Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
213-060
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. Q 13 - 0k)0 Well History File Identifier Organizing(done) /wo-sided III 11 Iliii ❑ Rescan Needed III illililli!111111 RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: � ❑ Other:: V'` BY: Date: 3 /s/ jJ I Project Proofing I 11111 BY: Date: 3 /s/ r CZ.r.i.0 �'Scann Preparation I x 30 = 3 0 + O.,.,9 = TOTAL PAGES 51 (Count does not include cover sheet) 1/4 BY: Date: 3/51/9,, /s/ Production Scanning li I III Stage 1 Page Count from Scanned File: 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO BY: ___ - Date: 3/51 t Li. /s/ i4 to Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 111111 11111 11111 ReScanned III 1111111111111111 BY: Maria Date: /s/Comments about this file: Quality Checked III 111111III II'I III 1 2/22/201 1 Well History File Cover Paoe.doc 6,i) I%%% �' THE STATE r,'acka ,3a c 333 West Seventh Avenue " j GOVERNOR SEAN PARNLI.L Anchorage, Alaska 99501-3572 Main: 907.279 1433 A ,:kl°' Fax: 907.27.%542 SCOW) 0.201 Darrell R. Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. �i 3-1,6) (Q P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F-17L1-02 Sundry Number: 314-151 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 144Ai_c Cathy P Foerster Chair DATED this'day of April, 2014. Encl. AI STATE OF ALASKA RECEI" D AL/ OIL AND GAS CONSERVATION COMMISSII TS4 APPLICATION FOR SUNDRY APPROVALS MAR. 2014 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Suspend r Rug Perforations r Perforate r Pull Tubing r Time extension Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Prod to WINJ IV. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development F,., 213-060-0 3.Address: Stratigraphic r Service r 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22731-62 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r' NO F. • 2F-17L1-02 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25657,25666 i Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10784 , 6076 , 10784' 6076' None None Casing Length Size MD TVD Burst Collapse LINER L1-02 1708 2.625 10784' 6076' i:: =tl, Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9172-10784 , 6068-6067 3.5 L-80 8704 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SEAL ASSY-BAKER GBH-22 LOCATOR/804-0 SEAL ASSEMBLY• MD=8550 TVD=5620 PBR-BAKER W/10'STROKE • MD=8554 TVD=5622 PACKER-BAKER FA-1 PRODUCTION PACKER ' MD=8568 TVD=5631 NIPPLE-CAMCO 2.813'X'NIPPLE • MD=8652 TVD=5689 PBR-BAKER W/10'STROKE , MD=8703 TVD=5727 12.Attachments: Description Summary of Proposal , F; 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P 14.Estimated Date for Commencing Operations: • 15. Well Status after proposed work: • 3/20/2014 OilSuspended(" Gas r WDSPL r p 16.Verbal Approval: Date: WIN JAbandoned • GINJ r WAG Comii'ission Representative: n',.. GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Email: n1139Aconocophillips.com Printed NameDarrell R. Humphre Title: NSK Production Engineering Specialist Signature �.Yi it j( Phone:659-7535 Date 3„s• ( Commission Use Only RBDM MAY 10 2014 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\i- -`5 k Plug Integrity r BOP Test r Mechanical Integrity Test177/Location Clearance r Other: IFGOLC w; 7137rT55d ✓1't I T- i- • r-tct iv, K-rd a 0--tv �7/---- b1 1137-el Spacing Exception Required? Yes❑ No Subsequent Form Required: �it G� l ` 4o / p APPROVEDY Approved by:A COMMISSIONER THE COMMISSION a Date: /'�/9 —/� Approved from the date of a roval. Form 10-403(Revised 10/2012) i'45 , /11/tj ppSubmit Form and Attachments in Duplicate viij 4 /5j141 2F-17L1-02 , DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2F-17 and its associated laterals from Oil Production service to Water Injection service. The CTD Permit to Drill (which added multi-laterals L1, L1- 01, L1-02)was completed with the well as an injection well, but the completion report was filed as an oil producer to allow for extended pre-production. The pre-production period following CTD operations has now been completed and the well is being prepared for initial water injection. • • RECEIVE° M 20 Robert Christensen/Darrell Humphrey Production Engineering Specialists. AcGCC Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhillips Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 March 8, 2014 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit wells 2F-17, 2F-17L1, 2F-17L1-01 and 2F-17L1-02 from Oil Production to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regardi 2F-17 2F-17L1, 2F-17L1-01 and 2F-17L1-02. (PTD 196-204, 213-058, 213-059 13-060). If you have any questions regarding this matter, please contact myself or Bob Christensen at 659-7535. Sincerely, Darrell Humphrey Attachments Sundry application Well schematic s KUP 2F-17L1-02 ConocoPhillips �4Well Attributes Max An &MD D IncAlaska, Wellbore APVUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(61113) 500292273161 KUPARUK RIVER UNIT SVC 97.14 9,750.23 10,784.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Coolie •2F•17L14Y2,7l3A01311.19:55 AM SSSV:NIPPLE Last WO: 5/15/2013 2/5/1997 Schematic-A teal Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,175.0 5/18/2013 Rev Reason:GLV C/O,PULL CATCHER haggea 7/3/2013 HANGER.28 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER L1-02 (off 23/8 1.992 9,075.8 10,784.0 4.70 L-80 ST-L 9Imain wellbore) ,Liner Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (°) _item Description Comment ID(in) CONouctoR. 111 l9,075.8 6,003.5 40.39 DEPLOY DEPLOYMENT SLEEVE 1.000 43-121 • Perforations&Slots ilk`- Shot NIPPLE,493 Top(TVD) Btm(TVD) Dens III Top(ftKB)Btm(ftKB) MB) (ftKB) Zone Date (eh... Type Comment 9,174.0 10,784.0 6,066.0 6/12/2013 32.0 SLOTS SLOTTED LINER INotes:General&Safety End Date Annotation 6/132013 NOTE:ADD LATERALS L1,L1-01,L1-02(off main wellbore) 6/132013 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, 3,005 at tl ' SURFACE, 41-4,018 Or GAS LIFT, I hi 5,403 sr GAS LIFT. _. 6.844 GAS LIFT. 7,7% GAS LIFT. 8,499 1 - SEAL ASSY, — 8,550-------...._ PBR.8,554 I I PACKER,8,568 NIPPLE,8,652 . iii4u,. . SEAL ASSY. 8,704 PBR.8.704 -lisi; ANCHOR, 8.717 Mandrel Top Depth Top Port 5... (TVD) Incl OD Valve Latch Size TRO Run PRODUCTION, N...Top(ftKB) (ftKB) C) Make _ Model (In) son. Type Type (in) (psi) Run Date Corn... 398.975 1 3,004.6 2,594.2 58.68 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,299.0 6262013 (PERF, 9,0389,048 2 5,403.5 3,892.8 54.83 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.313 1,328.0 6/26/2013 3 6,844.4 4,681.2 56.64 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.188 1,316.0 6262013 VMIPSTOCK, 9,062 t 453 7,796.1 5,184.3 58.89 Camco KBG-2-9 1 GAS LIFT OV BTM 0.250 0.06252013 WINDOW L1-02, 5 8,498.7 5,586.3 49.43 CamcoKBG-2-9 111 GAS LIFT DMY INT 000...200015808 .000 0.0 5/122013 9,0829,092 LINER, 8,718-9.561 SLOTS, i 9,174.10,784 LINER L1-02 (Omen wellbore). 9,076-10,710.7844 TD I 111 10,784 ) E I Kuparuk Well 2F-17 Conversion from Production to Water Injection Area of Review Well Summary Kuparuk well 2F-17 was drilled in 1997, approximately 13 years after initial drillsite 2F Kuparuk, to exploit A4 and A5 sand targets on the southern flank of the Kuparuk field. The well was completed as a Kuparuk AC sand producer over the interval of 9,038' MD to 9,181' MD. It was initially produced for a period of six months, during which time it produced a total of 31 MBO, before being converted to injection in order to support the neighbouring well 2F-18, which was drilled in the same time period. Well 2F-17 was a water injector from December 1997 to June 2012. In June 2013, three laterals were drilled from well 2F-17 in the A4 and A5 sands with coiled tubing from a whipstock located at 9,082' MD. All three laterals were completed with slotted liners. The well was pre- produced before being shut in February 22, 2014, having produced 80 MBO, for a well lifetime total production of 111 MBO. Converting well 2F-17 to injection will provide water injection support to the offset Kuparuk producers 2G- 11 and 2F-18. Below, the Area of Review includes a description of the following: • Map with 1/4 mile radius shown around the target injection zone; • 2F-17, 2F-17L1, 2F-17L1-01, 2F-17L1-02 wellbore schematics; • The mechanical condition of the proposed injection well; and • 2F-17 CBL and interpretation of the cement quality of the subject well Area Map with 1/4 mile radius around target iniection zone Kuparuk well 2F-17 is located in the Southwest quadrant of the drillsite 2F Kuparuk development. The map attached shows that there are no other wells located within a 1/4 mile radius of the 2F-17 penetration of the Kuparuk A and C sands. Kuparuk well 2F-17 Wellbore Schematic Kuparuk well 2F-17 was completed with a single completion having a 3-1/2" 9.21b/ft L-80 liner by 5-1/2" 15.5lb/ft L-80 production casing. The surface hole was completed with 7-5/8"29.7lb/ft L-80 casing. 2F-17 was originally perforated over the AC sand interval of 9,038' MD to 9,181' MD. The three coiled tubing laterals drilled in June 2013 were completed with 2-3/8"4.71b/ft L-80 slotted liner. The top of the Kuparuk C-sand was encountered at 9,038' MD, and the top of the Kuparuk A sand was encountered at 9,105' MD. The schematics for 2F-17, 2F-17L1, 2F-17L1-01, and 2F-17L1-02 are attached. Mechanical Condition of Well to be Converted to Infection and MIT History (2F-17) The mechanical condition of Kuparuk well 2F-17 is good. The well is classified as a"Normal Well", meaning that the historical MIT-T and MIT-IA tests have passed. The most recent MIT-T was tested to 3500psi on May 9, 2013. The most recent MIT-IA was tested to 2500psi on May 12, 2013. A State-witnessed MIT-IA will be performed once well 2F-17 is converted to water injection, online, and stabilized. 2F-17 CBL and interpretation of the cement quality of the subject well (no other wells are located within 1/4 mile radius) Well 2F-17 is located in an injector row in the drillsite 2F development. Although the well was pre- produced after initially being drilled, and again after the three laterals 2F-17L1, 2F-17L1-01, 2F-17L1-02 were drilled, it has been an injector for the majority of its life. 2F-17L1-02 DESCRIPTION SUMMARY OF PROPOSAL • ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2F-17 and its associated laterals from Oil Production service to Water Injection service.The CTD Permit to Drill(which added multi-laterals L1, L1- 01, L1-02)was completed with the well as an injection well, but the completion report was filed as an oil producer to allow for extended pre-production. The pre-production period following CTD operations has now been completed and the well is being prepared for initial water injection. • • • • - r 2F-01 o2F-02 • iiil 2B-04 Q. \ ,•2F-08 2BJ20 s 7 %'r y1 •2G-06 ,2F-16 `® F-09 02F-15 •2F I \\ \ ' . • I..\12 2 \\ \* ,,,,\ 2F-13 • F-12 ` 2F-14 • 0 2G . , ,s, . • . . 2F-17 i F-18PB1 ••.. .•2G-09 2F-18 F g�2 2F-17L1-02 2F-18L1-019PB1 2F-19AL2 2F-19AL3 2G-11 •t '`2F-18L1-02 ' ,' 2F-17L1-01 2F-19AL1 2G-11AL2PB1 2F-17L1 2F-18L1 ® Legend 2G-11APB1 WeilTypes ♦ ACTIVE,INJ,SW A ACTIVE,INJ,GAS ACTIVE,INJ,MG A ACTIVE,INJ,PW • ACTIVE,PROD,OIUGAS • 2G-11 AL1-01 A ACTIVE,INJ,DG 0 ACTIVE,INJ,MWAG 2G-11 2G-11AL1 2G-141$.L2 .✓ ACTIVE,INJ,IWAG r ACTIVE,DISP/SERVICE •2G-1V11-1511 l 1'I I + OPSH/SUSP P+A , r El 1/4 Mile Radius Conoc PhiIIips 2G-17 Alaska,Inc. 2F-17 Convert to Injection """""""""" 1/4 Mile Radius Evaluation N A ,\ 0 0125 0.25 05 imm mos Wes 2F-17MWAG-swop mxd CSR 3111/2014 2F-17i Final CTD Laterals Last Updated:6/12/13 16"62#H40 shoe • 3-1/2"Camco D nipple @ 506'MD @ 121'MD . , .' L 3 1/ 3-12;29".3# CamcL-80oMMG EUE Srd Tubing to surface gas liftmandrels @ 3018',5417',6858',7810'&8512' 7-5/8"29.7#L-80 3-1/2"x 5-1/2"FA packer(3.0"ID)@ 8568' RKB shoe @ 4019'MD — J. .- r 3-1/2"Camco X landing nipple @ 8652' RKB(2.813"min ID) Baker 3-1/2"PBR @ 8703'RKB(3"ID) Baker KBH-22 Anchor-seal nipple(3.0"ID)@ 8717'RKB Liner top Baker SABL-3 liner top packer/hanger @ 8718'RKB F (min ID 2.78") shoe @8975'MD .__...._J1 IL___ C-sand perfs 9038' 3-1/2"monobore -9048'MD _ whipstock 2F-17L1-02 TD=10784'MD 2F-17L1-01 TD=12981'MD Liner 9075'-10784'MD Liner.9550'-12981'MD KOP©9082'MDL \\ Liner top @ 9075'MD Liner billet @ 9550'MD !—J E 3.00"OH 9082'- 10784'MD 3.25"OH 9082'- 11005'MD \\ 3.00"OH 11005'- 12981'MD A-sand perfs 9126' \\\ ///--- _� - — — -9181'MD - 2F-17L1 TD=13375'MD 3-1/2"9.3#L-80 Liner:10967'-13028'MD shoe @ 9560'MD Anchor billet @ 10697'MD 3.25"OH 9082'- 12744'MD The cement job on the 5-1/2"casing was completed on February 4, 1997. No cement bond log was run. Per the cementing details report, 120 sacks of G-class cement at a yield of 1.15ft3/sack was pumped at 3.3bpm. Calculated top of cement(assuming 30%excess factor)is 8,418' MD, which provides more than 500' of isolating cement between the top of cement and the casing shoe at 8,932' MD. (These measured depths reference the original 1997 schematic depths,which has the 5-1/2"casing shoe at 8,932' MD.) From the drilling report of February 4, 1997: Flush lines w/5 bbl water. Test to 3500 psi. Pump 10 bbl preflush, 50 bbl 11.0#spacer, drop plug, 24 bbl(120 sx) 15.8 slurry, drop plug. Displace w/5 bbl water, 48 bbl diesel and 156 bbl water. Did not bump plug. Hole started packing off when slurry went around shoe. CIF'@ 2014 hrs. Calculated top of cement as follows: • Total displacement of cement=5 bbl (water) +48 bbl (diesel)+ 156 bbl (water)=209 bbls • Shoe depth= 8,932' MD • Casing capacity of 5-1/2" 15.5Ib/ft casing to shoe= 8,932' *0.022075 bbl/ft= 197.2 bbls • Cement displaced into annulus= 209 bbls— 197.2 bbls= 11.8 bbls • Height of 11.8 bbls of cement in the annular space between 6.75" hole and 5-1/2" 15.5Ib/ft casing assuming 35% excess factor (11.8bbl*0.65y 6 bblt)— 514ft • Calculated top of cement= 8,932' MD—514'of cement= 8,418' MD In addition to the 5-1/2"casing cement job, the 3-1/2"liner was cemented on March 24, 1997.A cement bond log of the 3-1/2" liner cement job was performed on May 1, 1997. The cement bond log shows good cement from the bottom of the log at 9,445' MD up to 8,720' MD, including the overlap between the 3-1/2" liner and 5-1/2"casing from 8,932' MD to 8,720' MD. (The measured depths from the 1997 log reference the original schematic, which has the 5-1/2"casing shoe at 8,932' MD.) • • I ' • , •6!••1 '..'L•••;11,,,I1_ 1,' •; : I t - . . I ,II-•- ; 1 .-I-•F.'..•''...:''',C,.:7:-.,''-:!...:',:'::2 : :-..',"E: :.- ,. i..i'Hy cl '.::'...,-_'.--,,-'-,,:','::,r'i.,' . . -- - . I 1 . , , ,. --.1.1_.' 6.6 I.,0Lci ''10A 1•• •7";16', i I I • i : I ;ICC I1-%;•.7 :5;1";11 '' ' 6,;11. .,-, . ',-,;"'. - . - I A ; ' I ' I ' ! ,P';OI. :•,.' -, i• '' • 0;IAA, 7"A;.'1 r,s .. ' 1' .1- : ' 1 1 1 i'-'1-L.,:'LT.;F5 t.'-',1; :: 1 . I I . • I ..,O , . ' 1, 1,1T,: 1"T: 1:;-;) : 1 , 1 ' ' ' ' .;r:'TT 52 1711::f.;';' '1 1 R 1'-1 ..' s 1,11 1•11,-,''' ,:IR),•i 7 i, i! ,.., l' DJ- ,r6A1 ' I ;,I,I 1 I I 1 I,V.Ie•,I.L).'.'7,,I,'6I ! ,•,',..,. I 0: 03-. ...;KE- I' A......q4. .97 .,! 1 ljeA,-•,1. I I-tl t E2.k:-!,r- 1: ----I • i, bete , 6,6. Le of j Per, I,T.-• 1 I I'``-I ' I 6 AA,'''''g,';..,..' 1, < C ,...... 4 _ ),,,,th. :3,,,ts 1 Ft urn In ji. :_._,...,, T. .1 ,...1_,P.E' C''•Z Lg 1,1 8888 '222888SE8SZg886 1a• , .. ' or Log 7 NT I I II I I I 0 2 L''; .&; '66 ° 00000000000 'g° D <3 502823 <7. i; ff O.< E' I.; I-- 5,-, 1 lIc , Fir6i Reecing L.132 j, -1 I , . ! I ,,g0_20 , L0 I;LPN ReedingI 8600 ) 1 I I „, 1 1 1 pl)1,),,,L0:71, V) II C: U.1 _LI, ' FLA TILLesur-LAL 332 E __I i_ 1 , . I 6.`.2,,_`'.. u u r ,_ i 1 t".1 ,1! i cz 00....ssg...00.00.0... I, Depth Peaciled 1-3•150 I < ,- 8.:3:63. 8E.E4g.88.E.85.E.8.8.S.SE88 I 0 , 0 il Bottom Driller ,16, , . -LC -1&, k ,...,--' i:U.L't Il Heat Pressure i ,-, 0 L__ 1 1— , 11 • I sgstL,.,2. 1 . I CI ,loid LeVel 0 1 6uo Type: t , HL , 3337 I I ;2c'ort ! 7 CASING RECORD I' I CO t;U•;<M ' E '_!ope9co.soocoo-DoocLoc;c6-A,c.5c; II . i. Size 11 1 '))1,1911 1 Troro 1 TO ,,, ,td PgiVfa'W5'1 ' k 0 ns 1:1 W 1,1,..C1ALE); 11 3 1/7 • 8702 -1 ' 9160 ;;), a. ..,...-isF;Vke: 5, --00o,,o-,00,,,,...,,,,,,,,00 Iwitnessno4 1 ,35R JORDAN 1 3 117 JJ, 1 0 I 35702 j1-1°. : 1 1a•<W:;:i tg X , . 0,,,Z,,,, _____ __ __ ____— COLI AR LOCATION OTHER SERVICES M _ - ____ 1 TLjpe T Size 1 0000 tC....,t, <4.;L'•_.1,0 4l CALE a. - i- , . . w 1 1 i I un 2 i,:. t,-- ' 7. °<'ej''''ii I • '4 z Pm= 0 I _ --1, ; I ; ; ; • . 0= c. '''-ii:1 ij ; ;, r1 I - - .Al E80,,,,i) 1 1 ., iold ,§-t.„t.._z It,,,t,--.:,,,....0?„,!..-•4.- .i...,e;,,,c.ts„...6....Al,,I; .11_,:7';,,I 1,. I 6-; • I 1 0 1 ; • • - -- --, - - ------- - -- - - - --- -- ---1 E E L''-2 :_l 1,LeiRiCaNpre, r7r) I, Scating Nipple; P1''..17a; La? .-S''<-- 31',I.• 2/ 2 - 6,--,,e,6.--e6,c,o]=E-_,:2"LL.C•2•2EI.dEP.,.9e,r7;n I, .0-1 L7-1,3;3..,, 360.;;LRiPJ 211.1,0,20 1 L __...._._,..,...___....,.._....._. _________ _.._____. • , , I ...- ,-.-, t; c,..) i E, __1 -;------• I I ; ig —i g FeJ !---J I. , ',. i 1-- ,!,--• I a, = =-7, 11.1,7.1 <,,•'', NI V -", i 1 '-';' I• ' _1 „„ L,:-- / 0 • r r f 1 v1m y c. k it 12 m... L 11_-r ';1 1 I 4 t 14 LI �! -- ;' _i u _ CIS__ , I 1 � � ; ■ a Il lir; sI I1 ; .S u � NII I- I_ -I . Ir ,IM � p.,1' Ink 1 ' 1 _._;J_ 1 1111 1 ,_ gnun., .. we c i , 11 11 1111111 :1� II- 't, I Flip 111:11111111::1111111111:111, �.ir .►JI 1 o 1 lam_ 111 111 11_11 111 1 NN ( m El ; 1111 1 s n j �� null i 1 p EL% • .. tt " .4 ti`s"F., *• .t s.�' ,.ras> "'-'"'Vev rMi. N� OAP r ,(, ' - 11. .sn.sm,".-., = '* 2,"LIMY>4TR...cw a� • :., • 4 t _'*' N"a-aT + `c` fi;' ...« {Y " " •v.� ' 4... tY^sw +}V' "ti.ViMM ;a ..'M'e. vme' t'. 1-- ea�a*•xa� --,,,-, --,�wsn .s�, ."`. 4` *...—'T :: ++ ge aw wr..•1,• ---- ._.'e*r v r - t� „`i ,: a d , 44 f?!"t4 �' '"; . , Y t-,,®w � ., 1+; 01 i,`. -- F ,,,,,.4.'!- , S J i_1 � n Y ; 1riitillflhIiIi:iIIII_11 ' 1 . -141111111111111111111111111111111 iIillIll'liiiiiiRhiiIlluiH 111luli1u11111lllll1111111 11u11n111111n1m 111111 �J;__�i _LI 1111i.i.._ -_ iIIIifli !ijhII 11 ,Ei I 11 �Lg .:.: 1 , . . . !.. 11I.1 �. 1 O r _ _ ,,, w �. II 1I g -- _E I 1 di 11 IJ' IIiIIIII1 u1_�_i 10II1II 111 Ill1111;111! 111_.,. �I `,13,•,1 nor rir ►I n 1111 rr�ti ■1 111 Ii�ii �I_ ■ 11 11/�1 [ 1 11 itr� Xk . 1 j i1 1 I 1 1 ii1i! 11 . II ilii- 1111111 1 o , 0 71 _. ►�► �i�i" 1�i 1__ 11 1 111 I u I , I 1 1n11p 11 I I II I tun 1 eIIII I II 1111111111111 _ i1gu I 111, IlIl_1 . �n�nIIM•1n�i11 I J I i i_l -SII Ir , J 1111111I11 I ups 11 i I. _, 11111 1- 11HIH o inn ' unL i rMI ■1111 � II 1 1 _ I 1 'lu1 ___ n111In1r I A 1 V II 1 i 1_ i� 1 1 11__I r�11u1111 u►ii ►Ii1�1 vi ••. 1 11 kJ V. ► 111 E o L ! I 1_I_�_ 11 r _,,� 1...I L NinaJ�_. ! ...+97. A_ l_ , _I l . . r. I_ .L . 11 1 _ _= _ 'J,_. _!.r _r _._ 1 11 . ,I. LI d ! L'to ,rt0 n `p w n y ---;----- ,-,:-.4,/ :f 1/4',;:,,,'',' 1-7-7-7- '„' ti th .z4,-..-.7,:••, -.:,;•,44',t)...-�s�T- - V „,,I,,,”Y:. •N i,•••d;; .� ff'.�t F •• },' "k4.1.n . y' - ,-.1V.,,, '"'4' z.''''-',-.' ' r-lt�' s-^r-'%1-4,1040, ,-,u Krn waw Agyl . +nv 'Wl +l°y 1 �`. .;' Yi ' i`�`';,"i' pili r '�-.. -3 .i 7.,- +r A.PF. .. t "-',;;;..Z.� 4 M ,. • Ty), fir, .¢. 4- ',44.77,1- ..2,45,7 -.y.lv �"O om, ' .„...,,,,,,,,,,,,m...._, t:,/,,..,«e"r;ur, 'lo :;, , hs,.';' ,.'- rf, r0ot r �yy,. S A Str4 4 3c �..a �. 4 a-�i y' ,�.' �fi�r-.A?f�7 ��g_��."�- ,�Yash vc..�y-r- '„ ..1.1•064,,,,,:.....'^w hr�.�'„��.r" r 4.�� oa4c Ak^� �,, Hy , s. -' ," '�` . _�F'w �yn`or. ...,.�'o„�'� �� \,,...�'?.sro u yw,, ,,r„.,,:-a �, c. ''',"-:--?1.0 4 4 R* '. ''''-7.'''''.-.•-'''.:" `& ,gr/�.MP !,04.0.y"rM� 'U. -rplor ti'��T k 4 ..,„;00:'&,'"'art 4,./n'' .0�y4, jr '''.i.ittt'l,,, 4✓ W,,7y '-.r ¢hr'.*4r�v ..s,y...,W.Zv1eY-cv�w.`, r•ntajf ....w; ♦o,4n+ ..a '" i y Y �`:,d.+.r. 44,,...4,,,...' i--...0,...- 11 _,�.xa,T .Ji:;"'.'"Ai.4 n:r4W Ka rw f'> .,Ia7NY.t:i l'i:h�',Z'•.�'MF' +rw� .%:ik `h' .1 S.; ` - I I liul 1111111%11 i11111n11111�Ini1 11 io n.I 11 i •a 111 111111111111 ii11111I11ili 1111111111111111un11I '11 lain '_ {. Li 1, _ I nI I _ 1_ •Inl I1 11 ilIIinil IIIM III11I1DUIIII I I 1n;11 r i I �.Il_�., J_ -._1_ III _I U_ I 1 ,� n1I� 1 111011111111111 virgin IH 1 11 11 II ! Iii, i;. 1_ LII .fi. a t1I/`►�!h i � _r1:.i ' II I Valli ldbi_ i !N l�ifiipl/ Sit (_ `I IJis I ..__ 1 . i IIIIII ItuIll � i 1 1 I I n II111 11 1 IIInI111II I. _, II . 1p 1 n11 11� ;.t i 1 i 1 1 11111 1n1II nl� > 1Ipp111 n1 Il_I I �Il JJ 1 1n111I1 ILII �.. . -U.- — 11 1 _. 1 I iIi hnl 1 II11h�11 i1 Ilh 11111 lh II i i , 1111 I _ _ 1 mils i - IT III 11 1 1 1i1o111 �,�1 1III7:; � 1t■M r 1'i1'r■ : .r:...r fi[ 'i: r M� .■ C 'i.t 'f u mule in �n.r. i.. . intra r L' : • ..c r. rnt I rrr rwrrw.�i...i1.i. ..i...rr r a .rr-+�n�V: �1� k Yri�Of6�.lQ1N! i[ !r► �Cii++51F16TiSGlr, il�i!!11 !:"•Ylr�:�r�hrl:aiiY f - .��rlcrli! � rn1!lrHlrioiiALlrse! "ai6f1�0Bifll Rll9Y18Hir3'iAk yrls � -4l_ _ ilJ I ..i. 1 1n rd0''''r°''' II tali . I `'i mogul II InII 1I�hj IIIIlhlI1111111 nU0UIhIl� I '1, I I�1r11111. '-,--°- Il1 1 n lI i_ =_,__, I_I ��1 i 1 ur 1 11 II�IIn IIIIn111111 1 111 1•►/i 11 1 i i `'111 ,2_ l.- i {! In or, 1n _L JI I1 I I 11 ip ■ II41111111I _ 1 _. l '' ' _ J I11 _ _ LI 1 • ! It1 1111111 I 9111 __ 1 I1 1_- ! 1 1 or 1, i i1111n 1 I J __III II. ��. I� f _ 1 JI i 1 IH I . U1I ! 111111 H �I�/I�n1 I11' � 11 1 -1'--, �_' '_ - ►I Ill _ Ii- 1 _1..J_.7�I 11 I I_._L- 1 - --i IIIIII 1 tri I ni II 1111 ll 1 1 I 4_� II 11ITil i i,� I lIF1 d__L_4 _ 1 11 I I 1 _I I.i,'nI l 1 ] I1 1 ! iI i ! -.J _ I_ 1 I - I _. . 1 ._ - ki1. C u`, u; s h y S Y) ;';'?z.,.:013.' ...��.,�. :3`4.1 ,. .4. uFi:'vY ,-,,,,k.4,+".. r€ ! !7 Hi+ ; t ',-,';,,,:i,%-',:,;:-: ',41, r._ ; l +; h ?4h 5.. ,s ' .. ..-..A't xL,,g � ;. .i -3�.*.L4F ; s. . 'rWe� ' it �`� (ana N.A ytg;.. Y.,f• 44-.4w 3cr; wscp � tiR4 �`...,iiey.4,.f'^Amer.yn , y.i ,A ' y''+.�'r w./r't .. '' ' ".:...* ' ..----;:V•:."'"..,, rete r .�,kwww.• .++ 'ti.me.." Na b•oly.+q�twW..w..sw .d -,,,,,, -y..w.',, 4e :- ',2, '- :.4,• k14"..ar.v... }- ♦.t—.,,, +.-rte ..9"•��K 'N.- 'r ..'+.. ,, Y b'h ,. :.0%w`�5.'",,L : .!»....,,,...:,;::,.!",..:1'.-.:,1,-,:..,..- z. duSaw4.x•,,,,r.,...ay...: �+c`.+w-+.-..aw..�,.,. '-+ ,...... `• ' r ..r' '•r�.+4w. ..:wat kR1 k • I s '3p yi` .r�j 1, L II`µ .1 _ 1r.1 iIIIn11111n11 111I.N111111111111 111111111111 iu11111111111111111111111111.■a 11 .11111 . i_. 11� I I 11 IL_ L-.L_ 1 IIIIIIII1111111ilII111111iIID1MIM : 1111111111111111 iniii1111111 iin111i� �'uni 1-.. it 1 11111 I I I lifi .1 .ILL-1-'1,1j r _la_j 1_/-_LI 1 i 1lm 11�111N,.rnlni1111n11!11 , 111111uuun 11111 I111111111111111n11 Iw 11 am_ 1 i. ,T ' MI- 1 a (_; I i_LJ1_L 101__L I I__.I:II 1n11 iniIIIII VIII 11 11n111i111I1n1111�1n111 #11.1■1�1� II w 1 _I LT.1114 A__ 1W 1= It as ran / a��nuraimunra r, n ■ m 1 . pip �� �� o�p 11 r IIlLI 11 !IL_.� 1 1 1111„ q111w11111 1u11 � 1111111 ill 11111111111111111111111111111UaIIl II U JX 11 1 11 1n/ I1 all In 1 I1 1 '- 1, rill Ilei, 11111 11 11 n1111I1n1 ill In11I11111IInnn1111n.11111 111 C, i l I JII h r �1 IlinIti liiiiiis i►.r�w.ro.mms, ..nrrr.� r[11rrrYiiiow=e-,.... ..wolitiviZigiMrr 1 i' -1 +� ...' rmy ,.� '�'L�:c.. 3?� r... w ..n.w�. .;.wr�.r. rr..�.... .t.w.r.a.w.+rr.w..y...r.- .wn..w..rr..n..... i�+�t1�In I I� �� � � °, IT -�__ 1 _ 1�, �remitv.�� n'�1i� 1u1 �e a eo1 1 ��@In1�n�1 n1I1 -�*� •�, 7a rrmie9�r •. �� ■ ►ieaEar+Nr,r mRe�xr r r � ■ars �ror m»�� erg �ar�warw�c a����e�ea�n_.;i! il_.�h 17I_ l z i llIilla'I___1 ,1 -I �11�� 111/ 111 �In111111� 11111 111 11111 IIIIIInn 11111111 11 1 ! I_I 1 I J 1 NIS I 1�f 1 ILU 1 ! 1I1 010111111 1"Li'III!:1 11 mum= mull ' i 110 I!_ )�1 L Ili]. ��I ii L U. J i_ 111 1� 1� ■ I_.�Ani.i uIu "EOM ` III�IIUUCI9il10MR 11 ll� 11 'IP16 . I l'17l 1 0 11171- I I l LU1 4 I� -,--_l - 1 pp' _ 11 F i it 111' VIII Io• 101`.----14-- - _um I_ � �� �- ( �.-,-L! , 11 �11 111111 I 1 11 Inn►"111 1 11 nln: Cr_�. �' 1 �'TI�1 I� i� L-�-�� � � 1 J. 1 11� 1111 1 . 11 mom 1� 1C1 111. 1 �I ��� 1111 In ,iIiii "�t� 1 X11111. 111 I Ill HI 1 1 -Thi�`I 1NMIII 1111 1 1 _ I 1 _ 1 IA 1111 11 rf, I � i i I I I� I ITI 1- 11.1 i 1 I l! I 1 1 I,_I_IT�IIl I I. __.I 1�i1__rl _TFL=�_�o —_,� 1 __1TL � .�.r._1 ni J.I_� I —_ I 1_....,_ InL _i.1-, i_ I .�I , U O N V „ n m 0 ` � 1 --:,qt-!.---7:--. . ,,,q../..... ;.. , a...�n . i6 ; "` , ,4, I've)r, 4`'' ,1.' :.yy,ry„W;'...wy4,%t,-; `YR', 77'..-_,__tom`+ .-7 .4.0".';:.,.--•:.-:':. ' te 1 ,1.,W,54;vm�•"' :� �``, + Y •.r� p ..r �,,,.-'.n......wr• ;:"'".". ."'"'."',W,'''':'!°T...+....^^ �,......• ,,. ...4�+.... ,.,--. ,,T-4. '.....,� ... .y �'4' ',r {' ,..,...,..,......--r----.,,,-------,-:,...,!,,,f` wrap.;,,..,. '"'yYtir,r.,.., oy,-,�... • .. ', `arar' +rM.. *-e,', s..;.-= p IV x k ".:""".''',"7 ",:;=:;:::". Ncµn v n•W r:"" :'"'.' •4`K.:, ...'1:'''"" .;,e ': N...4. 2,,,,,,::,: +'. •by.v.4,..�..k.V Kw'''.. ,c4,rarr�" r�'" „- ,14.: .J+a,:,*:: �7 .! �., m.-.4 Z.rw. `-, ;-: ,, r-t1-1:7:::::,..::,:.:-4-..; ::: ::<•- •-• .`.vrYr r b J.•.. r 0*• ,Y,o.v _ == - .y 111 . 1. . I' 'hi 11 ilii 1III1/IIIIIIIIi'11I11II1p1 I/IIIIIIIIIIIII , 1 IIIIIIIIIIIIIIIIIIIIII��IIIIIIIIIIIIIIE#II/IIII IIo,IIII 1II , y 1 i . [1! 1 1-1 11 11111111111111111111111 1111111111111111111 111111111111111111111111111111111111114111111112111 '�' -1 ii �_ m1111111111111111111111 1,0 111_' L--1 .',. 1 1.1 1 np 111 an1111111I111 mini 111 111 ', J.I rt i 1.: 1. 1 _ X11: 1111 11� 111 i`ry�1C.b gilii11I111n� ..IiiZ rrill_111151111111 1'11I1Iu1 n 1u1 ► 1� �9r ' �' i 1 n _ 141"111171 11"1 hI 1� 11" i alum uIII h imuihiiiiuip uuiiiii I` ri 1' 8" � I I n 1 I _� 1�. __1 1 lime_�Inup In. 11n1 i1111 1 UpU�pp111111n11 111111�mono' 111 1 i __ 1 � 1 L I . _ ill 1111111�IIII�111 ; 1CIIIIIlI11111II IIhI111111I1111111111111111111�1 11 LI _ '_ - ,,: _" 1- W fri,, a' -id acypcir■.rigictl�ur�f iv diF/...02 Birt. .... irrrriifir■:. ■ te..�ir■0,' y �.�-� rw.wdw rtaraw wwwr ..w..ww.ww.w. w v. wrr - �� "t s •ri ■■s ■r■d ■'a ;�■ea B arls■r1 llarmilimilinitinlitiliiiiIMMISIVIP9: a■:a s rvagB asia■ I }':;t .'. l l i'1_ i 1 1_,_ I I I I;_ `��fn 1 11n91 IIIIi$f . 1IIii1 I1fl1IS I VII ,1 ' I 1 ; 11 1 U I I (' fI111111111I 11 U11111 111I1111n11 11111111111n IIIII111111111111111 I11,m I L. l_ 1 U_, W q i v P ■ i ... w. wr 1Ar- - _ crisizr;I ! it ii rr!.1R.. I I ;I • o i J f ��, .L� � ► �'��.: AGI � ■ rI� n r■1►.unl■ ran � ■ ■ � t' � 10 -ti VI r„l' 71 1 I II_^ 1_i GNI �1Ip IIIJI I� i II 1111 . 11 a1 1111101111111n11 til! 1 0. - - i -- 111111 IIIII .T I j 11 �1 I I I J 11. �L _ I 1 I IIn 1 �j1I II Igni 11E� 11_I_: 1 k � _ _ II11B 111n11 1 u m 1 11 E II �IU_' '�1 FII 1 1 , �__ -- -_-'11� __I 1__1 1 I11u_ 1 _ _1111 1 11 In G 1 r i L' 1! I_;_Lr 1_ f 111 ItT , ' _{ I � -1 1 I 1 1 111__11 1 _ 1 r 1 11111 III,_III 11� n � {_i I , I ' I I1� � ' I I)_' 1 I.iI I I I I� 1 I I ' ii... :-.__ 1. . .i. , . r, :.1...�.. �_ L_ 1 h_ I_. . j.___ 1 _ .. Ial _� _ 1 _'. is . I '-... V M 8, \1r) I `\1 o C V 1 E J I n 0 a a 8) Cl NI ° ! o) o) E o) o) E — N co N NI Z N 1 0 a) 0 0 0 J J C) C C C O �1 p m it it it LE LE iL 2 N u) 9 NI 0 > = 0 0 2 2 2 2 2 I- F- I- F' O Z a) W W N N N Ln LO l[) SO LO LO Z Z > > N N N N N N N N N N N EL- ' N o ° °oili ill o o a o o o a a > Q co V J = J J J J J J J J J QC I,- N- N- N- N- N- N I,- N- N- N Y O r � U `� LL Q LL LL LL LL IL LL LL LL LL LL J N C y N •n N N N N N N N N N N C U p o ui 0.1 ui ui ai ui ai ai ai ai ai ai a to Z r m •u.Q it it LL ii it ii iL ii ii LL D I Q ° E 0 Z c_ c� t� c� U U t) U c) 0_ Y a) a E •E ° ° E ° E •E •E ELL •E •° ace N CS O U 0 o O N 0 0 0 0 0 0 0 a 2 2 (°D WQ E Q u) J U a U 0 U 0 0 0 0 V U • 3 U M Q O N I— J a) ° a)Q a) a) a) a) a) a) a) ° a) a) w 0 Ci Q C E W W Z W w w w w w W J W w N 2 N O co O J 0 ! M M M M M M M M M M M 0 . CL 0000 J ,� 0 0 0 0 0 0 0 0 0 0 o Ern E W co N N N N N N N N N N N CO O S V o O U) Z Ce d w y N N N N N N N N N N N O re j(O CO CO CO CO W CO W CO CO CO U V W z J 2 2 a) V U rQ _ ' Z O U Z O < I ° IX j ... 0. II ) 1 «O E a) i M ° Z I a) c O g o- N Cl) o N O N 73. (I) j E O_ I N U ; g E 9 I J J I Ce Z1 ,. CS to 0. LL a H M O a)I u) z / o J2! co 2 N a) • N a3 2 Y co J co c X of 1 1 a Q Y °� O) Q C aI z Z y 0 d 0 , o O C E -J 1 /f CO CO 0 III 2 o co co a) m CO CO a) CO CO CO a) a) o is a) co co co co co co ) N v 1, cn0 I', I E E O 0 0 0 0 0 0 0 0 0 0 co a) 1 •• /o e m m La m as ca m co m TO TOO 2 ! o c0 1, rn 1 I La) rn o) rn rn _ rn rn Er) rn rn U) o o i t z ;I 0) .., , i o 0 0000000 0 o J ! E � ° m ° w a) V .5 E N N N N N N N N N N — W co Q 1 z t C d aS 7 M M M M co co co co co co co co N r2 0 Q 0 w ° z N N N N N N N N N N N N Q CO I a v a) ill z O ° E E E R z O ° / ° ` ° O ` .3 cLL L 5d z 4 d U " � W ...LA- -S! o 2 U 0 0000000 00 2 u W J ce E 5 I W U Q T a 0 W W W W W OW OOW d d w Q a W W W W J z In NI O '` O •,,..1 N M o Z• �L �Z ti N Z >- >- >- _ � bA c� 0 �' Q N T N• 5 CO >, o a m -`°o ell (a m c v u, o Q �i '+ E_•o z Z r .c O I c. U d Q m `o I i ' o o m U U J -I 1 1 O � z Q Q � Z/ co l Z R J m > >- >. M ,N 0 Ce a - °' O w d a I- t_ 03 CO I CL LI J U •rn .5 I W 0 I I/ O N m LL. 1 W Z 0 J m a, a Co) 0 O _ J E Z rL+ — N w U)cy) I Q ` O) IN J d c . CL 0 cr, 0 U el c 20 2 'hi 1 • N Q I � Fs z (4 I N ✓ o0 o U / � ac) o >- r >- E N 41:t n H a. co a. N E F.. rn 0 N 1 • N f0 C CO • r N Iii II `!. W co O E ! I'I N .T 7 •co COQ Q C N C 0 V a C O- V• Q ] c 0 m I— Y a> c •v a Q Z o a2i N .- . O E 0 0 Imo+► z d M M 1, co Q o 0 n Z N N (O N LO I I I C co cc o co C N -C •O N d C ` o —_ = N a� N Y W l4 I ce 'C c F� m 0 0 d c y a co Z c � O V! (� c 2 CO 7 Q o 0 11 , ! 0 U - ._ U J t N _d '�. N co d U rn n v, 0 E d E 0 o ° a) Ilil O o aoi 111 0 o Q a U a C7 U U G .1, U l I O n s-uotf-23579 213-059-23580 TA LOGGED 213-060-23581 Wed RECEIVED_ M K BENDER BAKER PRINT DISTRIBUTION LIST NOV 0 7 2013 HUGHES AO CC COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE Yes (mandatory) WELL NAME 2F-17 and siblings RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Jesse Salyer (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) STATE Alaska PAGE (mandatory) LOG DATE: July 1,2013 TODA' 11/05/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS *OF NRIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I I 2 I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOCCC I I 1 I I titn}ten ,333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I I 1 I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I I 1 I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 0 6 0 0 TOTALS FOR ALL PAGES: 0 0 6 0 0 STATE OF ALASKA AL _.A OIL AND GAS CONSERVATION COMIVh—olON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Farforations r Perforate r Other p. Inj to Prod>30 Alter Casing r Pull Tubing r Stimulate-Frac Waiver r days r r Time Extension Change Approved Program rOperat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Development r Exploratory r 213-060-0 3.Address: 6.API Number: Stratigraphic r Service F P. O. Box 100360,Anchorage,Alaska 99510 50-029-22731-62 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25657,25666 - 2F-17L1-02 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 10784 feet Plugs(measured) None true vertical 6076 feet Junk(measured) None Effective Depth measured 10784 feet Packer(measured) 8550,8554, 8568, 8652, 8703 true vertical 6076 feet (true vertical) 5620,5622, 5631, 5689, 5727 Casing Length Size MD TVD Burst Collapse LINER L1-02 1708 2.625 10784 6076 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9172-10784 True Vertical Depth: 6068-6067 RECEIVED SEP 2 4 203 Tubing(size,grade,MD,and TVD) 3.5, L-80, 8704 MD,5728 TVD AOGCC Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER GBH-22 LOCATOR/804-0 SEAL ASSEMBLY @ 8550 MD and 5620 TVD PBR-BAKER W/10'STROKE @ 8554 MD and 5622 TVD PACKER-BAKER FA-1 PRODUCTION PACKER @ 8568 MD and 5631 TVD NIPPLE-CAMCO 2.813'X' NIPPLE @ 8652 MD and 5689 TVD PBR-BAKER W/10' STROKE @ 8703 MD and 5727 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1235 400 1190 Subsequent to operation 534 288 2951 1368 195 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development p .Service r Stratigraphic r 16.Well Status after work: Oil F , Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell Humphrey Email n1139(p conocophillips.com Printed Name Darrell R. Hum hrev Title NSK Production Engineering Specialist Signature a'c'N-J 1 w Phone:659-7535 Date 3 CL z C n � � l Form 10-404 Revised 10/2012 1/i1- IO / 5-1/ 3 Submit Original Only ic "'OAF - RBDMS OCT 11 20 2F-17L1-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/23/13 Convert to Producer(pre- produced water injector> 30 days) 1 KUP 2F-17L1-02 • ConocoPhillips Ili Well Attributes Max Angle&MD TD Inc Wellbore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Ellin(ftKB) .nvPnilups 500292273161 KUPARUK RIVER UNIT SVC 97.14 9,750.23 10,784.0 Comment H2S(ppm) Date Annotation End Date 'KR43rd(ft) Rig Release Date ••• Well Confi9:-2F-17L1-02,7131201311x19:55 AM SSSV:NIPPLE _ Last WO: 5/15/2013 2/5/1997 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,175.0 5/18/2013 Rev Reason:GLV C/O,PULL CATCHER_ haggea 7/3/2013 HANGER.28 Casing Strings Casing Description String o... String ID...Top(CKB) Set Depth(f...'Set Depth(TVD)... String Wt...String... String Top Thrd LINER L1-02 (off 2 3/8 1.992 9,075.8 10,784.0 4.70 L-80 ST-L main wellbore) Liner Details -� I Top Depth (ND) Top Intl Nomi... Top(ftKB) (RKB) (°) hem Description Comment ID(in) CONDUCTOR, 9,075.8 6,003.5 40.39 DEPLOY DEPLOYMENT SLEEVE 1.000 43-121 Perforations&Slots Shot NIPPLE.493 UF4. Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh-. Type Comment 9,174.0 10,784.0 6,066.0 6/12/2013 32.0 SLOTS SLOTTED LINER I Notes:General (! End Date Annotation 6/13/2013 NOTE:ADD LATERALS L7,L1-01,L1-02(off main wellbore) 6/13/2013 NOTE:View Schematic w/Alaska Schematic9.0 B GAS LIFT. = 3.IFT rimy I SURFACE, • 41-4,018 7>I I I GAS LIFT. 5.403 MI 1011 GAS LIFT, 6,844 11111 GAS LIFT, M{, '� 7,798 �a 111111111 GAS LIFT. 8,499 SEAL ASSV. MI IN 8.550 PBR,0,554— !i PACKER,8,568 MENIM I 1 B NIPPLE,8,652 III SEAL ASSY. In 8.704 PBR,8,704 ANCHOR. 8,717 R. Mandrel Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run PRODUCTION, N...Top(ftKB) (ftKB) C) Make Model (in) Sam Type Type (in) 39-8975 P1 ) _ (peg Run Date Com... 1 3,004.6 2,594.2 58.68 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,299.0 6262013 IPERF. 9,038-9,048 2 5,403.5 3,892.8 54.83 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.313 1,328.0 6/26/2013 3 6,844.4 4,681.2 56.64 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.188 1,316.0 6/26/2013 WHIPSTOCK, 9,082- 4 7,796.1 5,184.3 58.89 Camco KBG-2-9 1 GAS LIFT OV BTM 0.250 0.0 6/25/2013 WINDOW L1-02, ` 5 8,498.7 5,586.3 49.43 Camco KBG-2-9 1 GAS LIFT DMY -INT 0.000 0.0 5/12/2013 9.082-9,092 LINER, 8,718-9,581 SLOTS. 9,174-10,784 LINER L1-02 � o184 Ibore), ! 9.076-10.7 0.7D TD (2F-17L1472), 10,781 Bender, Makana K (DOA) From: Bender, Makana K(DOA) Sent: Tuesday, September 10, 2013 4:44 PM To: Bender, Makana K(DOA) Subject: RE: KRU 2F-17 Laterals:API Number Revisions From: Davies, Stephen F (DOA) Sent: Tuesday, September 10, 2013 1:41 PM To: Bender, Makana K(DOA); Okland, Howard D (DOA); Johnson, Elaine M (DOA) Cc: Bettis, Patricia K (DOA) Subject: KRU 2F-17 Laterals: API Number Revisions Makana: Please pull the paper files for these well branches, change the API number on any labels, and place a copy of this email string in each file. If Maria has scanned these files, please have her add a copy of this email string to each Laserfiche file. Thanks, Steve D. From: Davies, Stephen F (DOA) Sent: Tuesday, September 10, 2013 1:29 PM To: 'James.J.Ohlinger @conocophillips.com'; 'Lemke, Sandra D' Cc: Ferguson, Victoria L(DOA); Bettis, Patricia K(DOA); Okland, Howard D (DOA); Johnson, Elaine M (DOA); Bender, Makana K(DOA) Subject: FW: 2F-17 API request James, You are correct: this is a mistake made by the AOGCC as we assigned API Numbers to the Permits to Drill for Kuparuk River Unit 2F-17L1, Kuparuk River Unit 2F-17L1-01, and Kuparuk River Unit 2F-17L1-02. In conformance with AOGCC's standardized API numbering system, we will adjust the API numbers for these well branches in AOGCC's records and databases as follows: Wellbore Name Permit to Drill Number Erroneous API Number Revised API Number Kuparuk River Unit 2F-17L1 213-058-0 50-029-22731-01-00 50-029-22731-60-00 Kuparuk River un'L2F-17L1-01 213-059-0 50-029-22731-60-00 50-029-22731-61-00 Kuparuk River Unit 2F-17L1-02 213-06(57- 50-029-22731-61-00 50-029-22731-62-00 For reporting pur oses any production from,or injection into,these well branches must be assigned to the primary well Kuparuk River Unit 2F-17 (Permit to Drill Number 196-204-0;API Number 50-029-22731-00-00). I will send a follow-up email when these changes have been completed. Please call me if you have any questions or concerns. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 2 AYTALOGGED RECEIVED• fired&III M K BENDER BASER 1 INT DISTRIBUTION I.JS` UG 2 12013 HUGHES AOGCC COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2F-171L.&Siblings RUN NUMBER 2-\. " O 0 (mandatory) 2'52".4 I FIELD Kuparuk BH SALESMAN Jesse Salyer (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: May 21,2013 TODAYS DATE: 8/19/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FIN AL CD (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Of'1'NIN I S #OF COPIES #OF COPIES 4 U U U U 4 4 i 1 ConocoPhillips Alaska,Inc. I I I I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I I 1 I i I I I I Christine Mahnken 3 33 West 7th Ave,Suite IOU Anchorage,Alaska 99501 3 B 1 I 1 I 1 I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 I 4 Chevron/KRU REP [ I 1 I 1 1 1 I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT 1 I I 1 I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS -FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil o , Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 , Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. • orAband.: June 12,2013 213-060/ • _ 3.Address: 6.Date Spudded: 13.API Number: (�j'7/ P.O. Box 100360,Anchorage,AK 99510-0360 June 10,2013 50-029-22731• • sb 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: f' Surface: 128'FNL, 1738'FEL,Sec.33,T11N,R9E, UM June 11,2013 2F-17L1-02 . '- it.- 3 Top of Productive Horizon: 8. KB(ft above MSL): 129'RKB 15.Field/Pool(s): 1415'FNL, 1883'FWL,Sec.4,T1ON, RO9E, UM GL(ft above MSL): 93'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2378'FNL, 1840'FWL,Sec.4,T1ON, R9E, UM 10784'MD/6076'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-517494 y- 5948755 Zone-4 10784'MD/6076'TVD ' ADL 25657,25666 TPI: x-515866 y- 5942185 Zone-4 • 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-515829 y- 5941222 Zone-4 nipple @ 506'MD/506'TVD 2583,2587 18.Directional Survey: Yes 0 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) 1650'MD/1610'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 9546'MD/6088'ND • 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 43' 121' 43' 121' 24" 260 sx AS I 7.625" 29.7# L-80 41' 4018' 41' 3136' 9.875" 251 sx ASLW,530 sx Class G,65 sx AS I 5.5" 15.5# L-80 39' 8975' 39' 5930' 6.75" 120 sx Dlass G 3,5" 9.2# L-80 8718' 9561' 5738' 6396' 4.75" 114 sx Class G 2.375" 4.6# L-80 9075' 10784' 6006' 6076' 3" slotted liner 24.Open to production or injection? Yes 0 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8563' 8568'MD/5632'ND, slotted liner 9075'-10784'MD 6006-6076'ND 8718'MD/5738'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ''..#114.61/0N, I Was hydraulic fracturing used during completion? Yes❑ No 0 N aa1 � ��f!' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED :-. rya ., E G na A..,'..� =:.� JUL_ 15 2013 27. >��OGG PRODUCTION TEST Date First Production et od of Operation(Flowing,gas lift,etc.) waiting on facility hook-up/pre-produced injector 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 ig Sidewall Cores Acquired? Yes ❑ No isi 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 y RBDMS JUL 26 2013:/4 Form 10-407 Revised 10/2012 1/'r--- CONTINUED ON REVERSE Submit original only /3. 1 13 ,\‘', .7 G 29. GEOLOGIC MARKERS(List all formations and mt,....,.s encountered): 30. FORMATION TESTS NAME MD TVD Well tested? 0 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 1650' 1610' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A4 9546' 6088' Base A5/A4(inverted) 9640' 6080' Base AS/A4(inverted) 9812' 6060' Kuparuk A5 10784' 6076' N/A Formation at total depth: Kuparuk A5 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Burke @ 265-6097 Email: Ja 11.B .cop.com Printed Name Lamar Gantt Title: CT Drilling Supervisor / Signature Raftktu1/4,71C ,jZ� Phone 263-4021 Date 1/ /`3 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 r 1 KUP 2F-17L1-02 ConocoPhillips Well Attributes Max Angle&MD TO Alaska ifs Wel!bore API/UWI / Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) i�, <,+1.I� 5002922731 „..7�KUPARUK RIVER UNIT INJ 10,784.0 Comment tbj I" H2 ppm) Date Annotation End Date_ KB-Grd(ft) Rig Release Date VVelI • -2F-17L1.02 6/13/2013e:31:31 AM SSSV:NIPPLE .411 f Last WO: 5/152013 2/5/1997 - aec-ActwI Annotation De.h(ft =I End Date Annotation Last Mod...End Date Last Tag:SLM 9,175.0 5/182013 Rev Reason:ADD LATERALS L1,L1-01,L1-02 osborl 6/13/2013 HANGER.28 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER L1-02 (off 23/8 1.992 9,075.8 10,784.0 4.70 L-80 ST-L �r main wellbore) 5 Liner Details Top Depth - (TVD) Top Inci Nomi-.. Top(ftKB) (ftKB) (°) Item Description Comment ID(in) CONDUCTOR 9,075.8 DEPLOY DEPLOYMENT SLEEVE 1.000 43-121 114 Perforations&Slots Shot NIPPLE.493 II_ Top(ND) Btm(TVD) Dens 1111.,_ Top(ftKB)Btm(ftKB( (MB) (ftKB_) Zone Date Oh— Type Comment 9,174.0 10,784.0 6/12/2013 32.0 SLOTS SLOTTED LINER Notes:General&Safety End Date Annotation 6/132013 NOTE:ADD LATERALS L1,L1-01,L1-02(off main wellbore) 6/132013 NOTE:View Schematic w/Alaska Schematic9.0 GASL3.IFT005_ - y lir I SURFACE, -J l 41-4,018 GAS LIFT, 5,403 liti GAS LIFT 6 844 II GAS LIFT I • 7756 GAS LIFT,_ I 8.499 SEAL ASSY. 5550 -- P88,8,554--_-- -_ I PACKER,8.568 --- MI IIIII NIPPLE,8.652--- SEAL ASSY. 8,704" PER,8,704 ANCHOR. 8,717 ■ Mandrel Details Top Depth Top Port ■ S--- (TVD) Intl OD Valve Latch Size TRO Run PRODUCTION, N...Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 3943,975 1 3,004.6 2,594.3 58.73 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 5/9/2013 IPERE. 90389.018 2 5,403.5 3,892.8 54.83 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 5/9/2013 3 6,844.4 4,681.2 56.64 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 5/9/2013 WHIPSTOCK, 9,082 4 7,796.1 5,184.3 59.00 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 5/9/2013 WINDOW II L1.02, ' 5 8,498.7 5,586.3 49.51 Camco KBG-2-9 1 GAS LIFT SOV INT 0.000 0.0 5/9/2013 9,082-9,092 LINER, 8,718-9.561 SLOTS, 9,174-10,784 LINER L1-02 (oil main wellborn),\\ 9076-10.784 TD ( II 2F-17L1.02), 10,784 ill Pre-Rig Well Work Summary DATE SUMMARY 5/12/2013 GAUGED TBG TO 2.85"TO 8504'SLM (UNABLE TO PASS), REPLACED SOV @ 8498' RKB WITH DV. MIT IA TO 2500 PSI (PASSED). ATTEMPTED TO EQUALIZE XX PLUG @ 8652' RKB WITH NO SUCCESS. IN PROGRESS. 5/13/2013 PULLED 2.81"XX PLUG @ 8652' RKB; BAILED MUD OFF IBP @ 8740' RKB. IN PROGRESS. 5/15/2013 BAILED MUD OFF IBP @ 8740' RKB. ATTEMPTED PULL IBP. IN PROGRESS. 5/16/2013 BAILED MUD/CaCO3 OFF IBP @ 8740' RKB. ATTEMPTED PULL IBP, NO SUCCESS. RESUMED BAILING, LOST 16'. READY FOR CTU. 5/17/2013 RUN#1:PERFORM FCO TO 8722' CTMD, RUN#2: LATCHED INTO IBP FISHNECK AT 8722'CTMD, 5K OVERPULL AND THE IBP CAME FREE AND RECOVERED AT SURFACE, F/P TBG, JOB IN 5/18/2013 PERFORMED FCO WITH DIESEL/GEL TO 9350'CTMD, MUD WITH LIGHT TRACES OF FORMATION SAND RETURNS, SWEPT THE HOLE WITH 20 BBLS GEL, READY FOR S/L DRIFT, 5/18/2013 TAGGED @ 9175'SLM. DRIFTED TBG w/2.63" DUMMY WHIPSTOCK TO 9175' SLM. READY FOR 5/19/2013 (PRE CTD): TREE TEST-MV, SSV, SV DDT PASSED, MV, SSV, SV PT PASSED. 5/19/2013 RAN 24-ARM MIT FROM 9200'TO 8600' TO INSPECT PIPE INTEGRITY FOR WHIPSTOCK, 30 MIN STATIC PRESSURE READING @ 9100', PRESSURE &TEMPERATURE @ 9100': 3940 PSI & 125 DEG F, 15 MIN STATIC PRESSURE READING @ 8964', PRESSURE &TEMPERATURE @ 8964': 3885 PSI & 143 DEG F. ASSISTED VALVE CREW WITH SETTING BPV. JOB COMPLETED. • Conoco P hillips Time Log & Summary We//view Web Reporting Report Well Name: 2F-17 Rig Name: NABORS CDR2-AC Job Type: DRILLING SID Rig Accept: 5/20/2013 7:00:00 AM Rig Release: 6/13/2013 5:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/19/2013 24 hr Summary Move rig over and spot subs on well 2F-17 21:00 00:00 3.00 MIRU MOVE MOB P Trucks on location PJSM. 05/20/2013 Move rig to next well and spot subs in. R/U. Fill pits with drilling fluid and KWF. Start BOPE test. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Move subs off of well 02:00 05:00 3.00 0 0 MIRU MOVE MOB P Clean up around previous well. Prep well 17 for rig. Spot subs over well. 05:00 07:00 2.00 0 0 MIRU MOVE MOB P Rig up 07:00 09:00 2.00 0 0 MIRU WHDBO NUND P Continue rig up,Accept rig @ 07:00. fill stack. 09:00 19:00 10.00 0 0 MIRU WHDBO BOPE P Start BOP test. C#9, pac-off, and annular failed test. 19:00 00:00 5.00 0 MIRU WHDBO BOPE T Conduct PJSM-Replace pac-off element and retest. 35/21/2013 Complete BOPE test repairs, Pull BPV, RIS and set whipstock TOWS=-9082. M/U Window milling BHA, RIH and start milling window 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE T Conduct PJSM-replace annular element and retest C#9 and annular. XXX Total BOP testing time 18 hrs XXX XXX 6 hrs billable Maintenance hours XX 01:00 03:00 2.00 0 0 MIRU WHDBO BOPE P Replace o-rings and test PDL's 03:00 03:30 0.50 0 0 MIRU WHDBO BOPE P PJSM-load FMC lubricator. 03:30 04:30 1.00 0 0 MIRU WHDBO BOPE P R/U and P/T lubricator 04:30 06:30 2.00 0 0 MIRU WHDBO BOPE T Attempting to pull BPV.Thought it might be hydrates but found that the SSV had stroked a little to the closed postion. Pressured up to actuate it fully open and pulled BPV. 1600psi will head pressure. 06:30 06:45 0.25 0 0 MIRU WHDBO BOPE P Install BHI check valves 06:45 06:45 0.01 0 0 SLOT WELLPF CIRC P 06:45 09:29 2.74 0 0 PROD1 WHPST PULD P PJSM-M/U WS and deploy BHA#1 without pressure management. 09:29 12:29 3.00 0 8,935 PROD1 WHPST TRIP P RIH with WS pumping min rate. 12:29 12:44 0.25 8,935 8,992 PROD1 WHPST DLOG P Tie into the K1 correction of-25.5ft. 12:44 12:59 0.25 8,992 8,760 PROD1 WHPST CIRC P PUH PUW 35k Page 1 of 16 ConocoPhillips Time Log & Summary WeUview Web Reporting Report Well Name: 2F-17 Rig Name: NABORS CDR2-AC Job Type: DRILLING SID= Rig Accept: 5/20/2013 7:00:00 AM Rig Release: 6/13/2013 5:00:00 AM Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 35/19/2013 24 hr Summary Move rig over and spot subs on well 2F-17 21:00 00:00 3.00 MIRU MOVE MOB P Trucks on location PJSM. 35/20/2013 Move rig to next well and spot subs in. R/U. Fill pits with drilling fluid and KWF. Start BOPE test. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Move subs off of well 02:00 05:00 3.00 0 0 MIRU MOVE MOB P Clean up around previous well. Prep well 17 for rig. Spot subs over well. 05:00 07:00 2.00 0 0 MIRU MOVE MOB P Rig up 07:00 09:00 2.00 0 0 MIRU WHDBO NUND P Continue rig up,Accept rig @ 07:00. fill stack. 09:00 19:00 10.00 0 0 MIRU WHDBO BOPE P Start BOP test. C#9, pac-off, and annular failed test. 19:00 00:00 5.00 0 MIRU WHDBO BOPE T Conduct PJSM-Replace pac-off element and retest. 05/21/2013 Complete BOPE test repairs, Pull BPV, RIS and set whipstock TOWS=-9082. M/U Window milling BHA, RIH and start milling window 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE T Conduct PJSM-replace annular element and retest C#9 and annular. XXX Total BOP testing time 18 hrs XXX XXX 6 hrs billable Maintenance hours XX 01:00 03:00 2.00 0 0 MIRU WHDBO BOPE P Replace o-rings and test PDL's 03:00 03:30 0.50 0 0 MIRU WHDBO BOPE P PJSM-load FMC lubricator. 03:30 04:30 1.00 0 0 MIRU WHDBO BOPE P R/U and PIT lubricator 04:30 06:30 2.00 0 0 MIRU WHDBO BOPE T Attempting to pull BPV.Thought it might be hydrates but found that the SSV had stroked a little to the closed postion. Pressured up to actuate it fully open and pulled BPV. 1600psi will head pressure. 06:30 06:45 0.25 0 0 MIRU WHDBO BOPE P Install BHI check valves 06:45 06:45 0.01 0 0 SLOT WELLPF CIRC P 06:45 09:29 2.74 0 0 PROD1 WHPST PULD P PJSM-M/U WS and deploy BHA#1 without pressure management. 09:29 12:29 3.00 0 8,935 PROD1 WHPST TRIP P RIH with WS pumping min rate. 12:29 12:44 0.25 8,935 8,992 PROD1 WHPST DLOG P Tie into the K1 correction of-25.5ft. 12:44 12:59 0.25 8,992 8,760 PROD1 WHPST CIRC P PUH PUW 35k Page 1of16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:59 13:26 0.45 8,760 9,760 PROD1 WHPST DLOG P Log CCL 13:26 13:44 0.30 9,760 9,093 PROD1 WHPST TRIP P PUH to set depth 13:44 13:59 0.25 9,093 9,093 PROD1 WHPST TRIP P Close EDC, Pick up to neutral weight. 13:59 14:05 0.10 9,093 9,093 PROD1 WHPST TRIP P Set TOWS at 9082' 15°LOHS, Stack 5k down 14:05 14:59 0.90 9,093 9,050 PROD1 WHPST CIRC P PUH to 9000', start displacing well to 9.8ppg powervis. 14:59 18:11 3.20 9,050 65 PROD1 WHPST TRIP P Trip out of well 18:11 19:17 1.10 65 0 PROD1 WHPST PULD P PJSM, PUD BHA#1 whipstock setting BHA 19:17 20:05 0.80 0 66 PROD1 WHPST PULD P PD BHA#2,Window milling BHA W/ 2.74 window mill and 2.74 string reamer on straight motor 20:05 22:11 2.10 66 8,940 PROD1 WHPST TRIP P Trip in well EDC Open 22:11 22:29 0.30 8,940 8,984 PROD1 WHPST DLOG P Tie into K1 for-24.5', Shut EDC, PUW=32K 22:29 22:41 0.20 8,984 9,082 PROD1 WHPST TRIP P Trip in to mill window,dry tag @ 9082.25, PUW=33K off Whipstock 22:41 23:17 0.60 9,082 9,082 PROD1 WHPST MILL P Pumps online @ 1.5 BPM @ 3560 PSI FS, BHP=3895,WHP=320PSI Call pinch point @ 9082.16, Mill window per procedure 23:17 23:47 0.50 9,082 9,082 PROD1 WHPST DLOG P Counter seems to have stopped, PUH to confirm depth,Tie in for+.3, RBIH to mill window 23:47 23:59 0.20 9,082 9,083 PROD1 WHPST MILL P Milling, 1.5 BPM @ 3560 PSI FS, WHP=290 PSI, BHP=3900 05/22/2013 Complete window, M/U build section BHA. Drill to 9168,Trip out for low build rate 00:00 08:15 8.25 9,083 9,092 PROD1 WHPST MILL P Continue milling window per procedure 08:15 10:30 2.25 9,092 9,103 PROD1 WHPST MILL P Mills are out of the window. Start drilling ahead,TD'd rat hole at 9103'. 10:30 12:00 1.50 9,103 9,078 PROD1 WHPST REAM P Perform 4 reaming passes across window area. 12:00 14:00 2.00 9,078 0 PROD1 WHPST TRIP P Trip out of hole for drilling BHA. 14:00 15:15 1.25 0 0 PROD1 WHPST PULD P PJSM-Undeploy milling BHA. Pumping 844psi on MP ---Mill 2.73"go ---String Reamer 2.74"go 15:15 17:21 2.10 0 62 PROD1 DRILL PULD P PJSM-M/U and deploy drilling bha. 17:21 19:27 2.10 62 8,950 PROD1 DRILL TRIP P RIH, EDC open 19:27 19:39 0.20 8,950 8,963 PROD1 DRILL DLOG P Log K1 fot tie in, +25'correction, Close EDC, PUW=32K 19:39 19:51 0.20 8,963 9,103 PROD1 DRILL TRIP P Trip in to drill,clean pass through window,tagged up @ 9103', 19:51 23:15 3.40 9,103 9,168 PROD1 DRILL DRLG P Tagged up @ 9103', 1.47 BPM @ 3800PS1 FS,WHP=330, BHP=3970 23:15 00:00 0.75 9,168 8,170 PROD1 DRILL TRIP T Current BHA config(1.9°AKO W/2.74 X 3.25"Bi Center)giving 22° DLS vs. planned 27°DLS would result in landing-17'low of plan.Trip out to dial up motor Page 2 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/23/2013 24 hr Summary Complete build section to 9265,tied in RA marker @ 9089',TOWS=9082, BOW=9265, Drill lateral to 9615' Lost 66 BBIs last 24 Hrs 00:00 02:00 2.00 8,170 46 PROD1 DRILL TRIP T Continue trip out of well to dial up AKO on motor 02:00 03:00 1.00 46 0 PROD1 DRILL PULD T At surface, PJSM to PUD BHA#3 03:00 04:18 1.30 0 62 PROD1 DRILL PULD T PJSM, PD BHA#4, Build section with 2.6°Motor and re run 2.74 X 3.25 Bi Center bit, M/U to coil and surface test 04:18 06:33 2.25 62 8,960 PROD1 DRILL TRIP T Trip in with BHA#4, EDC closed 06:33 06:48 0.25 8,960 8,985 PROD1 DRILL DLOG T Tie into the K1 correction of-26.5'. 06:48 07:03 0.25 8,985 9,168 PROD1 DRILL TRIP T Continue to bottom. RIW 17k 07:03 08:48 1.75 9,168 9,265 PROD1 DRILL DRLG P BOBD-1.52 bpm at 3938psi, BHP 4009,WHP 284, CSW 15k, IA 636, OA 301 08:48 11:18 2.50 9,265 62 PROD1 DRILL TRIP P TD build section 9265'. POOH PUW 33k 11:18 12:48 1.50 62 0 PROD1 DRILL PULD P PJSM-Undeploy bha. 12:48 14:48 2.00 0 72 PROD1 DRILL PULD P PJSM-M/U lateral bha and deploy 14:48 17:18 2.50 72 8,950 PROD1 DRILL TRIP P RIH BHA#5 L1 lateral section bha with a 2.74"x 3.25"bi-center bit. • 17:18 17:33 0.25 8,950 8,996 PROD1 DRILL DLOG P Tie into the K1 minus 25.5'. , log RA @ 9089',TOW @ 9082, BOW=9087.4 17:33 18:33 1.00 8,996 9,265 PROD1 DRILL TRIP P Continue in hole RIW 15k 18:33 20:21 1.80 9,265 9,425 PROD1 DRILL DRLG P OBD-1.35bpm at 3839psi, BHP 4036,WHP 275, IA 491, OA 298, New mud @ bit 18:05 @ 9265' 20:21 21:15 0.90 9,425 9,425 PROD1 DRILL WPRT P Wiper trip with MADD pass 9275 to 9100, PUW=32K 21:15 22:57 1.70 9,425 9,575 PROD1 DRILL DRLG P 9425', Drill ahead, 1.36 BPM @ 3940 PSI FS, BHP=4040 22:57 23:21 0.40 9,575 9,575 PROD1 DRILL WPRT P Wiper to window, PUW=32K 23:21 00:00 0.65 9,575 9,615 PROD1 DRILL DRLG P 9575', Drill ahead, 1.36 BPM @ 4020PSI FS, BHP=4045,WHP=200 05/24/2013 Drilled 9615 to 10,243, Lost 66 BBLs MNight to MNight 00:00 02:36 2.60 9,615 9,725 PROD1 DRILL DRLG P Drill ahead from 9615, 1.36 BPM @ 4020PS1 FS, BHP=4050 02:36 03:30 0.90 9,725 9,725 PROD1 DRILL WPRT P Wiper trip with tie in for 0'correction, PUW=33K 03:30 07:36 4.10 9,725 9,875 PROD1 DRILL DRLG P 9725', Drill ahead, 1.35 BPM @ 4080 PSI FS, BHP=4052,WHP=161 07:36 08:00 0.41 9,875 9,120 PROD1 DRILL WPRT P Wiper up hole. 36k PUW 08:00 08:25 0.43 9,120 9,875 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 08:25 09:25 1.00 9,875 9,908 PROD1 DRILL DRLG P BOBD-1.34bpm at 3992psi, BHP 4075,WHP 184, IA 705,OA 302 09:25 09:40 0.25 9,908 9,768 PROD1 DRILL WPRT P Perform Geo wiper. 09:40 09:55 0.25 9,768 9,908 PROD1 DRILL WPRT P Wiper back to bottom. RIW 15k Page 3 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:55 13:25 3.50 9,908 10,025 PROD1 DRILL DRLG P BOBD-1.36bpm at 3979psi. BHP 4058,WHP 184, IA 760, OA 302 13:25 13:55 0.50 10,025 9,295 PROD1 DRILL WPRT P Wiper Up Hole. PUW 36K Bleed IA from 807psi to 400psi. 13:55 14:25 0.50 9,295 10,025 PROD1 DRILL WPRT P Pressure Survey at 9300'MD 1.35bpm-WHP 115 Annular pressure 4010 1.40bpm-WHP 95 Annular pressure 4010 Wiper back in hole. 14:25 18:07 3.70 10,025 10,175 PROD1 DRILL DRLG P BOBD-1.39bpm at4065psi, BHP 4030,WHP 104, IA 411, OA 304 18:07 20:25 2.30 10,175 10,175 PROD1 DRILL WPRT P Wiper to window with tie in for-1' correction, PUW=39K 20:25 23:58 3.56 10,175 10,243 PROD1 DRILL DRLG P 10175', Drill Ahead, 1.35 BPM @ 4100 PSI FS, BHP=4056,WHP=130 35/25/2013 Drilled 10243 to 10929, Lost 68 BBLs MNight to MNight 00:00 08:00 8.00 10,243 10,325 PROD1 DRILL DRLG P Drilling ahead, 1.35 BPM @ 4100 PSI FS, BHP=4075,WHP=138 10276'looks like we broke out of the ankerite. 08:00 08:30 0.50 10,325 9,290 PROD1 DRILL WPRT P Wiper up hole. PUW 36k 08:30 09:00 0.50 9,290 10,325 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 09:00 11:00 2.00 10,325 10,475 PROD1 DRILL DRLG P BOBD-1.35bpm at 4130psi, BHP 4032,WHP 146, IA 563, OA 312 11:00 11:45 0.75 10,475 9,300 PROD1 DRILL WPRT P Wiper up hole. PUW 36 11:45 12:21 0.60 9,300 10,475 PROD1 DRILL WPRT P Wiper back in hole. RIW 14.5k 12:21 14:06 1.75 10,475 10,624 PROD1 DRILL DRLG P BOBD-1.36bpm at 4232psi. BHP 4099,WHP 108, IA 587,OA 312 14:06 15:00 0.90 10,624 9,115 PROD1 DRILL WPRT P Wiper up hole. PUW 37k 15:00 15:46 0.78 9,115 10,624 PROD1 DRILL WPRT P Wiper back in hole. RIW 15:46 17:31 1.75 10,624 10,775 PROD1 DRILL DRLG P BOBD-1.34bpm at 4,258 psi BHP 4111.0 WHP 111 IA:576 OA: 308 17:31 19:25 1.90 10,775 10,775 PROD1 DRILL WPRT P Wiper up hole. PUW=36K, Up to 9315 to get bottoms up 19:25 22:13 2.80 10,775 10,925 PROD1 DRILL DRLG P 10775', Drill Ahead 1.34 BPM @ 4220 PSI FS, BHP=4155 22:13 23:55 1.70 10,925 10,925 PROD1 DRILL WPRT P 10925', Wiper to 9270', PUW=36K, Start New Mud down coil while RIH 23:55 23:59 0.07 10,925 10,929 PROD1 DRILL DRLG P 10925', Drill Ahead, 1.35 BPM @4270 PSI FS,WHP=100, BHP=4170 10929 Midnight depth 05/26/2013 Drilled 10929 to 11538, Lost 88 BBLs MNight to Mnight 00:00 07:15 7.25 10,929 11,075 PROD1 DRILL DRLG P Drilling ahead 1.35 BPM @ 4270 PSI FS, BHP=4170, New mud coming out of bit @ 10,929',@ 00:12:32 Hrs 07:15 08:00 0.75 11,075 9,115 PROD1 DRILL WPRT P Wiper up hole. PUW 36K 08:00 08:15 0.25 9,115 9,138 PROD1 DRILL DLOG P Tie into RA marker correction of- 4.5'. 08:15 09:00 0.75 9,138 11,075 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k Page 4 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 13:00 4.00 11,075 11,225 PROD1 DRILL DRLG P BOBD-1.38bpm at 4150psi. BHP 4075,WHP 222, IA 529, OA 310 13:00 13:35 0.59 11,225 10,000 PROD1 DRILL WPRT P Wiper up hole. PUW 36k 13:35 14:05 0.50 10,000 11,225 PROD1 DRILL WPRT P Wiper back in the hole. RIW 14k 14:05 16:35 2.50 11,225 11,375 PROD1 DRILL DRLG P BOBD-1.37bpm at 4148psi, BHP 4187,WHP 162, IA 588, OA 312 16:35 17:20 0.75 11,375 10,100 PROD1 DRILL WPRT P Wiper up hole. PUW 36k 17:20 17:50 0.50 10,100 11,375 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 17:50 21:14 3.40 11,375 11,525 PROD1 DRILL DRLG P BOBD-1.37bpm @ 4000 PSI FS, BHP=4185 21:14 23:38 2.40 11,525 11,525 PROD1 DRILL WPRT P Wiper to window with tie in for-3' correction, PUW=35K 23:38 23:59 0.36 11,525 11,538 PROD1 DRILL DRLG P 11523, Drill Ahead, 1.36BPM @ 4240 PSI FS, BHP=4195,WHP=90, RIW=12K 05/27/2013 Drilled 11538 to 12318', Lost 70bbls of 10.0ppg flo-pro. Performed mud swap at 12225'with 9.8ppg PowerPro 20:30. Mud System 2 drilled 1283'with.7%DS 00:00 01:36 1.60 11,538 11,675 PROD1 DRILL DRLG P Drill ahead from 11538, 1.35 BPM @ 4150PSI FS, BHP=4180 01:36 03:18 1.70 11,675 11,675 PROD1 DRILL WPRT P Wiper trip to 10875, PUW=34.5K 03:18 06:18 3.00 11,675 11,825 PROD1 DRILL DRLG P 11675', Drill Ahead, 1.36 BPM @ 4150PS1 FS, BHP=4231WHP=150, RIW=14.3K 06:18 06:52 0.58 11,825 10,500 PROD1 DRILL WPRT P Wiper up hole. PUW 35 06:52 07:22 0.50 10,500 11,825 PROD1 DRILL WPRT P Wiper back in hole. RIW 13 07:22 08:52 1.50 11,825 11,975 PROD1 DRILL DRLG P BOBD-1.36bpm at 4233psi. BHP 4209,WHP 94, IA 631, OA 313 08:52 10:10 1.30 11,975 9,115 PROD1 DRILL WPRT P Wiper on hole. PUW 36 10:10 10:25 0.25 9,115 9,133 PROD1 DRILL DLOG P Tie into the RA marker correction of- 3'. 10:25 11:25 1.00 9,133 11,975 PROD1 DRILL WPRT P Wiper back in hole. RIW 15k 11:25 12:32 1.13 11,975 12,055 PROD1 DRILL DRLG P BOBD-1.37bpm at 4144psi. BHP 4227,WHP 117, IA 651, OA 313 12:32 14:32 2.00 12,055 9,300 PROD1 DRILL WPRT P 12055', 120fph, stall motor, PUW 45k, losing 0.3bpm losses.Talk to town and decide to PUH to 9300'to perform a pressure survey. 14:32 14:47 0.25 9,300 9,320 PROD1 DRILL WPRT P 9300'Conduct pressure survey- 1.37bpm,WHP 107, BHP 4010 14:47 15:47 1.00 9,320 12,055 PROD1 DRILL WPRT P Wiper back in hole. RIW 14.5K still losing 0.3bpm 15:47 19:02 3.25 12,055 12,215 PROD1 DRILL DRLG P BOBD- 1.37bpm at 4133. BHP 4208,WHP 92, IA 644, OA 315 19:02 19:47 0.75 12,215 10,495 PROD1 DRILL WPRT P Wiper out of hole. PUW 35k 19:47 20:38 0.85 10,495 12,215 PROD1 DRILL WPRT P Wiper back in hole. RIW 10k, Start mud swap 20:38 21:44 1.10 12,215 12,293 PROD1 DRILL DRLG P BOBD-1.37bpm at 394psi. BHP 4239,WHP 100, IA 661, OA 316. XX New Mud at the bit 12225'XX,@ 20:50 Page 5 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:44 22:38 0.90 12,293 12,293 PROD1 DRILL DRLG P New mud(9.8 PPG power pro)all around, Cann't keep it drilling, perform mini wiper and will not go back to bottom 22:38 23:02 0.40 12,293 12,318 PROD1 DRILL DRLG P Got drilling 1.38 BPM @ 3800PSI FS, BHP=4281, RIW=7K 23:02 23:58 0.94 12,318 12,346 PROD1 DRILL DRLG P Lost weight transfer.Cannot drill ahead, Pump 10-10 sweeps. Drilled normally as sweeps come out and around BHA 05/28/2013 Drilled L1 lateral from 12,236'to 12,670',diffculty drilling most of the day, pockets of ankerite. 00:00 00:12 0.20 12,346 12,347 PROD1 DRILL DRLG P Drilling Contined, Ran out of sweep and drilling stopped. No weight transfer 00:12 01:42 1.50 12,347 9,300 PROD1 DRILL WPRT P Perform wiper to window with tie, Add lubes to mud, Increased lubes from 2%to 4%. Kla Stop from 1.5 to 2.5% 01:42 02:06 0.40 9,300 9,115 PROD1 DRILL WPRT P Perform PSI/Choke experiment, 1.4 BPM drilling rate, BHP=4012, WHP=205 @ 5FPM 02:06 02:18 0.20 9,115 9,129 PROD1 DRILL DLOG P Tie into RA for-3'correction 02:18 03:42 1.40 9,129 12,347 PROD1 DRILL WPRT P Wiper back in hole to drill, RIW=13K 03:42 05:24 1.70 12,347 12,357 PROD1 DRILL DRLG P 12344', Drill ahead, 1.36 BPM @ 3980PS1 FS, BHP=4270, 05:24 05:54 0.50 12,357 12,355 PROD1 DRILL DRLG P BHA Wiper with 10/10 sweep see if we can get drilling, Gained 6K surface weight with pill coming out and maitaind drilling untill pill halfway up annulas 05:54 09:24 3.50 12,357 12,374 PROD1 DRILL DRLG P Lost WOB and motor work, P/U, PUW=37K, 09:24 10:24 1.00 12,374 12,445 PROD1 DRILL DRLG P Drilling break after stall, ROP=75FPH, 1.34 BPM @ 3960 PSI FS, BHP=4270 10:24 11:30 1.10 12,445 12,511 PROD1 DRILL DRLG P Stacking out P/U and BHA Wiper, PUW=38K 11:30 14:18 2.80 12,511 12,511 PROD1 DRILL WPRT P Wiper trip to 9300' 14:18 19:24 5.10 12,511 12,522 PROD1 DRILL DRLG P 12511', Drill Ahead, 1.39 BPM @ 4070PS1 FS, BHP=4280,WHP=250, diffculty drilling, BHA wiper,pump 10/10 sweep, continue to be diffcult drilling, made several BHA wipers, another 10/10 sweep,ankerite? 19:24 22:09 2.75 12,522 12,665 PROD1 DRILL DRLG P Continue drilling ahead, had some initial losses @ 12,522', but healed itself,change incline to 90 degrees, better drilling. 1.35 BPM @ 4100 PSI, BHP=4302 PSI,WHP=245, ROP=50-70. 22:09 23:51 1.70 12,665 12,665 PROD1 DRILL WPRT P Wiper trip, PUW=35K. 23:51 00:00 0.15 12,665 12,670 PROD1 DRILL DRLG P 12,665', Drill Ahead, 1.40 BPM @ 4028 PSI, BHP=4290,WHP=240, ROP=50. Page 6 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/29/2013 24 hr Summary POOH for agitator. PUD BHA#5,function test BOPE, injector maintenance. PD BHA#6 agitator assembly. Drill ahead from 12,739'to 13,190'. 00:00 02:30 2.50 12,670 12,744 PROD1 DRILL DRLG P Continue drilling ahead, 1.40 BPM @ 4018 PSI, BHP=4295,WHP=228, ROP=50. ROP slowed to 20, decision made to POOH for agitator. 02:30 06:24 3.90 12,744 75 PROD1 DRILL TRIP P POOH for agitator. 06:24 07:48 1.40 75 0 PROD1 DRILL PULD P PSJM,At surface, Check Stripper, PUD BHA#5, Lay down BHA#5 07:48 09:18 1.50 0 0 PROD1 DRILL SVRG P Function test BOPE, Service top drive, injector, and reel,check injector accumulators,Check Koomy accumulators 09:18 10:18 1.00 0 78 PROD1 DRILL PULD P M/U BHA#6, .5°AKO motor and new Hycalog razor 2.7 X 3"bi-center, PD BHA, M/U to injector and service test. 10:18 12:48 2.50 78 9,000 PROD1 DRILL TRIP P RIH with EDC open, at 500'open EDC, Pump 1.36 BPM 4387 CT Circ pressure,WHP=850, Diff Press=847PSI, LSRV=48K, Open EDC and continue in well 12:48 12:54 0.10 9,000 8,975 PROD1 DRILL TRIP P Stop and shut EDC, Tie in for-25.5', PUW=31K, Perform pump test LSRV=39K, 1.36 BPM @ 4100, Diff press=816,WHP=220, BHP=3870 12:54 14:24 1.50 8,975 12,744 PROD1 DRILL TRIP P Trip into drill 14:24 16:18 1.90 12,744 12,890 PROD1 DRILL DRLG P 12739',touch down early and stall, PUW=36K, Pumps back on @ 1.38 BPM @ 4030PSI FS, BHP=4290, WHP=243, Diff=793 16:18 18:03 1.75 12,890 12,890 PROD1 DRILL WPRT P Wiper trip to 11,700, PUW=34K, 12550 to 12650 stacking observed RIH, Reduce pump to 1 BPM 18:03 19:30 1.46 12,890 13,040 PROD1 DRILL DRLG P 12890', Drill Ahead 1.33 BPM @ 4140 PSI FS, BHP=4330 PSI, WHP=242, ROP=70-80 19:30 21:33 2.05 13,040 13,040 PROD1 DRILL WPRT P Wiper trip to 11,000', PUW=35K 21:33 23:59 2.44 13,040 13,190 PROD1 DRILL DRLG P 13,040', Drill Ahead 1.36 BPM @ 4555 PSI FS, BHP=4318 PSI, WHP=242, ROP=70-80, GEO target 101 degrees. 05/30/2013 Drill ahead to called L1 TD @ 13,375',wiper trip to swab. RBIH to TD, POOH laying in 12.95 ppg liner pill, paint EOP flags @ 10,700'and 6,600',continue OOH. 00:00 05:09 5.16 13,190 13,190 PROD1 DRILL WPRT P Wiper trip for tie-in @ 9,115', PUW=35K. Log RA marker, had depth issues, log RA again for-51' correction,check counter head, excess grease on wheels,correct problem, log RA for 0'correction. RBIH. Page 7of16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:09 07:21 2.20 13,190 13,289 PROD1 DRILL DRLG P 13,190', Drill Ahead 1.28 BPM @ 4310 PSI FS, BHP=4326 PSI, WHP=248, ROP=60,GEO target 101 degrees. 07:21 08:45 1.40 13,289 13,355 PROD1 DRILL DRLG P Drilling break, ROP Up, Fluid tossed .5 BPM. P/U PUW=34K off bottom, RBIH and drill monitoring losses, Pump sweeps to try and heal losses 08:45 08:51 0.10 13,355 13,375 PROD1 DRILL DRLG P Drill to TD @ 13375, Sweeps coming out, Pull long wiper, PUW=36K 08:51 13:15 4.40 13,375 115 PROD1 DRILL WPRT P Tag swab,check counter 13:15 14:51 1.60 115 7,505 PROD1 DRILL WPRT P RBIH, EDC open 14:51 15:45 0.90 7,505 7,505 PROD1 DRILL WPRT T Gooseneck counter seized up, Replace counter assembly 15:45 16:09 0.40 7,505 8,965 PROD1 DRILL WPRT P Continue in hole 16:09 16:21 0.20 8,965 8,974 PROD1 DRILL DLOG P Log K1 for-16', PUW=31K, Shut EDC 16:21 19:57 3.60 8,974 13,150 PROD1 DRILL TRIP P Continue in well,close EDC,wait on pill. 19:57 23:59 4.04 13,150 3,438 PROD1 DRILL TRIP P POOH laying in liner pill,paint EOP flags @ 10,700'&6,600',continue OOH. 05/31/2013 Continue laying in 12.95 ppg liner pill, LD BHA#6. PU/MU 74 joint slotted liner assembly, RIH with liner assembly,set down @ 11,480', had to work liner in hole to hard bottom @ 13,029',top of liner 10,710'. Circulate out remaining 12.95 liner pill with 9.8 used Power Pro. POOH. PUD BHA#7, PD BHA#8,start in hole with OH anchored billet, in progress. 00:00 01:30 1.50 3,438 65 PROD1 DRILL TRIP P Continue OOH laying in liner pill,on surface. 01:30 02:00 0.50 65 65 PROD1 DRILL OWFF P Monitor well for flow, PJSM. 02:00 03:00 1.00 65 0 PROD1 DRILL PULD P LD BHA#6,service injector 03:00 06:48 3.80 0 2,362 COMPZ CASING PUTB P PJSM. PU/MU Liner assembly, shorty deployment sleeve,74 jts slotted liner, bull nose. M/U to coiltrack and surface test 06:48 08:36 1.80 2,362 8,980 COMPZ CASING TRIP P Trip in well, EDC closed 08:36 08:42 0.10 8,980 8,962 COMPZ CASING DLOG P Stop and correct to 6600'EOP flag, 8962.19,for-17.65. PUW=34K 08:42 09:24 0.70 8,962 11,406 COMPZ CASING RUNL P Continue in with liner 09:24 09:30 0.10 11,406 11,420 COMPZ CASING DLOG P tie into RA for-2'correction. Did not stop and input correction. Corrected set depth now 13157 Bit 09:30 12:54 3.40 11,420 13,028 COMPZ CASING RUNL P Continue in hole, Set down @ 11480',work pipe to 11490 then continue in hole,Work pipe from 12475 on down 12:54 13:42 0.80 13,028 11,341 COMPZ CASING RUNL P 13028, Hard bottom for liner, Pumps on and release from liner, PUW=32K, BOL=13028,TOL=10709 13:42 13:48 0.10 11,341 9,024 COMPZ CASING CIRC P Remove liner length left in hole -2318.4, Circulate to recover 12.95PPG completion fluid Page 8 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:48 14:00 0.20 9,024 9,024 COMPZ CASING DLOG P PUH to tie in while circulating spacer down coil for+2'go cack down to 9024, made no correction to ETOL 14:00 15:36 1.60 9,024 9,024 COMPZ CASING CIRC P Continue circulating 10PPG spacer and used 9.8 Pwr pro to displace 12.95 completion fluid. started getting returns after spacer out of coil 15:36 18:03 2.45 9,024 57 COMPZ CASING TRIP P Trip out on MP schedule,displacing KWF,open EDC,on surface. 18:03 20:18 2.25 57 57 COMPZ CASING PULD P PJSM. PUD BHA#7, unload PDL and load PDL. 20:18 21:30 1.20 57 57 PROD2 STK PULD P PJSM. PD BHA#8,surface test. 21:30 00:00 2.50 57 8,700 PROD2 STK TRIP P RIH w/BHA#8 anchored billet assembly 06/01/2013 RIH w/anchored billet assembly set @ 10,710'. POOH and PUD BHA#8, PD BHA#9. Found flat spot on coil above connector, rehead coil. RIH w/kick-off mill assembly to 10,698',spent rest of day attempting to kick-off billet, in progress. 00:00 01:24 1.40 8,700 10,710 PROD2 STK TRIP P Continue in hole with anchored billet assembly,log GR tie-in,-21.5' correction, PUW=31 K,close EDC, tag top of liner @ 10,710', PU to neutral weight, pump up to 3,200 psi, _ release from billet,stack 2K down. 01:24 04:15 2.85 10,710 53 PROD2 STK TRIP P POOH with BHA#8,circulate out remaining 12.95 liner pill. 04:15 05:57 1.70 53 0 PROD2 STK PULD P PJSM. PUD BHA#8, Unload PDL and lay down tool 05:57 06:27 0.50 0 0 PROD2 STK SFTY P Crew change,Valve check list, PJSM to Load and deploy BHA#9 06:27 08:03 1.60 0 72 PROD2 STK PULD P Load BHA#9 into PDL and deploy, .7°motor and re run Hughes 2.74 X 3.35 Bi Center 08:03 10:45 2.70 72 72 PROD2 STK CTOP T Inspect coil above connector,flatspot down to 1.78 X 2.15, Remove CTC and trim 20'coil. Install new CTC, Pull test to 35K. Rehead UQC, PT to 4K 10:45 11:03 0.30 72 72 PROD2 STK PULD P M/U coil to coiltrack, Surface test, Strip on 11:03 13:09 2.10 72 8,955 PROD2 STK TRIP P RIH, EDC open 13:09 13:21 0.20 8,955 8,973 PROD2 STK DLOG P Log K1 for-21.5'correction,Close EDC, 13:21 14:21 1.00 8,973 10,699 PROD2 STK TRIP P RIH to kick off anchor billet, Clean pass through window, Dry tag @ 10699 14:21 18:18 3.95 10,699 10,699 PROD2 STK KOST P Time mill off anchored Billet per procedure,multiple stalls and PU's, pump 20 bbls new system,keep stalling,weight transfer issues,try slower ROP rate and increased pump rates,decide to pump new mud system. 18:18 20:18 2.00 10,699 10,699 PROD2 STK CIRC T Pump in new pump system Page 9 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:18 22:48 2.50 10,699 10,699 PROD2 STK KOST T Continue kick off,several more stalls,try different pump rates and ROP rates,back ream up once, can not seem to get bite, pump 10 slick pill, PU hole, change orientationm RBIH. 22:48 00:00 1.20 10,699 10,699 PROD2 STK KOST T Continue to battle weight transfer issues,try different pump rates, pump additional slick pills. 36/02/2013 Continue billet kick-off @ 10,699',time drill to 10,714'. Drill ahead build section from 10,714'to 10,997'with 150'wiper trips, build section in progress. 00:00 06:12 6.20 10,699 10,704 PROD2 STK KOST T Continue kick off,several more stalls,try different pump rates and ROP rates,back ream up once, pump two additional 10 bbls slick pills to load annular for weight transfer issues,start getting better motor work,start time milling again as per procedure. 06:12 07:42 1.50 10,704 10,714 PROD2 STK KOST T Time control drilling, 1.5K DHWOB, 1.41 BPM @ 3949 PSI FS, BHP=4160, Low ROP<10 FPH 07:42 08:06 0.40 10,714 10,724 PROD2 DRILL DRLG P 10714, Drilling break, ROP=76 FPH 08:06 14:06 6.00 10,724 10,740 PROD2 DRILL DRLG P Back to Low ROP,Ankorite in bottoms up sample,grind ahead 14:06 14:24 0.30 10,740 10,740 PROD2 DRILL WPRT . P PUH and dry drift billet area, Clean up saw small bobble-5'@ 10704, PUW=32 14:24 14:54 0.50 10,740 10,742 PROD2 DRILL DRLG P 10740', Drill Ahead, 1.4 BPM @ 4070PSI FS, BHP=4165, 14:54 17:48 2.90 10,742 10,865 PROD2 DRILL DRLG P Drilling break ROP 30-60 FPH, continue drilling ahead, 1.4 BPM @ 4070PSI FS, BHP=4170, ROP=40 17:48 19:54 2.10 10,865 10,865 PROD2 DRILL WPRT P Wiper trip to 9,120', PUW=34K, RBIH. 19:54 00:00 4.10 10,865 10,997 PROD2 DRILL DRLG P 10865', Drill Ahead, 1.41 BPM @ 4058 PSI FS, BHP=4195, WHP=210, ROP=25-40 06/03/2013 Complete build section to 11,005', POOH and LD BHA#9. Perform full BOPE test.Cut 1,900'coil, perform slack management, install coil connector. 00:00 00:30 0.50 10,997 11,005 PROD2 DRILL DRLG P Drill ahead build section, 1.41 BPM @ 4058 PSI, BHP=4205 PSI, WHP=210, ROP=60. Pump 5 bbl to/hi sweeps. 00:30 04:24 3.90 11,005 52 PROD2 DRILL TRIP P POOH w/BHA#9 04:24 06:00 1.60 52 0 PROD2 DRILL PULD P PUD BHA#9 Lay down motor 06:00 07:30 1.50 0 0 PROD2 DRILL BOPE P Crew change,valve check list, PJSM, Prep for BOPE test, roll coil to water and jet stack 07:30 08:00 0.50 0 0 PROD2 DRILL BOPE P BOPE Test,Test Inner reel valve 08:00 09:00 1.00 0 0 PROD2 DRILL SVRG P Grease crew here to service tree 09:00 16:00 7.00 0 0 PROD2 DRILL BOPE P Perform full BOPE Test,test witness waived by Lou Grimaldi,AOGCC Page 10 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:00 2.00 0 0 PROD2 DRILL CTOP P PJSM to cut 1900'of coil, rig up hydraulic cutter 18:00 18:30 0.50 0 0 PROD2 DRILL SFTY P Crew change,valve checklist 18:30 22:00 3.50 0 0 PROD2 DRILL CTOP P Continue to trim pipe, 1850' 83 pp , 22:00 23:30 1.50 0 0 PROD2 DRILL CTOP P PJSM, Boot E-line and pump slack, cut 15'to find wire,trim to get good wire test.Total trim 1910' 23:30 00:00 0.50 0 0 PROD2 DRILL CTOP P Install coil connector. 06/04/2013 Drill ahead from 11,005 to 11,520'. 00:00 03:30 3.50 0 0 PROD2 DRILL CTOP P Complete coil connector and pull test, load coil with mud, install UQC and PT to 4,000 psi. 03:30 05:30 2.00 0 0 PROD2 DRILL PULD P PJSM. PDL BHA#10,surface test, PD BHA#10 05:30 12:00 6.50 0 11,005 PROD2 DRILL TRIP P RIH w/drilling assembly,tie-in GR for-23'correction.Town requested LSRV adjustment at window to 38k-40K,circulate to adjust mud, close EDC,continue in hole to 11,005'. 12:00 14:45 2.75 11,005 11,155 PROD2 DRILL DRLG P Drill ahead 1.44 BPM @ 3910 PSI, BHP=4155 PSI,WHP=245 PSI, ROP=50-60. 14:45 17:00 2.25 11,155 11,155 PROD2 DRILL WPRT P Wiper trip, PUW=35K,tie-into GR, RBIH. 17:00 19:00 2.00 11,155 11,315 PROD2 DRILL DRLG P Drill ahead 1.45 BPM @ 3950 PSI, BHP=4158 PSI,WHP=245 PSI, ROP=60-80 19:00 19:45 0.75 11,315 10,100 PROD2 DRILL WPRT P Wiper up, 33k off BTM. 19:45 20:15 0.50 10,100 11,315 PROD2 DRILL WPRT P Turn around, 20:15 22:00 1.75 11,315 11,465 PROD2 DRILL DRLG P Drill ahead 1.40 BPM @ 3889 PSI, BHP=4152,WHP 236, ROP=80 22:00 23:30 1.50 11,465 11,465 PROD2 DRILL WPRT P Wiper up,33k 23:30 00:00 0.50 11,465 11,520 PROD2 DRILL DRLG P Drill ahead 1.42 BPM @ 3823 PSI, BHP=4154,WHP 175, ROP=74 06/05/2013 Drill ahead from 11,520'to 12,493. 00:00 01:00 1.00 11,520 11,615 PROD2 DRILL DRLG P Continue; Drill ahead 1.42 BPM @ 3823 PSI, BHP=4154,WHP 175, ROP=74 Pump 5 X 5, sweep out the bit @ 11610' 01:00 02:30 1.50 11,615 9,062 PROD2 DRILL WPRT P Wiper up,tie in wiper.33k off BTM. 02:30 03:00 0.50 9,062 9,150 PROD2 DRILL DLOG P Get above window @ 9062. Perform pump test for 5 minutes 1.44 BHP @ 3952,WHP 228. Pump for 5 minutes, BHP @ 3945.Tie in @ 9110, +.5 correction. 03:00 04:00 1.00 9,150 11,615 PROD2 DRILL WPRT P RBIH on wiper trip 04:00 05:33 1.55 11,615 11,750 PROD2 DRILL DRLG P Drill ahead 1.42 BPM @ 3900 PSI, BHP=4180,WHP 204, ROP=96 05:33 07:18 1.75 11,750 11,750 PROD2 DRILL WPRT P Wiper trip to 10,290', PUW=33K, RBIH Page 11 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:18 09:03 1.75 11,750 11,915 PROD2 DRILL DRLG P Drill ahead 1.50 BPM @ 4060 PSI, BHP=4210,WHP 225, ROP=80 09:03 10:39 1.60 11,915 11,915 PROD2 DRILL WPRT P Wiper trip 10,300', PUW=34K, RBIH 10:39 12:15 1.60 11,915 12,065 PROD2 DRILL DRLG P Drill ahead 1.50 BPM @ 4030 PSI, BHP=4220,WHP 180, ROP=60 12:15 15:45 3.50 12,065 12,065 PROD2 DRILL WPRT P Long wiper to window, PUW=34K. Perform pump test just above window for 5 minutes, 1.49 BPM @3950, WHP=225 PSI,tie-in for+1' correction, RBIH. 15:45 17:30 1.75 12,065 12,215 PROD2 DRILL DRLG P Drill ahead 1.47 BPM @ 4065 PSI, BHP=4220,WHP 200, ROP=70 17:30 19:00 1.50 12,215 12,215 PROD2 DRILL WPRT P Wiper trip 19:00 21:15 2.25 12,215 12,365 PROD2 DRILL DRLG P Drill ahead 1.47 BPM @ 3981 PSI, WHP=188, BHP=4251, 21:15 22:30 1.25 12,365 12,365 PROD2 DRILL WPRT P Wiper up 22:30 23:30 1.00 12,365 12,440 PROD2 DRILL DRLG P Drill ahead 1.45 BPM @ 4037, WHP=183, BHP=4259 23:30 00:00 0.50 12,440 12,493 PROD2 DRILL DRLG P Back rate down to 1.35 BPM, BHP= 4240,WHP=178 06/06/2013 Drill ahead in lateral L1-01 from 12,493'to a called TD of 12981'. Perform wiper to the swab.TIH,tie in& confirmed TD @ 12981'.Start laying in 12.95 liner pill. 00:00 00:30 0.50 12,493 12,515 PROD2 DRILL DRLG P Continue drilling to 12,515' 00:30 02:00 1.50 12,515 9,035 PROD2 DRILL WPRT P Long Wiper&Tie in for 0'correction. perform 5 minute pressure test, Pump @ 1.36 BPM @ 3951-3931 dies)in BHP @ 3952. 02:00 03:30 1.50 9,035 11,670 PROD2 DRILL WPRT P Wiper, RBIH. 03:30 04:00 0.50 11,670 12,515 PROD2 DRILL WPRT P Continue RIH,start sending new mud down the coil for mud swap. 04:00 06:00 2.00 12,515 12,665 PROD2 DRILL DRLG P New mud out the bit, Drill ahead 1.37 BPM @ 3751 WHP=299 BHP 4237, ROP=85 06:00 07:30 1.50 12,665 12,665 PROD2 DRILL WPRT P Short wiper trip, PUW=34K, RBIH. 07:30 10:00 2.50 12,665 12,815 PROD2 DRILL DRLG P Drill ahead 1.34 BPM @ 3675 WHP= 265 BHP 4240, ROP=65 10:00 11:30 1.50 12,815 12,815 PROD2 DRILL WPRT P Short wiper trip to 11,315[, PUW=34K, RBIH. 11:30 14:15 2.75 12,815 12,981 PROD2 DRILL DRLG P Drill ahead 1.34 BPM @ 3525 WHP= 272 BHP 4250, ROP=50,continue to called TD, pumped 10 bbl to/hi sweeps. 14:15 18:30 4.25 12,981 72 PROD2 DRILL WPRT P Long wiper trip to swab, chase sweep to surface. PUW=37K. 18:30 21:00 2.50 72 8,945 PROD2 DRILL TRIP P RBIH 21:00 21:15 0.25 8,945 8,992 PROD2 DRILL DLOG P Log from 8945 to 8992.tie in for-20' correction.Get a pick up wt,31k 21:15 23:15 2.00 8,992 12,981 PROD2 DRILL TRIP P RIH @ 12,365'start sending 12.95 liner pill down coil 23:15 00:00 0.75 12,981 11,480 PROD2 DRILL CIRC P Tag TD @ 12981'. 36 pu wt.Jog pipe, 7 bbls until line pill at the bit. Start laying in 13.1 liner pill with beads. Page 12 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/07/2013 24 hr Summary killed well with 13.1 KWF,good no flow at surface. Picked up&ran lower section of L1-01 liner. Picking up upper section of liner in progress. 00:00 04:00 4.00 11,480 71 PROD2 DRILL CIRC P @ 11,480',continue laying in liner running pill(50 bbls)lay in 12.95 KWF to surface.paint TD&window flags. 04:00 04:30 0.50 71 71 PROD2 DRILL OWFF P Tag up.Shut down pumps. No flow at the shaker.Watch for 30 minutes. Conduct PJSM 04:30 07:45 3.25 71 0 PROD2 DRILL PULD P LD BHA#10, prep rig floor, PJSM. Change-out C-13 valve 07:45 10:30 2.75 0 1,531 COMPZ CASING PUTB P PU/MU Lower liner assembly,shorty deployment sleeve,48 jts slotted liner, bull nose. MU BHA#11. 10:30 17:15 6.75 1,531 12,981 COMPZ CASING RUNL P RIH w/BHA#11 lower liner assembly @ 60 FPM, pumping at min rate,decrease RIH rate to 40 FPM, pushing fluid away, EOP flag @ 7,500,correction of+14.5,WT check 36K.Continue in hole, start pumping across top to minimize losses, losses down to 2-3 BPH,tag TD, PUW=46K, RBIH to TD, pump to release GS spear,release from liner, PUW=35.5, loss during RIH 50-60 BBLS. BOL @ 12981'&TOL @ 11494' 17:15 20:00 2.75 12,981 44 COMPZ CASING TRIP P POOH w/BHA#11,continue to build KWF. 20:00 20:30 0.50 44 44 COMPZ CASING OWFF P Tag up.Watch for flow. Conduct PJSM on lay down of BHA#11 20:30 22:00 1.50 44 0 COMPZ CASING PULD P Lay down BHA#11.Service injector, take a look at the counter. 22:00 00:00 2.00 0 0 COMPZ CASING PUTB P PJSM, PU liner. 06/08/2013 Set upper section of L1-01 liner,top at 9550'. Swap well back to drilling mud recovering KWF.Waiting on pallets of kill weight material to be flown in from PBU. 00:00 01:30 1.50 0 1,935 COMPZ CASING PUTB P Continue picking up L1-01 upper section of liner. 01:30 02:30 1.00 1,935 1,988 COMPZ CASING PULD P Liner all picked up. PJSM; PU coil track BHA. 02:30 04:45 2.25 1,988 1,988 COMPZ CASING RGRP T Attempt to RIH, BHI counter not working,troubleshoot. Pull counter off, swap out encoder. 04:45 09:00 4.25 1,988 11,615 COMPZ CASING RUNL P RIH W/upper section of liner, EDC closed. Start pumping across top @ 2,500'. EOP flag @ 7,000'correction of-2.5', PUW=35K,tag top of lower liner 11,515', PUW=42K, RBIH, pump up to release from GS spear, PUW=35K:TOL 9550' 09:00 09:45 0.75 11,615 9,057 COMPZ CASING TRIP P POOH w/BHA#12,tie-in for top of liner correction-21.5',corrected TD 11,494.5',top of upper liner 9,550', POOH to 9,057'. Page 13 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 12:00 2.25 9,057 9,057 COMPZ CASING CIRC P Set at window,open EDC,circulate out KWF, 160 bbls usable KWF after dust-up on surface. 12:00 15:00 3.00 9,057 0 COMPZ CASING TRIP P POOH w/BHA#12,tag up,space out. 15:00 17:45 2.75 0 0 COMPZ CASING PULD P PJSM. PUD BHA#12, Load PDL with BHA#13. 17:45 00:00 6.25 0 0 PROD3 STK CIRC T Waiting on product needed to mix additional KWF due to bridge out. Recd 10 pallets of formate @ 11:30 PM. Still not enough.The other shipment of 10 pallets will not be shipped until tomorrow morning. 06/09/2013 Stood by for emergency kill weight due to Kuparuk bridge outage. 00:00 07:00 7.00 0 0 PROD3 STK CIRC T Still waiting on emergency kill weight material. Mix up the 10 pallets that we have,giving us—197 bbls. Still need 37 more bbls. Function test BOPE, perform light maintence and cleaning around the rig. 07:00 22:00 15.00 0 0 PROD3 STK CIRC T Still waiting;decide to unstab and change out skates. 22:00 00:00 2.00 0 0 PROD3 STK CIRC T All equip normalled back up. Still waiting for Kill weight material. 06/10/2013 Dry tagged top of billet at 9546'. Kicked off billet,drilled lateral L1-02 to 9953.0. 00:00 04:30 4.50 0 0 PROD3 STK CIRC T Still waiting on emergency kill weight material. 04:30 07:00 2.50 0 0 PROD3 STK PULD P Formate on location. PJSM.Start PD drilling BHA#13,surface test, crew change, PJSM. 7: 0 0 PROD3 STK TRIP P 07:00 0 03 0 05 RIH w/BHA#13 drilling assembly, counter not counting. 07:03 08:36 1.55 0 95 PROD3 STK TRIP T Troubleshoot counter issues 08:36 11:30 2.90 95 9,546 PROD3 STK TRIP P Continue in hole drilling assembly, log GR tie-in for-24'correction, PUW=32K, continue in hole. 11:30 14:00 2.50 9,546 9,580 PROD3 STK KOST P Dry tag, PUW=36K,start drilling, stalled once, PUH, RBIH.Start time drilling as per procedure. 14:00 14:45 0.75 9,580 9,580 PROD3 STK DRLG P PUW=31 K,dry drift clean,choke plugging off,blow down choke, RBIH. 14:45 17:30 2.75 9,580 9,720 PROD3 DRILL DRLG P Drill ahead 1.48 BPM @ 3890 PSI, BHP=4031 PSI,WHP=250, ROP=50. 17:30 18:09 0.65 9,720 9,720 PROD3 DRILL WPRT P Wiper trip#1 to window, PUW=33K 18:09 21:15 3.10 9,720 9,870 PROD3 DRILL DRLG P Drill ahead 1.43 BPM @ 3675 PSI, BHP=4045 PSI,WHP=275, ROP=40. 21:15 22:30 1.25 9,870 9,870 PROD3 DRILL WPRT P Wiper trip 22:30 00:00 1.50 9,870 9,953 PROD3 DRILL DRLG P Drill ahead 1.42 BPM @ 3679 psi, WHP=259, BHP=4032 06/11/2013 Drill ahead in lateral L1-02 to TD 10784'. Perform wiper to the swab. Page 14 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 9,953 10,020 PROD3 DRILL DRLG P Continue...Drill ahead 1.42 BPM @ 3679 psi,WHP=259, BHP=4032 00:45 01:45 1.00 10,020 9,133 PROD3 DRILL WPRT P Wiper,34k pick-up.Tie in for+ 1.5 correction. 01:45 02:15 0.50 9,133 10,020 PROD3 DRILL WPRT P Wiper; RBIH 02:15 03:59 1.74 10,020 10,170 PROD3 DRILL DRLG P Drill ahead 1.42 BPM @ 3679 psi, WHP=273, BHP=4032 03:59 04:59 1.00 10,170 10,170 PROD3 DRILL WPRT P Wiper 04:59 06:44 1.75 10,170 10,320 PROD3 DRILL DRLG P Drill ahead 1.41 BPM @ 3720, WHP=293, BHP=4060 06:44 07:59 1.25 10,320 10,320 PROD3 DRILL WPRT P Wiper 07:59 09:29 1.50 10,320 10,470 PROD3 DRILL DRLG P Drill ahead 1.40 BPM 3856 PSI, WHP=289, BHP 4072 09:29 11:14 1.75 10,470 10,470 PROD3 DRILL WPRT P Wiper 11:14 12:33 1.32 10,470 10,620 PROD3 DRILL DRLG P Drill ahead 1.42 bpm 3755 psi WHP=286 psi BHP=4,078 psi 12:33 14:03 1.50 10,620 10,620 PROD3 DRILL WPRT P Wiper. 36k pick up. Tie-in correction of+1 14:03 15:33 1.50 10,620 10,784 PROD3 DRILL DRLG P Drill ahead to TD. 1.40 bpm 3,755 psi WHP=279 psi BHP=4,108 psi 15:33 19:23 3.84 10,784 0 PROD3 DRILL WPRT P Wiper trip to surface chasing 15/15 sweep pill. 19:23 21:23 2.00 0 8,960 PROD3 DRILL WPRT P Wiper back in hole. 21:23 21:38 0.25 8,960 8,970 PROD3 DRILL DLOG P Tie into K1 marker correction of-22'. Weight Check 31k 21:38 22:49 1.19 8,970 10,784 PROD3 DRILL WPRT P Continue tripping in hole. Confirm TD 10784'. 22:49 23:58 1.16 10,784 0 PROD3 DRILL TRIP P POOH laying in 13.0ppg competion fluid with alpine beads up to 9050' and without bead to surface. 36/12/2013 Performed wiper to the swab valves. RBIH and confirmed TD 10784'. Displaced well to 13.0 completion fluid. M/U 52 jts of slotted liner with 3 jts of solid liner. RIH set on bottom leaving TOL at 9075.74'. Lost 113 bbls of completion fluid to formation during trip in hole with liner. 00:00 02:00 2.00 8,475 0 PROD3 DRILL TRIP P Continue POOH, Painting EOP flags at 7300'(White)and 8628'(Yellow). 02:00 02:09 0.15 0 0 PROD3 DRILL SFTY P Conduct PJSM-checking well for flow and L/D drilling BHA. 02:09 02:24 0.25 0 0 PROD3 DRILL PULD P Continue flow check. 02:24 02:54 0.50 0 0 PROD3 DRILL PULD P L/D drilling BHA. 02:54 03:24 0.50 0 0 COMPZ CASING SVRG P Service INJH,while setting up rig floor for running liner. 03:24 03:39 0.25 0 0 COMPZ CASING SFTY P Conduct PJSM-running L1-02 liner completion. 03:39 07:16 3.62 0 0 COMPZ CASING PUTB P M/U L1-02 2 3/8"liner competion. 07:16 12:16 5.00 0 10,787 COMPZ CASING RUNL P RIH slowly w/Liner completion. Lost 113 bbls of KWF.TOL @ 9075'MD BOL @ 10,787'MD 12:16 17:16 5.00 10,787 2,500 DEMOB WELLPF CIRC P Displace wellbore to seawater and POOH. 17:16 18:16 1.00 2,500 0 DEMOB WELLPF FRZP P Freeze Protect well from 2500'. Page 15 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:16 18:31 0.25 0 0 DEMOB WELLPF SFTY P Conduct PJSM-Undeploying liner running equipment. 18:31 20:31 2.00 0 0 DEMOB WELLPF PULD P Undeploy BHA 20:31 21:31 1.00 0 0 DEMOB WHDBO DMOB P Close Master Valve.WHP 1370psi. Flush surface lines with fresh water. R/U SLB N2 pump truck to cement line. 21:31 23:31 2.00 0 0 DEMOB WELLPF CTOP P Conduct PJSM-pumping N2 for reel blowdown. 23:31 23:45 0.24 0 0 DEMOB WHDBO NUND P Conduct PJSM-Set BPV, SITP- 1370psi. 23:45 23:59 0.24 0 DEMOB WHDBO NUND P Set BPV, SITP- 1370psi 06/13/2013 00:00 01:00 1.00 0 0 DEMOB WHDBO DMOB P Continue to set BPV 01:00 05:00 4.00 0 0 DEMOB WHDBO DMOB P *****RIG RELEASE********5:00AM *********** Page 16 of 16 Post-Rig Well Work Summary DATE SUMMARY 6/25/2013 DRIFT W/2.61" MAGNET TO LINER TOP @ 9075' RKB. BRUSH &GAUGE TBG W/ 2.78" GAUGE RING TO PBR @ 8704' RKB. MEASURE BHP (3859 psi)@ 9050' RKB. SET AVA CATCHER @ 9075' RKB. PULL DV @ 7796' RKB AND SET OV. IN 6/26/2013 PULLED DV'S&SET GLV'S @ 6844', 5403' &3004' RKB; OBTAINED GOOD TBG. TEST W/HOLEFINDER; PULL AVA CATCHER @ 9,075' RKB. JOB COMPLETE. IP ra ail z mime `an gi N Q Z I C C 0 CU a a) W Ce a F- >, Q. co Z > •_ ,Cl) L •— — u a a r f w 0 ) a M = >T . ie M+ N N 4J •— c C 0 -e - p N L c N O C L 2 d " • c V ti N a a o c, w V Y Y L 2 m CI . 1 Z > (0 Iiii (Dv' > a co C (no N o r co W C a) �r ( if, ,_- i M T d O m CO M CO M !")CI c r d Q M ..1-._ N N O V') j a N O O N N '7 a q) C N CO (1) a1 W .- M )(1 0 0) IL } 0 C) C v o^ C o N I� CO h L v W i N CI N W O CO 0 — N O N («a N N N 0, d (A .- M 1n CO d I 00 J a 7 a) C O J J () 81 n C _. °c;,1 a a; 0. N h a CIE CO I x 0 a) .o = = m a 2, m m N ` E E CO OS 0 0 0) O) ,- U N �i N N ti 0) c o 7 0 a 'o Q ao a w - °o (a (a N N- L a1 C U 41 b i; + .-. C O O C fp, 0 N N 1- 2- W C 0 ' :12 O O o (n (A N g• N (6 O 0 0 0 0 0 0 0 J CC a) V V V d T T—al >)0 O O (1) CI 0 0 2 2 W Q y (A > 0) n M I— 0 = a C 01 01 C Z N 0 N .N .N n O (.O U) >` . m > > rn v1 v C 'n .0 > 0 0 U2 CO is v .° 0 ° N = C 0 a) I .>>> a m c � u = m w' Y cf V y T m C m a, 4 Ct O U U m 0 > a 0 = w O to oo i 0 0 J 2 (A O £ W F 2 .� • G L' 0' > O M N 0 0 2 2 7 61 0 t C t E t N N z W T co aJ 2 3 i R • a {( 0 CO o 4; G N C E o _, i,D M M C 0 N .i C j < 6- CO 7D'N r O N O_ o i' U o 1- IL O. 0 N u) Q £ O O .N_. Y N z I G N N'L l LL r) li li Q O C hi N '-1 T ... J J Z O O O a1 0 4) a) N- N- N- I,- C d1 L) a m 3 li LL I,L U _ 0 (A N N N N Q C a) C< O a > a1 Z O N a1 N N 0 0 CC a C O £ o O d > LL j Y N J Z N J 0 O V N O a) {A a N 0 : a1 d r O • 1(1 I!) a Y Y Q (n Y 'O 0 0 01 O N .1 y! co 2 2 (A m LL Z L.V. u_ o C7 a o rn o CO vi O a7 a7 1` ^ n Y Z Q N + N 2 CO N r W W C a a 0 Y Y N N N c a m 4 a C 43 iii 0 C c C . 6 0 .. c y = 11 O m p. E o0 00 o 0 Q a z o - 3 m o not ao 0 47, c i o m ° o ° m v a1 ., d 07 y .0 C of LL R1 O o b ^O'El U £ Q -0 a1 0 o m ow m v 0 0 '41 R w 'O 41 r 2 N 0 a U) 3 3 o 0 2 (7 2 3 3 a. 3 E 0 a' > > (0 o= m Igo 0 as 8 c 0 0 0 a < Cl-Y O U E co z 0 I- >. M V V V V V V V V V V V V V V V V V V V V' V V V V V V V V V m Q P Q p e e Q Q e p Q 5 5 5 5 5 5 5 5 5 5 5 co O co N N N CO N- n n 0) N- n 0) n U) N 0 03 00 CO N M Cl (0 O COO I,- O V; N r CO Y N O n O) Ian co co co, n n CO n CO �Ny N pNp O 0) U O �•' M t+1 M :Tr V )Of) )00 CD U3 c0 U3 I— n CO W OMi SS O O O CO 7.-, W c0 <o co co- co <o co- co- N (O O) N C0 Ui <O fo fo c0 N N co (o (O (O V] n n n r 1` > > 10 x N a a 'C CO O M n t0 h N O V N N `r `° W O M n 0n 0 M r N 1 ". N M O U M 0 N N m m N CO N C. � Of CC a A O O O O C O O CO 0 a D .- D n 0 O 3 2 u) J r r r r r r r r n N ,- U @ V co pp,, E ri @ Q t6 co N- 0) 0 0 CO r M M n O N O '1- '328 N M V O " 3 '- N n E 0) W cc! co N V V Cl) M () !,4 l 2 8 (V V 1N; N r V' N (V V' n N V O N n C N N It W Q C m N 0 2 00 l0 UO N 00 M O n 00 OO U N 8 0 00 OO O3OO U) O O O O) co 00 O co CO OO OO CO N 5 U U U N U U U b N N N N Ui N U N N ui N N N 6 N N U N N N N N /y La U) U) U) U) U) co U) U) U) U) N U) U) U) U) N U) N N N U) (O U) U) U) N U) U) UI N V W o i— CI 0) Q) U .O co N V O 0 N U) V CO U) N M N n N V n n Q (0 O M Z C 0 U) N 00 r O 00 V CO n O (0 (O (C n Ng r Of O V 8 O O r V U) c$ M m O) L (S N n n 660 M 0 N v n m N n W N N 0)) cCcDp M O C'- 6 6 OMO P. N W 60 PO) O >` w N 0 ,• V 4 .+7- (T.) M M M N N N r r •- O O O 0) 0) 0) 0) 00 U) 00 n n n c0 c0 cO cO 01 2 _ (p t v N N N N N N N N cV yN pN N N N N N 3133 CD a – z id i ri O U) v c U 6 ri N h vU (t c vI ri ( i U c ( i c 6- ca) M = ) •• c m C u y I a c o g to :) o 2 m w m 12 X.' N m O n N M 00 n 22 ,73 `- N M n n n 4' 8388 V 0) 00 c O U d U U (O O c0 U) C) n n N C) O r V N O V O 00 (0 O) Y �' U 0) d ce T A aD OD c0 U) fV r O) U) M cV I: s t` U) CV OD cV U) n n cV 0) U) p) cV a6 0 0 t .0 (no- CO CO (0 m CO co (0 c (O CO co CO CO CO n 00 (0 (0 (0 (0 (0 (0 (0 (0 ro CO CO coi ❑ ❑ x (o cn CO CO o (o CO CO CO (o (o m ( mJ l 2 Z cO ❑ W i ( ( . ( ( ( ( ( ( ( ( ( ( ( ( ( ( . ( co O co co Uf N CO N- N- n 0) N- n N- O) V N- U) U) 0 CO CO M N CO (p N CO O c0 n O V N 00 Y N O n 0) n CO 00 M n n CO n CO N N N O O) V' V' �} a 6 6 N- O) 6 4 6 V' 4 N) h U) V M M 6 C7 M M tl) C) CM (N (I) O) O M U) U) V n O M CO 0) M c0 0) N (0 CO n 0 M CO 0I N (0 (C act _ N M M M M V V V (0 (0 (0 cO CO c0 CO n n n QO CO O) 0) 0I O O O Z '.. (Q (Q 4 4 4. 4 (Q Si (Q (9 (9 (Q q 4 (Q (Q ui '9 (9 Si (9 (9 (9 4 1- N- T. n N- + M O a M V (M C) N N O N O 0 V O n 0) n O n 0 Q2 ,731`,112 p b C O = 8 2 N 0 g 0 0 M g M N a a m m N n 0 O M N O O) M N N ❑ O 0) 0) W 0 0 O O) O Si) ) Si 0) 0) 0) 0) 0 0) 0) W O) O) O) Of O) St N) 0) U) N U) Ui (0 N cq N Ui Ui N Ui Ui U) (O vi Ui cri Ui Ui cci N N Ui N h Ui N to' U) N _ V M V M N N N 0 N 00 M 0 0 N- W N 0 n co N N N 0 U) U) O_ CO n (N- CO n cO 0) CO V CO CO V N N- M N N- N N n a0 U) CO O) Y OnO 0np OO OVO OOO n r O 1c-p (Mp N (1n (N N aos n vi cc0� n co 6 6 6 OD OO N oi N 0 0 0 0 0 0 O O O O O O O O O S 3 0 0 3 8 8 0 0 8 8 S 0 0 0 (3 `•' CO M f0 6 co- 6 co- (O CO (0 (O (O (O co- 6 (O CO 6 M (0 c0 N N CO- O CO- CC; t0 (O CO C (O Ii N n V 0 0 0 n 0) . M 00 M U) CO c0 OO 0 CO CO Of V M) M N M n 0 O V N n g Q "C , N N O O U) U 0) Cr) N V U) 00 n CO (O O OD tU n n N- N O) �p n O n O) M n (V O cp 0) U) fV M n O a .N ^ n n n n n CO t0 (O n ,....6 n 00 U con 00 0) O) C) O) 0) W U) OD n n n n ;,..4: n G7 N 00 Q *".. O- Cl) 6. = > LL N L d N /1 a Y Y YL 7 ` C a V M 07 cA ap. q. M 7 (O N p n O N I8. 8 O. o s on O(( N N 2 N • O N O N CO n n n C O. Q r r r ( O 00 g0O O W n n 88202 W O oD D D m Oc p n M p m a U Y Y N N N O I. O V { V O V CO N U N N M M m M O V p cO CO O UO m V M n V h M M 0V n) O O 1 M U Un U) co:, O O O O d U O O g n O M UcO N U U U U U U U U 0 C N C }i .. O) .. ❑ N N N t0 0 n n h ro D co O CA O O O O O V :2 0r 0 N N cr.; o M M O (..) O ( V Q O C . .0 a o Z O O O O O O 0 0 O) O O O Ci ac co- O O O O O O O O O C O 0 O 0 O O tri am c) a ) 0 Cl) a H CI® All Z - hil 0 ca g= o 0 N O (n O C Q U I C) N 0 Z O 0 o w H I- ev v v v v v pv v v v a v 0 I S 5 5 5 5 OD 0 — CO CO m h 0) U) t0 N N- O CO CO CO (O O O 1� 1` CO. UI Lb 0 N N (N r n CO CO 0) co U 5' r N CV; N c,-.--;. m C) N O IT CO CO U > >`' U) X o N a rn N m m ao m r` o m 0 Z m y 6 ro ro mr d a o d cO ai to o J O co O Oi (V a0 O a0 O O O O CD > N ❑ I-' 1` " " O F _ �` © � N a V V N N N- 0 •E 2 r O2) P t0 si ' ' �g�pp "' N (V P N N H g ❑W Ll c m m co N m N co N co m m ro 0 0 ro co N R N =U) try U) U) U) U) U) U) b Lo L0 t0 L0 2 W N U) U) U) U) V) to N )n U1 In 111 111 LW 0 I— a 4 Q) V -a 0) co CD N CO O CO U) CO 0) 1� Z C[ G O O O O O N CO 0) CO m CO r i L Ql O CCyD Oi Cp co O CO') O N- O N m co O N () w y C L.) Ln U) v c O O m co h CO N N N CO co •,yt z U) U) LO U1 Lp LO LO N L0 N W U) L0 c CI C) C g C) _• > V C i V C $ Q o c O 412 w d U N 0 0 S 0 O D 0 W O %r M Y• 0 V 0C') y CT) 9 m O 0 0 g CO g ? (0 Y P! R (O O c a : O o CO o o o o n o co o o to O u 0 ❑ r ° J 2 CO ❑ W L L L L L L L L L L L L O 0 CO aD 0 CO 0 n N. 0 CO 1.-- CO CO CO N m N N CO < ai Z r N; N n N- r r 1; 1- Pi r n n r I + N (O N ,- m r N 0 N 0 CO O U) t0 U) O O LO CD m O s 0 OO m U)0) N N N N N CO CO co CO 0 cri v CO 7 ❑ .' 0 0 0) 0) 0 0) 01 0 CO. 0) 0 CO_ 0) U) U) 10 U) t0 U) VI L0 U U) N LO to N M m VN) V N N CO N NLO ON) IQ COD ,O 0. Y ❑ 0 co 0 0 0 0 0 0 0 0 0 0 0 C) . (O (0 (0 (O (O (0 (0 (0 (O (O (0 (O (O c (--,3‘ m N •.• r V N O I-- - LOO V 8 LA Z COD Q C (V n V' M O O O O N Q v •O OD O n n r n 1. P Cu N co co a .6 a s c N a a U 2 2 • O co c9 N- — r V N O °f P P. O pp 0 V- N N• LL u ad ti ro O r r; ($' Ui I g g Lri S U Y Y N N N `"' O CD O O O O CD O m O a..0 in co r r N X IT rn 0 O O O N h O O Uj U1 Lri U) O O O O (0 O 0 U) ' N C C .. Z1... ❑ CO v v v WI CO N CO 0 (O O n CO r 1 O ( U 00 0 >. 2 0 O O CJ CJ O O O 660 O O U c m _ a a) Z o o m « N \ c o a' in o co r\ _�� co I #, `' '''`` Letter of Transmittal KAI Date: BAKER 60 HUGHES June 18, 2013 To: From: Makana Bender Carl Ulrich/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage,Alaska 99515 G t l Please find enclosed the directional survey data for the following well(s): 2F-17L1 913 , 05 11 2F-17L1-01 3 (Y. J 2F-17L1-02 13 6 t 3 d. I 3 ,g.52. (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files 14( Note: Please feel free to send us an email in place of return Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich @BakerHughes.com oF Tit w��\\I%% ■ THE STATE Alaska Oil and Gas o1 1L AVKl 1 Cznseivaticri Ccironissi� fix-=4 _ GOVERNOR SEAN PARNELL *�. 333 West Seventh Avenue OJT; P- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt CT Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F-17L1-02 ConocoPhillips Alaska, Inc. Permit No: 213-060 Surface Location: 128' FNL, 1738' FEL, SEC. 33, T11N, R9E, UM Bottomhole Location: 2293' FNL, 1846' FWL, SEC. 4, T1ON, R9E, UM Dear Mr. Gantt: 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 KRU 2F-17L1, Permit No 213-058, API 50-029-22731-01-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ) 312.,e_i Cathy P Foerster Chair DATED this/S day of May, 2013. DIVED , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 2 2013 PERMIT TO DRILL ���� 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj 0 - Single Zone ❑ 1c.Specify if well is proposed for: Drill ❑ •Lateral 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180• 2F-17L1-024 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10700'. TVDSS: 5960'4' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 128'FNL, 1738'FEL,Sec.33,T11 N,R9E,UM - ADL 25657,25666 . Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 723'FNL, 1787'FWL,Sec.4,T10N,R9E, UM • 2583,2587 5/22/2013 Total Depth: 9.Acres in Property: 14.Distance to 2293'FNL, 1846'FWL,Sec.4,T1 ON, R9E,UM ' 5120 • Nearest Property: 6600 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: ' 129 feet 15.Distance to Nearest Well Open Surface:x- 517494 y- 5948755 Zone- 4 GL Elevation above MSL: '93 feet to Same Pool: 2F-13,2300 16.Deviated wells: Kickoff depth: 9375 a ft. 17.Maximum Anticipated Pressures in psig(see zo AAC 25.035) Maximum Hole Angle: 98°d deg Downhole:4659 psig a Surface:4054 psig• 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 SLT 1623' 9077' 5879' 10700' 5960' 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) 9561 6336 none 9461 6263 none Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 260 sx AS 1 121' 121' Surface 3977' 7.625 251 sx ASLW,530 sx CI G, 4018' 3136' Intermediate 65 sx AS 1 Production 8936' 5.5 120 sx Class G 8975' 5929' Liner 842' 3.5 114 sx Class G 9560' 6396' Perforation Depth MD(ft): Perforation Depth ND(ft): 9038'-9048', 9126'-9136', 9164'-9181' 5975'-5983', 6042'-6049', 6071'-6084' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 4/5°/1g 22. I hereby certify that the foregoing is true and correct. Contact Jason Burke @ 265-6097 Email Jason.Burkeaconocophi lip com Printed Name Lamar Gantt Title CT Drilling Supervisor Signature i�'l/ ,� , Phone: 265-4021 Date $///(3' j ommissise 49'1�1}y Permit to Drill API Number: `y "Permit Approval I See cover letter Number: 2 13 V(00 50-02°1-.22-431- -00' Date: c5 1 3 ‘97 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed ethane,gas hydrates,or gas contained in shales: Other: 3 t�0 p f(75 f i_o SG ei p si Samples req'd: Yes No Mud log req'd: YesLJ No LI H2S measures: Yes No ❑ Directional svy req'd: Yes No❑ Spacing exception req'd: Yes ❑ No EA Inclination-only svy req'd: Yes❑ No I � ���" fi._ A{PPROVD BY THE Approved by: MMI StpNER 'i COMMISSION Date: S^- -7 3 Form 10-401 (Revis d 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) �� '�o� RECEIVED ConocoPhillips MAY 022013 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 29, 2013 • Commissioner- State of Alaska • Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a tri-lateral out of the Kuparuk Well 2F-17 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in May 2013. The CTD objective will be to drill tri-laterals (2F-17L1, 2F-17L1-01 &2F-17L1-02), targeting the A sand intervals. Prior to starting an RWO will be performed to place new tubing and a packer in the well. As the wells packer will be placed greater than 200 ft above the injection zone, a separate sundry has been submitted for approval. The well will be produced for 1-3 months before it is turned over to injection once again. Attached to this application are the following documents: — Permit to Drill Application Form for 2F-17L1, 2F-17L1-01 and 2F-17L1-02 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed RWO Schematic — Proposed CTD Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, Jason Burke Coiled Tubing Drilling Engineer Kuparuk CTD Laterals r4ABOBS AGASRA Drilling , &Weil* 2F-17L1, 2F-17L1-01, & 2F-17L1-02 Application for Permit to Drill Document 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 2 (Requirements of 20 AAC 25.005(c)(6)) 2 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 2F-17L1, 2F-17L1-01 &2F-17L1-02 7 Attachment 2: Current Well Schematic for 2F-17 7 Attachment 3: Proposed Well Schematic for 2F-17L1,2F-17L1-01 &2F-17L1-02 7 Page 1 of 7 , f 4/30/2013 PTD Application: 2F-17L1, 2F-17L1-01 &2F-17L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AA C 25.005(b)) The proposed laterals described in this document are 2F-17L1, 2F-17L1-01 &2F-17L1-02. All three of these laterals will be classified as"Service— Water Injection"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 2F-17L1 sidetrack and the 2F-17L1-01 and 2F-17L1- 02 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. (Using the p P p p p ( 9 maximum pressure in the area of 4659 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 4058 psi. See the"Drilling Hazards Information and Reservoir Pressure"section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure(Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom-hole pressure of 2F-17, measured in April 2013, indicated a reservoir pressure of 3968 psi or 12.7 ppg equivalent mud-weight. The maximum down-hole pressure in the 2F-17 area is at injector 2F-13 with 4659 psi. It is not expected that reservoir pressure will be as high in 2F-17 because we will be drilling away from the 2F-13. Using the 2F-13 pressure as the maximum possible in 2F-17, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 4054 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; and the 2F pad hasn't had any MI injection. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 2F-17 laterals will be shale stability in the A-sand, maintain target ECD(12.9 ppg)to maintain shale stability. 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 MC 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)) Page 2 of 7 4/30/2013 rTh PTD Application: 2F-17L1, 2F-17L1-01 & 2F-17L1-02 New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2F-17L1 10900' 13400' 6021' 6019' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 2F-17L1-01 9375' 13400' 5964' 6043' 2%" 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. 2F-17L1-02 9077' 10700' 5879' 5960' epl dept4.7#, 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 (PO MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 43' 121' 0' 121' 1640 630 Surface 7-5/8" 29.7 L-80 BTC 41.3' 4018' 0' 3136' 6890 4790 Casing 51" 15.5 L-80 LTC-MOD 38.6' 8975' 0' 5929' 7740 6290 Tubing 3 1/2" 9.2 L-80 EUE-abm 26.9' 8718' 0' 5738' 10160 10540 Liner 3%" 9.2 L-80 BTC 8718' 9560' 5738' 6369' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Flo-Pro FloVis mud (10.0 ppg) — Drilling operations: Chloride-based Flo-Pro FloVis mud (10.0 ppg). While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 2F-17 does not contain a subsurface safety valve (SSSV). The well will be loaded with 13.0 ppg Potassium Formate completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes(-234 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume"is defined as the tubing volume plus the volume of the longest lateral. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP Page 3 of 7 .4-" 3 5 y 4/30/2013 PTD Application: 2F-17L1, 2F-17L1-01 &2F-17L1-02 promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 12.9 ppg will be initially targeted at the window based on the recent static bottom-hole pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 2F-17 L1 Window(9,082' MD,6,008'TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(12.7 ppg) 3968 psi 3968 psi Mud Hydrostatic(10.0 ppg) 3124 psi 3124 psi Annular friction (i.e. ECD, 0.095 psi/ft) 863 psi 0 psi Mud +ECD Combined 3987 psi 2996 psi (no choke pressure) (overbalanced (underbalanced —19 psi) —844 psi) Target BHP at Window(12.9 ppg) 4030 psi 4030 psi Choke Pressure Required to Maintain Target BHP 43 psi 906 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Summary of Operations Background Well 2F-17 is a Kuparuk A-sand/C-sand injection well equipped with 31/2"tubing and a 3 W'liner. Three proposed A-sand CTD laterals will help support wells to the south in area 2. Prior to drilling, a rig work- over will install a new packer will be installed above the current packer. A variance from the requirements Page 4 of 7 4/30/2013 ORIG1Nt ' PTD Application: 2F-17L1, 2F-17L1-01 &2F-17L1-02 of 20 AAC 412(b)has already been requested for placing this new packer greater than 200' above top of the perforations. A mechanical whip-stock will be placed in the 3-1/2"tubing at the planned kickoff point(9082'). The 2F- 17L1 sidetrack will exit through the 3-1/2"tubing at 9,082' MD and will target the A4 sand south of the existing well with a 4318' lateral. The hole will be completed with a 2-%" slotted liner to the TD of 13,400' MD with an aluminum billet at 10,900' MD. The 2F-17L1-01 lateral will kick off from the aluminum billet at 10,900' MD and will target the A4 sand south of the existing well with a 2500' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 13,400' MD with an aluminum billet at 9,375' MD. The 2F-17L1-02 lateral will kick off from the aluminum billet at 9,375' MD and will target the A4 sand south of the existing well with a 1325' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,700' MD ran back into the 3 '/2"tubing. Pre-Rig Work 1. RU RWO. a. Pull existing 3 '/2"tubing b. Run FA(3.0")stacker packer c. Re-install 3 'A"tubing 2. RU slickline. Drift&tag PBTD. i. Last tag @ 9404' RKB (223' rathole) 3. RU E-line. i. Caliper 3-1/2"liner from 9200' MD to 8700' MD. ii. Log GyroData gyro from surface to 8650' RKB. iii. Run whipstock oriented for high side exit 4. RDMO E-line. 5. 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. 2F-17L1 Sidetrack(A4 sand,south) PTO 2 /3 O 3-- 5 a. Set whip-stock at 9,082' MD b. Mill 2.74"window at 9,082' MD. c. Drill 2.70"x 3.00"bi-center lateral to TD of 13,400'MD d. Run 2%"slotted liner with an aluminum billet from TD up to 10,900' MD 3. 2F-17L1-01 Lateral(A5 sand,south) n 7`D Z/,j a 5-1 a. Kick off of the aluminum billet at 10,900' MD b. Drill 2.70"x 3.00"bi-center lateral to TD of 13,400' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 9,375' MD 4. 2F-17L1-02 Lateral(A5 sand,south) P 7-0 2/3 0 6. D a. Kick off of the aluminum billet at 9,375' MD b. Drill 2.70"x 3.00"bi-center lateral to TD of 10,700' MD c. Run 2%"slotted liner from TD up to 9,077' MD,up inside the 3'h"tubing 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV(if needed). Page 5 of 7 4/30/2013 PTD Application: 2F-17L1, 2F-17L1-01 &2F-17L1-02 3. Turn over to pre-production for 1—3 months 4. Return well 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. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment,the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2F-17 CTD laterals will be displaced to an overbalancing fluid (13 ppg KFormate) prior to running liner. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%"liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class I I liquids to KRU 1R Pad Class I I disposal well — Class II drill solids to Grind &Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Page 6 of 7 4/30/2013 PTD Application: 2F-17L1, 2F-17L1-01 &2F-17L1-02 Lateral Name Distance 2F-17L1 4320 2F-17L1-01 4320 2F-17L1-02 6600 — Distance to Nearest Well within Pool (heel measured to offset well) Lateral Name Distance Well 2F-17L1 2075 2F-13 2F-17L1-01 3175 2G-09 2F-17L1-02 2300 2F-13 16. Quarter Mile Injection Review(for injection wells only) (Requirements of 20 AAC 25.402) There are no wells that lie within 1/4-mile of the proposed 2F-17 CTD laterals. See the attached schematic for confirmation. The existing 2F-17 wellbore already serves as a service water injection well.The last state witnessed MIT-IA was April of 2013. 17. Attachments Attachment 1: Directional Plans for 2F-17L1, 2F-17L1-01 & 2F-17L1-02 Attachment 2: Current Well Schematic for 2F-17 Attachment 3: Proposed Well Schematic for 2F-17L1, 2F-17L1-01 & 2F-17L1-02 Page 7 of 7 4/30/2013 N , -,,. KUP 2F-17 ConocoPhillips ,' Well Attributes Max Angle&MD TD Alaska.Inc ;: Wellbore APIJUWI 'Field Name Well Status Inc/(') MD(MB) Act Blot(RKB) cnooc f,a,pz 1, 500292273100 KUPARUK RIVER UNIT INJ 60.13 7,90000 9,561.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date .. onT'�T�A)<^r � SSSV:NIPPLE Last WO: 2/5/1997 - me. -Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,399.0 2/25/2012 Rev Reason:WELL REVIEW osborl 7/9/2012 _.---.--------.___-- Casing Strings HANGER,27 i'. sa Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd CONDUCTOR 16 15.062 430 121.0 121.0 62-50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 75/8 6.750 41.3 4,018.5 3,136.0 29.70 1$0 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd PRODUCTION 51/2 4.767 38.6 8,975.4 5,929.5 15.50 L-80 LTC-MOD Casing Description String 0... Stri g ID._'Top(RKB) Set Depth(f...Set Depth /3)...String Wt...String...String Top Thrd CONDUCTOR, ' LINER 31/2 2.867 8718.0 9,560.5 6,396.0 920 L$0 BTC 43721 v - Liner Details Top Depth (TVD) Top Inel Nomi... NIPPLE,498 Top(ftKB) (ROB) P) hem Description Comment ID(in) 8,718.0 5,738.5 40.70 PACKER BAKER SABL-3 w/LINER HANGER 2.867 I=ler. Tubing Strings I Tubing Description Stdng 0... String ID...Tap(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 31/2 2.902 26.9 8,718.0 5,738.4 9.30 L-80 EUE-abm Completion Details Top Depth (TVDy Top Inc/ Nomi... Top(ftKB) (RKB} F) hem Description Comment ID(in) 26.9 26.9 0.42 HANGER FMC GEN IV TUBING HANGER 3.500 on. 495.7 495.7 0.42 NIPPLE CAMCO DS NIPPLE 2.812 GAS 3LIFT, 8,694.5 5,720.7 41.56 NIPPLE CAMCO D NIPPLE 2.750 .704 8,702.2 5,726.4 41.28 LOCATOR BAKER LOCATOR 3.000 IR 8,703.4 5,727.3 41.24 PBR BAKER w/10'Stroke 3.000 8,717.4 5,737.9 40.73 ANCHOR BAKER KBH-22 ANCHOR 3.000 Other in Hole reline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Ind Top(ftKB) (ftKB) F) Description Comment Run Date ID(in) 8,331.0 5,482.7 52.53 PATCH 2.71"X-SPAN TTS PATCH w/10'ELEMENT 4/21/2011 2.250 8,694.5 5,720.7 41.56 NIP Reducer 2.75"NIPPLE REDUCER 4/8/2011 1.810 Perforations&Slots Shot S 48-4.0 8 • Top(ftKB) tm(ftKB)7(ftKB)D) �(RKB)D} Zone Date (sh s p ) ( Type Comment 9,038.0 9,048.0 5,975.4 5,982.8 C-4,UNIT B, 8/2/1997 6.0 IPERF 60 deg.Phasing;2.5"HSD DP 2F-17 GAS LIFT, 6,336 9,126.0 9,136.0 6,041.8 6,049.4 A-5,2F-17 8/2/1997 6.0 IPERF 60 deg.Phasing;2.5"HSD DP 9,164.0 9,181.0 6,071.4 6,084.4 A-4,2F-17 5/6/1997 4.0 IPERF 180 deg.Phasing;2.5"HSD BH I Notes:General&Safety End Dote Annotation PATCH,6,331 10/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 a GAS LIFT, 8,643 1. NIP Reducer, I 8.695- NIPPLE.8,695 I LOCATOR, 8,702 PBR,6,703 . ANCHOR, 8,717 PRODUCTION, 39-8.975 IPERF, 9,038-9,048 Mandrel Details Top Depth Top Port (ND) Inel OD Valve Latch Size TRO Run'. :912591E Stn Top(ftKB) (RKB} (`I Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 3,103.7 2,646.0 58.22 BST AXT 1 GAS LIFT DMY Ti 0.000 0.0 4/1/1997 6:30 IPERF, 2 6,335.5 4,410.4 57.44 BST AXT 1 GAS LIFT DMY Ti 0.000 0.0 4/1/1997 12:30 9,164-9,167 3 8,642.9 5,683.1 44.71 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 5/7/1997 9:30 LINER, 8,71&9,561 TO.9.561 OA - ORIGIN/!:tom onocoPh llips Rig Workover Procedure 2F-17 Kuparuk Injector Pull and Replace 3'//"Tubing with Stack Packer/CTD Setup • Qc ■ hilIi i Conductor Shoe -16"62#,H-40 @ 2 F-17 1 121'MD Proposed RWO Stacked Packer/CTD Setup Camco DS Landing Nipple @ 500't lD 4 (2.8751D) r g d1 +M- Casing Shoe-7-518"29.7#,L-80 BTC 4019'MD I Proposed RWO 'd • 3-':.Camco OS Nipple @ XXXX'RKB(2.8751D) • 3-'W 9.3#L-80 EUE IBTM-SCC Tubing to Surface • 3-W KBG-2-9 Gas Lift Mandrel @: MD TVD l .4.-- Campo KBG-2-9 Gas Lift Mandrel XXXX' Xxxx @ XXXX'RKB • 3-'W x 5-W FA Packer @ XXXX'RKB(3^ID) • 3-W Camco X Landing Nipple @ XXXX'RKB(2.813" ID) c--,_ -._, #-4-- PBR 0 XXXX'RKB Existinci Completion 3-W x 5-W Baker FA Packer ca XXXX'RKB • Baker 3-W PBR @ 8,703'RKB(3'IO) , 4- (31D)• Baker KBH-22 Anchor-Seal Nipple @ 8,71T RKB(31D) I finer Too c '11-- Camco X Nipple©XXXX'RKB(2.812"ID) • Baker SABL-3 Liner Top Packerllanger @ 8,718'RKB (2.78 1D) " ' tt � J Baker 3-W PBR©8,703'RKB(3"ID) -4—Baker KBH-22 Anchor-Seal Nipple a@ 8,717'RKB(3"ID NE E—Baker SABL-3 Liner Top PackerrHanger(3 8.718'RKB(2.781 II — __.4_ Casing Shoe-5-1/2"15.5#,L-80 LTCM @ 8,975'MD - +t C4-Sand Perfs:9,038'-9,048'MD w----- KOP @ 9,082'MD 4 A5-Sand Perfs:9,126-9,136'MD imm -4 A4-Sand Perfs:9,164'-9,181'MD 4i--- Liner Shoe-3-W 9.3#,L-80,BTC @ 9,561'MD Monty M Myers-Wells Engineer Page 15 4/29/2013 0 0 v 2 2 To AS r a Si Q ° (p o N �` o @ V- V O N Q O J`."9 Jr.O p ,- u E n Li.0 7 C (,ri—Q NI-q a E Y m 1 GL m m Y a CON CO N. CK iri b) Y a � ©_ r to:( F-- 00 CO [0 Do N \ u) rn _ ri a) \ 1] o Q d C w o MC p uoCI� ■Co as Q (B p. co,e.:3,�- f2 O O U� (7 elm O a O • LJJ <(n n C C •- N °� I • o 1-1-0 m Q M 0 J CO 0-CV CO O J O Cy0 _ (y (V (c M (a4 I N ,-co Q I ) o) 0 x0 ri Y p N (V (V CV CV �� Q�■ \ c0(6 Ca) \ O N \ i _C) C- i N O IIE o A , n N Q yw ,---E O M // c� c�N C) t6 �. iIl_ / ii T E j W CO U l'SI 1 :619 o (`i 0 Ini rn oo � u) o 00 a`>o es �� �° a J"' Q o Q �t u> I o 0 rn C) co (nom C �@� Y o a, N p o us r- o N p O oo Q o 0 of `- 0 0 - (h LL *t- N OA r` 0 OR ! G ConocoPhilhi ps Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2F Pad 2F-17 2F-17L1-02 Plan: 2F-17L1-02_wp01 Standard Planning Report 25 April, 2013 BAKER HUGHES ConocoPhillips or its affiliates II FA, ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-17 @ 128.80ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-17 Survey Calculation Method: Minimum Curvature Wellbore: 2F-17L1-02 Design: 2F-17L1-02_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2F Pad Site Position: Northing: 5,949,341.82 ft Latitude: 70°16'21.978 N From: Map Easting: 517,392.55 ft Longitude: 149°51'33.576 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.13° Well 2F-17 Well Position +N/-S 0.00 ft Northing: 5,948,755.07 ft Latitude: 70°16'16.204 N +E/-W 0.00 ft Easting: 517,493.62 ft Longitude: 149°51'30.673 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 93.20 ft Wellbore 2F-17L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2012 6/30/2013 15.49 79.87 57,348 Design 2F-17L1-02_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,375.00 Vertical Section: Depth From(TVD) +NI-S +E1-W Direction (ft) (ft) (ft) r) -96.80 0.00 0.00 192.71 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,375.00 89.80 176.77 5,964.47 -6,143.10 -1,768.44 0.00 0.00 0.00 0.00 9,445.00 98.20 176.77 5,959.59 -6,212.76 -1,764.50 12.00 12.00 0.00 0.00 9,555.00 97.98 163.44 5,944.03 -6,319.79 -1,745.83 12.00 -0.20 -12.12 270.00 9,625.00 90.08 160.57 5,939.11 -6,386.14 -1,724.26 12.00 -11.29 -4.09 200.00 9,875.00 89.47 190.57 5,940.11 -6,632.55 -1,705.17 12.00 -0.24 12.00 91.20 10,125.00 89.54 160.57 5,942.31 -6,878.96 -1,686.07 12.00 0.03 -12.00 270.00 10,425.00 87.69 196.53 5,949.80 -7,173.86 -1,678.56 12.00 -0.62 11.99 93.30 10,700.00 88.06 163.51 5,960.27 -7,444.87 -1,678.64 12.00 0.14 -12.01 270.00 4/25/2013 3:43:52PM Page 2 COMPASS 2003.16 Build 69 Li fl I f. _ 4 1 k ® ' ConocoPhillips or its affiliates INS Conoco Phillips Planning Report HUGHES Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-17 @ 128.80ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-17 Survey Calculation Method: Minimum Curvature Wellbore: 2F-17L1-02 Design: 2F-17L1-02_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (0) (ft) (ft) (ft) (ft) (°/100ft) (0) (ft) (ft) 9,375.00 89.80 176.77 5,964.47 -6,143.10 -1,768.44 6,381.64 0.00 0.00 5,942,608.48 515,739.64 TIP/KOP 9,400.00 92.80 176.77 5,963.90 -6,168.05 -1,767.03 6,405.67 12.00 0.00 5,942,583.54 515,741.11 9,445.00 98.20 176.77 5,959.59 -6,212.76 -1,764.50 6,448.72 12.00 0.00 5,942,538.85 515,743.74 Start 12 dls 9,500.00 98.15 170.10 5,951.76 -6,266.81 -1,758.28 6,500.08 12.00 -90.00 5,942,484.81 515,750.08 9,555.00 97.98 163.44 5,944.03 -6,319.79 -1,745.83 6,549.02 12.00 -90.95 5,942,431.87 515,762.66 3 9,600.00 92.91 161.59 5,939.77 -6,362.50 -1,732.37 6,587.73 12.00 -160.00 5,942,389.19 515,776.22 9,625.00 90.08 160.57 5,939.11 -6,386.14 -1,724.26 6,609.00 12.00 -160.18 5,942,365.58 515,784.37 4 9,700.00 89.89 169.57 5,939.13 -6,458.53 -1,704.96 6,675.38 12.00 91.20 5,942,293.23 515,803.84 9,800.00 89.65 181.57 5,939.53 -6,558.05 -1,697.25 6,770.77 12.00 91.20 5,942,193.74 515,811.78 9,875.00 89.47 190.57 5,940.11 -6,632.55 -1,705.17 6,845.18 12.00 91.15 5,942,119.23 515,804.04 5 9,900.00 89.47 187.57 5,940.34 -6,657.24 -1,709.11 6,870.13 12.00 -90.00 5,942,094.54 515,800.16 10,000.00 89.49 175.57 5,941.25 -6,757.01 -1,711.84 6,968.06 12.00 -89.97 5,941,994.77 515,797.66 10,100.00 89.53 163.57 5,942.10 -6,855.18 -1,693.77 7,059.85 12.00 -89.86 5,941,896.66 515,815.96 10,125.00 89.54 160.57 5,942.31 -6,878.96 -1,686.07 7,081.35 12.00 -89.76 5,941,872.90 515,823.71 6 10,200.00 89.03 169.55 5,943.24 -6,951.34 -1,666.75 7,147.71 12.00 93.30 5,941,800.57 515,843.19 10,300.00 88.39 181.54 5,945.50 -7,050.83 -1,659.00 7,243.06 12.00 93.19 5,941,701.10 515,851.18 10,400.00 87.82 193.53 5,948.82 -7,149.73 -1,672.08 7,342.42 12.00 92.92 5,941,602.18 515,838.33 10,425.00 87.69 196.53 5,949.80 -7,173.86 -1,678.56 7,367.38 12.00 92.52 5,941,578.05 515,831.91 7 10,500.00 87.72 187.52 5,952.81 -7,247.08 -1,694.16 7,442.23 12.00 -90.00 5,941,504.80 515,816.48 10,600.00 87.84 175.52 5,956.69 -7,346.78 -1,696.80 7,540.08 12.00 -89.64 5,941,405.10 515,814.07 10,700.00 88.06 163.51 5,960.27 -7,444.87 -1,678.64 7,631.77 12.00 -89.17 5,941,307.06 515,832.45 Planned TD at 10700.00 4/25/2013 3:43:52PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates Pr ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-17 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-17 @ 128.80ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-17 Survey Calculation Method: Minimum Curvature Wellbore: 2F-17L1-02 Design: 2F-17L1-02_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2F-17L1_Faultl 0.00 0.00 0.00 -6,675.27 -1,660.60 5,942,076.62 515,848.71 70°15 10.551 N 149°52'18.973 W -plan misses target center by 5940.41ft at 9866.98ft MD(5940.03 TVD,-6624.66 N,-1703.77 E) -Rectangle(sides W500.00 H1.00 D0.00) 2F-17L1-02_T2 0.00 0.00 5,942.00 -6,911.23 -1,685.15 5,941,840.63 515,824.70 70°15'8.231 N 149°52'19.686 W -plan misses target center by 8.89ft at 10156.45ft MD(5942.62 TVD,-6908.93 N,-1676.59 E) -Point 2F-17L1-02_T1 0.00 0.00 5,939.00 -6,354.09 -1,728.86 5,942,397.62 515,779.71 70°15'13.710 N 149°52'20.961 W -plan misses target center by 6.08ft at 9593.13ft MD(5940.16 TVD,-6355.99 N,-1734.52 E) -Point 2F-17L1_Fault2 0.00 0.00 0.00 -7,464.37 -1,646.43 5,941,287.64 515,864.70 70°15'2.791 N 149°52'18.556 W -plan misses target center by 5956.88ft at 10463.27ft MD(5951.34 TVD,-7210.92 N,-1687.96 E) -Rectangle(sides W500.00 H1.00 D0.00) 2F-17L1-02_T3 0.00 0.00 5,960.00 -7,464.37 -1,647.43 5,941,287.64 515,863.70 70°15'2.791 N 149°52'18.585 W -plan misses target center by 36.80ft at 10700.00ft MD(5960.27 TVD,-7444.87 N,-1678.64 E) -Point 2F-17 CTD Polygon 0.00 0.00 0.00 -5,890.67 -1,892.80 5,942,860.61 515,614.70 70°15'18.267 N 149°52'25.733 W -plan misses target center by 5960.64ft at 9600.00ft MD(5939.77 TVD,-6362.50 N,-1732.37 E) -Polygon Point 1 0.00 -5,890.67 -1,892.80 5,942,860.61 515,614.70 Point 2 0.00 -5,891.35 -1,592.77 5,942,860.63 515,914.70 Point 3 0.00 -7,445.65 -1,533.30 5,941,306.62 515,977.78 Point4 0.00 -8,648.73 -1,550.03 5,940,103.63 515,963.85 Point 5 0.00 -9,266.96 -1,475.43 5,939,485.63 516,039.88 Point 6 0.00 -10,333.95 -1,089.82 5,938,419.65 516,427.93 Point 7 0.00 -10,446.36 -1,356.10 5,938,306.63 516,161.94 Point 0.00 -9,270.28 -1,775.47 5,939,481.62 515,739.88 Point9 0.00 -8,641.05 -1,850.05 5,940,110.61 515,663.84 Point 10 0.00 -7,430.96 -1,834.30 5,941,320.61 515,676.78 Point 11 0.00 -5,890.67 -1,892.80 5,942,860.61 515,614.70 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (1 11 4,018.00 3,006.50 7-5/8" 7-5/8 9-7/8 8,932.00 5,769.41 5 1/2" 5-1/2 6-3/4 10,700.00 5,960.27 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,375.00 5,964.47 -6,143.10 -1,768.44 TIP/KOP 9,445.00 5,959.59 -6,212.76 -1,764.50 Start 12 dls 9,555.00 5,944.03 -6,319.79 -1,745.83 3 9,625.00 5,939.11 -6,386.14 -1,724.26 4 9,875.00 5,940.11 -6,632.55 -1,705.17 5 10,125.00 5,942.31 -6,878.96 -1,686.07 6 10,425.00 5,949.80 -7,173.86 -1,678.56 7 10,700.00 5,960.27 -7,444.87 -1,678.64 Planned TD at 10700.00 4/25/2013 3:43:52PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2F Pad 2F-17 2F-17L1-02 2F-17L1-02_wp01 Travelling Cylinder Report 24 April, 2013 BAKER HUGHES ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-17 Project: Kuparuk River Unit TVD Reference: 2F-17 @ 128.80ft Reference Site: Kuparuk 2F Pad MD Reference: 2F-17 @ 128.80ft Site Error: 0.00ft North Reference: True Reference Well: 2F-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-17L1-02 Database: EDM Alaska Prod v16 Reference Design: 2F-17L1-02_wp01 Offset TVD Reference: Offset Datum Reference 2F-17L1-02_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,375.00 to 10,700.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,266.80ft Error Surface: Elliptical Conic Survey Tool Program Date 4/24/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 9,050.00 2F-17(2F-17) GYD-CT-CMS Gyrodata cont.casing m/s 9,050.00 9,375.00 2F-17L1_wp02(2F-17L1) MWD MWD-Standard 9,375.00 10,700.00 2F-17L1-02_wp01(2F-17L1-02) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 8,932.00 5,898.21 5 1/2" 5-1/2 6-3/4 4,018.00 3,135.30 7-5/8" 7-5/8 9-7/8 10,700.00 6,089.07 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2F Pad 2F-17-2F-17-2F-17 9,375.00 9,550.00 296.64 108.99 259.34 Pass-Major Risk 2F-17-2F-17L1-2F-17L1_wp02 9,444.47 9,450.00 10.70 1.47 9.36 Pass-Major Risk 2F-17-2F-17L1-01-2F-17L1-01_wp01 9,375.00 9,375.00 0.00 0.34 -0.22 FAIL-Major Risk 2F-18-2F-18-2F-18 Out of range 2F-18-2F-18L1-2F-18L1_wp03 Out of range 2F-18-2F-18L1-01-2F-18L1-01_wp01 Out of range 2F-18-2F-18PB1-2F-18PB1 Out of range 2F-19-2F-19-2F-19 Out of range 2F-19-2F-19A-2F-19A Out of range 2F-19-2F-19AL1-2F-19AL1 Out of range 2F-19-2F-19AL2-2F-19AL2 Out of range 2F-19-2F-19AL3-2F-19AL3 Out of range 2F-19-2F-19PB1-2F-19PB1 Out of range 2F-19-2F-19PB2-2F-19PB2 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/24/2013 3:13:37PM Page 2 of 8 COMPASS 2003.16 Build 69 0 (1 c..1 ,, c, i' ' �,- ConocoPhillips or its affiliates FAQ ConocoPt1iiiips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-17 Project: Kuparuk River Unit TVD Reference: 2F-17 @ 128.80ft Reference Site: Kuparuk 2F Pad MD Reference: 2F-17 @ 128.80ft Site Error: 0.00ft North Reference: True Reference Well: 2F-17 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-17L1-02 Database: EDM Alaska Prod v16 Reference Design: 2F-17L1-02_wp01 Offset TVD Reference: Offset Datum Reference Depths are relative to 2F-17 @ 128.80ft Coordinates are relative to:2F-17 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.13° Ladder Plot 300 I � � I I I I I 1 I I I J J J J J J I 1 I I 1 I I I I I I GLLJJ _m (0 J J a) I (n I � I w x,150 - U 0 a) J J J J J E' a) U 75 I � ' J J J J I r L IA 0 I 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND 2F-17,2F-17,2F-17 V3 —*- 2F-1 7,2F-17L1,2F 17L1 wp02V0 -- 2F-17,2F-17L1-01,2F-17L1-01 wp01 VO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/24/2013 3:13:37PM Page 8 of 8 COMPASS 2003.16 Build 69 1 Oil g I Eli a. s -g " $ ' g 4. �� o C F o a. o Q ? ^`O' N _ v C ry gg a , . a a 8 E e t ■ n o 0 N o v, • oa o N ' L'' lEill 1z ttuu° 4 W d d PI ti N v q • $ � Ei 4 gi P Cam-. N U.-el n J COI N N . -_ ^ 0 30 8 i 1 g o h S r - o N UJ AL' CC• 4u (m/8°CV)(+)quoNJ(-)g3noS R • a $ 0 UJ g 0 OM o $ I `�i $ � aye a �• o a.o is EY fladl Z .D N 5 aN , E y Q O QHln.n<.n(o lid ill 8 1 9 :E9-., — g '`° 8W0P8 dLL 2° evN��mR y 2 to E" 9n o00 2 2 �.- `•1� / $ 11d_d_LL DoN[1.o.“?V8tV 0. / Y Y N j, Z 31 .i8i ^^o�i aNa4 .ii J � £° c 4 FS v o N R ^ g 2.`=' g:'-`A4.. _ o °i v w W W 4'4 4 W R •■ gi gi Epn c3wn .0 v c ,n o-—.,:0m ry a S N ::: 0 0 V 3S o minnnn M ° ✓4 r", ,^ k / 8 " e R N N o o Wel as MOO (u!8 09)g3daQ p39.1aA 3111.1_ TRANSMITTAL LETTER CHECKLIST WELL NAME R/R(A, W-17.0 -02, PTD# 02/3 0(A) Development ',Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: gyon.QA 1Qi ,f POOL: 14Apakk,K 1Q;u4.r K Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well a.F- 11.1 (If last two digits in Permit No. 0Z 130S-1?OS-1? ,API No. 50-029 - 203 1 -01 - 00. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 To U) CD 0 (0 a) 0 vi - 0 (n 0 (n O C d C_ O C m = C L a ° 3 -`o n a) a) c N co c co U oo_ C N O CO O I N co N-o w O 0 N o_ m E w c t u) a W 0 ° m 0• ots c co E O �° o o 2 a m m m "' a) U w O m co C C N a) o) > d U c L c n L 0 co > .0 o on .3 c o -o '3 (0 Q C O T 0 - ots t ° 0 7 N a) o.) N 3 O' 'O Z > U n C_ N = O a) E O O) n ° C C 3 0 U) L .0 C U) O- 7 = m = O) N .E o ° c 0 0 3 w >3 3 J d O L U) N D 0 0 0) .Q m > N- o- v () 4 a5i 0 -o '5 n O E w Y Ll O i > V) L "O l (n CO _ I- (0 Q O U E _ ° 0 _° 0 n o c co > c m o E o Q h rn 0 N 2 c Q c•) r E a m 2 c 0 - o Y o) m o Y 0 E W m m N co Tii C m o N > o a) 0 n 0 Q 2 > < a n = m N ° 0 C E OD 0 d co 2O p J N N L 3 0 U I- Q O o o C a) z st 7 D Y 72 - - 't M 2 a) Y c 0 o a m .3 Q a '9 2 0 o u. o 1- a) Y m = (.) w c E a N o N N Z Y •U) c 0 , > w° c _0 O J O 0) 0) 0 n T 0 co u) d a) 3 c c C C m 0 It ai o (L° - o 0 = ° ° N .N '� 'E 0 c o. o ° w 2 ~ m I� U a) ) m @ C.7 Lo Y L 3 U LL O CO U U O N >. N C -0 O• [L U U 0 N = w - 0 0. Z o N Q m (Ni r 3 0 0 m E is 0 E U)i 0 'c ° a) 0 J D d V = m `- - c CO 0 L 'X E U) 0) - a L to 0 cC D O O °� m >0 0 > > 2 co 2 O a N a) x 0 c W Q Y Y U U Q N > U co co 0 d 2 I W O a cC w (1) a a N U) U) aU) U)) Ui U)) a)i aO) U)) U)) CI) UN) U)) aU) a a a a o U) aU) a N a aU) aai N o U) U)) U)) O U) a a a a z z >- >- >- >- >- >- >- >- >- >- >- )- >- )- >- Z Z Z Z Z >- >- z >- Z >- >- >- >- >- >- >' Z >- Z Z Z T H ro 0 v T a Vo m U 0 O Ts C 0 0 •2 E 3 E a) O U U 'j C Lo O O o O v `T O T y a E co Q C L_ O E v a* 0 c a) >' 0 .J o m E 3 0 0 -2 3 M n 0 T > O 0 c 0 U C N C '` m @ a o U) 0 0) >o E 0 ° �` cC m a) (� N a) O O co �- ' ) tx N a j E O N ° _ a (Q 0 V U) dV O T LL C c O) N co O" C _o f5/) w f6 Q L a) n L -° y 0 `O C a) co a) a) D I}a) c c - 0 0 w t c E 0 ° m c o E N fX O 7 )) C > .0 N C o N o N O C N C > Q) w o c 3 .� °- 3 r a n 8 0 .N n o o n n o Ct -o u) ui = a`) 0 a) m T a) 0 -° o xs E a) m 'E o M -o O 3 m 0 2 cc U o = L o) () > w m ° 3 c o) L c 0 0 0- _ (0 o a 0 0 a) CD Z -° ° .E ° N c `n m > n c > m -°o a ° 0 d C c o `O ° a) co E E _ -o c c E aa)) o C C ti f- _ c o 06 X C 0 o) 0. N L n c c Q Y C o o `o v m °� c o 0 0 ° o) 0 U 1 n 0 0 o ai d °- 3 0 > h 2 Y o a Q o E p 0 a) c .E > o c c ° ° m .m @ o 0 0 > m o .@ .c c a m a o rn o 0 n 0 0 0 _0 o O 0 c - o E 3 a`) o a L is 3 = a) E a E m e -o M m OS n n L L a m CO a 0 m ` E c" � N M m 'N L c o 0 o n 3 0 .c T 3 c SO Li)o d `o .0 a c 0 h '(a 0 0 0 3 3 > m a) .. v o v°O o of n a c 0 3 o CO Z w�°�• O C O C '- :o :o > o a) .Q -O O (0 O p a) O O C D- o N -O N m o o) C -0 n N C 0 0_ 13 m m m 0 0 0 5 0 o E a) E L o a) c 0 n -0 o a`> 0 � 0 0 n c v U n o 0 0 - -0 a) •- E a m E o N c 0 o �2) = U _co CU E m 0 0 O) a) 0 tN N n - a) o) O- (E m (9 m O) CU 0 0 O) C U 3 N E a) o N C L 0 m U E m 3 m CO m :c c 0) > > N m n - o .0 0 I c n 0 '4) o n a) O O @ a) C n n 0 - T 0 L L 4 3 L_ _° U C a) a) > O) C m a) d n _0C1) O U O 0 a) C T E•it U C 0 E a) 0 0 0 0 o .c c c " 0 m m m m ° N m s 3 2 7 0 u) :E o 0 m o c c E O > w 0 3 U) U) a m m E a 3 ° o ° - 0 0 ._ 0 m = c m ° m co Z C C - U 0 U o m ° ° .0 +0 N U co O U a) O O - m m 45 m r U) O' E '3 a) .0 ° 2 o �. U. N Q 0 O O O 0 0 .1) .1 m m Q ° a) n a 0 > > 3 C O . 6 a) C7 w w Y Y co L n •E a) m 4) J 0 o Zr) ° '� N N N 7 a a a o a`> (CO N 3 2 0 7 2 2 2 as -o m -o - - 0 o_ t-.)r ° O' aU) d) CU 'N a) o m 0 0 Tza _ID � � � (n • OOaaUaa 00) 0000 < ± a2000U � l'). g 0_ 00 (00 W E r O N M V (() (0 CO 0) O N M V C) (D h W C)) O N M V (O (0 h 00 C)) I - N co V (O (0 N- co 0) .-- - - - - - - - N N N N N N N N N N C)) CO CO CO CO CO C)) CO CO CO U co M co a) N a) O r U C ce O o CO N CO CO N o)(., W O co 0 co C (n 1° °'E O. T U0 E - N c 0i o) o uj iIv a s c co < > a) a s 0 Q Q w Q c9 Q
