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214-133
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. Qj i - X33 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: olor Items: ❑ Maps: rayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: C Maria Date: *V/5- IMP Project Proofing BY: C.A.:2), Date: Z qpS /s/ MP V p Scanning Preparation a x 30 = (Pb + = TOTAL PAGES f(J U BY: lap (Count does not include cover sheet) " Y Date:3 /5— /s/ Production Scanning Stage 1 Page Count from Scanned File: b 9 (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: CP Date: 3/ /- /s/ vl4F Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o „' o a • o m0. • 0 Q E •L • N e- N ' Q 2 • • O) • 0 • • C' m r J M 0 LL LL LL• 'C a) �_ N N } C Q a) O 0 U U J d d J a)CL t U X m N O) O) = m O) Op a- 7:12 J N J LL D > co aaC C aO To co 0 y 7 7 N N C C fn C C fA 7 7 j 7 C .b >. = (0 F LL it CO LL LL ( co u) V) U) LL 4 o a) m -J m o 0 0 0 0 0 m m o .0 Z 3 0 0 Z E H O 0 S E [- W W ; N LU LU N LU � W W LL it N E u) m _ Q C 0 J J J J J J J J J J J J J C 0) 0) O) LL O) O) O) O) a) Q) O) O) O) O) O) Z 2 O O O Y O O O O O O O O O O O (9 2 O N N N CC U I— I— N F- N N N N N N I— CD co d a) a) aa) a) a) N N N N a U Q O C a) N a) ._ d it it w LL D( 0 it it: LL it it it it w LL LL it it O O Y c) c) 0 0 v v c)'O 0 v c 00 7 dN E C C . C OWC N C C C C C C C C . 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Io• \0 0 d 0. to t co O ZI C (o O ago G O N N LU O N N OE n UN N U co c o - co �' z° a o ° F a c I N F- O a) Z o J2 (N1 as CCI o CC• O o ) J tl) Cl) n a) V/ Q 0 Q a C > Y o I— a) o Q a • E Z aUi o CC us 0 d C• a) E _ce co ca -a U Z 7 U U) y0 y0 co N co CO C0 CO CO CO O) CO 00 CO 03 c0 a) o (0 CO as 'O c0 co co co CO 03 m CO CO CO CO CO COco E E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a Z o o m I co co (a co co co co co o m m m 2 o) o) rn ca -rn -rn 'rn 'rn 'o) 'rn 'rn ca co 'rn 'rn o 0 z _ ` D D D 0 0 0 0 0 0 0 0 0 0 0 0 co > O J ` d d O) O) O) O) V .7 -7 -7 V V V R -4- V V -a- es F p N -0 V V V V 7 7 .1 .1 V .7 V V V V V a) w E as O) O) O) co co co C) C) C) C) C) C) co co co Q Z L C N 10 7 V V V V t!) to LU O O W 0 z N (Ni N N N N N N N N N N N N N N N CC IP H , @ LL Q O Z 2 00 w 2 01LL o r— D O t) C v U) re 2 W p 0 2a) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Co :. l J a 2 o 3 Joy w 0 0 0 LLI w LU W W W W 0W IL LU 0 0 �o 0 C __ -_-- Ln O I 1• ��U co Om )- >- r Z M U o C W co N ca. C J it 9 a T H uo C f° N N C L-J 'O a CI 0 o Y o `o ca Z U U < N N < 1CO V > i H (•^�, U U p Gt 1f�7/I �J ` Yq 43 _IX Mw Y } co I—cc Q CH .5 %, W V .@y p c W U W U N 2 CO N 0 it 1 11 O a C +. co U '� C. .- CL a J may ; p p W = v v v> zui rn IX 0 N N CU IX w W z z • y a) co0) a V O c7 Q > E U d Z dCC u :? <n a to' O• O coim ` N J a C J a)a 7 o E c w4 = o O c 2 U U in C a) C O I s G I' 1 O a c> E I H ca z c w N m o J J , EN a o a N p E H N O Cl) H CO CL• o IliLrens N m c c < p ` ° 1 1 ICE Y ta 0 a c a ° c O ICC z E m —' 0 oco m E co co in 1, z II m CO ZI3 vv m CO CO v C 4 N N co To To II v ao p V o a ISI 7 co co M co a O m N 10 10 10 N N N 1 ai W C H co d l a a) a' 0 C - = .. 1 •> E E Z a 5 Y w m cc m to O o 1) c 1 pco cc) Lo m z Q o o Q o 0 iri c C.) m c °° 0 U U V x n 0 o a a m - E ' a p d 0 p a o o OLL o o aa' OO o aoi d E E a 2 w w _1 3 Z U a 0 ' 0 0 c p 0 1 0 Guhl, Meredith D (DOA) From: Phillips, Ron L [Ron.L.Phillips@conocophillips.com] Sent: Thursday, February 26, 2015 9:07 AM To: Guhl, Meredith D (DOA) Subject: RE: KRU 2T-09 L1 and KRU 2T-09 L1-01, PTD 214-133&214-134, Data Required Meredith, My mistake the only logs we ran were the GR/Res for both these wells(2T-09L1 and 2T-09L1-01).The other logs listed on the 10-407 forms (CBL, sonic, neutron,density and CCL)were not ran. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, February 19, 2015 1:10 PM To: Phillips, Ron L Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 2T-09 L1 and KRU 2T-09 L1-01, PTD 214-133 &214-134, Data Required Ron, On the 10-407 forms for KRU 2T-09 L1 and KRU 21-09 L1-01, PTD 214-133 and 214-134, in Box 21. Logs Obtained, the following logs are listed:GR/Res,CBL,sonic, neutron,density,CCL.The two wells were completed on October 4, 2014. At this time the only data received at the AOGCC is GR/Res for both wells. Data is due within 90 days of well completion. Please submit the CBL, sonic, neutron, density and CCL logs for each well branch by March 5, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 F►..CEIVED FEB 0 4 2015 Letter of Transmittal min AOGCC BAKER Date: DATA LOGGED February 3, 2015 z BENDgbi S HUGHES To: From: State of Alaska, AOGCC Jesse Salyer 333 West 7th Ave, Suite 100 Baker Hughes INTEQ Anchorage, Alaska 99501 795 East 94th Avenue Anchorage, Alaska 99515 jesse.salyer@bakerhughes.com Please find enclosed the final well data for the following well(s): Well: 2 -1. 1 % 14L3 253 ' 1-01 2 1 4 1 3 4 4 5 Enclosed for each well(s): 1 hardcopy print of final logs • 2MD, 5MD & TVDSS 1 compact disk containing final field data • CGM • PDF • SURVEY • TIFF • LAS RECEIVED STATE OF ALASKA OCT 3 0 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANIYLG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑✓ ' WDSPL ❑ Other ❑ No.of Completions: Service Q StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: October 4,2014 214-133/ ' 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 September 20,2014 50-103-20071-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 227'FSL,556'FWL,Sec. 1,T11 N, R8E, UM September 25,2014 K94.) 2T-09L1 Top of Productive Horizon: 8.KB(ft above MSL): 117'RKB 15.Field/Pool(s): 1455'FSL, 1493'FWL,Sec. 1,T11 N,R8E, UM GL(ft above MSL): 78'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 737'FNL, 1530'FWL,Sec. 12,T11 N, R8E, UM 8785'MD/5866'TVD , Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498945 y- 5970208 Zone-4 8785'MD/5866'ND • ADL 25569 ' TPI: x-499881 y- 5971435 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-499919 y- 5969243 Zone-4 SSSV @ 2022'MD/2018'TVD 2667 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) 1463'MD/1463'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res, pie rm. fa. e4,„A,y .,2Aa(„• MG 5985'MD/5763'ND • 23. CASING,LINER AND CEMENTING RECORD 1 SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 35' 110' 35' 110' 24" 255 sx CS II 10.75" 45.5# J-55 35' 1992' 35' 1989' 12.25" 850 sx AS III,160 sx Class G 7" 26# J-55 1795' 6351' 1794' 6122' 8.5" 540 sx Class G,175 sx AS I 2.375" 4.6# L-80 6262' 8733' 5868' 5865' 3" slotted liner 24.Open to production or injection? Yes Q 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(MDfTVD) 3.5"x 5.5" 6011' 5850'MD/5630'ND slotted liner from 6287'-8732'MD 5861'-5865'ND flbMPl.E710t g 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes No❑ 1(>) [. ILI DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012V IL- Z l G//5" CONTINUED ON REVERSE S b it original only .moi 'z%% '- RBDM; , JAN - 4 .2015 G 29..GEOLOGIC;MARKERS(List all formations and ma :ncountered). 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1463' 1463' needed,and submit detailed test information per 20 AAC 25.071 Kuparuk B1 5985' 5763' Kuparuk Top A6 6010' 5786' Kuparuk Top A5 6013' 5790' Kuparuk Top A4 6019' 5795' Kuparuk Top A3 6027' 5803' Kuparuk Top A2 6092' 5855' Kuparuk A3 6311' 5855' N/A Formation at total depth: Kuparuk A3 I 31 LIST OF ATTACHMENTS Summary of Daily Operations,final directional survey, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact' Ron Phillips @ 265-6312 Email 1` Ron.L.Phillipsaconocophillips.com Printed Name D. haus Title CTD Engineering Supervisor p Signature(2/WI- L G " Wl� Phone 263-4372 Date I C� 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 summaryof this box.Submit detailed test and P 9 analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 i I� KUP INJ 2T-09 ,,.- • Co �CVri il��)P S Well Attributes Max Angle&MD TD Alaska,Inc. Wel[bore APIRA l Field Name Weitbore Status ncl(°) MD(ftKB) Act Btm(0103) ,mocriR.1,ps 501032007100 KUPARUK RIVER UNIT INJ 25.70 3,600.00 6,370.0 .°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 27-09,10/27/201411:43:40 AM SSSV:TRDP _ _Last WO: 7/10/2014 40.69 7/5/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,268.0 9/1/2014 Rev Reason:SET WHIPSTOCK lehallf 9/14/2014 HANGER;28.3 1t5 met Casing Strings Casing Description OD(In) ID(In) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SURFACE 103/4 9.950 34.8 1,992.3 1,988.7 45.50 J-55 BUTT IU' Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(L..Grade Top Thread PRODUCTION TIE- 7 6.276 30.3 1,795.3 1,794.3 26.00 L-80 TC-II ..................,,.,,,,.,,,...,..,,..,,,,",...... W BACK Casing Description 013(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread WINDOW 7 6.276 5,990.0 6,000.0 5,777.4 -A-A1 CONDUCTOR 35.0.110.0e4 I t c/,,h.Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 1,795.3 6,351.1 6,122.1 26.00 J-55 BUTT - Tubing Strings Tubing Description !String Ma...10(in) !Top(ftKB) I Set Depth(ft..1Set Depth(ND)(...'Wt(lb/It) Grade Top Connection TUBING WO 3 1/2 x 5 31/2 2.992 283 6,012.0 5,789.2 9.30 L-80 EUE 1/2 @5926.1 PRODUCTION TIE-6ACK;30. 3 ,, Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) I 28.3 28.3 0.03 HANGER MacEVOY GEN 4 TUBING HANGER 2.992 2,022.2 2,018.2 9.32 SAFETY VLV TRMAXX-CMT-SSR SAFETY VALVE 2.812 SURFACE;34.84.992.3- 5,820.5 5,601.7 12.84 LOCATOR SEAL ASSEMBLY LOCATOR SUB 2.980 5,820.8 5,602.0 12.83 SEAL ASSY SEAL ASSEMBLY"Stick-Up"(21.69'total length) 3.000 5,827.8 5,608.8 12.71 PBR 80/40 BAKER POLISH BORE RECEPTACLE 2.990 SAFETY VLV;2,022.2 5,851.0 5,631.3 12.30 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 5,882.9 5,662.6 11.73 NIPPLE HES"X"NIPPLE 2.813 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl GAS LIFT;2,604.3 Top(ftKB) 1 (ftKB) 1 (°) 1 Des Corn Run Date ID(In) 5,985.0 5,762.7 11.23 WHIPSTOCK WHIPSTOCK AND 2 RA TAGS 9/7/2014 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f GAS LIFT;3,615.2 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 6,022.0 6,040.0 5,799.0 5,816.6 A-4,A-3,2T- 10/13/1986 1.0 IPERF 90 Deg.Phasing;4" 09 HyperJet 6,040.0 6,058.0 5,816.6 5,834.3 A-3,21-09 10/13/1986 4.0 (PERF 90 Deg.Phasing;4" HyperJet GAS LIFT,4,6807 Cement Squeezes Top(ND)I Blm(ND) Top(ftKB) Btm(ftKB)IIF (ftKB) (ftKB) Des Start Date _ Com 44.0 1,784.0 44.0 1,783.1 CEMENT SQZ 7" 7/26/2014 PUMP 152 BBL of 15.7#CLASS G CEMENT 0 10-3/4" PressureNet.TOC 44.3'RKB GAS LIFT,5,329.9 Mandrel Inserts St ati on Top(ND) Valve Latch Port Sire TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type _ (In) (psi) Run Date Corn { 2,604.3 2,592.2 CAMCO 'MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/2/2014 GAS LIFT;5,764.5 2 3,815.3 3,730.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/2/2014 3 4,680.7 4,532.3 CAMCO 'MMG 11/2 GAS LIFT DMY RK 0.000 0.0 8/2/2014 -. 4 5,329.9 5,131.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 8/2/2014 5 5,764.5 5,547.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/31/2014 Notes:General&Safety LOCATOR;5,620.5 End Date Annotation 12/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SEAL ASSY;5,aZ0.a 7/10/2014 NOTE:DRILLED OUT CEMENT SQZ @ 5,700'DURING 2014 WO PER 5,827.8 PACKER;5,851.0 NIPPLE;5,882.9Fl I II XO Enlarging(Tubing);5,9261 011-$1 1 III SLOTS;5,939.8.8,047.1 4.1_. LINER L1-01;5.915,7-8.047.51 WHIPSTOCK 5,985.0 WINDOW;5,990.0.6000.0 CMT PLUG;5,700.0 (PERF;6,022.06,0400~-� I IPERF;6,040.06,0580 PRODUCTION;1,795.36.351.1 - KUP SVC 2T-09L1 ' ConocoPhillips " Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Const,rniop, 501032007160 KUPARUK RIVER UNIT SVC 105.96 6,285.14 8,785.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 2T-091_1,1027/201411:44:34 AM Last WO: 40.69 7/5/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date T�.�Fr�rr.,,,_,.,. Last Tag: Rev Reason:ADD LATERAL L1,L1-01 haggea 10/21/2014 II,',NGLit.;n3 L.LsYSd.I Casing Strings Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(ND)...Wt/Len(I.,,Grade Top Thread LINER LI 23/8 1.992 6,261.7 8,733.0 5,865.3 4.60 L-80 STL Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(°) item Des Com (in) 6,261.7 5,867.9 105.71 BILLET OH ANCHORED BILLET 1.000 is/ 6,382.3 5,838.0 101.28 DEPLOY SHORTY DEOPLOYMENT SLEEVE 1.920 8,732.6 5,865.2 89.08 SHOE BULL NOSE(Non-Ported) 1.000 .AAI CONDUCTOR;35.0.110.0 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(11KB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PRODUCTION TIE-BACK;30.3- 4 ) 5,939.8 8,047.1 5,718.4 5,848.1 A-3,2T-09 10/1/2014 SLOTS Slotted Liner 1,795.3 6,287.3 6,382.0 5,860.9 5,838.1 A-3,2T-09 9/27/2014 SLOTS Slotted Liner ( Notes:General&Safety End Date Annotation 9/27/2014 NOTE:ADD LATERALS L1-L1-01 SURFACE;34.8.1,992.3-1 �- SAFETY VW;2.022.2 GAS LIFT;2,604.3 1 E GAS LIFT;3.815.2 ■ F GAS LIFT;4.6807 1 F GAS LIFT;5,3299 i F GAS LIFT;5,764.5 LOCATOR;5,820.5 SEAL ASSY;5,820.6 “ PBPo 5,827.81 CMT PLUG;5,700.0 PACKER;5,851.0 NIPPLE;5,882.9 I ;(0 Enlarging(Tubing);5,9261 WHIPSTOCK;5,985.0 PRODUCTION;1,795.3.6,351.1 LINER LI-01;5,915.7-8,047.5 SLOTS;6.287.3-6,381.9 i SLOTS;5,939.88.047.1 LINER Lt;6,261.6-8,733.0 l n i CD in N N A o 0 - Xco N 0 0 . . a Q N 1c0 o � o C o C O m v E 3 t 0`O .q' Ch 1A <Va) O O ° � j , , CO > Z � O, , ri V M CO 9 X 0,30 �CI , , ' Ogg N I - ..� iD j� O O , , w O > CD C13(n coc2 1n in a) C a) a) ' I co co m c00 (n C C 1. J (� N © C © N F-J J �1 i ©CO J CC ct O) C 00 a) Oa 3 , , Q N a) (1) N 1A > WO I. F-0C -0 1n : �` o 7S$ Jv s, s NI--Jm l- a Q V N = -2 a (C6 2 a) O co L 4 U oo E -• a V c 6 . 'a X W 1A •E a) O r O X ,°o° a, -ta� NN 2 Q W W C O _p_ m 4t E o Cl) ' J Cr) m m W r r I i CO 6 U a. 2 o m ' , N N N a) N J N 1 , Yr r •,-- 01) M ("') C'S m M C') 10 , , U I (Uii i I ��► \:\: _ U n n •% 2T-09 WELL WORK SUMMARY DATE ' SUMMARY PRE-RIG WELL WORK 8/26/2014 (PRE-CTD): TREE TEST, DDT'S: MV-PASSED. SSV-PASSED.SV-PASSED. PT'S: SV-PASSED. SSV-PASSED. MV-PASSED. 8/31/2014 SET CATCHER PXX PLUG @ 5882' RKB; PULL SOV & SET DV© 5764' RKB; MIT TBG TO 2500 & MIT IA TO 2500 (BOTH PASSED); PULLED CATCHER; PULL P PRONG & PX PLUG BODY @ 5882' RKB. IN PROGRESS 9/1/2014 MEASURE BHP @ 6200' RKB (3132 PSI); DRIFT TBG W/2.63" x 20' BAKER WHIPSTOCK DRIFT DOWN TO 6200' RKB. READY FOR E-LINE. IN PROGRESS. 9/7/2014 SET TOP OF WHIPSTOCK AT 5985'. WHIPSTOCK ORIENTATION 2 DEGREES RIGHT OF HIGH SIDE. BOTTOM OF WHIPSTOCK AT 5998'. 2 RA TAGS INSTALLED AT 5992.35'. COLLARS IN 5 1/2"TUBING AT 5979'AND 6022'. JOB COMPLETED • ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 21-09 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 9/19/2014 12:00:00 AM Rig Release: 10/4/2014 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/18/2014 24 hr summary Move rig from 2M-Pad to 2T-Pad. MIRU CDR2 on 2T-09. NU BOP stack. 12:00 17:00 5.00 0 0 MIRU MOVE MOB P Move Rig 2M to 2T-09 17:00 22:00 5.00 0 0 MIRU MOVE MOB P Arrive on location, PJSM. Have 21-201 injector shut-in. Prep well site for modules,spot modules over 21-09, berm up cellar, R/U Putz, steam and interconnect, pre-spud checklist. 22:00 00:00 2.00 0 0 MIRU WHDBO NUND P NU BOPE, MP line and cellar lines, check all flange bolts. 39/19/2014 Complete initial BOPE test. Pull BPV, load coil,test PDL's and Tiger tank line. MU BHA#1, TIH w/milling assembly. Start time milling window exit @ 5,990', milling in progress. 00:00 02:00 2.00 0 0 MIRU WHDBO RURD P Grease BOPE stack,fluid pack equipment,service tree valves. MU hardline to tiger tank. Rig Accept: 00:00 on 09-19-14 02:00 11:30 9.50 0 0 MIRU WHDBO BOPE P Begin initial BOPE test,250/3,800 psi.2,500 annular. State test witnessed by Chuck Scheve. BOP test complete,tested inner real iron, and stripper. No faillures. 11:30 12:30 1.00 0 0 MIRU WHDBO BOPE P Stab injector on well, Fill coil and PT inner reel iron and packoffs 12:30 14:15 1.75 0 0 MIRU WHDBO MPSP P PJSM, R/U BPV Lubricator, Pull BPV, R/D and load out lubricator 14:15 15:00 0.75 0 0 MIRU WHDBO PRTS P Pressure test PDL's and tiger tank line, attempt to bleed off WHP, unable to bleed off WHP 15:00 15:42 0.70 0 0 SLOT WELLPF SFTY P Pre spud meeting held with new day crew-Kaleo Ensfield 15:42 18:27 2.75 0 76 PROD1 WHPST PULD P PJSM, M/U BHA#1 and pressure deploy 18:27 19:57 1.50 76 5,980 PROD1 WHPST TRIP P TIH w/Window milling assembly, tie-in K1 marker for+ 1.5'correction, continue in hole 19:57 21:00 1.05 5,980 5,990 PROD1 WHPST DISP P Displace hole to used mud system, losing .5 bph. RBIH. 21:00 00:00 3.00 5,990 5,992 PROD1 WHPST WPST P Dry tag TOWs @ 5,990'. Begin time milling @ 1.45 bpm @ 3,050 psi, as per well plan. 39/20/2014 Time window exit as per well plan, back ream window. Drill rathole to 6,010'. POOH for drilling assembly. PUD BHA#1, PD BHA#2. Start drilling build section to 6,116', drilling in progress. Page 1 of 13 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 09:37 9.62 5,992 6,001 PROD1 WHPST WPST P Continue window milling operation as per well plan @ 1.45 bpm @ 3,100 psi, losing mud @.5 bph. 09:37 12:12 2.59 6,001 6,010 PROD1 WHPST WPST P Milling Rathole 6001'-6010'. PUW 24k 12:12 14:40 2.47 6,010 72 PROD1 WHPST REAM P Backream window and open hole, dry drift,drift clean and POOH for drilling assembly 14:40 16:52 2.20 72 73 PROD1 WHPST PULD P PJSM, L/D BHA#1 Milling Assembly,WS mill NO-GO 2.80", String mill NO-GO 2.79". 16:52 19:01 2.15 73 PROD1 DRILL PULD P PD BHA#2 Build Section Assembly 2.30"AKO motor. 19:01 21:25 2.40 73 6,010 PROD1 DRILL TRIP P TIH w/drilling assembly,tie-in to K1 with zero correction,continue in hole. PUW @ window 21K. 21:25 23:59 2.57 6,010 6,116 PROD1 DRILL DRLG P Start drilling build: 1.45 BPM @ 3,125 psi, BHP=3820 psi, CTW=9.8K, DHWOB=2.5K, ROP=40. 09/21/2014 Drill ahead build section to called TD @ 6,553'.TOOH for RSM assembly, PUD BHA#2, PD BHA#3. TIH w/ RSM drilling assembly,start drilling L1 lateral,drilling in progress. 00:00 05:24 5.40 6,116 6,270 PROD1 DRILL DRLG P Continue drilling build: 1.45 BPM @ 3,150 psi, BHP=3,580 psi, CTW=9K, WOB=2.6K, ROP=30. Started pumping new mud, new mud at bit @ 6,209'. 05:24 05:50 0.44 6,270 6,014 PROD1 DRILL WPRT P Wiper trip, PUW 22k 05:50 14:24 8.58 6,270 6,470 PROD1 DRILL DRLG P RBIH,continue drilling build: 1.45 BPM at 2980 psi, BHP=3580,WOB 2.6k 14:24 14:58 0.58 6,470 6,015 PROD1 DRILL WPRT P Wiper trip, PUW 22k 14:58 16:40 1.70 6,470 6,553 PROD1 DRILL DRLG P RBIH,continue drilling build and into turn: 1.45 BPM @ 3050 psi, BHP= 3580 psi, CTW=7k,WOB 2.4k,Avg ROP=40 16:40 19:13 2.55 6,553 72 PROD1 DRILL TRIP P Weight check=23k, POOH 19:13 21:55 2.70 72 70 PROD1 DRILL PULD P At surface, PJSM. PUD BHA#2, LD motor&bit. PJSM PD BHA#3 RSM assembly. 21:55 23:40 1.75 70 6,553 PROD1 DRILL TRIP P TIH w/RSM assembly,tie-in for+1' correction,continue in hole. 23:40 23:58 0.30 6,553 6,571 PROD1 DRILL DRLG P Drill ahead: 1.44 BPM @ 3,360 psi, BHP=3,640 psi, CTW=7.3K, WOB=1.5K, ROP=50. 09/22/2014 Drill ahead L1 lateral from 6,571'to 7,410',drilling in progress. 00:00 02:45 2.75 6,571 6,760 PROD1 DRILL DRLG P Drill ahead: 1.44 BPM @ 3,360 psi, BHP=3,640 psi, CTW=7.8K, WOB=1.8K, ROP=90. 02:45 03:48 1.05 6,760 6,760 PROD1 DRILL WPRT P Wiper trip, PUW=22K, RBIH @ 03:20 03:48 07:48 4.00 6,760 6,960 PROD1 DRILL DRLG P Drill ahead: 1.44 BPM @ 3,260 psi, BHP=3,630 psi, CTW=6.7K, WOB=1.25K, ROP=100. Page 2 of 131 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:48 08:24 0.60 6,960 6,960 PROD1 DRILL WPRT P 6960',Wiper to 6018, PUW=23K 08:24 14:48 6.40 6,960 7,160 PROD1 DRILL DRLG P 6960', Drill ahead, 1.44 BPM @ 3036 PSI FS, BHP=3611 14:48 15:48 1.00 7,160 6,009 PROD1 DRILL WPRT P 7160,Wiper to window and jet 5" tubing to 5930 with 5 X 5 sweeps 15:48 15:54 0.10 6,009 6,021 PROD1 DRILL DLOG P Log RA marker for+3.5' 15:54 16:30 0.60 6,021 7,160 PROD1 DRILL WPRT P Wiper trip back to bottom 16:30 23:33 7.05 7,160 7,410 PROD1 DRILL DRLG P 7160', Drill, 1.45 BPM @ 3030 PSI FS, BHP=3635, stacking @ 7,338', perform mini wiper, PUW=28K. Continue drilling, had bad wrap on reel, so we drill to 7,410'. 23:33 00:00 0.45 7,410 7,410 PROD1 DRILL WPRT P Wiper to window, PUW=23K. 09/23/2014 Drill ahead L1 lateral from 7,410'to 8,187', pumped new mud system @ 7,625', drilling in progress. 00:00 00:33 0.55 7,410 7,410 PROD1 DRILL WPRT P RBIH after wiper to window 00:33 05:25 4.88 7,410 7,610 PROW DRILL DRLG P Drill ahead: 1.43 BPM @ 3,210 psi, BHP=3,640 psi, CTW=6K, WOB=1.85K, ROP=40. 05:25 05:55 0.50 7,610 6,570 PROD1 DRILL WPRT P Wiper trip to 6570, PUW=23K 05:55 06:25 0.50 6,570 7,609 PROD1 DRILL WPRT P RBIH. 06:25 11:55 5.50 7,610 7,809 PROD1 DRILL DRLG P 7609', Drill ahead, 1.44 BPM @ 3140 PSI FS, BHP=3700 11:55 13:19 1.40 7,809 5,930 PROD1 DRILL WPRT P Wiper trip to 5,930' PUW=23K Continue reciprocating pipe while cuttings(a lot of cuttings)keep coming across the shaker 13:19 13:31 0.20 5,930 5,992 PROD1 DRILL DLOG P RBIH and Tie into RA Marker© 5,992' Make correction of+4.5' 13:31 14:19 0.80 5,992 7,810 PROD1 DRILL WPRT P RBIH. RIW= 10.7K 14:19 18:49 4.50 7,810 8,010 PROD1 DRILL DRLG P BOBD. Rate=1.44 bpm CP= 3,125 psi WHP=264 psi IA=274 psi OA=0 psi. BHA wiper© 7,926', one stall @ 7,963', BHA wiper, new mud system around at 7,925'. 18:49 19:55 1.10 8,010 8,010 PROD1 DRILL WPRT P Wiper trip to 6,810', PUW=23K, RBIH @ 19:35. 19:55 23:59 4.07 8,010 8,187 PROD1 DRILL DRLG P Drill ahead: 1.44 BPM ©3,395 psi, BHP=3,740 psi, CTW=6K, WOB=1.5K, ROP=45. 09/24/2014 Drill ahead L1 lateral from 8,187'to 8,695', drilling in progress. 00:00 00:45 0.75 8,187 8,210 PROD1 DRILL DRLG P Drill ahead: 1.44 BPM @ 3,420 psi, BHP=3,760 psi, CTW=2K, _WOB=1.3K, ROP=45. 00:45 01:51 1.10 8,210 8,210 PROD1 DRILL WPRT P Wiper trip to 7,010', PUW=24K, RBIH @ 01:25 01:51 07:39 5.80 8,210 8,410 PROD1 DRILL DRLG P Drill ahead: 1.42 BPM @ 3,410 psi, BHP=3,745 psi, CTW=4.5K, WOB=1.5K, ROP=35. Page 3 of 13 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:39 09:21 1.70 8,410 5,920 PROD1 DRILL TRIP T Trouble with rib steer motor (intermittent signals)POOH. 09:21 09:51 0.50 5,920 5,920 PROD1 DRILL OTHR T Stop @ 5,920'and test new BOP Chart Recorder piping in Doghouse. 09:51 10:47 0.94 5,920 65 PROD1 DRILL TRIP T Continue POOIH to change RSM and bit. 10:47 10:59 0.20 65 65 PROD1 DRILL SFTY T At surface. Pre-pressure undeploy safety meeting. 10:59 11:53 0.90 65 0 PROD1 DRILL PULD T Begin pressure undeploy procedures. 11:53 12:44 0.85 0 0 PROD1 DRILL PULD T Lay down BHA#3 and pick up BHA #4. Have.5 motor and agitator in BHA. 12:44 13:02 0.30 0 0 PROD1 DRILL SFTY T Pre-Pressure Deploy Safety Meeting. 13:02 14:29 1.45 0 69 PROD1 DRILL PULD T Begin pressure deploy procedures. 14:29 17:02 2.56 69 8,390 PROD1 DRILL TRIP T RBIH. WHP=628 psi IA=0 psi OA=0 psi .25 bpm CP= 1,435 psi Tie in @ K1 marker for a correction of+1' 17:02 19:47 2.75 8,410 8,590 PROD1 DRILL DRLG P BOBD @ 1.41 bpm at 8390' WHP =293 psi CP=3,343 psi IA=45 psi OA=0 psi. 19:47 21:02 1.25 8,590 8,590 PROD1 DRILL WPRT P Wiper trip, PUW=24K, RBIH. 21:02 23:29 2.45 8,590 8,695 PROD1 DRILL DRLG P Drill ahead: 1.43 BPM @ 3,460 psi, BHP=3,780 psi, CTW=2.5K, WOB=1.2K, ROP=35. Stacking @ 8,610',one overpull to 45K, pull free. Several mini wipers over the next 80'. Pump sweeps, pull early wiper to window. 23:29 23:59 0.50 8,695 8,695 PROD1 DRILL WPRT P Start wiper to window, PUW=30K. 09/25/2014 Drill ahead L1 lateral to 8,780', started losing returns @ 8,715', lost all returns @ 8,730'. Started laying completion fluid with losses,got bit stuck in window @ 5,988', able to pump down backside, free BHA. Change plan forward, circulate out KWF and recondition hole for laying in completion fluids, in progress. 00:00 02:30 2.50 8,695 8,695 PROD1 DRILL WPRT P Wiper to window,clean 5 1/2"tail pipe, RBIH. Increase lubes by half percent. 02:30 06:00 3.50 8,695 8,779 PROD1 DRILL DRLG P Drill ahead: 1.43 BPM @ 3,460 psi, BHP=3,780 psi, CTW=2.5K, WOB=1.2K, ROP=35.At 8,715' started expecting losses of 60 bph. PUH, pump hi vis pill. RBIH. Continue drilling, losses are currently 85 bph, no returns. Mini wiper @ .8,778'. 06:00 07:30 1.50 8,779 5,935 PROD1 DRILL CIRC T Continue reciprocating coil above the window pumping @ 1.42 bpm and getting about.25 bpm returns. Waiting on 0700 call-in meeting for plan forward. WHP=381 psi CP= 3,511 psi Page 4 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 10:00 2.50 5,935 5,975 PROD1 (DRILL CIRC T After morning call-in meeting we PUH above the window and lowered our wellhead pressure by 100 psi and monitored the return volumes while still pumping @ 1.45 bpm.After 20 minutes the returns had stabilized at 1 bpm while maintaining 290 psi WHP. Conferred w/town engineer and told to hold steady until decision made on plan forward. 10:00 11:24 1.40 5,975 79 PROD1 DRILL WPRT P Received plan forward and have started a wiper trip to the swab. 11:24 14:06 2.70 79 8,785 PROD1 DRILL WPRT P RBIH to TD. 14:06 14:12 0.10 8,785 6,175 PROD1 DRILL DISP P At TD. Make a corrective depth change from 8,778'to 8,785'. PUH pumping 23 bbls of 100LSRV 9.6 PowerVis mud w/2 ppb Alpine Beads to 6,175'. 14:12 15:18 1.10 6,175 5,985 PROD1 DRILL DISP P At 6,175'switch to pumping 11.9 ppg NaBr completion fluid w/2 ppb Alpine Beads to surface. 15:18 16:24 1.10 5,985 4,282 PROD1 DRILL DISP T Stuck at the top of the window with the bit. Can not pump down coil. Can not move north or south. Confer with town. Pump down backside to lessen DP. DP down to 0 psi. Pull bit through window. 16:24 17:33 1.15 4,282 5,975 PROD1 DRILL DISP T Town called and decision made to go back to TD,diplace well with 9.6 mud and sweep solids to the swab again. RBIH pumping 9.6 PowerPro. 17:33 20:03 2.50 5,975 5,975 PROD1 DRILL DISP T Displace hole back to 9.6 ppg mud, recover KWF.Jet 5 1/2"tail pipe three times max rate. 20:03 21:57 1.90 5,975 6,175 PROD1 DRILL WPRT T RBIH @ 20 fpm with pump off,tag @ 5,990'. Spin bit,try again,tag up same depth, stacked 3K down. Made several attempts at several different speeds and tool face changes, unsuccessful. PUH to for tie-in at K1 for+5.5'correction. RBIH at 15 fpm with pump down, tool face @ 15 ROHS, saw tag @ 5,995',then fell through BOW. 21:57 22:30 0.55 6,175 6,175 PROD1 DRILL WPRT T PUH to 3 1/2"tbg,jet 5 1/2"tail pipe max rate, RBIH through WS, saw 3K set down,then passed. 22:30 23:15 0.75 6,175 8,700 PROD1 DRILL WPRT T RBIH to 8,700' 23:15 23:45 0.50 8,700 8,700 PROD1 DRILL CIRC T Circulate in 15 bbl hi vis pill @ 1.40 bpm, return rate 85%. 23:45 00:00 0.25 8,700 8,150 PROD1 DRILL WPRT T Wiper trip to swab @ 1.42 bpm, POH rate in OH is 35 fpm. X9/26/2014 Complete wiper to swab, RBIH. Lay in completion fluid from 8,700'. Run lower liner assembly to 8,733', POOH w/BHA#5. 00:00 03:03 3.05 8,150 73 PROD1 DRILL WPRT T Continue wiper trip to swab @ 1.42 bpm, POOH rate in tubing 60 fpm. Page 5 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:03 04:18 1.25 73 5,450 PROD1 DRILL TRIP T RBIH to 8,700'. BHI counter failure @ 5,450'. 04:18 05:03 0.75 5,450 5,450 PROD1 DRILL TRIP T Troubleshoot BHI counter, swap out counter. 05:03 05:17 0.24 5,450 5,910 PROD1 DRILL WPRT T Continue in hole for tie-in 05:17 05:20 0.05 5,910 5,942 PROD1 DRILL DLOG T Log for tie in at the K1 marker. Make correction of+5'. 05:20 06:44 1.40 5,942 8,664 PROD1 DRILL WPRT T Continue RBIH.Tag at window and pop through 06:44 07:44 1.00 8,664 6,175 PROD1 DRILL DISP T POOH laying in 15 bbl hi-vis pill at the thief zone followed by the 9.6 mud with beads. 07:44 09:17 1.55 6,175 79 PROD1 DRILL DISP P Continue POOH with 11.9 NaBr laying in from 6,175'to surface. ***Only the slightest weight bobble was observed pulling up through the window on this trip.*** ***Laying in 11.9 NaBr @ 6,175' ends Trouble Time*** 09:17 09:53 0.60 93 93 PROD1 DRILL OWFF P At surface. Monitor well for flow. 09:53 11:41 1.80 93 0 PROD1 DRILL PULD P PJSM. L/D BHA#4. Prep floor to run liner. 11:41 12:11 0.50 0 0 PROD1 DRILL BOPE P Function test BOPE. Successful. ***Crew Change Out Day*** 12:11 14:41 2.50 0 2,395 COMPZ CASING PUTB P PJSM. PU/MU Liner Assembly: Bull Nose,74 jts. slotted liner and deployment sleeve. ***Test Joint Drill Performed during liner assembly*** 14:41 16:29 1.80 2,395 2,395 COMPZ CASING PULD P PJSM. M/U L1 lower liner running BHA#5 on liner assembly and M/U to coil. Test wire conductivity while on surface. 16:29 18:41 2.20 2,395 6,010 COMPZ CASING RUNL P TIH w/BHA#5,tie in correction, PUW above window24K, continue in hole, saw 4K stack in window,then fell through. 18:41 22:05 3.40 6,010 8,733 COMPZ CASING RUNL P Had to work liner in hole from 6,600' to 8,325',till BHA cleared bottom of window,stacked out @ 8,734', right at thief zone, unable to work liner below 8,733'. PUW=34K, set down, release from liner, PUW=22K. PUH, remove 2,350'from counter. 22:05 23:59 1.91 8,733 76 COMPZ CASING TRIP P POOH w/BHA#5,tie-in for+1.5' correction, paint EOP flag @ 5,700', continue out of hole. 09/27/2014 Run upper liner assembly to 6,379', release from liner. POOH and LD BHA#6. TIH w/BHA#7, circulate hole to drilling mud,dress window with 2.79"crayola mill. TOOH and LD BHA#7. PD BHA#8,TIH drilling assembly,start time milling off billet @ 6,260', milling in progress. 00:00 00:30 0.50 76 76 COMPZ CASING OWFF P At surface, monitor well for flow, no flow. Page 6 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:30 1.00 76 0 COMPZ CASING PULD P PJSM. LD BHA#5, prep floor second segment. 01:30 03:45 2.25 0 182 COMPZ CASING PUTB P PU/MU Upper liner assembly, bull nose, 3 jts slotted, 2 solid pups, OH anchored billet. MU BHA#6. 03:45 05:58 2.23 182 6,379 COMPZ CASING RUNL P TIH w/BHA#6, tie-in to EOP flag @ 5,700' 05:58 06:13 0.26 6,379 6,379 COMPZ CASING RUNL P Tag top of liner. P/U to weight, pumps up,set billet. 06:13 07:34 1.35 6,379 76 COMPZ CASING TRIP P TOOH @.62 bpm. WHP=2 psi 1CP=777 psi IA=0 OA=0 PUW= 18K 07:34 08:04 0.50 76 76 COMPZ CASING OWFF P At surface. Monitor well for flow. PJSM for UD#6 BHA. 08:04 09:04 1.00 76 0 COMPZ CASING PULD P L/D BHA#6. 09:04 10:58 1.90 0 70 PROD2 STK REAM T M/U BHA#7 w/1.1 bent motor and Crayola Mill. ***Confer with town engineer and decision made to RBIH and dress window**** 10:58 12:28 1.50 70 5,915 PROD2 STK TRIP T TIH to dress window. Pump minimum rate @ .40 bpm CP=603 psi WHP= 13 psi IA=0psi OA=0 psi 12:28 13:13 0.75 5,915 5,962 PROD2 STK DISP P Displace 11.9 mud w/beads to 9.6. Make tie-in correction of 4.5'at K1 marker. 13:13 15:28 2.25 5,962 5,996 PROD2 STK REAM T Wellbore displaced with 9.6 mud. Begin dressing window with Crayola Mill. Motor on initial pass and metal shavings collected at the shaker with first bottoms up.Zero to very slight motor work seen on subsequent passes. Dry pass made with no issues. 15:28 16:46 1.30 5,996 67 PROD2 STK TRIP T TOOH to UD BHA#7. 16:46 18:16 1.50 67 0 PROD2 STK PULD T At surface. PJSM.Begin Pressure _Undeploy procedures. LD BHA#7. 18:16 21:01 2.75 0 72 PROD2 STK PULD P PJSM. PU/MU BHA#8. PD kick-off _drilling assembly 21:01 23:04 2.05 72 6,260 PROD2 STK TRIP P TIH w/drilling assembly,tie-in to K1 for+5'correction,weight check @ 5,940'22K. Dry tag billet @ 6,260'. 23:04 23:58 0.91 6,260 6,261 PROD2 STK KOST P Start time milling billet as per well plan, 1.40 bpm @ 3,230 psi, BHP=3,625 psi, 1 fph. 09/28/2014 Time mill off billet to 6,265. Dry drift billet, clean. Drill ahead turn/build section to called TD @ 6,534'. POOH BHA#8, PUD BHA#8. PD BHA#9,TIH w/lateral drilling assembly,drill ahead L1-01 lateral from 6,534'to 7,006',drilling in progress. Page 7 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 6,261 6,265 PROD2 STK KOST P Continue time milling billet as per well plan, 1.40 bpm @ 3,240 psi, BHP=3,635 psi, 1,2,3,10 fph. 00:45 01:48 1.05 6,265 6,310 PROD2 DRILL DRLG P Drill ahead L1-01 turn section: 1.41 bpm @ 3,270 psi, BHP=3,640 psi, CTW=BK,WOB=1K, ROP=35. Dry drift billet, clean. RBIH. 01:48 03:45 1.95 6,310 6,460 PROD2 DRILL DRLG P Drill ahead L1-01 turn section: 1.43 bpm @ 3,490 psi, BHP=3,665 psi, CTW=8.5K,WOB=1.2K, ROP=75. 03:45 04:21 0.60 6,460 6,460 PROD2 DRILL WPRT P Wiper to window, PUW=22K, RBIH @ 04:05 04:21 06:12 1.85 6,460 6,534 PROD2 DRILL DRLG P Drill ahead L1-01 turn section: 1.44 bpm @ 3,480 psi, BHP=3,655 psi, CTW=8.3K,WOB=1.5K, ROP=80. 06:12 07:54 1.70 6,534 65 PROD2 DRILL TRIP P L1-01 turn section completed. TOOH. 07:54 09:12 1.30 76 0 PROD2 DRILL PULD P At surface, PJSM. Begin pressure undeploy procedures. 09:12 10:21 1.15 0 80 PROD2 DRILL PULD P MU/PU Drilling BHA#9. ***Change Pack-offs*** ***Address wire piching issue on injector skid skid*** 10:21 11:54 1.55 80 80 PROD2 DRILL PULD P PJSM. Pressure deploy. 11:54 13:06 1.20 80 5,915 PROD2 DRILL TRIP P TIH. Pumping minimum rate @.33 bpm CP=1,489 psi WHP=335 psi IA=0 psi OA=0 psi 13:06 13:18 0.20 5,915 5,935 PROD2 DRILL DLOG P Tie in at K1 Marker and make correction of+4'. 13:18 13:39 0.35 5,935 6,534 PROD2 DRILL TRIP P Continue TIH. .30 bpm CP= 1,403 psi WHP=339 psi 13:39 17:31 3.87 6,534 6,740 PROD2 DRILL DRLG P BOBD pumping @ 1.44 bpm CP= 3,443 psi WHP=246 psi IA=0 psi OA=0 psi 17:31 18:25 0.90 6,740 6,740 PROD2 DRILL WPRT P Wiper up hole. PUW=24K. RBIH @ 18:00 18:25 21:43 3.30 6,740 6,940 PROD2 DRILL DRLG P Drill ahead: 1.45 bpm @ 3,385 psi, BHP=3,618 psi, CTW=8.4K, WOB=1.5K, ROP=75. 21:43 22:49 1.10 6,940 6,940 PROD2 DRILL WPRT P Wiper to window, PUW=23K, RBIH @ 22:25 22:49 23:59 1.18 6,940 7,006 PROD2 DRILL DRLG P Drill ahead: 1.45 bpm @ 3,4155 psi, BHP=3,617 psi, CTW=9.2K, WOB=1.2K, ROP=45. 09/29/2014 Drill ahead L1-01 lateral from 7,006'to 8,140', pump new mud system @ 8,067', drilling in progress. 00:00 02:24 2.40 7,006 7,140 PROD2 DRILL DRLG P Drill ahead: 1.44 bpm @ 3,325 psi, BHP=3,665 psi, CTW=8.5K, WOB=1.5K, ROP=55. 02:24 04:39 2.25 7,140 7,140 PROD2 DRILL WPRT P Wiper to window, PUW=23K,tie-in for+2.5'correction, RBIH @ 04:05. 04:39 06:45 2.10 7,140 7,340 PROD2 DRILL DRLG P Drill ahead: 1.42 bpm @ 3,410 psi, BHP=3,665 psi, CTW=9.5K, WOB=1.2K, ROP=100. 06:45 07:33 0.80 7,340 6,140 PROD2 DRILL WPRT P WUH. PUW=21k 07:33 08:00 0.45 6,140 7,340 PROD2 DRILL WPRT P WIH. RIW=7k Page 8 of 13 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:00 10:51 2.86 7,340 7,540 PROD2 DRILL DRLG P BOBD. 1.45 bpm CP=3,529 psi BHP=3,655 psi CTW=9.3 K IA= 275 psi OA=0 psi 10:51 11:30 0.66 7,540 6,340 PROD2 DRILL WPRT P WUH. PUW= 21k 11:30 12:08 0.64 6,340 7,540 PROD2 DRILL WPRT P WIH. RIW= 11k 12:08 14:20 2.21 7,540 7,740 PROD2 DRILL DRLG P BOBD. 1.43 bpm CP=3,516 psi WHP=231 psi BHP=3,661 psi IA =362 psi OA=0psi 14:20 15:44 1.40 7,740 5,920 PROD2 DRILL WPRT P Wiper past window. PUW= 21.7k Jet thru 5 1/2"thoroughly. Tie in correction of+2.5' 15:44 16:38 0.90 5,920 7,740 PROD2 DRILL WPRT P WIH. RIW= 11.8k 16:38 19:32 2.90 7,740 7,940 PROD2 DRILL DRLG P BOBD. 1.43 bpm CP=3,494 psi WHP=236 psi BHP=3,693 psi IA=379 psi OA=0 psi 19:32 20:50 1.30 7,940 7,940 PROD2 DRILL WPRT P Wiper to 6,600', PUW=25K, RBIH @ 20:25 20:50 23:47 2.95 7,940 8,140 PROD2 DRILL DRLG P Drill ahead: 1.43 bpm @ 3,450 psi, BHP=3,710 psi, CTW=8.5K, WOB=2K, ROP=65. Start pumping new mud, mud at bit @ 8,067'. 23:47 23:57 0.18 8,140 8,140 PROD2 DRILL WPRT P Wiper to 6,990', PUW=27K. 09/30/2014 Drill ahead L1-01 lateral 8140'to 8940'. 00:00 01:00 1.00 8,140 8,140 PROD2 DRILL WPRT P Continue wiper from 6,990'. 01:00 04:45 3.75 8,140 8,340 PROD2 DRILL DRLG P Drill ahead: 1.43 bpm @ 3,460 psi, BHP=3,745 psi, CTW=6.5K, WOB=1.85K, ROP=50. 04:45 07:41 2.94 8,340 8,340 PROD2 DRILL WPRT P Wiper trip for tie-in. Make correction of+2.5' Thouroughly jet 5.5"up to 5,920' 07:41 11:08 3.45 8,340 8,540 PROD2 DRILL DRLG P BOBD. 1.44 bpm WHP=311 psi CP=3,321 psi IA=434 psi OA=0 psi 11:08 12:20 1.20 8,540 8,540 PROD2 DRILL WPRT P 8,540', Wiper up hole, PUW 23k, Wiper in hole from 7,340' 12:20 17:32 5.20 8,540 8,740 PROD2 DRILL DRLG P 8,540', BOBD 1.42 bpm at 3503 psi, BHP 3785 psi, CWT 7.2k,WOB 2.2k, ROP 50,WH 369, IA 525, OA 0. 17:32 18:47 1.25 8,740 8,740 PROD2 DRILL WPRT P 8,740', Wiper up hole, PUW 22k, Wiper in hole from 7540' 18:47 23:02 4.25 8,740 8,940 PROD2 DRILL DRLG P 8740', BOBD 1.43bpm at 3268psi, BHP 3783,WHP 359, IA 524, OA 0 ****Note:8890'bit depth encountered .5 bpm losses and slowly healed up to.2 bpm 23:02 23:59 0.96 8,940 6,769 PROD2 DRILL WPRT P 8940',Wiper up hole to 6769' PUW 23k, 10/01/2014 Drill ahead L1-01 lateral 8940'to TD 9150', perform swab wiper, confirm TD 9150',displace well to 11.9ppg completion fluid, L/D drilling BHA, M/U L1-01 liner competion with 101jts of slotted liner. Page 9 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 6,769 5,920 PROD2 DRILL WPRT P Continue wiper up hole. Pull up and jet the 5 1/2"5000'. RIH to 5920'for a tie in. 00:45 01:00 0.25 5,920 5,939 PROD2 DRILL DLOG P 5920',Tie into the RA marker correction of+.3.5'. 01:00 02:00 1.00 5,939 8,940 PROD2 DRILL WPRT P Continue wiper in hole RIW 6k 02:00 06:21 4.35 8,940 9,150 PROD2 DRILL DRLG P 8940', BOBD 1.43bpm at 3347psi, BHP 3752,WHP 275, IA 503, OA 0 """"Note: 8959'bit depth encountered losses.2 bpm. 06:21 10:39 4.30 9,150 72 PROD2 DRILL WPRT P 9,150', TD L1-01 lateral, 10x10 sweep pumped,wiper to swab, PUW 24k,at surface, reset counter, 10:39 11:54 1.25 72 5,900 PROD2 DRILL WPRT P Wiper back in hole. 11:54 12:06 0.20 5,900 5,940 PROD2 DRILL DLOG P Log K1 marker, +3'correction, PUW 21k. 12:06 13:48 1.70 5,940 9,150 PROD2 DRILL WPRT P Continue wiper in hole,tag corrected TD at 9,150', CWT 7.4k, PUW 22k. 13:48 17:30 3.70 9,150 72 PROD2 DRILL DISP P TOOH laying in 50 bbl beaded liner running pill, completion fluid to surface. paint EOP flags at 5,800' and 2,600'. 17:30 18:15 0.75 72 72 PROD2 DRILL OWFF P On surface, monitor well for flow, crew change out 18:15 18:45 0.50 72 72 PROD2 DRILL SFTY P PJSM-UD drilling tools 18:45 19:30 0.75 72 0 PROD2 DRILL PULD P UD drilling tools. 19:30 20:15 0.75 0 0 COMPZ CASING SFTY P Prep rig floor for liner operations. PJSM-M/U 101 jts of slotted liner 20:15 00:00 3.75 0 2,646 COMPZ CASING PUTB P M/U lateral completion 10/02/2014 Set down at 8122', attemp to work liner to bottom, unable to move liner, 1105'from TD 9150', TOL 4811.2', BOL 8045'. 00:00 01:30 1.50 2,646 3,234 COMPZ CASING PUTB P Continue M/U L1-01 liner assyembly jt84 of 101 jts of slotted liner. """"Note: Lost 9 bbls while at surface M/U liner. Losses for 10/1/14 Lost 49 bbls of 9.6 ppg Lost 22 bbls of 12 ppg Sodium Bromide displacing well 01:30 02:30 1.00 3,234 3,234 COMPZ CASING PULD P M/U BHI tools to liner BHA#10 02:30 03:30 1.00 3,234 5,980 COMPZ CASING RUNL P RIH,with L1-01 completion with 101 jts of slotted liner with 2 MI Magnostar magnets. 03:30 03:45 0.25 5,980 5,980 COMPZ CASING DLOG P Correct to the EOP flag 0'correction. PUW 26k 03:45 04:45 1.00 5,980 8,122 COMPZ CASING RUNL P Continue RIH RIW 11k, BHP 2083, IA 0, OA 0 Page 10 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 08:00 3.25 8,122 8,045 COMPZ CASING RUNL T 8,122', Set down hard, PUH weight broke over at 28k, pull heavy 50'up hole,work pipe to suggested limits, 48k up weight, unable to move up or down, pull to 50k and monitor, relax pipe, confer with town,waiting on plan forward keeping hole full 08:00 09:00 1.00 8,045 8,045 COMPZ CASING RUNL T Conference call with town team on plan forward, losses at 2.5 bph. 09:00 11:30 2.50 8,045 8,045 COMPZ CASING RUNL T Bring in product and begin making up 100 bbl of 12 ppg beaded pill per plan forward, bring on 12 ppg to keep hole full 11:30 13:06 1.60 8,045 8,045 COMPZ CASING CIRC T PJSM-begin pumping 12 ppg, 50-60k LSRV liner running oill with 2 ppb Alpine beads and 4%lubes down coil holding 10k down weight on liner assembly, .7 bpm at 3069 psi, BHP 2957,WHP 0, DHWOB 11.3k, CWT 2.9k 13:06 14:06 1.00 8,045 8,045 COMPZ CASING CIRC T 10 bbl beaded pill up around coil, close choke, bullhead 20 bbl .3 bpm at 1393 psi, BHP 3108,WHP 205 14:06 16:24 2.30 8,045 8,045 COMPZ CASING RUNL T 8,045', no movement down noticed, shut down pumps, open choke, PU to 65k, SO-22k,4 pick ups, no movement,set down 10k,close choke, bring on pump.3 bpm at 1535,20 bbls,WHP 210,open choke, PU 65k, SO-26k, no movement, confer with town. 16:24 17:06 0.70 8,045 8,045 COMPZ CASING RUNL T Leave liner in tension, 64k, close choke, pump 15 bbl .9 bpm at 3381 psi, BHP 3167,WHP 283,down on pump, SO-17k, pump 5 bbl, .9 bpm at 3208 psi,WHP 287,call from town. 17:06 20:36 3.50 8,045 8,045 COMPZ CASING RUNL T Leave in compression-16k, pump 15 bbl, 1.2 bpm at 3860 psi, BHP 3202, WHP 320, PU to 63k, no movement, SO-5k, no movement, PU to neutral weight, pump 20 bbl 20:36 20:51 0.25 8,045 8,045 COMPZ CASING TRIP T Bring pump up to 1.2bpm at 3000psi, release from liner PUW 20k. """"Note: TOL 4811.2' BOL 8045'. 20:51 22:06 1.25 8,045 69 COMPZ CASING TRIP T Line up across the top, POOH 22:06 22:36 0.50 69 69 COMPZ CASING PULD T Fill the coil, lost 20bbls on trip out of hole, PJSM for laying down liner running tools 22:36 23:36 1.00 69 0 COMPZ CASING PULD T L/D BHA#10 23:36 00:00 0.40 0 0 COMPZ WHDBO CTOP T Displace coil to fresh water,jet BOPE equipment. 10/03/2014 Unable to move liner,disconnect from liner TOL 4811'BOL 8045', Perform bi-weekly BOPE test, R/U DSL 00:00 02:00 2.00 0 0 COMPZ WHDBO RURD T Prep rig floor for BOPE test. PJSM Page 11 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 14:00 12.00 0 0 COMPZ WHDBO BOPE T Begin Bi-weekly BOPE test, 250/3,800 psi. 2,500 annular. State test waived by John Crisp. BOP test complete,tested inner real iron, and stripper. No faillures. 14:00 14:39 0.65 COMPZ CASING RURD T LD test equipment, prep floor for Slickline. 14:39 15:00 0.35 0 0 COMPZ CASING SFTY T PJSM w/SLB and CDR2 crews 15:00 19:30 4.50 0 0 COMPZ CASING SLKL T RU SLB Digital Slickline,full lubricator and equipment, MU chemical cutter BHA, P/T equipment. """"Note: Losing 4bph of 12ppg Nabr 19:30 20:30 1.00 0 6,100 COMPZ CASING SLKL T RIH w/1 11/16"chemical cutter BHA, tie-in at K1, position cutter, 20:30 20:48 0.30 6,100 6,100 COMPZ CASING SLKL T DSL-Tie into the K1 marker plus 20' correction. Pull up to setting depth. 20:48 21:03 0.25 5,916 5,916 COMPZ CASING SLKL T DSL-PUH,to shoot cutter at 5915.7'SLMD 21:03 22:03 1.00 5,916 200 COMPZ CASING SLKL T POOH,with DSL 22:03 23:33 1.50 200 0 COMPZ CASING SLKL T PJSM-finish POOH, R/D Chem Cutter 23:33 00:00 0.45 0 0 COMPZ CASING DISP T Displace coil to 12.0 ppg Nabr, PJSM for M/U BHA#11 10/04/2014 Recovered 6.42'SBR deployment sieve and 1095.59'of 2 3/8"slotted liner, LD same,good cut. Bull head 25 bbl seawater, freeze protect with diesel to 2,800'. Set FMC BPV, Flush coil and surface lines. ND BOP stack, secure wellhead, load with methanol. RDMO CDR2AC. 00:00 01:30 1.50 0 53 COMPZ CASING PULL T M/U BHA#11 01:30 03:00 1.50 53 4,700 COMPZ CASING PULL T RIH w/fishing tools, 60 fpm to minimize losses. 03:00 03:15 0.25 4,700 4,811 COMPZ CASING PULL T 4700', PUW 21k,zero BHI WOB, RIH, 20fpm set down 3500k at 4815', PUW 26k, minus 4k on BHI WOB 03:15 04:15 1.00 4,811 53 COMPZ CASING PULL T POOH 04:15 04:30 0.25 53 0 COMPZ CASING PULL T PJSM-L/D fishing tools. 04:30 06:00 1.50 0 0 COMPZ CASING PULL T Unstab INJH, L/D BHA#11 06:00 09:30 3.50 0 0 COMPZ CASING PULL T PJSM-Lay down 6'SBR, 34 jts slotted liner, 7.56'of jt#67. loses at 8-10 bph. 09:30 10:00 0.50 0 0 COMPZ CASING PULL T RD liner equipment, prep rig floor. 10:00 12:00 2.00 0 0 DEMOB WHDBO FRZP P PJSM-RU LRS, bullhead 25 bbls seawater and 25 bbls diesel down tbg .5 bpm,max WHP 825, RD LRS, recover 12 ppg in coil. 12:00 14:00 2.00 0 0 DEMOB WHDBO MPSP P PJSM-P/T FMC lubricator,set type "H"BPV, SITP 683 psi, LD FMC equipment. 14:00 17:00 3.00 0 0 DEMOB WHDBO NUND P Flush and purge coil, blow down CT reel and rig lines to tiger tank. RD MP line and misc. lines in cellar. ND BOPE and secure,secure wellhead, load with methanol. Page 12 of 13 Tine Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 0 DEMOB WHDBO'RURD P Continue to prep rig for move to 1G-Pad-RIG RELEASE 18:00 Page 13 of 13 2T-09 WELL WORK SUMMARY IcATE SUMMARY POST-RIG WELL WORK 10/12/2014 TAGGED LINER TOP @ 5916' RKB WITH 2.5" MAGNET. RECOVERED METAL SHAVINGS / DEBRIS. MEASURED BHP © 5916' RKB: 3142 PSI. SET AVA CATCHER @ SAME. IN PROGRESS. 10/13/2014 RECOVERED SHAVINGS / DEBRIS WITH MAGNET. PULLED DVs © 5764', 5329', 4680', 3815', 2604' RKB. SET OV @ 5764' RKB, GLVs @ 5329',4680', 3814', 2604' RKB. IN PROGRESS. 10/14/2014 (SEC)T POT PASSED, T PPPOT PASSED, BLEED T AND IA FOR SECURE T & IA DDT IN PROGRESS 10/15/2014 (SEC) : DDT-T (PASSED), DDT-IA (PASSED), MIT-T AGAINST WRP TO 2030 PSI (PASSED). 10/15/2014 SET WEATHERFORD 2.77"WRP MID-ELEMENT AT 500', CCL TO MID-ELEMENT OFFSET: 10.8', CCL STOP DEPTH: 489.2'. 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( ( XH � @ ] \ ] ) \ ] t.'.. § 2 2 e \ y _ \ / \ J { , 2 ) c•-, '1 \ ( / 2 B , f E{ \ ( £ ) -; ; _ /± j v) csi t ) j Z § R � § 22 £\ \ C _ )1 $ f� | & e 2 7 f § Q L. k Ci CI a / ! k \ E \ § I- • § o Cl) Co \ + - ® | ] q CO f '4' 7 § | | + 0- ! � | C — } ( § \ D & k \ \ \ k 1 k \ = 2 - 0) ; 4 ' 2 LA .. ) % ) ) ) § _ _ osi } 3 } } ( \ \ — 0acooi ` \ }0 NI 0 u .9E / Iii = % . = j '47:1 >. co c \ V 7 p - - . 2 ) G 0 0 a Q § . 4ECEIVED OCT 16 2014 Letter of Transmittal VU AOGCC BAKER Date: DATA LOGGED October 15, 2014 `°/«/2014 HUGHES M.K.BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2T-09 -� 2T-09L1-01 '2-40 s O 2A4-t3L1 (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager )49,4.4) 6.e.eat Yosha.Ragbirsingh@BakerHughes.com 3 j p o0 0 a 0 C7 w ocD v _. o -0 -0 o n -4, o w c -' 0 0- CD N ,- 77 0 0 N1"4` o -I - n 0 el r. < j su - o � 0 `D r^o o Q C �T113 C `V 7— t^ 73 m Z v' vi ‘< --I ..-.... X m D cD 0 A) -0 Cl) o a) 0 o IX c N _; C X 11111 2) 0 61111 ift > c) M ii c m N no <"lin ..t (A 8 co < < » 0 ■ ■so m 7 ƒ * ƒ 0 7 13 e ¥ * CO -0 0 ' Iv io ) § E - _ & § { 0 3 k 7 ' # 0 p E, \ \ ; ° / : 2 [ \ .. .. P a o co @ n co / k �f \ S M g » C ° = co _ - _ » z = » * � _ CTI \ 0 ° S § ° 6 m ƒ % 0 W - ° - ( ( • a6 '00 ` z - � � N ( ( -co vi gR < -,0 § 22 C2 # \ ( 7 m � \_ \ \ / o \ j \ co - zw Z f / j7 � \ ..03 \ \ \ \ / % cS \ ƒ \ } ] \ co G CD 2 / 2 \ / < C \ \ - 3 \ o § 5 f co ■CD 2 z ( & \ c \ 3 / - m .. 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C / -. \ _ , zco ' Cr) \ \ /� \ ` co CD NJ 71/ ,cr, 0 D .. \ CO So co )J /I K Zee CO @ & 2 71 71 ( 7 CD 6 - ° > 5 / \ ] 'I P \ / f § § t \ CT CD co < ^ 1:3 \ { ( meg ( } } \ \ to 0 / —10 ( § >co § o \ \ f Z \ Mk 011 m 2 ® OF Ty ,,i)-- �I%%i �, THE STATE k, Ack CTS and Ge ' - i %�_ (-1 �f, `, /, ('- 1 7 f ..F.r-F -` • $ sflt__ 333 West Seventh Avenue GOVERNOR SEAN PA RNLI Anchorage, Alaska 99501-3572 °r Man 907 279 1433 o\F..,'' Pc-;,- 911„2 27( D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-09L1 ConocoPhillips Alaska, Inc. Permit No: 214-133 Surface Location: 227' FSL, 556' FWL, SEC. 1, Ti 1N, R8E, UM Bottomhole Location: 1129' FNL, 1498' FWL, SEC. 12, T11N, R8E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 186-110, API No. 50-103- 20071-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, G (.4(_. /-1.----_ Cathy P Foerster Chair DATED this ) day of September, 2014. ` RECEWED ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 4 2014 PERMIT TO DRILL ��� 20 AAC 25.005 la Type of Work 1 b Proposed Well Class Development-Oil ❑ Service-Winj ❑ Single Zone 0• lc Specify if well is proposed for Drill ❑ . Lateral D Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry E Exploratory ❑ Service-WAG D. Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name 5 Bond U Blanket• U Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-180• XXL.... 2T-09L1 • 3 Address 6.Proposed Depth. 12 Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD•9000' • TVD. 5783' Kuparuk River Field . 4a Location of Well(Governmental Section). 7 Property Designation(Lease Number) Surface:227'FSL,556'FWL,Sec. 1,T11N, R8E, UM ADL 25569 • Kuparuk River Oil Pool Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date: 1364'FSL, 1446'FWL,Sec. 1,T11N, R8E, UM 2667 9/17/2014 Total Depth 9 Acres in Property 14 Distance to 1129'FNL, 1498'FWL,Sec. 12,T11N, R8E,UM 2560 - Nearest Property 11900 4b Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL• 117 feet 15 Distance to Nearest Well Open Surface:x- 498945 y- 5970208 Zone- 4 • GL Elevation above MSL: 78 feet to Same Pool 2T-11 ,706 16 Deviated wells- Kickoff depth . 5985 ft. 17 Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle Ic644)3L deg Downhole:3884 psig • Surface'3303 psig • 18.Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 2810' 6190' 5758' 9000' 5783' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft) Junk(measured) 6370' 6141' 5700' 6268' 6040' none Casing Length Size Cement Volume MD TVD Conductor/Structural 75' 16" 255 sx CS II 110' 110' Surface 1958' 10.75" 850 sx AS III, 160 sx CI G 1992' 1989' Intermediate Production 6321' 7" 540 sx Class G, 175 sx AS I 6351' 6122' Perforation Depth MD(ft). Perforation Depth TVD(ft): 6022'-6058' 5799'-5834' 20 Attachments Property Plat❑ BOP Sketch ❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements Q 21 Verbal Approval: Commission Representative Date: 1 /3/ /N 22. I hereby certify that the foregoing is true and correct. Contact Ron Phillips @ 265-6312 g P Email Ron.L.Phillips©conocophillips.com Printed Name D. Venhaus Title CTD Engineering Supervisor �/ Signature f^3—1'( Phone: 263-4372 Date /�3//'7 Commission Use Only Permit to Drill API Number. > / Permit Appr v4 See cover letter Number: a 1 9 - 33 50- 1o3-a,QO -/- l¢O -00 I Date O\1\ \ Iforotherrequirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed thane,gas hydrates,or gas contained in shales [l�-�1 Other:8 0,0 f CS/- to 3 a O a /75 a Samples req'd: Yes No ( Mud log req'd: Yes❑ No L S f cstc kv i tot r 5 5 c H2S measures. Yes No ❑ Directional svy req'd: Yes Ef No❑ /14 I 7-,A- rcc,v i v-cc1 ct f fr Spacing exception req'd: Yes ❑ No 2 Inclination-only svy req'd: Yes❑ No[( sf h, II3 cJ�vJCcti� ..nom �j p Approved by��1 Y '7".„/ ( ISSIOf�EI II PG V DsAN E Date. q— Form 10-401(Rev' ed 10/2012) This permit is valid for 24 months from tate df 6roval(20 AAC 25.005(g)) PI cj0 y e/� VL q/19/14, ,e9151,4- RECEIVED ConocoPhillips SEP 0 4 2014 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 02, 2014 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a dual-lateral out of the Kuparuk Well 2T-09 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin Mid September 2014. The CTD objective will be to drill dual-laterals (2T-09L1 and 2T-09L1-01), targeting the A sand intervals.' Note the current A sand perforations are still open below the whipstock. Attached to this application are the following documents: - Permit to Drill Application Form 10-401 for 2T-09L1 and 2T-09L1-01 - Detailed Summary of Operations - Directional Plans - Current Schematic - Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6312. Sincerely, 62.7-` 02 Pig, Ron Phillips Coiled Tubing Drilling Engineer . Kuparuk CTD Laterals NABOR'S�A,LASKA 0 `` '� � ` 2T-09L1 & 2T-09L1 -01 OVA Application for Permit to Drill Document 2nt 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 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 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 2T-09L1 &2T-09L1-01 7 Attachment 2: Current Well Schematic for 2T-09 7 Attachment 3: Proposed Well Schematic for 2T-09L1 &2T-09L1-01 7 Page 1 of 7 O ' ` IGINf , L 9/2/2014 PTD Application: 2T-09L1 & 2T-09L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2T-09L1 & 2T-09L1-01. Both laterals will be classified as "Service- Water Alternating Gas Injection" wells. / 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 2T-09L1 & 2T-09L1-01. 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 3800 psi. Using the maximum formation pressure in the area of 3,884 psi in the 2T-26, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3303 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)) The final mud weight during the rig work over in August 2014 was 10.7 ppg. There are no other active injectors in the area and there are two active producers bringing the pressure down. Well 2T-03 was at 10.4 ppg back in May 2013 and well 2T-08 was at 10.0 ppg back in March 2013, both are on production. The maximum down hole pressure in the 2T-09 pattern to the north is the 2T-26 injector at 12.8 ppg that is 1574' away and on the other side of a sealing fault. All surrounding wells are between 10.0 ppg and 10.5 ppg. The maximum down hole pressure in the 2T-09 pattern to the south is the 2T-12 producer at 10.5 ppg which in online. It is not expected that reservoir pressure as high as 2T-26 will be encountered while drilling the 2T-09 laterals because of the offset distance and faulting, but the 2T-26 injection pressure of 12.8 ppg represents the maximum realistic pressure we expect to see while drilling the 2T-09 laterals./ Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; no gas injection has been performed in this area, so low probability of encountering gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 2T-09 laterals will be pressure differentials across the faults. Managed pressure drilling will be used to reduce this risk. Close approaches The 2T-09L1 lat ral has no close approach issues but at TD will drill within 706' of the plugged and abandoned 2T-11 injector.rhe 2T-09L1 lateral is drilling south toward 2T-11 to replace its injection. The 2T-09L1-01 only has one close approach. At 8,879' it passes with in 89' of the plugged and abandoned 2T-05 injector. The 2T- 09L1-01 lateral is drilling north toward 2T-05 to replace its injection. Both the 2T-05 and the 2T-11 have been abandoned due to subsidence. There is no HSE risk associated with a collision with these wells while drilling the 2T-09 laterals, but there is an economic risk due to the potential for an open-hole sidetrack. Page 2 of 7 Q R S I t /6, L 9/2/2014 PTD Application: 2T-09L1 & 2T-09L1-01 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 2T-09L1 6,190' 9,000' 5,758' 5,783' 2%', 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 2T-09L1-01 5,980' 9,150' 5,758' 5,659' 2%", 4.7#, L-80, ST-L slotted liner; 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" 62.50 H-40 Welded 35' 110' 35' 110' 1,640 630 Surface 10-3/4" 45.5 J-55 BTC 35' 1,992' 35' 1,988' 3,580 2,090 Casing 7" 26.0 J-55 BTC 30' 6,351' 30' 6,122' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 28' 5,927' 28' 5,706' 10,160 10,530 Tubing tail 5-W 15.5 L-80 STC 5,927' 5,969' 5,706' 5,747' 7,000 4,900 Tubing tail 5-%" 14.0 H-40 STC 5,969' 6,012' 5,747' 5,789' 3,110 2,620 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.8 ppg) — Drilling operations: Chloride-based FloVis mud (9.8 ppg).7 While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: Well 2T-09 contains a subsurface safety valve (SSSV) at 2022'MD. If the SSSV tests good and we decide to run a shorter than planned section of liner we may use it. The current plan is to run 2,810' of liner for the first lateral and 3,170' of liner for the second lateral. The Page 3 of 7 ORIGINAL 9/2/2014 PTD Application: 2T-09L1 & 2T-09L1-01 current plan is to load the well with 12 ppg NaBr completion fluid in order to provide formation over- balance while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-162 bbl) of at least 12 ppg emergency kill/ weight fluid will be within a short drive to the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing 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 kicking out into the B silt and landing in the A2, we plan to hold 11.8 ppg at the window for stability. 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. Pressure at the 2T-09 Window(5985' MD, 5646' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (10.7 ppg) 3141 psi 3141 psi Mud Hydrostatic(9.8 ppg) 2877 psi 2877 psi Annular friction (i.e. ECD, 0.090 psi/ft) 419 psi 0 psi Mud + ECD Combined 3296 psi 3131 psi (no choke pressure) (overbalanced (underbalanced —155 psi) —10 psi) Target BHP at Window(11.8 ppg) 3464 psi 3464 psi Choke Pressure Required to Maintain 168 psi 333 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. ORIGINAL Page 4 of 7 9/2/2014 PTD Application: 2T-09L1 & 2T-09L1-01 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2T-09 is a Kuparuk A-sand injection(service)well equipped with 3'/2"tubing and 7"production casing. The CTD laterals will target the Kuparuk A-sands to the north and the south to restore injection to the two bottom hole locations abandoned due to subsidence(2T-05 &2T-11). The 2T-09 is planned for 2 laterals or 5,975' of total hole in the A-sand reservoir. Note the A sand perfs are still open below the whipstock. The 2T-09L1 &2T-09L1-01 laterals will exit through the 5-1/2"tail pipe at 5,985' MD and will target the A3 sands north and south of the existing well. The first lateral will drill south to restore the lost injection to the 2T-11 area and the second lateral will drill north to restore injection to the 2T-05 area. The laterals will be coTpleted with 2-3/8" slotted liner from TD with the liner top located 5' inside the tubing tail at 5,980' MD. Pre-CTD Work 1. RU Slickline: Pull sheared SOVand dummy, Pull PXX plug from the X nipple, get SBHP and Perform a dummy whip stock drift. 2. RU E-line: Perform a GR/CCL jewelry log then run and set WS. 3. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE,test. 2. 2T-09L1Lateral(A3 sand to south) a. Mill 2.80"window at 5,985' MD. b. Drill 2.74"x 3"bi-center lateral to TD of 9,000' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 6,190' MD. 3. 2T-09L1-01Lateral(A3 sand to north) a. Kick off of the aluminum billet at 6,190' MD. b. Drill 2.74"x 3"bi-center lateral to TD of 9,150' MD. c. Run 2%" slotted liner from TD up to 5,980' MD, inside the tubing tail. 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Obtain static BHP. Install GLV's(if needed). 3. Return to injection. 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. If the subsurface safety valve (SSSV) tests good we will use it to for BHA swaps. If the SSSV fails to function or hold pressure then 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. Page 5 of 7 ,� ` I v I N A L 9/2/2014 PTD Application: 2T-09L1 & 2T-09L1-01 During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - If the SSSV functions and holds pressure and we decide to run a shorter than planned section of liner the SSSV will be utilized. - The current plan for the 2T-09 CTD laterals is to displace the wellbore to an overbalancing fluid (12 ppg NaBr) prior to running liner. See the"Drilling Fluids" section for more details. - While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal.-- • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. / • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plan - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire openhole section. ORIGINAL Page 6 of 7 9/2/2014 Ferguson, Victoria L (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Wednesday, September 17, 2014 4:23 PM To: Venhaus, Dan E; Ferguson,Victoria L(DOA) Subject RE:2T-09L1-01(PTD 214-134)AOR df 2T-05 WV Schematic. Attachments: p Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here is the current well bore schematic of the P&A'd offset injector 2T-05. Cement in the OA is 58" from surface. The bubbling in the conductor was from pressuring up on the OA. As soon as the pumping on the OA was shut down the bubbling in the conductor stopped on May 20`h. Cement in the conductor is 33.5" from the top of the conductor. After pumping cement into the conductor there is no mention of bubbling in the conductor. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Venhaus, Dan E Sent: Wednesday, September 17, 2014 2:03 PM To: Ferguson, Victoria L(DOA) Cc: Phillips, Ron L Subject: RE: 2T-09L1-01(PTD 214-134)AOR The email you have listed for Ron is an old BP address. I have cc'd Ron's ConocoPhillips address From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Wednesday, September 17, 2014 1:20 PM To: Venhaus, Dan E Subject: [EXTERNAL]FW: 2T-09L1-01(PTD 214-134) AOR Have not received any response on this email. Cannot process PTD until I hear back from CPAI. From: Ferguson, Victoria L(DOA) Sent: Friday, September 12, 2014 3:13 PM To: ron.phillips@bp.com Subject: 2T-09L1-01(PTD 214-134)AOR Ron, Please send a well bore schematic of P&A'd offset injector 2T-05.What was bubbling from the conductor? Did the bubbling subside after the conductor was topped off with cement? Thanx, 1 PTD Application: 2T-09L1 & 2T-09L1-01 — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2T-09L1 11,900' 2T-09L1-01 11,900' — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 2T-09L1 706' 2T-11 (P&A'd offset injector) 2T-09L1-01 89' 2T-05 (P&A'd offset injector) 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 4 f fi i C rf 5 t,ry o , The only wells that lie within 1/4-mile of the proposed 2T-09 CTD laterals are the 2T-09 mother bore, 2T-05 P&A'd injector and 2T-11 P&A'd injector. 2T-09 (mother bore) Well 2T-09 was drilled and completed in 1986. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 6351' MD/6122' TVD. The 2T-09 was a WAG A-sand injector from 3/31/1987 to 4/30/2009. Due to subsidence issues a RWO with Nabors 7ES was performed earlier this year to replace the 7" casing from 1793' up to surface, cement the 7" x 10-3/4"" OA from 1793' to surface and to replace the 2-7/8" completion with 3-1/2". 2T-05 (P&A'd offset injector, —89' away from L1-01 lateral to north Well 2T-05 was drilled and completed in September 1986. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 7670' MD/6060' TVD. The 2T-05 was a WAG A-sand injector from 3/31/1988 to 5/31/2009. The 2T-05 was plugged and abandoned due to subsidence issues. On May 24, 2009 8.6 bbls of 15.8 ppg class G cement was pumped down tubing and 4 bbls squeezed into the perforations. State witnessed successful MIT- T to 2500 psi on May 2009. On March 22, 2012 the tubing was punched at 6,927' MD and 149 bbls of 15.8 ppg class G cement was pumped down the tubing and up the IA. The estimated top of cement in tubing and IA is at —2900' MD. There was a passing MIT-T and MIT-IA to 1500 psi on March 25, 2012. May 11, 2012 they punched holes in tubing and circulated 95 bbls of 15.7 ASI down the tubing taking returns up the IA and bullheaded 55 bbls 15.7 ppg ASI down the OA. On May 20, 2012 there was a passing MIT-T to 1500 psi, the MIT-IA and MIT-OA failed and bubbling was coming from the conductor. October 2013 poured 1.3 bbls cement in the conductor to top off the annulus. 2T-11 (P&A'd offset injector, —706' away from L1 lateral to south Well 2T-11 was drilled and completed in 1986. The 7", 26 ppf, J-55, BTC-Mod production casing was set at 6170' MD/5665' TVD. The 5", 18ppf, L-80 liner is set from 5,961'MD to 6,789' MD/6,139' TVD. The 2T-11 was a WAG A-sand andC-sand injector from 3/31/1987 to 4/30/2009. The 2T-11 was plugged and abandoned due to subsidence issues. On October 10, 2009 23 bbls of 15.8 cement was bullheaded down the tubing, TOC was estimated at 5,600'. On November 3, 2009 state witnessed passing MIT-T. On March 23, 2012 holes were punched in the tubing at 5297' MD and on May 13, 2012 97 bbls of 15.8 ppg "G" cement was pumped down the tubing and up the IA, top of the cement in tubing and IA is estimated at 2,900' MD. There was a passing MIT-T post cement job. They punched holes in the tubing at 2,050' MD and pumped 122 bbls of ASI 15.7 ppg down the tubing taking returns up the IA. 17. Attachments Attachment 1: Directional Plans for 2T-09L1 & 2T-09L1-01 Attachment 2: Current Well Schematic for 2T-09 Attachment 3: Proposed Well Schematic for 2T-09L1 & 2T-09L1-01 Page 7 of 7 ORIGINAL 9/2/2014 o co`- 2 2 m v N N U) O _ N a)ttl M O N E LC) CO 0 N@ CO N CO fY m . co O N W N (0<O C� co a O c. co E - Co C tiii:.- -a '-a 'a) U U .0 O §W C Rd W o Lo 1.0 CD N . co �,.` O 0 cc _ � O V d �"-== CO C 0? 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U N 0) I A A / H Ni1. , •90 r 1 1 n0 as Y2 1!N aln t. 2b m0 •E 2s A'- .e �� g o iy�ppk N N o C N N Fi ;,N , N y,N b ^6 Q IY. 1 { I I t"' ` , l t I ( .,, I'1 1 I'"r'1'M'1'I'il i 1 1 I I:!:!:!:!:111:'11: I 11ll I 111 I 1 1'11 11 1 . 11111111 1 8 - � 111111 1 1111 I ''1111 1111111111 I • 111 111 1 1 1 1 1 1 1 1.11111 1 11 11 I I I I I.t 1 1 1 1 1 1' 11 I I I 11.1 111 1 II 1 • I I I I111 1 111 III 1 11 1 1 1 1 111 1 1 1 1 1"I m 5_1.f. 11 IIII1111111 I'Y I., -III IIII IIII1111111111111111111111 I, ,1,1,11,1,1,1,1,1,1,1,11,1,:, ,1,1,1,I,I,I,1,1,1,1,1,11,1,1,1,1,1,1,1,1,1,1,,1,1,1,1,1,11,1,0 FM MR M"MO R) INTERNI. --Y + 4 44--e---471. + M , c - ' I 1 1 I ;, 1 1 f- 1I 111 ,f`'I 1 I1 1 1 1 1 -1 ':1,., 1 R1 c '1~4 11 SSTY0 12 P j § CV FET.=SF£RF_STATUS ®1 I IIIIiItIRII 111 MEASURED DEPTH r I I I • I e I I Mrrt 0 ,la iI L (q1 } 1 f C ii 3 Ply i �' }} }} I_ - , 1 t 1 }.__Itit I t i._.. _-f r ( a P ttt $ 1111111. — + i i:l.—.**-S+ I 4 .- ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2T Pad 2T-09 2T-09L1 Plan: 2T-09L1wp05 Standard Planning Report 21 August, 2014 IrakI BAKER HUGHES ORIGINAL ra" ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2T-09 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-09 @ 117.00usft(2T-09) Site: Kuparuk 2T Pad North Reference: True Well: 2T-09 Survey Calculation Method: Minimum Curvature Wellbore: 2T-09L1 Design: 2T-09L1_wp05 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2T Pad Site Position: Northing: 5,970,382.43 usft Latitude: 70°19'49.129 N From: Map Easting: 498,944.93usft Longitude: 150°0'30.807 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 2T-09 Well Position +N/-S 0.00 usft Northing: 5,970,207.62 usft Latitude: 70°19'47.409 N +El-W 0.00 usft Easting: 498,945.01 usft Longitude: 150°0'30.804 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft :. 2T 09L1 W ti" t ,, tkOWM tsawbm S itivu^2Av,,y,inzar:�lt .r,,,kw,,.'�n`Ali%',,'r,w n gVkM,,tSFSasP.uraak 9,Y.M`.4K,"VkA.As`°L.AN i.aurec M,A.wzswi`�iis%f3tfo&5w4.f+ ,•. Ea iii/a06A4,0*ANSingAVASAVt,49,/r 5*a Me.. Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BG G M 2014 11/1/2014 19.03 80.89 57,572 :a�F Design 2T-09L1_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 5,900.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 0.00 0 00 0.00 145.19 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +El-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (0) Target 5,900.00 11.43 36.80 5,562.34 1,004.17 788.72 0.00 0.00 0.00 0.00 5,985.00 11.23 37.72 5,645.69 1,017.46 798.83 0.32 -0.24 1.08 138.35 6,010.00 16.48 37.72 5,669.95 1,022.19 802.49 21.00 21.00 0.00 0.00 6,200.04 102.00 37.72 5,758.37 1,139.71 893.38 45.00 45.00 0.00 0.00 6,350.04 102.76 107.05 5,721.89 1,181.20 1,023.62 45.00 0.51 46.22 81.00 6,450.04 90.06 150.60 5,710.18 1,120.18 1,098.69 45.00 -12.70 43.55 103.00 6,850.04 90.06 166.60 5,709.75 748.97 1,244.17 4.00 0.00 4.00 90.00 7,150.04 91.30 178.54 5,706.17 452.05 1,282.91 4.00 0.41 3.98 84.00 7,400.04 89.56 188.38 5,704.28 202.83 1,267.84 4.00 -0.70 3.94 100.00 7,650.04 81.38 194.16 5,724.03 -41.28 1,219.25 4.00 -3.27 2.31 145.00 7,950.04 90.35 186.17 5,745.66 -335.28 1,166.66 4.00 2.99 -2.67 318.00 8,350.04 87.33 201.88 5,753.81 -722.03 1,070.08 4.00 -0.76 3.93 101.00 8,800.04 87.46 183.86 5,774.46 -1,158.45 970.34 4.00 0.03 -4.00 270.00 9,000.00 87.48 191.87 5,783.30 -1,356.17 943.02 4.00 0.01 4.00 90.00 8/21/2014 3:28:13PM Page 2 COMPASS 5000.1 Build 61 ORIGINAL VA' ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2T-09 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-09©117.00usft(2T-09) Site: Kuparuk 2T Pad North Reference: True Well: 21-09 Survey Calculation Method: Minimum Curvature Wellbore: 2T-09L1 Design: 2T-09L1_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 5,900.00 11.43 36.80 5,562.34 1,004.17 788.72 -374.16 0.00 0.00 5,971,211.57 499,733.79 TIP 5,985.00 11.23 37.72 5,645.69 1,017.46 798.83 -379.30 0.32 138.35 5,971,224.86 499,743.90 KOP 6,000.00 14.38 37.72 5,660.31 1,020.09 800.86 -380,30 21.00 0.00 5,971,227.49 499,745.94 6,010.00 16.48 37.72 5,669.95 1,022.19 802.49 -381.10 21.00 0.00 5,971,229.60 499,747.56 End 21 dls,Start 45 dls 6,100.00 56.98 37.72 5,740.59 1,063.89 834.74 -396.92 45.00 0.00 5,971,271.28 499,779.81 6,200.00 101.98 37.72 5,758.38 1,139.67 893.36 -425.68 45.00 0.00 5,971,347.05 499,838.44 6,200.04 102.00 37.72 5,758.37 1,139.71 893.38 -425.69 45.00 0.00 5,971,347.09 499,838.46 4 6,300.00 104.79 83.95 5,733.96 1,185.87 975.61 -416.65 45.00 81.00 5,971,393.23 499,920.69 6,350.04 102.76 107.05 5,721.89 1,181.20 1,023.62 -385.41 45.00 92.30 5,971,388.56 499,968.69 6 6,400.00 96.91 129.09 5,713.26 1,158.13 1,066.71 -341.86 45.00 103.00 5,971,365.48 500,011.78 6,450.04 90.06 150.60 5,710.18 1,120.18 1,098.69 -292.45 45.00 106.82 5,971,327.53 500,043.74 End 46 dls,Start 4 dls 6,500.00 90.06 152.60 5,710.13 1,076.24 1,122.45 -242.81 4.00 90.00 5,971,283.59 500,067.50 6,600.00 90.06 156.60 5,710.02 985.92 1,165.34 -144.17 4.00 90.00 5,971,193.28 500,110.37 6,700.00 90.06 160.60 5,709.91 892.84 1,201.82 -46.92 4.00 90.01 5,971,100.20 500,146.84 6,800.00 90.06 164.60 5,709.80 797.44 1,231.72 48.48 4.00 90.01 5,971,004.80 500,176.72 6,850.04 90.06 166.60 5,709.75 748.97 1,244.17 95.38 4.00 90.02 5,970,956.34 500,189.16 7 6,900.00 90.27 168.59 5,709.61 700.18 1,254.90 141.56 4.00 84.00 5,970,907.55 500,199.88 7,000.00 90.69 172.56 5,708.77 601.55 1,271.27 231.88 4.00 84.01 5,970,808.93 500,216.24 7,100.00 91.10 176.54 5,707.22 502.04 1,280.76 319.00 4.00 84.04 5,970,709.43 500,225.71 7,150.04 91.30 178.54 5,706.17 452.05 1,282.91 361.27 4.00 84.10 5,970,659.45 500,227.85 8 7,200.00 90.96 180.50 5,705.18 402.11 1,283.33 402.51 4.00 100.00 5,970,609.51 500,228.26 7,300.00 90.26 184.44 5,704.12 302.23 1,279.01 482.05 4.00 100.04 5,970,509.64 500,223.94 7,400.00 89.56 188.38 5,704.28 202.88 1,267.85 557.25 4.00 100.08 5,970,410.30 500,212.76 7,400.04 89.56 188.38 5,704.28 202.83 1,267.84 557.28 4.00 100.07 5,970,410.25 500,212.75 9 7,500.00 86.28 190.68 5,707.91 104.34 1,251.31 628.71 4.00 145.00 5,970,311.77 500,196.21 7,600.00 83.01 192.99 5,717.24 6.91 1,230.89 697.04 4.00 144.92 5,970,214.36 500,175.78 7,650.04 81.38 194.16 5,724.03 -41.28 1,219.25 729.96 4.00 144.70 5,970,166.17 500,164.14 10 7,700.00 82.87 192.82 5,730.88 -89.40 1,207.71 762.88 4.00 -42.00 5,970,118.06 500,152.59 7,800.00 85.86 190.14 5,740.70 -186.90 1,187.91 831.63 4.00 -41.82 5,970,020.57 500,132.78 7,900.00 88.85 187.49 5,745.32 -285.60 1,172.61 903.92 4.00 -41.55 5,969,921.89 500,117.46 7,950.04 90.35 186.17 5,745.66 -335.28 1,166.66 941.32 4.00 -41.43 5,969,872.21 500,111.50 11 8,000.00 89.97 188.13 5,745.52 -384.85 1,160.44 978.46 4.00 101.00 5,969,822.65 500,105.28 8,100.00 89.21 192.06 5,746.23 -483.28 1,142.92 1,049.27 4.00 101.01 5,969,724.23 500,087.75 8,200.00 88.45 195.98 5,748.28 -580.26 1,118.71 1,115.07 4.00 100.98 5,969,627.26 500,063.53 8,300.00 87.70 199.91 5,751.64 -675.32 1,087.92 1,175.54 4.00 100.90 5,969,532.22 500,032.72 8,350.04 87.33 201.88 5,753.81 -722.03 1,070.08 1,203.71 4.00 100.77 5,969,485.52 500,014.88 12 8,400.00 87.33 199.88 5,756.14 -768.65 1,052.30 1,231.83 4.00 -90.00 5,969,438.90 499,997.09 8,500.00 87.34 195.88 5,760.79 -863.69 1,021.63 1,292.36 4.00 -89.91 5,969,343.87 499,966.42 8,600.00 87.37 191.87 5,765.41 -960.65 997.68 1,358.29 4.00 -89.72 5,969,246.92 499,942.46 8,700.00 87.41 187.87 5,769.97 -1,059.05 980.56 1,429.30 4.00 -89.54 5,969,148.54 499,925.32 8/21/2014 3:28.13PM 0 Rgrn I NAL COMPASS 5000.1 Build 61 riI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 21-09 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-09 @ 117.00usft(2T-09) Site: Kuparuk 2T Pad North Reference: True Well: 2T-09 Survey Calculation Methoc: Minimum Curvature Wellbore: 2T-09L1 Design: 2T-09L1_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 8,800.00 87.46 183.87 5,774.46 -1,158.40 970.35 1,505.04 4.00 -89.35 5,969,049.20 499,915.10 8,800.04 87.46 183.86 5,774.46 -1,158.45 970.34 1,505.08 4 00 -89.17 5,969,049.15 499,915.09 13 8,900.00 87.46 187.87 5,778.89 -1,257.76 960.14 1,580.79 4.00 90.00 5,968,949.85 499,904.88 9,000.00 87.48 191.87 5,783.30 -1,356.17 943.02 1,651.81 4.00 89.82 5,968,851.45 499,887.74 Planned TD at 9000.00 8/21/2014 3:28:13PM Page 4 COMPASS 5000.1 Build 61 O1GINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 21-09 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-09 @ 117.00usft(2T-09) Site: Kuparuk 2T Pad North Reference: True Well: 2T-09 Survey Calculation Method: Minimum Curvature Wellbore: 2T-09L1 Design: 2T-09L1_wp05 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) - Latitude Longitude 2T-09L1-01_Fault 1 0.00 0.00 0.00 1,090.941,141,068.95 5,971,138.00 1,639,900.00 70°5'50.525 N 140°49'41.291 W -plan misses target center by 1139800.11 usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Rectangle(sides W460.00 H1.00 D0.00) 2T-09L1 Polygon 0.00 0.00 0.00 973.901,140,851.95 5,971,021.00 1,639,683.00 70°5'49.708 N 140°49'47.982 W -plan misses target center by 1139583.05usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Polygon Point 1 0.00 0.00 0.00 5,971,021.00 1,639,683.00 Point2 0.00 319.08 263.97 5,971,340.01 1,639,946.99 Point 3 0.00 -166.87 778.11 5,970,854.04 1,640,461.01 Point 4 0.00 -916.95 736.25 5,970,104.04 1,640,419.05 Point 5 0.00 -1,917.09 541.42 5,969,104.03 1,640,224.10 Point 6 0.00 -2,764.20 416.57 5,968,257.02 1,640,099.14 Point7 0.00 -2,695.28 -55.49 5,968,326.00 1,639,627.14 Point 8 0.00 -1,945.18 55.38 5,969,076.01 1,639,738.10 Point9 0.00 -1,139.07 222.24 5,969,882.01 1,639,905.06 Point 10 0.00 -319.97 319.09 5,970,701.02 1,640,002.01 Point 11 0.00 0.00 0.00 5,971,021.00 1,639,683.00 2T-09L1_T5 0.00 0.00 5,731.00 -178.151,141,354.16 5,969,869.00 1,640,185.00 70°5'37.782 N 140°49'38.659 W -plan misses target center by 1140070.98usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Point 2T-09L1_Fault 3 0.00 0.00 0.00 635.941,141,396.05 5,970,683.00 1,640,227.00 70°5'45.624 N 140°49'33.940 W -plan misses target center by 1140127.02usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Rectangle(sides W470.00 H1.00 D0.00) 21-09L1_T3 0.00 0.00 5,710.00 916.961,141,302.00 5,970,964.00 1,640,133.00 70°5'48.492 N 140°49'35.403 W -plan misses target center by 1140018.79usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Point 2T-09L1_T1 0.00 0.00 5,761.00 1,026.931,141,021.96 5,971,074.00 1,639,853.00 70°5'49.973 N 140°49'42.907 W -plan misses target center by 1139738.80usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Point 2T-09L1-01 Polygon 0.00 0.00 0.00 4,210.221,140,809.49 5,974,257.00 1,639,641.00 70°6'21.193 N 140°49'35.174 W -plan misses target center by 1139546.81 usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Polygon Point 1 0.00 0.00 0.00 5,974,257.00 1,639,641.00 Point2 0.00 -194.93 472.08 5,974,062.02 1,640,113.01 Point 3 0.00 -820.00 431.20 5,973,437.02 1,640,072.04 Point4 0.00 -2,695.16 570.57 5,971,562.03 1,640,211.13 Points 0.00 -3,139.22 486.65 5,971,118.03 1,640,127.16 Point6 0.00 -3,473.29 306.70 5,970,784.01 1,639,947.18 Point7 0.00 -3,181.32 -27.39 5,971,076.00 1,639,613.17 Point8 0.00 -2,625.23 195.52 5,971,632.01 1,639,836.13 Point 9 0.00 -834.10 -68.85 5,973,422.99 1,639,572.04 Point 10 0.00 0.00 0.00 5,974,257.00 1,639,641.00 2T-09L1_Fault 1 0.00 0.00 0.00 1,042.931,141,033.96 5,971,090.00 1,639,865.00 70°5'50.110 N 140°49'42.496 W -plan misses target center by 1139765.09usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Rectangle(sides W455.00 H1.00 D0.00) 2T-09L1_Fault 2 0.00 0.00 0.00 916.961,141,303.00 5,970,964.00 1,640,134.00 70°5'48.490 N 140°49'35.375 W -plan misses target center by 1140034.07usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Rectangle(sides W455.00 H1.00 D0.00) 2T-09L1_T7 0.00 0.00 5,783.00 -1,445.311,141,089.31 5,968,602.00 1,639,920.00 70°5'25.870 N 140°49'51.691 W -plan misses target center by 1139807.49usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Point 2T-09L1_Fault 5 0.00 0.00 0.00 -772.221,141,231.23 5,969,275.00 1,640,062.00 70°5'32.195 N 140°49'44.734 W -•Ian misses tar.et center b 1139962.79usft at 7200.00usft MD 5705.18 TVD 402.1N1 N 1283.33 E 8/21/2014 3:28:13PM Pagg.�� A [ COMPASS 5000.1 Build 61 a ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2T-09 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2T-09 @ 117.00usft(2T-09) Site: Kuparuk 2T Pad North Reference: True Well: 2T-09 Survey Calcuk Jon Method: Minimum Curvature Wellbore: 2T-09L1 Design: 21-09L1_wp05 -Rectangle(sides W475.00 H1.00 D0.00) 2T-09L1_T6 0.00 0.00 5,752.00 -772.221,141,231.23 5,969,275.00 1,640,062.00 70°5'32.195 N 140°49'44.734 W -plan misses target center by 1139948.51 usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Point 2T-09L1_Fault 4 0.00 0.00 0.00 -178.151,141,354.16 5,969,869.00 1,640,185.00 70°5'37.782 N 140°49'38.659 W -plan misses target center by 1140085.26usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Rectangle(sides W470.00 H1.00 D0.00) 2T-09L1_T2 0.00 0.00 5,760.00 1,042.931,141,033.96 5,971,090.00 1,639,865.00 70°5'50.110 N 140°49'42.496 W -plan misses target center by 1139750.81 usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Point 2T-09L1_T4 0.00 0.00 5,710.00 635.941,141,396.05 5,970,683.00 1,640,227.00 70°5'45.624 N 140°49'33.940 W -plan misses target center by 1140112.75usft at 7200.00usft MD(5705.18 TVD,402.11 N,1283.33 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,000.00 5,783.30 2-3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 5,900.00 5,562.34 1,004.17 788.72 TIP 5,985.00 5,645.69 1,017.46 798.83 KOP 6,010.00 5,669.95 1,022.19 802.49 End 21 dls,Start 45 dls 6,200.04 5,758.37 1,139.71 893.38 4 6,350.04 5,721.89 1,181.20 1,023.62 5 6,450.04 5,710.18 1,120.18 1,098.69 End 45 dls,Start 4 dls 6,850.04 5,709.75 748.97 1,244.17 7 7,150.04 5,706.17 452.05 1,282.91 8 7,400.04 5,704.28 202.83 1,267.84 9 7,650.04 5,724.03 -41.28 1,219.25 10 7,950.04 5,745.66 -335.28 1,166.66 11 8,350.04 5,753.81 -722.03 1,070.08 12 8,800.04 5,774.46 -1,158.45 970.34 13 9,000.00 5,783.30 -1,356.17 943.02 Planned TD at 9000.00 8/21/2014 3.28.13PM Page 6 COMPASS 5000.1 Build 61 RtGI \ AL ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2T Pad 2T-09 2T-09L1 2T-09L1_wp05 Travelling Cylinder Report 21 August, 2014 BAKER HUGHES ORIGINAL Fr- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 21-09 Project: Kuparuk River Unit TVD Reference: 2T-09 @ 117.00usft(21-09) Reference Site: Kuparuk 2T Pad MD Reference: 2T-09 @ 117.00usft(21-09) Site Error: 0.00usft North Reference: True Reference Well: 2T-09 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2T-09L1 Database: EDM Alaska Prod Reference Design: 2T-09L1_wp05 Offset TVD Reference: Offset Datum Reference 2T-09L1_wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 5,900.00 to 9,000.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,088.30usft Error Surface: Elliptical Conic Survey Tool Program Date 8/20/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 5,900.00 2T-09(2T-09) BOSS-GYRO Sperry-Sun BOSS gyro multishot 5,900.00 9,000.00 2T-09L1_wp05(2T-09L1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ('U) ( ) 9,000 00 5.900 30 2-3/8" 2-3/8 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/21/2014 9:50:35AM 0 ri°tc. A L COMPASS 5000.1 Build 61 • ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-09 Project: Kuparuk River Unit TVD Reference: 2T-09 @ 117.00usft(2T-09) Reference Site: Kuparuk 2T Pad MD Reference: 2T-09 @ 117.00usft(2T-09) Site Error: 0.00usft North Reference: True Reference Well: 2T-09 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft_ Output errors are at 1.00 sigma Reference Wellbore 2T-09L1 Database: EDM Alaska Prod Reference Design: 2T-09L1_wp05 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) 'Kuparuk 2T Pad 2T-203-2T-203-2T-203 wp06 Out of range Plan:2T-208-Plan 2T-208(Mainbore)-2T-208 P Out of range Plan:2T-208-Plan 2T-208(Mainbore)-2T-208 R Out of range Plan:2T-208-Plan:2T-208PB1-2T-208 PB1 Out of range Plan:2T-208-Plan:21-20BPB2-2T-208 PB2 Out of range 'Kuparuk 3S Pad 3S-08C Doyon 141-3S-08C-3S-08C-to delete in Out of range Kuparuk 2T Pad 2T-02-2T-02-2T-02 Out of range 2T-03-2T-03-2T-03 Out of range 2T-03-2T-03A-2T-03A Out of range 2T-03-2T-03AL1-2T-03AL1 Out of range 2T-03-2T-03AL2-2T-03AL2 Out of range 21-03-2T-03APB1-2T-03APB1 Out of range 21-05-2T-05-2T-05 Out of range 2T-06-21-06-2T-06 Out of range 2T-07-2T-07-2T-07 Out of range 21-08-2T-08-2T-08 Out of range 2T-09-21-09-2T-09 5,999.98 6,000.00 0.41 2.41 -1.98 FAIL-Major Risk 2T-09-2T-09L1-01-21-09L1-01_wp02 6,199.98 6,200.00 0.37 0.49 -0.07 FAIL-Major Risk 2T-10-2T-10-2T-10 Out of range 2T-10-2T-10L1-2T-10L1 Out of range 2T-10-2T-10L1-01-2T-10L1-01 Out of range 2T-10-2T-10L1-01 PB1-2T-10L1-01 PB1 Out of range 2T-11-2T-11-2T-11 8,995.59 5,750.00 705.89 204.72 561.91 Pass-Major Risk 2T-12-2T-12-2T-12 Out of range 2T-12-2T-12A-2T-12A Out of range 2T-13-2T-13-2T-13 Out of range 2T-14-2T-14-21-14 Out of range 2T-15-2T-15-2T-15 Out of range 2T-16-2T-16-2T-16 Out of range 2T-17-2T-17-21-17 Out of range 2T-18-2T-18-2T-18 Out of range 2T-19-2T-19-2T-19 Out of range 2T-20-2T-20-21-20 Out of range 2T-203-2T-203-2T-203 Out of range 2T-203-2T-203-2T-203wp06 Out of range 2T-204-2T-204-2T-204 Out of range 2T-208-21-208-2T-208 Out of range 2T-208-2T-208-2T-208 wp05 Out of range 2T-208-2T-208PB1-2T-208PB1 Out of range 2T-208-2T-208PB2-2T-208PB2 Out of range 21-208-2T-208PB3-2T-208PB1 wp06 Out of range 2T-208-2T-208PB3-2T-208PB3 Out of range 21-21-2T-21-2T-21 Out of range 2T-215-2T-215-2T-215 Out of range 2T-217-2T-217-2T-217 Out of range 2T-217-2T-217A-2T-217A Out of range 2T-220-21-220-21-220 Out of range 2T-23-2T-23-2T-23 Out of range 2T-26-2T-26-2T-26 Out of range CC-Min centre to center distance or covergent point,S2.F-min separation factor,ES-min ellipse separation 8/21/2014 9:50:35AM P,ag�3 1"N A L COMPASS 5000.1 Build 61 NrA ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2T-09 Project: Kuparuk River Unit TVD Reference: 2T-09©117.00usft(2T-09) Reference Site: Kuparuk 2T Pad MD Reference: 2T-09 @ 117.00usft(2T-09) Site Error: 0.00usft North Reference: True Reference Well: 2T-09 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2T-09L1 Database: EDM Alaska Prod Reference Design: 2T-09L1_wp05 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 2T Pad 2T-27-2T-27-2T-27 Out of range 2T-27-2T-27A-2T-27A Out of range 2T-27-2T-27AL1-2T-27AL1 Out of range 2T-27-2T-27APB1-2T-27APB1 Out of range 2T-27-2T-27APB2-2T-27APB2 Out of range 2T-28-2T-28-2T-28 Out of range 2T-29-2T-29-2T-29 Out of range 2T-29-2T-29A-2T-29A Out of range 2T-29-2T-29AL1-2T-29AL1 Out of range 2T-29-2T-29AL1-01-2T-29AL1-01 Out of range 2T-29-2T-29AL1-01 PB1-2T-29AL1-01 PB1 Out of range 2T-29-2T-29AL1-02-2T-29AL1-02 Out of range 2T-30-2T-30-2T-30 Out of range 2T-31-2T-31-2T-31 Out of range 2T-32-2T-32-2T-32 Out of range 2T-32-2T-32A-2T-32A Out of range 2T-32-2T-32AL1-2T-32AL1 Out of range 2T 36 2T 36 2T 36 Out of range 2T-37-2T-37-2T-37 Out of range 2T-38-2T-38-2T-38 Out of range 2T-38-2T-38A-2T-38A Out of range 2T-40-2T-40-2T-40 Out of range 2T-40-2T-40L1-2T-40L1 Out of range 2T-41-2T-41-2T-41 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/21/2014 9:50:35AM ,. g of COMPASS 5000.1 Build 61 1 x y 1 NC00�00)�4?88 S�O"28 E,1 (022 • (0_ C. a822pp004,>M M M v ?QMC7 U,r rn N ,0 M. g m JC do 0000 o 000000 00O O M 0 0 0 0 0 0 0 0 0 0 0 0 Z N Foadoos-C+ io otri ca oo CDom co o o"rn 0 C>C� 0p(10 N OO OOOOO pp OOOO C�1 4 N O M 0 0 0 0 0 0 0 0 0 0 0 0 CO 4 4 W °OONV V'mt VV YVVVV 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S , O =d I n l do q n' 0 k IL ® F 44- 0° I n o _ F. o ,r Al � ��► \ 7,-_'''' I s rk' F n N N , \1 n A. CC '< N ooo000o h 8 0 8 0O o 8 ' F8 0 & F8 $ NOrhNO M ^ r27Ot-• m 7 n O N P N m N mO ,,-,,--, V Y M N A]$ [ w/ Ferguson, Victoria L (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Wednesday, September 17, 2014 4:23 PM To: Venhaus, Dan E; Ferguson,Victoria L(DOA) Subject: RE:2T-09L1-01(PTD 214-134)AOR Attachments: 2T-05 WV Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here is the current well bore schematic of the P&A'd offset injector 2T-05. Cement in the OA is 58" from surface.The bubbling in the conductor was from pressuring up on the OA. As soon as the pumping on the OA was shut down the bubbling in the conductor stopped on May 20th. Cement in the conductor is 33.5" from the top of the conductor. After pumping cement into the conductor there is no mention of bubbling in the conductor. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Venhaus, Dan E Sent: Wednesday, September 17, 2014 2:03 PM To: Ferguson, Victoria L(DOA) Cc: Phillips, Ron L Subject: RE: 2T-09L1-01(PTD 214-134)AOR The email you have listed for Ron is an old BP address. I have cc'd Ron's ConocoPhillips address From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Wednesday, September 17, 2014 1:20 PM To: Venhaus, Dan E Subject: [EXTERNAL]FW: 2T-09L1-01(PTD 214-134) AOR Have not received any response on this email. Cannot process PTD until I hear back from CPAI. From: Ferguson, Victoria L(DOA) Sent: Friday, September 12, 2014 3:13 PM To: ron.ohillips@bp.com Subject: 2T-09L1-01(PTD 214-134)AOR Ron, Please send a well bore schematic of P&A'd offset injector 21-05.What was bubbling from the conductor? Did the bubbling subside after the conductor was topped off with cement? Thanx, 1. Mg; KUP 2T-05 ConocoPhillips s well Attributes Max Angle a MD ID 24 Alaska,Inc. WNbon APW WI Field Nana Wee Status aid('I MD(MB) Act Bim(NCB) 501032007500 KUPARUK RIVER UNIT INJ 46.75 3,100.00 7,676.0 _ C000nsot H26(ppm) Dab Annotation End Dias K8-0rd(R) Rig Release Dab ... wall :-2r 10/aB/10121097D/AM SSSV:TRDP_ Last WO: 40.00 9/5/1986 Sdhemeto-Aceta Annotation Depth(MB) End Dab Annotation Last Mod...End Dab Last Tag:SLM 7,260.0 5/19/2009 Rev Reason:UPDATE CEMENT DATA osborl 10/26/2012 Casing Strings Casing Description i String 0... String ID_.Top(IN(B) ISet Depth(1...Sat Dept(ND).. String Wt...String...String Top Thud HANGER,28 ' CONDUCTOR 16 15.062 32.0 115.0 115.0 62.50 H-40 WELDED i. , Casing Description String 0... String ID_.Top(SKB) Set Depth(1...Sat Depth(TVD)...String Wt...Siting...String Top The) SURFACE 9 5/8 8.921 32.0 3,010.4 2,792.2 36.00 .1-55 BTC --g Gaiting Description 'String 0... 'String ID...Top(M(B)---i Set Depth(1...Set Depth(ND)...String WL..String_.String Top Thal PRODUCTION 7 .6.276 30.4 L 7,669.5 6,060.3 26.00 J-55 BTC Tubing Strings kli , Tubing Description String 0... story D_.Top(IIKB) Set Depth It...Set Depth(IVO)_.String WL.String_.String Top Tied TUBING 312 2.992 28.3 7,157.0 5,697.0 9.30 J-55 EUE-8rd Completion Details Top Depth CONDUCTOR. (TOO) Top Ind Norm.- 32-115 Top(MB) (lKB) (') Nam Description Comment D(in) 283 28.3 0.06 HANGER CIW TUBING HANGER 3.500 CEMENT.32 CEMENT,32 B 1,807.2 1,801.6 13.97 SAFETY VLV CAMCO TROP-1A SSA control line defeated:not locked out 2.812 7,122.1 5,672.4 45.18 PBR BAKER PBR 2.991 7,135,8 5,682.0 45.18 PACKER BAKER FHL PACKER 2.991 SAFETY VW, ..- W, � 7,148.7 5,691.2 45.18 NIPPLE CAMCO D NIPPLE NO GO PROFILE 2.750 1,807 7,156.2 5,696.4 45.18 SOS CAMCO SHEAR OUT 2.992 Other In Hole(Wireline retrievable I valves,pumps,fish,etc.) IPERF, Top Depth 2448-215'0 MD) Top Ind Top IRKS) (IIKB) (') DeecdptIon Comment Run Date D(In) 32.0 32.0 0.08 CEMENT CEMENTED TUBING,IA 8 OA TO SURFACE w/15.7 PPG 5/1112012 0.000 ARTICSET 1,OA CEMENTED DOWN TO CASING LEAK IPERF, @ 300'. 2480-2.412 2,900.0 2,7162 46.30 CEMENT PUMPED 15.8 PPG'G'CEMENT DOWN THE TUBING,UP 3/25/2012 0.000 THE IA,TOP OF CEMENT IN TUBING AND IA @ 2900' IPERF, 7,157.0 5,697.0 45.18 CEMENT PUMP 8.6 BBLS OF 15.8 PPG CLASS'G'CEMENT,ALL 5/23/2009 0.000 3.875.2670 PERFS COVERED Perforations 8 Slots IPERF. ---_----- -- got -- ---- - 2.703-3.703 Top(TVD) Btm(TVD) Dens Top(88(B)atm(111(8) ( B) MD) Zone Dab Oh-- Type Camnmt 2,448.0 2,450.0 2,379.3 2,380.9 A-2,2T-05 4/9/2012 3.0 IPERF 1.375'HSC Loaded,0 Deg Phased CEMENT,30 2,490.0 2,492.0 2,413.3 2,414.9 4/9/2012 3.0 IPERF 1.375'HSC Loaded,0 Deg Phased 2,675.0 2,678.0 2,554.9 2,557.2 A-2,2T-05 4/6/2012 3.0 IPERF 1.375"HSC Loaded,0 Deg Phased 2,700.0 2,703.0 2,572.9 2,575.1 4/6/2012 3.0 IPERF 1.375'HSC Loaded,0 Dag Phased 6,927.0 6,930.0 5,533.4 5,535.5 3/22/2012 4.0 IPERF 1-3/8'Titan Tbg Punch,0 Deg Phasing,Decentralized 6,930.0 6,933.0 5,535.5 5,537.7 321/2012 4.0 IPERF 1-3/8"Titan Tbg Punch,0 Deg SURFACE, A 1. Phasing,Decentralized 32-3,010 CEMENT. 7,234.0 7,249.0 5,751.3 5,761.8 A-4,A-3,21-05 10/16/1986 1.0 IPERF 4'HyperJet II;90 deg.Ph Zeno IPERF _ 7,249.0 7,274.0 5,761.8 5,779.5 A-3,2T-05 10/16/1986 4.0 IPERF 4'HyperJet II;90 deg.Ph 6927-0,930 = 7,308.0 7,332.0 5,803.8 5,820.6 A-2,2T-05 9/3/2002 6.0 APERF 2.5'HSD PJ/2506 PJ,60 Deg IPERF, Random Orientation to low side 8,93.6,833 No General&Safety End Date Annotation 5/23/2009 NOTE:PM well due to Production 8 Surface CSG leaks 8 corkscrewed TBG 7,076lit 5111/2012 NOTE WELL CEMENTED TO SURFACE;SUSPENDED I a- FOR,7,122 a PACKER, ,122PACKER,7,138 T NIPPLE,7.149 _... -. MU 5CE,7.156 CSMENT,NT, CEMENT. 2,900 IPERF, 7,234-7,249 Mandrel Details T. CEMENT. ..... 7,157 Top Depth Top Port IPERF, (TVD) Incl OD Valve Latch Sae TRO Run 7,248-7,274 Sin Top(51(8) (a(B) r) Maas Model (In) Bert Type TYps (h) (Psi) Run Dab Com... -'- 1 7,076.0 5,639.6 44.80 01I5 LBX 1 12 GAS UFT DMY ROS 0.000 0.0 11/11/1986 APERF, 7,306-7.332 --"-_,--7_ - Cement Pkg. 7.157 i PRODUCTION, 33-7,670 TD,7,870 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: i<1 ()1/4, / — OL.( PTD: oC /3 Development ✓Service Exploratory Stratigraphic Test Non-Conventional FIELD: j'4 c,1%,\ /�i �/,c 1- POOL: /K if 4J'W( c k,,r k ( PJr v) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit / (If last two digits No. )?(0 —HO , API No. 50- /03 - Z00 7( - DO - o . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 N❑ a u)cm o a N N a) 6 u) 3 o m a) a) a c c TD c Cu Cu o a a a); r > CJ E 0 N a) c c d' 30 C. c O V gyp, ° zca E I y, N N -0 , I 7, .p, 0 -O ui o. @ E, f), w N O t a c co 4 N O_ ° c aa) w, eo m CO 7 c CA. c o 3 a — O y a ° c. c ao, �' �, o 0 0 ) CA a T c 3 3 rn a a = 0a -5, a) . 17 CL �o E p co a = N .3 ai v, 0 _ 00 a0) o `) 3 = o) P `r 3' m; o) a a c m e- a m .� N, • a) co i- a a o m , c O. ' -p p CY ao 0 C 3 CO' _ _- _ o o w: J 0 C a) O (0 I 0 (0a), co 0 o 0) 3 o a) N v a 0 =o E. 2.- a) m N J o c C L > 'O (/) O 7 .N (a v '3. p. 0 N co O H O .0 0 o. 3 in. 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