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211-156
Originated: Delivered to:2ͲMayͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11DͲ117 50Ͳ029Ͳ22844Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 21ͲAprͲ24 0 121EͲ05A 50Ͳ029Ͳ20479Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 2ͲAprͲ24 0 131HͲ102 50Ͳ029Ͳ23580Ͳ00 909266407 Kuparuk River Multi Finger Caliper Field & Processed 22ͲAprͲ24 0 142BͲ03B 50Ͳ029Ͳ21151Ͳ02 909270379 Kuparuk River Perforation Record FieldͲFinal 11ͲAprͲ24 0 152CͲ12 50Ͳ029Ͳ21222Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 29ͲAprͲ24 0 162DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Leak Detect Log FieldͲFinal 11ͲAprͲ24 0 172DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Multi Finger Caliper Field & Processed 9ͲAprͲ24 0 183GͲ24 50Ͳ103Ͳ20145Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 8ͲAprͲ24 0 193JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Leak Detect Log FieldͲFinal 7ͲAprͲ24 0 110 3JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Multi Finger Caliper Field & Processed 6ͲAprͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T38757T38758T38759T38760T38761T38762T38762T38763T38764T3876421EͲ05A50Ͳ029Ͳ20479Ͳ01 n/aKuparukRiverPlugSettingRecordFieldͲFinal2ͲAprͲ2401 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 b direct inspection of the file. 1 I - 1s (0 Well History File Identifier Organizing(done) wo-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Coor Items: vGri ❑ M s: ayscale Items: Logs: f R lY AT t bN LOG' ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: CM.ai .... __ Date: OP /s/ u • Project Proofing BY: Maria Date: #' /s/ MP Scanning Preparation 3 x 30 = 9'0 + .:: ,14. = TOTAL PAGES Ii 4— (Count does not include cover sheet) BY: 1�- .. Date: Wiffig. /s/ Production Scanning 0 Stage 1 Page Count from Scanned File: 115 (Count does include cove heet) Page Count Matches Number in Scanning Preparation: YES NO BY: MD Date: r , /s/ 114f) Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: NO TOTAL PAGES:3(3 Digital version appended by: Meredith ~jh Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: /5-5 9 g Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o cc 9 - rn a) rn o + Z o 2 p mC a) 0 us c o U < 8 « O O 0) O U Oq as J + Z t Tr Z rs 0 u)a aa) o` aa) J � 0) 0 a o o m c c 0) a U m a) 0N c g o r o 0 0 E U 0 o i. al m y a Uw N ® o oat o.c m m ,v_ 0 t ty 0) m m e o. Op a @ a c :? E a)C�cn aai'� E E cn p 5 m = in 0) E °° y a p ca >. m E a 0 o a J f4 C7 ._ 0 a)r a) ••-• t O 0 2 a) C o 2 o �c) o o u p 0 J p U p 0 0 Y a U a as p O Z Z U Opa Oa 0 0 p > p p m .- p a) pp > u) 0) a w2 m w m 2 1- 2 2 H 2 2 I- a0 2 00 2< H = o' o -o a 0 0 > N N N N N N N N N N N N N N (N N N a °� o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J N )/) e N N N N N N N N N N N N N N N N N CT? o cc a) a) a) a) O) 0) 0) 0) a) 0) 0) CO T Q) N N N U T p J jM CO CO CO CO CO CO CO CO CO CO N CO CO CO Z E o C C C C C C C C C C C a) a) O C C C "' _ = a) a) a) a) a) a) a) N a) a) a) N w Na) a) a) m e a a a a a a 0. a a a a ca CO CO a a s a N Y OU O 0 O O O O O O O O O U U U 0 O O C/ a c CO (5 a M M M M M M M M M M M 00 v v M M O CO o n n n n n n n n n n n o N- n n in n a 7 w N N N N N N N N N N N N V N a J 0 A Cl) n n N- n n n n n n n n co n N. n to n J_ Ill- a c t v v v v v a v o o v CO v Ce 0 « 0 0 0 0 0 0 0 0 0 0 0 in v v E. coo0 O co )n U) in u) u) an In in u) CO CO u) v u) W z J V V O z 8 T Q ° c' z° R t, N 7 J a m ca o^ a)16O O O O O O O O O O O O CL el c ZI J 2 U U U U U U U U U 0 0 0 o • 7:7; a) u) o O T J f0 N N N N N N N N N )I) 1.0 N 1.0N o Vco J a j' Q o ▪ w T 5� H N CO Z N CC• N O a) < coa Q a Yg HOII cn Q c a z w w w Q z o w a� fl) > '> m U 0 v)• in in EJ iii m c c a) 0 N N Z 0 c c c o o c[ x it it o m m 0 0 0 0 0 o) 0 o) rn c c c TT) £ o 0 0 0 0 0 0 0 0 c c o 0 0 C O O J J J J J J J J J a a) a) U U U Lc) o o a a -a -o -o v v v -o a E E E > > > v Z a) a) > > > > > > > > > o a) a) -0 0 v co yr U U c c c 0 p Z O a) a) Q) 7 0 NCD J O) `- 2 Z w 0 w G z N O O4 O Q RO o E 4-0 U) , 1 \ y wV.Z < r- LI. y a M W rw d p171 J co co J 5 o \O Nn U Z w \ \ \ N'O�\ U U \ \ Uc E p a aJ � 0) 0) py a WQ « a p a o00000p CO0 0 o O 0 d HJC) Wp 1- a' J J J J J J J J J W J W J J W O 9 s- 9 O at I- ek n O Z I N en U_ a N 0 1 Z Er_ 0 U .4 QZ c Y N E y m I— N U E o LL a c U o m ' a 5 " „ a z z CL J aco 0 w 2 N Z D a O v U W z d � J ✓ 0 q Z C cc a Q o ? 1- 6.o 7 N 0 J d o z 0 ^ in c >, E 11 r, c d .Es o g co 0Ll- N 2 0 N a in E ✓ 0 J < Q U 9 W G. I— r N N I Z o m /y� > N 1 W > N C N • a) II Q a co Q a 0 Y )QOI— tr.,— (X6 a Q Z o d U ISI E is Z i a> E I 0 � R co 0 o c E.-0� jZ CO N aa) 0 a) E E z v a Y N d Z a) U c c v 0 = a m u E E GI • 2 3 0 U <c 0 U RECEIVED AUG 072013 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 4, 2013 Commissioner Dan Seamount 1 S Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 r - ---- Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped May 5 &August 1, 2013. The corrosion inhibitor/sealant was pumped August 2, 2013. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 8/4/2013 1C,1D, 1E PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1C-127 50029230240000 2011140 18'3" 2.5 41" 5/26/2013 12.75 8/2/2013 1D-102 50029229600000 2000750 SF NA 10" NA 2.125 8/2/2013 1D-103 50029230860000 2020960 20' 3.0 65" 8/1/2013 3.825 8/2/2013 1D-107 50029229830000 2001770 6'6" NA 66" NA 10.99 8/2/2013 1D-115 50029228400000 1972320 SF NA 8" NA 3.55 8/2/2013 1D-129 50029228900000 1972130 77" 1.20 16" 8/1/2013 4.825 8/2/2013 1E-01 50029204640000 1800390 10" NA 10" NA 5.1 8/2/2013 r>1E-05A 50029204790100 2111560 45" 0.69 3" 8/1/2013 3.825 8/2/2013 1E-29 50029208280000 1821540 7" NA 7" NA 3.775 8/2/2013 STATE OF ALASKA ALM,,1G4 OIL AND GAS CONSERVATION COM1,,SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r • Other pr SC repair Alter Casing r Pull 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: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Development r Exploratory r 211-156 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20479-01 - 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0025651 1E-05A • 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool • 11. Present Well Condition Summary: Total Depth measured 7273 • feet Plugs(measured) None true vertical 6451 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6745 true vertical 0 feet (true vertical) 6012 Casing Length Size MD TVD Burst Collapse CONDUCTOR 63 20 95 95 0 0 PRODUCTION 171 9.625 202 2210 5380 2670 SURFACE 2385 16 2417 5968 4750 6870 ' Prod liner 6492 9.625 6694 5968 Perforation depth: Measured depth: NA SCANNED JUL 3 2013 a a <; True Vertical Depth: NA If b •''' Tubing(size,grade,MD,and TVD) 3.5, L-80, 6787 MD,6048 TVD F-. + x Packers&SSSV(type,MD,and TVD) PACKER-BAKER 45-FA-36 PRODUCTION PACKER @ 6745 MD and 6012 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r • Service r Stratigraphic r X 16.Well Status after work: Oil r . Gas r WDSPL r Daily Report of Well Operations GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-200 Contact Martin Walters/MJ Loveland Email n1878(c�conocophillips.com Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature Phone:659 3 Date 6/3/13 ItRBDMS JUN - 7 No Go'/ P//3 Form 10-404 Revised 10/2012 Submit Origina Onl . ConocoPhillips { Alaska A ooce P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 3, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1 E-05, PTD 211-156, Sundry 313-200 surface casing repair. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, 1:2Y 777c MJ Lo/717 land ConocoPhillips Well Integrity Projects Supervisor mer . 0 -° -° m _'2 IS o 0 (i) co C , = C C Q CO i._.. Qco ) M O) O 4‘, p4 •— � �S , e r., . , i _, OO ^ W' n— • \te. _ $ s ' C O e" O O, 0 � C C S C _'. ', ,.1 ,,,,,,,. f:,,,-_,,,,,,,f,;,!,;,0,;,„,,,.„ '''''',,,,,,,,..,-,,,,,;%7:4,,,, h • ., IOW i I t r Olio , • 1E-05A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/11/13 Cut Two 15"X 25"windows on conductor and remove cement to expose the 13 3/8"surface casing collar. 04/15/13 Surface casing leak detect found surface casing collar leaking. 04/28/13 Remove 42"of 20"conductor. 05/17/13 Welders set up and welded top and bottom of surface casing collar. 06/01/13 Weld 41 1/4"of 20"X65 .437 wall pipe back to replace conductor. 06/02/13 MITOA Passed: Initial T/I/O = Si0/0/0, pressure up OA to 1800 psi T/I/O = Si0/0/1800, 15 min T/I/O = Si0/0/1765, 30 min T/I/O = Si0/0/1760, 45 min T/I/O = Si0/0/1760, 60 min TWO = Si0/0/1760, bled OA to 0 psi, final TWO = Si0/0/0 WELL LOG TRANSMITTAL AOGCC PROACTIVE DIAgNoslIC SERVICES, INC. 2A\-45(C) To: AOGCC Z L \ Christine Shartzer 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 (907)793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907)245-8952 1) Leak PointTm Survey 09-May-13 1E-05A 1 CD 50-029-20479-01 2) Signed : Date : Print Name: \A---1.1 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Archives\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx te753 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 8, 2013 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAY 10 2013 AOGCC RE: Multi Finger Caliper(MFC): 1E-05 Run Date: 5/5/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating,6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1E-05k Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20479-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cock@halliburton.com Date: 5�tfo��`,� Signed: aA, ,„.9-\\ I//7,',v THE STATE T' Oil Alaska Oil and Gas °ALASKA Conservation C, tnarnission Le pp GOVERNOR SEAN PARNELL �*e 333 West Seventh Avenue ALAS* Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. f � P.O. Box 100360 l Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-05A Sundry Number: 313-200 Dear Mr. Walters: 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, 10/1/— Daniel T. Seamount, Jr. Commissioner I‘ DATED this c. day of May, 2013. Encl. STATE OF ALASKA RECEIVED AL ,(A OIL AND GAS CONSERVATION COML.-310N APR 2 5 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approve Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r StimulateAlter casing r r Other: SC repair rJ . 2.Operator Name: ✓ 4.Current Well Class: 5.Permit to Drill Number: ,/ ConocoPhillips Alaska, Inc. Development J . Exploratory r 211-156 • ✓ 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-20479-01 7.If perforating, 8.Well Name and Number: / What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No rJ 1 E-05A` 9.Property Designation(Lease Number): 10.Field/Pool(s): ✓ ADL0025651• 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 TVD(ft): Plugs(measured): Junk(measured): 7273• 6451 Casing Length Size MD TVD Burst Collapse CONDUCTOR 63 20 95' .95' SURFACE 2385 13.375 2417' 2210' 5380 2670 - PRODUCTION 6492 9.625 6694' 5968' 4750 6870 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): NA NA 3.5 L-80 6787 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 45-FA-36 4 MD=6745 TVD=6012 SSSV-Camco TRMAXX-CMT-5-CR • MD=1784 TVD=1693 12.Attachments: Description Summary of Proposal p• 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p', Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: ✓ 5/15/2013 Oil ( " Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r 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: Martin Walters/MJ Loveland Email: nI878(c�conocophillips.com Printed Name Martin Walter Title: Well Integrity Project Supervisor Signature / 17gf LA/2 ,, Phone:659-7043 Date:04/21/13 Commission Use Only n Sundry Number:315— Conditions of approval: Notify Commission so that a representative may witness •/ A( Plug Integritynr BOP Test r Mechanical Integrity Test r LocationJClearance r RBDMS MAY - 2 ;013 Other: t' b 74/ fc7 4"0 G? c C t-/o l vi cp p'G✓ G./Gt wr a C/c . /' rov/ `,1t ph0ILO �G(7cvvt,7cr, f-ar �7�.,J of rcpa r . Spacing Exception Required? Yes ❑ No i Subsequent Form Required: /G - 4-0 4- APPROVED BY Approved by: .i COMMISSIONER THE COMMISSION Date:5/2,(L.,....5 Approved at Mi iGarNrArEnths from the date of approval. Form 10-403(Revised 10/2012) 51) / /3 Submit Form and Attachments in Duplicate 9k0 17t-F SIF Fvr CPT'5[213 ,. ✓ RECEIVED ConocoPhillips APR 2 5 2013 Alaska P.O. BOX 100360 AOGC�•s�.d ANCHORAGE,ALASKA 99510-0360 April 21, 2013 Commissioner Dan Seamount Alaska.Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1E-05A, PTD 211-156 surface casing inspection and repair. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, Xittet174e& Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska, Inc. Kuparuk Well 1E-05A (PTD 211-156) SUNDRY NOTICE 10-403 APPROVAL REQUEST April 21, 2013 This application for sundry approval for Kuparuk well 1E-05A is for the inspection and repair of a near surface surface casing leak. The 1E-05 well was drilled and completed as a development well in 1980. In 2012, a coiled tubing sidetrack was performed which resulted in multilateral well 1E-05A. On 04/15/13 a surface casing leak was determined to be in the top connection of the uppermost collar as visually witnessed through conductor windows. ConocoPhillips would like to permanently repair the well by backwelding the collar or with a welded patch. With approval, repair of the surface casing will require the following general steps (some of which has already been completed): 1. Secure the well as necessary. 2. Remove the floor grate,well house, flow lines,and other equipment from around the wellhead. 3. Remove any previous sealant treatment from the conductor. 4. Install nitrogen purge equipment for the conductor(and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. 6. Excavate wellhead location as needed to remove cellar and repair leak. 7. Remove conductor to find damage to surface casing.Notify AOGCC Inspector for opportunity to inspect. 8. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 9. If a patch is required, QA/QC will verify the repair for a final integrity check. 10. Perform pressure test of the patched area. 11. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 12. Replace the conductor,fill the void with cement,and top off with sealant. 13. Backfill as needed with gravel around the wellhead. 14. Remove plugs and return the well to service. 15. File 10-404 with the AOGCC post repair. Well Integrity Project Supervisor 4/22/2013 •a -.a r �,, a KUP 1E-05A ConocoPhillips 1utes 1. __. Wellbore API/UWI Feld Name Well Status Incl() ',MD(568) Act Btm(RKB) A(B,,k•- 500292047901 1KUPARUK RIVER UNIT PROD j 39.84 j 3,970.60 7,273.0 mni Carcpa 5 `".' Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date �1Ysll Conan MULTIPLE LATERALS-tE-05A,11520731:0616 PM SSSV:TRDP 210 8/14/2012 Last WO: 2/19/2012 39.49 8/25/1980 Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,152.0 3/21/2012 Rev Reason:GLV C/O,SET PLUG,ADD ZONES osborl 3/15/2013 HANGER,26 - S - $fllR .;;- Casing Description String 0... String ID...Top(R103) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 20 19.124 32.0 95.0 95.0 94.00 H-40 WELDED Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 133/8 12.415 31.8 2,416.7 2,210.2 72.00 N-80 BUTT Casing Description String 0.., String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd r' 1.1PRODUCTION 95/8 8.525 201.7 6,694.0 5,968.2 47.00 L-80 BTC CONDUCTOR. Pont S/T 32-95- Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION PRODUCTION 9 5/8 8.681 31.2 201.7 201.7 47.00 1-80 HYD 563 TIE-BACK, ---- - TIE-BACK 31-202 Casing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(TOD)...String Wt...String...String Top Thrd SAFETY VLV, WINDOW'A' 8 7.000 5,014.0 5,031.0 4,374.6 1,784 ` ` Casing Description String 0... String ID...Top(MB) Set Depth(I...Set Depth(ND)...String Wt...String...String Top Thrd I WINDOW AL3 6 5.000 6,967.0 6,972.0 6,200.8 15.50 BTCM Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd WINDOW AL2-02 6 5.000 6,994.0 6,999.0 6,223.1 15.50 BTCM Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE WINDOW AL1 6 5.000 7,016.0 7,021.0 6,241.4 15.50 BTCM 32-2,417Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd LINER A 5 1/2 4.950 4,801.7 7,267.0 6,446.4 15.50 L-80 BTCM GAS LIFT, - 2.760 1=- ._� ';:: .. .. .. .. Eli Top Depth (ND) Top Incl Nomi... Top(RKB) (568) 11 Item Description Comment ID(in) . GAS LIFT, 4,801.7 4,158.9 21.46 PACKER ZXP LINER PACKER 6.280 4,389 tea` NIB Tubing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd IIP TUBING WO 312 2.992 26.4 6,788.0 6,048.0 9.30 L-80 EUE8RDMOD ..i _ Top Depth (ND) Top Incl Nomi... WHIPSTOCK I - Top(RKB) (RKB) (°) Item Description Comment ID(in) 5-874\ 26.4 26.4 -0.32 HANGER FMC GEN V TUBING HANGER 2.992 WINDOW'A., 5.014-5,031 _ 1,783.6 1,692.7 32.62 SAFETY VLV CAMCO TRMAXX-CMT-5-CR SAFETY VALVE W/2.812"X PROFILE 2.812 6,718.3 5,989.0 32.08 LOCATOR LOCATOR SUN a 6'OF STICK UP 3.000 GAS LIFT _ 5,399 sr6,724.7 5,994.4 32.17 PBR BAKER TRIMMED POLISHED BORE RECEPTACLE 4.000 Mk6,745.1 6,011.8 32.43 SEAL ASSY BAKER 80-40 ANCHOR SEAL ASSEMBLY 2.980 GAS LIFT, ( IR. 6,745.5 6,012.1 32.44 PACKER BAKER 45-FA-36 PRODUCTION PACKER 3.000 6.089 6,775.7 6,037.6 32.83 NIPPLE HES X PROFILE NIPPLE SET AT 30 DEG INCLINATION 2.813 1.1 6,787.4 6,047.5 32.98'WLEG BAKER WIRELINE ENTRY GUIDE 2.990 • GAS LIFT, IIII ,.:1•:byline. 6,632 + Top Depth (TOD) Top Ind PRODUCTION . Top(MB) MKS) Description Comment Run Date IO(in) Post 5,014.0 4,358.5 WHIPSTOCK ANCHOR TRAY'A' 2/9/2012 202-6,694 LOCATOR, �. 6,770.0 6,032.8 32.75 PLUG WRP WITH MID ELEMENT @ 6772,CCL TO MID 3/1/2013 0.000 6,718 I Mr, ELEMENT 10.9,CL @6761.1 PBR,6,725 IMO 6,967.0 6,196.6 34.19 WHIPSTOCK AL3 Baker 3-1/7 X 5-12"Through tubing WHIPSTOCK 5/7/2012 SEAL ASSY, 6,745 PACKER,6,745 6,990.0 6,215.7 34.10 WHIPSTOCK AL2-02 Baker 3-12"X 5-1/7 TT WHIPSTOCK 4/27/2012 _ - P. 7,012.0 6,233.9 34.02 WHIPSTOCK AL1 Baker 3-1/2"X 5-1/2"Through tubing WHIPSTOCK 14/23/2012 PLUG.6,770 - _-'----_-- . II .d Date % NIPPLE,6,776 se End Date - - - -- - --- _ -Annot t n 2/19/2012 NOTE:WELL SIDETRACKED TO'A' I 5/20/2012 NOTE:MULTI-LATERAL WELL:AL1,AL2,AL2-01,AL2-02,AL3(AL1-01 8 AL1-02 not drilled) ■: WLEG,6,787 j WINDOW AL3. 6IPSTOC72 WHIPSTO9K,N _ 6,967 - WHIPSTOCK. ; 6 _ WINDOW AL2-02, 6.994-6.999 WHIPSTOCK, 7,012 WINDOW All. • 7,016-7,021 PSI WHIPSTOCK, b. 7.031 • LINER A Top Depth Top Port ._ 4.802-7.267 S... (TVD) Incl OD Valve Latch Size TRO Run TDDEM` Si N...Top(1TKB) MS)) P) Make Model (in) Sent Type Type (in) (Psi) Run Date Com... 7,273 1 2,760.0 2,488.8 36.77 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/15/2013 SLOTS, ' 6.991'7.961 2 4,387.8 3,786.3 30.07 CAMCO MMG 1 12 GAS LIFT OMY RK 0.000 0.0 2/152013 SLOTS, 6.797-8,370 3 5,398.8 4,726.4 10.32 CAMCO KBG 2-9 1 GAS LIFT DMY BTM 0.000 0.0 2/15/2013 SLOTS, 7.2418216 4 6,089.3 5,405.5 13.17 CAMCO KBG 2-9 1 GAS LIFT OMY BTM 0.000 0.0 2/15/2013 ' LINER AL2-02, _ 6,991-7.961 5 6,631.5 5,913.6 28.65 CAMCO KBG 2-9 1 GAS LIFT'DMY INT 0.000 0.0 2/16/2013 LINER AL2-01, 7.2328,216 I! 8,3715. SLOTS. 677 LINER AL3, 6,780-9,677 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE:Wednesday,August 01,2012 Jim Regg ' P.I.Supervisor Se j 7 1 v SUBJECT:Mechanical Integrity Tests I l BP EXPLORATION(ALASKA)INC 04-350 FROM: Jeff Jones PRUDHOE BAY UN LIS 04-350 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ...1.8/2-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS 04-350 API Well Number 50-029-23453-00-00 Inspector Name: Jeff Jones Permit Number: 211-106-0 Inspection Date: 7/10/2012 Insp Num: mitJJ120730180105 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-350 ., Type Inj W TVD 8832 ' IA 0 2436 • 2366 2351 ' PTD 2111060 - Type Test SPT Test psi i 2208 , OA 97 268 -I 228 212 Interval INITAL P/FP J I Tubing� 213 ' 221 213 217 - Notes: 4.4 BBLS methanol pumped. 1 well inspected,no exceptions noted. . Wednesday,August 01,2012 Page 1 of 1 zit-16 Lib.3 WELL LOG TRANSMITTAL To: State of Alaska March 27, 2012 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 1E-05A AK-MW-0008472247 1E-05A 50-029-20479-01 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5"TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images&LWDG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant@halliburton.com Benjamin.Schulze@halliburton.com / I / /i Date: `.D�l�j 12.. Signed: ! 532. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 26, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Cement Bond Log: 1E-05A Run Date: 3/25/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 1E-05A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20479-01 Cement Bond Log 1 Color Log 50-029-20479-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 5(\LC(12, Signed: 'L* Iv ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: 1 E-05A AOGCC permit: 211-156-0 DATE: 03/07/2012 Transmitted: Kuparuk River Unit, North Slope, Alaska 1 E-05A CD and hardcopy report t• Final Well report, Mud logging report, CANRIG;well 1 E-05A(500292047901); February 28, 2012 2) 2 G 9 Equipment,well data, geological data, pressure/formation strength, drilling data, daily reports,formation logs color prints; Formation log (MD)L_ Formation log(TVD)-'- , Gas ratio (MD)— 5) Gas ratio (TVD)i C'' , ' rd) f.. 45.\off LWD Combo (MD) > � LWD Combo (TVD); Nct Zi'y s�o f o• Drilling dynamics (MD) L F, ,t,< Drilling dynamics (TVD) L2DROM contains; daily reports, DML data, final well report, LASS Wes' , mud log PDF files, remarks and tiff files Sign, scan and return electronically to Sandra.D.Lemke0Conocophil/ips com CC: 1 E-05A tr nsmittal folder, production well files, eSearch (A Receipt: /IL j 2 Date: 6) ReaL.- ;,()` .Z 11131511MIlltw, GIS-Technical Data Management I ConocoPhillips 1 Anchorage, Alaska Ph; 907265.6947 oZ H -- 16--b H1'- WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 22, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1E-05A Run Date: 2/18/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-05A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20479-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 1'1 Signed: ✓; &� <.• � STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR Rndoned ❑RECOMPLETIONn � Well REPORT AND LOG la.Well Status: Oil Gas O❑MPSPLUG L ❑ Other ❑ 20AAC 25.105 20AAC 25.110 Development Q 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.: February 21,2012 211-156/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 February 12,2012 50-029-20479-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: fL... CTt.> Surface: 653'FSL,633'FEL,Sec. 16,T11 N,R10E,UM February 15,2012 1E-05A ce Top of Productive Horizon: 8.KB(ft above MSL): 101'RKB 15.Field/Pool(s): 2146'FSL, 1754'FWL,Sec. 15,T11 N, R10E, UM GL(ft above MSL): 69.5'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2244'FSL, 1802'FWL,Sec. 15,T11 N, R10E, UM 7224'MD/6410'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-549890 y- 5960237 Zone-4 7273'MD/6451'TVD ADL 25651 TPI: x-552263 y- 5961749 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-552310 y- 5961847 Zone-4 1784'MD/1693'TVD 469 18.Directional Survey: Yes 0 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1622'MD/ 1554'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 5063'MD/ 4405'TVD 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 20" 94# I-1-40 32' 95' 32' 95' 32" 300 sx Permafrost 13.375" 72# N-80 32' 2416' 32' 2213' 17.5" 2300 sx Fondu,275 sx Permafrost 9.625" 47# L-80 202' 6694' 202' 5968' 12.25" 620 sx Class G 5.5" 15.5# L-80 4802' 7267' 4159' 6446' 8.5" 672 sx Class G Y/ 24.Open to production or injection? Yes ❑ No 0 If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/ND) .5" 6788' 4802'MD/4159'ND and 6764'MD/6028'ND --( none \y�' ge1 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. •� -- `� 't2 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1n . _ �: \ kA cement\etainer©5037' 121 sx Class G ; \ kA s Cons.COONS S �On .T_- ', .NIaska C'ti& �n�crage 27. , QCT ON TEST Date First Production \ Methgd. elation(Flowing,gas lift,etc.) shut-in 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(torr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 2 Sidewall Cores Acquired? Yes ❑ No 2 If Yes to either question,list formations and intervals cored(MD+ND 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 RBDMS MAR 2 2 Zg92df1 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 2,6 1f-2`7- 12-- 28. GEOLOGIC MARKERS(List all formations and mi. encountered): 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 1622' 1554' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A 7075' 6286' Bottom Kuparuk A 7207' 6396' N/A Formation at total depth: Kuparuk A 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: Haibin Guo©265-1487 CI Printed Name G. Ivord,6-64 Title: Alaska Drilling Manager Signature yig Phone 263-4021 Date h_ /— 2-D12-- Sharon w12Sharon 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 1E-05A SIDETRA Up-_.;d on 02/21/2012 9-5/8"casing tie-back @ 182' _ - w/Hydri1563 02/05/12 -- _ 20"Condutor Arctic Pack Job done in @ 95' 8/13/1980 3 ,'/z" 49 bbls cement ..m--=...=',71: -•• TRMAXX 116 bbls diesel - CMT SCSSV No record of press.test 2.813"IDS :.:.: 1,785'MD/ 1,694'TVIy:::::: 13-3/8"72#N80 casing @ ,iih' 2,416'MD/2,210'TVD Eli 3-1/2"9.3#,L-80,EUE Tubing @4,714' MI MD and above Baker ZXP lir e IIIX/O EUE B X Hydri1563 P packer @ - KOP in 9-5/8"@ 4,802'MD/4,1.x.:::.:.:.:: 5,012'MD/4,362'TVD TVD' GLM# TVD ft MD ft Valve Type Mandrel Type 1 2,488 2,762 Dummy 3-1/2"x 1-1/2" MMG 2 3,789 4,389 Dummy 3-1/2"x 1-1/2" MMG 3 4,733 5,400 Open 3-1/2"x 1"KBG-2-9 'lM 'jo 4 4 5,411 6,091 Dummy 3-1/2"x 1"KBG-2-9 5 5,901 6,633 SOV 3-1/2"x 1" KBG-2-9 2'..!:, *SOV(annulus to tubing shear) s.. Cement retainer .o- +/-5,100'MD 3-'/2"9.2#,L-80,Hydril 563 Special Squeeze pert'.= Clearance Tubing 3.886"4,725'-6,649' below retainer MD :-:-:-:-:-::::'•::::::::::::::::::::::::::::: ' ubing Cut @ ✓ �: •:•:;:::•::•::::: 5,246'MD ::.. Backer Production Packer ;.> @+1-6,747 MD/5,998' 7 liner Seal >; / A::: TVD Assembly 6,399'MD :!:: , 3 ''/z" HES"X"selective 9-5/8"47#BTC nipple w/2.813"ID @ :;i> < @ 6,694'MD 6,776'MD/6,025'TVD Packer @ mat M il 6,587' :,,. Perfs Cr.) > _ 6,766'-6,902' 3 " WLEG @ 6,788' Packer @ _ . 'MD/6,035'TVD. 6,923' I�� �T5-1/2" 15.5#BTCM Perfs @ 7,267 MD/6,452'TVD -:: ` :::< :::::..- 6,976'-6,994' Perfs @ 7,0001-7,014' 7"26#K-55 7,195'MD/6,514'TVD HB 11/28/11 • • `. KU P 1E-05A - ConocoPhillips 4;.,. Well Attributes Max Angle&MD TD • Alaska,• Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btrn(ftKB) �n„a,�y�5 500292047901 KUPARUK RIVER UNIT PROD 39.84 3,970.60 7273.0 Comment HIS(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date °° Well coma:-1E-OSA,Snrzo12 9:49:25 AM SSSV:TRDP Last WO: 2/19/2012 39.49 8/25/1980 Scnemauc-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 3/7/2012 MANGER,20 • • Casing Strings Casing CONDUCTOR an String 0... String 19.124 Top 320 Set Depth(f...'Set Depth(TVD)...String WI...String...String Top Thrd ME _ 95.0 94.00 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 133/8 12.415 31.8 2,416.7 2,210.2 72.00 N-80 BUTT 1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd PRODUCTION 95/8 8.525 201.7 6,694.0 5,968.2 47.00 L-80 BTC Post S/T • Casing Description String 0... String ID...Top(ftKB) Set Depth(I...-Set Depth(ND)...String Wt...String...String Top Thrd • PRODUCTION 95/8 8.681 31.2 201.7 201.7 47.00 L-80 HYD 563 TIE-BACK Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WI...String... String Top Thrd CONDUCTOR._y WINDOW'A' 8 7.000 5,014.0 5,031.0 4,374.6 62-95 Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...'String...String Top Thrd LINER 51/2 4.950 4,801.7 7,267.0 6,446.4 15.50 L-80 BTCM PRODUCTION Liner Details TIE-BACK. Top Depth 01-202 (ND) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) SAFETY VLV, o I 4,801.7 4,158.9 21.46 PACKER ZXP LINER PACKER -6.280 1,784 , Tubing Strings 1 I Tubing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(ND)...String Wt...String...String Top Thrd {`-J` TUBING 31/2 2.992 26.4 6,788.0 6,048.0 9.30 L-80 EUE8RDMOD Completion Details Iii Top Depth (ND) Top Incl Nomi... Top(ftKB) (RKB) (°) Item Description Comment ID(in) 26.4 26.4 -0.32 HANGER FMC GEN V TUBING HANGER 2.992 s 22-24 E___ 1,783.6 1,692.7 32.62 SAFETY VLV CAMCO TRMAXX-CMT-5-CR SAFETY VALVE w/2.812"X PROFILE 2.812 low 6,718.3 5,989.0 32.08 LOCATOR LOCATOR SUN+5 OF STICK UP 3.000 1.1 6,724.7 5,994.4 32.17 PBR BAKER TRIMMED POLISHED BORE RECEPTICLE 4.000 GAS LFT. 2 76c 6,745.1 6,011.8 32.43 SEAL ASSY BAKER 80-40 ANCHOR SEAL ASSEMBLY -2.980 ■ 6,745.5 6,012.1 32.44 PACKER BAKER 45-FA-36 PRODUCTION PACKER -3.000 ■ 6,775.7 6,037.6 32.83 NIPPLE HES X PROFLE NIPPLE SET AT 30 DEG INCLINATION 2.990 El 6,787.4 6,047.5 32.98 WLEG BAKER WIRELINE ENTRY GUIDE -2.990 GAS LFT. Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) 4 318 Top Depth . (ND) Top Incl 11.11 Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 5,014.0 4,358.5 18.21 WHIPSTOCK ANCHOR TRAY Comment Mr Notes:General&Safety End Date Annotation 2/19/2012 NOTE:WELL SIDETRACKED TO'A' WHIPSTOCK 0.014 WINDOW'A', II 5,014-5.071 Mt GAS LIFT, 5,899 Ill V I 6.08/ I ■ a a GAS LIFT. I -I 6.632 B PRODUCTION 2 6 202-6694 II LOCATOR. - 6.718 4 PBR,6,725 SEAL ASSY, 6.745 PACKER,0,745 Mandrel Details III f Top Depth Top Port (TVD) Incl OD Valve Latch Size IRO Run NIPPLE,0,710 'l Stn Top(RKB) (RKB) (°) Make Model lin) here Type Type (me) (psi) Run Date Cont.. 1 2,760.0 2,488.8 36.77 CAMCO MMG 1 GAS LIFT DMY RK 0.000 0.0 2/19/2012 IIIII 2 4,387.8 3,786.3 30.07 CAMCO MMG 1 GAS LIFT DMY RK 0.000 0.0 2/19/2012 WLEG,6,787 3 5,398.8 4,726.4 10.32 CAMCO KBG 2-9 1 GAS LIFT DMY INT 0.000 0.0 2/19/2012 4 6,089.3 5,405.5 13.17 CAMCO KBG 2-9 1 GAS LIFT DMY INT '0.000 0.0 2/19/2012 5 6,631.5 5,913.6 28.65 CAMCO KBG 2-9 1 GAS LIFT SOV INT 0.000 0.0 2/19/2012 LINER, 4,802-7,267 TD(1E-054), a a 7,273 .9 I !,1 a 2 ❑ a m /'� co b L 1 n �J k, 1N❑ to N SCJ N N N r`ao�'o w CON M C u ❑ N E N J N c4m - QEm GCmmm CO wO H .O-m _ b O d��YYY J � O w Nnwg 0F❑En 0 Y H A x x x x x wa❑ 2 1n in in in in H Y ririririri in �- co I e- 0 ~ II w - - `° CO1 ma�r� co co Q co � Nc) I)L ) w I CD E0 II a .r. ` 7 = (V WO ( -YE OnMON -4-c, O � II ? to Q' sN V In CO CO V Q .0 Nm \ F m N d a \ (D eD O i',1M C N co X O O o n �, N M V Ln 7 °�(n CO iV ui a I 0 11- x�=N @ £, 1 ��, a a � I V Nc�a/chw a0 c%�« app• >J> o �� dc7- N- > O V n3\ / O ^II - °n m issaa.....00a7 \ \ N O N N w 5 ❑ 2 o° O E n \ e bc0n a a 2 fa n N - co co o .—, Y m o " o `f 3 a g `W U of t�t c3D O c w 4 Cn N N C Y N J E N �'3 U --9 Horn u) q a g J w0❑ g LLIF- F- J � U to W0 o W awP 4 Em L 0 w ,O ❑ Ti 9-o lV O O O` ag.. o 0. q a m CL w 0 0 <c, R_ -- wib b w w00 1E-05 Well Work Summary DATE SUMMARY 9/19/11 GAUGED TBG TO 2.77"TO h CH @ 6901' RKB. SET CATCHER @ SLM. PULLED C SAND DV @ 6626' RKB. IN PROGRESS. 9/20/11 PULL DV @ 6693' RKB, SET HFCV @ 6626', 6693' RKB, PULL CATCHER @ 6899' SLM. C-SANDS OPEN. JOB COMPLETE. 11/18/11 PULLED UPPER STRADDLE PATCH ASSEMBLY FROM 6898' CTMD. PUMPED OFF FISH @ 6896' CTMD FP WELL TO 2500'TVD. JOB IN PROGRESS. 11/22/11 LATCH 39' BAKER 35 KB PKR PATCH ASSY' @ 6883' SLM, PULLED UP HOLE HANGING UP @ 6546', 6184' SLM, 5711' SLM, LEFT @ 5711' SLM, IN PROGRESS. 11/23/11 PULLED 39' BAKER 35 WL KB STINGER ASSY PACKER @ 5703' SLM, DSM REMOVED AL LINE OFF 7", UNABLE TO SET2.81"X-PLUG @ 6561' RKB„ IN PROGRESS. 11/24/11 ATTEMPT TO RUN BRAND NEW 2.813"XX PLUG @ 6561' RKB, FELL PAST NIPPLE, ( SUSPECT BAD PROFILE), SET 3 1/2 AVA CATCHER SUB @ 6833' SLM, PULLED 1" OV @ 6201' RKB. IN PROGRESS. 11/25/11 PULLED 1"GLV'S @ 5730' RKB, 4796' RKB, 3400' RKB, & 1920' RKB, PULLED 1" HFCV'S @ 6693' RKB &6625' RKB, SET 1" DMY VLV'S @ 1920' RKB, 3400' RKB, 4796' RKB, TRAY ON KOT SWIVELED OFF AFTER SETTING 1" DMY VLV @ 5730' RKB . IN PROGRESS. 11/26/11 RECOVERED KOT TRAY IN CATCHER SUB @ 6887' SLM, PULLED 3 1/2 AVA CATCHER SUB @ 6887' SLM, CATCHER SUB HAD 1" DMY VLV FROM STA#4 VLV APPEARED TO BE FULLY SET, SET 3 1/2 AVA CATCHER SUB @ 6888' SLM, SET 1" DMY VLV @ 4796' RKB, PULLED 3 1/2 AVA CATCHER SUB @ 6888' SLM, LRS PUMPED 175 BBL DIESEL FREEZE PROTECT DOWN IA, SET 1" DMY VLV @ 6201' RKB. IN PROGRESS 11/27/11 RAN 3 1/2 HOLE FINDER, GOOD TBG PT DOWN TO 6525' SLM. COMPLETE, READY FOR COIL, 12/3/11 RUN#1=RIH W/NIPPLE LOCATOR, FLAG PIPE, KILL THE WELL W/ 150 BBLS SEAWATER, RUN #2= RIH, CORRECT DEPTH, SET CMT RETAINER AT 6600' RKB, PUMPED 20 BBLS (15.8#) CEMENT BELOW THE RETAINER, PUH LAYING IN 2 BBLS (15.8#) CEMENT ABOVE RETAINER. CONTAMINATE TO 6566' RKB TOC, JOB IN PROGRESS, READY FOR S/L 12/7/11 TAG TOC @ EST. 6573' RKB. TESTED CEMENT PLUG TO 2500 PSI, GOOD. PULLED DV @ 6515' RKB. PUMPED 10 BBL DOWN TBG TO VERIFY INJECTIVITY. SET 2.81"X LOCK IN SBR @ 6561' RKB. COMPLETE. �� 12/9/11 SET CEMENT RETAINER AT 6450' CORRELATING FROM X-LOCK AT 6561'. PUMPED 68 BBL'S CEMENT TO IA AND LAYED CEMENT IN TBG TO 5300'. WASHED OUT DOWN TO 5400'. FREEZE Pt' PROTECTED WELL. JOB COMPLETE. 12/14/11 TAG TOP OF CEMENT @ 5390' SLM, MIT TBG TO 2500 PSI PASS ( ELECTRONIC CHOKE IS THE ONLY VALVE THAT HOLDS) . JOB COMPLETE 12/17/11 MIT TBG TO 2500 PSI **PASS**, MITIA TO 1500**PASS**, BLEED TBG, IA, OA DN TO 200 PSI. JOB COMPLETE 12/19/11 CUT TUBING USING A 2.7" JRC JET CUTTER AT A DEPTH OF 5246'; IN THE MIDDLE OF THE 14TH JOINT BELOW THE GLM AT 4796'. TUBING/IA PRESSURE EQUALIZED FROM 900/250 PSI TO 250/250 PSI AFTER CUTTER WAS FIRED. RIGGED DOWN AND TURNED WELL OVER TO DSO. 12/20/11 Circulated 25 bbls diesel down tbg, up IA to tanks to verify tubing cut. Steady rate @ 1.5 BPM, 500 psi on TBG, 250 psi on IA throughout circulation. Note: Pump report in well file. 12/28/11 PRE ST T-POT( INCONCLUSIVE DUE TO LOW CASING PRESSURE ), T-PPPOT( PASSED), IC- POT( PASSED ), IC-PPPOT( PASSED ). FT-LDS ( MULTIPLE FROZEN ). ConocoPhillips Time Log & Summary Welfwew Web Reporting Report Well Name: 1E-05 Rig Name: NORDIC 3 Job Type: DRILLING SIDETRACK Rig Accept: 1/22/2012 7:30:00 PM Rig Release: 2/21/2012 12:00:00 PM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01/20/2012 24 hr Summary Breaking down 11"5M BOPE stack on 2T-Pad. Move Camp to 1E-Pad. Begin Rig move to 1E-Pad. 00:00 07:30 7.50 MIRU MOVE OTHR P Breaking down 11"5M BOP Stack and racking on skid. Rig Camp moved from 2T-Pad at 04:00 hrs to 10:00 hrs. 07:30 09:30 2.00 MIRU MOVE MOB P Move Nordic Rig 3 from 2T-Pad to 2A-Pad. 09:30 10:30 1.00 MIRU MOVE OTHR P Standby with crews while roads and Pad cleared drifting snow from road. 10:30 11:30 1.00 MIRU MOVE MOB P Continue to move Nordic Rig 3 from 2A-Pad to Four Corners. 11:30 12:00 0.50 MIRU MOVE OTHR P Stand-by at Four Corners to wait on traffic to pass. 12:00 14:00 2.00 MIRU MOVE MOB P Continue to move Rig to 2B-Pad Access Road. (Flat tire on Rig). 14:00 00:00 10.00 MIRU MOVE RGRP T PJSM. Wait on Rig tire. Change Rig tire. 01/21/2012 Complete Rig move to 1 E-Pad. RU at 1 E-05A Well Slot. Make-up 13 3/8"BOP Stack. 00:00 06:00 6.00 MIRU MOVE MOB P Continue with the Rig move to 1 E-Pad. Rig at the"Y"for Crew Change-out. 06:00 07:30 1.50 MIRU MOVE OTHR P Stand-by at the"Y"for Kuparuk Crew Change-outs. 07:30 09:00 1.50 MIRU MOVE MOB P Continue Rig move.to 1R"Y". 09:00 11:30 2.50 MIRU MOVE OTHR P Stand-by 1R"Y". Wait on field traffice to pass. 11:30 16:30 5.00 MIRU MOVE MOB P Continue Rig move to 1E-Pad. 16:30 00:00 7.50 MIRU MOVE RURD P Rig has arrived on 1E-Pad(17 mile Rig move from 2T-Pad to Location). Make-up 13 5/8"BOP Stack components and set on Cellar Stump. Prep area in front of Well Slot. 01/22/2012 Move Rig over Wellhead. Berm, level,and shim up Rig. MIRU support equipment. Fill Pits with Sea Water. RU and PT Lines. 00:00 07:00 7.00 MIRU MOVE RURD P Continue to prep to move over Wellhead. Lay additional rig mats. Notify DSO before moving over Wellhead. Move Rig over Wellhead. Level up and berm Rig. 07:00 21:00 14.00 MIRU MOVE RURD P Weather at-37 degrees ambient, Fill out cold weather Variance and start hauling in offsite Non-rig equipment. Spot and berm up same. Page 1 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 MIRU WHDBO PULD P PJSM. Warn up Lubricator. Pick-up Lubricator. Pull BPV. Lay down same. TP=20 psi(est), IAP= Slight Vacuum, OAP=70 psi. 01/23/2012 Circulate Well from Tbg Cut w/Sea Water. Install BPV. ND Tree. Install Blanking Plug. NU BOP. 00:00 03:00 3.00 MIRU WELCTI KLWL P PJSM. Pressure test Circulating Lines at 3,500 psi. Good. Bring Rig Pump on line. Initial circulating pressure, 3.0 bpm/210 psi. Final circulation pressure 3.0 bpm/400 psi. Total volume circulated=360 bbls. Moniter Well,"dead". Rig down Circulating Lines. Blow down line to Kill Tank. 03:00 06:30 3.50 MIRU WELLPF NUND P PJSM. Install BPV. Nipple down Production Tree. 06:30 08:00 1.50 MIRU WHDBOOTHR P Clean 3 1/2 IBT TBG Hanger Threads, large amounts of scale had to be chipped out of threads. Chased with blanking plug. 08:00 00:00 16.00 MIRU WHDBO NUND P NU 13 5/8"BOPE and install 2 7/8 x 5 1/2"VBRS in UPR and LPR's 01/24/2012 Continue to NU 13 5/8 x 5K BOP Stack. Perform Initial BOPE Test. Pull Blanking Plug and BPV. Spear Tubing. 00:00 05:00 5.00 MIRU WHDBO NUND P Continue to nipple up the 13 5/8"x 5K BOP Stack. Having trouble lining up BOP Stack with Rig Centered over the Well head. Wellhead was cocked—5 degs to the off-Driller's side due to a possible subsidence issue. Also the 13 5/8"Wellhead had very little give when back to center. Conduct shell test,found leaks in flange and continue to re-tighten flange. 05:00 11:00 6.00 MIRU WHDBO BOPE P Attempt to conduct Initial BOP Test at 250/3,500 psi. Unable to get test on any 13 5/8 Component-Had closure but no seal. Disconnect lines and tie back into themselves, circulate system while injecting steam into the test joint and warming fluid in BOP Stack. 11:00 22:00 11.00 MIRU WHDBO BOPE P Conduct Initial BOP test at 250/ 3,500 psi with 3 1/2 and 5 1/2 Test joint. Test 3 1/2 8rd and 4 1/2 IF FOSV and associated BOP equipment. Blind rams failed- change out blind rams and retest, good test.test upper and lower kelly valve 250/3500,good test. all alarms checked, koomey draw down tested good, ri down test equipment 22:00 23:00 1.00 5,000 5,000 MIRU WHDBO MPSP P MU retrieving tool and pull blanking plug, pull BPV, lay down same. Page 2 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 5,000 5,000 SLOT WELLPF THGR P MU ITCO Spear for 3-1/2"tbg, engage tbg below tbg hanger. 01/25/2012 Pull Tubing Hanger to the Floor. Circulate well surface to surface. Single down 3 1/2"Tubing to SSSV to Plpe Shed. MU and Re-land Tubing Hanger to Kill String.Circulate hole thru choke to increase fluid temp. 00:00 02:00 2.00 5,000 5,000 SLOT WELLPF THGR P BOLDS, pull tbg hanger to floor,85k Up wt. back out spear and lay down landing joint,spear and tbg hanger. 02:00 04:00 2.00 5,000 5,000 SLOT WELLPF CIRC P Rig up circ equipment. circulate hole 380 bbls,7.5 bpm, 800 psi, rig down circ equipment. 04:00 07:30 3.50 5,000 5,000 SLOT RPCOM PULL P Single down 61 jts of 3 1/2 IBT TBG to pipe shed, (3-1/2"decompletion showed no signs of subsidence) spooling back control line to SSSV. 07:30 12:30 5.00 5,000 5,000 SLOT WELLPF CIRC T RU and Circulate thru circulation line at 1.5 bpm at 60 psi thru choke manifold with 20 psi back pressure. OA at 50 psi. 12:30 16:30 4.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating 2.0 bpm at 100 psi thru choke manifold with 20 psi back pressure.OA at 50 psi 16:30 18:00 1.50 5,000 5,000 SLOT WELLPF THGR T PJSM-PU MU tbg hanger on landing joint to kill string, Land tbg hanger and RILDS, RU circ equipment. Wrap spacer spool below single gate with steam blanket to warm BOPE and fluids. 18:00 21:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 44°,fluid out at 48°,OA at 50 psi. Review well program,audit rig for repair and maintenance 21:00 00:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 46°,fluid out at 50°,OA at 50 psi as of midnight. Review well program,audit rig for repair and maintenance 01/26/2012 Continue to circulate hole to warm well bore. Pressure test 9-5/8"csg/Cement Plug to 1500 psi.Waiting on weather,severe cold. 00:00 03:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 46°,fluid out at 50°,OA at 50 psi. Review well program,audit rig for repair and maintenance Page 3 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 46°,fluid out at 56°,OA at 70 psi Review well program,audit rig for repair and maintenance 06:00 09:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 50°,fluid out at 55°, Fluid inside 13 5/8"5M at 52°F. OA pressure maintaining 70 psi. Review well program,audit rig for repair and maintenance 09:00 12:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 58°,fluid out at 64°, Fluid inside 13 5/8"5M at 64°F. OA pressure maintaining 70 psi. Review well program, audit rig for repair and maintenance 12:00 15:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 59°,fluid out at 62°, Fluid inside 13 5/8"5M at 62°F. OA pressure maintaining 70 psi. Review well program,audit rig for _ repair and maintenance 15:00 22:00 7.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 58°,fluid out at 65°, Fluid inside 13 5/8"5M at 60°F. OA at 40 psi. Review well program,audit rig for repair and maintenance 22:00 22:30 0.50 5,000 5,000 SLOT WELLPF PRTS T PJSM-Pressure testing casing. Bring 9-5/8"csg up to 1500 psi and chart 10 minutes,good. Page 4 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 62°,fluid out at 67°, Fluid inside 13 5/8"5M at 68°F. OA pressure maintaining 40 psi. Review well program,audit rig for repair and maintenance 01/27/2012 Continue to circulate hole to warm well bore.Waiting on weather,severe cold. 00:00 03:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 62°,fluid out at 67°, Fluid inside 13 5/8"5M at 68°F. OA pressure maintaining 40 psi. Review well program,audit rig for repair and maintenance 03:00 06:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 61°,fluid out at 67°, Fluid inside 13 5/8"5M at 67°F. OA pressure maintaining 40 psi. li Review well program,audit rig for repair and maintenance 06:00 18:00 12.00 5,000 5,000 SLOT WELLPF CIRC T Reverse circulate bottoms up 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 55°,fluid out at 55°, Fluid inside 13 5/8"5M at 55°F. OA pressure at 30 psi. Review revised well program,audit rig for repair and maintenance 18:00 00:00 6.00 5,000 5,000 SLOT WELLPF CIRC T Continue to reverse circulate bottoms up 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 47°,fluid out at 52°, Fluid inside 13 5/8"5M at 52°F. OA pressure maintaining 30 psi. Review revised well program,audit rig for repair and maintenance 01/28/2012 Continue to circulate hole to warm well bore. Clean pad, and make up lay down area.Off load 3-1/2" completion. Load and Tally 5"Drill pipe and 6-1/4"Drill collars.Waiting on weather. Page 5 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 09:00 9.00 5,000 5,000 SLOT WELLPF CIRC T Continue to reverse circulate bottoms up 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 45°,fluid out at 47°, Fluid inside 13 5/8"5M at 47°F. OA pressure maintaining 30 psi. Review revised well program,audit rig for repair and maintenance. 09:00 00:00 15.00 5,000 5,000 SLOT WELLPF CIRC T Continue circulating at 2.5 bpm at 1,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 49°,fluid out at 49°, Fluid inside 13 5/8"5M at 49°F. OA pressure maintaining 30 psi. Review well program,audit rig for repair and maintenance Set up lay down area,off load 3 1/2" competion, load and tally 5"DP and 6 1/4"DC's. 01/29/2012 Un-land tubing hanger. Single down 3-1/2"completion.Set test plug. Preform BOPE test. Pressure Test and Chart 9-5/8"Csg 250/3500 psi,good. MU 9-5/8"Scraper Assembly. 00:00 01:00 1.00 5,000 5,000 SLOT WELLPF OTHR P PJSM-Rig down circulating equipment. lay down landing joint. 01:00 02:30 1.50 5,000 5,000 SLOT WELLPF PULD P MU 3-1/2"ITCO spear,engage tubing hanger, BOLDS and pull tubing hanger to floor, lay down same. 02:30 09:00 6.50 5,000 5,000 SLOT WELLPF PULL P PJSM-Single out 3-1/2"completion from 3,365-ft. 09:00 10:00 1.00 5,000 5,000 SLOT WHDBO MPSP P Set FMC Test plug in Hanger profile. 10:00 19:00 9.00 5,000 5,000 SLOT WHDBO BOPE P Conduct weekly BOP Test 250/ 3,500 psi with 3 1/2",5"and 5 1/2" Test joints. 24 hr notice was given on 1/28/12 at 13:20 hrs. Right to witness test was waived by Matt Herrera at 13:25 hrs on 1/28/12. RD test equipment and pull test plug. 19:00 21:00 2.00 5,000 5,000 SLOT WELLPF PRTS P PJSM-Rig up test equipment, presure test 9-5/8"csg against blind rams 250/3,500 psi on chart 15 minutes, Rig down test equipment. 21:00 00:00 3.00 5,000 5,000 SLOT WELLPF PULD P PJSM-PU MU 8-1/2"Bit, 9-5/8" Scraper, Bit Sub, 8-1/2"String Mill, Bumper Sub,XO,6 jts 6-1/4"DC's, XO, 15 jts 5"HWDP to 656-ft. 01/30/2012 Run 9-5/8"Scraper to 5,259-ft. Circulate hole clean. POOH standing back DP. Suspend E-line operations due to CPAI Cold Weather SOP. Run 5"DP to 2,928-ft for a circulation string. Circulate while Waiting on Weather. Page 6 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 5,000 5,000 SLOT WELLPF TRIP P TIH with 9-5/8"Casing Scraper Assembly on 5"Drill pipe from 656-ft, soft tag top of tubing stub at 5,259-ft w/6k down wt. 170k Up wt/130k Dn wt. 04:30 06:30 2.00 5,000 5,000 SLOT WELLPF CIRC P Circulate 1.5 times hole volume at 5,246-ft, 8 bpm at 350 psi. 06:30 08:30 2.00 5,000 5,000 SLOT WELLPF TRIP P POOH f/5,257-ft.to 656-ft. 08:30 10:00 1.50 5,000 5,000 SLOT WELLPF PULD P POOH with BHA#2(Casing Scraper assy)up wt 67k do wt 67k from 656-ft to bit. 10:00 12:00 2.00 5,000 5,000 SLOT WELLPF ELOG T Suspend wireline operations due to CPAI Cold Weather SOP of-35 degrees. 12:00 15:30 3.50 5,000 5,000 SLOT WELLPF PULD T PU and MU 3 1/2 IF Bull nose,X-O and RIH w/93 jts of 5"DP to 2,928-ft for a circulation string to maintain wellbore temperature during Suspended wireline operations due to CPAI Cold Weather SOP of-35 degrees. 15:30 00:00 8.50 5,000 5,000 SLOT WELLPF CIRC T PJSM-Rig up circulating equipment, circulate bottoms up 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 39°,fluid out at 40°, Fluid inside 13 5/8"5M at 40°F. OA pressure 60 psi. Review revised well program,audit rig for repair and maintenance. 01/31/2012 Continue to Circulate while Waiting on Weather. Review revised well program,audit rig for repair and maintenance. 00:00 06:00 6.00 5,000 5,000 SLOT WELLPF CIRC T Continue to circulate 1 pipe volume 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 42°,fluid out at 50°, Fluid inside 13 5/8"5M at 50°F. OA pressure 60 psi. Review revised well program,audit rig for repair and maintenance. 06:00 09:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Circulate at 2.5 bpm at 2,000 psi maintaining back pressure with choke allowing friction to induce heat into kill weight fluid. Fluid in at 42°, fluid out at 48°, Fluid inside 13 5/8" 5M at 48°F. OA pressure maintaining 40 psi. Review well program, audit rig for repair and maintenance Page 7 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 5,000 15,000 SLOT WELLPF CIRC T Circulate 1 pipe volume 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 52°, fluid out at 58°, Fluid inside 13 5/8" 5M at 58°F. OA pressure 60 psi. Review revised well program,audit rig for repair and maintenance. 12:00 15:00 3.00 5,000 5,000 SLOT WELLPF CIRC T Continue to circulate 1 pipe volume 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 50°,fluid out at 54°, Fluid inside 13 5/8"5M at 55°F. OA pressure 60 psi. Review revised well program, audit rig for repair and maintenance. 15:00 00:00 9.00 5,000 5,000 SLOT WELLPF CIRC T Continue to circulate 1 pipe volume 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 49°,fluid out at 52°, Fluid inside 13 5/8"5M at 54°F. OA pressure maintaining 60 psi. Review revised well program, audit rig for repair and maintenance. 02/01/2012 00:00 12:00 12.00 5,000 5,000 SLOT WELLPF CIRC T Continue to circulate 1 pipe volume 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 49°,fluid out at 52°, Fluid inside 13 5/8"5M at 52°F. OA pressure maintaining 60 psi. Review revised well program,audit rig .for repair and maintenance. 12:00 00:00 12.00 5,000 5,000 SLOT WELLPF CIRC T Continue to circulate 1 pipe volume 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 49°,fluid out at 52°, Fluid inside 13 5/8"5M at 52°F. OA pressure maintaining 60 psi. Review revised well program,audit rig for repair and maintenance. 02/02/2012 Continue to Circulate while Waiting on Weather. PJSM-Warm up elevators, Bring in tools. POOH with Circ String. RU Test Joint. RU E-line. Run GYRO/Calliper. Perforate 9-5/8"Casing. MU String Shot. 00:00 02:30 2.50 5,000 5,000 SLOT WELLPF CIRC T Continue to circulate 1 pipe volume 2.5 bpm at 130 psi every 2 hrs to maintain heat to kill weight fluid. Fluid in at 49°,fluid out at 52°, Fluid inside 13 5/8"5M at 52°F. OA pressure maintaining 60 psi. Review revised well program,audit rig for repair and maintenance. Page 8 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 5,000 5,000 SLOT WELLPF SFTY P PJSM-temp at-33°,discussed hazards of starting up after severe cold weather,we are not behind, keep focused,warm up elevators before using. 03:00 05:30 2.50 5,000 5,000 SLOT WELLPF OTHR P Bring in MWD. Move DC and HWDP out of derrick alley. Bring in Tubing head and packoff in to cellar. 05:30 08:00 2.50 5,000 5,000 SLOT WELLPF TRIP P TOOH with 5"DP circ string from 2,862-ft standing back in derrick. 08:00 09:15 1.25 5,000 5,000 SLOT WELLPF OTHR P Load Baker tools and Equipment to Rig floor.Ship out generator from MI solid control van. Rig down secondary containment from MI skid and remove a bad heater and install another working heater. Install containment. 09:15 09:45 0.50 5,000 5,000 SLOT WELLPF SFTY P PJSM. Discuss hazard for rigging up E-line equipment and spotting unit. Making up logging tools, use good communication with HES,Gyro data, PDS and Rig crew while unloading and loading tools to floor. 09:45 12:45 3.00 5,000 5,000 SLOT WELLPF ELOG P Spot E-line Unit. Load Logging Tools to Floor. MU HES, Gyro Data and PDS logging assembly. 12:45 15:00 2.25 5,000 5,000 SLOT WELLPF ELOG P RIH with Gyro/caliper to 5,200-ft and log 9 5/8"casing to evaluate for any subsidence. 15:00 19:00 4.00 5,000 5,000 SLOT WELLPF ELOG P Start logging 9 5/8"casing from 5,200-ft to surface at 50 fpm. 19:00 19:15 0.25 5,000 5,000 SLOT WELLPF SFTY P PJSM-Discussed hazards of running perf guns. Communication is key. 19:15 21:15 2.00 5,000 5,000 SLOT WELLPF PULD P MU 3-3/8"x 10-ft, mille,6 spf,25g. 60 deg. carrier, NIS deep penetrating Perf Gun. HES E-line crew change out, held another PJSM with new crew. 21:15 23:00 1.75 5,000 5,000 SLOT WELLPF PERF P RIH with GR,CCL and Perf Gun, correlate collar at 5,086-ft, PU to 5,062.5 with CCL(CCL 7.5-ft above top shot)Perf 9-5/8"csg 5,070 to 5,080-ft POOH 23:00 23:15 0.25 5,000 5,000 SLOT WELCTL SFTY P PJSM-Discussed working around explosives. 23:15 00:00 0.75 5,000 5,000 SLOT WELCTL PULD P MU CCL and 5-ft String Shot. 02/03/2012 Run String Shot. Run 9-5/8"Cement Retainer on Drill Pipe. Correlate setting depth with E-line. RD E-line. Set Cement Retainer,Top Retainer set at 5,037-ft. Preform Injectivity Test and Set Perameters. RU SLB Cementers. Squeeze Perfs.Test 9-5/8"csg and retainer 3500 psi. RD Cementers. Run 9-5/8"Baker"G" Lock-set RBP. 00:00 00:45 0.75 0 0 SLOT WELCTL PULD P Continue to MU 5-ft String Shot, arm on rig floor, pressure test equipment 1000 psi. Page 9 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 01:45 1.00 0 214 SLOT WELCTI PERF P RIH with CCL and 5-ft string shot, shoot across 9-5/8"csg collar at 214-ft,good indication of gun fire. POOH and rig back E-line equipment. 01:45 02:00 0.25 0 0 SLOT WELCTI SFTY P PJSM-discussed hazards handleing and running 5"DP and ertainer. 02:00 05:00 3.00 0 5,040 SLOT WELCTI PULD P PU MU 9-5/8"Baker cement retainer and RIH on 5"DP to 5,040-ft 05:00 06:00 1.00 5,040 5,040 SLOT WELLPF ELOG P PJSM-RU E-line on DP. 06:00 07:45 1.75 5,000 5,000 SLOT WELLPF ELOG P RIH with CCL Logging Assembly and Logged up and Correlated and Corrected depth of Cement Retainer at 5,039-ft. Discuss sitting depth of retainer with Town Engineer. Decision was made to set retainer at current depth.Top of Retainer at 5,037-ft 07:45 10:00 2.25 5,000 5,000 SLOT WELLPF ELOG P POOH with E-line logging assembly. RDMO E-Line unit and equipment from Rig. 10:00 10:45 0.75 5,000 5,000 SLOT WELLPF EQRP T Trouble Shoot Top Drive. Found Bad Connection. Good to go for now. 10:45 11:30 0.75 5,000 5,000 SLOT WELLPF MPSP P Set Baker Cement Retainer dressed for 9 5/8"Casing, up wt=135k/down wt=115k. Start setting sequence, rotate 12 turns, puh to 175k, stack 115k down wt to compress slips, puh to 170k again, rih and stack 75k down weight and confirmed retainer is set, rotate 10 turns and release from retainer.Top Of Cement Retainer at 5,037-ft 11:30 11:45 0.25 5,000 5,000 SLOT WELLPF PRTS P Sting into retainer,Test backside to 1000 psi for 5 mins. 11:45 13:00 1.25 5,000 5,000 SLOT WELLPF CIRC P Unsting from retainer.Set parameters back circulating down Drill Pipe at 3 bpm while holding 200 psi back pressure on choke to determent holding pressure for cement job,Circulating pressure at 290 psi.. MIRU SLB pumping unit and equipment. Stand Back working joint. Blow down top drive. 13:00 13:30 0.50 5,000 5,000 SLOT WELLPF SFTY P Hold PJSM with Rig Crew and SLB pumping personal. Discuss hazard for high pressure pumping, used good communication, proper valve aliment and review pumping program. 13:30 14:15 0.75 5,000 5,000 SLOT WELLPF RGRP T While blowing air from Rig to Pumping unit to confirm treating lines where clear,found blockage in treating line. Page 10 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 16:15 2.00 5,000 5,000 SLOT WELLPF CMNT P Open rig valve to SLB cement treating iron,pump 10 bbls of seawater at 3 bpm, 290 psi. Shut down and close floor valve and perform low and high PT 650/4500 psi. Bleed back pressure, open floor valve and perform Injectivity test. .5 bpm, 1250 psi,lbpm,1350 psi,1.5 bpm, 1400 psi,2.0 bpm,1400 psi,2.5 bpm,1400 psi,3 bpm,1425 psi,3.5 bpm,1500 psi,4 bpm,1525 psi. Pressure went up to 1600 psi before breaking over. Mixed and pumped 8.5 bbls of MUDPUSH at 2 bpm, at 160 psi, close choke and Batch up and start circulating a total of 26.5 bbls of 15.8 PPG class G cement. Once mudpush reached retainer, slowed pump rate to 1 bpm,and shifted down to pump mudpush and cement into perforation. Pump Rate 3 bpm,1150 psi with cement at perf,pump another 21 bbls at 3 bpm, 1300 psi, lower pump to 1 bpm,1150 psi with 5 bbls remaining, pump 4 bbls more at 1 bpm, 1194 psi,stop pumping with 1 bbl of cement in drill pipe,Close annular and trapped 600 psi on the backside and pulled of retainer and seen pressure drop. Shut cement treating and blow back. Total 8.5 bbls of MUDPUSH and 25 bbls of 15.8 ppg cement squeeze into the perf. Initial pressure 1150 psi at 3 bpm,final pressure at 25 bbls pumped 1296 psi. 16:15 18:00 1.75 5,000 5,000 SLOT WELLPF CIRC P Sting out of retainer, reverse circulate 382 bbls,8 bpm at 340 psi. 18:00 18:30 0.50 5,000 5,000 SLOT WELLPF PRTS P Pressure test 9-5/8"csg and cement retainer 3500 psi,chart test 15 minutes. RD cement hoses. 18:30 22:30 4.00 5,000 5,000 SLOT WELLPF TRIP P TOOH standing back 5"drill pipe, lay down stinger.Clean and Clear Floors. 22:30 00:00 1.50 5,000 5,000 SLOT WELLPF MPSP P PJSM-PU MU 9-5/8"Model"G" Lock-set RBP,Model"L"Retrieving Head and RIH on 5"Drill Pipe. 02/04/2012 Run 9-5/8"Baker"G"Lock-set RBP. Dump 50-ft Sand. ND BOP. Remove Tubing head, 9-5/8"Casing Pack-off seized inside Tubing head. 1-1/4"casing growth. Confer with town Engineer, plan forward to back off 9-5/8"casing and pull. NU BOP. 00:00 01:15 1.25 5,000 5,000 SLOT WELLPF MPSP P Continue RIH with 9-5/8"Model"G" Lock-set RBP, Model"L"Retrieving Head on 5"Drill Pipe. Set top of RBP at 2,431-ft, release off,stand back 2 stands. 01:15 05:30 4.25 5,000 5,000 SLOT WELLPF OTHR P PJSM-Rig up and proceed to dump 50-ft of 20/40 mesh sand(44 sks) Page 11 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:30 1.00 5,000 5,000 SLOT WELLPF CIRC P Circulate seawater at.5 bpm to clear drill pipe. 06:30 07:00 0.50 5,000 5,000 SLOT WELLPF OTHR P PUH 2 stands and let sand settle. 07:00 09:00 2.00 5,000 5,000 SLOT WELLPF TRIP P RIH, set down and tagged top of sand at 2,390-ft. PJSM.TOOH standing back Drill Pipe. 09:00 09:15 0.25 5,000 5,000 SLOT WELLPF SFTY P PJSM. Discuss hazard for Nipple down BOPE. 09:15 11:30 2.25 5,000 5,000 SLOT WELLPF NUND P Nipple Down BOPE and stand back onto stand. 11:30 17:00 5.50 5,000 5,000 SLOT WELLPF NUND P Break tubing head from casing head and remove. Had to install stream blanket. 17:00 18:30 1.50 5,000 5,000 SLOT WELLPF PUTB P MU and RIH with 9 5/8"CSG spear. Engage Casing and pulled 100k,top of mandrel hanger flush with casing spool flange, .5-ft of movement.SO to neutral weight, mandrel hanger 1-1/4"from landing,stack 25k on casing,still 1"from landing fully, back out spear and POOH. 18:30 18:45 0.25 5,000 5,000 SLOT WELCTL SFTY P PJSM-Discuss hazard for running bumper sub and HWDP. 18:45 20:15 1.50 5,000 5,000 SLOT WELCTL PUTB P MU and RIH with 9 5/8"CSG spear, Bumper Sub and HWDP, Engage Casing and set down 30k,some movement, PU and SO multiple times to get to within 3/8"of fully landing, casing returns to 1"growth when weight gets back to neutral, back out spear-POOH. 20:15 21:30 1.25 5,000 5,000 SLOT WELCTL OTHR P Confer with Town Engineer on plan forward. Clean and clear floors. move on with back off and replace 9-5/8" casing. 21:30 21:45 0.25 5,000 5,000 SLOT WELLPF SFTY P PJSM. Discuss hazard for Nipple Up BOPE. 21:45 00:00 2.25 5,000 5,000 SLOT WELLPF NUND P Nipple Up BOPE. 02/05/2012 NU BOP. Cut 9-5/8"casing above string shot collar. Circulate OA to seawater. Pull 9-5/8"casing from cut. Back-off 20'x 9-5/8"casing stub. 00:00 02:00 2.00 5,000 5,000 SLOT WELCTL NUND P Continue to nipple Up BOPE. Fill stack and monitor for leaks. 02:00 02:15 0.25 5,000 5,000 SLOT WELCTL SFTY P PJSM-Discuss hazard for running Multi-String Cutter. 02:15 05:15 3.00 5,000 5,000 SLOT WELCTL PULD P Load Baker tools. PU MU Baker 8-1/4 Multi-String Cutter,XO, Stabilizer,XO,6 DC's, locate collars at 203.5-ft and 161.5-ft, RBIH and cut 9-5/8"casing at 184-ft. 05:15 08:30 3.25 5,000 5,000 SLOT WELLPF CIRC P Circulate OA with 140 deg seawater, 40 bbls,2 bpm at 90 psi taking returns to cutting box x2. 08:30 10:30 2.00 5,000 5,000 SLOT WELLPF TRIP P TOOH standing back Drill Collars and Lay down MSC Assembly. 10:30 11:30 1.00 5,000 5,000 SLOT WELLPF PULD P P/U and MU Spear, Unland 9 5/8" CSG at 110k up weight. Page 12 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:30 1.00 5,000 5,000 SLOT WELLPF CIRC P Still having gas breaking out of Arctic Pack, line up and circulate thru choke to kill tank at 4 bpm,120 psi. Pump a total of 100 bbls and monitor well for 15 mins. 12:30 13:30 1.00 5,000 5,000 SLOT WELLPF PULD P R/U GBR Casing Equipment. 13:30 18:00 4.50 5,000 5,000 SLOT WELLPF PULD P Start POOH with 9 5/8"CSG. Having problems breaking connection with the 20k power tongs. Install stream blasket on connection. Finally able to break first connection at 19k. Continue to pull 9 5/8"casing. 18:00 18:30 0.50 5,000 5,000 SLOT WELCTL OTHR P Clean and clear floors. Load Tools. 18:30 18:45 0.25 5,000 5,000 SLOT WELCTL SFTY P PJSM-Discussed hazards associated with making up back-off tool, hans placement, communication. 18:45 20:30 1.75 5,000 5,000 SLOT WELCTL PULD P PU MU Baker 8"Back-off tool- Swedge,XO,2 stds DC's,XO, Blanking Sub, Lower Anchor, Power Section, Upper Anchor,XO.RIH on 2stds 5"HWDP. 20:30 00:00 3.50 5,000 5,000 SLOT WELCTL BKOF P RIH with BHA#10 on 5"HWDP, position across collar, Up wt 60k, Dn wt 65k, rig up test pump equipment, set lower then upper anchors,start back-off sequence,cycled 10 times, achieved approximately 6 turns- POOH, stand back HWDP, lay down BO Tool. 02/06/2012 Back-off and Pull 20'x 9-5/8"casing stub. Run New 9-5/8",47#,L-80 casing.Test 9-5/8"casing 3500. ND BOP. Pull Casing in tension,set emergency slips,trim casing and set 9-5/8"casing pack-off. Inspect, repair and replace unusable Lock Down Screws. 00:00 00:30 0.50 0 0 SLOT WELCTL PULD P Continue to lay down BO Tool assembly,clear floor. 00:30 01:00 0.50 5,000 5,000 SLOT WELCTL PULL P PJSM-PU MU and RIH with 9-5/8" ITCO Spear on 5"DP, Up wt 43k, Dn wt 45k,engage csg stub, back out 5 turns, PUH 01:00 01:30 0.50 5,000 5,000 SLOT WELCTL CIRC P Circulate 30 bbls,2 bpm at 90 psi, BDTD. 01:30 03:00 1.50 5,000 5,000 SLOT WELCTL PUTB P PJSM-POOH stand back DP, back out spear, lay down 20.10-ft stub,pin looking down,kick out 170.5-ft total of 9-5/8"casing plus hanger pup pulled. 03:00 05:00 2.00 5,000 5,000 SLOT WELCTL OTHR P Clean and clear floors, load out Baker tools. change over floors to run 9-5/8"casing. 05:00 08:00 3.00 0 197 SLOT WELCTL RNCS P PJSM. RIH w/9-5/8"Tie-Back Casing String. 08:00 09:30 1.50 5,000 5,000 SLOT WELLPF CIRC P Stop short of exerting completion.PJSM. RU Little Red Pumping unit and ciruclate 50 bbls of diesel down casing and taking returns up the OA to surface. Page 13 of 30 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 09:30 10:00 0.50 5,000 5,000 SLOT WELLPF RNCS P Once clean diesel was seen at surface, locate top of exerting casing stub and screw new 9 5/8"tie-back string. 10:00 11:15 1.25 5,000 5,000 SLOT WELLPF PRTS P RU LRS again and pressure test new 9 5/8"casing string to 3700 psi for 30 mins&chart with 6.8 ppg diesel. Obtain good MIT on chart. Lost 50 psi in 15 minutes and 50 in 30 minutes.Total 100 psi in 30 minutes. 11:15 12:15 1.00 5,000 5,000 SLOT WELLPF PULD P Bleed down pressure. PJSM. RDMO Little Red Pumping service. 12:15 12:30 0.25 5,000 5,000 SLOT WELLPF SFTY P Crew Change Out. PJSM. 12:30 13:30 1.00 5,000 5,000 SLOT WELLPF PULD P Break down landing joint. RD casing handling equipment and unload from Rig floor. 13:30 17:30 4.00 5,000 5,000 SLOT WELLPF NUND P PJSM. ND BOPE, Pull Casing to 100k tension, lift BOPE and install Emergency Slips, cut 9-5/8"CSG and lay down same. 17:30 19:00 1.50 5,000 5,000 SLOT WELLPF PULD P Set BOPE on stump. Remove cut CSG debris and trim and clean CSG stub and Install new pack-off. 19:00 00:00 5.00 5,000 5,000 SLOT WELLPF NUND T Remove and inspect Lock Down Screws that seemed gauld,several of the LDS's and packing nuts have bad threads, round up proper tap's for threads, remove and inspect LDS's from old tubing head still onsite to replace several of the bad casing head LDS's.9 of 14 LDS's in as of midnight. 02/07/2012 Continue Lock Down Screw replacement. NU Tubing Head.Test casing pack-off. NU DSA and BOPE. Preform BOPE test. Pull RBP. PU CO Assembly. 00:00 00:30 0.50 5,000 5,000 SLOT WELLPF NUND T Continue to replace several of the _bad casing head LDS's. 00:30 01:30 1.00 5,000 5,000 SLOT WELLPF NUND P Install new TBG Head. 01:30 02:30 1.00 5,000 5,000 SLOT WELLPF PRTS P Rig up test equipment, pressure test 9-5/8"casing pack-off to 3800 psi (80%of collapse),good 15 minutes, rig down test equipment. 02:30 06:00 3.50 5,000 5,000 SLOT WELLPF NUND P NU 13-5/8"5k x 11"5k Double Studded Adapter and BOPE. 06:00 14:00 8.00 5,000 5,000 SLOT WELLPF BOPE P Conduct Weekly BOPE test at 250/ 3,500 psi with 3 1/2",5"and 5 1/2" Test joints. 24 hr notice was given to AOGCC at 14:00 hrs on 2-6-12 and Right to witness was waived at 14:05 hrs on 2-6-12 by Bob Noble. 14:00 15:00 1.00 5,000 5,000 SLOT WELLPF MPSP P Pull test plug and install 9 1/8"ID wear ring 15:00 15:15 0.25 5,000 5,000 SLOT WELLPF SFTY P Held PJSM on RIH w/RBP retrieving head, circulating sand off RBP and releasing of RBP. 15:15 17:30 2.25 5,000 5,000 SLOT WELLPF TRIP P RIH with retrieving head on 5"DP to 2,385-ft Tag up on sand. Page 14 of 30 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 17:30 19:00 1.50 5,000 5,000 SLOT WELLPF FCO P Circulate sand off top of RBP at 8 bpm at 120 psi from 2,385-ft to2 ,431-ft. 19:00 19:30 0.50 5,000 5,000 SLOT WELLPF CIRC P Release Baker Lock-Set Retrievable Bridge Plug with no problems. Circulate bottons-up at 5.0 bpm/70psi. Monitor Well static. 19:30 20:30 1.00 5,000 5,000 SLOT WELLPF TRIP P Trip out with 5"Drill Plpe,standing back in the Derrick and the Baker RBP. 20:30 22:00 1.50 5,000 5,000 SLOT WELLPF PULD P Lay down Baker RBP, complete. Lay down the Retrieving Tool. Clear and clean Floor. 22:00 23:30 1.50 5,000 5,000 SLOT WELLPF PULD P PJSM. Pick-up Clean-out BHA as follows: 8 1/2"Blt, Bit sub, 8 1/2" String Mill, Bunper sub,XO,6 ea 6 1/8"Drill Collars,XO, 15 Jts of HWDP. 23:30 00:00 0.50 5,000 5,000 SLOT WELLPF TRIP P Begin to trip in with clean-out BHA on 5"Drill Pipe from the Derrick to 290-ft. Up Weight=58K. Down Weight=60 K. 02/08/2012 RIH w/8 1/2"Bit/8 1/2"String Mill to the Cmt Ret at 5,037-ft. Swap Wellbore over to 9.6 lb/gal Milling Fluid. TOOH. PU Whiostock System.TIH.Set/Orient Whipstock. Begin milling the Window. 00:00 04:00 4.00 5,000 5,000 SLOT WELLPF TRIP P Continue to trip in with the Clean-out BHA. Up weight= 173K. Down Weight=124K. Tagged up at 5,030-ft. 04:00 06:30 2.50 5,000 5,000 SLOT WELLPF CIRC P Bring Rig Pump on line at 4.2 bpm/100 psi. Wash through fill with no rotation from 5,030-ft down to the Cement Retainer at 5,037-ft. Reverse in a 30 bbl Hi-Vis Sweep. Continue to Reverse circulate and chase the Sweep back to surface with the 9.6 lb/gal Milling Fluid at 4.0 bpm/110 psi. Blow down Top Drive. 06:30 07:00 0.50 5,000 5,000 SLOT WELLPF TRIP P POOH w/1 stand from 5,037-ft to 4,904-ft. 160k up wt 128/k do wt. Break circulation at 550 gpm at 85 spm at 890 psi-Shakers able to maintain. 07:00 11:00 4.00 5,000 5,000 SLOT WELLPF SLPC P Slip and cut 84-ft of drill line, Service draw works and sync 5 Totco units to record same. 11:00 14:30 3.50 5,000 5,000 SLOT WELLPF TRIP P POOH from 4,904-ft to BHA#13 at 652-ft 14:30 15:00 0.50 5,000 5,000 SLOT WELLPF PULD P POOH w/BHA#13 15:00 15:30 0.50 5,000 5,000 SLOT WHPST SFTY P Held PJSM on PU, MU and RIH w/ BHA#14(8.5"Whip stock)with Nordic, Baker, Sperry and Can rig personnel. 15:30 21:00 5.50 5,000 5,000 SLOT WHPST PULD P PU, MU and RIH w/BHA#14(8.5" Whip stock)to 372-ft. Shallow Pulse Test at 9.0 bpm/920 psi-Good Test. Blow down Top Drive. Page 15 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 5,000 5,000 SLOT WHPST TRIP P Continue trip in hole from 372-ft with the Whipstock Assembly. Running speed=90- 120 seconds per stand of 5"Drill Pipe to 3,093.0-ft. Up Weight=113K. Down Weight= 100K. 02/09/2012 Continue to mill Window in the 9 5/8"Casing.Continue drilling a gauged hole to 5,072-ft. 00:00 03:00 3.00 5,000 5,000 SLOT WHPST TRIP P Continue to trip in with the Whipstock BHA with 5"Drill Pipe from 3,093-ft. Stop at 4,983.5-ft. Up Weight= 157K. Down Weight= 132K. 03:00 04:00 1.00 5,000 5,000 SLOT WHPST SRVY P Bring Pump on line at 10.0 bpm/900 psi. Oriented the Whipstock to 31 degs left of high side of the hole. Tagged the Cement Retainer at 5,037-ft. Set 17K down and set Anchor. Pulled up to 167K(10K over String Weight)to confirm Anchor set. Set back down to 98K and shear Milling Assembly free from Whipstock. 04:00 10:30 6.50 5,000 5,020 SLOT WHPST MILL P Record slow Pump Rate as follows: 25%=120 psi at 17 strokes. 50%= 160 psi at 35 strokes. Establish Milling parameters as follows: 10.0 bpm/880 psi, RPMs=80-100, WOM=5-25K Begin Milling on lug at 5,014-ft,mill off lug with minimal WOM at 5-10k torque at 80 rpm circulating at 420 gpm. Continue to mill to 5,019-ft with increasing WOM to 5k and rpm's to 100. Started getting cement returns at 5,020-ft with 4k WOM at 10k [ torque at 100 rpm's. 10:30 12:30 2.00 5,020 5,022 SLOT WHPST MILL P Continue to milling from 5,020-ft to 5,022-ft with 4 to 5k WOM with torque increasing from 5 to 10k torque at 80 rpm circulating at 420 gpm. Continue to mill to 5,019-ft with f fiy� increasing WOM to 5k and rpm's to 100. Started getting cement returns at 5,020-ft with 4k WOM at 10k torque at 100 rpm's. 12:30 18:00 5.50 5,020 5,036 SLOT WHPST MILL P Continue to Mill from 5,022-ft to 5,036-ft with the following parameters. RPMs= 100,WOM= 10-15K, Pump Rate=425-450 gpm, Stand Pipe Pressure=950 psi -1,000 psi.Top Drive Torque=9K off bottom/12K on bottom. Page 16 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 5,036 5,048 SLOT WHPST MILL P Continue to Mill from 5,036-ft- 5,046-ft with the following parameters: RPMs= 100. Pump Rate=455 gpm/1,020 psi. WOM= 15k,Average penetration rate=2.0 ft/hr. Note: attempted to increase WOM. However,torque increased and penetration rate decreased. Change parameters to RPMs=60, Pump Rate=400 gpm/870 psi, WOM=15-17K. Torque on bottom = 12K. 02/10/2012 Finish gauged hole to 5,072-ft. Perform Leak-Off Test.Trip out with Milling Assy. Make-up Cean-out BHA. 00:00 06:00 6.00 5,048 5,054 SLOT WHPST MILL P Continue to mill 8 1/2"gauged hole from 5,027 to 5,032-ft w/window mill at 5,054-ft at 60 rpm's w/12k ave. torque at 15 to 20K WOM, circulating at 500 gpm. 06:00 10:00 4.00 5,054 5,062 SLOT WHPST MILL P Continue to mill 8 1/2"gauged hole from 5,032 to 5,042-ft w/window mill at 5,062-ft at 60 rpm's w/12k ave. torque at 15 to 20K WOM, circulating at 500 gpm. Giving us 20-ft 8 1/2"Gauged hole from 5,022 to 5,042-ft. 10:00 10:30 0.50 5,062 5,062 SLOT WHPST REAM P Back ream up with"No Bobbles above top of window at 5,014-ft,Then reaming back down with No Bobbles" 150k up wt and 130k do wt 10:30 12:00 1.50 5,062 5,062 SLOT WHPST CIRC P Pump 30 bbl super sweep Surface to Surface at 12 bpm at 1,200 psi Blow down Top drive. 12:00 12:30 0.50 5,062 5,062 SLOT WHPST OTHR P RU for LOT 12:30 13:00 0.50 5,062 5,062 SLOT WHPST SFTY P Held PJSM with Rig crew on Setting up for and Conducting LOT. 13:00 14:00 1.00 5,062 5,062 SLOT WELCTI LOT P Conduct_LOT w/9.6 ppq fluid in hole. Pressure up to 1420 psi in 30 strokes. Shut down and record pressure drop for 10 minutes. Lost ir- � 470 psi in 10 minutes, Bleed off and recover 1.0 bbls of 2.1 bbls pumped. RD test equipment. 14:00 14:30 0.50 5,062 5,062 PROD1 DRILL OWFF P Monitor well for flow-Good no flow 14:30 16:00 1.50 5,062 5,062 PROD1 DRILL TRIP P POOH w/Milling BHA from 5,054-ft to 710-ft.to BHA#14 16:00 18:00 2.00 5,062 5,062 PROD1 DRILL PULD P POOH w/BHA#14 from 710-ft. Gauge mills-8.5"OD Window mill 1/4"under gauge(Upper side buttons were missing), 8.375"OD Lower String Mill= 1/8"under gauge and Upper Mill was in full gauge. Page 17 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 22:00 4.00 5,062 5,062 PROD1 DRILL CIRC P PJSM. Clear Floor. Make-up Magnets(2 ea)and Swizzle Stick to wash out BOP Stack. Rotate and reciprocate Swizzle Stick across the Stack while jetting a 8.0 bpm. Pull out and clean off Magnets. Recovered a normal expected amount of metal cuttings. Clean Magnets. Run back in and repeat. Pull out. Clean Magnets. Recovered a total of 17 lbs. Total metal cuttings recovered from milling the Window to date=367 lbs. Lay down BHA sections not needed for the next BHA. 22:00 22:30 0.50 5,062 5,062 PROD1 RIGMNT SVRG P Sercive and inspect Top Drive. 22:30 00:00 1.50 5,062 5,062 PROD1 DRILL PULD P PJSM. Make-up the Clean-out BHA #16 as follows: Window Mill, Lower String Mill, Flex Joint, Upper String Mill, 1 Jt of HWDP, Float Sub, MI Razor Back Scraper, MI Magnet, MI Magnet,XO,6 ea Drill Collars,XO, 15 sits of HWDP. Prep to start in hole. 02/11/2012 Trip in with the clean-out BHA. Circulate Wellbore,clean.Trip out and LD BHA. Make-up the next BHA: PDC Bit and MWD equipment. Start TIH w/BHA. 00:00 04:30 4.50 5,062 5,063 PROD1 DRILL TRIP P Trip in with BHA 16 to clean-out the Gauged-hole section. Stop at 2,930-ft to fill the Drill Plpe. Continue to trip in. Stop at 4,850-ft. Fill Drill Pipe. Perform Slow Pump rates. Bring Pump on line at 11.0 bpm/1,020 psi. Continue to slide down to and out the Lower Window at 5,031.8-ft. Continue to bottom at 5,063-ft. 04:30 06:00 1.50 5,063 5,063 PROD1 DRILL CIRC P Circulate Well at 11.0 bpm/1,025 psi. Pump a 25 bbl Super Sweep. Chase back to surface with clean 9.6 lb/gal of LSND Mud while reciprocating Drill Pipe. (Note: Mill was at 5,063-ft while Super Sweep turned the corner). 06:00 07:00 1.00 5,063 5,063 PROD1 DRILL OWFF P POOH to 4,973-ft 155k up wt. Monitor well-Static. Blow down top drive 07:00 10:00 3.00 5,063 5,063 PROD1 DRILL TRIP P POOH f/4,973-ft to BHA#16 at 782-ft. Monitor well-Static 10:00 13:00 3.00 5,063 5,063 PROD1 DRILL PULD P Continue to POOH w/BHA -Clean magnets-(Recovered 120 lbs. of Metal) Continue to lay down BHA. Pictures of Magnets are in well. 13:00 13:30 0.50 5,063 5,063 PROD1 DRILL SFTY P Held PJSM on using beaver slide, and off loading Baker tools,along with MI Well bore clean tools. Page 18 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 5,063 5,063 PROD1 DRILL OTHR P Off load Baker tools, along with MI Well bore clean tools. 14:30 15:00 0.50 5,063 5,063 PROD1 DRILL SFTY P Held PJSM with Sperry, MI,Can rig and Nordic Rig crew on picking up, making up and RIH w/DrIg BHA. Discuss hazards of working with Radioactive sources. 15:00 18:00 3.00 5,063 5,063 PROD1 DRILL PULD P PU and MU Sperry DrIg BHA#17 and RIH to 126-ft and Upload tool. 18:00 22:15 4.25 5,063 5,063 PROD1 DRILL PULD P Monitor Well static. Continue to plug in and load MWD Tools. PJSM: "Loading Radioactive Source". Pick-up Flex Collar#1. Perform Shallow Pulse Test at 400 gal/min at 800 psi. Good test. Blow down Top Drive. Pick-up BHA and clean Source Ports. Make announcement on Rig and secure Cellar/Rig entrances. Load Nuke Sources. Pick-up remaining Flex Collars(#2 and#3), HWDP(3 ea), Drilling Jars, HWDP(2 ea). 22:15 00:00 1.75 5,063 5,063 PROD1 DRILL TRIP P Trip in with BHA#17 on 5"Drill Pipe from the Derrick. Stop at 2,005-ft. Fill Pipe. Up Weight=95K. Down Weight=88K. Perform slow pump rates. Continue to trip in with 5"Drill Pipe. 02/12/2012 Complete TIH with 8 1/2"Directional Drill BHA. Begin to Drill the 8 1/2"Directional Hole from 5,063-ft to 5,620-ft MD. 00:00 04:00 4.00 5,063 5,063 PROD1 DRILL TRIP P Continue to trip in with the 8 1/2"DD BHA from 2,005-ft. Stop at 3,995-ft. Fill Pipe. Stop at 4,810-ft. Make-up Top Drive. Bring Pump on line at 400 gpm/1,260 psi. Circulate. 9.6 lb/gal, 60 Vis in/out. Orient 55L. End Pump. Continue in hole. Slide across Whipstock(TW st 5,014-ft, BW at 5,031-ft)with no problems or bobbles. Stop at 5,044-ft(depth of gauged hole). Bring Pump on at 400 gpm/1,280 psi. Continue down to 5,063-ft. 04:00 12:00 8.00 5,063 5,250 PROD1 DRILL DDRL P Begin drilling new hole from 5,063-ft at 04:09 hrs. Directional drilling ahead from 5,063-ft at 140° L to 5,250-ft sliding at 170 R 12:00 18:00 6.00 5,250 5,470 PROD1 DRILL DDRL P Continue drilling new hole from 5,250-ft, Directional drilling ahead from 5,250-ft at 170°R to 5,470-ft sliding at 120°R. Avg. ECD= 10.67 ppg Avg.Total Flow=530 gpm Avg. SSP=2,200 psi Page 19 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 23:30 5.50 5,470 5,594 PROD1 DRILL DDRL P Continue drilling new hole from 5,470 -ft at 120° R to 5,594-ft. Back ream hole up to Shoe, but leave the BHA below the Shoe. Return to bottom on Elevators. No problems or bobbles. Hole in good condition.. Last Survey at 5,548-ft, 10.23 inc, 83.07 adz OAP=550 (Note: increase in pressure due to thermal expansion because of a fluid packed Annulus. Continue to monitor). Perform and record Slow Pump Rates. 23:30 00:00 0.50 5,594 5,620 PROD1 DRILL DDRL P Continue drilling new Hole from 5,494-ft. Directional drilling ahead to 5,620-ft. Avg ECD 10.7 Lb/gal Avg Total Flow 540 gal/min Avg SPP 2,050 psi Mud Weight 9.6+lb/gal in/out 02/13/2012 Drill the 8 1/2"Directional Hole from 5,620-ft to 6,161-ft(TD to be determined). 00:00 06:00 6.00 5,620 5,865 PROD1 DRILL DDRL P Continue drilling ahead from 5,620-ft. (5,713-ft Slide 60R.)to 5,865-ft. Avg ECD 10.85 lb/gal Avg Total Flow 540 gal/min Avg SPP 2,325 psi Mud Weight 9.8 lb/gal OAP at 05:00 hrs=850 psi. Bleed down to 500 psi. Continue to monitor. 06:00 12:00 6.00 5,865 5,972 PROD1 DRILL DDRL P Continue drilling ahead from 5,865-ft. (5,964-ft Slide 70L.)to 5,972-ft. Avg ECD 10.70 lb/gal Avg Total Flow 550 gal/min Avg SPP 2,250 psi Mud Weight 9.8 lb/gal 12:00 18:00 6.00 5,972 6,161 PROD1 DRILL DDRL P Continue drilling ahead from 5,972-ft. (6,142-ft Slide 70L.)to 6,161-ft. Avg ECD 10.70 lb/gal Avg Total Flow 550 gal/min Avg SPP 2,300 psi Mud Weight 9.9 lb/gal Page 20 of 30 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 6,161 6,380 PROD1 DRILL DDRL P Continue drilling ahead from 6,161-ft. OAP=700 psi. At 6,186-ft bump Mud Weight to 10.0 lb/gal.At 6,171=ft-6,224-ft, slide 60L. At 6,224-ft,pulling out on a Slide had to unload Jar one time. Ream tight area. OK now. At 6,234-ft-6,246-ft Slide 70L. Continue drilling ahead. At 6,300-ft. Add a 290 bbl 10.8 lb/gal Mud Spike to the present 9.9 lb/gal Mud in the Hole. R&R Drill Pipe until 10.8 Lb/gal Mud Spike starts up the Annulus. ECD= 10.85 lb/gal. Continue drilling from 6,380-ft. AVG ECD 10.85 lb/gal AVG Total Flow 500 gal/min AVG SPP 2,350 psi Present Mud Weight= 10.2 lb/gal in/out 02/14/2012 Drill the 8 1/2"Directional Hole from 6,380-ft to 7,010-ft(TD to be determined). 00:00 13:00 13.00 6,380 6,793 PROD1 DRILL DDRL P Continue drilling ahead at 6,380-ft. Start to increase Mud Weight 10.3 lb/gal in. 10.3 lb/gal out. Slide 6,455-ft-6,529-ft 10L. Mud Weight 10.4 lb/gal in, 10.3+out. ECD 11.31 lb/gal. Avg ECD 11.1 lb/gal Avg Flow 450 gal/min Avg SPP 2,200 psi. 13:00 14:00 1.00 6,793 6,793 PROD1 DRILL COND P Increase Mud from 10.3 Lb/gal to 10.8 Lb/gal 14:00 18:00 4.00 6,793 6,955 PROD1 DRILL DDRL P Continue drilling ahead at 6,793-ft. Mud Weight at 10.8 Lb/gal in. 10.7 lb/gal out. ECD 11.5 lb/gal, 170 SPM,2500 psi. Avg ECD 11.5 lb/gal Avg Flow 490 gal/min Avg ROP 57 ft/hr. Page 21 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 6,955 7,010 PROD1 DRILL DDRL P OAP=700 psi. Continue drilling ahead from 6,955-ft to 7,010-ft. Short-Trip and back ream at 400 gal/min x 50 RPMs up to the Whipstock(note: leave BHA just below the Whipstock). Circulate bottoms up. Run back to bottom on Elevators to 7,010-ft. Saw no tight spots or bobbles. (Perform Slow Pump checks at 6,980-ft). Avg ECD 11.5 lb/gal Avg Flow 425 gal/min Avg SPP 2,425 psi Present Mud Weight 10.9 lb/gal OAP=550 psi at Midnight. 02/15/2012 Drilled 8 1/2"Hole to TD at 7,273-ft.Circ&Cond the Hole w/11.0 lb/gal Mud. Start Trip out w/5'Drill Pipe. 00:00 05:00 5.00 7,010 7,142 PROD1 DRILL DDRL P Continue drilling ahead from 7,010-ft. Broken Slide from 7,010-ft-7,061-ft (26-ft interval)60L. Encountered excessive vibration at several intervals between 7,010-ft-7,100-ft. Tried different RPMs, Flow Rates, and WOB. Also began to see Top Drive torque spikes to 12/13 k ft/lbs between 7,090-ft-7,104-ft. Back ream 7,104-ft-7,010-ft. Drilling ahead again at 7,135-ft. Avg ECD 11.5 lb/gal Avg Flow Rate 500 gpm Avg SPP 2,250 psi Present Mud Weight 10.8 lb/gal in, 10.8+Ib/gal out. 05:00 10:00 5.00 7,142 7,273 PROD1 DRILL DDRL P Continue drill ahead from 7,142-ft to 7,273-ft where TD was called. Up wt 195k/Dn wt 148k while pumping and rotating. 208k up wt and 153 do wt not pumping or rotating. SPP 1900 psi at 440 gpm. ECD 11.4, 10.7 lb/gal in and 10.7 lb/gal out, 75 rpm. 10:00 12:00 2.00 7,273 7,273 SLOT DRILL CIRC P Circulated hole clean x3 while reciprocating 500 gpm/2400 SPP, pu wt 208k,so wt 152k, rotating wt 174k at 80 rpm, 11.58 ECD. 12:00 13:00 1.00 7,273 7,273 SLOT DRILL CIRC P Backream to 6,818-ft while conditing mud(5 stands)while pumping at 450 gpm,1,950 SPP,50 rpm. Page 22 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 19:00 6.00 7,273 7,273 SLOT DRILL CIRC P Orient drilling assembly to high side RIH down to 7,199-ft w/elevators with no problem. Kelly up and ream down to 7,273-ft,208k up wt, 152k do wt. Off-load additional Mud products. Circulate and condition hole x 1.5 volumes with 11.0 lb/gal Mud. Blow down Top Drive. Monitor Well, static. 19:00 21:30 2.50 7,273 7,273 SLOT DRILL TRIP P Begin trip out with 5"Drill Pipe, standing back in the Derrick. Stop at 5,220-ft. Orientated the BHA to the Whipstock. Pull BHA through the window with no problems or bobbles. Pump"Dry-Job". Secure Well for Rig Maintenance. 21:30 23:00 1.50 7,273 7,273 SLOT RIGMN1 RGRP P PJSM. Cut and Slip Drilling Line (84-ft) Inspect and adjust Brake Bands. 23:00 00:00 1.00 7,273 7,273 SLOT DRILL TRIP P Drop 2"Drift. Resume Trip out with 5"Drill Plpe and BHA to 3,532-ft. 02/16/2012 Complete TOOH w/5"DP. LD 8 1/2"DD BHA. Run 5 1/2"Liner as designed. RU Cementers. Condition Mud. 00:00 02:15 2.25 7,273 7,273 SLOT DRILL TRIP P Continue to trip out with 5"Drill Pipe standing back in the Derrick to the BHA. 02:15 02:45 0.50 7,273 7,273 SLOT DRILL PULD P BHA at Surface. Lay down HWDP and Drilling Jars. Stop for Safety Meeting. 02:45 03:00 0.25 7,273 7,273 SLOT DRILL SFTY P Safety Meeting with All. Reviewed and discussed the hazards associated with removing the Nuke Sources from the BHA. Secure work area and entrances to the Rig. 03:00 07:00 4.00 7,273 7,273 SLOT DRILL PULD P Remove and account for both Nuke Sources. Place in proper storage container and remove from the Rig. Download MWD Data. Continue to lay down BHA. 07:00 09:30 2.50 0 0 COMPZ RPCOM OTHR P Clean&Clear Floor.Change Out Handling Equipment to run 5.5" Liner. Stage MWD tools in pipe shed. 09:30 10:15 0.75 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Running Liner. Review Running Tally and Procedure. Page 23 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 15:30 5.25 0 2,430 COMPZ RPCOM RUNL P Start Running 5.5"Liner Assembly. PU&MU 5 1/2"Float Shoe, 1 jt of 5.5"15.5#L-80 BTCM,5 1/2"Float Collar, 1 jt of 5.5"BTCM liner and the Landing Collar Insert Assembly and Baker lock shoe track connection. Confirm floats can be pumped through. Installed HydroForm centralizer on shoe and collar joint and one for the first 10 joints.Avg Make-up torque for the first 10 joints was 5400 psi. PU Wt for first 10 joints was 46k 10 Jts Up Wt 46k/Dn 46k 20 Jts Up Wt 50k/Dn 50k 30 Jts Up Wt 56k/Dn 56k 40 Jts Up Wt 64k/Dn 60k 50 Jts Up Wt 70k/Dn 65k Installed a total of 31 HydroForm centralizer. 15:30 16:30 1.00 2,430 2,662 COMPZ RPCOM PULD P MU 7"BTCM x 5.5"BTCM X-over, liner packer assembly and C-2 Running Assembly. RIH with liner w/ 2 stands of DP and Circulate 60 bbls (Liner Volume)at 3 bpm, 180 psi. Up Wt 73k/Dn Wt 70k 16:30 21:30 5.00 2,662 7,267 COMPZ RPCOM RUNL P Continue to RIH with 5.5"Liner on 5" Drill Pipe. Shoe Track passed through the Whipstock with no problems. Stop and break circulation at 3.0 bpm/280 psi x 10 bbls. Continue running 5 1/2"Liner to bottom with no problems Tag TD at 7,273-ft. ,Make up Cementing Head and space out with the Shoe at 7,267-ft. (Note: Landing Collar at 7,180-ft,Top of Window at 5,014-ft, Top of Liner Hanger Packer at _ 4,801-ft, Liner Lap=213-ft.) 21:30 00:00 2.50 7,267 7,267 COMPZ RPCOM CIRC P Begin to circulate and condition the 11.0 lb/gal Mud. Reciprocate Pipe (20-ft).YP at start=35. Cementers arrive on Location. 02/17/2012 Finish Conditioning Mud. PJSM. RU Cementers.Cmt Liner per Program. Set Liner Top Packer.Circ out excess Cmt from above Liner Top Packer. LD 5"Drill Pipe. 00:00 03:00 3.00 7,267 7,267 COMPZ CEMEN-CIRC P Spot and rig up Cement Equipment. j Review cementing and displacement calculations and volumes with Cement Engineer. All good. Continue to circulate and condition 11.0 lb/gal Mud. Final YP 25 in/26 out. 03:00 03:30 0.50 7,267 7,267 COMPZ CEMEN-SFTY P PJSM/Ops Meeting with All Page 24 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 7,267 7,267 COMPZ CEMEN-CIRCP (Continue to circulate and reciprocate Pipe. Spot Vac Trucks. Walk Lines. 04:30 08:30 4.00 7,267 7,267 COMPZ CEMEN"CMNT T 'Begin Cement Job. Prime up. Pressure test Lines at 4,800 psi. Good. Start Chem Wash100 at 3.0 bpm/475 psi. End with 40 bbls pumped at 5.0 bpm/775 psi. Begin MUDPUSH II at 3.5 bpm/600 psi, 12.2 lb/gal density. End with 40 bbls pumped at 5.0 bpm/810 psi. Attempt to mix Cement. However, having a foaming problem(Note: No Cement went downhole) Blow line down with rig air back to mixer to prevent line freeze up. Suspend operations and allow Schlumberger to sort out problem and re-group. 08:30 09:00 0.50 7,267 7,267 COMPZ CEMENT SFTY T Foaming Problem Solved. Hold PJSM with SLB,Nordic,MI,Baker and ASRC. Discuss Hazard for Cement pumping operation. 09:00 10:45 1.75 7,267 7,267 COMPZ CEMEN-CMNT P Blow Air back to pumping to confirm lines are still clear. Start cement mixing process.Start Pumping Cement while slowly reciprocating,. avg pump rate 5 bpm,avg pressure 950 psi, pump a total of 140 bbls at, 15.8 ppg class G cement. Drop wiper plug and started displacement with 11.0 ppg drilling fluid at 5 bpm,310 psi,slow rate at 80 bbls away to 2 bpm, 90 psi and saw plug enter liner top at 84 bbls away, increase pump back to 5 bpm,625 psi, continue displacement,slow pump to 3.0 bpm /850 psi at 130 bbls away and stop reciprocating,saw plug bump at 139 bbls away, increase psi to 1,450 psi and hold for 1 minute. Increase pressure to 3,558 psi with a slack weight of 40k down and set liner packer. Bleed down pressure to zero and check floats for flow. (NO FLOW). 10:45 11:15 0.50 7,267 7,267 COMPZ CEMEN"RURD P Release Setting tool from liner. Rotate 12 turns to the right, pressure up drill pipe to 980 psi, PU and slowly PU and release setting tool from liner and seen good pressure .drop. Packer set with 55,000 lbs. Page 25 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 13:45 2.50 7,267 7,267 COMPZ CEMEN-CIRCP Start Pumping 11.0 ppg drilling fluid at 10 bpm, 355 psi to circulate hole clean and watch for cement volume circulated from wellbore. Note: No cement observed or circulated from well. CBU x 3. Observe well for flow. Well is static. 13:45 15:30 1.75 7,267 7,267 COMPZ CEMEN'PULD P PJSM. Un-load MWD&LWD Tools and Equipment from Pipe Shed to have shipped out and make room to L/D drill pipe. RD Cement Head 15:30 16:15 0.75 COMPZ CEMEN'CIRC P Circulate Dry Job at 3 bpm,230 psi down Drill Pipe. 16:15 22:15 6.00 COMPZ CEMEN'PULD P TOOH laying down 5"Drill Pipe from4731-ft Up Weight=130K. 22:15 22:45 0.50 COMPZ CEMEN'PULD P Break out and lay down Baker Setting Tool(complete). 22:45 00:00 1.25 COMPZ CEMEN'TRIP P Trip in with the remaining 5"Drill Pipe from the Derrick to 2,757-ft. 02/18/2012 Finish LD 5"Drill Pipe. Load,drift,and tally 3 1/2"Completion. RU E-Line. Run GR/JB. Run and set Completion Packer. RD E-Line. Prep to run the 3 1112"Completion. 00:00 04:00 4.00 7,267 7,267 COMPZ CEMEN"PULD P Single down 5"Drill Pipe from 2,757-ft in Pipe shed. Kick out Drill Pipe. Pull Wear Bushing. Wash BOP Stack. Blow down Top Drive. Clear and clean Rig Floor. 04:00 14:00 10.00 COMPZ RPCOM PUTB P Load 3 1/2"Tubing. Drift and tally same. Load Completion Jewely. Page 26 of 30 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 14:00 00:00 10.00 COMPZ RPCOM ELOG P PJSM. MIRU E-Line Unit and load equipment. Pick-up a 4.755"Gauge Ring/Junk Basket, GR/CCL. RIH to the top of the Baker ZXP Liner Packer at 4,801-ft. Had to work several times to get tool string to fall through. Continue on down inside the 5 1/2"Liner to 6,900-ft with no problems. Log Well and record Gamma Ray and Liner Collars. Top of the C-Sand at 6,838-ft. POOH. Pick up the Baker 45-FA-36 Production Packer and Tailpipe Assembly(verify the HES 2.813" X-Nipple). Run in hole to the top of the ZXP Liner Packer. Once again had to try several times to fall through. Continue on down to 6,875-ft with no problems. Log up and record a tie-in pass(make a +22-ft correction). repeat tie-in pass. Good. Log Packer into place as follows: C-Sand at 6,838-ft elmd,WLEG at 6,788-ft elmd, Packer center element at 6,749.5 elmd(9-ft above the 5 1/2" Liner collar at 6,758-ft), Center of the CCL at 6,734.0-ft. Fire Setting Tool. Good. Log off. POOH. Lay down tool string. Rig down and release E-Line Unit. 02/19/2012 ,,.- Single in with the 3 1/2"Completion. Displace Wellbore over to 10.6 lb/gal Brine. Space-out and land 1-9,, Completion.Test the Tubing at 37500 psi.Test the Annulus at 3,500 psi. 00:00 07:00 7.00 0 4,964 COMPZ RPCOM PUTB P Perform final jewelry inspection and /1_t,G proper running order. Single in with the 3 1/2"Completion as designed. 07:00 12:00 5.00 4,964 6,696 COMPZ RPCOM PUTB P Stop and MU 3 1/2" TRAMAXX-CMT-5-S R-SCSS V. Function tested SCSSV and pressure tested to 6,000 psi for 15 mins. Continue to RIH with 3.5" Completion while Maintaining SCSSV in open postion and securing control line with SS Bands. 12:00 12:30 0.50 6,696 6,696 COMPZ RPCOM SFTY P Hold PJSM and discuss hazard for Pumping Operation with Nordic,Baker,Camco, MI and ASRC trucking crew. 12:30 16:00 3.50 6,696 6,696 COMPZ RPCOM CIRC P Starting Pumping Operation. Pumping Schedule as followed, 30 bbls of Un-inhibited brine,25 bbls of Hi-Vis Spacer pill, 150 bbls of Un-inhibited brine,380 bbls of Inhibited brine follow with 10 bbls of Un-inhibited brine to flush surface line. Pump Rate 5.5 bpm,1150 psi. Page 27 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:00 17:45 1.75 6,696 6,748 COMPZ RPCOM PUTB P Continue to lower completion string and saw the anchor seals enter seal bore and fully located at 6,748-ft. Pressure up seal to 500 psi for confirmation the seals are in place,good test. Pulled 40k over and shear the pins. 17:45 19:45 2.00 6,748 6,788 COMPZ RPCOM PUTB P Make up space out pups to make sure we are 6 feet above fully located position. Make up tubing hanger and secure control line to hanger assembly. A total of 60 SS BAnds were used to install the SSSV Control Line. Land Tubing Hanger. RILDS. 19:45 00:00 4.25 6,788 6,788 COMPZ RPCOM PRTS P PJSM. Rig up test equipment. Pressure test the 3 1/2"Tubing at 3,500 psi x 30 minutes. Good. Bleed Tubing pressure down to 2,000 psi and block in. Pressure up on the 3 1/2"x 5 1/2"/9 5/8" Annulus to 3,500 psi x 30 minutes. Good. Bleed the Annulus down to 0 psi. Bleed the Tubing down to 0 psi. Ramp pressure up on the Annulus to 2650 psi. Saw a weak indication that the DCK Valve had sheared. Have slight communications in both directions. However, unable to establish any circulation rate in either direction after several attempts. Call out S-Line Unit to pull the Valve. 02/20/2012 Rig up S-Line to pull the partially sheared DCK SV. Rig down S-Line Unit. Install TWCV. Nipple Down BOPE. 00:00 03:00 3.00 6,788 6,788 COMPZ RPCOM SLKL T Wake-up S-Line Crew. S-Line Unit arrived on Location. Spot Unit. Bring equipment to Rig Floor. 03:00 06:30 3.50 6,788 6,788 COMPZ RPCOM SLKL T PJSM. Rig up S-Line Equipment. RIH with a 2.780"Gauge Ring. Tagged some kind of debris at 6,090-ft. Work and push debris down to 6,696-ft 64 feet below Camco SOV. POOH and Standback SLick-line. 06:30 07:30 1.00 COMPZ RPCOM CIRC T Rig up Pumping Iron,started pumping at 2 bpm,2100 psi/2.5 bpm,2700 psi, lower rate 1.0 bpm, 1400 psi and slowly increase to 2050 psi.Shut down pump and discuss opinion with town engineer. Page 28 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 13:30 6.00 COMPZ RPCOM SLKL T PJSM with New SLick-line crew. Rig back pumping iron and rig up slick-line to pull shear out sub. CHANGE OUT W/759 CREW, JSSM W/RIG CREW.TBG PSI UP TO 2050#. CONFER W/NSK FIELD REP,CO REP. RIH W/2.76"SWAGE,5'X 2.5"DD BLR TO SD @ 6635'SLM,WORK TO 6677'SLM, POOH W/ 1/4 BLR OF MUD. CONFER W/CO REP. NEW TS=6',KJ,OJ,KJ,LSS(26.2' V OAL) RIH W/3"GS, 3"SS CATCHER, SD @ 6088'SLM,WORK BY, CRIH TO SD @ 6635'SLM,WORK DOWN TO 6643'SLM, SS SHEARED,SET CATCHER, POOH. RIH W/3"OK-1 AND 1.25"JD, SD @ 5400'SLM(5399' RKB), PULL BIND, LIGHT OJ LICK, POOH W/ DV.CONFER W/CO REP,CIRC OUT FROM HERE OK. RIH W/3"GR TO PULL CATCHER SUB @ 6643'SLM. RDMO SICK-LINE. 13:30 13:45 0.25 COMPZ RPCOM PULD P Pull and LID landing Joint. Install 2-way check into hanger. 13:45 14:15 0.50 COMPZ RPCOM PRTS P RU Testing Iron and PT 2-way check to 2500 psi and hold for 5 mins. Bleed down pressure to zero. 14:15 21:00 6.75 COMPZ RPCOM RURD P PJSM.Clean and Flush BOP Stack. Open Ram Gates and clean cavities. Install 2 3/8"Pipe Rams(solids). The lower Pipe Rams remain 5 1/2"x 2 7/8"VBRs. 21:00 00:00 3.00 COMPZ RPCOM NUND P Nipple down BOP Stack and set back on Stump. Nipple down the DSA Spool. Continue to clean Mud Plts. 02/21/2012 Nipple up Production Tree and test at 5,000 psi. Pull the TWCV. Rig up Lil' Red Services and Freeze Protect the Well. Install BPV. Secure Cellar. Release Rig. Page 29 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 COMPZ RPCOM NUND P Continue to nipple up Adaptor Flange and Production Tree. Test Adaptor void at 5,000 psi x 15 minutes. Good. Test Tree at 5,000 psi x 15 minutes. Good Record Tree test on chart. MIRU RU LRS and Freeze protected TBG x IA with 160 bbls of Freeze protect diesel at 2 bpm,480 psi., and allow to equalize. RDMO LRS. RU and SET BPV.Well Secure, RDMO Nordic Rig 3. Rig release at 12:00 Noon. Page 30 of 30 .-� 1 11 ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-05A 500292047901 Sperry Drilling Definitive Survey Report k 23 February, 2012 i ..... r C __ mm - mom mow HALLIBURTON Am Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-05 Project: Kuparuk River Unit TVD Reference: 1 E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Well: 1E-05 North Reference: True Wellbore: 1E-05A Survey Calculation Method: Minimum Curvature Design: 1E-05A Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1E-05 Well Position +N/-S 0.00 ft Northing: 5,960,237.32 ft Latitude: 70°18'7.714 N +E/-W 0.00 ft Easting: 549,890.40 ft Longitude: 149°35'45.239 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 69.50 ft Wellbore 1E-05A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 1/31/2012 20.77 80.92 57,637 Design 1 E-05A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,995.60 i Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 31.60 0.00 0.00 49.44 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 45.60 4,995.60 1 E-05 GyroData_9.625 casing(1E-05) GYD-CT-CMS Gyrodata cont.casing m/s 2/2/2012 12:0C 5,014.74 7,229.25 1 E-05A MWD(R200)(1E-05A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/12/2012 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 31.60 0.00 0.00 31.60 -69.50 0.00 0.00 5,960,237.32 549,890.40 0.00 0.00 UNDEFINED 45.60 0.86 359.85 45.60 -55.50 0.11 0.00 5,960,237.42 549,890.40 6.14 0.07 GYD-CT-CMS(1) 70.60 0.82 2.86 70.60 -30.50 0.47 0.01 5,960,237.79 549,890.41 0.24 0.31 GYD-CT-CMS(1) 95.60 0.40 11.99 95.60 -5.50 0.74 0.04 5,960,238.05 549,890.43 1.72 0.50 GYD-CT-CMS(1) 120.60 0.38 0.26 120.59 19.49 0.90 0.05 5,960,238.22 549,890.45 0.33 0.63 GYD-CT-CMS(1) 145.60 0.32 7.02 145.59 44.49 1.06 0.06 5,960,238.38 549,890.46 0.29 0.73 GYD-CT-CMS(1) 170.60 0.27 39.11 170.59 69.49 1.17 0.11 5,960,238.49 549,890.50 0.68 0.84 GYD-CT-CMS(1) 195.60 0.38 82.07 195.59 94.49 1.23 0.23 5,960,238.55 549,890.62 1.04 0.97 GYD-CT-CMS(1) 220.60 0.38 81.94 220.59 119.49 1.25 0.39 5,960,238.57 549,890.78 0.00 1.11 GYD-CT-CMS(1) 245.60 0.27 33.25 245.59 144.49 1.31 0.51 5,960,238.63 549,890.90 1.14 1.24 GYD-CT-CMS(1) 270.60 0.11 20.24 270.59 169.49 1.38 0.55 5,960,238.71 549,890.94 0.66 1.32 GYD-CT-CMS(1) 295.60 0.25 12.62 295.59 194.49 1.46 0.57 5,960,238.78 549,890.96 0.57 1.38 GYD-CT-CMS(1) 320.60 0.26 40.88 320.59 219.49 1.56 0.62 5,960,238.88 549,891.01 0.50 1.48 GYD-CT-CMS(1) 2/23/2012 8:48:34AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Well: 1 E-05 North Reference: True Wellbore: 1 E-05A Survey Calculation Method: Minimum Curvature Design: 1E-05A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 345.60 0.27 79.18 345.59 244.49 1.61 0.71 5,960,238.93 549,891.10 0.70 1.59 GYD-CT-CMS(1) 370.60 0.23 118.55 370.59 269.49 1.60 0.81 5,960,238.92 549,891.20 0.69 1.66 GYD-CT-CMS(1) 395.60 0.15 179.99 395.59 294.49 1.54 0.86 5,960,238.86 549,891.25 0.82 1.65 GYD-CT-CMS(1) 420.60 0.17 321.32 420.59 319.49 1.54 0.83 5,960,238.86 549,891.22 1.21 1.63 GYD-CT-CMS(1) 445.60 0.24 0.27 445.59 344.49 1.62 0.81 5,960,238.94 549,891.20 0.61 1.67 GYD-CT-CMS(1) 470.60 0.30 42.47 470.59 369.49 1.72 0.86 5,960,239.04 549,891.24 0.81 1.77 GYD-CT-CMS(1) 495.60 0.62 56.86 495.59 394.49 1.84 1.01 5,960,239.17 549,891.40 1.35 1.97 GYD-CT-CMS(1) 520.60 1.51 59.01 520.59 419.49 2.08 1.41 5,960,239.41 549,891.79 3.56 2.42 GYD-CT-CMS(1) 545.60 2.52 57.14 545.57 444.47 2.55 2.15 5,960,239.88 549,892.54 4.05 3.29 GYD-CT-CMS(1) 570.60 3.43 56.54 570.54 469.44 3.26 3.24 5,960,240.60 549,893.62 3.64 4.58 GYD-CT-CMS(1) 595.60 4.25 57.53 595.48 494.38 4.17 4.64 5,960,241.52 549,895.02 3.29 6.24 GYD-CT-CMS(1) 620.60 4.85 57.99 620.40 519.30 5.23 6.32 5,960,242.59 549,896.69 2.40 8.20 GYD-CT-CMS(1) 645.60 5.40 57.68 645.30 544.20 6.42 8.21 5,960,243.79 549,898.57 2.20 10.41 GYD-CT-CMS(1) 670.60 6.09 56.82 670.18 569.08 7.77 10.32 5,960,245.16 549,900.66 2.78 12.89 GYD-CT-CMS(1) 695.60 7.28 55.33 695.00 593.90 9.40 12.73 5,960,246.80 549,903.06 4.81 15.78 GYD-CT-CMS(1) 720.60 8.50 55.19 719.77 618.67 11.36 15.55 5,960,248.78 549,905.87 4.88 19.20 GYD-CT-CMS(1) 745.60 9.47 54.38 744.46 643.36 13.61 18.74 5,960,251.05 549,909.04 3.91 23.08 GYD-CT-CMS(1) 770.60 10.51 55.32 769.08 667.98 16.10 22.28 5,960,253.57 549,912.57 4.21 27.40 GYD-CT-CMS(1) 795.60 11.41 57.51 793.63 692.53 18.73 26.24 5,960,256.22 549,916.52 3.97 32.12 GYD-CT-CMS(1) 820.60 12.34 60.62 818.09 716.99 21.37 30.66 5,960,258.89 549,920.91 4.51 37.19 GYD-CT-CMS(1) 845.60 13.27 64.77 842.47 741.37 23.90 35.58 5,960,261.45 549,925.82 5.23 42.58 GYD-CT-CMS(1) 870.60 14.28 66.46 866.75 765.65 26.36 41.00 5,960,263.95 549,931.23 4.35 48.29 GYD-CT-CMS(1) 895.60 15.05 67.13 890.93 789.83 28.85 46.82 5,960,266.48 549,937.03 3.15 54.33 GYD-CT-CMS(1) ' 920.60 15.88 67.03 915.03 813.93 31.45 52.96 5,960,269.11 549,943.15 3.32 60.68 GYD-CT-CMS(1) 945.60 16.24 67.10 939.05 837.95 34.14 59.33 5,960,271.85 549,949.50 1.44 67.28 GYD-CT-CMS(1) 970.60 17.43 66.85 962.98 861.88 36.97 65.99 5,960,274.73 549,956.14 4.77 74.18 GYD-CT-CMS(1) 995.60 18.41 66.27 986.77 885.67 40.03 73.05 5,960,277.83 549,963.18 3.98 81.53 GYD-CT-CMS(1) 1,020.60 19.43 66.98 1,010.42 909.32 43.25 80.49 5,960,281.10 549,970.60 4.18 89.28 GYD-CT-CMS(1) 1,045.60 20.65 67.20 1,033.90 932.80 46.58 88.38 5,960,284.48 549,978.46 4.89 97.44 GYD-CT-CMS(1) 1,070.60 21.48 66.93 1,057.23 956.13 50.09 96.66 5,960,288.04 549,986.72 3.34 106.00 GYD-CT-CMS(1) 1,095.60 22.01 65.83 1,080.45 979.35 53.80 105.14 5,960,291.81 549,995.17 2.67 114.86 GYD-CT-CMS(1) 1,120.60 22.95 65.29 1,103.55 1,002.45 57.75 113.85 5,960,295.82 550,003.85 3.85 124.05 GYD-CT-CMS(1) 1,145.60 23.39 64.53 1,126.54 1,025.44 61.92 122.75 5,960,300.05 550,012.73 2.13 133.53 GYD-CT-CMS(1) 1,170.60 23.76 64.68 1,149.45 1,048.35 66.21 131.79 5,960,304.40 550,021.73 1.50 143.18 GYD-CT-CMS(1) 1,195.60 24.20 64.75 1,172.29 1,071.19 70.55 140.97 5,960,308.80 550,030.89 1.76 152.98 GYD-CT-CMS(1) 1,220.60 24.48 65.15 1,195.07 1,093.97 74.91 150.31 5,960,313.22 550,040.19 1.30 162.91 GYD-CT-CMS(1) 1,245.60 25.09 65.24 1,217.77 1,116.67 79.31 159.82 5,960,317.68 550,049.68 2.44 173.00 GYD-CT-CMS(1) 1,270.60 25.33 65.32 1,240.39 1,139.29 83.76 169.49 5,960,322.20 550,059.32 0.97 183.24 GYD-CT-CMS(1) 1,295.60 25.73 65.63 1,262.95 1,161.85 88.24 179.30 5,960,326.74 550,069.09 1.69 193.60 GYD-CT-CMS(1) 1,320.60 26.15 65.55 1,285.43 1,184.33 92.76 189.25 5,960,331.32 550,079.02 1.69 204.10 GYD-CT-CMS(1) 2/23/2012 8:48:34AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad MD Reference:'' 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Well: 1 E-05 North Reference: True Wellbore: 1 E-05A Survey Calculation Method: Minimum Curvature Design: 1E-05A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,345.60 26.51 65.02 1,307.83 1,206.73 97.39 199.33 5,960,336.02 550,089.06 1.72 214.77 GYD-CT-CMS(1) 1,370.60 26.66 64.47 1,330.19 1,229.09 102.17 209.45 5,960,340.86 550,099.14 1.15 225.56 GYD-CT-CMS(1) 1,395.60 26.64 62.78 1,352.53 1,251.43 107.15 219.49 5,960,345.91 550,109.15 3.03 236.43 GYD-CT-CMS(1) 1,420.60 26.41 61.56 1,374.90 1,273.80 112.36 229.36 5,960,351.19 550,118.99 2.37 247.32 GYD-CT-CMS(1) 1,445.60 26.50 60.41 1,397.29 1,296.19 117.76 239.10 5,960,356.65 550,128.69 2.08 258.23 GYD-CT-CMS(1) 1,470.60 26.75 60.05 1,419.63 1,318.53 123.32 248.83 5,960,362.28 550,138.38 1.19 269.24 GYD-CT-CMS(1) 1,495.60 26.76 59.94 1,441.96 1,340.86 128.95 258.57 5,960,367.97 550,148.09 0.20 280.30 GYD-CT-CMS(1) 1,520.60 27.20 59.52 1,464.24 1,363.14 134.67 268.37 5,960,373.75 550,157.84 1.92 291.46 GYD-CT-CMS(1) 1,545.60 27.69 59.62 1,486.42 1,385.32 140.50 278.31 5,960,379.65 550,167.74 1.97 302.80 GYD-CT-CMS(1) 1,570.60 27.94 59.43 1,508.53 1,407.43 146.42 288.36 5,960,385.64 550,177.75 1.06 314.29 GYD-CT-CMS(1) 1,595.60 28.45 59.07 1,530.57 1,429.47 152.46 298.51 5,960,391.74 550,187.86 2.15 325.93 GYD-CT-CMS(1) 1,620.60 28.85 58.68 1,552.51 1,451.41 158.66 308.77 5,960,398.01 550,198.08 1.77 337.75 GYD-CT-CMS(1) 1,645.60 29.40 58.51 1,574.35 1,473.25 165.00 319.16 5,960,404.42 550,208.42 2.22 349.77 GYD-CT-CMS(1) 1,670.60 30.05 58.67 1,596.06 1,494.96 171.46 329.74 5,960,410.95 550,218.96 2.62 362.00 GYD-CT-CMS(1) 1,695.60 30.40 58.50 1,617.66 1,516.56 178.02 340.48 5,960,417.58 550,229.65 1.44 374.43 GYD-CT-CMS(1) 1,720.60 31.02 58.40 1,639.15 1,538.05 184.70 351.36 5,960,424.33 550,240.49 2.49 387.04 GYD-CT-CMS(1) 1,745.60 31.61 58.15 1,660.51 1,559.41 191.53 362.41 5,960,431.23 550,251.49 2.42 399.88 GYD-CT-CMS(1) 1,770.60 32.20 57.66 1,681.73 1,580.63 198.55 373.60 5,960,438.33 550,262.64 2.58 412.95 GYD-CT-CMS(1) 1,795.60 33.01 57.46 1,702.79 1,601.69 205.78 384.97 5,960,445.63 550,273.96 3.27 426.28 GYD-CT-CMS(1) 1,820.60 33.30 56.94 1,723.72 1,622.62 213.18 396.46 5,960,453.11 550,285.40 1.62 439.83 GYD-CT-CMS(1) 1,845.60 33.77 56.43 1,744.56 1,643.46 220.77 408.00 5,960,460.77 550,296.89 2.19 453.53 GYD-CT-CMS(1) 1,870.60 34.20 56.75 1,765.29 1,664.19 228.46 419.67 5,960,468.54 550,308.50 1.86 467.40 GYD-CT-CMS(1) 1,895.60 34.51 56.94 1,785.93 1,684.83 236.18 431.48 5,960,476.34 550,320.26 1.31 481.39 GYD-CT-CMS(1) 1,920.60 34.89 57.25 1,806.48 1,705.38 243.91 443.43 5,960,484.15 550,332.16 1.68 495.49 GYD-CT-CMS(1) 1,945.60 35.37 57.49 1,826.93 1,725.83 251.67 455.54 5,960,491.98 550,344.22 2.00 509.74 GYD-CT-CMS(1) 1,970.60 35.53 57.72 1,847.30 1,746.20 259.44 467.79 5,960,499.83 550,356.41 0.83 524.09 GYD-CT-CMS(1) 1,995.60 35.81 57.70 1,867.60 1,766.50 267.22 480.11 5,960,507.70 550,368.68 1.12 538.52 GYD-CT-CMS(1) 2,020.60 35.79 58.05 1,887.88 1,786.78 275.00 492.49 5,960,515.56 550,381.01 0.82 552.99 GYD-CT-CMS(1) 2,045.60 35.82 57.95 1,908.16 1,807.06 282.75 504.90 5,960,523.39 550,393.36 0.26 567.45 GYD-CT-CMS(1) 2,070.60 35.71 58.21 1,928.44 1,827.34 290.48 517.30 5,960,531.20 550,405.71 0.75 581.90 GYD-CT-CMS(1) 2,095.60 35.76 58.28 1,948.74 1,847.64 298.16 529.72 5,960,538.96 550,418.07 0.26 596.32 GYD-CT-CMS(1) 2,120.60 35.69 58.38 1,969.03 1,867.93 305.82 542.14 5,960,546.71 550,430.44 0.36 610.75 GYD-CT-CMS(1) 2,145.60 35.59 58.45 1,989.35 1,888.25 313.45 554.55 5,960,554.42 550,442.80 0.43 625.14 GYD-CT-CMS(1) 2,170.60 35.39 58.42 2,009.70 1,908.60 321.05 566.92 5,960,562.10 550,455.12 0.80 639.47 GYD-CT-CMS(1) 2,195.60 35.37 58.39 2,030.09 1,928.99 328.64 579.24 5,960,569.76 550,467.39 0.11 653.77 GYD-CT-CMS(1) 2,220.60 35.38 58.54 2,050.47 1,949.37 336.21 591.58 5,960,577.41 550,479.68 0.35 668.06 GYD-CT-CMS(1) 2,245.60 35.49 58.25 2,070.84 1,969.74 343.80 603.92 5,960,585.09 550,491.97 0.80 682.38 GYD-CT-CMS(1) 2,270.60 35.49 58.39 2,091.20 1,990.10 351.42 616.28 5,960,592.79 550,504.27 0.33 696.72 GYD-CT-CMS(1) 2,295.60 35.41 58.58 2,111.56 2,010.46 359.00 628.64 5,960,600.45 550,516.58 0.54 711.04 GYD-CT-CMS(1) 2,320.60 35.35 58.70 2,131.95 2,030.85 366.54 641.00 5,960,608.07 550,528.89 0.37 725.33 GYD-CT-CMS(1) 2/23/2012 8:48:34AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Well• " 1 E-05 North Reference: True Wellbore: 1 E-05A Survey Calculation Method: Minimum Curvature Design: 1 E-05A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 2,345.60 35.46 58.68 2,152.32 2,051.22 374.06 653.37 5,960,615.68 550,541.21 0.44 739.63 GYD-CT-CMS(1) 2,370.60 35.48 58.78 2,172.68 2,071.58 381.59 665.77 5,960,623.29 550,553.56 0.25 753.94 GYD-CT-CMS(1) 2,395.60 35.41 58.78 2,193.05 2,091.95 389.11 678.17 5,960,630.88 550,565.91 0.28 768.25 GYD-CT-CMS(1) 2,420.60 35.33 58.84 2,213.44 2,112.34 396.60 690.55 5,960,638.46 550,578.23 0.35 782.53 GYD-CT-CMS(1) 2,445.60 35.23 58.77 2,233.84 2,132.74 404.08 702.90 5,960,646.02 550,590.53 0.43 796.77 GYD-CT-CMS(1) 2,470.60 35.29 58.95 2,254.26 2,153.16 411.54 715.25 5,960,653.56 550,602.84 0.48 811.01 GYD-CT-CMS(1) 2,495.60 35.30 59.03 2,274.66 2,173.56 418.99 727.63 5,960,661.09 550,615.17 0.19 825.26 GYD-CT-CMS(1) 2,520.60 35.65 59.34 2,295.02 2,193.92 426.42 740.09 5,960,668.60 550,627.58 1.57 839.56 GYD-CT-CMS(1) 2,545.60 35.85 59.70 2,315.31 2,214.21 433.83 752.68 5,960,676.09 550,640.11 1.16 853.94 GYD-CT-CMS(1) 2,570.60 35.55 59.84 2,335.61 2,234.51 441.17 765.29 5,960,683.52 550,652.67 1.24 868.29 GYD-CT-CMS(1) 2,595.60 35.66 60.10 2,355.94 2,254.84 448.46 777.89 5,960,690.89 550,665.22 0.75 882.60 GYD-CT-CMS(1) 2,620.60 35.72 60.23 2,376.24 2,275.14 455.71 790.54 5,960,698.23 550,677.82 0.39 896.93 GYD-CT-CMS(1) 2,645.60 35.69 60.39 2,396.54 2,295.44 462.94 803.21 5,960,705.54 550,690.45 0.39 911.26 GYD-CT-CMS(1) 2,670.60 35.95 60.51 2,416.82 2,315.72 470.15 815.94 5,960,712.83 550,703.12 1.08 925.62 GYD-CT-CMS(1) 2,695.60 36.26 60.54 2,437.01 2,335.91 477.40 828.77 5,960,720.17 550,715.90 1.24 940.08 GYD-CT-CMS(1) 2,720.60 36.61 60.48 2,457.13 2,356.03 484.71 841.69 5,960,727.56 550,728.77 1.41 954.65 GYD-CT-CMS(1) 2,745.60 36.64 60.48 2,477.19 2,376.09 492.06 854.67 5,960,735.00 550,741.70 0.12 969.29 GYD-CT-CMS(1) 2,770.60 36.75 60.45 2,497.24 2,396.14 499.42 867.67 5,960,742.45 550,754.65 0.45 983.95 GYD-CT-CMS(1) 2,795.60 36.71 60.23 2,517.27 2,416.17 506.82 880.66 5,960,749.93 550,767.59 0.55 998.63 GYD-CT-CMS(1) 2,820.60 36.66 60.23 2,537.32 2,436.22 514.24 893.62 5,960,757.43 550,780.50 0.20 1,013.30 GYD-CT-CMS(1) 2,845.60 36.68 60.08 2,557.37 2,456.27 521.67 906.57 5,960,764.95 550,793.40 0.37 1,027.97 GYD-CT-CMS(1) 2,870.60 36.76 60.01 2,577.41 2,476.31 529.13 919.52 5,960,772.49 550,806.30 0.36 1,042.67 GYD-CT-CMS(1) 2,895.60 36.78 59.97 2,597.44 2,496.34 536.62 932.48 5,960,780.06 550,819.21 0.12 1,057.38 GYD-CT-CMS(1) 2,920.60 36.63 59.89 2,617.48 2,516.38 544.10 945.41 5,960,787.64 550,832.09 0.63 1,072.07 GYD-CT-CMS(1) 2,945.60 36.71 59.77 2,637.53 2,536.43 551.61 958.32 5,960,795.22 550,844.95 0.43 1,086.76 GYD-CT-CMS(1) 2,970.60 36.72 59.67 2,657.58 2,556.48 559.14 971.23 5,960,802.85 550,857.80 0.24 1,101.46 GYD-CT-CMS(1) 2,995.60 36.88 59.56 2,677.59 2,576.49 566.72 984.15 5,960,810.50 550,870.67 0.69 1,116.20 GYD-CT-CMS(1) 3,020.60 36.91 59.52 2,697.59 2,596.49 574.33 997.09 5,960,818.20 550,883.55 0.15 1,130.98 GYD-CT-CMS(1) 3,045.60 36.79 59.56 2,717.59 2,616.49 581.93 1,010.01 5,960,825.88 550,896.43 0.49 1,145.74 GYD-CT-CMS(1) 3,070.60 36.72 59.46 2,737.62 2,636.52 589.52 1,022.90 5,960,833.56 550,909.26 0.37 1,160.47 GYD-CT-CMS(1) 3,095.60 36.73 59.34 2,757.66 2,656.56 597.13 1,035.77 5,960,841.25 550,922.08 0.29 1,175.20 GYD-CT-CMS(1) • 3,120.60 36.63 59.03 2,777.71 2,676.61 604.78 1,048.59 5,960,848.99 550,934.85 0.84 1,189.91 GYD-CT-CMS(1) 3,145.60 36.75 58.79 2,797.76 2,696.66 612.49 1,061.38 5,960,856.78 550,947.59 0.75 1,204.65 GYD-CT-CMS(1) 3,170.60 36.75 58.39 2,817.79 2,716.69 620.29 1,074.15 5,960,864.66 550,960.30 0.96 1,219.42 GYD-CT-CMS(1) 3,195.60 37.05 58.36 2,837.78 2,736.68 628.16 1,086.93 5,960,872.62 550,973.03 1.20 1,234.24 GYD-CT-CMS(1) 3,220.60 37.57 58.22 2,857.66 2,756.56 636.12 1,099.82 5,960,880.67 550,985.87 2.11 1,249.22 GYD-CT-CMS(1) 3,245.60 37.72 58.38 2,877.46 2,776.36 644.15 1,112.81 5,960,888.78 550,998.81 0.72 1,264.30 GYD-CT-CMS(1) 3,270.60 37.65 58.24 2,897.24 2,796.14 652.17 1,125.82 5,960,896.89 551,011.75 0.44 1,279.40 GYD-CT-CMS(1) 3,295.60 37.56 58.33 2,917.05 2,815.95 660.19 1,138.80 5,960,905.00 551,024.68 0.42 1,294.48 GYD-CT-CMS(1) 3,320.60 37.44 58.19 2,936.88 2,835.78 668.20 1,151.74 5,960,913.09 551,037.57 0.59 1,309.52 GYD-CT-CMS(1) 2/23/2012 8:48:34AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1 E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1 E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Well: 1 E-05 North Reference: True Wellbore: 1 E-05A Survey Calculation Method: Minimum Curvature Design: 1E-05A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,345.60 37.41 58.44 2,956.74 2,855.64 676.18 1,164.67 5,960,921.15 551,050.44 0.62 1,324.53 GYD-CT-CMS(1) 3,370.60 37.51 58.51 2,976.58 2,875.48 684.13 1,177.63 5,960,929.19 551,063.35 0.43 1,339.55 GYD-CT-CMS(1) 3,395.60 37.70 58.67 2,996.39 2,895.29 692.08 1,190.65 5,960,937.22 551,076.31 0.85 1,354.61 GYD-CT-CMS(1) 3,420.60 37.90 58.75 3,016.14 2,915.04 700.04 1,203.74 5,960,945.27 551,089.35 0.82 1,369.73 GYD-CT-CMS(1) 3,445.60 37.76 58.88 3,035.89 2,934.79 707.98 1,216.86 5,960,953.29 551,102.41 0.64 1,384.86 GYD-CT-CMS(1) 3,470.60 37.63 58.84 3,055.67 2,954.57 715.88 1,229.94 5,960,961.28 551,115.44 0.53 1,399.94 GYD-CT-CMS(1) 3,495.60 37.63 58.94 3,075.47 2,974.37 723.77 1,243.01 5,960,969.26 551,128.46 0.24 1,415.00 GYD-CT-CMS(1) 3,520.60 37.97 59.01 3,095.22 2,994.12 731.67 1,256.14 5,960,977.24 551,141.54 1.37 1,430.11 GYD-CT-CMS(1) 3,545.60 37.84 59.17 3,114.95 3,013.85 739.56 1,269.32 5,960,985.22 551,154.66 0.65 1,445.25 GYD-CT-CMS(1) 3,570.60 38.00 59.42 3,134.67 3,033.57 747.40 1,282.53 5,960,993.15 551,167.82 0.89 1,460.39 GYD-CT-CMS(1) 3,595.60 38.02 59.60 3,154.37 3,053.27 755.21 1,295.80 5,961,001.05 551,181.03 0.45 1,475.54 GYD-CT-CMS(1) 3,620.60 38.05 59.58 3,174.06 3,072.96 763.01 1,309.08 5,961,008.93 551,194.26 0.13 1,490.71 GYD-CT-CMS(1) 3,645.60 38.00 59.71 3,193.75 3,092.65 770.79 1,322.37 5,961,016.80 551,207.49 0.38 1,505.86 GYD-CT-CMS(1) 3,670.60 38.12 59.71 3,213.44 3,112.34 778.57 1,335.68 5,961,024.66 551,220.75 0.48 1,521.03 GYD-CT-CMS(1) 3,695.60 38.07 59.94 3,233.11 3,132.01 786.32 1,349.01 5,961,032.50 551,234.03 0.60 1,536.20 GYD-CT-CMS(1) 3,720.60 38.03 60.30 3,252.80 3,151.70 794.00 1,362.37 5,961,040.27 551,247.34 0.90 1,551.34 GYD-CT-CMS(1) 3,745.60 38.11 61.26 3,272.48 3,171.38 801.52 1,375.83 5,961,047.88 551,260.74 2.39 1,566.46 GYD-CT-CMS(1) 3,770.60 38.42 61.74 3,292.11 3,191.01 808.91 1,389.43 5,961,055.36 551,274.30 1.72 1,581.60 GYD-CT-CMS(1) 3,795.60 38.75 62.05 3,311.65 3,210.55 816.25 1,403.19 5,961,062.79 551,288.00 1.53 1,596.82 GYD-CT-CMS(1) 3,820.60 38.74 62.26 3,331.15 3,230.05 823.56 1,417.02 5,961,070.19 551,301.78 0.53 1,612.09 GYD-CT-CMS(1) 3,845.60 38.79 62.45 3,350.64 3,249.54 830.82 1,430.89 5,961,077.55 551,315.60 0.52 1,627.34 GYD-CT-CMS(1) 3,870.60 38.91 62.89 3,370.11 3,269.01 838.02 1,444.82 5,961,084.84 551,329.48 1.20 1,642.61 GYD-CT-CMS(1) 3,895.60 39.11 63.12 3,389.54 3,288.44 845.17 1,458.84 5,961,092.07 551,343.45 0.99 1,657.91 GYD-CT-CMS(1) 3,920.60 39.27 63.43 3,408.91 3,307.81 852.27 1,472.95 5,961,099.27 551,357.52 1.01 1,673.25 GYD-CT-CMS(1) 3,945.60 39.76 64.37 3,428.20 3,327.10 859.27 1,487.23 5,961,106.36 551,371.75 3.09 1,688.65 GYD-CT-CMS(1) 3,970.60 39.84 64.92 3,447.41 3,346.31 866.12 1,501.70 5,961,113.31 551,386.17 1.44 1,704.09 GYD-CT-CMS(1) 3,995.60 39.72 65.21 3,466.62 3,365.52 872.87 1,516.20 5,961,120.15 551,400.62 0.88 1,719.50 GYD-CT-CMS(1) 4,020.60 39.72 65.27 3,485.85 3,384.75 879.56 1,530.71 5,961,126.93 551,415.09 0.15 1,734.87 GYD-CT-CMS(1) 4,045.60 39.67 65.23 3,505.09 3,403.99 886.24 1,545.21 5,961,133.71 551,429.54 0.22 1,750.23 GYD-CT-CMS(1) 4,070.60 38.93 65.23 3,524.43 3,423.33 892.88 1,559.59 5,961,140.44 551,443.87 2.96 1,765.47 GYD-CT-CMS(1) 4,095.60 37.82 64.97 3,544.03 3,442.93 899.41 1,573.66 5,961,147.07 551,457.90 4.49 1,780.42 GYD-CT-CMS(1) 4,120.60 37.30 64.90 3,563.85 3,462.75 905.87 1,587.47 5,961,153.62 551,471.66 2.09 1,795.10 GYD-CT-CMS(1) 4,145.60 36.74 64.88 3,583.81 3,482.71 912.25 1,601.10 5,961,160.09 551,485.25 2.24 1,809.61 GYD-CT-CMS(1) 4,170.60 35.81 64.89 3,603.96 3,502.86 918.53 1,614.49 5,961,166.46 551,498.60 3.72 1,823.87 GYD-CT-CMS(1) 4,195.60 35.18 65.11 3,624.32 3,523.22 924.67 1,627.65 5,961,172.68 551,511.71 2.57 1,837.85 GYD-CT-CMS(1) 4,220.60 34.63 65.06 3,644.82 3,543.72 930.69 1,640.62 5,961,178.79 551,524.65 2.20 1,851.63 GYD-CT-CMS(1) 4,245.60 33.57 65.04 3,665.52 3,564.42 936.60 1,653.33 5,961,184.79 551,537.31 4.24 1,865.13 GYD-CT-CMS(1) 4,270.60 33.11 65.06 3,686.41 3,585.31 942.40 1,665.79 5,961,190.67 551,549.73 1.84 1,878.36 GYD-CT-CMS(1) 4,295.60 32.54 65.05 3,707.42 3,606.32 948.12 1,678.07 5,961,196.46 551,561.98 2.28 1,891.41 GYD-CT-CMS(1) 4,320.60 31.88 65.04 3,728.57 3,627.47 953.74 1,690.16 5,961,202.17 551,574.02 2.64 1,904.25 GYD-CT-CMS(1) 2/23/2012 8:48:34AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-05 Project: Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Well: 1 E-05 North Reference: True Wellbore: 1 E-05A Survey Calculation Method: Minimum Curvature Design: 1 E-05A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 4,345.60 31.03 64.86 3,749.89 3,648.79 959.26 1,701.97 5,961,207.77 551,585.80 3.42 1,916.82 GYD-CT-CMS(1) 4,370.60 30.26 64.78 3,771.40 3,670.30 964.68 1,713.51 5,961,213.26 551,597.30 3.08 1,929.10 GYD-CT-CMS(1) 4,395.60 29.83 64.77 3,793.04 3,691.94 970.02 1,724.83 5,961,218.67 551,608.58 1.72 1,941.18 GYD-CT-CMS(1) 4,420.60 29.07 64.31 3,814.81 3,713.71 975.30 1,735.93 5,961,224.03 551,619.65 3.17 1,953.04 GYD-CT-CMS(1) 4,445.60 28.53 64.45 3,836.72 3,735.62 980.51 1,746.79 5,961,229.31 551,630.47 2.18 1,964.68 GYD-CT-CMS(1) 4,470.60 28.11 64.51 3,858.73 3,757.63 985.62 1,757.49 5,961,234.49 551,641.14 1.68 1,976.13 GYD-CT-CMS(1) 4,495.60 27.72 64.29 3,880.82 3,779.72 990.68 1,768.04 5,961,239.62 551,651.66 1.61 1,987.44 GYD-CT-CMS(1) 4,520.60 27.16 64.24 3,903.01 3,801.91 995.68 1,778.42 5,961,244.69 551,662.00 2.24 1,998.58 GYD-CT-CMS(1) 4,545.60 26.66 64.42 3,925.30 3,824.20 1,000.58 1,788.62 5,961,249.65 551,672.16 2.03 2,009.51 GYD-CT-CMS(1) 4,570.60 26.19 64.61 3,947.69 3,846.59 1,005.37 1,798.66 5,961,254.51 551,682.17 1.91 2,020.26 GYD-CT-CMS(1) 4,595.60 25.57 64.78 3,970.18 3,869.08 1,010.03 1,808.53 5,961,259.24 551,692.01 2.50 2,030.78 GYD-CT-CMS(1) 4,620.60 25.21 64.97 3,992.76 3,891.66 1,014.58 1,818.23 5,961,263.85 551,701.68 1.48 2,041.12 GYD-CT-CMS(1) 4,645.60 24.70 65.15 4,015.43 3,914.33 1,019.03 1,827.80 5,961,268.36 551,711.21 2.06 2,051.28 GYD-CT-CMS(1) 4,670.60 24.26 65.32 4,038.18 3,937.08 1,023.37 1,837.20 5,961,272.77 551,720.59 1.78 2,061.24 GYD-CT-CMS(1) 4,695.60 23.76 65.66 4,061.02 3,959.92 1,027.59 1,846.46 5,961,277.05 551,729.82 2.08 2,071.02 GYD-CT-CMS(1) 4,720.60 23.14 66.12 4,083.96 3,982.86 1,031.65 1,855.54 5,961,281.17 551,738.87 2.59 2,080.56 GYD-CT-CMS(1) 4,745.60 22.77 66.49 4,106.98 4,005.88 1,035.57 1,864.47 5,961,285.15 551,747.77 1.59 2,089.89 GYD-CT-CMS(1) 4,770.60 22.28 66.79 4,130.07 4,028.97 1,039.37 1,873.26 5,961,289.00 551,756.54 2.01 2,099.04 GYD-CT-CMS(1) 4,795.60 21.80 67.04 4,153.24 4,052.14 1,043.05 1,881.89 5,961,292.74 551,765.14 1.96 2,107.99 GYD-CT-CMS(1) 4,820.60 21.17 67.33 4,176.50 4,075.40 1,046.60 1,890.33 5,961,296.35 551,773.56 2.56 2,116.71 GYD-CT-CMS(1) 4,845.60 20.79 67.84 4,199.85 4,098.75 1,050.01 1,898.60 5,961,299.81 551,781.81 1.69 2,125.22 GYD-CT-CMS(1) 4,870.60 20.49 67.90 4,223.24 4,122.14 1,053.33 1,906.77 5,961,303.19 551,789.95 1.20 2,133.58 GYD-CT-CMS(1) 4,895.60 20.12 68.52 4,246.69 4,145.59 1,056.55 1,914.82 5,961,306.46 551,797.98 1.71 2,141.79 GYD-CT-CMS(1) 4,920.60 19.73 68.40 4,270.19 4,169.09 1,059.68 1,922.75 5,961,309.64 551,805.88 1.57 2,149.85 GYD-CT-CMS(1) 4,945.60 19.41 68.55 4,293.75 4,192.65 1,062.75 1,930.54 5,961,312.76 551,813.65 1.30 2,157.76 GYD-CT-CMS(1) 4,970.60 19.03 68.44 4,317.35 4,216.25 1,065.77 1,938.19 5,961,315.83 551,821.29 1.53 2,165.54 GYD-CT-CMS(1) 4,995.60 18.57 68.73 4,341.02 4,239.92 1,068.71 1,945.70 5,961,318.82 551,828.77 1.88 2,173.15 GYD-CT-CMS(1) 5,014.74 18.20 69.27 4,359.18 4,258.08 1,070.88 1,951.33 5,961,321.02 551,834.39 2.13 2,178.84 MWD+IFR-AK-CAZ-SC(2) 5,031.74 17.89 69.15 4,375.35 4,274.25 1,072.75 1,956.25 5,961,322.93 551,839.30 1.84 2,183.80 MWD+IFR-AK-CAZ-SC(2) 5,078.77 17.37 68.80 4,420.17 4,319.07 1,077.86 1,969.55 5,961,328.12 551,852.56 1.13 2,197.22 MWD+IFR-AK-CAZ-SC(2) 5,172.37 20.39 68.00 4,508.72 4,407.62 1,089.02 1,997.70 5,961,339.47 551,880.63 3.24 2,225.87 MWD+IFR-AK-CAZ-SC(2) 5,268.54 16.78 67.11 4,599.86 4,498.76 1,100.70 2,026.03 5,961,351.34 551,908.88 3.77 2,254.99 MWD+IFR-AK-CAZ-SC(2) 5,363.23 11.94 65.64 4,691.57 4,590.47 1,110.06 2,047.56 5,961,360.84 551,930.35 5.13 2,277.43 MWD+IFR-AK-CAZ-SC(2) 5,413.38 10.33 77.02 4,740.78 4,639.68 1,113.21 2,056.67 5,961,364.05 551,939.43 5.42 2,286.40 MWD+IFR-AK-CAZ-SC(2) 5,456.30 10.35 82.37 4,783.00 4,681.90 1,114.59 2,064.24 5,961,365.48 551,946.99 2.24 2,293.05 MWD+IFR-AK-CAZ-SC(2) 5,504.47 9.88 81.82 4,830.42 4,729.32 1,115.75 2,072.62 5,961,366.70 551,955.37 1.00 2,300.17 MWD+IFR-AK-CAZ-SC(2) 5,548.55 10.23 83.07 4,873.82 4,772.72 1,116.76 2,080.25 5,961,367.76 551,962.99 0.94 2,306.62 MWD+IFR-AK-CAZ-SC(2) 5,645.73 9.72 84.50 4,969.54 4,868.44 1,118.59 2,096.98 5,961,369.70 551,979.70 0.58 2,320.53 MWD+IFR-AK-CAZ-SC(2) 5,739.52 10.05 88.21 5,061.93 4,960.83 1,119.60 2,113.04 5,961,370.82 551,995.76 0.76 2,333.39 MWD+IFR-AK-CAZ-SC(2) 5,833.70 9.97 89.53 5,154.68 5,053.58 1,119.93 2,129.41 5,961,371.25 552,012.12 0.26 2,346.03 MWD+IFR-AK-CAZ-SC(2) 2/23/2012 8:48:34AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 1E-05 Project Kuparuk River Unit TVD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Site: Kuparuk 1E Pad MD Reference: 1E-05A @ 101.10ft(Nor3(69.5+31.6)) Well: 1E-05 North Reference: True Wellbore: 1E-05A Survey Calculation Method: Minimum Curvature Design: 1E-05A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,929.38 9.90 89.17 5,248.93 5,147.83 1,120.11 2,145.92 5,961,371.55 552,028.62 0.10 2,358.70 MWD+IFR-AK-CAZ-SC(2) 6,024.14 12.11 72.48 5,341.96 5,240.86 1,123.22 2,163.55 5,961,374.77 552,046.23 4.07 2,374.11 MWD+IFR-AK-CAZ-SC(2) 6,117.84 13.63 52.92 5,433.35 5,332.25 1,132.84 2,181.74 5,961,384.51 552,064.35 4.90 2,394.19 MWD+IFR-AK-CAZ-SC(2) 6,166.75 14.28 48.50 5,480.82 5,379.72 1,140.32 2,190.85 5,961,392.05 552,073.42 2.55 2,405.97 MWD+IFR-AK-CAZ-SC(2) 6,211.45 15.44 44.42 5,524.02 5,422.92 1,148.22 2,199.15 5,961,400.00 552,081.66 3.49 2,417.41 MWD+IFR-AK-CAZ-SC(2) 6,253.10 15.54 40.45 5,564.16 5,463.06 1,156.42 2,206.65 5,961,408.26 552,089.11 2.56 2,428.45 MWD+IFR-AK-CAZ-SC(2) 6,307.09 17.18 33.32 5,615.97 5,514.87 1,168.59 2,215.72 5,961,420.48 552,098.10 4.80 2,443.25 MWD+IFR-AK-CAZ-SC(2) 6,358.35 19.54 28.76 5,664.62 5,563.52 1,182.44 2,224.00 5,961,434.38 552,106.29 5.39 2,458.55 MWD+IFR-AK-CAZ-SC(2) 6,402.03 20.59 29.47 5,705.64 5,604.54 1,195.53 2,231.30 5,961,447.52 552,113.49 2.47 2,472.60 MWD+IFR-AK-CAZ-SC(2) 6,453.72 22.18 29.98 5,753.77 5,652.67 1,211.89 2,240.65 5,961,463.95 552,122.73 3.10 2,490.35 MWD+IFR-AK-CAZ-SC(2) 6,494.50 24.42 28.54 5,791.23 5,690.13 1,225.97 2,248.52 5,961,478.07 552,130.51 5.67 2,505.48 MWD+IFR-AK-CAZ-SC(2) 6,590.85 27.44 28.49 5,877.87 5,776.77 1,262.98 2,268.63 5,961,515.22 552,150.37 3.13 2,544.83 MWD+IFR-AK-CAZ-SC(2) 6,685.09 30.25 26.72 5,960.41 5,859.31 1,303.28 2,289.67 5,961,555.65 552,171.14 3.12 2,587.01 MWD+IFR-AK-CAZ-SC(2) 6,778.20 32.86 25.62 6,039.74 5,938.64 1,347.01 2,311.14 5,961,599.52 552,192.32 2.87 2,631.76 MWD+IFR-AK-CAZ-SC(2) 6,873.22 34.09 25.45 6,119.00 6,017.90 1,394.31 2,333.73 5,961,646.95 552,214.59 1.30 2,679.67 MWD+IFR-AK-CAZ-SC(2) 6,967.53 34.19 25.30 6,197.06 6,095.96 1,442.13 2,356.41 5,961,694.92 552,236.95 0.14 2,727.99 MWD+IFR-AK-CAZ-SC(2) 7,062.10 33.82 26.08 6,275.46 6,174.36 1,489.79 2,379.34 5,961,742.73 552,259.56 0.60 2,776.40 MWD+IFR-AK-CAZ-SC(2) 7,156.37 33.37 26.27 6,353.98 6,252.88 1,536.60 2,402.34 5,961,789.69 552,282.26 0.49 2,824.32 MWD+IFR-AK-CAZ-SC(2) 7,229.25 33.32 25.96 6,414.86 6,313.76 1,572.57 2,419.98 5,961,825.77 552,299.65 0.24 2,861.10 MWD+IFR-AK-CAZ-SC(2) 7,273.00 33.32 25.96 6,451.42 6,350.32 1,594.18 2,430.50 5,961,847.45 552,310.02 0.00 2,883.15 PROJECTED to TD 2/23/2012 8:48:34AM Page 8 COMPASS 2003.16 Build 69 Page 1of1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, February 03, 2012 9:47 AM To: 'Myers, Monty M' Subject: RE: BOP Test- Deadline Extension (PTD 211-156) Monty, A delay to do the full BOP test is granted until you have the new 9 5/8" casing packoff and tubing spool installed. Once you exit the window and are drilling you revert to a 2 week BOP cycle. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Myers, Monty M [mailto:Monty.M.Myers@conocophillips.com] Sent: Friday, February 03, 2012 9:08 AM To: Schwartz, Guy L(DOA) Cc: Nordic 3 Company Man; Guo, Haibin Subject: BOP Test- Deadline Extension Well Name: 1 E-05A API#: 50-029-20479-01-00 Guy, We are currently in the process of setting a retainer to do a squeeze on this well in preparation for milling a window. While working in cased hole we are on 7 day BOP test cycles. Our deadline to re-test our BOPE is Saturday, February 4th by midnight. After our squeeze work is complete we are going to have to nipple down to change out the 9-5/8" packoff and tubing head. There is a possibility that this work will be complete before it is time to re-test. If this work is not completed before the deadline we would like to ask for permission to extend our deadline out until after said work is complete. Otherwise we will have to perform 2 separate BOP test almost back to back. If this is okay with you, please reply to all on this email and let us know. Thank you for the help in this matter. Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell 9/1/901? ITF ALASKA SEAN PARNELL,GOVERNOR ALASKA OIL AND GirAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-05A ConocoPhillips Alaska, Inc. Permit No: 211-156 Surface Location: 653' FSL, 633' FEL, SEC. 16, Ti1 N, R 10E, UM Bottomhole Location: 2260' FSL, 1789' FWL, SEC. 15, T11N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. 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, / � % Daniel . Seamount, Jr. Chair DATED this C6 day of December, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska, Inc. Post Office Box 100360 y� Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 RECEIVED ECEIVE November 28,2011 DEC 0 5 2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Alaska Oil& Gas Cons.Commission Anchorage,Alaska 99501 AnCilOfiF Re: Application for Permit to Drill Rotary Sidetrack CTD Setup 1E-05A Producer Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a Permit to Drill/Sidetrack an onshore producer well from the lE pad for CTD setup. The expected spud date for this well is January 1st,2012 conducting operations with Rig Nordic 3. The 1E-05 wellbore will be temporarily abandoned per separate sundry with 22 bbls of cement squeeze into the perforations A and C sands from 7,014' to 6,766' MD and well as placed inside the 3-1/2"tubing from 6,650' to 6,566'MD. The proposed plan is to pull the un-cemented tubing and set a 9-5/8"retainer at 5,100' MD with a permanent whipstock on top at 5,000 MD/4,348' TVD. Next,an 8-1/2"window will be cut and 20' of new formation drilled. A formation integrity test will be performed to 16.0 ppg EMW,with a required minimum leak/-off of 12.5 ppg EMW. The open hole section will then be drilled with an 8-1/2"PDC bit to 7,257' MD/6,441' TVD. It will be lined from 7,257' MD to 4,800' MD with 5-1/2" 15.5#L-80 casing. A 3-1/2"tubing completion will be landed in packer at 6,750' MD. Nordic 3 will then rig down and move off for CTD to sidetrack in the A-sands. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Haibin Guo at 265-1487 or Chip Alvord at 265-6120. Sincerely, TT'' 1~ ogr Haibin Guo Drilling Engineer Application for Permit to Drill Document rip,' 1E-05A STATE OF ALASKA 4 ALASKA OIL AND GAS CONSERVATION COMMISSION ! PERMIT TO DRILL Alaska till , 20 AAC 25.005 41 fit WRVS la.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ . Service-Winj ❑ Single Zone 0 - 1 c.Specify if well i� r15 R7y1'f�►; Drill ❑ Re-drill❑✓ 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: U Blanket u Single Well 11.Well Name and Number: Gln ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 1E-05A ser- uv" 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:7257' . TVD: 6441' .. Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:653'FSL,633'FEL,Sec. 16,T11N,R10E,UM ADL 25651 ` Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2191'FSL, 1757'FWL,Sec. 15,T11N,R10E,UM 469 1/1/2012 Total Depth: 9.Acres in Property: 14.Distance to 2260'FSL, 1789'FWL,Sec. 15,T11N,R10E, UM 2560 Nearest Property: >1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 101 feet 15.Distance to Nearest Well Open Surface:x- 549890 - y- 5960237 • Zone- 4 GL Elevation above MSL: . 71 feet to Same Pool: 1 E-05,444'@ 6853' 16.Deviated wells: Kickoff depth: 5000 .ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25035) Maximum Hole Angle: 30° deg Downhole:3500 psig Surface:2868 psig , 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.5" 5.5" 15.5# L-80 BTCM 2457' 4800' 4160' 7257' 6441' 677 sx 15.8 ppg Class G 19 PRESENT WELL CONDITION SUMMARY (Tobe completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 7195 6514 7148 6467 7012 Casing Length Size Cement Volume MD TVD Conductor/Structural 63' 20" 300 sx Permafrost 95' 95' Surface 2385' 13.375" 2300 sx Fondu,275 sx 2417' 2213' Intermediate Permafrost Production 6694' 9.625" 620 sx Class G 6694' 6020' Liner 801' 7" 245 sx Class G 7200' 6526' Perforation Depth MD(ft): Perforation Depth TVD(ft): 6766'-6902',6976'-6994',7000'-7014' 6092'-6228',6302'-6320',6326'-6340' 20.Attachments: Property Plat❑ BOP Sketch❑✓ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements E 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Haibin Guo @ 265-1487 6 Printed Name G. Alvord Title Alaska Drilling Manager Signature 1 1..{.... ( Phon 265-612o Date / (Z4z J r Commission Use Only Permit to Drill API Number: , �/�7 \ Permit Approval See cover letter Number: 2_ I I I C6 50-08 Z( /{/ /7/ C 66 Date: 1 t ll, I t I for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed met ane,gas hydrates,or gas contained in shales: # 35ed pS.:. $vv ,/f7, Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [' Other: HLIo2S measures: Yes No ❑ Directional svy req'd: Yes Er No ❑ k Z� �s� Kh 4.1e.,. ��oe-i.....) / APPROVED BY THE COMMISSION IDATE: I�,.. ,COMMISSION ; `( Form 10-401 (R vised 7/2009) This permit is valid r:4 n �'a ;.f;pproval(20 AAC 25.005(9)) Ord in Duplicate r^ c, `Z_7-(( 4 i / I-i([I VI' 1E-05A SIDETRA. Arctic Pack Job done in0,1 Drillin 8/13/1980 '' e, 3 ,'/z„ 49 bbls cement 116 bbls diesel TRMAXX- ConocoPhillips CMT SCSSV No record of press.test 2.813"ID @ -: 1,910'MD/ 1,800'TVD n 13-3/8"72#N80 casing @ h2,416'MD/2,210'TVD 3-'/2"9.3#,L-80,EUE Tubing from+/- E) 4,750'MD Baker ZXP line packer @ KOP in 9-5/8"@ +/-4,800'MD a +7-5,000'MD/4,348'TVD (WP06) (WP06) GLM# TVD ft MD ft Valve Type Mandrel Type 1 2,500 2,771 Dummy 3-1/2"x 1-1/2" MMG ,:.., 2 3,800 4,399 Dummy 3-1/2"x 1-1/2" MMG a 3 4,750 5,417 Dummy 3-1/2"x 1" KBG-2-9 4 5,435 6,116 Dummy 3-1/2"x 1" KBG-2-9 5 5,935 6,672 SOV 3-1/2"x 1" KBG-2-9 mmoviaiiitoitiftim *SOV(annulus to tubing shear) F 4 mem gkimpkItA.,.. Cement retainer +/-5,100'MD - 3-'/z"9.3#,L-80,IBT-M Special Squeeze perf : : ` �; :' : ::-::z: a Clearance Tubing+/-4,800'-6,750'MD below retainer ......:•:•:•••••••, -: Tubing Cut @ �/ 4\, 5,246'MD NNBacker Production Packer A@+/-6,750'MD/5,995' 7"liner Seal TVD(WP06) Assembly10 , 6,399'MD 3 /Z„ HES"X"selective @ nipple w/2.813"ID @+/- 6,800'MD/6,045'TVD Packer @ ' (WP06) 6,587' Perfs @ .------: 0- E 6,766'-6,902' 3 '/2" WLEG @+/-6,8 MD/6,005'TVD,50' Packer @ -D above Kuparuk C sand. 6,923' (WP06) ' G ` , A 5-1/2" 15.5#BTCM A7,257'MD/6,441'TVD Perfs @ .:.:.:::':`:::::::: :::: 6,976'-6,994' :iii:: : : :.- Perfs @ `.::< :' 7,000'-7,014' .........in,:.. ............. ... ................. ................. ....... ........ 7"26#K-55 7,195'MD/6,514'TVD HB 11/28/11 KUP 1 E-05 ..--• illConocoPhi ' •1 Weil �Max Angle&MD TD KMune n.lt Status Incl(• MD(ftKB) Act Ban(Re)Alaska.Inc. ,-awca,V, 500292047900 KUPARUK RIVER UNIT ,. PRODUCING 40.00 4,000.00 7,200.0 Comment H25(ppm) Dab --AnnotationIEnd Date KB-God(R) Rig R.I.es.Deb ..• wet cove--1855.81a2689 1279 PM -SSSV:LOCKEDOUT 0 8/18/2008. Last WO: 10/26/1984 39.49 8/25/1980 Sdwrrtic-Acari Annotation Depth(NCB) End Dat. Annotation .- - Last Mod By End Dab Last Tag:SLM 7,009.0 2/15/2009 Rev Reason:GLV C/O triplwj 8/29/2009 Casing Strings Shing 00' String ID Set Depth Set Depth(TVD) String Wt String 7: ' Geeing Description (In) (In) Top(frKB) ROW) OMB) (lbs/ft) Grade Stang Top Thrd CONDUCTOR 20 18.940 39.5 95.0 95.0 94.00 14-40 CONDUCTOR, _ 95 SURFACE 13.38 12.190 0.0 2,416.0 2,209.9 72.00 N-80 PRODUCTION 9 5/8 8.525 0.0 6,694.0 6,013.1 47.00 L-80 SAFETY VLV, 1,881 .._ o LINER 7 6.151 6,399.0 7,195.0 6,513.7 26.00IK55 Tubing Strings GAS LIFT, String OD Shing ID Sot Depth sat Depth(TVD) String Wt I Shing 1.921 -- Tubing W Deaption On) (in) Top(BKS) PM) 011110) (199/f1) ) Grade String Top Thad TUBING 31/2 2.992 0.0 6,941.0 6,259.9 9.20.1-55 ABMOD Buttress uttress 2.416 Other in Hole(All JeWeiry:Tubing Run&Retrievable,Fish,etc.) _ Top Depth GAS LIFT, r_ (TVD) Top Ind 3,401 Top(BKB) (hKB) (1 Description Comment Run Dat. ID 1/n) 1,881 1,775.1 34.51 SAFETY VLV Cameo TRDP-1A-ENC(Locked Out on 4/21/89) Pulled 10/26/1984 2.813 WRDP on 12/28/94 GAS LIFT, 4297 - 1,921 1,807.9 35.01 GAS LIFT CAMCO/KBUG/1/GLVBK/.125/1324/Comment STA 1 7/4/2009 2.875 3,401 3,000.7 38.00 GAS LIFT CAMCO/KBUG/1/GLV/BK/.156/1327/Comment:STA2 7/3/2009 2.875 GAS LIFT, 4,297 3,707.4 33.09 GAS LIFT CAMCO/KBUG/1/DMY/BK////Comment STA 3 9/24/2004 2.675 4,798 4,796 4,151.1 22.08 GAS LIFT CAMCO/KBUG/1/GLV/BK/.156/13001 Comment STA 4 7/3/2009 2.875 5,268 4,599.6 13.64 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment STA 5 1/15/1994 2.875 GAS UFT, 5,730 5,054.2 8.00 GAS LIFT CAMCO/KBUG/1/GLVBK/.188/1315/Comment STA 6 7/2/2009 2.875 5,268 _ .. 6,201 5,521.8 5.50 GAS LIFT CAMCO/KBUG/1/OV/BK/.188//Comment STA7 7/3/2009 2.875 6,516 5,835.6 4.42 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment:EXTENDED 7/19/2004 2.875 GAS LIFT, PACKING STA 8 5,730 6,561 5,880.5 4.20 SBR Baker SBR w/2.81"X-PROFILE 10/26/1984 2.813 8,587 5,906A 4.07 PACKER Baker'FHL'PACKER 10/26/1984 3.500 GAS LIFT, 6,201 6,626 5,945.5 5.48 PRODUCTION CAMCO/KBUG/1/DMYBK-FT///Comment STA9 11/15/2005 2.875 6,693 8,012.1 4.14 PRODUCTION CAMCO/KBUG/1/DMYBK-FT///Comment STA 10 11/18/2005 2.875 6,896 6,214.9 2.00 PACKER STRADDLE PATCH UPPER PACKER(351B')GOOD 4/14/2009 1.830 TEST 2500 PSI GAS LIFT, 6,901 6,219.9 1.75 PATCH STRADDLE PATCH ASSY 34'OAL=XO,SPACE PIPE,& 5/17/2009 1.000 6,516 STINGER SET IN NIPPLE REDUCER(Patch inside Patch from 6908'b 6919) 6,908 6,226.9 1.77 PATCH 11'HES PERMANENT PATCH(TOP SWAGE,SEAL,PUP, 8/21/1994 1.910 SBR,6,561 - - BOTTOM SEAL,SWAGE)SET ACROSS GLM#11(6912) 6,912 6,230.9 1.78 PRODUCTION CAMCO/KBUG/1/PATCH/M///Comment:CLOSED STA 11 8/28/1990 2.875 6,923 6,241.9 1.81 PACKER Baker ro-1.PACKER 10/26/1984 3.500 PACKER,6,587 6,935 6,253.9 1.84 NIPPLE Camco'D'Nipple NO GO 10/26/1984 2.750 6,935 6,253.9 1.84 NIPPLE RDCR AVA;Seton 8/11/94 8/11/1994 1.810 PRODucnoN,___ 6,940 6,258.9 1.85 SOS Baker 10/26/1984 2.992 6.626 6.941 6,259.9 1.85 TTL 10/26/1984 2.992 7,012 6,330.9 2.48 FISH 4 WL Grab Fingers and SSSV Flapper piece Dropped 4/18/1989 0.000 PRODUCTION, Downhole when Pulling ToolString Fish 6,693 PRODUCTION, i 7,012 6,330.9 2.48 FISH 1'CV Lost Downhole 11/11/1991 0.000 6,696 7,012 6,330.9 2.46 FISH 13"JDC skirt Lost while pulling WRDP 4/18/1992 0.000 6.766-6,902 Perforations&Slots _ Shot PACKER,6,896-- - Top(TVD) Ban(TVD) Top MB) Ban(MB) OMR) MOM Zone Date (•h... Typs Comment 6,766 6,902 6,065.0 6,220.9 C-3,C-2,C-1, 11/5/1980 8.0 UNIT B,1E-05 6,976 6,994 6,294.9 6,312.9 A5,1E-05 8/6/1994 6.0 RPERF 180 deg.Ph,2.5'Titan Guns 7,000 7,014 6,318.9 6,332.9 A-4,1E-05 8/6/1994 6.0 RPERF 180 deg.Ph,2.5'Than Guns PRODUCT6,912ION, 1 C PATCH,6,906 PATCH,6,901 PACKER,6,923 _- i NIPPLE,6,935 _! NIPPLE RDCR_\ I! 6,935 I SOS,6,940 --. F TTL,6,941 --__ 11 RPERF, -4 6,976-6,994 RPERF, 7,000-7,014 FISH,7,012 - FISH,7,012 FISH,7,012 s ----111 LINER,7,195-:\ TO,7,200 mommismommismimmommimmummosimommiminummimmoommi Well Name Requirements of 20 AAC 25.005(0 The well for which this application is submitted will be designated as 1E-05A Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identfing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I 653' FSL, 633'FEL, Sec 16, T11N,R10E,UM NGS Coordinates RKB Elevation 101.4' AMSL r- Northings: 5,960,237.3' Eastings: 549,890.4' Pad Elevation 71.4'AMSL Location at Top of 2,191'FSL, 1,757'FWL,Sec 15,T11N,R10E,UM Productive Interval (Kuparuk A Sand) NGS Coordinates Measured Depth, RKB: 7,105' Northings: 5,961,793.4' Eastings: 552,265.2' Total Vertical Depth, RKB: 6,309' Total Vertical Depth, SS: 6,207' Location at Total Depth 2,260' FSL, 1,789'FWL, Sec 15,T11N,R10E,UM NGS Coordinates Measured Depth, RKB: _ 7,257' ` Northings: 5,961,862.7' Eastings:552,296.9' Total Vertical Depth, RKB: 6,441' Total Vertical Depth, SS: 6,340' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan No close approach issues exist. Separation factors are above 1.5 once the sidetrack is greater than 100' ' MD beyond the window and continue to increase with depth. The 1/4"mile pool scan of the top of Kuparuk C Sand shows the closest approach to be the original 1E-05 wellbore 444'away at 6,853' MD. And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Nordic 3. r A ‘.%. e' Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP)while drilling 1E-05A is calculated using a maximum reservoir pressure of 3,500 psi, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A sand at 6,318' TVD (WP06): A Sand SIBHP =3,500 psi - / A Sand estimated depth(WP06) 6,318' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =6 (6,318' TVD * 0.10 psi/ft) MPSP= SIBHP—gas column 2,868 psi (3,500 psi—632 psi) (B)data on potential gas:ones; The well bore is not expected to penetrate any gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and:ones that have a propensity for differential sticking; See attached 1E-05A Drilling Hazards Summary , Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. For 1E-05A the formation integrity test for the intermediate hole will occur after milling the window and 20' of new formation. The formation at the window depth will be pressured until leak-off occurs or to 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 12.5 t be obtained. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre-perforated liner,or screen to be installed Casing Program Casing Hole Weight Top Btm OD Size (1b/ft) Grade Connection Length MD/TVD MD/TVD Conduct 70- 94.0 H-40 Weld 95' Surface=34' 129' / 129' or ---------_--___-- --— _______________ OriUinal Wellbore 13-3/8'' 16" 72 N-80 BTC 2,383' Surface=-33' 2,416' /2,210' 9-5/8" 12-1/4- 47 L80 BTC 6,662' Surface 32' 6,694' /6,013' Sidetrack Out of 5-1/2" 8-1/2" 15.5 L-80 BCTM 2,457' 4,800'/4,160' 7,257/6,441' 9-5/8"Casing Liner ' 3-1/2" Tubing_ 9.3 L-80 — EUE_ 4,722' Surface 28' 4,750'/4,112' 3-1/2" Tubing 9.3 L-80 -IBT-M 2,000' 4,750'/6,441' 6,750'/5,995' Single Stage Cement Program Cement will be placed from the TD at 7,257' MD to 100' above the top of liner. The liner shoe will be at 7,257' MD and the top of liner set at 4,800' MD (approximately 200'of overlap inside the existing 9-5/8" casing). The slurry consists of 677sacks of Class G cement plus additives at 15.8 ppg with 35%excess yielding 1.17 ft3/sx. Cement System Preflush: 40 bbls Chemical Wash Spacer: 40 bbls MudPush II Slurry: 677 sacks Class G Cement+additives Yield= 1.17 ft3/sx Mix Water= 5.1 gal/sx Slurry Volumes Length Capacity Excess Total(ft3) Total(sacks) (ft) (ft3) Liner LIT_ 200 49 0% 49 41.9 - —- —- - — --------•---- 9-5/8"x x 5-1/2" bVI-- Open Hole x Liner OD 2,258 —�- 517 35% 699 597.4 8-1/2"x 5-1/2" _�— Shoe Track ID 80 11 � 0% 11 --- 9.5 4.950" _ Top of liner 100 33 0% _—_ 33 28.2 6.276" --------- ---- Total_----- 792 ---- 67 Diverter System Information Requirements of 20 AAC 25.005(0(71 An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 MC 25.035(h)(2); This rotary sidetrack will exit pre-existing 9-5/8"casing at 5,000' MD. BOPE will be installed prior to exiting the casing, and therefore no diverter is required. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Depth MD Mud Wt. Funnel API Fluid (ft) (ppg) Vis(cp) PV YP Loss pH Comments (cc/30min) Milling Fluid 9.6-9.8 50-60 15-20 50-60 NC 10.5-11 Milling fluid can be reconditioned 5,016'-5,046' ? for dilling sidetrack LSND 10.8-11.5 ' 60-80 i 25-35 7-8 <6 9.5-10 5,046'-7,257' Milling Fluid: A 9.8 ppg viscosified water based milling fluid consisting of pH control and weighting agents will be used to cut the 8-1/2"window and 20' of new formation. This fluid will maintain good rheology to remove metal fragments from the wellbore and prevent their recirculation. The milling fluid can be reconditioned for use in the sidetrack. Sidetrack Fluid: A 10.8 ppg LSND drilling fluid will be used to drill to 7,257' MD/6,441' TVD. The drilling mud weight is calculated using an A Sand EMW of 10.3 ppg plus 0.5 ppg trip margin to result in a 10.8 ppg. Fluid weight will have sufficient density to overbalance the pressure of uncased formations penetrated. Additional focus will be on minimizing the potential of a hydrostatic pressure surge or swab and good hole cleaning practices. These practices include monitoring tripping speeds and PWD data, controlling ROP, pumping regular sweeps, adjusting rheology, and charting drag weights. Diagram of Nordic 3 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A- Application is not for an exploratory or stratigraphic test well. / Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A- Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A- Application is not for an offshore well. -) � , Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: 1E-05 P&A Pre Rig Work(previous sundry): a. Replace GLVs with dummy valves. b. RIH on coil tubing and set retainer at+/-6,650'RKB. 1 c. Pump 22 bbls of 15.8 ppg cement into A and C sand perforation and fill the tubing above the retainer from 6650' —6,566' RKB. d. Pull DV from GLM#8 at 6,516'RKB. P ,t, ) e. Set a retainer at+/-6,450' RKB. Mix and pump 78 bbls of cement,68 bbls circulated into the IA through the � tubing holes and 10 bbls layed on top the cement retainer. f. Tag top of cement with bailer. Test the plug. I A S MD -lies& lit g. E-line cut tubing at+/-5,246'MD - Tubing is freeze protected with diesel. - Set BPV. • 1. Move Nordic 3 on 1E-05 and rig up. 2. Pull BPV. Record tubing,IA,and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. ' 3. Set BPV and nipple down tree.M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low/3,$110 psi high as per drilling permit. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3-1/2"completion. 5. Run 9-5/8"casing scraper to 5,240' MD. • Spot a weighted pill with corrosion inhibitor between tubing stub and cement retainer. 6. Rig up E-line and run gyro/caliper in 9-5/8"casing to evaluate for subsidence related issues. . 7. Using E-line,perforate 9-5/8"casing at+/-5,110' MD for cement squeezer • 8. Set 9-5/8"cement retainer bottom at+/-5,100'MD. .51,tN1 9. Squeeze 25 bbls cement into perforations. -----P 1' 311'36 10. Nipple down BOP stack and tubing head. Pull 9-5/8"packoff and expect casing growth. 11. Run 9-5/8"casing spear and engage 9-5/8"casing with overpull. Cut excess casing and reset slips with casing. 2f1A 12. Install 9-5/8"packoff,nipple up tubing head and BOP stack. Retest same. 13. Test 9-5/8"casing and cement retainer to 3,500 psi,chart for 15 minutes. 14. Pick up 9-5/8"whipstock/milling assembly. Run in hole and displace casing to milling fluid. Orient whipstock. ' t 15. Set whipstock and mill window in 9-5/8"plus 20' of new formation for FIT/LOT. Perform FIT with rig pump as per CPAI • procedure to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. x- 16. Pull out of hole whipstock/milling assembly and gauge mills. _ 17. Pick-up and make up 8-1/2"PDC bit with 6-3/4"LWD/MWD drilling BHA. f VD 18. Run in hole with drilling BHA to top of window and displace to 10.8 ppg drilling mud. 1 19. Drill 8-1/2"hole from 5,036'MD to 7,257 MD' (Top Miluveach). it -4-Arc. (K"-7144-4A -5--,4-101)S 20. At total depth,circulate hole clean and wiper trip to window. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. 21. Run 5-1/2", 15.5 ppf,L-80 liner to TD. Top of liner will be+/-200' above window. 0 IN i t i t``%. +'t L 22. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. 23. Monitor well then pull out of hole laying down drill pipe. 24. Run upper completion as per procedure with SCSSV and GLMs. � _ (A '� 25. RD and MO Nordic 3. Coil tubing drilling rig will return at a future date to dril A Sand producers. G • A) b` Se.5 ., cc Discussion of Mud and Cuttings Disposal and Annular Disposal CTS — Requirements of 20 AAC 25.005(c)(14) �i An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with a commission? /( and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic rt a ! ( 1 t6 t iti i i t ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 E Pad 1E-05 Plan: 1E-05A Plan: 1E-05A (wp06) Standard Proposal Report 04 November, 2011 +� HALLIBURTON Ile w" Sperry Drilling Services ORIGLNAL HALLIBURTON Project: Kuparuk River Unit WELL DETAILS: 1E-05 Site: Kuparuk 1E Pad Ground Leel: 71.40 Well: 1 E-05 +N/-S +E/-W Northing Easting Latittude Longitude Slot Sperry Drilling Wellbore: Plan: 1 E-05A 0.00 0.00 5960237.32 549890.40 70°18'7.714 N 149°35'45.239 W Plan: 1E-05A (wp06) REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well 1E-05,True North Vertical(TVD)Reference:1E-05A CO 101.409(Nor3(71.4+30)) Measured Depth Reference: 1E-05A @ 101.408(Nor3(71.4+30)) Calculation Method:Minimum Curvature ._ 4250— - I 1 1 : I i 1 I l I ( I I - 9 5/8"TOW - TOW @ 5000'MD,4348'TVD:1702'FSL,1320'FWL-Sec15-TIIN-RIOE 4500--- - 1s` I CASING DETAILS 4750— - i MD TVD TVDSS Name Size Hole Size 2411.90 2208.24 2106.84 13 3/8" 13-3/8 17-1/2 - 5000.02 4348.43 4247.03 9 5/8"TOW 9-5/8 13-1/2 11° 7257.13 6441.40 6340.00 5 1/2" 5-1/2 6-3/4 5000— — - 1 _ I I I 5250= DDI = 5.699 86800 - 4 - 5500 - ( 3. 0, —__.-_-- 0 - 1.5° . 5750 - 'i F - `Top HRZ - r I 6000 Top Kalubik(Base HRZ) - - �„K-1 Marker I _- 3p -.- II.-n5471 If^) - Top C Sand I—l.-.. - 6250—Top B Shale — Y Top A6 3 6500—Top A3 ----- 5 1/2" -'- ---- 1 1 I I BHL @ 7257'MD,6441'TVD 2260'ESL,1789'FWL-Sec15-TI IN-RIOE 1E-05 1E-05A(wp06) 6750 1 1 1 1 I l 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 Vertical Section at 49.44°(500 ft/in) 1700 _ l I I — - 5 1/2" le 06:9 1600 BHL @ 7257'MD,6441'TVD:2260'FSL,1789'FWL-Sec15-T11N-RIOE - I I I-(:�:A TI I,shnn)I S1500 - - 51}.a Z - en en1400 _ 6000 1 1300 - S,sO `y�a1'1200 - 30° C - 9 5/8"TOW -:eT M Azimutha to True North 1100 � Magnetic North:'6.83° \' ___o o. Magnetic Field -- Streng h:5735...9snT 1000 _ _-------- Dip Angle:7'9.86° TOW @ 5000MD,4348'TVD:1702'FSL,1320'FWL-SeclS-T1IN-RIOE Date: 4/29/2011 05 Model:BGGM2010 900 - iii 1117 '1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 ilii 1111 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 West(-)/East(+)(300 ft/in) ConocoPhillips Alaska Halliburton -Sperry 1. 1ALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-05A Design: 1E-05A(wp06) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk l E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.021 N From: Map Easting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.38° Well 1E-05 Well Position +N/-S 0.00 ft Northing: 5,960,237.32 ft Latitude: 70°18'7.714 N +El-W 0.00 ft Easting: 549,890.40 ft Longitude: 149°35 45.239 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 71.40ft Wellbore Plan:1E-05A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 4/29/2011 16.83 79.86 57,356 Design 1 E-05A(wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,000.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) 30.00 0.00 0.00 49.44 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 5,000.00 18.77 66.36 4,348.41 4,247.01 1,051.77 1,950.30 0.00 0.00 0.00 0.00 5,016.50 21.00 66.36 4,363.93 4,262.53 1,054.02 1,955.44 13.56 13.56 0.00 0.00 5,076.50 21.00 66.36 4,419.94 4,318.54 1,062.64 1,975.14 0.00 0.00 0.00 0.00 5,286.57 10.72 74.72 4,621.77 4,520.37 1,082.95 2,028.63 5.00 -4.89 3.98 171.46 5,954.49 10.72 74.72 5,278.01 5,176.61 1,115.71 2,148.53 0.00 0.00 0.00 0.00 6,441.45 30.00 25.00 5,735.00 5,633.60 1,239.86 2,245.15 5.00 3.96 -10.21 -67.70 6,951.13 30.00 25.00 6,176.40 6,075.00 1,470.83 2,352.85 0.00 0.00 0.00 0.00 7,257.13 30.00 25.00 6,441.40 6,340.00 1,609.49 2,417.51 0.00 0.00 0.00 0.00 11/4/2011 12:55:02PM Page 2 COMPASS 2003.16 Build 69 + i ) g ...> i .yL✓'` . t i�'t;‘ Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1 E-05A Design: 1 E-05A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -71.40 30.00 0.00 0.00 30.00 -71.40 0.00 0.00 5,960,237.32 549,890.40 0.00 0.00 45.90 0.78 358.76 45.90 -55.50 0.11 0.00 5,960,237.43 549,890.40 4.91 0.07 70.90 0.60 357.73 70.90 -30.50 0.41 -0.01 5,960,237.73 549,890.39 0.72 0.26 95.90 0.46 6.74 95.90 -5.50 0.64 0.00 5,960,237.96 549,890.39 0.65 0.41 120.90 0.32 29.81 120.90 19.50 0.80 0.04 5,960,238.12 549,890.44 0.83 0.55 145.90 0.33 43.65 145.90 44.50 0.91 0.13 5,960,238.23 549,890.52 0.32 0.69 170.90 0.30 29.13 170.90 69.50 1.02 0.21 5,960,238.34 549,890.60 0.34 0.82 195.90 0.28 37.97 195.90 94.50 1.13 0.28 5,960,238.45 549,890.67 0.20 0.94 220.90 0.30 46.23 220.89 119.49 1.22 0.36 5,960,238.54 549,890.75 0.19 1.07 245.90 0.37 40.39 245.89 144.49 1.33 0.46 5,960,238.65 549,890.85 0.31 1.21 270.90 0.32 41.37 270.89 169.49 1.44 0.56 5,960,238.76 549,890.95 0.20 1.36 295.90 0.28 39.09 295.89 194.49 1.54 0.64 5,960,238.86 549,891.03 0.17 1.49 320.90 0.31 42.71 320.89 219.49 1.64 0.73 5,960,238.96 549,891.12 0.14 1.62 345.90 0.27 32.20 345.89 244.49 1.74 0.81 5,960,239.06 549,891.20 0.27 1.74 370.90 0.30 29.80 370.89 269.49 1.84 0.87 5,960,239.17 549,891.26 0.13 1.86 395.90 0.27 20.68 395.89 294.49 1.96 0.92 5,960,239.28 549,891.31 0.22 1.97 420.90 0.31 26.93 420.89 319.49 2.07 0.98 5,960,239.40 549,891.36 0.20 2.09 445.90 0.24 20.91 445.89 344.49 2.18 1.02 5,960,239.51 549,891.41 0.30 2.20 470.90 0.35 32.70 470.89 369.49 2.29 1.08 5,960,239.62 549,891.47 0.50 2.32 495.90 0.72 48.14 495.89 394.49 2.46 1.24 5,960,239.79 549,891.63 1.58 2.55 520.90 1.32 55.86 520.89 419.49 2.73 1.60 5,960,240.06 549,891.98 2.46 2.99 545.90 2.26 56.56 545.87 444.47 3.16 2.25 5,960,240.50 549,892.63 3.76 3.76 570.90 3.23 56.24 570.84 469.44 3.83 3.24 5,960,241.17 549,893.62 3.88 4.95 595.90 4.08 56.62 595.79 494.39 4.71 4.57 5,960,242.06 549,894.94 3.40 6.53 620.90 4.71 57.01 620.72 519.32 5.75 6.18 5,960,243.11 549,896.54 2.52 8.43 645.90 5.24 56.62 645.63 544.23 6.94 7.99 5,960,244.31 549,898.34 2.12 10.58 670.90 5.94 56.68 670.51 569.11 8.28 10.02 5,960,245.67 549,900.37 2.80 13.00 695.90 7.14 55.06 695.34 593.94 9.88 12.38 5,960,247.28 549,902.71 4.86 15.83 720.90 8.33 54.53 720.12 618.72 11.82 15.13 5,960,249.24 549,905.45 4.77 19.18 745.90 9.40 55.38 744.82 643.42 14.03 18.28 5,960,251.47 549,908.59 4.31 23.01 770.90 10.23 56.97 769.45 668.05 16.40 21.82 5,960,253.86 549,912.11 3.49 27.25 795.90 11.02 59.04 794.02 692.62 18.84 25.73 5,960,256.33 549,916.01 3.51 31.80 820.90 12.02 61.64 818.52 717.12 21.31 30.07 5,960,258.82 549,920.33 4.51 36.70 845.90 13.09 64.74 842.92 741.52 23.75 34.93 5,960,261.30 549,925.16 5.06 41.98 870.90 14.23 66.46 867.21 765.81 26.19 40.30 5,960,263.77 549,930.52 4.84 47.65 895.90 15.01 67.64 891.40 790.00 28.65 46.11 5,960,266.27 549,936.32 3.34 53.66 920.90 15.62 67.77 915.52 814.12 31.15 52.22 5,960,268.81 549,942.41 2.44 59.93 945.90 16.19 67.76 939.56 838.16 33.74 58.57 5,960,271.45 549,948.73 2.28 66.44 970.90 17.09 67.75 963.51 862.11 36.45 65.19 5,960,274.20 549,955.34 3.60 73.23 995.90 18.24 67.83 987.33 885.93 39.32 72.21 5,960,277.12 549,962.35 4.60 80.43 1,020.90 19.39 67.72 1,011.00 909.60 42.37 79.68 5,960,280.21 549,969.79 4.60 88.09 1,045.90 20.33 67.61 1,034.51 933.11 45.60 87.53 5,960,283.49 549,977.62 3.76 96.15 1,070.90 21.22 67.27 1,057.88 956.48 49.00 95.72 5,960,286.95 549,985.79 3.59 104.59 1,095.90 22.11 66.74 1,081.12 979.72 52.61 104.22 5,960,290.61 549,994.26 3.64 113.39 1,120.90 22.77 65.97 1,104.22 1,002.82 56.44 112.96 5,960,294.50 550,002.97 2.89 122.52 11/4/2011 12:55:02PM Page 3 COMPASS 2003.16 Build 69 a e- ,,, IK t Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1 E-05A Design: 1E-05A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (') (") (ft) ft (ft) (ft) (ft) (ft) 1,025.83 1,145.90 23.32 65.81 1,127.23 1,025.83 60.43 121.89 5,960,298.55 550,011.88 2.21 131.90 1,170.90 23.60 65.81 1,150.16 1,048.76 64.51 130.97 5,960,302.69 550,020.93 1.12 141.45 1,195.90 23.96 65.63 1,173.04 1,071.64 68.66 140.16 5,960,306.90 550,030.09 1.47 151.13 1,220.90 24.36 65.68 1,195.85 1,094.45 72.87 149.48 5,960,311.18 550,039.38 1.60 160.96 1,245.90 24.70 65.81 1,218.59 1,117.19 77.14 158.95 5,960,315.50 550,048.81 1.38 170.92 1,270.90 25.09 65.71 1,241.27 1,139.87 81.46 168.54 5,960,319.89 550,058.38 1.57 181.02 1,295.90 25.44 65.86 1,263.88 1,162.48 85.84 178.27 5,960,324.33 550,068.08 1.42 191.26 1,320.90 25.82 65.68 1,286.42 1,185.02 90.27 188.13 5,960,328.83 550,077.91 1.55 201.63 1,345.90 26.16 65.50 1,308.89 1,207.49 94.80 198.11 5,960,333.42 550,087.86 1.40 212.16 1,370.90 26.54 65.05 1,331.29 1,229.89 99.44 208.19 5,960,338.13 550,097.90 1.72 222.83 1,395.90 26.51 63.72 1,353.66 1,252.26 104.27 218.26 5,960,343.03 550,107.94 2.38 233.62 1,420.90 26.30 62.36 1,376.05 1,274.65 109.31 228.16 5,960,348.13 550,117.81 2.56 244.43 1,445.90 26.38 61.46 1,398.46 1,297.06 114.53 237.95 5,960,353.42 550,127.56 1.63 255.26 1,470.90 26.60 60.99 1,420.83 1,319.43 119.90 247.72 5,960,358.85 550,137.30 1.22 266.17 1,495.90 26.75 60.71 1,443.17 1,341.77 125.37 257.53 5,960,364.38 550,147.06 0.78 277.17 1,520.90 27.09 60.32 1,465.46 1,364.06 130.94 267.38 5,960,370.02 550,156.88 1.53 288.28 1,545.90 27.51 60.14 1,487.68 1,386.28 136.63 277.33 5,960,375.78 550,166.79 1.71 299.55 1,570.90 27.86 60.07 1,509.82 1,408.42 142.42 287.40 5,960,381.63 550,176.82 1.41 310.96 1,595.90 28.29 59.76 1,531.87 1,430.47 148.32 297.58 5,960,387.60 550,186.96 1.82 322.53 1,620.90 28.78 59.52 1,553.84 1,452.44 154.35 307.89 5,960,393.70 550,197.22 2.01 334.28 1,645.90 29.26 59.47 1,575.70 1,474.30 160.51 318.33 5,960,399.92 550,207.63 1.92 346.23 1,670.90 29.78 59.38 1,597.45 1,496.05 166.78 328.94 5,960,406.26 550,218.19 2.09 358.36 1,695.90 30.32 59.18 1,619.09 1,517.69 173.17 339.70 5,960,412.73 550,228.91 2.20 370.69 1,720.90 30.88 59.15 1,640.61 1,539.21 179.69 350.63 5,960,419.32 550,239.79 2.24 383.24 1,745.90 31.49 58.91 1,662.00 1,560.60 186.36 361.73 5,960,426.06 550,250.85 2.49 396.00 1,770.90 31.99 58.53 1,683.26 1,581.86 193.19 372.97 5,960,432.96 550,262.04 2.15 408.98 1,795.90 32.68 58.24 1,704.38 1,602.98 200.20 384.36 5,960,440.04 550,273.38 2.83 422.19 1,820.90 33.17 57.73 1,725.37 1,623.97 207.40 395.88 5,960,447.32 550,284.85 2.25 435.63 1,845.90 33.62 57.67 1,746.24 1,644.84 214.75 407.51 5,960,454.75 550,296.43 1.80 449.24 1,870.90 34.11 57.59 1,767.00 1,665.60 222.21 419.27 5,960,462.29 550,308.15 1.97 463.03 1,895.90 34.61 57.76 1,787.64 1,686.24 229.76 431.20 5,960,469.91 550,320.02 2.04 477.00 1,920.90 34.72 57.88 1,808.20 1,706.80 237.33 443.23 5,960,477.56 550,332.00 0.52 491.06 1,945.90 35.33 58.03 1,828.67 1,727.27 244.94 455.39 5,960,485.25 550,344.11 2.46 505.25 1,970.90 35.50 58.23 1,849.05 1,747.65 252.59 467.70 5,960,492.98 550,356.37 0.82 519.58 1,995.90 35.83 58.39 1,869.36 1,767.96 260.25 480.10 5,960,500.72 550,368.72 1.37 533.98 2,020.90 35.71 58.44 1,889.64 1,788.24 267.90 492.55 5,960,508.46 550,381.11 0.49 548.41 2,045.90 35.66 58.60 1,909.95 1,808.55 275.52 504.99 5,960,516.16 550,393.50 0.42 562.81 2,070.90 35.72 58.68 1,930.25 1,828.85 283.11 517.44 5,960,523.83 550,405.90 0.30 577.21 2,095.90 35.72 58.91 1,950.55 1,849.15 290.67 529.92 5,960,531.47 550,418.33 0.54 591.61 2,120.90 35.67 58.88 1,970.85 1,869.45 298.20 542.41 5,960,539.09 550,430.77 0.21 606.00 2,145.90 35.50 58.97 1,991.18 1,889.78 305.71 554.87 5,960,546.68 550,443.18 0.71 620.35 2,170.90 35.26 58.88 2,011.57 1,910.17 313.18 567.27 5,960,554.23 550,455.52 0.98 634.63 2,195.90 35.10 58.77 2,032.00 1,930.60 320.64 579.60 5,960,561.77 550,467.80 0.69 648.84 2,220.90 35.18 58.86 2,052.44 1,951.04 328.09 591.91 5,960,569.30 550,480.06 0.38 663.04 2,245.90 35.35 58.96 2,072.86 1,971.46 335.54 604.27 5,960,576.84 550,492.37 0.72 677.27 11/4/2011 12:55:02PM Page 4 COMPASS 2003.16 Build 69 ",, , -, i,-, ! .1,1/4, IA .._ i\ ( U i i Y i Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-05A Design: 1E-05A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (') (ft) ft (ft) (ft) (ft) (ft) 1,991.85 2,270.90 35.30 58.96 2,093.25 1,991.85 343.00 616.65 5,960,584.37 550,504.70 0.20 691.53 2,295.90 35.30 59.22 2,113.66 2,012.26 350.42 629.05 5,960,591.87 550,517.04 0.60 705.77 2,320.90 35.27 59.45 2,134.06 2,032.66 357.78 641.47 5,960,599.32 550,529.42 0.54 720.00 2,345.90 35.36 59.32 2,154.46 2,053.06 365.14 653.91 5,960,606.76 550,541.80 0.47 734.23 2,370.90 35.49 59.39 2,174.84 2,073.44 372.53 666.37 5,960,614.23 550,554.22 0.54 748.51 2,395.90 35.45 59.47 2,195.20 2,093.80 379.91 678.86 5,960,621.69 550,566.66 0.25 762.80 2,411.90 35.36 59.45 2,208.24 2,106.84 384.62 686.85 5,960,626.45 550,574.61 0.56 771.92 13 3/8" 2,420.90 35.31 59.44 2,215.58 2,114.18 387.27 691.33 5,960,629.13 550,579.08 0.56 777.05 2,445.90 35.16 59.43 2,236.00 2,134.60 394.60 703.75 5,960,636.54 550,591.44 0.60 791.25 2,470.90 35.16 59.44 2,256.44 2,155.04 401.92 716.14 5,960,643.95 550,603.79 0.02 805.43 2,495.90 35.32 59.48 2,276.86 2,175.46 409.25 728.57 5,960,651.36 550,616.16 0.65 819.64 2,520.90 35.47 59.74 2,297.24 2,195.84 416.58 741.06 5,960,658.77 550,628.61 0.85 833.89 2,545.90 35.71 60.13 2,317.57 2,216.17 423.86 753.65 5,960,666.14 550,641.15 1.32 848.20 2,570.90 35.47 60.51 2,337.90 2,236.50 431.07 766.29 5,960,673.42 550,653.74 1.31 862.49 2,595.90 35.43 60.64 2,358.26 2,256.86 438.19 778.92 5,960,680.63 550,666.32 0.34 876.71 2,620.90 35.53 60.91 2,378.62 2,277.22 445.28 791.58 5,960,687.80 550,678.93 0.74 890.94 2,645.90 35.71 60.94 2,398.94 2,297.54 452.35 804.31 5,960,694.96 550,691.61 0.72 905.21 2,670.90 36.02 61.00 2,419.20 2,317.80 459.46 817.12 5,960,702.15 550,704.37 1.25 919.56 2,695.90 36.30 61.00 2,439.39 2,337.99 466.61 830.02 5,960,709.39 550,717.22 1.12 934.01 2,720.90 36.50 61.00 2,459.51 2,358.11 473.80 842.99 5,960,716.66 550,730.15 0.80 948.55 2,745.90 36.59 60.94 2,479.59 2,378.19 481.03 856.01 5,960,723.97 550,743.11 0.39 963.13 2,770.90 36.71 61.00 2,499.65 2,398.25 488.27 869.06 5,960,731.30 550,756.11 0.50 977.76 2,795.90 36.77 60.68 2,519.68 2,418.28 495.56 882.12 5,960,738.67 550,769.12 0.80 992.42 2,820.90 36.60 60.63 2,539.73 2,438.33 502.88 895.14 5,960,746.08 550,782.09 0.69 1,007.07 2,845.90 36.41 60.48 2,559.83 2,458.43 510.19 908.09 5,960,753.47 550,794.99 0.84 1,021.66 2,870.90 36.50 60.52 2,579.94 2,478.54 517.50 921.02 5,960,760.87 550,807.87 0.37 1,036.24 2,895.90 36.68 60.61 2,600.01 2,498.61 524.83 933.99 5,960,768.28 550,820.80 0.75 1,050.86 2,920.90 36.74 60.43 2,620.05 2,518.65 532.18 947.00 5,960,775.72 550,833.76 0.49 1,065.53 2,945.90 36.82 60.12 2,640.07 2,538.67 539.60 960.00 5,960,783.23 550,846.71 0.81 1,080.23 2,970.90 36.66 60.15 2,660.11 2,558.71 547.05 972.97 5,960,790.76 550,859.62 0.64 1,094.92 2,995.90 36.59 59.93 2,680.17 2,578.77 554.50 985.89 5,960,798.30 550,872.49 0.59 1,109.58 3,020.90 36.66 59.92 2,700.24 2,598.84 561.97 998.80 5,960,805.85 550,885.35 0.28 1,124.25 3,045.90 36.69 59.98 2,720.29 2,618.89 569.45 1,011.72 5,960,813.42 550,898.22 0.19 1,138.93 3,070.90 36.81 60.11 2,740.32 2,638.92 576.92 1,024.68 5,960,820.97 550,911.13 0.57 1,153.63 3,095.90 36.79 59.79 2,760.34 2,658.94 584.42 1,037.65 5,960,828.55 550,924.04 0.77 1,168.36 3,120.90 36.64 59.45 2,780.38 2,678.98 591.97 1,050.54 5,960,836.20 550,936.89 1.01 1,183.07 3,145.90 36.59 59.13 2,800.44 2,699.04 599.59 1,063.36 5,960,843.90 550,949.65 0.79 1,197.76 3,170.90 36.65 58.84 2,820.51 2,719.11 607.27 1,076.14 5,960,851.66 550,962.38 0.73 1,212.47 3,195.90 36.92 58.62 2,840.53 2,739.13 615.04 1,088.94 5,960,859.52 550,975.12 1.20 1,227.24 3,220.90 37.35 58.66 2,860.46 2,759.06 622.90 1,101.82 5,960,867.46 550,987.96 1.72 1,242.14 3,245.90 37.51 58.87 2,880.31 2,778.91 630.78 1,114.82 5,960,875.42 551,000.90 0.82 1,257.13 3,270.90 37.52 58.93 2,900.14 2,798.74 638.64 1,127.85 5,960,883.37 551,013.88 0.15 1,272.15 3,295.90 37.52 58.77 2,919.97 2,818.57 646.52 1,140.88 5,960,891.33 551,026.85 0.39 1,287.17 3,320.90 37.58 58.62 2,939.79 2,838.39 654.43 1,153.90 5,960,899.34 551,039.82 0.44 1,302.21 11/4/2011 12:55:02PM Page 5 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-05A Design: 1E-05A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,858.22 3,345.90 37.47 58.77 2,959.62 2,858.22 662.35 1,166.91 5,960,907.33 551,052.78 0.57 1,317.24 3,370.90 37.55 58.83 2,979.45 2,878.05 670.23 1,179.93 5,960,915.31 551,065.74 0.35 1,332.26 3,395.90 37.56 58.81 2,999.27 2,897.87 678.12 1,192.97 5,960,923.28 551,078.72 0.06 1,347.29 3,420.90 37.70 59.16 3,019.07 2,917.67 685.99 1,206.05 5,960,931.23 551,091.75 1.02 1,362.35 3,445.90 37.68 58.99 3,038.85 2,937.45 693.84 1,219.16 5,960,939.17 551,104.81 0.42 1,377.42 3,470.90 37.58 59.17 3,058.65 2,957.25 701.68 1,232.26 5,960,947.10 551,117.85 0.59 1,392.46 3,495.90 37.60 59.33 3,078.46 2,977.06 709.48 1,245.36 5,960,954.98 551,130.90 0.40 1,407.49 3,520.90 37.81 59.55 3,098.24 2,996.84 717.26 1,258.53 5,960,962.85 551,144.02 1.00 1,422.55 3,545.90 37.86 59.40 3,117.99 3,016.59 725.04 1,271.74 5,960,970.72 551,157.17 0.42 1,437.65 3,570.90 38.10 59.98 3,137.69 3,036.29 732.81 1,285.02 5,960,978.57 551,170.40 1.72 1,452.79 3,595.90 37.98 59.78 3,157.38 3,055.98 740.54 1,298.35 5,960,986.39 551,183.67 0.69 1,467.94 3,620.90 37.98 59.91 3,177.09 3,075.69 748.27 1,311.65 5,960,994.21 551,196.92 0.32 1,483.07 3,645.90 37.67 59.98 3,196.83 3,095.43 755.95 1,324.92 5,961,001.97 551,210.14 1.25 1,498.15 3,670.90 37.88 60.16 3,216.59 3,115.19 763.59 1,338,19 5,961,009.70 551,223.36 0.95 1,513.20 3,695.90 37.92 60.26 3,236.32 3,134.92 771.22 1,351.52 5,961,017.42 551,236.64 0.29 1,528.28 3,720.90 38.12 60.69 3,256.02 3,154.62 778.80 1,364.92 5,961,025.09 551,249.98 1.33 1,543.40 3,745.90 38.14 61.42 3,275.68 3,174.28 786.27 1,378.42 5,961,032.65 551,263.44 1.80 1,558.52 3,770.90 38.28 62.03 3,295.33 3,193.93 793.60 1,392.04 5,961,040.07 551,277.01 1.61 1,573.63 3,795.90 38.47 62.24 3,314.92 3,213.52 800.85 1,405.76 5,961,047.41 551,290.68 0.92 1,588.77 3,820.90 38.56 62.28 3,334.49 3,233.09 808.10 1,419.54 5,961,054.75 551,304.41 0.37 1,603.95 3,845.90 38.70 62.80 3,354.02 3,252.62 815.30 1,433.39 5,961,062.04 551,318.21 1.41 1,619.15 3,870.90 38.82 63.16 3,373.51 3,272.11 822.41 1,447.33 5,961,069.24 551,332.10 1.02 1,634.37 3,895.90 38.82 63.37 3,392.99 3,291.59 829.46 1,461.33 5,961,076.38 551,346.05 0.53 1,649.59 3,920.90 38.98 63.79 3,412.44 3,311.04 836.44 1,475.39 5,961,083,46 551,360.06 1.23 1,664.81 3,945.90 39.55 64.38 3,431.80 3,330.40 843.36 1,489.62 5,961,090.47 551,374.25 2.73 1,680.12 3,970.90 39.77 65.60 3,451.05 3,349.65 850.10 1,504.08 5,961,097.31 551,388.66 3.24 1,695.49 3,995.90 39.76 65.78 3,470.26 3,368.86 856.68 1,518.65 5,961,103.99 551,403.19 0.46 1,710.84 4,020.90 39.64 65.29 3,489.50 3,388.10 863.30 1,533.19 5,961,110.69 551,417.68 1.34 1,726.18 4,045.90 39.54 65.37 3,508.76 3,407.36 869.95 1,547.67 5,961,117.44 551,432.11 0.45 1,741.51 4,070.90 38.84 65.35 3,528.14 3,426.74 876.53 1,562.03 5,961,124.12 551,446.42 2.80 1,756.70 4,095.90 37.75 65.73 3,547.76 3,446.36 882.95 1,576.13 5,961,130.63 551,460.48 4.46 1,771.59 4,120.90 37.27 64.98 3,567.59 3,466.19 889.30 1,589.96 5,961,137.07 551,474.27 2.65 1,786.22 4,145.90 36.82 64.95 3,587.55 3,486.15 895.67 1,603.61 5,961,143.53 551,487.87 1.80 1,800.74 4,170.90 35.98 64.97 3,607.67 3,506.27 901.95 1,617.05 5,961,149.90 551,501.27 3.36 1,815.03 4,195.90 35.03 65.74 3,628.02 3,526.62 908.00 1,630.25 5,961,156.04 551,514.42 4.20 1,828.99 4,220.90 34.50 65.72 3,648.56 3,547.16 913.86 1,643.24 5,961,161.98 551,527.38 2.12 1,842.68 4,245.90 33.51 64.38 3,669.28 3,567.88 919.76 1,655.92 5,961,167.96 551,540.02 4.97 1,856.14 4,270.90 33.04 66.13 3,690.18 3,588.78 925.50 1,668.37 5,961,173.79 551,552.43 4.28 1,869.34 4,295.90 32.73 65.22 3,711.18 3,609.78 931.09 1,680.74 5,961,179.46 551,564.76 2.33 1,882.37 4,320.90 31.96 64.06 3,732.30 3,630.90 936.82 1,692.83 5,961,185.27 551,576.81 3.96 1,895.28 4,345.90 30.89 66.02 3,753.63 3,652.23 942.32 1,704.64 5,961,190.85 551,588.58 5.92 1,907.83 4,370.90 30.37 65.89 3,775.14 3,673.74 947.51 1,716,28 5,961,196.11 551,600.18 2.10 1,920.04 4,395.90 29.70 64.63 3,796.79 3,695.39 952.75 1,727.64 5,961,201.42 551,611.51 3.68 1,932.08 4,420.90 29.24 63.40 3,818.55 3,717.15 958.13 1,738.70 5,961,206.88 551,622.53 3.04 1,943.99 4,445.90 28.51 65.88 3,840.44 3,739.04 963.31 1,749.60 5,961,212.13 551,633.40 5.61 1,955.63 11/4/2011 12:55::02PM Page 6 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1 E-05A Design: 1 E-05A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,761.02 4,470.90 28.41 65.24 3,862.42 3,761.02 968.24 1,760.45 5,961,217.13 551,644.21 1.28 1,967.08 4,495.90 27.53 63.63 3,884.50 3,783.10 973.29 1,771.03 5,961,222.26 551,654.75 4.64 1,978.40 4,520.90 27.31 63.22 3,906.69 3,805.29 978.44 1,781.32 5,961,227.47 551,665.01 1.16 1,989.58 4,545.90 26.59 64.47 3,928.98 3,827.58 983.44 1,791.49 5,961,232.54 551,675.15 3.66 2,000.55 4,570.90 25.75 65.54 3,951.42 3,850.02 988.10 1,801.48 5,961,237.26 551,685.11 3.85 2,011.17 4,595.90 26.05 66.54 3,973.91 3,872.51 992.53 1,811.46 5,961,241.76 551,695.06 2.12 2,021.64 4,620.90 25.80 63.07 3,996.39 3,894.99 997.18 1,821.35 5,961,246.48 551,704.91 6.15 2,032.17 4,645.90 23.89 64.86 4,019.08 3,917.68 1,001.80 1,830.78 5,961,251.15 551,714.31 8.21 2,042.34 4,670.90 24.24 67.51 4,041.90 3,940.50 1,005.91 1,840.11 5,961,255.33 551,723.61 4.54 2,052.10 4,695.90 24.62 64.47 4,064.67 3,963.27 1,010.12 1,849.55 5,961,259.60 551,733.02 5.25 2,062.01 4,720.90 22.29 65.45 4,087.60 3,986.20 1,014.33 1,858.56 5,961,263.87 551,742.00 9.45 2,071.60 4,745.90 23.03 68.99 4,110.67 4,009.27 1,018.06 1,867.44 5,961,267.65 551,750.86 6.21 2,080.76 4,770.90 22.09 64.84 4,133.76 4,032.36 1,021.81 1,876.26 5,961,271.46 551,759.65 7.39 2,089.90 4,795.90 23.01 67.59 4,156.85 4,055.45 1,025.67 1,885.03 5,961,275.38 551,768.40 5.60 2,099.08 4,820.90 20.74 69.45 4,180.05 4,078.65 1,029.09 1,893.70 5,961,278.86 551,777.04 9.49 2,107.88 4,845.90 21.21 64.64 4,203.39 4,101.99 1,032.58 1,901.93 5,961,282.40 551,785.25 7.14 2,116.41 4,870.90 21.09 69.92 4,226.71 4,125.31 1,036.06 1,910.24 5,961,285.94 551,793.53 7.63 2,124.99 4,895.90 19.32 69.21 4,250.17 4,148.77 1,039.07 1,918.33 5,961,289.01 551,801.60 7.15 2,133.09 4,920.90 19.65 66.15 4,273.74 4,172.34 1,042.24 1,926.04 5,961,292.22 551,809.29 4.29 2,141.01 4,945.90 20.41 70.48 4,297.23 4,195.83 1,045.40 1,934.00 5,961,295.43 551,817.22 6.66 2,149.11 4,970.90 18.15 69.59 4,320.83 4,219.43 1,048.21 1,941.75 5,961,298.30 551,824.96 9.12 2,156.83 4,995.90 18.86 65.74 4,344.53 4,243.13 1,051.23 1,949.09 5,961,301.37 551,832.28 5.65 2,164.37 5,000.00 18.77 66.36 4,348.41 4,247.01 1,051.77 1,950.30 5,961,301.91 551,833.48 5.37 2,165.63 TOW @ 5000'MD,4348'TVD:1702'FSL,1320'FWL-Sec15-T11N-R10E 5,000.02 18.77 66.36 4,348.43 4,247.03 1,051.77 1,950.30 5,961,301.91 551,833.49 0.00 2,165.64 9 5/8"TOW 5,016.50 21.00 66.36 4,363.93 4,262.53 1,054.02 1,955.44 5,961,304.19 551,838.61 13.58 2,171.00 5,076.50 21.00 66.36 4,419.94 4,318.54 1,062.64 1,975.14 5,961,312.95 551,858.25 0.00 2,191.58 5,100.00 19.84 66.87 4,441.97 4,340.57 1,065.90 1,982.66 5,961,316.25 551,865.75 5.00 2,199.41 5,200.00 14.92 69.91 4,537.37 4,435.97 1,076.99 2,010.38 5,961,327.53 551,893.39 5.00 2,227.69 5,286.57 10.72 74.72 4,621.77 4,520.37 1,082.95 2,028.63 5,961,333.61 551,911.60 5.00 2,245.42 5,300.00 10.72 74.72 4,634.96 4,533.56 1,083.61 2,031.04 5,961,334.28 551,914.00 0.00 2,247.68 5,400.00 10.72 74.72 4,733.21 4,631.81 1,088.51 2,048.99 5,961,339.31 551,931.92 0.00 2,264.51 5,500.00 10.72 74.72 4,831.47 4,730.07 1,093.42 2,066.94 5,961,344.33 551,949.84 0.00 2,281.34 5,600.00 10.72 74.72 4,929.72 4,828.32 1,098.32 2,084.90 5,961,349.35 551,967.76 0.00 2,298.17 5,700.00 10.72 74.72 5,027.97 4,926.57 1,103.23 2,102.85 5,961,354.38 551,985.67 0.00 2,315.00 5,800.00 10.72 74.72 5,126.23 5,024.83 1,108.13 2,120.80 5,961,359.40 552,003.59 0.00 2,331.82 5,900.00 10.72 74.72 5,224.48 5,123.08 1,113.04 2,138.75 5,961,364.42 552,021.51 0.00 2,348.65 5,954.49 10.72 74.72 5,278.01 5,176.61 1,115.71 2,148.53 5,961,367.16 552,031.27 0.00 2,357.82 6,000.00 11.78 64.35 5,322.66 5,221.26 1,118.84 2,156.80 5,961,370.34 552,039.52 5.00 2,366.14 6,100.00 15.06 47.90 5,419.95 5,318.55 1,131.97 2,175.65 5,961,383.60 552,058.28 5.00 2,389.00 6,200.00 19.08 37.73 5,515.55 5,414.15 1,153.62 2,195.30 5,961,405.38 552,077.78 5.00 2,418.00 6,300.00 23.48 31.11 5,608.72 5,507.32 1,183.62 2,215.61 5,961,435.51 552,097.89 5.00 2,452.94 6,400.00 28.06 26.52 5,698.76 5,597.36 1,221.74 2,236.41 5,961,473.77 552,118.44 5.00 2,493.53 6,441.45 30.00 25.00 5,735.00 5,633.60 1,239.86 2,245.15 5,961,491.94 552,127.05 5.00 2,511.95 11/4/2011 12:55:02PM Page 7 COMPASS 2003.16 Build 69 Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-05A Design: 1 E-05A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,637.00 6,445.37 30.00 25.00 5,738.40 5,637.00 1,241.64 2,245.98 5,961,493.72 552,127.87 0.00 2,513.74 Top HRZ 6,500.00 30.00 25.00 5,785.71 5,684.31 1,266.39 2,257.52 5,961,518.55 552,139.24 0.00 2,538.60 6,600.00 30.00 25.00 5,872.31 5,770.91 1,311.71 2,278.65 5,961,564.00 552,160.07 0.00 2,584.12 6,658.99 30.00 25.00 5,923.40 5,822.00 1,338.44 2,291.12 5,961,590.81 552,172.36 0.00 2,610.97 Top Kalublk(Base HRZ) 6,700.00 30.00 25.00 5,958.91 5,857.51 1,357.02 2,299.78 5,961,609.45 552,180.90 0.00 2,629.64 6,745.60 30.00 25.00 5,998.40 5,897.00 1,377.69 2,309.42 5,961,630.17 552,190.39 0.00 2,650.39 K-1 Marker 6,800.00 30.00 25.00 6,045.52 5,944.12 1,402.34 2,320.91 5,961,654.90 552,201.73 0.00 2,675.15 6,829.89 30.00 25.00 6,071.40 5,970.00 1,415.88 2,327.23 5,961,668.49 552,207.95 0.00 2,688.76 Top C Sand 6,900.00 30.00 25.00 6,132.12 6,030.72 1,447.65 2,342.04 5,961,700.35 552,222.55 0.00 2,720.67 6,951.13 30.00 25.00 6,176.40 6,075.00 1,470.83 2,352.85 5,961,723.59 552,233.20 0.00 2,743.95 Top B Shale-1E-05A T1(wp06) 7,000.00 30.00 25.00 6,218.72 6,117.32 1,492.97 2,363.17 5,961,745.80 552,243.38 0.00 2,766.19 7,100.00 30.00 25.00 6,305.32 6,203.92 1,538.29 2,384.31 5,961,791.25 552,264.21 0.00 2,811.71 7,104.71 30.00 25.00 6,309.40 6,208.00 1,540.42 2,385.30 5,961,793.39 552,265.19 0.00 2,813.85 Top A6 7,115.10 30.00 25.00 6,318.40 6,217.00 1,545.13 2,387.50 5,961,798.12 552,267.35 0.00 2,818.58 Top A5 7,139.35 30.00 25.00 6,339.40 6,238.00 1,556.12 2,392.62 5,961,809.14 552,272.40 0.00 2,829.62 Top A4 7,200.00 30.00 25.00 6,391.93 6,290.53 1,583.60 2,405.44 5,961,836.70 552,285.04 0.00 2,857.23 7,214.40 30.00 25.00 6,404.40 6,303.00 1,590.13 2,408.48 5,961,843.25 552,288.04 0.00 2,863.78 Top A3 7,228.26 30.00 25.00 6,416.40 6,315.00 1,596.41 2,411.41 5,961,849.55 552,290.92 0.00 2,870.09 Top Miluveach 7,257.13 - 30.00 25.00 6,441.40 . 6,340.00 1,609.49- 2,417.51 - 5,961,862.67 552,296.93 0.00 2,883.23 BHL @ 7257'MD,6441'TVD:2260'FSL,1789'FWL-Sec15-T11 N-R10E-TD(Miluveach) Targets Target Name -hfUmiss target Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 1E-05A T1(wp06) 0.00 0.00 6,176.40 1,470.83 2,352.85 5,961,723.59 552,233.20 -plan hits target center -Circle(radius 150.00) 11/4/2011 12:55:02PM Page 8 COMPASS 2003.16 Build 69 ,- , ;,, , ,,..„ '\ ) L., t 1 Vt, ,I , Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 1E-05 Company: ConocoPhillips(Alaska)Inc.-Kupt TVD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Project: Kuparuk River Unit MD Reference: 1 E-05A @ 101.40ft(Nor3(71.4+30)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-05 Survey Calculation Method: Minimum Curvature Wellbore: Plan:1E-05A Design: 1E-05A(wp06) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (') 7,257.13 6,441.40 5 1/2" 5-1/2 6-3/4 2,411.90 2,208.24 13 3/8" 13-3/8 17-1/2 5,000.02 4,348.43 9 5/8"TOW 9-5/8 13-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (") (') 7,104.71 6,309.40 Top A6 0.00 7,257.13 6,441.40 TD(Miluveach) 0.00 6,658.99 5,923.40 Top Kalubik(Base HRZ) 0.00 6,829.89 6,071.40 Top C Sand 0.00 7,214.40 6,404.40 Top A3 0.00 6,951.13 6,176.40 Top B Shale 0.00 7,228.26 6,416.40 Top Miluveach 0.00 7,115.10 6,318.40 Top A5 0.00 7,139.35 6,339.40 Top A4 0.00 6,745.60 5,998.40 K-1 Marker 0.00 6,445.37 5,738.40 Top HRZ 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 5,000.00 4,348.41 1,051.77 1,950.30 TOW @ 5000'MD,4348'TVD:1702'FSL,1320'FWL-Sec15-T11 N-R1OE 7,257.13 6,441.40 1,609.49 2,417.51 BHL @ 7257'MD,6441'TVD:2260'FSL,1789'FWL-Sec15-T11 N-R1OE 11/4/2011 12:55:02PM Page 9 COMPASS 2003.16 Build 69 N 01 U L 01 a M3 C W 0 J J f QL Q! = N r lin M as C iii E 1 �> c N y • V C /' O N v v. ` a N N 0 ITNM CON O O d t0 a O i w G 2 O i c a ',1. 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On `QnN oaLno Zo ttno ' Zco U N 8w 4.) m R moc0m o RI o � <n G c c8— Ili ni Ac of a co aN rn ad m aNa - r> 0.E17;C) Q S 0 Q i C) 0.E 0 M o 4 NI. b N Y pc Yom d d Y 1<y c b um t M0uw P u r. o o u -AUAAUo UAo B Uo Jr\ Lb [ NilA L 1E-05A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 8-1/2" Hole with 5-1/2" Liner Event lvel Mitigation Strategy LeWindow/Open Hole leak Moderate - Squeeze cement at 9-5/8"casing window off less than required Hole instability while Moderate Utilize a mud weight to stabilize formations without drilling shale section sustaining losses Directional control Moderate Placement of KOP and bottom hole location to allow for 5° • DLS. Drill 8-1/2"hole with proper mud weight for hole stability, Run liner to bottom Moderate directional plan with 5° DLS and a tangent from HRZ to TD, and run 5-1/2" liner. Reduced trip speeds, real time equivalent circulating Hole swabbing/surging Moderate • density (ECD)monitoring, mud rheology, and proper hole filling. Pump and rotate out of hole as necessary. Abnormal Reservoir BOPE drills, keep mud weight above 10.5 ppg, check for Pressure Low flow during connections and if needed increase mud weight. Reduced pump rates, real time equivalent circulating Lost Circulation Low . density(ECD)monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. Tracking along 9-5/8" Perforate 9-5/8"casing and squeeze cement in 9-5/8"X casing during window Moderate 12-1/4" annulus. milling Cement Bonding Moderate Run liner with centralization for standoff. Reciprocate during circulation and pump 35%excess cement. Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, and standard well control practices. *See Well Plan for more detailed risk information and offset data. 1E-05A SIDETRACK O Arctic Pack Job done in ��� 8/13/1980 �� 3 %" 49 bbls cement TRMAXX- 116 bbls diesel ConocoPhillips CMT SCSSV No record of press.test , 2.813" ID @+/, 1,910'MD/ 1,800'TVD 13-3/8"72#N80 casing @ 2,416'MD/2,210'TVD 3-'/z"9.3#,L-80,EUE Tubing from+/- 4,750'MD Baker ZXP liner F packer @ g KOP in 9-5/8"@ +/-4,800'MD +/-5,000'MD/4,348'TVD (WP06) (WP06) GLM# TVD ft MD ft Valve Type Mandrel Type 1 2,500 2,771 Dummy 3-1/2" x 1-1/2" MMG 2 3,800 4,399 Dummy 3-1/2"x 1-1/2" MMG 3 4,750 5,417 Dummy 3-1/2"x 1" KBG-2-9 'it 4 5,435 6,116 Dummy 3-1/2"x 1" KBG-2-9 5 5,935 6,672 SOV 3-1/2"x 1" KBG-2-9 'SOV(annulus to tubing shear) Cement retainer C +/-5,100'MD 3-'/2"9.3#,L-80,IBT-M Special Squeeze perfs > A Clearance Tubing+/-4,800'-6,750'MD below retainer V \ Tubing Cut @ :, 111, �\\,/ 5,246'MD .• \ 4P\ Backer Production Packer @+/-6,750'MD/5,995' 7"liner Seal TVD(WP06) . e_ Assembly @ 6,399'MD / -- 4 3 V2" HES"X"selective . nipple w/2.813" ID @+/- L. 6,800'MD/6,045'TVD Packer @ ��, ��, (WP06) 6,587' / a Perfs @ 6,766'-6,902' 3 ''/2" WLEG @+/-6,8 :' MD/6,005'TVD,50' Packer above Kuparuk C sand. 6,923' �� (WP06) 5-1/2" 15.5#BTCM Perfs 7,257'MD/6,441'TVD 6,976'-6,994' c-T-1) s r Perfs @ s-O` nti 0 A 470--'--- ...- :.:.i.:. 0--'--- 7,000'-7,014' 'C' K "r. 7"26#K-55 7,195'MD/6,514'TVD HB 11/28/11 1E-05A SIDETRA( . V Arctic Pack Job done in ►;e rili� 8/13/1980 2Wells 3 'h„ 49 bbls cement TRMAXX- 116 bbls diesel ConocoPhillips CMT SCSSV I. No record of press.test aee� 2.813"ID @ -: 1,910'MD/ �-*�,.r' 1,800'TVD [.. 1 13-3/8"72#N80 casing @ 2,416'MD/2,210'TVD 3-'/2"9.3#,L-80,EUE Tubing from+/- 4,750'MD Baker ZXP line , ;. packer @ KOP in 9-5/8"@ +/-4,800'MD +1-5,000'MD/4,348'TVD (WP06) (WP06) GLM# ND ft MD ft Valve Type Mandrel Type 1 2,500 2,771 Dummy 3-1/2"x 1-1/2" MMG 2 3,800 4,399 Dummy 3-1/2"x 1-1/2" MMG 3 4,750 5,417 Dummy 3-1/2"x 1" KBG-2-9 NVA:' o; `'. 4 5,435 6,116 Dummy 3-1/2"x 1" KBG-2-9 ii ..,z a„,,. 5 5,935 6,672 SOV 3-1/2"x 1" KBG-2-9 < `;.: 1 *SOV(annulus to tubing shear) Cement retainer C- +/-5,100'MD .:......................: 3-'h"9.3#,L-80,IBT-M Special Squeeze perf�_::::: :'::::::::::::::::?::m Clearance Tubing+1-4,800'-6,750'MD below retainer is Tubing Cut @\\ j...ai •�. ....... 5,246'MD Backer Production Packer @+/-6,750'MD/5,995' 7"liner Seal // // TVD(WP06) Assembly 6,399'MD 3 'A" HES"X"selective @ / nipple w/2.813"ID @+/- �� 6,800'MD/6,045'TVD Packer @ '•••• • • ' (WP06) 6,587' �� ��� :_: �, Perfs @ -..y`.]..: 6,766 6,902' 3 '''A" WLEG @+/-6,8 MD/6,005'TVD,50' Packer @ above Kuparuk C sand. 6,923' �� ��4 (WP06) 5-1/2" 15.5#BTCM 7,257'MD/6,441'TVD Perfs @ ">:::-::.: :,:':-::: . 6,976'-6,994' ................. ................. .. ............. ................. ................. ................. ................. ................. .................. ................. ............... . ................. . .. ............ . .. ......... . .......... ..it- Perfs @ -:::::•:•:•:::::::•:•:•::::•:::::::= 7,000'-7,014' .................. ................. ................. ................. ................. 7"26#K-55 7,195'MD/6,514'TVD HB 11/28/11 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/ i CHECKLIST WELL NAME f<e-v\ PTD# l// C (ice Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ei-2_2( VG( L VOOL: / f�C _� ITL ee_e o;/ Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter ADD-ONS CHECK (OPTIONS) WHAT TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 I __ Cn a c) .g g cn a 0. I C) D 0 u) ° co o a 3 Cl r o r 3 m m H 13 0 0 N N (o N - _s m N.co 001 0 -4 0 0, 0 0 0) ;./'9 O n N ,„,. N .d. N 0) 3 p W p ID p ID O CD .. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. FINAL WELL REPORT MUDLOGGING DATA 1E-05A Provided by: Approved by: Laird Little Compiled by: Tollef Winslow Greg Hammond Robert Athan Distribution: 2/28/12 T.D. Date: 02/15/2012 1E-05A 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 2 1.1 Equipment Summary ...................................................................................................................... 2 1.2 Crew................................................................................................................................................ 2 2 WELL DETAILS ..................................................................................................................................... 3 2.1 Well Summary................................................................................................................................. 3 2.2 Hole Data ........................................................................................................................................ 3 2.3 Daily Activity Summary ................................................................................................................... 4 3 GEOLOGICAL DATA ............................................................................................................................. 6 3.1 Lithostratigraphy ............................................................................................................................. 6 3.2 Mudlog Summary ............................................................................................................................ 7 3.2.1 Window to HRZ ....................................................................................................................... 7 3.2.2 HRZ ......................................................................................................................................... 7 3.2.3 Kalubik ..................................................................................................................................... 8 3.2.4 Kuparuk “C” Sand .................................................................................................................... 8 3.2.5 “B” Shale .................................................................................................................................. 8 3.2.6 Kuparuk “A” Sand .................................................................................................................... 9 3.2.7 Miluveach ................................................................................................................................ 9 3.3 Connection Gases ........................................................................................................................ 11 3.4 Trip (Wiper) Gases........................................................................................................................ 11 3.5 Sampling Program / Sample Dispatch .......................................................................................... 12 3.6 Show Reports ............................................................................................................................... 13 4 PRESSURE / FORMATION STRENGTH DATA ................................................................................. 15 4.1 Pore pressure evaluation .............................................................................................................. 15 4.2 Quantitative Methods .................................................................................................................... 15 5 DRILLING DATA .................................................................................................................................. 17 5.1 Survey Data .................................................................................................................................. 17 5.2 Bit Record ..................................................................................................................................... 18 5.3 Mud Record .................................................................................................................................. 18 6 DAILY REPORTS ................................................................................................................................ 19 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Well Data on CD/ROM 1E-05A 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 Effective Circulating Density (ECD) From Sperry-Sun 5063’ to TD 0 Hook Load / Weight on bit Totco WITS Feed 2 hrs Totco data feed in and out during network interruptions Mud Flow In Derived from Strokes/Minute and Pump Output 2 hrs See above Mud Flow Out Totco WITS Feed 2 See above Mudlogging unit computer system HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 Mudlogging unit DAC box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss Totco WITS Feed 2 hrs See above Pump Pressure Totco WITS Feed 2 hrs See above Pump stroke counters Totco WITS Feed 2 hrs See above Totco Well Monitoring Components Totco computer networked in Mudlogging Unit 2 hrs See above Rate of penetration Totco WITS Feed 2 hrs See above RPM Totco WITS Feed 2 hrs See above Torque Totco WITS Feed 2 hrs See above 1.2 Crew Unit Type : Steel Arctic Unit Number : ML030 Mudloggers Years *1 Days *2 Sample Catcher Years Days Tollef Winslow 4 25 Dickey Hudgins 2 25 Greg Hammond 1 25 Robert Athan 0.5 25 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 1E-05A 3 2 WELL DETAILS 2.1 Well Summary Well: 1E-05A API Index #: 50-029-20479-01-00 Field: Kuparuk River Field Surface Coordinates: 651’ FSL, 631’ FEL, Sec. 16, T11N, R10E Borough: North Slope Primary Target Depth: 7257’ State: Alaska TD Depth: 7273’ Rig Name / Type: Nordic 3, Arctic Triple Suspension Date: Primary Target: A- and C-sands License: Spud Date: February 9, 2012 Ground Elevation: 69.5’ MSL Completion Date: February 16, 2012 RT Elevation: 101.1’ MSL Completion Status: Ran 5.5” liner to TD Secondary Target: Depth: None Classification: Production TD Date: February 15, 2012 TD Formation: Miluveach Days Testing: None Days Drilling: 7 2.2 Hole Data Hole Section Maximum Depth TD Formation Mud Weight (ppg) Dev. (oinc) Coring Casing/ Liner Shoe Depth LOT (ppg) MD (ft) TVDSS (ft) MD (ft) TVD (ft) 8 ½” 7273’ 6450’ Miluveach 10.75 33.32 No 5.5” 7268’ 6451’ 15.8 Additional Comments 1E-05A was drilled by setting a whipstock in the existing 9-5/8” casing and milling a window. Top of window = 5014.74’, bottom of window = 5031.85’. 30’ new formation was drilled to 5062’ and a FIT = 15.8 EQMW was established. Wiper trips were performed at 5594’ (4 stands), 7010’ (19 stands), and 7273’ (5 stands) with no problems. No problems were encountered in the drilling of this well. 1E-05A 4 2.3 Daily Activity Summary 1/30/12: Continue to RIH with BHA #2 from 1,001’ to 5,259’, soft tag tubing stub; pull up to 5,246’, circulate 1.5 hole volumes at 8 bpm, 350 psi; B/D to TD; POOH from 5,259’ to 137’; lay down BHA #2, clean and clear floors; suspend e-line operation due to CPAI SOP; makeup bullnose and crossover; RIH with 5” DP to 2929’; rig up circulating hose, circulate hole 1 DP volume every 2 hours, continue to wait on weather. 1/31/12: Continue to wait on weather, circulate 1 DP volume every 2 hours; circulate through choke to warm fluid 2.5 BPM, 2000 psi; continue to wait on weather, circulate 1 DP volume every 2 hours. 2/1/12: Continue to wait on weather, circulate 1 DP volume every 2 hours 2/2/12: Cont. to wait on weather, circ. 1 DP vol every 2 hrs; load MWD tools, move DC in derrick; POOH from 2929’ to surface; pickup 4.5” test joint, remove 6’ PUP from JT install in slips; rig up e-line; RIH w/ gyro and memory. cal. Log on e-line to 5200’; POOH from 5200’ @ 50ft/min.; PJSM w/ e-line crew; make up 3.375”x10’ perf. gun, RIH to 5080’, fire guns from 5070’ to 5080’, POOH, lay down fired gun, make up string; shot. 2/3/12: m/u String Shot. RIH w/CCL & String Shot. Shot. POOH RU E-Line. RIH w/Baker cement retainer on 5"DP. Logged hole to Depth of Cement Retainer @ 5039'. Top of retainer 5037'.POOH. Set Baker Cement Retainer. Run Cement. test Cement and Cement Retainer. RIH w/Baker "G" Lock-Set RBP 2/4/12: Cont. RIH w/ BHA #5 RBP from 1000’ to 2450’; set RBP @ 2431’; POOH to 2316’; r/u to dump sand, dumped 44 sks @ 5 min/sk; circ 0.5 BPM 1 DP vol; pull up 2 stands, let sand settle; RIH 2 stands, tag up @ 2390’; POOH to surface, lay down RBP tool; nipple down BOP; nipple down tubing head; make up 9-5/8 spear, spear casing, pull up 100k tension; make up bumper sub on spear, attempt to re-land; lay down bumper sub and spear, consult with town for plan forward; nipple up BOP. 2/5/12: Nipple up BOP; load Baker tools, make up BHA #6; RIH, locate collars @ 161’ and 203’ with 9-5/8” msc; rig up hoses to cuttings box; cut casing @ 183’; circulate out arctic pack with hot water 2 bpm 80 psi; stand back collars, lay down msc; pick up, make up spear; unload 9-5/8” casing @ 100k; gas breaking out of arctic pack, circ through choke to kill tank @ 4 bpm 120 psi, pumped 100 bbl, monitored well; rig up casing equip; POOH with 9-5/8” casing, lay down in pipe shed, excessive trouble breaking out connections; clear floor, load tools; rig down casing equip; make up back off tool BHA #10; RIH to 410’; fill pipe with water; rig up test pump hoses; back off @ 204’ 6 turns; rig down test pump hoses; POOH with BHA #10. 2/6/12: Clean floor; m/u BHA #11 9-5/8” casing spear; RIH, engage fish @ 182’; circ b/u @ 3 bpm 60 psi, b/d TD; POOH, L/D fish; clear floor, offload tools and casing; r/u casing equipment; RIH with 9-5/8” casing to 197’; r/u cross-over to TD; r/u LRS; freeze protect with diesel 2 bmp 200 psi, 50 bbl pumped; screw into casing stub with 10.5k torque; r/u test equipment; test 9-5/8” casing 3500 psi for 30 min; r/d casing equipment, clear floor; nipple down BOP and lift; pull 100k tension on casing, set emergency slips, cut casing; continue to nipple down BOP and rack back; install packoff; tap and clean LDS. 2/7/12: Continue to tap and clean LDS; nipple up tubing head, test pack off 3800 psi 15 min; nipple up BOPE; rig up test equipment, grease choke; test BOPE; rig down test equipment, pull test plug, set wear ring; make up BHA #12 retrieving head, RIH, tagged sand @ 2385’; pump 8 bpm circulate out sand 120 psi, wash to 2436’; release RBP, monitor well, circ bottoms up 5 bpm @ 70 psi; POOH, lay down BHA #12; clear floor, prep for BHA #13; make up BHA #13, RIH. 2/8/12: Continue to RIH with BHA #13 to tag @5030’, wash to 5037’; solid tag @ 5037’; recirc 22 bbl hi-vis sweep; swap well to 9.6 @ 4 bpm; ICP 120 FCP 240 psi; blow down TD; pull from 5037’ to 4904’; cut and slip drill line; rig up circ hose, attain parameters, sync totco and MWD; POOH with BHA #13; pump dry job; make up BHA #14 whipstock/mill assembly; RIH to 372’; circ 475 bbl @ 920 psi, achieve successful shallow pulse test; continue to RIH from 372’ to 3093’. 1E-05A 5 2/9/12: Continue in hole with BHA #14 whipstock/mill assembly from 3093’; tag at 5037’; orient whipstock’ circ @ 10 bpm 900 psi; set whipstock per Baker rep; 1.5 rot wght; 10 bpm 890 psi; milled from 5014’ to 5015.5’; BPTD; set TD torque to 18k; continue to mill from 5015.5’ to 5023’ 130 rpm 10 bpm 850 psi 5k free torque; continue mill to 5036’ 100 rpm 10-15k WOB 425-450 gpm 950-1000 psi 9k torque off bottom 12k on bottom; continue mill from 5036’ 100 prm 450 gpm 1020 psi 15k WOB 2’/hr ROP 5k torque 142 rpm; mill 5045’ to 5048’ at 60 rpm 400 gpm 880 psi 3’/hr ROP 12k torque on bottom 142 rpm 9k torque off bottom. 2/10/12: Cont mill from 5048’ 400 gpm 880 psi 60 rpm 15-17k wob; from 5049.5’ to 5050.5’ 15-17k wob 13k torque on bottom 500 gpm 1150 psi; 450 gmp 1000 psi 15k wob 12k torque on bottom 5050.5’ to 5051’; 500 gpm 1100 psi 5051.5’ to 5053’ 13k torque on bottom 17-18k wob; continue to mill from 5053’ 12 bpm 1200 psi 1’/hr ROP 5k wob 12k torque; TD @ 5062.74’; pumped super sweep @ 12 bpm 1200 psi; rig up test equip, perform FIT test EMO 15.8 ppg; pumped 20 bbl dry job 4 bpm 270 psi; POOH from 5054’; lay down BHA #14; clear floor; pick up magnet and swizzle stick; wash stack @ 8 bpm 130 psi; clean; l/d magnet swizzle assembly; m/u BHA #16 cleanout magnet/mill. 2/11/12: Continue to make up BHA #16, RIH, tag bottom @ 5063’; pump 30 bbl super sweep; swap hole to 9.6 drill mud; POOH; lay down BHA #16, clean magnets; offload Baker tools/magnets, clear floor; make up BHA #17; download MWD tools; shallow pulse test 400 gpm 790 psi, good test; continue to pick up BHA; RIH to 2005’, fill pipe. 2/12/12: Continue in with BHA #17 from 200’ to 4842’; establish parameters, orient; lower through whipstock to 5044’; drill from 5062’ to 5594’; short trip, back ream 5594’ to 5220’; RIH 5220’ to 5594’; continue drilling to 5620’. 2/13/12: Continue to drill from 5620’ to 6300’ MD 2/14/12: Continue drilling from 6380’ to 7011’; back ream out of hole from 7011’ to 5325’; circulate bottoms up; run into hold from 5325’ to 6729’ MD. 2/15/12: Continue to RIH 6991’ to 7011’; drill ahead from 7011’ to 7273’ TD; back ream to 6818; RIH from 6818’ on elevators, hole in good condition; while circulating, condition mud to 11 ppg; back down to TD, monitor hole; POOH from 7273’ to 4925’; pump dry job; hang block; cut and slip drill line; continue POOH with 5” DP from 4925’ to 3236’ MD. 2/16/12: Continue to POOH from 3236’ to BHA; lay down BHA, unload nukes, download LWD, continue to lay down BHA; clear and clean floor; bring up tools; prep for 5.5” liner run; clear off floor equipment; make up 5.5” liner, fill pipe every 10 joints; circulate 60 bbl at 3 bpm at 2566’; clear off floor equipment; continue to run in with 5” drill pipe from 2566’; broke circulation at 5000’; rig up cementing head; work up and down and condition mud 2 bpm 420 psi. 1E-05A 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the town geologist. FORMATION PROGNOSED LWD PICK MD (ft) TVDSS (ft) MD (ft) TVDSS (ft) Top HRZ 6445.96 5635.40 Not Available Not Available Top Kalubik (Base HRZ) 6659.58 5820.40 6675 5851 K-1 Marker 6746.18 5895.40 6755 5922 Top C Sand 6830.47 5968.40 6838 5984 Top B Shale 6951.72 6073.40 6945 6083 Top A6 7105.29 6206.40 7091 6200 Top A5 7115.68 6215.40 7097 6206 Top A4 7139.93 6236.40 7116 6223 Top A3 7214.99 6301.40 7207 6298 Top Miluveach 7228.84 6313.40 Not Available Not Available TD (Miluveach) 7257.71 6338.40 Not Available Not Available 1E-05A 7 3.2 Mudlog Summary 3.2.1 Window to HRZ 5014’ to 6450' MD (4258' to 5650' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 610 0 81 321 6 62 This interval includes siltstone, claystone, sand, and sandstone, until approximately 5900’, when carbonaceous shale is encountered similar to the underlying HRZ. Siltstone fairly uniform olive black to dark olive gray, poorly indurated, across the entire formation. Carbonaceous material is added to the siltstone about 5900’ and is uniformly laminated throughout. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5723 90 14012 461 99 0 0 0 0 5802 101 15251 504 0 0 0 0 0 5981 108 16015 793 108 0 0 0 0 6136 161 25063 1618 468 67 110 36 37 6199 312 39264 3096 1080 154 260 67 69 6299 321 39912 3477 1029 114 222 45 42 3.2.2 HRZ 6450’ to 6675' MD (5650' to 5851' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 202 3 78 210 34 123 The HRZ includes carbonaceous shales and some interbedded sands and minor ash fall tuff. The shale is typical HRZ, variably organic claystone with slight to moderate and rare bookleaf partings of carbon matter or carbon residue, and traces of pyrite associated with the carbon matter. Some thin laminations of sandstone, siltstone, and ash, also with carbon partings, and some interbedded sandstone is also noted. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6524 210 30278 2582 936 103 210 58 106 6539 202 27145 2088 718 81 162 36 41 6594 181 24562 2068 768 83 169 35 44 1E-05A 8 3.2.3 Kalubik 6675’ to 6838’ MD (5851’ to 5984’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 245 4 100 545 26 149 This is primarily a shale section with dark grayish brown to dark brownish gray to brown shales, carbonaceous in part, and some slightly to moderately calcareous grading to mudstone. Occasional interlaminated siltstone and sandstone, and traces of calcite fracture fill were noted. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6676 144 19654 1812 900 135 273 101 126 6707 145 22316 1583 595 81 167 73 70 6742 545 81916 5156 1549 182 336 83 135 6832 430 55970 3325 984 114 203 48 46 3.2.4 Kuparuk “C” Sand 6838’ to 6945' MD (5984' to 6083' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 176 2 85 698 18 354 Kuparuk “C” Sand (6838-6945’) The Kuparuk “C” was light brownish gray to light olive gray with the brownish coloring due largely to oil staining, and the olive coloring due to glauconite and oil. The top of the sand was unconsolidated. Grains in the upper sandstone were fine to medium. The sample taken from 6880’ to 6940’ included consolidated matrix supported sandstone and loose grains. Glauconite was present. Overall the trend grain size was a downward trending from medium to lower fine. Fluorescence was a bright uniform golden yellow with a blue white instantaneous blooming to streaming cut. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6848 425 43110 5265 2954 933 2133 422 430 6867 424 45423 7209 3347 586 1193 270 282 6927 698 73423 9958 4421 795 1312 360 429 3.2.5 “B” Shale 6945’ to 7091' MD (6083' to 6200' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 145 3 70 432 44 201 1E-05A 9 “B” Shale (6945-7091’) The olive black to olive gray Kuparuk “B” interval is predominantly siltstone with carbonaceous siltstone, sand/sandstone, shale, and clay. The siltstone grades to clayey siltstone and occasionally silty claystone or carbonaceous siltstone with rare carbonaceous interbeds. The associated sand and sandstone was predominantly quartzose. The sand/sandstone decreases from abundant to scattered with depth. The siltstone becomes well-sorted and occasionally grades to lower very fine sandy siltstone in the lower end of the interval. Scattered to rare well-indurated shale was observed throughout the interval. Minor oil indicators were observed: moderate to faint white fluorescence, bright white to yellow residue fluorescence, bright white to yellow residue fluorescence, trace to light amber to straw cut, and trace yellow to dark straw residue. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6947 280 27534 2348 1110 196 440 122 132 6971 432 50494 5306 2385 439 844 340 524 6995 405 48056 5395 2342 294 724 312 316 7038 208 26543 2009 750 87 292 68 118 3.2.6 Kuparuk “A” Sand 7091’ to 7221' MD (6200' to 6310' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 225 6 47 539 36 158 Kuparuk “A” Sand (7091-7221’) The Kuparuk “A” was medium dark gray to medium gray with brown coloring due in large part to oil staining. Grains were lower very fine to upper very fine lower, dominantly very fine upper, subangular to subrounded, dominantly quartz and minor other silicates and lithics. Observed porosity and permeability was fair. Fluorescence was a dull yellow, with a streaming bright white cut, light amber visual cut with light brown residual cut. There was bright yellow residual fluorescence. Oil bleebs where entrained within sandstone and siltstone as well as free oil was in the sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7102 446 48014 4956 1976 262 594 264 226 7111 355 41641 3769 1452 163 324 136 144 7125 539 55877 6259 2701 356 671 163 205 7152 299 30857 3766 1171 247 401 194 208 3.2.7 Miluveach 7221’ to 7273' MD (6310' to 6351' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 1442 4 121 100 31 73 1E-05A 10 The Miluveach borders on being a siltstone or a shale. It is medium dark gray to medium light gray with thin siltstone/shale beds with clay laminations. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7257 100 16000 883 338 35 132 49 67 1E-05A 11 3.3 Connection Gases No connection gasses were observed during the drilling of the well. 3.4 Trip (Wiper) Gases 1unit = 0.05% Methane Equivalent Depth (feet) Trip to (feet) Gas (units) Downtime (hours) 5062’/4404’ 0 19 16.5 5594’/4919’ 5220’ 28 1.5 7010’/6232’ 5325’ 275 8 7273’/6451’ 6818’ 72 1.5 7273’/6451’ 0’ (running liner) 98 27.5 1E-05A 12 3.5 Sampling Program / Sample Dispatch Samples were collected for logging purposes only. No reference sets were kept. Frequency was locally altered according to drill rate constraints and zones of interest, but was at least every 20’. 1E-05A 13 3.6 Show Reports 1E-05A 14 1E - 0 5 A 15 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Th e w e l l w a s d r i l l e d s l i g h t l y o v e r b a l a n c e d a s w a s i n d i c a t ed b y n o c o n n e c t i o n g a s s e s a n d l o w t r i p a n d w i p e r g a s s e s . 4. 1 P o r e p r e s s u r e e v a l u a t i o n Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) In t e r v a l T o p s P o r e P r e s s u r e ( M W ) Tr e n d In d i c a t o r s MD (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Ki c k o f f P o i n t S l t s t 6 0 % CS l t s t 2 0 % , Cl y s t 1 0 % , S d 10 % 50 1 4 4 2 5 8 9 . 6 1 0 . 2 U p B G , C G , E C D HR Z C S l t s t 5 5 % Sl t s t 3 0 % , Cl y s t 1 0 % , As h 5 % 64 5 0 5 6 5 0 1 0 . 2 1 0 . 5 U p B G , C G , E C D Ka l u b i k S l t s t 7 0 % Cl y s t 2 0 % , CS l t s t 1 0 % 66 7 5 5 8 5 1 1 0 . 5 1 0 . 8 U p B G , C G , E C D Ku p a r u k C S s t 7 0 % S d 3 0 % 6 8 3 8 5 9 8 4 1 0 . 8 1 0 . 8 E v e n B G , C G , E C D B S h a l e S l t s t 7 0 % Sd 2 0 % , S h 10 % 69 4 5 6 0 8 3 1 0 . 8 1 0 . 9 E v e n B G , C G , E C D A S a n d S s t 5 0 % S l t s t 5 0 % 7 0 9 1 6 2 0 0 1 0 . 7 5 1 0 . 9 E v e n B G , C G , E C D Mi l u v e a c h S l t s t 6 5 % Sh 3 0 % , C l y s t 5% 72 2 1 6 3 1 0 1 0 . 7 5 1 0 . 7 5 E v e n B G , C G , E C D NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i l t s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f , C S l t s t = C a r b o n a c eous Siltstone 4. 2 Q u a n t i t a t i v e M e t h o d s Th e p r i m a r y i n d i c a t o r s u s e d f o r P P G e v a l u a t i o n w e r e g a s t r e n d s re l a t i v e t o m u d w e i g h t ( M W ) a n d e f f e c t i v e c i r c u l a t i n g d e n s i t y ( E CD), including increases in b a c k g r o u n d g a s ( B G ) , a p p e a r a n c e a n d t r e n d s o f c o n n e c t i o n g a s ( C G ) , an d m a g n i t u d e s o f t r i p g a s ( T G ) a n d w i p e r g a s ( W G ) . R e g i onal pore pressure tr e n d s f r o m s o n i c d a t a , p r o v i d e d b y C o n o c o P h i l l i p s , a n d s u r f a c e ma n i f e s t a t i o n s o f h o l e c o n d i t i o n s w e r e a l s o c o n s i d e r e d . As a r e f e r e n c e , P P G i s c a l c u l a t e d i n i t i a l l y w i t h a f o r m u l a p r ov i d e d b y C a n r i g D r i l l i n g T e c h n o l o g y L T D , a n d t h e n m o d i f i e d u s i n g the indicators described ab o v e , D X C a n d r e s i s t i v i t y ( R E S ) d a t a . T h e f o r m u l a u s es D X , E C D , a n d B G a s m e a s u r e d b y t o t a l d i t c h g a s : 1E - 0 5 A 16 PP G = E C D – ( 0 . 6 - ( ( . 0 0 1 * T L G S U ) + ( 0 . 0 5 * D X ) ) ) Th e f o r m u l a h a s c e r t a i n l i m i t a t i o n s , s u c h t h a t i t d o e s n o t a l l o w f o r a P P G m o r e t h a n 1 p p g l e s s t h a n t h e E C D , a n d T L G S U m u s t b e differentiated from sh o w g a s a n d g a s c a r r i e d f r o m o v e r p r e s s u r e z o n e s , a n d i s d e p e n d e n t on r e l i a b l e D X d a t a . H o w e v e r , t h e f o r m u l a p r o v e d u s e f u l i n helping formulate a PP G r a n g e , w h e n e s t i m a t i n g t r e n d s , a s w i t h D X C d a t a , w i t h d a t a p o i n t s i n s h a l e i n t e r v a l s . 1E-05A 17 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 4995.60 18.57 68.73 4341.02 1068.95 1945.69 1068.95 1.88 5014.74 18.20 69.27 4359.18 1071.11 1951.33 1071.11 2.13 5031.74 17.89 69.15 4375.35 1072.98 1956.25 1072.98 1.84 5078.77 17.37 68.80 4420.17 1078.09 1969.55 1078.09 1.13 5172.37 20.39 68.00 4508.72 1089.26 1997.70 1089.26 3.24 5268.54 16.78 67.11 4599.86 1100.94 2026.03 1100.94 3.77 5363.23 11.94 65.64 4691.57 1110.30 2047.56 1110.30 5.13 5413.38 10.33 77.02 4740.78 1113.45 2056.67 1113.45 5.42 5456.30 10.35 82.37 4783.00 1114.82 2064.24 1114.82 2.24 5504.47 9.88 81.82 4830.42 1115.99 2072.62 1115.99 1.00 5548.55 10.23 83.07 4873.82 1117.00 2080.25 1117.00 0.94 5645.73 9.72 84.50 4969.53 1118.82 2096.98 1118.82 0.58 5739.52 10.05 88.21 5061.93 1119.84 2113.04 1119.84 0.76 5833.70 9.97 89.53 5154.68 1120.16 2129.41 1120.16 0.26 5929.38 9.90 89.17 5248.92 1120.35 2145.91 1120.35 0.10 6024.14 12.11 72.48 5341.96 1123.46 2163.55 1123.46 4.07 6117.84 13.63 52.92 5433.35 1133.08 2181.74 1133.08 4.90 6166.75 14.28 48.50 5480.81 1140.55 2190.85 1140.55 2.55 6211.45 15.44 44.42 5524.02 1148.46 2199.15 1148.46 3.49 6253.10 15.54 40.45 5564.16 1156.66 2206.65 1156.66 2.56 6307.09 17.18 33.32 5615.97 1168.83 2215.72 1168.83 4.80 6358.35 19.54 28.76 5664.62 1182.67 2224.00 1182.67 5.39 6402.03 20.59 29.47 5705.64 1195.77 2231.30 1195.77 2.47 6453.72 22.18 29.98 5753.77 1212.13 2240.65 1212.13 3.10 6494.50 24.42 28.54 5791.23 1226.21 2248.52 1226.21 5.67 6590.85 27.44 28.49 5877.87 1263.22 2268.63 1263.22 3.13 6685.09 30.25 26.72 5960.41 1303.52 2289.67 1303.52 3.12 6778.20 32.86 25.62 6039.74 1347.25 2311.14 1347.25 2.87 6873.22 34.09 25.45 6119.00 1394.54 2333.73 1394.54 1.30 6967.53 34.19 25.30 6197.06 1442.36 2356.41 1442.36 0.14 7062.10 33.82 26.08 6275.46 1490.03 2379.34 1490.03 0.60 7156.37 33.37 26.27 6353.98 1536.84 2402.34 1536.84 0.49 7229.25 33.32 25.96 6414.86 1572.81 2419.98 1572.81 0.24 1E - 0 5 A 18 5. 2 B i t R e c o r d Bi t S i z e M a k e T y p e / S # J e t s / T F A De p t h I n MD / To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) WO B (K l b s ) RP M W e a r B H A 1 8 . 5 ” B a k e r Wi n d o w M i l l / 11 7 0 5 8 4 8 5 0 1 4 4 8 2 8 . 5 1 . 6 8 7 8 . 3 3 7 8 . 3 3 ¼ o u t 1 2 8 . 5 ” H D B S F X 5 5 + / 1 1 7 8 5 5 2 8 5 x 1 3 5 0 6 2 2 2 1 1 3 9 . 7 8 2 . 0 1 9 . 4 4 1 . 7 1 - 6 - B T - S - X - I - E R - T D 2 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) Mu d t y p e : s e a w a t e r 2/ 7 / 1 2 5 0 0 0 8 . 6 2 6 1 5 0 0 0 Mu d t y p e : m i l l i n g f l u i d 2/ 8 / 1 2 5 0 0 0 9 . 6 4 1 6 2 6 1 0 / 1 1 / 1 1 1 / 8 . 5 8 0 0 2/ 9 / 1 2 5 0 4 6 9 . 6 4 2 5 3 0 1 4 / 1 5 / 1 5 8 9 . 0 3 9 0 0 2 0 0 2/ 1 0 / 1 2 5 0 6 2 9 . 7 5 2 1 3 3 5 1 2 / 1 4 / 1 2 5 . 5 1 / 9 . 5 1 8 0 0 1 6 0 Mu d t y p e : L S N D d r i l l i n g f l u i d 2/ 1 1 / 1 2 5 0 6 2 9 . 6 6 0 1 5 3 6 1 4 / 1 5 / 1 6 4 . 8 1 / 1 2 2 / 9 7 9 . 5 1 2 0 0 1 6 0 2/ 1 2 / 1 2 5 6 2 2 9 . 6 1 0 . 6 5 3 1 2 3 3 1 2 / 1 5 / 1 7 4 . 8 1 / 1 7 3 / 9 0 T r 9 . 5 2 0 0 0 6 0 2/ 1 3 / 1 2 6 1 0 0 9 . 9 1 0 . 6 4 6 1 6 3 1 1 1 / 1 4 / 1 8 4 . 6 1 / 1 7 . 5 2 / 9 1 T r 9 . 0 1 6 0 0 4 0 2/ 1 4 / 1 2 7 0 1 1 1 0 . 8 1 1 . 6 4 7 1 8 2 7 1 0 / 1 3 / 1 6 3 . 4 1 / 1 1 3 2 / 8 5 T r 9 . 0 2 2 0 0 6 0 2/ 1 5 / 1 2 7 2 3 5 1 0 . 8 1 1 . 5 5 0 2 0 2 9 1 0 / 1 3 / 1 5 3 . 2 1 / 1 1 4 3 / 8 3 T r 9 . 4 2 0 0 0 6 0 Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o n t e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y WL = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t 19 6 DAILY REPORTS ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Rory Ober Date:1/30/12 Time:24:00 Current Depth (MD):5259’Current Operations:Weather holdCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Continue to RIH with BHA #2 from 1,001’ to 5,259’, soft tag tubing stub; pull up to 5,246’, circulate 1.5 hole volumes at 8 bpm, 350 psi; B/D to TD; POOH from 5,259’ to 137’; lay down BHA #2, clean and clear floors; suspend e-line operation due to CPAI SOP; makeup bullnose and crossover; RIH with 5” DP to 2929’; rig up circulating hose, circulate hole 1 DP volume every 2 hours, continue to wait on weather. Calibrations:Chromatograph, THA Failures:None Daily Cost: $3,295.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Rory Ober Date:1/31/12 Time:24:00 Current Depth (MD):5259’Current Operations:Wait on weatherCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Continue to wait on weather, circulate 1 DP volume every 2 hours; circulate through choke to warm fluid 2.5 BPM, 2000 psi; continue to wait on weather, circulate 1 DP volume every 2 hours. Calibrations:None Failures:None Daily Cost: $3,295.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Rory Ober Date:2/1/12 Time:24:00 Current Depth (MD):5259’Current Operations:Wait on weatherCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary:Continue to wait on weather, circulate 1 DP volume every 2 hours Calibrations:None Failures:None Daily Cost: $3,295.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Rory Ober Date:2/2/12 Time:24:00 Current Depth (MD):5259’Current Operations:E-loggingCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Cont. to wait on weather, circ. 1 DP vol every 2 hrs; load MWD tools, move DC in derrick; POOH from 2929’ to surface; pickup 4.5” test joint, remove 6’ PUP from JT install in slips; rig up e-line; RIH w/ gyro and mem. cal. Log on e-line to 5200’; POOH from 5200’ @ 50ft/min.; PJSM w/ e-line crew; make up 3.375”x10’ perf. gun, RIH to 5080’, fire guns from 5070’ to 5080’, POOH, lay down fired gun, make up string; shot. Calibrations:None Failures:None Daily Cost: $3,770.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Rory Ober Date:2/3/12 Time:24:00 Current Depth (MD):5259’Current Operations:RIH w/ Baker toolCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Mu String Shot. RIH w/CCL & String Shot., Shot. POOH RU E-Line. RIH w/Baker cement retainer on 5"DP. Logged hole to Depth of Cement Retainer @ 5039'. Top of retainer 5037'.POOH. Set Baker Cement Retainer. Run Cement. test Cement and Cement Retainer. RIH w/Baker "G" Lock-Set RBP Calibrations:None Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Rory Ober Date:2/4/12 Time:24:00 Current Depth (MD):5259’Current Operations:Nippling up BOPCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Cont. RIH w/ BHA #5 RBP from 1000’ to 2450’; set RBP @ 2431’; POOH to 2316’; r/u to dump sand, dumped 44 sks @ 5 min/sk; circ 0.5 BPM 1 DP vol; pull up 2 stands, let sand settle; RIH 2 stands, tag up @ 2390’; POOH to surface, lay down RBP tool; nipple down BOP; nipple down tubing head; make up 9-5/8 spear, spear casing, pull up 100k tension; make up bumper sub on spear, attempt to re-land; lay down bumper sub and spear, consult with town for plan forward; nipple up BOP. Calibrations:THA, Chromatograph Failures:None Daily Cost: $3,770.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Rory Ober Date:2/5/12 Time:24:00 Current Depth (MD):5259’Current Operations:POOHCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Nipple up BOP; load Baker tools, make up BHA #6; RIH, locate collars @ 161’ and 203’ with 9-5/8” msc; rig up hoses to cuttings box; cut casing @ 183’; circulate out arctic pack with hot water 2 bpm 80 psi; stand back collars, lay down msc; pick up, make up spear; unload 9-5/8” casing @ 100k; gas breaking out of arctic pack, circ through choke to kill tank @ 4 bpm 120 psi, pumped 100 bbl, monitored well; rig up casing equip; POOH with 9-5/8” casing, lay down in pipe shed, excessive trouble breaking out connections; clear floor, load tools; rig down casing equip; make up back off tool BHA #10; RIH to 410’; fill pipe with water; rig up test pump hoses; back off @ 204’ 6 turns; rig down test pump hoses; POOH with BHA #10. Calibrations:None Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Rory Ober Date:2/6/12 Time:24:00 Current Depth (MD):5259’Current Operations:Tap and clean LDSCurrent Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Clean floor; m/u BHA #11 9-5/8” casing spear; RIH, engage fish @ 182’; circ b/u @ 3 bpm 60 psi, b/d TD; POOH, L/D fish; clear floor, offload tools and casing; r/u casing equipment; RIH with 9-5/8” casing to 197’; r/u cross-over to TD; r/u LRS; freeze protect with diesel 2 bmp 200 psi, 50 bbl pumped; screw into casing stub with 10.5k torque; r/u test equipment; test 9-5/8” casing 3500 psi for 30 min; r/d casing equipment, clear floor; nipple down BOP and lift; pull 100k tension on casing, set emergency slips, cut casing; continue to nipple down BOP and rack back; install packoff; tap and clean LDS. Calibrations:None Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Lee Hinkel Date:2/7/12 Time:24:00 Current Depth (MD):5259’Current Operations:RIH with BHA #13Current Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:8.6 FV:26 PV:YP:FL: Gels:Sol:pH:Cl-:15000 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Continue to tap and clean LDS; nipple up tubing head, test pack off 3800 psi 15 min; nipple up BOPE; rig up test equipment, grease choke; test BOPE; rig down test equipment, pull test plug, set wear ring; make up BHA #12 retrieving head, RIH, tagged sand @ 2385’; pump 8 bpm circulate out sand 120 psi, wash to 2436’; release RBP, monitor well, circ bottoms up 5 bpm @ 70 psi; POOH, lay down BHA #12; clear floor, prep for BHA #13; make up BHA #13, RIH. Calibrations:None Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Lee Hinkel Date:2/8/12 Time:24:00 Current Depth (MD):5259’Current Operations: RIH with BHA #14 (whipstock/mill assembly)Current Depth (TVD): 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:9.6 FV:41 PV:6 YP:26 FL:NC Gels:10/11/11 Sol:pH:8.5 Cl-:800 Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Continue to RIH with BHA #13 to tag @5030’, wash to 5037’; solid tag @ 5037’; recirc 22 bbl hi-vis sweep; swap well to 9.6 @ 4 bpm; ICP 120 FCP 240 psi; blow down TD; pull from 5037’ to 4904’; cut and slip drill line; rig up circ hose, attain parameters, sync totco and MWD; POOH with BHA #13; pump dry job; make up BHA #14 whipstock/mill assembly; RIH to 372’; circ 475 bbl @ 920 psi, achieve successful shallow pulse test; continue to RIH from 372’ to 3093’. Calibrations:THA, chromatograph Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Lee Hinkel Date:2/9/12 Time:24:00 Current Depth (MD):5048’Current Operations:Milling windowCurrent Depth (TVD):4391’ 24 hr Footage (MD):34’ Drilling Parameters ROP:Current:2.82 Max:5.19 Torque:Current:12000 Max:17592 WOB:Current 15 Max:26.2 RPM:Current:65 Max:109 PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:9.6 FV:42 PV:5 YP:30 FL:8 Gels:14/15/15 Sol:pH:9.0 Cl-:3900 Ca++:200 MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current:70% claystone, 20% siltstone, 10% cement Last 24 hrs:70% claystone, 20% siltstone, 10% sand (not including cement or casing) Operational Summary: Continue in hole with BHA #14 whipstock/mill assembly from 3093’; tag at 5037’; orient whipstock’ circ @ 10 bpm 900 psi; set whipstock per Baker rep; 1.5 rot wght; 10 bpm 890 psi; milled from 5014’ to 5015.5’; BPTD; set TD torque to 18k; continue to mill from 5015.5’ to 5023’ 130 rpm 10 bpm 850 psi 5k free torque; continue mill to 5036’ 100 rpm 10-15k WOB 425-450 gpm 950-1000 psi 9k torque off bottom 12k on bottom; continue mill from 5036’ 100 prm 450 gpm 1020 psi 15k WOB 2’/hr ROP 5k torque 142 rpm; mill 5045’ to 5048’ at 60 rpm 400 gpm 880 psi 3’/hr ROP 12k torque on bottom 142 rpm 9k torque off bottom. Calibrations:None Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Lee Hinkel Date:2/10/12 Time:24:00 Current Depth (MD):5062’Current Operations: RIH with magnet/cleanout assemblyCurrent Depth (TVD):4404’ 24 hr Footage (MD):14’ Drilling Parameters ROP:Current:Max:6.92 Torque:Current:Max:16872 WOB:Current Max:28.2 RPM:Current:Max:91 PP:Current:Max:1450 Lag:Strokes:3272 Time:Surf-Surf:Strokes:4451 Time: ECD:Current:Max: Mud Properties @ MW:9.7 FV:52 PV:13 YP:35 FL:5.5 Gels:12/14/12 Sol:pH:9.5 Cl-:1800 Ca++:160 MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current:80% siltstone, 20% claystone Last 24 hrs:70% siltstone, 30% claystone Operational Summary: Cont mill from 5048’ 400 gpm 880 psi 60 rpm 15-17k wob; from 5049.5’ to 5050.5’ 15-17k wob 13k torque on bottom 500 gpm 1150 psi; 450 gmp 1000 psi 15k wob 12k torque on bottom 5050.5’ to 5051’; 500 gpm 1100 psi 5051.5’ to 5053’ 13k torque on bottom 17-18k wob; continue to mill from 5053’ 12 bpm 1200 psi 1’/hr ROP 5k wob 12k torque; TD @ 5062.74’; pumped super sweep @ 12 bpm 1200 psi; rig up test equip, perform FIT test EMO 15.8 ppg; pumped 20 bbl dry job 4 bpm 270 psi; POOH from 5054’; lay down BHA #14; clear floor; pick up magnet and swizzle stick; wash stack @ 8 bpm 130 psi; clean; l/d magnet swizzle assembly; m/u BHA #16 cleanout magnet/mill. Calibrations:None Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Lee Hinkel Date:2/11/12 Time:24:00 Current Depth (MD):5062’Current Operations:RIH with drilling BHACurrent Depth (TVD):4404’ 24 hr Footage (MD):0’ Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:9.6 FV:60 PV:15 YP:36 FL:4.8 Gels:14/15/16 Sol:2 pH:9.5 Cl-:1200 Ca++:160 MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG :12u Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas 5062’/4405’2249 249 Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Continue to make up BHA #16, RIH, tag bottom @ 5063’; pump 30 bbl super sweep; swap hole to 9.6 drill mud; POOH; lay down BHA #16, clean magnets; offload Baker tools/magnets, clear floor; make up BHA #17; download MWD tools; shallow pulse test 400 gpm 790 psi, good test; continue to pick up BHA; RIH to 2005’, fill pipe. Calibrations:THA, Chromatograph Failures:None Daily Cost: $3,670.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Lee Hinkel Date:2/12/12 Time:24:00 Current Depth (MD):5620’Current Operations:DrillingCurrent Depth (TVD):4946’ 24 hr Footage (MD):558’ Drilling Parameters ROP:Current:80 Max:Torque:Current:5900 Max:9300 WOB:Current 25 Max:44 RPM:Current:82 Max:83 PP:Current:2100 Max:2600 Lag:Strokes:3644 Time:19:54 Surf-Surf:Strokes:5015 Time:24:24 ECD:Current:10.6 Max:10.9 Mud Properties @ MW:9.6 FV:53 PV:12 YP:33 FL:4.8 Gels:12/15/17 Sol:7 pH:9.5 Cl-:2000 Ca++:60 MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:22u Max:42u Depth (MD/TVD):5175’/4511’ Avg BG :12u Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas 5594’/4919’4025 193 Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current:70% siltstone, 25% claystone, 5% sand Last 24 hrs:80% siltstone, 10% claystone, 10% sand/sandstone Operational Summary: Continue in with BHA #17 from 200’ to 4842’; establish parameters, orient; lower through whipstock to 5044’; drill from 5062’ to 5594’; short trip, back ream 5594’ to 5220’; RIH 5220’ to 5594’; continue drilling to 5620’. Calibrations:THA, Chromatograph Failures:None Daily Cost: $3,770.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Randy Dolcater Lee Hinkel Date:2/13/12 Time:24:00 Current Depth (MD):6380’Current Operations:DrillingCurrent Depth (TVD):5693’ 24 hr Footage (MD):760’ Drilling Parameters ROP:Current:80 Max:100 Torque:Current:67 Max:8200 WOB:Current 19 Max:45 RPM:Current:0 Max:85 PP:Current:2100 Max:2600 Lag:Strokes:4113 Time:24:28 Surf-Surf:Strokes:5664 Time:33:42 ECD:Current:11.1 Max:11.2 Mud Properties @ MW:9.9 FV:46 PV:16 YP:31 FL:4.6 Gels:11/14/18 Sol:7.5 pH:9.0 Cl-:1600 Ca++:40 MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:80u Max:312u Depth (MD/TVD):6199’/5512’ Avg BG :20u Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current:50% siltstone; 30% carbonaceous siltstone; 20% clay Last 24 hrs:55% siltstone; 25% carbonaceous siltstone; 15% clay, tr sand, tr tuff. Operational Summary:Continue to drill from 5620’ to 6388’ MD. Calibrations:None Failures:None Daily Cost: $3,770.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Lee Hinkel Date:2/14/12 Time:24:00 Current Depth (MD):7010’Current Operations:Tripping inCurrent Depth (TVD):6232’ 24 hr Footage (MD):622’ Drilling Parameters ROP:Current:Max:100 Torque:Current:Max:10500 WOB:Current Max:50 RPM:Current:Max:92 PP:Current:Max:2650 Lag:Strokes:4521 Time:27:24 Surf-Surf:Strokes:6231 Time:37:45 ECD:Current:11.5 Max:11.7 Mud Properties @ MW:10.8 FV:109 PV:18 YP:27 FL:3.4 Gels:10/13/16 Sol:13 pH:9.0 Cl-:2200 Ca++:60 MW Change:Depth:6200- 7010 From:9.9 To:10.8 Reason:Weight up for A sand Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:n/a Max:699u Depth (MD/TVD):6927’/6163’ Avg BG :50u Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current:60% siltstone, 30% sand/sandstone, 10% shale Last 24 hrs: 60% siltstone, 25% carbonaceous siltstone, 15% claystone (above C sand) 60% sandstone, 40% sand (C sand) 60% siltstone, 30% sand/sandstone, 10% shale (below C sand) Operational Summary:Continue drilling from 6380’ to 7011’; back ream out of hole from 7011’ to 5325’; circulate bottoms up; run into hold from 5325’ to 6729’ MD. Calibrations:THA, Chromatograph Failures:None Daily Cost: $3,770.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Lee Hinkel Date:2/15/12 Time:24:00 Current Depth (MD):7273’Current Operations:POOH from TDCurrent Depth (TVD):6451’ 24 hr Footage (MD):263’ Drilling Parameters ROP:Current:Max:100 Torque:Current:Max:15000 WOB:Current Max:50 RPM:Current:Max:86 PP:Current:Max:2620 Lag:Strokes:4687 Time:Surf-Surf:Strokes:6460 Time: ECD:Current:11.5 Max:11.7 Mud Properties @ MW:11.0 FV:53 PV:26 YP:30 FL:2.6 Gels:12/15/17 Sol:14 pH:9.0 Cl-:1800 Ca++:60 MW Change:Depth:7271’From:10.8 To:11.0 Reason:For RIH with liner Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:n/a Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas 7010’/6232’ 7271’/6451’ 33340 12149 2087 662 781 233 140 31 336 73 112 45 106 48 Connection Gases Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current:60% siltstone, 30% shale, 10% clay Last 24 hrs:70% siltstone/shale, 25% sand/sandstone, 5% clay Operational Summary: Continue to RIH 6991’ to 7011’; drill ahead from 7011’ to 7273’ TD; back ream to 6818; RIH from 6818’ on elevators, hole in good condition; while circulating, condition mud to 11 ppg; back down to TD, monitor hole; POOH from 7273’ to 4925’; pump dry job; hang block; cut and slip drill line; continue POOH with 5” DP from 4925’ to 3236’ MD. Calibrations:None Failures:None Daily Cost: $3,770.00 ConocoPhillips Alaska Inc. 1E-05A Daily Report Report for: Dale Rowell Lee Hinkel Date:2/16/12 Time:24:00 Current Depth (MD):7273’Current Operations: Conditioning mud for cementing linerCurrent Depth (TVD):6451’ 24 hr Footage (MD): Drilling Parameters ROP:Current:Max:Torque:Current:Max: WOB:Current Max:RPM:Current:Max: PP:Current:Max: Lag:Strokes:Time:Surf-Surf:Strokes:Time: ECD:Current:Max: Mud Properties @ MW:FV:PV:YP:FL: Gels:Sol:pH:Cl-:Ca++: MW Change:Depth:From:To:Reason: Mud Loss event:Depth:Volume: Gas Data Ditch Gas:Current:Max:Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD)C1 C2 C3 C4I C4N C5I C5N Trip Gas 7273’/6451’ (liner run)20826 872 201 23 48 13 15 Connection Gas Gas Samples No.Depth (MD/TVD)TG C1 C2 C3 C4I C4N C5I C5N Lithologies:Current: Last 24 hrs: Operational Summary: Continue to POOH from 3236’ to BHA; lay down BHA, unload nukes, download LWD, continue to lay down BHA; clear and clean floor; bring up tools; prep for 5.5” liner run; clear off floor equipment; make up 5.5” liner, fill pipe every 10 joints; circulate 60 bbl at 3 bpm at 2566’; clear off floor equipment; continue to run in with 5” drill pipe from 2566’; broke circulation at 5000’; rig up cementing head; work up and down and condition mud 2 bpm 420 psi. Calibrations:None Failures:None Daily Cost: $3,770.00 zit-k5& 111Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 22 15:04:42 2012 RECEIVED Reel Header MAR 2 9 2012 Service name LISTPE Date 12/03/22 AJG CC Origin STS V Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 12/03/22 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER ( tl 00, Kuparuk River MWD/MAD LOGS �� WELL NAME: 1E-05A API NUMBER: 500292047901 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 22-MAR-12 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: -XX-0008472247 -XX-0008472247 LOGGING ENGINEER: SHAWN HANSON SHAWN HANSON OPERATOR WITNESS: RANDY DOLCAT RANDY DOLCAT SURFACE LOCATION SECTION: 16 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 653 FEL: 633 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 101.10 GROUND LEVEL: 69.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9. 625 5014.0 2ND STRING 3RD STRING PRODUCTION STRING . 411 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) , UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. THIS SIDETRACK EXITED 1E-05 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 5014 'MD/4358'TVD. THE WINDOW WAS MILLED AND ABOUT 20' OF RAT HOLE WERE DRILLED DURING MWD RUN 1. ONLY ROPA DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AZIMUTHAL DEEP RESISTIVITY (ADR) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO- DENSITY (ALD) , PRESSURE WHILE DRILLING (PWD) , AND DRILL STRING DYNAMICS SENSOR (DDSr) . NOTE: THE 32 INCH 500 KHZ CURVE IS PRESENTED RATHER THAN THE 32 INCH 2MHZ CURVE. 5. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER E-MAIL FROM LAIRD LITTLE (CPAI) TO BUSTER BRYANT (SD) ON 20 MARCH 2012. 6. MWD RUNS 1,2 REPRESENT WELL 1E-05A WITH API #50-029-20479-01. THIS WELL REACHED A TOTAL DEPTH OF 7273'MD/6451'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR OR GM COMBINED GAMMA RAY AH1P/ARH16P AVG 16 INCH 2M PHASE RESISTIVITY AM2P/ARM32P AVG 32 INCH 500K PHASE RESISTIVITY AM3P/ARM48P AVG 48 INCH 500K PHASE RESISTIVITY ADXT ADR FORMATION EXPOSURE TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDL/ALCDLC ALD LCRB COMPENSATED DENSITY ADCL/ALDCLC ALD LCRB DENSITY CORRECTION APEL/ALPELC ALD LCRB Pe FACTOR ALRP/ALRPM ALD RPM (NON-SLIDE INDICATOR) AHSI/ALHSI ALD HOLE SIZE INDICATOR PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED - 8.5" BIT MUD WEIGHT: 9. 6-10.8 PPG WHOLE MUD CHLORIDES: 1200-2400 PPM FORMATION WATER SALINITY: 14, 545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL • CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/22 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4984.0 7194.5 NPHI 5005.0 7160.5 NCNT 5005.0 7160.5 RHOB 5005.0 7178.0 FCNT 5005.0 7160.5 AM3P 5005.0 7214 .5 DRHO 5005.0 7178.0 AH1P 5005.0 7214.5 PEF 5005.0 7178.0 AM2P 5005.0 7214.5 FET 5014 .5 7214.5 ROP 5015.5 7273.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 5015.5 5062.0 MWD 2 5062.0 7273.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD HR 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 DRHO MWD G/CC 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 AH1P MWD OHMM 4 1 68 20 6 • III 411 AM2P MWD OHMM 4 1 68 24 7 AM3P MWD OHMM 4 1 68 28 8 GR MWD API 4 1 68 32 9 ROP MWD FPH 4 1 68 36 10 FCNT MWD CP30 4 1 68 40 11 NCNT MWD CP30 4 1 68 44 12 NPHI MWD PU 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4984 7273 6128.5 4579 4984 7273 FET MWD HR 0. 62 74 .82 3.3817 4401 5014.5 7214 .5 RHOB MWD G/CC 0.057 3.295 2.3512 4347 5005 7178 DRHO MWD G/CC -4.375 0.341 0.0507665 4347 5005 7178 PEF MWD B/E 1. 96 16.75 4.81198 4347 5005 7178 AH1P MWD OHMM 0.02 3902.23 4. 68147 4420 5005 7214.5 AM2P MWD OHMM 0.02 2000 6. 99958 4420 5005 7214 .5 AM3P MWD OHMM 0.02 2000 16.9958 4420 5005 7214 .5 GR MWD API 33.56 473.63 132.809 4422 4984 7194.5 ROP MWD FPH 0.09 346.26 76.3475 4516 5015.5 7273 FCNT MWD CP30 493.4 1481.12 836.018 4312 5005 7160.5 NCNT MWD CP30 95876.6 152295 117734 4312 5005 7160.5 NPHI MWD PU 24.45 66.19 38. 9728 4312 5005 7160.5 First Reading For Entire File 4984 Last Reading For Entire File 7273 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/22 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/22 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROPA 5015.5 5062.0 $ LOG HEADER DATA DATE LOGGED: 10-FEB-12 • • SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 5062.0 TOP LOG INTERVAL (FT) : 5014.0 BOTTOM LOG INTERVAL (FT) : 5062.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 18.2 MAXIMUM ANGLE: 18.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $ # I BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.500 DRILLER'S CASING DEPTH (FT) : 5014.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 42.0 MUD PH: 8.5 MUD CHLORIDES (PPM) : 3900 FLUID LOSS (C3) : 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: 102.7 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5015.5 5062 5038.75 94 5015.5 5062 ROP MWDO10 FPH 0.09 4.85 1.83348 94 5015.5 5062 • I First Reading For Entire File 5015.5 Last Reading For Entire File 5062 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/22 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/22 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. ' BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 4984 .0 7194.5 AM2P 5005.0 7214.5 TNNA 5005.0 7160.5 TNFA 5005.0 7160.5 TNPS 5005.0 7160.5 AM3P 5005.0 7214.5 AH1P 5005.0 7214.5 APEL 5005.0 7178.0 ADCL 5005.0 7178.0 ACDL 5005.0 7178.0 ADXT 5014 .5 7214.5 ROPA 5062.5 7273.0 LOG HEADER DATA DATE LOGGED: 15-FEB-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7273.0 TOP LOG INTERVAL (FT) : 5062.0 BOTTOM LOG INTERVAL (FT) : 7273.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 9.7 MAXIMUM ANGLE: 34.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11557009 CTN COMP THERMAL NEUTRON 10900821 . ALD Azimut al Litho-Dens 10471335 ADR Azimuthal Deep Resis $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.500 DRILLER'S CASING DEPTH (FT) : 5014.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) : 10.20 MUD VISCOSITY (S) : 47.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 2200 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .890 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .477 132.8 MUD FILTRATE AT MT: .850 68.0 MUD CAKE AT MT: . 950 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD020 HR 4 1 68 4 2 RHOB MWD020 G/CC 4 1 68 8 3 DRHO MWD020 G/CC 4 1 68 12 4 PEF MWD020 B/E 4 1 68 16 5 AH1P MWD020 OHMM 4 1 68 20 6 AM2P MWD020 OHMM 4 1 68 24 7 AM3P MWD020 OHMM 4 1 68 28 8 GR MWD020 API 4 1 68 32 9 ROP MWD020 FPH 4 1 68 36 10 FCNT MWD020 CP30 4 1 68 40 11 NCNT MWD020 CP30 4 1 68 44 12 NPHI MWD020 PU 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4984 7273 6128.5 4579 4984 7273 FET MWD020 HR 0.62 74 .82 3.3817 4401 5014.5 7214.5 RHOB MWD020 G/CC 0.057 3.295 2.3512 4347 5005 7178 DRHO MWD020 G/CC -4.375 0.341 0.0507665 4347 5005 7178 PEF MWD020 B/E 1.96 16.75 4.81198 4347 5005 7178 411 410 , AH1P MWD020 OHMM 0.02 3902.23 4. 68147 4420 5005 7214.5 AM2P MWD020 OHMM 0.02 2000 6. 99958 4420 5005 7214 .5 AM3P MWD020 OHMM 0.02 2000 16. 9958 4420 5005 7214.5 GR MWD020 API 33.56 473.63 132.809 4422 4984 7194.5 ROP MWD020 FPH 0.49 346.26 77 . 9315 4422 5062.5 7273 FCNT MWD020 CP30 493.4 1481.12 836.018 4312 5005 7160.5 NCNT MWD020 CP30 95876.6 152295 117734 4312 5005 7160.5 NPHI MWD020 PU 24.45 66.19 38. 9728 4312 5005 7160.5 First Reading For Entire File 4984 Last Reading For Entire File 7273 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/22 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 12/03/22 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 12/03/22 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
