3845 BHP Set auto driller: 1 FPH for 1' 2 FPH for 1' 3 FPH for 1' 10:00 10:15 0.25 9,629 9,629 PROD4 STK KOST P Stall. PU 31K PUW. 10:15 12:00 1.75 9,629 9,639 PROD4 STK KOST P Cont. Milling off Billet at 2 FPH for 1'. Following schedule: 10 FPH 2' 20 FPH for 6' 12:00 12:15 0.25 9,639 9,665 PROD4 STK KOST P Drill Ahead 1.4 BPM,3888 CTP, 121 ✓ WHP, 3894 BHP 12:15 12:30 0.25 9,665 9,665 PROD4 STK KOST P Drift Sidetrack. Looks good. 12:30 14:00 1.50 9,665 9,780 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM,4011 CTP, 113 WHP,3894 BHP 14:00 14:30 0.50 9,780 9,780 PROD4 DRILL WPRT P Wiper trip to window,32K PUW 14:30 17:30 3.00 9,780 9,930 PROD4 DRILL DRLG P Drill ahead 17:30 18:30 1.00 9,930 9,930 PROD4 DRILL WPRT P Wiper trip 18:30 19:30 1.00 9,930 10,080 PROD4 DRILL DRLG P Drilling ahead 1.40 bpm,3910, BHP 3899, ROP 130,WOB 1.2K,CT weight 11K, 19:30 21:00 1.50 10,080 10,080 PROD4 DRILL WPRT P Wiper trip-34K P/U,wipe up to 3.5", tie in+2.5ft. RIH. Page 12 of 15 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 21:00 22:00 1.00 10,080 10,230 PROD4 DRILL DRLG P Drilling ahead-1.43 bpm,3850, BHP 3910, ROP 120,WOB.8K,Ct weight 12K. 10113'-Started pumping new mud. 10147'-new mud at bit. 10200'-New mud to surface 22:00 23:30 1.50 10,230 10,230 PROD4 DRILL WPRT P Wiper trip-P/U 34K. 23:30 00:00 0.50 10,230 10,267 PROD4 DRILL DRLG P Drilling ahead. 06/01/2012 Continue Drilling AL2-01 lateral.Decision to Pull BHA due to lack of ROP,weight transfer&difficulty in steering. 00:00 03:30 3.50 10,267 10,380 PROD4 DRILL DRLG P Drilling ahead-1.44 bpm,3720, BHP 3890,WHP 177,WOB 2.8K,Ct weight 7K, ROP 15. Drilling in A-3. 03:30 05:00 1.50 10,380 10,380 PROD4 DRILL WPRT P Wiper trip -P/U weight 34K 05:00 08:45 3.75 10,380 10,531 PROD4 DRILL DRLG P Drilling ahead-1.43 bpm,3691, BHP 3895,WHP 150,WOB 1.9K,CT weight 10K, ROP 80. Increase Tubes .5%each 08:45 10:30 1.75 10,531 10,531 PROD4 DRILL WPRT P Wiper trip to window 32K PUW.Tie in depth+4'correction 10:30 12:45 2.25 10,531 10,680 PROD4 DRILL DRLG P Drilling ahead-1.5 bpm,3691, BHP 3910,WHP 120,WOB 1.9K,CT weight 10K, 12:45 14:15 1.50 10,680 10,680 PROD4 DRILL WPRT P Wiper trip to window 35K PUW ' 14:15 16:15 2.00 10,680 10,830 PROD4 DRILL DRLG P Drilling ahead-1.5 bpm,3991,BHP 3921,WHP 90,CT weight 5K, 16:15 18:00 1.75 10,830 10,830 PROD4 DRILL WPRT P Wiper trip to 35K PUW. Increase lubes.5%each.Total Tubes in system 4%. 18:00 20:45 2.75 10,830 10,884 PROD4 DRILL DRLG P Drilling ahead-Started to get some gas cut mud-Trip gas. 1.50 bpm,4300, BHP 3980, ECD 13.2, ROP 20,WOB 2.8K,Ct weight 6K.WHP 80.Starting to stack CT weight. 20:45 22:45 2.00 10,884 10,915 PROD4 DRILL DRLG P Very slow ROP,hard time turning up call town-continue to push,P/U ' clean. Drill another hour before BHA trip.Ct weight-5K,WOB 2.5K. ROP 2-4 fph. 10900'ROP increased to 90 fph. String weight came back to 6K. ROP dropped right off again 10915' deflected down. 22:45 00:00 1.25 10,915 6,000 PROD4 DRILL TRIP P POOH for BHA change&agitator. 06/02/2012 POOH to change out BHA#16(poor bit grade). P/U BHA#17 with.8 AKO, agitator&new razor bit. RIH continue drillin AL2-02 lateral.Slow ROP in C-4 formation. 00:00 02:00 2.00 6,000 72 PROD4 DRILL TRIP P POOH with BHA#16 02:00 03:00 1.00 72 0 PROD4 DRILL PULD P PJSM-Flow check-pass. Lay down BHA. Bit inspection-nose cutters are all worn. Page 13 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:30 0.50 0 78 PROD4 DRILL PULD P P/U BHA#17 with .8 AKO, new razor bit&agitator. 03:30 05:30 2.00 78 9,250 PROD4 DRILL TRIP P Test Agitator. Open SSSV, RIH pumping min. rate. 05:30 05:45 0.25 9,250 9,250 PROD4 DRILL DLOG P Tie in depth-22.5'correction 05:45 06:15 0.50 9,250 10,915 PROD4 DRILL TRIP P RIH 06:15 09:15 3.00 10,915 11,011 PROD4 DRILL DRLG P Drill Ahead 1.3 BPM, 180 WHP, 4000 CTP.Attempt to drill out of A3 up thru hard layer above BHA. Anable to build. Deflecting off. Attempt several different approaches, increase WOB, slowly time drill,to create a ledge. 09:15 10:30 1.25 11,011 11,065 PROD4 DRILL DRLG P Break thru hard layer, Drill Ahead 1.3 BPM,4150 CTP, 190 WHP,3980 BHP. 10:30 12:30 2.00 11,065 11,065 PROD4 DRILL WPRT P Wiper trip back to window 34K PUW 12:30 15:15 2.75 11,065 11,175 PROD4 DRILL DRLG P Drill Ahead 1.3 BPM,4141 CTP, 174 WHP, 3933 BHP, 10 CTW 15:15 18:15 3.00 11,175 11,175 PROD4 DRILL WPRT P Wiper trip to window,pull heavy 40K. Pull wiper trip 20-25 FPM to window. At window PU into casing.Open EDC and circulate bottoms up at max rate, PUH to TT 18:15 23:15 5.00 11,175 11,325 PROD4 DRILL DRLG P Drilling ahead-1.35 bpm,4100, BHP / 3950,WOB 2.1K,CT weight 11K, ROP 44. Pump sweeps prior to wiper trip. 23:15 00:00 0.75 11,325 11,325 PROD4 DRILL WPRT P Wiper trip P/U weight 33K 06/03/2012 Drill to TD of 11391'.Wiper trip, lay in liner pill&POOH. Close SSSV&P/U 33 jnts of 2 3/8"slotted liner. RIH. 00:00 01:30 1.50 11,325 11,325 PROD4 DRILL WPRT P Wiper trip 01:30 06:00 4.50 11,325 11,388 PROD4 DRILL DRLG P Drilling ahead-1.35 bpm,4200, BHP 3970,WHP 150, ECD 13.3, ROP 18, WOB 3K, CT weight 8K,steering up to cross cut C-4 prior to TD.Weight checks once in a while-clean P/U 34K. 06:00 08:00 2.00 11,388 11,390 PROD4 DRILL DRLG P Unable to drill,Multiple attempts picking up, new mud sweep,low/high sweeps.. Bit seems to be wore out. Drill 2'in 2 hours. 08:00 08:15 0.25 11,390 11,390 PROD4 DRILL DRLG P Discuss with Geo,Call Engineer-requesting permission to TD 08:15 10:30 2.25 11,390 11,390 PROD4 DRILL WPRT P Call TD, Pump low/high sweeps, chase OOH. PU to TT.tie in depth. +1.7'correction 10:30 12:30 2.00 11,390 11,390 PROD4 DRILL WPRT P RBIH,tag TD 11390'. POOH laying in liner running pill in OH. 12:30 14:30 2.00 11,390 2,000 PROD4 DRILL TRIP P POOH, Paint EOP flags 10200,8300 14:30 15:45 1.25 2,000 0 PROD4 DRILL TRIP P Jet on SSSV thru EDC. POOH Page 14 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:45 16:00 0.25 0 0 PROD4 DRILL SFTY P At surface, Close SSSV, PJSM, monitor well for flow 16:00 16:45 0.75 0 0 PROD4 DRILL PULD P LD BHA 16:45 17:15 0.50 0 0 COMPZ CASING SVRG P Prep floor for running liner 17:15 18:00 0.75 0 0 COMPZ CASING PUTB P PU/MU AL2-01 liner#1.33jnts 2 3/8"Slotted liner 18:00 20:30 2.50 0 1,050 COMPZ CASING PUTB P Crew change-PJSM for P/U liner& coiltrak assembly 20:30 00:00 3.50 1,050 11,000 COMPZ CASING TRIP P RIH with EDC closed pumping.3 bpm.Stop EOP flag 8300'Depth correction minus 26ft. Ct string 17K, WOB-3K. P/U weight 33K,-4.5K WOB. RIH. 06/04/2012 RIH set liner from TD to 9410'. Swap well to SW&freeze protect from 2500'to surface. SSSV closed with 1400 psi below&bled WHP off at surface. Set BPV, RDMO. Rig release at Midnight. 00:00 00:15 0.25 11,000 11,386 COMPZ CASING RUNL P RIH tag bottom @ 11,386'-P/U weight 39K, -3K WOB. RIH set down 4K. Bring pumps online 1.3bpm, P/U 33K WOB zero.Stop reset counters. Set up to pump down backside. 00:15 03:15 3.00 10,355 48 COMPZ CASING RUNL P POOH pumping down backside.Tie in at window. +6ft correction. BOL= 11392'/TOL 10,386'. POOH 03:15 04:15 1.00 48 0 COMPZ CASING RUNL P Close SSSV,flow check, PJSM & lay down BHA. 04:15 06:00 1.75 0 1,050 COMPZ CASING PUTB P PJSM-P/U 30 joints of 2 3/8" slotted liner with ported nozzle. 06:00 08:00 2.00 1,050 9,341 COMPZ CASING RUNL P RIH 08:00 08:06 0.10 9,314 9,314 COMPZ CASING RUNL P Tie in depth with EOP flag.-27.8'. Record up and down weights 32K PUW. 14.5K RIH 08:06 08:21 0.25 9,314 10,377 COMPZ CASING RUNL P RIH to TOL#1 08:21 08:30 0.15 10,377 10,377 COMPZ CASING RUNL P Tag TOL, Release off liner, 08:30 08:45 0.25 9,668 9,250 COMPZ CASING RUNL P Remove liner length from bit depth. PU to tie in depth 08:45 09:00 0.25 9,250 9,250 COMPZ CASING RUNL P Log K1. +4'correction.TOL 9410.3 09:00 12:00 3.00 9,400 0 DEMOB WELLPF DISP P RBIH swap well to seawater, POOH freeze protect well 2500'TVD 12:00 14:00 2.00 0 0 COMPZ CASING RUNL P At surface. PJSM, LD BHA. 14:00 16:00 2.00 0 0 DEMOB WELLPF DISP P MU nozzle,flush BOP's and Rig, pump inhibitor thru CT and rig and blow down 16:00 17:00 1.00 0 0 DEMOB WHDBO NUND P Set BPV 17:00 18:00 1.00 0 0 DEMOB WHDBO NUND P RD 18:00 22:00 4.00 0 0 DEMOB WHDBO RURD P Crew change-PJSM for rigging down. Remove fusable cap, lift BOP's,break down lines in Putz. 22:00 00:00 2.00 0 0 DEMOB WHDBO MOB P Trucks arrived. PJSM-stage trucks and prepare to pull off well. Contact DSO. ***Rig Release at Midnight*** Page 15 of 15 3G-22 Post Rig Well Work DATE SUMMARY 6/14/12 SCSSSV CLOSED ON ARRIVAL, OPENED WITH PUMP TRUCK AND PRESSURE ( FUNCTION TESTED ) GAUGE 2.80" TO 9410' RKB, MEASURE BHP @ 9400' RKB ( 3779 psi ), GRADIENT @ 9226' RKB ( 3712 psi ) IN PROGRESS. 6/15/12 SET 2.813"XXPLUG @ 9093' RKB, DEPLOYED CATCHER SUB, PULLED DVs @ 9033' RKB & 8328' RKB, LEFT GLM @ 9033' RKB OPEN FOR CIRC OUT; SET GLV @ 8328' RKB. IN PROGRESS 6/16/12 PULLED DV @ 7133' RKB AND SET GLV. CIRC OUT W/317 BBLS OF DIESEL DOWN TBG., UP IA(THRU OPEN POCKET @ 9032' RKB ) , AND DOWN FLOWLINE ON WELL 21. PULLED DV @ 5445' RKB. LDFN DUE TO SWAB NOT HOLDING. IN PROGRESS. 6/17/12 SET OV @ 9032' RKB, PULLED DV @ 3160' RKB, SET GLV'S @ 5445', 3144' RKB, TESTED GL STRING TO 1500 PSI; PULLED CATCHER @ 9093' RKB, PULLED XX PLUG @ 9093' RKB. COMPLETE. Letter of Transmittal BAKER Date: June 8, 2012 HUGHES To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Q Anchorage, Alaska 99515 Alva ry Please find enclosed the direlV J1 - rvt; ata for the following well(s): � o 3G-22A a I Z. 3G-22AL1 y cQ 3G-22AL2PB1 3G-22AL2 3G-22AL2-01 A ) O q 228f ±5at (5) Total prints DA4(9' G -M/\ tV&\ 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 ret ►i il. Sachin Gandra, Baker Hughes, Project Engineer 4 Sachin.Gandra@BakerHughes.com AIKW)Y). Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com r ty' kk L� ALAsun SEAN PARNELL, GOVERNOR %) @ 4 3 7 ALASKA OIL ANI) GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 L. Gantt FAX (907)276-7542 CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3G-22AL2-01 ConocoPhillips Alaska, Inc. Permit No: 212-048 Surface Location: 2538' FNL, 220' FEL, SEC. 23, T12N, R8E, UM Bottomhole Location: 2570' FNL, 1504' FEL, SEC. 27, T12N, R8E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3G-22A, Permit No 212- 045, API 50-103-20147-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revoca 'i n or suspension of the permit. af m. / 'o '; ioner DATED this;(day day of April, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) 1 - 7 -.`i��E..�rl nr L—✓ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONAL 3 Q 2012 PERMIT TO DRILL 20 AAC 25.005 „ ._ ^r-n S. fnmmissiafl la.Type of Work' • lb.Proposed Well Class. Development-Oil ❑✓ 'Service-Winj ❑ Single Zone 0 •1c.Speciifyiifwell iiTs.proposed for: Drill ElRe-drill2Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone El Coalbed Gas U Gas Hydrates- Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2 Operator Name 5. Bond: u Blanket u Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 3G-22AL2-01 ' 3.Address 6 Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11380' • TVDSS: 5781' • Kuparuk River Field 4a. Location of Well(Governmental Section). 7.Property Designation(Lease Number): Surface:2538'FNL,220'FEL,Sec.23,T12N, RO8E,UM ADL 25547,25549 ' Kuparuk River Oil Pool Top of Productive Horizon 8.Land Use Permit 13 Approximate Spud Date: 1096'FNL,508'FEL,Sec.27,T12N,RO8E, UM 2661,2663 5/1/2012 Total Depth. 9.Acres in Property: 14.Distance to 2570'FNL, 1504'FEL,Sec.27,T12N, RO8E,UM 2560 Nearest Property: 2215 4b.Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL: 90 feet 15.Distance to Nearest Well Open Surface:x- 498160 y- 5988561 Zone- 4 GL Elevation above MSL 54 feet to Same Pool: 3G-21 ,1185 16.Deviated wells: Kickoff depth: 9775 " ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle: 99. ' deg Downhole:3914 psig Surface:3337 psig • 18 Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (Including stage data) 3" 2.375" 4.7# L-80 ST-L 9400' 5797' 11380' 5781' slotted liner - 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft) Junk(measured) 9782 6085' 9625' 6002' 9561', 9643' Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 216 sx AS I 115' 115' Surface 4007' 9.625" 950 sx AS III,550 sx Class G 4042' 2947' Intermediate Production 9729' 7" 200 sx Class G 9764' 6076' Liner 461' 4.5" 21 bbls Class G 9611' 5994' Perforation Depth MD(ft): Perforation Depth ND(ft): none none 20 Attachments' Property Plat❑ BOP Sketch❑ Drilling Program Q Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 MC 25.050 requirements Q 21 Verbal Approval Commission Representative' Date 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 Printed Name L. Gantt Title CTD Supervisor Signatureary JV i r .39\leVgif— Phon zss-aort Date /Z 9(/Z Commission Use Only / / Permit to Drill L/C- API Number: 1 Permit Approv I See cover letter Number. 2/2 ( 50-/C5-2C`L/7 2.— Date: y 1st 12„ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coal me ane,`gas hydrates,or gas contained in shales 44- L O ` Se)P /62_,_ Samples req'd: Yes ❑ o r ud log req'd: Yes ❑ No Other: H2S measures: Yes 2 'o 1 .' - al svy req'd: Yes [ No ❑ Z r-i t. / PPROVE s BY THE COMMISSION DATE /— F ''' 1 ft, t 1 it ,COMMISSIONE Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval('7T" 25.005(g)) /p/Submi D plicate i 80RS ALASKA ,�a �n Kuparuk CTD Laterals NA»^k ° ""elis 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 Girt Con°`°F dips Application for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)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 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 4 (Requirements of 20 MC 25.005(c)(7)) 4 8. Drilling Fluids Program 4 (Requirements of 20 AAC 25.005(c)(8)) 4 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 AAC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 AAC 25.005(c)(12)) 5 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 • 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 MC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 3H-34L1,3H-34L1-01,and 3H-34L1-02 7 Attachment 2: Current Well Schematic for 3H-34 7 Attachment 3: Proposed Well Schematic for 3H-34L1,3H-34L1-01, and 3H-34L1-02 7 Page 1 of 7 3/29/2012 PTD Application: 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(t) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01. All four of these laterals will be classified as"Development- Oif'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 2538' FNL, 220' FEL, Sec 23, T12N, R08E, UM NAD 1927 RKB Elevation 90 AMSL Northings: 5,988,560 Eastings: 498,160 Pad Elevation 54 AMSL 3G-22A Location at Top of Productive Horizon 315' FNL, 503' FEL, Sec 27, T12N, R08E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 10,600' Northings: 5,985,507 Eastings: 492,599 Total Vertical Depth, SS: 5,803' Location at Total Depth 681' FSL, 441' FWL, Sec 23, T12N,R08E, UM NAD 1927 Measured Depth, RKB: 11,980' Northings: 5,986,502 Eastings: 493,542 Total Vertical Depth, SS: 5,770' 3G-22AL1 Location at Top of Productive Horizon 1182' FNL, 660' FEL, Sec 27, T12N, R08E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 9600' Northings: 5,984,640 Eastings: 492,442 Total Vertical Depth, SS: 5,815' Location at Total Depth 570' FSL, 351' FWL, Sec 23, T12N, R08E, UM NAD 1927 Measured Depth, RKB: 11,875' Northings: 5,986,391 Eastings: 493,452 Total Vertical Depth, SS: 5,770' 3G-22AL2 Location at Top of Productive Horizon 1213' FNL, 831' FEL, Sec 27, T12N, R08E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 9775' Northings: 5,984,610 Eastings: 492,271 Total Vertical Depth, SS: 5,819' Location at Total Depth 2400' FSL, 1834' FEL, Sec 27, T12N, R08E, UM NAD 1927 Measured Depth, RKB: 11,820' Northings: 5,982,944 Eastings: 491,269 Total Vertical Depth, SS: 5,771' G-22AL2-01, Location at Top of Productive Horizon 1096' FNL, 508' FEL, Sec 27, T12N, R08E, UM __( Gparuk) NAD 1927 Measured Depth, RKB: 9416' 17- Northings: 5,984,726 Eastings: 492,594 Total Vertical Depth, SS: 5,797' Location at Total Depth 2570' FNL, 1504' FEL, Sec 27, T12N, R08E, UM NAD 1927 Measured Depth, RKB: 11,380' Northings: 5,983,253 Eastings: 491,599 Total Vertical Depth, SS: 5,781' • Page 2 of 7 3/29/2012 PTD Application: 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 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 pressure in the area of 3914 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3337 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 in November 2011 indicated a reservoir pressure of 3386 psi or 11.2 ppg equivalent mud weight. During a December 2001 rig workover, the fluid weight at TD (9625'MD/5912'TVDSS) at which the reservoir (both A and C sands combined) remained static was 12.9 ppg. This agreed with offset injectors in the area that were shut in prior to the RWO and have remained shut in since. Reservoir pressure has continued to decrease in the area. • The maximum downhole pressure in the 3G-22 pattern is near injector 3G-23. 3G-23 has been shut-in since January '03. An updated static bottomhole pressure (BHP) reading was obtained on March 28, 2012, indicating a pressure of 3914 psi at 7075' MD/5769' TVDSS. This would be the equivalent of 13.0 ppg fluid. These offset pressures are not expected to be that high drilling the laterals due to offset distance and faulting. Using the 3G-23 pressure as the maximum possible in 3G-22, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3337 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 3G pad does have some wells on miscible gas injection (MI) so encountering MI gas is a possibility. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 3G-22 laterals will be crossing a fault into an over pressurized reservoir block. The surrounding injectors have been shut in to bring the reservoir pressure down. 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 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. 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 Liner Details Name MD MD TVDSS TVDSS 2%" 4.7#, L-80, ST-L slotted liner; 3G-22A 10600' 11980' 5803' 5770' anchored aluminum billet on top. 3G-22AL1 9600' 11875' 5815' 5770' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3G-22AL2 9775' 11820' 5819' 5771' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. Page 3 of 7 3/29/2012 PTD Application: 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 3G-22AL2-01 9400' 11380' 5797' 5781' 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 36' 115' 0' 107' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 36' 4042' 0' 2947' 3520 2020 Casing 7" 26.0 J-55 BTC 0' 9764' 0' 6076' 4980 4330 Liner 4-1/2 " 12.6 L-80 EUE 8rd-mod 9126' 9611' 5720' 5994' 7700 7500 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 24' 9611' 0' 5749' 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 AA C 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 Biozan brine (9.0 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.0 ppg). While this mud weight does not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 3G-22 contains a subsurface safety valve (SSSV). The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 13.1 ppg Potassium Formate completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-210 bbl)of 13.5 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. 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 anactively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 12.1 ppg will be initially targeted at the window based on the recent rig work- over of the 3G-22 parent wellbore. 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. Page 4 of 7 3/29/2012 PTD Application: 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Summary of Operations Background Well 3G-22 was drilled January 1991 and completed as a producer in June 1991 in the Kuparuk A2,A3, and C4-sands. The initial commingled A- and C-sand rates were tested at 1300 BOPD, 0%water cut, and 1500 GOR (Fig. 1). In May 1996, After 5 years of production a pressure build up (PBU) test was performed on well 3G-22. The PBU test results determined the need for a refrac in the A-sands. The A-sand refrac was completed June 1996 and well 3G-22 benefitted in a short-lived increase in production of 250 BOPD. The A- sand refract may have protruded into the C sand, which would have caused the short-lived production spike, followed by the steep decline and increasing water cut. The first scale squeeze on well 3G-22 was completed November 9, 1997. Scale squeezes have been performed as a preventative measure on an approximately yearly basis since. Miscble injectant service on surrounding injection wells 3G-13 and 3G-15 began in mid 2003. Well 3G-22 indicated a GOR and oil rate response approximately 3 months after the service commenced. The liquid rate in well 3G-22 has held steady at—800 bfpd from the time the MI service began and is currently holding at approximately that rate. Oil rate increased from 300 bopd prior to MI to approximately 450 bopd after the response. The rate of 450 bopd has dropped slightly since 2009 and the current rate is —300 bopd, 70% WC, and 1000 GOR. A rig workover was required prior to CTD development due to a stuck frac sleeve and casing obstruction. The frac sleeve is stuck in the SSSV and could not be pulled after several fishing attempts. A caliper log was run in August prior to the latest fishing attempt to gain a better understanding of the location of the fish. However, the caliper instead indicated a casing anomaly at —9400 MD. During the rig workover, the tubing was pulled (including the stuck frac sleeve), a 4-1/2 inch casing liner was run and cemented (to remediate casing anomaly) and 3.5 inch tubing installed. The existing perfs are now isolated by the cemented scab liner. Well 3G-22 has remained shut in for production until the development plan is executed. Pre-Rig Work 1. Perform drift and tag. Perform a dummy whipstock drift as well. 2. Perform GR/CCL log for tie-in purposes to confirm KOP is spaced between collars. 3. Set whipstock pre-rig at 9416' MD (+/- 10'to adjust for actual collar locations). 4. Set BPV and prepare wellsite for rig arrival. Page 5 of 7 3/29/2012 PTD Application: 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE, test. �s 2. If the whipstock was not set pre-rig, set whipstock at 9416' MD (+/- 10' to adjust for actual collar locations). 3. Mill a 2.80", dual string window exit with high-side orientation. 4. Drill 3G-22A Lateral a. Drill 2.70"x 3"bi-center lateral in the A2 sand to a TD of 11,980' MD b. Run 2%" slotted liner from TD to-10600', utilizing the SSSV for deploying the liner 5. Drill 3G-22AL1 Lateral a. Drill 2.70"x 3" bi-center lateral in the A3/C4 sand to a TD of 11,875' MD b. Run 2%" slotted liner from TD to-9600', utilizing the SSSV for deploying the liner 6. Drill 3G-22AL2 Lateral a. Drill 2.70"x 3" bi-center lateral in the A2 sand to a TD of 11,820' MD __..b_ Run 23/" slotted liner from TD to 9775', utilizing the SSSV for deploying the liner 7. Drill 3G-22AL2-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A3/C4 sand to a TD of 11,380' MD b. Run 2%" slotted liner from TD up into the 4.5"tubing to-9400' MD. 8. POOH swapping well over to brine. Freeze protect. 1114 5 9. Set BPV. ND BOPE. RDMO Nabors CRD2-AC. t)-11) 10. Handover to Production group. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Put on production. Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment 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. Page 6 of 7 3/29/2012 PTD Application: 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 Liner Running — Since 3G-22 is equipped with a SSSV, the 3G-22 CTD laterals will not need to be displaced to an overbalancing fluid 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. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — 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. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line (measured to Tarn PA boundary at closest point) Lateral Name Distance 3G-22A 2060 3G-22AL1 2060 3G-22AL2 2150 3G-22AL2-01 2215 — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 3G-22A 1850 3G-23 3G-22AL1 1950 3G-23 3G-22AL2 1375 3G-21 3G-22AL2-01 1185 3G-21 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for this well because it will be put on production service. 17. Attachments Attachment 1: Directional Plans for 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 Attachment 2: Current Well Schematic for 3G-22 Attachment 3: Proposed Well Schematic for 3G-22A, 3G-22AL1, 3G-22AL2, and 3G-22AL2-01 Page 7 of 7 3/29/2012 t. KUP 3G-22 ConocoPhillips Well Well Attributes Max Angle&MD TD Alaska,In,:: Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(ftK8) cnomrt9np3 501032014700 KUPARUK RIVER UNIT PROD 61.02 3,500.00 9782.0 ' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date - SSSV:TRDP 110 11/3/2010 Last WO: 12/8/2011 37.11 10/30/1990 mu comic:.-3G-22 15300011 6.11.26 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,472.0 11/22/2011 Rev Reason:WORKOVER ninam 12/30/2011 Casing Strings Casing Description String 0... String ID...Top(ft/4B) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd HANGER,24 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 35.0 4,042.2 2,947.1 36.00 J-55 BTC 1 F Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 0.0 9,764.0 6,075.9 26.00 J-55 _ Casing Description String 0... String ID...Top(ftK8) Set Depth(F..Set Depth(ND)...String Wt...String...String Top Thrd SCAB LINER 4 1/2 4.000 9,126.3 9,611.0 5,994.1 11.60 L-80 BTC-Mod Liner Details Top Depth CONDUCTOR, (ND) Top Incl Nomi... 38-115 Top(BKB) (RKB) (°) Item Description Comment ID(in) 9,126.3 5,719.8 54.53 PACKER BAKER C2 @ ZXP LINER TOP PACKER 4.470 SAFETY VLV, f -1 l 9,L146.4 -5,731.4 54.59 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.470 1.907 l I 9,156.2 5,737.1 54.61 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 31/2 2.992 23.9 9,177.0 5,749.2 9.30 L-80 EUE8rdABMOD GAS LIFT, Completion Details 3,160 Top Depth (ND) Top Incl Nomi... Top(kKB) (MB) (°) Item Description Comment ID(in) 23.9 23.9 -0.03 HANGER TUBING HANGER&PUP 3.500 11 11 1,906.7 1,783.9 45.41 SAFETY VLV CAMCO TRMAZZ-CMT-5-SR SAFETY VALVE 2.812 9,093.2 5,700.6 54.44 NIPPLE CAMCO X NIPPLE 2.813 SURFACE, .1 l - 9,140.4 5,727.9 54.57 SEAL ASSY SEAL ASSEMBLY FOR BOT 80-40 SEAL BORE EXTENSION HALF 2.990 35-4.042 MULE SHOE Oer In Hole(Wireline retrievable plugs,valves,pumps,fish,etc-) To Depth �5514�45 -- illi (TVD) Top Incl Top th(RKB) (RKB) (°) Description Comment Run Date ID(in) 9,561 5,967.3 57.66 FISH 1.5"OV Dropped valve into rathole while attempting to set a 10/17/1999 0.000 MI GLM at GLM#6 on 10/17/98 - 9,643 6,011.2 57.66 FISH 1"GLV Found Empty Pocket @ GLM#4;Fell to Rathole 10/11/1996 0.000 GAS LIFT,7 133 Perforations&Slots II. Shot - • Top(ND) Btm(TVD) Dens Top(ftK8) etm(ttKB) (ftK8) (RKB) Zone Date (eh.-- Type Comment 9,376 9,426 5,863.8 5,891.5 C-4,A-3,3G-22 6/10/1991 4.0 APERF 180 deg.phasing;2 1/2"Titan GAS 8LFT,,326__ 9,426 9,462 5,891.5 5,912.3 A-2,3G-22 1/4/1991 4.0(PERF 180 deg.phasing;HLS 41/2°Csg - Gun Notes:General&Safety End Date Annotation Illi 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, IMP 9,033 IN MI ME NIPPLE,9,093 W. 111. 1 , I • SEAL ASSY, r 1 9,140 f APERF, I I' 9,376-9,426 IPERF, 9.426-9.462 , I 1 Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(RKB) (RKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... FISH,9,561 1 3,160.1 2,495.3 59.20 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/8/2011 iii 2 5,445.4 3,686.0 58.11 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/8/2011 3 7,133.2 4,581.0 58.07 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/8/2011 I 4 8,328.2 5,254.2 54.24 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/8/2011 5 9,032.8 5,665.3 54.28 CAMCO MMG 1 12 GAS LIFT SOV REK 0.000 0.0 12/8/2011 I SCAB LINER, a'J 9,126-9,811 S FISH,9,843II 0 D ! r1 j 1' 77 PRODUCTION, i \ b . t(, d �' „ t °ry � , I 0.9,784 d TD,9,782 s 00 En m m J N Q(!��� p W N G m 6o J r ix co I— F- m '— 7 @.) Y e) N V m CC _ m U, O N M O Vm M F CI c =Y Y N O E o`er y m , .•N m v 9 n ti o H M Y O M 2 2 m m m CC co (m(���� a cs U M N iD V m 'a �( m M m N Y Y Y m m �' HI co g .J U m ,O h n a m 2 m c rn n o m `i m i; E c4 a ''' a X a m I 03 -, ° L °' E nI a 8 N U m ' •- L Z N Y a- i0 i0 01 0 U (h (0 E C) T O O E N /a��, CO a) U X ()LL m F LL. 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Kuparuk River Unit Kuparuk 3G Pad 3G-22 3G-22AL2-01 Plan: 3G-22AL2-01_wp03 Standard Planning Report 06 March, 2012 - ' ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3G-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3G-22 @ 90.00ft(3G-22) Site: Kuparuk 3G Pad North Reference: True Well: 3G-22 Survey Calculation Method: Minimum Curvature Wellbore: 3G-22AL2-01 Design: 3G-22AL2-01_wp03 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3G Pad Site Position: Northing: 5,988,559.95ft Latitude: 70°22'47.920 N From: Map Easting: 498,724.97ft Longitude: 150°0'37.320 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 3G-22 Well Position +N/-S 0.00 ft Northing: 5,988,560.56 ft Latitude: 70°22'47.925 N +E/-W 0.00 ft Easting: 498,159.82 ft Longitude: 150°0'53.862 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft , Wellbore 3G-22AL2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 5/15/2012 16.13 79.92 57,372 Design 3G-22AL2-01_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,775.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 0.00 0.00 0.00 200.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,775.00 91.38 247.84 5,819.01 -3,952.25 -5,887.96 0.00 0.00 0.00 0.00 9,805.00 94.92 247.22 5,817.36 -3,963.70 -5,915.64 12.00 11.82 -2.09 350.00 9,835.00 97.67 244.88 5,814.07 -3,975.80 -5,942.88 12.00 9.18 -7.78 320.00 9,865.00 98.89 241.46 5,809.75 -3,989.20 -5,969.37 12.00 4.06 -11.41 290.00 9,935.00 97.92 233.02 5,799.50 -4,026.64 -6,027.55 12.00 -1.39 -12.05 264.00 10,005.00 91.30 227.84 5,793.87 -4,071.06 -6,081.27 12.00 -9.46 -7.41 218.20 10,085.00 91.28 218.24 5,792.07 -4,129.45 -6,135.79 12.00 -0.02 -12.00 270.00 10,435.00 90.28 176.24 5,787.09 -4,456.26 -6,237.19 12.00 -0.28 -12.00 269.00 10,545.00 90.39 189.44 5,786.44 -4,565.88 -6,242.64 12.00 0.10 12.00 89.50 10,655.00 90.38 176.24 5,785.71 -4,675.50 -6,248.08 12.00 -0.01 -12.00 270.00 11,030.00 90.27 221.24 5,783.49 -5,021.54 -6,365.51 12.00 -0.03 12.00 90.00 11,180.00 90.25 203.24 5,782.80 -5,147.89 -6,445.21 12.00 -0.01 -12.00 270.00 11,380.00 90.80 227.24 5,780.93 • -5,310.04 -6,559.76 12.00 0.27 12.00 88.60 3/6/2012 5:12:27PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL • ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3G-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3G-22 @ 90.00ft(3G-22) Site: Kuparuk 3G Pad North Reference: True Well: 3G-22 Survey Calculation Method: Minimum Curvature Wellbore: 3G-22AL2-01 Design: 3G-22AL2-01_wp03 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1OOft) (°) (ft) (ft) 9,775.00 91.38 247.84 5,819.01 -3,952.25 -5,887.96 5,727.70 0.00 0.00 5,984,610.15 492,271.48 TIP/KOP 9,800.00 94.33 247.32 5,817.76 -3,961.78 -5,911.04 5,744.55 12.00 -10.00 5,984,600.63 492,248.40 9,805.00 94.92 247.22 5,817.36 -3,963.70 -5,915.64 5,747.93 12.00 -10.03 5,984,598.71 492,243.80 2 9,835.00 97.67 244.88 5,814.07 -3,975.80 -5,942.88 5,768.62 12.00 -40.00 5,984,586.62 492,216.55 3 9,865.00 98.89 241.46 5,809.75 -3,989.20 -5,969.37 5,790.27 12.00 -70.00 5,984,573.23 492,190.06 4 9,900.00 98.43 237.24 5,804.48 -4,006.84 -5,999.13 5,817.02 12.00 -96.00 5,984,555.60 492,160.30 9,935.00 97.92 233.02 5,799.50 -4,026.64 -6,027.55 5,845.34 12.00 -96.64 5,984,535.81 492,131.89 5 10,000.00 91.77 228.21 5,794.01 -4,067.71 -6,077.56 5,901.05 12.00 -141.80 5,984,494.75 492,081.87 10,005.00 91.30 227.84 5,793.87 -4,071.06 -6,081.27 5,905.46 12.00 -142.21 5,984,491.41 492,078.15 6 10,085.00 91.28 218.24 5,792.07 -4,129.45 -6,135.79 5,978.97 12.00 -90.00 5,984,433.04 492,023.62 7 10,100.00 91.25 216.44 5,791.74 -4,141.37 -6,144.89 5,993.29 12.00 -91.00 5,984,421.12 492,014.53 10,200.00 91.00 204.44 5,789.77 -4,227.41 -6,195.44 6,091.44 12.00 -91.04 5,984,335.09 491,963.95 10,300.00 90.72 192.44 5,788.27 -4,322.10 -6,227.01 6,191.21 12.00 -91.28 5,984,240.43 491,932.37 10,400.00 90.40 180.44 5,787.30 -4,421.28 -6,238.21 6,288.24 12.00 -91.46 5,984,141.26 491,921.15 10,435.00 90.28 176.24 5,787.09 -4,456.26 -6,237.19 6,320.76 12.00 -91.57 5,984,106.28 491,922.15 8 10,500.00 90.35 184.04 5,786.73 -4,521.20 -6,237.36 6,381.84 12.00 89.50 5,984,041.34 491,921.97 10,545.00 90.39 189.44 5,786.44 -4,565.88 -6,242.64 6,425.63 12.00 89.54 5,983,996.68 491,916.68 9 10,600.00 90.38 182.84 5,786.07 -4,620.53 -6,248.52 6,479.00 12.00 -90.00 5,983,942.03 491,910.79 10,655.00 90.38 176.24 5,785.71 -4,675.50 -6,248.08 6,530.50 12.00 -90.04 5,983,887.07 491,911.21 10 10,700.00 90.38 181.64 5,785.41 -4,720.47 -6,247.25 6,572.48 12.00 90.00 5,983,842.10 491,912.03 10,800.00 90.36 193.64 5,784.77 -4,819.40 -6,260.53 6,669.98 12.00 90.04 5,983,743.18 491,898.73 10,900.00 90.33 205.64 5,784.16 -4,913.40 -6,294.09 6,769.79 12.00 90.11 5,983,649.19 491,865.16 11,000.00 90.28 217.64 5,783.63 -4,998.38 -6,346.45 6,867.56 12.00 90.19 5,983,564.24 491,812.77 11,030.00 90.27 221.24 5,783.49 -5,021.54 -6,365.51 6,895.84 12.00 90.25 5,983,541.08 491,793.71 11 11,100.00 90.26 212.84 5,783.16 -5,077.37 -6,407.64 6,962.71 12.00 -90.00 5,983,485.28 491,751.57 11,180.00 90.25 203.24 5,782.80 -5,147.89 -6,445.21 7,041.82 12.00 -90.04 5,983,414.77 491,713.99 12 11,200.00 90.31 205.64 5,782.70 -5,166.10 -6,453.48 7,061.76 12.00 88.60 5,983,396.57 491,705.71 11,300.00 90.59 217.64 5,781.91 -5,251.07 -6,505.85 7,159.52 12.00 88.61 5,983,311.61 491,653.33 11,380.00 . 90.80 227.24 5,780.93 . -5,310.04 -6,559.76 7,233.37 12.00 88.71 5,983,252.67 491,599.41 TD 3/6/2012 5:12.27PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3G-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3G-22 @ 90.00ft(3G-22) Site: Kuparuk 3G Pad North Reference: True Well: 3G-22 Survey Calculation Method: Minimum Curvature Wellbore: 3G-22AL2-01 Design: 3G-22AL2-01_wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3G-22AL2-01_T2 0.00 0.00 5,788.00 -4,364.35 -6,186.63 5,984,198.17 491,972.74 70°22'4.977 N 150°3'54.821 W -plan misses target center by 47.32ft at 10337.52ft MD(5787.84 TVD,-4359.02 N,-6233.65 E) -Point 3G-22AL2-01_T3 0.00 0.00 5,783.00 -5,110.43 -6,268.46 5,983,452.19 491,890.72 70°21'57.639 N 150°3'57.196 W -plan misses target center by 131.76ft at 11042.50ft MD(5783.43 TVD,-5031.05 N,-6373.62 E) -Point 3G-22AL2-01_T1 0.00 0.00 5,794.00 -4,093.30 -6,047.68 5,984,469.16 492,111.74 70°22'7.644 N 150°3'50.763 W -plan misses target center by 38.99ft at 9993.16ft MD(5794.26 TVD,-4063.18 N,-6072.45 E) -Point 3G-22AL2,AL2-01 Pc 0.00 0.00 100.00 -5,549.64 -7,099.45 5,983,013.22 491,059.71 70°21'53.312 N 150°4'21.488 W -plan misses target center by 5711.54ft at 11380.00ft MD(5780.93 TVD,-5310.04 N,-6559.76 E) -Polygon Point 1 100.00 -5,549.64 -7,099.45 5,983,013.22 491,059.71 Point 2 100.00 -5,774.61 -6,923.37 5,982,788.23 491,235.72 Point 3 100.00 -5,609.51 -6,646.39 5,982,953.24 491,512.71 Point4 100.00 -5,483.44 -6,449.40 5,983,079.25 491,709.72 Point 5 100.00 -5,322.37 -6,253.43 5,983,240.26 491,905.71 Point 6 100.00 -5,055.31 -6,142.50 5,983,507.26 492,016.69 Point 7 100.00 -4,738.24 -6,021.58 5,983,824.27 492,137.68 Point 8 100.00 -4,431.21 -6,016.67 5,984,131.27 492,142.66 Point 9 100.00 -4,139.14 -5,885.75 5,984,423.28 492,273.64 Point 10 100.00 -4,018.09 -5,754.77 5,984,544.28 492,404.64 Point 11 100.00 -3,902.11 -5,880.82 5,984,660.28 492,278.63 Point 12 100.00 -3,972.17 -6,057.81 5,984,590.27 492,101.64 Point 13 100.00 -4,139.24 -6,219.78 5,984,423.26 491,939.64 Point 14 100.00 -4,450.29 -6,281.70 5,984,112.26 491,877.65 Point 15 100.00 -4,763.33 -6,318.61 5,983,799.26 491,840.67 Point 16 100.00 -5,050.40 -6,444.53 5,983,512.25 491,714.69 Point 17 100.00 -5,262.48 -6,656.49 5,983,300.24 491,502.70 Point 18 100.00 -5,433.58 -6,933.47 5,983,129.22 491,225.71 Point 19 100.00 -5,549.64 -7,099.45 5,983,013.22 491,059.71 3G-22AL2-01_T4 0.00 0.00 5,781.00 -5,342.49 -6,463.43 5,983,220.20 491,695.72 70°21'55.355 N 150°4'2.892 W -plan misses target center by 100.78ft at 11300.00ft MD(5781.91 TVD,-5251.07 N,-6505.85 E) -Point rCasing Points ;, r.. .,,s: s ,s+^:'^^za-«;1^'zcRr•+^z¢a,.uazr'°' ., a,r.r',:', ,arc r„ ,,..e.,Sr� s °s ,a ..,.�a ..'*21 .m.',.. Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") ('') 11,380.00 5,780.93 2-3/8" 3 3 3/6/2012 5:12:27PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL • ConocoPhillips or its affiliates ConocoPhillips Planning Report Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3G-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3G-22 @ 90.00ft(3G-22) Site: Kuparuk 3G Pad North Reference: True Well: 3G-22 Survey Calculation Method: Minimum Curvature Wellbore: 3G-22AL2-01 Design: 3G-22AL2-01_wp03 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,775.00 5,819.01 -3,952.25 -5,887.96 TIP/KOP 9,805.00 5,817.36 -3,963.70 -5,915.64 2 9,835.00 5,814.07 -3,975.80 -5,942.88 3 9,865.00 5,809.75 -3,989.20 -5,969.37 4 9,935.00 5,799.50 -4,026.64 -6,027.55 5 10,005.00 5,793.87 -4,071.06 -6,081.27 6 10,085.00 5,792.07 -4,129.45 -6,135.79 7 10,435.00 5,787.09 -4,456.26 -6,237.19 8 10,545.00 5,786.44 -4,565.88 -6,242.64 9 10,655.00 5,785.71 -4,675.50 -6,248.08 10 11,030.00 5,783.49 -5,021.54 -6,365.51 11 11,180.00 5,782.80 -5,147.89 -6,445.21 12 11,380.00 5,780.93 -5,310.04 -6,559.76 TD 3/6/2012 5:12:27PM Page 5 COMPASS 2003.16 Build 69 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 CHECKLI.SST WELL NAME K r� L 5�� – G —2-'1C— —c PTD# i Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: LL�,C �1 L L7-r--4 POOL: /C1---<-( c�(h a_c.„ c, Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a`new wellbore segment of existing �� well KR (If last two digits inPermit No. 2/Z-LN ,API No. 50-/C-3 API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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