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211-095
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.1 L - OyWell History ile Identifier Organizing(done) Two-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: C for Items: ❑ aps: Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: al. Date: 31 isiII ° Project Proofing MP BY: CM Date: 7/31 ) ! /s/ Scanning Preparation x 30 = ( D =TOTAL PAGES (07 (Count does not include cover sheet) f BY: (Mariam Date: /3 1 ' 14" /s/ (y) Production Scanning Stage 1 Page Count from Scanned File: W U g (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO 7J3i BY: 4110 Date: I op/s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith _ Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc a� o o ii $O6 J N O6.6 ( o N - N l �I � C III Q' C' fy U V } > c O 0_ (� t L 1 31 4 i r) o voi N E w u) CL w m a 'I o Q 0 a� i U11 0sh �'n 1 ° 2 �J �E- Er. g SII m o � o > 0 0 0 o Z N V N N N N NN 01 N N N N N N Z O J O O O O x{ Q W c c c c c c ig N m 11 c =O U a a a CD a ses < x 0 0 0 0 O O E Ce a :° as alo 0 0 0 0 D CO ° r) ch ch ch r) Z Z CL -J U � Cn � 0) rnco LC) cnrn Q >3. , 1 r11 W cc 0 v` Ce 0. O ! ! C N M N O NO N Z 1 Ali U N OD OD OD OD co W ZJ N U v oI Z cL a ° Z Z` I-° O Q y 7 1 1 w O 11 O CL rn o 0 0 c >, E I O. N OI ZI' Jd U U 0 N O I C r cl y 0 O H O Ntgal E wCDO_ gym o o N On On U t-1 U 1 m i J N c I QN F. w a 0 y C 0 11 o 1 CO > N ''I m Il c C�/O� l v� Q p N 0 c 1 Y 10 Qa ZI ! .>, .>-. .>, .>. a o N N Z Q N U I on ° j Z N m N 0IV E J ; 7 7 .y V) N ':.U) V) N N N CD CO l j C C C C H, 1 C C O O O O I N I��1 H a 10 OU N 7 > > 7 '1 C I (0 i! 0! Z - c c c c lo-+ I ; N D - - i O6 Z 0 0) •� E O � tn > ;I ZO J y y a o •H,(Z) m N CO i c0 2 ce O O O W O Zco m d Q d Q �. l0 w a O LL O.. I > o E EI0 E E ? -o °' i CC •� 1, Z V Li o m 16 10 J > i „, 0 O i 0 as, w• p)-. Q J N Z Q O.. N M ' W N C gi Q 9 • 1i, d Z N N C CD i C bj A O) Z W •U °U O O LL, N N d 1; • I� o J C) U M >`•N I� E I; d a III it 0 i 3 J0I—! W -J J W _ ct 0 <CL o 1fu -Prbz� Regg, James B (DOA) i I o5'Sb From: CPF1 Prod Engr[n1269@conocophillips.com] Sent: Tuesday, May 15, 2012 6:39 PM To: 'tom.maunder@alaska.gov'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr& Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr Subject: LPP/SSV Returned to service for 1E-27 on 05/15/2012 Tom/Jim: The low pressure pilot (LPP) on dual Kuparuk injector 1E-27 (PTD#211-095 and 211-096)was returned to service on 05/15/2012 after the well injection pressure increased above 500 psi. The current injection pressure is 820 psi and the injection rate is 1130 bwpd. This pilot had been defeated on 04/15/2012 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Dana Glessner ConocoPhillips Alaska, Inc Kuparuk CPF1 Production Engineer office (907) 659-7493 Dana.Glessner@conocophillips.com 'rod Engr ,April 16,2012 6:36 AM aalaska.gov' Lead Techs;CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr&Optimization Supv;Seitz, Brian;CPF1&2 Ops Supt; NSK Prod Engr Specialist;Gauer,Jenn L; CPF1 Prod Engr;Seitz,Brian PP/SSV Defeated for 1E-27 on 04/15/2012 Tom: The low pressure pilot(LPP) on dual Kuparuk injector 1E-27 (PTD#211-095 and 211-096)was defeated on 04/15/2012 when well was brought online and the injection pressure was below 500 PSI while on injection. This low pressure is most likely because this injector was pre-produced for some time after the CTD laterals were completed. As of 0630 hrs on 04/16/2012 , wellhead injection pressure is 316 psi; injection rate is 2180 bwpd. The LPP and SSV have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure on either well has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. /7- ,e.,-,24z. yam" ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.659.3910 Mobile - 303.489.8833 1 f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Rug F rforations r Fbrforate r Other r ProD=>Inj H2O Aker Casing r Rill Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: I 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 211-095-0 3.Address: 6.API Number: Stratigraphic r Service r P.O.Box 100360,Anchorage,Alaska 99510 50-029-20837-60 00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-25651 - 1E-27L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9310 feet Plugs(measured) None true vertical 6324 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 5966,6220 true vertical 0 feet (true vertucal) 5888,6120 Casing Length Size MD TVD Burst Collapse CONDUCTOR 53 16 85 85 SURFACE 2186 10 3/4 2218 2218 PRODUCTION 6257 7 6288 6182 LINER LI 861 23/8 9310 6324 RECEIVED MAY 1 5 2012 Perforation depth: Measured depth: 8,460.9-8,494.4:8,505.1-9,309.6 AOGCC True Vertical Depth: 6,293.8-6,296.8:6,297.8-6,323.7 Tubing(size,grade,MD,and TVD) 3.5,J-55,6245 MD,6142 TVD Packers&SSSV(type,MD,and TVD) PACKER-OTIS RRH RETRIEVABLE PACKER @ 5966 MD and 5888 ND PACKER-OTIS WD PERMANENT PACKER @ 6220 MD and 6120 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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 356 988 1366 1350 204 Subsequent to operation 0 0 2344 1453 913 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations GSTOR r WINJ 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: 312-062 Contact Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Title Production Engineering Specialist Signature ` i- _ \ Phone:659-7535 Date , 1 Form 10-404 Revised 11/2011 RBDMS MA F i ( �/L Submit Original Only 1E-27L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/15/12 Injection commenced 05/06/12 Initial State Witnessed(John Crisp)MITIA(Passed), Initial T/I/O=275/633/180. Pressured up IA to 3000 psi with 2.0 bbls of diesel. Start MITIA,T/1/0=275/3020/200, 15 min reading T/I/0=275/2968/210, 30 min reading T/l/0=275/2953/210. Bleed IA down, (5 min bleed, all fluid). Final T/I/0=275/500/180. 3ilo KUP 1 E-27L1 ConocoPhillips ' Well Attributes Max Angle&MD TD Alaska,1111' Wellbore APVUWI Field Nome Well Status Incl(') MD(RKB) Act Btm(RKB) CarnmRYlBps 500292083760 KUPARUKRIVERUNIT PROD 96.21 8,765.49 9,310.0 . """ Comment H25(ppm) ,Date Annotation End Date KB-0rd(It) Rig Release Date Well Contig:DEVIATED-1E-27Lt.4/10/20122:07:27 PM SSSV:TRDP ,Last WO: 12/30/1984 39.00 10/19/1982 Schematic-Acts& Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,362.0 7/30/2011 Rev Reason:WELL REVIEW osbod 4/10/2012 Casing Strings HANGER,27 i PIP Casing Description String 0... String ID...Top(RKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top Thrd 6. ILINER LI 23/8 1.992 8,449.4 9,310.0 6,323.7 4.70 L-80 STL Liner Details Top Depth _- (TVD) Top Incl N006... L Top(RKB) (RKB) Cl Item Description Comment ID(in) 8,449.4 6,293.0 85.78 BILLET ANCHORED BILLET 1.000 8,504.2 6,297.7 84.61 DEPLOY SHORTY DEPLOYMENT SLEEVE 1910 CONDUCTOR, Other In Hole(Nireline retrievable plugs,valves,pumps,fish,etc.) 3205 Top Depth (TVD) Top Incl SAFETY VEV. I Top(RKB) (RKB) P) Description Comment Run Date ID(in) 1'174 8,450.0 6,2930 85.76 WHIPSTOCK ANCHOR BILLET 9/9/2011 • Perforations&Slots Shot Top(ND) Btrn(TVD) Dens Top(RKB) Stet(RKB) IRKS) (RKB) Zone Date (ph-- Type Comment 41 dk 8,460.9 8,494.4 6,293.8 6,296.8 9/8/2011 32.0 SLOTS Alternating solid/slotted pipe- SURFACE.2-z- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg.3'non-slotted ends GAS LIFT, 8,505.1 9,309.61 6,297.8' 6,323.7 9/8/2011 32.0 SLOTS 5.198 Notes:General&Safety End Date Annotation 9/2/2011 NOTE:ADD LATERALS L1,L1-01,L1-02 SBR,5,940 El PACKER,5,966 lid INJECTION. 8,005 Ell L.../ INJECTION, 6O80 nn' N, PERF, E LEI, 61226.16] r , '— IPERE 6.177-6 185 E INJECTION, 6ION, Cement Squeeze.6,215 L-1 r LOCATOR, L 8.219 PACKER.6.220- ADAPTER, 6,224 SHE,8.224 ) ( PUNCHES. / 6 235 NIPPLE,6,239 ,1.I 503,6]45\ I PRo0UC6Mandrel Details 31fi,715,715 Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Ste Top(ftKB) (RKB) C) Make Model (In) Sery Type Type lin) (psi) Run Date Corn... 1 5,897.9 5,825.0 22.31 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.188 0.0 3/12/2012 WHIPSTOCK, 8,450 2 6,005.1 5,923.6 22.55 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 7/31/2011 3 6,080.1 5,992.5 23.55 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 SLOTS, 4 6,203.8 6,105.3 24.95 OTIS LBX ' 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 8,461-8,494 i SLOTS. 5,505-9,310 LINER LI. 8,449-9,310 TD(1E-27L1). 9.310 ................ ILTI ,.\} ° i t a r 111' ; t 1 " )I6, ( " iAi SEAN PARNELL, GOVERNOR LIt ik ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Robert D. Christensen NSK Production Engineering Specialist (�6 ConocoPhillips Alaska, Inc. oft \ A 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-27L1 Sundry Number: 312-062 Dear Mr. Christensen: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, 61-7 ,-- Daniel T. Seamount, Jr. Chair h DATED this Z Z.day of February, 2012. Encl. , ."‘ STATE OF ALASKA ALAS )IL AND GAS CONSERVATION COMMIS �,'?-td -1.7 4 �'L` APPLICATION FOR SUNDRY APPROVALS ,LA 20 AAC 25.280 1.Type of Request: Abandon [.j Rug for Redrill r Forforate New Pool T Repair wet r Change Approved Rogram r Suspend r Rug Perforations T Ferforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r StimulateAlter casing 9 r Other: Convert to Injector n • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development -, Exploratory r 211-095-0 - 3.Address: Stratigraphic r Service r 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20837-60 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No Ii 1E-27L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 Kuparuk River Field/Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9310 - 6324 9310' 6324' Casing Length Size MD TVD burst GuIl6Fo CONDUCTOR 80 16 112' 112' RECEIVED SURFACE 2186 10.75 2218' 2218' PRODUCTION 6685' 7 6715' 6564' FFB 1 6 2012 LINER L1 861 2.375 9310' 6324' Plaska Oil&Gas Cons.Commission Anchorage Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8461'-8494',8505'-9310' 6294'-6297',6298'-6324' 3.5 J-55 6245 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-OTIS RRH RETRIEVABLE PACKER MD=5966 TVD=5888 PACKER-OTIS WD PERMANENT PACKER MD=6220 TVD=6120 SSSV-CAMCO TRDP-1A-ENC MD=1874 TVD=1874 12.Attachments: Description Summary of Proposal F,F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service PI • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/20/2012 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG PI - Abandoned r Commission Representative: 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 Printed Name Rob-; D Chris sen Title: NSK Production Engineering Specialist Signature ' f ""-- 4 Phone:659-7535 Date 02frc,42.— t Commission Use Only Sundry Number:3I 1,..0(.0 a Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: Subsequent Form Required: /6 ..-4/0 1 I APPROVED BY f > Approved by: `, I COMMISSIONER THE COMMISSION Date: Z. I Z2 ) ( Form 10-403 Revised 1/2010 ,.h.�. z1"/16--.1—) RBOMS FE:' it in Duplicate �2i kV IGNAL '� 24 1E-27L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 1E-27-L1 from Oil Production service to WAG Injection service. Well 1E-27-L1 was completed as a Kuparuk Oil Pool A4 sand on September 8, 2011. Oil production rates and bottom hole pressures have declined and warrant converting this well to a service injector. Conversion of well 1E-27-L1 to WAG Injection service will provide pressure support to offset producers 1E-29, 1E-05 and 1E-06. The 16"Conductor was cemented with 272 sx AS II. The 10-3/4"Surface casing(2218' and/2218'tvd)was cemented with 1500 sx AS III, 250 sx AS I. The 7" Production casing (6715' and/6564'tvd)was cemented with 635 sx Class'G"&250 sx AS I.. A State Witenessed MIT-IA was last performed on 06/24/10; MITIA 2720 psi, 30 minutes, Passed The injection tubing/casing annulus is isolated via OTIS Retrievable Packer located @ 5966' and/5888'tvd. The injection tubing/casing annulus is isolated via OTIS Permanent Packer located @ 6221' and/6120'tvd. The Top of the Kuparuk"C"Sand is 6122' and/6032'tvd The Top of the Kuparuk"A"Sand is 6317' and/6208'tvd w r� •-w J -:. KUP 1 E-27L1 ConocoPhillips 0" Well Attributes Max Angle&MD TD Alaska,in, Wellbore API/UWI Field Name Well Status Incl I") MD(ftKB) Act Btm(16(8) Lonomnalkps 500292083760 KUPARUK RIVER UNIT PROD 96.21 8,765.49 9,310.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(5) Rig Release Date •••Well ConnoDEVIATED-IE-27L11/25201211.41.95 AM SSSV:TRDP Last WO: 12/30/1984 39.00 10/19/1982 Schematic-Actual Annotation Depth MB) End Date Annotation Last Mod... End Date Last Tag:SLM 6,362.0 7/30/2011 Rev Reason:PULL VALVE ninam 1/25/2012 Casing Strings HANGER,27PIP 9 Casing Description String o... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER L1 23/8 1.992 8,449.4 9,310.0 6,323.7 4.70 L-80 STL _ r Liner Details Top Depth (TVD) Top incl Nora.. i I Top(111(B) IRKS) (°) Item Description Comment ID(In) • 8,449.4 6,293.0 85.78'BILLET ANCHORED BILLET 1.000 • 8,504.2 6,297.7 84.61 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.992 CONDUCTOR, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 32-85 Top Depth (TVD) Top not SAFETY 1,KV,874 1 111 col Top(ftKB) (RKB) (°) Description Comment Run Date ID(In) 8,450 6,293.0 85.76 WHIPSTOCK ANCHOR BILLET 9/9/2011 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(MB)Btm(ftKB) (RKB) (ftKB) Zone Date (a,••• Type Comment SURFACE, .l l 8,461 8,494 6,293.8 6,296.8 9/8/2011 32.0 SLOTS Alternating solid/slotted pipe- 32-2,210 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends GAS LIFT, 8,505 9,310 6,297.8' 6,323.7 9/8/2011 -32.0 SLOTS 5,898 SBR,5.940 ---- fl PACKER,5,966 ow INJECTION, 6,005 1:1 ---- INJECTION, 6,030 6,122PE8,16RF7 / , . 6,1778,18.5 PERF, 11 II INJECTI 6ON,ON._ - 1 Cement Squeeze.6,215 LOCATOR, 8,219 PACKER.6.220 ADAPTER, ? 6,224 S SBE,6,224 1 IPERF, ==—) 5235-6,237 NIPPLE.6.239 SOS,6,295 PRODUCTION, i.- ---1Mandrel Details 3o-s,715 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (In) (psi) Run Data Cont.. 1 5,897.9 5,825.0 22.31 OTIS LBX 1 1/2 GAS LIFT OV RM 0.188 0.0 9/25/2011 WHIPSTOCK, 6,450 2 6,005.1 5,923.6 22.55 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 7/31/2011 3 6,080.1- 5,992.5 23.55 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 SLOTS 4 6,203.8- 6,105.3 24.95 OTIS LBX -1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 8,451-8,493 SLOTS, 8,505-9,3101 LINER LI. 8,449-9.310 TO(1E-271.1), J 9,310 PFr`P,VED1 BAKER PRINT DISTRIBUTION I,IST HUGHES p \O .2_77/1 AlasKa Oil SSI Gr. ••►S. '' '' !ISSIOA COMPANY ConocoPhillips,Alaska Inc. INTERME TE /,•hnlegeFINAL Yes (mandatory) WELL NAME 1E-27L1 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 9/9/2011 TODAYS DATE: 10/25/2011 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Or PHIN i S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I 1 I I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 I 1 I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP I 1 1 I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 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 4 4 1 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 ❑✓ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: September 21,2011 211-095/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 September 2,2011 50-029-20837-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 307'FNL,641'FEL,Sec.21,T11 N,R10E, UM September 8,2011 1E-27L1 Top of Productive Horizon: 8.KB(ft above MSL): 105.7'RKB 15.Field/Pool(s): 197'FNL, 1179'FEL,Sec.21,T11 N,R10E, UM GL(ft above MSL): 66.7'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 145'FSL, 1362'FWL,Sec. 15,T11 N, R10E, UM 9310'MD/6324'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-549890 y- 5959280 Zone-4 9310'MD/6324'ND ADL 25651 TPI: x-549351 y- 5959387 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-551889 y- 5959746 Zone-4 1874'MD/1874'ND 469 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 3308'MD/3308'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 6288'MD/6182'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65# H-40 32' __ 112' 32' 112' 24" 272 sx AS II 10.75" 45.5# K-55 32' 2218' 32' 2218' 13.5" 1500 sx AS III,250 sx AS I 7" 26# K-55 31' 6715' 31' 6564' 8.75" 635 sx Class G,250 sx AS I 2.375" 4.7# L-80 8450' 9310' 6293' 6324' 3" slotted liner V 24.Open to production or injection? Yes O 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) na na 5966'MD/5888'ND slotted liner ;.~ 6221'MD/6120'ND 8450'-9310'MD 6293'-6324'N + D .+t. rE 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. L J _ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ' -'.tip+ na 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) 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. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RECEIVED" OCT 0 4 2011 RBDMS OCT 0 4 2011 • '� p{a>,ka o"& Gas Cons.Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Anchorage Submit original only C ,(Z. ec ,, -Il s/ 6 28. GrOLOGIC MARKERS(List all formations and markers en,,.,,,ntered): 29. FORMATION TESTS • NAME MD TVD Well tested? Yes ❑✓ 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 3308' 3308' needed,and submit detailed test information per 20 AAC 25.071. Top A4 6368' 6242' Top Upper A4 sand 6379' 6243' Top Lower A4 sand 8410' 6290' N/A Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike infree @ 265-6820 t°N" Printed Name L. nttt Title: CTD Engineering Supervisor Signature '( ONIA.&\� t. Phone 263-4021 Date /D/3//1 Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 "7 Pre and Post Rig Work Summary DATE ' SUMMARY 7/36/11 DRIFT TBG W/5'X 2.5" BLR TO TAG @ 6362' SLM, SET 2.75" SV IN D-NIP @ 6239' RKB, PULL HFCV @ 6005' RKB, IN PROGRESS. 7/31/11 SET DV IN CSM @ 6005' RKB, ATTEMPT MITT, PULL 2.75" SV @ 6239' RKB, SET 2.75" CA-2 PLUG, PERFORM PASSING 2500 PSI MITT, PULL 2.75"CA-2 PLUG. **C-SAND ISOLATED**, IN PROGRESS. 8/1/11 MEASURE BHP @ 6354' RKB, GRADIENT @ 6243' RKB. READY FOR E-LINE. 8/2/11 RIG IN HOLE WITH 2" OD PERF GUN LOADED 6 SPF 60 DEG PHASE. LOADED 2'WITH 6.8 GM BH HMX CHARGES AND PERFORATE FROM DEPTH OF 6235' -6237'. SHOTS IN THE MIDDLE OF THE 6' PUP JOINT ABOVE THE D NIPPLE AT 6239'. 8/5/11 RIH, MILL NIPPLE @ 6239' CTMD USING USED MILL THAT GAUGE NOGO 2.79", MILLED FOR 9HRS DID NOT GET THROUGH NIPPLE, IN PROGRESS 8/6/11 RIH, MILL OUT D NIPPLE @ 6,239' RKB TO 2.80", RAN NEW MILL 5HRS, IN PROGRESS 8/7/11 RIH, SQUEEZE CEMENT, COULD NOT OBTIAN SQUEEZE PRESSURE, PUMPED AWAY, IN PROGRESS 8/8/11 RIH, PUMP 15BBL 17PPG NEAT CEMENT, SQUEEZE TO 500,600,7.5.0,1000 PSI, CLEAN OUT TO 6215' • CTMD, POOH, READY FOR WIRE LINE 8/11/11 TAGGED CEMENT TOP @ 6231' SLM, EST. 6242' RFSB. PRESSURE TEST TBG 2000 PSI, PASSED. , COMPLETE. 1 . e 8/13/11 PRE-CTD T-POT( PASSED ), T-PPPOT( PASSED), IC-POT( PASSED ), IC-PPPOT( PASSED ), , OC- �. POT( FAILED ), OC-PPPOT( PASSED ), MIT-IA(PASSED), MIT-OA( PASSED), PT-MV&WV PASSED), DD- MV&WV(PASSED ), PT-SSV( PASSED), DD-SV(PASSED , PT-SV( PASSED), DD-SV (,PASSED). 9/24/11 ASSIST VLV CREW W/PULLING BPV, DRIFT TBG TO 2.79"TO TAG LINER TOP @ 6215' RKB, MEASURE BHP 3421 psi @ 6210' RKB, GRADIENT 3341 psi @ 6111' RKB, SET CATCHER @ 6205' SLM, PULL DV @ 5897' RKB. JOB IN PROGRESS. 9/25/11 SET OV @ 5897' RKB, PULL CATCHER @ 6205' SLM. JOB COMPLETE. k ConocoPhillips Time Log & Summary We/View Web Reporting Report Well Name: 1E-27 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/29/2011 12:00:00 PM Rig Release: 9/23/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T' Comment 08/28/2011 24 hr Summary Move rig from 3H to 1 E 06:00 00:00 18.00 MIRU MOVE MOB P Mob rig from 3H pad 08/29/2011 MIRU on 1E-27, rig accepted at 12:00 change skates on injector, pump slack,start testing BOP,State witnessing waived by Jeff Jones 00:00 06:00 6.00 MIRU MOVE MOB P Move rig from 3H to 1E 06:00 09:00 3.00 MIRU MOVE MOB P On location spot rig 09:00 12:00 3.00 MIRU WHDBO NUND P Nipple up and prepare for BOPE test 12:00 19:30 7.50 MIRU WHDBO RGRP P Injector maintenace ***Nabors on Non-Billable time*** 19:30 23:00 3.50 MIRU WHDBO SLPC P Pump slack, cut 70'of pipe(57'to find wire) 23:00 00:00 1.00 MIRU WHDBO BOPE P Test BOP to 4000 PSI,state witness waived by Jeff Jones 08/30/2011 Complete BOP Test, Head up E-Coil, Run Cement pilot hole BHA,Tie in for+4',Tag TOC @6236'. Mill Cement 00:00 10:00 10.00 0 0 MIRU WHDBO BOPE P Continue testing BOP 250 low 4000 6 high. Lower Blind/Shear failed Replaced both upper&lower blind 1,5 rams. Re-tested-passed.C-9& C-10 failed-re-tested. 10:00 12:00 2.00 0 0 SURPRI WELLPF SLPC P MU CTC, Pull test 35K, M/U Quick connect.Pressure test TT line. 12:00 14:00 2.00 0 0 SURPRI WELLPF MPSP P Rig Up FMC&pressure test to 2000 psi. Pull BPV. 150 psi on well. Bled down to zero.Shut in a static test for 10 minutes,zero PSI on well. 14:00 14:30 0.50 0 0 PROD1 WHPST SLPC P Pressure test CTC to 4000 psi. 14:30 15:30 1.00 0 0 PROD1 WHPST SFTY P Pre-spud meeting with Maddy Crew. 15:30 16:30 1.00 0 0 PROD1 WHPST PULD P PJSM-P/U cement milling BHA for Run#1 with 2.81 go,2.80"no go D331 bit with 0.6 AKO motor assembly. 16:30 18:36 2.10 0 6,045 PROD1 WHPST TRIP P IA=300/OA=29. Check SSSV- RIH with EDC closed pumping SW.5 bpm taking returns to the tiger tank. 18:36 18:48 0.20 6,045 6,082 PROD1 WHPST DLOG P Log Gamma tie in fora+4' correction,Start swap to Biozan 18:48 19:12 0.40 6,082 6,236 PROD1 WHPST TRIP P RIH to mill cement Page 1 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode -T Comment _ 19:12 19:54 0.70 6,236 6,245 PROD1 WHPST MILL P Tag TOC @.25 BBIs/Min, Pick up and bring rate to 1.44 BPM@ 2330 PSI FS,TF=20ROHS 19:54 20:06 0.20 6,245 6,246 PROD1 WHPST MILL P Bleed IA from 1000 psi to 350 PSI, OA from 620psi to 300psi Milling ahead 10-15 FPH 20:06 00:00 3.90 6,246 6,304 PROD1 WHPST MILL P Mill Cement pilot hole,TF=20ROHS, 1.44 BPM @ 2330 PSI FS Midnight depth 6304, ROP=-15 FPH 08/31/2011 Complete Cement pilot hole to 6315', Run Dummy to 6300',set whipstock 6285 TOWS, P/U Window mill and start milling window 00:00 00:45 0.75 6,304 6,315 PROD1 WHPST MILL P Milling Cement pilot hole 00:45 01:15 0.50 6,315 6,230 PROD1 WHPST REAM P P/U and ream pilot hole before drift, PUW=41 K, 1.32 BPM @ 2336 PSI 01:15 01:30 0.25 6,230 6,315 PROD1 WHPST REAM P Dry Drift hole,saw light stacking in transition area, clean below that area to TD 01:30 02:30 1.00 6,315 6,220 PROD1 WHPST REAM P PUH and Ream Transition area 6220 to 6265 02:30 03:30 1.00 6,220 6,220 PROD1 WHPST REAM P Dry drift after 2 up and 1 down pass, still seeing a bobble on DHWOB. Rotate TF to 180 03:30 04:15 0.75 6,220 6,220 PROD1 WHPST REAM P Ream 2 down and 2 up passes @ 180 degree TF 6620 to 6680 1.37 BPM @ 2320 PSI FS. No Motor work at this TF 04:15 04:30 0.25 6,220 6,280 PROD1 WHPST REAM P Dry drift 6210 to 6285, Looks good still have bobble @ 6250'700 lbs on DHWOB, PUH for no flow 04:30 04:45 0.25 6,280 6,280 PROD1 WHPST CIRC P 6217', Perform no flow test,good test, Open EDC and trip out PUW=40K 04:45 06:45 2.00 6,280 71 PROD1 WHPST TRIP P POOH 06:45 08:15 1.50 71 71 PROD1 WHPST PULD P PJSM-no flow check. Lay down BHA&P/U Dummy WS BHA 08:15 08:45 0.50 71 71 PROD1 WHPST COND P Take on old flo-pro fluid&remove Bio-zan 08:45 10:45 2.00 71 6,072 PROD1 RPEQP1TRIP P RIH with Dummy WS-EDC closed pumping flo-pro @.3 bpm.Started seeing weight swings from 4000' down.P/U weight check 33-39K weight swings. RIH 10:45 11:15 0.50 6,072 6,300 PROD1 RPEQP1DISP P Tie in&increase pump rate to 1.4 bpm to circ out Bio fluid. +3 ft correction. RIH to 6300'. Clean drift. Circ out Bio-zan. 11:15 13:15 2.00 6,300 71 PROD1 RPEQP1TRIP P POOH-P/U weight 40K.Weight swings not as noticable with flo-pro. 13:15 14:15 1.00 71 71 PROD1 RPEQP1PULD P PJSM-Lay down Dummy WS& P/U WS with 2 pip tags. 14:15 16:15 2.00 71 6,295 PROD1 WHPST TRIP P RIH pumping.3 bpm through EDC. 6050'-Tie in+3ft correction. RIH slowly to 6300'-P/U weight 34K to setting depth of TOWS 6285',. BOWS 6294.84'. High side. Page 2 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 16:30 0.25 6,285 6,285 PROD1 WHPST WPST P Stop pumping ,WOB zero-close EDC. Bring up pump,WS set @ 3600psi.WOB increase to 2K.Set down 3K.-good indication of set. P/U weight 38K dry-33K wet. 16:30 18:06 1.60 6,285 79 PROD1 WHPST TRIP P POOH for milling BHA 18:06 19:21 1.25 79 0 PROD1 WHPST PULD P Lay down BHA#3 Whipstock setting run 19:21 20:00 0.65 0 0 PROD1 WHPST PRTS P Rig up PDL to Pressure test 3K 20:00 20:30 0.50 0 73 PROD1 WHPST PULD P P/U BHA#4,Window milling BHA with.6 degree motor, Dimond string mill and window mill 20:30 21:06 0.60 73 73 PROD1 WHPST SFTY P Pre spud meeting with Corder's crew 21:06 22:48 1.70 73 6,070 PROD1 WHPST TRIP P Tag up,set counters,trip in well with BHA#4, EDC shut 22:48 22:54 0.10 6,070 6,092 PROD1 WHPST DLOG P Log Gamma tie in for a+3'correction 22:54 23:36 0.70 6,092 6,288 PROD1 WHPST TRIP P Trip in well,stacked out @ 6240, Pick up and inspect injector. PUW= 45K Everything looks good. RIH and dry tag TOWS @ 6288 23:36 00:00 0.40 6,288 6,288 PROD1 WHPST MILL P Pick up and bring pumps online, 1.5 BPM @ 3700 PSI FS,wash down to whipstock,call pinch point 6287.6. Start time milling per procedure, Midnight 6288.1 09/01/2011 Complete window and rat hole,Trip out.Cut 1400'for fatigue mgmt. Investigate injector noise. Head up E-Line 00:00 04:00 4.00 6,288 6,291 PROD1 WHPST MILL P Continue time milling window, 1.5 �1 BPM @ 3700 PSI FS,stalled @ 6288.6, PUW=37K L 04:00 06:30 2.50 6,291 6,293 PROD1WHPST MILL P Milled 3.2'go to auto drill 1 FPH, 1.5 1 BPM @ 3600 FS, Bleed down IA and OA 06:30 10:30 4.00 6,293 6,308 PROD1 WHPST MILL P Increase ROP to 2 fph-both mill,& string mill exit out the window. Increase to 5 fph from 6296'.Keeping WOB below 2K. 10:30 11:30 1.00 6,308 6,308 PROD1 WHPST REAM P Backreaming passes. P/U weight off bottom 37K. Make two passes- clean no motor work detected. Dry drift with WH trapped, no leak off. Clean drift at 8 fpm. P/U weight-40K. Clean up pass. TOW=6287.5 BOW=6293.5 11:30 13:30 2.00 6,308 200 PROD1 WHPST TRIP P POOH following MPD.Open EDC. Jet across SSSV a couple of times. 13:30 14:00 0.50 200 71 PROD1 WHPST RGRP T Injector making new vibration noises close to surface.Stop and inspect and troubleshoot. POOH to surface. 14:00 15:30 1.50 71 0 PROD1 WHPST PULD P PJSM-undeploy BHA. Mechanic inspected both drive shafts with no indications of fatigue. Page 3 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode <T Comment 15:30 16:30 1.00 0 0 PROD1 DRILL RGRP T Continue working on injector- checked gear oil&gear box, looked good. Lay down entire BHA&set up rig floor to cut pipe. Mill guage 2.81 go,2.80 no.String mill 2.80 go,2.79 no. 16:30 18:00 1.50 0 0 PROD1 DRILL SLPC P Cut off CT connector&BHA UQC. _ Start cutting pipe. 18:00 21:00 3.00 0 0 PROD1 DRILL SLPC P Crew change, PJSM, Continue cutting coil,Total cut of 1400', R/D CT Cutter 21:00 23:00 2.00 0 0 PROD1 DRILL RGRP T M/U External coil connector,Trouble shoot injector noise,didn't find anything out of spec 23:00 00:00 1.00 0 0 PROD1 DRILL SLPC P Remove external connector. Install CTC, pull test to 36K, Head Up E-line 09/02/2011 Drill Build section to TD @ 6715,Tie in Whipstock RA Marker @ 6294.,TOW=6288/BOW=6294 00:00 00:45 0.75 0 0 PROD1 DRILL SLPC P Complete E-Line rehead and Pressure test CTC to 4K 00:45 02:15 1.50 0 62 PROD1 DRILL PULD P PJSM-M/U BHA#5 Build section w 2.5 AKO motor and Bi Center Bit, Surface test tool.Tag up and set counters. 02:15 04:00 1.75 62 6,060 PROD1 DRILL TRIP P Trip in well, EDC Shut 04:00 04:12 0.20 6,060 6,081 PROD1 DRILL DLOG P Log Gamma tie, +3'correction 04:12 04:30 0.30 6,081 6,309 PROD1 DRILL TRIP P Trip into drill, Clean pass through window 04:30 06:30 2.00 6,309 6,340 PROD1 DRILL DRLG P 6309', Drill ahead, 1.3 BPM @ 3100 PSI FS, One for one returns. BHP=3900 PSI,WHP=110(going to Tiger tank) 06:30 08:00 1.50 6,340 6,400 PROD1 DRILL DRLG P Drilling ahead on new used mud system 1.30 bpm, 3000psi, BHP 3850,WOB 2K, ROP 40,WHP zero, ECD 12.Pull mini wiper-ratty P/U weight 42K.Increase pump rate. 08:00 11:30 3.50 6,400 6,460 PROD1 DRILL DRLG P Drill ahead-1.40 bpm, 3150, BHP 3870, ECD 12.1,WOB 2K, ROP 25, CT weight 13K. Soft, packing clay coming over shakers with higher pump rates. 11:30 12:00 0.50 6,460 6,460 PROD1 DRILL WPRT P Wiper trip-P/U 37K off bottom but dragging&increased WOB from 6440'-6300'.Wipe into cased hole for tie in.Min rate through cement pilot hole. Mix up drill-zone sweep.& start pumping 20 bbls.Clay& siltstone samples. 12:00 12:30 0.50 6,460 6,460 PROD1 DRILL DLOG P K-1 Tie in+1ft. RA marker=6294' TOW=6288'/BOW 6294' RIH pumping .3 bpm.- 12:30 12:45 0.25 6,460 6,460 PROD1 DRILL WPRT P Wipe up to window @ 1.3 bpm, P/U weight 39K-Weight swings at 6435' &6427' RIH pumping .3 bpm.- Drillzone exiting bit. Page 4 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 15:45 3.00 6,460 6,610 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3150, BHP 3860,WOB 1.5K, ECD 12.1, ROP 60; Ct weight 12K.Samples are indicating sand. Pumped 30 bbls Drillzone sweep. 15:45 16:15 0.50 6,610 6,610 PROD1 DRILL WPRT P Wiper trip-P/U weight 43K. 16:15 18:15 2.00 6,610 6,715 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3300, BHP 3900, ECD 12.2, ROP 50,WOB 1.5K, Ct weight 12K. 18:15 20:30 2.25 6,715 46 PROD1 DRILL WPRT P TD Build section-POOH for BHA change. .-_..__.._._.. _ 20:30 23:30 3.00 46 0 PROD1 DRILL PULD P PJSM @ Surface, LD BHA#5 23:30 00:00 0.50 0 0 PROD1 DRILL PULD P PJSM, PU BHA#6 Lateral section with RSM 09/03/2011 Drilled with RSM 6715 to 7746,Mud Swap @ 6715 00:00 01:00 1.00 0 68 PROD1 DRILL PULD P Continue PD BHA#6 RSM Lateral section, Surface test tool,Tag up and set counters 01:00 02:30 1.50 68 6,065 PROD1 DRILL TRIP P RIH 02:30 02:36 0.10 6,065 6,086 PROD1 DRILL DLOG P Log Gamma tie in for+2.5'correction PUW=34k, Close EDC 02:36 02:54 0.30 6,086 6,715 PROD1 DRILL TRIP P Trip in to drill, Roll in new 9.8 PPG Mud 02:54 04:42 1.80 6,715 6,865 PROD1 DRILL DRLG P 6715', Drill Ahead 1.40 BPM @ 3260 PSI FS, BHP=3860 04:42 06:42 2.00 6,865 6,865 PROD1 DRILL WPRT P 6865 wiper trip to window, PUW=37k, BHP=3835 Bring rate up 1.45 @ 3100 PSI FS With MAD Pass 6720 to 6310 06:42 08:30 1.80 6,865 7,015 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3250, BHP 3855, ECD 12, ROP 90,WOB 1.7K, Ct weight 12K. 08:30 09:30 1.00 7,015 7,015 PROD1 DRILL WPRT P Wiper trip-40K-smooth wiper all the way to window. 09:30 10:30 1.00 7,015 7,165 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3380, BHP 3910, ECD 12.1, ROP 120,WOB 1.9K,Ct weight 10K. 10:30 12:00 1.50 7,165 7,165 PROD1 DRILL WPRT P Wiper trip-P/U weight 40K.Tie in correction+1.5 12:00 15:00 3.00 7,165 7,315 PROD1 DRILL DRLG P Drilling ahead-1.40,3250, BHP 3910, ROP 110, ECD 12.1,WOB 1.7K.Ankerite @ 7250' ROP dropped to 15 fph. 15:00 16:00 1.00 7,315 7,315 PROD1 DRILL WPRT P Wiper trip-P/U weight 40K 16:00 17:18 1.30 7,315 7,465 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3300, BHP 3913, ECD 12.1, ROP 110,WOB 1.5, Ct weight 11K. 17:18 18:48 1.50 7,465 7,465 PROD1 DRILL WPRT P Wiper trip-40K P/U weight. 18:48 20:00 1.20 7,465 7,615 PROD1 DRILL DRLG P 7465', Drill Ahead, 1.4 BPM @ 3270 PSI FS, BHP=3960, RIW=11.4, ROP=150' 20:00 20:54 0.90 7,615 6,305 PROD1 DRILL WPRT P 7615 Wiper to window with tie in, PUW=37K Page 5 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:54 21:06 0.20 6,305 6,328 PROD1 DRILL DLOG P 6305 Log RA marker for a+.5' 21:06 21:48 0.70 6,328 7,615 PROD1 DRILL WPRT P Continue wiper to bottom 21:48 00:00 2.20 7,615 7,746 PROD1 DRILL DRLG P 7615', Drill Ahead, 1.4 BPM @ 3150PSI FS, RIW=7.7K,WOB=2K, BHP=3979 Pass through some Ankorite stringers 09/04/2011 Drilled 7746 to 7806. RSM locked up, POOH and swap out. Drill 7806 to 8226 00:00 00:39 0.65 7,746 7,765 PROD1 DRILL DRLG P 7746', Drill Ahead, 1.4 BPM @ 3150 PSI FS, 00:39 02:27 1.80 7,765 7,765 PROD1 DRILL WPRT P Wiper to window, PUW=37K 02:27 03:39 1.20 7,765 7,806 PROD1 DRILL DRLG P 7765', Drilling ahead, 1.4 BPM @ 3150 PSI FS, RIW=12.6K, WOB=1.6K, BHP=3990 03:39 03:57 0.30 7,806 7,500 PROD1 DRILL WPRT T Stall, PUH for BHA wiper, PUW=37K Still stalled, BHA Locked up. PUH, Unable to pump down coil, Annular=3200 Bore=6100, Line up to well and coil. Get WHP to 650 pressure. BHP not increasing as expected on downhole gauge. Reboot tool. 03:57 06:27 2.50 7,500 68 PROD1 DRILL TRIP T POOH to diagnose plugged BHA, Maintain 660 PSI WHP.Open EDC @ 3000'. POOH. BHI Trouble time begin 06:27 07:57 1.50 68 0 PROD1 DRILL PULD T PJSM for un deploying BHA.Well is injecting @ 600 psi WHP 2 bbls/hour. Bit came out a 1:1 with no plugged nozzles but motor was siezed. 07:57 09:57 2.00 0 68 PROD1 DRILL PULD T PJSM-deploy new BHA#7 with RSM&2.73"Bi-center. 09:57 12:27 2.50 68 7,806 PROD1 DRILL TRIP T RIH with EDC open pumping .3 bpm. +2.5 tie in. Clean through window& OH section. End BHI Trouble time 12:27 14:57 2.50 7,806 7,960 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3300, BHP 4020, ECD 12.4, ROP 90,WOB 1.8K 14:57 16:57 2.00 7,960 7,960 PROD1 DRILL WPRT P Wiper trip-40K-After 1.5 B/U start taking returns to Tiger tank for mud swap due to lack of vac trucks. 16:57 19:27 2.50 7,960 8,110 PROD1 DRILL DRLG P 7960', Drill ahead, 1.38 @ 3023 PSI FS, RIW=11.1,WOB=2.1K, BHP=4042 19:27 21:27 2.00 8,110 8,110 PROD1 DRILL WPRT P Wiper to window, PUW=42K 21:27 00:00 2.55 8,110 8,226 PROD1 DRILL DRLG P 8110', Drill Ahead, 1.38 BPM @ 3150 PSI FS, RIW=9K,WOB=2.5K, BHP=6067 Midnight depth 8226 09/05/2011 Drill 8226 to 8789, Swap out mud 00:00 00:45 0.75 8,226 8,260 PROD1 DRILL DRLG P 8226', Drill Ahead, 1.38 BPM @ 3150 PSI FS, BHP=4050 Page 6of20 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:45 02:00 1.25 8,260 6,305 PROD1 DRILL WPRT P Wiper to window with tie in, PUW=40K 02:00 02:12 0.20 6,305 6,325 PROD1 DRILL DLOG P Tie into RA marker for a +2' correction 02:12 03:12 1.00 6,325 8,260 PROD1 DRILL WPRT P Trip in well to drill,Swap Mud with 1500'on the system. 03:12 05:27 2.25 8,260 8,410 PROD1 DRILL DRLG P 8260', Drill Ahead, 1.46 BPM @ 3050 PSI FS, BHP=3995, New mud at bit 05:27 08:00 2.55 8,410 8,410 PROD1 DRILL WPRT P Wiper trip-P/U weight 40K. 08:00 08:30 0.50 8,410 8,446 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3300, BHP 4020, ECD 12.5,WOB 2.1,Ct weight 9K. Start stacking surface weight with higher differential. 08:30 11:30 3.00 8,446 8,560 PROD1 DRILL DRLG P Started losing surface weight-P/U weight 46K. BHA wiper. Drill ahead- 1.40 bpm, 3240, BHP 4040, ECD 12.5,WOB 1.6, ROP 40,CT weight 10K. 11:30 14:00 2.50 8,560 8,560 PROD1 DRILL WPRT P Pump 5/5 bbls low/high sweep prior to Wiper trip-P/U weight 44K 14:00 16:30 2.50 8,560 8,640 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3450, BHP 4075psi, ECD 12.6, ROP 40,WOB 1.6,Ct weight 9.5K.Started getting into silstone/shale formation @ 8580'. Pump a 5/5 sweep to help with weight transfer. 16:30 18:30 2.00 8,640 8,710 PROD1 DRILL DRLG P BHA wiper due to CT weight stacking -P/U weight 45K-Drilling ahead- 1.40 bpm, 3250, BHP 4088, ECD 12.7, ROP 10,WOB 1.8K, Ct weight 8K 18:30 20:06 1.60 8,710 6,310 PROD1 DRILL WPRT P 8710',wiper to window with tie in, 41K v 20:06 20:12 0.10 6,310 6,324 PROD1 DRILL DLOG P Tie into RA marker for+1'correction, trip in to drill 20:12 21:24 1.20 6,324 8,710 PROD1 DRILL WPRT P Continue wiper trip to bottom 21:24 22:54 1.50 8,710 8,777 PROD1 DRILL DRLG P 8710', Drill Ahead, 1.38BPM @ 3040 PSI FS, RIW=8K,WOB=1.5K, BHP=4124 22:54 00:00 1.10 8,777 8,789 PROD1 DRILL DRLG P 8777, BHA Wiper,Stacking out, PUW=47K, RIW=-2K,WOB=2.8K, Midnight depth 8789 D9/06/2011 Drill to 9010, Overpulls in shaley section, POOH for agitator and.8 degree motor 00:00 00:54 0.90 8,789 8,816 PROD1 DRILL DRLG P Continue to drill ahead, 1.4 BPM @ 3050 PSI FS, BHP=4040, ECD=12.5 00:54 02:54 2.00 8,816 8,860 PROD1 DRILL DRLG P BHA Wiper, stacking weight, RIW= -2K, Pump Low Hi Sweeps 02:54 05:54 3.00 8,860 8,860 PROD1 DRILL WPRT P Wiper trip to window, PUW=44K, ECD=12.7 05:54 10:54 5.00 8,860 9,008 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3200, BHP 4110, ECD 12.5, ROP 15,WOB.8K, Ct weight 9K. Poor formation drilling. Pump 717 sweep 20 ft from wiper. Page 7of20 Time Logs Date '' From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:54 11:24 0.50 9,008 8,000 PROD1 DRILL WPRT P Wiper trip-47K P/U weight.-sweep brought back lots of clay/shale material soft pebbles. Drag increased to 52K as wiping through poor section 8600'-8400. 11:24 12:24 1.00 8,000 8,600 PROD1 DRILL WPRT T Pump sweep&RIH through troubled section with sweep at bit.Stacked at 8580' Down on pump rate work through and P/U 54K.Sweep at the bit. Dragged heavy 55K keep wiping up to window. 12:24 13:24 1.00 7,300 6,330 PROD1 DRILL WPRT T 'Wiper trip top window 53K-Second sweep-normal returns over shakers @ 7300'still pulling 53K.All pressures are normal but 7K drag vs last trip on Coil but nothing on BHA. Increase speed to 30 fpm,weight bouncing from 46-52K. Slow down in build section. 13:24 13:54 0.50 6,330 6,200 PROD1 DRILL WPRT T Started pulling heavy 30 ft from window. RIH 6400'pumping min. rate. P/U weight 55K.Min. rate. Drag on BHA-1.5K.CT weight 52K, dropped to 48K through window. Differential dropped from 330psi to 90psi. 13:54 14:12 0.30 6,200 6,200 PROD1 DRILL TRIP P RIH through window&tie in+1. P/u through window and saw drag again with 4K drop off through window. -1.4K on BHA. 14:12 16:42 2.50 6,200 68 PROD1 DRILL TRIP P POOH to change out BHA&P/U agitator, conventional BHA. Noticed increase in cuttings over shaker @ 2800'-Lots of Scale&shale returns. Cleaned up around 900'from surface. Ct pipe has rough marks on it. Downhole rough not injector rough. 16:42 18:00 1.30 68 0 PROD1 DRILL PULD P PJSM for undeploying BHA. BHA looked clean of debris at surface. 18:00 20:00 2.00 0 0 PROD1 DRILL SVRG P Crew change out, Lay down RSM. Service injector and MP Choke, Function test BOPE,Change packoff 20:00 22:30 2.50 0 0 PROD1 DRILL PULD P PJSM,M/U and deploy BHA#8. .8 degree motor, Bi Center bit and agitator Surface test tool,Tag up and set counter 22:30 23:48 1.30 0 6,075 PROD1 DRILL TRIP P Trip in well 23:48 00:00 0.20 6,075 6,096 PROD1 DRILL DLOG P Tie into K-1 for+3.5, PUW=36K, shut EDC 09/07/2011 Continue in well with .8 Degree motor,Clean trip through window down to 8700',condition hole,swap mud, Drill ahead to 9297 00:00 01:15 1.25 6,096 8,597 PROD1 DRILL TRIP P Trip in hole after tie in, Clean pass through window, RIW=12.5K @ window Page 8 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:27 0.20 8,597 8,700 PROD1 DRILL TRIP P 8597 set down were pumping 1 BPM, PUW 35k gradually up to 39K, reduce rate to .5BPM went right through. Run clean to 8700. Bring pumps up to 1.45 BPM @ 3800 PSI and back ream 01:27 01:45 0.30 8,700 8,430 PROD1 DRILL TRIP T 8700 Back ream section up to 8570 pumping 1.45 @ 3800 PSI, BHP=4200 Stall and pulled heavy @ 8615,able to RIH no problem.Trap WHP and move down. PUH motor still in stall PUH Pull 48 @ 8620,60k @ 8575,Work back down and get out of stall, PUH up to 8430 01:45 02:09 0.40 8,430 8,810 PROD1 DRILL REAM T 8430 RIH @ 1 BPM @ 2700 PSI, Started to set down, Slowed down to 5-8 FPM and continued in all @ 1/2 BPM 02:09 02:51 0.70 8,810 8,500 PROD1 DRILL REAM T 8810, Pumps up to 1.4 @ 370, PUH 5-10 FPM to clean up area Stalled at 8567 and 8585 pulling heavy in that area 47k-49K 02:51 03:27 0.60 8,500 8,800 PROD1 DRILL REAM T 8500'RBIH, .5 BBL.Min and 20 fpm, WHP=150, BHP=4045, Pump 7/7 sweep. Nothing substantial coming across shaker 03:27 04:27 1.00 8,800 8,450 PROD1 DRILL REAM T 8800', PUH 1.4 BPM @ 3725 PSI, 5-7 FPM, Dragging hard @ 8700, Stop and RBIH @8450 Recip this area 8500 to 8700.doesn't seem to be improving.Call out trucks for mud swap. 04:27 06:27 2.00 8,450 6,200 PROD1 DRILL REAM T 8350',Weight still pulling heavy, 50K, Pulling to window,Trucks here. start pulling off old mud for swap.All night been able to RIH without much problem. Even stopping during high overpulls. Seldom saw any negative DH WOB when pulling heavy. 06:27 08:27 2.00 6,200 8,400 PROD1 DRILL CIRC T Open EDC and pump new mud. P/U weight 50K in cased hole-new mud around 42K.Temperature of old mud 86 degree,temp of new mud 74 degrees. RIH Page 9 of 20 Time Logs Date From To Dur S. DepthE. Depth Phase Code Subcode T Comment 08:27 10:27 2.00 9,008 9,008 PROD1 DRILL TRIP P Weight check prior to shale area @ 8400' P/U weight 46K. lower pump rates to.5 bpm. RIH. Clean down to 8670'Weight check-46K. RIH clean to 8725'P/U and wipe back up through section @ 1.2 bpm. 45K. up to 8500',clean. RIH-stacking at 8855'P/U weight 47K. 1 bpm to 8800' RIH -stacking @ 8900' P/U weight 47K 1 bpm to 8800' RIH-stacked 8998'-P/U 47K @ 1.2 bpm up to 8960' RIH 1 bpm tagged bottom @ 9004' 2.5K WOB P/U 52K. broke over. Stacked early a few times @ 8998' range ont he way back down. Lower pump rate and hit TD @ 9007' 10:27 10:57 0.50 9,008 9,011 PROD1 DRILL DRLG P Drilling ahead-1.35 bpm,3600, BHP 4030, ECD 12.5,WOB 2K, Ct weight 13K. ROP 10 10:57 11:27 0.50 9,011 9,011 PROD1 DRILL DRLG P Not drilling off P/U weight 55K-8892' WOB-5K.Weight broke over out at 8950'-POOH to 8900' RIH-clean holding 4180 BHP.Clean to TD 11:27 17:27 6.00 9,011 9,160 PROD1 DRILL DRLG P Drilling ahead-1.38 bpm,3640, BHP 4160,WHP 140, ECD 12.9, ROP 10, WOB 2K,Ct weight 10K.Very slow drilling, not regular ankerite drilling. ROP picked up @ 9060' 17:27 21:03 3.60 9,160 9,160 PROD1 DRILL WPRT P Wiper trip-46K off bottom drag through shale section 8990'Had to lower pump rate to 1 bpm. Reduce rate to.5 on way back in. Multiple attempts to bring up rate met with reduced RIW 21:03 22:45 1.70 9,160 9,297 PROD1 DRILL DRLG P 9160', Drill Ahead, 1.3 BPM @ 3450 PSI FS, BHP=4148 RIW=5.9K WOB=1.7k ROP=70-50 22:45 00:00 1.25 9,297 9,297 PROD1 DRILL DRLG P 9227 ROP down to-30 FPH, RIW= -3K,WOB=2K, 1.37BPM @ 3450 PSI FS, BHP=4110 09/08/2011 TD A Lateral early @ 9310,Condition hole, Kill Well,M/U lower liner section 00:00 00:24 0.40 9,297 9,310 PROD1 DRILL DRLG P Drilling Ahead , - I 00:24 04:24 4.00 9,310 9,310) PROD1 DRILL WPRT P Wiper trip to window, PUW=48K, ECD=12.7,9205 dragging heavy 50-52K. Turn around @ 6230'. Geos/Town called TD while we are at 7100'. Heading in to tag and pump sweeps Page 10 of 20 Time Logs Date From To Dur S.Depth`E. Depth Phase Code Subcode T Comment 04:24 08:24 4.00 9,310 77 PROD1 DRILL WPRT P Pumped 10/10 Lo High vis sweeps Wiper to swab, PUW=47, RIW=2K, BHP=4112. CT string weight starting to pull heavy again. 55K through build& window section. 08:24 12:24 4.00 77 9,300 • PROD1 DRILL TRIP P No increase in cuttings near surface. Open EDC-RIH.Tie in correction +2ft, P/U weight 40K. RIH-saw one small weight bobble @ 8899'-RIH pumping .5 bpm through shale sections.Tag bottom or shale section @ 9298' 12:24 16:24 4.00 9,300 71 PROD1 DRILL TRIP P POOH while start pumping P/U weight 49K-broke over to 45K.Wipe up while Liner pill is getting to nozzle. P/U weight 50K POOH-laying in liner pill from 9300- TOC 6236'-Open EDC lay in KWF. 16:24 18:00 1.60 71 0 PROD1 DRILL PULD P Tag up and flow check for 15 minutes. PJSM for laying down BHA. 18:00 18:42 0.70 0 0 PROD1 DRILL SFTY P Crew change, PJSM, Rig up floor to P/U Tubing 18:42 21:42 3.00 0 0 COMPZ CASING PUTB P Start Making up L1 Lines, 21:42 22:42 1.00 849 850 COMPZ CASING PULD P P/U Coil track,M/U and strip on, surface test tool,Tag up and set counters 22:42 23:48 1.10 849 6,149 COMPZ CASING TRIP P RIH, EDC Closed 23:48 00:00 0.20 6,149 6,150 COMPZ CASING TRIP P Correct to 5300' EOP Flag for a+2.6' correction, PUW=37k Continue in hole 09/09/2011 M/U and run A Liner to 9310,TOL 8449, Make up drill by BHA.Time mill off Billit, Drill ahead 00:00 01:00 1.00 6,150 9,310 COMPZ CASING RUNL P Continue in hole with liner 01:00 01:18 0.30 9,310 48 COMPZ CASING RUNL P Tag up 9311 with 3K DHWOB, PUW-42K, Set liner back down, Pump 1.4 BPM, 1 BBL Out. PUH 36K, Remove 805.36 from counters, continue out of well BOL=9310,TOL 8494.24 Lower section 01:18 03:42 2.40 47 0 COMPZ CASING TRIP P At Surface, PJSM while flo checking well,to lay down liner running equipment 03:42 04:57 1.25 0 0 PROD2 STK PUTB P M/U Anchored billet with 10'solid pup,30'slotted joint with ported bullnose 04:57 06:27 1.50 0 115 PROD2 STK SFTY P Crew change, Hold PJSM to continue Making up to billet to Coil Track 06:27 08:57 2.50 115 8,502 PROD2 STK RUNL P RIH with EDC open-tie in K-1 +3ft& weight check-36K.Close EDC- RIH to setting depth.Tagoed TOL @ 8502'2.5K down. P/U weigth 43K- RIH intial soft tag 1K @ 8501' Page 11 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:57 11:27 2.50 8,547 62 PROD2 STK TRIP P Estimated BOL 8502'TOB 8447> P/U string weight 35K-BHA 1.5 K. Set @ 3100 psi.-Set down 1.5K POOH laying in KWF.Stop&minus off 54.81' POOH laying in KWF 11:27 12:57 1.50 62 0 PROD2 STK PULD P PJSM-15 minute flow check. Lay down BHA. Service injector 12:57 13:45 0.80 0 72 PROD2 STK PULD P P/U drilling BHA with.8 AKO& bi-center. 13:45 17:00 3.25 72 8,450 PROD2 STK TRIP P RIH with EDC open.-tie in+3.5ft circ out KWF. RIH tag TOB @ 8449.5' 17:00 19:06 2.10 8,450 8,459 PROD2 STK KOST P Dry tag TOB @ 8449.5'-P/U and start Milling] 1.33 BPM @ 3286 PSI FS 19:06 19:48 0.70 8,459 8,500 PROD2 DRILL DRLG P 8459', Drill Ahead, 1.32 BPM @ 3150 PSI FS, ROP=130 FPH, BHP=4040 19:48 20:06 0.30 8,500 8,500 PROD2 DRILL WPRT P PUH to drift billit, PUW=37K, P/U to 8430 Pumps to Min coming up, Pumps off going down. Clean pass both directions 20:06 21:06 1.00 8,500 8,610 PROD2 DRILL DRLG P 8500', Drill Ahead 1.4 BPM @ 3400 PSI FS, BHP=4110 21:06 23:42 2.60 8,610 8,610 PROD2 DRILL WPRT P Wiper to window, PUW=38K 23:42 00:00 0.30 8,610 8,641 PROD2 DRILL DRLG P 8610',drill Ahead, 1.4 BPM @ 3420 PSI FS, BHP=4100 09/10/2011 Drill Ahead from 8641 to 9253, Lateral L1-02 00:00 02:45 2.75 8,641 8,760 PROD2 DRILL DRLG P 8641', Drill Ahead 02:45 05:45 3.00 8,760 8,760 PROD2 DRILL WPRT P Wiper trip to window, PUW=40k 05:45 07:45 2.00 8,760 8,910 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3600, BHP 4140, ECD 12.9, ROP 60,WOB 1.5K,CT weight 7K 07:45 10:45 3.00 8,910 8,910 PROD2 DRILL WPRT P Wiper trip-P/U weight 45K-tie in +2ft. RIH. 10:45 13:00 2.25 8,910 9,030 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3590, BHP 4112, ECD 12.8, ROP 80,WOB 1.6K, Ct weight 8K. 9030'Started stacking surface weight. P/U 13:00 14:00 1.00 9,030 9,060 PROD2 DRILL DRLG P P/U weight 44K, BHA wiper-made 3 attempts 10 fpm, increase to 25 fpm,good WOB transfer. Pump 7 bbls sweeps-drill ahead.Good CT weight transfer 7K surface weight. 14:00 17:15 3.25 9,060 9,060 PROD2 DRILL WPRT P Wiper trip-P/U weight 43K 17:1519:21 2.10 9,060 9,210 PROD2 DRILL DRLG P 9060',drill Ahead, 1.35 BPM @ 3360 PSI FS, BHP=4100 19:21 22:45 3.40 9,210 9,210 PROD2 DRILL WPRT P Wiper to window, PUW=40K 22:45 00:00 1.25 9,210 9,253 PROD2 DRILL DRLG P Drill Ahead 1.4 @ 3400 PSI FS, RIW=3K, BHP=4200, ECD=13.0 Midnight 9253 Page 12 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/11/2011 24 hr Summary Drilled 9253 to 9604 Called TD.Wiper tripto swab 00:00 02:30 2.50 9,253 9,332 PROD2 DRILL DRLG P Drilling Ahead, 1.4 BPM @ 3400 PSI FS, BHP=4200 02:30 03:00 0.50 9,332 9,332 PROD2 DRILL WPRT P BHA Wiper. PUW=44K, Hard to get back to drilling. Unable to RIH at full rate. Rest of"CooL'mud will here shortly.Will swap as soon as rest of mud gets on location, Pump Lo-Hi sweep 03:00 03:30 0.50 9,332 9,358 PROD2 DRILL DRLG P Drilling Ahead, 1.40 BPM @ 3380 PSI FS, ECD=13.0, BHP=4220 03:30 07:30 4.00 9,358 9,358 PROD2 DRILL WPRT P Pump 10/10 sweeps before coming off bottom, PUW=42K With Tie In +4.5 ft.Observed some additional material on shakers with sweeps 07:30 08:30 1.00 9,358 9,422 PROD2 DRILL DRLG P Start pumping new mud back on bottom. Drilling ahead-1.45 bpm, 3400, BHP 4090,WHP 110, ECD 13, ROP 60,WOB 2.1K, Ct weight 5K. 08:30 09:30 1.00 9,422 9,422 PROD2 DRILL WPRT P Wiper trip to fix pump cavitation. P/U 44K. hard time getting WOB at bottom again. P/U to 9000'-RIH 09:30 11:00 1.50 9,422 9,485 PROD2 DRILL DRLG P Drilling ahead-hard ankerite or dilling.WOB 2.5K ROP 7 fph.-Good ROP&Weight transfer once drilled through ankerite @ 9450. 1.40 bpm, 3200, BHP 4170,WHP 180, ECD 13,WOB 1.6K,Ct weight 2K. hard drilling again @ 9490' 11:00 11:30 0.50 9,485 9,490 PROD2 DRILL DRLG P Surface weight stacking-10K-no WOB-BHA wiper P/U weight 42K. RIH 35 fpm. Good WOB transfer but slow ROP-stack out at surface again WOb 1K, Ct weight-10K. Pump Sweeps&pull wiper. 11:30 15:30 4.00 9,490 9,490 PROD2 DRILL WPRT P Wiper trip-44K. RIH-started losing string weight at 9320'-more weight loss @ 9460' 15:30 18:00 2.50 9,490 9,604 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,3370, BHP 4140,WHP 150, ECD 12.9,WOB 2.8K,Ct weight 3K. Run out of ph._ j 2 9604' 18:00 22:45 4.75' 9,604 73 PROD2 DRILL WPRT P Pump sweeps, P/U weight 43K., '„j,Z- Wipe to swab,—1800'well unloaded small flake type scale observed from last wiper to swab,Tag up,set counters, RBIH 22:45 00:00 1.25 73 5,800 PROD2 DRILL WPRT P 5800',Tripping in 09/12/2011 Condition hole, Lay in Liner Pill&KWF. M/U and Run L1-02 Lower segment to 9601,TOL 8231,M/U and trip in with upper segment 00:00 00:06 0.10 5,800 6,070 PROD2 DRILL WPRT P Wiper trip from swab contined 00:06 00:18 0.20 6,070 6,090 PROD2 DRILL DLOG P Tie in for a+2.5'correction,Close EDC Page 13 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T `Comment 00:18 01:54 1.60 6,090 9,603 PROD2 DRILL WPRT P Continue to TD 01:54 02:48 0.90 9,603 8,171 PROD2 DRILL TRIP P Tag TD @ 9603, POOH jeyipg ip. beaded liner running pill 02:48 04:12 1.40 8,171 4,871 PROD2 DRILL TRIP P Paint yellow EOP Flag,Continue OOH 04:12 06:12 2.00 4,871 71 PROD2 DRILL TRIP P Paint 4800'EOP Flag,Continue out of well 06:12 07:12 1.00 71 0 PROD2 DRILL PULD P Ct at surface. PJSM for laying down BHA-15 minute no-flow check. Lay down BHA. 07:12 08:12 1.00 0 0 COMPZ CASING SVRG P Service injector&top drive. Inspect liner running equipment. 08:12 11:12 3.00 0 1,370 COMPZ CASING PUTB P PJSM-P/U 41 joints of slotted liner with bull noze plug. 11:12 12:12 1.00 1,370 1,413 COMPZ CASING PULD P P/U coiltrack assembly&make up injector. 12:12 15:42 3.50 1,413 9,601 COMPZ CASING RUNL P RIH with EDC closed pumping .3 bpm.Correction at window flag+2 ft. P/U weight 45K.Clean trip all the way to 9600'Stacked weight. P/U weight 48K. RIH. 15:42 18:27 2.75 9,601 48 COMPZ CASING TRIP P Stack 3K down-Pump 1.2 bpm, release liner-P/U weight 38K. Est. BOL 9601'-TOL 8230' Stop and reset counters and line up down the backside. POOH laying in KWF. 18:27 19:27 1.00 48 0 COMPZ CASING PULD P PJSM while observing well for flow, Lay down liner running BHA#12 19:27 21:03 1.60 0 1,304 COMPZ CASING PUTB P PJSM, P/U L1-02 Upper liner section, Ported Bullnose,39 Jts Slotted Liner BOP Drill @ Jt 15, Good Drill 1:35 21:03 22:27 1.40 1,304 1,349 COMPZ CASING PULD P 39 Jts Liner in well, R/D floor, M/U Coil Trak,Service Injector,Strip on well 22:27 23:27 1.00 1,349 6,148 COMPZ CASING RUNL P Trip in well, EDC closed 23:27 00:00 0.55 6,148 7,560 COMPZ CASING RUNL P At Flag, Correct+1.5, PUW=41K, Continue trip In 09/13/2011 RIH upper section L1-02 liner setting on depth TOL 6926'. PU/MU/RIH OH anchored billet setting on depth single slip 30 ROHS.TOB 6900'. POOH.Test BOPE.State witnessed by:John Crisp 00:00 00:15 0.25 7,560 8,232 COMPZ CASING RUNL P Continue trip In 00:15 00:21 0.10 8,232 8,232 COMPZ CASING RUNL P Tag up @ 8232, PUW with liner 45K, RBIH and set dowm, Pump off Liner_ PUW=36K. DHWOB indicates liner release also. PUH and remove liner length from counters, 1305.7, TQL=6925.7 00:21 02:03 1.70 8,232 45 COMPZ CASING TRIP P POOH, EDC Closed on 12LB KWF 02:03 02:45 0.70 45 0 COMPZ CASING PULD P At Surface, PJSM, lay down Liner running tools, BHA#13 02:45 03:27 0.70 PROD3 STK PULD P P/U BHA#14 Anchored Billet with, 9.68 and 3.80 Pup(13.48) Page 14 of 20 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 03:27 05:03 1.60 86 6,085 PROD3 STK TRIP P RIH with BHA#14,Anchored Billit, 13.48'solid pups 05:03 05:09 0.10 6,085 6,104 PROD3 STK DLOG P Tie into K-1,correct+3.5',Close EDC, PUW=38K 05:09 05:33 0.40 6,104 6,926 PROD3 STK TRIP P Trip in to set billet, clean pass through window 05:33 05:39 0.10 6,926 6,926 PROD3 STK WPST P Set down A 6926 PUW=38.5 K, ! Set back down. Pull up to 15K, L�, O' (6925.8) DHWOB=1.5K,Oriented15`� 30ROHS. Bring Pumps on.3 BPM tool stroked @ 3500 PSI, DHWOB now @ 4.8K, PUW=38.5 Clean Pick up,TOL=6900 05:39 07:30 1.85 6,926 0 PROD3 STK TRIP P POOH laying in KWF 07:30 09:00 1.50 0 0 PROD3 STK TRIP P Lay down BHA 09:00 10:30 1.50 0 0 PROD3 STK CIRC P Circ out Coil to F/W 10:30 12:00 1.50 0 0 PROD3 STK BOPE P Greased choke.stack and tree in preparation for BOP Test. 12:00 21:00 9.00 0 0 PROD3 STK BOPE P Start BOP Test. -a c 21:00 21:30 0.50 0 0 PROD3 STK CIRC P Swap CT back to KWF ►s} 21:30 22:00 0.50 0 0 PROD3 STK SVRG P Service inj. head 22:00 23:15 1.25 0 0 PROD3 STK PULD P PU/MU BHA 15. 23:15 00:00 0.75 0 PROD3 STK SVRG T Find error in Coil Life. Rerun jobs to correct. 09/14/2011 RIH with BHA 15. E-line pull out of drilling head at 1000'. POOH, perform slack management operations.Cut 50'CT. MU CTC and drilling head. RIH with BHA 16. Sidetrack L1-01 lateral off alluminum billet HS at 6900'. Drill ahead L1-01 lateral. 00:00 01:00 1.00 0 0 PROD3 STK SVRG T Correct Coile Life 01:00 01:15 0.25 0 1,000 PROD3 STK TRIP P RIH 01:15 01:30 0.25 1,000 1,000 PROD3 STK TRIP T Short in BHA, Diagnose surface equipment 01:30 01:45 0.25 1,000 0 PROD3 STK TRIP T POOH 01:45 02:00 0.25 0 0 PROD3 STK PULD T Diagnose short 02:00 03:30 1.50 0 0 PROD3 STK PULD T Pulled E-line out of Drilling Head. LD BHA. Prepare to reverse circulate fresh water for slack managmenet. 03:30 04:00 0.50 0 0 PROD3 STK SLPC T Reverse circulate to freshwater 04:00 04:30 0.50 0 0 PROD3 STK SLPC T Cut CT to find cable,fond cable 1 ft in, comectors pulled free. 04:30 05:30 1.00 0 0 PROD3 STK SLPC T Pump slack management, cut total of 47 ft of coil. 05:30 07:00 1.50 0 0 PROD3 STK SLPC T MU drilling head and pressure test. 07:00 09:00 2.00 0 0 PROD3 STK PULD T Pump slack foward, PU/MU drilling BHA, RIH 09:00 11:00 2.00 0 2,500 PROD3 STK TRIP P At 2500 ft,start spacer pill followed by flowpro at.3 bpm. 11:00 12:00 1.00 2,500 6,900 PROD3 STK TRIP P Tagged billet at 6900.8 ft,Circ out KWM at 1.2 bpm Page 15 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:30 2.50 6,901 6,910 PROD3 STK KOST P Start milling, 1.41 bpm, 1.0 fph, ctp=3430 14:30 15:00 0.50 6,910 6,930 PROD3 DRILL DRLG P Milled through billet, increase ROP to 32 FPH, Drill to 6930ft, puh to 6878ft, PU WT is 37k,offline with V pumps,drift through billet. No WT i i swings, looks good. � - (`► 15:00 16:00 1.00 6,930 6,966 PROD3 DRILL DRLG P Online at 1.4 BPM, Start Drilling at 105 FPH,CTP=3610 16:00 18:00 2.00 6,966 7,060 PROD3 DRILL DRLG P Drillling hard at 6966 ft, ROP down to 11 fph, broke through at 6973 ft, continue drilling ahead. 18:00 19:00 1.00 7,060 7,060 PROD3 DRILL WPRT P Wiper trip to window 40K PUW 19:00 21:00 2.00 7,060 7,210 PROD3 DRILL DRLG P Drill Ahead 3570 CTP,3900 BHP, 10K CTW, 1.4 BPM 21:00 22:00 1.00 7,210 7,210 PROD3 DRILL WPRT P Wiper trip to window 40K, PUW 22:00 00:00 2.00 7,210 7,360 PROD3 DRILL DRLG P Drill Ahead 3590 CTP, 3914 BHP,9K CTW, 1.4 BPM, 12 ECD X9/15/2011 Drill L1-01 Lateral, Perform mud swap 7960'. 00:00 01:30 1.50 7,360 7,360 PROD3 DRILL WPRT P Wiper trip back to window,40K.Tie in depth to RA marker+1'correction 01:30 03:15 1.75 7,360 7,510 PROD3 DRILL DRLG P Drill Ahead 3450 CTP,3921 BHP,9K CTW, 1.4 BPM 03:15 04:30 1.25 7,510 7,510 PROD3 DRILL WPRT P Wiper trip to window,41K PUW 04:30 06:00 1.50 7,510 7,660 PROD3 DRILL DRLG P Drill Ahead 3500 CTP,3963 BHP,7K CTW, 1.4 BPM 06:00 08:00 2.00 7,660 7,660 PROD3 DRILL WPRT P Wiper trip to window,46K PUW 08:00 09:45 1.75 7,660 7,810 PROD3 DRILL DRLG P Drill Ahead 3480 CTP,3947 BHP, 8K CTW, 1.4 BPM 09:45 11:30 1.75 7,810 7,810 PROD3 DRILL WPRT P Wiper trip back to window,46K PU WT.Tie in depth to RA marker+1.5' correction 11:30 13:30 2.00 7,810 7,960 PROD3 DRILL DRLG P Drill Ahead 3585 CTP,4016 BHP,6K CTW, 1.4 BPM, Pump sweep. 13:30 15:30 2.00 7,960 7,960 PROD3 DRILL WPRT P Wiper trip back to window,46K PU WT.Chase sweep up, Start Mud Swap after wiper trip.. 15:30 17:30 2.00 7,960 8,110 PROD3 DRILL DRLG P Drill ahead, 3579 CTP,4023 BHP, 8K CTW, 1.4 BPM 17:30 19:30 2.00 8,110 8,110 PROD3 DRILL WPRT P Wiper trip to window,47K PUW 19:30 21:30 2.00 8,110 8,260 PROD3 DRILL DRLG P Drill Ahead,3480 CTP,4020 BHP, 5K CTW, 1.4 BPM 21:30 23:45 2.25 8,260 8,260 PROD3 DRILL WPRT P Wiper trip to window,47K PUW.Tle in depth to RA marker. +3.5' 23:45 00:00 0.25 8,260 8,282 PROD3 DRILL DRLG P Drill Ahead,3480 CTP,4020 BHP, 5K CTW, 1.4 BPM 09/16/2011 TD L1-01 lateral 8530'. POOH to swab valves. RBIH to TD. Lay in liner running pill.Stuck pipe/packed off 7600'bit depth.After 6 hours get free.Clean up OH. 00:00 02:00 2.00 8,282 8,410 PROD3 DRILL DRLG P Drill Ahead.,3480 CTP,4020 BHP, 5K CTW, 1.4 BPM 02:00 04:30 2.50 8,410 8,410 PROD3 DRILL WPRT P Wiper trip to window Page 16 of 20 Time Logs Date` From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 04:45 0.25 8,410 8,410 PROD3 DRILL WPRT P Tag up, 8295,8300'._PU 45K,47K. RIH with TF drilled lower pump rates .5 BPM. 04:45 07:00 2.25 8,410 8,530 PROD3 DRILL DRLG P Drill Ahead 3480 CTP,3947 BHP, 8K CTW, 1.4 BPM,TD lateral at 8530 ft. 07:00 11:00 4.00 8,530 0 PROD3 DRILL WPRT P Pump low high sweep,chase up hole to surface, 1.48 BPM,CTP=3230, BHP=3822. 11:00 14:30 3.50 0 8,528 PROD3 DRILL WPRT P RBIH to tag at 8303 ft, rotate tool ‘<> face, rih to next tag at 8434 ft, worked through. rih to TD at 8528 ft. L t sf 14:30 15:30 1.00 8,528 7,600 PROD3 DRILL TRIP P On line with Beads, 1.0 BPM, CTP=2310, BHP=3927. 15:30 19:30 4.00 7,600 7,600 PROD3 DRILL TRIP T Pulled Heavy, Pipe stuck, attempt to get free. Pressure up coil 1500psi, Pressure up backside 1500 psi. Bleeding off backside. Pull 65K Set down-15K.Stuck 19:30 20:15 0.75 7,600 7,600 PROD3 DRILL TRIP T Call town for conf.Call. Discuss plan forward 20:15 21:00 0.75 7,600 7,013 PROD3 DRILL TRIP T Neutral weight 1500psi WHP, push -15K, PU 60K.ann. psi 3700, bore 3700. Neutral weight 2000psi WHP, push -15K, PU 60K.ann psi 3700, bore 3700. Neutral weight 2250psi WHP at 1.6 BPM,push-15K,Ann.psi increase 4100,4500, 5100. Shut down pumps.swap to circulate down CT. .5 BPM in .25 BPM out.Weight pop free to neutral. PU 41K. CT Free. Cont. PUH pumping 1.4 BPM 3450 CTP, 3900 ann psi. 21:00 21:15 0.25 7,013 7,100 PROD3 DRILL TRIP T 7013,over pull,ann. psi increase. RBIH to 7100'cleaning up hole. PUH,38K 1.4 BPM, 3450 CTP,3983 ann psi. Looks alot cleaner,7013, small pressure spike.A5 silt transition to A5 pay seems to have fell in on CT. 21:15 22:00 0.75 7,100 6,000 PROD3 DRILL TRIP T Cont POOH to TT displacing KWF with beads out CT circulating back to surface with FP. Increase MP schedule 200psi. Pebble size shale in bottoms up returns. Photos on S drive. 22:00 22:30 0.50 6,000 6,000 PROD3 DRILL DLOG T Tie in depth to K1 marker. Blow back MP choke,large amounts of silty rcok. +1'correction 22:30 23:45 1.25 6,000 8,300 PROD3 DRILL WPRT T RIH to TD, Inspect pipe for gripper block markings due to over pulls. Pipe looks good. 23:45 00:00 0.25 8,300 8,400 PROD3 DRILL WPRT T Tag 8300'PU 43K. Orient to drilled TF. Drop pump rate to.5 BPM. RIH to 8400'. Large amounts of silty rock in returns.size getting smaller Page 17 of 20 Time Logs Date From To Dur S.Death E. Depth Phase Code' Subcode T Comment 09/17/2011 24 hr Summary Pinhole CT 7200'. POOH.swap reels. Swap out reel motor and skates on inj. head. 00:00 01:30 1.50 8,400 6,194 PROD3 DRILL WPRT T POOH to window 45K 01:30 02:09 0.65 6,194 6,194 PROD3 DRILL SVRG T Repair MP choke 02:09 03:39 1.50 6,194 8,400 PROD3 DRILL WPRT T RBIH. Large amounts of lower A5 • silt. Smaller in size. 03:39 05:09 1.50 8,400 6,300 PROD3 DRILL WPRT T Tag$396.Still large amounts of Lower A5 silt in returns,smaller. POOH to window for another wiper trip. pressure spike at 8300'.Cont. PUH.43K PUW, 05:09 07:00 1.85 6,300 8,401 PROD3 DRILL WPRT T RBIH to stack out at 8401 ft, 07:00 10:00 3.00 8,401 0 PROD3 DRILL WPRT T POOH for wiper run,at 7200 ft, pin hole in pipe, hole is at reel,shut down for very short period, back online at 1.0 bpm, pooh. 10:00 14:00 4.00 0 0 PROD3 DRILL EQRP T At surface,Start to pressure undeploy, Rig injector off well. 14:00 20:00 6.00 0 0 PROD3 DRILL EQRP T Unstab pipe. Remove reel from rig 20:00 00:00 4.00 0 0 PROD3 DRILL RGRP T Swap out reel motor and skates on injector ***Nabors on Rig Repair rate***4hrs 09/18/2011 Diagnose/repair electrical alarms on reel motor.Complete Skate change. 00:00 08:00 8.00 0 0 PROD3 DRILL RGRP T Install new CT rael,JahQurs)Swap out reel motor ***Nabors on Rig Repair rate**** 8hrs. 08:00 18:00 10.00 0 0 PROD3 DRILL RGRP T Work on injector head,swapping out skates. MU inner reel iron. (3hrs) ***Nabors on Non-Billable rate*** 18:00 00:00 6.00 0 0 PROD3 DRILL RGRP T Conitnue working on reel motor ***Nabors back on Billable Time*** 6 hours adjusted for CPA tasks. (Install reel, MU reel iron) 09/19/2011 Complete reel motor swap. Stab CT. MU CTC/drilling head. Deploy BHA 17. RIH to 8295'.Wiper trip back to window. Lay in liner running pill. 00:00 06:00 6.00 0 0 PROD3 DRILL RGRP T Cont.working on reel motor,MU psi bulk head 06:00 12:00 6.00 0 0 PROD3 DRILL RGRP T Start to stab pipe,change packoffs, reverse circulate f/w through new coil string,off well,a-line cable is hanging out of coil, no pipe cut, make up connector. 12:00 17:00 5.00 0 0 PROD3 DRILL PULD T Make up CTC and drilling head, BHA 17,pressure deploy. 17:00 19:15 2.25 62 6,065 PROD3 DRILL TRIP T RIH with BHA#17, Page 18 of 20 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 19:15 19:30 0.25 6,065 6,065 PROD3 DRILL DLOG T Tie in depth to K1 +8.5' 19:30 20:45 1.25 6,065 8,291 PROD3 DRILL TRIP T RIH to TD,_Pump low/high sweeps. Tag 8291' 20:45 22:00 1.25 8,291 6,300 PROD3 DRILL WPRT T Wiper trip to window chasing pills to. 39K PUW 22:00 22:15 0.25 6,300 6,300 PROD3 DRILL WPRT T Pull heavy,with pressure spike 6422', 6317'.Tie in depth to RA marker. +5'correction. 22:15 22:30 0.25 6,300 6,720 PROD3 DRILL WPRT T RBIH,to EOB 22:30 23:00 0.50 6,720 6,300 PROD3 DRILL WPRT T PUH to window. 39K PUW.Clean wiper to window 23:00 00:00 1.00 6,300 PROD3 DRILL WPRT T RBIH 09/20/2011 Run Slotted liner from 8308'-6770'. Ran Solid liner with 6ft sealbore assembly from 6770'-6213'.Swap well to SW and POOH freeze protecting well from 2500'. 00:00 00:30 0.50 8,000 8,300 PROD3 DRILL WPRT T RIH to 8300' 00:30 01:45 1.25 8,300 6,300 PROD3 DRILL TRIP P Lay in liner running pill. (Formate with beads)to window. 01:45 03:15 1.50 6,300 0 PROD3 DRILL TRIP P POOH laying in KWF. 13.1ppg Formate. Paint EOP flag 6600', 4600'. 03:15 03:30 0.25 0 0 PROD3 DRILL SFTY P At surface, PJSM,flow check 03:30 04:30 1.00 0 0 PROD3 DRILL PULD P LD BHA 17 04:30 07:30 3.00 0 0 COMPZ CASING SVRG P Perform BOPE function test. Prepare floor to run liner 07:30 11:15 3.75 0 1,538 COMPZ CASING PUTB P Start running bottom section of liner,_ 46jts of slotted. 11:15 11:45 0.50 1,538 7,586 COMPZ CASING RUNL P RIH, EOP depth correction+4 11:45 13:15 1.50 7,586 8,308 COMPZ CASING RUNL P Tag 7586. PUH 60K, RIH-5K,Cont to work liner down 13:15 13:30 0.25 8,308 8,308 COMPZ CASING RUNL P Release off liner.4500psi CTP, PUH 37K. Liner released.TOL 6769'. 13:30 15:45 2.25 8,308 0 COMPZ CASING RUNL P POOH 15:45 16:00 0.25 0 0 COMPZ CASING RUNL P Monitor well for flow 16:00 17:00 1.00 0 0 COMPZ CASING PULD P LD BHA 17:00 18:00 1.00 0 550 COMPZ CASING PUTB P Prepare floor&P/U 18 joints of solid liner. 18:00 18:30 0.50 550 598 COMPZ CASING PULD P P/U Coiltrack assembly 18:30 20:30 2.00 598 6,765 COMPZ CASING RUNL P RIH with EDC closed pumping.3 bpm.Weight check @ 6205'-34K. RIH tag bottom x_6765'-WOB 5K. String 42K-4.3K WOB. RIH Tag. 6765' 20:30 21:00 0.50 6,765 6,060 COMPZ CASING RUNL P Start pumping 1.25 bpm, P/U weight 36K-1.8 WOB. P/U&tie into K-1. +3ft correction. TOL=6213' 21:00 00:00 3.00 6,060 5,000 COMPZ CASING TRIP P RIH to 6180'&circ out KWF.POOH pumping SW,followed by diesel to freeze protect the well. Page 19 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09/21/2011 24 hr Summary Freeze protect well from 2500'to surface.SITP 1300 psi.Set BPV. Pump corrosion inhibitor through CT& stack. Rig down&wait on rig move equipment due to road closure. 00:00 02:00 2.00 5,000 50 COMPZ CASING TRIP P POOH freeze protecting the well from 2500'taking returns to Tiger tank. 02:00 03:30 1.50 50 0 COMPZ CASING PULD P PJSM-Undeploy BHA. 1250 psi SITP. 03:30 04:30 1.00 0 0 DEMOB WHDBO SVRG P Set up rig floor for BPV instalation 04:30 07:30 3.00 0 0 DEMOB WHDBO NUND P PJSM-rig up BPV lubricator and pressure test. Install BPV. 07:30 08:30 1.00 0 0 DEMOB WHDBO NUND P Prepare to Flush CT,and rig with corrosion inhibitor. 08:30 09:30 1.00 0 0 DEMOB WHDBO NUND P Flush and purge, ND BOP's 09:30 18:00 8.50 0 0 DEMOB WHDBO DMOB P Prepare rig for move 18:00 00:00 6.00 0 0 DEMOB MOVE DMOB T Wait on Trucks. (Spine road blocked from dadhorse to KRU due to road/Rig repairs). Work on mud pump&pit repairs or inspections. 09/22/2011 Wait on spine road closure. 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O CC y L..--.0) 0) 0) 0) m 0) 0) m 0) C N Ln to Lf) to to to Ln 10 O _ .. v is 5 0 0) rn m mamma co Z to (n Ln !n Ln l0 Ln Ln (n CO Q a) v 0 c ,_ c'i al › 0 N 2 w --,.,75 co - 0 d C) cc 0 N to in v N- CO m N- to Q �.L >. (0 m O M n V (0 N V Y. (I?,4yy-, 2� S (6 � co m (V to to O 4- O 0 4..1 O >p p o 7 N _ r` ti n CO W W m ✓ J I- Z (n p W .- .- L- N O + 0 0 U N CO CO 0) N CO CO V N (n co N a Ln N a m N co c0 m m O CO CO M CO CO CO R V V R Z w�. +coo CO ((00 ((00 N to (">, 00 CO O 0) CO N .- M4V a to p ..'�.. m N N N N (V N N N (0 ( D (O (D 0 CO(0 COO m (0 h (0 co M a) .- O I LL On to m M CO m 0 0 M o ow O O NCA N N M M M M M (h CO M CO — F- — (0 CO CO CO CO CO Co CO CO (Q Y N (D = _ _ _ Q D -a N- N N to co 4 7 co (0 /� Ci 6 m v L a) a- a) Q a(o CO COO N N. n N. (O CO f _ > w .vim , Y 0 idd Y D (� O• l4 O N N N _ ((0 N 0) CD CO CO V CO CO w<r 0 o p c1 O W W W =°... ro CO COao CO CO CO CO CO 0. U Y Y a a OCOu (MO 7 (CO O CO CO (NO O /+ >, _ (o a Lf) N h h O M O C C .. .. p O O O r LO a0 •N N co n l"\ O. .. S m v m m m m m m m m m �`( • '� ii;i — — (n N Io O 0 v) 0 cn N ConocoPhillips PTD zit- 615 1E-27L1 4 4 e Co ocoP fillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) t mncoH•,II,p. 500292083760 KUPARUK RIVER UNIT PROD 96.21 8,765.49 9,310.0 Comment H2S(ppm) Date Annotation End Dote KB-Grd(ft) Rig Release Date "' SSSV:TRDP Last WO: 12/30/1984 39.00 10/19/1982 Well Contg:-1E-27L1.10/5/2011 11.12.10 AM Schematb-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6.362.0 7/30/2011 Rev Reason:ADD LATERALS ninam 10/5/2011 HANGER,27 Casing Strings ;�. Casing Description String 0... String ID...Top(ftKB) Set Depth)f...Set Depth(TVD)...String Wt...String...String Top Thrd 1 r LINER L1 2 3/8 1.992 8,449.4 9,310.0 6.323.7 4.70 L-80 STL Liner Details Top Depth I (TVD) Top not Nani... Top(ftKB) (ftKB) e) Item Description Comment ID(in) 8,449.4 6,293.0 85.78 BILLET ANCHORED BILLET 1.000 8,504.2 6,297.7 84.61 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.992 CONDUCTOR, • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 32.65Top Depth __---- I 1! (TVD) Top net SAFETY VLV, T B (ftKB) (°) Description 1,871 op(ftK) pilon Comment_ Run Date ID(In) 8,450 6,293.0 85.76 WHIPSTOCK ANCHOR BILLET 9/9/2011 Perforations&Slots Shot Top(TVD) Bte,(TVD) Dans Top(ftKB) Bbn(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment SURFACE. -A & 8,461 8,494 6,293.8 6,296.8 9/8/2011 32.0 SLOTS Alternating solid/slotted pipe- 32-2 218 -` 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered ���p 18 deg,3'non-slotted ends GAS LES iaai PC0 %�, 8,505 9,310 6,297.8 6,323.7 9/8/2011 3Z0 SLOTS IL SBR,5,940- _\ PACKER.5.966 1.1 INJECTION, 6,005 INJECTION, 6.080 i`—T PERF, _, • 6,122-e,167 IPERF, • - 0,17].6,185 I INJECTION, 'int 0,204 INF Cement Squeeze,6,215 LOCATOR, _ 8,219 PACKER,6,220 ADAPTER, 6,224 SBE,6,224 IPERF, 6,235.6,237 NIPPLE,0,230 VALVE,6.230f !. PRODUCT s05,6.24ION5, - 'Mandrel Details — - 30-0,775 � � Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Ste Top(ftKB) (ftKB) (0) Mak* Model _(In) Ser, Type Type (in) (PM) Run Date Can... 1 5,897.9 5,825.0 22.31 OTIS LBX 1 12 GAS LIFT OV RM 0.188 0.0 9/25/2011 WHIPSTOCK, 2 6,005.1 5,923.6 22.55 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 7/31/2011 8,460 3 6,080.1 5,992.5 23.55 OTIS -LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 SLOTS, 6,203.8 6,105.3 24.95 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 8/5/1997 8,461.8,404 - SLOTS, 8,5054,310 s.3 LINER LI, 8,4404,310 TO(1E-27L1),� 0,310 1E-27L1, L1-02, and L1-01 CTD ConocoPhillips SIDETRACK Ott-c 5 3'/2" Camco TRDP-1A-ENC SSSV sssv at 1,874'MDrkb LEEM GLM# Type MD-RKB TVD-RKB Valve Type 1 Otis LBX 5,898 5,825 Dummy 2 Otis LBX 6,005 5,924 Dummy 3 Otis LBX 6,080 5,993 Dummy 4 Otis LBX 6,204 6,105 Dummy 10-3/4"45.5#K-55 BTC casing Set @ 2,218'MD/2,217'TVD Otis RRH Packer Set 5966'MD/5,888'TVD 1 - C Sand Perfs: - J - 7,704'-7,726' �-� r- Isolated between packers 5 Otis WD Packer Set 6,221'MD/6,120'TVD 2-3/8"4.7#L-80 liner top 6,215'MD/6,115'TVD 3'h"9.3#L-80 IBTM SC tubing tail at 6,237 MD 1E-27L1-01 1E-27L1-02 TD:8,528'MD/6.278'TVD TD:9,603'MD/6,253 TVD Top of window 1 6,288'MD/ j 6,182'TVD ....../1111.111111111111 1E-27L1 TD:9,310'MD/6,324'TVD I A Sand Perfs: 7,704'-7,726' - •- ., Anchored Billet Anchored Billet 6,900'MD/ 8,449'MD/ 6,261'TVD 6,293'TVD Original Wellbore 7.0"26.0#K-55 @ 6,715 MD/6,563'TVD rage i or i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) (a r a 0 Sent: Tuesday, September 27, 2011 8:10 AM —�' a O� c To: 'CPF1 Prod Engr' 7 k \ -0c1. (4, Cc: NSK Prod Engr& Optimization Supv; Schwartz, Guy L(DOA); Davies, Stephen F (DOA) Subject: RE: 1E-27 (PTD 182-163) Daniel, I checked our records and 1E-27 is still listed as a service well, lwinj and I do not find that any completion reports (Form 407) for the new laterals have been filed. A 404 should be submitted changing 1 E-27 to development, 1-oil and 407s should be submitted for the new laterals also showing development, 1-oil. When was drilling completed on the new laterals? For a production well or well + laterals, I am not aware that the paperwork needs to be submitted prior to placing the well(s) in operation although new completion reports are due within 30 days of well completion which in this case would be likely when CDR2AC was released. You are correct that when the well is changed from production (pre-produced)to injection that the 403s (4 of them in this case) must be filed. Those documents need to be approved PRIOR to initiating injection into the well(s). Call or message with any questions. Please reply all with any messages. Tom Maunder, PE AOGCC From: CPF1 Prod Engr [mailto:n1269@conocophillips.com] Sent: Tuesday, September 27, 2011 6:24 AM To: Schwartz, Guy L(DOA) Cc: Maunder,Thomas E (DOA); NSK Prod Engr&Optimization Supv Subject: 1E-27 (PTD 182-163) Guy, ConocoPhillips requests confirmation that all required documentation is in place to bring newly CTD sidetracked well 1E-27 (PTD 182-163)on production as a pre-produced injector. The well will be pre produced for 1-3 months then swapped over to an injection well after the appropriate 10-403 documentation has been filed. Please advise, thanks. Daniel Bearden/David Lagerlef CPF1 Production Engineers n1269@conocophillips.com 907-659-7493 pager 907-659-7000 #765 9/27/2011 'RECEIVED SEP 2 3 2Q11 Letter of Transmittal ka p:181, GasCans•Cossionpies • eBAKER Date: �nC�O{�September 2011 HUGHES To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1E-27L1 1E-27L1-01 1E-27L1-02 (3) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes Operations Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes SurveyManager r Carl.Ulrich@BakerHughes.com scifE T$/ [ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMAIISSIONT ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Lamar Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-27L1 ConocoPhillips Alaska, Inc. Permit No: 211-095 Surface Location: 307' FNL, 641' FEL, SEC. 21, T11N, R 10E, UM Bottomhole Location: 181' FSL, 1570' FWL, SEC. 15, T11N, R10E, 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 1E-27, Permit No 182- 163, API 50-029-20837-00. 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, l aniel T. eamount, Jr. 14 Chair DATED this Zday of August, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COM ION PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj 0 - Single Zone 0 - 1 c.Specify if well is proposed for: Drill ❑ Redrill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: 0 Blanket ❑ Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 . 1E-27L1 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage AK 99510-0360 MD: 9600 ' TVD: 6233 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Oil Pool - Surface: 307'FNL,641'FEL,Sec 21,T11N,R10E,UM , ` ADL 25651 ALK 469 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 213'FNL,1153'FEL,Sec 21,T11N,R10E,UM 2657 8/30/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 181'FSL,1570'FWL,Sec 15,T11N,R10E,UM 2560 / 5N�,.=) ( 20,200'to KPA Boundary - 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above fid/c,-)66:7-7 feet 15.Distance to Nearest Well Open Surface x- 549,890 . y- 5,959,280 ' Zone-4 GL Elevation above f 40.1 feet to Same Pool: 1E-21, 800' 16.Deviated wells: Kickoff depth: 6,285 feet . 17.Maximum AnticipatedPPressures in psig(see 20 AAC 25.035) 714-Sof/./r Maximum Hole Angle: 103.2 degrees Downhole:37z0 d Ydf-i/ Surface: 3ouo 18.Casing Program: Specifications Top - Setting Depth - Bottom ,:tCement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD ¢ Ipetin�4stage data) 3" 2-3/8 4.7 ppf L-80 STL 2,495 7100 6153 9595 6233 ' "L .. l . 411: �i�u �e '�'� x r. . '-iE4,. a.iofiS, �_z,,. ,f !.,,),f)isson 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) /IP,t ,ti�G Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 6800 6550 6377 6265 Casing Length Size Cement Volume MD TVD Conductor/Structural 85 16 272 sx AS II 85 85 Surface 2,186 10-3/4 1500 sx AS III,250 sx AS I 2218 2218 Intermediate Production 6,685 7 635 sx Class G,250 sx AS I 6715 6564 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): (6122,6167),(6177,6185),(6330,6340),(6357,6382),(6390,6394) (6031,6072),(6081,6088),(6219,6228),(6244,6266),(6273,6277) 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.0 0 req irements 0 21. Verbal Approval: Commission Representative: Date 8/4/2011 22. I hereby certify that the foregoing is true and correct. Contact Mike A.Winfree Printed Name Lamar Gantt Title CTD Engineering Supervisor Signature thaw/12z Fog LAWN:. /7rPhone 263-4021 Date 8/4/2011 Commission Use Only Permit to Drill API Number: �} Permit A r val See cover letter for other Number: / I 50 ( �20657 �� 3 �'� � Date: i 1 i requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [r j� Other: 10-p 0 (S` 5 a r ll/�S 1- Samples req'd: Yes❑;No[r Mud log req'd: Yes ❑ No 0T �7 / \ HZS measures: Yes[ No El Directional svy req'd: Yes ❑✓ No CI it- “. l 4-i rn 4. .. d pe-r "os. arccoed �( Al 0 Z B �T re �� / APPROVED BY THE COMMISSION / DATE: .�r�/ ,COMMISSIONER 7.Ir-its 1 r Form 10-401(Revised 7/2009) This permit is valid for 24 ft ti f r .n Il ft$f ApEal(20 AAC 25.005(g)) Submit in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 LVED AUG 0 8, ?Q1` August 5, 2011 nr �r�l itift6, �`j�fniss10R Commissioner- State of Alaska !MOH?N6g0 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill applications for two coiled tubing drilling (CTD) laterals out of Kuparuk well 1E-27 (PTD# 182-163) using the Nabors CDR2-AC coiled tubing drilling rig. The objective is to drill two injection A-sand laterals: 1E-27L1, and 1E-27L1-01. Work is scheduled to begin in September 2011. A sundry has already been approved (#311-228)for 1 E-27 pre-rig well work. Attached to this application are the following documents that explain the proposed job operations: - Permit to Drill Application Forms for 1E-27L1 and 1E-27L1-01 - Proposed & Current Wellbore Schematic - BOP Schematic - Detailed Summary of Operations - Directional Plans If you have any questions or require additional information regarding the 1E-27L1 and 1E-27L1-01 Application for Permit to Drill, please call 907-265-6820. Sincerely, NNAv.._. Mike -- Mike A. Winfre ConocoPhillips Alaska CTD Drilling Engineer ORIGINAL KRU 1E-27L1 and 1E-27L1 01 — Coiled Tubing Drilling Summary of Operations: Well 1E-27 is a Kuparuk A/C sand production well equipped with a selective single 3Y2"tubing completion and 7"production casing. Two proposed A-sand CTD laterals will increase reservoir exposure and support future CTD producers 1E-05 and 1E-24A. Prior to drilling,the existing A-Sand perfs in 1E-27 will be squeezed with cement to provide a means to kick out of the 7"casing. C sand perforations will be left open. ✓ After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 6,285' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 1E-27L1 sidetrack will exit the 7"casing at 6,285' MD and will target the A4 sand east of the existing well with a 3,315' lateral. The hole will be completed with a 2%" slotted liner from the TD of 9,600' MD with an anchored aluminum billet at 7,100' MD. • The 1E-27L1-01 lateral will kick off from the aluminum billet at 7,100' MD and will target the A5 sand east of the existing well with a 2,350' lateral. The hole will be completed with a 2%" slotted liner from the TD of 9,450' MD with the final liner top located just inside the 3'/2"tubing at 6,240' MD. CTD Drill and Complete 1E-27 Laterals Pre-CTD Work(Sundry Number 311-228) 1. Positive pressure and drawdown tests on master valve&swab valve 2. RU slickline. Obtain updated static BHP on A-sand. Dummy off all GLMs. RD slickline. 3. RU e-line. Perf holes in 3'/2"tubing tail at 6,230' MD. RD e-line. 4. RU coil. Mill out XN-nipple in tubing tail to 2.80"ID. Plug the A-sand perfs with cement up to 6,230' MD. RD coil. . , 5r4 N p zt. 5. RU slickline. Tag top of cement. RD slickline. a PEN to 6. Prep site for Nabors CDR2-AC, including setting BPV , Sundry Work Ends Here The Following Operations are Proposed for the APD Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE,test. 2. 1E-27L1 Sidetrack(A4 sand, east) - a. Drill 2.80"high-side pilot hole through cement to 6,315' MD. • b. Drift pilot hole with whipstock dummy • c. Set whipstock at 6,285' MD with high-side orientation. d. Mill 2.80"window with high-side orientation at 6,285' MD. \ , e. Drill 2.70"x 3"bi-center lateral to TD of 9,600' MD f. Run 2%"slotted liner with an aluminum billet from TD up to 7,100' MD 3. 1E-27L1-01 Lateral(A5 sand, east) a. Kick off of the aluminum billet at 7,100' MD b. Drill 2.70"x 3"bi-center lateral to TD of 9,450' MD c. Run 2%" slotted liner from TD up to 6,240' MD,up inside the 3'/2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Flow back well to clean up and put on injection ORG1NAL KRU 1E-27L1 and 1E-27L1 01 — Coiled Tubing Drilling Mud Program: • Will use chloride-based Biozan brine or used drilling mud(9.8 ppg)for milling operations, and chloride- ,/ based Flo-Pro mud(9.ppg)for drilling operations. We will have to kill the well with weighted brine in order to deploy 2%"slotted liner in the two laterals. Disposal: • This well will not be used for annular injection • Class II liquids to KRU 1R Pad Class II disposal well / • Class II drill solids to Grind&Inject at PBU Drill site 4 . • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1E-27L1: 2%",4.7#, L-80, ST-L slotted/solid liner from 7,100' MD to 9,595' MD - • 1E-27L1-01: 2%",4.7#,L-80, ST-L slotted/solid liner from 6,285' MD to 9,445' MD Existing Casing/Liner Information Surface: 10-3/4",K-55,45.5 ppf Burst 3,580 psi Collapse 2,090 psi Production: 7",K-55, 26 ppf Burst 4,980 psi Collapse 4,320 psi Logging • MWD directional,resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 1E-27 was taken August 1St,2011. The A-sand reservoir pressure was measured at 3,284 psi at 6,354' MD,6,233' SSTVD,which is 10.2 ppg EMW. Well Control: / • Two well bore volumes(-180 bbl)of KWF will be available to the rig during drilling operations. The kill ./ weight fluid may or may not be stored onsite,but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2"coil tubing. • Pipe rams,blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum potential surface pressure in 1E-27 is 3,120 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 3,724 psi at 6,032' TVD taken April 19th 2011,corresponding to 11.9 ppg EMW formation pressure. The BHP has been managed down to the current pressure of 10.3 ppg EMW by allowing the A sand to crossflow to the C sand. • The annular preventer will be tested to 250 psi and 2500 psi. ORIGINAL KRU 1E-27L1 and 1E-27L1 01 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 1E-27L1wp04 2. 1E-27L1-0 1 wp06 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 1E-27 CTD laterals L1 and L1-01 are 20,200' and 20,350' respectively to KPA boundary Hazards • Shale stability is the most significant problem expected. It will be mitigated by directional planning to minimize exposure to the worst shales and by applying MPD pressure to maintain hole stability. • There has been MI gas injection in the vicinity of 1E-27 in injector 1E-21. The vast majority of the MI has been into the C sand and not the A sand which is the target sand for this well, so it is unlikely that an influx will yield significant quantities of gas. • Well 1E-27 is located at the end of the well row and 60' to the offset well 1E-170 surface location. 1E- 170 measured 40 ppm on 9/15/2010. The maximum H2S level on the pad is 250 ppm from well 1E-05 (6/18/06)which is currently shut in. All H25 monitoring equipment will be operational. / Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by 1 using 9.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure.Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. Well 1E-27 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 3,284 psi at 9,600' MD(6,233' TVDss), or 10.2 ppg EMW. • Expected annular friction losses while circulating: 960 psi(assuming annular friction of 100 psi/1000 ft due to the 3'/2"tubing) • Planned mud density of 9.8 ppg equates to 3,176 psi hydrostatic bottom hole pressure at 6,233' TVD. ' • While circulating 9.8 ppg mud,bottom hole circulating pressure is estimated to be 4,140 psi or 12.8 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 1E-27. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability,but not necessarily for well control. • When circulation is stopped,—960 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. ORIGINAL KRU 1E-27L1 and 1E-27L1 01 — Coiled Tubing Drilling Quarter-Mile Injection Review The following wells lay within one-quarter mile of the proposed 1E-27 CTD laterals. 1E-25(SI Injector) r Shut in since 9/94 due to low productivity/freezing problem. 1E-21 (Active MWAG injector) Currently on water. Injection is C sand dominated. The last BHP pressure was 2506 PSI(AC)in December ' 2010. 1E-29(active producer) , A/C sand producer. ORIGINAL obi 11111 W te10 a= Me '', ill1111�I . . t '!II . T LI II .� I,- i g Q r, Lr3 w.-. OOZ9 g 0.9 ii ViA 0019 _ is 1W2)S�� s d o pillN I� - 8 J IIH � W N /1 r /- co • w� 1 / H �� — Lu 82 • m o � � R m L m • 1 Ali II o it '711-- s ..<__ ED. imin i LI 0 , ..._... _ ,Af:Illo A ,.. ..,3 1 'Ai, 0 z - C J `' O 7 9 A ,,„:„.—.....,„.....„4-*Or is �. w w J N Q : 6N N w .. y,-_ �bgr _ x o .,.., Y Y '— .... G L J Boo - , C i - - 14 1._ , „ -‘,.., . _. " . , w 23 �F- O 1611 s _ . v L }QK � N N N O� 00. � N N ORtlNkL0 8 c 8 °..1 N Proposed 1E-27L1 and 1E-27L1-01 Schematic i LI 16"65#H-40 shoe @ 85' MD n 10-314"45#K- 55 shoe @ 2218'MD W Otis RH Pkr @ _____r–r 5966'MD .6005 6080 C-sand perfs * �.__— Steel Blast its - 6120-6197 6122-6185' _ MD f Otis WD Pkr d- - w__ 16220'RKB -----............i, E! 6204 Otis SOS @ 6245'RKB .37'ELM based ----1- 1,2187 PPROF) OP@6285'MD _ 1E-27L1WP04 _ Csg collar at 6300' a A-sand perfs `kms 6330'-6394'MD 1E-27 L1-01 WP06 7"26#K55 shoe @6715'MD —.mall ........_ ORIGINAL KUP 1E-27 ConocoPhillips /" Well Attributes Max Angle&MD TD Aid>nd,Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(RKB) Lq„rKorhi11irrs 500292083700 KUPARUK RIVER UNIT INJ 27.20 6,550.00 6,800.0 Comment H25(ppm) Date Annotation End Date KB.Grd(R) Rig Release Date --• Well Confla:-1E-27.4/20/2011 1:21:07 PM -SSSV:TRDP Last WO: 12/30/1984 39.00 10/19/1982 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,362.0 12/9/2010 Rev Reason:Pull Plug/Gauges,GLV C/O Imosbor 4/20/2011 - - Casing Strings HANGER.27 ' Casing Description String 0... String ID...Top(ROB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.060 32.0 85.0 85.0 65.00 H-40 WELDED _ Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd _' r SURFACE 103/4 9.794 31.6 2,217.6 2,217.5 45.50 K-55 BTC Casing Description String 0... Strang ID...Top(RKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd ' PRODUCTION 7 6.151 30.5 6,715.1 6,563.8 26.00 K-55 BTC Tubing Strings i Ili Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd I TUBING 31/2 2.992 27.3 6,245.4 6,143.2 9.20 J-55 BTC-MOD ' '" Completion Details CONDUCTOR, Top Depth 32-85 (TVD) Top Incl Noma... Top(RKB) (RKB) (1) Rem Description Comment ID(In) SAFETY-VLV, I �.I 27.3 27.3 0.09 HANGER FMC GEN III HANGER 3.500 1.674 1,874.3 1,874.2 0.66 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.813 5,940.0 5,864.2 23.06 SBR OTIS SBR 2.813 5,966.1 5,888.2 23.11 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 ( 6,120.3 6,029.6 24.03 BLAST JTS CAMCO STEEL BLAST JOINTS 2.992 1 6,219.2 6,119.4 24.99 LOCATOR OTIS STRAIGHT SLOT LOCATOR 2.992 BURFAE,___ ,/ ► 6,220.5 6,120.6 25.00 PACKER OTIS WD PERMANENT PACKER 4.000 322,218 6,223.9 6,123.6 25.02 ADAPTER OTIS PACKER ADAPTER 4.000 6,224.4 6,124.1 25.02 SBE OTIS SEAL BORE EXTENSION 2.970 GAS LIFT 6,238.7 6,137.1 25.09 NIPPLE CAMCO D NIPPLE NO GO 2.750 5.898 t 6,244.7 6,142.6 25.13 SOS OTIS SHEAR OUT SUB 3.950 Perforations&Slots Shot sSR.5,940 ToBt(f(TVD) Dens i---1 Top(RKB) Btm(RKB) (ftKB)RKB) (RKB) Zone Date (sh _ Type Comment 6,122.0 6,167.0 6,031.2 6,072.2 C-4,C-3,1E-27 10/18/1982 4.0 IPERF PACKER,5,966 6,177.0 6,185.0 6,081.3 6,088.6 C-2,C-1,1E-27 10/18/1982 4.0 IPERF --- 6,330.0 6,340.0 6,219.7 6,228.7 A-5,1E-27 10/18/1982 4.0,IPERF 6,357.0 6,382.0 6,244.0 6,266.6 A-4,1E-27 10/18/1982 4.0 IPERF _ 6,390.0 6,394.0 6,273.8 6,277.4 A-4,1E-27 10/18/1982 4.0 IPERF INJECTION,_ 6,005 ION. _--4 Com. Notes:General&Safety End Date Annotation 9/72010 NOTE:View Schematic w/Alaska Schematic9.0 INJECTION. s ONMO. 0 H PERF, 8,12IERF. 2-6,167 IPERF, --- 6,177-6,185 H INJECTION, 6.204 T LOCATOR, 6,219 PACKER,6,220 ADAPTER, 6,224 i En SSE,0.224 ) NIPPLE,6.239 IIII L Mandrel Details Top Depth I Top Port (TVD) Incl OD Valve Latch Site TRO Run SOS 6,285 Ste Top(RKB) (RKB) r) Make Model (In) Sere Type Type (In) (pep Run Date Com... I. 1 5,897.9 5,825.4 22.98 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0 8/5/1997 2 6,005.1 5,923.5 22.62 OTIS LBX 1 1/2 INJ HFCV RM 0.000 0.0 4/19/2001 IPERF. II3 6,080.1 5,992.9 23.54 OTIS LBX 1 12 INJ DMY RM 0.000 0.08/5/1997 6.3306,340 III 41 6,203.81 6,105.4 24.91 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 85/1997 PERF, 6,357-6.382(PERE, IPERF, 6.3906,394 PRODUCTION, 366.7,5 ORIGINAL TD,6,800 Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing C4 Lubricator Riser r J Annular/ Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator f� \ J L 4 above BHA rams ►V / <D<1 ' I Choke 1 2-3/8" Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip(BHA) Kill ►D�><J L><D><� 1 1- Blind Blind/Shear 2" Pipe/Slip (CT) -1 r Choke 2 1 Swab Valves L, °�\Wing Valves J L Si z Tree Flow Cross 1 r Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, CO62 Union ORIGINAL ConocoPh i l l i s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-27 1E-27L1 Plan: 1 E-27L1_wp04 Standard Planning Report 14 July, 2011 v' u BAKER HUGHES ConocoPhillips or its affiliates F/,h ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-27 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-27 @ 105.70ft(1 E-27) ' Site: Kuparuk 1E Pad North Reference: True Well: 1E-27 Survey Calculation Method: Minimum Curvature Wellbore: 1E-27L1 Design: 1 E-27L1_wp04 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Datum:D m: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.022 N From: Map Easting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38° Well 1 E-27 Well Position +N/-S 0.00 ft Northing: 5,959,279.85 ft • Latitude: 70°17'58.297 N +EI-W 0.00 ft Easting: 549,889.55 ft - Longitude: 149°35'45.449 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 66.70 ft Wellbore 1E-27L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) O (nT) BGGM2011 9/1/2011 16.66 79.88 57,370 Design 1E-27L1_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,275.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) -66.70 0.00 0.00 90.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (1100ft) (°) Target 6,275.00 25.20 297.42 6,064.16 92.39 -507.90 0.00 0.00 0.00 0.00 6,285.00 25.27 297.52 6,073.21 94.36 -511.69 0.82 0.70 1.00 31.39 6,306.00 28.21 297.52 6,091.96 98.72 -520.06 14.00 14.00 0.00 0.00 6,443.31 90.00 297.52 6,159.10 150.56 -619.57 45.00 45.00 0.00 0.00 6,735.00 90.00 68.78 6,159.10 382.17 -606.82 45.00 0.00 45.00 90.00 7,085.00 91.57 82.69 6,154.28 468.19 -268.49 4.00 0.45 3.98 83.50 7,435.00 90.00 96.61 6,149.46 470.31 80.60 4.00 -0.45 3.98 96.30 7,585.00 75.00 96.61 6,168.98 453.24 227.91 10.00 -10.00 0.00 180.00 7,725.00 78.10 101.41 6,201.55 431.90 362.33 4.00 2.21 3.43 57.00 8,022.51 90.00 101.41 6,232.34 373.49 651.87 4.00 4.00 0.00 0.00 8,372.51 93.36 87.81 6,222.04 345.43 999.72 4.00 0.96 -3.89 284.00 8,497.51 103.36 87.81 6,203.90 350.16 1,123.15 8.00 8.00 0.00 0.00 8,664.51 90.00 87.81 6,184.54 356.50 1,288.52 8.00 -8.00 0.00 180.00 8,924.51 86.12 78.15 6,193.37 388.20 1,546.07 4.00 -1.49 -3.71 248.00 9,184.51 86.00 88.57 6,211.29 418.15 1,803.35 4.00 -0.04 4.01 91.00 9,600.00 87.96 72.05 6,233.31 487.81 2,210.89 4.00 0.47 -3.98 276.30 7/14/2011 9:51:25AM Page 2 COMPASS 2003 16 Build 69 ORG1NAL r-' ConocoPhillips or its affiliates Fri ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-27 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-27 @ 105.70ft(1E-27) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-27 Survey Calculation Method: Minimum Curvature Wellbore: 1E-27L1 Design: 1 E-27L1_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-w Section Rate Azimuth Northing Easting (ft) (°) (') (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 6,275.00 25.20 297.42 6,064.16 92.39 -507.90 -507.90 0.00 0.00 5,959,368.86 549,381.09 TIP 6,285.00 25.27 297.52 6,073.21 94.36 -511.69 -511.69 0.82 31.39 5,959,370.80 549,377.30 KOP 6,300.00 27.37 297.52 6,086.65 97.43 -517.58 -517.58 14.00 0.00 5,959,373.83 549,371.38 6,306.00 28.21 297.52 6,091.96 98.72 -520.06 -520.06 14.00 0.00 5,959,375.11 549,368.89 3 6,400.00 70.51 297.52 6,151.80 130.94 -581.89 -581.89 45.00 0.00 5,959,406.91 549,306.86 6,443.31 90.00 297.52 6,159.10 150.56 -619.57 -619.57 45.00 0.00 5,959,426.28 549,269.06 4 6,500.00 90.00 323.03 6,159.10 186.91 -662.46 -662.46 45.00 90.00 5,959,462.34 549,225.92 6,600.00 90.00 8.03 6,159.10 281.27 -686.81 -686.81 45.00 90.00 5,959,556.52 549,200.95 6,700.00 90.00 53.03 6,159.10 365.21 -637.31 -637.31 45.00 90.00 5,959,640.78 549,249.89 6,735.00 90.00 68.78 6,159.10 382.17 -606.82 -606.82 45.00 90.00 5,959,657.95 549,280.26 End 45DLS 6,800.00 90.29 71.36 6,158.93 404.33 -545.72 -545.72 4.00 83.50 5,959,680.50 549,341.21 6,900.00 90.75 75.34 6,158.02 432.97 -449.94 -449.94 4.00 83.51 5,959,709.78 549,436.79 7,000.00 91.19 79.31 6,156.33 454.90 -352.41 -352.41 4.00 83.54 5,959,732.36 549,534.17 7,085.00 91.57 82.69 6,154.28 468.19 -268.49 -268.49 4.00 83.61 5,959,746.20 549,617.99 Ribsteer 7,100.00 91.50 83.29 6,153.88 470.02 -253.61 -253.61 4.00 96.30 5,959,748.13 549,632.85 7,200.00 91.06 87.27 6,151.64 478.24 -153.99 -153.99 4.00 96.32 5,959,757.01 549,732.40 7,300.00 90.61 91.24 6,150.18 479.54 -54.03 -54.03 4.00 96.40 5,959,758.98 549,832.34 7,400.00 90.16 95.22 6,149.51 473.91 45.79 45.79 4.00 96.46 5,959,754.01 549,932.19 7,435.00 90.00 96.61 6,149.46 470.31 80.60 80.60 4.00 96.49 5,959,750.64 549,967.02 7 7,500.00 83.50 96.61 6,153.14 462.84 145.03 145.03 10.00 -180.00 5,959,743.60 550,031.49 7,585.00 75.00 96.61 6,168.98 453.24 227.91 227.91 10.00 -180.00 5,959,734.55 550,114.42 8 7,600.00 75.33 97.13 6,172.82 451.51 242.31 242.31 4.00 57.00 5,959,732.91 550,128.83 7,700.00 77.54 100.56 6,196.28 436.55 338.34 338.34 4.00 56.87 5,959,718.60 550,224.95 7,725.00 78.10 101.41 6,201.55 431.90 362.33 362.33 4.00 56.06 5,959,714.10 550,248.97 9 7,800.00 81.10 101.41 6,215.09 417.31 434.63 434.63 4.00 0.00 5,959,700.00 550,321.36 7,900.00 85.10 101.41 6,227.10 397.69 531.92 531.92 4.00 0.00 5,959,681.02 550,418.77 8,000.00 89.10 101.41 6,232.16 377.94 629.80 629.80 4.00 0.00 5,959,661.93 550,516.77 8,022.51 90.00 101.41 6,232.34 373.49 651.87 651.87 4.00 0.00 5,959,657.62 550,538.86 10 8,100.00 90.75 98.40 6,231.83 360.17 728.19 728.19 4.00 -76.00 5,959,644.81 550,615.27 8,200.00 91.71 94.51 6,229.68 348.93 827.52 827.52 4.00 -76.02 5,959,634.23 550,714.65 8,300.00 92.67 90.63 6,225.86 344.44 927.32 927.32 4.00 -76.10 5,959,630.41 550,814.47 8,372.51 93.36 87.81 6,222.04 345.43 999.72 999.72 4.00 -76.25 5,959,631.88 550,886.86 11 8,400.00 95.55 87.81 6,219.91 346.48 1,027.10 1,027.10 8.00 0.00 5,959,633.11 550,914.23 8,497.51 103.36 87.81 6,203.90 350.16 1,123.15 1,123.15 8.00 0.00 5,959,637.43 551,010.24 12 8,500.00 103.16 87.81 6,203.33 350.25 1,125.56 1,125.56 8.00 -180.00 5,959,637.53 551,012.66 8,600.00 95.16 87.81 6,187.43 354.03 1,224.14 1,224.14 8.00 -180.00 5,959,641.96 551,111.19 8,664.51 90.00 87.81 6,184.54 356.50 1,288.52 1,288.52 8.00 -180.00 5,959,644.86 551,175.55 13 8,700.00 89.46 86.49 6,184.70 358.26 1,323.96 1,323.96 4.00 -112.00 5,959,646.86 551,210.97 8,800.00 87.97 82.78 6,186.95 367.61 1,423.48 1,423.48 4.00 -111.99 5,959,656.87 551,310.41 7/14/2011 9:51:25AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ti-' ConocoPhillips or its affiliates FailConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-27 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-27©105.70ft(1 E-27) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-27 Survey Calculation Method: Minimum Curvature Wellbore: 1E-27L1 Design: 1E-27L1_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,900.00 86.48 79.06 6,191.79 383.37 1,522.09 1,522.09 4.00 -111.91 5,959,673.28 551,408.91 8,924.51 86.12 78.15 6,193.37 388.20 1,546.07 1,546.07 4.00 -111.73 5,959,678.27 551,432.85 14 9,000.00 86.07 81.17 6,198.52 401.72 1,620.15 1,620.15 4.00 91.00 5,959,692.27 551,506.84 9,100.00 86.02 85.18 6,205.41 413.56 1,719.18 1,719.18 4.00 90.79 5,959,704.78 551,605.78 9,184.51 86.00 88.57 6,211.29 418.15 1,803.35 1,803.35 4.00 90.52 5,959,709.93 551,689.91 15 9,200.00 86.07 87.95 6,212.36 418.62 1,818.80 1,818.80 4.00 -83.70 5,959,710.50 551,705.35 9,300.00 86.52 83.97 6,218.82 425.65 1,918.32 1,918.32 4.00 -83.66 5,959,718.18 551,804.81 9,400.00 86.99 79.99 6,224.49 439.57 2,017.16 2,017.16 4.00 -83.40 5,959,732.76 551,903.55 9,500.00 87.47 76.02 6,229.32 460.32 2,114.84 2,114.84 4.00 -83.17 5,959,754.16 552,001.09 9,600.00 87.96 72.05 6,233.31 • 487.81 2,210.89 2,210.89 4.00 -82.98 5,959,782.28 552,096.94 TD 7/1'4/2011 9.51:25AM Page COMPASS 2003.16 Build 69 --' ConocoPhillips or its affiliates �/k ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-27 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-27 @ 105.70ft(1 E-27) Site: Kuparuk 1E Pad North Reference: True Well: 1E-27 Survey Calculation Method: Minimum Curvature Wellbore: 1E-27L1 Design: 1 E-27L1_wp04 Targets Target Name -hitmiss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1E-27L1 T3 0.00 0.00 6,208.00 407.81 310.42 5,959,689.68 550,197.22 70°18'2.307 N 149°35'36.400 W -plan misses target center by 37.05ft at 7680.23ft MD(6191.94 TVD,439.98 N,319.36 E) -Point 1E-27L1 T5 0.00 0.00 6,222.00 381.45 965.31 5,959,667.67 550,852.21 70°18'2.047 N 149°35'17.307 W -plan misses target center by 36.98ft at 8338.64ft MD(6223.93 TVD,344.53 N,965.92 E) -Polygon Point 1 6,222.00 664.00 1,039.18 5,959,950.67 550,924.20 Point 2 6,222.00 364.51 955.20 5,959,650.66 550,842.22 Point 3 6,222.00 103.92 889.47 5,959,389.66 550,778.22 1E-27L1 T6 0.00 0.00 6,184.00 381.15 1,311.34 5,959,669.66 551,198.21 70°18'2.044 N 149°35'7.219 W -plan misses target center by 23.58ft at 8688.54ft MD(6184.61 TVD,357.60 N,1312.51 E) -Point 1E-27L1 T4 0.00 0.00 6,232.00 374.59 644.23 5,959,658.67 550,531.22 70°18'1.980 N 149°35'26.668 W -plan hits target center -Point 1E-27L1 T1 0.00 0.00 6,160.00 415.76 -582.62 5,959,691.69 549,304.24 70°18'2.385 N 149°36'2.435 W -plan misses target center by 22.98ft at 6769.20ft MD(6159.05 TVD,394.17 N,-574.80 E) -Point 1 E-27L1 T2 0.00 0.00 6,149.00 451.43 68.68 5,959,731.68 549,955.23 70°18'2.736 N 149°35'43.447 W -plan misses target center by 20.10ft at 7425.09ft MD(6149.46 TVD,471.41 N,70.75 E) -Polygon Point 1 6,149.00 849.80 171.32 5,960,130.68 550,055.21 Point 2 6,149.00 479.42 70.86 5,959,759.68 549,957.22 Point 3 6,149.00 124.01 -25.49 5,959,403.67 549,863.24 1 E-27L1 T8 0.00 0.00 6,233.00 490.18 2,209.16 5,959,784.64 552,095.19 70°18'3.114 N 149°34'41.043 W -plan misses target center by 2.81ft at 9598.98ft MD(6233.27 TVD,487.49 N,2209.92 E) -Point 1E-271_1&L1-01 Polyg 0.00 0.00 0.00 451.43 68.68 5,959,731.68 549,955.23 70°18'2.736 N 149°35'43.447 W -plan misses target center by 6102.085 at 6275.00ft MD(6064.16 TVD,92.39 N,-507.90 E) -Polygon Point 1 0.00 153.30 -524.35 5,959,429.65 549,364.25 Point 2 0.00 56.93 -622.00 5,959,332.64 549,267.25 Point 3 0.00 285.13 -799.52 5,959,559.64 549,088.24 Point 4 0.00 455.39 -684.38 5,959,730.64 549,202.23 Point 5 0.00 623.26 -358.24 5,959,900.66 549,527.22 Point 6 0.00 644.33 87.95 5,959,924.69 549,973.22 Point 7 0.00 574.40 834.58 5,959,859.72 550,720.22 Point 8 0.00 632.72 1,849.09 5,959,924.77 551,734.22 Point 9 0.00 718.24 2,531.73 5,960,014.81 552,416.21 Point 10 0.00 375.78 2,594.48 5,959,672.81 552,481.23 Point 11 0.00 268.01 1,798.68 5,959,559.77 551,686.24 Point 12 0.00 200.20 1,010.14 5,959,486.73 550,898.24 Point 13 0.00 285.80 312.62 5,959,567.69 550,200.24 Point 14 0.00 354.02 -173.99 5,959,632.67 549,713.23 Point 15 0.00 153.30 -524.35 5,959,429.65 549,364.25 1E-27L1 T7 0.00 0.00 6,211.00 451.78 1,818.86 5,959,743.65 551,705.20 70°18'2.738 N 149°34'52.422 W -plan misses target center by 33.18ft at 9202.315 MD(6212.52 TVD,418.71 N,1821.10 E) -Point 7/14/2011 9 5125A Page 5 COMPASS 2003.16 Build 69 ORIGINAL ►-' ConocoPhillips or its affiliates Fah- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-27 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-27 @ 105.70ft(1 E-27) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-27 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-27L1 Design: 1 E-27L1_wp04 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,218.00 2,112.16 10 3/4" 10-3/4 13-1/2 9,600.00 6,233.31 2-3/8" 3 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 6,275.00 6,064.16 92.39 -507.90 TIP 6,285.00 6,073.21 94.36 -511.69 KOP 6,306.00 6,091.96 98.72 -520.06 3 6,443.31 6,159.10 150.56 -619.57 4 6,735.00 6,159.10 382.17 -606.82 End 45DLS 7,085.00 6,154.28 468.19 -268.49 Ribsteer 7,435.00 6,149.46 470.31 80.60 7 7,585.00 6,168.98 453.24 227.91 8 7,725.00 6,201.55 431.90 362.33 9 8,022.51 6,232.34 373.49 651.87 10 8,372.51 6,222.04 345.43 999.72 11 8,497.51 6,203.90 350.16 1,123.15 12 8,664.51 6,184.54 356.50 1,288.52 13 8,924.51 6,193.37 388.20 1,546.07 14 9,184.51 6,211.29 418.15 1,803.35 15 9,600.00 6,233.31 487.81 2,210.89 TD 7/14/2011 9:51 25AM Page 6 COMPASS 2003.16 Build 69 OR1GNAt . 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—1- '� 3g 0888�i88888,-,0,0,c.,,08 8 = 8 O W O �M�ppq�MM NNn^fQpN78 Sp N N M 3 O V, Om m�{c O Q i-f p O 'J O G V ,n in io r r Ci.N. lanai en UealAl O0 cop yy 1r 3 8 N.-NMC,i�co,c0 Qi O N c7<h fD 411/1/ 001) gidaQ IENuan arui URIGINAL • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1E Pad 1E-27 1E-27L1 1 E-27L1_wp04 Travelling Cylinder Report 14 July, 2011 BAKER HUGHES nRIGINAi ..-- ConocoPhillips or its affiliates r/` ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 E-27 Project: Kuparuk River Unit TVD Reference: 1 E-27 @ 105.70ft(1 E-27) Reference Site: Kuparuk 1 E Pad MD Reference: 1 E-27 @ 105.70ft(1 E-27) Site Error: 0.00ft North Reference: True Reference Well: 1 E-27 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1E-27L1 Database: EDM Alaska Prod v16 Reference Design: 1 E-27L1_wp04 Offset TVD Reference: Offset Datum Reference 1 E-27L1_wp04 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 6,275.00 to 9,600.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,156.10ft Error Surface: Elliptical Conic Survey Tool Program Date 7/12/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 6,275.00 1 E-27 GyroData(1 E-27) GYD-CT-CMS Gyrodata cont.casing m/s 6,275.00 9,600.00 1E-27L1_wp04(1E-27L1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (1 2,218.00 2,217.86 10 3/4" 10-3/4 13-1/2 9,600.00 6,339.01 2-3/8" 3 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 1E Pad 1 E-02-1 E-02-1 E-02 Out of range 1E-166-1E-166-1E-166 Out of range 1E-166-1E-166L1 -1E-166L1 Out of range 1 E-166-1 E-166L1 PB1 -1 E-166L1 PB1 Out of range 1 E-166-1 E-166L2-1 E-166L2 Out of range 1E-168-1E-168-1E-168 Out of range 1 E-168-1 E-168L1 -1 E-168L1 Out of range 1 E-168-1 E-168L2-1E-168L2 Out of range 1E-168-1E-168L2PB1 -1 E-168L2PB1 Out of range 1E-168-1E-168PB1 -1 E-168PB1 Out of range 1 E-21 -1 E-21 -1 E-21 Out of range 1E-25-1E-25-1E-25 7,085.00 6,200.00 990.26 143.26 855.80 Pass-Major Risk 1E-27-1 E-27-1 E-27 6,299.99 6,300.00 0.26 0.98 -0.68 FAIL-Major Risk 1E-27-1E-27L1-01 -1 E-27L1-01_wp06 7,100.00 7,100.00 0.00 0.34 -0.25 FAIL-Minor 1/10 1 E-28-1 E-28-1 E-28 Out of range 1 E-29-1 E-29-1 E-29 6,283.10 6,500.00 963.47 109.49 858.57 Pass-Major Risk 1 E-30-1 E-30-1E-30 Out of range 1 E-34-1 E-34-1 E-34 Out of range 1 E-35-1 E-35-1 E-35 Out of range 1 E-35-Plan 1 E-35A-1 E-35A(wp02) Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 7/14/2011 8.56:04AM Page 2 of 9 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates Vali ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1E-27 Project: Kuparuk River Unit TVD Reference: 1E-27 @ 105.70ft(1E-27) Reference Site: Kuparuk 1 E Pad MD Reference: 1 E-27 @ 105.70ft(1 E-27) Site Error: O.00ft North Reference: True Reference Well: 1 E-27 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1E-27L1 Database: EDM Alaska Prod v16 Reference Design: 1 E-27L1_wp04 Offset TVD Reference: Offset Datum Reference Depths are relative to 1 E-27 @ 105.70ft(1 E-27) Coordinates are relative to:1 E-27 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:0.38° Ladder Plot I 1 I I 1200 I I I I I I I I I I I I 1 I I I 1 I I I I I I I I I 900 ' c I I I I I I I I I I (4 I 1 I I I C I I I I I O 1 I I I I cry 1 I I I I Q) I I I I I I I 1 I m 600 U I I I I I I I I I I I I o I I I I 1 I I I I ly J J J _ J J J _ _ C I I I I I I a) I I I I I 1 U I I I I I 1 I I I I I 1 300 I I I I I I I I I I I I I I I I I I I I I I I I _ J J I I I I I I I I I I I I I I I I I I I I I)< OS6 .4" (5 I I I I ll 0 2000 4000 6000 8000 10000 12000 M easured Depth LEGEND -- 1E-25,1E-25,1E-25 V1 --)- 1E-27,1E-27L1-01,1E-27L1-01 wp06'O -�- 1 E-27,1E-27,1E-27 V2 --# 1E-20.1E-25,1E-20 V2 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 7/14/2011 8.56:04AM Page 9 of 9 COMPASS 2003 16 Build 69 QRIGINAL. OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLISlT WELL NAME PTD# 2--1 l n cM Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: kit Z�-' �,/G'--e--i POOL: 4-2/ 1 (21 Circle 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 e/( /�, "2 7 (If last two digits in Permit No. /. 216.3',API No. 50-G12 2(4-.3,37- J 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 perforate and produce I 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: 1/11/2008 m = 0.(0 D 0 D w D � � CO - ro 0 ' > 30 m0 - r 3• co co -s. 7 W .s. O rn N.m "-- p - O �° co o con 73 0 O j D) N o N 0) O O 'S 0 • E O 0 O) (D -' .-I O C) co co co W W CO CO W CO Cr) N N N N fV N N IV N N - -" CO CO V 0) 01 A Cr) N -, -, 3 CO CO - 0) 01 A W N -, 0 CD 00 �1 0) 01 A W N - O (D CO 0) 01 A W N -, O V M 0 C/3 co o b ;K y * '0 03 co 0 �. > -, D 0000 (/) 0 v > 0 v 13 O O (/) * * C r v z ,� C) 0 0 CD N. 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