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Home My WebLink About212-177CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:CD1-36, 46 and 49 non-witnessed MITIA"s on 6-25-25 Date:Friday, June 27, 2025 7:43:46 AM Attachments:image001.png MIT CRU CD1-36, 46 and 49 06-25-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-36, 46, and 49 that were conducted on 6-25-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1991120 Type Inj N Tubing 1570 1570 1570 1570 Type Test P Packer TVD 6944 BBL Pump 1.2 IA 560 2300 2250 2240 Interval 4 Test psi 1736 BBL Return 1.2 OA 560 580 580 580 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040240 Type Inj N Tubing 530 885 910 910 Type Test P Packer TVD 6918 BBL Pump 3.0 IA 520 3300 3260 3255 Interval V Test psi 3000 BBL Return 3.0 OA 620 635 635 635 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2121770 Type Inj N Tubing 65 175 200 205 Type Test P Packer TVD 7013 BBL Pump 2.1 IA 390 2010 1950 1950 Interval 4 Test psi 1753 BBL Return 2.1 OA 55 70 70 70 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp 06/25/25 Notes: Notes: CD1-36 CD1-46 Notes:MITIA to maximum anticipated injection pressure per AIO 18C.004 CD1-49 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2025-0625_MIT_CRU_CD1-49 9 9 9 9 999 99 99 9 9 -5HJJ CD1-49 Originated: Delivered to:8-Jul-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 CD1-49 50-103-20661-00 910162676 Colville River Multi Finger Caliper Field & Processed 2-Jul-25 0 12 CD1-49 50-103-20661-00 910162676 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 2-Jul-25 0 13 CD4-213B 50-103-20540-02 910162674 Colville RiverMulti Finger CaliperField & Processed 1-Jul-25 0 14 CD4-213B 50-103-20540-02 910162674 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 1-Jul-25 0 15PLEASE 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:212-177212-005T40653T40653T40654T406547/9/20251CD1-4950-103-20661-00910162676Colville RiverMulti Finger CaliperField & Processed2-Jul-2501Electromagnetic Pipe2CD1-4950-103-20661-00910162676Colville RiverXaminer Record (EPX-V)Field & Processed2-Jul-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:34:43 -08'00' MEMORANDUM TO: Jim Regg� P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD 1-49 COLVILLE RIV UNIT CD1-49 Src: Inspector Reviewed By: P.I. Supry J Comm Well Name COLVILLE RIV UNIT CD1-49 ` API Well Number 50-103-20661-00-00 Inspector Name: Lou Laubenstein Permit Number: 212-177-0 Inspection Date: 6/12/2021 ' Insp Num: mitLOL210612182021 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WellT CDI-49 Type Inj 1 w •TVD 1 7012 - Tubing 2345 2345 - 2345 - 2345 PTD 2121770 Type Test' SPT';Test psi 1753 IA 780 3000 _ 2950 - 2940 BBL Pumped: 2.8 ' BBL Returned 28 OA 440 720 720 - l 720- - - Interval 4YRTST TPF- P t -- - - — — - - - Notes: Thursday, June 17, 2021 Page 1 of I • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 19,2017 TO: Jim Regg Z! r P.I.Supervisor 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-49 FROM: Bob Noble COLVILLE RIV UNIT CD1-49 Petroleum Inspector Src: Inspector Reviewed By: P.1.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-49 API Well Number 50-103-20661-00-00 Inspector Name: Bob Noble Permit Number: 212-177-0 Inspection Date: 6/9/2017 Insp Num: mitRCN170612080138 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-49 - Type Inj W TVD 7012 - Tubing F 2325 2340 - 2340 ' 2340 PTD 2121770 Type Test SPT Test psi 1753 IA 1620 3000 - 2980 - 2980 " BBL Pumped: 1.8 - BBL Returned: 1.8 - OA 450 625 - 620 620 - Interval 4YRTST P/F P - Notes: SCANNED AUG 2 22017, Monday,June 19,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,November 04,2016 < 'I� (� SUBJECT: Mechanical Integrity P.I.Supervisor Keg Ty Tests CONOCOPHILLIPS ALASKA INC CD 1-49 FROM: Johnnie Hill COLVILLE RIV UNIT CD1-49 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-49 API Well Number 50-103-20661-00-00 Inspector Name: Johnnie Hill Permit Number: 212-177-0 Inspection Date: 10/19/2016 Insp Num: mitJWH161019164223 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-49 Type Inj TVD 7012 - Tubing 2300 2300 - 2300- r 2307 PTD 2121770 - Type Test SPT Test psi 1753 - IA 1460 3010 - 2980 - II 2975- Interval OTHER P/F P / OA 125 320 . 320- 320 • Notes: Post patch MIT 2bbls diesel used SCANNED P Friday,November 04,2016 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r PlugPerforationsPull Tubing Fracture Stimulate r r Operations shutdown Performed: Suspend r Perforate r Other Stimulate Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well V Re-enter Susp Well r Other: Tubing patch IV 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 212-177-0 3.Address: 6.API Number: Stratigraphic r Service 17 P. O. Box 100360,Anchorage,Alaska 99510 50-103-20661-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025559/ADL0372097 CRU CD1-49 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 15348 feet Plugs(measured) 2420 true vertical 7155 feet Junk(measured) 12743 Effective Depth measured 15348 feet Packer(measured) 12714, 12724, 12742 true vertical 7155 feet (true vertical) 7010, 7013, 7018 Casing Length Size MD TVD Burst Collapse CONDUCTOR INE 81 16 114 114' SURFACE 3072 13.75 3109 2238' INTERMEDIATE 2 11305 7.67 11338 6407' INTERMEDIATE 1 8804 11.75 11753 6613' LINER 2095 9.6 13433 7152' OPEN HOLE 1915 6.125 15348 7155' REc V . Perforation depth: Measured depth: Open hole 13,433-15,348 OCT 2 4 2a True Vertical Depth: 7,152-7,155 Tubing(size,grade,MD,and TVD) 3.5, L-80, 13337 MD, 7141 TVD Packers&SSSV(type,MD,and TVD) SSSV=None NIPPLE-HES XN LANDING NIPPLE @ 12714 MD and 7010 TVD PACKER-BAKER PREMIER PACKER @ 12724 MD and 7013 TVD XO-REDUCING-XO 4-1/2"HYD 563 B X 3 1/2"EUE P© 12742 MD and 7018 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development r Service Pr Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG p- 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: 316-373 Contact Dusty Freeborn/Jan Byrne Email: N1617(a�conocophillips.com Printed Name Jan Byrne Title: Well Integrity Supervisor Signature () 3 Phone:659-7126 Date 10-20-16 �� Form 10-404 Revised 5/2015 k 72- 1 /z4/lG Submit Original Only lz/o, /,,6 RBDMS l-vOu i L 4 2016 • pv . . RECEIVED ConocoPhillips OCT 24 2016 �� P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ! ' October 20th, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry 316-373 Well Operations for ConocoPhillips Alaska, Inc. well CRU CD1-49 (PTD 212-177-0) for tubing patch repair. Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659- 7224 if you have any questions. Sincerely, Jan Byrne Problem Wells Supervisor Attachments • • C D 1-49 DESCRIPTION OF WORK COMPLETED SUMMARY A 37' patch utilizing the 2.813" HES XN nipple at 12,743' as the lower seal and a 4.5" Paragon II Packer at 12,706' as the upper seal was succesfully set and tested proving tubing integrity. A passing state witnessed MITIA was performed after the well had been brought online and stabilized. The work completed is copied below. 9/30/2016 SET 4.5" PIIP PATCH @ 12,743' RKB. MIT-IA @ 3000 PSI; PASSED. SET MOD. A- 1 INJ VLV @ 1894' RKB. GOOD CLOSURE TEST. COMPLETE. MIT-IA @ 3000 PSI. PRE=1625/1484/25 PUMPED 1.7 BBLS INITIAL = 1625/3025/25 15 MIN=1625/2995/25 30 MIN=1625/2990/25 PASSED. 10/19/2016 (SW) STATE WITNESSED (JOHNNIE HILL) MITIA- PASSED 3010 PSI. Initial T/I/O= 2300/1460/125. IA FL @ SF. Pressurized IA with 2 bbls. of diesel. T/I/O=2300/3010/320. 15 min. reading T/I/O=2300/2980/320 (-30) 30 min. reading T/I/O= 2307/2975/320 (-5) Bled IA fluid. Final T/I/O=2307/1200/100. • • I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(a alaska.gov AOGCC.InspectorsAalaska.gov phoebe.brooks(a�alaska.gov chris.wallacealaska.gov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Alpine/CRU/CD1 DATE: 10/19/16 OPERATOR REP: Phillip/VanCamp AOGCC REP: Johnnie Hill Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD1-49 Type Inj. W TVD 7,013' Tubing 2,300 2,300 2,300 2,307 Interval O P.T.D. 2121770 Type test P Test psi 1753.25 Casing 1,460 3,010 2,980 2,975 P/F P Notes: Post Patch sundry#316-373 OA 125 320 320 320 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT CRU CD1-49 10-19-16.xls WNS INJ • CD149 ConocoPhillips ® Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIfUWI Field Name Wellbore Status Incl(°) MD(RIM Act EM,(ftKB) 1_mem,,,,, 501032066100 ALPINE INJ 92.05 13,892.55 16348.0 ••• ,� Comment H25(ppm) 'Date Annotation End Date 60-0,9(h) Rig Release Date HORIZONTAL-C01-49,10(102016120517 PM SSSV:Al INJECTION VALVE Last WO: 35.99 7/14/2013 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ------- - - Last Tag: 4,224.0 12/6/2014 Rev Reason:PULL PLUG.SET PLUG,GLV pproven 10/10/2016 C/0,SET PATCH&Al INJ VALVE HANGER;30.9-ligNI,131. I♦ Casing Strings Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread ___- ....._......._._..___._. _..CONDUCTOR Insulated 16 15.250 33.0 114.0 114.0 62.50 H40 Welded 42' Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread r::ql SURFACE 113/4 10.772 36.3 3,108.5 2,338.0 60.00 L-80 BTCM rw�,,,,,,,,,,,,,,.,,°„",,..:.:::.'y It#918.Casing De0Mptlon 0D(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len II...Grade Top Thread INTERMEDIATE 1 95/8 8.835 2:949.2 11,753.0 6,612.6 40.00 L-80 Hyd 521 Casing Description SOD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len p...Grade Top Thread INTERMEDIATE 2 7 6.276 33.3 11,338.0 6,407.2 26.00 L-80 BTCM Casing Description 00(In) ID(in) Top(hKB) Set Depth(hKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread ;•`/ I. 7.7'`LINER 7 6.276 11,338.0 13.433.0 7,151.7 26.00 L-80 Tenaris Blue CONDUCTOR Insulated 427 4 ` Liner Details 33.0-114.0 Nominal ID Top(11KB) Top(TVD)(hKO) Tap not(°) Item Des Com (In) • 11,338.0 6.407.2 60.34 PACKER HRD-E ZXPN LINER TOP PACKER 7.625 • • 11,353.5 6.414.9 60.35 HANGER FLEX-LOCK LINER HANGER 7.625 11,363.2 6,419.7 60.35 SEAL ASSY LATCHING BULLET SEAL ASSYw/SEL BORE 6.200 VALVE:1,893.0 I? •::::::' COUPLING NIPPLE;1,8941 11,367.0 6,421.6' 60.36 SLEEVE "HRD-E"LINER SETTING SLEEVE w/Latch profile 6.200 11,375.9 6,426.0 60.36 CONNECT BAKER QUICK CONNECT - 6.059 14.• 13,427.5 7,151.1 84.09 Stabilizer BakerSDL INTEGRAL STABILIZER 6.070 Casing Descrlptlon 019(In) ID(In) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread OPEN HOLE 6 1/8 I 13,433.0 15,348.0 Tubing Strings • Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/It) Grade Top Connection • TUBING 41/2 3.958 30.8 13.340.1 7,141.2 12.60 L-80 IBTM 4.5'13.5°7012742' SURFACE;38.3-3,108,5 Completion Details Nominal ID •• Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 30.8 30.8 0.00 HANGER 'FMC TUBING HANGER(Elastomer) 3.900 1,894.1 1,652.9 51.81 NIPPLE BP-6(CAMCO HYD LANDING NIPPLE 3.812 12,713.8 7,010.2 72.83 NIPPLE HES XN LANDING NIPPLE 3.725 (Was 3.813'changed 7/272016) INTERMEDIATE 2'33.3- '• 12,723.7 7,013.1 72.93 PACKER BAKER PREMIER PACKER 3.870 11.338.0 12,742.0 7,018.4 73.13 XO-Reduci X0 4-12"Hyd 563 B x 3 12"EUE P 2.992 PROD CSG TIE BACK;33.3 • n9 r ftKB _am 12,743.5 7,018.9 73.15 NIPPLE HES XN NIPPLE 2.813'2.75 NO GO 2.750 13,098.8 7,101.0 78.43 SLOTTED 3-1/2",Slotted Liner,SLHT,9.38,L-80 2.992 13,129.7 7,107.2 78.42 PERF 3-12"SLHT Pert Pup 9.3#L-80 2.992 13,135.4 7,108.4 78.42 SLOTTED 3-12",Slotted Liner,SLHT,9.3#,L-80 2.992 13,227.0 7,125.1 80.62 PERF 3-1/2"SLHT Pert Pup 9.3#L-80 2.992 13,232.7 7,126.1 80.77 SLOTTED 3-1/2",Slotted Liner,SLHT.9.3#.L-80 2.992 13,325.1 7,139.3 82.70 PERF 3-1/2'SLHT Perf Pup 9.3#L-80 2.992 13,336.6 7,140.8 82.88 SHOE 3-1/2"Orange Peel shoe,SUIT,9.38,L-80 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Ind INTERMEDIATE 1;2,949.2- Top(ftKB) (IIKB) (°) Des Com Run Date ID(In) 11,753.0 1,893.0 1,652.2 51.80 VALVE A=1 INJ VLV(HSS-158)1.25"ORIFICE 9/30/2016 1.250 12.706.0 7,007.9 72.74 PATCH 4.5"PIIP&2.81 XN NO-GO STINGER PATCH 9/3012016 1.630 1111. ASSEMBLY(37.04'LEFT IN HOLE) GAS LIFT 12,187.5 13,686.0 7,171.6 87.30 FISH BHA STRING 7/10/2013 2.000 Mandrel Inserts St 89 on Top(TVD) Valve Latch Port Sian TRO Run NIPPLE;12,?73.8 N, Top(ftKB) (f1KB) Mane Model OD(In) Sere Type Type (In) (pal) Run Date Com 1 12,187.5 6,821.0 CAMCO KBG-4- 1 GAS LIFT DMY BK 0.000 0.0 9/28/2016 PATCH:12,706.0, (i 5 PACKER'.12,723.7 Notes:General&Safety End Date Annotation XO-Reducing;12,742.0 1' 11/182014 NOTE:7",26#L80,Tenaris Blue from 11,381.53'to 12,995.47'MD' NIPPLE;12,743.5 a l 11/18/2014 NOTE:7",29#TNI LOSS,S.D.6.125"Tenaris Blue from 12,995.47 to 13,398.48'MD' 111 7/27/2016 NOTE:1@ 12,714'-HES XN NIPPLE IS MIN ID OV 3.725 not 3.813,3.813 POLISH BORE 3.725 NO GO I a SLOTTED,13,098.8 PERF,13,129.7 ,IN; SLOTTED,13,135.4 PERF;13,227.0 II SLOTTED'13,232.71 , CSG GMT:13,306.0 ftKB I PERF;13,325.1 SHOE:13.336.6 LINER;11,338.0-13.433.0-- FISH. 1,338.0.13.433.0 FISH'13.686.0 OPEN HOLE;13,433.0.15]48.0 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. R t V E August 17, 2016 Attn.: Makana Bender OCT 0 4 2010 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 ,, GC iv`K o/.BENDER SCANNED NOV 0 3 2016. RE: Leak Detect Log with ACX: CD1-49 Run Date: 7/11/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-49 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20661-00 Leak Detect Log with ACX 1 Color Log 50-103-20661-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: OF r„, • „,,,,„„,t THE STATP Alaska Oil and Gas ofA LAsKAL Conservation Commission 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF r'.. Fax: 907.276.7542 www.aogcc.alaska.gov Dusty Freeborn Well Integrity Supervisor ConocoPhillips Alaska, Inc. SCANNED ( P.O. Box 10036 2Ci Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD 1-49 Permit to Drill Number: 212-177 Sundry Number: 316-373 Dear Mr. Freeborn: Enclosed is the approvedapplicationsundry approval for a roval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0,44.41"4.e,t4c/L\ Cathy 44. Foerster Chair DATED this Z day of August, 2016. RBDMS LL- AUG - 2 2016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2122 APPLICATION FOR SUNDRY APPROVALS 075 5'/iJCC 20 AAC 25.280 AOGC 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well 17 s Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change. proved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r pt'h�erP4frh 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 212-177-0 ' 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 � 50-103-20661-00 7.If perforating, .4%L1 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Alit Will planned perforations require spacing exception? Yes r No r CRU CD1-49 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0025559/ADL0372097 Colville River Field/Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth IVA9A Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15348 7155 1M03(01548' 1 ' '17'2,. 7j' 2420' 12743' 13686' Casing Length Size MD TVD Burst Collapse CONDUCTOR INSULATED 42" 81 16 114' 114' SURFACE 3072 11.75 3109' 2238' INTERMEDIATE 2 11305 7 11338' 6407' INTERMEDIATE 1 8804 9.625 11753' 6613' LINER 2095 7 13433' 7152' OPEN HOLE 1915 6.125 15348' 7155' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Open hole 13,433-15,348 . 7,152-7,155 3.5 L-80 13337 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=Nipple • MD=1894 TVD=1653 NIPPLE-HES XN LANDING NIPPLE • MD=12714 TVD=7010 PACKER-BAKER PREMIER PACKER ' MD=12724 TVD=7013 XO-REDUCING-XO 4-1/2"HYD 563 B X 3 1/2"EUE P - MD=12742 TVD=7018 12.Attachments: Proposal Summary p' WellBore Schematic F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17. 14.Estimated Date for 15. Well Status after proposed work: 08/01/16 OIL r WINJ r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r• GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: Dusty Freeborn/Jan Byrne Printed Name Dusty.Freeborn Phone:659-7126 Email: N1617@conocophillips.com Title: Well Integrity Supervisor Signature a . Date: 18 July 16 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `Liz ^ 31 Rug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No V Subsequent Form Required: 1 U 4 D IF g/t Approved by: P5L_. COMMISSIONER APPROVED BY C THE COMMISSION Date:g-2,14 1/7/- 3 2g`ll to ?I Ir �iif—�(J Submit Form and Form 10-403 Revised 11/2015 O r�v �lc i al d for 12 months from the date of approval. Attachments in Duplicate RBDMS (.t- AUG - 2 2016 • ✓ , , RECEIVED ConocoPhillips JUL 21 2016 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 18 July, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well CD1-49 (PTD 212-177). The request is for approval to set a retrievable tubing patch to regain TxIA integrity. Please contact Jan Byrne or myself at 659-7126 or if you have any questions. Regards, /tCW Dusty Freeborn Well Integrity Supervisor • • ConocoPhillips Alaska,Inc. CRU Well CD1-49 (PTD 212-177) SUNDRY NOTICE 10-403 TUBING REPAIR 7/18/16 On October 13, 2013,the AOGCC was initially notified of suspected TxIA communication while on water injection. A leak detect log was performed but no apparent tubing leak was identified. The well was returned to injection but again showed signs of TxIA communication. The well was shut in February of 2014. With the advancement in leak detection tools the well diagnostics have recently identified a tubing leak at 12,724' RKB, at the upper connection of the packer. The repair plan is to set a retrievable patch over the leak point, conduct an MITIA to verify tubing and patch integrity, and return the well to its normal injection status. REPAIR PLAN 1. Set 20' 4.5"retrievable tubing patch over the leak at 12,724' RKB. 2. MIT-IA to verify patch integrity. 3. Submit 10-404pos p t-re air. NSK Problem Well Supervisor WNS INJ • CD1-49 ConocoPhillips Oa Well Attributes Max Angle&MD TD A..ISK�1,itll;. " Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) 501032066100 ALPINE INJ `r 92.05 13,892.55 15,348.0 • s'mococ+eeR I -- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD1-49,1/5/20163:10.07 PM SSSV:Al INJECTION VALVE I Jl Last WO: 35.99 7/14/2013 Vertical schematic(actual) ` _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 4,224.0 12/6/2014 Rev Reason:SET XXN PLUG pproven 1/5/2016 HANGER;30.8- Al Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR Insulated 16 15.250 33.0 114.0 114.0 62.50 H-40 Welded .._... .. -_42" ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 11 3/4 10.772 36.3 3,108.5 2,338.0 60.00 L-80 BTCM 1::.-!r;::.".; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread :.j .�s INTERMEDIATE 1 95/6 8.835 2949.2 11,753.0 6,612.6 40.00 L-80 Hyd 521 `� :�+ -_--Casing DescdPDon OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE2 7 6.276 33.3 11,338.0 6,407.2 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �:,:, LINER 7 6.276 11,338.0 13,433.0 7,151.7 26.00 L-80 Tenaris Blue Liner Details CONDUCTOR Insulated 42'; 330-114.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 11,338.0 6,4072' 60.34 PACKER HRD-E ZXPN LINER TOP PACKER 7.625 NIPPLE;1,894.1 11,353.5 6,414.9. 60.35 HANGER FLEX-LOCK LINER HANGER 7.625 11,363.2 6,419.7' 60.35'SEAL ASSY LATCHING BULLET SEAL ASSY w/SEL BORE 6.200 COUPLING ]l;' .rt 11,367.0 6,421.6 60.36 SLEEVE "HRD-E"LINER SETTING SLEEVE w/Latch profile 6.200 r' ! .-f 11,375.9 6,426.0 60.36 CONNECT BAKER QUICK CONNECT 6.059 • • 13,427.5 7,151.1 84.09 Stabilizer Baker SDL INTEGRAL STABILIZER 6.070 • • • Casing Description 1013(in)1)8 IID Fn) Top(ftKB)13,433.0(Set Depth(ftKB)15,348.0'Set Depth(TVD)...'WtlLen(I...'Grade 'Top Thread OPEN HOLE 6 Tubing Strings • • Tubing Description (String Ma...ID(in) Top(ftKB) I Set Depth(ft..Set Depth(TVD)(...I Wt(Ib/ft) Grade Top Connection SURFACE;38.3-3,106.5 TUBING 41/2 3.958 30.8 13,340.1 7,141.2 12.60 L-80 IBTM 4.5"x3.5"@12742' Completion Details Nominal ID J l Sr, Top(ftKB) Top(TVD)(ftKB) Top Incl 1°) Item Des Com 30.8 30.8 0.00 HANGER FMC TUBING HANGER(Elastomer) 3.900 1,894.1 1,652.9 51.81 NIPPLE BP-6i CAMCO HYD LANDING NIPPLE 3.812 12,713.8 7,0102 72.83 NIPPLE HES XN LANDING NIPPLE ,\ 3.8`3870 INTERMEDIATE 2;33.3- = 12,723.7 7,013.1 72.93 PACKER BAKER PREMIER PACKER 11,338.0 12,742.0 7,018.4 73.13 XO-Reducing XO 4-1/2"Hyd 563 B x 3 1/2"EUE P 2.992 ( 12,743.5 7,018.9' 73.15 NIPPLE HES XN NIPPLE 2.813'2.75 NO GO 2.750 13,098.8 7,101.0 78.43 SLOTTED 3-1/2",Slotted Liner,SLHT,9.3#,L-80 2.992 ® 13,129.7 7,107.2 78.42 PERF 3-1/2"SLHT Pert Pup 9.3#L-80 2.992 } 13,135.4 7,108.4 78.42 SLOTTED 3-1/2",Slotted Liner,SLHT,9.3#,L-80 2.992 [CE ` 13,227.0 7,125.1 80.62 PERF 3-1/2"SLHT Perf Pup 9.3#L-80 2.992 I 13,232.7 7,126.1 80.77 SLOTTED 3-1/2",Slotted Liner,SLHT,9.3#,L-80 2.992 13,325.1 7,139.3 82.70 PERF '3-1/2"SLHT Perf Pup 9.3#L-80 2.992 I 13,336.6 7,140.8 82.88 SHOE 3-1/2"Orange Peel shoe,SLHT,9.3#,L-80 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) INTERMEDIATE 1;2,0492- Top(TVD) Top Incl 11,7534 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 12,743.0 7,018.7 73.15 PLUG XXN Plug w/FILL EXT(OAL 52") 1/1/20)6 0.000 GAS LIFT;12,167.5 13,686.0 7,171.6 87.30 FISH BHA STRING 7/10/2013 2.000 % 1t Mandrel Inserts 1, 'Y v st II oil Top(ND) Valve Port Size TRO Run NIPPLE'1213.8 N Top(ftKB) (ftKB) Make Model OD(7n) Sery Typepo Type (in) (psi) Run Date Com , CI) Ic 12,187.5 6,821.0 CAMCO KBG-4- 1 GAS LIFT DMY BK 0.000 0.0 2/6/2014 ��/ '1 5 ' \TPACKER;12,723.7 I tes:General&Safety V End Date Annotation xO-Reducing;12,742.0 aA y,,11/18/2014 NOTE:7",26#L80,Tenaris Blue from 11,361.53'to 12,995.47'MD' 11/18/2014 NOTE:7",29#TN1IOSS,S.D.6.125"Tenaris Blue from 12,995.47'to 13,398.48'MD' NIPPLE;12,743.5 PLUG;12,743.0 I I SLOTTED;13,098.8 ,{,y��y� PERF;13,129.7 SLOTTED;13,1354 1 PERF;13,227.0 m3 SLOTTED;13,232.7 j PERF;13,325.1 SHOE;13,336.8 E 1 LINER;11,338.0-13,433.0 _o FISH;13,880.0 "0) OPEN HOLE;13,433.0-15,348.0 • Bettis, Patricia K (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday,July 22, 2016 10:44 AM To: Bettis, Patricia K (DOA) Subject: RE: CRU CD1-49 (PTD 212-177): Sundry Application Patricia, The current plug back depth for CDU CD1-49 (PTD212-177) is 13,686' MD/7,172' TVD. Located at the BHA tool string left down hole. Please let me know if there is anything else you may need. Thank you. Cheers, Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 AWELLSTEAM C From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,July 21, 2016 1:55 PM To: NSK Problem Well Supv<n1617@conocophillips.com> Subject: [EXTERNAL]CRU CD1-49 (PTD 212-177): Sundry Application Dusty, What is the plug-back depth for CRU CD1-49, both MD and TVD? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, July 21, 2016 1:55 PM To: NSK Problem Well Supv (n1617@conocophillips.com) Subject: CRU CD1-49 (PTD 212-177): Sundry Application Dusty, What is the plug-back depth for CRU CD1-49, both MD and TVD? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. oja_ 1 7i. Well History File Identifier Organizing (done) p Two-sided ❑ Rescan Needed 7RE AN: OVERSIZED: NOTES: Co r Items: ❑ Maps: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: r Date: 1 (6S— /s/ re Project Proofing BY: Ai= Date: 6 /s/ rit3 c2 1 Scanning Preparation 7 x 30 = 1 O + 5 =TOTAL PAGES Vrr (Count does not include cover sheet) BY: Date: 1 6 /c /s/ r I Production Scanning Stage 1 Page Count from Scanned File: 04-3 ) (Count does include covers eet) Page Count Matches Number in Scan ing Preparation: YES NO BY: MED Date: 1 ici15 /s/ mp Stage 1 If NO in stage 1, page(s) discrepan es were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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N. c > co CO CO co co co co aco CO a (o (a w N R V V V V V V V V - y T- NN N N N N N N N N N N N a1 W N a a) re E E Z 6 v Z c y a U U 0 0 0 0 0 0 0 0 0 0 0 0 p CL 0 8j aE 0 0 0 Q 0 0 0 0 0 0 0 0 0 o IliZ 2 w w w w w w w w w w w w J - 0 o 0 No N 4Q Q II I y L J Z Z I o I ba N u) 1 l ¢ r' U_ a' L an >, c7 o a. m v an Ev2 c o' Q c o a o I 3 aa_a 1° Q m a' a z U U � Q Y It9 0 co H ,H!N •JN IIa tIIJ 0 a W I al � N Ce 0a' m U u- £ N W z z rn V V : ni co I y'al O • 2 0 0 CL v. c C , o O a' OJM aE I I 1 en U O6Q C woO 0 I bA I E M o w N• a7 C Z'a' E CO cccn O I- E J a' 7 ` Cl) —> o cO o \;4k. 440 U N c -E o_ a m O 4 Q 2 p N V •T I `� 0 E 0 o 2 0 1 1 1111 z , l M N W I I \ 3 ,r, o 0 N N I _ N C o n N EO O N r `c N N CL Nrt a' 03 F' ro U 0 O c y c Z c O tl V O in O O ''I Q O 0 le. c c U ay+ I J a' • ' N • IR . o a a m w E a E 0 E o 0 O o aO) w o E ¢ a 2 0 a 0 „ O 0 c 0 I 8 2___\ t,11 F/t 0 BAKER PRINT DISTRIBUTION LIST DATA LOGGED HUGHES M.5/K.BENDER COMPANY ConocoPhillips Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME CDI-49 RUN NUMBER (mandatory) FIELD Colville River BH SALESMAN Christian Klotz (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: July 2,2013 TODAYS DATE: 12-Aug (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY CD (digital FINAL digital/ ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #OF t-NIN I S #OF COPIES #OF COPIES 1 State of Alaska -AOGCC 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 2 s E,CEiVED AUG 12 2014 AOGCC 4 5 6 I TOTALS FOR THIS PAGE: 0 1 1 0 0 0 • 0,1.5-.,\7i//7,-t 4, THE STATE — ,r , ,---,_ :F=, �� ~mc 4{-0 _, I _ - ,=_‘ re =,1::.,:t:-:.,_- . 333 Wes' Seventh Avenue t___ __ i Anchoro e, Alaska 99501-35/2 GOVERNOR SEAN PARNELL 9 1 r-�x,o' Main 907 279 1433 : ��Rc:�e` =ox 907 976 75/2 a I a- tirl Mick Davasher Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-49 Sundry Number: 314-245 Dear Mr. Davasher: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a4 P.7.1,41., Cathy P. erster Chair DATED thisLLS day of April, 2014. Encl. STATE OF ALASKA r 1 !i K!4 A IL AND GAS CONSERVATION COMM IS', DT5 4-i/S/f es ' • • APPLICATION FOR SUNDRY APPROVALSrj --,,-•�. • 20 AAC 25.280 � � 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Farforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casino r Other:Production Packer Repair Ri• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r -- 212-177-0 • 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 "S- 50-103-20661-00 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 p N. CD1-49 9.Property Designation(Lease Number): X10.Field/Pool(s): ADL 372097,25559 - Colville River Field/Alpine 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): 15348 ' 7155 - 13686' • 7171' , none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 114' 114' SURFACE 3072 11.75 3109' 2338' INTERMEDIATE 11715' 9.625" 11753' 6613' LINER 2095 7" 13433' 7152' Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 4.5"x 3.5" L-80 13340 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) PACKER-HRD-3 ZXPN LINER TOP PACKER ' MD=11338 TVD=6407 PACKER-BAKER PREMIER PACKER % MD=12724 TVD=7013 NIPPLE-CAMCO HYD LANDING NIPPLE ' MD=1894 TVD=1653 12.Attachments: Description Surrrnary of Proposal - f;, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F- 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/16/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG Fi - Abandoned r Commission Representative. GSTOR r SPLUG i- 17. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mick Davasher @ 265-6870 Email: Mick.J.Davasher@conocophillips.com Printed Name Mick Davasher Title: Sr. Wells Engineer _ Signature VIA9O t / Phone:265-6870 Date /51 Zo/(f rA Commission Use On RBDM ' MAY U 7 2014 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -j k —2-4S Plug Integrity r, BOP Test r Mechanical Integrity Test t ' Location Clearance r / / J Other: . -l /-[-1{. W , t•s t-/'-? S 6/ /Vt I T- /4 rt 7 v/ r-e-G! a. I tt I C! 2-c G/t lt � re- t ,7 / � - Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /2 APPROVED BY /r / Approved by: � a ' OMMISSIONER THE COMMISSION Date: /I S —I App •ved app I ation is valid tor 12 months from the date of approval. Form 10-403(Revised 10/2012) •lam till slly Submit Form and Attachments in Duplicate 1/ /124// /4 71—'4' ORIGINAL • gib alp C ,M. ConocoPhillips Lp„ 5 Alaska ��`^^�� P.O. BOX 100360 �='+`,.��-,71(1 ANCHORAGE,ALASKA 99510-0360 10 April 2014 State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit— Request to repair leaking packer Dear Sir/Madam: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to repair the leaking packer in CD1-49 by placing a 300' resin plug on top of the packer. CD1-49 is an Alpine C injector that was drilled and completed in June/July 2013. The well was converted to injection in September 2013. In October the well started to demonstrate suspected TxIA communication. The well was left on injection for a further 30 days to see if the TxIA communication would stabilize. By the end of October the IA did not appear to be stabilizing and was shut-in. In late November, the downhole diagnostics team ran a series of mechanical integrity tests and drawdown tests with varying outcomes. It was decided to conduct a waterflow log while bleeding down the IA. The log did not detect a leak and the well was approved to be returned to service. After six days of service the TxIA communication re-appeared. The well was approved to keep injecting for a further 30 days to evaluate the communication. An Ultrasonic LDL was run on 1/31/2014 while the well was still on injection. The leak was found to be at the production packer. The objective of the proposed packer repair is to pump a 10.5ppg resin pill into the IA through the GLM. The resin pill will swap out with the lighter packer fluid and cover the leaking packer. It is intended to save the functionality of the GLM. After the resin cures, coil tubing will mill out the composite plug. CD1-49 will be returned to injection service after obtaining a passing MIT-IA. The attached proposal illustrates the plan forward. If you have any questions or require any further information, please contact me at 265-6870. Sincerely, VV ` Mick Day sher Wells Engineer CPAI Drilling and Wells 4101) • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 CD1-49 Packer Repair Procedure Outline 1. Set a composite bridge plug at 12,217' MDRT (30' below the GLM). 2. Pull Dummy Valve from GLM and install a Circulation Valve. 3. Rig up Coil Tubing. Pressure test PCE as required. 4. RIH with coil to 20' above the GLM and circulate two tubing volumes of 140 degF diesel through coil and up the TxCT annulus (this brings the coil and tubing to temperature to ensure the pumpability of the resin product). 5. When temperatures are sufficiently high, pump resin product into the IA with the following schedule: a. 140 degF diesel followed by; b. 10 bbls inhibited 9.0ppg brine c. 6.0 bbls 10.5ppg Resin d. 10 bbls inhibited 9.0ppg brine 6. Wait 30 minutes for resin to swap with IA fluid. 7. Pump 10 bbl solvent pill to contaminate resin in tubing, to jet across the GLM to ensure functionality of the GLM, and confirm circulation to the IA. 8. Rig down coil tubing. 9. Rig up Slickline 24 hours later. Pressure test PCE as required. 10. Confirm circulation from tubing to IA. 11. RIH and retrieve circulation valve from GLM. Install Dummy Valve in same GLM. 12. Rig down Slickline 13. After a minimum of 7 days since resin was pumped, perform a MIT-T and MIT-IA to 2500psi. If MIT-IA fails may need to pump another resin job. If this is done the GLM will be lost. 14. Rig up coil tubing. Pressure test PCE as required. 15. Mill out composite bridge plug. 16. Rig down coil tubing. 17. Return CD1-49 to injection service. , ilk IIII. Ili II, P Conocos pPhilli Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 / ,-\ WNS SVC CD1-49 ConocoPhilbps \ - r 1 n atirIbutes Max B. Mgle&MD ID ti.:1i63.t`E. I _ 53103X86100 94070E 0.64 ISYD 1 32 D61�� '3}9255 K em IS USC _. Cm.... 1""" I" .9r. or0444N. 6 .1 le . a14 96 'M.11•111•1•••• . , G . .on, 4p. rr'N 583V.Al INIEcrCt VALVE LO 3599 7042813 16601 mr A•1r...1 P..6.w.:.oa1 Lat'r, lc". 1004 R..RE ,DAV C.O 10 LL FL YA:YE um as erApW.f I�'a'1.2011 .A.c[4 v T Lasing C5,5992 CO b1 1905,1 Tap 45.41 a.Cepa 111681 1r 0941 PEP-PEP-RE.9..mr TaP E17.411 R'19' CC4131-1O6•44.04d 1E '5250 33.3 1140 114 C 6225 11.80 W.983 •�3aT 7f.‘, L..a lC.nV�•.' ®Oy 190'1 l5,015,8, a.1 Cep•14.13 Sr ORE 0342.MI..X 3-W TeeBI T9... _ SLRPACE 1134 '277: 36.3 31[85 01338E 69.X 323 BIDS tree 6.v4m, Q911., IC 491 Tan 0389 El Gera mNI 6r 0041!17[94..6ARr1 9..man Tap 1T1�8 INTERME.D.IATE' 956 6835 2.9492 "7530 66128 40.X L-63 4W 521 %.'▪' .INTERMEDIATE ISO 0., 19091 166 4001 3.4o43 MINI .8r 19941 rm...921301_.'0.33 166 ro� �..� IINTERMECIA7E2 7 52751 33.3 '13380 64971 26.X L'S) STOW Cr..1947700474 CO al IC Ont1 E 7/1.1r 1 Gra 11681 asatTTY .60 9a...rE.p..On. rep 002 2 LINER 7 6275 1'3283 '31330 7 151 7 28 X9L23 To..ESN FLEO -V 6 LIE '5 3. 335,14: 01 TTA 6338; Rd 059 9. Col vstiaar 1000ep T113386 643721 Tw n rC.6[234 ASE+ NREE E9'N 1EER 701 7PACKER 7.623 113515 6,4149 60.X NA11C3,. 00NER 81110 7.6- • 9aa PET 1b1 1 L 4.354SA.07 SEEM tABS4 LA XHIN6 BULL,P-777.4457.964 EAME 6-EC COUPLMO - 1 E 367.C 6.421 6 60.36 SLEE F_ '•*10.2 OPER 56700G SLEEVE.'LANE pr.% 619 r.. ,j 11375.9 8.126:) 6C. CANIE31 BAN 01)3110E..0ENC! 6769 1342/4 7,151.1 3433 EIRE ! PN.413 INTE.s.AL 3TA311.i J 6079 CP'EM NOCe I°° 61.6119 pro Tg1t,ai I"Cepa 596 tl,.Ceps.Tvp..I.wL.1 4..1mr I1991W * Tubing Strs9gs I` ._94194[[mil 1E1 ♦ • ',".7,2-"`" 'S) De "4/119 7113 95811""n0.1""711:07`,1""'"17'41 Som"32.03 1.22 1ETNollrmin 4.5'3.5 ..12713' aopi 117P 171.171 Tell i 7477 11 04 C 1 3)33 T 335 ..oe N4t16t-. FMC _3IFia:A/3E'.i,aswlrl i 3.930 Id90 I 1,6E21 5i9(41,43E SSI.7)4.0 WE.,IM1:136U NPP-E 3912 '27138 7:3102 7..81 94.073E 03 8 311 03110)11..470.E 3.613 wTv1r¢ur:v> 127737 7,013.1 72.43 7943}(66 8941166 PRESIIEE PACIER 3.870 1Ta- 12,7420 7.318.4 73.11 X0-R.lunp :[04.1.2'11,4563 Ba 31.2'EUE F 2.502 7273717! /,018.9 73.1$MPP_E R R NP _711 T7.7514 *0 2.150 130988 7,161.3 843 SLCT7ED •31.2',31ma13lil�,801,9.111 -90 I992 1 13119.1 7,1079 78.11 7603 33':'9013':'901P6/1095 93202[ 24112 131354 7,1081 78.42 SLOTTED 3-1.2',900tl Lt.,SUET,9.31 LEP 2.902 132176 7,18.1 80. 03 1-130BLNT0.6P1p 033LS6 2902 132127 7,126.1 80. 6T7ED '3.13',Wm.33..39617.9.31'L20 2.922 13381 7,1393 82. • TE '31781347Pr1.4P 9.39 L-BC 2.992 '33366 7,140.5 6296 E]ICE 31.2'09001 Par.04.SLIT,930.:20 2.992 Other In Flom(WWrels3e varves,pumps,fish,eta) e-rcur_w _t71,41 ^_ 3•3,68601 1 7,'71116 r73441 678600 [m l71032'3Rue r I I92XG '-_ 1491199!Inserts 111 CI Pt on NE( 91 T.1er .. s!921 Y.5, !9211 REM ,n5,. CM,331 s.. w. 16• h 10 r 1 ! ,100 P.Ms TRO nen m '( 12'875 6,82•:)C4.33-4-5EO 4.33-4-54-5 1 GAS LIFT DWT B( 0003 0C i16'2C'4r 97413 111.8 a 10 PAGER-12 TA 7 X .97.11.2.4 UTC[ 1 9243 v,w mom scr Ear 330=7ili ..-,,,U Int r RE 19mp444.- -® METED n=7 WY-nae RE 434•05111k Ol6 70G2•11,430174340. • 1 0 0 . , • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 C D 1-49 Downhole Diagram Sketch ConocoPhillips / / POST—Resin Packer Repair Alaska ' " 16"65#H-40 Welded AM , Conductor to 114' 1111 II 1111: wiiii �Liii ' 11-3/4"60#L-80 BTC Surface Casing 3,143'MD/2,350'TVD @ 60° cemented to surface ilii • • 4-1/2" 12.6#L-80 IBT-M Surface—9,000' iii ii Hyd 563 9,000'-12,500' il ii ;':ice 7"x 9 5/8"Liner Top Packer Approx. 300' resin product in IA ?i ?; @ 11,338'MD/6,432'TVD from Packer to GLM. Top of resin at 12,187.5' MDRT. 4?t?t 9 5/8"40#L-80 Hydril 521 Line to 11,753'MD/6,615'TVD Composite plug set at 12,217' MDRT(to be milled out after resin "' placement) 3'/2"9.3#L-80 SLHT Liner w%t ;,,:.s d 6"Hole,TD 7"26#L-80 Tenaris Blue Liner to 13,433'MD/7,151'TVD @ 84° 212 \-11 23965 Z3c2\426 WELL LOG TRANSMITTAL II• PROACTIVE DIACINOSTIC SERVICES, INC. DATA LOGGED Kit/2014 M NDER To: State of Alaska-AOGCC Makana Bender RECEIVED 333 West 7th Ave Suite 100 MAR 0 4 2[. Anchorage,Alaska 99501 (907] 793-1225 AOGCC 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 31-Jan-14 CD1-49 BL/ CD 50-029-20661-00 2) Leak Point Survey 01-Feb-14 CD1-49 BL/ CD 50-029-20661-00 Signed : o d 1` Date : '2441 Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFdes\Templates\Dtstnbutton\TransmittalSheets\ConocoPhdhps_Transmrt docx z12-t`t 11111 RECEIVED FEB 122014 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 30, 2014 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7t`Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). 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 in the spring of 2007. The corrosion inhibitor/sealant was pumped in the month of January 2014. 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, ,/,'W /L. aaM---- Martin Walters ConocoPhillips Well Integrity Projects Supervisor 4116 Ill ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 1/30/2014 CD1&2 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 CD1-10 50103203530000 2001710 18" na 18" na 15.3 1/20/2014 CD1-12 50103205010000 2042050 4" na 4" na 4.5 1/20/2014 CD1-14 50103203710000 2010380 4" na 4" na 3.5 1/20/2014 CD1-18 50103205020000 2042060 4" na 4" na 2.7 1/20/2014 CD1-26 50103203050000 1990880 6" na 6" na 6.4 1/20/2014 CD1-35 50103202970000 .1990380 4" na 4" na 3.5 1/20/2014 CD1-45 50103203070000 :1991010 4" na 4" na 3.7 1/20/2014 CD1-48A 50103205920100 2120040 SF na 5" na 2.8 1/20/2014 CD1-49 50103206610000 2121770 12" na 12" na 2.4 1/20/2014 CD2-1 50103205140000 2051180 4" na 4" na 4.6 1/27/2014 CD2-3 50103205120000 2050920 4" na 4" na 4.4 1/27/2014 CD2-5 50103204950000 2040970 4" na 4" na 3.5 1/27/2014 CD2-19 50103204230000 2021120 4" na 4" na 4.9 1/27/2014 CD2-21 50103205040000 ,2042450 6" na 6" na 4.2 1/27/2014 CD2-22 50103204210000 2020920 27" na 27" na 11.5 1/27/2014 CD2-32 50103204110000 2020290 4" na 4" na 2.7 1/27/2014 CD2-34 50103203930000 2011910 6" na 6" na 2.7 1/27/2014 CD2-36 50103204470000 2030140 7' 0.95 5" 3/21/07 5.7 1/27/2014 CD2-39 50103203870000 2011600 34" na 11" na 17.9 1/27/2014 CD2-49 50103204010000 2012490 8" na 8" na 5.2 1/27/2014 CD2-52 50103204590000 2030930 5'7" 0.80 4" 3/21/07 3.5 1/27/2014 CD2-54 50103204990000 2041780 8" na 8" na 5.4 1/27/2014 CD2-57 50103204920000 2040720 8" na 8" na 2.7 1/27/2014 CD2-72 50103205460000 2070570 6" na 6" na 4.3 1/27/2014 CD2-73 50103205900000 2081960 4'5" na 4'5" na 24.2 1/27/2014 CD2-465 50103205830000 2081450 19" na 19" na ,9.3 1/27/2014 111, III • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 1/30/2014 CD3&4 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD3-107 50103205290100 2061890 2'10" na 12" na 12.7 1/28/2014 CD3-108 50103205070000 2050330 10" na 10" na 3.2 1/28/2014 CD3-115 50103205930000 2090060 8" na 8" na 2.9 1/28/2014 CD3-119 50103206530000 2120070 19" na 19" na 1.7 1/28/2014 CD3-122 50103206090000 2091530 6'1" na 6'1" na 32.3 I 1/28/2014 CD3-123 50103206170000 21b0310 17" na 17" na 5.1°'', 1/28/2014 CD3-124 50103206120000 2100080 17" na 17" na 5.1 _ 1/28/2014 CD3-125 50103206320000 2101890 14" na 2' na 2.1 1/28/2014 CD3-127 50103206340000 2110050 8" na 10" na 3.4 1/28/2014 CD4-16 50103205350000 2061310 SF na 5" na 4.8 1/28/2014 CD4-27 50103206440000 2111460 SF na 15" na 1.7 1/28/2014 CD4-208A 50103205170100 2110600 SF na 7" na 2.9 1/28/2014 CD4-210A 50103205330100 2110720 SF na 7" na 2.9 _ 1/28/2014 CD4-301B 50103205570200 2071800 SF na 7" na 4.2 1/28/2014 CD4-318A 50103205190100 2061130 SF na 7" na 3.4 1/28/2014 1111, S Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, January 07, 2014 7:45 AM To: 'NSK Problem Well Supv' Cc: Senden, R. Tyler Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Kelly, Approved to keep well online for additional 28 days monitoring and diagnostics. If still undetermined by the end of the month, add an update to the monthly report with a plan forward. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7Th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Tuesday, January 07, 2014 6:54 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Chris, There is a correction to the report below: due to a miscommunication,there was not water in the annulus. Samples, which were taken that day, were reviewed and freeze protect dead crude was in fact confirmed on the backside. Due to the intermittent nature of the apparent communication, we have continued to keep the well on-line in order to keep the suspected leak active so that an LDL can be run. However, logistics have proved problematic due to weather and lack of availability of logging resources. An additional unexpected manpower resource issue has newly arisen and therefore logging will now have to be delayed till next week. Because of the extended time that the well will need to be online, CPAI requests permission to keep the well online till the logging can be completed. We have been maintaining the IA below 2000psi by limiting injection pressure. Attached is an updated 90 day TIO plot. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907)659-7000 pgr 909 1 411110 (tuarioototi D S ..•"-1 .-- •-- I I.i ' .1• 0 • I, .1• I •l• .1• II . 1.• •I• I . II Fl • 1 •I. .1, 1 .1 .1• 03 . . . . . . US .• . . . . . i• : i _ C.) • • e • • . . I• . . ' II . . 1.....----- • • i • • — . . . . • • . . .. . . . . • • • • • I:• . . . . . . . . • 'I . I : • • • ..I • • ..- CV) . . • . ', ku . . . . 0 :..... ... • • . . . . t . . y- . . - . ,. . . . . . . . . . . . . . . . • • - • - • i 1.--- . . . . . . . . . . . . . • • • . • • .,... ...._ . . . . 1 -: . . . . . _ • • • . _ . . . . . . • • • • • . ._ . . . . . , _ .... . . . . . . • . . ... . _ . . . . . . . . . . . — el i. •,--- i cr, — • . . • . — 0 .1. • . • • . . . • . . . . . C ' . . • . is....) • . • . . . • . . . . . • I : • . cu ...-. . • • • . • _ 173 4..• . _ . . . CI 0 - • • I : . • 4... " • ' " ' C. . . . .1 . . • • • ' • 0 . . . • .—. -- ...‘ .... • . , ' • I . . —•• • • . . .-- , . . • . • :: • • . • . . . . . . . • . • . • . ' • . • . ... . . . . . . . . • • ' • : ....._. _. :: . . . . . • . • • — 0, • ' . . ..— . . . . 'IC • • • —,— 0 — . . . . . . ,..„. . . . . ..._ . • • • • . . . . . . 1-.....1 • . . . _ .:) • • ' ' • . : '..________.___: ____.1 .: . . • • _ • --__ . / I.1 - • • . • . I..- • • • • Ce3 • ' I.'. . . . . • • . r — . • • •• • _._, 415 • ' :. • ' . . I I • C43 . . • II'. . • . . . 1,• . EL • • • • - ., L_ . • • • • i• I • • ' • • • • . . . I• . . . • • I:. • • • . . • • • • • - 0'3 • • J • • • • • .1, • • • ,_ . . •I . . . .....7, W , rt t i'l l•f I t-I rt ',Hi tit 11 '1 rt f tit 11104 ri ,...0 ..._.) C) 11 c7.3, C) C) C) C) C 1 Y. n (-) C3 C) C) C3 r-- 0 () cu) C) u) c-> ..—) .7) CI CN r, 1 ISd ki WELL LOG TRANSMITTAL ATA GG To: Alaska Oil and Gas Conservation Comm. December 20, 2013 DT; �2LO./2014ED Attn.: Makana Bender M K BENDER 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 -.. lit 2 6 (U ;7, AOGCC RE: Leak Detect Log W/ Spectra Flow: CD 1-49 Run Date: 12/17/2013 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 CD1-49 Data in DLIS/LAS format, Digital Log file, Interp. report 1 CD Rom 50-103-20661-00 Leak Detect Log W/Spectra Flow (field print) 1 Color Log 50-103-20661-00 SpectraFlow Oxygen Activation Log(post-processed) 1 Color Log 50-103-20661-00 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.cook@halliburton.com Date: ‘194 N Signed: di b.,24,6x., zY12ke) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 20, 2013 Attn.: Makana Bender LD 333 West 7th Avenue, Suite 100 DATA 2-2014 M K BENDER Anchorage, Alaska 99501 RECEIVED IDE. 2 6 2013 RE: Multi Finger Caliper: CD 1-49 AOGCC Run Date: 12/20/2013 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 CD 1-49 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20661-00 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.cook@halliburton.com Date: (-z....I\4 Signed: �J�� — / Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, December 23, 2013 7:40 AM To: 'NSK Problem Well Supv' Cc: Senden, R. Tyler Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Brent, Thank you for the update. Approved for return to injection. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage,AK 99501 (907) 793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, December 20, 2013 5:11 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Chris, The well was BOI on 12/07/13 in preparation for the water flow log. The water flow log was performed on 12/17/13. The IA was bled down for the logging and showed no signs of communication during the time of logging. Below are the results of the logging: OPEN IA TO CD1-48 FLOWLINE, BLEED DOWN TO 190 PSI, PERFORM CHECKS FOR FLOW UP IA USING SPFL, CHECK IA AFTER 15 MIN -STILL AT 190 PSI, NO FLOW SEEN ON SPFL AND IA NOT TRACKING WITH TUBING PRESSURE, INCREASE INJ RATE FROM 500 TO 1700 BWPD, INCREASE TUBING PRESSURE FROM 1800 TO 1900- IA PRESSURE FROM 190 TO 200 PSI, IA WILL NOT PRESSURE UP BEYOND 200, PERFORM CHECKS FOR FLOW UP IA AT INCREASED RATE, NO LEAK FOUND USING SPFL OR OBSERVED IN IA PRESSURE, LOG TEMP OUT OF HOLE. ConocoPhillips request to return CD1-49 to injection under AIO 18B. If pressure trends indicate further pressure anomalies the well will be reported to the AOGCC at that time and further diagnostics will be planned. Let me know if you have any questions or would like any further data. Please let me know if this is acceptable. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 1 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, December 02, 2013 12:44 PM To: 'NSK Problem Well Supv' Cc: Senden, R. Tyler Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Kelly, Approved for continued water injection for monitoring and diagnostics including running the waterflow log(s). Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocoohillips.com] Sent: Monday, December 02, 2013 12:11 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Chris, After setting a tubing plug in early November, initial diagnostics were completed last week. MITT/MITIA/CMIT/DDTs had varying outcomes. Because the relatively small leak is of an intermittent nature and more evident in the direction of tubing to IA and not vice versa, we believe a waterflow log while bleeding the inner annulus may give us the best opportunity for identifying the leak point. Since water flow logging technology requires the usage of water, CPAI requests permission to bring the well on water injection temporarily, long enough to complete the logging. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 From: NSK Problem Well Supv Sent: Friday, October 25, 2013 4:09 PM To: 'Wallace, Chris D (DOA)' Cc: Dethlefs, Jerry C; NSK Problem Well Supv Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Chris, •The IA pressure does not appear to be stabilizing. The well has been shut in and further diagnostics will be scheduled. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 From: Wallace, Chris D (DOA) [mailto:chris.wallace(aalaska.gov] Sent: Tuesday, October 15, 2013 2:07 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Jolin, Approved for 30 days injection for additional monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542 (fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocoohillios.com] Sent: Sunday, October 13, 2013 1:39 PM To: Wallace, Chris D (DOA) Subject: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Chris— Alpine Injector CD1-49(PTD#212-177-0) is demonstrating suspected TxIA communication based on bleeds of the IA over the past week. The well may still be normalizing itself to being an injector as it was only recently converted to an injector and was first brought online on 09/28/13. The well passed a witnessed MIT-IA on 10/05/13. Since the MIT-IA, the pressure has built up above 1,900 psi two times in a couple of days with subsequent follow-up bleeds to allow the IA to stabilize to its new operating conditions. CPAI requests permission to leave the well on injection for 30 days for further monitoring and to allow the well to continue to stabilize as a new injector. If the well continues to show signs of suspected TxIA communication and does not show a stabilizing trend, it will be shut in for further diagnostics. The well has been added to the monthly report. Attached is a 15 day TIO plot rather than a 90 day TIO plot due to the well being an injector for only—14 days. Let me know if you have any questions. Regards, Jolin Oksness Well Integrity Engineer ConocoPhillips,Alaska 907 659-7224 (c)907 230-7493 2 x2 AM1 RECEIVED 254, NOV 1 ;2013' AOGCC HALLIBURTON I Wireline ire faer- ing DATA LOGGED .\.t/26/2013 .M K BENDER Oxygen Activation Log Evaluation Company: ConocoPhillips Alaska, Inc. Well: CD1 -49 Field: Colville River Unit Borough: North Slope State: Alaska Formation and Reservoir Solutions — Anchorage AK Analyst : Fanny A. Sari Email : fannyartika.sari@halliburton.com Office : 907-275-2605 Report : 10/31/2013 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES,OR EXPENSES RESULTING FROM THE USE THEREOF. 1 1 HALLIBURTON ConocoPhillips 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY 3 2.0 SPECTRAFLOW LOG EVALUATION 4 2.1 IMPULSE TESTS 7 Impulse test#1 at depth 13060 ft. MD, 5000 BWPD injection rate 7 1 Impulse test#2 at depth 13060 ft. MD, 5000 BWPD injection rate 8 Impulse test#3 at depth 13060 ft. MD, 5000 BWPD injection rate 9 1 Impulse test#1 at depth 13080 ft. MD, 3000 BWPD injection rate 10 Impulse test#2 at depth 13080 ft. MD, 3000 BWPD injection rate 11 Impulse test#3 at depth 13080 ft. MD, 3000 BWPD injection rate 12 3.0 WELL DIAGRAM 13 1 1 1 1 1 i I II 1 1 Page 2 of 13 1 ' HALLIBURTOP" ConocoPhillips 1.0 EXECUTIVE SUMMARY ' Well: CD1-49 Oxygen Activation Evaluation Survey date: 18 OCT 2013 Logging Objective Monitor water up-flow movement while the well was injecting on 3000 and 5000 BWPD Conclusions The SpectraFlow Tool was run using impulse tests at two depth 13060 and 13080 ft MD. Three impulse tests were performed in each depth. Test at 13060 ft MD was done under 5000 BWPD injection, and the test at 13080 ft MD was done under 3000 BWPD injection. The tool was run in normal mode configuration (generator positioned below detectors)for water up flow detection. The survey data from the SpectraFlow showed no up flow water movement in this well. I i I i t 1 1 1 l ' Page 3 of 13 I ' HALLIBURTON ConocoPhillips 2.0 SPECTRAFLOW LOG EVALUATION IThe SPFL was run using stationary impulse tests across the zones of interest. Water flow can be detected by measuring gamma rays originating from activated oxygen within any water flowing past the I neutron generator(activation)then moving past the detector section (decay). The fluid/water velocity is estimated from oxygen activation using impulse test data. The flow direction is determined by the position of the sensor relative to the neutron generator. The flow region, near or far, is I derived by the ratio of Compton backscatter gamma rays compared to original gamma ray counts from activated oxygen. Lower Compton ratio indicates a flow region further from the tool i.e. behind the next string of pipe. ITotal oxygen activation will be a function of: • volume of water in the region of neutron cloud • flow velocity of water • tool speed • flow distance to detector • time exposure Below is a representation of the sequence of radioactive excitation and subsequent relaxation of Oxygen. 1 I 016 Spectral Y X6.13�1€va seta ' ' Gamma Ray U1 ` Decay Detector I N15 7.13-sec Half-Life High Energy i n4. oxygen(14-AIIeV) Activation Neutron Generator I 015 E IFigure 1: Sequence events of oxygen activation The tool is configured in the inverted mode with the neutron generator above the detector section. In the I inverted configuration, water will only be detected when moving down relative to the Spectral Flow tool, in both the stationary impulse mode and continuous mode. Any oxygen activation detected by near and far detector should be from water flow down. If there is water 1 flow in the upward direction the GR sensor above the neutron generator will detect the activated oxygen. I Page 4of 13 I HALLIBURTON ConocoPhillips I GR 1 14 Far detector 1 II Near detector V GEN I A I = - f MI I i = - 1 1 1 Figure 2: Flow scenario related to spectra flow log tool I Stationary Impulse Method This technique is basically a travel-time measurement and has the significant advantage of not requiring any calibration of the detectors. When the tool is stationary at a specified depth, the generator is turned I on and allowed to stabilize. The count rate in each detector is then recorded for one or two minutes, at which time the generator is shut down. At some time later (depending on the fluid flow velocity and distance from the various detectors to the source), the count rate recorded in the detectors will drop to I background level. The count rate will drop to nearly zero in the spectral window encompassing the oxygen peak. The surface computer records the various detector count rates, steps down the generator, measures the time until the recorded count rates fall to one-half full value, and then computes a velocity from the travel time. The fluid velocity is the distance from the source to the detector divided by the time I between the count-rate drop and the time when the generator was shut down. The procedure is completely automated. IPage 5 of 13 I HALLIBURTON ConocoPhillips r The spectral data can be processed to provide fluid velocity in one step because the count rate falls essentially to zero after the activation passes. Processing the total gamma ray count rates requires two I steps. The natural background must be measured for approximately one minute after the drop to correct for the nonzero background activity. Fig. 3 is a graphical representation of the timing cycle used by the stationary impulse method. I 110 OAI Curve I 100 90 �� 80 Generator '/ Value I 1 o Voltage ao70 > 60 ° \T o i 50 < V; c 40 30 1Distance to Detector 20 Velocity = 10 AT In 1 0 0 50 100 150 200 Time/Seconds IFigure 3: Stationary Impulse timing sequence I The rate computation: Casing ID =2.992 inch (3.5"tubing), tool OD = 1.6875 inch. Vavg = average water velocity Qw(bpd) = Vavg (ft/min)x 1.4 x(CasinglD2 (inch)—ToolOD2(inch)) 1 1 I I I I IPage 6 of 13 I I II HALLIBURTON ConocoPhillips I 2.1 Impulse tests Impulse test #1 at depth 13060 ft. MD at 5000 BWPD injection rate shows no water flowing up as indicated by the far and near detectors. Both near and far detectors read no oxygen activation when the generator is on. IGR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow upward. There is noise in the Total Near Activation (TNA curve) which should not be use for interpretation. 1 GR cu 1:600 CRATN TNA GAIN 0153 SECS. u "1° iuufV ....0 e4U GENV CRATF TFA OAIF 0A114 c VTOU OLTS 0' '100 100P u t u0 u eau 1240 0A194 ❑ �. NEAR ACT SIT FAR ACT U 24d I ■..■■■■■■■ ■■C■■■■■■■ ■■ri■!■■■■ m. I■E7!■■■■■ ■F■■■■■■■I ■■N!>t■■■■■ILIIIIIMMI ■■FA■■■■■■ ■■FM■■■■■ ' Mj■PJ■■■■■■■ ;�� , ■■C1■■■■■■■ .. ,. --- ■■t■■■■■■■ 1111 ■G■■■■■■■ u■3■■■■■■■ j `■ I ■■■ 1.--:-H 11 , ,..,- . ,h' =■ ■■■■■I■ ■ i ■ II■ .7. 1 1111/111111111/1111111111111111111111111111111•1111111111111111•1111 � . .. ;� ,...�■■c!■ ■■l■ 1111111M11111111111111M111111111111 I ; ,....» FAR ACT NEAR ACT 0A194 GE�NV CRATF TFA OAIF 0A114 c 10. • i. ... . I v'e, 1:600 CRATN MEM OAII. 0 5 SECS. 11.1111MMI111111111C Impulse test#1 at depth 13060 ft. MD, 5000 BWPD injection rate ISPECTRAFLOW RESULTS FILE- 13060_1_m.cls TOOL DEPTH = 13060 FT. I CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR I OAIN 5.82 0.97 NC UP OAIF 0.29 0.00 UNDETECTABLE UP TNA 580.52 0.83 NC UP TFA 89.12 0.18 UNDETECTABLE UP GR 40.39 0.00 UNDETECTABLE UP CRATN 1.00 ICRATF 0.80 IPage 7 of 13 I I i HALLIBURTPI " ConocoPhillips Impulse test #2 at depth 13060 ft. MD at 5000 BWPD injection rate shows no water flowing up as I indicated by the far and near detectors. Both near and far detectors read no oxygen activation when the generator is on. GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow upward. There is noise in the Total Near Activation (TNA curve) which should not be use for I interpretation. 1 CR 1:600 CRAIN TNA - 0153 u 1 SECS. . iu a 70074— 'o:=. _--7 GENV CRATF TFA CA�.F 0A114 I 0 VOLTS Alf 'G -19c1 lUUub luo u ` 0A194 u NEAR ACT o 74^. FAR ACT U .4I a ■E1■u■■■■ ■■C4■i■■■■■ ■■F■■■■■■■ ■■[a■■■■■■■ I ■■:j■i■■■■■ - ■■I..■i■■■■■ taakhlw 1.1111110111 - ■■F�■1■■■■■ I ■■1:i1■■■■■ _ ■■Ic"■1■■■■■ ■■F11■■■■■ 11111131111111111 1-1■■i,■■■■■■■ ;? - - 11 ■■Ci1■■■■■ - 1■►�■::::1■ ■■[i■■■■1■ ■■r�■■■■■■■ - �;, ■■EJ■■■■■■■ f.i ■■E�■■■■■■ w- ii��iiiiiii • ,,, ■■�•■■■■■1■ : r* ,. FAR ACT NEAR ACT 0A194 I . GENV _ CRATF TFA OAIF 0A114 v. s 1:600 C- N T,• T :. •• CAIN • .e 11011.1111 SECS. 111111111f .00 0 - ... - .. IImpulse test#2 at depth 13060 ft. MD, 5000 BWPD injection rate I SPECTRAFLOW RESULTS FILE= 13060_Z_n.cls TOOL DEPTH = 13060 FT. CASING(ID) = 2.99 IN. I AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIN 5.33 0.95 NC UP I OAIF 0.24 0.00 UNDETECTABLE UP TNA 569.20 0.82 NC UP TFA 89.85 0.20 UNDETECTABLE UP GR 39.27 0.00 UNDETECTABLE UP CRATN 0.92 ICRATF 0.66 I Page 8 of 13 I 111 HALLIBURTON ConocoPhillips Impulse test #3 at depth 13060 ft. MD at 5000 BWPD injection rate shows no water flowing up as I indicated by the far and near detectors. Both near and far detectors read no oxygen activation when the generator is on. GR sensor above SPFL tool does not show different readings during generator on and off, indicating no I water flow upward. There is noise in the Total Near Activation (TNA curve) which should not be use for interpretation. I r GR 101600 CRATN TNA GAIN 0153 SECS. a 7U'a lout u roJ u 245 GENV Tw CRATF 7D o TFA oou a OAIF IVO u 0A114 4d VOLTS 0A194 u 242 NEAR ACT 0 242 I a FAR ACT 242 INF!11■1111■■ ■11F_111■■■■11■ I ■■10111■■■■■ ■■r;1111■11■■■ MINIUM ��. ��C�f��IN 11 i"F•■■■■■■■ c i A. �11F•i11■■■■■ I■ei■■■■■■ ., 'N: IMAM= Y' 1i ---��- w• I ■■ ■ ■■■ ■ O ■ ■■ ■■ Uiiiii■ �� ;a _ j ■■ei ■ ■i■ - , ----- 11111111111111,11 I■ ■■■ ■ii I ■■M■■■■■II■ ■■ a11■i■ BE= ■■F■ ■ ■i■ i 1, ■■C■■■■lii I- ■■I M■■■'i■I .. .....• . 111111111111•11111111 _44 r 44,41 FAR ACT I 0A194 GENV CRATF TFA OAIF 0A114 IIMPSMI 1:600 , CRAT T2 MEW M • IIIIIIIIIIIII SECS. � �r� I Impulse test#3 at depth 13060 ft. MD, 5000 BWPD injection rate P P1 I SPECTRAFLOW RESULTS FILE= 13060_3_m.cls TOOL DEPTH = 13060 FT. I CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL, FLOW GEN. ON INDEX (FT/M) DIR I OAIN 5.19 0.97 NC UP OAIF 0.33 0.00 UNDETECTABLE UP TNA 587.86 0.83 NC UP TFA 89.49 0.19 UNDETECTABLE UP GR 40.67 0.01 UNDETECTABLE UP I CRATN 0.85 CRATF 0.78 I I I I HALLIBURTON ConocoPhillips Impulse test #1 at depth 13080 ft. MD at 3000 BWPD injection rate shows no water flowing up as I indicated by the far and near detectors. Both near and far detectors read no oxygen activation when the generator is on. GR sensor above SPFL tool does not show different readings during generator on and off, indicating no I water flow upward. There is noise in the Total Near Activation (TNA curve) which should not be use for interpretation. GR 1'600 CRATN TNA GAIN 0152 16 SECS. ❑ 005 lo bow e40 GEIJ�' CRATF TFA OAIF OA114 ❑ VOLTS 1❑0 Cr BILI❑ 10110 U ¶00 U 240 U OA194 240 NEAR ACT O 240 I0 FAR ACT 40 1 I i , 1 I / ZZZZZ Za. g 1 1 -,;R ACT O 240 NEAR ACT I ❑ [4u 0A194 o z.. GENV CRATE TFA OAIF 0A114 0 V L 9 IOU. z_ _10 70000 1000 240 1600 CRATN TNA OAIN 0163 MDU SEC5. 0 100 16000 1000 240 IT Impulse test#1 at depth 13080 ft. MD, 3000 BWPD injection rate 1 SPECTRAFLOW RESULTS I FILE= 13080_1_m.cls TOOL DEPTH = 13080 FT. CASING(ID) - 2.99 IN. AVERAGE COUNT I _ENINDEX _FLOW VEL. - FLOW GEN.. ON ON INDEX (FT/M) DIR GAIN 5.09 0.98 NC UP OAIF 0.36 0.00 UNDETECTABLE UP TNA 535.80 0.84 NC UP TFA 84.26 0.19 UNDETECTABLE UP I GR 39.97 0.00 UNDETECTABLE UP CRATN 0.89 CRATF 1.07 IPage 10 of 13 I i HALLIBURTON ConocoPhillips Impulse test #2 at depth 13080 ft. MD at 3000 BWPD injection rate shows no water flowing up as indicated by the far and near detectors. Both near and far detectors read no oxygen activation when the Igenerator is on. GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow upward. There is noise in the Total Near Activation (TNA curve) which should not be use for I interpretation. GR 1:600 CRATN TNA Ilt GAIN 0153 D ieu SECS. O Wu i 1.-0 uu SGENV CRATF TFA OAIF 0A114 I U 100 Cr 'I9 u u 1000IOU U zaP rn 0A194 eau NEAR ACT ?a, FAR ACT o tau rt N.,,, 1,4,7111,...,,,I t. ^ Iilia _mit I Io` 3 I ' r MHu FAR ACT u eau v NEAR ACT Z40( 0A194I z4113ENV CRATF TFA OAIF 0A114 C- ,,,.. c TOC .0_ CRA _100 mu u WI a �i9 73- 159 SECS. 0 CRATN Too TNA loon 0 OAIN 100 0 0153 2g7 IImpulse test#2 at depth 13080 ft. MD, 3000 BWPD injection rate I SPECTRAFLOW RESULTS FILE= 13080_2_m.cls TOOL DEPTH = 13080 FT. CASING(ID) = 2.99 IN. I AVERAGE GDUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR Y GAIN 4.91 0.97 NC UP OAIF 0.33 0.00 UNDETECTABLE UP TNA 527.13 0.83 NC UP TFA 83.63 0.18 UNDETECTABLE UP GR 40.13 0.00 UNDETECTABLE UP CRATN 0.91 CRATF 0.72 I IPage 11 of 13 i HALLIBURTON ConocoPhillips Impulse test #3 at depth 13080 ft. MD at 3000 BWPD injection rate shows no water flowing up as indicated by the far and near detectors. Both near and far detectors read no oxygen activation when the Igenerator is on. GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow upward. There is noise in the Total Near Activation (TNA curve) which should not be use for I interpretation. OR 1600 CRATN TNA GAIN 0153 Z 190 SECS. 0 100 1I 1000 24U (ENVVOLTS 1.1( CRATF ?- 1D 0 TFA OAIF OA114 mr tuu u u 0A194 NEAR ACT zau 240 U Lag FAR ACT 0 240 1 a 1. r 1.' ♦_ it. .. I '' 7 i_ ' ti'','‘'‘\:..."\:' :'......1 ------ d.`4 4r.... 1 1'1 A41,66 FAR ACT o 245 NEAR ACT ,u LaJ I 0A194 0 240 GENV CRATF TFA OAIF 0A114 u we D'----'-T00 10000 1000 245 0 VWINSECSS, 0 0 CRATN 11:r0 10010 tou00 GAIN t0o0 0163 240 iImpulse test#3 at depth 13080 ft. MD, 3000 BWPD injection rate I SPECTRAFLOW RESULTS FILE= 13080_3_m.cls TOOL DEPTH - 13080 FT. I AVERAGE CASING(ID) - 2.99 IN. COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR I CAIN 5.69 0.97 NC UP OAIF 0.33 0.00 UNDETECTABLE UP TNA 568.59 0.84 NC UP TFA 86.73 0.23 UNDETECTABLE UP GR 39.76 0.00 UNDETECTABLE UP CRATN 0.90 CRATF 1.07 IPage 12 of 13 I HALLIBURTON ConocoPhillips 3.0 WELL DIAGRAM I WNS SVC CD1-49 ConocoPhillips I `Dwell Attributes Max Angle&MD TD . .. -. Ilw xera248 Iwte.n xx.I 1,x•1 I 1054 , Aa RC,(ken 2 2 •23422 ca inn..- rr .1,,,,,:7,..,,....,.t. af.n IDptn lf3KR4 IRII30.4 4:I2.:v- _ Ione ox.a..I ,..,:vaii,..11,... . WsIng strings tbn DD IMI OAlap tllRel MDKM;nKtl fx KI,'T. YL a i -_tlbJ Rl.a_.N: '4 .5 ZS 33v nnpowpuan WIMI ip on) PMInR6 NICpMI. . lYl.acl"'r.... LL 3JRFA^> •,3Y 772 363 '.-. = "_..N corns C.vhebn 170 inl b(ml Vol,to:el N4 non)4.91!!! •Ni 3 l•r;_• .r l. -- :t-•..: _. —'IY'ER'AEJIA?E' 313 653! '4.40 -.. '.. /i``. .r:'I?' CxASLIED9Amn ISD f0I ID Imp TopinKal C. Mt Dch;T,O• i941,•x: 2222.. MK, IN'RII_3iA'E2 7 02,0 R Clone 5atorlplion 00 fat bile) 055lflKS, SM 1 'IIKtl NI 5041.r: t - i i--..: '$ 9 Liner 7 4275 - NC mIlli.,0 Liner Details ';\ roil lrota'� Top 910091rtltel roil mal'i - rcwn Da Com WO 5' 1 Kn7 07 AC ER .4 .)>4.IVER'C=PA eER >x. .Jc.V •• ."- ... ..36V1 '5422.4 VEA01''3 v .'. :t a ?now SJ.r4'E348,3'AE'.I22:. ... roaISKil NI slnlnNel .x D.aIK IM' Nt'L.rt; •.3. 3PTn•..5 i Tubing Strings •:2 2 Tubinv.:-. ••s al >:mNsl {M Dn[t,?v}; D-.L r9:cv,.Ko, ,. 1f :3�34DKI; 3�at a 1 � � Completion Details 222.1 I - •I JE'V3 MV3 R:E anr; Y A.I 43.45'7 \ V Vixx_E ! -1ESXN W131130'o .. .•>. ♦.,._ 9AKER PREMIER>A - -.. C = 137: 441 I' : .. . �M!!Z'Hya 6�E>: .1,_Er 2942 'hOC GD'..aGt ilii `- ,I . 2 - I 2 22 . .. _aa _. • -..•.. -.. ... 22 2»2 i iii 2 422 • 9 i Other InHole(Wireline retrievable plugs,valves,•pumps fish.etc.), > 292 l'Op1.x1 'INi.B .. Rall DYt. 0I.1 '3383: . - .. -.. _v. ,_ 74'32.•3 2:33 Mandrel Inserts ",— x a D TPpl1,1, •yP. L p* PM i 750Runa Ra TYP hNtlI MNa Mw Moab Oi,ml UN Tlp. Ilp. Iml IP4 RYnDN 3.s •:•.r4 '2"575 4 42..2:,0.123 083-I.7 ' 3AS:IFT 3V ER 322 3 722.22'3 t I I t x-arl.c 2222 ' I ab.•I:N. i ,.. ., •III: . YS,,..I 1.11.1an,- 111 n,� . ' Page 13 of 13 STATE OF ALASKA ALA— JIL AND GAS CONSERVATION COMAN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate 1— Other r put on injection Alter Casing r Pull Tubing r Stimulate Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 212-177-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20661-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372097,25559 . CD1-49 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): water flow log Colville River Field/Alpine Oil Pool • 11.Present Well Condition Summary: Total Depth measured 15348 feet Plugs(measured) none true vertical 7155 feet Junk(measured) 13686 Effective Depth measured 13686 feet Packer(measured) 11338, 12724 true vertical 7172 feet (true vertical) 6407, 7013 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 114 114 SURFACE 3072 11.75 3109 2338 INTERMEDIATE 8804 9 625 11753 6613 LINER 2066 7 13433 7152 RECEIVED Perforation depth: Measured depth: slotted liner 13099-13325' NOV 18 2013 True Vertical Depth: 7100-7126 '' AOGCC Tubing(size,grade,MD,and ND) 4.5x3.5, L-80, 13340 MD,7141 TVD Packers&SSSV(type,MD,and TVD) PACKER-HRD-E ZXPN LINER TOP PACKER @ 11338 MD and 6407 TVD PACKER-BAKER PREMIER PACKER @ 12724 MD and 7013 TVD NIPPLE-BP-6 CAMCO HYD LANDING NIPPLE @ 1894 MD and 1653 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1030 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run .4 (x Exploratory r Development r Service r• Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL lr Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r • GINJ r SUSP r SPLUG r- 17. 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 313-412 Contact Michael.Dammeyer@ 265-6548 Email Michael.Dammeyer(a�conocophillips.com Printed Name Mike Dammeyer Title Sr. Production Engineer Signature 0/4 Phone:265-6548 Date Form 10-404 Revised 10/2012 1/I ///4 Submit Original Only • CD 1-49 Summary of Operations for Water Flow Log 10/18/13: LOG WATERFLOW LOG W/ SPECTRAFLOW AND PRES, TEMP, SPIN. IMPULSE TESTS AT 13080' SHOWS NO UPFLOW FROM BEHIND THE TUBING PUMPING AT 3000 BWPD. IMPULSE TEST AT 13060' SHOWS NO UPFLOW FROM BEHIND TUBING AT 5000 BWPD. 09:30 RIH, FUNCTION TEST SPFL ON RIH, SET SHORT SPACE AND LONG SPACE AM VOLTAGES AT 11500', FREE FALL TO 13182' 11:30 CHANGE RATE FROM 1750 BWPD TO 3000 BWPD AT 2150 PSI AM 12:00 PUH TO 13080', PERFORM THREE IMPULSE TESTS,NO UPFLOW OBSERVED W/ PM SPFL 01:00 INCREASE INJ RATE TO 5000 BWPD AT 2200 PSI, PERFORM THREE IMPULSE PM TESTS,NO UPFLOW OBSERVED, SET RATE BACK TO 1750 BWPD, POOH N.- WNS SVC CD1-49 ConocoPhillips n Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) rr.r,,r:rh,ll,p, 501032066100 ALPINE SVC 92.05 13,892.55 15,348.0 °"° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CDt-09,1029/20131:03.18 PM SSSV:WRDP Last WO: 35.99 7/14/2013 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ....................__...... __..Last Tag: Rev Reason:RESET INJ VLV hipshkf 10/29/2013 HANGER.30.8 ` •(lj'1 axing ungs Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 4CONDUCTOR Insulated 16 15250 33.0 114.0 114.0 62.50 H-40 Welded dI `_ Casing Description OD(in) ID(in) op(ROB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ::..t I-,.`. SURFACE 11 3/4 10.772 36.3 3,108.5 2,338.0 60.00 L-80 BTCM :fir. iC:r. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' `�• ',"'i INTERMEDIATE 1 95/8 8.835 2,949.2 11,753.0 6,612.6 40.00 L-80 Hyd 521 4,`:‘ '`'I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread INTERMEDIATE 2 7 6276 33.3 11,338.0 6,407.2 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ROB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ?,;� LINER 7 6276 11,338.0 13,433.0 7,151.7 26.00 L-80 Tenaris Blue Liner Details CONDUCTOR Insulated 421 33.0-114.0 Nominal ID To (MB) TopND ftKB Top Incl(°) Item Des Corn Top ) l 1( 1 (in) • 11,338.0 6,407.2 60.34 PACKER HRD-E ZXPN LINER TOP PACKER 7.625 • • 11,353.5 6,414.9 60.35 HANGER FLEX-LOCK LINER HANGER 7.625 11,363.2 6,419.7 60.35 SEAL ASSY LATCHING BULLET SEAL ASSY w/SEL BORE 6.200 COUPLING VALVE;1,894.1 NIPPLE;1,894.11 } 11,367.0 6,421.6 60.36 SLEEVE "HRD-E"LINER SETTING SLEEVE w/Latch profile 6.200 • 11,375.9 6,426.0 60.36 CONNECT BAKER QUICK CONNECT 6.059 .i 4 13,427.5 7,151.1 84.09 Stabilizer Baker SDL INTEGRAL STABILIZER 6.070 4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ROB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 13,433.0 15,348.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(5...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 30.8 13,340.1 7,141.2 12.60 L-80 IBTM 4.5"x3.5"@12742' Completion Details SURFACE;36.33,108.5- ' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Corn (in) 30.8 30.8 0.00 HANGER FMC TUBING HANGER(Elastomer) 3.900 1,894.1 1,652.9 51.81 NIPPLE BP-6i CAMCO HYD LANDING NIPPLE 3.812 • 12,713.8 7,010.2 72.83 NIPPLE HES XN LANDING NIPPLE 3.813 • • 12,723.7 7,013.1 72.93 PACKER BAKER PREMIER PACKER 3.870 •,: ,, 12,742.0 7,018.4 73.13 XO-Reducing XO 4-1/2"Hyd 563 B x 3 1/2"EUE P 2.992 PROD CSG TIE BACK;33.3 INTERMEDIATE; 0 °_ _ 12,743.5 7618.9 73.15 NIPPLE HES XN NIPPLE 2.813' 2.813 ,>I ji" 13,098.8 7,101.0 78.43 SLOTTED 3-1/2",Slotted Liner,SLHT,9.3#,L-80 2.992 ■ 13,129.7 7,107.2 78.42 PERF 3-1/2"SLHT Perf Pup 9.3#L-80 2.992 1 I) 13,135.4 7,108.4 78.42 SLOTTED 3-1/2",Slotted Liner,SLHT,9.3#,L-80 2.992 13,227.0 7,125.1 80.62 PERF 3-1/2"SLHT Perf Pup 9.3#L-80 2.992 • 13,232.7 7,126.1 80.77 SLOTTED 3-1/2",Slotted Liner,SLHT,9.39,L-80 2.992 13,325.1 7,139.3 82.70 PERF 3-1/2"SLHT Perf Pup 9.3#L-80 2.992 13,336.6 7,140.8 82.88 SHOE 3-1/2"Orange Peel shoe,SLHT,9.3#,L-80 2.992 • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(NO) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) • 1,894.1 1,652.9 51.81 VALVE 3.81"DB LOCK ON MODIFIED A-1 INJECTION VLV 10/23/2013 2.810 INTERMEDIATE 1;2,949.2- (HAGS-0028) 11,753.0 13,686.0 7,171.6 87.30 FISH BHA STRING 7/10/2013 2.000 Mandrel Inserts St GAS LIFT;12187.5 .,a ati C MI on on Top(ND) Valve Latch Port Size TRO Run m _ Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type 9n) (psi) Run Date 1 12,187.5 6,821.0 CAMCO KBG-4-5 1 GAS LIFT DMY BK 0.000 0.0 9/23/2013 NIPPLE;12,713.8 PACKER;12,723.7 XO-Reducing;12.742.0. II NIPPLE;12.7435 I 1111 SLOTTED;13,098.8-- (� PERF;13,129.7- I1 SLOTTED;13,135.4 IIy� PERF;13,227.0 wpmI SLOTTED;13,232.7.E 1 1 CSG CMT;13,306.0 I 1 PERF;13,325.1 t! SHOE;13,336.6 LINER;11,338.0-13,433.0 444• FISH;13,686.0' OPEN HOLE;13,433.0-15,348.0 ''S P i O p7/2 -/7-7-- Ferguson, /2 -/7--- Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Thursday, November 07, 2013 8:31 AM To: 'Dammeyer, Michael' Cc: Walker,Jack A Subject: RE: CD1-49 waterflow log (sundry number 313-412) Michael, Thank you for the notification. Please submit a CD/Paper copy with the 10-404. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria ferqusonalaska.qov From: Dammeyer, Michael [mailto:Michael.Dammeyer©conocoDhilliDs.com] Sent: Wednesday, November 06, 2013 11:00 AM To: Ferguson, Victoria L(DOA) Cc: Walker, Jack A Subject: CD1-49 waterflow log (sundry number 313-412) Victoria, • The waterflow log for WAG injector CD1-49(sundry#313-412) is complete. It shows no water up-flow movement, indicating isolation of the injected fluids to the approved interval as per 20 AAC 25.412(d). The 10-403 does not specify a distribution;would you prefer a log copy by email,or by CD/paper copy submitted with the 10-404? Thank you, Michael Dammeyer WNS Production Engineer ConocoPhillips Alaska,Inc. 907-265-65481 ATO 1762 1 2‘'Z-c1-7 z3s"►5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 1, 2013 Attn.: Makana Bender DATA LOGGED ./2013 333 West 7th Avenue, Suite 100 M 2 BENDER Anchorage, Alaska 99501 RECEIVED NOV 19 202 RE: Spectra Flow Log, Water Flow Log: CD1-49 AOGCC Run Date: 10/18/2013 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 CD1-49 Digital Data in DLIS format, Digital Log Image file 1 CD Rom 50-103-20661-00 Spectra Flow Log 1 Color Log 50-103-20661-00 Water Flow Log 1 Color Log 50-103-20661-00 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.cook@halliburton.com Date: v.122 i3 Signed: )3 obae,..a...—.L 411 % MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Jit DATE: Tuesday,October 08,2013 P.I.Supervisor �(, 101 I ?' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-49 FROM: Lou Grimaldi COLVILLE RIV UNIT CDI-49 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry i' NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDI-49 API Well Number 50-103-20661-00-00 Inspector Name: Lou Grimaldi Permit Number: 212-177-0 Inspection Date: 10/5/2013 Insp Num: mitLG131005172418 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ,Type e InJ - 1753- 1750 2770 PTD 2121770 Type TestiSPiTstt psi I j OA 570 600 610610 Interval IINITALP/F TubingL— P �— — g 1940 .1 1940 1940 1940 - � ; Notes: IA @ 2030 psi w/gas cap bled to fluid at 1750 psi(approx 5 min's). .8bbl's diesel pumped and returned.Good solid test v • Tuesday,October 08,2013 Page 1 of 1 Wallace, 1111 Chris D (DOA) From: NSK Problem Well Supv[n1617@conocophillips.com] Sent: Friday, October 25, 2013 4:09 PM To: Wallace, Chris D(DOA) Cc: Dethlefs, Jerry C; NSK Problem Well Supv Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49(PTD 212-177-0) 10-13-13 Chris, The IA pressure does not appear to be stabilizing. The well has been shut in and further diagnostics will be scheduled. Please let me know if you have any questions. Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Tuesday, October 15, 2013 2:07 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Report of suspected TxIA communication of Alpine injector CD1-49(PTD 212-177-0) 10-13-13 Jolin, Approved for 30 days injection for additional monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Su :. , October 13, 2013 1:39 PM To: Wallace, D (DOA) Subject: Report of s• • ed TxIA communication of Alpine injector CD1-49(PTD 212-177-0) 10-13-13 Chris— Alpine Injector CD1-49(PTD#212-177-0) is •- ••nstrating suspected TxIA communication based on bleeds of the IA over the past week. The well may still be normalizin: ' self to being an injector as it was only recently converted to an injector and was first brought online on 09/28/13. The w- •assed a witnessed MIT-IA on 10/05/13. Since the MIT-IA, the pressure has built up above 1,900 psi two times in a couple • •ays with subsequent follow-up bleeds to allow the IA to stabilize to its new operating conditions. CPAI requests permission : leave the well on injection for 30 days for further monitoring and to allow the well to continue to stabilize as a new in • or. If the well continues to show signs of suspected TxIA communication and does not show a stabilizing trend, it will be s • 'n for further diagnostics. The well has been added to the monthly report. Attached is a 15 day TIO plot rather than a • •ay TIO plot due to the well being an injector for only"'14 days. 1 Wallace, Chris D (DOA) From: Wallace, Chris D(DOA) Sent: Tuesday, October 15, 2013 2:07 PM To: 'NSK Problem Well Supv' Subject: RE: Report of suspected TxIA communication of Alpine injector CD1-49(PTD 212-177-0) 10-13-13 Jolin, Approved for 30 days injection for additional monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)7934250(phone) (907)276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocophillips.com1 Sent: Sunday, October 13, 2013 1:39 PM To: Wallace, Chris D (DOA) Subject: Report of suspected TxIA communication of Alpine injector CD1-49 (PTD 212-177-0) 10-13-13 Chris— Alpine Injector CD1-49(PTD#212-177-0)is demonstrating suspected TxIA communication based on bleeds of the IA over the past week. The well may still be normalizing itself to being an injector as it was only recently converted to an injector and was first brought online on 09/28/13. The well passed a witnessed MIT-IA on 10/05/13. Since the MIT-IA, the pressure has built up above 1,900 psi two times in a couple of days with subsequent follow-up bleeds to allow the IA to stabilize to its new operating conditions. CPAI requests permission to leave the well on injection for 30 days for further monitoring and to allow the well to continue to stabilize as a new injector. If the well continues to show signs of suspected TxIA communication and does not show a stabilizing trend, it will be shut in for further diagnostics. The well has been added to the monthly report. Attached is a 15 day TIO plot rather than a 90 day TIO plot due to the well being an injector for only^'14 days. Let me know if you have any questions. Regards, Jolin Oksness Well Integrity Engineer ConocoPhillips,Alaska 907 659-7224 (c)907 230-7493 1 lb 1110 rn i 11 f•f g >+ N M i. en N III i'd el oI 43 1 11. 14 VI N �Fd •-� B I 2 > ' 0 7i •. v+ r. x > w z - aw NC o .p M 0 L ,:iia ~ W 0 4.41 HN o <, a C4 CCti, H1-3 z c sZ E a. E • • m • • rl • • o Lrl Co M • IJ•f we .-1 O O N r , r- -, r---- ti F 4.0 m 10 O • in Lf1 0 \\\ 4 On = � nau` ,..1 N N N N r4 W cd O a• r i o . . m • •• t. • •• E ' ¼O• • ti)CM 000N 17 N t0 (II 10 O • LF" D O C• O .-t t\ 0 in En Y N NN 04 .-1 •. J.... I. J. ........._ .-i •.-- U 0 oa fi J 1414 :4404314 ChZNt • aVJ DI 4�= r O xF•4a1 as rf w,,',-; • a a wag o I-, g unroll' 74 " Q 0 0 0 0 O 0 O o 0 O O U 1 O o 0 0 0 0 0 0 0 0 CI O f\ K .y OD Ln N en t0 rn .--i 0.1N ,-IN N l r I N C4 3 U y W I. a II El oco ccn • o • • PC oco c o . 00 o 0 o V • • 000 , oo .04 ' :-'' 0 000 =' 000 044 U 0 1-1 > W d En C/7 4? iWNS SVC CD1-49 ConocoPhillips 01 Well Attributes Max Angle&MD a TD Wellbore API/DWI Field Name Wellbore Status Incl(°) MD(NKR) Act Still(NKR) carlpatiFelYgps 501032066100 1ALPINE SVC 92.05 13,892 55 15,348.0 Comment 1125(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date Well Conf.,HORIZONTAL-CD1-49.8/24.'2013753.27 AM SSSV:NIPPLE _ Last WO: 35.99 7/14/2013 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Dab Last Tag: Rev Reason:PULL WRDP osbod 8/24/2013 HANGER,31- - ° ,n " -° �". Casin�c Strings 'i C sing Description -Si ing 0... St ng ID...Top(ftKB) Set Depth(f...Set Depth(TVD) String Wt..'String_.String Top Thrd CONDUCTOR I 16 1 15.250 33.0 114.0 114.0 62.50 i H-40 Welded Insulated 42" / Casing Description String 0... 'String ID...Top(ftKB) Set Depth(f...Set Depth(NO)...String Wt...String...String Top Thrd t ! SURFACE 11 3/4 10.772 36.3 3,108.5 2,338.1 60.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 1 95/8 8.835 2,949.2 11,753.0 6,611.1 40.00 L-80 Hyd 521 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd INTERMEDIATE2 7 6.276 33.3 11,338.0 6,407.2 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR LINER 7 6.276 11,338.0 13,433.0 7,151.7 26.00 L-80 Tenads Blue In.ulatea42".- - 33-n4 r Details Top Depth (TVD) Top Incl Nonni... Top(ftKB) (ftKB) (") Item Description Comment ID(in) NIPPLE.1.894 - 11,338.0 6,407.2 60.34 PACKER HRD-E ZXPN LINER TOP PACKER 7.625 11,353.5 6,414.9 60.35 HANGER FLEX-LOCK LINER HANGER 7.625 NE 11,363.2 6,419.7 60.35 SEAL ASSY LATCHING BULLET SEAL ASSY w/SEL BORE COUPLING 6.200 " 11,367.0 6,421.6 60.36 SLEEVE "HRD-E"LINER SETTING SLEEVE w/Latch profile 6.200 11,375.9 6,426.0 60.36 CONNECT BAKER QUICK CONNECT ' 6.059 13,427.5 7,151.1 84.09 Stabilizer Baker SDL INTEGRAL STABILIZER 6.070 I' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd OPEN HOLE 6 1/8 13,433.0 15,348.0 Tubine Strin!s Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 35-3. SURFACE._ TUBING 4.5"x3.5"@12742' 41/2 3.958 30.8 13,340.1 7,138.8 12.60 L-80 IBTM 109 `•mpletion Det' I Top Depth (TVD) Top Incl Nornl... Top(ftKB) (ftKB) (") Item Description Comment ID(in) 30.8 30.8 0.00 HANGER FMC TUBING HANGER(Elastomer) 3.900 1,894.1 1,652.1 51.56 NIPPLE BP-6i CAMCO HYD LANDING NIPPLE 3.812 INTERMEDIATE ' - 12,713.8 7,009.3 72.10 NIPPLE HES XN LANDING NIPPLE 3.813 �'. 2,33.11.338 - 12,723.7 7,012.5 72.35 PACKER BAKER PREMIER PACKER 3.870 I , " 12,742.0 7,018.2 72.81 XO-Reducing XO 4-1/2"Hyd 563 B x 3 1/2"EUE P 2.992 12,743.5 7,018.7 72.85 NIPPLE HES XN NIPPLE 2.813' 2.813 • 13,098.8 7,101.0 78.43 SLOTTED 3-1/2",Slotted Liner,SLHT,9.34,L-80 2.992 - 13,129.7 7,107.2 78.42 PERF 3-1/2"SLHT Perf Pup 9.3#L-80 2.992 13,135.4 7,108.4 78.42 SLOTTED 3-1/2",Slotted Liner,SLHT,9.34,L-80 2.992 13,227.0 7,125.1 80.66 PERF 3-1/2"SLHT Perf Pup 9.3#L-80 2.992 13,232.7 7,126.1 80.78 SLOTTED 3-1/2",Slotted Liner,SLHT,9.3#,L-80 _ - 2.992 13,325.1 7,139.3.'PERF 3-1/2"SLHT Pert Pup 9.3#L-80 2.992 13.336.6 7,138.2 81.71 SHOE 3-1/2"Orange Peel shoe.SLHT.9.38.L-80 2.992 Other I ".., L'- retrievabigplttgs,valves,pumps,fish,etc.) INTERMEDIATE Top Depth 1lIII (TVD) Top Incl 2,949-11.753 KKB Top(MB) ( ) (") Description Comment Run Data ID(in) MI I 13,686.0 7,171.5 87.04 FISH BHA STRING 7/10/2013 2.000 GAS LIFT. 1 12,133 IN i B 1 NIPPLE,12,714 IRR B PACKER, 12,724 V XO-Reducing, 12,742 li NIPPLE.12744 88 a I it 1 SLOTTED, 13,099 PERF,13,130 - SLOTTED, I.13,135 PERF,13227 i SLOTTED, ,, Mandrel Details 13233 Top Depth Top Port S... (TVD) Incl OD Vahn Latch Size TRO Run PEEP.13,325 - N...Top(ftKB) (ftKB) (°) Make Model (in) Sere Typ. Type lin) (psi) Run Dab Com... 11. 1 12,187.5 6,821.0 64.71 CAMCO KBG-4-5 1 GAS LIFT OV BK 0.250 0.0 7202013 SHOE.13.337 f Ir _ 1 LINER. - - 11,338-13.433 FISH,13.0361 OPEN HOLE, 13.433-15,348 TD(CD1-49). 15,348 Ta , STATE OF ALASKA p U G 1 4 2013 1 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L" "1'-- la Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned III Suspended ❑ 1b.Well Class , 20AAC 25.105 20AAC 25.110 Development E Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ ' WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2 Operator Name. 5.Date Comp,Susp, 12 Permit to Drill Number. ConocoPhillips Alaska, Inc. orAband: July 14,2013 ' 212-177/313-039 3 Address 6 Date Spudded 13 API Number P O. Box 100360,Anchorage,AK 99510-0360 January 12,2013 50-103-20661-00 ' 4a Location of Well(Governmental Section) 7 Date TD Reached. 14.Well Name and Number: Surface. 566'FNL,3042'FEL,Sec.5,T11N, R5E, UM June 12,2013 - CD1-49 . Top of Productive Horizon 8. KB(ft above MSL): 55'RKB 15.Field/Pool(s) 527'FNL, 1120'FEL,Sec. 17,T11N,R5E, UM , GL(ft above MSL): 19.5'AMSC Colville River Field Total Depth 9 Plug Back Depth(MD+TVD): 1988'FNL, 156'FWL,Sec. 16,T11N, R5E, UM 13686'MD/7171'TVD Alpine Oil Pool 4b Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD): 16.Property Designation • Surface: x-385660.6 y- 5975565 5 Zone-4 15348'MD/7155'TVD ADL 372097,25559 TPI: x-387457 y- 5965017 Zone-4• 11 SSSV Depth(MD+TVD) 17.Land Use Permit Total Depth: x-388714 y- 5963537 Zone-4 nipple @ 1894'MD/1652'TVD Tobin No.931996 18 Directional Survey: Yes Q 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) 1669'MD/1556'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 not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 33' 114' 33' 114' 42" Type II 11.75" 60# L-80 36' 3108' 36' 2338' 14" 797 sx ASLite,350 sx Class G 9.625" 40# L-80 2949' 11753' 2258' 6613' 11.75" 535 sx Class G,801 sx Class G,242 Class G 7" 26# L-80 11367' 13433' 6422' 7152' 8.5" slotted liner 24 Open to production or injection? Yes ❑ No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number). SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5"x 3.5" 13340' 12724'MD/7012'TVD slotted liner 13099'-13130'MD 7100'-7107'TVD DIMPLE-110W j pert pup 13130-13135'MD 7107-7108'TVD { - 3 1 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC slotted liner 13135-13227'MD 7108-7125'TVD 1 TED I Was hydraulic fracturing used during completion? Yes❑ No Mpelf pup 13227-13232'MD 7125-7126'TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED slotted liner 13232'-13325'MD 7126-7139'TVD - - mmy. cement plug#1 from 779'-1284' 1148 sx Class G pelf pup 13325'-13331'MD 7139-7140'TVD cement plug#2 from 187-674' 860 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No a If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071. NONE RBDMS AUG 15 2013 Form 10-407 Revised 10/2012 CONTINUED ON VE SE Submit original only 1%LG' •7/7 i /QCT, �/<� ' �1, PI # 77 G a 29. GEOLOGIC MARKERS(List all formations and market ,untered): 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1669' 1556' needed,and submit detailed test information per 20 MC 25.071 Alpine D 13147' 7111' Alpine C 13400' 7148' N/A Formation at total depth: Alpine C 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Duncan Hyden @ 265-6862 Email Duncan.P.Hyden(o�conocophillips.com Printed Name G. L.Alvord , / Title Alaska Drilling Manager / Signature �_` �i � Phone 265-6120 Date 8J l,/2013 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20 Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Name Depth [MD] Depth [TVD] Permafrost 1669 1556 C-30 3257 2411 C-20 3977 2767 C-10 4460 3005 K-3 6094 3814 K-3 BSL 6489 4010 K-2 6559 4045 K-2 BSL 6786 4157 ALB_97 10298 5894 NANUQ(ALB_96) 10917 6199 NANUQ BASE 11098 6289 Top HRZ 11791 6632 Base HRZ 12088 6776 top of the upper Kalubik shale K1 12235 6840 top of the lower Kalubik shale Kup C 12471 6930 top of the Kuparuk sand LCU 12475 6931 top of the Miluveach shale Alp D 13147 7111 Alp C 13400 7148 WNS CD1-49 •- COt10GOPhillip, :wren ,.III Attributes x Angle&MD TD Ill(: .ellbore API/UWI Field Name Well Status (°) MD(ftKB) Act Btm(ftKB) �y,,,1,1T. Ir 501032066100 ALPINE SVC 'Inc!192.05 13,892.55 15,348.0 t_craComment 112S(ppm) Dotn Annotation End Date KB-God(R) Rig Release Date -••Well Confit:HORIZONTAL-CDt-49,7/26/20137:49 59AM SSSV:WRDP Last WO. 35.99 7/14/2013 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O,set WRDP,Pull RHCBalI/Rod osbod 7/26/2013 HANGER.31 " -mu Casing Strings Casing Description String 0... String ID Top(ftKB) Set Depth(f...Set Depth(NL D)...String W..String..String Top Thrd CONDUCTOR 16 15250 33.0 114.0 114.0 62.50 H-40 Welded - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd SURFACE 113/4 10.772 36.3 3,108.5 2,338.0 60.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd --------- -- -- INTERMEDIATEqr 9 SIS 8.835 2,949.2 11,753.0 6,612.6 40.00 L-80 Hyd 521 -__Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd INTERMEDIATE 7 6276 33.3 11,338.0 6,407.1 26.00 L-80 BTCM TIE-BACK Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER 7 6.276 11,367.0 13,433.0 7,151.8 26.00 L-80 Tenaris Blue CONDUCTOR. Liner Details 33114 Top Depth (ND) Top Incl Nomi... Top(ftKB) (t B) (°) Item Description Comment ID(in) WRDP,1,894 13,427.5 7,151.3 85.00 Stabilizer Baker SDL Intergral stabilizer 6.070 NIPPLE,1894 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd ip ?: TUBING 41/2 3.958 30.8 13,340.1 7,141.1 12.60 L-80 IBTM 'I' 4.5"x3.5"@12742' tCompletion Details Top Depth % (TVD) Top Incl Nomi... / Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 30.8 30.8 0.00 HANGER FMC TUBING HANGER(Elastomer) 3.900 1,894.1 1,652.0 51.56 NIPPLE BP-6i CAMCO HYD LANDING NIPPLE w/DUMMY PACKOFF 3.812 12,713.8 7,009.2 72.10 NIPPLE HES XN LANDING NIPPLE 3.813 sub--los A 12,723.7 7,012.4 72.35 PACKER BAKER PREMIER PACKER 3.870 , 12,742.0 7,018.1 72.81 XO-Reducing XO 4-1/2"Hyd 563 B x 3 1/2"EUE P 2.992 12,743.5 7,018.6 72.85 NIPPLE HES XN NIPPLE 2.813' 2.813 13,336.6 7,140.7 82.88 SHOE 3-1/2"Orange Peel shoe,SLHT,9.38,L-80 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ` Top Depth INTERMEDIATE - (TVD) Top Incl 71E-BACK Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 33-11.338 1,894.1 1,652.05 51.56 WRDP WRDP(HABS-0557)ON 3.81 DB LOCK(OAL-5'S") 7/21/2013 2.125 13,686.0 7,171.5' 87.30 FISH BHA STRING 7/10/2013 2.000 Perforations&Slots --- Shot Top(ND) Btm(TVD) Dens Top(ftKB)Blot(ftKB) (ftKB) (ftKB) Zone Date (ah... Type Comment 13,099.0 13,130.0 7,100.2 7,107.1 7/12/2013 32.0 SLOTS SLOTTED LINER 13,130.0 13,135.0 7,107.1 7,108.2 7/12/2013 1.0 PERFP PERF PUP 13,135.0 13,227.0 7,108.2 7,125.0 7/12/2013 32.0 SLOTS SLOTTED LINER 13,227.0 13,232.0 7,125.0 7,125.8 7/12/2013 1.0 PERFP PERF PUP NTERMEDIATE, 2,949.11753 I. 13,232.0 13,325.0 7,125.8 7,139.2 7/12/2013 32.0 SLOTS SLOTTED LINER :. 13,325.0 13,331.0 7,139.2 7,140.0 7/12/2013 1.0 PERFP PERF PUP GAS LIFT, 12,189 Notes:General&Safety End Date Annotation 1/24/2013 NOTE:SET KILL STRING WELL SUSPENDED;WELL COMPLETED 7/15/2013 NIPPLE,12,714 Aa, 11 I PACKER, -- 12.724 XO-Red12,742ucing, NIPPLE.12,744- - it 1 I 1- SLOTS. , 13,09 SLOT 0 PERFP, 13,13 PERF 5 SLOTS. 13.13513.227 PERFP. - 13,227-13,212 I- SLOTS, Mandrel Details 13,232-13,325 Top Depth Top Port nd OD Valve 5... IKB) Ir) Make Model (In Sere Type Type (In)ch Rite T(psi)O un Run Date Com... PERFP, ■ N...Top(ftKB) ( 13,325-13,331 4 1 12,187.5 6,820.9 64.71 CAMCO KBG-4-5 1 GAS LIFT OV BK 0.250 0.0 7202013 I 't SHOE.13,337 11,367-1L3,433INER, FISH,13,686-4401 TO(C01-49). 15,348 ConocoPhitlips Time Log & Summary We?view Web Reporting Report Well Name: CD1-49 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 1/11/2013 1:00:00 PM Rig Release: 1/25/2013 6:00:00 PM Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 01/10/2013 24 hr Summary Prepare rig for rig move. 08:00 10:00 2 00 0 0 MIRU MOVE MOB P Modify drip pan for spill prevention and containment measures.Weld on and fix rotary table locking mechanism. 10 00 12 00 2.00 0 0 MIRU MOVE MOB P Prepare rig for rig move to CD1-49. Blow down and unhook steam lines, air lines,water lines, mud lines, electrical connections. 12:00 14:15 2 25 0 0 MIRU MOVE MOB P Prepare rig for slot to slot move, blow down steam lines to sub base. 14:15 15 15 1 00 0 0 MIRU MOVE MOB P Raise windwalls on sub. Correlate with Alpine electricians to disconnect ESD and highline power cables Disconnected. 15:15 00:00 8 75 0 0 MIRU MOVE MOB P Move pit complex, motors complex away from rig package. Skid rig floor back, raise feet on sub structure, move rig off CD1-47. Clean cellar area, prepare CD1-49 cellar for spotting rig on new slot. Crew change. 01/11/2013 Continue to trouble shoot moving system. Fix system. Complete rig move.Accept rig @ 13.00 Hrs. Rig up all service lines.Air,fuel, hydraulic, steam,corns,electrical.Weatherize cellar, pick up and install riser. Nipple up riser and bypass lines on wellhead. Install flow line. SIMOPS: Bring spud mud on board from mud plant 00:00 02:00 2 00 0 0 MIRU MOVE MOB P Troubleshoot rig moving system. Loose wire, and a failed valve) 02:00 10:00 8.00 0 0 MIRU MOVE MOB P Move sub base over to CD1-49 slot. Set support feet, skid rig floor into position. 10:00 12:00 2 00 0 0 MIRU MOVE MOB P Spot pits complex, spot motor complex. 12:00 13:00 1 00 0 0 MIRU MOVE RURD P Rig up, hook up service lines. Mud lines, steam lines,air, high line power.Accept rig @ 1300 HRS. 13 00 13.15 0.25 0 0 SURFAC RISER SFTY P Pre job safety meeting on picking up BHA components,weatherizing the cellar,picking up the riser 13:15 16:00 2 75 0 0 SURFA( RISER RURD P Pick up BHA components,tools, test gas alarms, pick up surface riser. 16:00 16:15 0.25 0 0 SURFAI RISER SFTY P Pre job safety meeting. Installing the riser. Page 1 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 22:15 6.00 0 0 SURFA( RISER NUND P Nipple up surface riser. Install by pass lines on well head, hook up hole fill lines,flow line. SIMOPS Bring spud mud on board from Mud Plant. 22 15 00:00 1.75 0 0 SURFA( DRILL PULD P Pick up safety valves,derrick climber was prepared for use,eye wash station in pits was placed back in postion. 01/12/2013 Rig up surface riser and associated equipment, PU/MU/standback 5"dp and HWDP, slip and cut drill line, PU/MU BHA#1,tag ice in conductor, clean out conductor, MU BHA#1, orient UBHO sub, rig up gyro equipment. Directional drill from 114'MD to 449'MD. 00.00 00:15 0 25 0 0 SURFA( DRILL SFTY P Pre job safety meeting. 00:15 01:30 1.25 0 0 SURFA( DRILL RURD P Secure cellar area, install boot around riser. Change out heads in the iron roughneck f/4"to 5". Pick up/Make up 5"elevators to the top drive 01:30 01:45 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on picking up and standing back 5"drill pipe. 01:45 05:00 3.25 0 0 SURFA( DRILL PULD P Pick up and stand back 25 stands of 5"drill pipe via the mouse hole. 05:00 05:30 0.50 0 0 SURFA( RIGMNT SVRG P Service rig while most of crew eats 05:30 07:15 1.75 0 62 SURFA( DRILL PULD P Pick up and stand back 9 stands of 5"HWDP via the mouse hole. Pick up/make up/RIH w/2 joints of 5" HWDP. 07:15 07:30 0.25 62 62 SURFA( RIGMNT SFTY P Pre job safety meeting on slip and cut drill line. 07:30 09:15 1.75 62 62 SURFA( RIGMNT SLPC P Slip and cut 75'of 1-3/8"drill line. Finish service of rig-change out grease zerts on the drawworks Calibrate TOTCO block height. Perform work orders.Adjust brake son the drawworks. 09:15 09:30 0.25 62 62 SURFA( DRILL PULD P Make up Weatherford/Daily jar, Stand back 5"HWDP with the jars. 09 30 11:30 2.00 0 58 SURFA( DRILL PULD P PU/MU BHA#1:Baker motor(1.3 deg bend), NM pony collar,string stabilizer, NM crossover, MWD. Tagged ice in the 16"OD conductor at'58'. 11:30 11:45 0 25 58 58 SURFA( DRILL SFTY P Pre job safety meeting. 11:45 12:00 0.25 58 45 SURFA( DRILL PULD P Lay down MWD and crossover to 45'. 12:00 12:30 0.50 45 45 SURFA( DRILL PULD P Pull out of hole w/BHA. Change dies in the tongs, make up 14"Baker MXL-1X 14"bit(ser#5211466).Run in hole. 12:30 12 45 0.25 45 45 SURFA( DRILL CIRC P Fill mud lines and hole, check f/ leaks Found leak on mud line @ mezzanine level 12:45 13:15 0.50 45 45 SURFA( DRILL OTHR T Replaced"0"ring on union of mud line. Page 2 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 13:45 0.50 45 45 SURFA( DRILL PRTS P Screw into lift sub.Test mud line to 3500 psi. Good. 13 45 14 00 0.25 45 45 SURFA( DRILL OTHR P Blow down the top drive. 14.00 14 15 0.25 45 45 SURFA( DRILL PULD P Pick up stand of HWDP. Make a top drive connection. 14 15 14:30 0.25 45 90 SURFA( DRILL WASH P Wash/ream w/10 rpm w/3k ft lbs of torque, 215 gpm @ 150 psi f/45'to 90 Clean out ice in the 16" conductor. 14:30 15:30 1.00 90 81 SURFA( DRILL PULD P Set back a stand of 5"HWDP. Pick up/make up MWD,filter sub and UBHO. 15:30 15:45 0.25 81 81 SURFA( DRILL OTHR P Scribe MWD to mud motor, align UBHO to mud motor high side. 15:45 16:00 0.25 81 81 SURFA( DRILL SFTY P Pre job safety meeting on rigging up and hanging sheave f/Gyro. 16:00 17 00 1.00 81 81 SURFA( DRILL RURD P Rig up Sperry WL unit and Gyro data tools Hang sheave in the derrick. 17:00 1730 0.50 81 81 SURFA( DRILL SFTY P Pre job safety meeting--Pre Spud. 17:30 18:00 0.50 81 81 SURFA( DRILL PULD P Make a top drive connection. 18:00 18:15 0.25 81 114 SURFA( DRILL WASH P Continue to wash&ream ice in the conductor f/90'to 114'. Rotate 48 rpm w/3k ft lbs of torque Pumping 445 gpm w/530 psi. 18 15 00:00 5.75 114 SURFA( DRILL DDRL P Drilled 14"directional hole from 114' 449L TVD-449'. ADT=2.9 hrs. ART=1.10 hrs AST=1.80 hrs WOB=15 to 20K/RPM=50/GPM 450 @ 900 psi/Torque on/off=5k to 5.5k ft/lbs String wt PU= 103k SO= 103k Rot= 103k Gyro _ every stand. 01/13/2013 Directional drill from 449'MD to 542'MD. Stop. Not achieving needed doglegs to follow well plan. Phase 3 conditions developed at the same time.Trip out of the hole to wait on weather,and prepare new well plan. Monitor well on trip tank.Taking'%BBL per hour. 00:00 02:45 2.75 449 542 SURFA( DRILL DDRL T Drilled 14"directional hole from 449' to 542'. TVD-542'. ADT=.8 hrs. ART=0.0 hrs AST=.80 hrs WOB=15 to 20K/RPM=50/GPM 450 @ 900 psi/Torque on/off=5k to 5.5k ft/lbs String wt. PU= 103k SO= 103k Rot= 103k Gyro every stand. Stop drilling unable to achieve needed dog legs, Phase 3 storm developed at the same time. Prepare to TOOH. 02:45 03:45 1.00 542 168 SURFA( DRILL TRIP T Flow check well. Static. Pump out of the hole 3 stands to stop of the monel collars 400 GPM/ 480 PSI/ 50 RPM/4K TQ 95k Up/Dn/Rot Wts. 03:45 04:15 0.50 168 82 SURFA( DRILL TRIP T blow down top drive. Stand back 3 monel drill collars. Leave 82 foot BHA hanging. Page 3 of 87 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 04 15 11:30 7.25 82 82 SURFA( DRILL OTHR T Waiting on weather. Phase 3 conditions persisted. Blizzard. Perform work orders. Monitoring well on trip tank Taking%to 1 barrel per hour. 11 30 12:00 0.50 82 82 SURFA( DRILL RURD T PJSM Rig up head pin to break circulation. Pump 10 Barrels every 4 hours Monitor on trip tank. 12:00 00:00 12.00 82 82 SURFA( DRILL OTHR T Wait on weather Break circulation every 4 hours. Pump 15 BBLS. Monitor well on trip tank.Well bore taking 1 BBL per hour. 01/14/2013 Phase 3 conditions persist.Wait on weather, and prepare new well plan. Monitor well on trip tank Taking%to 1 BBL per hour. Every 4 hours pump 15 BBLS mud through BHA, blow down and monitor.Alpine Control room pumped 30 BBLS of diesel freeze protect down CD1-48A tubing 00:00 00:00 24.00 82 82 SURFA( DRILL OTHR T Wait on weather. Break circulation every 4 hours. Pump 15 BBLS. Monitor well on trip tank.Well bore taking%to 1 BBL per hour. Alpine Operations freeze protected CD1-48A tubing. Pumped 30 BBLS diesel. CD1-48A pressures=OA=400 psi/ IA=200 psi/Tbg=0 PSI. Phase 3 conditions persist. 31/15/2013 Phase 3 conditions were declared until noon,due to snow removal operations.Monitor well on trip tank. Taking%to 1 BBL per hour. Every 4 hours pump 15 BBLS mud through BHA, blow down and monitor. Noon: Work was resumed on CD1-47. Lay down BHA, and TIH with Bit/Bit Sub/Totco ring to 1 stand of Monels and HWDP. Gyro run only for information about bottom hole location.TOOH to pick up mud motor set on 2.0°, /UBHO sub. 00:00 12:00 12.00 82 82 SURFA( DRILL OTHR T Wait on weather. Break circulation every 4 hours. Pump 15 BBLS. Monitor well on trip tank.Well bore taking%to 1 BBL per hour. Phase 3 conditions stayed in-effect due to snow removal operations around the rig. 12 00 12:15 0.25 82 82 SURFA( DRILL SFTY T PJSM. Return to work safely. Look the rig over. Clear snow 12:15 16:00 3.75 82 82 SURFA( DRILL RURD T Prepare rig for drilling ahead. Clean up snow after the blizzard. 16 00 16:15 0.25 82 82 SURFA( DRILL SFTY T Safety meeting on laying down BHA 16:15 17:30 1.25 82 0 SURFA( DRILL PULD T Lay down Mud Motor/MWD. 17:30 17:45 0.25 0 0 SURFA( DRILL PULD T Pick up BHA#2. Gyro run. Bit/Bit Sub/totco ring.(crow's foot) 17:45 18:30 0.75 0 542 SURFA( DRILL TRIP T Trip in the hole. Tag up @ 185' MD, slight bobble, 376'MD slight bobble, 503'MD set down hard.Wash to bottom with 300 GPM.270 PSI. 18.30 19:15 0.75 542 542 SURFA( DRILL WASH T Wash down to 542' MD with 300 GPM/270 PSI.40 feet of fill on bottom. Page 4 of 87 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:15 19.30 0.25 542 542 SURFA( DRILL PULD T Lay down single 5"HWDP/Pick up 16'pump joint to have the stump at the rig floor. Tag fill @ 536' MD. UD 16'pup joint 19:30 22:00 2.50 542 542 SURFA( DRILL SRVY T Run'Gyro Data'gyro surveys on Halliburton E-Line. Compile checkshots in old hole,and obtain new shot on bottom.Verify that Well Plan#6 is needed. 2200 2300 1.00 542 0 SURFA( DRILL TRIP T Trip out of the hole to pick up the Mud Motor. 23 00 00 00 1.00 0 0 SURFA( DRILL PULD T Make up BHA#3. Set Motor on 2° bend. 01/16/2013 Make up BHA#3. Motor set on 2°. Directional drill 14"surface hole from 542' MD to 687'MD.450 GPM/710 PSI.95k UP/DN/No rotation. Survey with gyro tool. POOH for BHA#4. Motor set on 1.5°, pick up MWD system Directional drill from 687'MD to 1095' MD. Stop. Close approach issue. POOH for BHA#5. 00 00 01 30 1.50 0 44 SURFA( DRILL PULD T MU BHA#3(bit-motor w/2°bend -XO-UBHO sub)to44' 01.30 01:45 0.25 44 134 SURFA( DRILL TRIP T RIH w/NM flex DC's to 134' 01:45 02:15 0 50 134 503 SURFA( DRILL TRIP T RIH w/jars&HWDP f/134'to 503'- PUwt95 SOwt95 0215 02 45 0.50 503 503 SURFA( DRILL SRVY T Ran Gyro survey 02 45 03 00 0.25 503 542 SURFA( DRILL WASH T Wah down f/503'to 542'@ 200 gpm @ 200 psi 03 00 06.30 3.50 542 687 SURFA( DRILL DDRL T Driectional drill 14"hole w/2°bend in motor f/542'to 687' MD 688'TVD ADT-1.3 hrs=AST-1.3 hrs WOB 10/25 k GPM 430 @ 710 psi 06:30 06:45 0.25 687 687 SURFA( DRILL CIRC T Circ btms up @ 430 gpm @ 450 psi 06:45 08:00 1.25 687 134 SURFA( DRILL TRIP T Flow ck(static)Blow down TD- POOH on TT f/687'to 134'-Tight spot©540' 08:00 08:15 0.25 134 44 SURFA( DRILL TRIP T Std back NM flex DC's 0815 0845 0.50 44 28 SURFA( DRILL PULD T PJSM on LD BHA-LD XO-UBHO- XO 08 45 09 15 0.50 28 0 SURFA( DRILL OTHR T Adjust bend in motor f/2.0°to 1.5°- clean clay f/stab on motor&bit 09:15 09.30 0.25 0 0 SURFA( DRILL OTHR T Clean up rig floor 09:30 11:00 1 50 0 83 SURFA( DRILL PULD T PJSM on MU BHA-MU BHA#4- bit-motor w/1 5°bend-NM pony DC-Stab-XO-MWD-UPA-filter sub-UBHO-XO to 83' 11:00 11:15 0.25 83 173 SURFA( DRILL TRIP T RIH w/NM flex DC's f/83'to 173' 11 15 12 00 0.75 173 542 SURFA( DRILL TRIP T RIH w/HWDP f/173'to 542' 12:00 12.15 0.25 542 634 SURFA( DRILL TRIP T Trip in hole with BHA#4. Motor set on 1.5°. From 542'MD to 634'MD. 12:15 12:30 0.25 634 687 SURFA( DRILL WASH T Kelly up and wash down from 634' MD to 687'MD 300 GPM/420 PSI. Page 5 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 20:30 8.00 687 1,095 SURFA( DRILL DDRL T Directional Drill 14"Surface hole from 687'MD to 1095'MD.TVD=1080'. 500 GPM/1350 PSI/25k WOB/ AST=3.2 HRS.Stop drilling. Survey on bottom placed the wellbore 2 feet from an error ellipse. Decide to POOH for bigger bend. 20 30 22:30 2.00 1,095 1,095 SURFA( DRILL CIRC T Discuss options with Drilling Engineer/Drilling Superintendent/Survey Manager. Decision made to trip out for a bigger bend Well bore position 2 feet from ellipse of uncertainty. 22:30 22'45 0 25 1,095 1,095 SURFA( DRILL SFTY T PJSM.Trip out of the hole. 22.45 00:00 1.25 1,095 357 SURFA( DRILL TRIP T Trip out of the hole on the trip tank. 01/17/2013 POOH with BHA#4. Re-shim motor to 1 8°. PU BHA#5 Directional drill to 1284'. Survey with gyro tool. Close approach issue. POOH and LD BHA#5. TIH with BHA#6. Bit/Bit Sub/Totco ring to 1 stand of Monels and 1 HWDP. Gyro run only for information to verify bottom hole location. POOH and LD BHA#6. Pick up and RIH with 3.5"EUE tubing to plug back 00:00 00:30 0.50 357 173 SURFA( DRILL TRIP T Trip out of the hole. From 357'MD to 173'MD. 00:30 00:45 0.25 173 82 SURFA( DRILL TRIP T Stand back 3 monel drill collars. 00:45 02:15 1 50 82 82 SURFA( DRILL PULD T PJSM Clean clay off BHA. Clean off and grade bit (1-1). Set Motor bend up to 1 8°. Orient UBHO and MWD tools. 02:15 02:30 0.25 82 82 SURFA( DRILL RURD T Clean up rig floor. 02 30 02 45 0.25 82 173 SURFA( DRILL TRIP T Trip in the hole with stand on monels. 02 45 03:30 0.75 173 1,002 SURFA( DRILL TRIP T Trip in the hole from 173'MD to 1002' MD. 120k Up/115k Dn. 03:30 04:00 0.50 1,002 1,095 SURFA( DRILL WASH T Wash to bottom while oriented highside. 500 GPM/930 PSI. 04:00 06:00 2.00 1,095 1,284 SURFA( DRILL DDRL T Directional Drill 14"hole from 1095' to 1284' MD 1255'TVD ADT- 1.4 hrs=ART-.1 hrs. AST-1.3 hrs WOB 10/30 k RPM 50 GPM 500 @1100 psi String wt PU 124 SO 124 Toruqe on btm.8 k Stopped drilling-assembly not building angle with strong right hand walk approaching travling cylinder for CD1-40-Contact Drilling Superintendent&sdrilling Engineer to discuss plan forward 06:00 07'30 1.50 1,284 1,284 SURFA( DRILL SRVY T Circ @ 300 gpm @ 420 psi-Ran gyro surveys to confirm MWD surveys 07:30 08:00 0.50 1,284 1,284 SURFA( DRILL CIRC T Circ hole clean @ 450 gpm @ 780 psi w/50 rpm's 7 k torque-RD gyro Page 6 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:45 1.75 1,284 173 SURFA( DRILL TRIP T FI ck-Blow down TD-POOH on TT f/1284'to 173' 09.45 10:00 0.25 173 83 SURFA( DRILL TRIP T Std back NM flex DC's to 83' 10:00 10:30 0.50 83 83 SURFA( DRILL OTHR T Check motor to MWD scribe 197.8- clean clay f/stabs&bit 10:30 12:00 1.50 83 0 SURFA( DRILL PULD T LD BHA#5 12:00 12:15 0.25 0 0 SURFA( DRILL SFTY T PJSM on rig up a-line&make up BHA 12:15 13:00 0.75 0 0 SURFA( DRILL RURD T Rig up e-line 13:00 13:15 0.25 0 93 SURFA( DRILL PULD T Make uo BHA#6 to 93'. 13:15 14:30 1.25 93 1,284 SURFA( DRILL TRIP T Run in hole from 93'to 1284'. 14:30 15:30 1.00 1,284 1,284 SURFA( DRILL ELOG T Run Gyro survey at 1281'. 15:30 17 00 1 50 1,284 93 SURFA( DRILL TRIP T Trip out of hole to 91'into trip tank. 17:00 18:00 1.00 93 0 SURFA( DRILL PULD T Lay down BHA#6 18:00 19.00 1.00 0 0 SURFA( DRILL OTHR T Clean and clear rig floor. 19 00 19:30 0.50 0 0 SURFA( DRILL SVRG T Rig maintenance 19:30 20:00 0.50 0 0 SURFA( DRILL PULD T Pick up tubing equipment 20.00 20:15 0.25 0 0 SURFA( DRILL SFTY T PJSM to rig down a-line 20:15 20:45 0.50 0 0 SURFA( DRILL RURD T Rig down e-line 20:45 21:15 0 50 0 0 SURFA( DRILL RURD T Rig up tubing equipment 21:15 21 45 0 50 0 0 SURFA( DRILL SFTY T PJSM to run in hole with 3.5" EUE tubing 21.45 22 15 0 50 0 90 SURFA( DRILL TRIP T Pick up mule shoe,trip in hole with 3 joints 31/2 EUE tubing cement string. 22:15 23:30 1.25 90 90 SURFA( DRILL SVRG T Repair 31/2 tubing elevators, clear ice from floor of pipeshed.(from last storm), Complete work order on top drive. 23:30 00:00 0.50 90 315 SURFA( DRILL TRIP T Trip in hole with 31/2 EUE tubing from 90'to 315'MD. 31/18/2013 Place_cement plug on bottom from 1284'MD to 674'M_D. 15.7 PPG Arctic Set cement.(190 BBLS). Circulate the top hole clean. Verify 1st plug height @ 674'MD. Set 10k weight down POOH to 378'MD, wait on cement&prepare to pump second plug. Load 875 SXS AS1 in cement silo Trip in to 623'MD with 3%EUE cement string. Hit bridge @ 623'MD. Stand back one stand of tubing. Wash down to 674 with stand of 5"DP. CBU. Stand back DP and trip in to 672' MD with 3W tubing. Circulate @ 9 BPM 430 PSI. Conduct pre job safety meeting Cement job. 00:00 01:00 1.00 315 1,079 SURFA( DRILL TRIP T Trip in the hole from 315'MD to 1079' MD.With 31/2'EUE tubing. 01:00 01:45 0.75 1,079 1,081 SURFA( DRILL RURD T Change out tong heads-Make up X-overs to 1081'MD Rig down tongs- change out elevators to 5" 01:45 02:00 0.25 1,081 1,270 SURFA( DRILL TRIP T Trip in the hole from 1081'MD to 1270'MD. 80k up 80k do 02:00 02:15 0.25 1,270 1,284 SURFA( DRILL RURD T Make up 16.12'- 5" Pup. Rig up head pin&cement hose. Page 7 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02 15 05:00 2.75 1,284 1,284 SURFA( DRILL CIRC T Break circulation. Stage pumps up from 1 BPM to 8 BPM slowly. SIMOPS: Heat 300 BBLs water to 70°, load mud push, prepare for cement job. 05:00 05:30 0.50 1,284 1,284 SURFA( DRILL SFTY T Held pre job safety&ops meeting on setting 1st stage of plug back/kick off plug 05:30 07 00 1 50 1,284 1,284 SURFA( DRILL PLUG T Set 1st stage plug as follows:w/3 1/2"tbg stinger set @ 1284'- Pumped 1 bbls 11 ppg mud push- Test lines to 3000 psi-Pumped 40 bbls 11 ppg @ 3.5 bbls/min @ 125 psi-Mixed&pumped 191 bbls 15.7 ppg AS1@ 4.5 bbls/min @ 150 psi- Pumped 2 bbls mud push behind- Switched to rig pump&displaced w/ 4.5 bbls of spud mud @ 9 0 ppg- CIP @ 0653 hrs.-Full returns while pumping job-Ck for balance OK 07:00 07:15 0.25 1,284 1,081 SURFA( DRILL TRIP T Break out head pin-LD 16'pup jt.- POOH&std back 5"DP to 1081' 07:15 07:30 0.25 1,081 1,081 SURFA( DRILL RURD T RU tbg tongs-chnage elevators 07:30 08:15 0.75 1,081 481 SURFA( DRILL TRIP T PJSM on pulling tbg-Pull&std back 6 stds 3 1/2"tbg&LD 1 jt.to 481' 08:15 08:45 0.50 481 670 SURFA( DRILL TRIP T RIH back in hole w/2 stds 5"DP& tbg stringer f/481'to 670' 08:45 09:45 1.00 670 670 SURFA( DRILL CIRC T Load wiper ball into DP-MU head pin&hose-Pumped 35 bbls Biozan sweep&circ @ 10 bbls/min -Observed mud push @ shakers& hole unloaded with large amount of clay-observed cement contaminated mud to surface-circ to clean up hole 09:45 11.00 1.25 670 670 SURFA( DRILL OTHR T Blow down lines-RD hose&head pin-Clean up under shakers-Flow ck(static-slight drop) 11 00 12 30 1 50 670 102 SURFA( DRILL TRIP T POOH on TT-Std back 2 stds 5" DP-LD 12 its 3 1/2"tbg to 102' 12 30 13.00 0 50 102 102 SURFA( DRILL RURD T Re-arrange tubing equipment. 13:00 13 30 0.50 102 670 SURFA( DRILL TRIP T Trip in the hole from 102'MD to 670' MD. 1330 14:15 0.75 670 670 SURFAt DRILL CIRC T Circulate hole clean with 8 BPM. 100 PSI. Hole appeared clean. 14:15 1515 1.00 670 670 SURFAt DRILL RURD T Blow down top drive Add 220 BBLS mud to pits, and raise viscosity to 300. Hook up line directly from pump #1 to stack to allow'black water'to be added to the flow stream while circulating the cement job out 15:15 16:00 0.75 670 670 SURFA( DRILL CIRC T Circulate bottoms up with 9 BPM/ 200 PSI 16 00 16:15 0.25 670 674 SURFA( DRILL CIRC T Wash down from 670 to 674'MD Tag cement with 10k down. Pump 1.5 BPM 40 PSI. Page 8 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 17:15 1 00 674 674 SURFA( DRILL CIRC T Circulate bottoms up @ 9 BPM.200 PSI 17 15 17:30 0.25 674 674 SURFA( DRILL OWFF T Observe well bore. Static Blow down top drive. Change out elevators. 17:30 18.00 0.50 674 674 SURFA( DRILL RURD T Prime hole fill pump 18.00 1830 0.50 674 387 SURFA( DRILL TRIP T Trip out of the hole. Stand back 3 stands of tubing work string. 18.30 20:00 1.50 387 387 SURFA( DRILL RURD T Make up cross overs and cement head. Circulate. Stage pump up to 8 BPM. 210 PSI. SLB cement team reported they are ready. 20 00 21:00 1.00 387 623 SURFA( DRILL TRIP T Rig down cement head.Trip in the 2 stands. One third stand tagged up on bridge @ 623'MD. Unable to pass by. Set 10k down. No Go. 21:00 23:00 2.00 623 674 SURFA( DRILL CIRC T Stand back one stand of tubing. Change out elevators to 5". Pick up one stand of 5"DP. Circulate down to 623' MD. Tag up Turn 1/4 turn, wash and work string. Break through. Wash to bottom. Circulate @ 8 BPM. 230 PSI Pick up second stand of 5"DP.Wash down to 674' MD.Verify that to be top of cement. Trip out 2 stands of 5"DP Change out elevators from 5"to tubing Trip in with stand of tubing. Saw some resistance at 623'again, but dropped through. 23:00 00:00 1.00 674 674 SURFA( DRILL CIRC T Circulate. Pre Job Safety Meeting. Cement job. Circ @ 10 BPM/430 PSI. 31/19/2013 Set cmt plug#2 f/674'w/142 bbls AS1 -POOH to 197' -Circ hole clean-LD excess 3 1/2"tbg-WOC- RIH @ tag top of plug#2 @ 342'-Circ-POOH-LD 3 1/2"tbg-MU BHA#7-Rig up Halliburton E-Line for gyro surveys. Off load cement contaminated mud. Load new mud in pits Directional ill 14"sut ace hole from 420'MD to 725' MD. Conduct Safety Stand Down with both crews. Topic: Pressure Washer Incident. 00:00 01:00 1.00 674 674 SURFA( DRILL CMNT T Set 2nd stage plug as follows:w/3 1/2"tbg stinger set @ 674'- Pumped 1 bbls 11 ppg mud push- Test lines to 3000 psi-Pumped 38.5 bbls 11 ppg @ 5.1 bbls/min @ 100 psi-Mixed&pumped 143.0 bbls 15.75 ppg AS1@ 5 1 bbls/min @ 200 psi-Pumped 2 bbls mud push behind- CIP @ 00:52 hrs.-Full returns while pumping job-Ck for balance OK 01:00 01:30 0 50 674 197 SURFA( DRILL TRIP T Well bore balanced. Trip out with 3%"EUE tubing Stand back 5 stands. From 674'to 197' MD. Page 9 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 197 197 SURFA( DRILL CIRC T Insert nerf ball. Rig up cement head to pump. Pump 33 BBLS biozan pill, followed by 200 BBLS spud mud. Circ. hole clean @ 9.5 BPM.260 PSI. Mud push seen, no cement returns.When 300 vis spud mud was seen in and out. Stopped pumping. 02:30 02:45 0.25 197 197 SURFA( DRILL SFTY T Safety meeting on rig floor. Discuss recent incident on D15. PJSM on laying down tubing. 02:45 03:30 0 75 197 197 SURFA( DRILL PULD T LD 3 1/2"tbg f/197'(6 jts)RIH w/2 stds 3 1/2"tbg f/derrick to 197' 03:30 03:45 0.25 197 197 SURFA( DRILL CIRC T Circ pipe volume @ 7 bbls/min @ 160 psi 03.45 05:00 1.25 197 0 SURFA( DRILL PULD T POOH&LD 6 jts 3 1/2"tbg-RIH w/ 1 std tbg to 94'-Circ to clean pipe @ 7 bbls/min @ 150 psi-POOH& LD 3 jts tbg 05:00 05:15 0.25 0 194 SURFA( DRILL TRIP T RIH w/mule shoe @ 2 stds-3 1/2" tbg to 194' 05:15 05:30 0.25 194 194 SURFA( DRILL CIRC T Circ @ 194'@ 7 bbls/min @ 150 psi -pumped 35 bbls-Blow down line 05:30 08:30 3 00 194 194 SURFA( DRILL WOC T WOC-Clean up rig floor-Bring BHA components to rig floor-Change out tugger line 08:30 09:15 0.75 194 341 SURFA( DRILL WASH T Wash down f/194'©2 bbls/min @ 80 psi-tagged top of cmt plug#2 @ 341'w/10 k wt 09:15 09:30 0.25 341 341 SURFA( DRILL CIRC T Circ 2 X btms up @ 8 bbls/min @ 90 psi 09 30 10 30 1.00 341 0 SURFA( DRILL TRIP T POOH f/341'-std back 2 stds 5" DP-LD 6 its 3 1/2"tbg&mule shoe 10 30 12:00 1.50 0 0 SURFA( DRILL OTHR T RD tbg tongs-Change elevators- Clear rig floor of excess equipment 12:00 1215 0.25 0 0 SURFA( DRILL SFTY T PJSM on rigging up wireline for gyro 12:15 14:30 2.25 0 90 SURFA( DRILL PULD T Make up BHA#7. Motor set on 1 7°, MX HTC bit, MWD system, UBHO sub. Motor top stab 12'W. Orient Up load 14:30 15:00 0 50 90 90 SURFA( DRILL RURD T Rig up Halliburton E-Line unit, hang sheave, pick up GyroData gyro tool 15:00 15:30 0.50 90 263 SURFA( DRILL TRIP T Trip in with stand of monel collars. 1st stand of HWDP with jars. 15:30 16:00 0.50 263 263 SURFA( DRILL SRVY T Run 1st gyro. Orient tool face. 16:00 16.30 0.50 263 356 SURFA( DRILL WASH T Wash down oriented to kick off direction.Tag firm cement @ 342' MD.400 GPM/560 PSI Drill cement of 356'MD 16:30 17:30 1.00 356 356 SURFA( DRILL CIRC T Load new spud mud in pits.Run Gyro #2 Page 10 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 22:30 5.00 356 725 SURFA( DRILL DDRL T Directional drill 14"surface hole. Drill cement from 356'to 420. Exit old well @ 420' MD. Drill from 420'MD to 725'MD.Gyro every stand, and get 31 foot stations.430 GPM/1050 PSI/25k Wob/Up Wt/Dn WT/Rot Wt=110k. Getting needed doglegs Gyro#3.#4.#5) 22:30 23:00 0.50 725 725 SURFA( DRILL SRVY T Run gyro#6 23:00 23:30 0.50 725 633 SURFA( DRILL CIRC T Circulate hole clean. 500 GPM/1100 PSI/50 RPM/7K TQ. Blow dwon top drive Stand one stand back.Well bore static. 23 30 00.00 0.50 633 633 SURFA( DRILL SFTY T Safety Stand down with both crews Pressure Washer Incident 01/20/2013 Directional drill 14"hole w/1.7°AKO motor f/725'to to 2617'MD_2080'TVD WOB 25/30 k RPM 60 GPM 680 @ 2600 psi String wt PU 140/ SO 125/ Rot 130 Torque on/off btm-9.5/9 k ft/lbs Last gyro survey @ 817'MD.Gyro release @ 1250'MD. MWD tool free of magnetic interference. 00:00 08:45 8.75 725 1,283 SURFA( DRILL DDRL T Directional drill 14"hole w/1.7°AKO motor f/725 to 1283'MD-1223'TVD WOB 25/30 k RPM 60 GPM 600 @ 1990 psi String wt PU 125 SO 1232 Rot 124 Torque on/off btm.-9/5.5 k ft/lbs *End of Trouble time 08:45 12:00 3.25 1,283 1,604 SURFA( DRILL DDRL P Directional drill 14"hole w/1.7°AKO motor f/1285'to to 1604'MD 1465' TVD ADT-6.6 hrs=ART-2.1 hrs AST- 4.5 hrs*Note total drilling time since midnight WOB 25/30 k RPM 60 GPM 600 @ 1990 psi String wt PU 126 SO 124 Rot 125 Torque on/off btm.-9/6 k ft/lbs 12:00 00:00 12.00 1,604 2,617 SURFA( DRILL DDRL P Directional drill 14"hole w/1.7°AKO V motor f/1604'to to 2617'MD 2080' TVD ADT-6.3 hrs=ART-5.2 hrs AST- 1.1 hrs* Note total drilling time since noon. WOB 25/30 k RPM 60 GPM 680 @ 2600 psi String wt PU 140 SO 125 Rot 130 Torque on/off btm.-9.5/9 k ft/lbs 01/21/2013 Directional drill 14"hole w/1 7°AKO motor f/2617' MD t/3123'MD 234.4'TVD. Circ 3 X btms up, Std back 1 std every 30 mins f/3123't/2789'.Wiper trip f/2789't/1098'. Circulate bottoms up @ 1098'. RIH t/3123'. Circulate bottoms up. POOH to run 11%' 60#L-80 BIC surface casing L/D BHA to 85'. Page 11 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00 00 0745 7.75 2,617 3,123 SURFA( DRILL DDRL P Drilled 14"hole w/1.7°AKO motor f/ 2617'to 3123' MD 2344'TVD ADT-4.3 hrs=ART-4.1 hrs. AST- .2 hrs WOB 25/30 k RPM 60 GPM 750 @ 3300 psi String wt. PU 144 SO 123 Rot 133 Torque on/off btm.-11.5/9.5 k ft/lbs 07:45 10.30 2.75 3,123 2,789 SURFA( CASING CIRC P Circ 3 X btms up @ 650 gpm @ 2400 psi w/60 rpms @ 10 k torque- Weight up mud system from 9.7+ ppg to 10 0 ppg. Std back 1 std every 30 mins. f/3123'to 2789' 10.30 10:45 0.25 2,789 2,789 SURFA( CASING OWFF P Flow ck-slight drop in fluid level 10:45 12:00 1.25 2,789 2,130 SURFA( CASING WPRT P Wiper trip f/2789'to 2130'w/pump @ 650 gpm @ 2400 psi w/60 rpm's @ 10 k torque 12:00 14:00 2 00 2,130 1,098 SURFA( CASING WPRT P Cont.wiper trip f/2130'to t/1700'w/ pump @ 650 gpm @ 2400 psi and f/ 1700't/1098'w/pump @ 450 gpm @ 1400 psi 14.00 1430 0.50 1,098 1,098 SURFA( CASING CIRC P Circulate bottoms up w/pump @ 450 gpm @ 1350 psi 14:30 16.00 1.50 1,098 3,123 SURFA( CASING TRIP P RIH f/1098't/3123'. Hole in good shape. No fill. 16:00 17:00 1.00 3,123 3,123 SURFA( CASING CIRC P Circulate bottoms up w/pump @ 650 gpm @ 2550 psi. Rotate and reciprocate 17:00 17:15 0.25 3,123 3,123 SURFA( CASING OWFF P Observe well Static. Slowly dropping. 17:15 19:30 2.25 3,123 1,192 SURFA( CASING TRIP P Trip out of the hole on elevators. Circulate out of the trip tank. Good hole fill Hole in good condition. 19:30 20:00 0.50 1,192 1,192 SURFA( CASING OWFF P Monitor well at top of HWDP. Wellbore static to a slow loss. Dropped 3 inches in 30 mins. 20:00 21:15 1.25 1,192 595 SURFA( CASING TRIP P Trip out with HWDP f/1192'to 595' MD. Began to pull tight @ 595'. RIH f/595'to 630'. 25k overpull:Wiped 1001'to 909'- OK after wiping. 25K overpull:Wiped 725'to 633'- OK after wiping. 21:15 21:45 0 50 595 595 SURFA( CASING CIRC P Make a top drive connection. Circulate @ 500 GPM's w/1250 psi, rotate 50 rpm w/8k ft lbs of torque f/ 630'to 560'. Large amount of cuttings on the shakers.The hole cleaned up. Pumped 225 bbls total. POOH with out pumps f/560'to 541'- OK. RIH f/541'to 633'without pumps-OK, SO wt 105-110k. 21:45 22.00 0.25 595 633 SURFA( CASING TRIP P Blow down top drive. Run one stand in the hole to check for bridge f/633' to 720'. Hole clear. SO wt 105-110k. POOH f/720'to 633. Page 12 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22 00 22:30 0.50 633 435 SURFA( CASING TRIP P Continue to POOH on elevators w/ HWDP f/633'. Pulled tight from 540 to 448'MD 20-25k over. Dropped down through twice and it cleaned up. 22:30 23.00 0 50 435 171 SURFA( CASING TRIP P POOH on elevators to the top of HWDP @ 171'. 23:00 23:15 0.25 171 171 SURFA( CASING SFTY P PJSM Lay down BHA components. Discuss hazards with DD. 23:15 00:00 0.75 171 85 SURFA( CASING PULD P Lay down 3 monel drill collars 01/22/2013 Lay down BHA#7 f/85',clear floor, MU FMC hanger and landing jt, L/D to pipe shed, RU TESCO, Run 11-3/4"60 ppf L-80 BTC-m casing to 1005'(23 jts+part of 24 in the hole). POOH, L/D jts 24, 23,22, 21 due to galled box's. Repalce jts, continue to run in f/ 854'to 1702'(jt#40 in the hole),washing in the hole, pumping 3 bpm. L/D jt#41,then jt 40, 39, 38 due to galled box's. I-• - I. - 00:00 01:15 1 25 85 0 SURFA(TCASING`PULD P Continue to Lay down BHA#7 f/85'. 01:15 02:30 1 25 0 0 SURFA(1CASING OTHR P Clean rig floor. Remove tools via beaver slide 02:30 03:30 1.00 0 0 SURFA( CASING RURD P Rig up Doyon casing tongs. Prepare to make up FMC hanger to the landing joint'41' 11-3/4"BTC. 03 30 03:45 0.25 0 0 SURFA( CASING SFTY P Pre job safety meeting on making up the FMC 11-3/4"hanger w/pup. 03.45 04:15 0.50 0 0 SURFA( CASING OTHR P Make up landing joint to 2500 ft lbs w/Doyon casing tongs. Run in hole, land on FMC load shoulder. Mark joint, Pull out and leave in the pipe shed made up Note: Nose of jt to makeup at the top of the hanger is 8-5/8"above bottom of the pin Approx 11-1/2 turns. 04:15 04 30 0.25 0 0 SURFA( CASING SFTY P Pre job safety meeting on rigging up TESCO Casing Running Tool. 04:30 06 30 2.00 0 0 SURFA(CASING RURD P Rig up TESCO casing running tool. 06:30 11 45 5.25 0 1,005 SURFA( CASING RNCS P Run 11-3/4160 ppf L-80 BTC-m casino as follows to 1005': Ray Oil Tools Silver bullet(essentric), (2) joints of casing,Weatherford model 402 float collar,then joints 3-24 to 1005'. Note:Work casing through tight hole @ 378', 509', 540',602', 895', 910'to 1000'. Note: Baker locked to pin of 4th joint.Applied astop ring 10'above the shoe on jt#1 &centralizer, stop ring 10'below the box of jt#2& centralzier, centralizers over the collars f/3 to 13,then every other collar. 11:45 1200 0.25 1,005 1,005 SURFA( CASING CIRC P Attempt to circualte @ 2 bpm w/380 psi(low return rate). 12 00 12.45 0.75 1,005 982 SURFA( CASING RNCS T Lay down jt#24 f/1005'to 982'. Galled pin threads. Page 13 of 87 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:45 1315 0.50 982 982 SURFA( CASING OTHR T Blow down the top drive. 13.15 13:45 0.50 982 940 SURFA( CASING CIRC T Work f/982'Qt#23) to 940'(jt#22 in the hole.20k over pull Circ 3 bpm w/270 psi initial circ pressure,final circ presure 100 psi. PU wt 125k, SO wt 105k. 13:45 17.00 3.25 940 854 SURFA( CASING PULD T Lay down jt#23,jt#22,jt#21 f/ 940'to 854'. Circulated joints out of the hole, pumping 3 bpm w/100 psi- -27%flow on TOTCO. Collars and pins were galled when laying down Jt #23 and#22. Rigged up Doyon Casing tongs and layed down jt#21, leaving jt#20 in the hole w/a good collar @ 854', using Doyon casing tongs. 17:00 2230 5.50 854 1,702 SURFA( CASING P Run 11-3/4"casing f/854'(jt#20)to 1702'(jt#40 in the hole). Circ each joint down, pumping 3 bpm w/180 psi. PU wt 150k, SO wt 120-115k 22:30 00:00 1.50 1,702 1,574 SURFA( CASING T Jt#41 pin did not make up good. Break out jt#41-galled pin/box. Lay down jt#41,jt#40,#39,#38-all galled. Pump out w/3 bpm 200 psi. PU wt 145, SO wt 120k f/1702' 01/23/2013 L/D casino due to galled threads to 1579', MU/RIH w/11-3/4" a to 1920'. CBU, con't to RIH w/casing, MU _ FMC hanger, land w/shoe @ 3018.30'. R/D TESCO casing running tool, RU 350 ton elevators w/long bales, RU cement head,circ&cond mud f/cement. Held PJSM, perform cement job w/100%returns with 168.6 bbls of cement returns. Bump plug, CIP @ 1651 hrs. Check floats-good. Monitor casing f/30 minutes-good Rig down Dowell cement head. RU to test casing, attempt to test w/BOP test pump-no test. Rig down testing eequipment. Lay down casing tools, nipple down riser. 00:00 01.00 1 00 1,579 1,579 SURFA( CASING RNCS P Cont.to LD casing to 1579'(Bad threads) 01:00 03:00 2.00 1,579 1,920 SURFA( CASING RNCS P RIH w/11 3/4"casing f/1579'to 1920'-PU wt 173 SOwt118 03:00 03:30 0.50 1,920 1,920 SURFA( CASING CIRC P Circ Btms up @ 1920'-Stage pump up to 6 bbls/min @ 270 psi 03:30 09:30 6.00 1,920 3,108 SURFA( CASING RNCS P Cont. RIH w/11 3/4"60#L-80 BTC casing f/1920'to 3068'(72 jts total in hole)PU FMC fluted hanger& landing_1t_Land cang in wellhead w/ shoe @ 3108.50' -FC @ 3018.30' Washed down every 5th jt @ 3 bbls/min @ 250 to 340 psi 09:30 10:00 0.50 3,108 3,108 SURFA( CASING RURD P RD Tesco casing running equipment Blow down TD 10:00 11.00 1.00 3,108 3,108 SURFA( CEMEN-RURD P MU long bails-RU cmt head&lines Page 14 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11.00 13 30 2.50 3,108 3,108 SURFA( CEMEN-CIRC P Circ&cond mud for cmt job-Stage pump up to 8 bbls/min-ICP 1.5 bbls/min @ 290 psi-FCP 8 bbls/min @ 440 psi Attempted to recipracate pipe pulled up tight w/hanger coming off seat @ 21"-Pulled 45 over Landed hanger back on landing ring 13:30 14:00 0.50 3,108 3,108 SURFA( CEMEN'SFTY P Held pre job safety meeting w/rig crew, cementrs,truck drivers, ball mill&mud engineers-cementing 11 3/4'casing. Continued to circ&cond mud for cmt job-pumping 8 bbls/min-w/440 psi . Mud wt 9.9+,vis 70-75. Circulated a total of 880 bbls after casing was on bottom. 14:00 14:30 0.50 3,108 3,108 SURFA( CEMEN CIRC P Rig pump 100 bbls of 9.9 ppg mud w/ 5 ppb medium nut plug marker, pumping 8 bpm w/430 psi. Follow w/ 33 bbls of Biozan water(2.5 ppb Biozan)w/5 ppb medium nut plug marker, pumped @ 3 to 5 bpm w/ 90-180 psi . 14:30 14:53 0 39 3,108 3,108 SURFA( CEMEN-PUCM P Dowell pump pump water to rig floor, pressure test lines to 3500 psi-OK. Batch up 10.5 ppb Mud Push @ 10.5 ppg Dowell pump 52.4 bbls of 10.5 ppg MudPush @ 5 8 bpm w/200 to 220 psi. Shut down, drop bottom plug. Batch up 10.7 ppg ASL cement_ (yield 2A5cuft/sx mix w ate_r 1__1._513_ gal/sx, 110#sx blend). 14 53 15:44 0.86 3,108 3,108 SURFA( CEMEN'PUCM P Dowell pumping 348.5 bbls(799 sx) of 10.7--ppg ASL lead cement(yield 2.45 cuft/sx, mix water 11.513 gal/sx, 110#sx blend). Pumped @ avg 6.8 bpm, inital 250 psi,final @ 7.1 bpm w/350 psi. Batch up Tail cement. 15:44 16:04 0.34 3,108 3,108 SURFA( CEMEN PUCM P Dowell pumping 74.2 bbls(359 sx)of 15.7 ppg tail cement(yield 1.16 cuft/sx, mix water 5.125 gal/sx. Additives. 2%BWOC D046 Antifoam, .3%BWOC D065 Dispersant, .8%BWOC S002 Accelerant). Pumped @ avg 4 5 bpm, inital 300 psi, final @ 4.5 bpm w/250 psi Shut down,drop top plug. 16:04 16.08 0.07 3,108 3,108 SURFA( CEMEN'DISP P Dowell kick out top plug w/20 bbls water-wash up thru the tub. Pumping 6.1 to 6.6 bpm w/300 to 370 psi. Shut down Page 15 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:08 16:59 0.86 3,108 3,108 SURFA( CEMEN'DISP P Rig pumped 9.8 ppg 6%KCUNaCI brine @ 8bpm w/580 psi initial rate. Once 310 bbls were pumped,slowed to 3 bpm w/830 psi Bumped plug w 1260 psi(3186 strokes). Held f/5 minutes-OK, bleed pressure to check floats-OK. CIP @ 1651 hrs 1/23/2013. Full returns throughout j_ob. Did not reciprocate for hanging up in the stack. 168.6 bbls of cement returns to surface. 16:59 17:13 0.24 3,108 3,108 SURFA( CEMEN'SFTY P Pre job safety meeting on rigging down Dowell cement head 17:13 17:43 0.50 3,108 3,108 SURFA( CEMEN'OWFF P Monitor casing f/30 minutes-static. Rig down Dowell cement head(Max rating 3000 psi). 17.43 17:58 0.25 3,108 3,108 SURFA( CEMEN-SFTY P Pre job safety meeting on rig up and test of 11-3/4"casing w/BOP test pump. 17 58 18 13 0.25 3,108 3,108 SURFA( CEMEN"RURD P Rig up to test casing: Install 11-3/4" cement swage, connect BOP test pump Fill lines. 18:13 18:43 0.50 3,108 3,108 SURFA( CEMEN'PRTS T Attempt to test the 11-3/4"60 ppf L-80 BTC-m casing to 3500 psi using the test pump. Output of pump approx 8.57 gallon per minute. Observed pressure drop @ 3090 psi, shut down pump,dropped to 1850 and was stable @ 1850 for 4 minutes. Brought test pump back on and once again reaching 3090 psi, the pressure fell and was stable @ 1850 psi. Bleed off pressure.Will test again with the mud pumps and 9.8 brine after testing the BOPE. Pumped a total of 4.38 bbls 18:43 18:58 0.25 3,108 3,108 SURFA( CEMEN-RURD P Rig down testing equipment. 18:58 19:13 0 25 3,108 3,108 SURFA( CEMEN'SFTY P Pre fob safety meeting on backing out and laying down the 11-3/4"160 ppf L-80 BTC-m landing joint 19:13 20:43 1.50 3,108 0 SURFA( CEMEN-RURD P Rig up casing tongs, back out the landing joint 3 turns w/tongs.Then finish backing out the landing joint w/ chain tongs. Pick up landing joint w/ tugger line and lay down same. Note: FMC rep watched the hanger through the 2"in the quick connect head to observe if the hanger was turning-No turning observed. 20:43 22:13 1.50 0 0 SURFA( CEMEN PULD P Clean up casing equipment, lay down tools. Remove long bales f/the top drive. 22:13 22:28 0.25 0 0 SURFA( CEMEN"SFTY P Pre job safety meeting on laying down the 16"drilling riser. Page 16 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:28 23:58 1.50 0 0 SURFA(WHDBO NUND P Lay down the mouse hole, remove the cementing bypass lines on the riser, nipple down the drilling riser. 31/24/2013 Nipple down surface riser, install FMC Gen V Big Bore 5000 psi wellhead, nipple up BOPE,change lower pipe rams Test wellhead seal to 1000 psi-good Install lower test plug, use 3-1/2"test joint, body test BOP stack using top pipe rams to 3500 psi f/10 minutes.Witness of test waived by AOGCC inspector Chuck Scheve Test 11-3/4"casing to 3500 psi using the blinds, hold test f/30 minutes-good, chart test. RU/then run 3-1/2"tubing to 1788.56' RKB, land, RILDS, set TWC, ND BOPE 00:00 01:00 1 00 0 0 SURFA(WHDBO NUND P Cont nipple down riser&adapter- LD riser 01 00 02.00 1.00 0 0 SURFA( WHDBO NUND P Install FMC wellhead Gen.V Big bore 5K 02 00 04:30 2.50 0 0 SURFA(WHDBO NUND P NU BOP stack 04:30 04:45 0.25 0 0 SURFA(WHDBO SFTY P PJSM on changing rams 04:45 06:30 1.75 0 0 SURFA(WHDBO NUND P Change lower pipe rams f/2 7/8"x 5' to 3 1/2"x 6'VBR 06:30 08 45 2.25 0 0 SURFA( WHDBO NUND P NU BOP riser, choke line&gas buster line 08:45 09:00 0.25 0 0 SURFA(WHDBO PRTS P Test metal x metal on wellhead to 1000 psi for 10 mins.(Good test) 09:00 10:00 1 00 0 0 SURFA(WHDBO RURD P Install lower test plug&3 1/2'test jt. -RU&fill lines 10 00 10 45 0.75 0 0 SURFA( WHDBO PRTS P Body test BOP stack-top pipe rams (3 1/2"x 6"VBR-HCR kill, choke valves 1,4,9,6&needle valve&upper annulus valve to 3500 psi for 10 mins (Good test) 10 45 11 00 0.25 0 0 SURFA(WHDBO OTHR P Pull test plug&3 1/2"test jt. 11:00 12:00 1.00 0 0 SURFA( CEMEN.PRTS P Test 11 3/4"casing to 3500 psi for 30 mins(Good test)-bleed off pressure&blow down lines 12:00 12:15 0 25 0 0 SURFA( RPCOM SFTY P Pre job safety meeting IN 12:15 13 00 0 75 0 0 SURFA( RPCOM RURD P Pick up 3-1/2"tubing running ,(J equipment,then rig up to run same -\\ ,,r°) 13:00 13 15 0 25 0 0 SURFA( RPCOM SFTY P Pre job safety meeting on running xt 3-1/2"9.3 ppf L-80 EUE-m tubing kill 5 string. 13:15 19:15 6.00 0 1,788 SURFA( RPCOM RCST P PU/MU/RIH w/3-1/2"9.3 ppf L-80 EUE-m tubing as follows WLEG, 56 jts of tubing, crossover to 4-1/2" IBT-m, FMC tubing hanger w/ elastomer seal(CPAI PN. 1339004, FMC PN: p1000087918)w/pup.Top connection of hanger is 5"Acme Right hand. Lower connection 4-1/2" IBT-m Run in the hole to land @ 1788.56' RKB w/landing joint"B". PU wt 77k, SO wt 83k, block wt 72k. Page 17 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 19:30 0.25 1,788 1,788 SURFA( RPCOM OTHR P FMC rep ran in the upper lockdown screws to 450 ft lbs of torque(3-3/4" of pin is exposed from the flange of the wellhead). Note: Upper LDS @ 30.87', LLDS @ 33.34', Surface Load shoulder @ 36.32', GL @ 35 99'(LCMF), GL rig measurement 36.32' 19:30 19:45 0.25 1,788 0 SURFA(WHDBO OTHR P Back out the 4-1/2"landing joint, lay down the landing joint, run the two way check into the hanger, lay down "T"bar. 1945 20:00 0.25 0 0 SURFA( WHDBO SFTY P Pre job safety meeting on nippling down the BOPE.Will remove Nordic's 13-5/8"5m spacer spool. Will bolt stack back to the FMC quick connect and DSA to stand back. 20 00 00.00 4.00 0 0 SURFA( WHDBO NUND P Nipple down BOPE. Remove drilling riser, chain falls, break bolts on Nordic spacer spool, break bolts to the FMC wellhead. Remove BOP stack f/wellhead, bolt BOP stack the 13-5/8"5m DSA on top of the FMC Quick connect on the stump 01/25/2013 NU FMC tree,test void to 5000 psi,test tree to 250 psi low and 5000 psi high, Pull TWC, RU to freeze protect ann and tubing, PJSM, Dowell pump 194.9 bbls freeze protection diesel. "U"tube f/annulus to tubing. Set BPV w/FMC lubricator,secure well, PJSM, UD 5"drill pipe f/derrick, PJSM, blow down lines,drain pumps, disconnect lines,clean pits. Rig released f/CD1-49 for pad to pad move to CD3-127 @ 1800 hrs 1/25/2013. 00.00 01:30 1.50 0 0 SURFA( WHDBO NUND P Nipple up tree, rig up to"U"tube and pump diesel 01:30 02:30 1.00 0 0 SURFA(WHDBO DHEQ P Test hanger void to 5000 f/10 min 02:30 03:15 0.75 0 0 SURFA( WHDBO DHEQ P Test tree to 250 psi f/10 min,then 5000 psi f/10 min. 03:15 04:00 0.75 0 0 SURFA( RPCOM RURD P Pull TWC& RU to Freeze protect w/ diesel 04:00 04:15 0.25 0 0 SURFA( RPCOM SFTY P PJSM on diesel freeze protection 04:15 05:30 1.25 0 0 SURFA( RPCOM FRZP P Dowell pump water,test lines to 1900 psi, pump 194.9 bbls diesel, pumping down the 11-3/4"x 3-1/2" annulus,taking returns f/3-1/2" tubing to the pits. Diesel returns to the pits 05:30 05:45 0.25 0 0 SURFA( RPCOM FRZP P "U tube diesel Annulus to tbg.-Shut in well 05:45 06:45 1.00 0 0 SURFA( RPCOM RURD P Flush dowell lines and 2"lines with water to the tote in the cellar.-Blow down lines-RD hard lines& squeeze manifold 06:45 08:00 1.25 0 0 SURFA( RPCOM OTHR P RU FMC lubricator&Set BPV-RD lubricator-Secure well-House keeping on rig floor 08 00 08 15 0 25 0 0 SURFA( RPCOM SFTY P Held PJSM on laying down 5"DP Page 18 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 13:30 5.25 0 0 SURFA( RPCOM PULD P Lay down 5"DP f/derrick via mouse hole 13:30 13:45 0.25 0 0 SURFA( RPCOM OTHR P Lay down mouse hole 13:45 14:00 0.25 0 0 SURFA( RPCOM SFTY P Pre job safety meeting on rig down chores. 14:00 18:00 4.00 0 0 SURFA( RPCOM OTHR P Blow down lines,drain pumps, disconnect lines, clean pits, lay down and pick up wear rings and test plugs Tighten bolts on DSA on the BOP stack. Rig released f/CD1-49 @ 1800 hrs 1/25/2013 to move to CD3-127. 35/03/2013 Move ball mill, motor complex, pit module from CD3 to CD1. Begin moving Sub Base from CD3 to CD1 Friday crew change. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P PJSM Continue to prep fro rig move. 01:00 0200 1.00 0 0 MIRU MOVE MOB P PJSM. Move pits and motors complex away from sub. 0200 04:15 2.25 0 0 MIRU MOVE MOB P PJSM. Skid rig floor&install braces for pad move. Raise sub wind walls, raise stomper feet. 04:15 06:45 2.50 0 0 MIRU MOVE MOB P PJSM. Separate pits and motors complex, position and install tongues on complexes for truck hook up and transport. 06:45 12:00 5.25 0 0 MIRU MOVE MOB P PJSM. Remove off driller side windwall in cellar and change out for CD1-49 spacing. Motor and pit complexes begin move @ 09:15. 12:00 1215 0 25 0 0 MIRU MOVE MOB P PJSM Installing new wind walls and general rig move hazards. 12:15 13 15 1 00 0 0 MIRU MOVE MOB P Install cellar wind wall. Pit's and motor complexes move to CD1 from CD3. 1315 15:00 1.75 0 0 MIRU MOVE MOB P Install tongue hitch on pipe shed, prep to move sub base. Clean up debris around drill site CD3-320. 15:00 00:00 9.00 0 0 MIRU MOVE MOB P Move sub base and pipe shed from CD3 to CD1 down the ice road to CD2. Connect pits and motor complexes on CD1. Hook up steam lines. 05/04/2013 Complete rig move from CD3 to CD1-49.Assemble rig. Spot Ball Mill Connect all lines,water, high line, fuel, air,corns, mud. Shim up pipe shed,sub base Bring rig floor safety valves to floor. Rig up tiger tank for diesel displacement.Accept rig @ 22:45 hrs 00.00 04:30 4.50 0 0 MIRU MOVE MOB P PJSM. Move sub base and pipe shed from CD3 to CD1. 04.30 06:00 1.50 0 0 MIRU MOVE MOB P PJSM. Remove tie bars from rig,and begin to crab sub base onto mats and into position. 06:00 07:30 1 50 0 0 MIRU MOVE MOB P PJSM Spot pipe shed into position, near sub base. 07:30 10:15 2.75 0 0 MIRU MOVE MOB P Re-install tie bars on rig to pull sub base over well. Spot sub and shim into place. 10 00 hrs. Rig in place. Page 19 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 12:00 1.75 0 0 MIRU MOVE MOB P PJSM. Lower rig floor support feet and wind walls. Move pits and motor complexes into position. Spot pipe shed into position. 12:00 12:30 0.50 0 0 MIRU MOVE SFTY P PJSM. Discuss skidding derrick back over sub base. Spotting the pits and motors complexes. Hooking up all interconnect lines.Air,water, corns,diesel, mud 12:30 1500 2.50 0 0 MIRU MOVE MOB P Pull securing ears on rig floor,skid floor to drilling position , complete the pits and motors compexes move. 15 00 18 15 3 25 0 0 MIRU MOVE MOB P Hook up service lines Mud, air, steam,water,fuel, high line power Prime mud pumps Electrician trouble shooting top drive SIMOPS FMC tested tree adapter to 5000 psi for 10 mins 18:15 18:30 0.25 0 0 MIRU MOVE SFTY P Prejob safety meeting on rigging up to the tiger tank to take diesel returns 18:30 22:00 3.50 0 0 MIRU MOVE RURD P Rig up double valves in the cellar from tree to the tiger tank. Berm in the 500 BBL tiger tank. Continue to rig up lines to ball mill, and prepare rig for acceptance. 22:00 00:00 2.00 0 0 MIRU MOVE RURD P Change out iron rough neck dies, lay plywood down outside for walk way on herculite behind motors,fix two inch bleeder on mud pump,fix transfer pump valve, prepare to take on brine into the pits 05/05/2013 FMC pulled BPV w/lubricator. 0 PSI on OA/IA,tubing on a slight vaccum.Test 11%'casing to 3500 PSI fpr 30 mins. Displace out freeze protection diesel with 9.8 kill weight brine. Monitor well 30 mins. Static. FMC set BPV.test BPV in direction of flow. 2500 PSI 10 mins. Nipple down tree, nipple up BOPE. Pick up and stand back 58 stands of 5"drill pipe. 00:00 00:45 0.75 0 0 INTRM1 WHDBO RURD P PJSM. Finalize pre-Spud, rig acceptance check list with new Driller. Rig up to pull BPV 00:45 01:30 0.75 0 0 INTRM1 WHDBO RURD P FMC pull back pressure valve,with lubricator. 0 PSI on tubing,0 PSI on OA/IA.Tubing on slight vacuum. Lay down lubricator. 01:30 02:30 1.00 0 0 INTRM1 WHDBO RURD P PJSM Rig up hard lines to tree, and tiger tank. Pressure test lines to 1500 psi for 10 mins. Charted. 02 30 04:15 1.75 0 0 INTRM1 WHDBO PRTS P Rig up and test 11'/4'surface casing to 3500 PSI for 30 mins. Charted. SIMOPS: Hold prejob safety meeting on displacing well to brine from diesel. Page 20 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04.15 0530 1.25 0 0 INTRM1 WELLPF CIRC P Displace out 6 8 ppg diesel with 9.8 ppg brine. Pump 43 barrels brine and safe-surf-O spacer @ 5 BPM 220 PSI,chase with 253 BBLS 9.8 ppg brine @ 8 BPM. 1200 ICP. 1760 FCP. Blow down lines. Pumped 296 BBLS,296 BBLS back. 05:30 06:00 0.50 0 0 INTRM1 WELLPF OWFF P Observe well for flow. Static. 06:00 06:15 0.25 0 0 INTRMI WELLPF RURD P Rig down hardline, valves,swing and test hose 06 15 06.45 0.50 0 0 INTRM1 WELLPF RURD P FMC set BPV. 06 45 07 15 0.50 0 0 INTRM1 WELLPF PRTS P PJSM.Test BPV in direction of flow. 2500 PSI for 10 mins. Charted,good. Blow down, rig down valves, hoses in cellar. Isolate to tiger tank 07:15 08:45 1.50 0 0 INTRM1 WHDBO NUND P PJSM Nipple down tree. SIMOPS: PJSM on changing out saver sub, grab heads on top drive. (SN:D19-NC50-52T). 08:45 10:30 1.75 0 0 INTRM1 WHDBO NUND P PJSM. Nipple up adapter spool for BOPE, onto well head. SIMOPS: Change out saver sub,elevators from 4"to 5". Tested gas alarms, rig evac alarms @ 09.30. 10:30 12:00 1 50 0 0 INTRMI WHDBO NUND P PJSM Remove Alpine speed head from BOPE, nipple up BOPE onto adapter spool. 12:00 1215 0.25 0 0 INTRMI WHDBO SFTY P PJSM. Discuss nippling up BOPE. 12:15 16:45 4.50 0 0 INTRM1 WHDBO NUND P Finish removing Alpine speed head from bottom of stack, nipple up BOPE, install mouse hole, position cellar tank. 16:45 17:00 0.25 0 0 INTRM1 WELLPF SFTY P PJSM: Discuss picking up drill pipe via the mouse hole. 17:00 00:00 7.00 0 0 INTRM1 WELLPF PULD P Pick up and stand back 5"drill pipe. 58 stands. X5/06/2013 Pick up and stand back 49 stands of 5"DP. Total of 107 stands stood back. Rig up and test BOPE. Pick up landing joint"B", screw into tubing hanger._Unseat, and pull to rig floor, begin to lay down 3W EUE 9 3#L-80 kill string. Lay down from 1789 to 1723'MD. 0000 04:45 4.75 0 0 INTRM1 WELLPF PULD P Pick up and stand back 5"drill pipe 49 stands 04 45 05:15 0 50 0 0 INTRM1 WELLPF SVRG P Service rig. Lubricate draw works, top drive. 05:15 05:30 0 25 0 0 INTRM1 WELLPF PULD P Finish picking up drll pipe. 107 stands total stood back in the derrick. 05:30 06:45 1.25 0 0 INTRM1 WHDBO BOPE P PJSM. Pick up 5"test joint. Make up cross over for blanking plug Run in hole and turn XO into position for BOPE test FMC rep. on location. Page 21 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06 45 12:00 5.25 0 0 INTRM1 WHDBO BOPE P PJSM. Full BOPE test. 5"test joint. Test annular ram to 250 psi/3500 psi Test Upper 3'/2'x 6"variable pipe rams, HCR choke and kill valves, choke manifold valves 1 to 16, FOSV, 5"dart valve,4" Demco, all to 250 PSI/4000 PSI 5 mins each, charted. Chuck Scheve AOGCC waived witness of test. Gas alarms tested. 12 00 12 15 0.25 0 0 INTRMI WHDBO SFTY P Prejob safety meeting in dog house. Testing BOPE. 12 15 16 30 4.25 0 0 INTRM1 WHDBO BOPE P Test BOPE Test manual kill and choke, lower 3%"x 6"pipe rams, blind rams with 5"test joint, all tests to 250 psi low 4000 psi high, 5 mins. ea,charted. Pull 5"TJ,set 3W TJ W/FMC Rep. Test Lower 3'/2'x 6" pipe rams, upper 3'W x 6"pipe rams,to 250 psi low,4000 psi high, 5 mins ea.,charted.Test annular preventer to 250 psi low, 3500 psi high, 5 mins, charted. Perform Conoco accumulator test,36 secs recovery 200 psi,235 secs to 3000 psi,electric pump test 66 secs to 3000 psi, air pump 70 secs to 2500 psi Both tests w/accumulator isolated Flush poor boy degasser Test super choke and manual choke to 1100 psi 16:30 17:00 0 50 0 0 INTRM1 WHDBO BOPE P FMC pulled blanking plug, back pressure valve, lay down 3W test joint. 17.00 19.00 2.00 0 0 INTRM1 WHDBO BOPE P Test Auto IBOP, 250 psi low 4000 psi high, 5 mins charted Unable to get a manual IBOP test Trouble shoot. 19:00 19:15 0.25 0 0 INTRM1 WHDBO BOPE P PJSM Discuss changing out the lower IBOP. Mechanic,AD,floor hands 19 15 22 00 2 75 0 0 INTRM1 WHDBO RGRP P Change out lower IBOP. Test to 250 psi/4000 psi, 5 mins ea charted. Re-install clamps Change out leaking wash pipe/swivel packing. 2200 2230 0 50 0 0 INTRMI WELLPF PULL P Change out elevators to 4'/2', pick up landing joint"B" 22 30 22 45 0.25 0 0 INTRM1 WELLPF SFTY P PJSM on backing out lock down studs, pull hanger. 22:45 2345 1.00 1,789 1,786 INTRM1 WELLPF PULL P Pull hanger to rig floor. Pulled with 85k. Lay down hanger and pup joint. Change out elevators to 3'/" . 23:45 00:00 0.25 1,786 1,723 INTRM1 WELLPF PULL P Lay down two joints of kill string. 3'/" EUE 9.3#L-80. Page 22 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/07/2013 24 hr Summary Lay down 3%"EUE Kill String. 56 joints Install wear bushing. Complete rigging up Baker MWD sensors and calibrate. Pick up Baker BHA#8 Rotary Steerable system,Weatherford expandable reamer. Surface test all tools. Single in the hole 51 joints.Wash down to 200 feet from the float collar.CBU. Slip and cut 45'of DL. Wash down to 3015'top of float collar. 00:00 02:30 2.50 1,723 0 INTRM1 WELLPF PULL P Continue to pull out of the hole with the 3%' EUE 9.3#L-80 kill string. Lay down 56 joints total. Calc fill=5.5 BBLS.Actual fill=5.5 BBLS 02.30 03 00 0.50 0 0 INTRM1 WELLPF RURD P PJSM Rig down and lay down tubing equipment. 03:00 03:45 0.75 0 0 INTRM1 WELLPF RURD P Pick up BHA components up beaver slide, lay down tools,clear and clean rig floor for BHA pick up. 03:45 04:15 0.50 0 0 INTRM1 WELLPF RURD P FMC install 12 3/8" ID wear bushing. 04.15 04 45 0.50 0 0 INTRM1 WELLPF RURD P Cont PU&LD tools/equipment-CO elevators f/3 1/2"tbg to 5"DP- Clean&clear rig floor 04:45 05:45 1 00 0 0 INTRMI WELLPF OTHR P PJSM-RU bypass actuator/install Baker transducer line to stand pipe 05:45 06:00 0.25 0 0 INTRM1 DRILL SFTY P PJSM on MU BHA 06:00 07:30 1.50 0 66 INTRM1 DRILL PULD P MU BHA#8-bit( 10 5/8"PDC) - ATK steerable sub-Flex sub w/stab -NM XO sub-ON Trak(MWD) CoPilot-MWD stab-BCPM-NM Stop sub-to 66' 07:30 08.30 1.00 66 66 INTRM1 DRILL OTHR P Plug into MWD 08:30 09:00 0 50 66 66 INTRM1 DRILL OTHR P Calibrate block height(BakerINTEQ) 09:00 09:45 0.75 66 135 INTRM1 DRILL PULD P Cont. MU BHA#8-float sub-filter sub-Compresive DP(Baker INTEQ) -XO-Rhino reamer to 135' 09:45 10:30 0.75 135 135 INTRM1 DRILL OTHR P PJSM on testing Rhino reamer-MU XO 6 5/8"H-90 x 4 1/2"IF-RIH w/ DP to 225'-Pump @ 600 gpm @ 760 psi w/reamer closed&pulse test MWD-Drop 4 open RFID chips to activate reamer-pump @ 600 gpm @ 560 psi to verify reamer opened-Dropped 4 closing RFID chips-pumped @ 600 gpm @ 760 psi-PU&So on drill string to verfiy reamer closed-POOH to 135& visually inspect reamer-Test Good 10:30 10:45 0 25 135 135 INTRM1 DRILL OTHR P Blow down TD 1045 13:45 3.00 135 1,156 INTRM1 DRILL PULD P Cont. MU BHA#8- 1 (8"DC)Ghost reamer-2(8"DC's)-jars-29 jts 5" HWDP-to 1156' 13:45 14:45 1.00 1,156 1,156 INTRM1 DRILL PRTS P Test surface lines, swivel packing, Bypass actuator to 3500 psi-Circ @ 600 gpm @ 1330 psi to pulse test MWD 14:45 15:00 0.25 1,156 1,163 INTRMI DRILL PULD P Blow down TD-PU Ghost reamer# 2 to 1163' Page 23 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:45 1 75 1,163 2,761 INTRM1 DRILL TRIP P RIH f/1163'to 2761'-picking up 51 jts. 5"DP f/pipe shed Held Kick while tripping drill 16.45 18 15 1.50 2,761 2,950 INTRMI DRILL WASH P Wash down f/2761'to 2950'@ 600 gpm @ 1330 psi w/70 rpm's. CBU. 18 15 18 30 0.25 2,950 2,950 INTRM1 DRILL OWFF P Observe well. Static. Blow down top drive 18:30 18:45 0.25 2,950 2,950 INTRM1 DRILL SFTY P Pre job on slipping and cutting drill line. 18:45 21:45 3.00 2,950 2,950 INTRM1 DRILL SLPC P Slip and cut 45'of drill line. Service top drive. Calibrate Baker Kelly height and hook load sensors. 21:45 00 00 2 25 2,950 3,015 INTRMI DRILL REAM P Continue to wash down from 2950'to 3015'MD.Tag top of float collar @ 3015'.650 GPM/1440 PSI/70 RPM 05/08/2013 Drill out shoe track, rat hole, and 20 feet of new hole. 10.625"hole size. Change over mud systems whileV D� drilling out. From 9 8 ppg brine to 9.6 ppg LSND. Perform LOT. 16.3 ppgjeak off achieved. Directional drill from 3143'to 3515'. Pick up EMS tool.(calculates downhole torque). Perform tests with top drive and drill 30 feet for data acquisition. Lay down NOV/EMS tool. Directional drill 10.625"hole from 3515'to 4453'. Pumping weighted sweeps every third stand, monitoring ECD's and cuttings load. 00.00 02.15 2.25 3,015 3,123 INTRM1 DRILL REAM P Cont.to drill out shoe track f/3015'- drill shoe @ 3105 top to 3107' MD. Clean out rat hole to 3123'@ 650 GPM, 1060 PSI. Displace well from 9.8 ppg brine to 9 7 ppg LSND while drilling shoe track, SIMOPS: Crane lift Sperry MWD building, and Sperry tool box off pit roof. Job complete by 01 00 hrs. 02:15 02 45 0.50 3,123 3,143 INTRM1 DRILL DDRL P Drill 20 feet of new hole. 3123'to 3143'.675 GPM, 1170 PSI, 80 RPM, 10k WOB, 14k TO on. PU=175k, SO=116k, Rot=140k.ADT=.4 hrs. 02:45 03:15 0.50 3,143 3,143 INTRM1 DRILL CIRC P Circulate and condition the mud system for LOT.675 GPM, 1170 PSI,80 RPM, 14k TQ off. 03:15 03:45 0 50 3,143 3,143 INTRMI DRILL OWFF P Observe well. Static. Blow down top drive. 03:45 04:15 0.50 3,143 3,143 INTRM1 DRILL LOT P Rig up and perform LOT to 16.3 PPG EMW.w/805psi w/9.7ppgmud wt @ 2341'TVD-Pumped in 2.4 bbls- bleed back 2.0 bbls 04.15 04:30 0.25 3,143 3,143 INTRM1 DRILL RURD P Rig down hard line on rig floor Blow down kill line. 04:30 04:45 0.25 3,143 3,143 INTRM1 DRILL TRIP P Trip in from 3082'to 3143'. Change out leaking air hose on top drive grab head actuator. Page 24 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment ✓ 04:45 10:00 5.25 3,143 3,515 INTRM1 DRILL DDRL P Directional Drill 10.625"hole w/ Baker Autotrack f/3143'to 3515'MD ECD10.25 ppg Footage-372' WOB 13/15 k RPM 80/130 GPM 650/825 @ 1440 to 1600 psi String wt PU 172 SO 125 ROT 145 Torque on/off btm.- 14/12 k ft/lbs 10:00 10 15 0.25 3,515 3,515 INTRM1 DRILL OTHR P PJSM-MU NOV EMS tool w/5"pup its(36 11')Obtain TD torque @ 10 5 k-20 k-25 k-29 k-hold torque for 30 secs @ each point for base line data for EMS tool 10:15 10:45 0.50 3,515 3,546 INTRMI DRILL DDRL P Drilled 10 5/8"hole f/3515'to 3546' MD-w/EMS tool to obtain drilling torque data 700 gpm @ 1460 psi-130 rpm's- Torque 12.5 to 13 k on btm torque/ 12 k torque off btm BROOH f/3546'to 3515'@ 700 gpm @ 1460 psi w/130 rpm @ 12 k torque w/NOV EMS tool-LD EMS tool-RIH to f/3515'to 3546' ✓ 10:45 12:00 1.25 3,546 3,610 INTRM1 DRILL DDRL P Drilled 10 5/8"hole w/Baker RSS f/ 3546'to 3610' MD-2586'TVD ADT-4.8 hrs((total drilling time last 12 hrs) ECD-10.22 ppg Footage- 31' WOB 10/15 k RPM 130 GPM 700 @ 1400 psi String wt. PU 172 SO 125 ROT 145 Torque on/off btm.-13/12 k ft/lbs 1200 00:00 12.00 3,610 4,453 INTRMI DRILL DDRL P Drilled 10 5/8"hole w/Baker RSS f/ 3610'to 4453' MD. 2994'TVD ADT=8.6 hrs. ECD=10.58 ppg Footage-843' WOB 12/20k RPM 120/140 GPM 825 @ 2350 psi String wt. P/U 169 5/0 132 ROT 147 Torque on/off btm.- 13/12k ft/lbs. Pump 4 weighted sweeps.3337'. 250%increase in cuttings load. 3614'. 250%increase in cuttings. 37 BBLS early. 3910'. 200%increase in cuttings 40 BBLS early 4200'. 200%increase in cuttings 20 BBLS early. All sweeps 35 BBLS and 2 lbs over. Page 25 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/09/2013 24 hr summary Drilled 10 5/8"hole w/Baker RSS f/4453'to 5495'MD. Pick up NOV/EMW tool,drill to 5531'MD. Lay down tool and download torque data. Drill from 5531'to 6156'MD. Open Weatherford rip tide reamer. Begin drilling 10 5/8"X 113/4'hole.6038'MD=depth of beginning of 11%"hole. Drill 10 5/8"X 11%"hole from 6156'to 6200' MD 150 RPM 900 GPM 3300 PSI. 00:00 12:00 12 00 4,453 5,400 INTRM1 DRILL DDRL P Drilled 10 5/8"hole w/Baker RSS f/ 4453'to 5400'MD. 3471'TVD ADT=7.8 hrs ECD=10.7 ppg Footage-947' WOB 15/20k RPM 150 GPM 900 @ 3200 psi String wt. P/U 184 S/O 143 ROT 157 Torque on/off btm -14.5/12 5k ft/lbs. 4480'.200%increase in cuttings load.On time. 35 BBL 4750'.200%increase in cuttings. On time. 35 BBL 5036'. 100%increase in cuttings On time. 35 BBL 5235'. 100%increase in cuttings On time.60 BBL All sweeps 2 lbs over. 12:00 12:30 0.50 5,400 5,495 INTRM1 DRILL DDRL P Drilled 10 5/8"hole w/Baker RSS f/ 5400'to 5495'MD. ADT=.5 hrs. ECD=10 7 ppg Footage -95' WOB 15/20k RPM 150 GPM 900 @ 3200 psi String wt. P/U 184 S/O 143 ROT 157 Torque on/off btm.- 14.5/12.5k ft/lbs 12.30 13 30 1.00 5,495 5,531 INTRM1 DRILL DDRL P PJSM. Pick up NOV EMS tool. Drill one single. From 5495'to 5531'. Lay down EMS tool. ADT=.25 hrs. Page 26 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 22.30 9 00 5,531 6,156 INTRM1 DRILL DDRL P Drilled 10 5/8"hole w/Baker RSS f/ 5531'to 6156'MD. 3844'TVD ADT=5.75 hrs. ECD=10.56 ppg Footage-625' WOB 15/20k RPM 150 GPM 900 @ 3450 psi String wt P/U 184 5/0 143 ROT 157 Torque on/off btm.- 14.5/12.5k ft/lbs. 5532'. 100%increase in cuttings load.On time.60 BBL Weighted sw. 5933'. 100%increase in cuttings. On time. 35 BBL 6080'. 100%increase in cuttings On time. 35 BBL.Hi-Vis sw. 6080'. 100%increase in cuttings On time. 60 BBL All sweeps 2 lbs over, The 35 BBL Hi-Vis pill followed by the 60 BBL weighted sweep were pumped prior to opening the"rip tide reamer". 22:30 23:30 1.00 6,156 6,156 INTRM1 DRILL PULD P Record torque and drag numbers. Establish pump pressure with drilling rate. Shut down,drop RFID chips. Pump down with full rate to 800 strokes, slow down to 2.4 BPM to 1100 strokes Bring pumps back to full rate, and begin rotating @ 30 rpm.Wait 5 mins. ICP=3370 psi. FCP=2740 psi 630 psi pressure loss. Shut down rotary and pumps and set 25k down to verify tool was opened.Tool was activated. Ream to bottom. RE-shoot MWD survey. Start of 113/4"hole @ 6038'MD 23:30 00:00 0.50 6,156 6,200 INTRM1 DRILL DDRL P Drilled 10 5/8"x 113/,"hole from J 6156'to 6200' 3866 TVD. ADT=.5hrs ECD=10.40ppg Footage-44' WOB 22k RPM 150 GPM 900 @ 2760 psi String wt. P/U 187 S/O 152 ROT 165 Torque on/off - 14/12k ft/lbs. 05/10/2013 Drilled 10 5/8"x 11 3/4"hole f/6200'to 7931'MD. 1731' in 18 9 bit hours.Ave Rop=92'/hr. Pump six,60 BBL weighted sweeps with 4 ppb nut plug every 3 stands for hole cleaning.Whole mud dilutions of 275 BBLS @ 6980', 7392', and 7790'MD to maintain MBT below 20 Page 27 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00 00 12:00 12.00 6,200 7,095 INTRM1 DRILL DDRL P Drilled 10 5/8"hole w/Baker RSS f/ 6,200'to 7,095'MD,4,312'TVD ADT=9.3 hrs. ECD=10.35 ppg Footage-895' WOB 18/20k RPM 150 GPM 900 @ 2,650 psi String wt. P/U 205 S/O 157 ROT 174 Torque on/off btm -19/15k ft/lbs. 3 sweeps pumped: 6345'.200%increase in cuttings load.On time. 35 BBL 6635'.200%increase in cuttings. On time.60 BBL 6912'. 100%increase in cuttings On time. 35 BBL All sweeps 2 lbs over. 12:00 00:00 12.00 7,095 7,931 INTRM1 DRILL DDRL P Drilled 10 5/8"hole w/Baker RSS f/ 7095 to 7931 ' MD.4725'TVD ADT=9.7 hrs. ECD=10.25 ppg Footage-836' WOB 18/24k RPM 150 GPM 900 @ 2680 psi String wt P/U 207 S/O 165 ROT 180 Torque on/off btm.- 19/13k ft/lbs. 3 sweeps 1st&3rd 2 lbs.over. 2nd 3Ibs.over. 7200'. 100%increase in cuttings load.10 BBLS early.60 BBL 7488'.200%increase in cuttings. On time.60 BBL. 3 lbs over 7755.200%increase in cuttings On time.60 BBL Negligible increase in cuttings load with 3#over sweep. 05/11/2013 Drilled 10 5/8"x 11 3/4"hole f/7931'to 9404' MD. 1473'in 19.2 bit hours.Ave Rop=77'/hr. Pump five,60 BBL weighted sweeps with 4 ppb nut plug every 3 stands for hole cleaning.The last two sweeps were 3lbs over the mud weight of 9 6 ppg Whole mud dilutions of 275 BBLS @ 7392', 7790', 8438, and 8795'MD to maintain MBT below 20. Page 28 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 1200 12.00 7,931 8,656 INTRM1 DRILL DDRL P Drilled 10 5/8"x 11 3/4"hole w/ ✓ Baker RSS&Rip Tide UR f/7931'to 8656'MD 5085'TVD ADT-9.3 hrs ECD-10.53 ppg Footage-725' WOB 25/27 k RPM 150 GPM 900 @ 2660 psi String wt. PU 219 SO 170 ROT 187 Torque on/off btm.-19.5/13 k ft/lbs. 3 sweeps pumped. 8040'. 125%increase in cuttings.On time 60 BBL 8321'. 125%increase in cuttings. On time 60 BBL 8620'. 50%increase in cuttings. On Time.60 BBL ' 12 00 00.00 12 00 8,656 9,404 INTRM1 DRILL DDRL P Drilled 10 5/8"x 11 3/4"hole w/ Baker RSS&Rip Tide UR f/8656'to 9404'MD 5454'TVD ADT-9.9 hrs ECD-10.33 ppg Footage-748' WOB 25/27 k RPM 150 GPM 900 @ 2660 psi String wt. PU 230 SO 170 ROT 195 Torque on/off btm.-22/15 k ft/lbs 2 sweeps pumped. 8887'. 150%increase in cuttings.On time.60 BBL 9170'. 50%increase in cuttings. On time.60 BBL Both of these sweeps were 3 lbs over. 05/12/2013 Drilled 10 5/8"x 11 3/4"hole f/9404'to 10766'MD.1362'in 18.1 bit hours.Ave Rop=75'/hr. Pump five,60 BBL weighted Hi-Vis sweeps with 4 ppb nut plug every 3 stands for hole cleaning.All sweeps were 3lbs over the mud weight of 9.6 ppg.Whole mud dilutions of 275 BBLS @ 9542', 10045', and 10490'MD to maintain MBT below 20. Page 29 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 0000 12:00 12 00 9,404 10,045 INTRM1 DRILL DDRL P Drilled 10 5/8"x 11 3/4"hole w/ Baker RSS&Rip Tide UR f/9,404'to 10,045' MD 5,770'TVD ADT-9 2 hrs. ECD- 10 25 ppg Footage-641' WOB 25k RPM 150 GPM 900 @ 2,500 psi String wt PU 245 SO 180 ROT 199 Torque on/off btm.-21/15.5k ft-lbs. 2 sweeps pumped: 9455' 100%increase in cuttings.On time 9830'. 100%increase in cuttings. 30 BBLS late. Sweeps are 3 lbs over, Hi-Vis.60 BBLS each. 12 00 00:00 12 00 10,045 10,766 INTRM1 DRILL DDRL P Drilled 10 5/8"x 11 3/4"hole w/ Baker RSS&Rip Tide UR f/10,045' to 10766' MD 6124'TVD ADT-8.9 hrs. ECD-10.25 ppg Footage-721' WOB 25k RPM 150 GPM 900 @ 2,650 psi String wt PU 255 SO 180 ROT 208 Torque on/off btm.-23/18k ft-lbs. 2 sweeps pumped. 10,124'.50%increase in cuttings.60 BBLS late. 10,488'. 100%increase in cuttings. 60 BBLS late Sweeps are 3 lbs over, Hi-Vis.60 BBLS each. 05/13/2013 Drilled 10 5/8"x 11 3/4"hole f/10,766'to 11758'MD. 12.5 bit hrs 992' 79'/hr rop average Weight up mud system to 10.1+ppg from 9 8 ppg Perform quadrant reaming of last 135 of hole with Baker Rotary Steerable system. Page 30 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 10,766 11,474 INTRMI DRILL DDRL P Drilled 10 5/8"x 11 3/4"hole w/ Baker RSS&Rip Tide UR f/10766' to 11,474'MD 6474'TVD ADT-9.3 hrs. ECD-10.44 ppg Footage-708' WOB 27k RPM 150 GPM 900 @ 3060 psi String wt. PU 270 SO 185 ROT 210 Torque on/off btm.-26/19k ft-lbs 3 sweeps pumped: 10,770'. 50%increase in cuttings.60 BBLS late 11,056'.25%increase in cuttings 70 BBLS late 11,335'. No increase in cuttings load. 80 BBLS late. Sweeps are 3 lbs over, Hi-Vis.60 BBLS each. 12 00 16:30 4.50 11,474 11,758 INTRM1 DRILL DDRL P Drilled 10 5/8"x 11 3/4"hole w/ Baker RSS&Rip Tide UR f/11,474' to 11,758'MD 6615'TVD ADT-3.3 hrs. ECD-10 44 ppg Footage-284' WOB 27k RPM 150 GPM 900 @ 3060 psi String wt. PU 270 SO 185 ROT 210 Torque on/off btm.-26/19k ft-lbs. 16 30 17:30 1.00 11,758 11,758 INTRM1 DRILL CIRC P Circulate and condition mud system on bottom Rotate and reciprocate drill string. 920 GPM. 3140 PSI. 150 RPM.24.5k TQ. 17:30 18 00 0.50 11,758 11,758 INTRM1 CASING OWFF P Observe well for flow. Bubbles breaking out. No flow.Annulus dropping 18 00 19.15 1.25 11,758 11,758 INTRM1 CASING CIRC P Circulate bottoms up.920 GPM. 3180 PSI 150 RPM. 24.5 TQ. Flow line fluctuation on bottoms up from 39%up to 42%. MW out on balance scale=8 9 ppg. Pressuer balance=9 8 ppg. 19.15 19:30 0.25 11,758 11,758 INTRM1 CASING OWFF P Observe well.Well oozing with no tapering off. Did not go static. SIMOPS change out rodwash hose on#2 MP. Decide to weight up system to 10+ppg from 9.8 ppg. 19:30 21:15 1.75 11,758 11,758 INTRMI CASING CIRC P Circulate,weight up system fr 9.8 ppg to 10.0 ppg 920 GPM, 3150=ICP, 3200=FCP 150 RPM.TQ off 22.5 to 24.0 ppg 21:15 21:30 0.25 11,758 11,758 INTRM1 CASING OWFF P Observe well for flow.Well became static in 10 mins. 21:30 21:45 0.25 11,758 11,706 INTRM1 CASING REAM P Back ream up to top of stand Rack stand back. Prepare to quadrant ream with Baker Rotary Steerable system. Page 31 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 11,706 11,612 INTRM1 CASING REAM P Quadrant ream from 11,612 to 11,706'. 920 GPM. 150 RPM 3280 PSI.23 to 25k TQ.Weight up trip margin to 10 1+. 05/14/2013 Cont. Quadrant ream-FLow Ck-Pump sweep&circ 4 X btms up-flow ck 30 mins(observed well bubbling after 28 mins. no gain static losses)Close Rip Tide reamer-RIH f/11,329'to 11,706'-Wash down to 11,758' (TD)-Circ&wt. up to 10.4 ppg, OWFF well static slight loss, Circ&Cond, POOH f/11758't/6906'observe tight spot @ 8231', Circ&condition hole pump hi vis weighted sweep 100%cuttings increase when sweep returned. 00.00 01:00 1.00 11,758 11,706 INTRM1 CASING CIRC P Cont.to quadrant ream f/11,758'to 11,706'@ 920 gpm @ 3430 psi w/ 130 rpm's w/24 k torque-stand back 1 std to 11,706' 01:00 01:45 0.75 11,706 11,706 INTRM1 CASING OWFF P Blow down TD-observed well-slow drop in 30 mins. (observed some bubbling) 01:45 05:45 4.00 11,706 11,329 INTRM1 CASING CIRC P Pumped 60 bbls 12.6 ppg hi-vis sweepwhile pumping 4 X btms up @ 900 gpm @ 3420 psi w/130 rpm w/ 26 k torque-Slight packing off f/ 11,395'to 11,365'-Backed pumps to 800 gpm @ 2980 psi-stood back 1 std every 30 mins to 11,329' 05:45 06:30 0.75 11,329 11,329 INTRM1 CASING OWFF P Blow down TD- Observed well-fluid level dropped 3'-after 25 mins,well began to bubble 06:30 07:00 0.50 11,329 11,329 INTRM1 CASING CIRC P Attempt to close Rip Tide reamer- dropped 7 RFID chips-pumped down @ 800 gpm @ 2860 psi w/50 rpm @ 21 k torque-slowed pump to 100 gpm @ 230 psi while chips pas reamer-work string w/pump off- Bring pumps back to 800 gpm @ 2850 psi-observed no pressure increase-indicate reamer closed 07:00 08:00 1.00 11,329 11,329 INTRMI CASING CIRC P Attempt to closeRip Tide reamer-6 RFID chips-&pump down @ 800 gpm @ 2860 psi-slow rate to 100 gpm while chips passed by reamer- Work string w/no pup-Brought puup back up to 800 gpm @ 2980 psi(120 psi increase-not sure reamer is closed)Blow down TD 08:00 08:15 0.25 11,329 11,706 INTRM1 CASING TRIP T RIH w/11,329'to 11,706' 08:15 11:00 2.75 11,706 11,758 INTRM1 CASING CIRC T Wash down f/11,706'to 11,758'- Circ&condition @ 800 gpm @ 3160 psi-wt up f/10.2 ppg to 10.4 ppg 11:00 11:30 0.50 11,758 11,758 INTRMI CASING OWFF T Blow down TD-Observe well for 35 mins.-fluid level dropping 2-3 ft- Observed well bubbling after 25 mins. -fluid level continued to drop 11:30 13:00 1.50 11,758 11,612 INTRM1 CASING CIRC P Circ btms up @ 11,758'@ 800 gpm @ 3060 psi w/150 rpm's w/27 k torque-Stood back 2 stds to 11,612' 13 00 13 30 0.50 11,612 11,612 INTRMI CASING OWFF P Blow down TD-Observed well for 15 mins-fluid level dropping Page 32 of 87 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 13:30 21:30 8 00 11,612 6,906 INTRM1 CASING TRIP IP POOH on elevators f/11,612'to 6906'tight spot observed @ 8231' 21:30 0000 2 50 6,906 6,906 INTRM1 CASING CIRC P Circ&Condition hole w/650 gpm 1960 psi, Pump hi vis weighted sweep observe 100%cuttings increase @ surface. 05/15/2013 Spot LCM Pill f/6812 t/6530' POOH f/6530't/5527'take weight, circ bottoms up, POOH f/5527't/4230' take weight, Circ. Bottoms up x 2 Increase in cuttings on bottoms up, POOH f/4230't/3044'OWFF f/30 min 6'drop in stack, Circ BTMs up POOH t/233' L/D BHA, C/O Upper rams t/9 5/8"solid body rams 00:00 00:15 0.25 6,906 6,812 INTRM1 CASING OWFF P Stand back stand U 6812'Observe well for flow well static slight loss 00:15 01:00 0.75 6,812 6,530 INTRM1 CASING CIRC P Spot LCM pill f/6812'U 6530'3 bpm 250 psi 01.00 02 45 1.75 6,530 5,527 INTRM1 CASING TRIP P POOH f/6530'U 5527'take weight 02.45 0315 0.50 5,527 5,527 INTRMI CASING OTHR P Work tight spot@ 5527'up U 75k over pull no movement,Attempt U rotate through w/30 rpm stalling top drive. 03:15 04:00 0 75 5,527 5,527 INTRMI CASING CIRC P Circ bottoms up @ 700 gpm 2100 psi 100 rpm cuttings increase @ bottoms up by 50%able to move throught tight spot freely, no over pull. 04:00 07:00 3.00 5,527 4,230 INTRM1 CASING TRIP P POOH f/5527'U 4230'-(tight spot) PUwt170 SOwt125 07:00 08:00 1 00 4,230 4,170 INTRM1 CASING CIRC P Wash&reem f/4230'to 4170'@ 800 gpm @ 2450 psi-120 rpm w/14 k torque-Circ 2 x btms up- Observed good amount of cuttings @ btms up-Flow ck-slight drop-Drop 2 7"drift 08 00 09.45 1.75 4,170 3,044 INTRM1 CASING TRIP P Cont. POOH on TT f/4170'to 3044'- PU wt 155 SO wt 125-Observed sligh over pull w/under reamer coming into 11 3/4'csg 09:45 10:15 0 50 3,044 3,044 INTRM1 CASING OWFF P Observed well for 30 mins.-fluid level dropped 6'-Observed very little bubbling 10:15 11:30 1.25 3,044 3,044 INTRM1 CASING CIRC P Circ&cond. @ shoe-pumped 40 bbls 12.6 ppg hi-vis sweep&35 bbls bit balling sweep @ 800 gpm @ 2340 psi w/120 rpm @ 12 k torque- Observed sweep come back @ shakers mostly the nut plug w/some cuttings 11:30 14:15 2.75 3,044 1,163 INTRM1 CASING TRIP P Cont.to POOH on TT f/3044'to 1163'-Functioned lower pipe rams- LD ghost reamer 14 15 14 45 0.50 1,163 1,163 INTRM1 CASING OWFF P Observe well for flow well static dropped 6'in stack in 30 min 14:45 1630 1.75 1,163 233 INTRM1 CASING TRIP P POOH f/1163'U 233' 1630 20:30 4.00 233 0 INTRMI CASING PULD P L/D BHA as per DD Down load MWD,clear floor, UD BHA 20:30 21:30 1.00 0 0 INTRM1 CASING OTHR P Clean&clear rig floor, drain stack, R/U U fill stack while changing rams Page 33 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21.30 21.45 0.25 0 0 INTRMI CASING SFTY P Pre Job Safety Meeting on Changing Rams. 21 45 23.30 1.75 0 0 INTRM1 CASING OTHR P C/O top pipe rams t/9 5/8"solid body rams. 23.30 00.00 0.50 0 0 INTRM1 CASING OTHR P Pull wear bushing set test plug 05/16/2013 Test Upper 9 5/8" rams t/250/4000 test ann.t/250 3000 R/U&Run 9 5/8 casing as per detail,t/3012' Circ casing vol stage pumps t/252 gpm 360 psi, Continue RIH w/Casing t/4596' (Wash through tight spot @ 3391') 00:00 01:00 1.00 0 0 INTRM1 CASING BOPE P Test top 9 5/8"rams t/250 low 4000 high f/5 min,test annular t/250 low 3000 high f/5 min. 01:00 01:30 0 50 0 0 INTRM1 CASING OTHR P Pull test plug&install wear ring 01:30 01:45 0.25 0 0 INTRM1 CASING OTHR P Install mouse hole 01 45 02 00 0 25 0 0 INTRM1 CASING SFTY P Pre Job Safety Meeting on R/U t/ Run 9 5/8"casing 02 00 04 00 2.00 0 0 INTRMI CASING RURD P R/U t/Run casing w/volant CRT 04.00 04.30 0.50 0 0 INTRM1 CASING SFTY P Pre Job Safety Meeting on running casing w/volant CRT. 04:30 12:00 7.50 0 1,488 INTRM1 CASING RNCS P Run 9 5/8"40#L-80 Hydril 521 liner as follows: Float shoe(composite) 1jt liner-float_ collar(Weatherford Mod.4020) 1�t liner---Landing-collar (Baker Type 1)2 its liner to 170'(4 jts total in hole) (all connections made up w/BakerLoc-Filled pipe& checked floats)Installed Weatherford bow spring centralizers w/stop rings on 1st 3 jts.& 1 Weatherford slip on bow spring centralizer on jt.#4- Cont to RIH w/liner f/170'to 1488' (35 jts total in hole)Installed Weatherford slip on bow spring centralizers as per program 12:00 17:30 5.50 1,488 3,012 INTRM1 CASING RNCS P Run 9 5/8"40# L-80 Hydril 521 liner f/1488't/3012'(71 jts total in hole) 1730 1830 1 00 3,012 3,012 INTRM1 CASING CIRC P Circ casing vol stage pumps t/252 gpm 360 psi 18 30 00 00 5 50 3,012 4,596 INTRM1 CASING RNCS P Continue RIH w/9 5/8"40#L-80 Hydril 521 liner f/3012't/4596'( wash&work through tight spot @ 3391'w/3 bpm 350 psi 160 PUW 108 SOW)-(108 jts total in hole) 05/17/2013 Cont. RIH w/9 5/8" Liner f/4596't/8897', Static test, R.D csaing running equip. P/U Liner Hanger RIH on DP f/8897't/9177'Stage Pumps t/250 gprn 370 psi. 00:00 02:45 2.75 4,596 5,530 INTRMI CASING RNCS P Cont. RIH w/9 5/8"40#L-80 Hydril 521 liner f/4596'to 5530'( 130 jts total in hole) PU wt 227 SO wt 120 -Worked thru tight spot @ 4660'w/ pump @ 1.2 bbls/min @ 260 PSI 02:45 04:00 1.25 5,530 5,530 INTRM1 CASING CIRC P Establish circ-stage pump up to 6 bbl/min @ 470 psi-circ btms up 04:00 11:00 7 00 5,530 7,961 INTRM1 CASING RNCS P Cont. RIH w/9 5/8"40#L-80 Hydril 521 liner f/5530'to 7961'(188 jts total in hole)SO wt 145 Page 34 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 7,961 7,961 INTRM1 CASING CIRC P Establish circ-stage pump up to 6 bbls/min @ 450psi-circ 2+btms up -Broke over @ 320 k 12.00 13:00 1.00 7,961 7,961 INTRM1 CASING CIRC P Continue Circ. &Cond. mud Stage pumps t/250 gpm 530 psi 13:00 16:00 3.00 7,961 8,773 INTRMI CASING RNCS P Run 9 5/8"casing f/7961't/8773' 164-SOW 16.00 19:00 3.00 8,773 8,773 INTRM1 CASING CIRC P Circ. &Cond. Mud stage pumps t/ 250 gpm 370 psi(Pull 425 t/break over. ) 19:00 1930 0.50 8,773 8,773 INTRM1 CASING OWFF P Static check well f/20 min PUW- 305 SOW-178 19.30 20:15 0.75 8,773 8,897 INTRM1 CASING RURD P R/D Casing running equip. R/U& P/U liner hanger, M/U stand of HWDP RIH t/8897'. 2015 22:00 1.75 8,897 8,897 INTRM1 CASING CIRC P Circ&Cond mud while clearing floor of csaing running equipment, Reciprocate pipe&pump 170 gpm 350 psi. 22:00 23:00 1.00 8,897 9,177 INTRM1 CASING RUNL P RIH w/9 5/8 liner on DP f/8897't/ 9177 35/18/2013 Contuinue RIH w/9 5/8"liner on 5" DP f/9177't/11753'Circ&Cond.f/CMT job, Perform CMT job, CIP 1623 ✓ hrs, Presure test liner top t/1000 Psi, CBU, Mudpush returns&contaminated ud on bottoms up. R/D cmt equip. POOH w/liner running tool, L/D Tool, P/U Baker Packer RIH t/1047' 00:00 04:00 4.00 9,177 10,950 INTRM1 CASING RUNL P Cont. RIH w/9.5/8"liner on 5"DP f/ 9177'to 10,950'-fill pipe every 5 1./ stds(string started taking wt)SO wt 160 04:00 06 00 2 00 10,950 10,950 INTRM1 CASING CIRC P Circ&cond. stage pump to 3.5 bbls/min @ 560 psi-brk over @ 400 k-PU wt 360 SO wt 160 -pumped 300 bbls 06:00 07:30 1.50 10,950 11,753 INTRM1 CASING RUNL P Cont. RIH w/9 5/8"liner on 5"Dp f/ 10,950'to 11,753'(PU 5,16'pupjts & 1 single DP)So wt 160-Liner @ setting depth 07:30 08:00 0.50 11,753 11,753 INTRM1 CEMEN-RURD P Blow down TD-RU BAker cement head 08:00 12:00 4.00 11,753 11,753 INTRM1 CEMEN'CIRC P Circ &Cond. Mud f/cement job, stage pumps t/250 gpm 510 psi. 12:00 12:15 0.25 11,753 11,753 INTRM1 CEMEN-SFTY P Pre Job safety meeting on cement job. 12.15 17:00 4.75 11,753 11,753 INTRM1 CEMEN'CMNT P Dowell pressure test lines t/4000 psi,dowell pump 40 bbls CW100,48 bbls 11 ppg mudpush spacer, 219 bbls 12.2 ppg lead cement w/ cemnet in first 75 bbls, 166 bbls of 15.8 tail cement, Drop plug, 10 bbls water,682 bbls of mud t/bump plug P/U plug @ 30.7 bbls pumped, CIP 1623 hrs, pressure up t/3500 psi, bleed off release f/liner hanger and set liner top paker as per BOT. 17:00 17:15 0.25 11,753 11,753 INTRM1 CEMEN PRTS P Close annular&pump down kill line &test liner top packer t/1000 psi f/ 10 min Page 35 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:15 1.00 11,753 2,904 INTRMI CEMEN-CIRC P Pressure up on DP t/500 psi pull out of liner top 39'CBU @ 335 gpm 460 psi, 1600 stks into bottoms up mudpush and contamintaed mud to surface. No cement returns observed. 18.15 19:00 0.75 2,904 2,904 INTRM1 CEMEN'RURD P B/D lines, R/D cement head, R/U t/ _ POOH 19:00 21:15 2.25 2,904 66 INTRMI CEMEN'TRIP P POOH f/2904't/66 w/liner running tool on 5"DP 21:15 22 15 1 00 66 0 INTRMI CEMEN-PULD P Make service breaks&L/D liner running tool. 22.15 22 45 0.50 0 15 INTRMI CEMEN-PULD P M/U Retrievable Packer as per BOT 22 45 00.00 1.25 15 1,047 INTRM1 CEMEN-TRIPP RIH w/Packer f/15't/1047' 05/19/2013 RIH f/1047't/2927', Displace DP t/Diesel Perform Negative test on Liner top packer, Slip&cut drill line, POOH w/Packer L/D, Stand back 23 stands of 4", UD 8 Stands of 5"HWDP, Change Rams on upper& lower cavities, R/U&test BOPE's 00:00 01:00 1.00 1,047 2,927 INTRMI CEMEN-TRIPP RIH w/packer f/1047't/2927' 01:00 02:00 1.00 2,927 2,927 INTRM1 CEMEN-CIRC P Circ. Bottoms up @ 4 BPM 150 psi 02 00 02 30 0.50 2,927 2,927 INTRM1 CEMEN PACK P Set Baker Packer, Blow Down Top Drive& R/U t/Displace 02 30 02 45 0.25 2,927 2,927 INTRM1 CEMEN SFTY P Pre Job Safety Meeting on Displacing well. 02 45 03:30 0.75 2,927 2,927 INTRMI CEMEN-CIRC P Dowell pressure test lines t/900 psi, Displace drill string w/52 bbls diesel, close bypass shut in, Blow down Dowell. 03:30 04'45 1 25 2,927 2,927 INTRM1 CEMEN-PRTS P Bleed pressure off DP t/0 psi observe f/30 min pressure increased t/50 psi in 30 min. Bleed off pressure t/0 psi, observe f/30 min Pressure increased t/30 psi in 30 min. 04 45 05.30 0.75 2,927 2,927 INTRMI CEMEN CIRC P Reverse Circ.diesel t/tiger tank, R/D circ. equip. OWFF static. 05 30 06:00 0.50 2,927 2,927 INTRMI CEMEN-OTHR P Move 5" DP stands in derrick to accomodate 4"DP 06:00 07:45 1.75 2,927 0 INTRM1 CEMEN-TRIPP POOH w/test packer UD 07:45 09:30 1 75 0 0 INTRMI CEMEN'SLPC P Slip&cut drilling line 60'Adjust brakes&rollers service TD 09:30 12 30 3 00 0 0 INTRMI CEMEN-PULD P P/U 4" DP stand back in derrick 23 stands 12:30 13 15 0.75 0 0 INTRM1 CEMEN'OTHR P C/O Iron Roughneck dies&Elevators C/O baker actuator 1315 14:30 1.25 0 0 INTRMI CEMEN PULD P Lay down 8 stands of 5" HWDP from derrick. 1430 15 00 0.50 0 0 INTRMI CEMEN-OTHR P L/D Mouse hole&drain stack 1500 18:30 3.50 0 0 INTRMI CEMEN'OTHR P Change top rams t/4 5"x 7"variable and lower rams t/2.875"x 5" _ variable. Install mouse hole. 18:30 19:00 0.50 0 0 INTRM1 CEMEN'OTHR P M/U running tool&pull wear ring, M/U and set upper test plug. Page 36 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:15 1.25 0 0 INTRM1 CEMEN-BOPE P R/U t/test BOPE,fill lines and stack with water. 20:15 00 00 3.75 0 0 INTRM1 CEMEN BOPE P Test BOPE,Annular t/250/3000 f/5 min, choke valves 1-16, HCR&Man. choke&kill,Auto&Man !BOP, TIW &DART,4"demco,Test t/250/4000 psi w/5"test jt.AOGCC waived witness of test as per Jeff Jones. Test All Rig Gas Alarms) 05/20/2013 Continue testing BOPE, M/U clean out BHA, RIH t/10140'Circ. &Cond. Mud every 20 stands& Installing WWT super sliders every jt. (Cement Contaminated Mud returns when CBU) 00:00 05:00 5.00 0 0 INTRMI CEMEN BOPE P Continue testing BOPE Koomey Test 200psi in 40 sec. 3000 psi in 205 sec, Test Annular t/250/3000 psi f/5 min&lower VBR's t/ 250/4000 f/5 min w/2 875 test jt, test annular 250/3000&Lower VBR's t/250/4000 f/5 min w/4"test jt,Test annular t/250/3000&Upper VBR's t/250/4000 f/5 min w/7"test jt, Test blinds t/250/4000 f/5 min Test Super Choke and Man. choke on manifold. 05:00 05:30 0.50 0 0 INTRM1 CEMENT OTHR P Pull test plug&install wear ring. 05:30 06:15 0.75 0 0 INTRM1 CEMEN OTHR P Blow Down choke manifold&lines, P/U BHA components, C/O Roughneck dies. 06:15 07:15 1.00 0 261 INTRMI CEMENT PULD P P/U Clean out BHA t/261' 07:15 12 00 4.75 261 4,871 INTRM1 CEMEN-TRIP P RIH w/clean out Assy. f/261't/ 4871' 170 PUW-112-SOW 12 00 13:15 1.25 4,871 4,871 INTRM1 CEMEN CIRC P Fill pipe Circ &Condition Mud Stage Pumps t/250 gpm 240 psi. 13:15 1430 1.25 4,871 5,810 INTRMI CEMENT TRIP P Continue RIH f/4871't/5810'Install WWT Super Sliders every jt. 14:30 15:45 1.25 5,810 5,810 INTRM1 CEMEN-CIRCP Fill Pipe Circ. &Condition Mud Stage pumps t/295 gpm 400 psi 15:45 17:15 1.50 5,810 7,129 INTRM1 CEMEN-TRIPP Continue RIH f/5810't/7129'Install WWT Super Sliders every Jt 17:15 18:30 1.25 7,129 7,129 INTRMI CEMENT CIRC P Fill Pipe Circ &Condition Mus Stage pumps t/335 gpm 510 psi 18:30 20:30 2.00 7,129 9,009 INTRMI CEMEN TRIP P Continue RIH f/7129't/9009' Instal WWT Super SLiders every jt. Stand #93 install 2 per jt. 2030 22 00 1.50 9,009 9,009 INTRM1 CEMEN CIRC P Fill pipe Circ. &Condition mud Stage pumps t/420 gpm 890 psi 22.00 00:00 2.00 9,009 10,140 INTRM1 CEMEN TRIP P Continue RIH f/9009't/10140' Installing 2 WWT super sliders every jt. 05/21/2013 Continue RIH f/10140't/11459'Circ&Cond Mud f/casing test, R/U&perform casing test U 3500 psi f/30 min._good test, Repair shock hose on mud line,Wash&Ream U TOC @ 11633' Drill CMT, LC, FC U 11750' Drilling on Float collar. 00:00 02:15 2.25 10,140 11,459 INTRMI CEMEN-TRIPP Continue RIH f/10140'U 11459' Installing Super slider 2 per jt. 02 15 03:30 1.25 11,459 11,459 INTRM1 CEMENT CIRC P Circ. &Cond. Mud f/casing test 600 gpm 1900 psi FCP 1630 Page 37 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:15 1.75 11,459 11,459 INTRM1 CEMEN-PRTS P R/U perform csaing test to 3500 psi f/30 min. (good test)Blow down Lines R/D 05:15 05:45 0.50 11,459 11,459 INTRM1 CEMEN-SVRG P Service Rig 05:45 17:45 12.00 11,459 11,459 INTRM1 CEMEN-RGRP T Repair shock hose in mezzanine, replace union on hose,welder had to cut union off t/remove,dress threads install new union. 17:45 18 00 0.25 11,459 11,459 INTRM1 CEMEN-PRTS P Pressure test mud line t/4200 psi good test 18 00 18:45 0.75 11,459 11,633 INTRM1 CEMEN-WASH P Wash in the hole f/11459't/11633' 600 gpm 1840 psi TOC @ 11633' 18:45 19:00 0.25 11,633 11,663 INTRM1 CEMEN COCF P Clean out cement f/11633't/11663' 19:00 22:00 3.00 11,663 11,742 INTRM2 CEMEN DRLG P Drill shoe track f/11663't/11702' 600 gpm 1740 psi 100 rpm 21.5 k torque 12-20 WOB(LC @ 11663'FC @ 11704') 22:00 22.15 0 25 11,742 11,742 INTRM2 CEMEN-DRLG P P/U EMS tool obtain torque readings. 22:15 00:00 1.75 11,742 11,750 INTRM2 CEMEN-DRLG P Continue drilling shoe track f/11742' t/11750'600 gpm 1710 psi 100 rpm 21.5 torque 1-8 WOB. (FS @ 11750' 35/22/2013 Drill float collar, rathole,20' new hole,displace to 9.6 ppg Glydril mud,observe well ooze, peform LOT to 17.0 + '� ppg,drill from 11778'to 11827', seen gas cut mud 300 bbls prior to bottoms up,wt up to 9.8 ppg,flow check slight ooze,wt up to 10.0 ppg,slight ooze on flow check weight up t/10.4ppg,well static slight drop, POOH f/11831't/6093' Drop 2 69"OD rabbit @ 11742' 00:00 01:15 1.25 11,750 11,758 INTRM2 CEMEN'DRLG P Drill shoe, rathole with EMS tool f/ 11750'to 11758'at 600 gpm, 1720 psi, 120 rpm,24K tq 01:15 03:00 1.75 11,758 11,778 INTRM2 DRILL DRLG P Drill 8-1/2"new hole from 11758'to 11778' MD, 6625'TVD.ADT-1.3 hrs 03:00 03:30 0 50 11,778 11,778 INTRM2 DRILL DRLG P Obtain EMS torque data off btm, brk dwn and LD EMS tool. PU single, 280K up, 160K dwn. 03:30 05:30 2 00 11,778 11,778 INTRM2 DRILL CIRC P Displace well from 10.1 ppg to 9.6 ppg Glydril @ 420 gpm, 820 psi 05:30 06:00 0.50 11,778 11,778 INTRM2 DRILL OWFF P Observe well, seeing constant trickle 06:00 07:45 1.75 11,778 11,778 INTRM2 DRILL FIT P RU and perform 17 0 ppg EMW LOT using Dowell with 9.6 ppg mud,2553 psi and 6613'TVD, blow down and rig down 07:45 0930 1 75 11,778 11,831 INTRM2 DRILL DRLG P DriII 8-1/2"hole from 11778'to 11831' MD, 6650'TVD, (seen gas cut mud while drilling 300 bbls prior to bottoms up from prey flow check,gas cut down to 8.5 ppg at the most) begin weighting up to 9 8 ppg. 1.3 hrs ADT 09:30 10:45 1.25 11,831 11,831 INTRM2 DRILL CIRC P Weight up from 9.6 to 9.8 ppg.600 gpm, 1390 psi, 80 rpm, 15K TQ 10:45 11:00 0.25 11,831 11,831 INTRM2 DRILL CIRC P Observe well,slight ooze Page 38 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11 00 13 00 2.00 11,831 11,831 INTRM2 DRILL CIRC T Weight up from 9.8 ppg to 10.0 ppg, seen gas cut mud to 9.4 ppg 30 bbls before bottoms up from flow check 13:00 13:45 0.75 11,831 11,831 INTRM2 DRILL OWFF T Observe well to very very slight ooze 13:45 15:45 2.00 11,831 11,831 INTRM2 DRILL CIRC T Weight up to 10.4 ppg @425 gpm 880 psi 600 gpm 1530 psi 60 rpm 13k tq 15:45 16:15 0 50 11,831 11,831 INTRM2 DRILL OWFF P Flow check well static slight drop in 30 min. 16:15 16:30 0.25 11,831 11,742 INTRM2 DRILL TRIP P POOH w/pumps f/11831't/11742' 16:30 17.00 0.50 11,742 11,742 INTRM2 DRILL OTHR P Blow down top drive drop 2 69" rabbit, rabbit 2 stands in derrick w/ 2.85"rabbit 17.00 19.00 2.00 11,742 10,328 INTRM2 DRILL TRIP P POOH f/11742't/10328'on trip tank 19:00 19:30 0.50 10,328 10,328 INTRM2 DRILL CIRC P Pump 31 bbl 11.9 ppg dry job 19:30 00:00 4.50 10,328 6,093 INTRM2 DRILL TRIP P POOH f/10328't/6093'on trip tank hole tanking proper fill 05/23/2013 POOH, add additional WWT super sliders to 14 more stands,observe well static, PU/MU and test well commander, LD, LD 8.5"clean out BHA, Clean clear floor, PU and pre assemble Baker 6"drilling assy and test, Stand Back&L/D 6""Assy. R/U&RIH w/7"Casing/Liner t/78', rolled sealing face on collar change out collar and work on tesco CRT. 00:00 06 30 6 50 6,093 445 INTRM2 DRILL TRIP P POOH on trip tank f/6093'to 445', applied WWT Super Sliders to 14 more stands 06:30 06:45 0.25 445 445 INTRM2 DRILL OWFF P Observe well static 06:45 08:00 1.25 445 445 INTRM2 DRILL PULD P MU Well Commander, RIH one stand, Circ at 600 gpm, 580 psi, drop 2.115"ball, open circ sub with 1480 psi,600 gpm, 20 psi,drop 2 115' ball,close circ sub with 1540 psi, 600 gpm, 580 psi, rack stand, LD and remove balls 08 00 09.00 1.00 445 74 INTRM2 DRILL PULD P LD 2 stands 5"dp, HWDP and jars to 74' 09.00 10:15 1.25 74 0 INTRM2 DRILL PULD P LD remaining clean-out assy, Mill, HWDP,XO, DC, NB stab, bit 10:15 12:00 1.75 0 0 INTRM2 DRILL OTHR P Clear floor, PU BHA equipment to floor 12:00 14 45 2.75 0 141 INTRM2 DRILL PULD P PJSM, MU SLD BHA(inner string) as follows:6"bit-4 3/4"GT steering head-Mod Stab-On Trak-CoPilot- Mod stab-reamer drive sub-4 3/4" X-Treme/Mod-BCPM-Top stop -Plug in&check tools and program- MU Smart battery w/XO-Float sub- Filter sub-XO-Plug in&check tools 14:45 15:45 1.00 141 141 INTRM2 DRILL PULD P Plug in program MWD 15:45 16:30 0.75 141 158 INTRM2 DRILL PULD P Continue t/M/U BHA as per Baker 16:30 17:30 1.00 158 158 INTRM2 DRILL PULD P Plug In& Load MWD 17:30 18:00 0 50 158 158 INTRM2 DRILL PULD P Shallow Pulse test MWD @ 300 gpm 1300 psi. Page 39 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18 00 18 45 0.75 158 90 INTRM2 DRILL PULD P L/D thruster, flt sub,filter sub& BCPM/Batt. 18:45 19:00 0.25 90 0 INTRM2 DRILL PULD P Drain Motor,Stand back Bit&Mtr Assy. in derrick 19 00 19 30 0 50 0 0 INTRM2 DRILL PULD P C/O eleveators&P/U&M/U Back Up Steering head&Bit. 19:30 20:00 0.50 0 0 INTRM2 DRILL OTHR P Clean&Clear Rig Floor, B/U Equip. F/Liner Run. 20.00 21:15 1.25 0 0 INTRM2 DRILL RURD P P/U tools&R/U Tesco CRT 21:15 21:30 0.25 0 0 INTRM2 DRILL SFTY P Pre Job Safety meeting on Running 7"Liner 21:30 22:30 1.00 0 78 INTRM2 DRILL RNCS P Run 7"Casing w/tesco tool 22 30 00 00 1.50 78 78 INTRM2 DRILL RNCS T C/O Collar&work on Tesco grapples 05/24/2013 Continue RIH w/7" Liner t/2040' R/D tesco CRT, R/U fasle table, P/U Inner String BHA&RIH w/4" DP, M/U Baker HRT tool&flow diverter, EMS&well commander, RIH on 5" DP t/3192'test flow diverter, Continue RIH f/3192't/3948' 00:00 04:45 4.75 78 2,040 INTRM2 DRILL RNCS P Continue RIH w/7" Liner f/78't/ 2040' 04:45 05:45 1 00 2,040 2,040 INTRM2 DRILL PULD P R/D Tesco CRT, remove f/rig floor. 05.45 08.30 2 75 2,040 2,040 INTRM2 DRILL RURD P R/U t/run inner string, Install working table, R/U false table, P/U Slips& Bowl, R/U Bales&Elevators, 08.30 10.15 1.75 2,040 2,040 INTRM2 DRILL PULD P Run Inner String BHA t/132' 10:15 10:30 0.25 2,040 2,040 INTRM2 DRILL OTHR P Plug in t/MWD Battery 10:30 12:00 1.50 2,040 2,040 INTRM2 DRILL PULD P Continue RIH w/Inner string t/158' 12:00 13:30 1.50 2,040 2,040 INTRM2 DRILL TRIP P RIH w/4"DP Inner String t/253' 1330 14 15 0.75 2,040 2,040 INTRM2 DRILL SFTY P Kick While Tripping Drill w/Long Kick Stand 35 min.to well shut in& post drill discussion. 14 15 17:15 3.00 2,040 2,097 INTRM2 DRILL TRIP P Continue t/RIH w/4"DP t/2097' P/U single f/shed, Space out. 17:15 17:45 0.50 2,097 2,097 INTRM2 DRILL PULD P P/U&M/U Baker HRD tool t/4" Inner String 17:45 18:45 1.00 2,097 2,097 INTRM2 DRILL RURD P R/D false table&C-plate,working platform&M/U Quick Connect, clean&clear rig floor, C/O Iron Roughneck dies, P/U tools t/Rig Floor. 18:45 19:30 0 75 2,097 2,097 INTRM2 DRILL PULD P M/U flow diverter&well commander, P/U EMS sub, PUW- 145 SOW- 138 19.30 20.15 0.75 2,097 2,097 INTRM2 DRILL OTHR P Plug into flow diverter and turn on. 20 15 22:00 1.75 2,097 3,099 INTRM2 DRILL TRIP P RIH f/2097't/3099' 22:00 23:00 1.00 3,099 3,099 INTRM2 DRILL CIRC P Test tools and function flow diverter All Operational. 23:00 00:00 1.00 3,099 3,948 INTRM2 DRILL TRIP P Continue RIH f/3099't/3948' 05/25/2013 Continue RIH w/SDL Assy.f/3948't/11806'Send DownLink to SDL Unable to communicate w/tools,Trouble shoot MWD, CBU, M/U Secondary BHA&stand back in derrick while waiting on drive sub to disengage, POOH w/pumps @ 84 gpm 420 psi f/11756't/10343' Page 40 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12 00 12 00 3,099 11,568 INTRM2 DRILL TRIP P Continue RIH f/3948't/11568'filling pipe every 20 stands. 12:00 14:15 2.25 11,568 11,806 INTRM2 DRILL TRIP P Continue RIH w/SDL Assy. f/11568' t/11806'(Observe 10k on bit& reamer shoe when passed shoe @ 11753' PUW-290 SOW- 180 14:15 16:15 2.00 11,806 11,806 INTRM2 DRILL OTHR T Send down link t/SDL shut off pumps f/15 min cycle pumps 286 gpm 1960 psi, unable to communicate w/MWD tools, Trouble shoot MWD. 16:15 17:30 1.25 11,806 11,806 INTRM2 DRILL CIRC T Open Flow Diverter 600 gpm 2610 psi 500 gpm 1940 psi Circulate bottoms up. 17:30 18.00 0.50 11,806 11,806 INTRM2 DRILL OWFF T Observe well for flow, slight flow slowing down. 1800 18:30 0 50 11,806 11,756 INTRM2 DRILL TRIP T POOH w/pumps 48 gpm 320 psi f/ 11806't/11756' 18:30 18:45 0.25 11,756 11,756 INTRM2 DRILL OTHR T B/D Top Drive&Monitor well on trip tank 18:45 21:00 2.25 11,756 11,756 INTRM2 DRILL PULD T While waiting 1.5 hrs f/RDS t/ disengage, P/U and stand back secondary Inner string BHA. Test tool string-4 3/4"GT steering head, Mod Stab, One trak, Copilot, Mod stab, reamer drive sub,4 3/4" Xtreme/Brass upset. 21:00 21:15 0.25 11,756 11,756 INTRM2 DRILL OTHR T C/O elevators, R/U t/POOH w/ Pumps 21:15 00 00 2 75 11,756 10,343 INTRM2 DRILL TRIP T POOH w/pumps @ 84 gpm 420 psi f/11756't/10343'at 1500'/hr pulling speed 05/26/2013 Continue POOH w/pumps f/10343't/6582', OWFF well static, POOH f/6582't/2249'w/pumps, OWFF well static, slip&cut 65 of drilling line, R/U working platform,c-plate, double stack tongs, Break HRD tool, flowing f/inner ann, M/U HRD tool, OWFF slight ooze, CBU,OWFF slight flow slowing f/1 34 BPH t/.11 BPH in 2 hrs,Observe flow increase, M/U BHA RIH f/2160't/2628' 00:00 05:15 5.25 10,343 6,582 INTRM2 DRILL TRIP T Continue POOH w/pumps @ 84 gpm 400 psi f/10343't/6582'at 1500'/hr pulling speed 05:15 05:30 0.25 6,582 6,582 INTRM2 DRILL OWFF T Observe well for flow well static. 05 30 12:00 6 50 6,582 2,249 INTRM2 DRILL TRIP T POOH w/pumps @ 84 gpm 250 psi f/6582't/2249' 12 00 1215 0 25 2,249 2,249 INTRM2 DRILL OTHR T Blow down top drive. 12 15 1245 0 50 2,249 2,249 INTRM2 DRILL OWFF T Observe well for flow well static. 12.45 13:45 1.00 2,249 2,249 INTRM2 DRILL SLPC P Slip&cut drill line 65' 13:45 1415 0 50 2,249 2,249 INTRM2 DRILL SVRG P Service Rig 14:15 14:45 0.50 2,249 2,160 INTRM2 DRILL TRIP T POOH f/2249't/2160'on trip tank 14:45 15:15 0.50 2,160 2,160 INTRM2 DRILL OTHR T Plug into flow diverter. 15:15 15:30 0.25 2,160 2,160 INTRM2 DRILL SFTY T Pre Job Safety Meeting on L/D BHA 15:30 17:00 1.50 2,160 2,160 INTRM2 DRILL RURD T Bring tools t/rig floor, R/U platform, double stack tongs,working plate, false table. Page 41 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 2,160 2,160 INTRM2 DRILL OWFF T Break quick connect under HRD, well flowing f/inner annulus, appears mud may be out of balance,turn off hole fill and monitor well. .5 bbl gain while monitoring on trip tank Cannot monitor all three flow paths visualy with false table rigged up 17:30 17:45 0.25 2,160 2,160 INTRM2 DRILL RURD T M/U quick connect under HRD running tool to eliminate one flow path, R/D false table,c plate, working platform. 17:45 18:45 1.00 2,160 2,160 INTRM2 DRILL OWFF T Flow check well slight flow slowing, mud out of balance. 18:45 19:30 0.75 2,160 2,160 INTRM2 DRILL CIRC T Circ. Bottoms Up even out MW Observed some10.6 ppg coming back. Circ to even 10 4 ppg MW 19:30 22:00 2.50 2,160 2,160 INTRM2 DRILL OWFF T Flow ck well slight flow well slowing f/1.34 bph t/.11 bph in 2 hrs then observe well visualy increase flow rate down flow line. Decision made to RIH 22:00 22:30 0.50 2,160 2,160 INTRM2 DRILL RURD T Tighten HRD, remove TIW&lift sub, M/U well commander&flow diverter, Plug into and turn on flow diverter. 22 30 00:00 1.50 2,160 2,628 INTRM2'DRILL TRIP T RIH w/SDL Assy. f/2160't/2628' 05/27/2013 Continue RIH w/SDL Assy.f/2628't/5639'CBU 600 gpm 2020 psi, no gas observed @ BU, Cont. RIH t/ 9215' CBU 600 gpm 2350 psi, Observed gas cut mud @ 2300 stks &4%LEL on handheld in th possum belly, RIH t/11756'wash t/11831'CBU x 2 @ 600 gpm 2720 psi, observed gas cut mud, OWFF, wt up t/ 10.7ppg, flow check well f/2 hrs static slight loss, CBU, No gas observed @ Bottoms up, POOH w/pumps f/ 11831't/10720' 00:00 02:30 2.50 2,628 5,639 INTRM2 DRILL TRIP T RIH w/SDL assy on 5"DP f/2628'to 5639'at 2000'/hr running speed 02:30 03:15 0.75 5,639 5,639 INTRM2 DRILL CIRC T Circulate 72 bbls at 300 gpm, 1760 psi,open flow diverter, pump 600 gpm,2020 psi to get bottoms up. No gas observed. 03 15 03 30 0.25 5,639 5,639 INTRM2 DRILL OWFF T Observe well static immediately, slight drop 03 30 07:00 3.50 5,639 9,215 INTRM2 DRILL TRIP T RIH w/SDL assy on 5"DP f/5639'to 9215'at 2000'/hr running speed 07.00 08:15 1.25 9,215 9,215 INTRM2 DRILL CIRC T Circulate 94 bbls at 300 gpm, 1950 psi,open flow diverter, pump 600 gpm,2350 psi to get bottoms up. Gas first observed 296 bbls before bottoms up. Max gas cut by 1.1+ ppg 196 bbls before bottoms up,4% LEL on handheld gas detector max at 123 bbls before BU and Totco GasWatch max at 250 units, dropped to normal 35 bbls after BU 08.15 11:15 3 00 9,215 11,756 INTRM2 DRILL TRIP T RIH w/SDL assy on 5"DP f/9215'to 11756'at 2000'/hr max, pilot assy bit 3'below 9-5/8"shoe.Calc total disp =80.38 bbls,Act total disp=70 8 bbls Page 42 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 11:30 0.25 11,756 11,831 INTRM2 DRILL WASH T Wash down f/11756'to 11831'at 84 gpm, 550 psi,tag bottom 11:30 11:45 0.25 11,831 11,756 INTRM2 DRILL CIRC T Stage pump rate up to 300 gpm, 2140 psi, PU to 11756'position TJ/Sliders, install TIW 11:45 13:15 1 50 11,756 11,756 INTRM2 DRILL CIRC T Circulate, open flow diverter and circ 600 gpm,2720 psi, initial ECD 11.75,final ECD 11.66, no losses. Gas first observed 90 bbls before bottoms up. Max gas cut by.65 ppg 128 bbls before bottoms up(Heaviest also at 10.9 on pressure balance, 10.2+on mud balance), also max of 3%LEL on handheld gas detector and Totco GasWatch max at 235 units, dropped to normal 131 bbls after BU. 13:15 14:00 0.75 11,756 11,805 INTRM2 DRILL CIRC T Position 8.5"reamer shoe below liner shoe, Observe well 10 min, slight ooze, Circ and send downlinks to engage RDS 14:00 14:15 0.25 11,805 11,805 INTRM2 DRILL OWFF T Observe well static while wait for RDS to engage 14:15 17:30 3.25 11,805 11,805 INTRM2 DRILL CIRC T Circ, confirm RDS engaged,Wt up t/10.7 ppg 300-600 gpm 2000-2740 psi 17:30 18:15 0.75 11,805 11,805 INTRM2 DRILL OTHR T Trouble shoot MWD, Obtain SPR's 18:15 18:30 0 25 11,805 11,756 INTRM2 DRILL TRIP T Stand back stand f/11805't/11756' 18:30 20:30 2 00 11,756 11,753 INTRM2 DRILL OWFF T Observe well for flow f/2 hours slight static drop in stack of 2'. 20:30 20:45 0.25 11,753 11,831 INTRM2 DRILL TRIP T RIH f/10756't/11831' 20:45 22:00 1.25 11,831 11,831 INTRM2 DRILL CIRC T Circ. Surface to surface 600 gpm 2760 psi, No gas observed @ bottoms up. 22:00 00:00 2.00 11,831 10,720 INTRM2 DRILL TRIP T POOH w/pumps 126 gpm 680 psi f/ 11831't/10720' 05/28/2013 Continue POOH w/pumps f/10720't/2249' MD. Observe well. Static. Stand back one stand 5"DP.Allow well to U-tube 10.1 PPG mud inside inner annulus to 10.7 PPG mud in outer annulus. Observe well. Static. Trip out 20 stands of 4"DP, inner string,to BHA 158' .7"casing shoe @ 2099'. 00:00 06:00 6.00 10,720 6,582 INTRM2 DRILL TRIP T Continue POOH w/pumps 126 gpm 550 psi f/10720't/6582'MD 06:00 06:15 0.25 6,582 6,582 INTRM2 DRILL OWFF T Observe well bore. Static Dropped slightly 06:15 12:00 5.75 6,582 2,628 INTRM2 DRILL TRIP T Continue POOH w/pumps 126 gpm 550 psi f/6582't/2628'MD. 12:00 13:00 1.00 2,628 2,249 INTRM2 DRILL TRIP T Continue POOH w/pumps 126 gpm 440 psi f/2628't/2249'MD. 13.00 14:00 1 00 2,249 2,249 INTRM2 DRILL TRIP T Observe well bore Static Dropped slightly. 14:00 1500 1.00 2,249 2,160 INTRM2 DRILL PULD T Stand back one stand of 5"DP. 2160' MD. Lay down NOV/EMS tool, Well Commander, Flow Diverter 15:00 15:15 0.25 2,160 2,099 INTRM2 DRILL PULD T Pull HRD and break quick connect. 7"casing now at surface in bowl. Page 43 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:30 1 25 2,099 2,099 INTRM2 DRILL OWFF T Monitor well @ 2099'MD.Allow inner annulus to U-tube. 10 1 ppg mud moving from 7"x 4"annulus Rig up platform, C-Plate&false table to stand back 4"DP. Stopped U-tubing 1630 16 45 0.25 2,099 2,099 INTRM2 DRILL PULD T Lay down HRD and rig up double stack tongs. 16 45 23 15 6 50 2,099 158 INTRM2 DRILL TRIP T Lay down 4"DP single from inner string. Stand back 20 stands 4"DP. Calc displacement=12.4 BBLS. Actual displacement= 11.2 BBLS 23:15 23:45 0.50 158 158 INTRM2 DRILL OWFF T Observe well. Monitor well on hole fill pit No loss, no gain for 30 mins. 23:45 00:00 0.25 158 158 INTRM2 DRILL PULD T Pick up Kick stand from skate,and break off bottom cross over.4"XT 39. 05/29/2013 Lay down BHA#10. Baker SDL SureTrak. Unable to determine cause of tool failure on rig floor. Pick up BHA#11. Baker SDL SureTrak.TIH.Test MWD system. Good Fill pipe every 20 stands. TIH to bottom. 00:00 00 30 0 50 158 132 INTRM2 DRILL PULD T PJSM. Continue to lay down inner string. BHA#10. From 158'to 132'. Plug into MWD system, smart battery. 00:30 01:00 0.50 132 42 INTRM2 DRILL PULD T Lay down inner string from 132'to 42' Plug into Co-Pilot 01:00 01:15 0.25 42 101 INTRM2 DRILL PULD T Run in the hole to 101', break out and lay down smart battery 01:15 02:00 0.75 101 33 INTRM2 DRILL PULD T Pull out to 33'of inner string. Plug into On Track port 02:00 03:30 1.50 33 0 INTRM2 DRILL PULD T Lay down inner string. BHA#10.As per Baker DD/MWD Unable to determine cause of failure on rig floor. 03:30 05.00 1.50 0 0 INTRM2 DRILL CIRC T OOH W/inner string Circulating through 7"casing @ 2099' MD Pump 10 BPM, 100 PSI,270 BBLS. 10.7 PPG MW in and out. 05 00 06 00 1.00 0 101 INTRM2 DRILL PULD T PJSM. C/O elevators from 5"to 4". Make up BHA#11 06.00 0615 0.25 101 101 INTRM2 DRILL PULD T Plug into MWD and up load for bit run. 06:15 07:00 0.75 101 253 INTRM2 DRILL TRIP T Trip in the hole with BHA#11. From 101'to 253' MD. Inner string. 07:00 07:15 0.25 253 253 INTRM2 DRILL PULD T Make up 4"XT 39 XO to bottom of Long Kick Stand.Well control device. 07:15 09:30 2.25 253 1,927 INTRM2 DRILL TRIP T Continue to trip in with inner string. 0930 09:45 0.25 1,927 1,927 INTRM2 DRILL RURD T Space out and land out motor splines into reamer shoe,to confirm measurements. 09:45 10.00 0.25 1,927 1,938 INTRM2 DRILL TRIP T Trip in the hole from 1927 to 1938'. Change out 4" DP to 5"DP elevators. 102k up, 95k down 10:00 10 30 0.50 1,938 1,938 INTRM2 DRILL PULD T Make up HRD tool. Page 44 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10.30 11:00 0.50 1,938 1,938 INTRM2 DRILL RURD T Rig down false bowl, rotary table, C-Plate,double stack tongs,stage. Change out iron roughneck heads from 4"to 5". 11:00 11:30 0.50 1,938 2,160 INTRM2 DRILL TRIP T Trip in the hole from 1938'to 2160' MD. Make up flow diverter, stab,well commander, NOV/EMS tool 11:30 12:00 0.50 2,160 2,249 INTRM2 DRILL TRIP T Trip in the hole from 2160'to 2249' MD. 12 00 13 00 1 00 2,249 3,099 INTRM2 DRILL TRIP T Trip in the hole from 2249'to 3099' MD 13:00 13 30 0.50 3,099 3,099 INTRM2 DRILL CIRC T Test MWD system 300 GPM 1670 PSI.600 GPM 2000 PSI. Good test. 13:30 21:15 7.75 3,099 10,626 INTRM2 DRILL TRIP T Trip in the hole from derrick with 5" DP. From 3099 to 10,626'MD. Fill pipe every 20 stands. Perform MWD test @ 8746'. Good. Function pipe rams. Observe well,went static in 5 mins after circulating 21:15 22'30 1.25 10,626 10,626 INTRM2 DRILL CIRC T Circulate bottoms up @ 600 GPM. 2710 PSI. No gas on BU. 22:30 00:00 1.50 10,626 11,663 INTRM2 DRILL TRIP T Trip in the hole to 11,663'MD. Calc. Disp=81.6.Actual Disp=78.5 BBLS. 35/30/2013 Wash down to TD Relog last 100'W/MWD tools. Perform SPR's Pump out 2 stands Observe well Static Set storm packer. Bi-weekly BOPE test conducted. Test with 4 test joints. 7", 5",4",2 7/8".AOGCC Inspector Lou Grimaldi witnessed the test. SIMOPS. Begin replacing purge system in dog house&replace 4" valve on kill side 00.00 01:00 1.00 11,663 11,831 INTRM2 DRILL WASH T Wash down from 11,663'to TD @ 11,831"MD.Tag bottom Obtain new SPR's 01:00 01:30 0 50 11,831 11,663 INTRM2 DRILL CIRC T Pump out 2 stands. From 11,831'to 11,663' MD. 300 GPM 2080 PSI Calc fill=1.576 BBLS.Actual fill=3 BBLS. 01 30 02 00 0.50 11,663 11,663 INTRM2 DRILL OWFF T Observe well bore. Static. Slight drop. 02:00 03:30 1.50 11,663 11,663 INTRM2 DRILL SLPC P PJSM. Slip and cut 60'of DRLG line. Service top drive, iron roughneck, draw works. 03:30 04:00 0.50 11,663 11,727 INTRM2 DRILL PACK P PJSM Pick up and make up Baker storm packer RIH to 11727' MD. Element 71 62'in,Top pup joint 60' down from rig floor. 04:00 04 15 0.25 11,727 11,727 INTRM2 DRILL PACK P Set storm packer. 04'15 0430 0.25 11,727 11,727 INTRM2 DRILL PRTS P Test storm packer to 200 psi, 5 mins. Charted. 04:30 05:30 1.00 11,727 11,727 INTRM2 DRILL BOPE P Drain stack, blow down kill line, retrieve FMC wear ring. 12 375"ID. 05:30 06:45 1.25 11,727 11,727 INTRM2 DRILL BOPE P PJSM Pick up 5"test joint and upper plug. Fill stack with water,fill kill line, choke line. Rig up FOSV, dart valve. rig up to test BOPE. SIMOPS. Begin changing out 4" Demco kill valve on mezzanine& prep work to install new purge system in dog house Page 45 of 87 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:45 12 00 5 25 11,727 11,727 INTRM2 DRILL BOPE P Test BOPE with 5"TJ.Test annular preventer to 250/3500 PSI .5 mins each test. Charted.Test UPR's (4'/2'x7"variables),Choke manifold valves 1 through 16,the 5"FOSV, 5" dart valve,250 low 4000 PSI high,5 mins each test Charted. Test LPR's (2 7/8"x5"variables), blind rams, HCR choke, HCR kill, manual choke, manual kill. 250 PSI low,4000 PSI high,each test 5 mins, charted. Test witnessed by AOGCC Inspector Lou Grimaldi.All gas alarms tested. 12.00 16:30 4.50 11,727 11,727 INTRM2 DRILL BOPE P Perform accumulator closing test. Attain 200 PSI in 36 secs after closing Attain full 3000 PSI in 218 secs.4 bottles of nitrogen @ 1800 PSI. Perform super choke and manual choke draw down test to 1200 PSI Test with 7"TJ.Annular preventer to 250 PSI low/3500 PSI high, 5 mins each,charted.Test UPR's,4'/2'x7"VBR's,250 PSI low, 4000 PSI high, 5 mins each, charted. Test with 4"TJ.Annular preventer to 250 PSI low/3500 PSI high, 5 mins each, charted.. Test LPR's 2 7/8"x 5". 250 PSI low/4000 PSI high, 5 mins each,charted Test 4"FOSV, 4"dart valve to 250/4000.All tests for 5 minutes,and recorded on chart recorder.AOGCC Inspector Lou Grimaldi witnessed the Bi-weekly test. SIMOPS: Changing out 4" Demco valve on kill, and replace purge system in doghouse 16:30 17:00 0.50 11,727 11,727 INTRM2 DRILL BOPE P Remove 2 7/8"test joint Install 5" test joint. 17:00 00:00 7.00 11,727 11,727 INTRM2 DRILL RGRP T Replace 4"Demco valve on kill line. SIMOPS: Review CPAI policy's on KWDD, KWTD, Kick while out of the hole, Kick with wireline in the hole. General house keeping. 35/31/2013 Continue to weld on 4"Demco valve kill side on mezzanine level. Remove and replace top jaw on iron roughneck.Test new 4"Demco valve. Body test to 5000 PSI. Good BOPE test of Demco valve,250 PSI low/ 4000 PSI high 5 mins each, charted. Complete Bi-weekly BOPE test. Retrieve storm packer Well bore static. Begin drilling 6"x 8'W hole with Baker SureTrak SDL system. Drill from 11,831'to 11,975'MD. 00:00 06:00 6.00 11,727 11,727 INTRM2 DRILL RGRP T Continue weld-Replace 4"Demco valve on kill line. 06:00 07:00 1.00 11,727 11,727 INTRM2 DRILL RGRP T Wait for 4"Demco valve body to cool, assemble valve ---SIMOPS, change out Iron roughneck upper jaw 07.00 08:00 1.00 11,727 11,727 INTRM2 DRILL RGRP T PJSM-Flood and flush mud line, test 4"Demco kill line valve body/welds to 250/5000 psi for 5 minutes ok Page 46 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 11,727 11,727 INTRM2 DRILL BOPE P Close and test 4"Demco kill line valve against 5"Test Jt, UPR, HCR Choke to 250/4000 psi for 5 mins 08:30 09:45 1.25 11,727 11,727 INTRM2 DRILL RURD P Flush kill line with mud, RD test equip, LD test Jt,test plug. Blow down lines 09:45 10:15 0.50 11,727 11,727 INTRM2 WHDBO PULD P PJSM, FMC set 12.375"ID wear ring 10.15 11:30 1.25 11,727 11,727 INTRM2 DRILL PACK P PJSM, RIH 55', MU 5"FOSV to stand,discuss test pressure with town 11:30 12:00 0.50 11,727 11,727 INTRM2 DRILL PACK P PJSM, MU stand and closed FOSV to storm packer top at 60',turn 12 turns to right to engage and open pkr safety valve, MU top drive, and open FOSV, monitor"0"pressure on DP, open paker bypass, no pressure, observe fuid level drop 1', unseat pkr 12:00 12:30 0 50 11,727 11,663 INTRM2 DRILL PACK P PJSM, pull and LD storm packer (Baker 11-3/4"Model"B" Retrievamatic Storm Packer) 12:30 12 45 0.25 11,663 11,757 INTRM2 DRILL TRIP P RIH from 11663'to 11757' 12:45 13:00 0.25 11,757 11,805 INTRM2 DRILL WASH P Wash from 11757'to 11805'at 300 gpm, , 8-1/2"reamer shoe 4'below 9-5/8 shoe. 13 00 13:15 0.25 11,805 11,805 INTRM2 DRILL CIRC P Circulate, 126 gpm, 590 psi. 300 gpm, 2130 psi 13 15 13:30 0 25 11,805 11,805 INTRM2 DRILL CIRC P Obtain parameters, 277K PUW, 178K SOW, 300 gpm, 1830 psi, send command to engage reamer drive sub. Shut down pump and wait for pads to engage. 13:30 14:00 0.50 11,805 11,831 INTRM2 DRILL WASH P Wash to bottom at 11831', confirm RDS engaged, open flow diverter 14:00 15:30 1.50 11,831 11,880 INTRM2 DRILL DCSG P Drill 6"pilot hole from 11831'to 11880', reamer shoe on bottom (activate steering head at 11837') 600 gpm, 2130 psi,30 rpm, 15K tq 15:30 00.00 8.50 11,880 11,975 INTRM2 DRILL DCSG P Drill 6"x 8-1/2"hole with Baker SDL system from 11880'-11975'MD. ADT=8 6 hrs. Drilled 144'@ 16.7'/hr. . GPM 620, split 50%. 310 GPM for motor.310 GPM for flow diverter. 157 RPM down hole. 30 RPM surface. WOB=4 to 11k.TQ=15k on/12k off 06/01/2013 Drill 6"x 8-1/2"hole with Baker SDL system from 11,975'-12,455'MD.6923'TVD ADT= Drilled 480'@21.4 '/hr. . GPM 620, split 50%. 310 GPM for motor. 310 GPM for flow diverter. 157 RPM down hole. 30 RPM surface. DWOB=4 to 7k. Surface WOB 20k to 30k.TQ=16k on/15k off ECD's= 11.9 PPG. Page 47 of 87 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 12 00 12.00 11,975 12,280 INTRM2 CSGDRI DCSG P Drill 6"x 8-1/2"hole with Baker SDL system from 11975'-12280'MD. 6857'TVD ADT=10.3 hrs Drilled 305' @ 29.6'/hr GPM 620,split 50%. 310 GPM for motor. 310 GPM for flow diverter. 157 RPM down hole 30 RPM surface. DWOB=4 to 7k. Surface WOB 20k to 30k.TQ=16k on/15k off. 12.00 00:00 12.00 12,280 12,455 INTRM2 CSGDRI DCSG P Drill 6"x 8-1/2"hole with Baker SDL system from 12280'-12455' MD 6923'TVD ADT=11.1 hrs. Drilled 175' @ 15.8'/hr. . GPM 620, split 50%. 310 GPM for motor. 310 GPM for flow diverter 157 RPM down hole 30 RPM surface. DWOB=4 to 7k. Surface WOB 20k to 30k TQ=16k on/15k off. 06/02/2013 Drill 6"x 8-1/2"hole with Baker SDL system from 12455'- 12511'MD 6945'TVD ADT=3.5 hrs. Drilled 56'@ 16'/hr. . GPM 620, split 50%. 310 GPM for motor 310 GPM for flow diverter. 157 RPM down hole. 30 RPM surface. DWOB=4 to 7k. Surface WOB 20k to 30k TQ=17.5k on/15k off.While drilling @ 12485 observed an immediate loss of 5k on torque and .3 PPG ECD values, both occurred simultaneously. Dis-engage reamer drive sub. Pick up weight decreased 40k. Suspect the 7"drilling liner came free.Weight up from 10.4 PPG to 10 7 PPG. POOH to investigate BHA problems. 00:00 04:00 4.00 12,455 12,511 INTRM2 CSGDRI DCSG P Drill 6"x 8-1/2"hole with Baker SDL system from 12455'- 12511' MD. 6945'TVD ADT=3.5 hrs. Drilled 56' @ 16'/hr. . GPM 620,split 50% 310 GPM for motor. 310 GPM for flow diverter. 157 RPM down hole. 30 RPM surface. DWOB=4 to 7k. Surface WOB 20k to 30k TQ=17.5k on/15k off.While drilling @ 12485 observed an immediate loss of 5k on torque and .3 PPG ECD values, both occurred simultaneously. 04:00 04:30 0.50 12,511 12,511 INTRM2 DRILL CIRC T While circualting @ 300 GPM, observed a 7 foot stroke of the thruster as the string was picked up. Going back to bottom ,we tagged 5 feet early. Indicating the 7" casing had parted, and the thruster was fully extended. 04:30 04:45 0.25 12,511 12,511 INTRM2 DRILL CIRC T Pumps and rotary off Close diverter sub. Begin C&C. Discuss findings with Anchorage Drilling Team. 04:45 05:00 0.25 12,511 12,511 INTRM2 DRILL OWFF T Observe well. Static. Drop 2 inches. 05:00 06:00 1.00 12,511 12,511 INTRM2 DRILL CIRC T Circulate&condition. Evaluate how to proceed. Conference call with Anchorage Drilling Team. Decide to de-activate reamer drive sub and determine if we lost the 7"drilling liner Page 48 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06 00 06 30 0.50 12,511 12,511 INTRM2 DRILL CIRC T Close Baker flow diverter, retract steering ribs, dis-engage RDS. Observed well while waiting for reamer drive shoe pistons to close. Well static. 06:30 06:45 0.25 12,511 12,511 INTRM2 DRILL CIRC T Pick up and observe up weight @ 235k. Dropped from 275K.40k lost, verify liner weight was missing. Liner weight in air=54k,calculated buoyed weight 42k. 06:45 08:45 2.00 12,511 12,511 INTRM2 DRILL CIRC T Circulate and condition.Weight up from 10.4 PPG to 10 7 PPG. 08:45 09:00 0.25 12,511 12,511 INTRM2 DRILL OWFF T Observe well Static. 09:00 12:00 3.00 12,511 10,626 INTRM2 DRILL TRIP T Pump out of the hole fr 12,511'to 10,626' MD. 126 GPM, 600 PSI. 235k Up 155k Dn Tour calc fill=15 76 BBLS Actual fill=21 BBLS 12:00 13:00 1.00 10,626 10,063 INTRM2 DRILL TRIP T Pump out of the hole fr 10,626'to 10,063'MD. 126 GPM, 600 PSI. 210k Up Good hole fill. 13:00 13:15 0.25 10,063 10,063 INTRM2 DRILL OWFF T Observe well. Static 13:15 17:15 4.00 10,063 7,991 INTRM2 DRILL TRIP T Pump out of the hole fr 10,063'to 7991'MD. 600 GPM,2550 PSI Open diverter sub with 300 GPM, 1800 PSI. 20%flow out. Good hole fill. 17:15 17:45 0.50 7,991 7,991 INTRM2 DRILL OWFF T Observe well. Static. Drop 1.5"in 15 mins. 17:45 19:45 2.00 7,991 6,582 INTRM2 DRILL TRIP T Trip out on the trip tank. Good hole fill. 19:45 20:00 0.25 6,582 6,582 INTRM2 DRILL OWFF T Observe well. Static. Conduct KWTD. 20:00 20:15 0.25 6,582 6,582 INTRM2 DRILL CIRC T Pump 30 BBL dry job. 5 BPM. 980 PSI. Blow down top drive. 20:15 00:00 3 75 6,582 3,570 INTRM2 DRILL TRIP T Trip out of the hole. Monitor the well on trip tank. From 6582'to 3570'MD. Calculate fill=75.05 BBLS.Actual fill 87 BBLS. 06/03/2013 Trip out to quick connect Discover the set screws had loosened, or the quick connect sleeve had rotated free, and allowed the 7"liner to drop off. The threads were clean with no damage. Further analysis to be done in the Baker shop. POOH with remaining inner string. Rack back MWD system. Pick up fishing assembly, BHA#12,spear.Trip in the hole to 3157'MD. 00:00 01:30 1.50 3,570 2,249 INTRM2 DRILL TRIP T Trip out of the hole. Monitor the well on the trip tank From 3570'to 2249' MD. 01:30 01:45 0.25 2,249 2,249 INTRM2 DRILL OWFF T Observe well. Static Functioned annular, upper and lower pipe rams. 01.45 02.15 0.50 2,249 2,097 INTRM2 DRILL TRIP T Trip out of the hole. Monitor the well on the trip tank. From 2249'to 2097' MD Observe SDL quick connect had separated.The set screws did not hold and allowed the sleeve to back out Page 49 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 03:00 0.75 2,097 2,097 INTRM2 DRILL THGR T After studying the BHA failure, tripped back in to lay down off the top Lay down NOV/EMS tool, commander sub, stab, flow diverter, liner setting tool. 03:00 06:15 3.25 2,097 158 INTRM2 DRILL RURD T PJSM Change out iron rough neck heads, mud bucket rubbers, elevators, from 5"to 4"equipment POOH on trip tank from 2097'to 158' 06:15 06:45 0.50 158 132 INTRM2 DRILL PULD T PJSM. Lay down BHA per Baker DD From 158'to 132' 06:45 07:00 0.25 132 132 INTRM2 DRILL PULD T Plug into battery collar. Smart battery. 07:00 07:45 0.75 132 42 INTRM2 DRILL TRIP T Pull out slowly, inspecting the MWD system, motor etc.. 07:45 08:15 0 50 42 42 INTRM2 DRILL PULD T Plug into MWD tools. Co-Pilot. Actuate reamer drive sub pistons Observe 3 of 6 pistons damaged on pads. Monitor well on trip tank. No loss, no gain 08:15 08:45 0.50 42 32 INTRM2 DRILL PULD T Plug into OnTrak tool. 08:45 09:00 0.25 32 0 INTRM2 DRILL PULD T Rack back BHA. Bit/Stab/O nTra k/Co Pi l ot/Sta b/RDS/ Motor. Observe well. Static. Slight drop.Trip calc fill=107.05 BBLS. Actual fill=125.5 BBLS. 09 00 10 45 1 75 0 0 INTRM2 DRILL RURD T Clean and clear rig floor. Lay down BHA tools. Mobilize fishing BHA components to rig floor. Monitor well on trip tank. No loss. No gain. 10 45 12 00 1.25 0 0 INTRM2 DRILL PULD T Pick up and rack back 3 stands of 6%'spiral drill collars 12:00 12 15 0.25 0 0 INTRM2 DRILL SFTY T PJSM on picking up 3 stands of DC's and flushing 12:15 12.30 0.25 0 300 INTRM2 DRILL CIRC T Trip in 3 stands and pump to clear debris from collars. 12:30 13:30 1.00 300 0 INTRM2 DRILL TRIP T Pull collars Perform Kick while collars across BOPE drill 13:30 13:45 0.25 0 0 INTRM2 DRILL SFTY T PJSM Pick up fishing assembly. 13:45 15:00 1.25 0 3 INTRM2 DRILL PULD T Make up spear BHA. 15:00 15:30 0.50 3 3 INTRM2 DRILL SVRG T Lube rig, iron rough neck,draw works,top drive, monitor well on TT. Static. 15:30 17:15 1.75 3 3 INTRM2 DRILL RURD T Wait on pack off for fishing assembly. SIMOPS:Work on mud pump's liners and swabs on#2 Valves and seats on#1. 17:15 18:00 0.75 3 338 INTRM2 DRILL PULD T Pack off arrived from Deadhorse. Make up spear BHA. 18 00 20 00 2.00 338 1,502 INTRM2 DRILL TRIP T Trip in the hole from 338'to 1502' MD. Stack weight @ 1502. BTC surface casing connection. Page 50 of 87 Time Logs Date From To Dur S Depth E. Depth Phase Code Subcode T Comment 20:00 2100 1.00 1,502 1,559 INTRM2 DRILL TRIP T Work BHA through with 5 RPM, 3 BPM, 50 PSI 5 RPM, 8 BPM, 130 PSI. Determine the 8 3/8" square shoulder No Go was hanging up every 42 feet on the connections. 21:00 23:30 2.50 1,559 3,157 INTRM2 DRILL TRIP T Trip in with 300 GPM, and rotating 5 RPM on every connection. Each connection seen. 3 BPM 60 PSI, 6 BPM 130 PSI. Trip two stands into the 9 5/8"521 Hydril and line up to trip in hole on trip tank. 23:30 23:45 0.25 3,157 3,157 INTRM2 DRILL CIRC T Circulate through both pumps.Test #1 after changing seats. Good 23:45 00:00 0.25 3,157 3,346 INTRM2 DRILL TRIP T Trip in the hole from 3157'to 3346' MD. 06/04/2013 Trip in the hole to top of fish CBU. Engage fish with spear.Work fish into 9 5/8"casing. CBU at shoe Monitor well. 00:00 06:45 6.75 3,346 10,311 INTRM21DRILL TRIP T Trip in the hole with BHA#12. Fishing assembly/Spear. From 3346'to 10311' MD. Fill every 20 stands. Calc. Fill=91 63 BBLS.Actual Fi11=81 BBLS. 06:45 08:00 1.25 10,311 10,311 INTRM2 DRILL FISH T Break circulation Obtain new slow pump rates From 10311 to 10405' MD circulate and condition mud system.600 GPM 1650 PSI. 242k Up Wt. 163k Dn Wt. 08:00 08 30 0.50 10,311 10,422 INTRM2 DRILL FISH T Trip in the hole. Tag top of fish @ 10422'. Pressure up from 240 PSI to 500 PSI @ 126 GPM. Shut down pump, set down 7k, pick up and see pack off come free of fish. Come down 2X's Each time the pack off came free. Pump down with 126 GPM until pack off pressured up to 650 PSI. Shut down pump,slack off 15k keeping steady as the pack off slid down to land See weight drop off as pack off enters 6.08"ID QC.Wt drop 3k. Slack off to 15/18k until cup is through small ID. Land out stop sub on TOF 9 feet of swallow Depth 10429'MD. Set Dn 7k, P/U to 15k, Set Dn 20k, P/U 50k. Bleed off hydraulic jar. 08:30 12 00 3 50 10,422 10,355 INTRM2 DRILL FISH T Establish circulation @ 1 BPM 170 PSI. Stage pumps up to 300 GPM 620 PSI. Slowly pulling fish up hole with 300k. 150k Dn Wt. Slight pack off seen 200 PSI increase to 850 PSI as No-Go tags top of the liner Increase max pull to 425k to keep working fish up hole. (Bull nose depth 10355'). (Liner shoe depth 12402') Page 51 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:15 1 25 12,402 12,392 INTRM2 DRILL FISH T Note: Switch to fish tally.Work fish out of hole from 12402 to 12392'MD. 425kUpWt. 125kDnWt 60 GPM 210 PSI. 13:15 13:30 0.25 12,392 12,392 INTRM2 DRILL FISH T Set down on No Go, circulate with 350 GPM 1360 to 1575 PSI. 151 BBLS pumped. 13:30 15:30 2.00 12,392 12,356 INTRM2 DRILL FISH T Work fish out of the hole from 13292' to 12356'MD.450k Up Wt. 125k Dn Wt. 350 GPM 1350 PSI Saw one pack off. Bled off and began pumping 126 GPM 350 PSI. 15:30 16:30 1.00 12,356 12,351 INTRM2 DRILL FISH T Pick up single out of pipe shed. Work fish out from 12356'to 12351'. 450k Up Wt. 125k Dn Wt 125 GPM 200 PSI. 16:30 17:00 0.50 12,351 12,351 INTRM2 DRILL FISH T Set down on NO Go and circulate for 30 mins. 126 GPM 750 PSI. 17:00 18:00 1.00 12,351 12,332 INTRM2 DRILL FISH T Work fish out of the hole from 12351' to 12332' MD.430 to 475k Up Wt. 125k Dn Wt 220 GPM 400 PSI. Pulled free @ 12347'MD. Up weight dropped to 300k. 18:00 20:00 2 00 12,332 11,699 INTRM2 DRILL FISH T Pump out of the hole into the 9 5/8" casing. 300 to 375k pick up weights. 200 GPM 400 PSI. 20:00 20:15 0.25 11,699 11,699 INTRM2 DRILL OWFF T Observe well.Went static in 10 mins. 20 15 22 30 2 25 11,699 11,699 INTRM2 DRILL CIRC T Circulate bottoms up 2x's.400 GPM 910 PSI. 1300 BBLS pumped. 22:30 23 30 1 00 11,699 11,699 INTRM2 DRILL OWFF T Observe well. Did not go static in one hour.Decide to CBU one more time. 23:30 00 00 0 50 11,699 11,699 INTRM2 DRILL CIRC T Begin to CBU. 300 GPM 570 PSI. 06/05/2013 Circulate and condition the mud 300 GPM. Monitor well. Static. Pump out of the hole with BHA#12 Fishing assembly and 2056'of 7"liner. Liner safely retrieved and on slips by 2330 Hrs. Lay down spear assembly. Rig up to break out top pup of 7"liner. 00.00 01:15 1.25 11,699 11,699 INTRM2 DRILL CIRC T Circulate and condition mud. 300 GPM 570 PSI. Obtain new SPR's on MP#1 (30)230 PSI, (40)280 PSI. 01:15 02:15 1.00 11,699 11,699 INTRM2 DRILL OWFF T Observe well. Flow back tapered to 1/10th BBUHr. in 30 mins went static in 45 mins. Remained static for the last 15 mins. 02:15 12:00 9 75 11,699 6,618 INTRM2 DRILL TRIP T Pump out of the hole from 11699'to 6618' MD.200 GPM 300 PSI. Calc fill=43.3 BBLS.Actual fill=52.5 BBLS. 12:00 1830 6 50 6,618 2,758 INTRM2 DRILL TRIP T Pump out of the hole from 6618'to 2758' MD.200 GPM 210 PSI. 18 30 19:00 0.50 2,758 2,758 INTRM2 DRILL OWFF T Observe well. Started with slight ooze,tapered to static. 19:00 20.00 1 00 2,758 2,474 INTRM2 DRILL TRIP T Pump out of the hole from 2758'to 2474' MD. 125 GPM 80 PSI. 20 00 21:00 1.00 2,474 2,474 INTRM2 DRILL OWFF T Observe well. Slight ooze,tapered to static. SIMOPS: Change out thruster Page 52 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21.00 21 30 0 50 2,474 2,380 INTRM2 DRILL TRIP T Pump out one stand. Last stand of 5"DP. 21:30 23:30 2.00 2,380 2,056 INTRM2 DRILL PULD T Lay down Commander Sub, Intensifier jar, 9-6'/:"Spiral DC's, put casing slips on the top of 7"liner. Fish at surface 23:30 00:00 0.50 2,056 2,056 INTRM2 DRILL PULD T Clear rig floor, Pick up 7"handling equipment,double stack tongs. Monitor well on trip tank. No loss/No gain Calc fill=86 BBLS Acutal fill=96.5 BBLS 06/06/2013 Lay down 11'Tenaris Blue pup joint with spear still inside. Rig up false floor, false bowl. Pick up and run inner string, latch motor into shoe track.Verify latching. Space out. Pick up HRD/liner setting assembly&make up to seal off inner annulus Finish picking up BHA.Test all tools.Trip in the hole to 9686'MD. Crew change. 00:00 01:00 1.00 0 0 INTRM2 DRILL RURD T PJSM-Cont cleaning&cleaning up rig floor-PU double stack tongs- PU&break out lower quick connect w/7"pup jt.(left spear in fish) 01 00 01 30 0.50 0 0 INTRM2 DRILL PULD T PJSM-Change out 5"DP elevators to 7"casing elevators-PU&MU lower quick connect w/7"Tenaris Blue pup jt 01 30 02 30 1 00 0 56 INTRM2 DRILL PULD T PJSM-Change out 7"casing elevators to 4" DP elevators-Install C-Plate-RU work platform&false rotary table-RIH inner string BHA# 13(6"bit-4 3/4"GT steering head- Mod Stab(NM)-On Trak-CoPilot- Mod Stab(NM)-Reamer drive sub-4 3/4"X-Treme/Brass Upset to 34' 02:30 03:15 0.75 56 34 INTRM2 DRILL OTHR T Plug into MWD @ On Trak 03:15 04:00 0.75 34 133 INTRM2 DRILL PULD T Cont. MU BHA#13-PU BCPM- Smart Battery w/XO f/34'to 133' 04:00 04:30 0.50 133 133 INTRM2 DRILL OTHR T Plug into MWD @ Smart battery 04:30 04:45 0.25 133 159 INTRM2 DRILL PULD T Cont. MU BHA#13-PU Thruster- float sub-filter sub-XO f/133'to 159' 04:45 07:45 3.00 159 2,098 INTRM2 DRILL TRIP T RIH w/inner string BHA on 4"DP f/ 159'to 2098'-Obtain space out measurements-Observed Thruster compression-pull back&stand back 1 std DP-PU 1 single f/pipe shed&RIH. 07:45 08 00 0.25 2,098 2,098 INTRM2 DRILL PULD T Change out 4"DP elevators to 5" DP elevators-PU&MU LLS&Upper quick connect. 08:00 08'30 0 50 2,098 2,119 INTRM2 DRILL RURD T Rig down false rotary table,work platform&double stack tongs-Pull C plate-MU Upper Quick connect to lower quick connect&RIH to 2119'. 08.30 09 45 1 25 2,119 2,160 INTRM2 DRILL PULD T Cont. MU BHA#13-PU flow diverter-stab-Well Commander& EMS tool to 2160' Page 53 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09.45 10:15 0.50 2,160 2,250 INTRM2 DRILL TRIP T RIH w/BHA on 5'DP f/2160'to 2250'-Pulse test MWD @ 275 gpm @ 1600 psi(Good) 10 15 10:30 0.25 2,250 2,250 INTRM2 DRILL OTHR T Cycle pumps tp function Flow diverter-Observed pressure loss f/ 1690 psi to 700 psi-Flow diverted opened-Cycle pumps 3 X-appears flow diverter still open. 10:30 11:00 0.50 2,250 2,133 INTRM2 DRILL TRIP T POOH f/2250 to 2133'-Visually observed flow diverter still open- Plug into flow diverter&trouble shoot -Tool failure. 11:00 12:00 1.00 2,133 2,119 INTRM2 DRILL PULD T PJSM-POOH f/2250 to 2119'-LD EMS tool-Well Commander&stab together in pipe shed-LD Flow diverter. * Note Waiting for Flow Diverter tool f/Deadhorse on DC6 12.00 12 15 0 25 2,119 2,119 INTRM2 DRILL SFTY T PJSM on MU BHA 12.15 13 00 0.75 2,119 2,119 INTRM2 DRILL OTHR T Clean up rig floor. Lay down double stack power tongs 13:00 14 30 1.50 2,119 2,250 INTRM2 DRILL PULD T From 2119'to 2160' PU Flow diverter tool-Plug into tool-PU Stab-Well commander-EMS tool to 2160'.TIH one stand.Test tools. 200 GPM 1280 PSI. 300 GPM 1900 PSI. Diverter closed. 300 GPM 1400. Diverter open.600 GPM 2270. Good test 14:30 00:00 9.50 2,250 9,686 INTRM2 DRILL TRIP T Trip in the hole with BHA#13. Baker SDL. SureTrak From 2250'to 9686' MD. Fill pipe every 20 stands. Calc.fill=74.34 BBLS. Actual fill=73.5 BBLS. 36/07/2013 Continue to RIH f/9686'to 11757'MD. Fill pipe every 20 stands. CBU at the shoe 11,753'MD. Slip and cut drill line Wash to bottom From 12,480'to 12,511'slight pack off. Slow ream to bottom. Drill 6"x 81/2'hole from 12,511'to 12,605'MD.With Baker SDL SureTrak. 00:00 03.00 3 00 9,686 11,757 INTRM2 DRILL TRIP T Cont. RIH w/BHA on 5"DP f/9686' to 11,757'(Fill pipe every 20 stds)- PU wt 270 SO wt 165 Calc fill 26.6 bbls Actual fill 17 bbls. 03.00 0515 2.25 11,757 11,757 INTRM2 DRILL CIRC T Circ btms up @ 300 gpm @ 2230 psi -Open flow diverter-Pump 600 gpm @ 3070 psi Observed 187 units gas-Halliburton mudlogger took samples-Obtained SPM's SIMOPS-changed out off driller's side bottom inside top drive guide roller assembly 05:15 06:30 1.25 11,757 11,757 INTRM2 DRILL OWFF T Observed well-Observed slight flow- well didn't go to static condition. Page 54 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06'30 07:45 1.25 11,757 11,757 INTRM2 DRILL CIRC T Circ btms up w/flow diverter open @ 600 gpm @ 3070 psi-Observed no gas @ btms up-Mud wt 10.8 ppg in &out. 07.45 08.00 0.25 11,757 11,757 INTRM2 DRILL SFTY T PJSM on slip&cut drill line 08:00 09:15 1 25 11,757 11,757 INTRM2 DRILL SLPC T Silp&cut drill line 60'-Service draw works&top drive Monitored well on trip during slip& cut-gained 1 bbls in 1.5 hrs 09:15 12:00 2.75 11,757 12,480 INTRM2 DRILL WASH T Wash down f/11,757'to 12,480'@ 220 gpm @ 1750 psi-brought flow rate up to 275 pgm @ 3100 psi to down link @ 12,480'. Engage RDS. 12:00 14:00 2.00 12,480 12,511 INTRM2 DRILL REAM T Wash&ream f/12,480'to 12,511'- @ 250 gpm @ 2150 psi w/30 rpm @ 16 k torque-rotating wt 185 1400 00:00 10.00 12,511 12,605 INTRM2 CSGDRI DCSG P Drilled 6"x 8%"hole w/SDL system f/12,511'to 12,605' 6976 TVD ADT 10.0 HRS. Drilled 94'@ 9.4'/hr. GPM 600, split 50%. 300 GPM for motor. 300 GPM for flow diverter. 157 RPM downhole. 30 RPM surface. DWOB=4 to 7k. Surface WOB=20 to 25k TQ= 17k ft/lbs on. 15.5k ft/lbs off. 06/08/2013 Drilled 6"x 8'/2'hole w/Baker SDL system f/12,605'to 12830'MD. 225'@ 107hr P rate.630 GPM split 315 GPM each between the diverter and the mud motor. 25k surface WOB.4k to 8k DHWOB. 35 RPM surface 157 DH RPM. 00 00 12.00 12.00 12,605 12,725 INTRM2 CSGDRI DCSG P Drilled 6"x 8'/2'hole w/SDL system f/12,605'to 12,725'MD 7013' TVD ADT- 11 hrs ECD- 11 88 ppg Footage 120'-10 9 ft/hr average P rate WOB 20-25 k Surface(4-7 k DH) RPM 30 (RPM DH 157) GPM 600 w/300 gpm thru flow diverter @ 3060 psi Torque on/off btm.- 17/15.5 k ft/lbs 12:00 00:00 12.00 12,725 12,830 INTRM2 CSGDRI DCSG P Drilled 6"x 8'/2'hole w/SDL system f/12,725'to 12,830' MD 7043' TVD ADT-11 3 hrs ECD-11.88 ppg Footage 105'-9.29 ft/hr average P rate WOB 20-25 k Surface(4-7 k DH) RPM 30 (RPM DH 157) GPM 630 w/315 gpm thru flow diverter @ 3250 psi Torque on/off btm.-19/17.5 k ft/lbs 06/09/2013 Drilled 6"x 8 1/2"hole w/Baker SDL system f/ 12,830'to 13026' MD. 196'@ 10 fUhr P rate 600 GPM 300 GPM split between floe diverter and the mud motor.28k surface WOB.4k to 8k DHWOB. 35 RPM surface. 217 DH RPM. Page 55 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 12,830 12,925 INTRM2 CSGDRI DCSG P Drilled 6"x 8 1/2"hole w/Baker SDL system f/12,830'to 12,925'MD 7065'TVD ECD-11.89 ppg ADT- 11.5 hrs Footage-95' Average P rate 8.26 ft/hr. RPM-Surface 35 DH-197 WOB- Surface 25 k DH 7 k GPM 630 w/ 50%diverted thru Flow diverter Rot wt 200 Torque on btm 18 k ft/lbs 12:00 17:45 5.75 12,925 13,026 INTRM2 CSGDRI DCSG P Drilled 6"x 8 1/2"hole w/Baker SDL system f/12,295'to 13026'MD 7085' TVD ECD- 11.8 ppg ADT-9.2 hrs Footage- 101' Average P rate 10.97 ft/hr. RPM-35 Surface DH-199 WOB- Surface 28 k DH 11k GPM 600 w/ 50%diverted thru Flow diverter Rot wt 210 Torque on btm 18 k ft/lbs Wash out in#1 Mud pump discharge valve swap t/1 pump @ 1930 hrs down f/2.25 hrs 06/10/2013 Drilled 6"x 8 1/2"hole w/Baker SDL system f/13026'to 13178' MD. 152'@ 7.06 ft/hr P rate 630 GPM 315 GPM split between floe diverter and the mud motor. 28k surface WOB. 8k to 12k DHWOB. 35 RPM surface. 217 DH RPM. 00:00 12.00 12.00 13,026 13,092 INTRM2 CSGDRI DCSG P Drilled 6"x 81/2"hole w/Baker SDL system f/13,026'to 13,092'MD 7099'TVD ADT- 10.3 hrs ECD- 11.79 ppg Footage-66' Average P rate 6.4 ft/hr RPM-35(surface)209(DH) GPM 630 @ 3150 psi w/50%flow diverted thru flow diverter WOB 27 k(surface)7/8 k(DH) String wt. PU 310 SO 150 ROT 200 Torque on btm.-19 k ft/lbs 12.00 0000 12.00 13,092 13,178 INTRM2 CSGDRI DCSG P Drilled 6"x 81/2"hole w/Baker SDL system f/13092'to 13178"MD 7117' TVD ADT- 11.2 hrs ECD- 11 84 ppg Footage-86' Average P rate 7.67 ft/hr RPM-35(surface)207(DH) GPM 630 @ 3400 psi w/50%flow diverted thru flow diverter WOB 27 k(surface)7/12 k(DH) String wt PU 305 SO 150 ROT 203 Torque on btm.-20 k ft/lbs 06/11/2013 Drilled 6"x 8 1/2"hole w/Baker SDL system f/13178'to 13448'MD. 270'@ 13.4 ft/hr P rate 630 GPM 315 GPM split between floe diverter and the mud motor. 27k surface WOB. 8k to 12k DHWOB.35 RPM surface. 217 DH RPM. Page 56 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 10:15 10.25 13,178 13,299 INTRM2 CSGDRI DCSG P Drilled 6"x 8 1/2"hole w/Baker SDL system f/13,178'to 13,299' MD 7135'TVD ADT-9.1 hrs ECD- 11 75 ppg Footage- 121' -Average P rate 13.3 fUhr RPM 35(surface) 189(DH) GPM 630 @ 3330 psi w/50%flow diverted fhru FLow Diverter-WOB- 27 k(surface)7/9 k(DH) String wt. PU 305 SO 150 ROT 203 Torque on btm. 20 k 10 15 11 30 1.25 13,299 13,299 INTRM2 CSGDRI DCSG T SRC overheated&pump#1 shut down-Attempt to close Flow Diverter-tool would not close 11:30 12 00 0.50 13,299 13,305 INTRM2 CSGDRI DCSG P Drilled 6"x* 1/2"hole w/Baker SDL system f/13,299'to 13,305'MD 7136'TVD ATD-.5 hrs ECD-11.75 ppg Footage-6' WOB 27 k(surface)7/9 k(DH) RPM 35(surface) 189(DH) GPM 630 @ 3330 psi w/50%flow diverted thru Flow diverter 12 00 00:00 12.00 13,305 13,448 INTRM2 CSGDRI DCSG P Drilled 6"x* 1/2"hole w/Baker SDL system f/13305'to 13,448'MD 7152'TVD ATD-10.5 hrs ECD-11.8 ppg Footage-143'Average P rate 13.6 ft/hr WOB 27 k(surface)7/9 k(DH) RPM 35(surface) 189(DH) GPM 630 @ 3330 psi w/50%flow diverted thru Flow diverter 06/12/2013 Drilled 6"x 8 1/2"hole t/TD @ 13488',Circ 3 x Liner Annular volumes#630 gpm Downlink deactivate reamer drive sub, confirm disengage,drop[ 1.75"ball position drill string 5'off bottom, reamer shoe @ 13435', ball on seat retract collets, P/U confirm release,force ball through seat establish circ POOH w/Pumps f/113483't/ 11286', Drop 2"ball open well commander w/dowell w/5000 psi after 3 min, CBU @ 700 gpm, Drop ball close well commander, POOH on Trip Tank f/11286't/2160' 00:00 0330 3.50 13,448 13,488 INTRM2 CSGDRI DCSG P Drilled 6"x* 1/2"hole w/Baker SDL system f/13448'to 13,488'MD 7156'TVD ATD-2.8hrs ECD- 11.77 ppg Footage-40'Average P rate 14.2 fUhr WOB 27 k(surface)7/9 k(DH) RPM 35(surface) 189(DH) GPM 630 @ 3280 psi w/50%flow diverted thru Flow diverter 03:30 04:00 0.50 13,488 13,488 INTRM2 CASING CIRC P Survey on bottom downlink t/close ribs. 04:00 04:30 0.50 13,488 13,488 INTRM2 CASING CIRC P Circ. 3 x Liner Annulus cap,630 psi 3180 psi 35 rpm 19 tq Page 57 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:00 0.50 13,488 13,488 INTRM2 CASING CIRC P Downlink t/deactivate reamer driver sub&wait 15 min confirm disengauge w/300 gpm 2080 psi, flow diverter closed Obtain slow pump rates. 05:00 05:15 0.25 13,488 13,483 INTRM2 CASING OTHR P Drop Ball position string 5'off bottom Reamer shoe @ 13435'Liner top @ 11369' 05:15 06:00 0.75 13,483 13,483 INTRM2 CASING CIRC P Pump ball t/seat @ 84 gpm 480 psi Pressure up t/1600 psi retract collets, P/U t/break over ensure release, Pressure up t/4100 psi force gball through seat 06:00 06:45 0.75 13,483 13,483 INTRM2 CASING CIRC P Circ&Cond. mud 126 gpm 630 psi, Shut down observe well f/30 min well static in 13 min. Fluid level in stack dropped 3"after 30 min. 06:45 10 30 3.75 13,483 11,474 INTRM2 CASING TRIP P POOH w/pumps @ 126 gpm 560 psi f/13483't/11474' 10 30 11 00 0 50 11,474 11,286 INTRM2 CASING TRIP P POOH on trip tank f/11474't/11286' Pulling BHA across liner top. 11.00 13:15 2.25 11,286 11,286 INTRM2 CASING OTHR P Drop 2"ball t/open well commander, pump down @ 84 gpm 380 psi, pressure up t/4100 psi didn't open, bleed down attempt to pressure up again t/4100 psi didn't open, Rotate &work string pressure up t/4100 psi didn't open, R/U cement line and pressure up w/dowel)U 5000 psi held f/3 min. and opened R/D Dowell 13:15 14:15 1.00 11,286 11,286 INTRM2 CASING CIRC P Circ through well commander @ 700 gpm 1350 psi. 14:15 14:45 0.50 11,286 11,286 INTRM2 CASING OTHR P Drop 2.115 closing ball pump U seat w/84 gpm 360 psi. Pressure up& close valve w/3460 psi. 14:45 15:15 0.50 11,286 11,286 INTRM2 CASING OWFF P R/D Pumping equip. Simops Observe Well for flow well static. 15:15 15:30 0.25 11,286 11,286 INTRM2 CASING SFTY P Pre Job Safety Meeting on tripping out of hole on trip tank. 15:30 00:00 8.50 11,286 2,160 INTRM2 CASING TRIP P POOH on Trip Tank f/11286'U 2160' 36/13/2013 POOH w/Inner Drilling Assy Down Load MWD L/D BHA, R/U&Test BOP's, M/U&RIH w/Liner Hanger/CMT Plug U 8883'. 00:00 01:30 1.50 2,160 2,098 INTRM2 CASING PULD P L/D BHA F/2160'U 2098' L/D NOV EMS sub,Well commander, Flow _-Diverter Liner running tool. 01:30 02:00 0.50 2,098 2,098 INTRM2 CASING RURD P C/O Elevateros&Iron Roughneck _dies f/4"DP 02:00 04:00 2.00 2,098 159 INTRM2 CASING TRIP P POOH w/4" Inner string f/2098'U 159' 04:00 07:30 3.50 159 0 INTRM2 CASING PULD P L/D BHA as per DD,download MWD, P/U 1 rst run steering head @ break bit. 07:30 08:30 1.00 0 0 INTRM2 CASING OTHR P 'Clean&Clear rig floor. 08:30 09:00 0.50 0 0 INTRM2 CASING OTHR P Pull Wear Ring Install test plug. Page 58 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:00 1.00 0 0 INTRM2 CASING RURD P R/U t/test BOP's, Fill stack&lines with water. 10.00 16.30 6.50 0 0 INTRM2 CASING BOPE P Test BOP's, Test choke valves 1-16, HCR&Man Choke&Kill,Auto& Man. IBOP,TIW&Dart, Upper Lower&Blind Rams,4"demco w/ 250 low 4000 high,Test Annular V 250 low 3000 high. Perform Accumulator test, 34 sec t/200 psi 200 sec V 3000 psi,Test w/4"5"& 17"Test joints.Jeff Turkington of AOGCC Waived witness of BOP test. 16 30 17.00 0.50 0 0 INTRM2 CASING RURD P R/D test equip, Blow Down Lines _Pull Test plug set wear ring. 17:00 17:15 0.25 0 0 INTRM2 CASING SFTY P Pre Job Safety Meeting on P/U Liner _Hanger CMT Plug. 17:15 00:00 6.75 0 8,883 INTRM2 CASING TRIP P M/U cmt Liner Hanger/CMT Plug& RIH on 5"dp t/8883' 36/14/2013 Continue RIH w/Liner Hanger on 5" DP f/8883'V 11365', Est circ parameters,Wash to top of liner @ 11374', Latch liner, Establish Circ Stage pumps V 6 bpm 870 psi, Packed off, Unable to circ.or work string,Work string establish circ. stage pumps V 1.5 bpm packing off,Attempt to establish circ Stage pumps V 1.1 bpm while working string. 00:00 02:00 2 00 8,883 111,334 INTRM2 CASING TRIP P Continue RIH w/liner hanger on 5" DP f/8883't/11334' 0200 02:15 0.25 11,334 11,334 INTRM2 CASING CIRC P Break Circ &Obtain circ rates, 1 bpm 190 psi, 2 bpm 250 psi, 3 bpm 300 psi. 02:15 03.15 1 00 11,334 11,365 INTRM2 CASING RURD P P/U single&pups, M/U CMT head w/pups 03:15 03 45 0 50 11,365 11,374 INTRM2 CASING CIRC P Establish Circ @ 1.5 bpm 230 psi, locate top of liner @ 11374'P/U& wash liner top @ 2 bpm 260 psi f/5 min, slack off 30 k down wt V latch on liner, P/U V 295 V confirm latch. 03 45 09 15 5.50 11,374 11,374 INTRM2 CASING CIRC P Circ&cond f/cmtjob stage pumps t/6 bpm 870 psi(packed off) 09 15 11.30 2.25 11,374 11,374 INTRM2 CASING CIRC T Work string up 235k do 100 no string movement, Est Circ&stage pumps up slowly V 1 bpm 260-440 psi, Packing off w/slight returns,work string and attempt est Circ. Still packing off w/slight flow. 11.30 12.00 0.50 11,374 11,374 INTRM2 CASING CIRC T Work String up t/375k do 130k string movement, Est circ.5 bpm 470 psi 12:00 00.00 12.00 11,374 11,374 INTRM2 CASING CIRC T Continue working string attempting to stage pumps V 6 bpm packing off unable V pump no more than 1.5 bpm without packing off.Work String continue attepmting V stage pump rate up. 1.1 bpm 320 psi,Work string while pumping packed off. Regain circ slowly bring strokes up V 1.1 bpm attempting V stage V 6 bpm f/ccmt job. Page 59 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/15/2013 24 hr summary Cont.to stage pumps up(packing off),Attepmt various pump rates unable to pump over 1 bpm without packing off,drop liner setting ball, set liner hanger as per baker, R/D CMT head, POOH w/liner hanger running tool f/11334't/1450' 00:00 10 15 10.25 11,374 11,374 INTRM2 CASING CIRC T Continue attepting t/stage pump rate up, Packing off @ various pump rates f/.3 bpm t/1.4 bpm FCP 1 bpm 430 psi PUW-310 SOW-160 Packed of when pump rate brought up t/1.4 bpm. 10:15 11:00 0.75 11,374 11,340 INTRM2 CASING CIRC T Drop liner setting ball&pump down @ 1 bpm 310 psi pressure up t/1000 psi set liner hanger as per baker break over @ 300k pressure up t/ 2080 psi slack off t/130 confirm set slack off t/100k psi up t/4000 psi bleed pressure t/500 psi observe ball drop, Pull out of liner top 260 k PUW TOL @ 11340' Reamer shoe @ 13437' 11:00 11:45 0.75 11,340 11,334 INTRM2 CASING RURD T L/D cement head&pup jts. 11:45 13:15 1.50 11,334 11,334 INTRM2 CASING CIRC T Circ bottoms up 425 gm ICP 930psi FCP 790 psi 13 15 13:30 0 25 11,334 11,334 INTRM2 CASING OWFF T Obesrve well for flow well static 13.30 13 45 0.25 11,334 11,334 INTRM2 CASING OTHR T Blow down t/d and cmt lines. 13:45 00:00 10.25 11,334 1,450 INTRM2 CASING TRIP T POOH on trip tank f/11334't/1450' 06/16/2013 Repair Iron roughneck, POOH f/1450't/49'Liner hanger running tool, L/D BHA M/U Retainer RIH w/4" DP, XO t/5"DP, RIH t/11327', CBU stage pumps t/250 gpm, RIH t/13409'set retainer,establish circ, Circ& Cond. mud f/cmt job 42 gpm 290 psi, R/U cmt equip. 00:00 00:30 0 50 1,450 1,450 INTRM2 CASING SVRG P Service Rig while wait on mechanic 00:30 03:00 2.50 1,450 1,450 INTRM2 CASING RGRP T Repair Hydraulic fittings on spinner 03 00 04:00 1 00 1,450 49 INTRM2 CASING TRIP T Continue POOH f/1450't/49'on trip tank-Calc. fill 94.6 bbl Actual 111.5 bbls 04:00 05:15 1.25 49 0 INTRM2 CASING PULD T L/D Liner Hanger running tool as per Baker-MU Baker 7"K-1 cement retainer&XO 05:15 06:30 1.25 0 2,201 INTRM2 CASING TRIP T RIH w/cement retainer on 4"Dp to 2201' 06:30 14:45 8.25 2,201 11,327 INTRM2 CASING TRIP T Change handling equipment f/4"to 5"-RIH w/cmt. retainer on 5" DP f/ 2201'to 11,327" 14:45 17:00 2.25 11,327 11,327 INTRM2 CASING CIRC T Circ btms up @ 250 pgm @ 660 psi -Blow down TD-flow check-very slight flow 17:00 20.15 3.25 11,327 13,380 INTRM2 CASING TRIP T Cont. RIH w/cmt retainer on 5"DP f/ 11,327'to 13306'P/U 15'pup continue RIH f/derrick t/13380' 20:15 20:30 0.25 13,380 13,409 INTRM2 CASING CIRC T Wash down f/13380't/13409'3 bpm 490 psi set cmt retainer @ 13409' 20:30 22:45 2.25 13,409 13,409 INTRM2 CASING CIRC T Circ&condition mud through cmt retainer 42 gpm 270 psi Page 60 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22 45 23:30 0.75 13,409 13,409 INTRM2 CASING PULD T Stand back stand do pup joints, M/U stand sting into cmt retainer M/U head pin&circ equipment. 23:30 00:00 0 50 13,409 13,409 INTRM2 CASING CIRC T Circ. Establish parameters 42 gpm 290 psi 36/17/2013 Pre job Safety Meeting on CMT job, Dowell Perform CMT Job as per detail, Rig pump 2114 stks t/spot cmt squeeze FCP @ 42 gpm 1120 CIP 0300 hrs, Pull out of retainer R/D CMT equip. CBU @ 336 gpm<Observe well for flow well static, POOH w/5"L/D WWT Super Sliders, C/O Eleveators Stand back 4" DP, L/D Retainer running tool. 00:00 00:15 0.25 13,409 13,409 INTRM2 CEMEN.SFTY T Pre Job Safety Meeting on Cement job. 00:15 03:00 2.75 13,409 13,409 INTRM2 CEMENT CMNT P CMT Liner as per detail,close annular&line up through choke dowell flood lines&test lines t/3000 psi, pump 11.1 bbls mud push, 50 bbls 15 8 ppg CMT,chase w/155 bbls drilling mud, holding back 400 psi back pressure,sting into retainer, bleed off back pressure open annular, Pump 59 bbls, ICP .3 bpm 970 psi FCP 1120 psi,214 bbl total dispalcement CIP 0300 hrs 03:00 03:30 0.50 13,409 13,306 INTRM2 CEMENT RURD P Pull out of retainer, R/D CMT equipment, stand back stand t/ 13306' 03 30 05:30 2.00 13,306 13,306 INTRM2 CEMENT CIRC P Circ Bottoms up @ 336 gpm 1270 psi FCP 1150 05:30 06:15 0.75 13,306 13,306 INTRM2 CEMENT OWFF P Blow down top drive, Observe well for flor f/30 min well static. 06:15 08:30 2.25 13,306 12,363 INTRM2 CEMENT TRIP P POOH on trip tank f/13306't/12363' 08:30 09:00 0.50 12,363 12,363 INTRM2 CEMENT CIRC P Pump s10 bbl slug @ 84 gpm 310 psi, blow down top drive and lines. 09:00 20:00 11.00 12,363 4,831 INTRM2 CEMENTTRIPP POOH f/12363't/4831'Remove WWT super sliders. 20.00 20:30 0.50 4,831 4,831 INTRM2 CEMENT CIRC P Pump 8 bbl slug,Test mud line that was replaced t/4200 psi. 20:30 22:30 2.00 4,831 2,200 INTRM2 CEMENT TRIP P POOH w/5" DP f/4831't/2200' 22:30 22:45 0.25 2,200 2,200 INTRM2 CEMENT RURD P C/O elevators&slips 22:45 23:45 1.00 2,200 0 INTRM2 CEMENT TRIP P POOH w/4" DP f/2200't/running tool 23:45 00:00 0 25 0 0 INTRM2 CEMENT PULD P L/D Retainer running tool, clear floor 06/18/2013 N/D riser N/U shooting flange, R/U Eline&pressure control equipment, RIH w/Eline&Well Tech tractors, @ 6600 Eline cable was damaged by back spooling drum, POOH w/Eline R/D pressure control)equip&tools, spool off eline rehead line, R/U Eline RIH t/13372' Log out of hole, RIH t/13370 Log out of hole w/500 psi held on casing t/11338' POOH R/D eline, N/D shooting flange N/U riser. 00:00 03:00 3.00 0 0 INTRM2 CEMENT RURD P N/D Riser N/U Shootiong flange. 03:00 03:15 0.25 0 0 INTRM2 CEMENT SFTY P Pre Job Safety Meeting w/haliburton Eline on rigging up t/run CBL 03:15 06:00 2.75 0 0 INTRM2 CEMENT ELOG P R/U E Line Pressure control equipment&logging tools w/Well Tech Tractor. Page 61 of 87 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 09:00 3.00 0 0 INTRM2 CEMEN'ELOG T RIH w/Eline, Eline operator back lashed the spool and causing a damaged spot in line, POOH w/ Elinef/6600' 09:00 13:00 4.00 0 0 INTRM2 CEMEN-ELOG T R/D Eline tools&pressure control equipment,spool off bad line, rehead eline head, Prep tools 13:00 14:15 1.25 0 0 INTRM2 CEMEN-FLOG T R/U Eline pressure control equipment&logging tools. 14:15 21:45 7.50 0 0 INTRM2 CEMEN'FLOG P RIH w/Eline t/13372' Eline depth Logg out of hole t/12950', Inconclisive data on CBL, RIH 13370' Log Out of Hole w/500 psi t/11338' Liner top POOH w/Eline.(Begin tractoring @ 12916') 21:45 23:00 1.25 0 0 INTRM2 CEMEN ELOG P R/D Eline pressure control equipment&logging tools,clear floor 23:00 00:00 1.00 0 0 INTRM2 CEMEN-RURD P N/D shooting flange N/U riser& lines 06/19/2013 Fininsh N/U riser&hole fill lines, M/U test&packer setting BHA, Cut&Slip Drill line, RIH w/5" DP t/11268', wash t/11363', R/U circ&testing equip, Set liner top packer, Displace drill string w/diesel, Perform negative test f/30 min.test good,displace diesel t/flow back tank, release test packer,CBU, OWFF static, POOH w/ 5"DP f/11363't/10041' 00 00 01.45 1.75 0 0 INTRM2 CEMEN-NUND P continue N/U Riser&hole fill lines. 01:45 02:15 0.50 0 49 INTRM2 CEMEN-PULD P M/U test packer&dog sub BHA as per baker 02:15 02:45 0.50 49 1,007 INTRM2 CEMEN TRIP P RIH w/5" DP f/49't/1007' 02:45 04:15 1.50 1,007 1,007 INTRM2 CEMEN-SLPC P Slip&Cut drill line, Service Top Drive &Adjust Brakes 04:15 12:00 7.75 1,007 10,419 INTRM2 CEMEN'TRIP P RIH w/5" DP f/1007't/10419' 12:00 12:45 0.75 10,419 11,268 INTRM2 CEMEN TRIP P RIH w/5" Dp f/10419't/11268' 12:45 13:30 0.75 11,268 11,363 INTRM2 CEMEN-CIRC P Wash down f/11268't/11363' @168 gpm 340 psi 13:30 13:45 0.25 11,363 11,363 INTRM2 CEMEN-PACK P Tag TOL @ 11338'Set liner top Packer 13:45 14:15 0.50 11,363 11,363 INTRM2 CEMEN-RURDP R/U to perform negative test, Remove bell guide install head pin swing& valves. 14:15 15:00 0.75 11,363 11,363 INTRM2 CEMEN-PRTS P Test lines t/2000 psi, Test liner top packer U 2500 psi f/10 min, Bleed off pressure U 300 psi, open bypass on test packer. 15:00 15:15 0.25 11,363 11,363 INTRM2 CEMEN SFTY P Pre Job Safety Meeting on pumping diesel&negativer test 15:15 16:45 1.50 11,363 11,363 INTRM2 CEMEN DISP P Dowell pressure test lines U 2000 psi &pump 195 bbls 75°diesel, close by-pass shut in 1300 psi on DP 16:45 18:00 1.25 11,363 11,363 INTRM2 CEMEN'PRTS P Bleed down pressure 200 psi increments U 0 psi, Monitor pressure f/30 min, no pressure increase, good test. Page 62 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 1800 19:30 1 50 11,363 11,363 INTRM2 CEMEN'CIRC P Open By-pass close top rams, line up line to reverse circ diesel t/flow back tank, displace diesel @ 168 gpm following pressure scedule FCP- 960 19:30 19:45 0.25 11,363 11,363 INTRM2 CEMEN-OWFF P Observe well f/flow well static, B/D lines t/tiger tank R/D head pin&circ equip. 19 45 20 00 0.25 11,363 11,363 INTRM2 CEMEN PACK P Release packer as per baker. 20:00 21:45 1.75 11,363 11,363 INTRM2 CEMEN CIRC P Circ bottoms up @ 336 gpm 520 psi 21:45 22:00 0.25 11,363 11,363 INTRM2 CEMEN-OWFF P Observe well for flow well static. 22:00 23:00 1.00 11,363 10,419 INTRM2 CEMEN-TRIPP POOH f/11363't/10419' 23:00 23:15 0.25 10,419 10,419 INTRM2 CEMEN-CIRC P Pump slug 15bbls 15 7ppg B/D top drive. 23:15 00:00 0.75 10,419 10,041 INTRM2 CEMEN-TRIPP POOH on trip tank f/10419't110041' 06/20/2013 POOH f/10041't/test packer&liner setting tool, LID BHA, Dummy run 7" Hanger, R/U t/run 7"tie back assy. Safety stand down on iron roughneck incident, RIH w/7"26#tie back assy.w. Volant CRT t/4804' 00:00 06:00 6.00 10,041 69 INTRM2 CEMEN-TRIP P POOH f/10041't/69' 06:00 06:15 0.25 69 69 INTRM2 CEMEN'OTHR P Function test Upper&Lower rams& Ann. 06:15 06:30 0 25 69 0 INTRM2 CEMEN-PULD P L/D Packer setting tool, retrievamatic &4"single w/cross overs&mule shoe. 06:30 07:45 1.25 0 0 INTRM2 CEMEN OTHR P drain stack, pull wear ring, make dummy run w/7"casing hanger. 07:45 10:15 2.50 0 0 INTRM2 CEMEN-RURD P R/U t/run 7"tie back w/GBR volant crt 10:15 10:45 0.50 0 0 INTRM2 CEMEN-SFTY P Safety Stand down on Iron roughneck&Pre Job Safety Meeting on Running Casing 10:45 00:00 13.25 0 4,804 INTRM2 CEMEN-RNCS P RIH w/7"Tie back 26#BTCM casing w/GBR volant CRT t/4804' 06/21/2013 Continue RIH w/7"Tie Back f/4804't/11306'Wash t/11337'land on NoGo,test seals t/1000 psi f/10 min. P/U space out casing, R/D Volant tool, R/U &Dispalce well t/9.5 ppg w/9.6ppg corrosion Inhibred brine& 150 Bbls Diesel 00:00 01:30 1.50 4,804 5,344 INTRM2 CEMEN-RNCS P RIH w/7"Tie Back w/volant CRT f/ 4804't/5344'Casing running over. 01.30 02:00 0.50 5,344 5,344 INTRM2 CEMEN'CIRC P Circ 34 bbl slug 12.5ppg 02 00 13.00 11.00 5,344 10,096 INTRM2 CEMEN"RNCS P Coniine RIH/7"Tie Back f/5344't/ 10096' 13:00 13:15 0.25 10,096 10,096 INTRM2 CEMEN CIRC P Pump 35 bbl slug 13.15 16 15 3 00 10,096 11,306 INTRM2 CEMEN'RNCS P RIH w/7"Tie Back f/10096't/11306' 16:15 16:45 0.50 11,306 11,337 INTRM2 CEMEN CIRC P Wash down w/1 bpm 130 psi/ 11306't/11337'NoGo, Observe seals @ 11329' 16:45 17:30 0.75 11,337 11,337 INTRM2 CEMEN PRTS P R/U&Test Annulus&Seals t/1000 psi f/10 min. 17.30 18:30 1.00 11,337 11,217 INTRM2 CEMEN'RNCS P UD 3 jts of 7"casing 18 30 19 15 0.75 11,217 11,297 INTRM2 CEMEN RNCS P M/U space out pups, 1 jt of casing &Casing hanger. Page 63 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 19 45 0.50 11,297 11,297 INTRM2 CEMEN.RURD P R/D Volant CRT Clear floor. 19 45 20 45 1.00 11,297 11,297 INTRM2 CEMEN-RURD P M/U Landing Jt, R/U U reverse circ 20:45 21:00 0.25 11,297 11,297 INTRM2 CEMEN"SFTY P Pre Job Safaty Meeting on Displacing well. 21.00 00:00 3.00 11,297 11,297 INTRM2 CEMEN-CIRC P Displace well w/393 bbls 9.5 ppg Glydril mud, 33.6 Hi Vis spacer,291 bbls corrosion Inhibited Brine 9.6 ppg, Dowell 150 bbls diesel FCP 820 psi 06/22/2013 Land 7"Casing on Hanger spaced out 1'off NoGo, set packoff RILDS,Test Annulus U 2500 psi f/30 min,test 7"Casing U 3500 psi f/30 min. R/U&UD 5" DP Via Mouse Hole 122 Stands total, P/U&Stand back 4"DP 31 Stands) 00.00 00:30 0.50 11,297 11,297 INTRM2 CEMEN CIRC P Dowell blow down lines(differential pressure 300 psi when done pumping) 00:30 00:45 0.25 11,297 11,336 INTRM2 CEMEN OTHR P Strip through bag land on hanger @ 11336' 1'off NoGo 00:45 01:15 0.50 11,336 11,336 INTRM2 CEMEN OTHR P Bleed off pressure&open Annular, R/D Circ equipment, L/D Landing Jt. 01:15 02:30 1.25 11,336 0 INTRM2 CEMEN OTHR P Set 11.75"x 7" Pack off, RILDS, R/U &Test Seals U 250/5000 F/10 min. 02:30 04:30 2.00 0 0 INTRM2 CEMEN-PRTS P R/U&Test Annulus U 2500 psi f/30 min., Swap lines test 7"csaing U 3500 psi f/30 min , bleed off pressure, R/D test equipment 04 30 09 15 4 75 0 0 INTRM2 CEMEN-PULD P UD 5" DP via mouse hole(38 stands) 09:15 10:00 0.75 0 0 INTRM2 CEMEN-SFTY P Safety Stand down 10:00 12 00 2.00 0 0 INTRM2 CEMEN-PULD P L/D 5" Dp via mouse hole( 12 stands 12:00 13 00 1.00 0 0 INTRM2 CEMEN-PULD P L/D 5" DP via mouse hloe(9 stands) 13:00 13:15 0.25 0 0 INTRM2 CEMEN-SFTY P STOP Safety Observation& discussion 13:15 19:30 6.25 0 0 INTRM2 CEMEN-PULD P L/D 5" DP via mouse hole(63 stands) 19:30 20:45 1.25 0 0 INTRM2 CEMEN-RURD P C/O elevators&Iron roughneck dies f/4" DP 20:45 0000 3.25 0 0 INTRM2 CEMEN PULD P P/U&Stand back 4" DP via mouse hole 31 stands 06/23/2013 Finish P/U 4" DP, CIO upper rams U 3%x 6 var. CIO saver sub, R/U&test BOPE witness of test waived by AOGCC inspector Bob Nobel,Test w/3%,4,4%test jts, P/U BHA as per Baker Rep, shallow pulse test tools, Single in the hole w/4" DP f/390't19438' 00 00 00.45 0.75 0 0 INTRM2 CEMEN-PULD P Continue P/U&Stand back 6 more stands 4"DP via mouse hole 00 45 03 00 2.25 0 0 INTRM2 WHDBO RURD P PJSM, CIO upper rams to 3-1/2"x 6" VBR's SIMEOPS: Change out top drive saver sub, iron roughneck dies 03.00 04:15 1.25 0 0 INTRM2 WHDBO BOPE P PJSM,Set test plug,test jt. RU to test BOPE Page 64 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04.15 10.30 6.25 0 0 INTRM2 WHDBO BOPE P Tested BOPE as follows:w/4"test jt.tested Annular to 250&3500 psi- Tested upper 3-1/2"x 6"pipe rams, TD IBOP's,4"Floor safety&dart valves, Choke&kill line valves, Choke manifold valves# 1,2,3,4,5,6,7,8,9,10,11,12,13,14,15, & 16 and needle valve to 250&4000 psi-HCR choke and Kill-4"Demco on kill line-manual kill&choke valves-Lower 2-7/8"x 5"pipe rams to 250&4000 psi-Performed accumulator recovery test, 2900 psi start, 1250 psi end,32 sec to 200 psi,208 sec to 2900 psi, Tested Blind rams 250/4000 psi-Tested gas alarms-With the 3-1/2"and 4" test joint tested annular, 250 PSI low/3500 PSI high, upper and lower variable pipe rams 250 PSI low/4000 PSI high Annulus open and monitored during test.All tests charted, 5 min/test. Bob Noble (AOGCC)waived witnessing tests RD 10:30 11 00 0.50 0 0 INTRM2 CEMEN-OTHR P PJSM, FMC install 8.625" ID wear ring 11:00 12 45 1.75 0 62 INTRM2 CEMEN'PULD P PJSM, C/O elevators, MU BHA as per Baker to 62' 12 45 13:45 1.00 62 62 INTRM2 CEMEN-PULD P Plug in&download MWD 13 45 15:00 1.25 62 390 INTRM2 CEMEN"PULD P Continue M/U BHA as per baker t/ 390' 15 00 15:30 0 50 390 390 INTRM2 CEMEN CIRC P Shallow pulse test BHA @ 200 gopm 540 psi 25 rpm 2.5 tq 15:30 00:00 8.50 390 9,438 INTRM2 CEMEN PULD P Single in the hole f/shed w/4" DP f/ 390't/9438' Fill pippe every 20 stands 06/24/2013 Continue Rlh w/4" DP f/shed f/9438't/13160',Wash&ream t/TOC @ 13367', Drill CMT&Cement retainer t/13437'Clean out rat hole t/13488'CBU R/U&perform FIT t/12 5 ppg EMW, Displace well t/9.0ppg FloPro Observe Well Static, Drill Ahead f/13488't/13494'@ 200 GPM 60-120 RPM 9k tq, 3-30 WOB, ROP.58 ft/hr ECD-10.25 00:00 01 15 1.25 9,438 10,164 INTRM2 CEMEN-TRIPP RIH w/4" DP from shed f/9438't/ 10164'filling pipe every 20 stands 01 15 02:45 1.50 10,164 10,164 INTRM2 CEMEN'SLPC P Slip&Cut drilling line 75'service top drive&draworks 02 45 03:00 0.25 10,164 10,164 INTRM2 CEMEN-OTHR P Calibrate Hook load sensor&block height f/MWD 03:00 06:15 3.25 10,164 13,160 INTRM2 CEMEN TRIP P Continue RIH w/4" DP f/shed f/ 10164't/13160'filling pipe every 20 stands. 06:15 06:45 0 50 13,160 13,160 INTRM2 CEMEN-PULD P M/U&Stand back 2 stands of 4" DP in derrick 06:45 08:15 1.50 13,160 13,367 INTRM2 CEMEN-WASH P Wash down f/13160'@ 200 gpm 2450 psi 50 RPM 15k tq Top of CMT @ 13367' Page 65 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 09:45 1.50 13,367 13,422 INTRM2 CEMEN'DRLG P Drill Cement&Retainer f/13367't/ 13422'200 gpm 2500 psi 50 RPM 15-18 tq @ 13422'stall out pack off, 25K overpull to pull free. 09:45 10:30 0.75 13,422 13,422 INTRM2 CEMEN-OWFF P Obtain slow pump rates, Observe Well for flow w/9.5 ppg Glydril well static. 10:30 12:00 1.50 13,422 13,447 INTRM2 CEMEN DRLG P Drill rat hole&CMT f/13422't/ 13447'w/200 gpm 1800 psi 75 rpm 18k tq Make connection flow ck well static. 12:00 12:45 0.75 13,447 13,488 INTRM2 CEMEN-DRLG P Drill rat hole f/13447't/13488'w/ 200 gpm 1780 psi 100 rpm 20 k tq 10-15 WOB 12:45 14:00 1.25 13,488 13,488 INTRM2 CEMEN-CIRC P Circ bottoms up 200 gpm 1720 psi 14.00 14:15 0.25 13,488 13,362 INTRM2 CEMEN'TRIP P Stand back stand&L/D single t/ 13362' 14:15 14:30 0.25 13,362 13,362 INTRM2 CEMEN'OWFF P Observe well for flow well static 14:30 15:15 0.75 13,362 13,362 INTRM2 CEMEN FIT P R/U&Perform FIT t/12.5ppg EMW, f,- R/U test equipment. r 15:15 15 30 0.25 13,362 13,488 PROD1 DRILL TRIP P P/U single&RIH w/4"DP t/13488' 15:30 17 00 1.50 13,488 13,488 PROD1 DRILL CIRC P Displace well t/9 0 ppg FloPro @ 220 gpm 1690 psi 17:00 17:30 0.50 13,488 13,488 PROD1 DRILL OWFF P Observe well f/flow well static, Obtain slow pump rates 17:30 18:45 1.25 13,488 13,488 PROD1 DRILL OTHR P Down link MWD trouble shoot connection issues while wait on new directional plan 18:45 00:00 5.25 13,488 13,494 PROD1 DRILL DDRL P Drill 6"production hole f/13488'U 13494'TVD-7157'ADT-.9 WOB-5-30 Tq 9 5 RPM 40-120 200 GPM 1500 psi, ECD 10.25. Hard spot or junk in hole,work string unable to get torque increase, not seeing weight to bit, no pressure increase when applying weight Varied parameters, Drilling off w/120 rpm low WOB 3-5k 9.5 k tq flagging U 10.5k 06/25/2013 Drill 6"Production hole with Baker Azi-Trak. from 13,494'to 14,165'MD.7164'TVD.ADT=18.6 hrs. WOB 15k to 18k. RPM 150 GPM 220. PP 1800.TQ 10.5k ON/8k OFF. ECD's 10.95 PPG. . Connection gas spiked to 900 units at 14,108'. MW on balance scale=8.1 PPG. Hole depth 14,115'weight up to 9.2 PPG from 9.0 PPG. Gas dropped frrom 900 units to 170 units as the new MW came up the annulus. Cont.to drilled ahead into loss zone at 14,165'. ROP increase from 50'/hr to 70'/hr. Torque increase from 11k ft/lbs to 12k ft/lbs. Observe losses of 95 BBLS/hr while pumping 2 BPM. Static losses measured @ 28 BBLS/hr. Mix LCM pill. 00:00 12:00 12.00 13,494 13,796 PROD1 DRILL DDRL P Drill 6"Production hole with Baker Azi-Trak.from 13,494'to 13,796' MD. 7175'TVD.ADT=10.3 hrs. WOB 15k to 18k. RPM 150. GPM 220. PP 1800.TQ 10 5k ON/8k OFF. Page 66 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 23:30 11.50 13,796 14,165 PROD1 DRILL DDRL P Drill 6"Production hole with Baker Azi-Trak.from 13,796'to 14,165'MD. 7164'TVD.ADT=8.3 hrs. WOB 15k to 18k. RPM 150. GPM 220. PP 1800.TQ 10.5k ON/8k OFF. MW on balance scale 8.1 to 8.4 PPG. Discuss weighting up to 9 2 PPG. Begin weight up @ 14,115. Gas dropped frrom 930 units to 170 units as the new MW came up the annulus. Hole depth 14,165' lost circulation. 23:30 00 00 0.50 14,165 14,165 PROD1 DRILL CIRC T Lost 500 PSI pump pressure. ECD's dropped to 9 55 PPG from 10 95 PPG. Lost returns while drilling. ROP increase from 50'/hr to 70'/hr.Torque increase 1000 ft/lbs Loss rate of 28 BBLS/Hr static. 95 BBLS/Hr.while pumping 2 BPM . Prepare LCM pill. 06/26/2013 Observed static losses of 25 BPH and Dynamic losses of 95 BPH. Pulled up 1 stand and pumped 2 LCM pill @ 14115'MD Tripped to bottom and resumed drilling from 14,165 to 14,202'MD. Logged loss zone with MWD tools, losing 60 BBL/Hr while drilling. Pumped 2 additional LCM pills while drilling to 14210'MD Observed decreased loss rate of 30 to 40 BBUHr Observed well bore breathing, Perform breathing test for 50 mins. Establish diminishing flow back rate. CBU and continue to directional drill 6"lateral from 14,210'to 14,390' MD. Loss rate @ 25 BPH by midnight. Pumped 5th LCM pill @ 14,302. LCM pill recipe: 5 ppb dynared fine/5 ppb dynared med. 10 ppb nut plug fine. 5 ppb nut plug medium. 10 ppb safecarb 250. 5 ppb safecarb 500. 00 00 00.15 0.25 14,165 14,165 PROD1 DRILL CIRC T Observe well-Observe fluid drop approx 20'in stack,4 bbls in 15 min, approx 16 bph 00:15 00:45 0.50 14,165 14,115 PROD1 DRILL CIRC T Stage pump rate up to 126 gpm, 740 psi, 50 rpm, 8.5k Tq,slight returns, pump out stand to 14115'and stand back 00 45 02 00 1.25 14,115 14,115 PROD1 DRILL CIRC T Pump 36 bbls,40 ppb, LCM pill, 84 gpm thru BHA then 126 gpm, 450-840 psi, 10 rpm, 9K tq, loss rate at 104 bph 02:00 03:15 1 25 14,115 14,115 PROD1 DRILL CIRC T Pump 2nd 36 bbls,40 ppb, LCM pill, 84 gpm thru BHA then 126 gpm, 450-840 psi, 10 rpm,9K tq, loss rate at 100 bph 03.15 0345 0.50 14,115 14,115 PROD1 DRILL CIRC T Observed increased returns,stage up pump rate to 147 gpm, 1050 psi, Loss rate 28 bph 03:45 04:00 0.25 14,115 14,115 PROD1 DRILL CIRC T Stage up pump rate to 168 gpm, 1340 psi, Loss rate 64 bph 04:00 04:15 0.25 14,115 14,165 PROD1 DRILL WASH T Wash ream from 14115'to 14165'w/ 168 gpm, 1320 psi, 100 rpm, 10k tq, Loss rate 128 bph 04:15 05'30 1.25 14,165 14,202 PROD1 DRILL DDRL P Drill f/14165'to 14202', 168 gpm, 1380 psi, 110 rpm, 11.5k tq, pump 3rd 36 bbl 40 ppb LCM pill w/drilling, Loss rate 128-88 bph Page 67 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 08:30 3.00 14,202 14,202 PROD1 DRILL CIRC T Circ and monitor losses,pump 4th 37 bbl 40 ppb, LCM pill, 84 gpm to BHA,then 189 gpm,620 psi-1420 psi, 30 rpm, 10 5k tq, Loss rate 4-90 bph,peak of 590 units gas coincided with bottoms up of drilled cuttings 08.30 09:15 0.75 14,202 14,202 PROD1 DRILL CIRC T Troubleshoot MWD,Vary pump rate and cycle pump to clear MWD pulsar of LCM 09.15 10:00 0.75 14,202 14,210 PROD1 DRILL DDRL P Drill f/14202'to stand dwon at 14210' MD, 7160'TVD,ADT 1 6 hrs, 80-50 bph loss rate at 200 gpm. Shut down pump, observe well breathing 4 min 10:00 12:00 2.00 14,210 14,210 PROD1 DRILL CIRC T CBU at 126 gpm, 930 psi, 30 rpm, 10.5k tq, Loss rate 30-60 bph. Total tour losses=508 bbls 12:00 12:30 0.50 14,210 14,210 PROD1 DRILL CIRC T Continue CBU, 126 gpm,970 psi, 30 rpm, 10.5k tq, max gas 250 units at bottoms up, not gas cut. 12:30 13:30 1.00 14,210 14,210 PROD1 DRILL OWFF T Perform exhale test, observe and plot diminishing flow back,gained 21 bbls over 51 minutes, initial backflow at 150 bph to final of 4.3 bph 13:30 15:00 1.50 14,210 14,210 PROD1 DRILL CIRC T CBU at 180 gpm, 1480-1610 psi, 30 rpm, 10k tq, observe little gas at bottoms,260 units max, not gas cut. 15:00 00:00 9.00 14,210 14,390 PROD1 DRILL DDRL P Drill f/14,202'to 14,390', 210 gpm, 1850 psi, 150 rpm, 14.5k tq, pump 5th 30 bbl 40 ppb LCM pill w/drilling, Loss rate 25 BPH.All LCM pills had same formula. 36/27/2013 Directional drill 6"production hole with Baker Azi-Trak system. Geo-steering in Alpine C sand. Drill f/14,390 to 15,030'MD, 7155 TVD,210 gpm,2120 psi, 150 rpm, 18.5k TQ on/12k TQ off.20k WOB. Pump LCM pills #6 @ 14,790, LCM pill#7 @ 14,980' MD. Perform exhale test to trip tank. Observe diminishing returns Lost 696 BBLS last 24 Hrs.29 BBL/Hr average 00:00 12:00 12.00 14,390 14,747 PROD1 DRILL DDRL P Drill f/14,390 to 14,747',210 gpm, 1940 psi, 150 rpm, 18.5k TQ on/12k TQ off.20k WOB. 03:30 Hrs bring weight up to 9.3 ppg from 9.2 ppg after connection gas spike of 1200 units, and MW recorded 8.1 ppg on balance scale. Lost 336 BBLS on tour. 28 BBUHr average loss rate. 12:00 16:00 4.00 14,747 14,877 PROD1 DRILL DDRL P Drill f/14,747 to 14,877',210 gpm, 1940 psi, 150 rpm, 18.5k TQ on/12k TQ off.20k WOB. Pump 37 BBL,40 PPB LCM pill(#6)@ 14,790' MD. 16:00 16:45 0.75 14,877 14,877 PROD1 DRILL DDRL P Perform exhale breathing test to trip tank Initial flow-300 BPH, diminished to 18 BPH in 30 mins 41 BBLS total. 16:45 00:00 7.25 14,877 15,030 PROD1 DRILL DDRL P Drill f/14,877 to 15,030,7155 TVD, 210 gpm,2120 psi, 150 rpm, 17.5k TQ on/12k TQ off 20k WOB Pump 37 BBL,40 PPB LCM pill(#7)@ 14,980' MD. Page 68 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/28/2013 24 hr summary Drilled from 15,030'to 15,034'MD. Penetration rate slowed to 0'/hr. Prepare to trip for new bit. Perform two exhale tests on bottom to verify breathing phenomenon. Pump 17 stands out into the 7"casing Observe well. Well went static in 15 mins. Pump out of the hole with 2 BPM to 5,149'MD. Crew change. 00:00 01.00 1.00 15,030 15,034 PROD1 DRILL DDRL P Drill f/15,030 to 15,034, 7154 TVD, 210 gpm, 2120 psi, 150 rpm, 14.5k TQ on/12k TQ off.20k WOB Torque dropped to 14.5k from 18.5k, ROP ceased, Pump pressure went up 100 PSI while on bottom. Prepare to trip for new bit. 01:00 02 15 1.25 15,034 15,034 PROD1 DRILL DDRL P Circulate and condition mud system. 220 GPM, 2230 PSI, 80 RPM, 12 5k TQ. ECD=10.95 PPG, MW=9 3 PPG. 02:15 03:00 0.75 15,034 15,034 PROD1 DRILL OWFF P Observe well. Exhale/Breathing test performed into trip tank. Record seconds per barrel for 30 mins Initial flow back rate 327 BPH. Final flow back rate 19 BPH.41 BBLS bled back 03:00 04:30 1.50 15,034 15,034 PROD1 DRILL CIRC P Obtain SPR's. Survey on bottom CBU. 220 GPM,2130 PSI, 80 RPM, 12.0k TQ. Gas spike=2569 units. MW out balance scale 8.6 PPG, pressure scale 9.4 PPG. 04:30 05:15 0.75 15,034 15,034 PROD1 DRILL OWFF P Observe well. Exhale/Breathing test performed into trip tank. Record seconds per barrel for 30 mins. Initial flow back rate 240 BPH. Final flow back rate 24 BPH.43 BBLS bled back. 0515 07.45 2.50 15,034 15,034 PROD1 DRILL CIRC P Circulate Bottoms up @ 126 GPM, 820 PSI, 80 RPM, 12k TQ. Gas spike=1960 units. MW out balance scale 8 6 PPG, pressure scale 9.4 PPG 07:45 10:30 2.75 15,034 13,351 PROD1 DRILL TRIP P Pump out of the hole with 2 BPM. 450 PSI. 1600 FPH string speed 10:30 11:15 0.75 13,351 13,351 PROD1 DRILL OWFF P Observe well. Initial flow back rate= 48 BPH Static in 15 mins. 1 BBUHr static loss rate. 11:15 12:00 0.75 13,351 12,969 PROD1 DRILL TRIP P Pump out of the hole from 13,351'to 12,969'. 2 BPM,450 PSI. Calc fill=12.4 BBLS.Actual fill=24 BBLS. 12:00 17:30 5.50 12,969 9,634 PROD1 DRILL TRIP P Pump out of the hole from 12,969'to 9634'.2 BPM, 380 PSI. Good hole fill. 17:30 18:00 0.50 9,634 9,634 PROD1 DRILL SFTY P Safety stand down. Discuss iron roughneck incident. Flow check. Went static in 2 mins. 1 1 BPH loss rate observed. 18:00 20:15 2.25 9,634 7,912 PROD1 DRILL TRIP P Pump out of the hole from 9634'to 7912'.2 BPM,380 PSI Good hole fill. 20:15 20:30 0 25 7,912 7,912 PROD1 DRILL OWFF P Kick while tripping drill. Observe well. Static. Page 69 of 87 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 20 30 00 00 3.50 7,912 5,149 PROD1 DRILL TRIP P Pump out of the hole from 7912'to 5149'.2 BPM, 380 PSI Calculated displacement for trip=60 14 BBLS Lost 181 BBLS for trip to this depth. 06/29/2013 Pump out of the hole from 5149'to 3147'MD.Trip on elevators, monitoring hole fill with trip tank to BHA. Inspect all downhole tools Bit grade 8-3-cored out-N-X-I-BT-PR Rerun all BHA components, pick up Well Commander. Trip in the hole @ 2000'/HR. Fill pipe every 20 stands Trip to 12,694'MD. Crew change. 00:00 00 30 0.50 5,149 5,149 PROD1 DRILL OWFF P Observe well bore. Static. Dropping @ 1 BPH 00:30 00 45 0.25 5,149 5,054 PROD1 DRILL TRIP P Pulled one stand on the trip tank. Gained 1/4 barrel. Swabbing Pipe came dry. (Should have lost 62 BBL) 00:45 03:15 2.50 5,054 3,147 PROD1 DRILL TRIP P Resumed pumping out from 5054'to 3147'MD. 2 BPM,250 PSI 03:15 06:45 3.50 3,147 479 PROD1 DRILL TRIP P Flow check. Static. Began tripping on elevators, filling from trip tank. Good hole fill Trip out from 3147'to 479'MD 06 45 07:00 0 25 479 479 PROD1 DRILL RURD P Function rams. Upper pipe rams(3% x 6), Lower pipe rams(2 7/8 x 5), annular 07:00 07:15 0 25 479 479 PROD1 DRILL CIRC P Circulate to test MWD tools. Good signal. 07 15 08 00 0 75 479 100 PROD1 DRILL TRIP P Trip out of the hole on trip tank. From 479'to 100' MD. 08 00 08 45 0.75 100 62 PROD1 DRILL PULD P PJSM. Change out 4"elevators to 3.5"elevators. Lay down BHA. Filter sub,float sub,flex monel collar. BHA#17 to 62'top of MWD string. 08:45 09:00 0.25 62 0 PROD1 DRILL PULD P POOH and brake off bit. (Bit grade=8-3-cored out). Total trip calc fill=97 BBLS.Actual fill=256 BBLS. 09:00 09.45 0.75 0 0 PROD1 DRILL PULD P Down load MWD data.Azitrak port. Clean and clear rig floor. 09.45 10:00 0.25 0 0 PROD1 DRILL PULD P Down load MWD data. Co-pilot port 10:00 10.15 0.25 0 0 PROD1 DRILL PULD P Make up bit#6. New bit 10:15 10:45 0.50 0 111 PROD1 DRILL PULD P Make up BHA#18. Rerun all MWD tools, pick up Well Commander,float sub,filter sub,flex monel. 10:45 11:15 0.50 111 490 PROD1 DRILL RURD P PJSM. Change out 3.5"elevators to 4"elevators. Trip in to first stand of DP. 11:15 11:45 0.50 490 490---PROD1 DRILL CIRC P Shallow pulse test MWD system 170 GPM,450 PSI. Cycle Well Commander sub. Drop activating ball. Pressure up from 450 to 1300 PSI. Hold for 30 secs. Pressure up to 1560,and open WC. 170 GPM,20 PSI. Shut down, drop closing ball. Pressure up to 1300 PSI. Hold 30 secs Pressure up to 1540 PSI Close WC Verify with 170 GPM,450 PSI. 11:45 12:00 0 25 490 869 PROD1 DRILL TRIP P Trip in the hole. Running mix and roll pump out of pit 5 to keep hole full. Page 70 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 22.00 j 10.00 869 11,834 PROD1 DRILL TRIP P (Trip in the hole. From 869'to 11834' MD. 1700'/hr running speed. Fill pipe every 2000 feet. 22:00 23:00 1.00 11,834 11,834 PROD1 DRILL CIRC P Fill pipe. Stage pump up to 4 BPM while rotating 30 RPM. 1130 PSI Pulse check MWD. Good. Circulate 1000 strokes to put new mud above BHA in annulus. Observe flow back. Well went static in 30 mins. SIMOPS:Weld on pin hole leak in hydraulic line. Patch service line on top drive. 23:00 00:00 1.00 11,834 12,694 PROD1 DRILL TRIP P Trip in the hole. From 11,834'to 12,694' MD 1700'/hr running speed. Fill pipe every 20 stands. Calculated hole fill=77.5 BBLS.Actual fill=47 BBLS. 06/30/2013 RIH to TD,wash and ream to bottom with the last stand. Drilled ahead to 15,349'and and lost full returns Spot two 40 bbl,40 lb/bbl pills Next mixed 80 Ib/bbl pill while losing 70-90 bbl/hr with pumps off. Dropped steel activation ball for the Well Comander circ sub and pumped down hole at 2 bbl/min, opening tool. Next, dropped BHA closing ball, and shut off circulation through the bit and BHA. Spot 81 bbls of 80 lb/bbl LCM pill. Let soak and monitored well. Prepare to spot and hesitation squeeze 50 bbl Forma-A-Blok pill. Monitor well on trip tank. Approximately 30 bbl/hr static loss rate. 00:00 04:00 4.00 12,694 14,984 PROD1 DRILL TRIP T Cont to RIH from 12,694'to 14,984' tmd filling pipe every 20 stands (Total trip calculated fill= 100.6 bbl, actual fill=89.6 bbl(-11 bbl) Pulled tight at 14,392'tmd with 15K excess down weight, UWT=212K, DWT= 135K. 04:00 05:15 1.25 14,984 15,034 PROD1 DRILL WASH T Flow check static. Wash and ream from 14,984'- 15,034'tmd,with 80 rpm, 11.5K ft-lb of torque. Stage pumps up to 167 gpm with 1,540 pump pressure. 05:15 06:30 1.25 15,034 15,057 PROD1 DRILL DDRL P Drill ahead from 15,034'to 15,057' (observerd GR log change). 06:30 08:15 1.75 15,057 15,057 PROD1 DRILL CIRC P Circ and Cond hole, circulate bottoms up for cuttings samples with 210 gpm, 1,960 psi,40 rpm, 9K ft-lb of torque 08:15 1200 3.75 15,057 15,218 PROD1 DRILL DDRL P Drill ahead from 15,057'to 15, 218' (tvd=7,154') Total losses for past 12 hours were 261 bbl. 12.00 1415 2 25 15,218 15,348 PROD1 DRILL DDRL P Drill from 15,218'- 15,348' losing 15-30 bbl per hour,dynamic mud losses with 9 3 ppg FloPro mud at 200 GPM, 1,990 psi, 10.9 EMW, 120 rpm, 14.8k ft-Ib,WOB=10-11 K lb, ROP=55-60 ft/hr. UWT=210-215K, DWT= 133-140K, ROT= 175K Page 71 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 16:30 2.25 15,348 15,348 PROD1 DRILL DDRL T @ 15,348'Mud losses went to 150 bbl/hr, Observed ECD, pump pressure and WOB reduction Reduced flowrate to 125 gal/min to reduce loss rate. Circulated two 40 bbl,40 lb/bbl LCM pills with DynaRed F-5 lb/bbl, DynaRed M-5 Ib/bbl, Nutplug-fine-10 lb/bbl, Nutplug-medium-5 Ib/bbl, SafeCarb 250-10 lb/bbl, Safe-Carb 500-5 Ib/bbl. Pumped around and saw only temporary reduction in 150 bbl/hr dynamic losses and static losses remained at 70-80 bbl/hr. 16 30 18 00 1.50 15,348 15,348 PROD1 DRILL CIRC T Take on new mud to the Active pit while pumping in 9.2 ppg FloPro mud and mixing LCM Prep.80 bbl of 80 lb/bbl LCM, doubling the above mixture concentration. Drop ball to open Well Commander-circulating sub(111'above the bit)whilst reciprocating the drillstring. Pump ball down at 2 bbl/min and 340 psi. At 780 strokes ball went on seat and continued pumping until 2,100 psi when the circ sub opened. Drop BHA isolation ball Static losses at 72 bbl/hr. 18:00 20 00 2.00 15,348 15,270 PROD1 DRILL CIRC T Pump out to top of stand.2 BPM, 200 PSI. Pump 81 BBL, 80 lbs/BBL LCM pill out fully isolated Well Commander sub. First half at 3 bpm, second half at 2 bpm. Shut down and monitor well on trip tank. 20:00 00:00 4.00 15,270 15,270 PROD1 DRILL CIRC T Monitor well on trip tank. Loses varied from 28 to 44 BBLS/Hr. Rotate string every 10 mins Pump 3 to 4 BBLS every 15 mins. Building mud volume at mud plant. Preparing to build Form-A-Blok pill in pits. Clean pits 07/01/2013 Attempt to cure downhole losses with 3 Form-A-Blok pills. 50 BBLS#1, 80 BBLS#2, 70 BBLS#3&one LCM pill 80 BBLS in size, 150#/BBL concentration. Loss rate at start of day measured on trip tank=24 to 30 BPH. Loss rate at end of day monitored on trip tank=8 to 10 BPH. Building 4th Form-A-Blok pill, and 12th LCM pill at crew change. 00:00 00:45 0.75 15,270 15,270 PROD1 DRILL OWFF T Monitor well on trip tank,while building Form-A-Blok pill#1. Static loss rate=24 BPH 00 45 03:15 2.50 15,270 14,126 PROD1 DRILL TRIP T PJSM. Pump out of the hole from 15,270'to 14,126'MD. 1.5 BPM, 180 PSI,Calc fill=7.44 BBLS.Actual fill=82 BBLS. Page 72 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 04.15 1.00 14,126 14,126 PROD1 DRILL CIRC T PJSM. Prejob on rig floor with Mud Engineer/Pitwatcher/CoMan/Driller. Pump 30 BBLS 9.2 PPG brine, 50 BBLS 9 2 PPG 20 PPB Form-A-Blok LCM pill, 10 BBLS 9 2 PPG brine, chase with 55 BBLS 9.2 PPG mud. 145 BBLS total. 3 BPM, 500 PSI, 10 RPM, 10k TQ. Shut down. Front of brine @ WC. 04:15 05:00 0.75 14,126 14,126 PROD1 DRILL SQEZ T Close annular preventer @ 04:17 hrs. Squeeze W/3 BPM,510 ICP, 850 FCP,Annular pressure 520 PSI 05:00 05:30 0.50 14,126 14,126 PROD1 DRILL SQEZ T Hold 410 PSI on DP,510 PSI on annulus, 15 mins. Bled down to 220 PSI. Bleed off remaining pressure. Open annular preventer. 05:30 06:00 0.50 14,126 14,126 PROD1 DRILL CIRC T Circulate 3 BPM, 540 PSI, Initial loss rate 60 BPH, accelerated to 90 BPH. Stop pumping Line up to TT. 06:00 07:15 1.25 14,126 14,126 PROD1 DRILL CIRC T Monitor well on Trip tank to measure loss rates. Build Form-A-Blok LCM pill#2,while monitoring. Static loss rate= 12.5 bbl/hr. 07:15 08:15 1.00 14,126 14,126 PROD1 DRILL CIRC T Held PJSM Pumped 30 bbl of 9 2 KCI Brine,80 bbl of 9.2 lb/bbl FloPro mud with 20 Ib/bbl of Form-A-Blok LCM followed by 10 bbl of 9 2 brine. Displaced with 25 bbl of 9 2 Flo-Pro mud pumping at 3 BPM and 480 psi. Shut down pumping. 08:15 10:00 1.75 14,126 14,126 PROD1 DRILL CIRC T Shut Upper Pipe rams(3.5"x 6" Varriable Bore Rams). Attempt to Hesitation squeeze the Form-A-Blok pill at 3 BPM and 490 initial circulating pressure on drill pipe,800 psi Final circ pressure on DP. ICP on annulus was 150 psi and FCP on annulus was 500 psi.. Shut down pumping and monitored DP pressure for 15 minutes. Pumped 3 hesitation squeezes of 2,7 and 21 bbl each, of mud at 1 BPM at 500 psi pumping pressure. Pumped for 15 minutes with pumping pressure at 480 psi for 15 minutes and dropping to 220 psi at the end of the third squeeze of 15 min. 10:00 10 15 0 25 14,126 14,126 PROD1 DRILL CIRC T Bled off pressure and opened rams. Checked for flow. Well was oozing back but went static within 7 minutes. 10 15 12:00 1.75 14,126 14,126 PROD1 DRILL CIRC T Monitored well on TT while building 40 Ib/bbl Form-A-Blok, LCM pill#3 Static loss rate was 13 bbl/hr. Total losses for the past 12 hour tour was 625 bbl. Page 73 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00' 13:30 1.50 14,126 14,126 PROD1 DRILL CIRC T Monitor well on Trip tank while building Form-A-Blok pill(pill#3) Average loss rate was 24 bbl/hr. 13:30 13.45 0.25 14,126 14,126 PROD1 DRILL CIRC T Held PJSM with next crew on pumping the Form-A-Blok pill. 13:45 14.30 0.75 14,126 14,126 PROD1 DRILL CIRC T Pumped 30 bbl of 9.2 brine, 70 bbl of 9.5 lb/bbl Form-A-Blok,followed by 10 bbl of 9.2 brine spacer and chased with 35 bbl of 9.2 FloPro mud displacing front of the pill down to the Well Commander circulating sub. 14 301 17:15 2.75 14,126 14,126 PROD1 DRILL CIRC T Closed annular preventer and bullheaded Form-A-Blok pill at 3.0-4.5 BPM. DP pressure 450-980 psi, Csg pressure 575-600 psi. Pump was cavitating and had to be slowed to 2 BPM. Final circulating DP press 380 psi,final Csg pressure 260 psi. Bled off pressure, open annular preventer and checked for flow-static. 17:15 17:30 0.25 14,126 14,126 PROD1 DRILL CIRC T Circulated well at 2 BPM, 370-380 psi, UWT=230K while reciprocating pipe slowly.Average loss rate was 28 bbl/hr. 17:30 21:00 3.50 14,126 14,126 PROD1 DRILL CIRC T Shutdown pumping and monitor well on TT.Average loss rate was 28 bbl/hr. Rotate every 15 min to move drillstring with rotating torque of 12.5K ft-lb. Mixed 100 bbl pill#4, with 150 lb/bbl of conventional mix LCM material. 21:00 21:15 0.25 14,126 14,126 PROD1 DRILL CIRC T Held PJSM on pumping LCM pill#4. 21:15 22:00 0.75 14,126 14,126 PROD1 DRILL CIRC T Bit depth 14,126'MD Pumped 80 bbls of 150 lb/bbl conventional LCM pill @ 3 BPM 460 PSI. ICP=460 PSI FCP=460 PSI. Position pill at Well Commander. Shut down. 22:00 23.30 1.50 14,126 14,126 PROD1 DRILL SQEZ T Close annular preventer. Begin bullheading LCM pill(#11). 3 BPM, ICP=750 DP Ann=210. Finish bull head with 2 BPM, FCP=930 DP, Ann=700 PSI. ISIP=650 after 3 mins holding 600 PSI. Bleed off all pressure, open annular preventer. Well bore static. 23.30 23 45 0.25 14,126 14,126 PROD1 DRILL CIRC T Work string free after bull head operation 2345 00:00 0.25 14,126 14,126 PROD1 DRILL CIRC T Bit depth 14,126'MD. Begin circulation to record loss rates after LCM pill was pumped 2 BPM, 520 PSI, 50 RPM, 12k TQ. Loss rate zero for first 15 mins. X7/02/2013 Pump LCM pill#12 Second pill of 150#/lb,80 bbl size. Bull head 40 bbls, leave 40 bbls in open hole. Open annular preventer. Packed off, and stuck pipe.Conduct jarring activities for 15 hrs.Jars stopped hitting. Prepare to run E-line to back off HWDP above fish. Page 74 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 14,096 14,096 PROD1 DRILL CIRC T Position bit 1 joint up. 143 and a dbl in the hole. Circulate after pumping LCM Stage pump up slow to test loss rates at each flow. 1.5 bpm=No loss,2.0 bpm=No loss,2 5 bpm=20 bph, 3 0 bpm=8 bph, 3 5 bpm=20 bph,4 0 bpm=64 bph 10 to 15 min increments. 01:15 03:45 2.50 14,096 14,096 PROD1 DRILL CIRC T Monitor well on trip tank while building LCM pill in suction pit. Average loss rate=20 bph. Rotate pipe free each 10 mins. 03:45 04:45 1.00 14,096 14,096 PROD1 DRILL CIRC T Pump LCM pill 150 lbs/bbl, 80 bbl volume. 3 bpm, ICP=480 PSI, FCP=560 PSI 63%returns. Chase with 9.2 ppg mud 67 bbls. Position pill at Well Commander. 04:45 06:00 1.25 14,096 14,096 PROD1 DRILL SQEZ T Shut annular. 1100 psi closing pressure. Bull head 40 bbls into formation leave 40 bbls in open hole ICP=890 psi W/2 5 bpm. FCP=940 W/1.3 bpm. Back pressure off annular, rotate while squeezing, 5 to 20 rpm. Initial torque= 13 to 14k, one spike of 16k seen @ 05 20 AM. 06:00 06:15 0.25 14,096 14,096 PROD1 DRILL RURD T Bleed off pressure and open annular preventer.Attempt to rotate.Torque up to 18.5k. Stall out Pump 1 BPM. Packed off no returns. rotary off, P/U to 25 to 50 k over pull, S/O to 25 to 35k under down weight Pipe stuck. 06:15 08:15 2.00 14,096 14,096 PROD1 DRILL JAR T Attempt to free stuck pipe,trap 9k torque, and jar down. No movement. Monitor well on TT. Fill pipe each 15 mins Loss rate average 18 bph. 08:15 08:45 0.50 14,096 14,096 PROD1 DRILL JAR T Shut annular.Attempt to pump down kill line. Pressure up to 250 psi.with 1.5 bpm Pump every 15 mins 08:45 12:00 3.25 14,096 14,096 PROD1 DRILL JAR T Attempt to free stuck pipe,trap 9k TQ and jar up. Max pulled 385k. No movement. Monitor well on trip tank Fill pipe every 15 mins. Losses 20 bph. 12:00 21:00 9.00 14,096 14,096 PROD1 DRILL JAR T Jar with 385k initially,working up to 400k,then 425k pick up weight.Using 9k TQ, 12k TQ, 16k TQ to jar down with. Jars firing off at 320k to 340k on up stroke, 100k on down stroke.4 to 5 feet of movement down seen,then stopped.Able to work back up to original position 2" to 3"movement up seen with each jar fire from 20 30 to 21:30.Jars stopped latching.No jar action Monitor well on trip tank. Fill pipe every 15 mins. Losses 20 bph. Page 75 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 14,096 14,096 PROD1 DRILL JAR T Jars quit hitting. Still see bumper sub travel.Attempt to work down with 425k P/U, smack bumper sub down with string weight to 100k. 23:00 23:15 0.25 14,096 14,096 PROD1 DRILL SFTY T PJSM on rigging up wire line goose neck adapter through top drive. 23:15 23 30 0.25 14,096 14,096 PROD1 DRILL PULD T Lay down single. 143 and a double in the hole. Blow down top drive, install FOSV, head pin, cement line to keep DP full. 23.30 00.00 0.50 14,096 14,096 PROD1 DRILL RURD T Begin to rig up gooseneck adapter on top drive Crew change. 37/03/2013 Rig up NOV Goose neck adapter on top drive. Run E-line operations to attempt to back off from stuck pipe. Fire shot @ 13,161' MD. (240 grains.)No back off. POOH with wireline. Confirm shot was fired. Prepare 320 grain shot,and Well Tec tractor for next run to back off from stuck pipe. 00:00 02:45 2.75 14,096 14,096 PROD1 DRILL ELNE T PJSM Rig up gooseneck adapter for wireline entry into top drive. 02:45 03:00 0.25 14,096 14,096 PROD1 DRILL RURD T PJSM. Rig up head pin, valves, and cement line to fill string. Rig down after string was full. 03:00 03:15 0.25 14,096 14,096 PROD1 DRILL SFTY T Prejob safety meeting on rigging up E-line sheeves 03:15 05'00 1.75 14,096 14,096 PROD1 FISH RURD T Rig up wireline sheeves to enter gooseneck adapter on top drive. Align entry guide/packoff with sheeve in derrick. 05:00 12:00 7.00 14,096 14,096 PROD1 FISH SVRG T Halliburton crew reached maximum hours. Send crew to camp for rest Perform derrick inspection, service drawworks, iron roughneck,top drive. Re-position off driller side inside rollers on top drive rails. Perform work orders on top drive,Work orders on mud cleaner pumps#1 & #2.Welder work on mud pits elevators. Motor complex guard at drive controls. Fill pipe every 30 mins Work drill string open and close bumper sub. 12:00 12:15 0.25 14,096 14,096 PROD1 FISH SFTY T Pre job safety meeting on wireline operations. Making up string shot 12:15 13:00 0.75 14,096 14,096 PROD1 FISH RURD T Pick up wireline tools, (weight bars, collar locator,240 grain back off charge.) 13:00 13:15 0.25 14,096 14,096 PROD1 FISH ELNE T Run in the with wireline to 1000'. Pressure test wireline pack off to 900 psi. Good. 13:15 15:00 1.75 14,096 14,096 PROD1 FISH ELNE T Run in the hole with wireline 10 12,900'. 75°inclination 15:00 16:00 1.00 14,096 14,096 PROD1 FISH ELNE T Work 9 left hand turns with 14k torque down hole. 300k up, 150k down. Leave 10k trapped in drill string. See string pop a connection. Screw back together and torque with 16k. Stopped seeing bumper sub travel. Page 76 of 87 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 16:00 16:45 0.75 14,096 14,096 PROD1 FISH ELNE T Pump 3.5 bpm, 1100 psi, pump wireline tools down hole to 13,300' MD Unable to travel further. 16.45 17:30 0.75 14,096 14,096 PROD1 FISH ELNE T Rig Supervisor discussed options with CPAI managment. Keep DP full. Annulus static. 17:30 18:45 1.25 14,096 14,096 PROD1 FISH ELNE T Decide to attempt to manually unscrew down hole. Place 8 left hand turns in string and work downhole 15 times. P/U weight 275,slack off to 220k.Work pipe, See a shudder left as a tool joint broke.Torque back up Unable to repeat the release seen earlier. Decide to use string shot Place 8 wraps to the left and work downhole. Pump to place string shot on depth. Top drive began leaking. Let 8 wraps back out. Set slips. Break out of top drive inspect, re-dope. Re-torque 18:45 19:45 1.00 14,096 14,096 PROD1 FISH ELNE T Place 8 left hand wraps in string Work down with 300k up, 150k down weight Trap 12k torque in string Pump 3.5 bpm, 1000 psi, pump WL tool to 13,168.WL on depth on collar @ 13,161'MD. Set off charge. 19:45 20 00 0 25 14,096 14,096 PROD1 FISH ELNE T POOH with wireline to 300'. 20:00 20:30 0.50 14,096 14,096 PROD1 FISH ELNE T Work the drill string with 8 wraps trapped, holding 12k torque. No back off. 20:30 22:00 1.50 14,096 14,096 PROD1 FISH ELNE T Back off top drive, POOH with wireline lay down spent charge. Halliburton crew prepared second shot of 320 grains. Rig crew placed FOSV on drill pipe, cement line, head pin, monitor well, keep well full with mud pump. Pump 3 to 4 barrels every 15 mins to see pressure. Losing 15 to 20 bbls per hour downhole. 22:00 00:00 2.00 14,096 14,096 PROD1 DRILL ELNE T Decide to run Well Tec wireline tractor for next run. Halliburton and Well Tec crews prepare equipment for run @ 0700 hrs.Wireline crew timed out at midnight SIMOPS: Rig work orders. 37/04/2013 Wait on E line&Well Tech crew(over hrs)Work on work overs for mud pumps, roughneck-RU Well Tech tractor&MU back off shot#2-RIH stopped @ 37'-POOH-remove centralizers f/tractor tool-RIH w/ back-off shot#2 Wireline operations,with Well Tec tractor down to 13,762'MD.Getting on depth to fire at crew change. Page 77 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00.00 09.00 9.00 14,096 14,096 PROD1 (FISH OTHR T Cont.to wait on E line crew&Well Tech. Over hrs)Perform work orders on Iron roughneck, Degaser in pit room, MP#1&#2 in pump room, pipe skate in pipe shed, Needle gun cabinets in pipe shed&prep to paint -Hang safety cable on SLB sensor in derrick-monitor well on TT&fill DP every 30 mins. 09:00 09:15 0.25 14,096 14,096 PROD1 FISH RURD T PJSM-RD head pin, FOSV,Tee,2" low torque valve, &cmt. line(used for filling DP) 09:15 12:00 2.75 14,096 14,096 PROD1 FISH ELNE T PJSM-RU Well Tec tractor&Back -off shot#2-RIH tools set down@ 37'-POOH-Measure OD's on Well Tec tractor centralizers-2 49"& 2.47"-tool jt ID on 4"XT-38 2.563"- LD back off shot-LD tracktor- Removed centralizers f/tractor-Fill DP w/fill up hose. Lost 115 bbls last 12 hrs. 12:00 13:00 1.00 14,096 14,096 PROD1 FISH ELNE T Fill pipe-Working on tractor tool- 13:00 13:15 0.25 14,096 14,096 PROD1 FISH SFTY T PJSM on picking up wireline tool string 13:15 13.30 0 25 14,096 14,096 PROD1 FISH PULD T PU wireline tools-back off shot(400 grain)Well Tec tractor w/2.362" (max OD) 1330 21.45 8.25 14,096 14,096 PROD1 FISH ELNE T RIH w/back-off shot&tractor. Tractor down to 13,450'. Begin to assist with mud pump. Pump 8 strokes per minute, 280 psi, begin tractoring again Keep drill pipe full. 21.45 00.00 2.25 14,096 14,096 PROD1 FISH ELNE T Tractor with rig pump assistance. 8 SPM, 280 PSI. Get down to 13,762' WL depth. Locate collars at top and bottom of HWDP stand.Work 8 left hand wraps down hole,working string with 275 P/U Wt, 150 S/O Wt. Trap 8 wraps with 12k surface torque,for back off shot.WL made one more pass and got hung up @ 13,762'WL depth. Pulled free and lost correlation depth Decide not to go that deep again,and shoot the top of the HWDP stand above the bumper sub.Target depth adjusted to 13670'MD. Getting on depth at crew change. '07/05/2013 Unsuccessful back off. POOH with wireline tools.-Shot didn't fire-LD tools-rehead wireline MU&pre check tractor tools-MU Back-off shot#3(400 grains)-RIH. Locate top of HWDP stand with collar locator. Place shot on depth.Work 10%left hand wraps downhole with 12k surface torque. Fire shot at 13668 WL depth. No back off. POOH with WL tools. Confirmed shot#3 fired. Monitor annulus on trip tank. Static. Keep drill pipe full,taking 9 bbls/hr. P/U weight baron WL, RIH 200'. Begin working pipe. Place 10 LH wraps and work 275k up&150k down. Page 78 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:15 0.25 14,096 14,096 PROD1 FISH ELNE T PJSM Prepare to fire back off shot. 400 grain @ 13,670'MD. Fire. 00:15 00:30 0.25 14,096 14,096 PROD1 FISH SFTY T Kick with wireline in the hole drill. 62 secs crew response time. 00:30 00:45 0.25 14,096 14,096 PROD1 FISH ELNE T Work string with 12k torque trapped. 8 left hand turns in the pipe. Measure torque trapped, 12k still in the string. No back off seen Unsuccessful. 00.45 05:45 5 00 14,096 14,096 PROD1 FISH ELNE T Pull out of the hole with wireline 60 feet per minute with the tractor, pulling speed Fill pipe every 15 to 30 mins.to 100'WL measurement 05:45 06:00 0.25 14,096 14,096 PROD1 FISH ELNE T Set slips-break out TD-Finish POOH w/wireline tools-Back off shot didn't fire-remove shot rod-LD Well Tec tractor tools to pipe shed 06:00 06:15 0.25 14,096 14,096 PROD1 FISH OTHR T PJSM-RU FOSV-head pin&2" low torque valve&cmt. line to fill pipe. 06:15 08:45 2.50 14,096 14,096 PROD1 FISH ELNE T Rehead wireline-MU&conduct pre run check on tractor tools&CCL(fill pipe every 15 to 30 mins.) 08:45 09:00 0.25 14,096 14,096 PROD1 FISH SFTY T PJSM w/HES&Well Tec on picking up WL tools. 09:00 09.30 0.50 14,096 14,096 PROD1 FISH PULD T PU Well Tec tractor-MU back-off shot(400 grains). 09:30 12:00 2.50 14,096 14,096 PROD1 FISH ELNE T RIH w/back off shot&tractor to 9500'(filling DP every 30 mins.) Lost 129 bbls last 12 hrs. 12:00 17:30 5.50 14,096 14,096 PROD1 FISH ELOG T Cont RIH w/Back-off shot&tractor to 12,800'-Energize tractor and cont RIH to 13,350'-began pumping © 7 bbls/min @ 280 psi to assist tractor downhole-increased pump rate to 1.5 bbls/min @ 730 psi f/ 13,548'to aid tractor to 13,725'-run CCL to get on depth for back-off shot 17:30 18.30 1.00 14,096 14,096 PROD1 FISH ELNE T With 10 to 12k torque, 2 to 10 left hand turns work string up and down. 275K up 150k down. Fire back off shot @ 13,668'WL depth. Top of stand of HWDP. Check torque after shot fire. Still had 12k 8 wraps returned 2 still down hole.Work string with 250k up, 150k down. 18:30 22 30 4.00 14,096 14,096 PROD1 FISH ELOG T POOH with 2.362"OD tractor and collar locator. 2230 22:45 0.25 14,096 14,096 PROD1 FISH SFTY T PJSM. On rig floor with all crews to lay down back off shot and tractor. 22:45 23:15 0.50 14,096 14,096 PROD1 FISH RURD T Break TD, pull wireline to surface, confirmed shot was fired Lay down tools, pick up 10'weight bar. Go in hole with WL and 10'weight bar to 200'. Page 79 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23.15 00:00 0.75 14,096 14,096 PROD1 FISH FISH T Attempt to back off.Work left hand torque down hole with 12k torque. Work pipe 275k up, 150k down. Pull up to 350k twice to look for movement. Put in 21 wraps and none were returned. Begin to see movement. Tour losses=264 bbls 37/06/2013 Work drill string-RD wireline&goose neck adapter-Cont.to work string-String came free-Establish circ- circ&condition mud-9.2 ppg in/out-Pump to 7"csg shoe-monitor well on trip tank, 8 BPH loss rate. Slip &cut DL-Pump out of the hole to 9545'MD. 54 gpm, 150 psi 00.00 01:30 1.50 14,096 14,096 PROD1 FISH OTHR T Cont to work string-275 up& 125 do-starting to see movment-pulled up to 350 k(2 X)attempt to circ @ 1.4 bbls/min 480 psi-still packed off -Check torque in string 0 torque 01:30 03:30 2 00 14,096 14,096 PROD1 FISH RURD T PJSM-RD wireline&goose neck adaptor f/TD 03 30 03:45 0.25 14,096 14,096 PROD1 FISH PRTS T Test connection where goose neck adaptor was installed to top of swivel to 3500 psi(good test) 03.45 05:15 1.50 14,096 14,096 PROD1 FISH OTHR T Remove inspection plate cover on TD -remove broken dip strick(broken while removing goose neck adaptor) 05 15 07:00 1.75 14,096 14,096 PROD1 FISH OTHR T Cont.working string-275 up 125 down-observed 4'of movement up- Added left hand torque @ 10 k torque-Work string&check torque (no torque left in string) PU to 320 k- string came free @ 06:50 hrs. 07:00 12 00 5.00 14,096 14,096 PROD1 FISH CIRC T Establish circulation-Circ& condition mud for trip out @ 2.1 bbls/min @ 350 psi-pumped 550 bbls before mud wt.was 9.2 ppg in& out-Observed no gas @ btms up- Lost approx. 80 bbls while circulating Lost 158 bbls last 12 hrs. 12:00 13 45 1 75 14,096 13,362 PROD1 FISH TRIP T PJSM on pumping out-Pumped out of hole f/14096'(bit depth assuming entire string is free-PU wt indicated 225 K)into 7"casing @ 13„362'@ 2 bbls/min @ 400 psi-Checking torque on each std. 13 45 14:15 0.50 13,362 13,362 PROD1 FISH OWFF T Monitor well-fluid level dropped 6'in 30 mins.-took 2 bbls to fill hole-4 bbls/hr static loss 14.15 14:30 0.25 13,362 13,362 PROD1 FISH SFTY T PJSM on slip&cut drill line. 14 30 16:00 1.50 13,362 13,362 PROD1 FISH SLPC T Slip&cut drill line-Cut 120'. Monitor well on trip tank-hole took 7.5 bbls. Page 80 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 00:00 8.00 13,362 9,545 PROD1 FISH TRIP T Cont. pump out of the hole f/13,362' to 9545'MD. Start @ 2 BPM, 290 PSI. 1.5 BPM, 150 PSI. Lost 162 BBL's last 12 hours. 07/07/2013 Cont. POOH w/pump f/9545'to 5260'-Observed well for static lose rate 2 bbls/hr.-POOH on TT f/5260'to surface. Found the BHA had backed off from the last string shot, @ 13,683'MD.401'fish in the hole. Conduct Bi-Weekly BOPE test. AOGCC Inspector Jeff Turkington waived witness of test 00:00 08:00 8.00 19,545 5,260 PROD1 FISH TRIP T Cont. POOH w/pump @ 1.7 bbls/min @ 100 psi f/9545'to 5260' 08:00 08:45 0.75 15,260 5,260 PROD1 FISH OWFF T Observed well for 15 mins to obtain static loss rate @ 2 bbls/hr 08:45 12:00 3.25 5,260 3,253 PROD1 FISH TRIP T POOH on TT f/6260'to 3253'-PU wt 105 SO wt 100 Lost 115 bbls last 12 hrs 12:00 16:00 4.00 3,253 0 PROD1 FISH TRIP T Cont. POOH on TT f/3253'to surface -Didn't recover any of the BHA-top of fish @ 13,694'DP measurement- 13,668'WL measurement 16:00 16:15 0.25 0 0 PROD1 FISH OWFF T Monitor well on trip tank The well bore was taking fluid.8 BPH loss rate. 16 15 18:00 1.75 0 0 PROD1 FISH RURD T Clean and clear rig floor Prepare for BOPE test 18:00 18:30 0.50 0 0 PROD1 FISH BOPE T Pull wear bushing, set test plug with FMC service hand. 18:30 00:00 5.50 0 0 PROD1 FISH BOPE T Tested BOPE as follows.w/4"test jt.tested Annular to 250&3500 psi- Tested upper 3-1/2"x 6"pipe rams, TD IBOP's,4"Floor safety&dart valves, Choke&kill line valves, Choke manifold valves# 1,2,3,4,5,6,7,8,9,10,11,12,13,14,15, & 16 and needle valve to 250&4000 psi-HCR choke and Kill-4"Demco on kill line-manual kill&choke valves-Lower 2-7/8"x 5"pipe rams to 250&4000 psi-With the 3-1/2" test joint tested annular, 250 PSI low/3500 PSI high, upper and lower variable pipe rams 250 PSI low/4000 PSI high.Annulus open and monitored during test All tests charted, 5 min/test.Jeff Turkington (AOGCC)waived witnessing tests. Continue test next tour. 07/08/2013 Finish BOP test-Pull test plug-Set wear bushing-MU fishing assembly to 503'-RIH w/fishing assembly f/ 503'to 13369'MD. CBU @ 7"casing shoe. Shoe depth= 13,433'MD.Obtain even mud weights in and out. 9.2 ppg. Page 81 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 PROD1 FISH BOPE T Performed accumulator recovery test,2900 psi start, 1350 psi end, 32 sec to 200 psi, 190 sec to 2900 psi. 4-Nitrogen bottles average 2250 psi Tested Blind rams 250/4000 psi- Tested gas alarms-With 4W test joint tested annular, 250 PSI low/ 3500 PSI high, upper and lower variable pipe rams 250 PSI low/4000 PSI high.All tests charted, 5 min/ test. Jeff Turkington(AOGCC)waived witnessing tests Performed isolated tests on air and electric systems. Close accumulators. Open UPR's, LPR's, HCR choke for each test.Time to operating pressure. Air system= lmin 4 secs. Electric system= lmin 35 secs Annulus opened and monitored on trip tank during BOPE test.10 BPH loss rate during test 02:00 02:30 0.50 0 0 PROD1 FISH RURD T Pull test plug and install 8.625'wear ring with FMC service hand 02:30 03:00 0.50 0 0 PROD1 FISH PULD T Pick up bottom hole components to rig floor. 03:00 03:45 0.75 0 30 PROD1 FISH PULD T Pick up BHA#19 as per Baker Fisherman. Screw in sub/safety joint/side rupture sub/bumper sub/ jars/XO. 03 45 04:15 0.50 30 489 PROD1 FISH PULD T Pick up 15 jts of HWDP from shed. from 30'to 489'MD. 04.15 04:30 0.25 489 503 PROD1 FISH PULD T Make up XO's and Intensifire jar. From 489'to 503' MD. 04:30 11:30 7.00 503 6,691 PROD1 FISH TRIP T Trip in the with BHA#19. Fishing assembly. From 503'to 6691'MD. 1200'/hr trip rate Calculated displacement=45 bbls Actual=-22 bbls. 11:30 12:00 0.50 6,691 6,691 PROD1 FISH SVRG T Service rig.Adjust electric brake. 12:00 18:00 6.00 6,691 11,938 PROD1 FISH TRIP T Trip in the with BHA#19. Fishing assembly From 6691'to 11938' MD. 1200'/hr trip rate. 18:00 1830 0 50 11,938 11,938 PROD1 FISH CIRC T Circulate while filling trip tank with 9.2 ppg mud. 18:30 20:00 1.50 11,938 12,936 PROD1 FISH TRIP T Trip in the hole.Tag up @ 12,936' MD. Set down 70k 20:00 2030 0.50 12,936 12,936 PROD1 FISH CIRC T Break circulation. 2 bpm,260 psi,4 bpm, 520 psi. No losses while circulating. 20:30 23:30 3.00 12,936 13,418 PROD1 FISH REAM T Ream in the hole from 12,936'to 13,418'MD. CBU @ the shoe. (13,433').4 bpm,760 psi,40 rpm, 10k torque. Page 82 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 13,418 13,433 PROD1 FISH CIRC T Circulate to even out the mud weights at the shoe.4 bpm, 760 psi, 40 rpm, 10k torque. MW in=9.2 ppg, MW out=9.4+initially. Safecarb LCM seen on the shakers. 07/09/2013 Circ&Cond mud 168 gpm 750 psi 40 rpm,wash down f/13481't/13693'tag top of fish, Engage fish,Attepmt t/jar free, unable to move fish,establish circ. 1-2 bpm 180-370 psi, continue working pipe up t/425k hook load, pull up V 300 k hook load fire jars,still unable to move fish. 00:00 00:30 0.50 13,433 13,418 PROD1 FISH CIRC T Cont. circ&cond mud @ 4 bbls/min @ 750 psi ICP-710 psi FCP w/40 rpm @ 10 k torque 00.30 02:30 2.00 13,418 13,693 PROD1 FISH WASH T Wash&ream f/13,418'to 13,661'@ 4 bbls/min @ 810 psi w/40 rpm @ 95 k torque-slide in @ tag top of fish @ 13,693'@ 4 bbls/min @ 800 psi-PU wt 200 SO wt 145(tight hole @ 13,497') 02:30 04:00 1.50 13,693 13,693 PROD1 FISH CIRC T Circ btms up @ 4 bbls/min @ 760 psi w/40 rpm @9-10ktorque- FCP 720 psi 04:00 12:00 8.00 13,693 13,693 PROD1 FISH JAR T Screw into fish-work in 10 k torque- Begin jarring on fish-w/100 k over string wt. &pulling 225 k over string wt after jars fired-Slcaking off all string wt.-hitting down w/bmuper sub,&torque to 10 k&slump drill string- keeping hole fill on annulus &fill pipe every 30 mis. (no returns) PU wt 425 SO wt 75 Lost 120 bbls last 12 hrs 12:00 00:00 12 00 13,693 13,693 PROD1 FISH JAR T Cont.working struck pipe-w/1-2 bpm 180-370 psi Jar up w/300 PUW,slump string work 10k torque into pipe,work pipe, Pull V 425 k hook load, unable to work free, continue working pipe, pump 35 bbl 9.2ppg viscosified brine sweep,work string hold 425 hook load on string no change,work pipe applying 10 k torque no change.continue working pipe. Inspect drill line&adjust brakes after 12 hrs of working pipe Shut down hole fill pump monitor well fluid level dropping in annulus- pumped down DP established circ @ 1 bbls/min @ 200 psi-unable to circ well until now lost 155 bbls for the last 12 hrs 37/10/2013 Cont.working stuck string,jarring slumping, pull to hook load of 425k, pump 56 bbl black magic pill spot out side drill pipe, let pill soak,work string jarring pull up to 475 k hook load, release from fish,CBU, Observe well f/flow well static&dropping, POOH f/13369't/10506'w/pumps 84 gpm, POOH on trip tank f/10506'U 10029' Page 83 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:15 3 25 13,693 13,693 PROD1 FISH JAR T Cont.jarring and working stuck fish- Jarring @ 300 k&then pulling up to 425 k-Hitting down w/bumper sub- Torque to 10 k&slump-circulating @ 3 bbls/min @ 500 psi 03:15 04:45 1.50 13,693 13,693 PROD1 FISH CIRC T Pumped 53 bbls Black Magic pill @ 9.2 ppg&spot into annulus thru well commander @ 2 bbls/min @ 640 psi -working string 0445 06:45 2.00 13,693 13,693 PROD1 FISH OTHR T Let BM pill soak-w/425 k PU wt f/ 1 hr.slack off to)wt&let soak for 45 mins. 06 45 09:00 2.25 13,693 13,693 PROD1 FISH JAR T Jaron fish every 15 mins @ 300 k( 100 k over string wt)then pulling up to 475 k-&bumping down w/ bumper sub-NO pipe movement Fishing operation suspended as per Anchorage Drilling staff 09:00 09:15 0.25 13,693 13,686 PROD1 FISH OTHR T Release from safety jt w/20 turns to left& 11 k torque Top of fish @ 13,686' Fish in hole-6"bit-4 3/4"GT steering head-Mod Stab-Azi Trak- Mod stab-BCPM-Co-Pilot-Stop sub-float sub-filter sub-NMCSDP -Well commander-XO-4 jts 4" HWDP-jars-1 jt 4' HWDP- Bumper sub-3 jts.4'HWDP-4" XT39 screw-in sub-lower half of safety jt -total length 410" 09:15 12:00 2.75 13,686 13,686 PROD1 FISH CIRC T Circ&condition mud @ 3 bbls/min @520 to 610 psi w/40 rpm @10k torque-observed approx 7 bbls of Back Magic pill @ shakers- continue to circ and condition-Mu vis sweep&circ around 12:00 15:15 3.25 13,686 13,686 PROD1 FISH CIRC T Circ. Hi-Vis 35 bbl sweep @ 126 gpm 50 RPM 10 k tq 15:15 15:30 0.25 13,686 13,686 PROD1 FISH OWFF T Observe well for flow well static. static in 4 min dropping in stack 15:30 16.15 0.75 13,686 13,369 PROD1 FISH TRIP T POOH w/pumps 84 gpm 270 psi f/ 13686't/13369' 16:15 17:00 0.75 13,369 13,369 PROD1 FISH OWFF T Observe well for flow well static, perform derrick inspection. 17:00 23.00 6.00 13,369 10,506 PROD1 FISH TRIP T POOH w/pumps 84 gpm 250 psi f/ 13369't/10506' 23:00 00:00 1 00 10,506 10,029 PROD1 FISH TRIP T POOH on trip tank f/10506't/10029' 07/11/2013 POOH f/10029't/500', L/D BHA, L/D 62 stands of 4"dp via mouse hole while waiting on packer f/baker, R/U &Run Completion t/244' Page 84 of 87 Time Logs Date From To Dur S. Depth E. Depth_Phase Code Subcode T Comment 00:00 07:00 7.00 10,029 3,355 PROD1 FISH TRIP T Cont. POOH on TT w/fishing assembly f/10,029'to 3355' PU wt 115 SO wt 105 07:00 07:45 0.75 3,355 3,355 PROD1 FISH CIRC T Circ to even mud wt. 9.2 ppg in&out @ 3 bbls/min @ 120 psi(Observed- well static) 07:45 11:15 3 50 3,355 500 PROD1 FISH TRIP T Cont. POOH on TT f/3355'to 500'- Observe well @ 2402'-well static 11:15 11:30 0.25 500 500 PROD1 FISH OWFF T Monitor well for 15 mins-fluid level dropped 2 5' 11:30 12:30 1.00 500 0 PROD1 FISH PULD T LD-XO, intensifire,XO &15 jts 4" HWDP,fishing jars, bumper sub,circ sub,&top half of safety jt 12:30 13:00 0.50 0 0 PROD1 FISH PULD T Clear rig floor of Baker fishing tools 13:00 13:15 0.25 0 0 COMPZ RPCOM SFTY X PJSm on LD 4"DP f/derrick via mouse hole 13:15 20:45 7.50 0 0 COMPZ RPCOM PULD X LD 4"DP f/derrick via mouse hole while waiting on Baker packer assembly to arrive f/Deadhorse(62 stands) 20.45 21:45 1.00 0 0 COMPZ RPCOM RURD P R/U t/Run completion, Pull wear ring. 21:45 22:00 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on Running completion 22:00 00.00 2.00 0 244 COMPZ RPCOM RCST P Run Completion Assy. as per detail. t/244' 37/12/2013 Continue RIH w/3 1/2"/4 1/2"completion as per completion detail t/11625'M/U&test SSSV, RIH w/ completion t/13190'take weight 12k work string,establish circ @ 84 gpm 230 psi, Continue RIH working string t/13295'. 00:00 12:00 12.00 244 7,500 COMPZ RPCOM RCST P Continue RIH w/3 1/2"/4 1/2" completion-Ran 11 jts. 3 1/2"9.3# L-80 EUE-3 1/2"9.3#L-80 EUE pup jt-3 1/2"EUE XN nipple w/RHC plug-XO sub 3 1/2" EUE x 4 1/2" Hyd 563- Baker Premier packer assembly-4 1/2"XN nipple-4 1/2" 126# L-80Hyd 563 pup jt- 12 jts 4 1/2" 12 6#L-80 Hyd 563 tbg-Camco GLM assembly-83 jts 4 1/2" 12.6# L-80 Hyd 563 tbg-XO 4 1/2" Hyd 563 x 4 1/2"I BT-94 jts 4 1/2" 12.6# L-80 IBTM tbg 12:00 16:00 4.00 7,500 11,434 COMPZ RPCOM RCST P Continue RIH w/3 1/2"x 4 1/2" completion- 128 jts(222jts total)of 4 1/2" 12.6#L-80 IBTm tbg to 11,434' 16:00 17:00 1.00 11,455 111,455COMPZ RPCOM RCST P Bring control line spool&tools boxes to rig floor& RU-control lines t/SSSV&test lines t/5000 psi f/10 min. 17:00 22.30 5.50 11,455 13,280 COMPZ RPCOM RCST P Continue RIH w/3%-4'/completion - jts 4%IBT12.6#L-80 f/11455 t/ 13280'work through tight spots f/ 13190't/13280'take 12k weight working string. 22:30 23:15 0.75 13,280 13,280 COMPZ RPCOM CIRC P Stage pumps t/84 gpm 230 psi 50 bbls pumped, reciprocate pipe. Page 85 of 87 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23 15 00 00 0.75 13,280 13,295 COMPZ RPCOM RCST P Continue Working through tight spots f/13280't/13295'take 12k weight. 07/13/2013 Cont.Working tubing through tight spots f/13295 t113337',Wash tubing down t/13346'taking 12k wt, L/D 2 jts M/U hanger terminate conrol line through hanger,test line t/5000 psi, Land tubing on hanger @ 13340' RILDS, Displace well w/9 2 ppg brine, Spot Corr lnhb. Brine, Drop Ball&rod set packer, Pressure test tubing&casing,t/3500 psi shear DCK valve, Nipple down stack nipple up tree and adaptor. 00:00 03:00 3.00 13,295 13,337 COMPZ RPCOM RCST P Continue work tubing through tight spots f/13295't/13337'taking weight 12k 03'00 04.30 1.50 13,337 13,346 COMPZ RPCOM RCST P Establish circ stage t/126 gpm 300 psi wash string down f/13337't/ 13346' 04:30 05:45 1.25 13,346 13,306 COMPZ RPCOM RCST P L/D 2 jts tubing, M/U hanger terminate control line through hanger, test line t/5000 psi f/5 min. 05.45 06 15 0.50 13,306 13,340 COMPZ RPCOM RCST P RIH w/hanger land on hanger @ 13340' RILDS 06 15 07.30 1.25 13,340 13,340 COMPZ RPCOM RURD P R/U squeeze Manifold&lines t/ displace 07:30 08:00 0.50 13,340 13,340 COMPZ RPCOM SFTY P Pre Job Safety Meeting on displacing well t/brine. 08:00 12:00 4.00 13,340 13,340 COMPZ RPCOM CIRC P Displace well t/9.2 ppg brine, pump 36 bbl hi vis spacer, followed by 582 bbls brine @ 126 gpm ICP-580 FCP-420 12:00 12:30 0.50 13,340 13,340 COMPZ RPCOM OWFF P Observe well f/flow f/30 min well static 12:30 14:00 1.50 13,340 13,340 COMPZ RPCOM CIRC P Spot 12.7 bbls Corrosion Inhibited Brine, spot w/198 bbls brine @ 126 gpm 430 psi 14:00 14:30 0.50 13,340 13,340 COMPZ RPCOM PACK P Drop Ball&Rod wait 15 min Set packer as per Baker Rep. 14:30 16:45 2 25 13,340 0 COMPZ RPCOM PRTS P Test tubing t/3500 psi f/30 min. Bleed off tubing t/2200 psi, Pressure up annulus t/3500 psi, pressure bleeding off t/tubing, Bleed off ann& tubing, Pressure up on both annulus &tubing t/3500 psi hold f/30 min. Shear out valve leaking, Bleed off tubing pressure shear DCK valve. 16:45 17:45 1 00 0 0 COMPZ RPCOM OTHR P Blow down&Rig down lines, Pull landing jt set TWC. 17:45 19:00 1.25 0 0 COMPZ RPCOM PRTS P R/U&test TWC in direction of flow t/ 3000 psi f/10 min. 19:00 19:45 0.75 0 0 COMPZ RPCOM OTHR P R/D Lines&test equipmnet, R/D cellar lines. 19:45 20:00 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety meeting on Nippling down stack nippling up tree. 20:00 22.15 2.25 0 0 COMPZ WHDBO NUND P Nipple down riser&stack and DSA spool 22:15 00:00 1.75 0 0 COMPZ WHDBO NUND P Nipple up tree and adaptor flange. 1 07/14/2013 NU&test tree-Pull TWC-RU&pump freeze protect diesel 85 bbls-RD lines-MU FMC lubricator&test to 1000 psi-Set BPV&test to 3000 psi in direction of flow-Secure well-LD 4"DP f/derrick-Change SS in TD&arab head-S&C drill line 75'-LD tools f/rig floor-Released Rig @ 2359 hrs - 00:00 00:30 0.50 0 0 COMPZ RPCOM NUND P Cont. NU tree Page 86 of 87 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:30 1.00 0 0 COMPZ RPCOM PRTS P Pressure test tbg hanger seal&void to 5000 psi for 10 mins-tested tre to 5000 psi for 10 mins 01:30 02:00 0.50 0 0 COMPZ RPCOM OTHR P Pull TWC 02:00 02:45 0.75 0 0 COMPZ RPCOM RURD P RU lines to tbg&annulus for freeze protect 02:45 04.30 1.75 0 0 COMPZ RPCOM FRZP P PJSM-fill lines-test lines to 2500 psi(Good test)-Dowell pumped 85 bbls diesel down annulus @ 2 bbls/min @ 2300 psi-Shut down- Line up squeeze manifold&U-tube diesel f/annulus to tbg side for 1 hrs. -shut in w/200 psi 04:30 05:30 1.00 0 0 COMPZ RPCOM RURD P Flush&blow down lines&squeeze manifold-RD lines&maniflod 05:30 06:15 0.75 0 0 COMPZ RPCOM RURD P RU FMC lubricator&test to 1000 psi -Set BPV-RD lubricator 06:15 06:45 0.50 0 0 COMPZ RPCOM PRTS P Test BPV in direction of flow to 3000 psi for 10 mins.(good test) 06:45 07:45 1.00 0 0 COMPZ RPCOM OTHR P Secure well-Shut W/0 psi on OA& 30 psi on IA 07:45 12:00 4.25 0 0 COMPZ RPCOM PULD P PJSM-LD 4" DP f/derrick via mouse hole 12:00 21:30 9.50 0 0 COMPZ RPCOM PULD P Finish LD 4' DP f/derrick via mouse hole 21:30 22:15 0.75 0 0 COMPZ RPCOM OTHR P Change save sub f/4"XT39 to 4 1/2" IF-Change grab head to 5" 22:15 23:15 1.00 0 0 COMPZ RPCOM SLPC P PJSM-Slip&cut drill line 75' 23:15 00:00 0.75 0 0 COMPZ RPCOM OTHR P LD tools f/rig floor for move Release rig @ 2359 hrs 7/14/2013 Prep to move rig to CD4-292 II Page 87 of 87 • C1-49 Cement Detail Report CD1-49 ConocoPhillips String: Conductor Cement Job: DRILLING ORIGINAL,1/10/2013 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 4/24/2003 01:00 4/25/2003 08:00 CD1-49 Comment First stage 0100 hrs 4/24/2003. Second stage 0800 hrs 4/25/2003. Cement Type II 3000 psi.CIP 0800 hrs 4/25/2003. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btm Plug? Conductor Cement No Yes No Q Pump Inst(bbllm...Q Pump Final(bbll...0 Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(1KB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(Maack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pas) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btm Plug? Conductor Cement No No No 0 Pump mit(bbllm...0 Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(pal) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(11KB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(f'lsack) Mix H2O Ratio(gauss... Free Water(%) Density(Iblgal) Plastic Viscosity(Prs) 'Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 7/10/2014 zip—/ F"" 0Cement Detail Report 0„;,,, CD1-49 ConocoPhillips String: Cement Plug#1 Job: DRILLING ORIGINAL, 1/10/2013 08:00 Cement Details Description Cementing Start Date Cementing End Date Weilbore Name Cement Plug#1 1/18/2013 05:42 1/18/2013 06:53 CD1-49PB1 Comment Set 1st stage plug as follows:w/3 1/2"tbg stinger set©1284'- Pumped 1 bbls 11 ppg mud push-Test lines to 3000 psi-Pumped 40 bbls 11 ppg©3.5 bbls/min @ 125 psi-Mixed&pumped 191 bbls 15.7 ppg AS1@ 4.5 bbls/min©150 psi-Pumped 2 bbls mud push behind-Switched to rig pump&displaced w/4.5 bbls of spud mud©9.0 ppg-CIP©0653 hrs.-Full returns while pumping job-Ck for balance OK Cement Stages Stage*<Stage Number?> Description Objective Top Depth(ftKB) !Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btm Plug? Cement Plug 779.0 1,284.0 No No No Q Pump Mit(bbllm...Q Pump Final(bbil...Cl Pump Avg(bbU... P Pump Final(psi) P Plug Bump(pal) Reclp? Stroke(ft) Rotated? Pipe RPM(rpm) 4 4 4 100.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 674.0 Tubing Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush _ 668.0 779.0 41.0 Yield(ft'Isack) Mix H2O Ratio(gailss... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 779.0 1,284.0 1,148 G 191.0 Yield(ft/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 0.93 3.51 15.70 Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 7/10/2014 Z , 2 -174- Cement Detail Report ►�1 CD1-49 ConocoPhillips String: Cement Plug#2 Job: DRILLING ORIGINAL, 1/10/2013 08:00 Cement Details Description Cementing Start Date Cementing End Date Weilbore Name Cement Plug#2 1/19/2013 00:01 1/19/2013 00:52 CD1-49PB1 Comment Set 2nd stage plug as follows:w/3 1/2"tbg stinger set @ 674'- Pumped 1 bbls 11 ppg mud push-Test lines to 3000 psi-Pumped 38.5 bbls 11 ppg @ 5.1 bbls/min @ 100 psi-Mixed&pumped 143.0 bbls 15.75 ppg AS1@ 5.1 bbls/min @ 200 psi-Pumped 2 bbls mud push behind- CIP @ 00:52 hrs.-Full returns while pumping job-Ck for balance OK Cement Stages Stage#<Stage Number?> Description Objective Top Depth(WS) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Cement Plug 295.9 674.0 Yes 0.0 No No 0 Pump mit(bbilm...Q Pump Final(bbl/...Q Pump Avg(bbil... P Pump Final(pal) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 4 4 200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 342.0 Tubing Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbi) Pre Flush 187.5 295.9 41.0 Yield(Maack) Mix H2O Ratio(gauss... Free Water(%) Density(Iblgal) Plastic Viscosity(Prs) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 295.9 674.0 860 G 143.0 Yield(Maack) Mix H2O Ratio(galisa... Free Water(%) Density(Iblgal) Plastic Viscosity(Prs) Thickening Time(hr) CmprStr 1(psi) 0.93 3.51 15.70 Additives Additive Type Concentration Conc Unit label Page 1l1 Report Printed: 7/10/2014 Cement Detail Report Dry Ny°°^qi%,„, }, CD1-49 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/10/2013 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/23/2013 14:33 1/23/2013 16:51 CD1-49 Comment Circ&cond mud for cmt job-Stage pump up to 8 bbls/min-ICP 1.5 bbls/min©290 psi-FCP 8 bbls/min©440 psi Attempted to reciprocate pipe pulled up tight w/hanger coming off seat©21"-Pulled 45 over Landed hanger back on landing ring. Held pre job safety meeting w/rig crew,cementrs,truck drivers,ball mill&mud engineers-cementing 11 3/4'casing. Con't to circ&cond mud for cmt job-pumping 8 bbls/min-w/440 psi..Mud wt 9.9+,vis 70-75.Circ a total of 880 bbls after casing was on bottom. Rig pump 100 bbls of 9.9 ppg mud w/5 ppb medium nut plug marker,pumping 8 bpm w/430 psi.Follow w/33 bbls of Biozan water(2.5 ppb Biozan)w/5 ppb medium nut plug marker,pumped @ 3 to 5 bpm w/90-180 psi.Dowell pump pump water to rig floor,press test lines to 3500 psi-OK.Batch up 10.5 ppb MudPush @ 10.5 ppg.Dowell pump 52.4 bbls of 10.5 ppg MudPush @ 5.8 bpm w/200 to 220 psi.Shut down,drop bottom plug.Batch up 10.7 ppg ASL cement (yield 2.45 cuft/sx,mix water 11.513 gal/sx, 110#sx blend).Dowell pumping 348.5 bbls(799 sx)of 10.7 ppg ASL lead cement(yield 2.45 cuft/sx,mix water 11.513 gal/sx, 110#sx blend).Pumped @ avg 6.8 bpm,inital 250 psi,final @ 7.1 bpm w/350 psi.Batch up Tail cement.Dowell pumping 74.2 bbls(359 sx)of 15.7 ppg tail cement(yield 1.16 cuft/sx,mix water 5.125 gal/sx.Additives:.2%BWOC D046 Antifoam, .3%BWOC D065 Dispersant,.8%BWOC S002 Accelerant).Pumped @ avg 4.5 bpm,inital 300 psi,final©4.5 bpm w/250 psi.Shut down,drop top plug.Dowell kick out top plug w/20 bbls water-wash up thin the tub.Pumping 6.1 to 6.6 bpm w/300 to 370 psi.Shut down.Rig pumped 9.8 ppg 6%KCUNaCI brine©8bpm w/580 psi initial rate.Once 310 bbls were pumped,slowed to 3 bpm w/830 psi.Bumped plug w 1260 psi(3186 strokes).Held f/5 minutes-OK,bleed pressure to check floats-OK.CIP©1651 hrs 1/23/2013. Full retums.Did not reciprocate for hanging up in the stack.168.6 bbls cement retums to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth MKS) Full Return? Vol Cement..Top Plug? Btm Plug? Surface Casing Cement 38.0 3,123.0 Yes 168.0 Yes Yes Q Pump!nit(bbi/m...Q Pump Final(bbil..,Q Pump Avg(bbi/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 4 8 850.0 1,260.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(In) Comment Circ&cond mud for cmt job-Stage pump up to 8 bbls/min-ICP 1.5 bbls/min©290 psi-FCP 8 bbls/min @ 440 psi Attempted to reciprocate pipe pulled up tight w/hanger coming off seat©21"-Pulled 45 over Landed hanger back on landing ring. Held pre job safety meeting w/rig crew,cementrs,truck drivers,ball mill&mud engineers-cementing 11 3/4'casing. Con't to circ&cond mud for cmt job-pumping 8 bbls/min-w/440 psi..Mud wt 9.9+,vis 70-75.Circ a total of 880 bbls after casing was on bottom. Rig pump 100 bbls of 9.9 ppg mud WI 5 ppb medium nut plug marker,pumping 8 bpm w/430 psi.Follow w/33 bbls of Biozan water(2.5 ppb Biozan)w/5 ppb medium nut plug marker,pumped©3 to 5 bpm w/90-180 psi.Dowell pump pump water to rig floor,press test lines to 3500 psi-OK.Batch up 10.5 ppb MudPush @ 10.5 ppg.Dowell pump 52.4 bbls of 10.5 ppg MudPush @ 5.8 bpm w/200 to 220 psi.Shut down,drop bottom plug.Batch up 10.7 ppg ASL cement (yield 2.45 cuft/sx,mix water 11.513 gal/sx, 110#sx blend).Dowell pumping 348.5 bbls(799 sx)of 10.7 ppg ASL lead cement(yield 2.45 cuft/sx,mix water 11.513 gal/sx, 110#sx blend).Pumped©avg 6.8 bpm,inital 250 psi,final @ 7.1 bpm w/350 psi.Batch up Tail cement.Dowell pumping 74.2 bbls(359 sx)of 15.7 ppg tail cement(yield 1.16 cuft/sx,mix water 5.125 gal/sx.Additives: .2%BWOC D046 Antifoam,.3%BWOC D065 Dispersant, .8%BWOC S002 Accelerant).Pumped @ avg 4.5 bpm,inital 300 psi,final©4.5 bpm w/250 psi.Shut down,drop top plug.Dowell kick out top plug w/20 bbls water-wash up thru the tub.Pumping 6.1 to 6.6 bpm w/300 to 370 psi.Shut down.Rig pumped 9.8 ppg 6%KCL/NaCI brine©8bpm w/580 psi initial rate.Once 310 bbls were pumped,slowed to 3 bpm w/830 psi.Bumped plug w 1260 psi(3186 strokes).Held f/5 minutes-OK,bleed pressure to check floats-OK.CIP @ 1651 hrs 1/23/2013. Full returns.Did not reciprocate for hanging up in the stack. 168.6 bbls cement retums to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Eat Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 38.0 2,408.0 797 G 348.0 Yield(ft'Isack) Mix H2O Ratio(gaUaa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pas) Thickening Time(hr) CmprStr 1(psi) 2.45 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(WI) Tail Cement 2,408.0 3,108.0 350 G 74.0 Yield(fP/sack) Mix H2O Ratio(gaUsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pas) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Page 111 Report ort Printed: 7/1012014 ! / 7-q 0::.''1,. ' 't': ' , Cement Detail Report 1....1 . CD1-49 �r ConocoPhillips String: Liner Cement Job: DRILLING ORIGINAL,1/10/2013 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Liner Cement 5/18/2013 12:30 5/18/2013 16:23 CD1-49 Comment Circ.&Cond.Mud f/cement job,stage pumps U 250 gpm 510 psi.Pre Job safety meeting on cement job.Dowell pressure test lines U 4000 psi,dowel)pump 40 bbls CW100,48 bbls 11 ppg mudpush spacer,219 bbls 12.2 ppg lead cement w/cemnet in first 75 bbls, 166 bbls of 15.8 tail cement,Drop plug, 10 bbls water, 682 bbls of mud U bump plug P/U plug©30.7 bbls pumped,CIP 1623 hrs,pressure up U 3500 psi,bleed off release f/liner hanger and set liner top paker as per BOT.Close annular&pump down kill line&test liner top packer U 1000 psi f/10 min. Cement Stages Stage#1 Description Objective Top Depth MKS) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Liner Cement 6,069.0 11,758.0 No 0.0 Yes No ct Pump mit(bbllm...0 Pump Final(bbl/...0 Pump Avg(bbil... P Pump Final(pal) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 3 6 1,150.0 980.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(In) 11,633.0 Drill Bit 11,758.0 8 1/2 1 Comment Circ.&Cond.Mud f/cement job,stage pumps U 250 gpm 510 psi.Pre Job safety meeting on cement job.Dowell pressure test lines U 4000 psi,dowel)pump 40 bbls CW100,48 bbls 11 ppg mudpush spacer,219 bbls 12.2 ppg lead cement w/cemnet in first 75 bbls, 166 bbls of 15.8 tail cement,Drop plug, 10 bbls water, 682 bbls of mud U bump plug P/U plug @ 30.7 bbls pumped,CIP 1623 hrs,pressure up U 3500 psi,bleed off release f/liner hanger and set liner top paker as per BOT.Close annular&pump down kill line&test liner top packer U 1000 psi V 10 min. Cement Fluids&Additives Fluid I Fluid Type Fluid Description Estimated Top(ftKB) Eat Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 6,069.0 9,350.0 535 G 218.0 Yield(ft'laack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 2.30 12.20 0.0 5.00 Additives Additive Type Concentration Cone Unit label Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label Extender 3.0 %BWOC Additive Type Concentration Conc Unit label Retarder 0.4 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Eat Btm(ftKB) Amount(sacks) Class Volume Pumped(bbi) Tail Cement 9,350.0 11,758.0 801 G 166.0 Yield(n'Isack) Mix H2O Ratio(gauss... Free Water(%) Density(lb/gal) Plastic Viscosity(Pees) Thickening Time(hr) CmprStr 1(pal) 1.17 15.80 0.1 Additives Additive Type Concentration Conc Unit label Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant 0.3 %BWOC Additive Type Concentration Cone Unit label Fluid Loss Control 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder 0.11 %BWOC Fluid Fluid Type Fluid Description Estimated Top(ftKB) Eat Btm(ttKB) Amount(sacks) Class Volume Pumped(bbl) MudPush 2,949.0 6,069.0 48.0 Yield(ft'lsack) Mix H2O Ratio(gallss... Free Water(%) Density(lb/gal) Plastic Viscosity(Pas) Thickening Time(hr) CmprStr 1(psi) 11.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 7/10/2014 12iq- — of Cement Detail Report ..,..it. :. . ..: = CD1-49 C000coPhil l ips String: CMT SQZ Job: DRILLING ORIGINAL, 1/10/2013 08:00 Cement Details Description Cementing Start Date Cementing End Date -Wellbore Name CMT SQZ 6/17/2013 00:45 6/17/2013 03:00 CD1-49 Comment CMT Liner as per detail,close annular&line up through choke dowel/flood lines&test lines U 3000 psi,pump 11.1 bbls mud push,50 bbls 15.8 ppg CMT, chase w/155 bbls drilling mud,holding back 400 psi back pressure,sting into retainer,bleed off back pressure open annular,Pump33bbls,ICP.3 bpm 970 psi FCP 1120 psi,214 bbl total dispalcement.CIP 0300 hrs Cement Stages Stage#1 Description Objective Top Depth(RKB) Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btrn Plug? CSG CMT 13,306.0 No No No 0 Pump Mit(bbllm...0 Pump Final(bbl/...0 Pump Avg(bbl/... P Pump Final(pel) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 2 2 580.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(fIKB) Drill Out Diameter(In) Comment CMT Liner as per detail,close annular&line up through choke dowell flood lines&test lines U 3000 psi,pump 11.1 bbls mud push,50 bbls 15.8 ppg CMT, chase w/155 bbls drilling mud,holding back 400 psi back pressure,sting into retainer,bleed off back pressure open annular,Pump 59 bbls,ICP.3 bpm 970 psi FCP 1120 psi,214 bbl total dispalcement.CIP 0300 hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(itKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 13,306.0 11,758.0 242 G 50.0 Yield(ft'Isack) Mix H2O Ratio(gaUsa... Free Water(%) Density(Iblgal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(pal) 1.17 15.80 0.1 Additives Additive Type Concentration Cone Unit label Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant 0.3 %BWOC Additive Type 'Concentration Conc Unit label I Fluid Loss Control 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder 0.11 %BWOC Fluid Fluid Type Fluid Description Estimated Top(fIKB) Est Btm(MB) Amount(sacks) Class Volume Pumped(bbi) MudPush 11.1 1 Yield(ft'/sack) Mix H2O Ratio(gauss... Free Water(%) Density(ib/gal) Plastic Viscosity(Pars) 'Thickening Time(hr) CmprStr 1(psi) 11.50 Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 7/10/2014 Cement Detail Report 0 CD1-49 ConocoPhillips String: PROD CSG TIE BACK Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name PROD CSG TIE BACK 6/22/2013 00:00 6/22/2013 00:00 CD1-49 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(itKB) Full Return? Vol Cement..Top Plug? Btm Plug? PROD CSG TIE BACK 33.3 11,338.0 Q Pump knit(bbl/m...Q Pump Final(bbU...0 Pump Avg(bbU... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftMB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description ;Estimated Top(ftKB) Est Btm(ttKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ftlsack) Mix H2O Ratio(gaUsa... Free Water(1) Density(Ib/gal) Plastic Viscosity(Paps) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 7/10/2014 ConocoPhillips(Alaska) Inc. NAD27 Western North Slope CD1 Alpine Pad CD1-49 API:501032066100 - PTD:212-177 Sperry Drilling Services Definitive Survey Report 19 July, 2013 HALLIBURTON Sperry Drilling Services Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db Project Western North Slope,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 Well CD1-49 Well Position +N/-S 153,878.58 ft Northing: 5,975,565.51 ft Latitude: 70°20'31.53 N +EI-W -1,128,341.89 ft Easting: 385,660.62 ft Longitude: 150°55 40.630 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50 ft Wellbore CD1-49 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 6/24/2013 14.97 79.79 57,327 Design CD1-49 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 420.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 35.99 153,878.58 1,128,341.8 150.00 Survey Program Date 7/19/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 72.00 420.00 CD1-49PB1 Gyro(CD1-49PB1) GYD-GC-SS Gyrodata gyro single shots 01/12/2013 450.00 817.00 GYD-GC-SS(CD1-49) GYD-GC-SS Gyrodata gyro single shots 01/20/2013 889.80 15,237.15 MWD-IFR-AK-CAZ-SC(CD1-49) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/20/2013 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 35.99 0.00 0.00 35.99 -19.50 153,878.58 -1,128,341.89 5,975,565.51 385,660.62 0.00 0.00 UNDEFINED 72.00 0.01 65.18 72.00 16.51 153,878.58 -1,128,341.89 5,975,565.51 385,660.63 0.03 0.00 GYD-GC-SS(1) 100.00 0.08 215.43 100.00 44.51 153,878.56 -1,128,341.90 5,975,565.49 385,660.62 0.32 0.01 GYD-GC-SS(1) 130.00 0.12 228.79 130.00 74.51 153,878.52 -1,128,341.93 5,975,565.45 385,660.59 0.15 0.02 GYD-GC-SS(1) 172.00 0.23 177.57 172.00 116.51 153,878.41 -1,128,341.96 5,975,565.34 385,660.58 0.43 0.11 GYD-GC-SS(1) 200.00 0.41 161.38 200.00 144.51 153,878.26 -1,128,341.93 5,975,565.19 385,660.63 0.71 0.25 GYD-GC-SS(1) 230.00 0.57 170.92 230.00 174.51 153,878.01 -1,128,341.87 5,975,564.95 385,660.72 0.60 0.50 GYD-GC-SS(1) 265.00 0.90 154.18 265.00 209.51 153,877.59 -1,128,341.72 5,975,564.55 385,660.92 1.12 0.94 GYD-GC-SS(1) 300.00 1.10 155.92 299.99 244.50 153,877.04 -1,128,341.47 5,975,564.04 385,661.25 0.58 1.54 GYD-GC-SS(1) 330.00 1.34 159.69 329.98 274.49 153,876.45 -1,128,341.23 5,975,563.48 385,661.57 0.84 2.18 GYD-GC-SS(1) 359.00 1.71 158.95 358.97 303.48 153,875.72 -1,128,340.95 5,975,562.81 385,661.94 1.28 2.94 GYD-GC-SS(1) 390.00 1.86 166.14 389.96 334.47 153,874.80 -1,128,340.67 5,975,561.93 385,662.35 0.87 3.88 GYD-GC-SS(1) 7/19/2013 3:21:37PM Page 2 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 420.00 2.06 168.79 419.94 364.45 153,873.80 -1,128,340.45 5,975,560.97 385,662.70 0.73 4.86 GYD-GC-SS(1) 450.00 2.82 180.93 449.91 394.42 153,872.54 -1,128,340.35 5,975,559.72 385,662.97 3.05 6.00 GYD-GC-SS(2) 480.00 2.90 188.75 479.88 424.39 153,871.05 -1,128,340.48 5,975,558.23 385,663.04 1.33 7.23 GYD-GC-SS(2) 510.00 3.35 196.13 509.83 454.34 153,869.46 -1,128,340.84 5,975,556.60 385,662.90 2.01 8.42 GYD-GC-SS(2) 540.00 4.44 199.55 539.76 484.27 153,867.52 -1,128,341.47 5,975,554.60 385,662.53 3.71 9.79 GYD-GC-SS(2) 572.00 6.03 200.94 571.63 516.14 153,864.78 -1,128,342.49 5,975,551.74 385,661.90 4.98 11.65 GYD-GC-SS(2) 602.00 8.03 200.88 601.40 545.91 153,861.35 -1,128,343.80 5,975,548.17 385,661.06 6.67 13.96 GYD-GC-SS(2) 632.00 10.17 201.25 631.02 575.53 153,856.92 -1,128,345.50 5,975,543.54 385,659.96 7.14 16.94 GYD-GC-SS(2) 665.00 12.14 201.38 663.40 607.91 153,850.98 -1,128,347.83 5,975,537.33 385,658.47 5.97 20.93 GYD-GC-SS(2) 695.00 13.66 200.94 692.64 637.15 153,844.73 -1,128,350.24 5,975,530.81 385,656.91 5.08 25.13 GYD-GC-SS(2) 725.00 15.67 200.28 721.66 666.17 153,837.62 -1,128,352.91 5,975,523.40 385,655.22 6.72 29.96 GYD-GC-SS(2) 757.00 16.82 198.61 752.38 696.89 153,829.18 -1,128,355.89 5,975,514.62 385,653.41 3.88 35.78 GYD-GC-SS(2) 787.00 18.68 198.01 780.95 725.46 153,820.50 -1,128,358.76 5,975,505.62 385,651.74 6.23 41.86 GYD-GC-SS(2) 817.00 19.75 197.89 809.28 753.79 153,811.10 -1,128,361.80 5,975,495.89 385,649.99 3.57 48.48 GYD-GC-SS(2) 919.64 22.05 198.17 905.16 849.67 153,776.29 -1,128,373.14 5,975,459.83 385,643.44 2.24 72.96 MWD+IFR-AK-CAZ-SC(3) 948.67 22.92 198.19 931.98 876.49 153,765.74 -1,128,376.60 5,975,448.90 385,641.43 3.00 80.36 MWD+IFR-AK-CAZ-SC(3) 1,040.71 25.50 190.67 1,015.94 960.45 153,729.23 -1,128,385.87 5,975,411.43 385,637.17 4.36 107.35 MWD+IFR-AK-CAZ-SC(3) 1,092.85 27.44 187.01 1,062.62 1,007.13 153,706.27 -1,128,389.41 5,975,388.18 385,636.76 4.86 125.46 MWD+IFR-AK-CAZ-SC(3) 1,135.90 30.53 185.95 1,100.27 1,044.78 153,685.55 -1,128,391.76 5,975,367.30 385,637.23 7.28 142.23 MWD+IFR-AK-CAZ-SC(3) 1,186.65 32.11 185.12 1,143.62 1,088.13 153,659.29 -1,128,394.30 5,975,340.91 385,638.26 3.23 163.70 MWD+IFR-AK-CAZ-SC(3) 1,229.88 35.23 184.04 1,179.60 1,124.11 153,635.40 -1,128,396.20 5,975,316.96 385,639.59 7.35 183.44 MWD+IFR-AK-CAZ-SC(3) 1,324.58 37.80 185.87 1,255.70 1,200.21 153,579.28 -1,128,401.10 5,975,260.63 385,642.32 2.95 229.60 MWD+IFR-AK-CAZ-SC(3) 1,418.06 40.07 182.71 1,328.42 1,272.93 153,520.71 -1,128,405.45 5,975,201.95 385,645.91 3.23 278.14 MWD+IFR-AK-CAZ-SC(3) 1,511.51 42.49 183.04 1,398.64 1,343.15 153,459.14 -1,128,408.55 5,975,140.45 385,651.15 2.60 329.91 MWD+IFR-AK-CAZSC(3) 1,605.37 45.48 182.35 1,466.17 1,410.68 153,394.04 -1,128,411.60 5,975,075.46 385,656.92 3.23 384.77 MWD+IFR-AK-CAZSC(3) 1,699.75 48.71 180.58 1,530.42 1,474.93 153,324.95 -1,128,413.34 5,975,006.69 385,664.52 3.69 443.73 MWD+IFR-AK-CAZ-SC(3) 1,794.39 51.56 178.11 1,591.08 1,535.59 153,252.33 -1,128,412.48 5,974,934.77 385,675.19 3.62 507.06 MWD+IFR-AK-CAZ-SC(3) 1,889.14 51.77 178.61 1,649.85 1,594.36 153,178.04 -1,128,410.35 5,974,861.37 385,687.33 0.47 572.46 MWD+IFR-AK-CAZ-SC(3) 1,983.06 52.60 179.10 1,707.43 1,651.94 153,103.86 -1,128,408.87 5,974,787.98 385,698.82 0.98 637.44 MWD+IFR-AK-CAZ-SC(3) 2,076.89 53.70 177.33 1,763.70 1,708.21 153,028.81 -1,128,406.52 5,974,713.86 385,711.28 1.91 703.60 MWD+IFR-AK-CAZ-SC(3) 2,170.59 55.10 177.72 1,818.25 1,762.76 152,952.70 -1,128,403.23 5,974,638.81 385,724.82 1.53 771.16 MWD+IFR-AK-CAZ-SC(3) 2,264.92 54.09 177.53 1,872.90 1,817.41 152,875.88 -1,128,400.05 5,974,563.04 385,738.35 1.08 839.28 MWD+IFR-AK-CAZ-SC(3) 2,358.35 55.58 178.35 1,926.71 1,871.22 152,799.55 -1,128,397.31 5,974,487.70 385,751.38 1.75 906.75 MWD+IFR-AK-CAZ-SC(3) 2,453.71 53.02 177.07 1,982.35 1,926.86 152,722.18 -1,128,394.23 5,974,411.37 385,764.88 2.90 975.30 MWD+IFR-AK-CAZ-SC(3) 2,547.87 53.37 178.36 2,038.76 1,983.27 152,646.86 -1,128,391.22 5,974,337.05 385,778.04 1.16 1,042.03 MWD+IFR-AK-CAZ-SC(3) 2,642.07 53.48 178.86 2,094.89 2,039.40 152,571.23 -1,128,389.39 5,974,262.28 385,790.07 0.44 1,108.45 MWD+IFR-AK-CAZ-SC(3) 2,737.44 57.15 181.95 2,149.16 2,093.67 152,492.84 -1,128,389.99 5,974,184.44 385,800.06 4.68 1,176.03 MWD+IFR-AK-CAZ-SC(3) 2,831.72 59.70 181.54 2,198.53 2,143.04 152,412.56 -1,128,392.43 5,974,104.48 385,808.48 2.73 1,244.34 MWD+IFR-AK-CAZSC(3) 2,925.29 59.04 181.01 2,246.20 2,190.71 152,332.07 -1,128,394.23 5,974,024.39 385,817.57 0.86 1,313.15 MWD+IFR-AK-CAZSC(3) 3,020.79 59.84 179.11 2,294.76 2,239.27 152,249.84 -1,128,394.31 5,973,942.81 385,628.60 1.91 1,384.32 MWD+IFR-AK-CAZSC(3) 7/19/2013 3:21:37PM Page 3 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,070.60 60.73 178.82 2,319.45 2,263.96 152,206.58 -1,128,393.52 5,973,900.01 385,835.22 1.86 1,422.17 MWD+IFR-AK-CAZ-SC(3) 3,197.66 60.29 178.63 2,382,00 2,326.51 152,096.01 -1,128,391.06 5,973,790.67 385,852.59 0.37 1,519.16 MWD+IFR-AK-CAZ-SC(3) 3,289.88 60.26 178.59 2,427.72 2,372.23 152,015.95 -1,128,389.12 5,973,711.51 385,865.33 0.05 1,589.46 MWD+IFR-AK-CAZ-SC(3) 3,386.61 60.21 177.86 2,475.74 2,420.25 151,932.03 -1,128,386.52 5,973,628.61 385,879.24 0.66 1,663.45 MWD+IFR-AK-CAZ-SC(3) 3,478.59 60.36 178.98 2,521.34 2,465.85 151,852.17 -1,128,384.32 5,973,549.70 385,892.21 1.07 1,733.70 MWD+IFR-AK-CAZ-SC(3) 3,574.49 60.68 178.68 2,568.53 2,513.04 151,768.71 -1,128,382.61 5,973,467.14 385,905.18 0.43 1,806.84 MWD+IFR-AK-CAZ-SC(3) 3,669.69 60.43 178.23 2,615.33 2,559.84 151,685.83 -1,128,380.38 5,973,385.24 385,918.59 0.49 1,879.73 MWD+IFR-AK-CAZSC(3) 3,762.62 60.47 178.36 2,661.16 2,605.67 151,605.03 -1,128,377.97 5,973,305.41 385,931.88 0.13 1,950.91 MWD+IFR-AK-CAZSC(3) 3,857.10 60.65 178.73 2,707.60 2,652.11 151,522.77 -1,128,375.88 5,973,224.10 385,945.06 0.39 2,023.19 MWD+IFR-AK-CAZ-SC(3) 3,948.63 60.22 179.62 2,752.76 2,697.27 151,443.17 -1,128,374.74 5,973,145.29 385,956.95 0.97 2,092.70 MWD+IFR-AK-CAZ-SC(3) 4,040.73 60.41 180.26 2,798.38 2,742.89 151,363.16 -1,128,374.65 5,973,065.93 385,967.84 0.64 2,162.03 MWD+IFR-AK-CAZ-SC(3) 4,134.76 60.36 180.46 2,844.84 2,789.35 151,281.42 -1,128,375.17 5,972,984.78 385,978.37 0.19 2,232.57 MWD+IFR-AK-CAZ-SC(3) 4,229.68 60.36 180.90 2,891.79 2,836.30 151,198.92 -1,128,376.15 5,972,902.82 385,988.54 0.40 2,303.52 MWD+IFR-AK-CAZ-SC(3) 4,322.82 60.46 181.19 2,937.78 2,882.29 151,117.94 -1,128,377.62 5,972,822.29 385,998.01 0.29 2,372.91 MWD+IFR-AK-CAZ-SC(3) 4,417.78 60.35 181.24 2,984.67 2,929.18 151,035.39 -1,128,379.37 5,972,740.17 386,007.43 0.12 2,443.53 MWD+IFR-AK-CAZ-SC(3) 4,512.25 60.26 181.23 3,031.47 2,975.98 150,953.34 -1,128,381.14 5,972,658.54 386,016.75 0.10 2,513.70 MWD+IFR-AK-CAZ-SC(3) 4,606.71 60.23 181.69 3,078.35 3,022.86 150,871.37 -1,128,383.23 5,972,576.94 386,025.75 0.42 2,583.65 MWD+IFR-AK-CAZ-SC(3) 4,699.78 60.25 181.48 3,124.55 3,069.06 150,790.60 -1,128,385.47 5,972,496.53 386,034.44 0.20 2,652.48 MWD+IFR-AK-CAZ-SC(3) 4,794.94 60.30 180.90 3,171.73 3,116.24 150,707.98 -1,128,387.18 5,972,414.34 386,043.90 0.53 2,723.17 MWD+IFR-AK-CAZ-SC(3) 4,893.46 60.30 181.13 3,220.55 3,165.06 150,622.42 -1,128,388.70 5,972,329.26 386,053.95 0.20 2,796.51 MWD+IFR-AK-CAZ-SC(3) 4,988.04 60.30 180.30 3,267.41 3,211.92 150,540.27 -1,128,389.72 5,972,247.64 386,064.03 0.76 2,867.14 MWD+IFR-AK-CAZ-SC(3) 5,081.80 60.41 180.90 3,313.78 3,258.29 150,458.79 -1,128,390.58 5,972,166.70 386,074.18 0.57 2,937.28 MWD+IFR-AK-CAZ-SC(3) 5,176.07 60.30 180.14 3,360.41 3,304.92 150,376.86 -1,128,391.32 5,972,085.33 386,084.51 0.71 3,007.86 MWD+IFR-AK-CAZ-SC(3) 5,270.61 60.34 180.76 3,407.23 3,351.74 150,294.73 -1,128,391.97 5,972,003.77 386,094.96 0.57 3,078.67 MWD+IFR-AK-CAZ-SC(3) 5,363.44 60.37 180.48 3,453.14 3,397.65 150,214.05 -1,128,392.84 5,971,923.63 386,104.99 0.26 3,148.10 MWD+IFR-AK-CAZ-SC(3) 5,459.70 60.57 181.04 3,500.59 3,445.10 150,130.31 -1,128,393.95 5,971,840.41 386,115.20 0.55 3,220.07 MWD+IFR-AK-CAZ-SC(3) 5,554.70 60.34 180.87 3,547.43 3,491.94 150,047.67 -1,128,395.33 5,971,758.25 386,124.99 0.29 3,290.94 MWD+IFR-AK-CAZ-SC(3) 5,649,10 60.48 180.89 3,594.05 3,538.56 149,965.59 -1,128,396.59 5,971,676.66 386,134.83 0.15 3,361.40 MWD+IFR-AK-CAZ-SC(3) 5,743.03 60.58 181.46 3,640.26 3,584.77 149,883.83 -1,128,398.27 5,971,595.34 386,144.21 0.54 3,431.36 MVVD+IFR-AK-CAZ-SC(3) 5,837.57 60.36 181.12 3,686.85 3,631.36 149,801.59 -1,128,400.12 5,971,513.51 386,153.48 0.39 3,501.66 MWD+IFR-AK-CAZSC(3) 5,932.19 60.29 181.31 3,733.70 3,678.21 149,719.40 -1,128,401.86 5,971,431.75 386,162.85 0.19 3,571.96 MWD+IFR-AK-CAZSC(3) 6,026.31 60.41 180.76 3,780.26 3,724.77 149,637.62 -1,128,403.34 5,971,350.42 386,172.43 0.52 3,642.05 MWD+IFR-AK-CAZSC(3) 6,116.92 60.22 179.23 3,825.13 3,769.64 149,558.91 -1,128,403.33 5,971,272.34 386,183.06 1.48 3,710.22 MWD+IFR-AK-CAZSC(3) 6,214.00 60.29 177.59 3,873.30 3,817.81 149,474.65 -1,128,400.99 5,971,189.09 386,196.76 1.47 3,784.36 MWD+IFR-AK-CAZSC(3) 6,305.96 60.24 177.52 3,918.91 3,863.42 149,394.87 -1,128,397.59 5,971,110.41 386,210.92 0.09 3,855.15 MWD+IFR-AK-CAZ-SC(3) 6,401.70 60.29 176.80 3,966.40 3,910.91 149,311.84 -1,128,393.47 5,971,028.60 386,226.22 0.66 3,929.12 MWD+IFR-AK-CAZ-SC(3) 6,496.01 60.30 175.85 4,013.13 3,957.64 149,230.10 -1,128,388.22 5,970,948.22 386,242.46 0.88 4,002.54 MWD+IFR-AK-CAZ-SC(3) 6,590.75 60.26 175.89 4,060.10 4,004.61 149,148.03 -1,128,382.29 5,970,867.62 386,259.42 0.06 4,076.57 MWD+IFR-AK-CAZ-SC(3) 6,683.51 60.30 177.32 4,106.09 4,050.60 149,067.62 -1,128,377.52 5,970,788.50 386,275.02 1.34 4,148.60 MWD+IFR-AK-CAZ-SC(3) 6,777.28 60.26 179.89 4,152.58 4,097.09 148,986.22 -1,128,375.54 5,970,708.02 386,287.98 2.38 4,220.08 MWD+IFR-AK-CAZ-SC(3) 7/19/2013 3.21:37PM Page 4 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 6,871.32 60.26 180.08 4,199.23 4,143.74 148,904.56 -1,128,375.52 5,970,627.03 386,299.03 0.18 4,290.81 MWD+IFR-AK-CAZ-SC(3) 6,965.41 60.21 181.00 4,245.95 4,190.46 148,822.89 -1,128,376.29 5,970,545.91 386,309.29 0.85 4,361.15 MWD+IFR-AK-CAZ-SC(3) 7,058.24 60.26 181.36 4,292.03 4,236.54 148,742.33 -1,128,377.95 5,970,465.77 386,318.53 0.34 4,430.09 MWD+IFR-AK-CAZ-SC(3) 7,152.41 60.26 181.13 4,338.75 4,283.26 148,660.58 -1,128,379.72 5,970,384.44 386,327.80 0.21 4,500.00 MWD+IFR-AK-CAZ-SC(3) 7,247.28 60.23 182.87 4,385.83 4,330.34 148,578.27 -1,128,382.60 5,970,302.41 386,336.07 1.59 4,569.84 MWD+IFR-AK-CAZ-SC(3) 7,341.32 60.26 181.96 4,432.50 4,377.01 148,496.71 -1,128,386.04 5,970,221.04 386,343.67 0.84 4,638.76 MWD+IFR-AK-CAZ-SC(3) 7,435.75 60.22 181.70 4,479.38 4,423.89 148,414.77 -1,128,388.66 5,970,139.41 386,352.14 0.24 4,708.41 MWD+IFR-AK-CAZ-SC(3) 7,530.44 60.26 182.19 4,526.38 4,470.89 148,332.62 -1,128,391.45 5,970,057.54 386,360.47 0.45 4,778.16 MWD+IFR-AK-CAZ-SC(3) 7,624.74 60.23 181.08 4,573.18 4,517.69 148,250.79 -1,128,393.78 5,969,976.05 386,369.20 1.02 4,847.86 MWD+IFR-AK-CAZ-SC(3) 7,718.60 60.27 181.63 4,619.75 4,564.26 148,169.32 -1,128,395.71 5,969,894.98 386,378.29 0.51 4,917.45 MWD+IFR-AK-CAZ-SC(3) 7,813.18 60.24 181.20 4,666.68 4,611.19 148,087.23 -1,128,397.74 5,969,813.28 386,387.37 0.40 4,987.53 MWD+IFR-AK-CAZ-SC(3) 7,907.45 60.20 180.14 4,713.50 4,658.01 148,005.41 -1,128,398.69 5,969,731.99 386,397.47 0.98 5,057.91 MWD+IFR-AK-CAZ-SC(3) 8,001.88 60.21 179.79 4,760.42 4,704.93 147,923.47 -1,128,398.64 5,969,650.71 386,408.59 0.32 5,128.90 MWD+IFR-AK-CAZ-SC(3) 8,095.79 60.23 179.13 4,807.07 4,751.58 147,841.96 -1,128,397.87 5,969,569.97 386,420.36 0.61 5,199.87 MWD+IFR-AK-CAZ-SC(3) 8,189.06 60.23 178.63 4,853.38 4,797.89 147,761.02 -1,128,396.29 5,969,489.89 386,432.86 0.47 5,270.76 MVVD+IFR-AK-CAZ-SC(3) 8,281.79 60.25 178.95 4,899.40 4,843.91 147,680.54 -1,128,394.59 5,969,410.29 386,445.41 0.30 5,341.31 MWD+IFR-AK-CAZ-SC(3) 8,375.80 60.24 179.62 4,946.06 4,890.57 147,598.93 -1,128,393.57 5,969,329.47 386,457.45 0.62 5,412.49 MWD+IFR-AK-CAZ-SC(3) 8,470.58 60.21 179.13 4,993.13 4,937.64 147,516.67 -1,128,392.68 5,969,248.00 386,469.44 0.45 5,484.18 MWD+IFR-AK-CAZ-SC(3) 8,564.34 60.27 179.13 5,039.67 4,984.18 147,435.28 -1,128,391.44 5,969,167.43 386,481.66 0.06 5,555.28 MVVD+IFR-AK-CAZ-SC(3) 8,658.39 60.22 179.21 5,086.34 5,030.85 147,353.64 -1,128,390.26 5,969,086.61 386,493.86 0.09 5,626.58 MWD+IFR-AK-CAZ-SC(3) 8,753.78 60.23 179.65 5,133.72 5,078.23 147,270.85 -1,128,389.43 5,969,004.60 386,505.86 0.40 5,698.69 MWD+IFR-AK-CAZ-SC(3) 8,847.89 60.24 179.70 5,180.44 5,124.95 147,189.15 -1,128,388.97 5,968,923.62 386,517.35 0.05 5,769.67 MWD+IFR-AK-CAZ-SC(3) 8,942.28 60.55 179.31 5,227.07 5,171.58 147,107.09 -1,128,388.26 5,968,842.32 386,529.14 0.49 5,841.09 MWD+IFR-AK-CAZ-SC(3) 9,036.01 60.50 178.34 5,273.19 5,217.70 147,025.51 -1,128,386.59 5,968,761.62 386,541.82 0.90 5,912.58 MWD+IFR-AK-CAZ-SC(3) 9,130.14 60.57 178.16 5,319.49 5,264.00 146,943.59 -1,128,384.09 5,968,680.70 386,555.36 0.18 5,984.77 MWD+IFR-AK-CAZ-SC(3) 9,224.21 60.50 177.66 5,365.76 5,310.27 146,861.75 -1,128,381.10 5,968,599.92 386,569.38 0.47 6,057.15 MWD+IFR-AK-CAZ-SC(3) 9,317.98 60.49 178.84 5,411.94 5,356.45 146,780.18 -1,128,378.61 5,968,519.34 386,582.87 1.10 6,129.04 MWD+IFR-AK-CAZ-SC(3) 9,412.01 60.52 179.07 5,458.24 5,402.75 146,698.35 -1,128,377.11 5,968,438.37 386,595.40 0.22 6,200.65 MWD+IFR-AK-CAZ-SC(3) 9,506.46 60.53 179.76 5,504.71 5,449.22 146,616.13 -1,128,376.27 5,968,356.93 386,607.34 0.64 6,272.27 MWD+IFR-AK-CAZ-SC(3) 9,600.65 60.57 179.73 5,551.02 5,495.53 146,534.11 -1,128,375.91 5,968,275.62 386,618.77 0.05 6,343.49 MWD+IFR-AK-CAZ-SC(3) 9,693.00 60.55 180.23 5,596.41 5,540.92 146,453.68 -1,128,375.88 5,968,195.85 386,629.66 0.47 6,413.15 MWD+IFR-AK-CAZ-SC(3) 9,786.98 60.54 180.77 5,642.63 5,587.14 146,371.85 -1,128,376.60 5,968,114.58 386,640.01 0.50 6,483.66 MWD+IFR-AK-CAZ-SC(3) 9,882.28 60.48 181.96 5,689.54 5,634.05 146,288.93 -1,128,378.57 5,968,032.05 386,649.25 1.09 6,554.49 MWD+IFR-AK-CAZ-SC(3) 9,975.97 60.50 181.91 5,735.69 5,680.20 146,207.44 -1,128,381.32 5,967,950.85 386,657.52 0.05 6,623.68 MWD+IFR-AK-CAZ-SC(3) 10,068.82 60.49 182.18 5,781.42 5,725.93 146,126.68 -1,128,384.21 5,967,870.35 386,665.57 0.25 6,692.18 MWD+IFR-AK-CAZ-SC(3) 10,164.66 60.47 181.15 5,828.64 5,773.15 146,043.32 -1,128,386.63 5,967,787.34 386,674.42 0.94 6,763.16 MWD+IFR-AK-CAZ-SC(3) 10,258.23 60.50 180.71 5,874.74 5,819.25 145,961.90 -1,128,387.95 5,967,706.40 386,684.11 0.41 6,833.01 MWD+IFR-AK-CAZ-SC(3) 10,353.09 60.48 180.82 5,921.47 5,865.98 145,879.36 -1,128,389.05 5,967,624.37 386,694.16 0.10 6,903.94 MWD+IFR-AK-CAZ-SC(3) 10,445.73 60.52 179.51 5,967.09 5,911.60 145,798.73 -1,128,389.29 5,967,544.36 386,704.82 1.23 6,973.65 MWD+IFR-AK-CAZ-SC(3) 10,540.47 60.47 179.58 6,013.75 5,958.26 145,716.28 -1,128,388.63 5,967,462.66 386,716.60 0.08 7,045.39 MVVD+IFR-AK-CAZ-SC(3) 7/19t2013 3:21:37PM Page 5 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db 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) (0/1001 (ft) Survey Tool Name 10,634.69 60.46 179.40 6,060.19 6,004.70 145,634.31 -1,128,387.90 5,967,381.45 386,728.40 0.17 7,116.74 MWD+IFR-AK-CAZ-SC(3) 10,729.13 60.47 178.18 6,106.75 6,051.26 145,552.16 -1,128,386.17 5,967,300.20 386,741.21 1.12 7,188.75 MWD+IFR-AK-CAZ-SC(3) 10,823.16 60.48 178.65 6,153.09 6,097.60 145,470.37 -1,128,383.90 5,967,219.37 386,754.51 0.44 7,260.71 MWD+IFR-AK-CAZ-SC(3) 10,916.70 60.50 178.68 6,199.16 6,143.67 145,388.99 -1,128,382.01 5,967,138.90 386,767.38 0.04 7,332.14 MWD+IFR-AK-CAZ-SC(3) 11,011.43 60.48 179.78 6,245.83 6,190.34 145,306.56 -1,128,380.90 5,967,057.29 386,779.61 1.01 7,404.08 MWD+IFR-AK-CAZ-SC(3) 11,105.90 60.47 179.76 6,292.38 6,236.89 145,224.36 -1,128,380.57 5,966,975.79 386,791.04 0.02 7,475.44 MWD+IFR-AK-CAZ-SC(3) 11,199.56 60.30 180.30 6,338.67 6,283.18 145,142.93 -1,128,380.61 5,966,895.02 386,801.99 0.53 7,545.93 MWD+IFR-AK-CAZ-SC(3) 11,294.12 60.32 180.46 6,385.50 6,330.01 145,060.79 -1,128,381.16 5,966,813.46 386,812.55 0.15 7,616.80 MWD+IFR-AK-CAZ-SC(3) 11,338.00 60.34 180.55 6,407.22 6,351.73 145,022.66 -1,128,381.49 5,966,775.60 386,817.36 0.18 7,649.65 MWD+IFR-AK-CAZ-SC(3) 11,388.68 60.37 180.65 6,432.29 6,376.80 144,978.62 -1,128,381.95 5,966,731.85 386,822.85 0.18 7,687.56 MWD+IFR-AK-CAZ-SC(3) 11,482.37 60.35 181.80 6,478.63 6,423.14 144,897.21 -1,128,383.69 5,966,650.86 386,832.12 1.07 7,757.19 MWD+IFR-AK-CAZ-SC(3) 11,576.89 60.31 181.71 6,525.41 6,469.92 144,815.12 -1,128,386.21 5,966,569.09 386,840.71 0.09 7,827.02 MWD+IFR-AK-CAZ-SC(3) 11,671.23 60.32 180.81 6,572.13 6,516.64 144,733.18 -1,128,388.01 5,966,487.57 386,849.99 0.83 7,897.08 MWD+IFR-AK-CAZ-SC(3) 11,723.26 60.31 181.01 6,597.90 6,542.41 144,687.99 -1,128,388.73 5,966,442.64 386,855.38 0.33 7,935.87 MWD+IFR-AK-CAZ-SC(3) 11,800.97 60.12 180.58 6,636.50 6,581.01 144,620.55 -1,128,389.67 5,966,375.62 386,863.56 0.54 7,993.80 MWD+IFR-AK-CAZ-SC(3) 11,821.79 61.00 181.33 6,646.74 6,591.25 144,602.42 -1,128,389.97 5,966,357.60 386,865.71 5.26 8,009.35 MWD+IFR-AK-CAZ-SC(3) 11,914.89 60.47 181.95 6,692.25 6,636.76 144,521.24 -1,128,392.29 5,966,276.75 386,874.37 0.81 8,078.49 MWD+IFR-AK-CAZ-SC(3) 12,007.11 61.20 176.66 6,737.21 6,681.72 144,440.76 -1,128,391.30 5,966,197.05 386,886.22 5.07 8,148.69 MWD+IFR-AK-CAZ-SC(3) 12,101.44 61.81 174.67 6,782.22 6,726.73 144,358.10 -1,128,385.03 5,966,115.91 386,903.60 1.96 8,223.41 MWD+IFR-AK-CAZ-SC(3) 12,197.18 65.00 172.53 6,825.08 6,769.59 144,273.04 -1,128,375.47 5,966,032.83 386,924.57 3.89 8,301.85 MWD+IFR-AK-CAZ-SC(3) 12,292.87 67.84 170.59 6,863.36 6,807.87 144,186.31 -1,128,362.58 5,965,948.53 386,949.07 3.50 8,383.40 MWD+IFR-AK-CAZ-SC(3) 12,385.55 67.98 167.42 6,898.22 6,842.73 144,102.02 -1,128,346.21 5,965,867.14 386,976.70 3.17 8,464.59 MWD+IFR-AK-CAZ-SC(3) 12,475.46 68.36 164.99 6,931.66 6,876.17 144,020.97 -1,128,326.30 5,965,789.43 387,007.39 2.54 8,544.73 MWD+IFR-AK-CAZ-SC(3) 12,575.00 70.40 163.27 6,966.71 6,911.22 143,931.37 -1,128,300.82 5,965,704.00 387,044.76 2.61 8,635.06 MWD+IFR-AK-CAZ-SC(3) 12,670.41 72.35 162.35 6,997.18 6,941.69 143,845.01 -1,128,274.10 5,965,621.93 387,082.94 2.24 8,723.22 MWD+IFR-AK-CAZ-SC(3) 12,764.45 73.38 162.34 7,024.89 6,969.40 143,759.37 -1,128,246.84 5,965,540.67 387,121.54 1.10 8,811.01 MWD+IFR-AK-CAZ-SC(3) 12,858.88 75.77 158.98 7,050.01 6,994.52 143,673.51 -1,128,216.69 5,965,459.57 387,163.04 4.26 8,900.45 MWD+IFR-AK-CAZ-SC(3) 12,951.41 77.91 158.24 7,071.07 7,015.58 143,589.62 -1,128,183.83 5,965,380.80 387,206.97 2.44 8,989.53 MWD+IFR-AK-CAZ-SC(3) 13,046.53 78.45 155.79 7,090.56 7,035.07 143,503.92 -1,128,147.48 5,965,300.69 387,254.60 2.58 9,081.93 MWD+IFR-AK-CAZ-SC(3) 13,140.19 78.42 152.86 7,109.34 7,053.85 143,421.23 -1,128,107.72 5,965,224.04 387,305.20 3.06 9,173.41 MWD+IFR-AK-CAZ-SC(3) 13,234.89 80.82 152.35 7,126.40 7,070.91 143,338.53 -1,128,064.87 5,965,147.80 387,358.88 2.59 9,266.46 MWD+IFR-AK-CAZ-SC(3) 13,328.79 82.78 150.93 7,139.80 7,084.31 143,256.75 -1,128,020.72 5,965,072.64 387,413.72 2.57 9,359.35 MWD+IFR-AK-CAZ-SC(3) 13,423.49 83.99 149.24 7,150.71 7,095.22 143,175.22 -1,127,973.81 5,964,998.10 387,471.27 2.19 9,453.42 MWD+IFR-AK-CAZ-SC(3) 13,433.00 84.24 149.13 7,151.68 7,096.19 143,167.10 -1,127,968.96 5,964,990.70 387,477.17 2.87 9,462.88 MWD+IFR-AK-CAZ-SC(3) 13,456.23 84.85 148.87 7,153.89 7,098.40 143,147.28 -1,127,957.05 5,964,972.64 387,491.66 2.85 9,486.00 MWD+IFR-AK-CAZ-SC(3) 13,507.79 84.58 148.86 7,158.64 7,103.15 143,103.33 -1,127,930.50 5,964,932.64 387,523.93 0.52 9,537.33 MWD+IFR-AK-CAZ-SC(3) 13,606.19 85.84 148.92 7,166.86 7,111.37 143,019.38 -1,127,879.84 5,964,856.20 387,585.52 1.28 9,635.37 MWD+IFR-AK-CAZ-SC(3) 13,700.26 87.56 147.65 7,172.27 7,116.78 142,939.49 -1,127,830.47 5,964,783.63 387,645.28 2.27 9,729.23 MWD+IFR-AK-CAZ-SC(3) 13,795.92 91.03 146.47 7,173.45 7,117.96 142,859.23 -1,127,778.47 5,964,711.04 387,707.70 3.83 9,824.74 MWD+IFR-AK-CAZ-SC(3) 13,892.55 92.05 144.57 7,170.85 7,115.36 142,779.61 -1,127,723.79 5,964,639.44 387,772.70 2.23 9,921.04 MWD+IFR-AK-CAZ-SC(3) 7/19/2013 3:21:37PM Page 6 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db 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 13,987.53 91.50 141.93 7,167.91 7,112.42 142,703.55 -1,127,666.99 5,964,571.67 387,839.31 2.84 10,015.30 MWD+IFR-AK-CAZ-SC(3) 14,081.28 91.83 141.20 7,165.18 7,109.69 142,630.15 -1,127,608.74 5,964,506.72 387,907.01 0.85 10,108.00 MWD+IFR-AK-CAZ-SC(3) 14,176.69 91.93 140.61 7,162.05 7,106.56 142,556,14 -1,127,548.61 5,964,441.43 387,976.65 0.63 10,202.16 MWD+IFR-AK-CAZ-SC(3) 14,272.06 91.77 137.45 7,158.97 7,103.48 142,484.18 -1,127,486.12 5,964,378.49 388,048.35 3.32 10,295.73 MWD+IFR-AK-CAZ-SC(3) 14,365.89 91.34 138.03 7,156.43 7,100.94 142,414.76 -1,127,423.04 5,964,318.15 388,120.30 0.77 10,387.38 MWD+IFR-AK-CAZ-SC(3) 14,461.20 89.56 145.13 7,155.68 7,100.19 142,340.14 -1,127,363.85 5,964,252.12 388,189.08 7.68 10,481.60 MWD+IFR-AK-CAZ-SC(3) 14,556.42 89.07 147.61 7,156.82 7,101.33 142,260.87 -1,127,311.13 5,964,180.61 388,252.09 2.65 10,576.61 MWD+IFR-AK-CAZ-SC(3) 14,654.23 90.94 151.89 7,156.81 7,101.32 142,176.40 -1,127,261.87 5,964,103.48 388,312.36 4.78 10,674.39 MWD+IFR-AK-CAZ-SC(3) 14,749.70 90.94 152.18 7,155.24 7,099.75 142,092.09 -1,127,217.10 5,964,025.89 388,368.15 0.30 10,769.79 MWD+IFR-AK-CAZ-SC(3) 14,843.91 91.25 153.35 7,153.44 7,097.95 142,008.34 -1,127,174.00 5,963,948.64 388,422.22 1.28 10,863.87 MWD+IFR-AK-CAZ-SC(3) 14,940.33 89.22 151.97 7,153.05 7,097.56 141,922.70 -1,127,129.72 5,963,869.66 388,477.71 2.55 10,960.18 M1,ND+IFR-AK-CAZ-SC(3) 15,000.43 89.19 151.84 7,153.88 7,098.39 141,869.68 -1,127,101.42 5,963,820.90 388,512.94 0.22 11,020.24 MWD+IFR-AK-CAZ-SC(3) 15,045.34 89.65 152.24 7,154.34 7,098.85 141,830.02 -1,127,080.36 5,963,784.40 388,539.18 1.36 11,065.12 MWD+IFR-AK-CAZ-SC(3) 15,141.25 89.87 152.59 7,154.74 7,099.25 141,745.01 -1,127,035.95 5,963,706.07 388,594.72 0.43 11,160.94 MWD+IFR-AK-CAZ-SC(3) 15,237.15 89.87 152.35 7,154.95 7,099.46 141,659.97 -1,126,991.62 5,963,627.71 388,650.17 0.25 11,256.75 MWD+IFR-AK-CAZ-SC(3) 15,348.00 89.87 152.35 7,155.21 7,099.72 141,561.78 -1,126,940.18 5,963,537.25 388,714.46 0.00 11,367.51 PROJECTED to TD 7/19/2013 3:21:37PM Page 7 COMPASS 2003.16 Build 73 ' STATE OF ALASKA AL `IL AND GAS CONSERVATION CON. N REPOR• OF SUNDRY WELL OPERAT. NS 1 Operations Performed: Abandon r Repair w ell r Plug Perforations f Perforate E Other [- Alter Casing (` Pull Tubing E Stimulate-Frac r Waiver f Time Extension r Change Approved Program EOperat. Shutdownf✓ Stimulate-Other f"-" Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development f-- Exploratory (- 212-177-0 3.Address: 6.API Number: Stratigraphic f Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20661-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372097,25559 .- CD1-49/CD1-49PB1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 3108 feet Plugs(measured) none true vertical 2335 feet Junk(measured) none Effective Depth measured 3108 feet Packer(measured) none true vertical 2335 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR IN: 81 16 114 114 SURFACE 3072 11.75 3108 2335' RECEIVED MAR 0 1 2013 Perforation depth: Measured depth: none P DG C C True Vertical Depth: none Tubing(size,grade,MD,and TVD) kill string 3.5, L-80, 1790 MD, 1790 TVD Packers&SSSV(type,MD,and TVD) no packer no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation na Subsequent to operation na 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory ( Development (— Service (ti Stratigraphic C` 16.Well Status after work: Oil E Gas E WDSPL fT Daily Report of Well Operations XXX GSTOR (� WINJ r WAG 1 GINJ I SUSP I`- 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: 313-039 Contact Rob Stinson Ca. 263-4449 Email Rob.D.Stinson(c�conocophillips.com Printed Name Rob tinson Title Supervising Drilling Engineer Signature Phone:263-4449 Date RBDMS MAR 0120f3 ce ��r �/� 1/ ��` Form 10-404 Revised 10/2012Submit Original Only i WNS CD1-49 • ConocoPhillips /$ W Weli Attributes Ix Angle&MD TD _ Wellbore llbore API Field Name Well Status (°) MD(RKB) Act Btm(ftKB) 1944 501032066100 ALPINE SVC 'Inc!160.73 3,070.60 3,123.0 "` Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date •••Well Confer HORIZONTAL-COI-49,2/19/2013 1:26,09PM —SSSV.NONE Last WO. 35.99 1/25/2013 schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:NEW WELL haggea 2/19/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15250 33.0 114.0 114.0 62.50 H-40 Welded Insulated 34" ___ Casing Description String 0... String ID...Top HUM) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd SURFACE c� 113/4 10.772 36.3 3,108.5 2,337.9 60.00 L-80 BTCM HANGER.32 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WE..String... String Top Thrd KILL STRING 3 1/2 2.992 32.3 1,790.0 1,588.2 9.30 L-80 EUEM Completion Details Top Depth (ND) Top Incl Nomi... Top(RKB) (ORB) r) Item Description Comment ID(in) 32.3 32.3 -0.09 HANGER FMC tbg hanger-elastomer seal 3.958 35.3 35.3 -0.08 XO-Reducing XO-4 1/2"IBT(B)x 31/7 EUE(P) 2.992 i 1,789.5 1,587.9 51.41 WLEG 31/2"9.3#-WLEG 3.875 N1.7" ' otes:General&Safety End Date Annotation 1/24/2013 NOTE:SET KILL STRING WELL SUSPENDED CONDUCTOR Insulated 341. 33-114 WLEG,1,790 SURFACE,j I 36-3,109 TD(CDI-49), 3,123 4 Conoco hiIIips Time Log & Summary We/Niew Web Reporting Report Well Name: CD1-49 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 1/11/2013 1:00:00 PM Rig Release: 1/25/2013 6:00:00 PM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01/10/2013 24 hr Summary Prepare rig for rig move. 08:00 10:00 2.00 0 0 MIRU MOVE MOB P Modify drip pan for spill prevention and containment measures.Weld on and fix rotary table locking mechanism. 10:00 12:00 2.00 0 0 MIRU MOVE MOB P Prepare rig for rig move to CD1-49. Blow down and unhook steam lines, air lines,water lines,mud lines, electrical connections. 12:00 14:15 2.25 0 0 MIRU MOVE MOB P Prepare rig for slot to slot move,blow down steam lines to sub base. 14:15 15:15 1.00 0 0 MIRU MOVE MOB P Raise windwalls on sub.Correlate with Alpine electricians to disconnect ESD and highline power cables. Disconnected. 15:15 00:00 8.75 0 0 MIRU MOVE MOB P Move pit complex, motors complex away from rig package.Skid rig floor back, raise feet on sub structure, move rig off CD1-47.Clean cellar area,prepare CD1-49 cellar for spotting rig on new slot. Crew change. 01/11/2013 Continue to trouble shoot moving system. Fix system.Complete rig move.Accept rig @ 13:00 Hrs. Rig up all service lines.Air,fuel, hydraulic,steam,corns,electrical.Weatherize cellar, pick up and install riser. Nipple up riser and bypass lines on wellhead. Install flow line.SIMOPS: Bring spud mud on board from mud plant. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Troubleshoot rig moving system. Loose wire,and a failed valve) 02:00 10:00 8.00 0 0 MIRU MOVE MOB P Move sub base over to CD1-49 slot. Set support feet,skid rig floor into position. 10:00 12:00 2.00 0 0 MIRU MOVE MOB P Spot pits complex,spot motor complex. 12:00 13:00 1.00 0 0 MIRU MOVE RURD P Rig up, hook up service lines. Mud lines,steam lines, air, high line power.Accept rig @ 1300 HRS. 13:00 13:15 0.25 0 0 SURFA( RISER SFTY P Pre job safety meeting on picking up BHA components,weatherizing the cellar,picking up the riser. 13:15 16:00 2.75 0 0 SURFA( RISER RURD P Pick up BHA components,tools, test gas alarms,pick up surface riser. 16:00 16:15 0.25 0 0 SURFA( RISER SFTY P Pre job safety meeting. Installing the riser. Page 1 of 19 Time Logs 1111111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 22:15 6.00 0 0 SURFA( RISER NUND P Nipple up surface riser. Install by pass lines on well head, hook up hole fill lines,flow line.SIMOPS: Bring spud mud on board from Mud Plant. 22:15 00:00 1.75 0 0 SURFA( DRILL PULD P Pick up safety valves,derrick climber was prepared for use,eye wash station in pits was placed back in postion. 01/12/2013 Rig up surface riser and associated equipment, PU/MU/standback 5"dp and HWDP,slip and cut drill line, PU/MU BHA#1,tag ice in conductor,clean out conductor,MU BHA#1,orient UBHO sub, rig up gyro equipment. Directional drill from 114'MD to 449'MD. 00:00 00:15 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting. 00:15 01:30 1.25 0 0 SURFA( DRILL RURD P Secure cellar area, install boot around riser. Change out heads in the iron roughneck f/4"to 5". Pick up/Make up 5"elevators to the top drive. 01:30 01:45 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on picking up and standing back 5"drill pipe. 01:45 05:00 3.25 0 0 SURFA( DRILL PULD P Pick up and stand back 25 stands of 5"drill pipe via the mouse hole. 05:00 05:30 0.50 0 0 SURFA( RIGMNT SVRG P Service rig while most of crew eats. 05:30 07:15 1.75 0 62 SURFA( DRILL PULD P Pick up and stand back 9 stands of 5"HWDP via the mouse hole. Pick up/make up/RIH w/2 joints of 5" HWDP. 07:15 07:30 0.25 62 62 SURFA( RIGMNT SFTY P Pre job safety meeting on slip and cut drill line. 07:30 09:15 1.75 62 62 SURFA( RIGMNT SLPC P Slip and cut 75'of 1-3/8"drill line. Finish service of rig-change out grease zerts on the drawworks. Calibrate TOTCO block height. Perform work orders.Adjust brake son the drawworks. 09:15 09:30 0.25 62 62 SURFA( DRILL PULD P Make up Weatherford/Daily jar, Stand back 5"HWDP with the jars. 09:30 11:30 2.00 0 58 SURFA( DRILL PULD P PU/MU BHA#1:Baker motor(1.3 deg bend), NM pony collar,string stabilizer, NM crossover,MWD. Tagged ice in the 16"OD conductor at'58'. 11:30 11:45 0.25 58 58 SURFA( DRILL SFTY P Pre job safety meeting. 11:45 12:00 0.25 58 45 SURFA( DRILL PULD P Lay down MWD and crossover to 45'. 12:00 12:30 0.50 45 45 SURFA( DRILL PULD P Pull out of hole w/BHA. Change dies in the tongs, make up 14"Baker MXL-1X 14"bit(ser#5211466).Run in hole. 12:30 12:45 0.25 45 45 SURFA( DRILL CIRC P Fill mud lines and hole,check f/ leaks. Found leak on mud line @ mezzanine level. 12:45 13:15 0.50 45 45 SURFA( DRILL OTHR T Replaced"0"ring on union of mud line. Page 2 of 19 Time Logs 41111111 Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 13:15 13:45 0.50 45 45 SURFA( DRILL PRTS P Screw into lift sub.Test mud line to 3500 psi.Good. 13:45 14:00 0.25 45 45 SURFA( DRILL OTHR P Blow down the top drive. 14:00 14:15 0.25 45 45 SURFA( DRILL PULD P Pick up stand of HWDP.Make a top drive connection. 14:15 14:30 0.25 45 90 SURFA( DRILL WASH P Wash/ream w/10 rpm w/3k ft lbs of torque,215 gpm @ 150 psi f/45'to 90. Clean out ice in the 16" conductor. 14:30 15:30 1.00 90 81 SURFA( DRILL PULD P Set back a stand of 5"HWDP. Pick up/make up MWD,filter sub and UBHO. 15:30 15:45 0.25 81 81 SURFA( DRILL OTHR P Scribe MWD to mud motor,align UBHO to mud motor high side. 15:45 16:00 0.25 81 81 SURFA( DRILL SFTY P Pre job safety meeting on rigging up and hanging sheave f/Gyro. 16:00 17:00 1.00 81 81 SURFA( DRILL RURD P Rig up Sperry WL unit and Gyro data tools. Hang sheave in the derrick. 17:00 17:30 0.50 81 81 SURFA( DRILL SFTY P Pre job safety meeting—Pre Spud. 17:30 18:00 0.50 81 81 SURFA( DRILL PULD P Make a top drive connection. 18:00 18:15 0.25 81 114 SURFA( DRILL WASH P Continue to wash&ream ice in the conductor f/90'to 114'. Rotate 48 rpm w/3k ft lbs of torque. Pumping 445 gpm w/530 psi. 18:15 00:00 5.75 114 SURFA( DRILL DDRL P Drilled 14"directional hole from 114' to 449'. ND-449'. ADT=2.9 hrs. ART=1.10 hrs AST=1.80 hrs WOB=15 to 20K/RPM=50/GPM 450 @ 900 psi/Torque on/off=5k to 5.5k ft/lbs String wt. PU=103k SO=103k Rot= 103k Gyro every stand. 01/13/2013 Directional drill from 449'MD to 542'MD. Stop. Not achieving needed doglegs to follow well plan. Phase 3 conditions developed at the same time.Trip out of the hole to wait on weather,and prepare new well plan. Monitor well on trip tank.Taking''/Y BBL per hour. 00:00 02:45 2.75 449 542 SURFA( DRILL DDRL T Drilled 14"directional hole from 449' to 542'. ND-542'. ADT=.8 hrs. ART=0 0 hrs AST=.80 hrs WOB=15 to 20K/RPM=50/GPM 450 @ 900 psi/Torque on/off=5k to 5.5k ft/lbs String wt. PU= 103k SO=103k Rot= 103k Gyro every stand. Stop drilling unable to achieve needed dog legs, Phase 3 storm developed at the same time. Prepare to TOOH. 02:45 03:45 1.00 542 168 SURFA( DRILL TRIP T Flow check well. Static. Pump out of the hole 3 stands to stop of the monel collars.400 GPM/ 480 PSI/ 50 RPM/4K TQ. 95k Up/Dn/Rot Wts. 03:45 04:15 0.50 168 82 SURFA( DRILL TRIP T blow down top drive.Stand back 3 monel drill collars. Leave 82 foot BHA hanging. Page 3 of 19 Time Logs S 111. Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 11:30 7.25 82 82 SURFA( DRILL OTHR T Waiting on weather. Phase 3 conditions persisted. Blizzard. Perform work orders.Monitoring well on trip tank.Taking%to 1 barrel per hour. 11:30 12:00 0.50 82 82 SURFA( DRILL RURD T PJSM. Rig up head pin to break circulation. Pump 10 Barrels every 4 hours.Monitor on trip tank. 1200 00:00 12.00 82 82 SURFA( DRILL OTHR T Wait on weather. Break circulation every 4 hours. Pump 15 BBLS. Monitor well on trip tank.Well bore taking 1 BBL per hour. 01/14/2013 Phase 3 conditions persist.Wait on weather,and prepare new well plan. Monitor well on trip tank.Taking'/2 to 1 BBL per hour. Every 4 hours pump 15 BBLS mud through BHA,blow down and monitor.Alpine Control room pumped 30 BBLS of diesel freeze protect down CD1-48A tubing. 00:00 00:00 24.00 82 82 SURFA( DRILL OTHR T Wait on weather. Break circulation every 4 hours. Pump 15 BBLS. Monitor well on trip tank.Well bore taking%to 1 BBL per hour. Alpine Operations freeze protected CD1-48A tubing. Pumped 30 BBLS diesel. CD1-48A pressures=OA=400 psi/ IA=200 psi/Tbg=0 PSI. Phase 3 conditions persist. 01/15/2013 Phase 3 conditions were declared until noon,due to snow removal operations.Monitor well on trip tank. Taking%to 1 BBL per hour. Every 4 hours pump 15 BBLS mud through BHA,blow down and monitor. Noon: Work was resumed on CD1-47. Lay down BHA,and TIH with Bit/Bit Sub/Totco ring to 1 stand of Monels and HWDP.Gyro run only for information about bottom hole location.TOOH to pick up mud motor set on 2.0°, /UBHO sub. 00:00 12:00 12.00 82 82 SURFA( DRILL OTHR T Wait on weather. Break circulation every 4 hours. Pump 15 BBLS. Monitor well on trip tank.Well bore taking 1/2 to 1 BBL per hour. Phase 3 conditions stayed in-effect due to snow removal operations around the rig. 12:00 12:15 0.25 82 82 SURFA( DRILL SFTY T PJSM. Return to work safely. Look the rig over.Clear snow. 12:15 16:00 3.75 82 82 SURFA( DRILL RURD T Prepare rig for drilling ahead.Clean up snow after the blizzard. 16:00 16:15 0.25 82 82 SURFA( DRILL SFTY T Safety meeting on laying down BHA. 16:15 17:30 1.25 82 0 SURFA( DRILL PULD T Lay down Mud Motor/MWD. 17:30 17:45 0.25 0 0 SURFA( DRILL PULD T Pick up BHA#2.Gyro run. Bit/Bit Sub/totco nng.(crow's foot) 17:45 18:30 0.75 0 542 SURFA( DRILL TRIP T Trip in the hole.Tag up @ 185 MD, slight bobble,376'MD slight bobble, 503'MD set down hard.Wash to bottom with 300 GPM.270 PSI. 18:30 19:15 0.75 542 542 SURFA( DRILL WASH T Wash down to 542'MD with 300 GPM/270 PSI.40 feet of fill on bottom. Page 4 of 19 • Time Logs 4114111 11411 Date From To Dur S. Death E. Death Phase Code Subcode T Comment 19:15 19:30 0.25 542 542 SURFA( DRILL PULD T Lay down single 5"HWDP/Pick up 16'pump joint to have the stump at the rig floor.Tag fill @ 536'MD. UD 16'pup joint. 19:30 22:00 2.50 542 542 SURFA( DRILL SRVY T Run'Gyro Data'gyro surveys on Halliburton E-Line.Compile checkshots in old hole, and obtain new shot on bottom.Verify that Well Plan#6 is needed. 22:00 23:00 1.00 542 0 SURFA( DRILL TRIP T Trip out of the hole to pick up the Mud Motor. 23:00 00:00 1.00 0 0 SURFA( DRILL PULD T Make up BHA#3. Set Motor on 2° bend. 01/16/2013 Make up BHA#3. Motor set on 2°. Directional drill 14"surface hole from 542'MD to 687'MD.450 GPM/710 PSI.95k UP/DN/No rotation.Survey with gyro tool. POOH for BHA#4. Motor set on 1.5°,pick up MWD system. Directional drill from 687'MD to 1095'MD.Stop.Close approach issue. POOH for BHA#5. 00:00 01:30 1.50 0 44 SURFA( DRILL PULD T MU BHA#3(bit-motor w/2°bend -XO-UBHO sub)to 44' 01:30 01:45 0.25 44 134 SURFA( DRILL TRIP T RIH w/NM flex DC's to 134' 01:45 02:15 0.50 134 503 SURFA( DRILL TRIP T RIH w/jars&HWDP f/134'to 503'- PUwt95 SO wt 95 02:15 02:45 0.50 503 503 SURFA( DRILL SRVY T Ran Gyro survey 02:45 03:00 0.25 503 542 SURFA( DRILL WASH T Wah down f/503'to 542'@ 200 gpm @ 200 psi 03:00 06:30 3.50 542 687 SURFA( DRILL DDRL T Driectional drill 14"hole w/2°bend in motor f/542'to 687'MD 688'TVD ADT-1.3 hrs=AST-1.3 hrs. WOB 10/25 k GPM 430 @ 710 psi 06:30 06:45 0.25 687 687 SURFA( DRILL CIRC T Circ btms up @ 430 gpm @ 450 psi 06:45 08:00 1.25 687 134 SURFA( DRILL TRIP T Flow ck(static)Blow down TD- POOH on TT f/687'to 134'-Tight spot @ 540' 08:00 08:15 0.25 134 44 SURFA( DRILL TRIP T Std back NM flex DC's 08:15 08:45 0.50 44 28 SURFA( DRILL PULD T PJSM on LD BHA-LD XO-UBHO- XO 08:45 09:15 0.50 28 0 SURFA( DRILL OTHR T Adjust bend in motor f/2.0°to 1.5°- clean clay f/stab on motor&bit 09:15 09:30 0.25 0 0 SURFA( DRILL OTHR T Clean up rig floor 09:30 11:00 1.50 0 83 SURFA( DRILL PULD T PJSM on MU BHA-MU BHA#4- bit-motor w/1.5°bend-NM pony DC-Stab-XO-MWD-UPA-fliter sub-UBHO-XO to 83' 11:00 11:15 0.25 83 173 SURFA( DRILL TRIP T RIH w/NM flex DC's f/83'to 173' 11:15 12:00 0.75 173 542 SURFA( DRILL TRIP T RIH w/HWDP f/173'to 542' 12:00 12:15 0.25 542 634 SURFA( DRILL TRIP T Trip in hole with BHA#4. Motor set on 1.5°. From 542'MD to 634'MD. 12:15 12:30 0.25 634 687 SURFA( DRILL WASH T Kelly up and wash down from 634' MD to 687'MD.300 GPM/420 PSI. Page 5 of 19 Time Logs S. S. Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:30 20:30 8.00 687 1,095 SURFA( DRILL DDRL T Directional Drill 14"Surface hole from 687'MD to 1095'MD.TVD=1080'. 500 GPM/1350 PSI/25k WOB/ AST=3.2 HRS.Stop drilling. Survey on bottom placed the wellbore 2 feet from an error ellipse. Decide to POOH for bigger bend. 20:30 22:30 2.00 1,095 1,095 SURFA( DRILL CIRC T Discuss options with Drilling Engineer/Drilling Superintendent/Survey Manager. Decision made to trip out for a bigger bend.Well bore position 2 feet from ellipse of uncertainty. 22:30 22:45 0.25 1,095 1,095 SURFA( DRILL SFTY T PJSM.Trip out of the hole. 22:45 00:00 1.25 1,095 357 SURFA( DRILL TRIP T Trip out of the hole on the trip tank. 01/17/2013 POOH with BHA#4. Re-shim motor to 1.8°. PU BHA#5 Directional drill to 1284'.Survey with gyro tool. Close approach issue. POOH and LD BHA#5.TIH with BHA#6. Bit/Bit Sub/Totco ring to 1 stand of Monels and HWDP. Gyro run only for information to verify bottom hole location. POOH and LD BHA#6. Pick up and RIH with 3.5"EUE tubing to plug back. 00:00 00:30 0.50 357 173 SURFA( DRILL TRIP T Trip out of the hole. From 357'MD to 173'MD. 00:30 00:45 0.25 173 82 SURFA( DRILL TRIP T Stand back 3 monel drill collars. 00:45 02:15 1.50 82 82 SURFA( DRILL PULD T PJSM.Clean clay off BHA. Clean off and grade bit. (1-1).Set Motor bend up to 1.8°.Orient UBHO and MWD tools. 02:15 02:30 0.25 82 82 SURFA( DRILL RURD T Clean up rig floor. 02:30 02:45 0.25 82 173 SURFA( DRILL TRIP T Trip in the hole with stand on monels. 02:45 03:30 0.75 173 1,002 SURFA( DRILL TRIP T Trip in the hole from 173'MD to 1002' MD. 120k Up/115k Dn. 03:30 04:00 0.50 1,002 1,095 SURFA( DRILL WASH T Wash to bottom while oriented highside. 500 GPM/930 PSI. 04:00 06:00 2.00 1,095 1,284 SURFA( DRILL DDRL T Directional Drill 14"hole from 1095' to 1284'MD 1255'TVD ADT-1.4 hrs=ART-.1 hrs. AST-1.3 hrs WOB 10/30 k RPM 50 GPM 500 @1100 psi String wt. PU 124 SO 124 Toruqe on btm. 8 k Stopped drilling-assembly not building angle with strong right hand walk approaching travling cylinder for CD1-40-Contact Drilling Superintendent&sdrilling Engineer to discuss plan forward 06:00 07:30 1.50 1,284 1,284 SURFA( DRILL SRVY T Circ @ 300 gpm @ 420 psi-Ran gyro surveys to confirm MWD surveys 07:30 08:00 0.50 1,284 1,284 SURFA( DRILL CIRC T Circ hole clean @ 450 gpm @ 780 psi w/50 rpm's 7 k torque-RD gyro Page 6 of 19 Time Logs 41410 111411 Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 08:00 09:45 1.75 1,284 173 SURFA( DRILL TRIP T Fl ck-Blow down TD-POOH on TT f/1284'to 173' 09:45 10:00 0.25 173 83 SURFA( DRILL TRIP T Std back NM flex DC's to 83' 10:00 10:30 0.50 83 83 SURFA( DRILL OTHR T Check motor to MWD scribe 197.8- clean clay f/stabs&bit 10:30 12:00 1.50 83 0 SURFA( DRILL PULD T LD BHA#5 12:00 12:15 0.25 0 0 SURFA( DRILL SFTY T PJSM on rig up e-line&make up BHA 12:15 13:00 0.75 0 0 SURFA( DRILL RURD T Rig up a-line 13:00 13:15 0.25 0 93 SURFA( DRILL PULD T Make uo BHA#6 to 93'. 13:15 14:30 1.25 93 1,284 SURFA( DRILL TRIP T Run in hole from 93'to 1284'. 14:30 15:30 1.00 1,284 1,284 SURFA( DRILL ELOG T Run Gyro survey at 1281'. 15:30 17:00 1.50 1,284 93 SURFA( DRILL TRIP T Trip out of hole to 91'into trip tank. 17:00 18:00 1.00 93 0 SURFA( DRILL PULD T Lay down BHA#6 18:00 19:00 1.00 0 0 SURFA( DRILL OTHR T Clean and clear rig floor. 19:00 19:30 0.50 0 0 SURFA( DRILL SVRG T Rig maintenance 19:30 20:00 0.50 0 0 SURFA( DRILL PULD T Pick up tubing equipment 20:00 20:15 0.25 0 0 SURFA( DRILL SFTY T PJSM to rig down e-line 20:15 20:45 0.50 0 0 SURFA( DRILL RURD T Rig down a-line 20:45 21:15 0.50 0 0 SURFA( DRILL RURD T Rig up tubing equipment 21:15 21.45 0.50 0 0 SURFA( DRILL SFTY T PJSM to run in hole with 3.5"EUE tubing 21:45 22:15 0.50 0 90 SURFA( DRILL TRIP T Pick up mule shoe,trip in hole with 3 joints 3%EUE tubing cement string. 22:15 23:30 1.25 90 90 SURFA( DRILL SVRG T Repair 3%tubing elevators,clear ice from floor of pipeshed.(from last storm),Complete work order on top drive. 23:30 00:00 0.50 90 315 SURFA( DRILL TRIP T Trip in hole with 3'/ EUE tubing from 90'to 315'MD. 01/18/2013 Place cement plug on bottom from 1284'MD to 674'MD. 15.7 PPG Arctic Set cement(190 BBLS).Circulate the top hole clean.Verify 1st plug height @ 674'MD. Set 10k weight down. POOH to 378'MD, wait on cement&prepare to pump second plug. Load 875 SXS AS1 in cement silo. Trip in to 623'MD with 3%EUE cement string. Hit bridge @ 623'MD.Stand back one stand of tubing. Wash down to 674 with stand of 5"DP. CBU.Stand back DP and trip in to 672'MD with 3%"tubing. Circulate @ 9 BPM 430 PSI.Conduct pre job safety meeting. Cement job. 00:00 01:00 1.00 315 1,079 SURFA( DRILL TRIP T Trip in the hole from 315'MD to 1079' MD.With 3%"EUE tubing. 01:00 01:45 0.75 1,079 1,081 SURFA( DRILL RURD T Change out tong heads-Make up X-overs to 1081'MD. Rig down tongs- change out elevators to 5" 01:45 02:00 0.25 1,081 1,270 SURFA( DRILL TRIP T Trip in the hole from 1081'MD to 1270'MD.80k up 80k dn. 02:00 02:15 0.25 1,270 1,284 SURFA( DRILL RURD T Make up 16.12'- 5"Pup. Rig up head pin&cement hose. Page 7 of 19 Time Logs • Date From To Dur S. Death E.Death Phase Code Subcode T Comment 02:15 05:00 2.75 1,284 1,284 SURFA( DRILL CIRC T Break circulation. Stage pumps up from 1 BPM to 8 BPM slowly. SIMOPS: Heat 300 BBLs water to 70°, load mud push,prepare for cement job. 05:00 05:30 0.50 1,284 1,284 SURFA( DRILL SFTY T Held pre job safety&ops meeting on setting 1st stage of plug back/kick off plug 05:30 07:00 1.50 1,284 1,284 SURFA( DRILL PLUG T Set 1st stage plug as follows:w/3 1/2"tbg stinger set @ 1284'- Pumped 1 bbls 11 ppg mud push- Test lines to 3000 psi-Pumped 40 bbls 11 ppg @ 3.5 bbls/min @ 125 psi-Mixed&pumped 191 bbls 15.7 ppg AS1 @ 4.5 bbls/min @ 150 psi- Pumped 2 bbls mud push behind- Switched to rig pump&displaced w/ 4.5 bbls of spud mud @ 9.0 ppg- CIP @ 0653 hrs.-Full returns while pumping job-Ck for balance OK 07:00 07:15 0.25 1,284 1,081 SURFA( DRILL TRIP T Break out head pin-LD 16'pup jt.- POOH&std back 5"DP to 1081' 07:15 07:30 0.25 1,081 1,081 SURFA( DRILL RURD T RU tbg tongs-chnage elevators 07:30 08:15 0.75 1,081 481 SURFA( DRILL TRIP T PJSM on pulling tbg-Pull&std back 6 stds 3 1/2"tbg&LD 1 jt.to 481' 08:15 08:45 0.50 481 670 SURFA( DRILL TRIP T RIH back in hole w/2 stds 5"DP& tbg stringer f/481'to 670' 08:45 09:45 1.00 670 670 SURFA( DRILL CIRC T Load wiper ball into DP-MU head pin&hose-Pumped 35 bbls Biozan sweep&circ @ 10 bbls/min -Observed mud push @ shakers& hole unloaded with large amount of clay-observed cement contaminated mud to surface-circ to clean up hole 09:45 11:00 1.25 670 670 SURFA( DRILL OTHR T Blow down lines-RD hose&head pin-Clean up under shakers-Flow ck(static-slight drop) 11:00 1230 1.50 670 102 SURFA( DRILL TRIP T POOH on TT-Std back 2 stds 5" DP-LD 12 jts 3 1/2"tbg to 102' 12:30 13:00 0.50 102 102 SURFA( DRILL RURD T Re-arrange tubing equipment. 13:00 13:30 0.50 102 670 SURFA( DRILL TRIP T Trip in the hole from 102'MD to 670' MD. 13:30 14:15 0.75 670 670 SURFA( DRILL CIRC T Circulate hole clean with 8 BPM. 100 PSI. Hole appeared clean. 14:15 15:15 1.00 670 670 SURFA( DRILL RURD T Blow down top drive.Add 220 BBLS mud to pits,and raise viscosity to 300. Hook up line directly from pump #1 to stack to allow'black water'to be added to the flow stream while circulating the cement job out. 15:15 16:00 0.75 670 670 SURFA( DRILL CIRC T Circulate bottoms up with 9 BPM/ 200 PSI 16:00 16:15 0.25 670 674 SURFA( DRILL CIRC T Wash down from 670 to 674'MD. Tag cement with 10k down. Pump 1.5 BPM 40 PSI. Page 8 of 19 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 16:15 17:15 1.00 674 674 SURFA( DRILL CIRC T Circulate bottoms up @ 9 BPM.200 PSI. 17:15 1730 0.25 674 674 SURFA( DRILL OWFF T Observe well bore. Static. Blow down top drive. Change out elevators. 17:30 18:00 0.50 674 674 SURFA( DRILL RURD T Prime hole fill pump 18:00 18:30 0.50 674 387 SURFA( DRILL TRIP T Trip out of the hole. Stand back 3 stands of tubing work string. 18:30 20:00 1.50 387 387 SURFA( DRILL RURD T Make up cross overs and cement head.Circulate. Stage pump up to 8 BPM.210 PSI. SLB cement team reported they are ready. 20:00 21:00 1.00 387 623 SURFA( DRILL TRIP T Rig down cement head.Trip in the 2 stands. One third stand tagged up on bridge @ 623'MD. Unable to pass by. Set 10k down. No Go. 21:00 23:00 2.00 623 674 SURFA( DRILL CIRC T Stand back one stand of tubing. Change out elevators to 5". Pick up one stand of 5"DP.Circulate down to 623'MD.Tag up.Turn 1/4 turn, wash and work string. Break through. Wash to bottom. Circulate @ 8 BPM.230 PSI. Pick up second stand of 5"DP.Wash down to 674' MD.Verify that to be top of cement. Trip out 2 stands of 5"DP.Change out elevators from 5"to tubing.Trip in with stand of tubing.Saw some resistance at 623'again,but dropped through. 23:00 00:00 1.00 674 674 SURFA( DRILL CIRC T Circulate. Pre Job Safety Meeting. Cement job.Circ @ 10 BPM/430 PSI. 01/19/2013 Set cmt plug#2 f/674'w/142 bbls AS1 -POOH to 197' -Circ hole clean-LD excess 3 1/2"tbg-WOC- RIH @ tag top of plug#2 @ 342'-Circ-POOH-LD 3 1/2"tbg-MU BHA#7-Rig up Halliburton E-Line for gyro surveys.Off load cement contaminated mud. Load new mud in pits. Directional drill 14"surface hole from 420'MD to 725'MD. Conduct Safety Stand Down with both crews:Topic: Pressure Washer Incident. 00:00 01:00 1.00 674 674 SURFA( DRILL CMNT T Set 2nd stage plug as follows:w/3 1/2"tbg stinger set @ 674'- Pumped 1 bbls 11 ppg mud push- io Test lines to 3000 psi-Pumped 38.5 bbls 11 ppg @ 5.1 bbls/min @ 100 psi-Mixed&pumped 143.0 bbls 15.75 ppg AS1@ 5.1 bbls/min @ 200 psi-Pumped 2 bbls mud push behind- CIP @ 00:52 hrs.-Full returns while pumping job-Ck for balance OK 01:00 01:30 0.50 674 197 SURFA( DRILL TRIP T Well bore balanced.Trip out with 3W EUE tubing.Stand back 5 stands. From 674'to 197'MD. Page 9 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 197 197 SURFA( DRILL CIRC T Insert nerf ball. Rig up cement head to pump. Pump 33 BBLS biozan pill, followed by 200 BBLS spud mud. Circ. hole clean @ 9.5 BPM.260 PSI. Mud push seen, no cement returns.When 300 vis spud mud was seen in and out. Stopped pumping. 02:30 02:45 0.25 197 197 SURFA( DRILL SFTY T Safety meeting on rig floor. Discuss recent incident on D15. PJSM on laying down tubing. 02:45 03:30 0.75 197 197 SURFA( DRILL PULD T LD 3 1/2"tbg f/197'(6 jts)RIH w/2 stds 3 1/2"tbg f/derrick to 197' 03:30 03:45 0.25 197 197 SURFA( DRILL CIRC T Circ pipe volume @ 7 bbls/min @ 160 psi 03:45 05:00 1.25 197 0 SURFA( DRILL PULD T POOH&LD 6 jts 3 1/2"tbg-RIH w/ 1 std tbg to 94'-Circ to clean pipe @ 7 bbls/min @ 150 psi-POOH& LD 3 jts tbg 05:00 05:15 0.25 0 194 SURFA( DRILL TRIP T RIH w/mule shoe @ 2 stds-3 1/2" tbg to 194' 05:15 05:30 0.25 194 194 SURFA( DRILL CIRC T Circ @ 194'@ 7 bbls/min @ 150 psi -pumped 35 bbls-Blow down line 05:30 08:30 3.00 194 194 SURFA( DRILL WOC T WOC-Clean up rig floor-Bring BHA components to rig floor-Change out tugger line 08:30 09:15 0.75 194 341 SURFA( DRILL WASH T Wash down f/194'@ 2 bbls/min @ 80 psi-tagged top of cmt plug#2 @ 341'w/10kwt 09:15 09:30 0.25 341 341 SURFA( DRILL CIRC T Circ 2 X btms up @ 8 bbls/min @ 90 psi 09:30 10:30 1.00 341 0 SURFA( DRILL TRIP T POOH f/341'-std back 2 stds 5" DP-LD 6 jts 3 1/2"tbg&mule shoe 10:30 12:00 1.50 0 0 SURFA( DRILL OTHR T RD tbg tongs-Change elevators- Clear rig floor of excess equipment 12:00 12:15 0.25 0 0 SURFA( DRILL SFTY T PJSM on rigging up wireline for gyro 12:15 14:30 2.25 0 90 SURFA( DRILL PULD T Make up BHA#7. Motor set on 1.7°, MX HTC bit, MWD system, UBHO sub. Motor top stab 12%".Orient. Up load. 14:30 15:00 0.50 90 90 SURFA( DRILL RURD T Rig up Halliburton E-Line unit, hang sheave, pick up GyroData gyro tool. 15:00 15:30 0.50 90 263 SURFA( DRILL TRIP T Trip in with stand of monel collars. 1st stand of HWDP with jars. 15:30 16:00 0.50 263 263 SURFA( DRILL SRVY T Run 1st gyro. Orient tool face. 16:00 1630 0.50 263 356. SURFA( DRILL WASH T Wash down oriented to kick off direction.Tag firm cement @ 342' MD.400 GPM/560 PSI Drill cement of 356'MD 16:30 17:30 1.00 356 356 SURFA( DRILL CIRC T Load new spud mud in pits.Run Gyro #2 Page 10 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 22:30 5.00 356 725 SURFA( DRILL DDRL T Directional drill 14"surface hole. Drill cement from 356 to 420. Exit old well @ 420'MD. Drill from 420'MD to 725 MD. Gyro every stand,and get 31 foot stations.430 GPM/1050 PSI/25k Wob/Up WUDn WT/Rot Wt=110k.Getting needed doglegs.( Gyro#3.#4.#5) 22:30 23:00 0.50 725 725 SURFA( DRILL SRVY T Run gyro#6. 23:00 23:30 0.50 725 633 SURFA( DRILL CIRC T Circulate hole clean.500 GPM/1100 PSI/50 RPM/7K TQ. Blow dwon top drive. Stand one stand back.Well bore static. 23:30 00.00 0.50 633 633 SURFA( DRILL SFTY T Safety Stand down with both crews. Pressure Washer Incident. 01/20/2013 Directional drill 14"hole w/1.7°AKO motor f/725'to to 2617'MD 2080'TVD WOB 25/30 k RPM 60 GPM 680 @ 2600 psi String wt PU 140/ SO 125/ Rot 130 Torque on/off btm.-9.5/9 k ft/lbs Last gyro survey @ 817'MD.Gyro release©1250'MD. MWD tool free of magnetic interference. 00:00 08:45 8.75 725 1,283 SURFA( DRILL DDRL T Directional drill 14"hole w/1.7°AKO motor f/725'to 1283'MD-1223'TVD WOB 25/30 k RPM 60 GPM 600 @ 1990 psi String wt. PU 125 SO 1232 Rot 124 Torque on/off btm.-9/5.5 k fUlbs *End of Trouble time 08:45 12:00 3.25 1,283 1,604 SURFA( DRILL DDRL P Directional drill 14"hole w/1.7°AKO motor f/1285'to to 1604'MD 1465' ND ADT-6.6 hrs=ART-2.1 hrs AST- 4.5 hrs*Note total drilling time since midnight WOB 25/30 k RPM 60 GPM 600 @ 1990 psi String wt PU 126 SO 124 Rot 125 Torque on/off btm.-9/6 k fUlbs 12:00 00:00 12.00 1,604 2,617 SURFA( DRILL DDRL P Directional drill 14"hole w/1.7°AKO motor f/1604'to to 2617'MD 2080' ND ADT-6 3 hrs=ART-5.2 hrs AST- , 1.1 hrs*Note total drilling time since noon. WOB 25/30 k RPM 60 GPM 680 @ 2600 psi String wt PU 140 SO 125 Rot 130 Torque on/off btm.-9.5/9 k fUlbs 01/21/2013 Directional drill 14"hole w/1.7°AKO motor f/2617'MD U 3123'MD 2344'ND. Circ 3 X btms up,Std back 1 std every 30 mins f/3123'U 2789'.Wiper trip f/2789'V 1098'.Circulate bottoms up @ 1098'. RIH V 3123'. Circulate bottoms up. POOH to run 11%"60#L-80 BTC surface casing. UD BHA to 85'. Page 11 of 19 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 07:45 7.75 2,617 3,123 SURFA( DRILL DDRL P Drilled 14"hole w/1.7°AKO motor f/ 2617'to 3123'MD 2344'TVD ADT-4.3 hrs=ART-4.1 hrs. AST- .2 hrs WOB 25/30 k RPM 60 GPM 750 @ 3300 psi String wt. PU 144 SO 123 Rot 133 Torque on/off btm.-11.5/9.5 k ft/lbs 07:45 10:30 2.75 3,123 2,789 SURFA(CASING CIRC P Circ 3 X btms up @ 650 gpm @ 2400 psi w/60 rpms @ 10 k torque- Weight up mud system from 9.7+ ppg to 10.0 ppg. Std back 1 std every 30 mins.f/3123'to 2789' 10:30 10:45 0.25 2,789 2,789 SURFA(CASING OWFF P Flow ck-slight drop in fluid level 10:45 12:00 1.25 2,789 2,130 SURFA(CASING WPRT P Wiper trip f/2789'to 2130'w/pump @ 650 gpm @ 2400 psi w/60 rpm's @ 10 k torque 12:00 14:00 2.00 2,130 1,098 SURFA(CASING WPRT P Cont.wiper trip f/2130'to U 1700'w/ pump @ 650 gpm @ 2400 psi and f/ 1700't/1098'w/pump @ 450 gpm @ 1400 psi 14:00 14:30 0.50 1,098 1,098 SURFA(CASING CIRC P Circulate bottoms up w/pump @ 450 gpm @ 1350 psi 14:30 16:00 1.50 1,098 3,123 SURFA(CASING TRIP P RIH f/1098't/3223'. Hole in good shape. No fill. 16:00 17:00 1.00 3,123 3,123 SURFA(CASING CIRC P Circulate bottoms up w/pump @ 650 gpm @ 2550 psi. Rotate and reciprocate. 17:00 17:15 0.25 3,123 3,123 SURFA(CASING OWFF P Observe well.Static. Slowly dropping. 17:15 19:30 2.25 3,123 1,192 SURFA(CASING TRIP P Trip out of the hole on elevators. Circulate out of the trip tank. Good hole fill. Hole in good condition. 19:30 20:00 0.50 1,192 1,192 SURFA(CASING OWFF P Monitor well at top of HWDP. Wellbore static to a slow loss. Dropped 3 inches in 30 mins. 20:00 21:15 1.25 1,192 595 SURFA(CASING TRIP P Trip out with HWDP f/1192'to 595' MD. Began to pull tight @ 595'. RIH f/595'to 630'. 25k overpull:Wiped 1001'to 909'- OK after wiping. 25K overpull:Wiped 725'to 633'- OK after wiping. 21:15 21:45 0.50 595 595 SURFA( CASING CIRC P Make a top drive connection. Circulate @ 500 GPM's w/1250 psi, rotate 50 rpm w/8k ft lbs of torque f/ 630'to 560'. Large amount of cuttings on the shakers.The hole cleaned up. Pumped 225 bbls total. POOH with out pumps f/560'to 541'- OK. RIH f/541'to 633'without pumps-OK,SO wt 105-110k. 21:45 22:00 0.25 595 633 SURFA( CASING TRIP P Blow down top drive. Run one stand in the hole to check for bridge f/633' to 720'. Hole clear. SO wt 105-110k. POOH f/720'to 633. Page 12 of 19 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 22:00 22:30 0.50 633 435 SURFA( CASING TRIP P Continue to POOH on elevators w/ HWDP f/633'. Pulled tight from 540 to 448'MD.20-25k over. Dropped down through twice and it cleaned up. 22:30 23:00 0.50 435 171 SURFA( CASING TRIP P POOH on elevators to the top of HWDP @ 171'. 23:00 23:15 0.25 171 171 SURFA( CASING SFTY P PJSM. Lay down BHA components. Discuss hazards with DD. 23:15 00:00 0.75 171 85 SURFA( CASING PULD P Lay down 3 monel drill collars. 01/22/2013 Lay down BHA#7 f/85',clear floor, MU FMC hanger and landing jt, UD to pipe shed, RU TESCO, Run 11-3/4"60 ppf L-80 BTC-m casing to 1005'(23 jts+part of 24 in the hole). POOH, UD jts 24,23,22,21 due to galled box's. Repalce jts,continue to run in f/ 854'to 1702'(jt#40 in the hole),washing in the hole, pumping 3 bpm. UD jt#41,then jt 40,39,38 due to galled box's. Depth w/jt#37 in the hole 1574'. 00:00 01:15 1.25 85 0 SURFA( CASING PULD P Continue to Lay down BHA#7 f/85'. 01:15 02:30 1.25 0 0 SURFA( CASING OTHR P Clean rig floor. Remove tools via beaver slide. 02:30 03:30 1.00 0 0 SURFA( CASING RURD P Rig up Doyon casing tongs. Prepare to make up FMC hanger to the landing joint'41'11-3/4"BTC. 03:30 03:45 0.25 0 0 SURFA( CASING SFTY P Pre job safety meeting on making up the FMC 11-3/4"hanger w/pup. 03:45 04:15 0.50 0 0 SURFA(CASING OTHR P Make up landing joint to 2500 ft lbs w/Doyon casing tongs. Run in hole, land on FMC load shoulder.Mark joint, Pull out and leave in the pipe shed made up. Note: Nose of jt to makeup at the top of the hanger is 8-5/8"above bottom of the pin.Approx 11-1/2 turns. 04:15 04:30 0.25 0 0 SURFA(CASING SFTY P Pre job safety meeting on rigging up TESCO Casing Running Tool. 04:30 06:30 2.00 0 0 SURFA( CASING RURD P Rig up TESCO casing running tool. 06:30 11:45 5.25 0 1,005 SURFA( CASING RNCS P Run 11-3/4"60 ppf L-80 BTC-m casing as follows to 1005': Ray Oil Tools Silver bullet(essentric),(2) joints of casing,Weatherford model 402 float collar,then joints 3-24 to 1005'. Note.Work casing through tight hole @ 378',509',540',602',895', 910'to 1000'. Note: Baker locked to pin of 4th joint.Applied astop ring 10'above the shoe on jt#1 &centralizer,stop ring 10'below the box of jt#2& centralzier,centralizers over the collars f/3 to 13,then every other collar. 11:45 12:00 0 25 1,005 1,005 SURFA(CASING CIRC P Attempt to circualte @ 2 bpm w/380 psi(low return rate). 12:00 12:45 0.75 1,005 982 SURFA( CASING RNCS T Lay down jt#24 f/1005'to 982'. Galled pin threads. Page 13 of 19 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 12:45 13:15 0.50 982 982 SURFA(CASING OTHR T Blow down the top drive. 13:15 13:45 0.50 982 940 SURFA( CASING CIRC T Work f/982'(jt#23).to 940'(jt#22 in the hole.20k over pull.Circ 3 bpm w/270 psi initial circ pressure,final circ presure 100 psi. PU wt 125k, SO wt 105k. 13:45 17:00 3.25 940 854 SURFA( CASING PULD T Lay down jt#23,jt#22,jt#21 f/ 940'to 854'.Circulated joints out of the hole, pumping 3 bpm w/100 psi- -27%flow on TOTCO.Collars and pins were galled when laying down Jt #23 and#22. Rigged up Doyon Casing tongs and layed down jt#21, leaving jt#20 in the hole w/a good collar @ 854', using Doyon casing tongs. 17.00 22:30 5.50 854 1,702 SURFA(CASING P Run 11-3/4"casing f/854'(jt#20)to 1702'(jt#40 in the hole).Circ each joint down,pumping 3 bpm w/180 psi. PU wt 150k,SO wt 120-115k. 22:30 00:00 1.50 1,702 1,574 SURFA( CASING T Jt#41 pin did not make up good. Break out jt#41-galled pin/box. Lay down jt#41,jt#40,#39,#38-all galled. Pump out w/3 bpm 200 psi. PU wt 145,SO wt 120k f/1702' 01/23/2013 UD casing due to galled threads to 1579', MU/RIH w/11-3/4"csg to 1920',CBU,con't to RIH w/casing, MU FMC hanger, land w/shoe @ 3018.30'. R/D TESCO casing running tool, RU 350 ton elevators w/long bales, RU cement head,circ&cond mud f/cement. Held PJSM, perform cement job w/100%returns with 168.6 bbls of cement returns. Bump plug,CIP @ 1651 hrs. Check floats-good.Monitor casing f/30 minutes-good. Rig down Dowell cement head. RU to test casing, attempt to test w/BOP test pump-no test. Rig down testing eequipment. Lay down casing tools, nipple down riser. 00:00 01:00 1.00 1,579 1,579 SURFA(CASING RNCS P Cont.to LD casing to 1579'(Bad threads) 01:00 03:00 2.00 1,579 1,920 SURFA( CASING RNCS P RIH w/11 3/4"casing f/1579'to 1920'-PU wt 173 SOwt118 03:00 03:30 0.50 1,920 1,920 SURFA( CASING CIRC P Circ Btms up @ 1920'-Stage pump up to 6 bbls/min @ 270 psi 03:30 09:30 6.00 1,920 3,108 SURFA(CASING RNCS P Cont. RIH w/11 3/4"60#L-80 BTC casing f/1920'to 3068'(72 jts total in hole)PU FMC fluted hanger& landing jt-Land caing in wellhead w/ shoe @ 3108.50' -FC @ 3018.30' Washed down every 5th jt @ 3 bbls/min @ 250 to 340 psi 09:30 10:00 0.50 3,108 3,108 SURFA( CASING RURD P RD Tesco casing running equipment -Blow down TD 10:00 11:00 1.00 3,108 3,108 SURFA(CEMEN"RURD P MU long bails-RU cmt head&lines Page 14 of 19 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 11:00 13:30 2.50 3,108 3,108 SURFA(CEMEN'CIRC P Circ&cond mud for cmt job-Stage pump up to 8 bbls/min-ICP 1.5 bbls/min @ 290 psi-FCP 8 bbls/min @ 440 psi Attempted to recipracate pipe pulled up tight w/hanger coming off seat @ 21"-Pulled 45 over Landed hanger back on landing ring 13:30 14:00 0.50 3,108 3,108 SURFA( CEMEN"SFTY P Held pre job safety meeting w/rig crew,cementrs,truck drivers,ball mill&mud engineers-cementing 11 3/4'casing. Continued to circ&cond mud for cmt job-pumping 8 bbls/min-w/440 psi. . Mud wt 9.9+,vis 70-75. Circulated a total of 880 bbls after casing was on bottom. 14:00 1430 0.50 3,108 3,108 SURFA( CEMEN CIRC P Rig pump 100 bbls of 9.9 ppg mud w/ 5 ppb medium nut plug marker, pumping 8 bpm w/430 psi. Follow w/ 33 bbls of Biozan water(2.5 ppb Biozan)w/5 ppb medium nut plug marker, pumped @ 3 to 5 bpm w/ 90-180 psi.. 14:30 14:53 0.39 3,108 3,108 SURFA( CEMEN"PUCM P Dowell pump pump water to rig floor, pressure test lines to 3500 psi-OK. Batch up 10.5 ppb MudPush @ 10.5 ppg. Dowell pump 52.4 bbls of 10.5 ppg MudPush @ 5.8 bpm w/200 to 220 psi. Shut down,drop bottom plug. Batch up 10.7 ppg ASL cement (yield 2.45 cuft/sx, mix water 11.513 gal/sx, 110#sx blend). 14:53 15:44 0.86 3,108 3,108 SURFA(CEMEN"PUCM P Dowell pumping 348.5 bbls(799 sx) of 10.7 ppg ASL lead cement(yield 2.45 cuft/sx,mix water 11.513 gal/sx, 110#sx blend). Pumped @ avg 6.8 bpm, inital 250 psi,final @ 7.1 bpm w/350 psi. Batch up Tail cement. 15:44 16:04 0.34 3,108 3,108 SURFA(CEMEN'PUCM P Dowell pumping 74.2 bbls(359 sx)of 15.7 ppg tail cement(yield 1.16 cuft/sx,mix water 5.125 gal/sx. Additives: .2%BWOC D046 P Antifoam, .3%BWOC D065 Dispersant, .8%BWOC S002 Accelerant). Pumped @ avg 4.5 bpm, inital 300 psi,final @ 4.5 bpm w/250 psi. Shut down,drop top plug. 16:04 16:08 0.07 3,108 3,108 SURFA( CEMEN DISP P Dowell kick out top plug w/20 bbls water-wash up thru the tub. Pumping 6.1 to 6.6 bpm w/300 to 370 psi.Shut down. Page 15 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:08 16:59 0.86 3,108 3,108 SURFA(CEMEN"DISP P Rig pumped 9.8 ppg 6%KCUNaCI brine @ 8bpm w/580 psi initial rate. Once 310 bbls were pumped,slowed to 3 bpm w/830 psi. Bumped plug w 1260 psi(3186 strokes). Held f/5 minutes-OK,bleed pressure to check floats-OK.CIP @ 1651 hrs 1/23/2013. Full returns throughout job. Did not reciprocate for hanging up in the stack. 168.6 bbls of cement returns to surface. 16:59 17:13 0.24 3,108 3,108 SURFA(CEMEN"SFTY P Pre job safety meeting on rigging down Dowell cement head. 17:13 17:43 0.50 3,108 3,108 SURFA(CEMEN'OWFF P Monitor casing f/30 minutes-static. Rig down Dowell cement head(Max rating 3000 psi). 17:43 17:58 0.25 3,108 3,108 SURFA(CEMEN'SFTY P Pre job safety meeting on rig up and test of 11-3/4"casing w/BOP test pump. 17:58 18:13 0.25 3,108 3,108 SURFA( CEMEN'RURD P Rig up to test casing: Install 11-3/4" cement swage,connect BOP test pump. Fill lines. 18:13 18:43 0.50 3,108 3,108 SURFA( CEMEN"PRTS T Attempt to test the 11-3/4"60 ppf L-80 BTC-m casing to 3500 psi using the test pump.Output of pump approx 8.57 gallon per minute. Observed pressure drop @ 3090 psi, shut down pump,dropped to 1850 and was stable @ 1850 for 4 minutes. Brought test pump back on and once again reaching 3090 psi, the pressure fell and was stable @ 1850 psi. Bleed off pressure.Will test again with the mud pumps and 9.8 brine after testing the BOPE. Pumped a total of 4.38 bbls. 18:43 18:58 0.25 3,108 3,108 SURFA( CEMEN"RURD P Rig down testing equipment. 18:58 19:13 0.25 3,108 3,108 SURFA(CEMEN'SFTY P Pre job safety meeting on backing out and laying down the 11-3/4"160 ppf L-80 BTC-m landing joint. 19:13 20:43 1.50 3,108 0 SURFA(CEMEN"RURD P Rig up casing tongs, back out the landing joint 3 turns w/tongs.Then finish backing out the landing joint w/ chain tongs. Pick up landing joint w/ tugger line and lay down same. Note: FMC rep watched the hanger through the 2"in the quick connect head to observe if the hanger was turning-No turning observed. 20:43 22.13 1.50 0 0 SURFA( CEMEN"PULD P Clean up casing equipment, lay down tools. Remove long bales f/the top drive. 22:13 22.28 0.25 0 0 SURFA(CEMEN'SFTY P Pre job safety meeting on laying down the 16"drilling riser. Page 16 of 19 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 22:28 23:58 1.50 0 0 SURFA(WHDBO NUND P Lay down the mouse hole, remove the cementing bypass lines on the riser, nipple down the drilling riser. 01/24/2013 Nipple down surface riser, install FMC Gen V Big Bore 5000 psi wellhead, nipple up BOPE,change lower pipe rams.Test wellhead seal to 1000 psi-good. Install lower test plug, use 3-1/2"test joint,body test BOP stack using top pipe rams to 3500 psi f/10 minutes.Witness of test waived by AOGCC inspector Chuck Scheve.Test 11-3/4"casing to 3500 psi using the blinds, hold test f/30 minutes-good,chart test. RU/then run 3-1/2"tubing to 1788.56'RKB, land, RILDS, set TWC, ND BOPE. 00:00 01:00 1.00 0 0 SURFA(WHDBO NUND P Cont. nipple down riser&adapter- LD riser 01:00 02:00 1.00 0 0 SURFA(WHDBO NUND P Install FMC wellhead Gen.V Big bore 5K 02:00 04:30 2.50 0 0 SURFA(WHDBO NUND P NU BOP stack 04:30 04:45 0.25 0 0 SURFA(WHDBO SFTY P PJSM on changing rams 04:45 06:30 1.75 0 0 SURFA(WHDBO NUND P Change lower pipe rams f/2 7/8"x 5' to 3 1/2"x 6'VBR 06:30 08:45 2.25 0 0 SURFA(WHDBO NUND P NU BOP riser,choke line&gas buster line 08:45 09:00 0.25 0 0 SURFA(WHDBO PRTS P Test metal x metal on wellhead to 1000 psi for 10 mins. (Good test) 09 00 10:00 1.00 0 0 SURFA(WHDBO RURD P Install lower test plug&3 1/2'test jt. -RU&fill lines 10:00 10:45 0.75 0 0 SURFA(WHDBO PRTS P Body test BOP stack-top pipe rams (3 1/2"x 6"VBR-NCR kill,choke valves 1,4,9,6&needle valve&upper annulus valve to 3500 psi for 10 mins (Good test) 10:45 11:00 0.25 0 0 SURFA(WHDBO OTHR P Pull test plug&3 1/2"test jt. 11:00 12:00 1.00 0 0 SURFA(CEMEN'PRTS P Test 11 3/4"casing to 3500 psi for 30 mins(Good test)-bleed off d1 pressure&blow down lines 12:00 12:15 0.25 0 0 SURFA(RPCOM SFTY P Pre job safety meeting 12:15 13:00 0.75 0 0 SURFA( RPCOM RURD P Pick up 3-1/2"tubing running equipment,then rig up to run same. 13:00 13:15 0.25 0 0 SURFA( RPCOM SFTY P Pre job safety meeting on running 3-1/2"9.3 ppf L-80 EUE-m tubing kill string. 13:15 19:15 6.00 0 1,788 SURFA( RPCOM RCST P PU/MU/RIH w/3-1/2"9.3 ppf L-80 EUE-m tubing as follows:WLEG,56 jts of tubing,crossover to 4-1/2" IBT-m, FMC tubing hanger w/ elastomer seal(CPAI PN: 1339004, FMC PN:p1000087918)w/pup.Top connection of hanger is 5"Acme Right hand. Lower connection 4-1/2" IBT-m. Run in the hole to land @ 1788.56'RKB w/landing joint"B". PU wt 77k, SO wt 83k, block wt 72k. Page 17 of 19 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:15 19:30 0.25 1,788 1,788 SURFA( RPCOM OTHR P FMC rep ran in the upper lockdown screws to 450 ft lbs of torque(3-3/4" of pin is exposed from the flange of the wellhead). Note: Upper LDS @ 30.87', LLDS @ 33.34',Surface Load shoulder @ 36.32',GL @ 35.99'(LCMF), GL rig measurement 36.32'. 19:30 19:45 0.25 1,788 0 SURFA(WHDBOOTHR P Back out the 4-1/2"landing joint, lay down the landing joint, run the two way check into the hanger, lay down "T"bar. 19:45 20:00 0.25 0 0 SURFA(WHDBO SFTY P Pre job safety meeting on nippling down the BOPE.Will remove Nordic's 13-5/8"5m spacer spool. Will bolt stack back to the FMC quick connect and DSA to stand back. 20:00 00:00 4.00 0 0 SURFA(WHDBO NUND P Nipple down BOPE: Remove drilling riser, chain falls,break bolts on Nordic spacer spool,break bolts to the FMC wellhead. Remove BOP stack f/wellhead, bolt BOP stack the 13-5/8"5m DSA on top of the FMC Quick connect on the stump. 01/25/2013 NU FMC tree,test void to 5000 psi,test tree to 250 psi low and 5000 psi high, Pull TWC, RU to freeze protect ann and tubing, PJSM, Dowell pump 194.9 bbls freeze protection diesel."U"tube f/annulus to tubing. Set BPV w/FMC lubricator,secure well, PJSM, L/D 5"drill pipe f/derrick, PJSM, blow down lines,drain pumps,disconnect lines,clean pits. Rig released f/CD1-49 for pad to pad move to CD3-127 @ 1800 hrs 1/25/2013. 00:00 01:30 1.50 0 0 SURFA(WHDBO NUND P Nipple up tree, rig up to"U"tube and pump diesel 01:30 02:30 1.00 0 0 SURFA(WHDBO DHEQ P Test hanger void to 5000 f/10 min 02:30 03:15 0.75 0 0 SURFA(WHDBO DHEQ P Test tree to 250 psi f/10 min,then 5000 psi f/10 min. 03:15 04:00 0.75 0 0 SURFA( RPCOM RURD P Pull TWC& RU to Freeze protect w/ diesel 04:00 04:15 0.25 0 0 SURFA( RPCOM SFTY P PJSM on diesel freeze protection 04:15 05:30 1.25 0 0 SURFA( RPCOM FRZP P Dowell pump water,test lines to 1900 psi, pump 194.9 bbls diesel, pumping down the 11-3/4"x 3-1/2" annulus,taking returns f/3-1/2" tubing to the pits. Diesel returns to the pits. 05:30 05:45 0 25 0 0 SURFA( RPCOM FRZP P "U tube diesel Annulus to tbg.-Shut in well 05:45 06:45 1.00 0 0 SURFA( RPCOM RURD P Flush dowel)lines and 2"lines with water to the tote in the cellar.-Blow down lines-RD hard lines& squeeze manifold 06:45 08:00 1.25 0 0 SURFA( RPCOM OTHR P RU FMC lubricator&Set BPV-RD lubricator-Secure well-House keeping on rig floor 08:00 08:15 0.25 0 0 SURFA( RPCOM SFTY P Held PJSM on laying down 5"DP Page 18 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:15 13:30 5.25 0 0 SURFA( RPCOM PULD P Lay down 5"DP f/derrick via mouse hole 13:30 13:45 0.25 0 0 SURFA( RPCOM OTHR P Lay down mouse hole 13:45 14:00 0.25 0 0 SURFA( RPCOM SFTY P Pre job safety meeting on rig down chores. 14:00 18:00 4.00 0 0 SURFA( RPCOM OTHR P Blow down lines,drain pumps, disconnect lines,clean pits,lay down and pick up wear rings and test plugs.Tighten bolts on DSA on the BOP stack. Rig released f/CD1-49 @ 1800 hrs 1/25/2013 to move to CD3-127. Page 19 of 19 1 L. ConocoPhillips(Alaska) Inc. NAD27 Western North Slope CD1 Alpine Pad CD1-49 API:501032066100 - PTD:212-177 rs gu Sperry Drilling Services Definitive Survey Report r s 22 February, 2013 r E 1 N ki, i g. g I 7 -. HALLPRURTDN Sperry Drilling Services ConoDecoPhillipsfinitive (AlaskaReport) Inc. Survey Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1 49 Project: Western North Slope TVD RefeCD1-49 @ 55.49ft(019(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db Project Western North Slope,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 Well CD1-49 amuwimimmiuuimiNmiowimaim��uimuuu�uii1.miia. Well Position +N/-S 0.00 ft Northing: 5,975,565.51 ft Latitude: 70°20'31.53 N +E/-W 0.00 ft Easting: 385,660.62 ft Longitude: 150°55'40.63 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50 ft uuwuwmnnreeua" x uum� anm nnu�ws� Wellbore CD1-49 II III IIId�NIIIIIII�IhXIIIliil9iIIIIL4I'klr.YllII6lIlII'SiIII;vMilmivz14,01:::::.,1,i111:::::::,11:,m,MagneticsModel Name SampleDateDeclination (i DipAngli(°) "'111)1II (°) n f k � BGG M2011 1/17/2013 19.64 80.85 57,597 Design ,j j1 CD1 49 III'�I��I'IS'0, flX7��iIrmt,all II�YAx n n i nm III nt"LL�,.� .�. =m 7 awh Tl1NRIIIIM'IINIMIIEIIIIIIIERNIMIflidMIUM1I4, "a'01 M7llt�fi:i(III II IMII ;IIII1110I11IItiIIMIII(�A4N@ @giIIBIALx Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 420.00 Vertical Section: ��(�) ',11n{��11g.�a(rI Depth From(TVD) +NIS +E/-W irectid 1 1 (ft) (tt) (ft)' . ;� I �PO i.,{.,., i (°)',III�t'I' II[ 18�h'IN,��I =1111111101111= 1�,�,'� 35.99 0.00 0.00 150.00 SurveyProgram Date 2/21/2013 ,) .ii [` ),,.1, ,,,il �:�:'' ,','' From To �I I� Survey (ft) (ft) Survey(Wellbore) 'fool Name •escnption 1 Start Date 72.00 420.00 CD1-49PB1 Gyro(CD1-49PB1) GYD-GC-SS Gyrodata gyro single shots 01/12/2013 450.00 816.69 GYD-GC-SS(CD1-49) GYD-GC-SS Gyrodata gyro single shots 01/20/2013 889.49 3,070.60 MWD-IFR-AK-CAZ-SC(CD1-49) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/20/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (f- (ft) (ft) (°/100') (ft) Survey Tool Name 35.99 0.00 0.00 35.99 -19.50 0.00 0.00 5,975,565.51 385,660.62 0.00 0.00 UNDEFINED 72.00 0.01 65.18 72.00 16.51 0.00 0.00 5,975,565.51 385,660.63 0.03 0.00 GYD-GC-SS(1) 100.00 0.08 215.43 100.00 44.51 -0.01 -0.01 5,975,565.49 385,660.62 0.32 0.01 GYD-GC-SS(1) 130.00 0.12 228.79 130.00 74.51 -0.05 -0.04 5,975,565.46 385,660.58 0.15 0.02 GYD-GC-SS(1) 172.00 0.23 177.57 172.00 116.51 -0.16 -0.07 5,975,565.34 385,660.55 0.43 0.11 GYD-GC-SS(1) 200.00 0.41 161.38 200.00 144.51 -0.32 -0.04 5,975,565.19 385,660.58 0.71 0.25 GYD-GC-SS(1) 230.00 0.57 170.92 230.00 174.51 -0.56 0.02 5,975,564.94 385,660.64 0.60 0.50 GYD-GC-SS(1) 265.00 0.90 154.18 265.00 209.51 -0.98 0.17 5,975,564.52 385,660.78 1.12 0.94 GYD-GC-SS(1) 300.00 1.10 155.92 299.99 244.50 -1.54 0.42 5,975,563.96 385,661.03 0.58 1.54 GYD-GC-SS(1) 330.00 1.34 159.69 329.98 274.49 -2.13 0.66 5,975,563.37 385,661.26 0.84 2.18 GYD-GC-SS(1) 359.00 1.71 158.95 358.97 303.48 -2.85 0.94 5,975,562.64 385,661.52 1.28 2.94 GYD-GC-SS(1) 390.00 1.86 166.14 389.96 334.47 -3.77 1.22 5,975,561.72 385,661.79 0.87 3.88 GYD-GC-SS(1) 2/22/2013 10:26:28AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°11001 (ft) Survey Tool Name 420.00 2.06 168.79 419.94 364.45 -4.77 1.45 5,975,560.71 385,662.00 0.73 4.86 GYD-GC-SS(1) 450.00 2.82 180.93 449.91 394.42 -6.04 1.54 5,975,559.45 385,662.07 3.05 6.00 GYD-GC-SS(2) 480.00 2.90 188.75 479.88 424.39 -7.53 1.41 5,975,557.96 385,661.92 1.33 7.23 GYD-GC-SS(2) 510.00 3.35 196.13 509.83 454.34 -9.12 1.05 5,975,556.37 385,661.54 2.01 8.42 GYD-GC-SS(2) 540.00 4.44 199.55 539.76 484.27 -11.06 0.42 5,975,554.45 385,660.88 3.71 9.79 GYD-GC-SS(2) 572.00 6.03 200.94 571.63 516.14 -13.79 -0.60 5,975,551.73 385,659.82 4.98 11.65 GYD-GC-SS(2) 602.00 8.03 200.88 601.40 545.91 -17.22 -1.91 5,975,548.32 385,658.46 6.67 13.96 GYD-GC-SS(2) 632.00 10.17 201.25 631.02 575.53 -21.65 -3.61 5,975,543.92 385,656.68 7.14 16.94 GYD-GC-SS(2) 665.00 12.14 201.38 663.40 607.91 -27.60 -5.93 5,975,538.01 385,654.27 5.97 20.93 GYD-GC-SS(2) 695.00 13,66 200.94 692.64 637.15 -33.84 -8.35 5,975,531.80 385,651.76 5.08 25.13 GYD-GC-SS(2) 725,00 15.67 200.28 721.66 666.17 -40.95 -11.02 5,975,524.73 385,648.98 6.72 29.96 GYD-GC-SS(2) 757.00 16.82 198.61 752.38 696.89 -49.40 -14.00 5,975,516.34 385,645.88 3.88 35.78 GYD-GC-SS(2) 787.00 18.68 198.01 780.95 725.46 -58.08 -16.87 5,975,507.70 385,642.88 6.23 41.86 GYD-GC-SS(2) 889.80 21.69 198.27 877.43 821.94 -91.78 -27.91 5,975,474.17 385,631.32 2.93 65.53 MWD+IFR-AK-CAZ-SC(3) 919.64 22.05 198.17 905.12 849.63 -102.34 -31.39 5,975,463.67 385,627.68 1.21 72.93 MWD+IFR-AK-CAZ-SC(3) 948.67 22.92 198.19 931.94 876.45 -112.89 -34.85 5,975,453.18 385,624.06 3.00 80.34 MWD+IFR-AK-CAZ-SC(3) 1,040.71 25.50 190.67 1,015.90 960.41 -149.40 -44.12 5,975,416.81 385,614.23 4.36 107.32 MWD+IFR-AK-CAZ-SC(3) 1,092.85 27.44 187.01 1,062.58 1,007.09 -172.36 -47.67 5,975,393.91 385,610.34 4.86 125.43 MWD+IFR-AK-CAZ-SC(3) 1,135.90 30.53 185.95 1,100.23 1,044.74 -193.08 -50.01 5,975,373.23 385,607.68 7.28 142.21 MWD+IFR-AK-CAZ-SC(3) 1,186.65 32.11 185.12 1,143.58 1,088.09 -219.34 -52.55 5,975,347.02 385,604.74 3.23 163.68 MWD+IFR-AK-CAZ-SC(3) 1,229.88 35.23 184.04 1,179.56 1,124.07 -243.23 -54.45 5,975,323.16 385,602.47 7.35 183.41 MWD+IFR-AK-CAZ-SC(3) 1,324.58 37.80 185.87 1,255.66 1,200.17 -299.35 -59.35 5,975,267.12 385,596.72 2.95 229.57 MWD+IFR-AK-CAZ-SC(3) 1,418.06 40.07 182.71 1,328.38 1,272.89 -357.92 -63.70 5,975,208.64 385,591.48 3.23 278.11 MWD+IFR-AK-CAZ-SC(3) 1,511.51 42.49 183.04 1,398.60 1,343.11 -419.49 -66.80 5,975,147.13 385,587.44 2.60 329.89 MWD+IFR-AK-CAZ-SC(3) 1,605.37 45,48 182.35 1,466.13 1,410.64 -484.59 -69.85 5,975,082.08 385,583.40 3.23 384.74 MWD+IFR-AK-CAZ-SC(3) 1,699.75 48.71 180.58 1,530.37 1,474.88 -553.68 -71.59 5,975,013.03 385,580,60 3.69 443.71 MWD+IFR-AK-CAZ-SC(3) 1,794.39 51.56 178.11 1,591.04 1,535.55 -626.30 -70.73 5,974,940.41 385,580.36 3,62 507.03 MWD+IFR-AK-CAZ-SC(3) 1,889.14 51.77 178.61 1,649.81 1,594.32 -700.59 -68.60 5,974,866.10 385,581.35 0.47 572.43 MWD+IFR-AK-CAZ-SC(3) 1,983.06 52.60 179.10 1,707.39 1,651.90 -774.77 -67.12 5,974,791.91 385,581.70 0.98 637.41 MWD+IFR-AK-CAZ-SC(3) 2,076.89 53.70 177.33 1,763.66 1,708.17 -849.82 -64.77 5,974,716.85 385,582.90 1.91 703.57 MW1J+IFR-AK-CAZ-SC(3) 2,170.59 55.10 177.72 1,818.21 1,762.72 -925.93 -61.49 5,974,640.70 385,585.03 1.53 771.14 MWD+IFR-AK-CAZ-SC(3) 2,264.92 54.09 177.53 1,872.86 1,817.37 -1,002.75 -58.30 5,974,563.85 385,587.04 1.08 839.26 MWD+IFR-AK-CAZ-SC(3) 2,358.35 55.58 178.35 1,926.67 1,871.18 -1,079.08 -55.56 5,974,487.50 385,588.62 1.75 906.73 MWD+IFR-AK-CAZ-SC(3) 2,453.71 53.02 177.07 1,982.31 1,926.82 -1,156.45 -52.48 5,974,410.10 385,590.52 2.90 975.27 MWD+IFR-AK-CAZ-SC(3) 2,547.87 53.37 178.36 2,038.72 1,983.23 -1,231.77 -49.48 5,974,334.74 385,592.37 1.16 1,042.01 MWD+IFR-AK-CAZ-SC(3) 2,642.07 53.48 178.86 2,094.85 2,039.36 -1,307.40 -47.64 5,974,259.10 385,593.05 0.44 1,108.42 MWD+IFR-AK-CAZ-SC(3) 2,737.44 57.15 181.95 2,149.12 2,093.63 -1,385.79 -48.24 5,974,180.73 385,591.26 4.68 1,176.01 MWD+IFR-AK-CAZ-SC(3) 2,831.72 59.70 181.54 2,198.49 2,143.00 -1,466.07 -50.68 5,974,100.51 385,587.59 2.73 1,244.31 MWD+IFR-AK-CAZ-SC(3) 2,925.29 59.04 181.01 2,246.16 2,190.67 -1,546.56 -52.48 5,974,020.06 385,584.57 0.86 1,313.13 MWD+IFR-AK-CAZ-SC(3) 3,020.79 59.84 179.11 2,294.72 2,239.23 -1,628.79 -52.56 5,973,937.85 385,583.24 1.91 1,384.30 MWD+IFR-AK-CAZ-SC(3) 2/22/2013 10:26:28AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project Western North Slope TVD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49 Survey Calculation Method: Minimum Curvature Design: CD1-49 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100) (ft) Survey Tool Name 3,070.60 60.73 178.82 2,319.41 2,263 92 -1,672.05 -51.78 5,973,894.59 385,583.36 1.86 1,422.15 MWD+IFR-AK-CAZ-SC(3) 3,122.69 60.73 178.82 2,344.88 2,289.39 -1,717.48 -50.84 5,973,849.15 385,583.60 0.00 1,461.96 PROJECTED to TD 2/22/2013 10:26:28AM Page 4 COMPASS 2003.16 Build 69 r y II, 11 3 !A� s E.. ConocoPhillips(Alaska) Inc. NAD27 Western North Slope CD1 Alpine Pad CD1-49PB1 API:501032066170 - P10:212-177 71:1 fig Sperry E3rilling Services Definitive Survey Report 22 February, 2013 01 114 -s s HALLIIBURTON Aminismai ..,.,:, . .,4, 94a..re,.a -- Sperry Drilling Services ji i i ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope ND Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49PB1 Survey Calculation Method: Minimum Curvature Design: CD1-49PB1 Database: EDM 2003.16 Single User Db Project Western North Slope,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 Well CD1-49 Well Position +N/-S 0.00 ft Northing: 5,975,565.51 ft Latitude: 70°20'31.53 N +E/-W 0.00 ft Easting: 385,660.62 ft Longitude: 150°55'40.63 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50 ft Wellbore CD1-49PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2011 12/31/2012 19.67 80.85 57,598 Design CD1-49PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 35.99 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (ft) (ft) (ft) (1 35.99 0.00 0.00 150.00 Survey Program Date 2/21/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 72.00 1,269.11 CD1-49PB1 Gyro(CD1-49PB1) GYD-GC-SS Gyrodata gyro single shots 01/12/2013 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 35.99 0.00 0.00 35.99 -19.50 0.00 0.00 5,975,565.51 385,660,62 0.00 0.00 UNDEFINED 72.00 0.01 65.18 72.00 16.51 0.00 0.00 5,975,565.51 385,660.63 0.03 0.00 GYD-GC-SS(1) 100.00 0.08 215.43 100.00 44.51 -0.01 -0.01 5,975,565.49 385,660.62 0.32 0.01 GYD-GC-SS(1) 130.00 0.12 228.79 130.00 74.51 -0.05 -0.04 5,975,565.46 385,660.58 0.15 0.02 GYD-GC-SS(1) 172.00 0.23 177.57 172.00 116.51 -0.16 -0.07 5,975,565.34 385,660.55 0.43 0.11 GYD-GC-SS(1) 200.00 0.41 161.38 200.00 144.51 -0.32 -0.04 5,975,565.19 385,660.58 0.71 0.25 GYD-GC-SS(1) 230.00 0.57 170.92 230.00 174.51 -0.56 0.02 5,975,564.94 385,660.64 0.60 0.50 GYD-GC-SS(1) 265.00 0.90 154.18 265.00 209.51 -0.98 0.17 5,975,564.52 385,660.78 1.12 0.94 GYD-GC-SS(1) 300.00 1.10 155.92 299.99 244.50 -1.54 0.42 5,975,563.96 385,661.03 0.58 1.54 GYD-GC-SS(1) 330.00 1.34 159.69 329.98 274.49 -2.13 0.66 5,975,563.37 385,661.26 0.84 2.18 GYD-GC-SS(1) 359.00 1,71 158.95 358.97 303.48 -2.85 0.94 5,975,562.64 385,661.52 1.28 2.94 GYD-GC-SS(1) 390.00 1.86 166.14 389.96 334.47 -3.77 1.22 5,975,561.72 385,661.79 0.87 3.88 GYD-GC-SS(1) 420.00 2.06 168.79 419.94 364.45 -4.77 1.45 5,975,560.71 385,662.00 0.73 4.86 GYD-GC-SS(1) 451.00 2.17 177.49 450.92 395.43 -5.91 1.58 5,975,559.58 385,662.11 1.09 5.90 GYD-GC-SS(1) 2/22/2013 10:24:49AM Page 2 COMPASS 2003.16 Build 69 S ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.NAD27 Local Co-ordinate Reference: Well CD1-49 Project: Western North Slope TVD Reference: CD1-49©55.49ft(D19(35.99+19.50)) Site: CD1 Alpine Pad MD Reference: CD1-49 @ 55.49ft(D19(35.99+19.50)) Well: CD1-49 North Reference: True Wellbore: CD1-49PB1 Survey Calculation Method: Minimum Curvature Design: CD1-49PB1 Database: EDM 2003.16 Single User Db 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 480.00 2.10 187.68 479.90 424.41 -6.98 1.53 5,975,558.50 385,662.05 1.33 6.81 GYD-GC-SS(1) 514.00 2.29 186.80 513.87 458.38 -8.27 1.37 5,975,557.22 385,661.87 0.57 7.85 GYD-GC-SS(1) 542.00 2.69 209.93 541.85 486.36 -9.40 0.97 5,975,556.10 385,661.46 3.83 8.63 GYD-GC-SS(1) 609.00 6.53 208.51 608.62 553.13 -14.11 -1.63 5,975,551.43 385,658.78 5.73 11.41 GYD-GC-SS(1) 640.00 8.70 202.76 639.34 583.85 -17.82 -3.38 5,975,547.74 385,656.98 7.41 13.75 GYD-GC-SS(1) 665.00 10.01 197.66 664.01 608.52 -21.64 -4.77 5,975,543.95 385,655.53 6.20 16.35 GYD-GC-SS(1) 695.00 11.04 196.23 693.51 638.02 -26.88 -6.36 5,975,538.73 385,653.85 3.54 20.10 GYD-GC-SS(1) 725.00 11.45 195.55 722.93 667.44 -32.51 -7.96 5,975,533.13 385,652.17 1.44 24.17 GYD-GC-SS(1) 755.00 10.99 195.37 752.36 696.87 -38.13 -9.52 5,975,527.53 385,650.53 1.54 28.26 GYD-GC-SS(1) 785.00 10.95 192.33 781.81 726.32 -43.67 -10.89 5,975,522.01 385,649.07 1.93 32.38 GYD-GC-SS(1) 818.00 11.44 191.01 814.18 758.69 -49.95 -12.18 5,975,515.76 385,647.68 1.68 37.16 GYD-GC-SS(1) 849.00 12.39 189.01 844.51 789.02 -56.25 -13.29 5,975,509.47 385,646.48 3.34 42.07 GYD-GC-SS(1) 879.00 13.18 187.80 873.77 818.28 -62.82 -14.26 5,975,502.92 385,645.41 2.78 47.27 GYD-GC-SS(1) 909.00 13.74 185.04 902.95 847.46 -69.75 -15.03 5,975,496.00 385,644.53 2.84 52.89 GYD-GC-SS(1) 942.00 14.66 185.28 934.94 879.45 -77.82 -15.76 5,975,487.95 385,643.68 2.79 59.51 GYD-GCSS(1) 972.00 15.93 181.09 963.87 908.38 -85.71 -16.19 5,975,480.06 385,643.13 5.61 66.13 GYD-GC-SS(1) 1,002.00 17.93 178.67 992.57 937.08 -94.45 -16.16 5,975,471.33 385,643.03 7.07 73.71 GYD-GC-SS(1) 1,040.00 21.01 177.59 1,028.40 972.91 -107.10 -15.74 5,975,458.67 385,643.26 8.16 84.88 GYD-GC-SS(1) 1,070.00 22.72 177.13 1,056.24 1,000.75 -118.26 -15.22 5,975,447.50 385,643.60 5.73 94.81 GYD-GC-SS(1) 1,100.00 22.98 179.08 1,083.88 1,028.39 -129.91 -14.84 5,975,435.86 385,643.81 2.67 105.08 GYD-GC-SS(1) 1,130.00 21.52 180.92 1,111.65 1,056.16 -141.26 -14.83 5,975,424.50 385,643.64 5.39 114.92 GYD-GC-SS(1) 1,160.00 20.69 184.78 1,139.64 1,084.15 -152.05 -15.36 5,975,413.73 385,642.95 5.39 124.00 GYD-GC-SS(1) 1,191.00 20.74 190.76 1,168.64 1,113.15 -162.90 -16.84 5,975,402.90 385,641.30 6.82 132.65 GYD-GC-SS(1) 1,230.00 21.97 199.60 1,204.97 1,149.48 -176.56 -20.58 5,975,389.30 385,637.35 8.83 142.61 GYD-GC-SS(1) 1,269.11 23.19 206.23 1,241.09 1,185.60 -190.36 -26.44 5,975,375.59 385,631.29 7.21 151.64 GYD-GC-SS(1) 1,285.11 23.19 208.23 1,255.79 1,200.30 -196.01 -29.23 5,975,369.98 385,628.42 0.00 155.14 PROJECTED to TD 2/22/2013 10:24:49AM Page 3 COMPASS 2003.16 Build 69 VOF zit_ THE STATE Alaska til and Gas F --- -��"' ofALAS]� Conservation Commission �*h, GOVERNOR SEAN PARNELL 333 West Seventh Avenue O�,'�hrtr ,.. ¢� Anchorage, Alaska 99501-3572 ALAS'' Main: 907 279.1433 Fax• 907 276.7542 Mike Dammeyer Sr. Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-49 Sundry Number: 313-412 Dear Mr. Dammeyer: 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, / // -- Cathy P. Foerster Chair DATED this i!'day of August, 2013. Encl. STATE OF ALASKAiiRECEIVED ALASKA OIL AND GAS CONSERVATION COMM!, _JN VSAi APPLICATION FOR SUNDRY APPROVALS JUL 3 1 2013 20 AAC 25.280 ((�� 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change, GO �thn r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re-enter Susp.Well r Stimulate r Alter casing r Other:put on injection P- 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 212-177-0- 3.Address: Stratigraphic r Service r, 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20661-00 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No J7 CD1-49• 9 Property Designation(Lease Number): 10.Field/Pool(s): ADL 372097,25559• Colville River Field/Alpine Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft):Pp+3 Plugs(measured): Junk(measured): 7.-.2'15348 7155 13686'• 7 I is(tIl3 none 13686'- Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 114' 114' SURFACE 3072 11.75 3109' 2338' INTERMEDIATE 8804 9.625 11753' 6613' LINER 2066 7 13433' 7152' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slotted liner 13099-13325' • 7100-7126 4.5x3.5 L-80 13340 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER MD=12724 TVD=12724 ` NIPPLE-CAMCO LANDING NIPPLE MD=1894 TVD=1652 12.Attachments: Description Summary of Proposal - 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development E Service F 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/8/2013 Oil r Gas r VVDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r GINJ r WAG I✓ / 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: Michael.Dammever i 265-6548 Email: Michael.Dammeyer@conocophillips.con Printed Name Mike Damm Title: Sr. Production Engineer ----124,,,...Signature Phone:265-6548 Date -717t/1 Commission Use Only Sundry Number: 513-q l 2 Conditions of approval: Notify Commission so that a representative may witness ," Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: /411/ 4 ( .f� fr kv/1vlt$$rc�) rr�v4 )'-cd all-e- 6 b/ 11 37d n jrh lNw fir,Flaw J r2 GG vfV/&! (4�d`-ry S f T b171 6-( I )-1.J rcot7 1 Spacing Exception Required? Yes 111No Subsequent Form Required: _ l vi r�/7 L LCCeP /41-1t' b 7�6 —40 * RBDMS AUG 7 2 vagal. E APPROVED BY g ' /3 Approved by: AO A r ication is varlQ TOf . NOnths from thTAI tM130 val. Date: Form 10-403(Revised i 0/2012) Vi p R I G I N A Submit Form and Attachment in Duplicate I. , ,, -1 vi ) ''6 Reason for sundry: / Injection well CD1-49 has been completed, and permission to inject water and gas is requested. Once injection has commenced, a Spectra Flow Log will be run to verify no flowing water exists behind the 7" casing. 1Y livel/ U,rf eel,pi i.0-ed fv Ge. , r�0 /�?fill r vas 1 'I " s e��'`' N.- WNS CD1-49 ConocoPhilli "x� Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Teel(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc. 501032066100 ALPINE SVC 92.05 13,892.55 15,348.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release-Date °-•Well Congo.HORIZONTAL-CD1-49,7/26/20137.49:59AM SSSV:WRDP Last WO: 35.99 7/14/2013 Schematic-Achwl Annotation Depth MKS) End Date Annotation Last Mod...End Date Last Tag: Rev Reason.GLV C/O,set WRDP,Pull RHC/Ball/Rod osborl 7/26/2013 HANGER,31 :: Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.250 33.0 114.0 114.0 62.50 H-40 Welded Casing Description String 0... String ID .Top(5KB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd 11� SURFACE 113/4 10.772 36.3 3,108.5 2,338.0 60.00 L-80 BTCM Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd ----------- -- ---INTERMEDIATE 95/8 8.835 2,949.2 11,753.0 6,612.6 40.00 L-80 Hyd 521 = r Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 7 6.276 33.3 11,338.0 6,407.1 26.00 L-80 BTCM TIE-BACK Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 7 6.276 11,367.0 13,433.0 7,151.8 26.00 L-80 Tenaris Blue CONDUCTOR, Liner Details 33-114 Top Depth (TVD) Top Incl Nomi... Top(RKB) (RKB) 1°) Item Description Comment ID(in) ii. WRDP,1,894 1 .:. 13,427.5 7,151.3 85.00 Stabilizer Baker SDL Intergral stabilizer 6.070 NIPPLE,1,894 1s Tubing Strings iii Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 412 3.958 30.8 13,340.1 7,141.1 12.60 L-80 IBTM - E 4.5"x3.5"@12742' Completion Details Top Depth (TVD) Top Incl Nomi... Top MKS) (RKB) (°) Rem Description Comment ID(in) 30.8 30.8 0.00 HANGER FMC TUBING HANGER(Elastomer) 3.900 1,894.1 1,652.0 51.56 NIPPLE BP-6i CAMCO HYD LANDING NIPPLE w/DUMMY PACKOFF 3.812 12,713.8 7,009.2 72.10 NIPPLE HES XN LANDING NIPPLE 3.813 SURFACE,• • 12,723.7 7,012.4 72.35 PACKER BAKER PREMIER PACKER 3.870 12,742.0 7,018.1 72.81 XO-Reducing XO 4-12"Hyd 563 B x 312"EUE P 2.992 12,743.5 7,018.6 72.85 NIPPLE HES XN NIPPLE 2.813' 2.813 13,336.6 7,140.7 82.88 SHOE 3-1/2"Orange Peel shoe,SLHT,9.3#,L-80 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) i rop Depth' INTERMEDIATE (TVD) Top Teel TIE-BACK,- -- Top(ftKB) (ftKB) (°) Description Comment Run Date ID(inl 33-11,339 1,894.1 1,652.0 51.56 WRDP WRDP(HABS-0557)ON 3.81 DB LOCK(OAL-5'S') 7/21/2013 2.125 13,686.0 7,171.5' 87.30 FISH BHA STRING 7/10/2013 2.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (SKI) (fttS) Zone Date (sit... Type Comment 13,099.0 13,130.0 7,100.2 7,107.1 7/12/2013 32.0 SLOTS SLOTTED LINER 13,130.0 13,135.0 7,107.1 7,108.2 7/12/2013 1.0 PERFP PERF PUP 13,135.0 13,227.0 7,108.2 7,125.0 7/12/2013 '32.0 SLOTS SLOTTED LINER 13,227.0 13,232.0 7,125.0 7,125.8 7/12/2013 1.0 PERFP PERF PUP Nr 2,949.11,753 EL 13,232.0 13,325.0 7,125.8 7,139.2 7/122013 32.0 SLOTS SLOTTED LINER Ili 13,325.0 13,331.0 7,139.2 7,140.0 7/12/2013 1.0 PERFP PERF PUP GAS A LIFT. Notes:General&Safety ( End Date Annotation 1/24/2013 NOTE:SET KILL STRING WELL SUSPENDED;WELL COMPLETED 7/15/2013 NIPPLE.12.714 - ...( PACKER, 12,724 III SO-Reducing, 12.742 II NIPPLE,12,744 ;fa II TS, I V W SLOTS, II13. 31 OTS. 13,13-1 PERFP3,135, SLOTS, El13,13513,227 PERFP. - 13,717-13,232 SLOTS, Mandrel Details 13,232-13,325 . Top Depth Top Port S... (ND) Incl 0D Valve Latch Size TRO Run PERFP, 1 N...Top(ftKB) (ftKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Coin... 13.325-13,331 1 1 12,187.5 6,820.9 64.71 CAMCO KBG-4-5 1 GAS LIFT OV BK ,0.250 0.0 7202013 II SHOE,13,337 LINER. - • 11,367-13,433 - FISH,13,686-4W TD(CD1-4.9), 15.348 Bettis, Patricia K (DOA) From: Dammeyer, Michael [Michael.Dammeyer@conocophillips.com] Sent: Thursday, August 01, 2013 11:24 AM To: Bettis, Patricia K(DOA) Cc: Walker, Jack A; Allsup-Drake, Sharon K Subject: RE: CD1-49 (PTD 212-177): Sundry Application Hi Patricia, I believe the PTD should have been WAG, our mistake. The TVD at TD should be 7,172'. Sorry for the confusion. Please let me know if there is anything else we need to do about this. Michael Dammeyer WNS Production Engineer ConocoPhillips Alaska,Inc. 907-265-65481 ATO 1762 From: Bettis, Patricia K(DOA) [mailto:Datricia.bettis@alaska.gov] Sent: Wednesday, July 31, 2013 1:47 PM To: Dammeyer, Michael Subject: [EXTERNAL]CD1-49 (PTD 212-177): Sundry Application Good afternoon Mike, On Form 10-403, Box 15, well status after proposed work is checked "WAG" The AOGCC records show that the well was permitted as a "WINJ" injector. Would you verify which is correct? Also, please provide the TVD effective depth of the well. In Box 11 the measured depth of 13,686' was provided; however, the TVD box was left blank. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 RECEIVED WELL LOG TRANSMITTAL ,J U L 1 7 2013 AOGCC To: Alaska Oil and Gas Conservation Comm. July 9, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 2-- 1i Anchorage, Alaska 99501 2304\ Lo RE: String Shot Record: CD 1-49 —1646 Run Date: 7/4/2013 - 7/5/2013 1 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 CD1-49 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20661-00 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.cook@halliburton.com Date: Signed: pi/S WELL LOG TRANSMITTAL orc To: Alaska Oil and Gas Conservation Comm. June 20, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 I Anchorage, Alaska 99501 .9‘ 4k 1 7 RE: CAST-M/CBL-M/ACE: CD1-49 Run Date: 6/18/2013 )N)N:C21. 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 CD1-49 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20661-00 ACE Log (Processed Log) 1 Color Log 50-103-20661-00 CAST-M/ CBL-M Log (Field Print) 1 Color Log 50-103-20661-00 CBL-M Log (Field Print) 1 Color Log 50-103-20661-00 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.c'•k@halliburton.com Date: Aajat Signed:p-go SIA Ql t w \� � �� s7 THE STATE Alaska Oil and Gas „ALASKA Conservation Commission ret -- _ GOVERNOR SEAN PARNELL 333 West Seventh Avenue F�LA`3�P Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Duncan Hyden r� 177 Alpine Drilling Engineer ( a - ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD1-49 Sundry Number: 313-039 Dear Mr. Hyden: 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, Cathy P. oerster Chair DATED this VI day of January, 2013. Encl. RECEIVED STATE OF ALASKA \I `, ,J`A N [3� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request Abandon❑ va( 0 Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend 1�3 Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown Re-enter Susp Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2 Operator Name 4 Current Well Class 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q 212-177• 3 Address: Stratigraphic ❑ Service Q 10) 6.API Number. i P.O Box 100360 Anchorage,AK 99510-0360 50-10320661 • 7.If perforating. '8 Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? \ CD1-49. Will planned perforations require a spacing exception? Yes ❑ No 9 Property Designation(Lease Number). 10 Field/Pool(s). ADL 372697, 25559 Colville River Field/Alpine Pool- 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth ND(ft): Plugs(measured) Junk(measured) 31023' 13.1rMC i � .2338 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16 114 Surface 3071 11 75 3108 2338 3580 2480 Intermediate Production Liner Perforation Depth MD(ft) Perforation Depth ND(ft)• 'Tubing Size Tubing Grade: Tubing MD(ft). 3 5" L-80 1790 Packers and SSSV Type Packers and SSSV MD(ft)and ND(ft) 12.Attachments. Description Summary of Proposal ❑ 13 Well Class after proposed work- P4111,13 11,,91 Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0' Service 0 14.Estimated Date for 15 Well Status after proposed work. Commencing Operations 1/ 251 Z0/3 Oil ❑ Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval. Date. WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Duncan Hyden Email duncan.hvden(a�conocophillips.com Printed Name Duncan Hyden Title Alpine Drilling Engineer SignatureIt /� Phone 265-6862 Date 1/24/2013 1 COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number: . 1 V 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. .11t o j;{-t1IJ O Gz C C of a rr-VI a r 1 w I/1 11 c1�l 11 t I-t 1 re-5 vrvt e cf v -r v" P c r rv1 t -f- -1-n Cf r---r 11 a 12 --1"/-7- a;. • RBOMS FEB 01201$ Spacing Exception Required? Yes ❑ No Z Subsequent Form Required /C — IC APPROVED BY Approved by'0..../4 / r1 COMMISSIONER THE COMMISSION Date f_ 3/_ /3 Submit Form and 0OR1IJALFoiQ-4R used 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate o ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 January 24, 2013 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 JAN 2 5 2013 Anchorage, Alaska 99501 Re: Sundry Permit: CD1-49 Operational Shutdown (PTD: 212-177) A0000 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to shutdown the operations with the currently approved plan for well CD1-49 (PTD: 212-177). Doyon 19 moved onto CD1-49 on January 11, 2013 with the goal of drilling a 6"horizontal well to • inject into the Alpine C reservoir. The surface hole was drilled, cased to 3108'MD, and cemented with returns to surface. After completing the cement job casing was successfully tested to 3500 psi for 30 minutes. Due to the limited access of CD3 pad the decision was made to suspend CD1-49 until completion of the ice road drilling season. ConocoPhillips intention is to return CD1-49 post CD3 drilling season, approximately April 20th, 2013. Please find attached: ■ Form 10-403 Application • Plan forward • Proposed final well schematic Ifou have anyquestions or require further information, please contact Duncan Hyden at 265- YQY 6862. Sincerely, I—) /4/ Duncan Hyden/ Drilling Engineer Attachments CC: CD1-49 Well File Rob Stinson Chip Alvord Sharon Allsup-Drake/ Central files Proposed Plan: 1. Rig up and orient wellhead. 2. Nipple up BOP stack and check torque on the lock ring 3. Test the wellhead seals to 1,000 psi through the housing test port. 4. Shell test BOP to 3,500 psi for 10 minutes. 5. Rig up and run 3-1/2"EUE tubing kill string to ± 1790'MD. 6. Make-up hanger and landing joint, land same. 7. Install 2 way check valve. 8. Nipple down BOPE and Nipple up Tree 9. Test tubing adapter void to 5,000 psi for 10 minutes. 10. Test Tree 250 psi low/ 5,000 psi high for 5 minutes each 11. Pull 2 way check valve. 12. Rig up lines to displace. 13. Pump sufficient volume of diesel freeze protect to cover the permafrost(1740'MD)and allow to U-tube. 14. Set BPV and secure well. 15. Prep for rig move Schematic: Colville River Field CD1-49 Temporary Surface Suspension Updated 1/2312013 I6' Conductor to 114' CD1-49wp10 3.5"9.3 ppf L-80 EUE-Mod Kill String 2840'FID'2400'TVD Permafrost Depth 1740'MD 1556'TVD _ Diesel Freeze Protect 1790'1 10 1588'TVD I-3 4"40 ppf L-80 BTC-Mod Surface Casing 3 '1.ID ' Cemented to S2338urfaceTVD iSc *I�y�.. THE STATE Alaska Oil and Gas ALAsA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue o�+�LAgy�!• Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD1-49 ConocoPhillips Alaska, Inc. Permit No: 212-177 Surface Location: 566' FNL, 3042' FEL, SEC. 5, Ti1 N, R5E, UM Bottomhole Location: 5036' FNL, 201' FEL, SEC. 17, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. ConocoPhillips Alaska Inc.'s request for a waiver of the Diverter requirement for drilling surface hole is APPROVED. Under 20 AAC 25.035(h)(2) the Commission can waive this requirement if there is sufficient evidence that there is no shallow gas hazard in the area. Multiple wells have been drilled from the CD 1 pad with the closest only 300'away from the proposed surface casing point for CD 1-49. To date there is no evidence of any shallow gas on the drilling pad. 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, Cathy ". Foerster Chair DATED this Z-/ day of November, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA NOV 1 4 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work. 1 b Proposed Well Class: Development-Oil ❑ Service-Winj a • Single Zone a f 1c Specify if well is proposed for Drill a . Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑, Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name 5. Bond LJ Blanket U Single Well 11 Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • CD1-49 • • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 18473'• • ND: 7125 ' . Colville River Field • • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number).?Ite Surface:566'FNL,3042'FEL,Sec.5,T11N,R5E, UM • • ADL 372097a 2SSSS • Alpine Pool . . Top of Productive Horizon 8 Land Use Permit. 13.Approximate Spud Date: 570'FNL,2794'FEL,Sec. 17,T11N,R5E, UM Tobin No.931996 12/1/2012 Total Depth. 9 Acres in Property. 14.Distance to Nearest 5036'FNL,201'FEL,Sec. 17,T12N, R5E, UM 1239 . Property: 12,106'from ADL 372097 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL. • 55 8 feet 15.Distance to Nearest Well Open Surface:x- 385660.6 ' y- 5975565.5 -Zone- 4 GL Elevation above MSL • 19 5 feet to Same Pool CD1-48A,1106' 16.Deviated wells Kickoff depth: •250 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: • 90° deg Downhole:,,3168'Ssiy'2-41:4...A /(4-64•1-. Surface:2512 psig• 18.Casing Program. Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42" 16" 65# H-40 Weld 81' 37' 37' 114' 114' pre-installed 14" 11.75" 60# L-80 BTCM 3115' 37' 37' 3152' 2350' 878 sx 10.7#ASL3,331 sx 15.8 G 11.75" 9.625" 40# L-80 Hyd 521 8650' 3000' _ 2211' 11650' 6542' 531 sx 12.2#G,765 sx 15.8#G 8.5"_ 7"Tieback 26# L-80 TSH Blue 13265' 37' 37' 13302' 7115' 336 sx Class G, 15.8#from TD to +14.5" 12.6# L-80 IBT-M 13114' 37' 37' 13151' 7096' Production Tubing 3.5" 9.3# L-80 EUE 5321' 13152' 7097' 18473' 7126' Uncemented Slotted Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft) Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments. Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Programa 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval Commission Representative' Date: 22. I hereby certify that the foregoing is true and correct. Contact Duncan Hyden @ 265-6862 Email Duncan P.Hyden(a)conocoahillios corn Printed Name 0. L. Alvord Title Alaska Drilling Manager SignatureA,c_o_......_ Phone:265-6120 Date 11 ((44-2 I L-- - Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number 2 I 1 I 7- 50- Io 3- 2 0(4 I -00- :0 1 Date `I( 7f 1/. ... for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed ethane,gas hydrates,or gas contained in shales •g Other: -* Woo ,o,,� -yLOP (G,/ Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No a (.f•M (Dp...„r'�`J, w„ .c.�.e-6w--, H2S measures: Yes [1 No El Directional svy req'd: Yes Z1 No❑ ,/�T- I b Spacing exception req'd: Yes ❑ No 21 Inclination-only svy req'd: Yes❑ No[r1 `t( ` D t M Mfr.-BL- /c-Q tet✓ Submit in duplicate APPROVED BY THE Q /� Approved by f� COMM rsi Date f/ 2-% ��Form 10-401 (Revied 10/2012) This permit is val if r rn(hri �fp\cfmrAssipN i the'datef approval(20 AAC 25.005(g)) `� .t179e ConocoPhillips Alaska,Inc. Post Office Box 100360 y� Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 November 13,2012 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue,Suite 100 NOV 14 2012 Anchorage,Alaska 99501 AOGCC Application for Permit to Drill CD1-49 AOGCC Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore injection well from the CD1 drilling pad. The intended spud date for this well is 12/12/12. It is intended that Doyon Rig 19 be used to drill the well. CD1-49 is planned to be a horizontal Alpine C sand injector. The intermediate hole will be drilled in 2 sections to mitigate shale instability. The 10-5/8"hole—underreamed to 11-3/4"will be drilled to the upper Kalubik and landed at an inclination of 60 deg.and cased with a 9-5/8"liner. The Qannik sands will need to be cemented through a single stage cement job ensuring that cement is brought to 500 feet above the top of the Qannik reservoir. ' The second intermediate will be drilled with a 6 x 8-1/2"steerable drilling liner system down to the Alpine C sand. This interval will build from 60 to 85 deg. inclination,at which point,the inner BHA will be pulled out and the 7"liner cemented in place.After setting and cementing the 7"intermediate liner,a tie-back liner to surface will be run to complete the intermediate casing string. The 6"horizontal section will be geosteered in the Alpine C sand at 90 deg. inclination and the well completed as a injector with a slotted liner. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2)is granted. At CD1,there has not been a frl significant indication of shallow gas or gas hydrates through the surface hole interval. 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. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b) 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 Duncan Hyden at 265-6862 (Duncan.P.Hvden(a�conoconhillips.com)or Chip Alvord at 265-6120. Sincerely, cc: ;) CD1-49 Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson ATO 1728 Duncan Hyden Jack Walker ATO 1740 Drilling Engineer Lanston Chin Kuukpik Corp r� 1 r- 1• ° . rW Ar 'ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 Attachment 3-Well Schematic CD1-49 Weil Plan WP04 Proposed Schematic .•.•.• :::: i i.•• lig •iii 16"65#H-40 Welded Ali depths are Doyon 19 RKB. APli il,i II. Conductor to 114' Upper Completion: MD TVD ... !Hill' „:-...• .... :.•.•.• 1)4-W BAL-0 1000' 1000' .:„. ...... 3.81Z DB Profile(6.06T OD) ... 2)3-1/2"x 1"Camco KBMG GLM(81')wiDOK2 13,121' 7,093' !ily 0 7:11 :,.. E111 pinned for 2500 psi casing to tbg shear .•.•.• ....... ....... „•„:„:„ I .•.•.• ...•.•, ,•••,!:.:: : ....... .•.•.• I 3)XO 4-Y2"12.6#L-80 IBTM 13,151' 7,096 1 ,.•,, ....„.„. :•:.••*.•• x 3-1/2"9,3#L-80 EUE BxP ....... ••• !illii' j 11-3/4"60#L-80 BTC 4)Baker 3.5"x 7"Ported Packer 13152' 7,097' Surface Casing I 3,152MD!2,350'TVD©60' 5)HES XN 2.813"(2.75"NoGo)(83") 13,202 7,104' cemented to surface To be run we RHO plug body I 6)Freecap Swell packer 13350' 7,120' I Planned TOO (-100 ft MD into Alpine C) iiiii j 1111 in 9 58-6,069'ft MD 1111 7)Freecap Swell Packer 13386' 7,122' i I Top Qannik ill] 8)3'1/2",9.3#/ft,1-80 EUE Slotted Liner 18472' 7,126' 6,569'MD 1 a i ill 4,036'TVD ilili 4-1/2" 12.6#L-80 l IM Surface-8500 9)Fiber-Optic cable clamped on every joint ill BT- , ' Hyd 563 8,500'-13152' 10)3 1/2"Orange Peel Shoe 18473' 7126' „,„,. • wiFiber-optic cable clamped . H I on every joint Top HRZ I 11,745'MD! 6,589'TVD p-II 7"x 9 518"Liner Top Packer ilili Iii i • iiii iiii @ 11,300'MD/6,369'TVD I idili! ..,,,.,.. K*1 1111111111 ' ••••••- 12,212'MID! bi'a I lill]R 6,816'TVD ''' gli I 11114.. 9 5/8"40#1-80 Hydril 521 Liner Top Kuparuk C 11: k v, to 11.650'MD!6,542'TVD @ 60' 12,436'MD! 6,909°TVDII, N ']iiiii A Ai\ 1,4‘" LCU ::::.• ••• ... 12,441'MD! 6,911'TVD lip,. N. •IiiEl.. 7"26#1-80 Tenaris Blue Liner .,-;,--‘ to 13,302'POD!7.116'TVD @ 85' Vii"9.3#L-80 EUE Liner •.:s.l. 0"11Pii,. Ttk. 'Iiii],c) w/Fiber-optic cable clamped on every joint 0 0 ... - - /...z....N, - il ,,, _______ - ------------- -.-:-1. Top Alpine C -'",]i]iii„„:,.. . :t 13,250'MD/7,111'TVD ------ ,,,, 6"Hole,TO to 18,473'MD I 7,126'TVD @ 90' CD1-49 APD Page 11 of 13 Printed: 13-Nov-12 A ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 CD1-49 Application for Permit to Drill Document t ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AA C 25.005(fl) 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AA C 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 (Requirements of 20 AAC 25.005(c)(5)) 6. Casing and Cementing Program 5 (Requirements of 20 AAC 25.005(c)(6)) 7. Diverter System Information 5 (Requirements of 20 AA C 25.005(c)(7)) 8. Drilling Fluid Program 6 (Requirements of 20 AAC 25.005(c)(8)) 9. Abnormally Pressured Formation Information 6 (Requirements of 20 AAC 25.005 (c)(9)) 10. Seismic Analysis 6 (Requirements of 20 AAC 25.005(c)(10)) 11. Seabed Condition Analysis 7 (Requirements of 20 AAC 25.005(c)(11)) 12. Evidence of Bonding 7 (Requirements of 20 AAC 25.005(c)(12)) CD1-49 APD ngr^ t s Page 1 of 13 Printed: 13-Nov-12 fib.. A' ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 13. Proposed Drilling Program 7 (Requirements of 20 AAC 25.005(c)(13)) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 (Requirements of 20 AAC 25.005(c)(14)) 15. Attachments 8 Attachment 1 Cement Summary 8 Attachment 2 Directional Plan 8 Attachment 3 Well Schematic 8 Attachment 4 Drilling Hazards Summary 8 CD1-49 APD Page 2 of 13 i `: ! Printed: 13-Nov-12 Li ilk 1 A' 'ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as CD1-49. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for Location at Surface 566' FNL, 3042' FEL, Sec 5, T11N, R5E, UM NAD 1927 RKB Elevation 55.8' AMSL Northings: 5,975,565.51 Eastings: 385,660.62 Pad Elevation 19.5'AMSL Location at Total Depth 5035' FNL, 200' FEL, Sec 17, T11N, R5E, UM Nad 1927 Measured Depth, RKB: 18473.34' Northings: 5,960,495.45 Eastings: 388,321.62 Total Vertical Depth, RKB: 7125.80' Total Vertical Depth, SS: 7070.00' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 19. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Casing Setting Fracture Pore ASP Drilling Depth Gradient Pressure (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 114/ 114 10.9 52 53 11-3/4 3152/2350 14.5 1063 1772 9-5/8 11650/6542 12.5 2960 2508 7 13302/7116 12.5 3220 2512 N/A 18473/7126 12.5 3225 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP to 4000 psi. CD 1-49 APD Page 3 of 13 Printed: 13-Nov-12 A; 'ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) -0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP-(0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 X TVD ASP CALCULATIONS 1. Drilling conductor casing (16") ASP = [(FG x 0.052)-0.1] D = [(10.9 x 0.052)-0.1] x 114= 53 psi OR ASP = FPP-(0.1 x D) = 1063-(0.1 x 114') =1051.6 psi 2. Drilling below conductor(11 3/4") ASP = [(FG x 0.052)-0.1] D = [(14.5 x 0.052)-0.1] x 2350' = 1771.9 psi OR ASP = FPP-(0.1 x D) = 2960-(0.1 x 6542') = 2306 psi 3. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1] D = [(12.5 x 0.052)-0.1]x 6542' = 3598 psi OR ASP = FPP-(0.1 x D) = 3220-(0.1 x7116') = 2508 psi 4. Drilling below intermediate casing (7") ASP = [(FG x 0.052)-0.1] D = [(12.5 x 0.052)-0.1]x 7126' = 3919 psi OR ASP = FPP-(0.1 x D) = 3224-(0.1 x 7126') = 2512 psi - 1.7 rt, (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. CD 1-49 APD Page 4 of 13 CT ICI Printed: 13-Nov-12 ... Al ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/ FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 42 65 H-40 Welded 81' 37'/37' 114'/114' Cemented 4/25/2003 11 %" 14 60 L-80 BTCM 3115' 37'/37' 3152'/2350' 878 sx 10.7#ASL3/331 sx 15.8#G 10-5/8 9 5/8" x 40 L-80 521 8650' 3000'/2221' 11650'/6542' 531 sx 12.2#G/765 sx 15.8#G 11 % 6 Tenaris 7" x 26 L-80 Blue 13265' 37'/37' 1330277116' 336 sx 15.8#G 8 1/2 r-� 4 1/2" N/A 12.6 L-80 IBT-M 7500' 37'/37' 7500'/4495' N/A Hyd 4'/2" N/A 12.6 L-80 563 5621' 7500'/4495' 13121'/7095' N/A EUE- 3'/2" 6 9.6 L-80 5352' 13121'/7095' 18473'/7126' N/A 8RD-M Casing / Liner Design: The 85%collapse and burst ratings are listed in the following table: Wt Connection 85%of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 11-3/4" 60 L-80 3 BTC 3,180 psi 2,703 psi 5,830 psi 4956 psi 9-5/8" 40 L-80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,887 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At CD1, there has not been a significant show of shallow gas or gas hydrates. CD 1-49 APD Page 5 of 13 Printed: 13-Nov-12 A Ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface: Intermediate#1: Intermediate#2: Production: 14" hole 11.75" hole 8.5" hole 6" Hole 11.75" casing 9.625"casing 7" casing Density 8.7— 10.0 ppg 9.6—9.8 ppg 10.9— 11.5 pag.. 10 5 ppg_— PV 10 - 16 10- 16 7 - 12 YP 30-60 13-22 18-22 10 - 15 Funnel Viscosity 100—300 Initial Gels 4— 15 5— 10 6 -9 10 minute gels <30 <25 8 - 12 API Filtrate NC-10cc/30 4-10 cc/30 min <5.0 cc/30 min HPHT Fluid Loss min (drilling) (drilling) at 165 <8.0 cc/30 min <10.0 cc/30 min PH 8.5-9.0 9.5- 10.0 9.0-9.5 Surface Hole: A standard high viscosity fresh water/ gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight< 9.6 ppg by use of solids control system and dilution where necessary. Intermediate#1: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg_and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate#2: Intermediate 2 hole will be drilled with the same fresh water gel / polymer mud system used in the intermediate 1 section. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability and minimizing torque and drag. Production Hole: The horizontal production interval will be drilled using FloPro drill-in fluid. The fluid will consist of 6% KCI/NaCl based brine with calcium carbonate bridging material to minimize formation damage. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. CD 1-49 APD Page 6 of 13 ¢ t t Printed: 13-Nov-12 Le` E d l L A, ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (C)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 19 onto CD1-49. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 14" hole to the surface casing point as per the directional plan. (Directional/MWD/GR/Res). 4. Run and cement 11-3/4" surface casing. 5. Install and test BOPE to 4,000 psi. 6. Pick up and run in hole with 10-5/8" x 11-3/4" drilling BHA to drill intermediate #1. Pressure test casing to 3500 psi/30 mins. 7. Drill out 20' of new hole and perform Leak off Test(LOT)with a minimum value of 12.5 ppg EMW. 8. Drill 10-5/8" hole to just above the HRZ. Under ream to 11-3/4" while drilling. (LWD Program: GR/RES/PWD). 9. Run 9-5/8" liner with hanger and liner top packer. t C 10. Pump single stage cement job to cover the Nanuq and the Qannik sands. 11. BOPE test to 4,000 psi. 12. Pick up 7" steerable liner drilling system with 6" pilot bit and 8-1/2" reamer. 13. Drill out 20' of new hole and LOT test with a minimum value of 12.5 ppa_EMW. 14. Drill 8-1/2" hole to intermediate casing point in the Alpine C sand. (LWD Program: GR/RES/PWD/Neut/Dens/Sonic) 15. Disconnect drilling assembly from liner and POOH with liner drilling BHA. 16. RIH with cementing assembly and cement 7" liner per program. Tie back 7" liner to surface. 17. Freeze protect 11.75" by 7" annulus. 18. BOPE test to 4,000 psi. 19. Pick up and RIH with 6" drilling assembly. (LWD Program: GR/RES/PWD/AZI. RES.). Test casing to 3500 psi. CD 1-49 APD Page 7 of 13 Printed: 13-Nov-12 A tion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 20. Drill out 20' of new hole and LOT test with a minimum value of 12.5 ppg EMW.• 21. Drill 6" horizontal section to TD. 22. Circulate the hole clean and pull out of hole. ape__ 23. Perform CBL to confirm zonal isolation for reservoir containment for fluid injection. 24. Run a tapered completion string of 4-1/2" x 3-1/2" tubing and liner. A production packer will be run below the 4-1/2" x 3-1/2" cross over and swell packers are planned to be run between the 7" shoe and the liner perforations. The 4-1/2" portion will contain a DB profile for injection and a gas lift mandrel set deep. An XN nipple will be run in the 3-1/2" portion below the packer and fiber optic cable is planned to be run on the outside of the string (TD to surf) clamped to the outside of the string. 25. Space out and install hanger, displace to completion brine and land hanger. 26. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 27. Nipple up tree and Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 28. Drop ball and rod. 29. Set production packer. 30. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins./ 31. Shear circulation valve in GLM. 32. Circulate tubing to diesel and install freeze protection in the annulus. 33. Set BPV and secure well. Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Incidental fluids developed from drilling operations on well CD1-49 will be injected into a permitted annulus, or into the class 1 disposal well CD1-01A. CD1-49 will not be a viable candidate for annular injection due to the three string casing design. 15. Attachments Attachment 1 Cement Summary Attachment 2 Directional Plan Attachment 3 Well Schematic Attachment 4 Drilling Hazards Summary CD 1-49 APD Page 8 of 13 Printed: 13-Nov-12 A' 'ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 Attachment 1 -Cementing Summary ✓11.75" Surface Casing run to 3152' MD/2350' TVD Cement from 3152' MD to 2652'(500' of fill)with Class G + adds @ 15.8 PPG, and from 2652'to surface with Arctic Set Lite 3.Assume 250%excess annular volume in permafrost and 50% excess below the permafrost(1669' MD). Lead slurry: (2452'- 1669')X 0.3161 ft3/ft X 1.5(50%excess)=372 ft3 below permafrost (1669'-114')X 0.3161 ft3/ft X 3.5(250%excess)= 1720 ft3 above permafrost 114'X 0.5154 ft3/ft x 1.00(no excess)=59 ft3 in conductor Total volume=372+ 1720+59=2151 ft3=>878 Sx @ 2.45 ft3/sk System: 878 Sx ArcticSet Lite 3 @ 10.7 PPG Tail slurry: (3152'-2452')X 0.3161 ft3/ft X 1.5(50%excess)=332 ft3 annular volume 80'X 0.6329 ft3/ft=51 ft3 shoe joint volume Total volume=232+51=383 ft3=>331 Sx A 1.16 ft3/sk System: 331 Sx Class G+0.2% D046 antifoamer,0.3% D065 dispersant and 0.8% S001 accelerator @ 15.8 PPG yielding 1.16 ft3/sk / 9.625" Intermediate Liner run to 11650' MD/6542'TVD with Under ream hole to 11-3/4" Cement from 9350' to±6000' MD (minimum 500' MD above top of reservoir)with Class G + adds @ 12.2 PPG and from 11650' to 9350' MD Class G + adds @ 15.8 PPG + adds.Assume 50% excess annular volume. Lead Slurry: (9350'-6,069')X 0.2476 ft3/ft X 1.5(50%excess)= 1220 ft3 annular vol. Total volume= 1220 ft3=>531 Sx @ 2.3 ft3/sk System: 531 Sx Class G+0.2% D046 antifoamer,+3.0% D0179 extender+0.4 gal/sk cement D110 retarder @ 12.2 PPG yielding 2.3 ft3/sk Tail Slurry: (11650'-9350')X 0.2476 ft3/ft X 1.4 (50%excess) =855 ft3 annular vol. 80'X 0.42572 ft3/ft=34 ft3 shoe joint volume Total volume=855+34=889 ft3=>765 Sx A 1.17 ft3/sk System: 765 Sx Class G +0.2% D046 antifoamer, +0.3% D065 dispersant+0.4% D167 for fluid loss, 0.11% B155 retarder @ 15.8 PPG yielding 1.17 ft3/sk 7" Liner run to 13302' MD/7116' TVD Cement from 13302' MD to 11250' MD with Class G + adds @ 15.8 PPG. Assume 50% excess annular volume. Lead Slurry: Lap Vol. =(11,365'-11300')x 0.15849 ft3/ft x 1.00(no excess)= 11 ft3 Cap Vol.=(11300'-11250')x 0.28939 ft3/ft x 1.00(no excess)= 15 ft3 Total Vol. = 11 ft3+ 15 ft3=26 ft3=> 12 Sx @ 2.30 ft3/ft System: 12 Sx Class G +0.2% D046 antifomer+3% D079 additives+0.4 gal/sk cement D110 retarder @ 12.2 PPG yielding 2.30 ft3/ft Tail Slurry: Lap Vol.= (11650'-11365')x 0.15849 ft3/ft x 1.00(no excess)=46 ft3 Annular Vol. _(13302'-11650)x 0.12682 ft3/ft x 1.50(50%excess)=315 ft3 Shoe Vol. = (80')x 0.21482 ft/ft x 1.00(no excess)= 18 ft3 46 ft3+315ft3+ 18 ft3=379 ft3 Total Volume=379 ft3=> 324 Sx @ 1.17 ft3/sk System: 324 Sx Class G +0.2% D046 antifoamer,0.3% D065 dispersant, 0.11% B155 retarder and 0.4% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk CD1-49 APD Page 9 of 13 1,', 0 Printed: 13-Nov-12 A' 'ion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 Attachment 2—Directional Plan CD 1-49 APD Page 10 of 13 Printed: 13-Nov-12 ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad Plan: CD1-49 [ Plan: CD1-49 Changed Surface Casing depth to Plan: CD1-49wp04 2350' TVC to avoid penetrating the C30 formation, which historically has shown traces of gas. I Standard Proposal Report p p 24 October, 2012 I I ;r r I 14 17.7 g. 1.1 j� Edi I HAI.;_;LIBURTON Sperry Drilling Services - 1 Northing (4500 ft/in) 1 , r i i I i i i i I I , I I I I I I I I , I I i i i , I i i i I I I I I I 1 „ I I I I i i 1 i 1 1 1 i 1 i l , 1 1 i 1 i 1 , 1 1 1 1 CV O 23 In0 r:a -- o - tO I- d- O CO - o_ d NN. - 3 . m o d m coQ U 0oco 3 o U co pcp . U p U m U 0 4 U r U p p U O p NJ fCO,- ,, �U�IU • p N ,.,,CD L 0� U N o, p ¢ O oo v o ••a) Up N p T 0 Q p`t • 1- a .CO U U � U; m 22 _ aco co a fa 0 U pNNU O. 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T 0 0 I1 1 I I o 0 o O o O O N O O O O o 0 0 o O o N N Co co (u!Al 000z) uldea iaoPan anal ConocoPhillips HALLIBURTO. .. Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: ' Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-49 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-49 Design: CD1-49wp04 Project Western North Slope 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 CD1 Alpine Pad Site Position: Northing: 764.53ft Latitude: 53°45'41.214 N From: Map Easting: -1,140,676.12ft Longitude: 157°35'23.669 W I Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -6.11° Well Plan:CD1-49,Slot 49 Well Position +N/-S 0.00 ft Northing: 5,975,565.51ft Latitude: 70°20'31.533 N +EI-W 0.00 ft Easting: 385,660.62 ft Longitude: 150°55'40.630 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore Plan:CD1-49 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2011 9/4/2012 15.54 79.80 57,340 I Design CD1-49wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (ft) (ft) 1r (ft) (0) 36.30 0.00 0.00 150.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (ft) (0) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) 36.30 0.00 0.00 36.30 -19.50 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 194.20 0.00 0.00 0.00 0.00 0.00 0.00 450.12 3.50 190.00 450.00 394.20 -6.02 -1.06 1.75 1.75 0.00 190.00 600.82 7.27 190.00 600.00 544.20 -19.95 -3.52 2.50 2.50 0.00 0.00 907.71 16.48 190.00 900.00 844.20 -82.06 -14.47 3.00 3.00 0.00 0.00 2,172.78 60.44 179.98 1,867.20 1,811.40 -847.44 -47.08 3.50 3.48 -0.79 -12.52 12,046.36 60.44 179.98 6,737.54 6,681.74 -9,436.23 -44.28 0.00 0.00 0.00 0.00 13,302.42 85.00 149.71 7,115.80 7,060.00 -10,563.72 283.33 3.00 1.95 -2.41 -55.23 13,322.42 85.00 149.71 7,117.54 7,061.74 -10,580.92 293.38 0.00 0.00 0.00 0.00 13,446.67 89.97 149.71 7,122.99 7,067.19 -10,688.08 355.96 4.00 4.00 0.00 0.00 18,473.49 89.97 149.72 7,125.80 7,070.00 -15,029.00 2,890.77 0.00 0.00 0.00 109.35 10/24/2012 12:35:26PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTO.. ... Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-49 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-49 Design: CD1-49wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft' (ft) (ft) (ft) (ft) -19.50 36.30 0.00 0.00 36.30 -19.50 0.00 0.00 5,975,565.51 385,660.62 0.00 0.00 100.00 0.00 0.00 100.00 44.20 0.00 0.00 5,975,565.51 385,660.62 0.00 0.00 200.00 0.00 0.00 200.00 144.20 0.00 0.00 5,975,565.51 385,660.62 0.00 0.00 250.00 0.00 0.00 250.00 194.20 0.00 0.00 5,975,565.51 385,660.62 0.00 0.00 KOP: DLS 1.75 TFO 190 300.00 0.87 190.00 300.00 244.20 -0.38 -0.07 5,975,565.13 385,660.55 1.75 0.29 400.00 2.62 190.00 399.95 344.15 -3.38 -0.60 5,975,562.13 385,659.98 1.75 2.63 450.12 3.50 190.00 450.00 394.20 -6.02 -1.06 5,975,559.50 385,659.47 1.75 4.68 Start Build 2.50 500.00 4.75 190.00 499.75 443.95 -9.56 -1.68 5,975,555.98 385,658.79 2.50 7.43 600.00 7.25 190.00 599.19 543.39 -19.85 -3.50 5,975,545.72 385,656.82 2.50 15.44 600.82 7.27 190.00 600.00 544.20 -19.95 -3.52 5,975,545.62 385,656.80 2.50 15.52 Start DLS 3.00 TFO 0.00 700.00 10.24 190.00 698.02 642.22 -34.82 -6.14 5,975,530.79 385,653.96 3.00 27.08 800.00 13.24 190.00 795.91 740.11 -54.86 -9.67 5,975,510.80 385,650.12 3.00 42.67 900.00 16.24 190.00 892.61 836.81 -79.92 -14.09 5,975,485.82 385,645.32 3.00 62.17 907.71 16.48 190.00 900.00 844.20 -82.06 -14.47 5,975,483.68 385,644.91 3.00 63.83 Start DLS 3.50 TFO-12.53 1,000.00 19.64 187.92 987.74 931.94 -110.32 -18.88 5,975,455.50 385,640.07 3.50 86.10 1,100.00 23.09 186.29 1,080.85 1,025.05 -146.47 -23.34 5,975,419.42 385,635.05 3.50 115.18 1,200.00 26.55 185.06 1,171.60 1,115.80 -188.24 -27.46 5,975,377.72 385,630.30 3.50 149.29 1,300.00 30.02 184.10 1,259.64 1,203.84 -235.47 -31.22 5,975,330.56 385,625.82 3.50 188.32 1,400.00 33.50 183.32 1,344.66 1,288.86 -288.00 -34.61 5,975,278.10 385,621.63 3.50 232.11 1,500.00 36.98 182.67 1,426.32 1,370.52 -345.61 -37.61 5,975,220.54 385,617.75 3.50 280.50 1,600.00 40.46 182.12 1,504.33 1,448.53 -408.10 -40.21 5,975,158.11 385,614.19 3.50 333.31 1,668.91 42.86 181.79 1,555.80 1,500.00 -453.87 -41.77 5,975,112.36 385,611.94 3.50 372.18 Permafrost Base 1,700.00 43.95 181.64 1,578.39 1,522.59 -475.23 -42.41 5,975,091.02 385,610.97 3.50 390.35 1,800.00 47.44 181.22 1,648.23 1,592.43 -546.75 -44.19 5,975,019.54 385,608.10 3.50 451.41 1,900.00 50.92 180.85 1,713.59 1,657.79 -622.41 -45.55 5,974,943.92 385,605.59 3.50 516.24 2,000.00 54.41 180.51 1,774.22 1,718.42 -701.90 -46.49 5,974,864.46 385,603.44 3.50 584.62 2,100.00 57.90 180.19 1,829.91 1,774.11 -784.94 -46.99 5,974,781.44 385,601.68 3.50 656.29 2,172.78 60.44 179.98 1,867.20 1,811.40 -847.44 -47.08 5,974,718.96 385,600.63 3.50 710.36 2,172.79 60.44 179.98 1,867.20 1,811.40 -847.44 -47.08 5,974,718.95 385,600.63 0.02 710.37 Start 9873.59 hold at 2172.79 MD 2,200.00 60.44 179.98 1,880.62 1,824.82 -871.12 -47.07 5,974,695.29 385,600.28 0.00 730.87 2,300.00 60.44 179.98 1,929.95 1,874.15 -958.10 -47.05 5,974,608.32 385,598.98 0.00 806.22 2,400.00 60.44 179.98 1,979.28 1,923.48 -1,045.09 -47.02 5,974,521.34 385,597.68 0.00 881.57 2,500.00 60.44 179.98 2,028.61 1,972.81 -1,132.08 -46.99 5,974,434.37 385,596.38 0.00 956.91 2,600.00 60.44 179.98 2,077.93 2,022.13 -1,219.07 -46.96 5,974,347.40 385,595.08 0.00 1,032.26 2,700.00 60.44 179.98 2,127.26 2,071.46 -1,306.05 -46.93 5,974,260.43 385,593.78 0.00 1,107.61 2,800.00 60.44 179.98 2,176.59 2,120.79 -1,393.04 -46.90 5,974,173.46 385,592.49 0.00 1,182.96 2,900.00 60.44 179.98 2,225.91 2,170.11 -1,480.03 -46.88 5,974,086.49 385,591.19 0.00 1,258.30 3,000.00 60.44 179.98 2,275.24 2,219.44 -1,567.02 -46.85 5,973,999.52 385,589.89 0.00 1,333.65 3,100.00 60.44 179.98 2,324.57 2,268.77 -1,654.00 -46.82 5,973,912.55 385,588.59 0.00 1,409.00 10/24/2012 12:35:26PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips HALLI B U RTO. _ Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-49 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-49 Design: CD1-49wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (1 (ft) ft (ft) (ft) (ft) (ft) 2,294.20 3,151.56 60.44 179.98 2,350.00 2,294.20 -1,698.85 -46.80 5,973,867.71 385,587.92 0.00 1,447.85 11-3/4"x 14" 3,200.00 60.44 179.98 2,373.89 2,318.09 -1,740.99 -46.79 5,973,825.58 385,587.29 0.00 1,484.35 3,234.27 60.44 179.98 2,390.80 2,335.00 -1,770.80 -46.78 5,973,795.77 385,586.85 0.00 1,510.17 C-30 3,300.00 60.44 179.98 2,423.22 2,367.42 -1,827.98 -46.76 5,973,738.61 385,585.99 0.00 1,559.70 3,400.00 60.44 179.98 2,472.55 2,416.75 -1,914.97 -46.73 5,973,651.64 385,584.70 0.00 1,635.04 3,500.00 60.44 179.98 2,521.88 2,466.08 -2,001.95 -46.71 5,973,564.67 385,583.40 0.00 1,710.39 3,600.00 60.44 179.98 2,571.20 2,515.40 -2,088.94 -46.68 5,973,477.70 385,582.10 0.00 1,785.74 3,700.00 60.44 179.98 2,620.53 2,564.73 -2,175.93 -46.65 5,973,390.73 385,580.80 0.00 1,861.09 3,800.00 60.44 179.98 2,669.86 2,614.06 -2,262.92 -46.62 5,973,303.76 385,579.50 0.00 1,936.43 3,900.00 60.44 179.98 2,719.18 2,663.38 -2,349.90 -46.59 5,973,216.79 385,578.20 0.00 2,011.78 3,984.37 60.44 179.98 2,760.80 2,705.00 -2,423.29 -46.57 5,973,143.41 385,577.11 0.00 2,075.35 C-20 4,000.00 60.44 179.98 2,768.51 2,712.71 -2,436.89 -46.56 5,973,129.82 385,576.91 0.00 2,087.13 4,100.00 60.44 179.98 2,817.84 2,762.04 -2,523.88 -46.54 5,973,042.85 385,575.61 0.00 2,162.48 4,200.00 60.44 179.98 2,867.16 2,811.36 -2,610.87 -46.51 5,972,955.88 385,574.31 0.00 2,237.82 4,300.00 60.44 179.98 2,916.49 2,860.69 -2,697.86 -46.48 5,972,868.91 385,573.01 0.00 2,313.17 4,400.00 60.44 179.98 2,965.82 2,910.02 -2,784.84 -46.45 5,972,781.93 385,571.71 0.00 2,388.52 4,500.00 60.44 179.98 3,015.15 2,959.35 -2,871.83 -46.42 5,972,694.96 385,570.42 0.00 2,463.87 4,600.00 60.44 179.98 3,064.47 3,008.67 -2,958.82 -46.39 5,972,607.99 385,569.12 0.00 2,539.21 4,700.00 60.44 179.98 3,113.80 3,058.00 -3,045.81 -46.37 5,972,521.02 385,567.82 0.00 2,614.56 4,800.00 60.44 179.98 3,163.13 3,107.33 -3,132.79 -46.34 5,972,434.05 385,566.52 0.00 2,689.91 4,900.00 60.44 179.98 3,212.45 3,156.65 -3,219.78 -46.31 5,972,347.08 385,565.22 0.00 2,765.26 5,000.00 60.44 179.98 3,261.78 3,205.98 -3,306.77 -46.28 5,972,260.11 385,563.92 0.00 2,840.61 5,100.00 60.44 179.98 3,311.11 3,255.31 -3,393.76 -46.25 5,972,173.14 385,562.63 0.00 2,915.95 5,200.00 60.44 179.98 3,360.44 3,304.64 -3,480.74 -46.22 5,972,086.17 385,561.33 0.00 2,991.30 5,300.00 60.44 179.98 3,409.76 3,353.96 -3,567.73 -46.20 5,971,999.20 385,560.03 0.00 3,066.65 5,400.00 60.44 179.98 3,459.09 3,403.29 -3,654.72 -46.17 5,971,912.23 385,558.73 0.00 3,142.00 5,500.00 60.44 179.98 3,508.42 3,452.62 -3,741.71 -46.14 5,971,825.26 385,557.43 0.00 3,217.34 5,600.00 60.44 179.98 3,557.74 3,501.94 -3,828.69 -46.11 5,971,738.29 385,556.13 0.00 3,292.69 5,700.00 60.44 179.98 3,607.07 3,551.27 -3,915.68 -46.08 5,971,651.32 385,554.84 0.00 3,368.04 5,800.00 60.44 179.98 3,656.40 3,600.60 -4,002.67 -46.05 5,971,564.35 385,553.54 0.00 3,443.39 5,900.00 60.44 179.98 3,705.72 3,649.92 -4,089.66 -46.03 5,971,477.38 385,552.24 0.00 3,518.73 6,000.00 60.44 179.98 3,755.05 3,699.25 -4,176.64 -46.00 5,971,390.41 385,550.94 0.00 3,594.08 6,100.00 60.44 179.98 3,804.38 3,748.58 -4,263.63 -45.97 5,971,303.44 385,549.64 0.00 3,669.43 6,102.88 60.44 179.98 3,805.80 3,750.00 -4,266.14 -45.97 5,971,300.93 385,549.61 0.00 3,671.60 K-3 6,200.00 60.44 179.98 3,853.71 3,797.91 -4,350.62 -45.94 5,971,216.47 385,548.34 0.00 3,744.78 6,300.00 60.44 179.98 3,903.03 3,847.23 -4,437.61 -45.91 5,971,129.49 385,547.05 0.00 3,820.12 6,400.00 60.44 179.98 3,952.36 3,896.56 -4,524.59 -45.88 5,971,042.52 385,545.75 0.00 3,895.47 6,494.15 60.44 179.98 3,998.80 3,943.00 -4,606.49 -45.86 5,970,960.64 385,544.53 0.00 3,966.41 1 K-3 Base 6,500.00 60.44 179.98 4,001.69 3,945.89 -4,611.58 -45.85 5,970,955.55 385,544.45 0.00 3,970.82 10/24/2012 12:35:26PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTO. Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-49 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-49 Design: CD1-49wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +141-S +E/-W Northing Easting DLS Vert Section (ft), (°) (0) (ft) ft (ft) (ft) (ft) (ft) 3,980.00 6,569.16 60.44 179.98 4,035.80 3,980.00 -4,671.74 -45.84 5,970,895.41 385,543.55 0.00 4,022.93 K-2(Qannik) 6,600.00 60.44 179.98 4,051.01 3,995.21 -4,698.57 -45.83 5,970,868.58 385,543.15 0.00 4,046.17 6,700.00 60.44 179.98 4,100.34 4,044.54 -4,785.56 -45.80 5,970,781.61 385,541.85 0.00 4,121.52 6,800.00 60.44 179.98 4,149.67 4,093.87 -4,872.55 -45.77 5,970,694.64 385,540.56 0.00 4,196.86 6,800.27 60.44 179.98 4,149.80 4,094.00 -4,872.78 -45.77 5,970,694.41 385,540.55 0.00 4,197.07 K-2 Base 6,900.00 60.44 179.98 4,198.99 4,143.19 -4,959.53 -45.74 5,970,607.67 385,539.26 0.00 4,272.21 7,000.00 60.44 179.98 4,248.32 4,192.52 -5,046.52 -45.71 5,970,520.70 385,537.96 0.00 4,347.56 7,100.00 60.44 179.98 4,297.65 4,241.85 -5,133.51 -45.68 5,970,433.73 385,536.66 0.00 4,422.91 7,200.00 60.44 179.98 4,346.98 4,291.18 -5,220.50 -45.66 5,970,346.76 385,535.36 0.00 4,498.25 7,300.00 60.44 179.98 4,396.30 4,340.50 -5,307.48 -45.63 5,970,259.79 385,534.06 0.00 4,573.60 7,400.00 60.44 179.98 4,445.63 4,389.83 -5,394.47 -45.60 5,970,172.82 385,532.77 0.00 4,648.95 7,500.00 60.44 179.98 4,494.96 4,439.16 -5,481.46 -45.57 5,970,085.85 385,531.47 0.00 4,724.30 7,600.00 60.44 179.98 4,544.28 4,488.48 -5,568.45 -45.54 5,969,998.88 385,530.17 0.00 4,799.64 7,700.00 60.44 179.98 4,593.61 4,537.81 -5,655.43 -45.51 5,969,911.91 385,528.87 0.00 4,874.99 7,800.00 60.44 179.98 4,642.94 4,587.14 -5,742.42 -45.49 5,969,824.94 385,527.57 0.00 4,950.34 7,900.00 60.44 179.98 4,692.26 4,636.46 -5,829.41 -45.46 5,969,737.97 385,526.27 0.00 5,025.69 8,000.00 60.44 179.98 4,741.59 4,685.79 -5,916.40 -45.43 5,969,651.00 385,524.98 0.00 5,101.03 8,100.00 60.44 179.98 4,790.92 4,735.12 -6,003.38 -45.40 5,969,564.03 385,523.68 0.00 5,176.38 8,200.00 60.44 179.98 4,840.25 4,784.45 -6,090.37 -45.37 5,969,477.06 385,522.38 0.00 5,251.73 8,300.00 60.44 179.98 4,889.57 4,833.77 -6,177.36 -45.34 5,969,390.08 385,521.08 0.00 5,327.08 8,400.00 60.44 179.98 4,938.90 4,883.10 -6,264.35 -45.32 5,969,303.11 385,519.78 0.00 5,402.43 8,500.00 60.44 179.98 4,988.23 4,932.43 -6,351.33 -45.29 5,969,216.14 385,518.49 0.00 5,477.77 8,600.00 60.44 179.98 5,037.55 4,981.75 -6,438.32 -45.26 5,969,129.17 385,517.19 0.00 5,553.12 8,700.00 60.44 179.98 5,086.88 5,031.08 -6,525.31 -45.23 5,969,042.20 385,515.89 0.00 5,628.47 8,800.00 60.44 179.98 5,136.21 5,080.41 -6,612.30 -45.20 5,968,955.23 385,514.59 0.00 5,703.82 8,900.00 60.44 179.98 5,185.54 5,129.74 -6,699.29 -45.17 5,968,868.26 385,513.29 0.00 5,779.16 9,000.00 60.44 179.98 5,234.86 5,179.06 -6,786.27 -45.15 5,968,781.29 385,511.99 0.00 5,854.51 9,100.00 60.44 179.98 5,284.19 5,228.39 -6,873.26 -45.12 5,968,694.32 385,510.70 0.00 5,929.86 9,200.00 60.44 179.98 5,333.52 5,277.72 -6,960.25 -45.09 5,968,607.35 385,509.40 0.00 6,005.21 9,300.00 60.44 179.98 5,382.84 5,327.04 -7,047.24 -45.06 5,968,520.38 385,508.10 0.00 6,080.55 9,400.00 60.44 179.98 5,432.17 5,376.37 -7,134.22 -45.03 5,968,433.41 385,506.80 0.00 6,155.90 9,500.00 60.44 179.98 5,481.50 5,425.70 -7,221.21 -45.00 5,968,346.44 385,505.50 0.00 6,231.25 9,600.00 60.44 179.98 5,530.82 5,475.02 -7,308.20 -44.98 5,968,259.47 385,504.20 0.00 6,306.60 9,700.00 60.44 179.98 5,580.15 5,524.35 -7,395.19 -44.95 5,968,172.50 385,502.91 0.00 6,381.95 9,800.00 60.44 179.98 5,629.48 5,573.68 -7,482.17 -44.92 5,968,085.53 385,501.61 0.00 6,457.29 9,900.00 60.44 179.98 5,678.81 5,623.01 -7,569.16 -44.89 5,967,998.56 385,500.31 0.00 6,532.64 10,000.00 60.44 179.98 5,728.13 5,672.33 -7,656.15 -44.86 5,967,911.59 385,499.01 0.00 6,607.99 10,100.00 60.44 179.98 5,777.46 5,721.66 -7,743.14 -44.83 5,967,824.62 385,497.71 0.00 6,683.34 10,200.00 60.44 179.98 5,826.79 5,770.99 -7,830.12 -44.81 5,967,737.64 385,496.41 0.00 6,758.68 10,300.00 60.44 179.98 5,876.11 5,820.31 -7,917.11 -44.78 5,967,650.67 385,495.12 0.00 6,834.03 10,309.50 60.44 179.98 5,880.80 5,825.00 -7,925.38 -44.77 5,967,642.41 385,494.99 0.00 6,841.19 Albian 97 10,400.00 60.44 179.98 5,925.44 5,869.64 -8,004.10 -44.75 5,967,563.70 385,493.82 0.00 6,909.38 10/24/2012 12:35:26PM r'''''' .r^,, Pabe 5 COMPASS 2003.16 Build 69 ConocoPhillips HALLI B U RTO. _. Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-49 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-49 Design: CD1-49wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/S +E/-W Northing Easting DLS Veil Section (ft) (°) e) (ft) ft (ft) (ft) (ft) (ft) 5,918.97 10,500.00 60.44 179.98 5,974.77 5,918.97 -8,091.09 -44.72 5,967,476.73 385,492.52 0.00 6,984.73 10,600.00 60.44 179.98 6,024.09 5,968.29 -8,178.07 -44.69 5,967,389.76 385,491.22 0.00 7,060.07 10,700.00 60.44 179.98 6,073.42 6,017.62 -8,265.06 -44.66 5,967,302.79 385,489.92 0.00 7,135.42 10,800.00 60.44 179.98 6,122.75 6,066.95 -8,352.05 -44.64 5,967,215.82 385,488.63 0.00 7,210.77 10,900.00 60.44 179.98 6,172.08 6,116.28 -8,439.04 -44.61 5,967,128.85 385,487.33 0.00 7,286.12 10,937.96 60.44 179.98 6,190.80 6,135.00 -8,472.06 -44.60 5,967,095.84 385,486.83 0.00 7,314.72 Albian 96-Nanuq 11,000.00 60.44 179.98 6,221.40 6,165.60 -8,526.02 -44.58 5,967,041.88 385,486.03 0.00 7,361.46 11,100.00 60.44 179.98 6,270.73 6,214.93 -8,613.01 -44.55 5,966,954.91 385,484.73 0.00 7,436.81 11,100.14 60.44 179.98 6,270.80 6,215.00 -8,613.14 -44.55 5,966,954.79 385,484.73 0.00 7,436.92 Nanuq Base 11,200.00 60.44 179.98 6,320.06 6,264.26 -8,700.00 -44.52 5,966,867.94 385,483.43 0.00 7,512.16 11,300.00 60.44 179.98 6,369.38 6,313.58 -8,786.99 -44.49 5,966,780.97 385,482.13 0.00 7,587.51 11,400.00 60.44 179.98 6,418.71 6,362.91 -8,873.98 -44.47 5,966,694.00 385,480.84 0.00 7,662.86 11,500.00 60.44 179.98 6,468.04 6,412.24 -8,960.96 -44.44 5,966,607.03 385,479.54 0.00 7,738.20 1 11,600.00 60.44 179.98 6,517.36 6,461.56 -9,047.95 -44.41 5,966,520.06 385,478.24 0.00 7,813.55 11,650.00 60.44 179.98 6,542.03 6,486.23 -9,091.44 -44.39 5,966,476.57 385,477.59 0.00 7,851.22 9-5/8"x 11-3/4" 11,700.00 60.44 179.98 6,566.69 6,510.89 -9,134.94 -44.38 5,966,433.09 385,476.94 0.00 7,888.90 11,744.82 60.44 179.98 6,588.80 6,533.00 -9,173.93 -44.37 5,966,394.11 385,476.36 0.00 7,922.67 HRZ 11,800.00 60.44 179.98 6,616.02 6,560.22 -9,221.93 -44.35 5,966,346.12 385,475.64 0.00 7,964.25 11,900.00 60.44 179.98 6,665.35 6,609.55 -9,308.91 -44.32 5,966,259.15 385,474.34 0.00 8,039.59 12,000.00 60.44 179.98 6,714.67 6,658.87 -9,395.90 -44.30 5,966,172.18 385,473.05 0.00 8,114.94 12,046.36 60.44 179.98 6,737.54 6,681.74 -9,436.23 -44.28 5,966,131.86 385,472.44 0.00 8,149.87 12,046.38 60.44 179.98 6,737.55 6,681.75 -9,436.25 -44.28 5,966,131.84 385,472.44 0.00 8,149.89 Start DLS 3.00 TFO-55.22 12,069.32 60.84 179.33 6,748.80 6,693.00 -9,456.24 -44.16 5,966,111.84 385,472.26 3.00 8,167.27 HRZ base 12,100.00 61.37 178.48 6,763.62 6,707.82 -9,483.09 -43.65 5,966,084.99 385,472.36 3.00 8,190.78 12,200.00 63.14 175.74 6,810.18 6,754.38 -9,571.47 -39.16 5,965,996.57 385,475.50 3.00 8,269.55 12,212.48 63.36 175.40 6,815.80 6,760.00 -9,582.58 -38.30 5,965,985.44 385,476.19 3.00 8,279.61 K-1 12,300.00 64.96 173.09 6,853.94 6,798.14 -9,660.94 -30.39 5,965,906.98 385,482.90 3.00 8,351.42 12,400.00 66.83 170.51 6,894.79 6,838.99 -9,751.27 -17.36 5,965,816.47 385,494.56 3.00 8,436.17 12,436.10 67.51 169.60 6,908.80 6,853.00 -9,784.05 -11.61 5,965,783.61 385,499.80 3.00 8,467.43 Kuparuk C 12,441.34 67.61 169.47 6,910.80 6,855.00 -9,788.81 -10.73 5,965,778.84 385,500.61 3.00 8,471.99 LCU-Miluveach 12,500.00 68.73 168.01 6,932.61 6,876.81 -9,842.21 -0.10 5,965,725.28 385,510.43 3.00 8,523.55 12,600.00 70.68 165.57 6,967.30 6,911.50 -9,933.50 21.34 5,965,633.68 385,530.47 3.00 8,613.34 12,700.00 72.65 163.19 6,998.76 6,942.96 -10,024.91 46.90 5,965,541.91 385,554.63 3.00 8,705.27 12,800.00 74.65 160.87 7,026.91 6,971.11 -10,116.17 76.51 5,965,450.21 385,582.84 3.00 8,799.11 12,900.00 76.68 158.58 7,051.67 6,995.87 -10,207.04 110.09 5,965,358.85 385,615.03 3.00 8,894.60 13,000.00 78.73 156.34 7,072.97 7,017.17 -10,297.26 147.55 5,965,268.07 385,651.11 3.00 8,991.47 10/24/2012 12:35:26PM Page Q t. t 4.,.9 COMPASS 2003.16 Build 69 1 a i t, i `'c G t ConocoPhillips HALLI B U R TO i. Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-49 Survey Calculation Method: Minimum Curvature 'Wellbore: Plan:CD1-49 Design: CD1-49wp04 'Planned Survey Measured Vertical Map Map 1 Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section 1 (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 7,034.95 13,100.00 80.79 154.12 7,090.75 7,034.95 -10,386.60 188.78 5,965,178.12 385,690.97 3.00 9,089.45 13,132.73 81.47 153.40 7,095.80 7,040.00 -10,415.60 203.08 5,965,148.91 385,704.82 3.00 9,121.72 Alpine D 13,200.00 82.86 151.93 7,104.97 7,049.17 -10,474.80 233.68 5,965,089.25 385,734.51 3.00 9,188.29 ' 13,250.64 83.92 150.83 7,110.80 7,055.00 -10,518.96 257.77 5,965,044.74 385,757.92 3.00 9,238.57 Alpine C 13,300.00 84.95 149.76 7,115.59 7,059.79 -10,561.63 282.11 5,965,001.70 385,781.61 3.00 9,287.70 13,302.31 85.00 149.71 7,115.79 7,059.99 -10,563.62 283.27 5,964,999.70 385,782.74 3.00 9,290.00 Start 20.00 hold at 13302.31 MD-7"x 8-1/2" 13,302.42 85.00 149.71 7,115.80 7,060.00 -10,563.72 283.33 5,964,999.60 385,782.79 3.00 9,290.11 CD1-39South 11Jan12 Heel(copy) 13,322.31 85.00 149.71 7,117.53 7,061.73 -10,580.82 293.32 5,964,982.34 385,792.52 0.00 9,309.92 Start Build 4.00 13,322.42 85.00 149.71 7,117.54 7,061.74 -10,580.92 293.38 5,964,982.24 385,792.58 0.00 9,310.04 13,400.00 88.10 149.71 7,122.21 7,066.41 -10,647.78 332.43 5,964,914.80 385,830.60 4.00 9,387.46 13,446.56 89.97 149.71 7,122.99 7,067.19 -10,687.98 355.90 5,964,874.26 385,853.46 4.00 9,434.01 Start DLS 0.00 TFO 180.00 13,446.67 89.97 149.71 7,122.99 7,067.19 -10,688.08 355.96 5,964,874.16 385,853.52 4.00 9,434.13 13,500.00 89.97 149.71 7,123.02 7,067.22 -10,734.12 382.86 5,964,827.71 385,879.70 0.00 9,487.45 13,600.00 89.97 149.71 7,123.07 7,067.27 -10,820.47 433.29 5,964,740.61 385,928.81 0.00 9,587.45 13,700.00 89.97 149.71 7,123.13 7,067.33 -10,906.82 483.72 5,964,653.50 385,977.92 0.00 9,687.45 13,800.00 89.97 149.71 7,123.18 7,067.38 -10,993.18 534.16 5,964,566.40 386,027.02 0.00 9,787.45 13,900.00 89.97 149.71 7,123.23 7,067.43 -11,079.53 584.59 5,964,479.30 386,076.13 0.00 9,887.45 14,000.00 89.97 149.71 7,123.29 7,067.49 -11,165.88 635.02 5,964,392.19 386,125.23 0.00 9,987.45 14,100.00 89.97 149.71 7,123.34 7,067.54 -11,252.23 685.45 5,964,305.09 386,174.34 0.00 10,087.44 14,200.00 89.97 149.71 7,123.39 7,067.59 -11,338.58 735.89 5,964,217.99 386,223.44 0.00 10,187.44 14,300.00 89.97 149.71 7,123.45 7,067.65 -11,424.93 786.32 5,964,130.88 386,272.55 0.00 10,287.44 14,400.00 89.97 149.71 7,123.50 7,067.70 -11,511.29 836.75 5,964,043.78 386,321.65 0.00 10,387.44 14,500.00 89.97 149.71 7,123.55 7,067.75 -11,597.64 887.18 5,963,956.68 386,370.76 0.00 10,487.44 14,600.00 89.97 149.71 7,123.61 7,067.81 -11,683.99 937.61 5,963,869.57 386,419.86 0.00 10,587.44 14,700.00 89.97 149.72 7,123.66 7,067.86 -11,770.34 988.04 5,963,782.47 386,468.96 0.00 10,687.44 14,800.00 89.97 149.72 7,123.71 7,067.91 -11,856.70 1,038.47 5,963,695.36 386,518.07 0.00 10,787.44 14,900.00 89.97 149.72 7,123.77 7,067.97 -11,943.05 1,088.90 5,963,608.26 386,567.17 0.00 10,887.43 15,000.00 89.97 149.72 7,123.82 7,068.02 -12,029.40 1,139.33 5,963,521.15 386,616.27 0.00 10,987.43 15,100.00 89.97 149.72 7,123.88 7,068.08 -12,115.76 1,189.76 5,963,434.05 386,665.37 0.00 11,087.43 15,200.00 89.97 149.72 7,123.93 7,068.13 -12,202.11 1,240.19 5,963,346.94 386,714.47 0.00 11,187.43 15,300.00 89.97 149.72 7,123.99 7,068.19 -12,288.46 1,290.61 5,963,259.84 386,763.57 0.00 11,287.43 15,400.00 89.97 149.72 7,124.04 7,068.24 -12,374.82 1,341.04 5,963,172.73 386,812.68 0.00 11,387.43 15,500.00 89.97 149.72 7,124.10 7,068.30 -12,461.17 1,391.47 5,963,085.63 386,861.78 0.00 11,487.43 15,600.00 89.97 149.72 7,124.15 7,068.35 -12,547.53 1,441.90 5,962,998.52 386,910.88 0.00 11,587.43 15,700.00 89.97 149.72 7,124.21 7,068.41 -12,633.88 1,492.32 5,962,911.41 386,959.98 0.00 11,687.42 15,800.00 89.97 149.72 7,124.26 7,068.46 -12,720.24 1,542.75 5,962,824.31 387,009.07 0.00 11,787.42 15,900.00 89.97 149.72 7,124.32 7,068.52 -12,806.59 1,593.18 5,962,737.20 387,058.17 0.00 11,887.42 I 16,000.00 89.97 149.72 7,124.38 7,068.58 -12,892.95 1,643.60 5,962,650.09 387,107.27 0.00 11,987.42 16,100.00 89.97 149.72 7,124.43 7,068.63 -12,979.30 1,694.03 5,962,562.99 387,156.37 0.00 12,087.42 10/24/2012 12:35:26PM ifagel tk, I 4 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTO_ Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-49 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-49 Design: CD1-49wp04 !Planned Survey Measured Vertical Map Map I Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section i (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 7,068.69 16,200.00 89.97 149.72 7,124.49 7,068.69 -13,065.66 1,744.45 5,962,475.88 387,205.47 0.00 12,187.42 16,300.00 89.97 149.72 7,124.54 7,068.74 -13,152.01 1,794.88 5,962,388.77 387,254.57 0.00 12,287.42 16,400.00 89.97 149.72 7,124.60 7,068.80 -13,238.37 1,845.30 5,962,301.66 387,303.66 0.00 12,387.42 16,500.00 89.97 149.72 7,124.66 7,068.86 -13,324.73 1,895.73 5,962,214.56 387,352.76 0.00 12,487.41 16,600.00 89.97 149.72 7,124.71 7,068.91 -13,411.08 1,946.15 5,962,127.45 387,401.86 0.00 12,587.41 16,700.00 89.97 149.72 7,124.77 7,068.97 -13,497.44 1,996.57 5,962,040.34 387,450.95 0.00 12,687.41 16,800.00 89.97 149.72 7,124.83 7,069.03 -13,583.80 2,047.00 5,961,953.23 387,500.05 0.00 12,787.41 16,900.00 89.97 149.72 7,124.88 7,069.08 -13,670.15 2,097.42 5,961,866.12 387,549.15 0.00 12,887.41 17,000.00 89.97 149.72 7,124.94 7,069.14 -13,756.51 2,147.84 5,961,779.01 387,598.24 0.00 12,987.41 17,100.00 89.97 149.72 7,125.00 7,069.20 -13,842.87 2,198.26 5,961,691.90 387,647.34 0.00 13,087.41 17,200.00 89.97 149.72 7,125.06 7,069.26 -13,929.23 2,248.68 5,961,604.79 387,696.43 0.00 13,187.41 17,300.00 89.97 149.72 7,125.11 7,069.31 -14,015.58 2,299.11 5,961,517.69 387,745.52 0.00 13,287.40 17,400.00 89.97 149.72 7,125.17 7,069.37 -14,101.94 2,349.53 5,961,430.58 387,794.62 0.00 13,387.40 17,500.00 89.97 149.72 7,125.23 7,069.43 -14,188.30 2,399.95 5,961,343.47 387,843.71 0.00 13,487.40 17,600.00 89.97 149.72 7,125.29 7,069.49 -14,274.66 2,450.37 5,961,256.36 387,892.80 0.00 13,587.40 17,700.00 89.97 149.72 7,125.35 7,069.55 -14,361.02 2,500.79 5,961,169.25 387,941.90 0.00 13,687.40 17,800.00 89.97 149.72 7,125.40 7,069.60 -14,447.38 2,551.21 5,961,082.14 387,990.99 0.00 13,787.40 17,900.00 89.97 149.72 7,125.46 7,069.66 -14,533.74 2,601.63 5,960,995.02 388,040.08 0.00 13,887.40 18,000.00 89.97 149.72 7,125.52 7,069.72 -14,620.09 2,652.05 5,960,907.91 388,089.17 0.00 13,987.40 18,100.00 89.97 149.72 7,125.58 7,069.78 -14,706.45 2,702.46 5,960,820.80 388,138.27 0.00 14,087.40 18,200.00 89.97 149.72 7,125.64 7,069.84 -14,792.81 2,752.88 5,960,733.69 388,187.36 0.00 14,187.39 18,300.00 89.97 149.72 7,125.70 7,069.90 -14,879.17 2,803.30 5,960,646.58 388,236.45 0.00 14,287.39 18,400.00 89.97 149.72 7,125.76 7,069.96 -14,965.53 2,853.72 5,960,559.47 388,285.54 0.00 14,387.39 18,473.34 89.97 149.72 7,125.80 7,070.00 -15,028.87 2,890.69 5,960,495.58 388,321.54 0.00 14,460.73 TD at 18473.34-3-1/2"x 6" 18,473.49 89.97 149.72 7,125.80 7,070.00 -15,029.00 2,890.77 5,960,495.45 388,321.62 0.11 14,460.88 CD1-39South 11Jan12 Toe(copy) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (0) (ft) (ft) (ft) (ft) (ft) CD1-39South 11Jan12 Toe(copy) 0.00 0.00 7,125.80 -15,029.00 2,890.77 5,960,495.45 388,321.62 -plan hits target center -Circle(radius 100.00) CD1-39South 11Jan12 Heel(copy) 0.00 0.00 7,115.80 -10,563.72 283.33 5,964,999.60 385,782.79 -plan hits target center -Circle(radius 100.00) 10/24/2012 12:35:26PM 'Page 8 - COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTO. Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-49 Company: ConocoPhillips(Alaska)Inc. :TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope r MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine PadJNorth Reference: True Well: Plan:CD1-49 ,Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-49 Design: CD1-49wp04 Casing Points I Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,151.56 2,350.00 11-3/4"x 14" 11-3/4 14 11,650.00 6,542.03 9-5/8"x 11-3/4" 9-5/8 11-3/4 13,302.31 7,115.79 7"x 8-1/2" 7 8-1/2 18,473.34 7,125.80 3-1/2"x 6" 3-1/2 6 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 12,212.48 6,815.80 K-1 0.00 10,937.96 6,190.80 Albian 96-Nanuq 0.00 13,250.64 7,110.80 Alpine C 0.00 6,102.88 3,805.80 K-3 0.00 11,744.82 6,588.80 HRZ 0.00 12,441.34 6,910.80 LCU-Miluveach 0.00 6,569.16 4,035.80 K-2(Qannik) 0.00 11,100.14 6,270.80 Nanuq Base • 0.00 10,309.50 5,880.80 Albian 97 0.00 12,436.10 6,908.80 Kuparuk C 0.00 3,984.37 2,760.80 C-20 0.00 12,069.32 6,748.80 HRZ base 0.00 3,234.27 2,390.80 C-30 0.00 1,668.91 1,555.80 Permafrost Base 0.00 13,132.73 7,095.80 Alpine D 0.00 6,494.15 3,998.80 K-3 Base 0.00 6,800.27 4,149.80 K-2 Base 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) +', Comment 250.00 250.00 0.00 0.00 KOP: DLS 1.75 TFO 190 450.12 450.00 -6.02 -1.06 Start Build 2.50 600.82 600.00 -19.95 -3.52 Start DLS 3.00 TFO 0.00 907.71 900.00 -82.06 -14.47 Start DLS 3.50 TFO-12.53 2,172.79 1,867.20 -847.44 -47.08 Start 9873.59 hold at 2172.79 MD 12,046.38 6,737.55 -9,436.25 -44.28 Start DLS 3.00 TFO-55.22 13,302.31 7,115.79 -10,563.62 283.27 Start 20.00 hold at 13302.31 MD 13,322.31 7,117.53 -10,580.82 293.32 Start Build 4.00 13,446.56 7,122.99 -10,687.98 355.90 Start DLS 0.00 TFO 180.00 11 18,473.34 7,125.80 -15,028.87 2,890.69 TD at 18473.34 10/24/2012 12:35:26PM • Page ! s COMPASS 2003.16 Build 69 �a».` a a i 41 i i '' i ti L. 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N e-- •-- • s- s- s- s- .- w cl- d co -a _ _ o O -a co co O) N O) N (f) V V O (O O (O O) CO O CO CO O M V M O) (- O) N `— N N - N O) co O) co co v. co to O ,- O s- O) N co ,- co O N V N co co co co co N CO E O N O O O (O O) N N O M O M V N M N M N CO O (O N N L V N 3 L V co co co M (T CO N N to N to N co N N N N V (- 0) N h N (- V O) 01 C R $ V V V co V (C) (h N- N-N- N co N CO I CO co C) co co V V co r V V V - (O (O N E 0 O^ c0 i.i R O) (O V CO V (O CO CO CO CO V V 0 N CD CO CO CO CO (O LU CO V Cr Cr Cr N- co E O M (O V O V O O O (O CO O) V O) 4 v M O V O O O O C) O C) • O a c V r r V V V 4 O O) O O) O M4 O) O) O) O) n: O M4 O6 ca N.: ^ E C co CO N N N N N N co co O) O O) O co CO (- ti r N- co co V V V V V V co M V a) C y C N m a w 1" W U _ O) ( y x a M m N O) N (C) V O (O O .1-)) O) CO CO CO CO CO CO Cr Mr-- O) - N 0 M CoO) M M CO CO O O 0) Cl-) co .- M ,- O N V M CO C) COM COO N- C-1 U s- O L O N O (C) O t) O (O N N O M O M v N M N M N (O (O N N (O 4 I 3 V O M O M Co N N (O N (C) N co N N- N N- V ,--- co ‘- N N- N N V O) Z R 4-, 'cf V V U) V (C) co N-N- N-N- N co N co N co co co co co V V co N V V V - CO (U u ❑ 'a 0 EE 0 f6 c c n 0 m co a rn in Cr) t O a) RS Q. ` 00 o a) E U 7 U R L R 3 LL Z 20 I.1 oa � a, c °) O m m m m m m m m m O 'F'' m � 2m a as a as as as O U f6 (O (O O 6) O V V (n a $ N O M M M co CO V V Fel Ct. �+ C_ M U (O (O O O (- CO 0 0 6) 0 0 0 0 N N co co V V ❑ ❑ (1l CO N acc coCM COCO ' ' M M M M M '7 V' V V ' V '[r t* r' V V 1 1 V V E r M U U U U U U U U U tl o a vE ❑ ❑ O 0000 0 0 0 ❑ 0 ❑ 0 0 0_ 0 00 r Z• U U U U m m U U U m 0 0 pp �p U U U U pp pp 0 0 0 U 00O0 N C - . 11113_ 0_ a a s a s s a Y O t U O Cl) (O (O CD CD CO CO N- (-- CO CO Co Co O) Co O 0 N N M CO V V V V (O (O O N-- CO • O• O M M M M M M M M Cl) Cl) Cl) M M M d' V V V V V V V' V V V 'V V V N •N Z a) • N C ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 ❑ ❑ ❑ ❑ ❑ 0 ❑ ❑ ❑ 0 ❑ ❑ ❑ ❑ ❑ ❑ 0 0 ❑ ❑ 0 J d d . .N a) N 000000 000000 000000 000000 000000 o J N E O C CA 3 (a CO▪ 17 u) CO CO CD CO (� N- CO CO O) O) (T (T O O N N CO CO V V 7 V u) (O O ,- O C .0 Z ❑. M M M M M M M M M M M M M M 1- V V' V V V V V V V V V 'V V V 1- 4 Q co co U C O ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 0 ❑ ❑ 000000 000000 000000 co N I = ; O ) 000000 000000 000000 000000 000000 QORiGiNAL V4C) 30 •E 0 c; ., co 0 Hc:) Y Y Y Y .. . Y Y Y �C .. Y . . Y zC N N CO N _N N U) N U) N N N N U) U) E EEEEEE EE Cr Ajp O O O O O O O O O O O O O O 0 m .� N (6 (O (6 (0 W. (9 c6 c6 (0 (6 f6 I6 (0 2 2 2 2 2 a) a) .�11, co N N U) N N N N N U) N N CO N N N �../ U) N N CO U) N U) U) U) U) N U) U) N N Vi m Ca Ca (a CD CO (a (a ca ca (a (a CCM ca Co a a a a a a a a a a a a a s a C 0 ao a a) E Q) o Q) O a) o U) o U) O N o N o 0 0 N O U U U O UO U U U c-) U 0 U U r, m 3 c (a c Q) c m c Q) c m c m c Q) co p m E m u_ m u_ m u_ mu_ m u_ m u_ ca u. u_ r'. Z c N a) `n a) u) a) t a) a) N a) `) a) a) U U U U ca 0 u 0 0 o O O D O D 0 0 0 0 cn U U U 0 E C C C c c C C C V a) a) a) ca a) m a) ca a) ca a) CO m m 0 N N N N E m 8 c `al m 8' co 8 co 8 m8 (a m F Q Q Q Q 3 a -a) 0 a) Q, a) a) a) a) a) a) a) a) a) a) a U U U U CO 000000 0 (750 '605 U U 0 0) Y Y Y Cl) O) CO N CO I,- (n N- 'Cr CO CO 6) h 6) I.-- (O ' Q Q Q Q N a- O O CO CO CO CO N N M M CO CO U3 (9 LL' a a cc c — 00 V V N V N V V (O V I� V I- N N 0 LL LL LL LL E U cc cM 0 (O 6) — 6) ,- V M N .- N ,- M0 T t t t m co m a ❑ ❑ ❑ ❑ d LL >- 0 U 0 2 2 2 2 -0 O O N O O O U') C) 0 0 0 CD O C) ,s- 2 N 0 0 (n C) 0 0 N 0 0 0 0 0 O O O . . 7 t O O O ([) a0 O 0 0 0 0 U) O (n (D N (n O M N N 0 N O (n U) O N O N O m a= U7 (D CO N. r N CO N CO N M CO a) a) 05 V C 6) (O (C) CO V1--- VN- V N- N CO N O (D CO O CO CO I- CO I- CO 6) CO CO O (O CO a) O ti ti O (O CO (O O (f) (n V (n V (n V V N N N N N a— a— N COCD � W 0- a)a) cn a) O y -ON O O O O O (O O O O CO 0 CO y CO r CO M CO M U7 O V O ,— 0 (() C E L L .4 M V (O 6 M t` O O6 to O (O6 m a) C N O co c..] co 0 co O U7 V O N 0 N L p_', (n co N. N- N CO N M N M a CO D m a cD j .y U) p2�❑ s- a) V C V O O^ 0 ,-- _ CO 0- N- CO N CO N N- O CO CO V7 M V m E d O O CO O U7 O v7 (N a0 CO O a0 O O 0. 7 V co co Oc•iM co O r O ,- N N O) r 6) r O a) C y y $ CO . v 6) �. y C N I LIN 2 0 a u W Q) N O CO O 0 O (n O CO O CO O 00 V V V V V 0 a ❑ x N CO N- CO a- CO CO CO u) O V O a- LU n a d a y U 2 3 _c � v a; v cD 6 6 r i 6i o Lci o tri C 3 O CO N CO O CO O LU V O N O N a) O 01 -a N N U7 (O CO r N CO N CO N CO Ia Tr Z . - a) ❑ i ca U 0 U aE UUUUU m o c m a CO CO 7 t m? LO MO (nco 'N O O On. LU (\j C 0 a s 3 3 Co ( 0 r , ,_ mMvna c 0a) () 0 mm CO co , ` ❑ co CO (O CO a aEa 00 � 00_ 0. U) LUd . 0 L Uc 7 LL as NNoC) _ EO0 0 Z4-. o 0_ y CQU Cl)OCO Co-m v v n nUU, o o in o _ M O UO CO 0 0 0 0 m oN0 La) R u 03 co a a a s v v U U U U 00 m a s ,-- c) M . E (r°) (n n oO o $ N M ileeCt. U 0 OV 1- V V (n u (nn ❑ (V E a xavn v UV V V `E 0 0 0 0 0 0 0 m UUU000UU 0 _ a ❑ )` UO z m mU U U U mcmmmm a a Q Q cc, o CD Ne- W O • r a oNo 61 a a a s a ")VV VV V CO CO CO aa _ _ a v CD Cl) Z 0_7 • C 000000 oarrOO OO = U N J N o N a) Eyav LO U), ` EEE ❑ ❑ cz ,1 o Z J O ❑ aCi .E c) m m n (n COm m COoo CO0_o CO0o CO0_o UUU U Uz a v vvvvvvvUco 0 QU}� m cc ce +; O 000000 ❑ ❑ a) m ma) a) a) 0 0 N _ _ > C Cu 000000 UUn. aad as U 0 CCD a) C) U HALLIBURTON Conoco`Phillliips C D 1 -49wp04 Sperry Drilling ANTI-COLLISION SETTINGS 1422,October 232012 Interpolation Method: MD, interval:25.00 Depth Range From: 36.30 To 18473.34 Results Limited By: Centre Distance:2043.70 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1250.00 CD1-49wp04(Plan:CD1-49) GYD-GC-SS 1250.00 3151.55 CD1-49wp04(Plan:CD1-49) MWD+IFR-AK-CAZ-SC 3151.55 11650.00 CD1-49wp04(Plan:CD1-49) MWD+IFR-AK-CAZ-SC 11650.00 13302.31 CD1-49wp04(Plan:CD1-49) MWD+IFR-AK-CAZ-SC 13302.31 18473.34 CD1-49wp04(Plan:CD1-49) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2350.00 3151.55 11-3/4" x 14" 11-3/4 6542.06 11650.00 9-5/8" x 11-3/4" 9-5/8 7115.80 13302.31 7" x 8-1/2" 7 7125.80 18473.34 3-1/2" x 6" 3-1/2 L.. a . c. Q .2. , s , 300 lir 1 Oo I is : I as N CA , EI2 h. ,150 � U I I C cp /il ►• i tSli lb. i .. 0 1 I I 1 I I I I I I I I 1 I I I I I I I I 1 I I I I I 1 I I 0 3000 6000 9000 12000 15000 18000 Measured Depth LEGEND --X- CD1-229(aka NO1),CD1-229,CD1-229 V1 --T--- CD7-34,CD1-34,CD1-34 V7 --x---- CD1-43,CD1-43,CD1-43 V1 -A- CD7-229(aka NO1),CD1-229PB1,CD1-229PB1-0- CD1-35,CD1-35,CD1-35 VI -X- CD1-44,CD1-44,CD1-04 V1 -e- CD1-26,CD1-26,CD1-26 V1 -0- CD1-36,CD1-36,am-36 Vt --e- CD7-44,CD1-44PB1,CD1-44P61 V1 - CD1-26,CD1-26PB1,CD1-26PB1 V7 -e- CD1-36,CD1-36P61,CD1-36PB1 V1 -A- CD1-45,CD1-45,CD1d5 V7 -8- CD1-27,CD1-27,CD1-27 V1 -e- CD1-37,CD1-37,CD1-37 V5 -X- CD1-45,CD1-45P61,CD1-45PB1 V1 -X- CD1-28,CD1-28,CD1-28 V7 CD1-38,CD1-38,CD1-38 V1 $ CD1-46,CD1-46,CD1-46 V4 CD1-28,CD1-28PB1,CD1-28PB1 V1 - CD1-38,CD1-38P61,CD1-38PB1 V7 -X- CD1-48,CD7-48,CD1-48 VO --0- CD1-30,CD1-30,CD1-30 V1 -1- CD1-39,CD1-39,CD1-39 V7 --X- CD1-48,CD1-48A,CD1-48A V0 -e- CD1-30,CD1-30PB1,CD1-30PB1 V1 -A- CD1-39,CD1-39PB1,CD1-39P61 V1 -e- Plan:CD1-47,Plan:CD1-47,CD1-47wp03 VO CD1-31,CD1-31,CD1-31 V6 -X- CD1-40,CD1-40,CD1-40 V1 --A- Plan:CD1-50,Plan:CD1-50,CD1-50wp06 VO El CD7-32,CD1-32,CD1-32 V1 $ CD1-41,CD1-41,CD1-41 V1 -3f- Plan:CD1-50,Plan:CD1-50PB1,CD1-50P81wp06 VO -e- CD1-32,CD1-32PB1,CD1-32PB1 V3 -8- CD1-41,CD1-41PB1,CD1-41PB1 V1 -X- CD4-301,C04-301B,CD4-3018 VO -e- CD1-33,CD1-33,CD1-33 V1 -i- CD1-42,CD7-42,CDi-42 V7 -B- CD1-49wp04 1 ConocoPhillips HALLIBURTON Alaska C D 1 -49wp04 Sperry Drilling ANTI-COLLISION SETTINGS 14:22,October 232012 Interpolation Method: MD, interval:25.00 I Depth Range From: 36.30 To 18473.34 Results Limited By: Centre Distance:2043.70 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1250.00 CD1-49wp04(Plan:CD1-49) GYD-GC-SS 1250.00 3151.55 CD1-49wp04(Plan:CD1-49) MWD+IFR-AK-CAZ-SC 3151.55 11650.00 CD1-49wp04(Plan:CD1-49) MWD+IFR-AK-CAZ-SC 11650.00 13302.31 CD1-49wp04(Plan: CD1-49) MWD+IFR-AK-CAZ-SC 13302.31 18473.34 CD1-49wp04(Plan:CD1-49) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2350.00 3151.55 11-3/4" x 14" 11-3/4 6542.06 11650.00 9-5/8" x 11-3/4" 9-5/8 7115.80 13302.31 7" x 8-1/2" 7 7125.80 18473.34 3-1/2"x 6" 3-1/2 a a A -I4 • 4 49 '? til 4 U U (N 0-10 00' , , o / so- . ` / // i /1/\ "/ vs r -'. ,,I 1,1 OOPF,./ , , i:',, / c 41 Ail 0 30- i -1 N V j ..1...1.-iAS® 'i I1 0 1 I 1 r j 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -X- CD1-229(aka NQ1),CD1-229,CD1-229 V1 -f- CD1-34,CD1-34,CD1-34 V1 -I- CD1-43,CD1-43,CD1-43 V1 - CD1-229(aka NQ1),CD1-229PB1,CD1-229PB1-'- CD1-35,CD1-35,CD1-35 V1 -X- CD1-44,CD1-44,CD1-44 V1 - CD1-26,CDi-26,CD1-26 V1 -0- CD1-36,CD1-36,CD1-36 V1 -40- CD1-44,CD1-44PB1,CD1-44PB1 V1 --e-- CD1-26,CD1-26PB1,CDi-26PB1 VI -e- CD1-36,CD1-36P61,CD1-36PB1 Vi CD1-45,CD1-45,CD145 V1 1 - CD1-27,CD1-27,CD1-27 V1 --e-- CD1-37,CD1-37,CD1-37 V5 -X- CD1-45,CD145PB1,CD1-45PBi V1 --- CD1-28,CD1-28,CD1-28 V1 -A- CD1-38,CD1-38,CD1-38 Vi ---8- CD1-46,CD1-46,CD146 V4 CD1-28,CD1-28PB1,CD1-28P81 V1 -I- CD1-38,CD1-38PB1,CD1-38PB1 Vi -X- CD1-48,CD1-48,CD1-48 VO ---e- CD1-30,CD1-30,CD1-30 V1 -I- CD1-39,CD1-39,CD1-39 V1 -X- CD1-48,CD148A,CD148A VO 0 CD1-30,CD1-30PB1,CD1-30PB1 V1 CD1-39,CD1-39PB1,CD1-39PB1 V1 -e.- Plan:CD1-47,Plan:CD147,CD147wp03 VO CD1-31,CD1-31,CD1-31 V6 -X- CD1-40,CD1-40,CD140 V1 -h- Plan:CD1-50,Plan:CD1-50,CD1-50wp06 VO - CD1-32,CD1-32,CD1-32 Vi -e- CD1-41,CD1-41,CD141 Vi -X- Plan:CD1-50,Plan:CD1-50PB1,CD1-50PB1wp06 VO - CD1-32,CD1-32P81,CD1-32PB1 V3 --9- CD1-41,CD1-41PB1,CD1-41PB1 V1 -X- CD4-301,CD4-3018,CD4-3018 VO -e- CD1-33,CD1-33,CD1-33 V1 -I- CD1-42,CD142,CD1-42 V1 -8- CD1-49wp04 Northing (4500 ft/in) I I I I I I I I I I I I I 1 1 1 1 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 1 1 I I I I I I I 1 1 1 I 1 1 to O a 3 — m — a - o ion - n - o 0 — U - - 0 - - U - — co Q co co cli m m O _ N O. co W _ U N N ❑ d' ❑ U U 1 — - _- o FE - o - co _ O _ o '� rimi ❑ U a co - // -r 00 p o • N - a1 II c? y ` U lL Lo -U iiiNk 0 Ua p •- o - _Tr -o Z =U U- CO A U ❑ U Cr) T 0-1 60) c CL O.� Z - a _ Q Z Q. - - Rj - 30 =`a = o t yU — V? 0> — _ 1 o C 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I I I I I I I I 1r) F�iICI'pN I� IxI!I I I I I I I I I I 1 I I I 1 1 1 1 1 1 1 1 1 1 1 I I I I I I I: uU ObSt) 6uiytION = 00 00 cc co pp O ! 0 0 g¢g¢ O it1 / j O rnau _ O moo l OJ r101: / O bag ! ca O .c,m Q N N.2,1 Ite!! 0 la CO z�m 0 ! o � � / OJ W 2NOO WO0 co ,,- \\ O 0la C) Ov O mq aoy • 09 7,50 if 00 1' 110 ! 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E CO L9 yi O u- 2 U C c, C N eo a C CO , a F. in a'Cr , .7. , N Cr , N , i t CIO_ A in CO o A 3 • o a -§-- - g + + 3 `s + � v 3 0 cn + + 13 CA c� a 2 w` 1 0 a z W 0 a z W si M Trv a 0 _8 > o > o> 3 U CO I- U CO r- () 0 H a) 'H VCC N I.,I H < H- < r v Q q o a) a m a) _ < o _ a m4- q a, r u h IX g 1a) Ce 20 Fe`::. ce mo .c C) vu CCI CO a o 0 0 :: a 0 a +, ,- N d Nss M 19 y g CO y b n II u it: o Ti i oD o Ti I cr o T S C U A C a-- 0 A d 0 A a 01 z E E g 5g ORIGINAL P tion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 Attachment 4— Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 14" Hole / 11-3/4" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud Gas Hydrates Low weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Surface Formations >2000' Low Increased mud weight ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 10-5/8" Hole UR to 11-3/4" / 9-5/8" Liner Interval Event Risk Level Mitigation Strategy Abnormal Pressure in BOPE drills, Keep mud weight above 9.6 ppg. Check for Surface Formations>2000' Low flow during connections and if needed, increase mud ND weight. Reduced pump rates, reduced trip speeds, real time Lost circulation Low equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, Hole swabbing on trips Moderate pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Well control drills, increased mud weight. No mapped Pressure L0W faults occur within 500' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 8-1/2" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in BOPE drills, Static MW 10.9 ppg. Monitor pressure held Surface Formations>2000' Low on annulus with MPD for abnormal increase. ND Reduced pump rates, reduced trip speeds, real time Lost circulation Low equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, Hole swabbing on trips Moderate pumping out of hole, real time ECD monitoring, weighted sweeps, Utilizing MPD to minimize swab and surge Abnormal Reservoir Well control drills, increased mud weight. No mapped Pressure Low faults occur within 500' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers CD1-49 APD Page 12 of 13 Printed: 13-Nov-12 P lion for Permit to Drill,Well CD1-49 Saved: 13-Nov-12 6" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Reduced pump rates, reduced trip speeds, real time Lost circulation Moderate equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud Hole swabbing on trips Moderate properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir BOPE drills, Keep mud weight above 9.8 ppg. Check for Pressure Medium flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. CD1-48A is the closest existing well with a clearance factor of 1.495. Ellipse to ellipse separation is 5.85' @ 708' MD. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted; although this is unlikely, the rig will be prepared to weight up if required. Lower Shale Stability: Shale instability concerns in the intermediate will require higher mud weights to stabilize the Kalubik and Miluveach. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. CD1-49 APD R I Page 13 of 13 h Printed: 13-Nov-12 oouth(-)/Nprth(+) (60Q ft/in) W W N -' i w O -P00 N O) c O O O O O O 3 W 1 8 J O 1\ N O K.) s 0 �. v (p J _L A .t " 1 ' 0 < .1' (74 011\ \NaLf Ili i i , 1:h CO,...- '.0-3 o 9wm� i co N N b 00 r -- ®�Ll. // O cNo® ooy N in' cPn +�gl0 N O eV� O �! I I H2 m NEn,I N a. CO 1 ooN as O 88 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 19, 2012 10:24 AM To: 'Duncan.p.hyden@concophillips.com' Subject: CD1-49 ( PTD 212-177) Duncan, In the PTD application you are requesting a waiver from the diverter requirement. Please provide a spider plot of the nearest other surface casing points relative to the proposed SC point for CD1-49 Good luck with the drill—in liner. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 11/21/2012 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME - y 1 - PTD# a( Development ? Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: C O/.V/L.1„L RI(ILIk POOL: (442/VU 6- Oft. P301--, Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (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 ❑ ❑ To o, 0) O a) 0- u) (1) 0 O a , J , O U) _T O - N C C . I CO O a 0 Nu) C a) c -O ns N 7 C cC -c D o CO w (0 C 0) (0 N U °o a a) CC O .0 E @ O 7 c E rn co n o a m e a) aa)) �- a T C,) • ,r o co c - C n o E o O o .3 f) m L a) m U cv) ar a) o c a a) .3 co O >, a '`� T a) vi a. D 0) co a s m CO .0 Cl) .0 • == a 3 o c L V7 O N co Y� > N 0) O D CD3 0. p ami E ° o - , 2 a) 0) 00) C Z o - 0 co 0. u;' > = c v o 0 0 a) o E o a -co w ° •'� E' 3 3 0 17.1a F o N O) a 0 o T o O a) L n E O "O. 2 (° z `) 8 `0 g' - ' -p 3 0- u)) La oo N' m co ui w Cl) O) CO a +o+ 0. co. M ... 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