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214-078
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 26, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2E-02 KUPARUK RIV UNIT 2E-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2024 2E-02 50-029-23517-00-00 214-078-0 W SPT 6072 2140780 1518 2710 2715 2715 2715 525 525 525 525 4YRTST P Adam Earl 7/1/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2E-02 Inspection Date: Tubing OA Packer Depth 320 2110 2060 2060IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240703133024 BBL Pumped:2.5 BBL Returned:2.5 Friday, July 26, 2024 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg —I DATE: Wednesday, July 8, 2020 P.I. Supervisor�GAy' �((j"9 ZaL,p SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2E-02 FROM: Adam Earl KUPARUK RIV UNIT 2E-02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -J NON -CONFIDENTIAL Comm Well Name KUPARUx RIV UNIT 2E-02 API Well Number 50-029-23517-00-00 Inspector Name: Adam Earl Insp Num: mitAGE200705090943 Permit Number: 214-078-0 Inspection Date: 7/4/2020 Rel Insp Num: Packer Deptb Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2E-02 Type Inj I W TVD 1 6072 I Tubing 2400 24o0 . 2388 2388 PTD 2140780 Type Test SPT Test psi I Isis -A— 700 _ 1805 _ 1765 176 BBL Pumped: 1.5 BBL Returned: 1.7 OA 385 385 'T 385 ' 385d--4 Interval 4vRTSr P/F P Notes: MIT IA Wednesday, July 8, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,July 20,2016 TO: Jim Regg -Rae J P.I.Supervisor 1 G �(Z c, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2E-02 FROM: Matt Herrera KUPARUK RIV UNIT 2E-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry`J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2E-02 API Well Number 50-029-23517-00-00 Inspector Name: Matt Herrera Permit Number: 214-078-0 Inspection Date: 7/17/2016 Insp Num: mitMFH160717192413 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2E-02 � Type In� W'TVD 6072 'Tu b ing� 2590 2590 - 2580 2570.- PTD PTD 2140780 - Type Test SPT Test psi l 1518 IA 1565 3310 - 3285 - 1 3280 Interval 4YRTST P/F P ✓ OA 230 270 , 250 245 - Notes: 3300 PSI Test Pressure per Operator $ NNEV .�s ', : 2N? Wednesday,July 20,2016 Page 1 of 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 �cD �U� 1 6 2.°15� SCOL June 22, 2015 �,- o7 Commissioner Cathy Foerster 0 �-- Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement(one with carbolite) and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet 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, //2/ney MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 6/22/2015 1E,1Y,2E,2F,2M,2N,2V,3N&3S Pads 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 1E-32 50029227880000 1971320 15" na 15" na 1.8 6/18/2015 1Y-10 50029209340000 1830510 36' 3.70 13" 5/10/2015 4.6 6/20/2015 ? . 2E-02 50029235170000 2140780 9' 0.60 24" 6/14/2015 5.1 6/16/2015 2E-03 50029235090000 2132030 4' 0.62 7" 6/13/2015 3.9 6/16/2015 2E-04 50029235050000 2131680 10' 1.29 19" 6/15/2015 7.7 6/16/2015 2F-20 50029227390000 1970160 6' 0.80 13" 4/20/2015 3 6/20/2015 2F-21 50029223525000 2141360 22" 0.10 22" 4/25/2015 15.3 6/19/2015 2F-22 5002923530000 2141500 64" 1.10 17" 4/25/2015 11.5 6/19/2015 2M-36 50103206910000 2141020 8'7" 0.70 10" 5/23/2015 2.1 6/20/2015 2N-322 50103206780000 2131790 13" na 13" na 2.5 6/19/2015 2V-02 50029210370000 1831610 11" 1.00 14" 5/20/2015 2 6/16/2015 3N-11A 50029215800100 2120950 34' 27 cu.ft carbolite 10" 5/26/2015 2 6/18/2015 3S-620 50103206950000 2141670 6'3" 0.60 12" 4/26/2015 2.6 6/18/2015 STATE OF ALASKA AL .(A OIL AND GAS CONSERVATION CON 3SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other r Prod to WINJ Atter Casing r Pull Tubing r Stimulate-Frac f Waiver r Time Extension r Change Approved Program r'Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r,; Exploratory r 214-078-0 3.Address: 6.API Number: Stratigraphic r Service r- P. O. Box 100360,Anchorage,Alaska 99510 50-029-23517-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25658,25665,25670 KRU 2E-02 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary Total Depth measured 17652 feet Plugs(measured) None true vertical 6264 feet Junk(measured) None Effective Depth measured 17635 feet Packer(measured) 541, 8330, 9897, 9898 true vertical 6264 feet (true vertical) 541, 5696,6072,6072 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 107 107 0 0 SURFACE 4114 14.78 4142 3241 0 0 INTERMEDIATE 10028 8 5 10053 6094 0 0 LINER 7762 6.57 17635 6264 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9927-11441,11642-12302,12546-15572,15572-16138,16340-17623 True Vertical Depth: 6076-6107,6110-6141,6153-6223,6231-6226,6235-6263 RECEIVED Tubing(size,grade,MD,and TVD) 3.5, L-80, 9897 MD,6072 TVD SGot%E© i 1�I 2 8 2 ril J JUN 16 2015 Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE W/2.875"PROFILE @ 541 MD and 541 TVD A�*��nC NIPPLE-HES LANDING NIPPLE DS-PROFILE @ 8330 MD and 5696 TVD ' l� LOCATOR -BAKER LOCATOR @ 9897 MD and 6072 TVD SEAL ASSY-BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY W/12'OF SEALS @ 9898 MD and 6072 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 56 168 1 1039 178 Subsequent to operation 0 0 3525 1007 2440 14 Attachments 15 Well Class after work: Copies of Logs and Surveys run Exploratory r Development r' Service P Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ WAG r GINJ r SUSP r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-093 Contact Bob Christensen/Darrell Humphrey Email n1139(conocophillips.com 1 Printed Name Darrell R. Humphrey Title NSK Production Engineering Specialist Signature ( Phone 659-7535 Date 3- /Li Form 10-404 Revised 10/2012Submit r ginal Only /lur G 7//1//5-/y RBDMS JUN 2 5 2015 2E-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/15/15 Return well to Water Injection Service 1 KUP PROD 2E-02 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status nal CI MD(ftKB) Act Btm(ftKB) corKYte7dlhp. 500292351700 KUPARUK RIVER UNIT PROD a 17,635.0 .,. Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2E-02,5/11/20158. AM SSSV:NIPPLE 120 12/25/2014 Last WO: 27.401 8/24/2014 vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SEE NOTE 9,699.0 10/5/2014 Rev Reason:GLV C/O hipshkf 5/11/2015 Casing Strings HANGER;243- ',11.' t' ' ",'a- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(nKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 28.0 106.5 106.5 62.50 H-40 Welded ..._._._............................................................... .........Casing. Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..'Grade Top Thread SURFACE 103/4 9,950 27,6 4,141,5 3,240.8 45.50 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread INTERMEDIATE 75/8 6,875 252 10,0512 6,093.5 2970 L-80 W563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 9,872.7 17,635.0 6,263.8 11.60 L-80 H563 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) .A.A/CONDUCTOR,28.0-106.5• 9,872.6' 6,068.8 82.43 PACKER BAKER LINER TOP PACKER ZXPw/HRDE profile, 5.750 9,892.6 6,071.5 82.33 NIPPLE BAKER RS NIPPLE 4.880 NIPPLE;540.8 -- 9,895.4 6,071.9 8232 HANGER BAKER FLEX LOCK LINER HANGER 4.880 9,906.9 6,073.4 82.26 SBR BAKER 80-40 SEAL BORE 4.000 II 11,451.3 6,107.4 89.20 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;3,04.2 I PACKER a 11,614.5 -6,109.4 88.64 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER I 12,312.6 6,141.7' 88.94'SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER SURFACE;27,6-4,1415 12,518.3- 6,152.0 86.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER 15,582.4 6,224.2 86.71 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;4,882.3 PACKER 15,744.6' 6,231.5 89.04 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER 16,148.7 6,226.2 88.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;6,229.4 "€ PACKER 16,312.3 6,233.9 87.48 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 a (PACKER Tubing Strings GAS LIFT;7,231.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4 1/2 x 3 1/2 3 1/2 2.992 24.3 9.9173 6,074.8 9.30 L 80 EUE Ord MOD al @59.5 is Completion Details GAS LIFT;7.921.9 Nominal ID Top(RKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 24.3 24.3 0.00 HANGER CIW 4-1/2"TUBING HANGER 1910 III 59.5 59.5 0.05 X0 Reducing X0,2,4-12"L-80 IBTM bx x 3-1/2"L-80 EUE SRD-Mad 2.937 pin NIPPLE;8,329.9 540.8 540.8 0.18 NIPPLE CAMCO DS NIPPLE 4/2.875"Profile 2.875 8,329.9 5,695.9 68.90 NIPPLE HES LANDING NIPPLE DS-Profile 2.812 9,896.6 6,072.0 82.31 LOCATOR BAKER LOCATOR 2.940 _ 9,897.8 6,072.2 82.31 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY w/12' 2.990 _ of seals Perforations&Slots LOCATOR;9,896.6 1' Shot Dens !'`4�.i1 Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SEAL ASSY;9,897.8 =. 9,927.1 11,441.5 6,076.1 6,107.3 8/20/2014 SLOTS Slotted Liner 11,642.6 12,302.7 6,110.2 6,141.5 8/20/2014 SLOTS Slotted Liner --� ; i 12,546.5 15,572.6 6,153.8 6,223.7 8/20/2014 SLOTS Slotted Liner 15,772.8 16,138.9 6,231.8 6,226.0 8/20/2014 SLOTS Slotted Liner 16,340.6 17,623.9 6,235.0 6,263.8 8/20/2014 SLOTS Slotted Liner E Mandrel Inserts INTERMEDIATE;25.2-10,053.2 Stati SLOTS;9,927.1-11.4415- , on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date co. 3,049.3 2,605.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/7/2015 2 4,882.3 3,689.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/11/2015 3 6,229.4 4,503.3 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/72015 SLOTS;11.642.6-12,302.7 4 7,231.8 5,108.5 CAMCO MMG 1 12 GAS LIFT DMY RK 0,000 0.0 5/72015 5 7,921.9 5,510.5 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/8/2015 DCR- 1 Notes:General&Safety End Date Annotation # 10/5/2014 NOTE:SL DRIFTED TO 9699'RKB BEFORE STALLING OUT DUE TO DEVIATION SLOTS;12,546.5-15,572.6--I- #--_- SLOTS;15,772.8-16.138.9 I SLOTS;16.340-6-17,623.9 i LINER;9,8727-17,635.0 ri MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission _ DATE: Tuesday,June 02,2015 g1si'y TO: Jim Re P.I.Supervisor � " SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2E-02 FROM: Lou Grimaldi KUPARUK RIV UNIT 2E-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry:BA-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2E-02 API Well Number 50-029-23517-00-00 Inspector Name: Lou Grimaldi Permit Number: 214-078-0 Inspection Date: 5/29/2015 Insp Num: mtLG150529140605 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r 2E-02 ' Type Inj W 'TVD 6072 Tubing 1990 1990 1990 1990 PTI 2140780 Type Test SPT Test psi 1518 IA 1040 2800 2750 - 2740 - Interval[RJ1TAL P/F I P '- OA 215 310 -- 255 240 I Notes: 2.75 bbl's diesel pumped,2 4 bbl's returned.Good solid post RWO All required paperwork supplied prior to test. cis — EU .i LII I I 3 ,O l 3 Tuesday,June 02,2015 Page I of 1 Brooks, Phoebe L (DOA) PTD i}2140790 From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, June 01, 2015 4:19 PM To: Brooks, Phoebe L (DOA) Subject: RE: KRU recent MIT's Attachments: image002.png; image003jpg; 2E-02 schematic.pdf Let me know if you need anything else. Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 5CANNKI JUN 0 9 70i5 Pager(907) 659-7000 pgr. 909 411WELLS TEAM Conoco taips From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, June 01, 2015 3:34 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: KRU recent MITs Brent, Will you send me the well schematic for 2E-02? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, June 01, 2015 2:12 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Senden, R. Tyler Subject: KRU recent MIT's Attached are copies of the test forms for the recent MIT's performed at Kuparuk. Let me know if you have any questions. 1 KUP PROD 2E-02 ConocoPhillips ,11;04,:,". vi Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Btm MKS) coraacuAtillipe 500292351700 KUPARUK RIVER UNIT PROD 17,635.0 ... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2E-02,5111/20158.03.01 AM SSSV:NIPPLE 120 12/25/2014 Last WO: 27.40 8/24/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag-.SEE NOTE 9,699.0 10/5/2014 Rev Reason:GLV C/0 hipshkf 5/112015 Casing Strings HANGER,24.3- I".l.34 - 'L.�_.i, Casing Description OD(in) 10/In/ Top(ftK0) Set Depth(MB) Set Depth(ND)... Wt/Len(...Grade Top Thread CONDUCTOR 16 15.250 28.0 106.5 106.5 62.50 H-40 Welded a na.Casiriq Description OD ON ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(ND)...Wt/Len Q...Grade Top Thread SURFACE 103/4 9.950 27.6 4,141.5 32408 45.50 L-80 HYD 563 Cas Ing Description OD(In) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(ND)...Wt/Len(I.,.Grade Top Thread L INTERMEDIATE 75/8 6.875 25.2 10,053.2 6,093.5 29.70 L-80 W563 Casing Description OD(in) ID(In) Top(ttKB) Set Depth(ttKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 9,8727 17,635.0 6,263.8 11.60 L-80 H563 Liner Details Nominal ID Top(MKS) Top(ND)(868) Top Incl(°1 Item Des Com (in) .�.A1 CONDUCTOR,28.0-106.5 9,872.6 6,068.8 82.43 PACKER BAKER LINER TOP PACKER ZXPw/HRDE profile, 5.750 111 9,892.6 6,071.5 82.33 NIPPLE BAKER RS NIPPLE 4.880 NIPPLE;540.8 9,895.4 6,071.9 82.32 HANGER BAKER FLEX LOCK LINER HANGER 4.880 9,906.9 6,073.4 82.26 SBR BAKER 80-40 SEAL BORE ' 4.000 III 11.451.3 6,107.4 89.20 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT,3,049.2 PACKER III 11,614.5 6,109.4 88.64 SWELL Freecap I FSC-11 6.38"OD Swell Packer - 3.958 PACKER 12,312.6 6,141.7 88.94 SWELL ' Freecap I FSC-11 6.38"OD Swell Packer - 3.958 PACKER SURFACE;27,6-4.141.5 12,518.3 6,152.0 86.37 SWELL Freecap IFSC-11 6.38"OD Swell Packer 3.958 PACKER 15,582.4 6,224.2 86.71 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT,4,882.3 .; 1'• PACKER 15,744.6 6,231.5 89.04 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER 111 16,148.7 6,226.2 88.37 SWELL Freecap I FSC-11 6.38"0D Swell Packer 3.958 GAS LIFT,6,229.4 It PACKER 11 16,312.3 6,233.9 87.48 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 II PACKER Tubing Strings GAS LIFT;7,231.8 atTubing Description String Ma...ID(in) Top(566) Set Depth(ft..Set Depth(TVD)(...WI(lb/ft) Grade Top Connection ar TUBING 4 1/2 x 3 1/2 3 1/2 2.992 24.3 9,917.3 6,074.8 9.30 L-80 EUE 8rd MOD 21 @ 59.5 bin Completion Details GAS LIFT:7,921.9 g" Nominal ID Top(MB) Top(TVD)(ftKB) Top led CI ltem Des Can (In) 24.3 24.3 0.00 HANGER CIW 4-1/2"TUBING HANGER 3.910 59.5 59.5 0.05 XO Reducing XO,2',4-1/2"L-80 IBTM bx x 3-12"L-80 EUE 8RD-Mod 2.937 pin NIPPLE:8,329.9 `dT'x.'" 540.8 540.8 0.18 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 8,329.9 5,695.9 68.90 NIPPLE HES LANDING NIPPLE DS-Profile 2.812 9,896.6 6,072.0 82.31 LOCATOR BAKER LOCATOR 2.940 9,897.8 6,072.2 82.31 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY w/12' 2.990 of seals ( Perforations&Slots II LOCATOR;9,896.6 ) ( Shot I Dens t 'I Top(TVD) Btm MD) (shotsR Top(ftKS) Btm ONO) (ftKB) (ftKBI Zone Date t) Type Corn SEAL ASSY;9,897.8 9,927.1 11,441.5 6,076.1 6,107,3 8/20/2014 SLOTS Slotted Liner Ark 11,642.6 12,302.7 6,110.2 6,141.5 8/20/2014 SLOTS Slotted Liner 111111 12,546.5 15,572.6 6,153.8 6,223.7 8/20/2014 SLOTS Slotted Liner pry' 15,772.8 16,138.9 6,231.8 6,226.0 8/20/2014 SLOTS Slotted Liner ill,. 16,340.6 17,623.9 6,235.0 6,263.8 8/20/2014 SLOTS Slotted Liner r Mandrel Inserts INTERMEDIATE:25.2-10,053.2 /� St SLOTS;9,927.1-11.441.5--•r ..-- ad on Top(ND) Valve Latch Port Size TRO Run N Top(ttKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1/11 3,049.3 2,605.2 CAMCO MMG 112 GAS LIFT -DMY RK 0.000 0.0 5/7/2015 2 4,882.3 3,689.2 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/112015 -- - 3 6,229.4 4,503.3 CAMCO MMG 1 1/2 GAS LIFT 'DMY RK 0.000 0.0 5/7/2015 SLOTS;11,642.6-12,302.7 - 4 7,231.8 5,108.5 CAMCO MMG 1 1/2 GAS LIFT 'DMV RK 0.000 0.0 5/7/2015 5 7,921.9 5,510.5 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/8/2015 DCR- 1 Notes:General&Safety End Date Annotation 10/5/2014 NOTE:SL DRIFTED TO 9699'RKB BEFORE STALLING OUT DUETO DEVIATION SLOTS;12,546.5.15.572,6 li SLOTS.15,772.8.16,138.9 -I- _ SLOTS:16.340.6-17.623.9 LINER;9.872.7-17,635.0 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. j 14-- 07g/ Well History File Identifier Organizing(done) Two-sided 0 Rescan Needed RES AN: OVERSIZED: NOTES: Color Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: ylIJBY: (Maria , !1 Date: S / 3 /s/ P Project Proofing BY: 41112) Date: I/ /5-. /s/ I, I Scanning Preparation 112 x 30 = 1 go + = TOTAL PAGES 1 3 '4 p (Count does not include cover sheet) BY: Maria Date: Sp1 /5-- /s/ Production Scanning Q' Stage 1 Page Count from Scanned File: I, O 7 (Count does include cover eet) Page Count Matches Number in ScanningPreparation: YES NO p BY: 4111= Date: 51 I I / I5 /s/ Wi Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: lig, NO TOTAL PAGES: Digital version appended by: Meredith ' Michal Date: `--)(r o 1( 5— /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: c-Za / Scanning is complete at this point unless rescanning is required. 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Too c"co CL � N ; 0 0 w E N z vi ai OC o °' '° O it E W 0 z a) En • o a V 0 Z E _iE co Izce o 'CO co o m N 43 O J n c J o E O 'o 2 o 0 CL in co N I F, 0 2 O " Tx II E / yr (E) 5=-1 O 5 o J � 0 } G E �, Q co o0 II 0a WO. co N O E V N ° C • N .. co C Ca > CO • cu CV E 2 co .E . F- E 7 O a) r c m N w co a' m iik N • N c (5 d 0 c o Q = c N Y a) c o n Q ci a ° m0 _c O 0 z E o O U T E 0 l m o o H I ..)___:_t_ 1 co o z u) N I N Hv v 3 c y E Q N N N 2 O I M co 0 E } CO co > Ia o W o � � H m F- CO C lD cc W E n O N co CO 0 r 0 0 y_ I c ca E E 2 CD .se y aa) _ ° m 07 ` W m re E co..... CO O H CO 0 0 W c6 to m co z ~ c c z c@ O w u O d Q O ° Q 0 0 r C CI cc U 0 a 7 0 a n E a 0 E 0 °) _ O E ° ° I "E E a) ° E E 0 a 2 3 z 0 a 0 0 o w 0 0 Guhl, Meredith D (DOA) From: Hunter, Lindsey L [Lindsey.Hunter@conocophillips.com] Sent: Saturday, April 18, 2015 8:53 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2E-02, PTD 214-078, Geologic Markers Here are the final numbers for 2E-02 2E-02 Pick MD TVD TVDSS base permafrost 1507 963 830 Top Ugnu (Ugnu C) 2103 2005 1872 Top W Sak (W Sak D) 3159 2669 2536 base W Sak 4028 3173 3040 top HRZ 8253 5663 5530 upper_kalubik(base HRZ) 8884 5877 5744 lower_kalubik(K-1 mkr) 9084 5939 5806 Kuparuk C (top C4) 9631 6037 5904 Kuparuk B1 9649 6039 5906 Kuparuk A6 9919 6071 5938 Kuparuk A5 10039 6088 5955 TD (Kuparuk A5) 17652 6257 6125 MD where entered Top of Fm at 2E-02 TD Fm at TD Kuparuk A5 10039 From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday,April 17, 2015 1:29 PM To: Hunter, Lindsey L Cc: Bettis, Patricia K (DOA);Alvord,Chip Subject: [EXTERNAL]RE: KRU 2E-02, PTD 214-078, Geologic Markers Lindsey, I'd appreciate receiving the complete list of formations and markers via email, by Friday,April 24, 2015, so I may complete the compliance review of the well. Thank you, Meredith From: Guhl, Meredith D (DOA) Sent: Wednesday, April 15, 2015 4:13 PM To: 'Hunter, Lindsey L' Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2E-02, PTD 214-078, Geologic Markers Lindsey, 1 A complete list of formation tops and geologic markers would also include formations like the West Sak, HRZ, Ugnu, B1, K-1 and other formations listed in the PTD application. Only listing the Kuparuk C4 and Kuparuk A5 is not sufficient. Please provide a complete list of formation tops and geologic markers encountered in KRU 2E-02, PTD 214-078. As mentioned in my first email,you may email me the formation list and I will append it to the 10-407 form. Thank you, Meredith From: Hunter, Lindsey L [mailto:Lindsey.Hunter@conocophillips.com] Sent: Wednesday, April 15, 2015 4:05 PM To: Guhl, Meredith D (DOA) Subject: RE: KRU 2E-02, PTD 214-078, Geologic Markers Meredith, I apologize for my slow response, I was on vacation when the original email came through and I missed it. We pulled a copy of the 10-407 that was sent over for 2E-02 and it looks like the formation tops and geologic markers were included. I'm wondering if maybe there was an issue with single vs. double sided printing? I'm not sure, but please see the attached 10-407. Thanks, Lindsey From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Wednesday,April 15, 2015 11:06 AM To: Hunter, Lindsey L Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]RE: KRU 2E-02, PTD 214-078, Geologic Markers Importance: High Lindsey, I have not received a response from you yet, regarding my email of March 23. Data is due within 90 days of well completion, and should've been submitted by March 31. Please provide the complete list of formation tops and geologic markers for KRU 2E-02, PTD 214-078 by April 17, 2015. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. 2 The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl(aialaska.gov. From: Guhl, Meredith D (DOA) Sent: Monday, March 23, 2015 1:41 PM To: 'Hunter, Lindsey L' Cc: Bettis, Patricia K (DOA) Subject: KRU 2E-02, PTD 214-078, Geologic Markers Lindsey, Please provide the complete list of formation tops and geologic markers for KRU 2E-02, PTD 214-078, completed August 23, 2014. You may provide this list via email, and I will append it to the 10-407 form. Please provide the list by March 31, 2015 as all data is due within 90 days of completion. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 3 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, April 15, 2015 11:06 AM To: 'Hunter, Lindsey L' Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2E-02, PTD 214-078, Geologic Markers Importance: High Lindsey, I have not received a response from you yet, regarding my email of March 23. Data is due within 90 days of well completion, and should've been submitted by March 31. Please provide the complete list of formation tops and geologic markers for KRU 2E-02, PTD 214-078 by April 17, 2015. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Guhl, Meredith D (DOA) Sent: Monday, March 23, 2015 1:41 PM To: 'Hunter, Lindsey L' Cc: Bettis, Patricia K (DOA) Subject: KRU 2E-02, PTD 214-078, Geologic Markers Lindsey, Please provide the complete list of formation tops and geologic markers for KRU 2E-02, PTD 214-078, completed August 23, 2014. You may provide this list via email, and I will append it to the 10-407 form. Please provide the list by March 31, 2015 as all data is due within 90 days of completion. If you have any questions, please contact me. 1 Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, March 23, 2015 1:41 PM To: 'Hunter, Lindsey L' Cc: Bettis, Patricia K(DOA) Subject: KRU 2E-02, PTD 214-078, Geologic Markers Lindsey, Please provide the complete list of formation tops and geologic markers for KRU 2E-02, PTD 214-078,completed August 23, 2014. You may provide this list via email, and I will append it to the 10-407 form. Please provide the list by March 31, 2015 as all data is due within 90 days of completion. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 SOF Tye 0,1" I//7; 6, THE STATE Alaska Oil and Gas ofALASKA Conservation Commission Ott 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS*P Fax 907 276.7542 www.aogcc.alaska.gov Darrell R. Humphrey f O '1 NSK Production Engineering Specialist °L1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E-02 Sundry Number: 315-093 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner I'G DATED this Z day of February, 2015 Encl. t; . STATE OF ALASKA AL ,<A OIL AND GAS CONSERVATION COMM!. iN APPLICATION FOR SUNDRY APPROVALS 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 T Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: Prod to WINJ f 2.Operator Name 4.Current Well Class. 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. ' Exploratory r Development r, 214-078-0 ' 3 Address: Stratigraphic r Service r 6.API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-23517-00 • 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 r/ i KRU 2E-02 9.Property Designation(Lease Number). 10.Field/Pool(s). ADL 25658,25665,25670 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft)' Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured). 17652 • 6264 • 17635' • _ 6264' • None Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 107' 107' SURFACE 4114 14.78 4142' 3241' REC IVIED INTERMEDIATE 10028 8.5 10053' 6094' LINER 7762 6.57 17635' 6264' 1,I,_E{ 19 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft) 1441,11642-12302,12546-15572,15572-16138,16340 6076-6107,6110-6141,6153-6223,6231-6226,6235-6263 3.5 L-80 9897 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) NIPPLE-CAMCO DS NIPPLE W/2 875"PROFILE - MD=541 TVD=541 NIPPLE-HES LANDING NIPPLE DS-PROFILE • MD=8330 TVD=5696 LOCATOR -BAKER LOCATOR - MD=9897 TVD=6072 SEAL ASSY-BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY W/MD=9898 TVD=6072 • 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r..7 ' 14 Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/31/2015 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval. Date WINJ P • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact' Bob Christensen/Darrell Humphrey Email n1139e..conocoohillips.com Printed Name Darrell R. Humphrey Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date ,2 . 1(,.• 1 5 Commission Use Only I Sundry Number Conditions of approval: Notify Commission so that a representative may witness -.7 (5 —O / Plug Integrity r BOP Test r- Mechanical Integrity Test r Location Clearance r Other ,'fc.-f t w t�z c S S t 9/ !n / 7-- !-4 r r I, & `r-,-d4 {, t t '� -i 1-a {J i 1 r�_e(! i .�JI r c-f i o - Spacing Exception Required" Yes 0 No Er Subsequent Form Required. JO_, 419 '). v APPROVED BY Approved by. )i / COMMISSIONER THE COMMISSION Date. Z-- 12 3 I Is ( ) Approyea RIrrtrsrIIAo months tr1 t? date ofForm 10-403 Revised 10/2012 U LTIQ .1 `5I/S Submit F man a h encs in Duplicate I/7 c. 2 /20 /1 /,�/i2"/?/j RBDM FEB 2 4 2015 2E-02 DESCRIPTION SUMMARY OF PROPOSAL Area of Review Well Summary Kuparuk well 2E-02 was drilled in 2014 from Kuparuk drillsite 2E, to exploit the A5 sand target on the southern flank of the Kuparuk field through injection support to 2E-01. The well was completed as a Kuparuk A sand inj _ctor(to be pre-produced) over the interval of 9,927' MD to 17624' MD. Pre-production began on /2/16/2014 and is anticipated to last up to three months before conversion to injectionWort prove a support to No (ever... /1 eCe sSti •.� "..1194j Below, the Area of Review includes a description of the following: • Map with 1/4 mile radius shown around the target injection zone; •2E-02 wellbore schematic; •The mechanical condition of the proposed injection well; and • Cement quality of the 2E-02 Area Map with 1/4 mile radius around target injection zone Kuparuk well 2E-02 is located in the Southwest quadrant of the drillsite 2E Kuparuk development. The map attached shows that there is one well located within a 1/4 mile radius of the 2E-02 penetration of the Kuparuk A sands. Well 2E-04 is a Kuparuk A-sand producer that has been producing since August of 2014. Well 2E- 04 and 2E-03 were both drilled in 2014 as a producer-injector well pair to the east of 2E-02. Well 2E-02 was drilled as part of a three well package consisting of producer 2E-01 and additional pre-produced injector 2F- 21 to the west. Kuparuk well 2E-02 Wellbore Schematic Kuparuk well 2E-02 was completed with 4 %2" 11.6 lb/ft L-80 slotted liner from 9,927' MD to 17,624' MD. The intermediate section was completed with 7-5/8" 29.7 lb/ft L-80 casing. The surface hole was completed with 10-3/4"45.5 lb/ft L-80 casing. The top of the target Kuparuk A sand was encountered at 10,039' MD (6,088' TVD). ti • 2E-13 �2E:1 •'••. ................ 2G-08 ,F-1 \2F-14 14-•••••••••......._• 2F-11 • • ZF•11AL2 . ;r2F-17 \F12 . \\214 F--18 BBf• `••••.• 2G-09 \292 2 . 2F-19PB1 : 2F-17L1-02 2F-18L1• %O1 19F-11A ,01••• r2E-04PS1 2F-19AL2 2F-11AL.9 / Kuparuk PA'. 2F-19AL3 4R{'.• 2G-1, uparuk 2F-18L1-02 �.�g 2F-17L1-01 TCIV6TL 1 2F-17L1 nit i • 2G-11AL2P61i12F-18L1 2G-11APBf ;\ . C Ak , • .: : ,2 • 11AL1-01 t :2G-11A A11AL11 : ► 2G-11-AL2 ., N Q 2G-17L1-01 •CV a \ 0 17 • 2E-03 i 2E-04 i2E-02 .--' .2F-21 02E4)1 _•„..KFSSU TATE 1 :2F-22 2G-17L1 Legend A SLOTTED LINER STATUS,WELL_TYPE,FLUID_TYPE PROP, SVC,<Null> "= Producer:Oil INJ:MWAG INJ:PW P+A Pipeline Above Ground `' • • 1/4 Mile Radius ConocoPhillips 2E-02 Alaska, Inc. 2F-21 2F-22 Injection Swap Analysis Drill Site 2E-02, 2F-21, 2F-22 Primary Road NA CONFIDENTIAL nit Boundary 0 0.25 0.5 .„„;Participating Area Boundary Mies Meltwatecm*d CSR 2/3/2015 KUP PROD 2E-02 , r. ConocoPhillips (Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl 0) MD(ftKB) Act Btm(ftKB) C Ict-.lhah, 500292351700 KUPARUK RIVER UNIT PROD 17,635.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2E-02,2/5/201511:22:51 AM SSSV:NIPPLE Last WO: 27.40 8/24/2014 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SEE NOTE 9,699.0 10/5/2014 Rev Reason:PULLED PLUG lehallf 2/5/2015 Casing Strings MANGER,24 3- is il Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 28.0 106.5 106.5 62.50 H-40 Welded ,.. ..... ........... , .Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread "'" SURFACE 10 3/4 9.950 27.6 4,141.5 3,240.8 45.50 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt./Len(L..Grade Top Thread INTERMEDIATE 75/8 6.875 252 10,053.2 6,093.5 29.70 L-80 W563 I J Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)... Wt/Len(L..Grade Top Thread LINER 41/2 3.958 9,872.7 17,635.0 0,2038 11.60 L-80 H563 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(3 Item Des Com (in) .AAT CONDUCTOR;28.5-108.5 9,872.6 6,068.8 82.43 PACKER BAKER LINER TOP PACKER ZXPw/HRDE profile, 5.750 9,892.6 6,071.5 82.33 NIPPLE BAKER RS NIPPLE 4.880 NIPPLE;540.8 9,895.4 6,071.9 82.32 HANGER BAKER FLEX LOCK LINER HANGER 4.880 9,906.9 6,073.4 82.26 SBR BAKER 80-40 SEAL BORE 4.000' 11,451.3 6,107.4 89.20 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS UFT;3,049.2 ,-, PACKER 11,614.5 6,109.4 88.64 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 f PACKER 1 12,312.6 6,141.7 88.94 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER SURFACE;27.6-4,141.5 ik 12,518.3 6,152.0 86.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER - ''. 15,582.4 6,224.2 86.71 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;4,882.3 PACKER 15,744.6 6,231.5 89.04 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER 16,148.7 6226.2 88.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT,6.229.4 PACKER 16,312.3 6,233.9 87.48 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER Tubing Strings GAS LIFT;7,231.8 - Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 4 1/2 x 3 1/2 3 1/2 2.992 24.3 9,917.3 6,074.8 9.30 L-80 EUE 8rd MOD @ 59.5 Completion Details GAS LIFT;7,921.9 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(1) Item Des Com (in) • 24.3 24.3 0.00 HANGER CIW 4-1/2"TUBING HANGER 3.910 59.5 59.5 0.05 X0 Reducing X0,2,4-1/2"L-80 IBTM bx x 3-1/2"L-80 EUE 8RD-Mod 2.937 pin NIPPLE;8,329 9 540.8 540.8 0.18 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 8,329.9 5,695.9 68.90 NIPPLE HES LANDING NIPPLE DS-Profile 2.812 9,896.6 6,072.0 82.31 LOCATOR BAKER LOCATOR 2.940 9,897.8 6,072.2 82.31 SEAL ASSY BAKE 1/80-40 GBH LOCATOR SEAL ASSEMBLY w/12' 2.990 of seals • Perforations&Slots I LOCATOR;9,896.6 I.. 1 • Shot Dens ` ' Top(TVD) Ben(ND) (shotslf Top(ftKB) Btm(ftKB) (18(B) (IB(B) Zone Date t) Type Com It SEAL ASSY;9,897.8 ` 9,927.1 11,441.5 6,076.1 6,107.3 8/20/2014 SLOTS Slotted Liner i - :::- 11,642.6 12,302.7" 6,110.2 6,141.5 8/20/2014 SLOTS Slotted Liner in 12,546.5 15,572.6 6,153.8 6,223.7 8/20/2014 SLOTS Slotted Liner �} 15,772.8 16,138.9 6,231.8 6,226.0 8/20/2014 SLOTS Slotted Liner 11 I Z 16,340.6 17,623.9 6,235.0 6,263.8 8/20/2014 SLOTS Slotted Liner Mandrel Inserts INTERMEDIATE;25.2-10.053.2, 2 I I L. St SLOTS;9.927.1.11,441.5- • NTop(TVD) Valve Latch Port Size TRO Run ati Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Corn 1 3,049.3 2,605.2 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,323.0 10/5/2014 2 4,882.3 3,689.2 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,304.0 10/5/2014 3 6229.4 4,503.3 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1286.0 10/4/2014 SLOTS:11.6426-12,302.7- f- 4 7231.8 5,108.5 CAMCO 'MMG 1 1/2 GAS LIFT GLV RK 0.188 1269.0 10/4/2014 5 7,921.9 5,510.5 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 10/4/2014 DCR- 1 Notes:General&Safety End Date Annotation 10/5/2014 NOTE:SL DRIFTED TO 9699'RKB BEFORE STALLING OUT DUE TO DEVIATION 1 - SLOTS 12.5465-15.5726--1 • - 1 I SLOTS;15,772.8-18,138.9 II ell SLOTS;16,310.6-17.623.9 LINER;9,872.7-17.635.0 , rn r * C 0 0 U) Tl C) v �_ < . m cD O rc m r r K CO2 v a r— Z Z a r S P ° 3 o H D C1 Z7 Z CO ._ 03 _. ..,1 -..l c D C �CD co oD m W O Z v oz D o o N) oD l v c CD aiii co 0 > x CD 0 D c -o 0 O _ _ cnr Z wo D COP' CO sv CO .10 (.1) lom• 0 7 CO CD ° m P ♦V co Q = CD v . 1•'. m n cQ �• C 2 N >y CD CD D 11) ro c o l o mii Cn Ui (a (/) ON) VI O O OCo FOLD HERE The well name,location and borehole reference data were furnished by the customer. All interpretations are opinions based on inferences from electrical or other measurements and we cannot,and do not guarantee the accuracy or correctness of any interpretation, and we shall not,except in the case of gross or willful negligence on our part,be liable or responsible for any loss,costs,damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers,agents or employees. These interpretations are also subject to Clause 4 of our General Terms and Conditions as set out in our current Price Schedule. MH Waveform MH Waveform 0 ( us ) 3000 0 ( us) 3000 Casing Window Stop S/T Protection Casing Amp(No-fil Casing Window Stop l 0 ( us ) 3000 40 ( us/ft) 240 -20 ( ) 100 0 ( us ) 3000 MD Casing Window Start DTCO Casing Amp(Filter Casing Window Start 1 : 240 ft 0 ( us ) 1 ,,, 3000 40 ( us/ft) 240 -20 ( ) 100 ` 0 ( us ) 3000 �v 1 t„, 'bil,' ' ° i , lit , ' ' e y I 2 a J 1 . s: .. , , "' i Y p 1 11 ►: • . 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' 1 ,e ,..1 vii° '. pl re s p — L 11 1.. , ¢ E. I '. i ----- , it ••••,'' .' ii ti. '4'''')„ ,t," , 11 I 9400 I • t4 F j I 4.';; . t Nd 4.;;;;;Iir'it,t;;;. 4,-..'.p." .. 3 4.-,.. .; ., '11}4$., :".1,,..1:....A I 9450 ,t ,''',,i;Jii i '. f 14' ,.'i.,:.,...:.:1 ,11 t ► , '' Ill '''''''''''' 1- '''' '; I a (,,,, '. i t g ........... t i: „ ,,,, ,i , ,....- , ,- . •,..1 ii 11/4 / I 1 '} , -;;.'- ; 1) )' ..i.'t 4it ` . ((i ir.' 'i kti 1 II � 9500 , ; ',4)-, :1.,,,,•,:z I ' E' T f i I F E I 9 : - cI a a u . ianr o g. — I i j f,.,(. etc 9550 � ii 4 ir ,„.„,..... ' ,i.,1 ..„.,,,;*.,,,,, ,,,. i 'e* I._... .,,, ....... . ..... 3 4. li t f � I z '(----,:_ 1 —"----- : ,. .. 9600 �I ip ! j i ,r ,iii. li: , 1 , . , 1111 4 a.° t, ; { ' 'i,. ' ,i't, ii11 I .4,, 111 1 ........._� 9650 E I t s V 11 111!Iii 21 i'','' '''''''''''''''''' ( , i , ,.. . " 14 1 i ' 1.Ift, A q itf :=,1 ,,.- 4,11, ' ''' 1: .. .,,,,.. ,,, .-,„ 11 , , ,.I. . .. ..,lit 1 . y.. el ; ii. I _. 97004 _....... J rt-i--„, t r LI,', 1 . i gg � �P I ,SII I , _.._ .... 1 i I, 9750 s : ' t V'e\------ ill [ 980 1 ......... 0 1 3 i '. 1-i ft 1111 r-.411111 1 1 a 4 ;3 1 9850 _.. 1 :I L 4§ I 1 al " n/ J " T I 11 -, , . a J.J :TtI 1 1 g , 9900 ' LI ..ff t I,, , ;lir, ,n���� MD Casing Window Star DTCO Casing Amp(Filter Casing Window Start 1 : 240 ft 0 ( us ) 3000 40 ( us/ft) 240 -20 ( ) 100 0 ( us) 3000 Casing Window Stop S/T Projection Casing Amp (No-fit Casing Window Stop 0 ( us ) 3000 40 ( us/ft) 240 -20 ( ) 100 0 ( us ) 3000 MH Waveform MH Waveform 0 ( us) 3000 0 ( us ) 3000 Company: ConocoPhillips Alaska Inc. Well: 2E-02 Schlumberger FIELD: Kuparuk Rig Name Doyon 141 State: Alaska Date Logged: 13-August-2014 Date Processed: 20-August-2014 Well Location: NAD 83, Alaska State Plane, Zone 4, US Feet Elevations: KB:NA DF:132.51 ft GL:105.10 ft API Number: 50-029-23517-00-00 STATE OF ALASKA • ALS. A OIL AND GAS CONSERVATION COMM. ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed. Abandon r Repair w ell r Rug Furforations r Fbrforate r Other r WINJ to Prod Conversion 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 214-078-0 3.Address: 6.API Number: Stratigraphic r Service J P. O. Box 100360,Anchorage,Alaska 99510 50-029-23517-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25658,25665,25670 KRU 2E-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 17652 feet Plugs(measured) 8330 true vertical 6264 feet Junk(measured) None Effective Depth measured 17635 feet Packer(measured) 541, 8330,8330,9897, 9898 true vertical 6264 feet (true vertical) 541, 5696, 5696,6072,6072 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 107 107 0 0 SURFACE 4114 14.78 4142 3241 0 0 INTERMEDIATE 10028 8.5 10053 6094 0 0 LINER 7762 6.57 17635 6264 0 0 0 0 0 0 o 0 Perforation depth: Measured depth: 9927-11441,11642-12302,12546-15572,15772-16138,16340-17623 True Vertical Depth: 6076-6107,6110-6141,6153-6223,6231-6226,6235-6263 RECEIVED JAN 13 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 9897 MD,6072 TVD �j Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE W/2.875"PROFILE @ 541 MD and 541 TVD AV --CC NIPPLE-HES LANDING NIPPLE DS-PROFILE W/RHC PLUG INSTALLED @ 8330 MD and 5696 TVD CSA-2 PLUG-SLICK LINE SET CSA PLUG IN DS NIPPLE @ 8329.94 @ 8330 MD and 5696 TVD LOCATOR -BAKER LOCATOR @ 9897 MD and 6072 TVD SEAL ASSY-BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY W/12'OF SEALS @ 9898 MD and 6072 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured). Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 147 2340 35 941 164 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil J Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt N/A Contact Bob Christensen/Darrell Humphrey Email n1139(a�conocophillips.com Printed Name Darrell R. Humphrey Title NSK Production Engineering Specialist Signature Phone:659-7535 Date ti\N______ii,"‘\ /-96' Form 10-404 Revised 10/2012 VTI- h/2 /1 C-- Submit Origi.rial Only ,l[' </2,,liJ--- RBDMS JAN 1 3 2015 • 2E-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/16/14 Commenced Injector Pre- Production for more than 30 days 10/05/14 MEASURED BHP @ 9698' RKB: 3148 PSI. COMPLETE. • KUP SVC • 2E-02 • ConocoPhillips Weil Atgibutes rax Angle&MD ID Alaska Inc Wellbore APUUWI Field Name Wellbore Status ncl("I MD(ftKB) Act Btm(ftKB) 500292351700 KUPARUK RIVER UNIT SVC 17,635.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2E-02,1023/20145:39.42 AM SSSV:NIPPLE Last WO: 27,40 8/24/2014 Vesical schematic(aaw0 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag.SEE NOTE 9,699.0 10/5/2014 Rev Reason:NOTE RE TAG DEPTH hipshkf 10/23/2014 Casing Strings HANGER,24.3- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread ' CONDUCTOR 16 15.250 28.0 106.5 106.5 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread a SURFACE 1034 9.950 27.6 4,141.5 3,240.8 45.50 L-80 HYD 563 Casing Description INTERMEDIATE OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread 75/8 6.875 25.2 10,0532 6,093.5 2970 L-80 W563 Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread LINER 412 3.958 9,872.7 17,635.0 6,263.8 11.60 L-80 H563 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I") Item Des Com (in) .AA/CONDUCTOR,28.0-10.5 9,872.6 6,068.8 82.43 PACKER BAKER LINER TOP PACKER ZXPw/HRDE profile, 5.750 a 9,892.6 6,071.5 82.33 NIPPLE BAKER RS NIPPLE 4.880 NIPPLE;540.8 al 9,895.4 6,071.9 8232 HANGER BAKER FLEX LOCK LINER HANGER 4.880 a 9,906.9 6,073.4 8226 SBR BAKER 80-40 SEAL BORE 4.000 in 11,451.3 6,107.4 89.20 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT,3,049.2 - PACKER 11,614.5 6,109.4 88.64 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER 12,312.6 6,141.7 88.94 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER SURFACE;27.6-4.1415 12,518.3 6,152.0 86.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER a 15,582.4 6,224.2 86.71 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;4882.3 - PACKER a15,744.6 6,231.5 89.04 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 • PACKER 16,148.7 6,226.2 88.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;6,229.4 PACKER 16,312.3 6,233.9 87.48 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 IIII PACKER Tubing Strings GAS LIFT.7,231 8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 4 1/2 x 3 1/2 3 1/2 2.992 24.3 9,917.3 6,074.8 9.30 L-80 EUE 8rd MOD @ 59.5 • Completion Details GAS LIFT;7921.9 - Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel I") Item Des Com (in) 24.3 24.3 0.00 HANGER CIW 4-1/2"TUBING HANGER 3.910 59.5 59.5 0.05 X0 Reducing X0,2',4-1/2"L-80 IBTM box 3-1/2"L-80 EUE 8RD-Mod 2.937 NIPPLE;6,329.9 pin CSA-2 Plug;8.329.91 '' II 540.8 540.8 0.18 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 8,329.9 5,695.9 68.90 NIPPLE HES LANDING NIPPLE DS-Profile w/RHC Plug installed 2.812 9,896.6 6,0720 82.31 LOCATOR BAKER LOCATOR 2.940 9,897.8 6,0722 82.31 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY w/12' 2.990 of seals Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LOCATOR;98%6 Top(TVD) Top Incl g Top 111601 111601 (°I Des Corn Run Date ID(in) 8.329.9 5.695.9 68.90 CSA-2 Plug Slick line set CSA plug in DS nipple'/r1)8329.94 8/23/2014 0.000 SEAL ASSY;9,897,8 a. Perforations&Slots • Shot it: Dens ` Top(TVD) Stat(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com ii 9,927.1 11,441.5 6,076.1 6,1073 8/20/2014 SLOTS Slotted Liner C 11,642.6 12,302.7 6,110.2 6,141.5 8/20/2014 SLOTS Slotted Liner INTERMEDIATE;25.2-10,053.2,_1 r 12,546.5 15,572.6 6,153.8 6,223.7 8/20/2014 SLOTS Slotted Liner SLOTS;9,927.1-11,441.5- ' 15,772.8 16,138.9 6,231.8 6,226.0 8/20/2014 SLOTS Slotted Liner 16,340.6 17,623.9 6,235.01 6,263.8 8/20/2014 SLOTS Slotted Liner Mandrel Inserts St ae SLOTS;11,6426-12.302.7 - N ToTop(TVD) Valve Latch Port Size TRO Run Top (ftKB) Make Model OD(in) Sets Type Type (in) (psi) Run Date Corn f 3,049.3 2,605.2 CAMCO MMG 112 GAS LIFT GLV RK 0.188 1,323.0 10/5/2014 2 4,8823 3,689.2 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,304.0 10/5/2014 3 6,2294 4,503.3 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,286.0 10/4/2014 4 7,231.8 5,108.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,269.0 10/4/2014 5 7,921.9 5,510.5 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 10/4/2014 DCR- SLOTS:12.546.5-15,572.6 1 Notes:General&Safety End Date Annotation 10/5/2014 NOTE:SL DRIFTED TO 9699'RKB BEFORE STALLING OUT DUE TO DEVIATION SLOTS,15.772.8-16,138.9 SLOTS:16,340.6-17,623.9 LINER;9872.7-17,635.0 214078 25068 SehiumbergerDrilling & Measurements Transmittal #: 13NOV14-NG04 DATA LOGGED MWD/LWD LogProduct Delivery %%. /`1/201 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2E-02 Date Dispatched: 13-Nov-14 Job#: 14AKA0150 Dispatched By: Nathan Green Well / Product Description R EC E I V E Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION* Resistivi 2" MD NOV 13 Z014 x x VISION* Resistive'2"TVD q 0^ne x x VISION* Resistivi'5" MD x x VISION* Resistivil 5"TVD x x VISION* Resistivil 5' MD Ressitivity Image Log x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: PDF x Survey: txt,xls,pdf x Please sign and email a copy to: Please sign and email/fax a copy to: catherine.RosoConocophilips.com AlaskaPTSPrintCenter(&slb.com Cathaerine Roso Attn: Nathan Green 17) 6 Fax: 90 -561-8317 Received By: MAL-4zek—i 2 1 40 78 L5068 RECEIVED NOV 13 2014 ACC NADConversion N A D 2 7 Kuparuk River Unit Kuparuk 2E Pad 2E-02 Definitive Survey Report 02 September, 2014 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02: 105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02: 105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2E-02 Well Position +N/-S 0.00 usft Northing: 5,944,172.25 usft Latitude: 70°15'30.741 N +E/-W 0.00 usft Easting: 529,971.76 usft Longitude: 149°45'27.905 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.10 usft Wellbore 2E-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 7/15/2014 19.29 80.87 57,580 Design 2E-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.41 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.41 0.00 0.00 182.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 1,200.00 2E-02 SRV 1 SLB-NSG-SSHOT(2E-02) GYD-GC-SS Gyrodata gyro single shots 8/7/2014 1:51:0 1,224.30 4,080.12 2E-02 SRV 2 SLB-MWD-GMAG(2E-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/7/2014 1:55:0 4,127.21 4,127.21 2E-02 SRV 3 SLB-MWD-INC-ONLY-FILL INC+TREND Inclinometer+known azi trend 8/7/2014 2:01:0 4,223.18 10,001.20 2E-02 SRV 4 SLB-MWD-GMAG(2E-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/7/2014 2:01:0 10,052.53 10,052.53 2E-02 SRV 5 SLB-MWD-INC-ONLY-FILL INC+TREND Inclinometer+known azi trend 8/20/2014 3:04: 10,146.01 17,572.07 2E-02 SRV 6 SLB-MWD-GMAG(2E-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/20/2014 3:05: Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.41 0.00 0.00 27.41 -105.10 0.00 0.00 5,944,172.25 529,971.76 0.00 0.00 UNDEFINED 90.00 0.10 251.09 90.00 -42.51 -0.02 -0.05 5,944,172.23 529,971.71 0.16 0.02 GYD-GC-SS(1) 182.00 0.29 301.04 182.00 49.49 0.08 -0.33 5,944,172.32 529,971.43 0.26 -0.06 GYD-GC-SS(1) 275.00 0.23 276.10 275.00 142.49 0.22 -0.71 5,944,172.46 529,971.05 0.14 -0.19 GYD-GC-SS(1) 367.00 0.41 278.11 367.00 234.49 0.28 -1.22 5,944,172.53 529,970.54 0.20 -0.24 GYD-GC-SS(1) 461.00 0.21 336.31 461.00 328.49 0.49 -1.63 5,944,172.73 529,970.13 0.37 -0.43 GYD-GC-SS(1) 552.00 0.18 241.99 552.00 419.49 0.57 -1.82 5,944,172.82 529,969.94 0.32 -0.51 GYD-GC-SS(1) 614.00 0.39 225.67 613.99 481.48 0.38 -2.06 5,944,172.62 529,969.70 0.36 -0.31 GYD-GC-SS(1) 645.00 0.53 223.79 644.99 512.48 0.20 -2.23 5,944,172.44 529,969.53 0.45 -0.13 GYD-GC-SS(1) 737.00 1.09 224.75 736.98 604.47 -0.72 -3.14 5,944,171.51 529,968.62 0.61 0.83 GYD-GC-SS(1) 9/2/2014 5:05:50PM Page 2 COMPASS 5000.1 Build 65 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 830.00 2.21 232.75 829.94 697.43 -2.44 -5.19 5,944,169.79 529,966.58 1.23 2.62 GYD-GC-SS(1) 922.00 5.58 243.67 921.72 789.21 -5.50 -10.61 5,944,166.71 529,961.17 3.73 5.86 GYD-GC-SS(1) 1,015.00 8.25 243.02 1,014.03 881.52 -10.53 -20.61 5,944,161.64 529,951.19 2.87 11.24 GYD-GC-SS(1) 1,107.00 12.30 238.76 1,104.54 972.03 -18.61 -34.88 5,944,153.50 529,936.96 4.48 19.82 GYD-GC-SS(1) 1,153.00 14.07 237.56 1,149.33 1,016.82 -24.15 -43.79 5,944,147.93 529,928.07 3.89 25.67 GYD-GC-SS(1) 1,200.00 17.40 236.11 1,194.56 1,062.05 -31.14 -54.45 5,944,140.90 529,917.44 7.13 33.02 GYD-GC-SS(1) 1,224.30 18.13 238.02 1,217.70 1,085.19 -35.16 -60.67 5,944,136.85 529,911.24 3.84 37.26 MWD+IFR-AK-CAZ-SC(2) 1,318.77 19.56 237.62 1,307.10 1,174.59 -51.42 -86.50 5,944,120.49 529,885.48 1.52 54.41 MWD+IFR-AK-CAZ-SC(2) 1,411.19 20.96 238.05 1,393.80 1,261.29 -68.45 -113.59 5,944,103.35 529,858.46 1.52 72.38 MWD+IFR-AK-CAZ-SC(2) 1,503.27 21.14 239.73 1,479.74 1,347.23 -85.54 -141.90 5,944,086.16 529,830.21 0.68 90.44 MWD+IFR-AK-CAZ-SC(2) 1,595.46 23.35 239.30 1,565.06 1,432.55 -103.25 -171.97 5,944,068.33 529,800.22 2.40 109.19 MWD+IFR-AK-CAZ-SC(2) 1,689.80 23.12 240.89 1,651.75 1,519.24 -121.80 -204.23 5,944,049.65 529,768.04 0.71 128.86 MWD+IFR-AK-CAZ-SC(2) 1,783.07 29.62 237.85 1,735.28 1,602.77 -143.00 -239.78 5,944,028.31 529,732.57 7.12 151.28 MWD+IFR-AK-CAZ-SC(2) 1,829.07 30.75 237.43 1,775.04 1,642.53 -155.38 -259.32 5,944,015.85 529,713.09 2.50 164.34 MWD+IFR-AK-CAZ-SC(2) 1,876.26 31.60 236.78 1,815.41 1,682.90 -168.65 -279.83 5,944,002.51 529,692.63 1.94 178.31 MWD+IFR-AK-CAZ-SC(2) 1,969.05 33.28 235.61 1,893.72 1,761.21 -196.35 -321.18 5,943,974.64 529,651.40 1.93 207.44 MWD+IFR-AK-CAZ-SC(2) 2,019.33 37.05 234.27 1,934.82 1,802.31 -212.99 -344.87 5,943,957.91 529,627.78 7.65 224.90 MWD+IFR-AK-CAZ-SC(2) 2,060.30 39.08 234.74 1,967.07 1,834.56 -227.66 -365.43 5,943,943.16 529,607.27 5.01 240.27 MWD+IFR-AK-CAZ-SC(2) 2,154.26 37.86 234.39 2,040.64 1,908.13 -261.54 -413.06 5,943,909.09 529,559.79 1.32 275.80 MWD+IFR-AK-CAZ-SC(2) 2,245.09 41.03 235.00 2,110.77 1,978.26 -294.88 -460.16 5,943,875.57 529,512.83 3.52 310.76 MWD+IFR-AK-CAZ-SC(2) 2,339.46 44.39 234.79 2,180.10 2,047.59 -331.69 -512.51 5,943,838.56 529,460.63 3.56 349.37 MWD+IFR-AK-CAZ-SC(2) 2,431.68 49.03 232.76 2,243.32 2,110.81 -371.38 -566.62 5,943,798.65 529,406.68 5.28 390.93 MWD+IFR-AK-CAZ-SC(2) 2,479.57 51.28 231.42 2,274.01 2,141.50 -393.98 -595.62 5,943,775.95 529,377.78 5.17 414.52 MWD+IFR-AK-CAZ-SC(2) 2,522.72 52.79 231.30 2,300.55 2,168.04 -415.22 -622.19 5,943,754.60 529,351.29 3.51 436.68 MWD+IFR-AK-CAZ-SC(2) 2,615.93 53.90 231.91 2,356.20 2,223.69 -461.66 -680.80 5,943,707.93 529,292.88 1.30 485.13 MWD+IFR-AK-CAZ-SC(2) 2,708.24 53.43 232.38 2,410.89 2,278.38 -507.29 -739.51 5,943,662.07 529,234.35 0.65 532.79 MWD+IFR-AK-CAZ-SC(2) 2,802.68 56.22 232.79 2,465.29 2,332.78 -554.18 -800.82 5,943,614.94 529,173.24 2.98 581.79 MWD+IFR-AK-CAZ-SC(2) 2,894.14 55.47 232.31 2,516.64 2,384.13 -600.20 -860.90 5,943,568.68 529,113.34 0.93 629.88 MWD+IFR-AK-CAZ-SC(2) 2,986.15 55.19 232.20 2,568.98 2,436.47 -646.53 -920.74 5,943,522.13 529,053.69 0.32 678.27 MWD+IFR-AK-CAZ-SC(2) 3,079.33 54.68 232.10 2,622.51 2,490.00 -693.32 -980.96 5,943,475.10 528,993.66 0.55 727.14 MWD+IFR-AK-CAZ-SC(2) 3,172.18 53.78 232.84 2,676.78 2,544.27 -739.22 -1,040.70 5,943,428.97 528,934.11 1.17 775.09 MWD+IFR-AK-CAZ-SC(2) 3,262.76 55.01 231.61 2,729.52 2,597.01 -784.33 -1,098.91 5,943,383.63 528,876.09 1.75 822.21 MWD+IFR-AK-CAZ-SC(2) 3,355.72 53.81 231.92 2,783.62 2,651.11 -831.12 -1,158.29 5,943,336.61 528,816.91 1.32 871.04 MWD+IFR-AK-CAZ-SC(2) 3,449.61 55.28 231.16 2,838.08 2,705.57 -878.69 -1,218.17 5,943,288.81 528,757.22 1.70 920.67 MWD+IFR-AK-CAZ-SC(2) 3,541.30 54.83 231.06 2,890.60 2,758.09 -925.87 -1,276.67 5,943,241.39 528,698.92 0.50 969.87 MWD+IFR-AK-CAZ-SC(2) 3,635.63 55.64 230.13 2,944.39 2,811.88 -975.07 -1,336.54 5,943,191.97 528,639.25 1.18 1,021.12 MWD+IFR-AK-CAZ-SC(2) 3,726.21 55.25 231.03 2,995.77 2,863.26 -1,022.44 -1,394.17 5,943,144.37 528,581.81 0.92 1,070.47 MWD+IFR-AK-CAZ-SC(2) 3,818.80 54.78 231.78 3,048.85 2,916.34 -1,069.76 -1,453.45 5,943,096.82 528,522.72 0.84 1,119.83 MWD+IFR-AK-CAZ-SC(2) 3,911.61 53.55 232.06 3,103.19 2,970.68 -1,116.17 -1,512.68 5,943,050.18 528,463.69 1.35 1,168.28 MWD+IFR-AK-CAZ-SC(2) 4,005.59 53.26 232.39 3,159.22 3,026.71 -1,162.39 -1,572.32 5,943,003.73 528,404.24 0.42 1,216.55 MWD+IFR-AK-CAZ-SC(2) 9/2/2014 5:05:50PM Page 3 COMPASS 5000.1 Build 65 Schlumberger ' i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02: 105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,080.12 53.04 232.60 3,203.91 3,071.40 -1,198.70 -1,619.63 5,942,967.23 528,357.07 0.37 1,254.49 MWD+IFR-AK-CAZ-SC(2) 4,127.21 53.17 233.01 3,232.18 3,099.67 -1,221.46 -1,649.63 5,942,944.35 528,327.17 0.75 1,278.29 INC+TREND(3) 4,141.00 53.17 233.13 3,240.45 3,107.94 -1,228.10 -1,658.45 5,942,937.69 528,318.37 0.73 1,285.23 MWD+IFR-AK-CAZ-SC(4) 10-3/4"x 13-1/2" 4,223.18 53.15 233.88 3,289.73 3,157.22 -1,267.21 -1,711.33 5,942,898.37 528,265.66 0.73 1,326.16 MWD+IFR-AK-CAZ-SC(4) 4,317.23 52.97 232.83 3,346.25 3,213.74 -1,312.07 -1,771.64 5,942,853.27 528,205.53 0.91 1,373.10 MWD+IFR-AK-CAZ-SC(4) 4,408.54 53.01 233.03 3,401.21 3,268.70 -1,356.02 -1,829.82 5,942,809.09 528,147.54 0.18 1,419.06 M1ND+IFR-AK-CAZ-SC(4) 4,503.42 52.94 232.98 3,458.35 3,325.84 -1,401.61 -1,890.32 5,942,763.27 528,087.23 0.08 1,466.72 MWD+IFR-AK-CAZ-SC(4) 4,593.75 52.42 233.24 3,513.11 3,380.60 -1,444.73 -1,947.77 5,942,719.92 528,029.95 0.62 1,511.82 MWD+IFR-AK-CAZ-SC(4) 4,686.74 52.40 233.38 3,569.84 3,437.33 -1,488.75 -2,006.86 5,942,675.67 527,971.04 0.12 1,557.89 MWD+IFR-AK-CAZ-SC(4) 4,781.01 52.41 234.02 3,627.35 3,494.84 -1,532.97 -2,067.05 5,942,631.21 527,911.03 0.54 1,604.18 MWD+IFR-AK-CAZ-SC(4) 4,872.05 52.29 233.38 3,682.96 3,550.45 -1,575.65 -2,125.15 5,942,588.32 527,853.11 0.57 1,648.85 MWD+IFR-AK-CAZ-SC(4) 4,965.22 52.24 232.56 3,739.98 3,607.47 -1,620.02 -2,183.97 5,942,543.71 527,794.47 0.70 1,695.25 MWD+IFR-AK-CAZ-SC(4) 5,057.33 52.42 231.30 3,796.27 3,663.76 -1,664.98 -2,241.36 5,942,498.53 527,737.26 1.10 1,742.19 MWD+IFR-AK-CAZ-SC(4) 5,148.60 52.91 231.44 3,851.62 3,719.11 -1,710.28 -2,298.05 5,942,453.01 527,680.76 0.55 1,789.44 MWD+IFR-AK-CAZ-SC(4) 5,242.26 52.88 232.34 3,908.13 3,775.62 -1,756.38 -2,356.83 5,942,406.68 527,622.18 0.77 1,837.56 MWD+IFR-AK-CAZ-SC(4) 5,335.97 52.90 232.59 3,964.67 3,832.16 -1,801.91 -2,416.09 5,942,360.92 527,563.10 0.21 1,885.13 MWD+IFR-AK-CAZ-SC(4) 5,429.57 52.86 232.00 4,021.15 3,888.64 -1,847.56 -2,475.14 5,942,315.04 527,504.24 0.50 1,932.81 MWD+IFR-AK-CAZ-SC(4) 5,520.26 53.00 231.69 4,075.82 3,943.31 -1,892.26 -2,532.04 5,942,270.12 527,447.53 0.31 1,979.47 MWD+IFR-AK-CAZ-SC(4) 5,613.49 53.02 231.09 4,131.92 3,999.41 -1,938.73 -2,590.22 5,942,223.42 527,389.53 0.51 2,027.95 MWD+IFR-AK-CAZ-SC(4) 5,706.18 52.85 229.78 4,187.78 4,055.27 -1,985.84 -2,647.24 5,942,176.09 527,332.71 1.14 2,077.01 MWD+IFR-AK-CAZ-SC(4) 5,798.29 52.96 230.29 4,243.34 4,110.83 -2,033.03 -2,703.55 5,942,128.68 527,276.59 0.46 2,126.14 MWD+IFR-AK-CAZ-SC(4) 5,892.61 52.91 230.16 4,300.19 4,167.68 -2,081.18 -2,761.39 5,942,080.31 527,218.94 0.12 2,176.28 MWD+IFR-AK-CAZ-SC(4) 5,983.98 52.85 230.25 4,355.33 4,222.82 -2,127.81 -2,817.37 5,942,033.46 527,163.16 0.10 2,224.84 MWD+IFR-AK-CAZ-SC(4) 6,075.42 52.90 231.51 4,410.52 4,278.01 -2,173.81 -2,873.93 5,941,987.24 527,106.79 1.10 2,272.78 MWD+IFR-AK-CAZ-SC(4) 6,169.20 52.94 232.48 4,467.06 4,334.55 -2,219.87 -2,932.89 5,941,940.94 527,048.02 0.83 2,320.88 MWD+IFR-AK-CAZ-SC(4) 6,261.89 52.93 232.45 4,522.93 4,390.42 -2,264.94 -2,991.54 5,941,895.65 526,989.56 0.03 2,367.96 MWD+IFR-AK-CAZ-SC(4) 6,354.13 52.94 232.59 4,578.52 4,446.01 -2,309.72 -3,049.95 5,941,850.64 526,931.33 0.12 2,414.76 MWD+IFR-AK-CAZ-SC(4) 6,448.00 52.91 232.64 4,635.11 4,502.60 -2,355.20 -3,109.45 5,941,804.93 526,872.01 0.05 2,462.28 MWD+IFR-AK-CAZ-SC(4) 6,539.90 52.82 231.61 4,690.59 4,558.08 -2,400.17 -3,167.28 5,941,759.73 526,814.37 0.90 2,509.25 MWD+IFR-AK-CAZ-SC(4) 6,632.46 52.90 230.97 4,746.48 4,613.97 -2,446.32 -3,224.86 5,941,713.36 526,756.98 0.56 2,557.37 MWD+IFR-AK-CAZ-SC(4) 6,724.08 52.86 230.21 4,801.77 4,669.26 -2,492.70 -3,281.30 5,941,666.76 526,700.73 0.66 2,605.69 MWD+IFR-AK-CAZ-SC(4) 6,817.41 52.86 230.31 4,858.12 4,725.61 -2,540.26 -3,338.51 5,941,618.98 526,643.71 0.09 2,655.23 MWD+IFR-AK-CAZ-SC(4) 6,908.00 52.94 231.43 4,912.77 4,780.26 -2,585.86 -3,394.56 5,941,573.16 526,587.86 0.99 2,702.75 MWD+IFR-AK-CAZ-SC(4) 7,003.15 52.83 231.80 4,970.18 4,837.67 -2,632.97 -3,454.03 5,941,525.82 526,528.57 0.33 2,751.91 MWD+IFR-AK-CAZ-SC(4) 7,092.73 52.72 231.76 5,024.37 4,891.86 -2,677.10 -3,510.07 5,941,481.47 526,472.72 0.13 2,797.97 MWD+IFR-AK-CAZ-SC(4) 7,188.45 52.79 231.97 5,082.30 4,949.79 -2,724.15 -3,570.01 5,941,434.18 526,412.98 0.19 2,847.09 MWD+IFR-AK-CAZ-SC(4) 7,280.49 53.05 231.56 5,137.80 5,005.29 -2,769.60 -3,627.68 5,941,388.51 526,355.49 0.45 2,894.52 MWD+IFR-AK-CAZ-SC(4) 7,371.75 53.52 231.11 5,192.36 5,059.85 -2,815.30 -3,684.80 5,941,342.58 526,298.55 0.65 2,942.19 MWD+IFR-AK-CAZ-SC(4) 7,464.59 53.52 231.93 5,247.55 5,115.04 -2,861.75 -3,743.24 5,941,295.91 526,240.31 0.71 2,990.65 MWD+IFR-AK-CAZ-SC(4) , 7,558.61 53.51 231.49 5,303.46 5,170.95 -2,908.59 -3,802.57 5,941,248.83 526,181.17 0.38 3,039.53 MWD+IFR-AK-CAZ-SC(4) 9/2/2014 5:05.50PM Page 4 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) i (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,651.73 53.33 231.52 5,358.95 5,226.44 -2,955.14 -3,861.10 5,941,202.06 526,122.84 0.20 3,088.09 MWD+IFR-AK-CAZ-SC(4) 7,744.47 54.89 230.81 5,413.32 5,280.81 -3,002.26 -3,919.62 5,941,154.72 526,064.51 1.79 3,137.22 MWD+IFR-AK-CAZ-SC(4) 7,837.45 56.99 230.12 5,465.39 5,332.88 -3,051.29 -3,979.02 5,941,105.45 526,005.31 2.34 3,188.30 MWD+IFR-AK-CAZ-SC(4) 7,930.40 58.53 229.23 5,514.98 5,382.47 -3,102.17 -4,038.95 5,941,054.34 525,945.59 1.84 3,241.24 MWD+IFR-AK-CAZ-SC(4) 8,022.45 59.45 228.79 5,562.40 5,429.89 -3,153.92 -4,098.50 5,941,002.36 525,886.25 1.08 3,295.03 MWD+IFR-AK-CAZ-SC(4) 8,115.79 62.36 228.67 5,607.78 5,475.27 -3,207.71 -4,159.80 5,940,948.33 525,825.18 3.12 3,350.93 MWD+IFR-AK-CAZ-SC(4) 8,209.20 65.34 227.26 5,648.95 5,516.44 -3,263.86 -4,222.05 5,940,891.94 525,763.15 3.47 3,409.22 MWD+IFR-AK-CAZ-SC(4) 8,298.43 67.96 226.72 5,684.31 5,551.80 -3,319.73 -4,281.95 5,940,835.83 525,703.48 2.99 3,467.15 MWD+IFR-AK-CAZ-SC(4) 8,393.31 70.80 225.22 5,717.72 5,585.21 -3,381.45 -4,345.78 5,940,773.86 525,639.90 3.34 3,531.06 MWD+IFR-AK-CAZ-SC(4) 8,486.36 70.13 225.62 5,748.84 5,616.33 -3,443.01 -4,408.24 5,940,712.07 525,577.69 0.83 3,594.75 MWD+IFR-AK-CAZ-SC(4) 8,579.02 70.79 226.07 5,779.83 5,647.32 -3,503.84 -4,470.89 5,940,651.00 525,515.29 0.85 3,657.73 MWD+IFR-AK-CAZ-SC(4) 8,671.87 70.72 225.12 5,810.43 5,677.92 -3,565.17 -4,533.52 5,940,589.42 525,452.92 0.97 3,721.22 MWD+IFR-AK-CAZ-SC(4) 8,762.85 70.94 225.15 5,840.31 5,707.80 -3,625.80 -4,594.43 5,940,528.56 525,392.25 0.24 3,783.93 MWD+IFR-AK-CAZ-SC(4) 8,855.55 70.881 224.47 5,870.63 5,738.12 -3,687.94 -4,656.16 5,940,466.17 525,330.77 0.70 3,848.20 MWD+IFR-AK-CAZ-SC(4) 0.573,913.80 MWD+IFR-AK-CAZ-SC 4 8,949.24 71.14 223.98 5,901.11 5,768.60 -3,751.43 4 717.95 5940 402.45 525,269.24SC 9,041.21 73.30 222.67 5,929.20 5,796.69 -3,815.14 -4,778.03 5,940,338.51 525,209.42 2.71 3,979.56 MWD+IFR-AK-CAZ-SC(4) 9,134.03 75.39 221.06 5,954.24 5,821.73 -3,881.70 -4,837.67 5,940,271.72 525,150.05 2.80 4,048.16 MWD+IFR-AK-CAZ-SC(4) 9,224.13 77.64 219.89 5,975.25 5,842.74 -3,948.34 -4,894.54 5,940,204.85 525,09346 2.80 4,116.75 MVVD+IFR-AK-CAZ-SC(4) 9,318.27 79.75 219.36 5,993.71 5,861.20 -4,019.44 -4,953.41 5,940,133.53 525,034.88 2.31 4,189.86 M1ND+IFR-AK-CAZ-SC(4) 9,410.01 81.02 217.89 6,009.03 5,876.52 -4,090.10 -5,009.86 5,940,062.65 524,978.71 2.10 4,262.45 MWD+IFR-AK-CAZ-SC(4) 9,503.22 82.12 216.46 6,022.70 5,890.19 -4,163.57 -5,065.57 5,939,988.97 524,923.30 1.92 4,337.82 MWD+IFR-AK-CAZ-SC(4) 9,597.65 82.78 214.56 6,035.10 5,902.59 -4,239.77 -5,119.94 5,939,912.56 524,869.24 2.11 4,415.87 MWD+IFR-AK-CAZ-SC(4) 9,689.12 83.22 212.31 6,046.25 5,913.74 -4,315.53 -5,169.96 5,939,836.61 524,819.53 2.49 4,493.33 MWD+IFR-AK-CAZ-SC(4) 9,783.69 83.02 209.50 6,057.58 5,925.07 -4,396.08 -5,218.18 5,939,755.88 524,771.63 2.96 4,575.51 MWD+IFR-AK-CAZ-SC(4) 9,876.21 82.41 205.77 6,069.32 5,936.81 -4,477.36 -5,260.74 5,939,674.43 524,729.40 4.05 4,658.23 MWD+IFR-AK-CAZ-SC(4) 9,968.62 81.97 202.00 6,081.88 5,949.37 -4,561.06 -5,297.81 5,939,590.60 524,692.67 4.07 4,743.17 MWD+IFR-AK-CAZ-SC(4) 10,001.20 82.03 201.24 6,086.42 5,953.91 -4,591.05 -5,309.69 5,939,560.56 524,680.90 2.32 4,773.56 MWD+IFR-AK-CAZ-SC(4) 10,052.53 82.26 200.00 6,093.43 5,960.92 -4,638.64 -5,327.60 5,939,512.90 524,663.19 2.43 4,821.75 INC+TREND(5) 10,053.20 82.28 199.99 6,093.52 5,961.01 -4,639.27 -5,327.83 5,939,512.28 524,662.96 3.25 4,822.38 MWD+IFR-AK-CAZ-SC(6) 7-5/8"x 9-7/8" 10,146.01 84.78 198.29 6,103.98 5,971.47 -4,726.38 -5,358.06 5,939,425.06 524,633.09 3.25 4,910.49 MWD+IFR-AK-CAZ-SC(6) 10,242.38 87.12 194.66 6,110.79 5,978.28 -4,818.54 -5,385.31 5,939,332.80 524,606.21 4.47 5,003.55 MWD+IFR-AK-CAZ-SC(6) 10,338.36 88.96 191.07 6,114.07 5,981.56 -4,912.04 -5,406.66 5,939,239.22 524,585.23 4.20 5,097.73 MWD+IFR-AK-CAZ-SC(6) 10,432.77 91.28 187.18 6,113.88 5,981.37 -5,005.23 -5,421.63 5,939,145.98 524,570.63 4.80 5,191.39 MWD+IFR-AK-CAZ-SC(6) 10,526.38 90.79 184.51 6,112.18 5,979.67 -5,098.33 -5,431.16 5,939,052.86 524,561.47 2.90 5,284.77 MWD+IFR-AK-CAZ-SC(6) 10,575.84 92.09 182.91 6,110.94 5,978.43 -5,147.67 -5,434.36 5,939,003.51 524,558.47 4.17 5,334.19 MWD+IFR-AK-CAZ-SC(6) 10,621.73 93.47 181.10 6,108.72 5,976.21 -5,193.47 -5,435.96 5,938,957.70 524,557.05 4.96 5,380.02 MWD+IFR-AK-CAZ-SC(6) 10,663.39 92.64 180.96 6,106.50 5,973.99 -5,235.06 -5,436.71 5,938,916.11 524,556.47 2.02 5,421.61 MWD+IFR-AK-CAZ-SC(6) 10,715.07 91.64 179.98 6,104.57 5,972.06 -5,286.70 -5,437.13 5,938,864.47 524,556.25 2.71 5,473.24 MWD+IFR-AK-CAZ-SC(6) 10,809.21 90.15 179.51 6,103.10 5,970.59 -5,380.83 -5,436.71 5,938,770.36 524,557.04 1.66 5,567.29 MWD+IFR-AK-CAZ-SC(6) 9/2/2014 5:05:50PM Page 5 COMPASS 5000.1 Build 65 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,905.14 89.75 176.52 6,103.18 5,970.67 -5,476.69 -5,433.39 5,938,674.52 524,560.75 3.14 5,662.98 MWD+IFR-AK-CAZ-SC(6) 11,000.88 90.31 174.55 6,103.13 5,970.62 -5,572.14 -5,425.94 5,938,579.12 524,568.58 2.14 5,758.10 MWD+IFR-AK-CAZ-SC(6) 11,095.40 90.77 173.79 6,102.24 5,969.73 -5,666.16 -5,416.34 5,938,485.14 524,578.55 0.94 5,851.74 MWD+IFR-AK-CAZ-SC(6) 11,122.88 90.55 173.96 6,101.92 5,969.41 -5,693.48 -5,413.41 5,938,457.83 524,581.59 1.01 5,878.94 MWD+IFR-AK-CAZ-SC(6) 11,190.53 89.80 173.96 6,101.71 5,969.20 -5,760.76 -5,406.29 5,938,390.60 524,588.98 1.11 5,945.92 MWD+IFR-AK-CAZ-SC(6) 11,284.82 88.15 173.79 6,103.40 5,970.89 -5,854.49 -5,396.23 5,938,296.91 524,599.41 1.76 6,039.25 MWD+IFR-AK-CAZ-SC(6) 11,378.47 88.62 174.48 6,106.04 5,973.53 -5,947.61 -5,386.66 5,938,203.84 524,609.34 0.89 6,131.98 MWD+IFR-AK-CAZ-SC(6) 11,474.65 89.39 175.95 6,107.71 5,975.20 -6,043.44 -5,378.64 5,938,108.05 524,617.74 1.73 6,227.47 MWD+IFR-AK-CAZ-SC(6) ` 11,570.00 89.48 177.08 6,108.65 5,976.14 -6,138.61 -5,372.85 5,938,012.92 524,623.92 1.19 6,322.38 MWD+IFR-AK-CAZ-SC(6) 11,665.35 87.67 177.74 6,111.02 5,978.51 -6,233.82 -5,368.54 5,937,917.73 524,628.60 2.02 6,417.39 MWD+IFR-AK-CAZ-SC(6) 11,759.43 85.29 177.99 6,116.80 5,984.29 -6,327.66 -5,365.04 5,937,823.92 524,632.47 2.54 6,511.04 MWD+IFR-AK-CAZ-SC(6) 11,852.95 86.30 179.15 6,123.66 5,991.15 -6,420.89 -5,362.71 5,937,730.71 524,635.17 1.64 6,604.14 MWD+IFR-AK-CAZ-SC(6) 11,948.41 86.48 178.95 6,129.67 5,997.16 -6,516.15 -5,361.13 5,937,635.46 524,637.13 0.28 6,699.28 MWD+IFR-AK-CAZ-SC(6) 12,043.07 85.35 179.21 6,136.41 6,003.90 -6,610.55 -5,359.62 5,937,541.07 524,639.02 1.22 6,793.58 MWD+IFR-AK-CAZ-SC(6) 12,136.85 88.89 180.29 6,141.12 6,008.61 -6,704.20 -5,359.21 5,937,447.44 524,639.80 3.95 6,887.15 MWD+IFR-AK-CAZ-SC(6) 12,231.93 90.72 178.93 6,141.44 6,008.93 -6,799.27 -5,358.56 5,937,352.38 524,640.83 2.40 6,982.14 MWD+IFR-AK-CAZ-SC(6) 12,324.07 88.69 179.02 6,141.92 6,009.41 -6,891.39 -5,356.91 5,937,260.28 524,642.84 2.21 7,074.14 MWD+IFR-AK-CAZ-SC(6) 12,419.29 86.55 179.30 6,145.87 6,013.36 -6,986.51 -5,355.52 5,937,165.17 524,644.62 2.27 7,169.16 MWD+IFR-AK-CAZ-SC(6) 12,513.36 86.36 179.22 6,151.69 6,019.18 -7,080.39 -5,354.31 5,937,071.31 524,646.20 0.22 7,262.94 MWD+IFR-AK-CAZ-SC(6) 12,608.27 86.47 179.72 6,157.62 6,025.11 -7,175.11 -5,353.43 5,936,976.60 524,647.45 0.54 7,357.57 MWD+IFR-AK-CAZ-SC(6) 12,701.64 88.95 178.23 6,161.35 6,028.84 -7,268.38 -5,351.76 5,936,883.35 524,649.50 3.10 7,450.73 MWD+IFR-AK-CAZ-SC(6) 12,796.45 90.14 175.98 6,162.11 6,029.60 -7,363.06 -5,346.97 5,936,788.70 524,654.66 2.68 7,545.18 MWD+IFR-AK-CAZ-SC(6) , 12,889.73 90.73 175.15 6,161.40 6,028.89 -7,456.06 -5,339.76 5,936,695.74 524,662.24 1.09 7,637.87 MWD+IFR-AK-CAZ-SC(6) 12,984.47 90.84 175.26 6,160.10 6,027.59 -7,550.46 -5,331.84 5,936,601.38 524,670.54 0.16 7,731.94 MWD+IFR-AK-CAZ-SC(6) 13,079.04 89.96 174.94 6,159.44 6,026.93 -7,644.68 -5,323.76 5,936,507.20 524,678.99 0.99 7,825.82 MWD+IFR-AK-CAZ-SC(6) 13,173.48 89.23 174.10 6,160.11 6,027.60 -7,738.68 -5,314.75 5,936,413.24 524,688.38 1.18 7,919.45 MWD+IFR-AK-CAZ-SC(6) 13,268.34 89.21 174.22 6,161.40 6,028.89 -7,833.04 -5,305.09 5,936,318.93 524,698.40 0.13 8,013.42 MWD+IFR-AK-CAZ-SC(6) 13,362.75 89.19 173.84 6,162.72 6,030.21 -7,926.93 -5,295.28 5,936,225.09 524,708.59 0.40 8,106.91 MWD+IFR-AK-CAZ-SC(6) 13,456.85 90.67 174.70 6,162.83 6,030.32 -8,020.56 -5,285.88 5,936,131.52 524,718.36 1.82 8,200.15 MWD+IFR-AK-CAZ-SC(6) , 13,551.60 91.05 175.39 6,161.41 6,028.90 -8,114.94 -5,277.70 5,936,037.17 524,726.92 0.83 8,294.19 MWD+IFR-AK-CAZ-SC(6) 13,645.80 90.03 174.99 6,160.52 6,028.01 -8,208.80 -5,269.80 5,935,943.35 524,735.19 1.16 8,387.72 MWD+IFR-AK-CAZ-SC(6) 13,740.81 88.94 175.52 6,161.38 6,028.87 -8,303.48 -5,261.94 5,935,848.72 524,743.42 1.28 8,482.06 MWD+IFR-AK-CAZ-SC(6) 13,836.50 87.43 175.23 6,164.41 6,031.90 -8,398.81 -5,254.23 5,935,753.43 524,751.51 1.61 8,577.07 MWD+IFR-AK-CAZ-SC(6) 13,931.63 88.63 176.69 6,167.68 6,035.17 -8,493.64 -5,247.53 5,935,658.63 524,758.59 1.99 8,671.61 MWD+IFR-AK-CAZ-SC(6) 14,026.15 89.53 177.99 6,169.20 6,036.69 -8,588.05 -5,243.15 5,935,564.26 524,763.35 1.67 8,765.80 MWD+IFR-AK-CAZ-SC(6) 14,119.57 87.72 178.63 6,171.44 6,038.93 -8,681.40 -5,240.39 5,935,470.93 524,766.48 2.05 8,858.99 MWD+IFR-AK-CAZ-SC(6) 14,214.33 86.13 179.96 6,176.52 6,044.01 -8,776.01 -5,239.23 5,935,376.33 524,768.02 2.19 8,953.51 MWD+IFR-AK-CAZ-SC(6) 14,310.01 86.18 180.25 6,182.94 6,050.43 -8,871.47 -5,239.40 5,935,280.88 524,768.22 0.31 9,048.92 MWD+IFR-AK-CAZ-SC(6) 14,404.10 86.71 179.75 6,188.77 6,056.26 -8,965.38 -5,239.40 5,935,186.98 524,768.60 0.77 9,142.77 MWD+IFR-AK-CAZ-SC(6) 14,499.05 86.35 178.43 6,194.52 6,062.01 -9,060.14 -5,237.90 5,935,092.23 524,770.48 1.44 9,237.42 MWD+IFR-AK-CAZ-SC(6) 9/2/2014 5.05:50PM Page 6 COMPASS 5000.1 Build 65 • ' • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,593.86 86.81 177.95 6,200.17 6,067.66 -9,154.73 -5,234.91 5,934,997.66 524,773.84 0.70 9,331.85 MWD+IFR-AK-CAZ-SC(6) 14,687.81 89.33 178.71 6,203.34 6,070.83 -9,248.58 -5,232.17 5,934,903.84 524,776.95 2.80 9,425.55 MWD+IFR-AK-CAZ-SC(6) 14,781.39 88.85 178.56 6,204.82 6,072.31 -9,342.12 -5,229.94 5,934,810.31 524,779.55 0.54 9,518.96 MWD+IFR-AK-CAZ-SC(6) 14,876.07 88.87 178.29 6,206.71 6,074.20 -9,436.75 -5,227.34 5,934,715.71 524,782.53 0.29 9,613.43 MWD+IFR-AK-CAZ-SC(6) 14,971.08 88.42 178.80 6,208.95 6,076.44 -9,531.70 -5,224.93 5,934,620.78 524,785.32 0.72 9,708.24 MWD+IFR-AK-CAZ-SC(6) 15,065.28 90.69 179.79 6,209.69 6,077.18 -9,625.89 -5,223.77 5,934,526.61 524,786.85 2.63 9,802.33 MWD+IFR-AK-CAZ-SC(6) 15,160.27 90.74 179.31 6,208.50 6,075.99 -9,720.86 -5,223.02 5,934,431.64 524,787.98 0.51 9,897.22 MWD+IFR-AK-CAZ-SC(6) 15,255.23 89.55 177.27 6,208.26 6,075.75 -9,815.78 -5,220.19 5,934,336.75 524,791.19 2.49 9,991.98 MWD+IFR-AK-CAZ-SC(6) 15,349.41 86.49 175.11 6,211.51 6,079.00 -9,909.67 -5,213.94 5,934,242.89 524,797.81 3.98 10,085.60 MWD+IFR-AK-CAZ-SC(6) 15,444.36 87.20 176.01 6,216.74 6,084.23 -10,004.19 -5,206.60 5,934,148.41 524,805.53 1.21 10,179.81 MWD+IFR-AK-CAZ-SC(6) 15,538.36 86.73 175.48 6,221.72 6,089.21 -10,097.80 -5,199.64 5,934,054.84 524,812.86 0.75 10,273.12 MWD+IFR-AK-CAZ-SC(6) 15,633.93 86.68 176.10 6,227.21 6,094.70 -10,192.96 -5,192.63 5,933,959.72 524,820.25 0.65 10,367.97 MWD+IFR-AK-CAZ-SC(6) 15,728.40 88.50 178.00 6,231.18 6,098.67 -10,287.21 -5,187.78 5,933,865.50 524,825.48 2.78 10,461.99 MWD+IFR-AK-CAZ-SC(6) 15,823.47 91.69 180.68 6,231.03 6,098.52 -10,382.25 -5,186.68 5,933,770.47 524,826.95 4.38 10,556.94 MWD+IFR-AK-CAZ-SC(6) 15,918.42 92.05 181.37 6,227.93 6,095.42 -10,477.14 -5,188.38 5,933,675.59 524,825.63 0.82 10,651.83 MWD+IFR-AK-CAZ-SC(6) 16,012.97 90.79 180.66 6,225.58 6,093.07 -10,571.64 -5,190.05 5,933,581.09 524,824.33 1.53 10,746.33 MWD+IFR-AK-CAZ-SC(6) 16,107.61 89.40 180.29 6,225.43 6,092.92 -10,666.27 -5,190.84 5,933,486.46 524,823.92 1.52 10,840.93 MWD+IFR-AK-CAZ-SC(6) 16,203.00 87.02 179.14 6,228.41 6,095.90 -10,761.61 -5,190.36 5,933,391.14 524,824.78 2.77 10,936.19 MWD+IFR-AK-CAZ-SC(6) 16,296.92 87.20 178.92 6,233.14 6,100.63 -10,855.39 -5,188.78 5,933,297.37 524,826.74 0.30 11,029.87 MWD+IFR-AK-CAZ-SC(6) 16,390.88 88.92 179.79 6,236.32 6,103.81 -10,949.29 -5,187.72 5,933,203.49 524,828.17 2.05 11,123.67 MWD+IFR-AK-CAZ-SC(6) 16,485.70 89.13 180.99 6,237.94 6,105.43 -11,044.09 -5,188.36 5,933,108.69 524,827.90 1.28 11,218.44 MWD+IFR-AK-CAZ-SC(6) 16,578.75 89.89 181.16 6,238.73 6,106.22 -11,137.12 -5,190.11 5,933,015.67 524,826.52 0.84 11,311.47 MWD+IFR-AK-CAZ-SC(6) 16,672.43 88.60 181.36 6,239.97 6,107.46 -11,230.77 -5,192.17 5,932,922.02 524,824.84 1.39 11,405.13 MWD+IFR-AK-CAZ-SC(6) 16,767.75 88.52 181.53 6,242.36 6,109.85 -11,326.03 -5,194.57 5,932,826.76 524,822.81 0.20 11,500.42 MWD+IFR-AK-CAZ-SC(6) 16,862.47 88.59 183.01 6,244.75 6,112.24 -11,420.64 -5,198.32 5,932,732.14 524,819.44 1.56 11,595.10 MWD+IFR-AK-CAZ-SC(6) 16,956.77 88.53 184.00 6,247.12 6,114.61 -11,514.73 -5,204.09 5,932,638.04 524,814.05 1.05 11,689.34 MWD+IFR-AK-CAZ-SC(6) 17,052.11 88.07 183.65 6,249.95 6,117.44 -11,609.82 -5,210.44 5,932,542.94 524,808.07 0.61 11,784.59 MWD+IFR-AK-CAZ-SC(6) 17,146.85 88.66 183.99 6,252.65 6,120.14 -11,704.31 -5,216.75 5,932,448.43 524,802.14 0.72 11,879.24 MWD+IFR-AK-CAZ-SC(6) 17,241.56 87.51 183.99 6,255.82 6,123.31 -11,798.74 -5,223.34 5,932,353.99 524,795.93 1.21 11,973.84 MWD+IFR-AK-CAZ-SC(6) 17,336.41 87.61 183.14 6,259.86 6,127.35 -11,893.32 -5,229.23 5,932,259.40 524,790.42 0.90 12,068.57 MWD+IFR-AK-CAZ-SC(6) 17,431.77 89.48 183.13 6,262.28 6,129.77 -11,988.50 -5,234.44 5,932,164.20 524,785.58 1.96 12,163.88 MWD+IFR-AK-CAZ-SC(6) 17,525.78 89.22 183.06 6,263.34 6,130.83 -12,082.37 -5,239.52 5,932,070.33 524,780.88 0.29 12,257.86 MWD+IFR-AK-CAZ-SC(6) 17,572.07 89.91 183.96 6,263.69 6,131.18 -12,128.57 -5,242.35 5,932,024.12 524,778.23 2.45 12,304.13 MWD+IFR-AK-CAZ-SC(6) 17,635.00 89.91 183.96 6,263.79 6,131.28 -12,191.35 -5,246.70 5,931,961.33 524,774.14 0.00 12,367.03 PROJECTED to TD 4-1/2"x 6-3/4" 17,652.00 89.91 183.96 6,263.82 6,131.31 -12,208.31 -5,247.87 5,931,944.37 524,773.03 0.00 12,384.02 PROJECTED to TD 9/2/2014 5:05:50PM Page 7 COMPASS 5000.1 Build 65 r nLE o w o o 0 0 0 o V _ m T ''� ca a � CD � XI .0 WOO v oza = gao CtS O c V 0 o N O Q CD O a OI d a) �, 1 IO C i a) •Q 0 O =V J z E ai O a) r O 4- (q > .- O N +- C 1 d c 0 O O C r..0w 11 w 3 w o o d 2 5 1 C .. ate . 73 C U =u) a a ,_ a u- a) aa) u) 0 0 (T) u. V. 000E Q co w 0 CO N 0 Q N CL C N 0 2_14-b"T‘, ZS�cc1 SchlumbergerDrilling & Measurements Transmittal #: 13NOV14-NG05 DATA LOGGED MWD/LWD Log Product Delivery c1/2o14 K.BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2E-02 Date Dispatched: 13-Nov-14 Job#: 14AKA0150 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A TOC Top of Cement x x RECEIVED NOV 13 2014 OC LAS Digital Data N/A Contents on CD N/A x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: PDF x Please sign and email a copy to: Please sign and email/fax a copy to: catherine.Roso@Conocophilips.com AlaskaPTSPrintCenterslb.com Cathaerine Roso Attn: Nathan Green Fax: 907-561-8317 Received By: RECEIVED STATE OF ALASKA SEP 2 4 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANW1 GCC ta.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑✓ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service Q Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 2e 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August.2014 214-078/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 July 30,2014 50-029-23517-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 530'FSL, 160'FWL,Sec.36,T11N, RO9E, UM August 18,2014 tat.` 2E-02 Top of Productive Horizon: 8.KB(ft above MSL): 132.5'RKB 15.Field/Pool(s): FNL, FEL,Sec.2,T10N, RO9E, UM GL(ft above MSL): 105'AMSL Kuparuk River Field Total Depth: 1121'FNL, 183'FWL,Sec. 14,T1 ON, RO9E,UM 9.Plug Back Depth(MD+ND): 17635'MD/6264'TVD Kuparuk Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-529972 y- 5944172 Zone-4 17652'MD/6264'TVD ADL 25658,25665,25670 • TPI: x- y- Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-524773 y- 5931944 Zone-4 nipple @ 540'MD/540'TVD 2584,2586,2179 18.Directional Survey: Yes 0 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1509'MD/1487'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,stethoscope,Neutron/Density not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD ' SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE \NT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# 11-40 28' 110' 28' 110' 24" pre-installed 10.75" 45.5# L-80 28' 4142' 28' _ 3241' 13.5" 1754 sx ALC,225 sx LiteCRETE 7.625" 29.7# L-80 25' 10053' 25' 6094' 9.875" 387 sx Class G 4.5" 11.6# L-80 9873' 17635' 6069' 6264' 6.75" open hole slotted liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5' 9917' 9872'MD/6069'TVD slots from 9927'-11441'MD 6076'-6107'TVD slots from 11643'-12302'MD 6110'-6142'TVDLET) 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. slots from 12546'-15572'MD 6154'-6224'TVD Was hydraulic fracturing used during completion? Yes No Q slots from 15772'-16138'MD 6232'-6226'TVD i 11124314 I DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED slots from 16340'-17623'MD 6235'-6264'TVD 1 ......MED i 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility tie-in Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE ABC MS OCT - 1 2014 Form 10-407 Revised 10/2012 1/7--c. 3/7 7//� CONT��ON REVERSE 14 3I I� Submit original only G 29 GEOLOGIC MARKERS(List all formations and ma ncountered): 30. FORMATION TESTS NAME MD TVD Well tested? E 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 1509' 1487' needed,and submit detailed test information per 20 AAC 25.071 Top Kuparuk C4 9631' 6040' Kuparuk A5 10039' 6090' eVr—w.-/ y//g M Cary&JG �jjryy��7f'�6vLQ Alt/. $ bt 6.-S, 4/2,f1S N/A Formation at total depth. Kuparuk A5 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey,cement detail sheets 32 I hereby certify that the foregoing is true and correct to the best of my knowledge i Contact: Lindsey Hunter @ 263-6427 Email Lindsey.Hunter C!conocophillips.com Printed Name G.L.Alvord JO C.I�N Title Alaska Drilling Manager Signature Phone 265-6120 Date Cf/L i/ 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 KUP SVC 2E-02 ConocoPhillips =91, , Well Attributes kMax Angle&MD TD Alaska IncWellbore APIUWWellbornI Field Name WellboStatus ncl(') MD(ftKB) Act Rho(ftKB) 500292351700 KUPARUK RIVER UNIT SVC 17,635.0 --" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 2E-02,9/22/2014 10:25.44 AM SSSV: NIPPLE Last WO: 27.40 824/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL haggea 9/17/2014 casing Sings HANGER;24.3- 1m;-f. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 1703/4 9.950 27.6 4,141.5 3,240.8 45.50 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' I INTERMEDIATE 5/8 6.875 25.2 10,053.2 6,093.5 29.70 L-80 W563 i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Ji LINER 41/2 3.958 9,872.7 17,635.0 6,263.8 11.60 L-80 H563 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl("I Item Des Com (in) 9,872.6 6,068.8 82.43 PACKER BAKER LINER TOP PACKER ZXPw/HRDE profile, 5.750 ti 9,892.6 6,071.5 82.33 NIPPLE BAKER RS NIPPLE 4.880 NIPPLE,540.8 OM 9,8954 6,071.9 82.32 HANGER BAKER FLEX LOCK LINER HANGER 4.880 9,906.9 6,073.4 82.26 SBR BAKER 80-40 SEAL BORE 4.000 11,451.3 6,107.4 89.20 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;3,049.2 PACKER 11,614.5 6,109.4 88.64 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER 12,312.6 6,141.7 88.94 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER 12,518.3 6,152.0 86.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 SURFACE;27.64.141 5 PACKER a 15,582.4 6,224.2 86.71 SWELL PACKER Freecap I FSC-11 6.38"OD Swell Packer 3.958 GAS LIFT;4,882.3 • a 15,744.6 6,231.5 89.04 SWELL PACKER Freecap I FSC-11 6.38"OD Swell Packer 3.958 16,148.7 6,226.2 88.37 SWELL Freecap I FSC-11 6.38"OD Swell Packer 3.958 PACKER GAS LIFT,6,229.4 16 312.3 6,233.9 87.48 SWELL Freecap I FSC 11 6.38"OD Swell Packer 3.958 PACKER Tubing Strings GAS LIFT,7,231 8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 4 1/2 x 3 1/2 3 1/2 2.992 24.3 9,917.3 6,074.8 9.30 L-80 EUE 8rd a @ 59.5 I Completion Details Nominal ID GAS LIFT;7,921.9 g- Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com ON 24.3 24.3 0.00 HANGER CIW 41/2"TUBING HANGER 3.910 1.B 59.5 59.5 0.05 X0 Reducing X0,2',4-1/2"L-80 IBTM bx x 3-1/2"L-80 EUE 8RD-Mod 2.937 pin NIPPLE;8,3299 540.8 540.8 0.18 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875' CSA-2 Plug.8,329.9, • 8,329.9 5,695.9 68.90 NIPPLE HES LANDING NIPPLE DS-Profile w/RHC Plug installed 2.812 9,896.6 6,072.0 82.31 LOCATOR BAKER LOCATOR 2.940 9,897.8 6,072.2 82.31 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY w/12' 2.990 of seals Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LOCATOR;9,896 6 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) I 8,329.9 5,695.9 68.90 CSA-2 Plug Slick line set CSA plug in DS nipple @ 8329.94 '8/23/2014 0.000 SEAL ASSY;9.897.8 Perforations&Slots i Shot aDens Top(TVD) Btm(ND) (shotstt Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com i r 9,927.1 11,441.5 6,076.1 6,107.3 8/20/2014 SLOTS Slotted Liner L 11,642.6 12,302.7 6,110.2 6,141.5 8/20/2014 SLOTS Slotted Liner INTERMEDIATE;25.2-10.053.2 , 12,546.5 15,572.6 6,153.8 6,223.7 8/20/2014 SLOTS Slotted Liner SLOTS,9,927.1-11,441.5- 15,772.8 16,138.9 6,231.8 6,226.0 8/20/2014 SLOTS Slotted Liner 16,340.6 17,623.9 6,235.0 6,263.8 8/20/2014 SLOTS Slotted Liner Mandrel Inserts St an N Top(ND) Valve Latch Port Size TRO Run SLOTS;11,642612.302.7---. _ Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com f 3,049.3 2,605.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/18/2014 2 4,882.3 3,689.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/18/2014 3 6,229.4 4,503.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/18/2014 _ 4 7,231.8 5,108.5 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 8/18/2014 •._---•_.• 5 7,921.9 5,510.5 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 2,500.0 8/18/2014 OCR- _ 1 SLOTS,12,546.5.15,572.6 _ Notes:General Safety &Saf End Date ���7 Annotation NOTE: I SLOTS,15,772.616,138.9 SLOTS',16,340.617,623.9 LINER;9,872.7.17,635.0 ConocoPhiIIips Time Log & Summary We"view Web Reporting Report Well Name: 2E-02 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 7/28/2014 10:00:00 PM Rig Release: 8/24/2014 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/28/2014 24 hr Summary Rig down and move off of 2E-03. Spot rig over 2E-02. Change out drilling line spool. Set new boiler stacks with crane. Complete rig acceptance check list. Nipple up diverter riser&hook up lines. Load shed with BHA. Take on spud mud&water. 03:00 07:30 4.50 0 0 MIRU MOVE DMOB P PJSM PREP RIG F/RIG MOVE. 07:30 08:15 0.75 0 0 MIRU MOVE DMOB T WAIT ON PEAK TRUCKS. 08:15 10:00 1.75 0 0 MIRU MOVE MOB P PJSM W/PEAK DRIVERS MOVE POWER PACK, ROCK WASHER AND PIPE SHEDS. SET MATS TO CRAB SUB BASE TO 2E-02. 10:00 10:30 0.50 0 0 MIRU MOVE MOB P MOVE SUB OFF WELL 2E-03. 10:30 11:30 1.00 0 0 MIRU MOVE MOB P PREP WELL 2E-02 F/SUB. 11:30 13:30 2.00 0 0 MIRU MOVE MOB P POSITION SUB&SPOT OVER 2E-02. 13:30 15:30 2.00 0 0 MIRU MOVE SVRG P REMOVE DRILLING LINE SPOOL. 15:30 17:30 2.00 0 0 MIRU MOVE MOB P SPOT PITS, PUMPS, MOTORS, AND BOILERS MODULES. 17:30 18:15 0.75 0 0 MIRU MOVE SVRG P INSTALL NEW DRILLING LINE SPOOL. 18:15 19:15 1.00 0 0 MIRU MOVE MOB P LAY MATS&SPOT PIPE SHEDS. 19:15 20:15 1.00 0 0 MIRU MOVE SVRG P INSTALL NEW STACKS FOR BOILERS W/CRANE. 20:15 20:45 0.50 0 0 MIRU MOVE MOB P SPOT ROCKWASHER MODULE. 20:45 22:00 1.25 0 0 MIRU MOVE MOB P WORK ON RIG ACCEPTANCE CHECK LIST. ACCEPTED RIG @ 22:00 HRS 22:00 23:15 1.25 0 0 MIRU MOVE RURD P PJSM, N/U RISER, HOOK UP BOPE LINES,AND INSTALL TURNBUCKLES ON ANNULAR. 23:15 00:00 0.75 0 0 MIRU MOVE RURD P PJSM, LOAD SHED W/BHA,TAKE ON WATER AND MUD IN PITS. 07/29/2014 Change to 5"handling equipment. Load&strap DP in shed. P/U DP and stand back in derrick. Perform diverter test w/AOGCC Rep. P/U&stand back HWDP. Pre-spud derrick inspection. Change out high psi shock hose from mud pumps. Perform diverter drill. 00:00 02:00 2.00 0 0 MIRU MOVE SVRG P Change out XT39 saver sub,to 4.5" IF on TD. 02:00 04:00 2.00 0 0 MIRU MOVE RURD P Load&strap 5"DP in pipe shed. 04:00 06:45 2.75 0 0 MIRU MOVE PULD P Pick up of 5"DP and rack back in derrick. Page 1 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:45 1.00 0 0 MIRU MOVE BOPE P Function test diverter,test gas alarms,test pit level alarms& accumulator draw down test. Initial system psi 3000 psi; psi after closure 1800 psi;time to attain 200 psi 40 sec;full psi attained in 180 sec. 5 back up bottles of nitrogen averaged 1900 psi.Test witnessed by AOGCC rep. John Crisp. 07:45 09:45 2.00 0 0 MIRU MOVE PULD P Finish picking up 5"DP,45 total stands. 09:45 11:00 1.25 0 0 MIRU MOVE PULD P Strap and measure HWDP and Jar. Pick up and stand back 17 jts. HWDP and jar. 11:00 11:15 0.25 0 0 MIRU MOVE RURD P Pull mousehole and clear rig floor 11:15 12:30 1.25 0 0 MIRU MOVE PULD P Mobilize BHA tools to rig floor. 12:30 13:30 1.00 0 0 MIRU MOVE PULD P Make up BHA. Bit,mud motor and stabilizer 13:30 14:30 1.00 0 0 MIRU MOVE SVRG T Rig up and attempt pressure test HP mud lines to 5000 psi/10 min. 14:30 15:30 1.00 0 0 MIRU MOVE SVRG P Service rig. 15:30 17:00 1.50 0 0 MIRU MOVE SVRG P Pre-spud derrick inspection. 17:00 22:30 5.50 0 0 MIRU MOVE RGRP T Change out high pressure mud line from pumps. 22:30 23:15 0.75 0 0 MIRU MOVE SFTY P Pre-spud meeting. 23:15 23:30 0.25 0 0 MIRU MOVE SFTY T Diverter drill evacuate rig to muster area. CRT=240 sec 23:30 00:00 0.50 0 0 MIRU MOVE SVRG P Rig up to test high pressure mud lines. 07/30/2014 Pressure test HP mud lines. Hold pre-spud&diverter drill. Flood lines&clean out conductor with BHA#1. Lay down BHA#1. Rig up Gyro&MU BHA#2.TIH to 221' MD. Drill ahead from 221'-838'MD. 00:00 01:00 1.00 0 0 MIRU MOVE PRTS P Test HP mud lines to 5000 psi. 01:00 01:30 0.50 0 0 MIRU MOVE SFTY P Pre-spud meeting. 01:30 02:00 0.50 0 0 MIRU MOVE SFTY P Diverter drill evacuate rig to muster area. CRT=205 sec 02:00 02:45 0.75 0 0 MIRU MOVE RURD T Fill conductor w/water.4"conductor valve leaking. Drain riser and change out valve. 02:45 03:30 0.75 0 110 MIRU MOVE REAM P Fill conductor w/water.Tag fill @37' MD. Clean out conductor from 37' MD to 110'MD.415 gpm.400 psi. Displace with Drilplex mud. 03:30 05:30 2.00 110 221 SURFA( DRILL DRLG P DrIg. from 110'MD to 221'MD. 6-7K WOB. 50 RPM,2K Tq.. 375 GPM. 300 psi. P/U=40k S/O=40k Rot=40K.ART=1.5,ADT=1.5, 05:30 06:00 0.50 221 37 SURFA( DRILL TRIP P POOH from 221'MD to 37'MD. 06:00 06:30 0.50 37 37 SURFA( DRILL RURD P Pick up SLB tools and rig up Gyro. 06:30 09:15 2.75 37 180 SURFA( DRILL PULD P Make up BHA#2. Pulse test MWD. as per SLB Page 2 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:30 0.25 180 221 SURFA( DRILL REAM P Wash and ream from 180' MD to 221' MD. 09:30 12:00 2.50 221 346 SURFA( DRILL DDRL P Drlg. from 221' MD to 346' MD. TVD=346'. ART=1.85,ADT=1.85 Total jar hrs.=79.13 Bit hrs.=3.35 P/U=52K, S/0=54K Rot=54K.. Tq on=2K. Tq off=1K, ECD=10.70, Flow out=50%,WOB=10-15K, RPM=70, GPM=535, SPM=126, 550 PSI. Gyro each connection 12:00 18:00 6.00 346 649 SURFA( DRILL DDRL P Drlg. from 346' MD to 649' MD. TVD=649'. ART=1.80, AST=2.36, ADT=4.16 Total jar hrs.=85.92. Bit hrs.=7.51 P/U=67K, 5/0=70K Rot=70K.. Tq on=2-3K. Tq off=1K, ECD=10.12, Flow out=82%, WOB=15-20K, RPM=70, GPM=535, SPM=126, 700 PSI. Gyro each connection 18:00 00:00 6.00 649 838 SURFA( DRILL DDRL P Drlg. from 649' MD to 838' MD. TVD=838'.ART=0, AST=3.38, ADT=3.38 Total jar hrs.=85.92. Bit hrs.=10.89 P/U=72K, S/0=75K Rot=74K.. Tq on=2-3K. Tq off=1 K, ECD=10.04, Flow out=75%, WOB=20-25K, RPM=Slideing, GPM=550, SPM=130, 750 PSI. Gyro each connection 07/31/2014 Directional drill from 838'- 1826' MD. 00:00 06:00 6.00 838 1,003 SURFA( DRILL DDRL P Directional drilled from 838'-1003' MD, TVD=1002', ART=0, AST=4.88, ADT=4.88,Total jar hrs.=91.45, Bit hrs.=15.77, P/U=74K, S/0=76K, Rot=74K, Tq on=OK, Tq off=OK, ECD=10.0, Flow out=74%, WOB=25-30K, RPM=Slideing, GPM=522, SPM=123, 810 PSI. Gyro each connection. Fire Drill CRT= 135 sec @ 03:45 hrs. 06:00 12:00 6.00 1,003 1,205 SURFA( DRILL DDRL P Directional drilled from 1003'-1205' MD, TVD=1199',ART=0,AST=4.32, ADT=4.32, Total jar hrs.=95.77, Bit hrs.=20.09, P/U=79K, 5/0=80K, Rot=79K, Tq on=OK.Tq off=OK, ECD=9.82, Flow out=74%, WOB=25-35K, RPM=Slideing, GPM=525, SPM=123, 820 PSI. Gyro each connection. Page 3 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 1,205 1,455 SURFA( DRILL DDRL P Directional drilled from 1205'-11455' MD, TVD=1435',ART=.8,AST=2.11, ADT=2.91,Total jar hrs.=94.36, Bit hrs.=23, P/U=85K, S/0=73K, Rot=74K, Tq on=2-5K, Tq off=2-3K, ECD=9.96, Flow out=84%, WOB=25-30K, RPM=70, GPM=550, SPM=130, 1100 PSI. Last gyro survey at 1200' MD. 18:00 00:00 6.00 1,455 1,826 SURFA( DRILL DDRL P Directional drilled from 1455'-1826' MD, TVD=1774'.ART=.79, AST=2.18,ADT=2.97, Total jar hrs.=97.33, Bit hrs.=25.97, P/U=93K, S/0=84K, Rot=89K, Tq on=4-7K, Tq off=1-5K, ECD=9.85, Flow out=84%, WOB=10-15K, RPM=70, GPM=590, SPM=140, 1050 PSI. Spill Drill CRT=88 sec @ 18:30 Hrs. 08/01/2014 Directional drill from 1826'-3237' MD, 2713'TVD. 00:00 06:00 6.00 1,826 2,132 SURFA( DRILL DDRL P Directional drilled from 1826'-2132' MD, TVD=2021'.ART=.76, AST=2.03,ADT=2.79, Total jar hrs.=100.12, Bit hrs.=28.76, P/U=99K, S/O=85K, Rot=92K, Tq on=4-7K, Tq off=3-5K, ECD=9.92, Flow out=68%,WOB=5-10K, RPM=70, GPM=600, SPM=138, 1090 PSI. • 06:00 12:00 6.00 2,132 2,502 SURFA( DRILL DDRL P Directional drilled from 2132'-2502' MD, TVD=2288'. ART=.64, AST=3.62, ADT=4.26, Total jar hrs.=104.38, Bit hrs.=32.92, P/U=100K, S/0=88K, Rot=95K, Tq on=4-5K, Tq off=3K, ECD=9.74, Flow out=84%, WOB=25-30K, RPM=70, GPM=600, SPM=140, 1050 PSI. 12:00 18:00 6.00 2,502 2,873 SURFA( DRILL DDRL P Directional drilled from 2052'-2873' MD, TVD=2507'. ART=2.04, AST=2.18, ADT=4.22, Total jar hrs.=108.60, Bit hrs.=37.14, P/U=106K, 5/O=85K, Rot=94K, Tq on=7-8K, Tq off=3-5K, ECD=10.10, Flow out=81%,WOB=15-17K, RPM=80, GPM=650, SPM=152, 1400 PSI. Page 4 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 2,873 3,237 SURFA( DRILL DDRL P Directional drilled from 2873'-3237' MD,TVD=2713'.ART=4.72,AST=0, ADT=4.72,Total jar hrs.=113.32, Bit hrs.=41.86, P/U=107K, S/0=89K, Rot=95K,Tq on=5-7K,Tq off=2-4K, ECD=10.31, Flow out=87%, WOB=20-25K, RPM=90, GPM=750, SPM=176, 1900 PSI. Pumped 2 lbs over weighted sweep with substantial increase in cuttings. 08/02/2014 Directional drill ahead as per well plan to TD @ 4151'MD. CBU 2 weighted sweeps around,till shakers cleaned up. BROOH to 1670' MD. 00:00 06:00 6.00 3,237 3,635 SURFA( DRILL DDRL P Directional drilled from 3237'-3635' MD,TVD=2950'.ART=3.82,AST=1, ADT=4.82,Total jar hrs.=118.14, Bit hrs.=46.68, P/U=112K, 5/0=92K, Rot=100K, Tq on=4-6K, Tq off=4-5K, ECD=10.36, Flow out=81%, WOB=10-15K, RPM=90, GPM=750, SPM=176, 1900 PSI. 06:00 12:00 6.00 3,635 3,985 SURFA( DRILL DDRL P Directional drilled from 3635'-3985' MD,TVD=3147'.ART=3.87, AST=.80,ADT=4.67,Total jar hrs.=122.81, Bit hrs.=51.35, P/U=117K, 5/0=96K, Rot=104K, Tq on=5-10K,Tq off=5-6K, ECD=10.16, Flow out=80%,WOB=15-20K, RPM=90, GPM=750, SPM=176, 2000 PSI. 12:00 14:15 2.25 3,985 4,151 SURFA( DRILL DDRL P Directional drilled from 3985'-4151' MD,TVD=3246'.ART=2.36,AST=0, ADT=2.36,Total jar hrs.=124.15, Bit hrs.=52.69, P/U=120K, 5/0=99K, Rot=106K, Tq on=5-7K, Tq off=4-5K, ECD=10.16, Flow out=80%, WOB=12-15K, RPM=90, GPM=750, SPM=176, 2050 PSI. 14:15 17:15 3.00 4,151 4,151 SURFA( CASING CIRC P Pump 11.3 ppg sweep,weight up system 9.4 to 9.6 ppg, pump 11.6 ppg sweep, &circulate till hole clean @ 750 gpm, 2050 psi, 80 rpm. 17:15 17:30 0.25 4,151 4,151 SURFA( CASING OWFF P Monitor well,static. 17:30 00:00 6.50 4,151 1,670 SURFA( CASING REAM P BROOH from 4151'-1670'MD, 730 gpm, 1950 psi, 80 rpm,Tq 4-5K, ream @ 800-1000 fph. Calculated fill 18.75, actual 52.7 bbls; large fill due to amount of cuttings from well bore. 08/03/2014 Finish BROOH from 1670'-745'MD. Pump out of hole and lay down BHA#2. Clear&clean rig floor. Rig up to run casing. Make dummy run with hanger. Run in hole w/10.75"casing as per detail,stopping at 1500'& 2800'to condition mud. 00:00 03:00 3.00 1,670 745 SURFA( CASING REAM P BROOH from 1670'-745' MD, 750 gpm, 1550 psi, 80 rpm, Tq 2-8K, ream @ 800-1000 fph. Monitor well. Static. Page 5 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 745 96 SURFA( CASING TRIP P Pump out of hole @ 3 bpm, 100 psi., from 745'MD to 96'MD. Stand back HWDP and NMFDC.Act. disp.= 105 bbl's. Calc. disp. =40 bbls 04:30 06:30 2.00 96 0 SURFA( CASING PULD P Lay down BHA 06:30 08:00 1.50 0 0 SURFA( CASING RURD P Clear and clean rig floor. Bring hydroform centralizers to rig floor. Lay down short bails. 08:00 10:30 2.50 0 0 SURFA( CASING RURD P Remove bell guide for TD. Install long bails 10:30 11:30 1.00 0 0 SURFA( CASING SEQP P Make dummy run w/Cameron csg. hanger 11:30 12:00 0.50 0 0 SURFA( CASING RURD P Rig up 350T slips and strap tong. 12:00 15:30 3.50 0 1,500 SURFA( CASING RNCS P Run 10.75", L-80, 45.5 lbs, H563, casing. Make up shoe, 2 jts, float collar,&36jts to 1500'MD. 15:30 16:30 1.00 1,500 1,500 SURFA( CASING CIRC P CBU staging up pumps from 2-5.5 bpm, 160 psi. 16:30 19:15 2.75 1,500 2,800 SURFA( CASING RNCS P TIH with 10.75"casing from 1500'-2800',fill every 5 jts, hyroform centrilizer every jt. 19:15 21:45 2.50 2,800 2,800 SURFA( CASING CIRC P Circulate&condition to get a 9,7 ppg mud through out system @ 2800' MD, stage up pumps 2-5.5 bpm, 150-260 psi. . 21:45 00:00 2.25 2,800 3,842 SURFA( CASING RNCS P TIH with 10.75"casing from 2800'-3842'MD, fill every 5 jts, hydroform centralizer every jt. PU 180K, SO 114K, calculated displacement 63, actual 17 bbls. 1 bow spring centralizer, 91 hydroforms, 5 stop rings. 08/04/2014 Continue RIH to 4141'MD. Circulate&condition mud. Cement as per program. N/D diverter system. N/U wellhead&BOPE 00:00 00:45 0.75 3,842 4,110 SURFA( CASING RNCS P TIH with 10.75"casing from 3842'-4110'MD, fill every 5jts. PU 190K, SO 112K, 00:45 01:30 0.75 4,110 4,141 SURFA( CASING RNCS P Make up hanger and landing jt. Break circ.and land csg.at 4141' MD. 3 bpm, 350 psi. PU=165K SO=110K. No fill. 01:30 03:00 1.50 4,141 4,141 SURFA( CEMEN-CIRC P CBU @ 4141'MD. Stage pump up to 6 bpm,400 psi. 03:00 04:00 1.00 4,141 4,141 SURFA( CEMEN-RURD P Rig down Tesco CRT. Rig up cement head. 04:00 07:00 3.00 4,141 4,141 SURFA( CEMEN CIRC P Circ. and cond. mud. Stage pump up to 6.5 bpm,500 psi. Reciprocate pipe. PU=190K SO=115K 07:00 10:00 3.00 4,141 4,141 SURFA( CEMEN-PUCM P Hold PJSM. Pump 5 bbl's H2O.Test lines to 4000 psi.. Pump 75 bbl. 10.5 ppg Mud Push spacer. Drop bottom plug. Batch up and pump 585.8 bbls. 11 ppg lead cmt. followed by 63.9 bbls 12 ppg.tail cmt. Kick top plug out with 10 bbls. H2O. Page 6 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 4,141 0 SURFA( CEMEN-DISP P Displace cmt.with rig pumps. 5 bpm, 600 psi. Bump plugs @ 3772 stks. Pressure up to 1100 psi. and hold for 5 min. 200 bbls cmt.to surface. Check floats. OK. Flush stack and flow line. CIP @ 11:38 hrs 12:00 13:30 1.50 0 0 SURFA( CEMEN'RURD P Rig down cement equip., landing jt. spiders and long bails 13:30 14:45 1.25 0 0 SURFA( CEMEN-NUND P Nipple down diverter line, knife valve. Pull and lay down riser 14:45 17:00 2.25 0 0 SURFA( CEMEN-NUND P De-energize WQ seals, back out LDS. Pull adapter spool and annular from conductor. Clean and remove from cellar. 17:00 17:45 0.75 0 0 SURFA( CEMEN-NUND P Nipple up Cameron well head 17:45 19:00 1.25 0 0 SURFA( CEMEN-OTHR T Evacuate rig due to hot oil truck fire on pad. 19:00 19:15 0.25 0 0 SURFA( CEMEN-NUND P Continue to nipple up Cameron well head..Test seals to 250/5000 psi for 10 min. 19:15 21:30 2.25 0 0 SURFA( WHDBO NUND P Install new adapter flange, nipple up BOPE. Lengthen riser. 21:30 22:15 0.75 0 0 SURFA( CEMEN-RURD P Install TD bell guide,elevators and bails 22:15 23:00 0.75 0 0 SURFA(WHDBO RURD P Strap pipe in shed,and continue to load shed. Lay down tools from rig floor, pick up test plug and wear bushing from slide 23:00 00:00 1.00 0 0 SURFA(WHDBO NUND P Install riser, grease choke manifold. Rig up to test BOPE 08/05/2014 Test BOPE. Pick up DP. Make up BHA.TIH.Test casing.Wash down and tag float collar at 4057', begin drilling float equipment. 00:00 01:30 1.50 0 0 SURFA( WHDBO RURD P PJSM, set test plug per Cameron rep. R/U test equipment. 01:30 05:45 4.25 0 0 SURFA(WHDBO BOPE P Test BOPE with 5"test joint,test all CV and Rams to 250/3500 psi, annular to 2500 psi. Tested Hydraulic super choke and manual super choke.Accumulator test system pressure=3000 psi, pressure after closing=1850 psi. 200 psi attained=44 sec, full pressure attained=193 sec. 5 bottle N2 average 2050 psi.John Crisp w/AOGCC waived witness of test. 05:45 07:00 1.25 0 0 SURFA( WHDBO RURD P R/D test equipment, Blow down choke and kill lines, set mouse hole. 07:00 07:30 0.50 0 0 SURFA( CEMEN-SEQP P Set 10"ID wear bushing, run in lock downs per Cameron rep. 07:30 11:30 4.00 0 0 SURFA( CEMEN-PULD P PJSM, P/U 5"Drill pipe via mouse hole, rack back in derrick 37 stands, L/D mousehole. 11:30 12:00 0.50 0 0 SURFA( CEMEN"RURD P Clean and clear rig floor, P/U BHA tools. 12:00 14:45 2.75 0 760 SURFA( CEMEN PULD P PJSM, P/U BHA#3 per SLB reps. Page 7 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:30 0.75 760 1,500 SURFA( CEMEN-PULD P PJSM, single in hole from 760'MD to 1500'MD. 15:30 15:45 0.25 1,500 1,500 SURFA( CEMEN'DHEQ P Shallow test MWD, pump 450 gpm @ 750 psi. 15:45 16:15 0.50 1,500 1,815 SURFA( CEMEN-PULD P Continue single in hole to 1815'MD. 16:15 16:45 0.50 1,815 1,815 SURFA( CEMEN'SVRG P Service topdrive and draw works. 16:45 17:45 1.00 1,815 1,815 SURFA( CEMEN-OTHR T Mobilize ghost reamer to rig 17:45 19:45 2.00 1,815 4,018 SURFA( CEMEN-PULD P P/U Ghost reamer and continue singling in hole to 4018'MD. 19:45 20:30 0.75 4,018 4,018 SURFA( CEMEN"CIRC P CBU @ 600 gpm, 1700 psi. 20:30 21:30 1.00 4,018 4,018 SURFA( CEMEN PRTS P PJSM, R/U and test casing to 3000 psi, 30 minutes on chart. 21:30 21:45 0.25 4,018 4,018 SURFA( CEMEN-RURD P Rig down test equipment. SPR's @ 4010'MD, 3190'TVD, MW 9.7+ #1-30 spm=160 psi,40 spm=220 psi #2-30 spm=160 psi,40 spm=210 psi P/U=135k, S/O=84k, ROT=103k. 21:45 00:00 2.25 4,018 4,057 SURFA( CEMEN-DRLG P Wash down from 4018'MD to 4057' MD @ 650 gpm 1600 psi,tag up on float collar @ 4057'. Drill on floats w/ 10-12 WOB, 50 rpm,8-10k TQ. 08/06/2014 Drill out floats, cement,shoe and 20'formation. Perform LOT to 14.5 ppg EMW. Displace to 9.5 ppg LSND and drill 9-7/8"hole per program to 5999' MD @ 150-200 fph, keeping ECD below 11.5 ppg EMW. 00:00 03:30 3.50 4,057 4,171 SURFA( CEMEN-DRLG P PJSM, Continue drilling out float equipment,shoe track and shoe to 4141', cent and formation to 4171' MD. Pumping 660 gpm @ 2100 psi, Ti60 rpm TQ=5-12k,WOB=5-15k. 03:30 04:30 1.00 4,171 4,17SURFA( CEMEN CIRC P Circulate and condition mud for FIT/LOT,660 gpm,2100 psi, 80 rpm, TQ=5-10k. 04:30 05:30 1.00 4,171 4,171 SURFA( CEMEN LOT P R/U test equipment and perform LOT to 14.5 ppg EMW. R/D test equipment. 05:30 06:00 0.50 4,171 4,171 INTRM1 DRILL SFTY P PJSM on displacing well to 9.5 ppg LSND and drilling 9-7/8"section parameters. Page 8 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 4,171 4,845 INTRM1 DRILL DDRL P Displace to 9.5 ppg LSND on the fly, drill from from 4171' MD to 4845' MD, 3667'TVD. P/U=123k, S/O=101k, ROT=111k, TQ on/off=8/4k, Flow out=77%,WOB=5-10k, 120 rpm, 700 gpm ©2200 psi. Max gas=55 units. ART=4.15, ADT=4.15, Jars=4.15, ECD=10.52 ppg EMW. SPR's @ 4135'MD, 3237'TVD, 9.5 ppg, 06:00 hrs #1-30 spm=170 psi, 40 spm=220 psi #2-30 spm=170 psi,40 spm=230 psi SPR's @ 4658'MD, 3572'TVD, 9.5 ppg, 10:30 hrs #1-30 spm=200 psi,40 spm=260 psi #2-30 spm=190 psi, 40 spm=250 psi 12:00 18:00 6.00 4,845 5,515 INTRM1 DRILL DDRL P Directional drill from 4845' MD to 5515' MD, 4085'TVD,ART=4.08, ADT=4.08,Total Jars hrs=8.23, Bit hrs, 8.23, P/U=134k, S/O=112k, ROT=122k, TQ on/off=8/3k, ECD=11.26 ppg, Flow Out=76%, WOB=6-9k, 140 rpm, 700 gpm @ 2300 psi, Max gas=35 units. SPR's @ 5217' MD, 4150 TVD, 9.6 ppg, 15:20 hrs #1-30 spm=230 psi,40 spm=280 psi #2-30 spm=210 psi,40 spm=270 psi 18:00 00:00 6.00 5,515 5,999 INTRM1 DRILL DDRL P Directional drill from 5515' MD to 5999' MD, 4367'TVD.ART=3.63, ADT=3.63,Total Jars hrs=11.86, Bit Hrs=11.86, P/U=140k, 5/O=112k, ROT=123k, TQ on/off=8/5k, ECD=11.0-11.36 ppg. Flow out=77%,WOB=5-10k, 160 rpm, 704 gpm @ 2450 psi, Max gas=147 units. Observed ECD waves every 30', down to 11.0 ppg, up to 11.5 with –50 psi pump pressure increase. Started backreaming full stands to reduce overall ECD at 5565'. ECD wave continued after ghost reamer out of casing shoe. SPR's @ 5771' MD,4224'TVD, 9.5 ppg, 21:00 hrs #1-30 spm=250 psi,40 spm=310 psi #2-30 spm=240 psi,40 spm=320 psi C._..._. — Page 9 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/07/2014 24 hr Summary Drill 9-7/8"intermediate per program to 8307' MD,weight up to 10.0 ppg©8,000' MD and treat for HRZ. Adjust backream time for ECD management as needed, maintaining below 11.5 ppg EMW. 00:00 06:00 6.00 5,999 6,604 INTRM1 DRILL DDRL P Directional drill from 5999' MD to 6604' MD, 4727'TVD.ART=4.38, ADT=4.38,Total jars Hrs=16.24, Bit Hrs=16.24, P/U=150k, S/O=115k, ROT=131k, TQ on/off=10/5k, ECD=11.03 ppg, Flow out=78%, WOB=8-14k, 160 rpm, 700 gpm @ 2600 psi. Max gas=65 units. Backreaming full stands to reduce ECD. SPR's @ 6323'MD,4558'TVD, 9.6 ppg, 03:15 hrs #1-30 spm=300 psi, 40 spm=390 psi. #2-30 spm=300 psi, 40 spm=380 psi. 06:00 12:00 6.00 6,604 7,160 INTRM1 DRILL DDRL P Directional drill from 6604' MD to 7160' MD, 5063'TVD.ART=3.64, ADT=3.64,Total jars Hrs=19.88, Bit Hrs=19.88, P/U=155k, S/O=125k, ROT=136k, TO on/off=12/5k, ECD=11.25 ppg, Flow out=78%, WOB=10-15k, 160 rpm, 700 gpm @ 2800 psi. Max gas=67 units. Backreaming 60'per stand. SPR's @ 7160' MD, 5063'TVD, 9.65 ppg, 11:45 hrs #1-30 spm=330 psi,40 spm=420 psi. #2-30 spm=330 psi,40 spm=410 psi. 12:00 18:00 6.00 7,160 7,809 INTRM1 DRILL DDRL P Directional drill from 7160' MD to 7809' MD, 5419'TVD. ART=4.18, ADT=4.18, Total jars Hrs=24.06, Bit Hrs=24.06, P/U=164k, S/0=130k, ROT=144k, TQ on/off=12/7k, ECD=11.45 ppg, Flow out=83%, WOB=11-12k, 160 rpm, 700 gpm @ 2975 psi. Max gas=72 units. Begin whole mud dilution to increase density to 10.0 ppg and reduce MBT. SPR's @ 7160' MD, 5063'TVD, 9.65 ppg, 11:45 hrs #1-30 spm=330 psi,40 spm=420 psi. #2-30 spm=330 psi,40 spm=410 psi. Page 10 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 7,809 8,307 INTRM1 DRILL DDRL P Directional drill from 7809'MD to 8307'MD, 5689'TVD.ART=3.44, ADT=3.44,Total jars Hrs=27.50, Bit Hrs=27.50, P/U=174k, S/O=129k, ROT=145k,TQ on/off=12/7k, ECD=11.25 ppg, Flow out=83%, WOB=8-10k, 150 rpm, 700 gpm @ 3075 psi. Max gas=979 units. SPR's @ 7900'MD, 5500'TVD, 10.1 ppg, 19:30 hrs #1-30 spm=360 psi,40 spm=450 psi. #2-30 spm=370 psi,40 spm=400 psi. 08/08/2014 Drill 9-7/8"intermediate to TD per DD and Geo, TD at 10,065'MD, 82°inc. Circulate 3 BU until shakers clean, OWFF and begin POOH pumping 2 bpm. Increase to 500 gpm due pulling into cuttings, no backreaming. 00:00 06:00 6.00 8,307 8,922 INTRM1 DRILL DDRL P Directional drill from 8307'MD to 8922'MD, 5874'TVD.ART=4.52, ADT=4.52,Total jar Hrs=32.02, Bit Hrs=32.02, P/U=175k, S/O=127k, ROT=145k, TQ on/off=12/7k, ECD=11.3 ppg, Flow out=66%, WOB=10-15k, 150 rpm, 700 gpm @ 3100 psi. Max gas=1100 units. SPR's @ 8458'MD, 5740'TVD, 10.05 ppg, 01:15 hrs #1-30 spm=310 psi,40 spm=390 psi. #2-30 spm=300 psi,40 spm=400 psi. 06:00 12:00 6.00 8,922 9,477 INTRM1 DRILL DDRL P Directional drill from 8922' MD to 9477' MD, 6016'TVD.ART=3.80, ADT=3.80,Total jar Hrs=35.62, Bit Hrs=35.62, P/U=181k, S/O=125k, ROT=145k, TQ on/off=17/8k, ECD=11.32 ppg, Flow out=66%, WOB=15-20k, 160 rpm, 700 gpm @ 3150 psi. Max gas=650 units. SPR's @ 9256'MD, 5978'TVD, 10.0 ppg, 11:30 hrs #1-30 spm=300 psi,40 spm=380 psi. #2-30 spm=290 psi,40 spm=380 psi. Page 11 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 9,477 10,032 INTRM1 DRILL DDRL P Directional drill from 9477' MD to 10,032' MD, 6087'TVD.ART=4.92, ADT=4.92, Total jar Hrs=40.54, Bit Hrs=40.54, P/U=187k, S/O=115k, ROT=144k, TQ on/off=15/10k, ECD=11.01 ppg, Flow out=66%, WOB=3-7k, 160 rpm, 700 gpm @ 3050 psi. Max gas=1050 units. SPR's @ 9662' MD, 6041'TVD, 10.05 ppg, 13:30 hrs #1-30 spm=310 psi, 40 spm=360 psi. #2-30 spm=300 psi,40 spm=400 psi. 18:00 19:15 1.25 10,032 10,065 INTRM1 DRILL DDRL P Directional drill from 10,032' MD to 10,065' MD, 6091'TVD.ART=.96, ADT= .96, Total jar Hrs=41.5, Bit Hrs=41.5, P/U=180k, 5/O=125k, ROT=140k, TQ on/off=14/9k, ECD=10.89 ppg, Flow out=66%, WOB=5-8k, 160 rpm, 700 gpm @ 3050 psi. Max gas=775 units. Backream stand and take SPR's on bottom. SPR's @ 10,065' MD, 6091'TVD, 10.1 ppg, 19:10 hrs #1-30 spm=280 psi,40 spm=380 psi. #2-30 spm=300 psi, 40 spm=370 psi. 19:15 21:45 2.50 10,065 9,755 INTRM1 CASING CIRC P Circulate 3 bottoms up until shakers clean, rotate 166 rpm, 710 gpm on upstroke, reduce to 130 rpm and 600 gpm on downstroke. Stand back a stand each BU to 9755' MD. 21:45 22:15 0.50 9,755 9,755 INTRM1 CASING OWFF P Monitor well, slight flow briefly to static to slight drop after 30 min. 22:15 00:00 1.75 9,755 8,833 INTRM1 CASING TRIP P Pump out of hole from 9755' MD @ 2 bpm, 250 psi 1200 fph. Observed drag and overpull at 9388' MD and loss of down weight. Increase pump rate to 500 gpm-1700 psi to move cuttings above BHA. Observed 25k overpull @ 9220'and 9134', RIH 30' and pulled through with no packing off. Continue pumping out at 500 gpm to 8833' MD. P/U=185k, S/O=115k, Calc Fill=5.6 bbl, Actual fill=11.65 bbl. 08/09/2014 Pump out from 8833' MD to 4107' MD surface shoe. CBU and POOH, L/D BHA. Change and test 7-5/8" rams. R/U and run 7-5/8"casing. 00:00 01:30 1.50 8,833 8,183 INTRM1 CASING TRIP P PJSM, Pump out of hole from 8833' MD to 8183'MD @ 500 gpm 1500 psi no problems. P/U=185k, S/O=125k, Calc Fill=9.51 bbl,Actual fill=17.23 bbl. Page 12 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 03:00 1.50 8,183 7,998 INTRM1 CASING CIRC P Circulate 2 bottoms up @ 8183'MD, stand back a stand after 1 BU. Pump @ 700 gpm 2800 psi, 150 rpm, TQ=10k,63% Flow out. Significant cutting returns at shakers. 03:00 05:15 2.25 7,998 6,800 INTRM1 CASING TRIP P Pump out of hole from 7998' MD to 6800'MD @ 5 bpm 500 psi. Observe minor packing off and drag at 6800'. P/U=165k, 5/0=110k. 05:15 06:30 1.25 6,800 6,710 INTRM1 CASING CIRC P Circulate 2 bottoms up at 6800'MD, stand back a stand after 1 BU. Pump @ 700 gpm 2650 psi, 150 rpm, TQ=8k,63%Flow out. Significant cutting returns at shakers. 06:30 10:30 4.00 6,710 4,107 INTRM1 CASING TRIP P Continue pumping out of hole from 6710'MD to 4107' MD, 5 bpm 450 psi. Calc Fi11=28 bbl,Actual Fill=58 bbl. 10:30 11:15 0.75 4,107 4,107 INTRM1 CASING CIRC P CBU @ 4107'MD 650 gpm 1950 psi, 80 rpm, 5k TQ. 11:15 11:45 0.50 4,107 4,107 INTRM1 CASING OWFF P Monitor well for flow-static. 11:45 12:00 0.25 4,107 4,107 INTRM1 CASING CIRC P Pump 30 bbl 12.5 ppg slug for dry pipe. 12:00 12:15 0.25 4,107 4,107 INTRM1 CASING RURD P Blow down top drive. 12:15 13:45 1.50 4,107 774 INTRM1 CASING TRIP P POOH from 4107'MD to 774'MD. Calc fill=27.3 bbl,Actual fill=31.62 bbl. 13:45 14:15 0.50 774 200 INTRM1 CASING TRIP P Rack back HWDP,Jars and L/D Well Commander. 14:15 16:15 2.00 200 0 INTRM1 CASING PULD P PJSM-(Handling nukes and L/D BHA)LID 3 flex collars, remove sources, L/D ADN, M/U lift sub, break bit, L/D remaining BHA. Total Calc fill=43.22 bbl,Total Actual Fi11=47.09 bbl. 16:15 17:15 1.00 0 0 INTRM1 CASING RURD P Clean and clear rig floor, L/D BHA tools and equipment. 17:15 19:15 2.00 0 0 INTRM1 CASING BOPE P R/U and flush stack @ 550 gpm, R/U and pull wear ring, make dummy run with hanger,set test plug. 19:15 20:30 1.25 0 0 INTRM1 CASING BOPE P PJSM, C/O upper 2-7/8"x 5"VBR's to 7-5/8"solid rams. SIMOPS-rig up to test BOP with 7-5.8"test joint. 20:30 21:15 0.75 0 0 INTRM1 CASING BOPE P Install 7-5/8"test joint,fill stack& lines with water, R/U to test. 21:15 22:00 0.75 0 0 INTRM1 CASING BOPE P Test upper rams with 7-5/8"test joint to 250/3500 psi 5 min charted,test annular preventer to 250/2500 psi 5 min charted. 22:00 22:15 0.25 0 0 INTRM1 CASING BOPE P R/D test equipment. 22:15 00:00 1.75 0 0 INTRM1 CASING RURD P PJSM, MOB casing tools to rig floor, R/U to run 7-5/8"casing. 08/10/2014 Run 7-5/8"29.7#L-80 W563 casing to shoe and CBU, run to top HRZ CBU, run to bottom, C&C and pump cement job per program. No hole issues running in. Page 13 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 INTRM1 CASING RURD P PJSM, continue to rig up to run casing. 01:00 07:00 6.00 0 4,129 INTRM1 CASING RNCS P PJSM, RIH with 7-5/8"29.78#L-80 W563 casing to 4129'MD. P/U=125k, S/O=100k. 07:00 08:00 1.00 4,129 4,129 INTRM1 CASING CIRC P Establish circulation ICP 375 psi @ 3 bpm, stage up to 8 bpm 625 psi no losses. Pumped until MW evened out at 10.1 ppg and shakers clean 320 bbl. 08:00 13:15 5.25 4,129 8,106 INTRM1 CASING RNCS P Continue RIH with casing to 8106' MD, P/U=220k, 5/O=145k. 13:15 15:15 2.00 8,106 8,106 INTRM1 CASING CIRC P Circulate and condition mud to 10.1 ppg in/out, staged up from 1.5 bpm to 5 bpm, 575 psi 44% Flow out. P/U=210k, 5/0=140k after circulation. 15:15 18:15 3.00 8,106 10,049 INTRM1 CASING RNCS P Continue RIH with casing from 8106' MD to 10,049' MD. M/U hanger and landing joint. P/U=245k, S/0=120k. Total Calc disp=102.68 bbl, Total Actual disp=97.2 bbl. 18:15 19:45 1.50 10,049 10,049 INTRM1 CEMEN-CIRC P CBU with Franks fill-up tool,stage pumps up from 1 bpm to 5 bpm,675 psi FCP 40%flow out. 19:45 20:15 0.50 10,049 10,049 INTRM1 CEMEN"RURD P PJSM, R/D Franks tool, Blow down top drive, R/U cement head and circulating equipment. 20:15 22:15 2.00 10,049 10,053 INTRM1 CEMEN"CIRC P Circulate and condition with cement head, pump 800 bbls, staged up from 2 bpm to 7 bpm,250 psi to 750 psi, 44%flow out.. 22:15 00:00 1.75 10,053 10,053 INTRM1 CEMEN PUCM P PJSM, Cement per program. Pump 5 bbl CW100, PT lines to 4000 psi-good. Pump 355 bbl CW100, batch up and pump 41.5 bbl 12.5 ppg MudPush II, Drop bottom plug, pump 77.8 bbl 15.8 ppg CMT, chase with 10 bbl H2O from SLB, shut down to displace with rig. 08/11/2014 Displace cement, bump plugs and check floats. Set and test packoff. Lay down 5"Drill pipe, Pick up 4"drill pipe. 00:00 01:30 1.50 10,053 0 INTRM1 CEMEN"DISP P PJSM, continue cementing per program,displace 40 bbl CW100,40 bbl 12.5 ppg MudPush II and 77.8 bbl 15.8 ppg G Cement with rig pumps, pumped 4446 stks and bumped plugs @ 600 psi FCP, pressure up to 1100 psi and hold 5 minutes. Bleed to 0 and check floats-good. CIP 01:15 hrs. 01:30 03:00 1.50 0 0 INTRM1 CEMEN'RURD P Blow down, clean cement valves, rig down cementing equipment, L/D landing joint. 03:00 04:30 1.50 0 0 INTRM1 CEMEN WWSP P R/U and set packoff. RILDS. Page 14 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:00 0.50 0 0 INTRM1 CEMEN-PRTS P R/U and test packoff to 5000 psi for 10 min, rig down. 05:00 06:30 1.50 0 0 INTRM1 CEMEN RURD P PJSM, R/U mouse hole, L/D 350 ton elevators and C/O bails. 06:30 09:30 3.00 0 0 INTRM1 CEMEN FRZP P PJSM, R/U and flush annulus with 179 bbl Water from rig. Pumped 5.5 bbl @ 1 bpm, pressured up to 840 psi and broke down to 500 psi, staged up from 1.5 bpm 590 psi ICP to 3 bpm 700 psi. SIP=650 psi. Blow down and rig down circ lines. 09:30 11:30 2.00 0 0 INTRM1 CEMEN FRZP P R/U Little Red, PT line to 1500 psi. Pumped 81.4 bbl Isotherm NT @ 1.5 bpm, ICP=750 psi, FCP=1100 psi. SIP=750 psi. SIMOPS-load pipe shed with 4"drill pipe. 11:30 12:00 0.50 0 0 INTRM1 CEMEN-RURD P R/D Little Red, R/D circ equipment, R/U guage on OA. 12:00 15:45 3.75 0 0 INTRM1 CEMEN-PULD P PJSM, L/D 5"DP via mousehole. 15:45 16:15 0.50 0 0 INTRM1 CEMEN-SVRG P Lubricate rig, service top drive. 16:15 20:45 4.50 0 0 INTRM1 CEMEN-PULD P Continue L/D 5"DP via mousehole, unload pipe from pipeshed. 20:45 21:45 1.00 0 0 INTRM1 CEMEN'RURD P C/O handling tools to 4", unload shed of 5". Process 4"pipe in shed, 225 jts. 21:45 00:00 2.25 0 0 INTRM1 CEMEN PULD P PJSM, P/U 4"DP via mousehole. 08/12/2014 Pick up and stand back 75 stands DP. Change rams and test BOP. P/U BHA. 00:00 03:30 3.50 0 0 INTRM1 CEMEN RURD P PJSM, C/O upper pipe rams to 2-7/8"x 5"VBR's. SIMOPS-C/O saver sub and grease choke. 03:30 05:30 2.00 0 0 INTRM1 CEMEN PULD P PJSM, P/U 4"DP via mousehole and stand back in derrick, 17 stands. 05:30 07:15 1.75 0 0 INTRM1 WHDBO RURD P PJSM, R/U to test ROPE,set test plug with 4'/2'test joint,flush water through all lines and fill stack. 07:15 09:30 2.25 0 0 INTRM1 WHDBO BOPE P Test BOPE with 4"and 4%"test jts to 250/3500 psi, annular to 250/2500 psi,5 min ea on chart.#1 top pipe rams,#1-valves 1,12,13,14 and manual kill.#2-Upper IBOP, HCR kill,valves 9,11.#3-Lower IBOP, valves 5,8,10.#4-Dart valve,valves 4,6,7.#5-Floor valve and valve 2. 09:30 10:30 1.00 0 0 INTRM1 WHDBO BOPE P #6-HCR choke,4"kill line Demco valve.#7-Manual choke, HCR kill. #8-Annular preventer,#9-lower pipe rams,#10-Blind rams and valve 3. Page 15 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:30 1.00 0 0 INTRM1 WHDBO BOPE P Change out test joint to 4".#11- Upper rams 4",#12-Lower pipe rams 4",#13-Annular preventer 4". Accumulator test-System pressure 3000 psi, pressure after closed 1750 psi,200 psi attained 46 sec,full pressure attained 190 sec, 5 bottle N2 avg 1950 psi. No failures- AOGCC Johnny Hill witnessed test. 11:30 13:00 1.50 0 0 INTRM1 WHDBO RURD P Rig down testing equipment, blow down choke and kill lines,top drive. Remove test sub from top drive. Set 10"ID wear ring, break floor valve and dart valve, 13:00 16:30 3.50 0 0 INTRM1 CEMEN'PULD P PJSM, P/U and rack back 39 stands 4"drill pipe. (75 total in derrick). Clean and clear rig floor. 16:30 19:30 3.00 0 0 INTRMI CEMEN'SLPC P PJSM, slip on new spool of drilling line, insect brake bands. 19:30 20:45 1.25 0 0 INTRM1 CEMEN"RURD P Process 4"drill pipe and HWDP in pipe shed, MOB BHA components to rig floor. 20:45 22:45 2.00 0 175 INTRM1 CEMEN-PULD P MU BHA#4 per SLB rep 22:45 23:30 0.75 175 175 INTRM1 CEMEN SFTY P PJSM for handling nukes and loading source; Load source. 23:30 00:00 0.50 175 487 INTRM1 CEMEN-PULD P Continue to PU BHA; 3 Flex collars, 3 HWDP,Jars,2 HWDP. 08/13/2014 Single in to 1500'MD, Shallow test MWD no signal. POOH, UD BHA. Install new Impulse and single in hole to 7500'MD.Activate memory and log to 8527' MD. 00:00 01:45 1.75 487 1,722 INTRM1 CEMEN PULD P RIH picking up 4"drill pipe to 1722' MD.Actual displacement= 15 bbls, Calculated displacement= 15 bbls. 01:45 03:45 2.00 1,722 1,722 INTRM1 CEMEN DHEQ T Attempt to shallow hole pulse test tools, no go.Trouble shoot MWD. 03:45 04:15 0.50 1,722 1,466 INTRM1 CEMEN-TRIPT POOH standing back 3 stands to 1466' MD 04:15 04:45 0.50 1,466 1,466 INTRM1 CEMEN'CIRC T Drop 1.750 ball to open Well Commander,observed pump pressure drop 900 psi when open. Drop closing ball, observed pump pressure return to 1200 psi Ensure Well Commander was closed while attempting to test MWD. 04:45 05:15 0.50 1,466 490 INTRM1 CEMEN-TRIP T Cont to POOH to 490'MD.Actual displacement= 12 bbls, Calculated displacement= 11 bbls. 05:15 06:15 1.00 490 200 INTRMI CEMEN'TRIP T PJSM, Cont POOH standing back HWDP and Non Mag Flex Collars. 06:15 07:30 1.25 200 200 INTRM1 CEMEN-PULD T Remove nuclear sources from LWD tools and L/D. 07:30 08:30 1.00 200 67 INTRM1 CEMEN'PULD T Download MWD tools and L/D BHA to 67'MD 08:30 10:00 1.50 67 67 INTRM1 CEMEN-SVRG T Mobilize new IMPulse tool to rig. SIMOPS, clean and clear rig floor, service draworks and perform top drive and block inspection. Page 16 of 27 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:00 11:00 1.00 67 67 INTRM1 CEMEN-OTHR T Program IMPulse tool as per SLB. 11:00 12:00 1.00 67 174 INTRM1 CEMEN"PULD T M/U BHA as per SLB to 174'MD. 12:00 13:15 1.25 174 400 INTRM1 CEMEN'PULD T PJSM, loading nuke sources, M/U ADN, load source, M/U Flex collars, C/O elevators, RIH w/2 stands HWDP w/jars. 13:15 14:15 1.00 400 1,437 INTRM1 CEMEN-PULD T PJSM,single in hole from pipe shed to 1437'MD. 14:15 14:45 0.50 1,437 1,437 INTRMI CEMEN'DHEQ P Shallow test MWD @ 240 gpm, 1600 psi 40%flow out. 14:45 17:30 2.75 1,437 4,260 INTRMI CEMEN PULD P Continue single in hole with 4"DP, filling pipe every 1500'to 4260'MD. 17:30 18:00 0.50 4,260 4,260 INTRMI CEMEN'SVRG P Lubricate rig, grease top drive, service iron roughneck. 18:00 21:30 3.50 4,260 7,489 INTRMI CEMEN'PULD P Continue single in hole from 4260' MD to 7489' MD,fill every 1500'. Kelly up and wake tool for acoustic bond log @ 240 gpm,2000 psi, P/U=130k, S/O=90k. 21:30 00:00 2.50 7,489 8,527 INTRM1 CEMEN'QEVL P MAD pass from 7489'MD @ 900 fph, to 8527' MD. P/U=140k, S/O=85k. Calc Disp=55.85 bbl,Actual Disp=56.3 bbl. 08/14/2014 Continue logging to 10,000'. C&C, perform casing test. Drill out, C&C and perform LOT to 13.8 ppg. Displace to 10.5 ppg Flo Pro and drill production hole to 10513'MD, C&C for open hole PIT. 00:00 03:30 3.50 8,527 9,852 INTRM1 CEMEN-QEVL P PJSM, Continue singling in @ 900 fph performing MAD pass from 8527' MD to 9852'MD P/U=153k, S/O=82k, Calc Disp=64.5 bbl,Actual disp=66 bbl. 03:30 04:00 0.50 9,852 9,947 INTRM1 CEMEN'COCF P Establish circulation,wash down through stringers to 9940'and tag on TOC with 10K down weight. Drill to hard cement @ 9947'for casing test. Wash/ream at 50 rpm,220 gpm @ 2120 psi, 8k Tq, 2-3k WOB. 04:00 05:00 1.00 9,947 9,947 INTRM1 CEMEN-CIRC P Circulate BU for casing test 220 gpm, 2000 psi, 50 rpm, 7k Tq. 05:00 06:30 1.50 9,947 9,947 INTRM1 CEMEN-PRTS P R/U and perform casing test to 3500 psi/30 min charted. Rig down. 06:30 12:15 5.75 9,947 10,065 INTRM1 CEMEN-DRLG P Obtain SPR's, drill out cement and shoe track and rathole to 10065'MD, 200-220 gpm, 1550-2000 psi,40-70 rpm,TQ=10-14k, P/U=135k, S/0=106k, ROT=112k,WOB=5-15k. SPR's @ 9847'MD, 6065'TVD, 9.9 ppg, 06:30 hrs. #1-20spm=590 psi, 30 spm=840 psi #2-20 spm=550 psi, 30 spm=780 psi. Page 17 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 12:45 0.50 10,065 10,085 INTRM1 CEMEN-DDRL P Drill from 10065'MD to 10085'MD, 6097'TVD,ART=.27,ADT=.27,Total jar hrs=62.6, Bit Hrs=.27, P/U=160k, S/O=82k, ROT=112k,Tq on/off=13.5/13k, ECD=10.72, Flow out=38%,WOB=5-8k, 80 rpm,220 gpm @ 1900 psi. 12:45 13:45 1.00 10,085 10,085 INTRM1 CEMEN CIRC P Circulate and condition mud top 9.9+ ppg in/out for PIT @ 240 gpm,2175 psi,80 rpm, 12k Tq,40%Flow out. 13:45 14:45 1.00 10,085 9,993 INTRM1 CEMEN-LOT P Rack back a stand and R/U for PIT with 9.9+ MW,6097'ND. Perform initial test to 13.8 ppg EMW, 1275 psi. Chart not recording. Re-test to 1100 psi, 13.5 ppg EMW. B/D and R/D test equipment. 14:45 16:30 1.75 9,993 10,085 PROD1 DRILL DISP P P/U stand and establish circulation, displace well to 10.5 ppg FloThru mud @ 220 gpm. 16:30 17:00 0.50 10,085 10,085 PROD1 DRILL CIRC P Obtain SPR's and establish clean hole ECD's at different pump rates. SPR's @ 10085', 6098'TVD, 10.5 ppg, 16:30 hrs #1-20 spm=520 psi, 30 spm=840 psi #2-20 spm=560 psi, 30 spm=860 psi ECD @ 220 gpm=11.25 ppg, ECD @ 230 gpm=11.28 ppg. ECD @ 240 gpm=11.30 ppg. 17:00 18:00 1.00 10,085 10,132 PROD1 DRILL DDRL P Directional drill to build angle to 90° from 10085'MD to 10132'MD,6105' TVD.ART/ADT=.81,Total Jars Hrs=63.41, Bit Hrs=1.08, P/U=137k, S/O=92k, ROT=113k,Tq on/off=10/6k, ECD=11.33, Flow out=39%,WOB=5-14k, 80 rpm,240 gpm @ 2600 psi. 18:00 23:00 5.00 10,132 10,513 PROD1 DRILL DDRL P Directional drill to build angle to 90° from 10132'MD to 10513'MD, 6111' TVD.ART/ADT=3.43,Total Jars Hrs=66.57, Bit Hrs=4.24, P/U=145k, S/O=85k, ROT=112k,Tq on/off=13/8k, ECD=11.44, Flow out=39%,WOB=10-18k, 100 rpm, 250 gpm @ 2775 psi. 23:00 23:15 0.25 10,513 10,513 PROD1 DRILL CIRC P Ream 45', survey on bottom, obtain SPR's. SPR's @ 10512'MD,6112'TVD, 10.5 ppg, 23:15 hrs #1-20 spm=600 psi, 30 spm=830 psi #2-20 spm=570 psi, 30 spm=830 psi 23:15 00:00 0.75 10,513 10,513 PROD1 DRILL CIRC P CBU @ 245 gpm,2775 psi, 100 rpm, 9k Tq,42% Flow out. Page 18 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/15/2014 24 hr Summary Circulate and pull into shoe. Perform OH FIT with 14.1 ppg EMW.Trip to bottom and drill ahead to 11,840' MD.Attempted stethoscope reading without success, crossed fault#1 @ 11,557'MD.. 00:00 00:15 0.25 10,513 10,513 PROD1 DRILL CIRC P Circulate BU, ROT= 100 RPM, TQ= 9K,245 GPM with 2750 psi. 00:15 01:15 1.00 10,513 10,041 PROD1 DRILL TRIP P Pump out of the hole to the shoe 10041';220 GPM with 2200 psi. 01:15 01:30 0.25 10,041 10,041 PROD1 DRILL RURD P RU circulating lines and test equipment. 01:30 01:45 0.25 10,041 10,041 PROD1 DRILL FIT P Perform LOT to 14.1 ppg EMW. 10.5 mud in and out at 6111'TVD. 01:45 02:00 0.25 10,041 10,041 PROD1 DRILL RURD P RD circulating lines and test equipment. 02:00 02:30 0.50 10,041 10,513 PROD1 DRILL TRIP P RIH to bottom on elevators; no problems. 02:30 06:00 3.50 10,513 10,703 PROD1 DRILL DDRL P Drill from 10513'to 10703'; ART/ADT= 1.73, Total Jar Hrs=68.3, Bit hrs=5.97. 245 GPM @ 2775 psi. PU= 149K, SO=90K, RWT= 112K, RPM= 120,TQ on= 11-15K, TQ off= 7-8K, ECD= 11.43,WOB= 11-15K. 06:00 10:30 4.50 10,703 11,017 PROD1 DRILL DDRL P Drill from 10703'to 11017, ADT/ART=2.38,Total Jars Hrs=70.68, Bit Hrs=8.35, 246 GPM @ 2700 psi. PU= 150K, SO=80K, RWT= 110K, RPM= 120/140, TQ on=12-13K, TQ off=9K, ECD= 11.61,WOB= 12-15K. SPR's @ 10987'MD,6103'TVD, 10.5 ppg, 10:30 hrs. #1-20 spm=670 psi, 30 spm=990 psi. #2-20 spm=650 psi, 30 spm=980 psi. 10:30 13:15 2.75 11,017 11,017 PROD1 DRILL DLOG P Perform Stethescope sampling per SLB rep. Incomplete sample. 13:15 15:45 2.50 11,017 11,217 PROD1 DRILL DDRL P Drill from 11,017'MD to 11217' MD/6102'TVD. P/U=152k, S/O=81k, ROT=112k, Tq on/off=13/9k, ECD=11.65, Flow out=39%, WOB=12-13k, 140 rpm, 240 gpm @ 2725 psi. 15:45 16:30 0.75 11,217 11,217 PROD1 DRILL DLOG P Perform Stethescope sampling per SLB rep. Incomplete sample. 16:30 18:00 1.50 11,217 11,365 PROD1 DRILL DDRL P Drill from 11217'MD to 11365' MD/6108'TVD.ART/ADT=3.48, Total Jar hours=73.72, Bit hrs=11.17, P/U=155k, S/O=78k, ROT=110k,Tq on/off=13/9k, ECD=11.69, Flow out=42%,WOB=7-15k, 140 rpm, 240 gpm @ 2750 psi. Page 19of27 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 11,365 11,840 PROD1 DRILL DDRL P Drill from 11365'MD to 11840' MD/6115'TVD.ART/ADT=3.37,Total jar hours=77.09, Bit hrs=14.54, P/U=158k, S/O=77k, ROT=112k,Tq on/off=13/9k, ECD=11.84, Flow out=40%,WOB=10-15k, 140 rpm, 240 gpm @ 2975 psi. SPR's @ 11553'MD,6110'TVD, 10.5 ppg,20:15 hrs #1-20 spm=680 psi, 30 spm=980 psi. #2-20 spm=640 psi, 30 spm=980 psi. 08/16/2014 Drill ahead to 12422'where fault#2 was crossed. No abnormal parameters observed. Drill ahead to 13,113' perform Stethoscope sample. Drill ahead undulating in the A-5 sand to 13800'. 00:00 06:00 6.00 11,840 12,373 PROD1 DRILL DDRL P (Drill from 11840'MD to 12373' MD/6140'TVD.ART/ADT=3.77, Total Jar hours=80.86, Bit hrs=18.31, P/U=160k, S/O=75k, ROT=114k,Tq on/off=13.5/11k, ECD=11.67, Flow out=41%,WOB=5-10k, 140 rpm, 245 gpm @ 2900 psi. SPR's @ 12,218' MD,6150'TVD, 10.5 ppg, 04:30 hrs. #1-20 spm=580 psi, 30 spm=940 psi. #2-20 spm=660 psi, 30 spm=920 _psi. 06:00 12:00 6.00 12,373 12,855 PROD1 DRILL DDRL P Drill from 12373'MD to 12855' MD/6164'TVD.ART/ADT=3.34,Total Jar hours=84.20, Bit hrs=21.65, P/U=165k, 5/0=72k, ROT=113k,Tq on/off=13.5/11k, ECD=11.86, Flow out=40%,WOB=10-15k, 140 rpm, 240 gpm @ 2950 psi. 12:00 14:45 2.75 12,855 13,113 PROD1 DRILL DDRL P Drill from 12855'MD to 13113' MD/6158'TVD.ART/ADT=1.8,Total Jar hours=85.78, Bit hrs=23.45, P/U=167k, 5/0=70k, ROT=111k,Tq on/off=13.5/10k, ECD=11.92, Flow out=43%,WOB=5-10k, 140 rpm, 240 gpm @ 3125 psi. 14:45 16:00 1.25 13,113 13,113 PROD1 DRILL QEVL P Perform stethoscope reading per MWD in fault block 3. 16:00 18:00 2.00 13,113 13,318 PROD1 DRILL DDRL P Drill from 13113'MD to 13318' MD/6162'TVD.ART/ADT=1.42,Total Jar hours=87.2, Bit hrs=24.87, P/U=165k, 5/O=72k, ROT=111k, Tq on/off=12.5/9k, ECD=11.81, Flow out=40%,WOB=5-10k, 140 rpm, 240 gpm @ 3050 psi. SPR's @ 13158'MD,6157'TVD, 10.5 ppg, 16:30 hrs. #1-20 spm=680 psi, 30 spm=1020 psi. #2-20 spm=700 psi, 30 spm=1050 psi. Page 20 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 13,318 13,800 PROD1 DRILL DDRL P Drill from 13318' MD to 13800' MD/6160'TVD.ART/ADT=3.27,Total Jar hours=90.47, Bit hrs=28.14, P/U=168k, S/0=74k, ROT=111k,Tq on/off=13i9k, ECD=11.84, Flow out=44%, WOB=7-14k, 140 rpm, 242 gpm @ 3050 psi. 38/17/2014 Drilled ahead to 15,704', Geo-steering while in the A-5 sands. 00:00 06:00 6.00 13,800 14,294 PROD1 DRILL DDRL P Drill from 13800' MD to 14294' MD/6176'TVD.ART/ADT=3.82, Total Jar hours=94.29, Bit hrs=31.96, P/U=175k, S/0=57k, ROT=115k,Tq on/off=13.5/11 k, ECD=11.90, Flow out=40%,WOB=10k, 150 rpm, 240 gpm @ 3050 psi. SPR's @ 13916'MD, 6165'TVD, 10.5 ppg, 01:15 hrs. #1-20 sprn=640 psi, 30 spm=1030 psi. #2-20 sprn=710 psi, 30 spm=1020 psi. 06:00 12:00 6.00 14,294 14,800 PROD1 DRILL DDRL P Drill from 14294'MD to 14800' MD/6205'TVD.ART/ADT=3.46, Total Jar hours==97.75, Bit hrs=35.42, P/U=168k, S/0=65k, ROT=114k,Tq on/off=13i11k, ECD=11.90, Flow out=41%,WOB=10k, 150 rpm, 240 gpm @ 3000 psi. 12:00 18:00 6.00 14,800 15,285 PROD1 DRILL DDRL P Drill from 14800' MD to 15285' MD/6207'TVD.ART/ADT=4.19, Total Jar hours=101.94, Bit hrs=39.61, P/U=172k, S/0=56k, ROT=110k, Tq on/off=13.5/9k, ECD=12.06, Flow out=43%, WOB=7-16k, 150 rpm, 241 gpm @ 3250 psi. SPR's @ 14957' MD, 6208'TVD, 10.5+ppg, 13:30 hrs #1-20 sprn=670 psi, 30 spm=1050 psi #2-20 sprn=730 psi, 30 spm=1070 psi 18:00 00:00 6.00 15,285 15,704 PROD1 DRILL DDRL P Drill from 15285' MD to 15704' MD/6231'TVD. ART/ADT=3.85, Total Jar hours=105.79, Bit hrs=43.46, P/U=171 k, S/0=58k, ROT=111 k, Tq on/off=12.5/9.5k, ECD=12.4, Flow out=40%, WOB=7-12k, 150 rpm, 239 gpm (1 3200 psi. 38/18/2014 Drilled ahead to 15,704', Geo-steering while in the A-5 sands. Drill to TD at 17652' MD,6264'TVD. Page 21 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 15,704 16,149 PROD1 DRILL DDRL P Drill from 15704'MD to 16149' MD/6231'TVD.ART/ADT=3.61,Total Jar hours=109.40, Bit hrs=47.07, P/U=166k, S/0=52k, ROT=111k,Tq on/off=12.5/9.5k, ECD=12.12, Flow out=43%,WOB=6-10k, 140 rpm, 245 gpm @ 3150 psi. SPR's @ 15714'MD, 6232'TVD, 10.5+ppg, 12:20 hrs #1-20 spm=700 psi, 30 spm=1020 psi #2-20 spm=760 psi, 30 spm=980 psi 06:00 12:00 6.00 16,149 16,550 PROD1 DRILL DDRL P Drill from 16149'MD to 16550' MD/6231'TVD.ART/ADT=4.25, Total Jar hours=113.65, Bit hrs=51.32, P/U=170k, S/0=0k, ROT=114k,Tq on/off=13/9.5k, ECD=12.16, Flow out=41%,WOB=10-15k, 150 rpm, 241 gpm @ 3160 psi. 12:00 18:00 6.00 16,550 17,114 PROD1 DRILL DDRL P Drill from 16550'MD to 17114' MD/6251'TVD.ART/ADT=3.86,Total Jar hours=117.51, Bit hrs=55.18, P/U=172k, S/O=N/Ak, ROT=114k, Tq on/off=12/10k, ECD=12.15, Flow out=42%,WOB=5-12k, 150 rpm, 238 gpm @ 3225 psi. SPR's @ 16660'MD,6239'TVD, 10.5+ppg, 13:15 hrs #1-20 spm=640 psi, 30 spm=1030 psi #2-20 spm=660 psi, 30 spm=1040 psi 18:00 00:00 6.00 17,114 17,652 PROD1 DRILL DDRL P Drill from 17114'MD to 17652' MD/6264'TVD.ART/ADT=3.45, Total Jar hours=120.96, Bit hrs=58.63, P/U=168k, S/O=N/Ak, ROT=117k, Tq on/off=12/9.5k, ECD=12.21, Flow out=45%,WOB=7-12k, 150 rpm, 233 gpm @ 3250 psi. TD of well; 17,652'MD,6264'TVD. 08/19/2014 Circulated hole clean at TD w/3 BTU. BROOH f/17417'-13201'MD.Work tight spot 16474'-16191'MD. Perform Stethoscope @ 13201' MD, last 2 tests were no seal tests. Continue BROOH f/13201'-10895'MD. 00:00 05:30 5.50 17,652 17,417 PROD1 CASING CIRC P Obtain SPR's. Circulate hole clean at TD;240 gpm with 3160 psi, ECD= 12.12 ppg, RPM= 140. Stand one stand back every bottoms up f/ 17652' MD to 17417' MD. SPR's 17652'MD TVD=6225' MW= 10.5 ppg 12:00 hours MP#1=710 psi @ 20 spm, 1150psi @ 30 spm MP#2=810 psi @ 30 spm, 1190 psi @ 30 spm 05:30 07:15 1.75 17,417 17,417 PROD1 CASING OWFF P Monitor well, slight flow to static. Page 22 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 09:00 1.75 17,417 16,474 PROD1 CASING REAM P BROOH f/17417'MD to 16474'MD @ 1200 fpm, 220 gpm,2850 psi, 44%flow, 120 rpm, 9K Tq. Kick w/Tripping Drill CRT=30 sec @ 08:00 hrs 09:00 09:45 0.75 16,474 16,380 PROD1 CASING REAM P Observed pipe torquing up and slightly packing off,work tight spots pulling 300 fpm .Worked tight hole from 16474'MD to 16380'MD—4th fault crossing. 09:45 12:00 2.25 16,380 15,811 PROD1 CASING REAM P BROOH f/16380'MD to 15811'MD @ 1200 fpm, 220 gpm,2950 psi, 44%flow, 120 rpm, 9K Tq. 12:00 17:15 5.25 15,811 13,352 PROD1 CASING REAM P BROOH f/15811'MD to 13352'MD @ 1200 fpm,220 gpm, 2700 psi, 44%flow, 120 rpm, 9K Tq. 17:15 19:00 1.75 13,352 13,258 PROD1 CASING DLOG P Perform Stethoscope test per SLB,f/ 13352'-13258'MD,actual test at 13201'MD. No seal on last 2 tests. Kick w/Tripping Drill CRT=45 sec. @ 18:00 hrs. 19:00 00:00 5.00 13,258 10,895 PROD1 CASING REAM P BROOH f/13258'MD to 10895'MD @ 1200 fpm, 220 gpm, 2400 psi, 44%flow, 120 rpm,6K Tq. PU 145K, SO 80K, ROT 110K, Calculated fill 37.8, actual 73.76 bbls. 08/20/2014 BROOH to shoe. Circulated hole clean at shoe&weighted up to 10.7 ppg. Monitored well. Pulled out of the hole to surface. Laid down BHA. Rigged up&ran liner as per detail to 7708'MD. 00:00 02:00 2.00 10,895 10,040 PROD1 CASING REAM P BROOH f/10985'MD to 10040'MD © 1000 fpm, 220 gpm,2400 psi, 44%flow, 120 rpm, 6-7K Tq. PU 145K, SO 80K, ROT 110K, Calculated fill 4.8,actual 9.6 bbls. 02:00 04:00 2.00 10,040 10,040 PROD1 CASING CIRC P CBU 2 X and weight up to 10.7 ppg @ 220 gpm,2400 psi,40%FO, 120 rpm, TQ 5K, PU 140K, SO 95K, ROT 115K. 04:00 04:30 0.50 10,040 10,040 PROD1 CASING OWFF P Monitor well,static. 04:30 04:45 0.25 10,040 9,945 PROD1 CASING TRIP P TOH f/10040'-9945'MD, drop 2.4" drift, blow down TD. 04:45 11:30 6.75 9,945 584 PROD1 CASING TRIP P TOH f/9945'-584' MD, following MI trip schedule 1100-7200 fph as per depth. Spill Drill CRT= 140 sec @ 08:00 hrs. 11:30 11:45 0.25 584 584 PROD1 CASING OWFF P Monitor well,static. 11:45 15:00 3.25 584 0 PROD1 CASING PULD P Lay down BHA#4 as per SLB DD& MWD. 15:00 15:30 0.50 0 0 PROD1 CASING RURD P Clear rig floor of tools and equipment from BHA#4. 15:30 16:30 1.00 0 0 COMPZ CASING RURD P Rig up to run liner. Page 23 of 27 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:30 00:00 7.50 0 7,708 COMPZ CASING RNCS P TIH with 4.5", 11.6#, L-80, Hydril 563 liner as per detail to 7708'MD. PU 90K, SO 70K, calculated displacement 32.4,actual 28.7 bbls. Kick w/Tripping CRT= 100 sec @ 22:00 hrs. 38/21/2014 Picked up liner hanger/packer and TIH w/DP. Set liner hanger&test. Displaced to 10.7 ppg brine.TOH laying down HWDP&running tool. Test BOPE w/3.5"jt. Make dummy run w/hanger. Rig up&ran upper completion to 98'MD. 00:00 01:30 1.50 7,708 7,708 COMPZ CASING RUNL P M/U seal bore extension, liner hanger and ZXP as per Baker rep. 01:30 02:00 0.50 7,708 7,708 COMPZ CASING OTHR P Mix Pal-Mix, pour into liner tieback and wait 30min to set up. P/U=90K, 5/0=70K. 02:00 03:00 1.00 7,708 9,661 COMPZ CASING RUNL P RIH w/4-1/2"liner on drill pipe f/ 7762'MD to 9661' MD. 03:00 04:00 1.00 9,661 10,581 COMPZ CASING RUNL P RIH w/4-1/2"liner picking up 4" HWDP, picked up 30 joints of 4" HWDP. Obtain parameter @ 7-5/8" casing shoe, 10051'MD. P/U= 115K, S/0=68K, ROT @ 10 rpm's w/4K TQ, 04:00 08:45 4.75 10,581 17,635 COMPZ CASING RUNL P RIH w/4-1/2"liner on drill pipe f/ 10581'MD to 17635'MD. P/U= 178K,S/O=68K.Actual displacement=61.95 bbls, Calculated displacement=61.3 bbls. 08:45 09:15 0.50 17,635 17,635 COMPZ CASING OWFF P OWFF,static. 09:15 10:15 1.00 17,635 17,635 COMPZ CASING PACK P Drop 1-1/2"drop, pump down @ 3 bpm,700 psi. ball landed @ 840 strokes. Pressure up to 2700 psi to set liner hanger, S/O 50K, P/U. Pressure up to 4200 psi and hold for 5 minutes, bleed off pressure. P/U V break over 140K, P/U 6'after break over, slack off and set down 50K, observed dog sub shear. P/U and rotate 15 rpm's and set down 50K to confirm ZXP is set. ROT Wt= 102K, S/O= 105K, P/U= 140K. 10:15 11:00 0.75 17,635 9,873 COMPZ CASING PRTS P R/U and test ZXP liner top packer to 1500 psi for 15 minutes on chart, good. 11:00 11:15 0.25 9,873 9,830 COMPZ CASING TRIP P Pick up to release the seal assembly,observed no liner weight. Rack back 1 stand. 11:15 12:15 1.00 9,830 9,830 COMPZ CASING DISP P Displace well to 10.7 ppg brine. Pump 35 bbl spacer followed w/10.7 ppg brine @ 8 bpm, 1650 psi,46% FO. 12:15 13:15 1.00 9,830 9,830 COMPZ CASING OWFF P Monitor well till static. 13:15 16:15 3.00 9,830 2,850 COMPZ CASING TRIP P TOH from 9830'-2850'MD. 16:15 17:15 1.00 2,850 1,930 COMPZ CASING PULD P Lay down 30 joints of HWDP. Page 24 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:00 0.75 1,930 0 COMPZ CASING TRIP P TOH&lay down running tool. Calculated fill 60.3, actual 64.8 bbls. 18:00 18:30 0.50 0 0 COMPZ RPCOM RURD P Clear&clean rig floor. Moblize casing tools to rig floor. 18:30 19:45 1.25 0 0 COMPZ RPCOM RURD P Rig up,flush stack and blow down TD. 19:45 21:00 1.25 0 0 COMPZ RPCOM RURD P Remove wear bushing, install test plug, &rig up to test. 21:00 21:45 0.75 0 0 COMPZ RPCOM BOPE P Test with 3.5"joint 250/3500 psi for 5 min each, charted.Tested annular, upper&lower VBR's. 21:45 22:30 0.75 0 0 COMPZ RPCOM RURD P Rig down test equipment. Simop dry run hanger&landing joint. 22:30 22:45 0.25 0 0 COMPZ RPCOM RURD P Rig up tublar handling equipment. 22:45 23:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM for running upper completion. 23:00 00:00 1.00 0 98 COMPZ RPCOM PUTB P RIH with 3.5". 9.3#, L-80, EUE 8RD-Mod tubing completion. Make up seal assembly&RIH to 98'. 08/22/2014 Ran 3.5"upper completion as per detail. Spaced out. Spotted inhibited brine. Landed tubing hanger& RILDS. Attempted to PT tubing. Pressured up on IA to 3500 psi,while holding 2500 psi on tubing,for 30 min.testing good. Mobilized slick line and attempted to assist ball/rod on seat. Changed out tools and retrieved ball and rod. Rigged up to remove RHC plug to replace with CSA-2 plug. 00:00 08:45 8.75 98 9,926 COMPZ RPCOM PUTB P RIH with 3.5". 9.3#, L-80, EUE 8RD-Mod tubing completion as per detail to 9926' MD. No-Go @ 9926' MD.Actual displacement=30.45 bbls, Calculated displacement= 32.97 bbls. Kick w/Tripping Drill 159 sec @ 05:45 hrs 08:45 09:45 1.00 9,926 9,902 COMPZ RPCOM HOSO P Obtain space out,8.66'off no-go. L/D 3 joints of 3-1/2"tbg, P/U 1 joint 4-1/2"IBT,XO,tbg hanger and Inding joint. 09:45 10:00 0.25 9,902 9,902 COMPZ RPCOM RURD P Rig up circulating equipment to landing joint. 10:00 11:00 1.00 9,902 9,902 COMPZ RPCOM CRIH P Spot 80 bbls of 10.7 ppg,2%Conqor 303 inhibited brine @ 5 bpm, 800 psi, 30% FO. 11:00 11:30 0.50 9,902 9,902 COMPZ RPCOM OWFF P Monitor well, slight flow to static. 11:30 12:15 0.75 9,902 0 COMPZ RPCOM THGR P Pump 1 bpm and sting into seal bore. Observe psi increase. Shut down pumps and bleed to 0 psi. Land hanger and RILDS as per Cameron Rep. 12:15 12:45 0.50 0 0 COMPZ RPCOM PRTS P Pressure test hanger seals to 5000 psi,witnessed good. Page 25 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 16:45 4.00 0 0 COMPZ RPCOM PRTS T Attempt to PT tubing to 3500 psi, making several attempts.Test surface equipment to 3500 psi, good. Attempt to pressure up on tubing w/ surface equipment isolated, observed 350 psi loss in 30 min. Pressure up on IA to 3500 psi,while holding 2500 psi on tubing,for 30 min.testing good. Call slick line for assist with ball and rod. 16:45 17:15 0.50 0 0 COMPZ RPCOM RURD T Rig down test equipment. Rig up XO on landing joint for slick line. 17:15 18:30 1.25 0 0 COMPZ RPCOM RURD T Clear&clean rig floor. Rig down Tesco service loop. 18:30 19:00 0.50 0 0 COMPZ RPCOM SLKL T Spot slick line unit &mobilize equipment to rig floor. 19:00 21:15 2.25 0 0 COMPZ RPCOM SLKL T Rig up slick line tools and lubricator. 21:15 21:30 0.25 0 0 COMPZ RPCOM SLKL T PT surface lines and lubricator to 3500 psi. 21:30 22:15 0.75 0 8,328 COMPZ RPCOM SLKL T RIH with slick line to 8328' MD. 22:15 23:00 0.75 8,328 8,328 COMPZ RPCOM SLKL T Make several attempts to assist ball and rod on seat. Unable to hold psi on tubing. 23:00 23:15 0.25 8,328 0 COMPZ RPCOM SLKL T POOH with slick line to change out tools. 23:15 23:45 0.50 0 8,328 COMPZ RPCOM SLKL T RIH&retrieve ball and rod from 8328' MD. 23:45 00:00 0.25 8,328 0 COMPZ RPCOM SLKL T Lay down ball&rod and do tools. 38/23/2014 RIH and retrieve RHC w/slick line. RIH w/CSA-2 plug,set&test. POOH&rigged down slick line.PT tubing &annulus. Sheared DCR-1 valve. Installed BPV. Performed PT's in direction of flow. ND BOPE&NU tree. Tested tree. Freeze protect&U-tube well. Set BPV, dress tree, &secured well. Laid down 4"DP. 00:00 00:15 0.25 0 0 COMPZ RPCOM SLKL T PJSM, Cont to C/O slick line tools. 00:15 01:00 0.75 0 0 COMPZ RPCOM SLKL T RIH w/slick line plug retrieval tool, pull RHC plug and POOH w/slick line. Slick line operator noted that the RHC plug came out of the DS nipple without having to jar to unseat the plug, it came out with no over pull. 01:00 01:15 0.25 0 0 COMPZ RPCOM SLKL T PJSM, L/D RHC plug. 01:15 03:00 1.75 0 8,330 COMPZ RPCOM SLKL T P/U solid body"CSA"plug . RIH and set CSA plug in DS nipple @ 8330. 03:00 03:15 0.25 8,330 8,330 COMPZ RPCOM PRTS T Pressure test 3-1/2"tubing against CSA plug to 3500 psi for 10 minutes, good. Shear off plug and bleed of pressure. 03:15 04:30 1.25 8,830 0 COMPZ RPCOM SLKL T POOH w/HES slick line and L/D tools. Rig down slick line. 04:30 05:00 0.50 0 0 COMPZ RPCOM RURD T R/U to test 3-1/2"tbg and IA. Page 26 of 27 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 07:00 2.00 0 0 COMPZ RPCOM PRTS T Pressure test 3-1/2"tbg to 3500 psi for 30 minutes,good. Bleed down tbg to 2500 psi,pressure test IA to 3500 psi for 30 minutes,good. Bleed for IA and tbg, ramp up on pump to shear SOV in GLM, SOV sheared @ 3200 psi.All pressure tests charted. 07:00 07:30 0.50 0 0 COMPZ WHDBO OWFF P OWFF for 30 minutes,static. 07:30 08:00 0.50 0 0 COMPZ WHDBO MPSP P Set BPV, Test BPV in the direction of flow to 2500 psi f/5 minutes on chart,good. 08:00 09:30 1.50 0 0 COMPZ WHDBO NUND P Nipple down BOPE and stand back on stump. Sim-op flush&drain mud pumps for move. 09:30 11:15 1.75 0 0 COMPZ WHDBO NUND P Install SRL seals, adapter flange to well head as per Cameron Rep. Spill Drill @ 11:00 hrs, CRT= 148 sec. 11:15 11:45 0.50 0 0 COMPZ WHDBO PRTS P PT SRL seals&void 250/5000 psi, good. 11:45 12:45 1.00 0 0 COMPZ WHDBO NUND P Nipple up tree as per Cameron Rep. 12:45 13:00 0.25 0 0 COMPZ WHDBO PRTS P PT adapter x tubing hanger void to 5000 psi, good. 13:00 13:30 0.50 0 0 COMPZ WHDBO MPSP P Remove BPV&test equipment. 13:30 13:45 0.25 0 0 COMPZ WHDBO RURD P Rig up for freeze protect well. 13:45 14:00 0.25 0 0 COMPZ WHDBO PRTS P PT freeze protect lines to 2500 psi, good. 14:00 14:45 0.75 0 0 COMPZ WHDBO FRZP P Pump 85 bbls of diesel @ 2 bpm, ICP 700 psi, FCP 1050 psi, final IA 400 psi. 14:45 20:00 5.25 0 0 COMPZ WHDBO FRZP P U-tube well. Sim-ops lay down 4" DP. 20:00 21:30 1.50 0 0 COMPZ WHDBO MPSP P Lubricate in 4",type H, BPV into profile.. Dress tree&secure well. 21:30 00:00 2.50 0 0 DEMOB MOVE PULD P Lay down 4"DP from derrick. 08/24/2014 Cont. L/D 4"drill pipe. Cut drilling line and rig down. Released rig @ 06:00 hours 00:00 03:30 3.50 0 DEMOB MOVE PULD P PJSM, Cont.to L/D 4"drill pipe from derrick. 03:30 04:30 1.00 DEMOB MOVE SLPC P PJSM, Slip and cut drilling line, 16 wraps= 104" 04:30 06:00 1.50 DEMOB MOVE RURD P Clean drip and cellar. RDMO Rig Release @ 06:00 hours. Page 27 of 27 NADConversion N A D 2 7 Kuparuk River Unit Kuparuk 2E Pad 2E-02 Definitive Survey Report 02 September, 2014 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKE DM P2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2E-02 Well Position +N/-S 0.00 usft Northing: 5,944,172.25 usft Latitude: 70°15'30.741 N +E/-W 0.00 usft Easting: 529,971.76 usft Longitude: 149°45'27.905 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.10 usft Wellbore 2E-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 7/15/2014 19.29 80.87 57,580 • Design 2E-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.41 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.41 0.00 0.00 182.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 1,200.00 2E-02 SRV 1 SLB-NSG-SSHOT(2E-02) GYD-GC-SS Gyrodata gyro single shots 8/7/2014 1:51:0 1,224.30 4,080.12 2E-02 SRV 2 SLB-MWD-GMAG(2E-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/7/2014 1:55:0 4,127.21 4,127.21 2E-02 SRV 3 SLB-MWD-INC-ONLY-FILL INC+TREND Inclinometer+known azi trend 8/7/2014 2:01:0 4,223.18 10,001.20 2E-02 SRV 4 SLB-MWD-GMAG(2E-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/7/2014 2:01:0 10,052.53 10,052.53 2E-02 SRV 5 SLB-MWD-INC-ONLY-FILL INC+TREND Inclinometer+known azi trend 8/20/2014 3:04: 10,146.01 17,572.07 2E-02 SRV 6 SLB-MWD-GMAG(2E-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/20/2014 3:05: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.41 0.00 0.00 27.41 -105.10 0.00 0.00 5,944,172.25 529,971.76 0.00 0.00 UNDEFINED 90.00 0.10 251.09 90.00 -42.51 -0.02 -0.05 5,944,172.23 529,971.71 0.16 0.02 GYD-GC-SS(1) 182.00 0.29 301.04 182.00 49.49 0.08 -0.33 5,944,172.32 529,971.43 0.26 -0.06 GYD-GC-SS(1) 275.00 0.23 276.10 275.00 142.49 0.22 -0.71 5,944,172.46 529,971.05 0.14 -0.19 GYD-GC-SS(1) 367.00 0.41 278.11 367.00 234.49 0.28 -1.22 5,944,172.53 529,970.54 0.20 -0.24 GYD-GC-SS(1) 461.00 0.21 336.31 461.00 328.49 0.49 -1.63 5,944,172.73 529,970.13 0.37 -0.43 GYD-GC-SS(1) 552.00 0.18 241.99 552.00 419.49 0.57 -1.82 5,944,172.82 529,969.94 0.32 -0.51 GYD-GC-SS(1) 614.00 0.39 225.67 613.99 481.48 0.38 -2.06 5,944,172.62 529,969.70 0.36 -0.31 GYD-GC-SS(1) 645.00 0.53 223.79 644.99 512.48 0.20 -2.23 5,944,172.44 529,969.53 0.45 -0.13 GYD-GC-SS(1) 737.00 1.09 224.75 736.98 604.47 -0.72 -3.14 5,944,171.51 529,968.62 0.61 0.83 GYD-GC-SS(1) 9/2/2014 5:05:50PM Page 2 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 830.00 2.21 232.75 829.94 697.43 -2.44 -5.19 5,944,169.79 529,966.58 1.23 2.62 GYD-GC-SS(1) 922.00 5.58 243.67 921.72 789.21 -5.50 -10.61 5,944,166.71 529,961.17 3.73 5.86 GYD-GC-SS(1) 1,015.00 8.25 243.02 1,014.03 881.52 -10.53 -20.61 5,944,161.64 529,951.19 2.87 11.24 GYD-GC-SS(1) 1,107.00 12.30 238.76 1,104.54 972.03 -18.61 -34.88 5,944,153.50 529,936.96 4.48 19.82 GYD-GC-SS(1) 1,153.00 14.07 237.56 1,149.33 1,016.82 -24.15 -43.79 5,944,147.93 529,928.07 3.89 25.67 GYD-GC-SS(1) 1,200.00 17.40 236.11 1,194.56 1,062.05 -31.14 -54.45 5,944,140.90 529,917.44 7.13 33.02 GYD-GC-SS(1) 1,224.30 18.13 238.02 1,217.70 1,085.19 -35.16 -60.67 5,944,136.85 529,911.24 3.84 37.26 MWD+IFR-AK-CAZ-SC(2) 1,318.77 19.56 237.62 1,307.10 1,174.59 -51.42 -86.50 5,944,120.49 529,885.48 1.52 54.41 MWD+IFR-AK-CAZ-SC(2) 1,411.19 20.96 238.05 1,393.80 1,261.29 -68.45 -113.59 5,944,103.35 529,858.46 1.52 72.38 MWD+IFR-AK-CAZ-SC(2) 1,503.27 21.14 239.73 1,479.74 1,347.23 -85.54 -141.90 5,944,086.16 529,830.21 0.68 90.44 MWD+IFR-AK-CAZ-SC(2) 1,595.46 23.35 239.30 1,565.06 1,432.55 -103.25 -171.97 5,944,068.33 529,800.22 2.40 109.19 MWD+IFR-AK-CAZ-SC(2) 1,689.80 23.12 240.89 1,651.75 1,519.24 -121.80 -204.23 5,944,049.65 529,768.04 0.71 128.86 MWD+IFR-AK-CAZ-SC(2) 1,783.07 29.62 237.85 1,735.28 1,602.77 -143.00 -239.78 5,944,028.31 529,732.57 7.12 151.28 MWD+IFR-AK-CAZ-SC(2) 1,829.07 30.75 237.43 1,775.04 1,642.53 -155.38 -259.32 5,944,015.85 529,713.09 2.50 164.34 MWD+IFR-AK-CAZ-SC(2) 1,876.26 31.60 236.78 1,815.41 1,682.90 -168.65 -279.83 5,944,002.51 529,692.63 1.94 178.31 MWD+IFR-AK-CAZ-SC(2) 1,969.05 33.28 235.61 1,893.72 1,761.21 -196.35 -321.18 5,943,974.64 529,651.40 1.93 207.44 MWD+IFR-AK-CAZ-SC(2) 2,019.33 37.05 234.27 1,934.82 1,802.31 -212.99 -344.87 5,943,957.91 529,627.78 7.65 224.90 MWD+IFR-AK-CAZ-SC(2) 2,060.30 39.08 234.74 1,967.07 1,834.56 -227.66 -365.43 5,943,943.16 529,607.27 5.01 240.27 MWD+IFR-AK-CAZ-SC(2) 2,154.26 37.86 234.39 2,040.64 1,908.13 -261.54 -413.06 5,943,909.09 529,559.79 1.32 275.80 MWD+IFR-AK-CAZ-SC(2) 2,245.09 41.03 235.00 2,110.77 1,978.26 -294.88 -460.16 5,943,875.57 529,512.83 3.52 310.76 MWD+IFR-AK-CAZ-SC(2) 2,339.46 44.39 234.79 2,180.10 2,047.59 -331.69 -512.51 5,943,838.56 529,460.63 3.56 349.37 MWD+IFR-AK-CAZ-SC(2) 2,431.68 49.03 232.76 2,243.32 2,110.81 -371.38 -566.62 5,943,798.65 529,406.68 5.28 390.93 MWD+IFR-AK-CAZ-SC(2) 2,479.57 51.28 231.42 2,274.01 2,141.50 -393.98 -595.62 5,943,775.95 529,377.78 5.17 414.52 MWD+IFR-AK-CAZ-SC(2) 2,522.72 52.79 231.30 2,300.55 2,168.04 -415.22 -622.19 5,943,754.60 529,351.29 3.51 436.68 MWD+IFR-AK-CAZ-SC(2) 2,615.93 53.90 231.91 2,356.20 2,223.69 -461.66 -680.80 5,943,707.93 529,292.88 1.30 485.13 MWD+IFR-AK-CAZ-SC(2) 2,708.24 53.43 232.38 2,410.89 2,278.38 -507.29 -739.51 5,943,662.07 529,234.35 0.65 532.79 MWD+IFR-AK-CAZ-SC(2) 2,802.68 56.22 232.79 2,465.29 2,332.78 -554.18 -800.82 5,943,614.94 529,173.24 2.98 581.79 M1ND+IFR-AK-CAZ-SC(2) 2,894.14 55.47 232.31 2,516.64 2,384.13 -600.20 -860.90 5,943,568.68 529,113.34 0.93 629.88 MVVD+IFR-AK-CAZ-SC(2) 2,986.15 55.19 232.20 2,568.98 2,436.47 -646.53 -920.74 5,943,522.13 529,053.69 0.32 678.27 MWD+IFR-AK-CAZ-SC(2) 3,079.33 54.68 232.10 2,622.51 2,490.00 -693.32 -980.96 5,943,475.10 528,993.66 0.55 727.14 MWD+IFR-AK-CAZ-SC(2) 3,172.18 53.78 232.84 2,676.78 2,544.27 -739.22 -1,040.70 5,943,428.97 528,934.11 1.17 775.09 MWD+IFR-AK-CAZ-SC(2) 3,262.76 55.01 231.61 2,729.52 2,597.01 -784.33 -1,098.91 5,943,383.63 528,876.09 1.75 822.21 MWD+IFR-AK-CAZSC(2) 3,355.72 53.81 231.92 2,783.62 2,651.11 -831.12 -1,158.29 5,943,336.61 528,816.91 1.32 871.04 MWD+IFR-AK-CAZ-SC(2) 3,449.61 55.28 231.16 2,838.08 2,705.57 -878.69 -1,218.17 5,943,288.81 528,757.22 1.70 920.67 MWD+IFR-AK-CAZ-SC(2) 3,541.30 54.83 231.06 2,890.60 2,758.09 -925.87 -1,276.67 5,943,241.39 528,698.92 0.50 969.87 MWD+IFR-AK-CAZ-SC(2) 3,635.63 55.64 230.13 2,944.39 2,811.88 -975.07 -1,336.54 5,943,191.97 528,639.25 1.18 1,021.12 MWD+IFR-AK-CAZ-SC(2) 3,726.21 55.25 231.03 2,995.77 2,863.26 -1,022.44 -1,394.17 5,943,144.37 528,581.81 0.92 1,070.47 MWD+IFR-AK-CAZ-SC(2) 3,818.80 54.78 231.78 3,048.85 2,916.34 -1,069.76 -1,453.45 5,943,096.82 528,522.72 0.84 1,119.83 MWD+IFR-AK-CAZ-SC(2) 3,911.61 53.55 232.06 3,103.19 2,970.68 -1,116.17 -1,512.68 5,943,050.18 528,463.69 1.35 1,168.28 MWD+IFR-AK-CAZ-SC(2) 4,005.59 53.26 232.39 3,159.22 3,026.71 -1,162.39 -1,572.32 5,943,003.73 528,404.24 0.42 1,216.55 MWD+IFR-AK-CAZ-SC(2) 9/2/2014 5:05:50PM Page 3 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,080.12 53.04 232.60 3,203.91 3,071.40 -1,198.70 -1,619.63 5,942,967.23 528,357.07 0.37 1,254.49 MVD+IFR-AK-CAZ-SC(2) 4,127.21 53.17 233.01 3,232.18 3,099.67 -1,221.46 -1,649.63 5,942,944.35 528,327.17 0.75 1,278.29 INC+TREND(3) 4,141.00 53.17 233.13 3,240.45 3,107.94 -1,228.10 -1,658.45 5,942,937.69 528,318.37 0.73 1,285.23 MVVD+IFR-AK-CAZ-SC(4) 10-3/4"x 13-1/2" 4,223.18 53.15 233.88 3,289.73 3,157.22 -1,267.21 -1,711.33 5,942,898.37 528,265.66 0.73 1,326.16 MWD+IFR-AK-CAZ-SC(4) 4,317.23 52.97 232.83 3,346.25 3,213.74 -1,312.07 -1,771.64 5,942,853.27 528,205.53 0.91 1,373.10 MWD+IFR-AK-CAZ-SC(4) 4,408.54 53.01 233.03 3,401.21 3,268.70 -1,356.02 -1,829.82 5,942,809.09 528,147.54 0.18 1,419.06 MWD+IFR-AK-CAZ-SC(4) 4,503.42 52.94 232.98 3,458.35 3,325.84 -1,401.61 -1,890.32 5,942,763.27 528,087.23 0.08 1,466.72 MWD+IFR-AK-CAZ-SC(4) 4,593.75 52.42 233.24 3,513.11 3,380.60 -1,444.73 -1,947.77 5,942,719.92 528,029.95 0.62 1,511.82 M1ND+IFR-AK-CAZ-SC(4) 4,686.74 52.40 233.38 3,569.84 3,437.33 -1,488.75 -2,006.86 5,942,675.67 527,971.04 0.12 1,557.89 MWD+IFR-AK-CAZ-SC(4) 4,781.01 52.41 234.02 3,627.35 3,494.84 -1,532.97 -2,067.05 5,942,631.21 527,911.03 0.54 1,604.18 MWD+IFR-AK-CAZ-SC(4) 4,872.05 52.29 233.38 3,682.96 3,550.45 -1,575.65 -2,125.15 5,942,588.32 527,853.11 0.57 1,648.85 MWD+IFR-AK-CAZ-SC(4) 4,965.22 52.24 232.56 3,739.98 3,607.47 -1,620.02 -2,183.97 5,942,543.71 527,794.47 0.70 1,695.25 MWD+IFR-AK-CAZ-SC(4) 5,057.33 52.42 231.30 3,796.27 3,663.76 -1,664.98 -2,241.36 5,942,498.53 527,737.26 1.10 1,742.19 MWD+IFR-AK-CAZ-SC(4) 5,148.60 52.91 231.44 3,851.62 3,719.11 -1,710.28 -2,298.05 5,942,453.01 527,680.76 0.55 1,789.44 MWD+IFR-AK-CAZ-SC(4) 5,242.26 52.88 232.34 3,908.13 3,775.62 -1,756.38 -2,356.83 5,942,406.68 527,622.18 0.77 1,837.56 MWD+IFR-AK-CAZ-SC(4) 5,335.97 52.90 232.59 3,964.67 3,832.16 -1,801.91 -2,416.09 5,942,360.92 527,563.10 0.21 1,885.13 MVVD+IFR-AK-CAZ-SC(4) 5,429.57 52.86 232.00 4,021.15 3,888.64 -1,847.56 -2,475.14 5,942,315.04 527,504.24 0.50 1,932.81 MWD+IFR-AK-CAZ-SC(4) 5,520.26 53.00 231.69 4,075.82 3,943.31 -1,892.26 -2,532.04 5,942,270.12 527,447.53 0.31 1,979.47 MWD+IFR-AK-CAZ-SC(4) 5,613.49 53.02 231.09 4,131.92 3,999.41 -1,938.73 -2,590.22 5,942,223.42 527,389.53 0.51 2,027.95 MWD+IFR-AK-CAZ-SC(4) 5,706.18 52.85 229.78 4,187.78 4,055.27 -1,985.84 -2,647.24 5,942,176.09 527,332.71 1.14 2,077.01 MWD+IFR-AK-CAZ-SC(4) 5,798.29 52.96 230.29 4,243.34 4,110.83 -2,033.03 -2,703.55 5,942,128.68 527,276.59 0.46 2,126.14 MWD+IFR-AK-CAZ-SC(4) 5,892.61 52.91 230.16 4,300.19 4,167.68 -2,081.18 -2,761.39 5,942,080.31 527,218.94 0.12 2,176.28 MWD+IFR-AK-CAZ-SC(4) 5,983.98 52.85 230.25 4,355.33 4,222.82 -2,127.81 -2,817.37 5,942,033.46 527,163.16 0.10 2,224.84 MVD+IFR-AK-CAZ-SC(4) 6,075.42 52.90 231.51 4,410.52 4,278.01 -2,173.81 -2,873.93 5,941,987.24 527,106.79 1.10 2,272.78 MWD+IFR-AK-CAZ-SC(4) 6,169.20 52.94 232.48 4,467.06 4,334.55 -2,219.87 -2,932.89 5,941,940.94 527,048.02 0.83 2,320.88 MWD+IFR-AK-CAZ-SC(4) 6,261.89 52.93 232.45 4,522.93 4,390.42 -2,264.94 -2,991.54 5,941,895.65 526,989.56 0.03 2,367.96 MWD+IFR-AK-CAZ-SC(4) 6,354.13 52.94 232.59 4,578.52 4,446.01 -2,309.72 -3,049.95 5,941,850.64 526,931.33 0.12 2,414.76 MWD+IFR-AK-CAZ-SC(4) 6,448.00 52.91 232.64 4,635.11 4,502.60 -2,355.20 -3,109.45 5,941,804.93 526,872.01 0.05 2,462.28 MWD+IFR-AK-CAZ-SC(4) 6,539.90 52.82 231.61 4,690.59 4,558.08 -2,400.17 -3,167.28 5,941,759.73 526,814.37 0.90 2,509.25 MWD+IFR-AK-CAZ-SC(4) 6,632.46 52.90 230.97 4,746.48 4,613.97 -2,446.32 -3,224.86 5,941,713.36 526,756.98 0.56 2,557.37 MWD+IFR-AK-CAZ-SC(4) 6,724.08 52.86 230.21 4,801.77 4,669.26 -2,492.70 -3,281.30 5,941,666.76 526,700.73 0.66 2,605.69 MWD+IFR-AK-CAZ-SC(4) 6,817.41 52.86 230.31 4,858.12 4,725.61 -2,540.26 -3,338.51 5,941,618.98 526,643.71 0.09 2,655.23 MWD+IFR-AK-CAZ-SC(4) 6,908.00 52.94 231.43 4,912.77 4,780.26 -2,585.86 -3,394.56 5,941,573.16 526,587.86 0.99 2,702.75 MWD+IFR-AK-CAZ-SC(4) 7,003.15 52.83 231.80 4,970.18 4,837.67 -2,632.97 -3,454.03 5,941,525.82 526,528.57 0.33 2,751.91 MWD+IFR-AK-CAZ-SC(4) 7,092.73 52.72 231.76 5,024.37 4,891.86 -2,677.10 -3,510.07 5,941,481.47 526,472.72 0.13 2,797.97 MWD+IFR-AK-CAZ-SC(4) 7,188.45 52.79 231.97 5,082.30 4,949.79 -2,724.15 -3,570.01 5,941,434.18 526,412.98 0.19 2,847.09 MWD+IFR-AK-CAZ-SC(4) 7,280.49 53.05 231.56 5,137.80 5,005.29 -2,769.60 -3,627.68 5,941,388.51 526,355.49 0.45 2,894.52 MWD+IFR-AK-CAZ-SC(4) 7,371.75 53.52 231.11 5,192.36 5,059.85 -2,815.30 -3,684.80 5,941,342.58 526,298.55 0.65 2,942.19 MWD+IFR-AK-CAZ-SC(4) 7,464.59 53.52 231.93 5,247.55 5,115.04 -2,861.75 -3,743.24 5,941,295.91 526,240.31 0.71 2,990.65 MWD+IFR-AK-CAZ-SC(4) 7,558.61 53.51 231.49 5,303.46 5,170.95 -2,908.59 -3,802.57 5,941,248.83 526,181.17 0.38 3,039.53 MWD+IFR-AK-CAZ-SC(4) 9/2/2014 5:05:50PM Page 4 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit ND Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Nor-thing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,651.73 53.33 231.52 5,358.95 5,226.44 -2,955.14 -3,861.10 5,941,202.06 526,122.84 0.20 3,088.09 MWD+IFR-AK-CAZ-SC(4) 7,744.47 54.89 230.81 5,413.32 5,280.81 -3,002.26 -3,919.62 5,941,154.72 526,064.51 1.79 3,137.22 MWD+IFR-AK-CAZ-SC(4) 7,837.45 56.99 230.12 5,465.39 5,332.88 -3,051.29 -3,979.02 5,941,105.45 526,005.31 2.34 3,188.30 MWD+IFR-AK-CAZ-SC(4) 7,930.40 58.53 229.23 5,514.98 5,382.47 -3,102.17 -4,038.95 5,941,054.34 525,945.59 1.84 3,241.24 MWD+IFR-AK-CAZ-SC(4) 8,022.45 59.45 228.79 5,562.40 5,429.89 -3,153.92 -4,098.50 5,941,002.36 525,886.25 1.08 3,295.03 MWD+IFR-AK-CAZ-SC(4) 8,115.79 62.36 228.67 5,607.78 5,475.27 -3,207.71 -4,159.80 5,940,948.33 525,825.18 3.12 3,350.93 MWD+IFR-AK-CAZ-SC(4) 8,209.20 65.34 227.26 5,648.95 5,516.44 -3,263.86 -4,222.05 5,940,891.94 525,763.15 3.47 3,409.22 MWD+IFR-AK-CAZ-SC(4) 8,298.43 67.96 226.72 5,684.31 5,551.80 -3,319.73 -4,281.95 5,940,835.83 525,703.48 2.99 3,467.15 MWD+IFR-AK-CAZ-SC(4) 8,393.31 70.80 225.22 5,717.72 5,585.21 -3,381.45 -4,345.78 5,940,773.86 525,639.90 3.34 3,531.06 MWD+IFR-AK-CAZ-SC(4) 8,486.36 70.13 225.62 5,748.84 5,616.33 -3,443.01 -4,408.24 5,940,712.07 525,577.69 0.83 3,594.75 MWD+IFR-AK-CAZ-SC(4) 8,579.02 70.79 226.07 5,779.83 5,647.32 -3,503.84 -4,470.89 5,940,651.00 525,515.29 0.85 3,657.73 MWD+IFR-AK-CAZ-SC(4) 8,671.87 70.72 225.12 5,810.43 5,677.92 -3,565.17 -4,533.52 5,940,589.42 525,452.92 0.97 3,721.22 MWD+IFR-AK-CAZ-SC(4) 8,762.85 70.94 225.15 5,840.31 5,707.80 -3,625.80 -4,594.43 5,940,528.56 525,392.25 0.24 3,783.93 MVVD+IFR-AK-CAZ-SC(4) 8,855.55 70.88 224.47 5,870.63 5,738.12 -3,687.94 -4,656.16 5,940,466.17 525,330.77 0.70 3,848.20 MWD+IFR-AK-CAZ-SC(4) 8,949.24 71.14 223.98 5,901.11 5,768.60 -3,751.43 -4,717.95 5,940,402.45 525,269.24 0.57 3,913.80 MWD+IFR-AK-CAZ-SC(4) 9,041.21 73.30 222.67 5,929.20 5,796.69 -3,815.14 -4,778.03 5,940,338.51 525,209.42 2.71 3,979.56 MWD+IFR-AK-CAZ-SC(4) 9,134.03 75.39 221.06 5,954.24 5,821.73 -3,881.70 -4,837.67 5,940,271.72 525,150.05 2.80 4,048.16 MWD+IFR-AK-CAZ-SC(4) 9,224.13 77.64 219.89 5,975.25 5,842.74 -3,948.34 -4,894.54 5,940,204.85 525,093.46 2.80 4,116.75 MWD+IFR-AK-CAZ-SC(4) 9,318.27 79.75 219.36 5,993.71 5,861.20 -4,019.44 -4,953.41 5,940,133.53 525,034.88 2.31 4,189.86 MWD+IFR-AK-CAZ-SC(4) ., 9,410.01 81.02 217.89 6,009.03 5,876.52 -4,090.10 -5,009.86 5,940,062.65 524,978.71 2.10 4,262.45 MWD+IFR-AK-CAZ-SC(4) 9,503.22 82.12 216.46 6,022.70 5,890.19 -4,163.57 -5,065.57 5,939,988.97 524,923.30 1.92 4,337.82 MWD+IFR-AK-CAZ-SC(4) 9,597.65 82.78 214.56 6,035.10 5,902.59 -4,239.77 -5,119.94 5,939,912.56 524,869.24 2.11 4,415.87 MWD+IFR-AK-CAZ-SC(4) 9,689.12 83.22 212.31 6,046.25 5,913.74 -4,315.53 -5,169.96 5,939,836.61 524,819.53 2.49 4,493.33 MWD+IFR-AK-CAZ-SC(4) 9,783.69 83.02 209.50 6,057.58 5,925.07 -4,396.08 -5,218.18 5,939,755.88 524,771.63 2.96 4,575.51 MWD+IFR-AK-CAZ-SC(4) 9,876.21 82.41 205.77 6,069.32 5,936.81 -4,477.36 -5,260.74 5,939,674.43 524,729.40 4.05 4,658.23 MWD+IFR-AK-CAZ-SC(4) 9,968.62 81.97 202.00 6,081.88 5,949.37 -4,561.06 -5,297.81 5,939,590.60 524,692.67 4.07 4,743.17 MWD+IFR-AK-CAZ-SC(4) 10,001.20 82.03 201.24 6,086.42 5,953.91 -4,591.05 -5,309.69 5,939,560.56 524,680.90 2.32 4,773.56 MWD+IFR-AK-CAZ-SC(4) 10,052.53 82.26 200.00 6,093.43 5,960.92 -4,638.64 -5,327.60 5,939,512.90 524,663.19 2.43 4,821.75 INC+TREND(5) 10,053.20 82.28 199.99 6,093.52 5,961.01 -4,639.27 -5,327.83 5,939,512.28 524,662.96 3.25 4,822.38 MWD+IFR-AK-CAZ-SC(6) 7-5/8"x 9-7/8" 10,146.01 84.78 198.29 6,103.98 5,971.47 -4,726.38 -5,358.06 5,939,425.06 524,633.09 3.25 4,910.49 MWD+IFR-AK-CAZ-SC(6) 10,242.38 87.12 194.66 6,110.79 5,978.28 -4,818.54 -5,385.31 5,939,332.80 524,606.21 4.47 5,003.55 MWD+IFR-AK-CAZ-SC(6) 10,338.36 88.96 191,07 6,114.07 5,981.56 -4,912.04 -5,406.66 5,939,239.22 524,585.23 4.20 5,097.73 MWD+IFR-AK-CAZ-SC(6) 10,432.77 91.28 187.18 6,113.88 5,981.37 -5,005.23 -5,421.63 5,939,145.98 524,570.63 4.80 5,191.39 MWD+IFR-AK-CAZ-SC(6) 10,526.38 90.79 184.51 6,112.18 5,979.67 -5,098.33 -5,431.16 5,939,052.86 524,561.47 2.90 5,284.77 MWD+IFR-AK-CAZ-SC(6) 10,575.84 92.09 182.91 6,110.94 5,978.43 -5,147.67 -5,434.36 5,939,003.51 524,558.47 4.17 5,334.19 MWD+IFR-AK-CAZ-SC(6) 10,621.73 93.47 181.10 6,108.72 5,976.21 -5,193.47 -5,435.96 5,938,957.70 524,557.05 4.96 5,380.02 MWD+IFR-AK-CAZ-SC(6) 10,663.39 92.64 180.96 6,106.50 5,973.99 -5,235.06 -5,436.71 5,938,916.11 524,556.47 2.02 5,421.61 MWD+IFR-AK-CAZ-SC(6) 10,715.07 91.64 179.98 6,104.57 5,972.06 -5,286.70 -5,437.13 5,938,864.47 524,556.25 2.71 5,473.24 MWD+IFR-AK-CAZ-SC(6) 10,809.21 90.15 179.51 6,103.10 5,970.59 -5,380.83 -5,436.71 5,938,770.36 524,557.04 1.66 5,567.29 MWD+IFR-AK-CAZ-SC(6) 9/2/2014 5::05:50PM Page 5 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 10,905 14 89.75 176.52 6,103.18 5,970.67 -5,476.69 -5,433.39 5,938,674.52 524,560.75 3.14 5,662.98 MWD+IFR-AK-CAZ-SC(6) 11,000.88 90.31 174.55 6,103.13 5,970.62 -5,572.14 -5,425.94 5,938,579.12 524,568.58 2.14 5,758.10 MWD+IFR-AK-CAZ-SC(6) 11,095.40 90.77 173.79 6,102.24 5,969.73 -5,666.16 -5,416.34 5,938,485.14 524,578.55 0.94 5,851.74 MWD+IFR-AK-CAZ-SC(6) 11,122.88 90.55 173.96 6,101.92 5,969.41 -5,693.48 -5,413.41 5,938,457.83 524,581.59 1.01 5,878.94 MWD+IFR-AK-CAZ-SC(6) 11,190.53 89.80 173.96 6,101.71 5,969.20 -5,760.76 -5,406.29 5,938,390.60 524,588.98 1.11 5,945.92 MVVD+IFR-AK-CAZ-SC(6) 11,284.82 88.15 173.79 6,103.40 5,970.89 -5,854.49 -5,396.23 5,938,296.91 524,599.41 1.76 6,039.25 MVVD+IFR-AK-CAZ-SC(6) 11,378.47 88.62 174.48 6,106.04 5,973.53 -5,947.61 -5,386.66 5,938,203.84 524,609.34 0.89 6,131.98 MWD+IFR-AK-CAZ-SC(6) 11,474.65 89.39 175.95 6,107.71 5,975.20 -6,043.44 -5,378.64 5,938,108.05 524,617.74 1.73 6,227.47 MWD+IFR-AK-CAZ-SC(6) 11,570.00 89.48 177.08 6,108.65 5,976.14 -6,138.61 -5,372.85 5,938,012.92 524,623.92 1.19 6,322.38 MWD+1112-AK-CAZ-SC(6) 11,665.35 87.67 177.74 6,111.02 5,978.51 -6,233.82 -5,368.54 5,937,917.73 524,628.60 2.02 6,417.39 MWD+IFR-AK-CAZ-SC(6) 11,759.43 85.29 177.99 6,116.80 5,984.29 -6,327.66 -5,365.04 5,937,823.92 524,632.47 2.54 6,511.04 MWD+IFR-AK-CAZSC(6) 11,852.95 86.30 179.15 6,123.66 5,991.15 -6,420.89 -5,362.71 5,937,730.71 524,635.17 1.64 6,604.14 MWD+IFR-AK-CAZ-SC(6) 11,948.41 86.48 178.95 6,129.67 5,997.16 -6,516.15 -5,361.13 5,937,635.46 524,637.13 0.28 6,699.28 MWD+IFR-AK-CAZ-SC(6) 12,043.07 85.35 179.21 6,136.41 6,003.90 -6,610.55 -5,359.62 5,937,541.07 524,639.02 1.22 6,793.58 MWD+IFR-AK-CAZ-SC(6) 12,136.85 88.89 180.29 6,141.12 6,008.61 -6,704.20 -5,359.21 5,937,447.44 524,639.80 3.95 6,887.15 MWD+IFR-AK-CAZ-SC(6) 12,231.93 90.72 178.93 6,141.44 6,008.93 -6,799.27 -5,358.56 5,937,352.38 524,640.83 2.40 6,982.14 MWD+IFR-AK-CAZ-SC(6) 12,324.07 88.69 179.02 6,141.92 6,009.41 -6,891.39 -5,356.91 5,937,260.28 524,642.84 2.21 7,074.14 MWD+IFR-AK-CAZ-SC(6) 12,419.29 86.55 179.30 6,145.87 6,013.36 -6,986.51 -5,355.52 5,937,165.17 524,644.62 2.27 7,169.16 MWD+IFR-AK-CAZ-SC(6) 12,513.36 86.36 179.22 6,151.69 6,019.18 -7,080.39 -5,354.31 5,937,071.31 524,646.20 0.22 7,262.94 MWD+IFR-AK-CAZ-SC(6) 12,608.27 86.47 179.72 6,157.62 6,025.11 -7,175.11 -5,353.43 5,936,976.60 524,647.45 0.54 7,357.57 MWD+IFR-AK-CAZ-SC(6) 12,701.64 88.95 178.23 6,161.35 6,028.84 -7,268.38 -5,351.76 5,936,883.35 524,649.50 3.10 7,450.73 MWD+IFR-AK-CAZ-SC(6) 12,796.45 90.14 175.98 6,162.11 6,029.60 -7,363.06 -5,346.97 5,936,788.70 524,654.66 2.68 7,545.18 MWD+IFR-AK-CAZ-SC(6) 12,889.73 90.73 175.15 6,161.40 6,028.89 -7,456.06 -5,339.76 5,936,695.74 524,662.24 1.09 7,637.87 MWD+IFR-AK-CAZ-SC(6) 12,984.47 90.84 175.26 6,160.10 6,027.59 -7,550.46 -5,331.84 5,936,601,38 524,670.54 0.16 7,731.94 MWD+IFR-AK-CAZ-SC(6) 13,079.04 89.96 174.94 6,159.44 6,026.93 -7,644.68 -5,323.76 5,936,507.20 524,678.99 0.99 7,825.82 MWD+IFR-AK-CAZ-SC(6) 13,173.48 89.23 174.10 6,160.11 6,027.60 -7,738.68 -5,314.75 5,936,413.24 524,688.38 1.18 7,919.45 MWD+IFR-AK-CAZ-SC(6) 13,268.34 89.21 174.22 6,161.40 6,028.89 -7,833.04 -5,305.09 5,936,318.93 524,698.40 0.13 8,013.42 MWD+IFR-AK-CAZ-SC(6) 13,362.75 89.19 173.84 6,162.72 6,030.21 -7,926.93 -5,295.28 5,936,225.09 524,708.59 0.40 8,106.91 MWD+IFR-AK-CAZ-SC(6) 13,456.85 90.67 174.70 6,162.83 6,030.32 -8,020.56 -5,285.88 5,936,131.52 524,718.36 1.82 8,200.15 M1ND+IFR-AK-CAZ-SC(6) 13,551.60 91.05 175.39 6,161.41 6,028.90 -8,114.94 -5,277.70 5,936,037.17 524,726.92 0.83 8,294.19 MWD+IFR-AK-CAZ-SC(6) 13,645.80 90.03 174.99 6,160.52 6,028.01 -8,208.80 -5,269.80 5,935,943.35 524,735.19 1.16 8,387.72 MWD+IFR-AK-CAZSC(6) 13,740.81 88.94 175.52 6,161.38 6,028.87 -8,303.48 -5,261.94 5,935,848.72 524,743.42 1.28 8,482.06 MWD+IFR-AK-CAZSC(6) 13,836.50 87.43 175.23 6,164.41 6,031.90 -8,398.81 -5,254.23 5,935,753.43 524,751.51 1.61 8,577.07 MWD+IFR-AK-CAZ-SC(6) 13,931.63 88.63 176.69 6,167.68 6,035.17 -8,493.64 -5,247.53 5,935,658.63 524,758.59 1.99 8,671.61 MWD+IFR-AK-CAZ-SC(6) 14,026.15 89.53 177.99 6,169.20 6,036.69 -8,588.05 -5,243.15 5,935,564.26 524,763.35 1.67 8,765.80 MWD+IFR-AK-CAZ-SC(6) 14,119.57 87.72 178.63 6,171.44 6,038.93 -8,681.40 -5,240.39 5,935,470.93 524,766.48 2.05 8,858.99 MWD+IFR-AK-CAZ-SC(6) 14,214.33 86.13 179.96 6,176.52 6,044.01 -8,776.01 -5,239.23 5,935,376.33 524,768.02 2.19 8,953.51 MWD+IFR-AK-CAZ-SC(6) 14,310.01 86.18 180.25 6,182.94 6,050.43 -8,871.47 -5,239.40 5,935,280.88 524,768.22 0.31 9,048.92 MWD+IFR-AK-CAZ-SC(6) 14,404.10 86.71 179.75 6,188.77 6,056.26 -8,965.38 -5,239.40 5,935,186.98 524,768.60 0.77 9,142.77 MWD+IFR-AK-CAZ-SC(6) 14,499.05 86.35 178.43 6,194.52 6,062.01 -9,060.14 -5,237.90 5,935,092.23 524,770.48 1.44 9,237.42 MWD+IFR-AK-CAZ-SC(6) 9/2/2014 5:05:50PM Page 6 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-02 Project: Kuparuk River Unit TVD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-02:105.1+27.41 @ 132.51usft(Doyon 141) Well: 2E-02 North Reference: True Wellbore: 2E-02 Survey Calculation Method: Minimum Curvature Design: 2E-02 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,593.86 86.81 177.95 6,200.17 6,067.66 -9,154.73 -5,234.91 5,934,997.66 524,773.84 0.70 9,331 85 MWD+IFR-AK-CAZ-SC(6) 14,687.81 89.33 178.71 6,203.34 6,070.83 -9,248.58 -5,232.17 5,934,903.84 524,776.95 2.80 9,425.55 MWD+IFR-AK-CAZ-SC(6) 14,781.39 88.85 178.56 6,204.82 6,072.31 -9,342.12 -5,229.94 5,934,810.31 524,779.55 0.54 9,518.96 MWD+IFR-AK-CAZ-SC(6) 14,876.07 88.87 178.29 6,206.71 6,074.20 -9,436.75 -5,227.34 5,934,715.71 524,782.53 0.29 9,613.43 MWD+IFR-AK-CAZ-SC(6) 14,971.08 88.42 178.80 6,208.95 6,076.44 -9,531.70 -5,224.93 5,934,620.78 524,785.32 0.72 9,708.24 MWD+IFR-AK-CAZ-SC(6) 15,065.28 90.69 179.79 6,209.69 6,077.18 -9,625.89 -5,223.77 5,934,526.61 524,786.85 2.63 9,802.33 MWD+IFR-AK-CAZ-SC(6) 15,160.27 90.74 179.31 6,208.50 6,075.99 -9,720.86 -5,223.02 5,934,431.64 524,787.98 0.51 9,897.22 MWD+IFR-AK-CAZ-SC(6) 15,255.23 89.55 177.27 6,208.26 6,075.75 -9,815.78 -5,220.19 5,934,336.75 524,791.19 2.49 9,991.98 MWD+IFR-AK-CAZ-SC(6) 15,349.41 86.49 175.11 6,211.51 6,079.00 -9,909.67 -5,213.94 5,934,242.89 524,797.81 3.98 10,085.60 MWD+IFR-AK-CAZ-SC(6) 15,444.36 87.20 176.01 6,216.74 6,084.23 -10,004.19 -5,206.60 5,934,148.41 524,805.53 1.21 10,179.81 MWD+IFR-AK-CAZ-SC(6) 15,538.36 86.73 175.48 6,221.72 6,089.21 -10,097.80 -5,199.64 5,934,054.84 524,812.86 0.75 10,273.12 MWD+IFR-AK-CAZ-SC(6) 15,633.93 86.68 176.10 6,227.21 6,094.70 -10,192.96 -5,192.63 5,933,959.72 524,820.25 0.65 10,367.97 MWD+IFR-AK-CAZ-SC(6) 15,728.40 88.50 178.00 6,231.18 6,098.67 -10,287.21 -5,187.78 5,933,865.50 524,825.48 2.78 10,461.99 MWD+IFR-AK-CAZ-SC(6) 15,823.47 91.69 180.68 6,231.03 6,098.52 -10,382.25 -5,186.68 5,933,770.47 524,826.95 4.38 10,556.94 MWD+IFR-AK-CAZ-SC(6) 15,918.42 92.05 181.37 6,227.93 6,095.42 -10,477.14 -5,188.38 5,933,675.59 524,825.63 0.82 10,651.83 MVVD+IFR-AK-CAZ-SC(6) 16,012.97 90.79 180.66 6,225.58 6,093.07 -10,571.64 -5,190.05 5,933,581.09 524,824,33 1.53 10,746.33 MWD+IFR-AK-CAZ-SC(6) 16,107.61 89.40 180.29 6,225.43 6,092.92 -10,666.27 -5,190.84 5,933,486.46 524,823.92 1.52 10,840.93 MWD+IFR-AK-CAZ-SC(6) 16,203.00 87.02 179.14 6,228.41 6,095.90 -10,761.61 -5,190.36 5,933,391.14 524,824.78 2.77 10,936.19 MWD+IFR-AK-CAZ-SC(6) 16,296.92 87.20 178.92 6,233.14 6,100.63 -10,855.39 -5,188.78 5,933,297.37 524,826.74 0.30 11,029.87 MWD+IFR-AK-CAZ-SC(6) 16,390.88 88.92 179.79 6,236.32 6,103.81 -10,949.29 -5,187.72 5,933,203.49 524,828.17 2.05 11,123.67 MWD+IFR-AK-CAZ-SC(6) 16,485.70 89.13 180.99 6,237.94 6,105.43 -11,044.09 -5,188.36 5,933,108.69 524,827.90 1.28 11,218.44 MWD+IFR-AK-CAZ-SC(6) 16,578.75 89.89 181.16 6,238.73 6,106.22 -11,137.12 -5,190.11 5,933,015.67 524,826.52 0.84 11,311.47 MWD+IFR-AK-CAZ-SC(6) ' 16,672.43 88.60 181.36 6,239.97 6,107.46 -11,230.77 -5,192.17 5,932,922.02 524,824.84 1.39 11,405.13 MWD+IFR-AK-CAZ-SC(6) 16,767.75 88.52 181.53 6,242.36 6,109.85 -11,326.03 -5,194.57 5,932,826.76 524,822.81 0.20 11,500.42 MWD+IFR-AK-CAZ-SC(6) 16,862.47 88.59 183.01 6,244.75 6,112.24 -11,420.64 -5,198.32 5,932,732.14 524,819.44 1.56 11,595.10 MWD+IFR-AK-CAZ-SC(6) 16,956.77 88.53 184.00 6,247.12 6,114.61 -11,514.73 -5,204.09 5,932,638.04 524,814.05 1.05 11,689.34 MWD+IFR-AK-CAZ-SC(6) 17,052.11 88.07 183.65 6,249.95 6,117.44 -11,609.82 -5,210.44 5,932,542.94 524,808.07 0.61 11,784.59 MWD+IFR-AK-CAZ-SC(6) 17,146.85 88.66 183.99 6,252.65 6,120.14 -11,704.31 -5,216.75 5,932,448.43 524,802.14 0.72 11,879.24 MWD+IFR-AK-CAZ-SC(6) 17,241.56 87.51 183.99 6,255.82 6,123.31 -11,798.74 -5,223.34 5,932,353.99 524,795.93 1.21 11,973.84 MW13+IFR-AK-CAZ-SC(6) 17,336.41 87.61 183.14 6,259.86 6,127.35 -11,893.32 -5,229.23 5,932,259.40 524,790.42 0.90 12,068.57 MWD+IFR-AK-CAZ-SC(6) 17,431.77 89.48 183.13 6,262.28 6,129.77 -11,988.50 -5,234.44 5,932,164.20 524,785.58 1.96 12,163.88 MWD+IFR-AK-CAZ-SC(6) 17,525.78 8922 183.06 6,263.34 6,130.83 -12,082.37 -5,239.52 5,932,070.33 524,780.88 0.29 12,257.86 MWD+IFR-AK-CAZ-SC(6) 17,572.07 89.91 183.96' 6,263.69 6,131.18 -12,128.57 -5,242.35 5,932,024.12 524,778.23 2.45 12,304.13 MWD+IFR-AK-CAZ-SC(6) 17,635.00 89.91 183.96 6,263.79 6,131.28 -12,191.35 -5,246.70 5,931,961.33 524,774.14 0.00 12,367.03 PROJECTED to TD 4-1/2"x 6-3/4" 17,652.00 89.91 183.96 6,263.82 6,131.31 -12,208.31 -5,247.87 5,931,944.37 524,773.03 0.00 12,384.02 PROJECTED to TD 9/2/2014 5:05:50PM Page 7 COMPASS 5000.1 Build 65 '_ Cement Detail Report illi , 2E-02 c_onocophilhps String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 8/10/2014 22:15 8/11/2014 01:15 2E-02 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement 500'above Kup 8,700.0 10,065.0 No Yes Yes Cement C Q Pump nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 6 6 600.0 1,100.0 Yes 20.00 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(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 8,700.0 10,065.0 387 G 77.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 105.0 5.10 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Page 1/1 Report Printed: 9/22/2014 Cement Detail Report Oi 2E-02 Conoc°Phillips String: Surface Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/3/2014 07:30 8/3/2014 11:38 2E-02 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Surface Casing Cement to surface 26.0 4,141.0 No 200.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 2 4 600.0 1,100.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 26.0 3,601.0 1,754 G 603.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.93 5.96 11.07 141.0 6.00 Additives Additive Type Concentration Conc Unit label ALC 100.0#of Blend Additive Type Concentration Conc Unit label Freshwater 5.957 gal/sx Additive Type Concentration Conc Unit label D186 Accelerator 0.3 gal/sx Additive Type Concentration Conc Unit label D046 Anti-foam 0.3 %BWOB Additive Type Concentration Conc Unit label D065 Dispersant 0.9 %BWOB Additive Type Concentration Conc Unit label D145A Dispersant 0.05 gal/sx Additive Type Concentration Conc Unit label D044 Salt 10.0 %BWOW Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 3,601.0 4,151.0 225 G 64.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.62 5.38 12.00 149.0 6.00 Additives Additive Type Concentration Conc Unit label Freshwater 5.382 gal/sx Additive Type Concentration Conc Unit label Litecrete 100.0#of Blend Additive Type Concentration Conc Unit label D046 Anti-foam 0.2 %BWOB Additive Type Concentration Conc Unit label D185 Dispersant 0.07 gal/sx Additive Type Concentration Conc Unit label D177 Retarder 0.01 gal/sx Page 1/1 Report Printed: 9/22/2014 Z'2.k- o-?: RECEIVED ConocoPhillipsSEP 15 ;:31:, TRANSMITTAL AOGCC -BATA- it/ r M C Ny21 FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2E-02 DATE: 09/11/2014 Transmitted: Kuparuk River Unit, Alaska 2E-02 1 hardcopy report and 1 CD CANRIG Final well report mud logging data for 2E-02, 8/8/2014; table of contents, mud logging equipment; general well details, geologic data, pressure/formation strength, drilling data, show reports, daily reports and formation logs; color log presentations, one set each for 2N-322, 322PB1, 322PB2; Formation log MD &TVD Gas ratio MD &TVD Combo log MD &TVD Drilling dynamics MD & TVD CD contains daily reports, DML data, final well report, LAS files, Log PDF files, remarks, TIFF files, show report Please promptly sign, scan and return electronically to Sandra.D.Lemke(d COP.com CC: 2E-02 transmittal folder, production well files, eSearch RECEIVED j...e.eet; SEP 15 7` Receip ate: ql � kS 1 AOGCC .- GIS-Technical Data Management I ConocoPhillips (Anchorage, Alaska I Ph: 907.265.6947 � c� `�_i_� - i1THESTAJE U ; . i__ _ 333 Wesi $evenlh Avenue c Arcnoraoe A;asn 99501-3572 C�Ul'Llt\(,k ,L,�ti 1 ,11.\LLL :ASC ' Man 902 279 1433 "1C G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E-02 ConocoPhillips Alaska, Inc. Permit No: 214-078 Surface Location: 4750' FNL, 5120' FEL, Sec. 36. Tl 1M. R09E, UM Bottomhole Location: 1138' FNL, 5104' FEL, Sec. 14, T1ON, R09E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, l t;"1-e-- /-r. -- Cathy Y. Foerster Chair DATED this 3 day of July, 2014. RECEIVED STATE OF ALASKA JUN 20 2014 fALASKA OIL AND GAS CONSERVATION COMMISSION 2 '�� " 0-144(:. PERMIT TO DRILL A pppc 20 AAC 25.005 1 a Type of Work. lb Proposed Well Class Development-Oil ❑ Service-Winj ❑, Single Zone E., 1 c.Specify if well is proposed for Drill ❑✓ 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 U Blanket U Single Well 11 Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59-52-180, KRJ 2E-02 - 3 Address 6 Proposed Depth 12.Field/Pool(s): P.O Box 100360 Anchorage,AK 99510-0360 MD: 17657' • TVD: 6252' ' Kuparuk River Field - 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number) Surface.4750'FNL,5120'FEL,Sec.36,T11 N, RO9E,UM• ADL 25658,25665,25670 • Kuparuk Oil Pool . Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date 4085'FNL,5170'FEL,Sec.2,T1ON, RO9E,UM s 2584,2586,2179 7/14/2014 Total Depth 9 Acres in Property. 14 Distance to 1138'FNL, 5104'FEL,Sec. 14,T1ON,RO9E, UM• 256 �C,?,j Nearest Property <1 mile '4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL ' 134 feet 15 Distance to Nearest Well Open Surface:x- 529972 y- 5944172 Zone- 4• GL Elevation above MSL , 106 feet to Same Pool 2E-04,2250' 16.Deviated wells. Kickoff depth • 500 ft. 17 Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle •90° deg Downhole.3800 psig . Surface:3191 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' Coldset II 13.5" 10.75" 45.5# L-80 Hyd 563 4079' 28' 28' 4107' 3234' 1560 sx ALC, 195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hyd 563 10087' 28' 28' 10115' 6103' 315 sx Class G 6 75" 4.5" 11.6# L-80 Hyd 563 7542' 9915' 6082' 17657' 6252' open hole slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft) Junk(measured) Casing Length Size Cement Volume MD TVD 1 Conductor/Structural Surface Intermediate Production Perforation Depth MD(ft). Perforation Depth TVD(ft). 20 Attachments. Property Plat❑ BOP Sketch❑ Drilling Program ❑✓ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21.Verbal Approval Commission Representative: Date 22. I hereby certify that the foregoing is true and correct Contact Lindsey Hunter @ 263-6427 Email Lindsey.Hunter anconocophillips.com Printed Name G. L. Alvord Title Alaska Drilling Manager SignatureAz_oc& Phone:265-6120 Date 6(29(CJi( . 1 Commission Use Only Permit to Drill API Number Permit ApprovalSee cover letter Number Q I L O 7__g 50-02_9 —0235 I/— 00-00 Date lin fl/ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other. 509 fie 5 7 to 3 57(2 f) 5 , Samples req'd: Yesjil No ❑ Mud log req'd: Yes❑ No❑ 1 v) f c r rr,r�l ii iz' C(ky)e- ? H2S measures: Yes No ❑ Directional svy req'd: Yes No El c1 c-to/5 -to be- p ro vi4 pacing exception req'd: Yes ❑ No ❑ Inclination-only svy req'd: Yes El No❑ -- 40, cc/�/�iror r—c✓IE L , w1�ty1 cD,�-V )l -te .4/. Approved b �0/2012 ThiCOMMIafION4©t r m thIG4Aa e�of a rov�l 20 AAC 2 .00 Date 7— — Form 10-401LCd7/l,/l 4- permitT�� ��� f!r� PP ( �g� ',�,!!/ ConocoPhillips Alaska, Inc. )1."- Post /Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 May 29, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2E-02,A Kuparuk A5 Sand Water Injector Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots pre-produce water injector well from the 2E pad. The expected spud date for this well is July 14th,2014. It is planned to use Rig Doyon 141. 2E-02 is planned to be a horizontal Kuparuk A5 sand pre-produced water injector. The planned pre-production time is approximately 3 months. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-4,107'MD/ 3,234'TVD.The intermediate section will be drilled with 9-7/8"bit and run 7-5/8"casing to 10,115'MD/6,103'TVD. The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/- 17,657'MD/6,252'TVD. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005(a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035(d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Lindsey Hunter at 263-6427 (lindsey.hunter cr cop.com or Chip Alvord at 265-6120.) Sincerely, Chip Alvord Drilling Manager I Application for Permit to Drill Document Kuparuk Well 2E-02 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2E-02 Location Summary Requirements of 20 AAC 25.005(c)(2) .In application J6r a Permit to Drill must he accompanied ht•each of the following terns,except for an I/env already on Ile with the commission and identified in the application (2)u plat iclennf rig the properly and the property's owners and showing (Arnie coordinates of the proposed location o/the well al the surface,at the lop of each objective fonmianon,and al total depth, referenced to governmental section Ines (B)the coordinates of the proposed location o1 the well al/he surface,referenced to the s/cte plane coordinate sruem for this state as maintained by the \rational Geodetic Survey in the National Oceanic and Itrnos'pheric.ddniinistr•emrnr, ((')the proposed depth of the it ell at the top of each oh/ec iiia formation and at toted depth. Location at Surface 4750'FNL, 5120' FEL, Sec 36, T 11N,R009E,UM NGS Coordinates RKB Elevation 133.9'AMSL Northings: 5,944,172.37' Eastings: 529,972.21' Pad Elevation 105.9'AMSL Location at Top of 4085'FNL,5170'FEL,Sec 2,T1ON,R009E,UM Productive Interval (Kuparuk A5 Sand) NGS Coordinates Measured Depth, RKB: 10,015' Northings: 5,939,538.40' Eastings:524,663.73' Total Vertical Depth, RKB: 6,093' Total Vertical Depth, SS: 5,959' Location at Total Depth 1138' FNL, 5104'FEL, Sec 14,T1ON,R009E,UM NGS Coordinates Measured Depth,RKB: 17,657' Northings: 5,931,926.77' Eastings: 524,765.94' Total Vertical Depth,RKB: 6,252' Total Vertical Depth, SS: 6,118' and (D)other Information required by 20 -LI( 25 050th), Requirements of 20 AAC 25.050(b) if ca well is to he intentionally deviated, the application jor a Permit to Drill(Furor 10-4011 oust (1/include a plat drawn to a suitable Sc ale. showing the path of the proposed w ellhore. including all adjacent wellhores within 200 feet of any portion oldie proposed it ell Please see Attachment: Directional Plan .1nd 12)for all ire//s wrthu 200 feet of the proposed we//bore (II list the manes of the operators of those wells, to the extent that those names are disown or discoverable in public records.and show that each named operator has been furnished a copy of the application bi•certified mad. or (B)state that the applicant is the only affected owner The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied ht'each of the following terns,except for an item already on file with the COMM! won and tdentfied in the application (3)a diagram and de.scripton of the blow out prevention equipment(ROPE)as required by 20.1.-IC 25 035 20_-1,4('25 036 or 20.1,IC 25 037,cis applicable, Please reference BOP schematics on file for Doyon 141. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) In application for a Permit to Ili ill muct he accompanied hr each of the following items,except for an item already on,file with the romams,von and identified in the application (4)information on drilling ha=_cries, including (.4)the maximum downhole pressure that may he encountered,criteria used to determine rt,and maximum potential surface pressure based on a methane gradient The maximum potential surface pressure(MPSP) while drilling 2E-02 is calculated using an estimated maximum reservoir pressure of 3,800 psi(11.9 ppg),a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A5 sand at 6,093' TVD (WP05): A Sand Estimated. BHP = 3,800 psi A Sand estimated depth(WP06) =6,093' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 609 psi (6,093' TVD * 0.10 psi/ft) MPSP=BHP—gas column =3,191 psi (3,800 psi—609 psi) (B)data on potential gas=ones The well bore is not expected to penetrate any shallow gas zones. Ind 0C')data concerning potential causes'of hole problems such as ahnormalh'geo-pressured strata, lost circulation_ones,and:ones 11101 17(11'e a propensity for differential sticking See attached 2E-01 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) In application,for a Permit to Di ill must he accompanied hi'each of the following items except tar an item already on file a ith the commission and identified in the application (5)a description of the Procedure for conducting formation integral'tests,as required under 2(1 1.1( 25(13110, A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) an application for a Permit to Di ill must he acc'ompanie'd In'each of the following/terns,except for an item already on file with the c oninnssron and identified in the application (6)a a omplete proposed casing and cementing program as required by 20.-LIC 25 030,and a description of aim slotted finer,pre-perforated hoer,or screen to he installed Casing and Cement Program Casing and Cementing Program CsglTbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) Size (/ ) Grade Conn. O O (h) Cement Program (in) 16 24 62.5 H-40 Welded 78 Surf 106/106 Existing Cement to Surface with 10-3/4 13 45.5 L-80 Hydril 4,079 Surf 4,107/3,234 1,560 sx ALC Lead 11.02 ppg, 1/2 563 195 sx DeepCRETE Tail Slurry 12.0 ppg Hydril 315 sx Class G at 15.8 ppg w/TOC at 7-5/8 9-7/8 29.7 L-80 563 10,087 Surf 10,115/6,103 9,000 MD 4 1/2 6-3/4 11.6 L-80 563 Hydril 7,542 9,915/6,082 17,657/6,252 Open hole slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) -In application fin.a Permit to I trill must he accompanied hr each of the following items,esc cut for an item already on file with the commission and identified in the application (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the dialling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8"Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.5-11.5 10.6-12.2 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5-10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A-Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A -Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application fora Permit 10 Drill mist he accompanied hr each of the following items,except for an item alreadi on file with the eonunission and identified in the application The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. Ferguson, Victoria L (DOA) From: Hunter, Lindsey L <Lindsey.Hunter@conocophillips.com> Sent: Monday,June 30, 2014 7:25 AM To: Ferguson,Victoria L(DOA) Subject: RE: KRU 2E-02 (PTD 214-078) Attachments: 2E-02 Permit to Drill .doc Follow Up Flag: Follow up Flag Status: Flagged Victoria, I apologize for the errors. Please see the attached revised PTD, corrections are highlighted in yellow. 1. The BOPs should be tested to 3500 psi. 2. The planned mud weight will be up to 12.2 to accommodate the potentially high reservoir pressure. (Note we are setting the intermediate in the A5 reservoir but do not expect to see high pressures until crossing a fault in the lateral, so the mud weight upper limit was not changed for the intermediate.) Please note the figures below for cement yields. Surface: Cement 10-3/4" casing from shoe @ 4,107' MD to surface with 1560 sks Arctic LiteCRETE @ 11.02 ppg and '"205 sks DeepCRETE @ 12.0 ppg.Volumes are based on 250%excess in permafrost and 50%excess below the permafrost.Top of the tail slurry is designed @3,607'MD. Lead slurry: Arctic LiteCRETE @ 11.02 ppg yielding 1.93 ft3/sk (4,107'-1,510')x 0.3637 ft3/ft x 1.5(50%excess) = 1,145 ft3 below permafrost (1,510'—110')x 0.3637 ft3/ft x 3.5(250%excess)= 1,783 ft3 above permafrost (110'x 0.6381 ft3/ft x 1.0)=71 ft3 Total volume= 1,783+ 1,145+71=2,999 ft3=> 1554 sks("'1,560 sks) Tail slurry: DeepCRETE @ 12.0 ppg yielding 1.63 ft3/sk (4,107'—3,607')x 0.3637 ft3/ft x 1.5(50%excess)=273 ft3 annular volume 80'x 0.53997 ft3/ft=44 ft3 shoe joint volume Total volume=273+44=317 ft3=>195 sks(-205 sks) Intermediate: 1 Cement from 10,115' MD to 9,000' MD with Class G+adds @ 15.8 PPG. Assume 40% excess annular volume. Tail Slurry: (10,115' —9,000')X 0.2148 ft3/ft X 1.4 (40%excess)=336 ft3 annular vol. 80' X 0.2394 ft3/ft=20 ft3 shoe joint volume Total volume= 336+20=356 ft3=>307 sks(315 sks)@ 1.16 ft3/sk System: 315 sks Class G+additive @ 15.8 PPG yielding 1.16 ft3/sk Let me know if there is anything else you need. Y g Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska DB&W 907-265-6427 lindsey.hunte ii conocophillips.com From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Friday, June 27, 2014 9:50 AM To: Hunter, Lindsey L Subject: [EXTERNAL]IE: KRU 2E-02 (PTD 214-078) Also, please provide the yield on cementing details. From: Ferguson, Victoria L (DOA) Sent: Friday,June 27, 2014 9:43 AM To: Hunter, Lindsey L(Lindsey.Hunter(aconocophillips.com) Subject: KRU 2E-02 (PTD 214-078) Lindsey, 1. The MPSP is 3191 psi but the BOPs are only being tested to 3000 psi. 2. The maximum formation pressure is 11.9 ppg EMW while the planned mud weight is 10.6 to 11.5 ppg. Please advise, 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 ferquson(a)alaska.gov 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 2 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-4,107' MD/3,234'TVD as per directional plan (wp05). Survey with MWD,Gamma, Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe track and 20'of new hole. Perform formation integrity test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at 8,323' MD/5,686' TVD,back ream to the surface shoe at 4,107' MD ensuring a clean hole(this will allow us to drill and clean up the shales quickly,reducing exposure time). 9. RIH to top of HRZ and directionally drill to 10,115' MD/6,103'TVD,landing in the Kuparuk A5 sand. Wellsite geologist will call intermediate TD. Circulate and rotate until shakers are clean. Short trip to top of shales at 8,323' MD on elevators,if no tight spots encountered continue to POOH. (If tight spots are encountered,back ream through only tight areas to top of HRZ,run back to bottom and circulate bottoms up.) 10. POOH on elevators. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from TD at 10,115' MD to surface. 13. Pump cement job as per Schlumberger proposal,top of cement to be 9,015' MD(500'MD above top of the Kuparuk C sands). 14. Set slips and install wellhead x 7-5/8"packoff and test to 3500 psi. 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,stethoscope,periscope, microscope, neutron density,and sonic for top of cement evaluation.) 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 20. Directionally drill 6-3/4"hole geosteering though the Kuparuk A5 sand to TD 17,658'MD as per directional plan(wp05). 21. Circulate hole clean and POOH. Log top of cement with sonic on trip out of hole. 22. Lay down Production BHA. 23. PU and run 4-1/2", 11.6#,Hydril 563 slotted liner. The top of liner will be placed at 9,915' MD,allowing for 200'of overlap in the 7-5/8"casing. 24. Set liner hanger. Slackoff and set liner top packer. 25. Monitor well for flow for 15 minutes 26. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 27. Flow check well for 30 minutes to run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) In application fui a Permit to Drill niustc be accompanied by each of the fo/louvng items,except for an item a/reads•on file with the couuniuiarr and identified in the application (14)a general description of hoer the operator plans to dispose of drilling mud and cuttings and a statement of-whether the operator intends to meatiest authorr_ation under?0.4/C'25 080 for an annular disposal operation in the well, • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class 11 disposal well(IR- 18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification.(659-7212). Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic CongcoPhillips Alaska, Inc. Post Office Box 100360 )111V Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 May 29,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 1 Re: Application for Permit to Drill Well 2E-02,A Kuparuk A5 Sand W ter Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onsho grassroots pre-produce water injector well from the 2E pad. The expected spud date for this well is July 14th,20 . It is planned to use Rig Doyon 141. 2E-02 is planned to be a horizontal Kuparuk A5 sand pre-produced ater injector. The planned pre-production time is approximately 3 months. The surface section will be drilled with/3-1/2"bit and run 10-3/4"casing to+/-4,107'MD/ 3,234'TVD. The intermediate section will be drilled with 9-7/8" 'it and run 7-5/8"casing to 10,115'MD/6,103'TVD. The production hole will be drilled with 6-3/4"bit and run 4-1 j'slotted liner to+/- 17,657'MD/6,252'TVD. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by,20 ACC 25.035 (d)(2). 3. Casing and Cementing program. , 4. A drilling fluids program summary. 5. A proposed drilling program. , 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any question§ or require further information, please contact Lindsey Hunter at 263-6427 (lindsey.hunter@cop.com or Chip Alvord at 265-6120.) Sincerely, Chip Alvord Drilling Manager ORIGINAL Application for Permit to Drill Document Kuparuk Well 2E-02 Well Name Requirements of 20 AAC 25. 5(f) The well for which this pplication is submitted will be designated as 2E-02 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must h sacconipained by each of the following items,except for an item already on file with the commission and identified in the application (2)a plat identifi'mg the properth and the properts''s owners and showing (A)the coordinates of the proposed location of Nie well cit the surface.at the top of each objective formation and at total depth. referenced to !, governmental section hoes (B)the coordinates of the proposed location of t/ic,w ell at the surface referenced to the state plane coordinate system for this state as maintained h_i' the.Vational Geodetic Surlvey in the National Oceabic and Atmospheric Administration (C)the proposed depth of the well at the top of each\blective formation and at total depth, ,\ Location at Surface 4750' FNL, 512,0' FEL, Sec 36, T 11N,R009E,UM NGS Coordinates ,� RKB Elevation 133.9' AMSL Northings: 5,944,172.37' Eastings: 529,972.21' \� Pad Elevation 105.9' AMSL N Location at Top of 4085' FNL, 5170' FEL,\ ec 2,T1ON,R009E,UM Productive Interval (Kuparuk A5 Sand) NGS Coordinates Measured Depth, RKB: 10,015' Northings: 5,939,538.40' Eastings: 524,663.73' al Vertical Depth, RKB: 6,093' T 1 Vertical Depth, SS: 5,959' Location at Total Depth 1138' FNL, 5104' FEL, Sec 14,T10 R009E,UM NGS Coordinates Measu d Depth, RKB: 17,657' Northings: 5,931,926.77' Eastings: 524,765.94' Total Vertical Depth, RKB: 6,252' Total Vertical Depth, SS: 6,118' and (D)other information i equired by 20.4 4C 25 050(h) Requirements of 20 AAC 25.050(b) Ifo well is to be intentionally deviated the application for a Permit to Drill(Form 10-401)must (1)include a plat,droll n too suitable scale,show mg the pati of the proposed is el/bore. including all a acent wellhores within 200 feet of any portion of the proposed well. Please see Attachment: Directional Plan And (2)for all we/ls within 200 feet of the pi oposed wellbore (A)list the names oldie operators of those wells to the extent that those names are known or discoverable\s public records and show that each named operator has been furnished a cop of the application by certified mail, or (B)state that the applicant is the only affected owner The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must he accompanied by each of the following items.except,for an item already on file with the commission and identified in the application (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 A.AC 25 035. 20 A.40 25 036.or 20 AAC 25 037.as applicable, Please reference BOP schematics on file for Doyon 141. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) In application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application (4)information on drilling ha_ards, including (A)the maximum downhole pressure that may he encountered.criteria used to determine it.and macinmm7 potential surface pressure based on a methane gradient. The maximum poteial surface pressure (MPSP) wF) le drilling 2E-02 is calculated using an estimated maximum reservoir p assure of 3,800 psi (11.9 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A5 sand at 6,093' TVD (WP05): A Sand Estimated. BHP = 3,800 psi A Sand estimated depth (WP06) = 6,093' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full g s column = 609 psi (6,093' TVD * 0.10 psi/ft) MPSP =BHP—gas c ,lumn =3,191 psi (3,800 psi—609 psi) (B)data on potential gas=ones. The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata. lost circulation=ones,and=ones that have a propensity for differential sticking. See attached 2E-01 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each o 1hie folloring items,except,for an item already on file with the commission and identified in the application (5)a description of the procedure for conducting formation integrity tests: s required under 20 AAC 25 030(f), A procedure is on file with the commission forperformingT's. �PERS. - �.�)� Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) .lin application for a Permit to Drill must be accompanied by each of the following items,except- ran items already on file with the commission and identified in the application (6)a complete proposed casing and cementing program as required hi-20 A.-IC 25 030.and a descr tion of ani'slotted liner,pre-perforated liner, or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) ��) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/106 Existing Cement to Surface with 10-3/4 1�2 45.5 L-80 563i1 4,079 Surf 4,107/3,234 1,560 sx ALC Lead 11.02 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Hydril 315 sx Class G at 15.8 ppg w/TOC at 7-5/8 9-7/8 29.7 L-80 563 10,087 Surf 10,115/6,103 9,000 MD 4 1/2 6-3/4 11.6 L-80 563i1 7,542 9,915/6,082 17,657/6,252 Open hole slotted liner Diverter System Information Requirements.of 20 AAC 25.005(c)(7) An application for a Permit to Drill must he accompanied by each of the following items.except for an item already on file lath the commission and identified to the application. RIGINAL (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid'Program Requirements of 20 AAC 25.005(c)(8) ,1n application for a Permit to Drill must he accompanied hr each of the following Items,except for an item already on file with the commission and identified in the application. (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.5- 11.5 10.6-11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC < 6 <6 HTHP Fluid Loss at 160 F N/A". < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appy tt RNI tated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A- Application is not for an exploratory or stratigraphic test well. N Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A- Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) .an application for a Permit to Drill must be accompanied by each of the following items,except fin an item already on file with the commission mid identified in the application The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. ORIGINAL 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-4,107' MD/3,234' TVD as per directional plan (wp05). Survey with MWD,Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3000 psi(annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and hii iii g assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe traa-an3 20''`of new`TioTe`P6rfoTfi"i formation integrity test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. I 8. Directionally drill to the top of the HRZ at-8,323' MD/5,686' TVD,back ream to the surface shoe at 4,107' MD ensuring a clean hole(this will allow us to drill and clean up the shales quickly,reducing exposure time). 9. RIH to top of HRZ and directionally drill to 10,115' MD/6,103' TVD,landing in the Kuparuk A5 sand. Wellsite geologist will call intermediate TD. Circulate and rotate until shakers are clean. Short trip to top of shales at 8,323' MD on elevators, if no tight spots encountered continue to POOH. (If tight spots are encountered,back ream through only tight areas to top of HRZ,run back to bottom and circulate bottoms up.) 10. POOH on elevators. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from TD at 10,115' MD to surface. 13. Pump cement job as per Schlumberger proposal,top of cement to be 9,015' MD(500' MD above top of the Kuparuk C sands). 14. Set slips and install wellhead x 7-5/8"packoff and test to 3500 psi. 15. Flush 10-3/4"x 7-5/8"annulus with water,foal wedbSr dienei to freeze protect. 16. Lay down 5"DP. r 17. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gantra,resistivity, stethoscope,periscope, microscope, neutron density, and sonic for top of cement evaluation.) 18. RIB and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 20. Directionally drill 6-3/4"hole geosteering though the Kuparuk A5 sand to TD 17,658' MD as per directional plan(wp05). 21. Circulate hole clean and POOH. Log top of cement with sonic on trip out of hole. 22. Lay down Production BHA. 23. PU and run 4-1/2", 11.6#,Hydril 563 slotted liner. The top of liner will be placed at 9,915' MD,allowing for 200' of overlap in the 7-5/8"casing. 24. Set liner hanger. Slackoff and set liner top packer. Q3' iNYaflG 4110 25. Monitor well for flow for 15 minutes 26. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 27. Flow check well for 30 minutes to run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. RDMO. Discussion of Mud and Cuttings Disposal andAnnular Disposal Requirements of 20 AAC 25.005(c)(14) ,-In application for a Permit to Drill mestc he accompanied hi each of the fol/ou'irfgitehik,except for an nem already on file n rth the comnncsron and identified in the application (11)a general description of hou the operator plans to dispose of drilling mad and cuttings and a statement of it hether the operator intends to request authorcatron under_'0.1.1('25 080,for an annular disposal operatrrrn to the a ea, • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well(1R- 18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. 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ORIGINAL 0 )0 l0 )0 10 )0 l0 (O (O CO CO CO CO CO u) LO IO o j o m W a O Cu U) C c O > 0 0 0 If) O V CO CO V CO CO )0 CO CO l0 O 0 0 0 r N CO 10 CO r CO O 0 N CO )0 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N 0 0 W 0) 0) N 7 M M Cu v �MC�') J _` V V N 7 "0 Ol m (0 co O V CO 0) CO CO CO r Z d N N N N N N N 0 O 0 M 0) CO 0 CO U) Y 7 0 00 CO N N N N N N N r N M O C V Y r N- r r r r r r CO O ) V N 0 CO 10 w 0) 0) 0 0 O 0) O 0 0 0 0) 0) O 0) CO CO + + E of of CD- of of of 0)- • f o o CT; O O o O ai o 0 v v 7 Q C 3-' N N N N N N N N N N N N N N N N Y £ y N 6 6 6 10 0 l0 0 10 10 U) N 10 )0 10 )0 )0 O C C a) .0 2 a) 7 Cu Cu ` ❑ W w a a 1- 2 W r N- r N- r r r CO V 0 CO 0) 1) O N CO M CO CO CO CO CO r r V V r N N CO r r r N- r N- r N- CO O CO 0 V CO W 0 Cuci 'o p) .- e- a ,- v- ,- N- N- N- t- n- N- C 0 C ^ V V V V V V V V V V V V V V V V i L LV V V V V V V V V V V V V V V V O 0) O O O O O O 0 0) O O 0 0) 0) 0) N 2 a)0 a In In L.0 U) U!) 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OC y C < < 01 L u.I- r2 Z in 0 .,7 -20 -20170 2433 (-3Y42, U) 11 'a mIn inu_ cnluiunU- 0, + + + 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 y) O O O O O O O NN N t E 0 0 2 2 2 2 2 2 ^ Cy IL C N 07 O '=..' 0 Q C CO (Un Cl)U "' C 0 d << < 0 U U U 0 0 0 0 0 0 0 O O OD v U) v Y Y Y CO O O O O r N N V CO O O CO In Q < Q C') Lii M IO IO IO 0 U) O IO U) N Ni N O U) 0 d COM 0 COM IO IO COIO f0 IO CO (O f0 CO IO 10 l0 0) W' d' Q' s- N CO V t0 c0 N- CO O 0 N 0) R U LL LL IL <n ' . a V) Z ' 000000 0 w 0 0 0 0 0 0 0 CO CO CO aD V 0 0 0 0 0 0 0 0) C) c0 M n 0) o) O N 0 0 0 0 0 O 0) 0) O 0) O 0) O V N 0 0 0 0 0 O 0) 0) O 0) O 0) CO CO N CO V )0 10 (O N- CO 0) 0a-- N CO 7 NNNNNNN 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O 0 0 0 0 0 O 0 0 O O 0 0 0 0 W W W W W W Li, O O O O O O O O O O O6 O N N N N N N N ,CV V V V V V V V V d EECEEEE N N N NNCANN N 0 Cu a) 10 CO IO aS I0 E a a a a a a a_ N °� ,11 V 4' i0 In co U0 co i0 i0 '�' 0 0 0 0 0 0 0 Q 0. d 0_ 0. 0. 0. 1 Q Cu N N N N N N N Q r ` 0000000 7 W W W W W W W 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Cu, O CO NNNNNNN 0 0 O O 0 0 0 U) 0 10 0 U) 0 10 O U) O O O O O N O O O O O O O '- M V r O N V r O C Cl) a) 0 0 0 )0 )0 `- O L , IO O O (O (O 10 6 IO ` ❑ 0 0 0 0 U) V ^ 0 O N N 10 0 O 10 CO r CO CO C v > Z O 3 F- v N V CO- O x- O E j W W N U C2 rnN (V o 0 0 Z Y O_ W N A 0 O 0 O 0 0 0 0 0 0 0 0 0 0 0 N 0 0 0 0 0 O CO 0 0 0 6 )n 0 0 0 0 0 0 0 0 o a o 0 0 'a 0 0 0 0 0 o a 0 0 o co co vi ui IO yO 0 0 0 0 T o a0 0 0 0 0 0 .= 0 0 0 .= 0 0 0 0 0 o N O O x-- x- x- Cu N 0 0 0 0 0 m 0 0 0 m o 0 0 0 0 0 O. E _ _ V V O O N M V 10 (O L- CO Y O O N .4- - M O O a I) O s- U) c : FO- <L �. a .w3. N Cl) Q ou 0 0 T Cu . v a 0) ) C O 0 o 0 0 v . ca 0 a` in 3 3 o u) a ORIGINAL a o m 0 0 0 _ 0 0 0 0 0 0 0 0 U) N 7 7 O O m 0 ci of C', C) v V 7 U rn 0 W O Z a` 2 0 0 U 12 co a m ro E m • N N 7 Q t N 2 c a co d a F- 2 w ai U a C 0 2 L m y o 2 rt C O O C Na; '— Q G U Gl C 5 a fva , O C U• d V im ` v ▪ y C O M b o 412 '. w o y U a � m t .),'D Ti a V >0 - t' N 0 O O 0 0 O 0 O O O O O F 2. z° ('n o a 0 0 0 0 0 O 0 0 0 0 0 -� .- 0 0 0 0 0 0 0 0 0 0 O 0 °... 0. (B o E p a O w cm o • C n J U a) 0) m Q. g m Z N O (p m E CC Y 0 CN d O) CC = 7 Op O_ O_ O_ a N N ( ONCO Y Y F Q F H CO CO m 0 0 0 0 0 0 0 0 0 0 0 rn rn CD rn m CO rn CO CD CO rn Nt U) NL() O O N6 kri (0 (•) N. O N- co N M 0 0) m N. CO p_W CO 0 0 0) N. 0 O CO N 0 V d 50) `7,. (O (O (O V) N co. N (O COCO c- O t > Cu) N Q L C N t O Nr r 0) co CO 0) O V • Z O 0 O .a M O) 0 V CO 0) CO V r N O N 7 N (V 3 e = 1� (OO N COCr N N OO < O a 0 N (0 .. C O y a W 00 (O (O 0 N 0 CO 0 00 Ti) Q O 7 (p (p w N Q = CO W O) Oi M O N 0o V 0) Z Y a a N n a (o N N N M CLci C O (Q' • a+ N N � , � IGINAL a 0 m 0 0 0 LO c c Cl.. 00 0 0 0 NN O O CO O M M Hm ° Z a O O ( Y LO a m m E W Y N N 0 Q C d a> E 2 a m m ` c 0 U) 00 1- 2 w ci U ii c O .c w N a) 2 CY c m o C y U p a U C0.) y ° C G U O O L •� o . w v 0 a U m K N CC y L U) N W a 00 0WI Ce 0 0 J 2 Z N a Q. 2 2 0 2 2 M co 0 NO O O V 4 0 M 7 O E CO cc; CO n N V O co O N- h (O 0 O tG M u) O 0) N co 0 (00 N- 0- E N u) n 0 N M O A- 1` A- O 10 N• r CO () N •O n CO n O• co N O N N m N M oo TO p OV) r r m Di m U (13 O 7601-40c° 0 `- 0s- 00T3001-d007600 Z O O m O O C lL C CO O LL I- i IL IQ U. 7.) LL LL LL IL LL D U. IL lL LL "O w LO 0 0 L 0 Q O r G O O 0 O O 0 O O O O = O O N O O M O 0 ° O t L O O u) u) O N u) 0 0 0 0) O U s- N M O fM t0 N N M O M CO M M M N CO n N N R N N M N N 0. O O v ,� CO m CO 6 CO 0 (0 O (0 - m CO 0 to co N co CO m U) m ui (1) CO COO (0 CO (0 E co m 0 CO 0 C0O 0 O N 0 L- 0 0 .- 0 0 C0O 0 0 A- 0 0 CO O O N 0 a E r r C C C r r C t y -c C .c C C v r v v t .e -c = r t r 'C C W o N 2 m m .9 2 � 2 m m m m 9 m g w .9 2g g m m m m m 2 0 ap O m m y m m CO m m m N m in U) u) CO ( m CO CO CO m CO m (.0 CO CO CO CO >- CO u) N ,- CLO V C09 Ul M N N COOu) N CO 0 V CO r r COO CO CO CC. r 0 a) U) O V u) u) 4 O MpO co V O0NCOU) NCOCD I` n 0 O 0 ( COO) M h N- 6 CM CM V V V V M) O coM coN ( N N N N N N h w C? Y f f Y vi ui v> (n (n L9- vi vi U-11 vi ui )ri '9 ui ui vi KC ((i vi 1 + -- c 15. 0 U N 0 M r N V CO CO V CO CD CO 0 CO V V h CO CO CO CO N M CO CO a r O. N CO N N O u> CO u) CO O CO CO ti N u) O CO u) CO V t•-• N CO CO U vi CO at/ W CD CCI V M N6 - M 6 V O W O o 6 f` 4 a O n co CON CO O CO CO 0) CO 0 h 0) 0) 0) 0) u) UO V u) I- LC1 r M N. J C.) . m O h O O I- co O 0) 0) CO 1,-. O N CO O 0 V CO U0 (O O) N Z N M M M Y Y f f f '9i Cn (O (Q CO 1. I. a' a(i aD IC I1 Cn N + O o) 0 0 0 0 V 0 OM 0) CO 0 0) 0 V N 0 N V) 0 u) CO 0 V O CO V 0 O O co O 0 0) V h O) N O 0) 0) 0) CD CO O CO N 0) n CO. f0 y O O a0 O O O V O M M V O O O N O CO u) N N N NN. co N M 0 - r 0 0) I- 0 0 CO CO 0) 0 0 0 L- N N V V CO V CO 0 0) 0 CO 0 M V V u) d O LE a N N n V M V CO CO O O ., '- 7. '- l- N N N N p j N N N 0 (0 u) (0 CO (O CO CO CO f0 (0 (0 CO O (0 (0 CO (0 (0 (O CO CO C CO CD O t C :°_.3 r Z O O O N N > on' 0 0 0 N u) M_ V CO CO CO CO 0 CO_ _V I- CO A- CO - V M (O CO 1- L- 0) CO u) CO CS0 c Y W LLl d '0 O O O O O n N u ) O O O V O CO O u) CO 1` O Al: N O n N N N .c o O O O CO CO V (+I U) V V •- O N 00 O6 0 0 m O V (O u) 0I 6 h O 0 O V 0 0) 0 CO M CO M M O 0 CO O 0 N 0 h N CO N CO 0 N p, N c O N d W N CO u) I\ M CO M M .- '- M CO CO O r 0 ,- M V CO co O co O N CO (0 Z > Y CL CL N d 0 — N c. 0 0 O O O O O O O N N N M M M V u) N h 2 w 2 eL c (0 O N '`a CV a3 M O cri C U. N c 7 C 0 o Q a a a 0 O O N O O r a) v N A \ O d M 0 a 43 ORIGINAL e e 9 Q CL L3Ec-- -5.6ou m 8 0 8 e cmaai� O tim•ume�i sQ 'Mil mem.. mO V J • PPM H Zmine ( PAH v�i� 0 3N'n' a O l'-i3 e CC) NDN n IMP:.qm P: : .S• 1 N noo888 .14 CD • jm�'v�iom e I e e0 to :. `ai CY) 2101 AN N `_N poi �C, r4..1 x ca d g a RE a a z\ i,--1 �r M .4".-',32E���� \ r� o n \ v a Lb X N O '— N N O O Z� r 11)1 N I CO V. K I I \ rM 1. il".Yr N O jC \ _:( __,) c) r IIIIIIPF LO > ,. a co iii 0 ` N 0 Q eo�l o+ � _ � . 0, ____4a:a N N N ZD a." N ii 6. 0 Wu3 rp 7 n o I L a m r N N CO P OD C• N c0 :6103 CJD M in CD V O n O c" lo'llet T 1 LL N O O d O m O O O O O O I 3 O O O O O O O O O O c CO CO CC) O) N r 1 1 1 r tr: (uousn 000E) (+)utaoN/(-)upnoS I ORIGINAL O O i w N b N O L1. O N N U M V 1.0 i r Q N d7 ILL OR ! GINAL 2E-02 wp05 Surface Location In. 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Range: 009 IE L! t Y: 5944172.37 Meridian: IU Section:136 IFNL v 14749.9931 'FEL . 15119.8735 I Transform Quit I Help a 2E-02 wp05 Intermediate Casing a CPAI Coo-dinate Converter . „,,„ , 4 o I , From: — To: Datum: (NAD27 Region: lalaska J Datum: (NAD27 Region: Ialaska C LatitudelLongitude Decimal Degrees +1 C Latitude/Longitude 'Decimal Degrees _`I C UTM Zone: 1 I— South C UTM Zone: IT rue f- South if ' C• State Plane Zone:14 J Units: Ius-ft C State Plane Zone: 14 , Units: Ius-ft , L C Legal Description(NAD27 only t7 Legal Description(NAD27 only) -Starting Coordinates Legal Description X: 1524633.73 Township: 010 IN .' Range: 009 'E Y: 15939538.40 Meridian: IU ,1 Section:12 IFNL 14085.0947 'FEL LI 1521179 Transform Quit I Help L.. .., ORIGINAL 2E-02 wp05 TD CPAI Coordinate Converter o ar From: — To: Datum: NAD27 ] Region Ialaska J Datum: INAD27 Region: Ialaska J r. Latitude/Longitude (Decimal Degrees C Latitude/Longitude (Decimal Degrees .� C UTM Zone: r South C UTM Zone:IT rue I— South C State Plane Zone:IT-E. Units: F.:FE C State Plane Zone: ITrue I Units: ,us-ft C Leda!Decriptinn(NAD 27 only) a Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 1524765.94 Township: 010 N Range: 009 IE �I Y: 15931926.77 Meridian: IU J Section:114 IFNL J 1138.1977 (FEL J 5103.6648 Transform Quit I Help �®- a ORIGINAL N 0. .c N c O N N U C N b C c C O 10 oN 3 o m o momU O M 9 _a O - td. N R W O w x o N Z N• O (/) O c o C RS LI' ta d Nj L Q y CU 0 o .4 w _ . 3 n- I: IIi W ■- 0 CO 0 U M Z O a v Q O U INC ^c w�w,, •,/w . N a ;, ' w n D W _I £ 1 N C r N J o O W> ( a _ _ 2 0. � K Q 0. a, � � c, _ m o N O N 0rxmO ° O P. o mm CNI O YY (, O Q O Zrnd i 0 v N do .s o m o • i i N W �� mc cy m o = ° .m v (/) 0 Wa O 1171 _ j, U 02 R N UG T T — U ` E FF- / ,V Y Y a a N V < °r° ,- C 76 0 to i� CO j 0i N ORIGINAL a 1 <1) C) 0 0 c 0 ea C) x Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y OC tll N N O1 tl) N 00000 N 00000 N N W fq N N (q N otCI as a) 0 0 0 0 0 O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 44 0. W 'W 'W 'W W W W W W W W W 'W 'W W W W W 'W l0 N N N N N 1 ( 1 1 1 1 1 1 1 1 ( ( ( ( 1 ( ( 1 CA 000000 000000 0 N 0 0 0 0 N N N 0010 (0 N N N 0 0 0 000000 000) 000 0 (0 (0000 CO m 01 CO CO CO CO CO CO CO CO CO CO CO N m CO 0 CO (0 a) CO (0 CO CO CO CL LL 0 LL LL CL. a a a a a a a a LL 0. CL CL a a LL LL LL LL a. 0p U a b m E O O U U .)) U t U t 8 O U U U t U t U UO U (0 U U 8 t 8 0 m E C (0CaCaCOC0) C (0 C03C0C0 C0CNCN C (...) Z`.E A LL m LL a LL V LL 9 LL A LL O W a W m LL m LL m LL 19, LL 1a N a) N a) N a) N N N N y w N W O N a) A a) a) N o U o U o 0 0 °� o °U' o °6,' o U o U o U o U o U 0 o 0 E C C C C C C C C C C C E d m 2 m 2 m a1 m 2 2 2 m a) a) a) a) m m a) co N m d m m c a$ c m E. m c 03 c GI c 8 0 c (0 c m c a c m c m c m c M a) N m A a) N a) N a) N a) a) a) a) a) a) a) N a) a) a) N a) a) m 000000 000 U 000000 000000 0 O o V' O) V 0) CO o (0 CO (0 I- co c0 u) o s- r 0) m N O N O CO u) CO u) 0) u) CO V h CO V CO V CO COV. N M Cl (1) M U V: V' V' V' V' I- r t0 V a) t` O coC) O 0 0) O (C N N C O VN VN uV VV ' ' ) u) ' ' V' h a) d• a) V'V• a) O u) Q1 Q) u) u) 0 Vu N N a- r m m N LI- 0 0 o o O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O 0 (0 0 (0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d 0 N- u) u) u) N 10 O u) ((i 6 u) ui u) (n u) u) O u) O ui ui O N R N N N N N N N N u) h N. C.- h 1- r h 1- r on N u) N N O V' N fl.$ e0 a0 10 (0 u) (O (0 (0 10 N 10 N N N u) N u) 1- u) N. V' (0 .- mm N C ,_ ,_ a- s_ O p� V co co O (0 u) CO u) CO u) 01 0 (0 0 (0 0 O 10 0 Is- M M N N C 0) h 0) N O N O N N 0 N O N CO N 00 u) N Cl V' 1- (0 N CO CO m o r) 0) a) C) o a o ai (+) O) I ai In 0) n O) 1- o - 6 u) a) n vi N- N N a- N a- V' CO V. CO u) NCO I- CO N CO N. CO m 0 CO M (0 (0 N O A 0 0 W V) (O _ _ _ _ O O h0 h 1s- N N- N u) N V. V' V' V' O N M M O N -a a0 M a0 M ,- 00 a- CO 0) N N N N M M N Is- V CO 01 v a0 10 co u) (O u) (0 u) N N: 17 O .- 0 .- 0) ' Oi 6 a0 (O n n 0 di m L N N N N N N N N CO u) co CO CO M CO M (0 M M O M O a0 CO M N a a= CO CO u) (0 u) (0 0) CO to N u) N (0 N u) N u) N- u) N- M Cr a M N N ,_ r r r .4- 4- d ppo ,,^^ a) V Y/ E O C 0) CO W CO 0) 0 CO CO CO 00 V. CO_ O_ CO 0 M 0 CO O COCO 0) L-0) CO C) M V. W 0 CO0) 0 a a 3 ci, V M V M 00 D1 (0 a) cc; (0 n O r O r O N- O M (0 a06 N 0) (9. 7 U N CO N CO V. V' V' V' 0 0) 0 0) 0) o N N V. u) a) a) V' ol N c E 2 N Oo E N 1 e 2 p W (U Nu) m Io N O N. 0 I N- N N. N u) N a- V V { V' ,- V O N M M O p3. N p CO M CO M 1- (O 7 (7 0) N N N N M CO N r V CO O L 13 N p, t a0 u) a0 u) (O u) (0 u) N h a) 0 a) ' O) (0 e0 (O N I- o (6) Q C 9 C: N d N N 0) N o (0 CON (NM CONCO (NO u0) N u0) N co0N N N N I,- 0 ON- M 7 M VaI N W N 2 0 y ' of 2 z 4 r w si 1 tN 0 O C N ? (° E O (,g c. c I a) 1. LU a « 4) N Z d • c E i o o 3 'T d = N CO N d 0CU CL t N Ti LLI E L U E W LL m 0 N LI- 0 d c 2 2 ;vo -e—. c ,oi a Ts p d d a aOia - ° El C73 t J (p M WOU 3 LL LL M M 0 d (O (0 00 60. N . M M O O v v JJ00 W W Y ' a) O O W W O O O O W W N N Ce X (Op 7 E N N N N V' 8 N N O O O O W W N N Is- r CO CO 0) Cr) O v Q 0. ts N Z M M O O O O O O N N m m 0 0 0 0 0 0 ^O o 01 - m o 0 W W W W W W o o W W W W W W W N 4. Y (V N n' m m N N m m N N N N LL 0' N N N N N N N Q t +' 0a W 0_ 0_ N N CL CL I c c c J J J J J J a) .N O 01 o N co co C C O O 9 0 0 0 0 00 (0 0 CO O CO CO N- 0 0 0 0) 0 O- Z '(0 C N a) w Y W W W W W W W W W W W W W W W W W W W W W W W CO aQ .. 'N @ C N N O.. d N N N N N N N N N N N N N N N N N N N N N e. 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II 1 ! 1 I 1 1111111111111 1 1 ! ! 1 ! 1 ! 1 1 1 1 1 III CO O V O n N co co o O co UOf) N O V C O m n t0 t(1 co N O w ao oe uoiTeJeda = mCU ./05Z) 3 S Q 0 ORIGINAL MD Inc Azi TVD +N/-S +E/-W DLeg TFace Target 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 28 500 2E-02wp05500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 3 800.00 4.50 240.00 799.69 -5.89 -10.20 1.50 240.00 6.24 500 1000 , c 41500.00 22.00 240.00 1478.41 -85.80 -148.60 2.50 0.00 9093 28.00To 17657.18 52549.02 53.16 232.10 2300.00 -451.11 -663.00 3.00 -12.16 473.97 1000 1400 6 7718.95 53.16 232.10 5400.00 -2992.55 -3927.85 0.00 0.00 3127.81 7 8306.13 69.72 225.23 5680.00 -3333.50 -4311.80 3.00 -21.76 3481.95 _ __ _ 8 8894.74 69.72 225.23 5884.00 -372233 -4703.79 0.00 0.00 3884.22 1400 _- 1900 9:24,June 18 2014 10 9 9303.26 93115.58 79.90 221.04 5990.94.11 -4009.811 . -4972.68 000 -22.27. 419033 1900 2400 1110114.9884.53 196.56 6103.00 -4707.83 -5358.28 3.09 -81.04 4891.96 ..ORAL FILTER APPLIED: A 130134.96 84.53 196.56 6104.91 -4726.91 -5363.95 0.00 0.00 4911.23 2400 2800 130311.00 86.01 190.06 6119.43 4897.52 -5404.31 3.77 -77.38 5083.75 140330.13 86.01 190.06 6120.76 -4916.31 -5407.64 0.00 0.00 5102.04 2800 3300 190332.14 86.00 190.00 6120.90 -4918.28 -5407.99 3.10 -102.74 5104.02 2E-02 PB 15Jan14 T1 191038.47 90.58 169.30 6142.22 -5620.26 -5403.52 3.00 -77.97 5805.41 00p00 From Depth To Ss 'SoryopPlon Tool 171139.08 90.58 169.30 6141.20 -5719.11 -5384.83 0.00 0.00 5903.55 3300 3770 28.00 1000.00 2E-024,05(PI881E-02) GYDGCSS 1008.08 2500.08 2E-02,405{Plan:2E4D etwG 181396.61 90.00 177.00 6139.90 -5974.61 -5354.13 3.00 94.26 6157.82 2F-23 PB 220ct13 T2 1000.00 4106.51 0E-0,4005(P00:2E02) 61W1141811-6X-CAT-SC 191606.18 86.17 180.57 6146.91 -6183.94 -5349.69 250 137.09 6366.87 3770 4600 010651 5606.51 2E-01wp05(PIare2E02) Mwo 202188.97 86.17 180.57 6185.89 -6765.39 -5355.50 0.00 0.00 6948.17 6108.51 10115.00 2E-01,P05(8188:28.02) MWP4IR1-All-CAZSSC 10115.00 11615.00 2E-020605 71002E-02) MWO 2112398.54 90.00 177.00 6192.90 -6974.72 -5351.06 2.50 -43.03 7157.22 2F-23 PB 220ct13 T3 4600 5400 10115.00 11651.18 2E-02,05(Plan QE-02) MW0.1813-88LA4SC 222419.33 90.47 176.92 6192.83 -6995.49 -5349.96 2.00 -11.15 7177.94 233804.75 90.41 176.92 6182.96 -8378.88 -5275.51 0.00 0.00 8557.88 5400 6200 CASING DETAILS 24 3821.08 90.00 176.92 6182.90 -8395.18 -5274.63 2.50 179.94 8574.14 2F-23 PB 220ct13 T4 253986.11 86.72 176.53 6187.62 -8559.84 -5265.21 2.00 -173.21 8738.38 TVD MD Name Size 264871.41 86.72 176.53 6238.23 -9442.08 -5211.70 0.00 0.00 9618.21 6200 7000 3233.90 4106.51 10-3/4"x13-1/2" 10-3/4 275025.29 89.80 176.49 6242.90 -9595.59 -5202.34 2.00 -0.73 9771.30 2F-23 PB 220ct13 T5 6103.00 10115.00 7-5/6"09-7/8" 7-5/8 285269.06 89.80 181.37 6243.74 -9839.23 -5197.78 2.00 89.9610014.64 7000 7800 6251.90 17657.18 3-1/2"06-3/4" 3-1/2 297629.75 89.80 181.37 6251.81 -12199.24 -5254.03 0.00 0.0012375.17 9117557 1R 89 nn 1R1 97 F951 40-12226 60 -5154 fill 5 02 1152 4712409 60 2F-20 PR 22f1M19 15 7800 8600 8600 9400 pp##0/360 9400 10200 ' • Zli 10200 11100 • n \ 11100 - 12000 31:2 A 11�w 1i , 30 i lip�' 1, +►`,.k1;•w�; •'r,• ` 1 12000 12900 10,llPNit ; art 1 t41l/i��►1%, ►�• • s;= =�'‘. 12900 13800 An wa r ,- 1� 13800 14700 30,10M,'t ' .QF'•* 11�li� \W4N �_ ,►l•S igit, 4 -.. bey'gift,- �i 14700 15600 :Oil�� • r !� t:Ii�0114,,4,V$W�fir"' �• , ,•� ,. / ,'lA�1 :a: 1►'.V64di� i . 15600 16500 ,'•400 gilltl . ' 6�a0110:1 ®, ► � , ?;� io,, •e '�� cf► ��$...�,1 ;1',4•�' 16500 - --. 17660 60/300 Star ai .:rr►4 X84� 1 Willi: �0li " I 17::: ".4, ,+ems ���ill' , /� l / �Mh.`S, � �•� ��i������•`��q ���.���►�►��i.ri/�r�w\•y� 1�1Ai I`y!�1�•�D..� � " ��` z i11rb111 rirruuri//fir•• ��_ .`_-1��' ' ������ �.��;1•�,1� -90/270 1`••�ir 2� 90 apo• , - so ,„t -120/240 4010, a -=crr,k41111 fiutfn11argw cE► . 1�•e•i/ 1 1 1\ Ziurl141 \�\.� , N111i y -nis •-14�Iptit L. k.. e ( 11• ► e 20 • Nomas! Q+1,ti, �l‘ t. cmc-;;4�����iN-000 1!1" olk klikvt: ,..\AN.v..- -,,.',.,,k-,4-1:.+Srfo" -150/210 �-.:` � `�®®�����/��r/, /1 150 .^c::: -\ VA•4.�:•-•'� 0E-0 -180/180 -1- as 60006 Incorrect -4 u t 2E -$ 2E -e- E -- 2E $ 2E -� P E01.2E-51.PO4V0 � 2E � 2E + 6 -42 2F IIA VO a 2E 2E .e- -A- 2P 1.26,,.11 VO -4- 2E04.2Ea<P61.2E0.P6,VS ..)(-• 2Ea6,2Ea611P6,.2E020551W 2E11,0811.2E11VI .9. 2Ea'copos.E 2E-02 Drilling Risks Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement. Use proper pump rate. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning, stabilized BHA,proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 10.0 ppg.But there is small chance of over pressured pay zone due to the offset well in the neighbor block is 11.0 ppg.Re- estimate the formation pressure based on results from shut in bottom hole pressures taken at near by wells 2F- 11 and 2F-19 as they become available and adjust the mud weight accordingly.Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. 6-3/4" Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 10.0 ppg.But there is small chance of over pressured pay zone due to the offset well in the neighbor block is 11.0 ppg. Re- estimate the formation pressure based on results from shut in bottom hole pressures taken at near by wells 2F- 11 and 2F-19 as they become available and adjust the /� ! Prepared by Lindsey Hunter 3 t mud weight accordingly. Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Stuck pipe Moderate Good hole cleaning, stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Control trip speeds,monitor proper hole fill while tripping,good hole cleaning.Pump or back ream out if necessary. rTh ## I A I Prepared by Lindsey Hunter 2Eo02 05, ConocoPhillips Grass Roots Horizontal al A-Sand Injector Proposed Wellbore Schematic CAMERON 4-W tree,top joint is 4-W 12.6#IBTM Last Edited: Existing Conductor: Hunter-6/18/14 16"62.6#H-40 Drilplex —110' MD/110'TVD 9.3 ppg 3'A'Camco DS Nipple 2.875" XMD/XTVD Cameo 3-'h"x1-r" 13-1/2"Surface Hole MMG Mandrel @ x' MD/X TVD 1.1 Top West Sak:3,218'MD/2,701'TVD Base West Sak:4,082'MD/3,219'TVD Surface Casing 10-3/4"45.5#L-80 Hydril 563 4,107' MD/3,234'TVD @ 53° LSND xx PPG Tubing: 3-W 9.3#L-80 EUE8RD Camco 3-%"x 1-%" al MMG Mandrel @ X MD/X TVD 9-7/8"Intermediate Hole Estimated top of cement @+1-9,012'MD Camco 3-'G"x 1-'/," MMG Mandrel @ X MD/XTVD Intermediate Casing:Set in A5 7-5/8"29.7#L-80 Hydril 563 Surface to 10,115' MD/6,103'TVD @84° Top Kuparuk C:9,512'MD/6,026'TVD 6-3/4" Production Hole TARGET SAND-Top Kuparuk A5: 10,015'MD 6,093'TVD WBM Xx PPG Peel Shoe ge 3%"Camco DS Nipple 2.813" 7-5/8",ZXP Liner Top Packer • 1.1 ■ - 7-5/8"x 4-'/,"Baker Flex Lock Liner hanger 7,542'Horizontal Section w/RS Nipple,9,915'MD TD:17,657'MDI 6,252'TVD Production Liner: 4-1/2" 11.6#L-80 Hydril 563 Slotted Liner 17,657' MD/6,252'TVD @ 90° ORIGINAL r ECEIVED STATE OF ALASKA i u 3 2014 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 ❑✓ Single Zone Q 1c Specify if well is prop• ed for: Drill ❑✓ Lateral E Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry[I Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal III Shale Gas ❑ 2 Operator Name. 5 Bond .U Blanket U Single Well 11.Well Name- d Number. ConocoPhillips Alaska, Inc. • Bond No. 59-52-180 • y,Q 2E-02• (lie 3 Address' 6 Proposed Depth. 12.Field '001(s): W'N«l P.O.Box 100360 Anchorage,AK 99510-0360 MD 17657' • TVD 6252' • •aruk River Field. 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number) Surface:4750'FNL,5120'FEL, Sec 36,T11 N, RO9E, UM • ADL 25658,25665,25670• Kuparuk Oil Pool • Top of Productive Horizon 8 Land Use Permit: 13.Approximate Spud Date 303'FNL,5194'FEL,Sec. 11,T1ON, RO9E, UM 2584, 2586,2179 7/14/2014 Total Depth: 9 Acres in Property 14 Distance to 1138'FNL,5104'FEL, Sec 14,T1ON, RO9E, UM .2660—7(o$ Nearest Property <1 mile 4b Location of Well(State Base Plane Coordinates-NAD 27). 10 KB Elevation above MSL , 134 feet 15 Distance to Nearest Well Open Surface:x- 529972 y- 5944172 Zone- 4• GL Elevation above MSL . 106 feet to Same Pool. 2E-04,2250' 16 Deviated wells Kickoff depth. • 500 ft. 17.Maximum Anticipated P -ssures in psig(see 20 MC 25 035) Maximum Hole Angle: k 90° deg Downhol- 38e► •-g. Surface. 3186 psig 18 Casing Program' Specifications Top - Sett . •i h -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD TVI n MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' ..'V 106' 106' Coldset II 13.5" 10.75" 45.5# L-80 Hyd 563 4079' 28' 4107' 3234' 1560 sx ALC, 195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hyd 563 11508' 28' i,: 11536' 6143' 585 sx Class G 6.75" 4.5" 11.6# L-80 Hyd 563 6121' 11336' .140' 17657' 6252' open hole slotted liner 19 PRESENT WELL CONDITION SUMMARY � (o be completed for Redd!and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) r, cry h MD(ft) Effective Depth TVD(ft). Junk(measured) Casing Length Size ,ement Volume MD TVD lb Conductor/Structural Surface Intermediate Production Perforation Depth MD(ft): Perforation Depth TVD(ft): 20 Attachments' Property Plat❑ BO•Sketch❑ Drilling Prograrr a Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Div. er Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25 050 requirements Q 21.Verbal Approval' Commission Represent-• e Date (0/2/'4 22 I hereby certify that the foregoing is true=nd correct Contact Lindsey Hunter @ 263-642J4 Email Lindsey.Hunter@conocophillips.com Printed Na7 G. . Alvord Title Alaska Drilling Manager .• `" 102-f 2D Signature _' t(�t.;(y� +\� � Phone:265-6120 Date 4 Commission Use Only Permit to Drill API Number: I Permit Approval See cover letter Number: c2I 4 ti 50- ©2q - b235--1 _- 00 —co Date for other requirements Conditions of a•proval: If box is checked,well may not be used to explore for,test,or produce coalbed thane,gas hydrates,or gas contained in shales Other. Samples req'd: Yes ❑ No [ Mud log req'd: Yes❑ No Al H2S measures: Yes f❑ No Directional svy req'd: Yes( No❑ Spacing exception req'd: Yes ❑ No V Inclination-only svy req'd: Yes❑ No 2 APPR VED BY THE Approved by. COMMIO R MI SIGN Date: Form 10-401 (Revised 10/2012) This permit is . tbr�24rt h�Nic t of approval(20 AAC 25.005(g)) ConocoPhillips Alaska, Inc. Post Office Box 100360 RECEIVEDS�'I� Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 JUN 0 3 2014 May 29,2014 AOGCC Alaska Oil and Gas Conservation Commission l� 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2E-02,A Kuparuk A5 Sand Water Injector r Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a permit to drill an onshore grassroots pre-produce water injector well from the 2E pad. The expected spud date for this well is July 14th,2014. It is planned to use Rig Doyon 141. 2E-02 is planned to be a horizontal Kuparuk A5 sand pre-produced water injector. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-4,107'MD/3,234'TVD. The intermediate section will be drilled with 9- 7/8"bit and run 7-5/8"casing to 11,536'MD/6,143'TVD. The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 17,657'MD/6,252'TVD. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Lindsey Hunter at 263-6427 (lindsey.hunter@cop.com or Chip Alvord at 265-6120.) Sincerely, (\t/1"A `)r`tela} Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2E-02 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2E-02 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must he accompanied by each of the following items.except for an item a/reads on file with the conmtsston and identified in the application (2)a plat identifying the property and the property's on hers and showing (-I)the coordinates of the proposed location of the w ell at the surface at the top of each objective formation.and at total depth. referenced to governmental section lines (B)the coordinates of the proposed location of the it ell at the surface.referenced to the state plane coordinate sl stem for tins state as maintained hr the.National Geodetic Survey in the National Oceanic and Atmospheric Administration (C)the proposed depth of the well at the lop of each objective formation and at total depth. Location at Surface 4750' FNL, 5120' FEL, Sec 36, T 11N,R009E,UM NGS Coordinates RKB Elevation 133.9' AMSL Northings: 5,944,172.37' Eastings: 529,972.21' Pad Elevation 105.9'AMSL Location at Top of 303' FNL, 5194' FEL, Sec 11,T1ON,R009E,UM Productive Interval (Kuparuk A5 Sand) _ _ NGS Coordinates Measured Depth, RKB: 11,534' Northings: 5,938,040.70' Eastings: 524,646.88' Total Vertical Depth, RKB: 6,143' Total Vertical Depth, SS: _ 6,009' Location at Total Depth 1138' FNL, 5104' FEL, Sec 14,T1ON,R009E,UM NGS Coordinates Measured Depth, RKB: 17,657' Northings: 5,931,926.77' Eastings: 524,765.94' Total Vertical Depth, RKB: 6,252' Total Vertical Depth, SS: 6,118' and (D)other information required by 20 AAC 25 050(h), Requirements of 20 AAC 25.050(b) If a u ell fs to be intentionally dei fared, the application for a Permit to Drill(Form 10--10/)must (I)include a plat.draw n to a suitable scale,showing the path of the proposed wellbore, mcludmg all adjacent w ellbores within 200 feet of any portion of the proposed lief! Please see Attachment: Directional Plan And (21 for all wells within 200 feet of the proposed w ellhore (A)list the names of the operators of those hells to the extent that those sanies are known or discoverable in public records.and show that each named operator has been furnished a copy of the application by certified mail. or (B)state that the applicant is the only affected oil tier The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must he accompanied by each ofthe following items.except for an item already on file with the commission and identified fn the application' (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25 035, 20.4.1C 25 036. or 20 AAC 25 037.cis applicable, Please reference BOP schematics on file for Doyon 141. ORIGINAL Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application fill.a Permit to Drill must he accompanied by each of the_follouvng items.except for an Nem already on file with the commission and identified in the application (4)information on drilling ha=cards. including (-I)the maximum downhole pressure that mar he encountered.criteria used to determine it, and maximum potential surface pressure based on a methane gradient. The maximum potential surface pressure (MPSP) while drilling 2E-02 is calculated using an estimated maximum reservoir pressure of 3,800 psi (9.0 ppg);a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A5 sand at 6,143' TVD (WP04): A Sand Estimated. BHP = 3,800 psi A Sand estimated depth (WP06) = 6,143' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 614 psi (6,143' TVD * 0.10 psi/ft) MPSP =BHP—gas column = 3,186 psi (3,800 psi—614 psi) (B)data on potential gas=ones: The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as ahnormalh geo-pressured so ata lost circulation=ones,and=ones that have a propensity for differential sticking See attached 2E-01 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must he accompanied hr each of the following items.except for an item already on file w ith the cnmmicsuon and identified m the application (5)a description of the procedure for conducing formation integrity tests as required under 20.-1.IC 25 030il). A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) .-In application for a Permit to Drill must be accompanied hi each of the following,items except fbr an item already on fde with the commission and identified in the application 06)a complete proposed casing and cementing program as required by 20.44C 25 030 and a description of any slotted liner.pre-perforated finer or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) ���� (lb/ft) Grade Conn (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/ 106 Existing Cement to Surface with 10-3/4 1t2 45.5 L-80 H563'I 4,079 Surf 4,107/3,234 1,560 sx ALC Lead 11.02 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Hydril 585 sx Class G at 15.8 ppg w/TOC at 7-5/8 9-7/8 29.7 L-80 563 11,508 Surf 11,536/6,143 9,351'MD 4 1/2 6-3/4 11.6 L-80 H56311 6,121 11,336/6,140 17,657/6,252 Open hole slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) ,1n application for a Permit to Drill must he accompanied by each of thefollrnrmg tents.evicept for an item already on/dc w ala the commission and identified in the application ORIGINAL (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) .in application for a Permit to Drill must he accompanied byeach of the.folloirmg hemi,except.tor an item already on file with the commission and ident fled in the application' (8)a drilling fluid program,including a diagram and description of the dulling fluid system, as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.5- 11.5 10.6-11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. r�JRLGIN/\ Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) .In application for n Permit to Drill must be accompanied by each of the fnllou mg items.except,for an item already on file with the commission and identified in the application The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. OR1GNAL I 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-4,107' MD/3,234' TVD as per directional plan (wp04). Survey with MWD,Gamma,Resistivity, Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3000 psi(annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform formation integrity test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at-8,267' MD/5,666' TVD,back ream to the surface shoe at 4,107' MD ensuring a clean hole(this will allow us to drill and clean up the shales quickly,reducing exposure time). 9. RIH to top of HRZ and directionally drill to 11,536' MD/6,143' TVD, landing in the Kuparuk A5 sand. Wellsite geologist will call intermediate TD. Circulate and rotate until shakers are clean. Short trip to top of shales at 8,267' MD on elevators, if no tight spots encountered continue to POOH. (If tight spots are encountered,back ream through only tight areas to top of HRZ,run back to bottom and circulate bottoms up.) 10. POOH on elevators. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from TD at 11,536' MD to surface. 13. Pump cement job as per Schlumberger proposal,top of cement to be 9,351' MD(500' MD above top of the Kuparuk C sands). 14. Set slips and install wellhead x 7-5/8"packoff and test to 3500 psi. 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5" DP. 17. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity, stethoscope,periscope, microscope, neutron density, and sonic for TOC.) 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 20. Directionally drill 6-3/4"hole geosteering though the Kuparuk A5 sand to TD-17,658' MD as per directional plan(wp04). 21. Circulate hole clean and POOH. Log top of cement with sonic on trip out of hole. 22. Lay down Production BHA. 23. PU and run 4-1/2", 11.6#,Hydril 563 slotted liner. The top of liner will be placed at 11,336' MD, allowing for 200' of overlap in the 7-5/8"casing. 24. Set liner hanger. Slackoff and set liner top packer. e t A' , Rt1NAL 25. Monitor well for flow for 15 minutes 26. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes, chart results. 27. Flow check well for 30 minutes to run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) .1;,application to, a Permit to Drill nustc he accompanied hi each of the_follou arg Mems e.rcept,for an item already on file 711th the comm11ssron and identified in the application (I-I)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20.-L-I('25 080 for an annular disposal operation in the well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well(1R- 18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (659-7212). Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL co { 4 cn L -0 •� a O N O N O ♦1 r O i i N IIIN N >, O a Q. C C C as a V a. a. a a ORIGINAL CO Z Z ' 03 F.0 En _ \ E s- o ( 0o / o \ k t• `— `— s— 1 4: 7 ©@ ` 76„T k // % � � = o / �k % - ) NIN 7 < R§ \ — E e 0 — 2 )ƒ ƒ E \f / § \ D — ! ] A/ § k / _ A_j ] / ) - - ( 2 \ E2a{ k ° `\ \ `\ \ , } L. co 5 / § 3co ° ° ° R - 23 ±z E a E E } a / } C 0 / 2 / # E / in as ev \ ± § P \ \ 2 { .- ) / _ Z LI CO t _ z ] & t © f c ƒ £ 7 } co ) / .. E § - E ? 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Range: 009 E Y: 15931926.77 Meridian: IU j Section:I14 I FNL .I 1138.1977 I FEL . 5103.6648 Transform I Quit I Help %. 4 ORIGINAL ' 2E-02 Drilling Risks Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology, use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement. Use proper pump rate. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Use GKA LC decision tree. Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning, stabilized BHA,proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 10.0 ppg.But there is small chance of over pressured pay zone due to the offset well in the neighbor block is 11.0 ppg.Re- estimate the formation pressure based on results from shut in bottom hole pressures taken at near by wells 2F- 11 and 2F-19 as they become available and adjust the mud weight accordingly.Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. 6-3/4" Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 10.0 ppg.But there is small chance of over pressured pay zone due to the offset well in the neighbor block is 11.0 ppg.Re- estimate the formation pressure based on results from shut in bottom hole pressures taken at near by wells 2F- 11 and 2F-19 as they become available and adjust the nn ! n INCA ! Prepared by Lindsey Hunter mud weight accordingly. Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Stuck pipe Moderate Good hole cleaning, stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Control trip speeds,monitor proper hole fill while tripping,good hole cleaning.Pump or back ream out if necessary. ORIGINAL Prepared by Lindsey Hunter 2Eo02 04) ConocoPhillips Grass Roots Horizontal al A-Sand Injector Proposed Wellbore Schematic t''CAMERON 4-%"tree,top joint is 4-/'12 6#IBTM Last Edited: Existing Conductor: Hunter-5/22/14 16"62.6#H-40 Drilplex \ -110' MD/ 110'TVD 9.3 ppg 3W Camco DS Nipple 2.875" XMD/XTVD Camco 3-W x 1-W 13-1/2"Surface Hole MMG Mandrel @ MD/xi TVD Top West Sak:3,224'MD/2,705'TVD Base West Sak:4,083'MD/3,220'TVD Surface Casing 10-3/4"45.5#L-80 Hydril 563 4,107' MD/3,234'TVD @ 53° LSND xx PPG Tubing: 3-%"9.3#L-80 EUE8RD Camco 3-%"x 1-W11-1 MMG Mandrel(83 X MD/X TVD 9-7/8" Intermediate Hole Estimated top of cement @+/-9,351'MD Camco 3-X"x 1-%" MMG Mandrel @ x' MD/X TVD Intermediate Casing:Set in A5 7-5/8"29.7#L-80 Hydril 563 Surface to 11,536' MD/6,143'TVD @87° Top Kuparuk C:9,851'MD/6,074'TVD 6-3/4" Production Hole TARGET SAND-Top Kuparuk A5: 11,534'MD 6,143'TVD WBM Xx PPGe Pel Shoe e 3W Camco DS Nipple 2.813" '/i' 7-5/8',ZXP Liner Top Packer 7-5/8"x 4-W"Baker Flex Lock Liner hanger 6,121'Horizontal Section w/RS Nipple, 11,336'MD TD:17,657'MD/6,252'TVD Production Liner: 4-1/2" 11.6#L-80 Hydril 563 Slotted Liner 17,657' MD/6,252'TVD @ 90° ORIGINAL Ferguson, Victoria L (DOA) From: Hunter, Lindsey L <Lindsey.Hunter@conocophillips.com> Sent: Monday,June 30, 2014 7:25 AM To: Ferguson, Victoria L(DOA) Subject: RE: KRU 2E-02 (PTD 214-078) Attachments: 2E-02 Permit to Drill .doc Follow UpFlag: Follow 9 up Flag Status: Flagged Victoria, I apologize for the errors. Please see the attached revised PTD, corrections are highlighted in yellow. 1. The BOPs should be tested to 3500 psi. 2. The planned mud weight will be up to 12.2 to accommodate the potentially high reservoir pressure. (Note we are setting the intermediate in the A5 reservoir but do not expect to see high pressures until crossing a fault in the lateral, so the mud weight upper limit was not changed for the intermediate.) Please note the figures below for cement yields. Surface: Cement 10-3/4" casing from shoe @ 4,107' MD to surface with 1560 sks Arctic LiteCRETE @ 11.02 ppg and '"205 sks DeepCRETE @ 12.0 ppg.Volumes are based on 250%excess in permafrost and 50%excess below the permafrost.Top of the tail slurry is designed @3,607'MD. Lead slurry: Arctic LiteCRETE @ 11.02 ppg yielding 1.93 ft3/sk (4,107'-1,510')x 0.3637 ft3/ft x 1.5 (50%excess)= 1,145 ft3 below permafrost (1,510'—110')x 0.3637 ft3/ft x 3.5(250%excess)= 1,783 ft3 above permafrost (110'x 0.6381 ft3/ft x 1.0)=71 ft3 Total volume= 1,783+1,145+71=2,999 ft3=>1554 sks('"1,560 sks) Tail slurry: DeepCRETE @ 12.0 ppg yielding 1.63 ft3/sk (4,107'—3,607')x 0.3637 ft3/ft x 1.5(50%excess)=273 ft3 annular volume 80'x 0.53997 ft3/ft=44 ft3 shoe joint volume Total volume=273+44=317 ft3=>195 sks(^'205 sks) Intermediate: 1 Cement from 10,115' MD to 9,000' MD with Class G +adds @ 15.8 PPG.Assume 40% excess annular volume. Tail Slurry: (10,115' —9,000')X 0.2148 ft3/ft X 1.4 (40%excess)= 336 ft3 annular vol. 80' X 0.2394 ft3/ft=20 ft3 shoe joint volume Total volume= 336+20=356 ft3=>307 sks(315 sks)@ 1.16 ft3/sk System: 315 sks Class G+additive @ 15.8 PPG yielding 1.16 ft3/sk Let me know if there is anything else you need. Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsev.hunte ciconocophillips.corn From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson©alaska.gov] Sent: Friday, June 27, 2014 9:50 AM To: Hunter, Lindsey L Subject: [EXTERNAL]RE: KRU 2E-02 (PTD 214-078) Also, please provide the yield on cementing details. From: Ferguson, Victoria L(DOA) Sent: Friday, June 27, 2014 9:43 AM To: Hunter, Lindsey L(Lindsey.Hunter@>conocophillips.com) Subject: KRU 2E-02 (PTD 214-078) Lindsey, 1. The MP5P is 3191 psi but the BOPS are only being tested to 3000 psi. 2. The maximum formation pressure is 11.9 ppg EMW while the planned mud weight is 10.6 to 11.5 ppg. Please advise, 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 victona.ferqusonaalaska qov 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 2 s Bettis, Patricia K (DOA) From: Hunter, Lindsey L [Lindsey.Hunter@conocophillips.com] Sent: Thursday, June 19, 2014 9:33 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2E-02: Permit to Drill Patricia, To be safe I just re-wrote the permit to drill and will have it to you this afternoon. I apologize for the confusion. The updated PTD specifically states our expected pre-production time and the1/4 mile radius plot is more clear(denotes casing setting depths.) Please let me know if you have any questions. Thanks Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunte u,conocophillips.corn From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, June 18, 2014 10:28 AM To: Hunter, Lindsey L Cc: Ferguson, Victoria L(DOA) Subject: [EXTERNAL]RE: KRU 2E-02: Permit to Drill Good morning Lindsey, Under 20 AAC 25.015(a)(1), a new permit to drill application will need to be submitted if the proposed surface location is changed, if the proposed bottom-hole location or the proposed location of an objective formation is changed by more than 500 feet laterally or vertically, or if the change requires a spacing exception under 20 AAC 25.055. Otherwise just submit a revised Form 10-401 and a revised proposed wellbore schematic with the new intermediate casing point. Thank you, Patricia From: Hunter, Lindsey L [mailto:Lindsey.Hunter@conocophillips.com] Sent: Wednesday, June 18, 2014 8:53 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2E-02: Permit to Drill Patricia, Ok! I understand what you're asking now, thank you for the clarification. The 1/4 mile plot attached was misleading, the only areas of 2E-01 within the 1/4 mile radius of the injection zone of 2E-02 are behind intermediate casing. I'm having the plot edited now to clearly show where the casing setting depth is, I will send it to you this afternoon. 1 We also have some significant edits to the wellplan due to some misinterpretation of formation depths, this will adjust the intermediate casing setting depth significantly. Would you like me to just re-submit the permit to drill completely or would you prefer a revision? Thanks Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunten conocophillips.corn From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, June 17, 2014 12:54 PM To: Hunter, Lindsey L Subject: [EXTERNAL]RE: KRU 2E-02: Permit to Drill Good afternoon Lindsey, The AOGCC needs for ConocoPhillips to provide an assessment on the mechanical condition of each well that has penetrated the injection zone within one-quarter mile radius of a proposed injection well for demonstrating that no fluids will move behind casing beyond the approved injection zone. On the one-quarter mile radius plot, KRU 2E-01 is shown within the 1/4 mile radius. Thank you, Patricia From: Hunter, Lindsey L [mailto:Lindsey.Hunter@conocophillips.com] Sent: Friday, June 13, 2014 5:14 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2E-02: Permit to Drill Patricia, We are planning to pre-produce this well, however we don't know the duration at this time. It will depend on how the well is performing. I included a 1/4 mile radius view as a page in the anti-collision paperwork (page 24 of 27.) Do you need more information than this, or will the 1/4 mile radius plot be sufficient? Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter@conocophillips.com From: Bettis, Patricia K (DOA) [mailto:patricia.bettisalaska.gov] Sent: Tuesday, June 10, 2014 10:13 AM 2 r ' To: Hunter, Lindsey L Subject: [EXTERNAL]KRU 2E-02: Permit to Drill Good morning Lindsey, Will ConocoPhillips pre-produce the well and if so, for what duration? Also, the application did not provide a discussion of the one-quarter mile radius view under 20 AAC 25.402(c). 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. 3 1 Bettis, Patricia K (DOA) From: Hunter, Lindsey L [Lindsey.Hunter@conocophillips.com] Sent: Wednesday, June 18, 2014 8:53 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2E-02: Permit to Drill Patricia, Ok! I understand what you're asking now, thank you for the clarification. The 1/4 mile plot attached was misleading, the only areas of 2E-01 within the 1/4 mile radius of the injection zone of 2E-02 are behind intermediate casing. I'm having the plot edited now to clearly show where the casing setting depth is, I will send it to you this afternoon. We also have some significant edits to the wellplan due to some misinterpretation of formation depths,this will adjust the intermediate casing setting depth significantly. Would you like me to just re-submit the permit to drill completely or would you prefer a revision? Thanks Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunte u,conocophillips.corn From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, June 17, 2014 12:54 PM To: Hunter, Lindsey L Subject: [EXTERNAL]RE: KRU 2E-02: Permit to Drill Good afternoon Lindsey, The AOGCC needs for ConocoPhillips to provide an assessment on the mechanical condition of each well that has penetrated the injection zone within one-quarter mile radius of a proposed injection well for demonstrating that no fluids will move behind casing beyond the approved injection zone. On the one-quarter mile radius plot, KRU 2E-01 is shown within the 1/4 mile radius. Thank you, Patricia From: Hunter, Lindsey L [mailto:Lindsey.Hunter@conocophillips.com] Sent: Friday, June 13, 2014 5:14 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2E-02: Permit to Drill Patricia, We are planning to pre-produce this well, however we don't know the duration at this time. It will depend on how the well is performing. 1 a I included a 1/4 mile radius view as a page in the anti-collision paperwork (page 24 of 27.) Do you need more information than this, or will the1/4 mile radius plot be sufficient? Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter ,conocophillips.corn From: Bettis, Patricia K (DOA) [mailto:patricia.bettis(aalaska.gov] Sent: Tuesday, June 10, 2014 10:13 AM To: Hunter, Lindsey L Subject: [EXTERNAL]KRU 2E-02: Permit to Drill Good morning Lindsey, Will ConocoPhillips pre-produce the well and if so, for what duration? Also, the application did not provide a discussion of the one-quarter mile radius view under 20 AAC 25.402(c). 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. 2 1 ► Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday, June 17, 2014 12:54 PM To: 'Hunter, Lindsey L' Subject: RE: KRU 2E-02: Permit to Drill Good afternoon Lindsey, The AOGCC needs for ConocoPhillips to provide an assessment on the mechanical condition of each well that has penetrated the injection zone within one-quarter mile radius of a proposed injection well for demonstrating that no fluids will move behind casing beyond the approved injection zone. On the one-quarter mile radius plot, KRU 2E-01 is shown within the 1/4 mile radius. Thank you, Patricia From: Hunter, Lindsey L [mailto:Lindsey.Hunter@conocophillips.com] Sent: Friday, June 13, 2014 5:14 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2E-02: Permit to Drill Patricia, We are planning to pre-produce this well, however we don't know the duration at this time. It will depend on how the well is performing. I included a 1/4 mile radius view as a page in the anti-collision paperwork(page 24 of 27.) Do you need more information than this, or will the 1/4 mile radius plot be sufficient? Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter@conocophillips.com From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, June 10, 2014 10:13 AM To: Hunter, Lindsey L Subject: [EXTERNAL]KRU 2E-02: Permit to Drill Good morning Lindsey, Will ConocoPhillips pre-produce the well and if so, for what duration? Also, the application did not provide a discussion of the one-quarter mile radius view under 20 AAC 25.402(c). • 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. 2 Bettis, Patricia K (DOA) From: Hunter, Lindsey L [Lindsey.Hunter@conocophillips.com] Sent: Friday, June 13, 2014 5:14 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2E-02: Permit to Drill Patricia, We are planning to pre-produce this well, however we don't know the duration at this time. It will depend on how the well is performing. I included a 1/4 mile radius view as a page in the anti-collision paperwork (page 24 of 27.) Do you need more information than this, or will theY4 mile radius plot be sufficient? Thanks, Lindsey Lindsey Hunter Drilling Engineer ConocoPhillips Alaska DB&W 907-265-6427 lindsey.hunter(u,conocophillips.com From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, June 10, 2014 10:13 AM To: Hunter, Lindsey L Subject: [EXTERNAL]KRU 2E-02: Permit to Drill Good morning Lindsey, Will ConocoPhillips pre-produce the well and if so,for what duration? Also, the application did not provide a discussion of the one-quarter mile radius view under 20 AAC 25.402(c). 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: Tuesday, June 10, 2014 10:13 AM To: 'Lindsey.Hunter@conocophillips.com' Subject: KRU 2E-02: Permit to Drill Good morning Lindsey, Will ConocoPhillips pre-produce the well and if so, for what duration? Also, the application did not provide a discussion of the one-quarter mile radius view under 20 AAC 25.402(c). 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 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: KR1k, 4.E -W.. PTD: (Q)Lio?"g Development V Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: 47(tuNk- POOL: W� �✓E.l 4 cod< Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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FINAL WELL REPORT MUDLOGGING DATA 2E-02 Provided by: Approved by: Phil Bottrell Compiled by: Steven Pike Allan Odegaard Distribution: 9/02/2014 Date: 08/21/2014 2E-02 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................5 3.1 Lithostratigraphy .............................................................................................................................5 3.2 Mudlog Summary............................................................................................................................6 3.3 Connection Gases ........................................................................................................................20 3.4 Trip (Wiper) Gases........................................................................................................................20 3.5 Gas Peaks & Associated Mud Data..............................................................................................21 3.6 Sampling Program / Sample Dispatch..........................................................................................22 4 PRESSURE / FORMATION STRENGTH DATA.................................................................................23 4.1 Pore Pressure Gradient Evaluation ..............................................................................................23 4.2 Quantitative Methods....................................................................................................................24 5 DRILLING DATA..................................................................................................................................25 5.1 Survey Data..................................................................................................................................25 5.2 Bit Record.....................................................................................................................................29 5.3 Mud Record Contractor: MI SWACO...........................................................................................30 6 MORNING REPORTS .........................................................................................................................31 Enclosures 2”/100’ Formation Log 2”/100’ Drilling Dynamics Log 2”/100’ LWD / Lithology Log 2”/100’ Gas Ratio Log Mudlog Digital Data CD 2E-02 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator and Gas Trap (mounted in mud return trough) Flame ionization total gas and chromatography. 0 Note: Chromatograph was down from 4,152’ to 5,851’ Block Height/Bit depth TOTCO WITS Feed 0 Hook Load / Weight on bit TOTCO WITS Feed 0 Mud Flow In Derived from Pump Rates and Pump Output 0 Mud Flow Out TOTCO WITS Feed 0 Mudlogging unit computer system HP Compaq Pentium 4 (x3: DML, Rigwatch, and Sample Catcher station) 0 Pit Volumes, Pit Gain/Loss TOTCO WITS Feed 0 Pump Pressure TOTCO WITS Feed 0 Pump stroke counters TOTCO WITS Feed 0 Rate of penetration TOTCO WITS Feed 0 RPM TOTCO WITS Feed 0 Torque TOTCO WITS Feed 0 Data delivered as thousands of ft-lbs in integer format Crew Unit Type : Arctic Unit Number : ML056 Mudloggers Years *1 Days *2 Sample Catchers Years *1 Days *2 Technician Days Steven Pike 15 8/3 Tyler Harris 1 8/3 Howard Lamp 4 Allen Odegaard 17 8/3 Kurt Wallander 6 8/3 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down 2E-02 3 2 WELL DETAILS 2.1 Well Summary The 2E-02 is an injection well on the 2E Pad. Well: 2E-02 API Index #: 50-029-23517-00 Field: Prudhoe Bay Surface Co-Ordinates: Twn. 11 N, Rng. 9 E, Sec. 36, Umiat Meridian 4750 FNL, 5120 FEL Borough: North Slope Primary Target Depth: — State: Alaska Total Depth: 10,065’MD / 6,095.28’TVD Rig Name / Type: Doyon #141 Arctic Triple Suspension Date: NA Primary Target: Injection Well Ground Elevation: 105.1’ AMSL Spud Date: 07/29/2014 RT Elevation: 133.1’ AMSL Completion Date: (not available)* TD Date: 08/08/2014 Completion Status: 7 5/8” Casing Secondary Target: Depth: — Classification: Injection TD Formation: A5 Days Drilling: 3 * Mudloggers released from wellsite prior to completion run 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD TVDSS TD Formation Mud Weight (ppg) Dev. (oinc) Casing/ Liner MD (ft) TVDSS (ft) LOT (ppg) Int. 10,065’ 5,964.18’ A5 10.1 82.0o 7 5/8” 10,049’ 5,961.96’ — * Mudloggers released from wellsite prior to completion run Additional Comments: tapered production casing string; 4½” production tubing within upper 7⅝” casing. 2E-02 4 2.3 Daily Activity Summary 08/03/2014 Canrig personnel on site for unit ML032 rig up. 08/04/2014 Continued rig up; miscellaneous mudlogging activity – mount gas trap, run umbilical and poly flow lines. 08/05/2014 Continued rig up; troubleshooting on TOTCO EDR. 08/06/2014 Trip in hole; casing pressure test; drilled cement and new formation to 4,171’; FIT; drill ahead to 6,059’. 08/07/2014 Drilled ahead from 6,059’ to 8,394’. 08/08/2014 Drilled ahead from 8,394’ to 10,065’ – casing point; pump out of hole to 9,750’; pull out of hole. 08/09/2014 Finish pulling out of hole; test rams for running casing. 08/10/2014 Run casing to bottom; pump cement. 2E-02 5 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops provided by the Waters Petroleum Geologist. PROGNOSED LWD PICK HORIZON MD (ft) SSTVD (ft) MD (ft) SSTVD (ft) Base W Sak 4,059' -3,084' 4,028' -3,040' Top HRZ (K-2 Marker) 8,320' -5,552' 8,253' -5,530' U Kalubik (Base HRZ) 8,871' -5,742' 8,863' -5,737' L Kalubik (K-1 Marker) 9,067' -5,803' 9,084' -5,806' C (Top C4) 9,512' -5,892' — — B2 9,562' -5,899' — — B1 9,562' -5,899' 9,639' -5,906' A6 9,851' -5,940' 9,921' -5,939' A5 10,018' -5,959' 10,047' -5,957' 2E-02 6 3.2 Mudlog Summary Base W Sak (base of casing) to Top HRZ (4,151’ MD to 8,320’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 382 7 160 978 4 110 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 8173 978 154210 15050 10303 1141 1617 294 243 Individual sample descriptions are as follows: Claystone (4170-4220) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between clayey and gritty to clayey and silty; no visible structures; very slight reaction to HCL; no sample fluorescence. Sand/Sandstone (4225-4275) = light gray to medium gray to olive gray; lower fine to upper medium grain; well to moderately well sorted; sub-angular to sub-rounded to trace angular; moderate to sub-spheroidal; disaggregated to soft to friable; clay content has decreased to small clayey masses containing sand grains; predominately colorless transparent to translucent quartz; on calcareous; no oil indicators claystone (4280-4335) = light gray to medium light gray to brownish gray overall; curdy to pasty consistency; moderately to very cohesive; very little to slightly adhesive; dull earthy to slightly waxy luster; gritty to silty texture; common to abundant black lithic fragments; trace very fine to fine grain orange lithics and light bluish gray to grayish blue green glauconite; no visible structures; no oil indicators. Siltstone (4340-4390) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; very slight reaction to HCL; no sample fluorescence. Sand (4395-4440) = clear to light gray to dusky brown; sub-rounded to sub-angular low to moderate sphericity; lower fine to upper medium grained; <5% pyrite throughout sample interval as individual grains and as growths on other grains; trace pale green glauconite and trace shell fragments throughout interval; very slight reaction to HCL. Claystone (4445-4500) = medium light gray to light brownish gray to light olive gray overall; lumpy pasty consistency; moderately to very cohesive slightly to moderately adhesive when prodded; hydrophilic; dull earthy luster; silty to gritty texture, clayey siltstone to silty claystone; common to abundant very fine to fine grained black lithics; trace very fine orange and fine greenish gray lithics; no oil indicators siltstone (4535- 4590) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; very slight reaction to HCL; no sample fluorescence. Sand/Sandstone (4590-4655) = light gray to medium gray to light brownish gray throughout sample interval; lower fine to upper medium to upper very fine; moderately to well sorted; sub-angular to sub- rounded; moderate to high sphericity; very soft, disaggregated; clay matrix forming clayey masses in sample trays; scattered dark yellowish orange to dusky brown pebbles 5mm in sample interval; non calcareous; no oil indicators. 2E-02 7 Siltstone (4655-4705) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; very slight reaction to HCL; no sample fluorescence. Claystone (4710-4765) = light gray to medium light gray to brownish gray overall; curdy to pasty consistency; moderately to very cohesive; very little to slightly adhesive; dull earthy to slightly waxy luster; gritty to silty texture; common to abundant black lithic fragments; trace very fine to fine grain orange lithics and light bluish gray to grayish blue green glauconite; no visible structures; no oil indicators. Sandstone/Siltstone (4770-4850) = clear, light to medium light gray with a slight brownish secondary hue; soft to disaggregated; samples collected as irregular lumpy masses of disaggregated silt with variable amounts of loose sand is very fine upper to fine lower a very fine lower with trace to common medium lower grains; predominantly angular to sub-angular; translucent white to clear quartz predominates; trace to common medium, light and dark gray lithics; trace small micro- crystalline pyrite masses; scattered fine ground shell fragments; very slightly calcareous; no oil indicators. Siltstone (4855-4920) = light gray to medium gray; pasty consistency throughout sample interval; low to moderately cohesive; poor to non adhesive; dull earthy luster; clayey intergrades between silty claystone and clayey siltstone, with increasing silt and decreasing clay with depth; silty to gritty to locally clayey texture; gritty texture varies due to increase in amount of reworked sand and accessory minerals; no visible structures; no reaction to HCL. Claystone (4925-4780) = light gray to medium light gray to brownish gray overall; curdy to pasty consistency; moderately to very cohesive; very little to slightly adhesive; dull earthy to slightly waxy luster; gritty to silty texture; common to abundant black lithic fragments; trace very fine to fine grain orange lithics and light bluish gray to grayish blue green glauconite; no visible structures; no oil indicators. Siltstone (4985-5080) = medium gray to light gray; predominantly soft to some easily friable cuttings; most cuttings are reworked globular masses of clayey siltstone and silty claystone with sand and other accessory mineral grains worked in as well; moderately cohesive; slightly adhesive when prodded; dull earthy to a slightly vitreous and waxy luster throughout sample interval; texture varies depending on clay to silt ratio as well as amount of sand and other mineral grains within the mass, generally silty clayey to gritty and silty; some pure brittle siltstone cuttings contain reddish brown to dusky brown thin laminations; no petroleum indicators were observed. Claystone (5055-5110) = medium brown, dark brown to brownish gray; pasty to mushy; mostly crumbly; irregular fracture; amorphous cuttings habit; earthy to dull luster; predominantly clayey texture, with some slightly silty to gritty in places; thicker beds of claystones inter-bedded with clayey siltstones and very thin silty sands; no visible sample fluorescence was observed. Siltstone (5115-5165) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; very slight reaction to HCL; no sample fluorescence. Sand (5175-5245) = translucent to clear, with some light gray to white hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout; upper very fine to upper fine grain sand; well to moderately sorted throughout; well rounded to sub-rounded, with some sub-angular to angular; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystones and clayey siltstones; no visible sample fluorescence was observed. Claystone (5250-5300) = light gray to medium light gray to light brownish gray overall; curdy clumpy consistency; moderately to very cohesive; little to slightly adhesive; hydrophilic; waxy earthy luster; silty 2E-02 8 gritty texture, slightly gritty due to reworking very fine grained sands; almost silty in some clayey masses; no visible structures present; slight reaction with HCL; no petroleum indicators. Siltstone (5300-5365) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; very slight reaction to HCL; no sample fluorescence. Sand (5365-5440) = translucent to clear, with some light gray to white hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout; upper very fine to upper fine grain sand; well to moderately sorted throughout; well rounded to sub-rounded, with some sub-angular to angular; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystones and clayey siltstones; no visible sample fluorescence was observed. Claystone (5440-5550) = light gray to medium light gray to light brownish gray overall; curdy clumpy consistency; moderately to very cohesive; little to slightly adhesive; hydrophilic; waxy to earthy luster; silty gritty texture, slightly gritty due to reworking very fine grained sands; trace silt through- out sample; no visible structure present; slight reaction with HCL; no petroleum indicators. Siltstone (5550-5555) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and other accessory mineral grains between silty and gritty to silty and clayey; no visible structure; very slight reaction to HCL; no petroleum indicators. Sand (5555-5630) = translucent to clear, with some light gray to white hues; predominantly quartz grain sand matrix with common dark colored lithic fragments throughout; upper very fine to lower fine grained sand; well to moderately sorted throughout; well rounded to sub-rounded, with some sub-angular to angular; frosted surface abrasion, occasionally polished; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystones and clayey siltstones; no visible sample fluorescence. Claystone (5630-5690) = light gray to medium light gray to light brownish gray overall; curdy clumpy consistency; moderately to very cohesive; little to slightly adhesive; hydrophilic; waxy to earthy luster; silty gritty texture, slightly gritty due to reworking very fine grained sands; trace silt and sand throughout sample; no visible structure present; slight reaction with HCL; no petroleum indicators. Siltstone (5690-5740) = medium to medium dark gray; very pasty consistency; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and other accessory mineral grains between silty and gritty to silty and clayey; no visible structure; very slight reaction to HCL; no petroleum indicators. Sand (5740-5820) = translucent to transparent, occasionally light gray to white; predominantly quartz grain sand matrix with common dark colored lithic fragments throughout; upper very fine to lower fine grained, often grading to silt sized particles; well to moderately sorted throughout; well rounded to sub-rounded, with some sub-angular to angular; frosted surface abrasion, occasionally polished; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystones and clayey siltstones; trace ash; no visible sample fluorescence. Claystone (5820-5880) = light gray to medium light gray to light brownish gray overall; curdy clumpy consistency; moderately to very cohesive; slightly to moderately adhesive; hydrophilic; waxy to earthy luster; silty, gritty texture, grittiness due to inter-bedded very fine to fine grained sands; trace silt and sand throughout sample; no visible structure present; slight reaction with HCL; no petroleum indicators. Siltstone (5880-5930) = medium to medium dark gray; very pasty consistency; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and other accessory 2E-02 9 mineral grains between silty and gritty to silty and clayey; no visible structure; very slight reaction to HCL; no visible fluorescence or other petroleum indicators. Sand (5930-6010) = translucent to transparent, occasionally light gray to white; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout; upper very fine to lower fine grained, often grading to silt sized particles; well to moderately sorted throughout; well rounded to sub-rounded, with some sub-angular to angular; frosted surface abrasion, occasionally polished; moderate to high sphericity; very thin sand lenses inter- bedded with thicker beds of silty clay- stones and clayey siltstones; rare trace ash; no visible sample fluorescence. Claystone (6010-6090) = light to medium light gray to light brownish gray; curdy to clumpy consistency; moderately to very cohesive; slightly to moderately adhesive; hydrophilic; waxy to earthy luster; texture ranges from silty to gritty, grittiness due to inter-bedded very fine to fine grained sands; silt and sand throughout sample; no visible structure present; slight reaction with HCL; no petroleum indicators. Siltstone (6090-6150) = medium to medium dark gray; extremely pasty consistency; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture ranges between silty and gritty to silty and clayey due to the changing amount of sand and other accessory minerals; no visible structure; very slight reaction to HCL; no visible fluorescence or other petroleum indicators. Sand (6150-6230) = translucent to transparent, occasionally light gray to white; predominantly quartz grain sand matrix with abundant dark colored lithic fragments scattered throughout sample; upper very fine to upper very fine grained, often grading to silt; well to moderately sorted; well rounded to sub-rounded, with some sub-angular to angular; frosted to grinding surface abrasion; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystone and clayey siltstone; trace white ash; no visible fluorescence or other petroleum indicators. Claystone (6230-6290) = light to medium light gray to light brownish gray; curdy to clumpy consistency; moderately to very cohesive; slightly to moderately adhesive; hydrophilic; waxy to earthy luster; texture ranges from silty to gritty, grittiness due to inter-bedded very fine to fine grained sands; silt and sand throughout sample; no visible structure present; slight reaction with HCL; no petroleum indicators. Siltstone (6290-6350) = medium to medium dark gray; extremely pasty consistency; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture ranges between silty and gritty to silty and clayey due to the amount of sand and other accessory minerals; no visible structure; very slight reaction to HCL; no visible fluorescence or other petroleum indicators. Sand (6350-6430) = translucent to transparent, occasionally light gray to white; predominantly quartz grain sand matrix with common dark colored lithic fragments scattered throughout sample; upper very fine to upper very fine grained, often grading to silt; well to moderately sorted; well rounded to sub-rounded, with some sub-angular to angular; frosted to grinding surface abrasion; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystone and clayey siltstone; trace white ash; no visible fluorescence or other petroleum indicators. Sand (6435-6490) clear to translucent with some white to light gray; mostly quartz grain sand matrix with abundant dark colored lithic fragments throughout the sample; upper very fine to lower fine grain sand; very well rounded with some sub-rounded and sub-angular; high sphericity; very thin lenses of sand inter- bedded with thicker beds of clayey siltstones and silty to sandy claystone; no sample fluorescence was observed. Siltstone (6495-6560) = light gray to medium gray; pasty consistency throughout sample interval; low to moderately cohesive; poor to non adhesive; dull earthy luster; clayey intergrades between silty claystone and clayey siltstone, with increasing silt and decreasing clay with depth; silty to gritty to locally clayey texture; gritty texture varies due to increase in amount of reworked sand and accessory minerals; no visible sample fluorescence was observed. 2E-02 10 Sand (6565-6610) = translucent to clear with some milky white to light gray; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout the sample; lower fine with occasional upper fine grains; very well sorted; sub-angular to sub-rounded with moderate to high sphericity; no sample fluorescence. Claystone (6615-6665) = medium gray to medium dark gray; reworked globular masses containing sand and other accessory mineral; pasty to mushy consistency; moderately to high cohesive poorly adhesive; intergrades between silty claystone and clayey siltstone; dull earthy luster; silty clayey texture to locally gritty due to reworked sand; no reaction to HCL; no oil indicators. Siltstone (6670-6720) = medium gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and other accessory mineral grains between silty and gritty to silty and clayey; no visible structure; no visible sample fluorescence was observed. Claystone (6725-6760) = light gray to medium light gray to brownish gray overall; curdy to pasty consistency; moderately to very cohesive; very little to slightly adhesive; dull earthy to slightly waxy luster; gritty to silty texture; no oil indicators. Sand (6765-6835) = translucent to clear with some light gray to milky white and white hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout the sample; upper very fine to medium grain sand; moderately well to slightly fair sorting; very well rounded to sub-rounded with some very angular to sub-angular; moderate sphericity; thinner beds of very fine to medium grain sand inter-bedded with thicker beds of sandy siltstone and sandy claystones; no sample fluorescence was observed. Sand (6845-6900) = clear to translucent with some milky white to light gray; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout the sample; lower fine with occasional upper fine grains; well sorted; sub-angular to sub-rounded with moderate to high sphericity; no sample fluorescence was observed. Siltstone (6900-6955) = dark gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; sand content increases with sample depth; no sample fluorescence. Sand/Sandstone (6960-7035) = clear to white with some light gray; mostly quartz grain loose uncemented sand with friable calcareous cemented fine grain sandstone; predominantly moderate to poorly sorted; upper fine to upper and lower medium grain sand; very well rounded to sub-rounded with some very angular to sub-angular; high to moderate sphericity throughout; thicker beds of sand and fine grain sandstones inter-bedded with sandy siltstones and sandy claystones; no visible sample fluorescence was observed. Siltstone (7040-7090) = grayish black to brownish gray; pasty to stiff; brittle; poor to moderately indurated; irregular to earthy fracture; elongated to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure, at times barely discernable laminae; sand / sandstone upper fine to upper very fine grained; no visible sample fluorescence. Claystone (7095-7150) = light gray to medium gray to slight brownish gray overall; mushy to pasty consistency; moderately cohesive; slightly adhesive to moderately adhesive when prodded; earthy waxy luster; silty to gritty texture; so visible structures present; scattered brownish black splintered lithic fragments scattered throughout the sample; trace pyrite; no visible sample fluorescence. Siltstone (7155-7235) = medium gray to medium light gray; cuttings are mechanically reworked globular 2E-02 11 masses containing sand and accessory minerals; grades in between clayey siltstone and silty claystone throughout sample interval; slight to poor adhesiveness; moderate cohesiveness; consistency is predominantly pasty with some mushy cuttings; dull earthy luster; texture varies with clay and silt amounts, but is typically sandy clayey to silty gritty throughout sample interval; no visible structures; no visible sample fluorescence was observed. Sand/Sandstone (7240-7340) = clear to translucent with some white, light gray, and milky white hues; mostly quartz grain sand matrix with abundant dark colored lithic fragments in sample; moderately to poorly sorted; medium upper to medium lower; mostly angular to sub-angular with some well rounded; abundant light to medium gray lithics; trace to common dark gray to black mafic mineral/lithics; trace glauconite; trace yellow, brown, bronze and medium bluish gray lithics; trace pyrite as micro-crystalline; well indurated; scattered sandstone fragments; loose sand generated by very slow mechanical destruction of the rock; occasional thin claystone and siltstone inter-beds; no visible sample fluorescence was observed. Siltstone (7345-7390) = medium gray to medium dark gray; pasty to mushy throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; very slight reaction to HCL; no sample fluorescence. Sand/Sandstone (7400-7510) = clear to translucent, white to light gray; 90% quartz matrix; upper fine to lower medium to trace upper medium; poor to moderate sorting; sub-rounded to sub-angular; moderate to sub-spherical; disaggregated; soft to friable to occasional firm; predominately translucent to milky white to colorless transparent quartz; few quartz grains etched and slightly frosted; clay matrix becoming more apparent with depth in sample interval; trace orange and yellow lithics; common to abundant medium gray, brownish gray, dark gray and olive black grains/lithics through sample interval; green stained quartz and glauconite grains; trace to common very pale green to pale blue green to moderate green glauconite; fine to medium grained; trace pyrite microcrystalline masses; non calcareous; no oil indicators. Siltstone (7515-7585) = light gray to dark gray; mushy to slightly pasty throughout sample interval; low to moderately cohesive; poor to non adhesive; dull earthy luster; clayey grading between sandy claystone and gritty siltstone, with increasing silt and decreasing clay with depth; silty to gritty to locally clayey texture; gritty texture varies due to increase in amount of reworked sand and accessory minerals; no visible structures; no visible sample fluorescence was observed. Sand/Sandstone (7590-7665) = mostly clear to translucent with some white, milky white, light gray and dark gray hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout sample; upper fine to upper medium grain sand with some lower coarse grains in places; poorly sorted; very well rounded to sub-rounded with some very angular to sub-angular; moderate to high sphericity; thicker beds of loose uncemented sand and friable fine grained sandstones inter-bedded with sandy siltstones; no visible sample fluorescence. Siltstone (7665-7740) = light gray to dark gray; mushy to slightly pasty consistency; slightly to moderately cohesive; poor to non-adhesive; dull earthy luster; clayey, often grading between sandy claystone and gritty siltstone, with increasing silt and decreasing clay with depth; silty to gritty to locally clayey texture; gritty texture varies due to increase in amount of reworked sand and accessory minerals; no visible structures; no visible sample fluorescence. Sand/Sandstone (7740-7820) = clear to translucent with some white, milky white, light gray and dark gray hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout sample; upper fine to upper medium grained sand with occasional lower coarse grains; poorly sorted; very well rounded to sub- rounded with some very angular to sub- angular; moderate to high sphericity; thicker beds of loose uncemented sand and friable fine grained sandstones are inter-bedded with sandy siltstones; no visible sample fluorescence. 2E-02 12 Claystone (7820-7890) = light gray to medium gray to slight brownish gray; mushy to pasty consistency; moderately cohesive; slightly to moderately adhesive when prodded; earthy to waxy luster; silty to gritty texture; no visible structures present; scattered brownish black splintered lithic fragments scattered throughout; no visible sample fluorescence. Siltstone (7890-7960) = light gray to dark gray; mushy to slightly pasty consistency; slightly to moderately cohesive; poor to non-adhesive; dull earthy luster; clayey, often grading between sandy claystone and gritty siltstone; occasionally silty to gritty texture in places; gritty texture varies due to increase or decrease of accessory minerals and reworked sand; no visible structures; no visible fluorescence. Carbonaceous Siltstone (7960-8040) = olive black to grayish black, scattered medium dark gray; soft crumbly to firm friable; occasional dense to moderately hard; irregular to earthy to planar to blocky fracture; flaky to elongated, splintery to wedge-like cuttings habit; silty to gritty to occasionally smooth texture; laminated to massive structure; abundant carbonaceous micro-laminations; common subtle silt micro-bedding; scattered firm flexible carbonaceous material; trace to scattered soft white or yellowish gray devitrified ash; trace well rounded coarse sand grains; 10% soft yellow sample fluorescence. Claystone (8040-8100) = light gray to medium gray to slight brownish gray; mushy to pasty consistency; moderately cohesive; slightly to moderately adhesive when prodded; earthy to waxy luster; silty to gritty texture; no visible structures present; scattered brownish black splintered lithic fragments scattered throughout; inter-bedded with siltstone/carbonaceous siltstone; no visible sample fluorescence observed. Carbonaceous Siltstone (8100-8200) = greenish black to dark greenish gray, scattered medium dark gray, also olive black to grayish black, with scattered dark gray; soft crumbly to firm friable; occasional dense to moderately hard; irregular to earthy to planar to blocky fracture; flaky to elongated, splintery to wedge-like cuttings habit; silty to gritty to occasionally smooth texture; laminated to massive structure; abundant carbonaceous micro-laminations; common subtle silt micro-bedding; scattered firm flexible carbonaceous material; trace to scattered soft white or yellowish gray devitrified ash; trace well rounded coarse sand grains; 10% to 30% soft yellow sample fluorescence observed. Carbonaceous Siltstone (8200-8295) = greenish black to dark greenish gray, scattered medium dark gray, also olive black to grayish black; soft crumbly to firm friable; often dense to moderately hard; irregular to earthy to planar to blocky fracture; flaky to elongated and splintery to wedge-like cuttings habit; silty to gritty to occasionally smooth texture; laminated to massive structure; abundant carbonaceous micro-laminations; common subtle silt micro-bedding; scattered firm flexible carbonaceous material; trace to scattered soft white or yellowish gray devitrified ash; trace well rounded coarse sand grains; often inter- bedded with soft claystone; 10% to 30% soft yellow sample fluorescence observed. 2E-02 13 Top HRZ (K2-Marker) to U Kalubik (Base HRZ) (8,320’ to 8,871’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 286 20 154 1179 207 656 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 8813 1179 178755 20147 16164 828 2052 488 520 Individual sample descriptions are as follows: Claystone (8295-8370) = light gray to medium gray to slight brownish gray; mushy to pasty consistency; moderately cohesive; slightly to moderately adhesive when prodded; earthy to waxy luster; silty to gritty texture; no visible structures present; scattered brownish black splintered lithic fragments scattered throughout; 5% to 10% soft yellow sample fluorescence due to inter-bedded carbonaceous siltstone. Carbonaceous Siltstone (8370-8470) = greenish black to dark greenish gray, scattered medium dark gray, also olive black to grayish black; soft crumbly to firm friable; often dense to moderately hard; irregular to earthy to planar to blocky fracture; flaky to elongated and splintery to wedge-like cuttings habit; silty to gritty to occasionally smooth texture; laminated to massive structure; abundant carbonaceous micro-laminations; common subtle silt micro-bedding; scattered firm flexible carbonaceous material; trace to scattered soft white or yellowish gray devitrified ash; trace well rounded coarse sand grains; often inter- bedded with soft claystone; 5% to 20% soft yellow sample fluorescence observed. Claystone (8470-8530) = light gray to medium gray to slight brownish gray; mushy to pasty consistency; moderately cohesive; slightly to moderately adhesive when prodded; earthy to waxy luster; silty to gritty texture; no visible structures present; scattered brownish black splintered lithic fragments scattered throughout; 5% soft yellow sample fluorescence due to inter-bedded carbonaceous siltstone. Carbonaceous Siltstone (8530-8635) = greenish black to dark greenish gray, scattered medium dark gray, also olive black to grayish black; soft crumbly to firm friable; often dense to moderately hard; irregular to earthy to planar to blocky fracture; flaky to elongated and splintery to wedge-like cuttings habit; silty to gritty to occasionally smooth texture; laminated to massive structure; abundant carbonaceous micro-laminations; common subtle silt micro-bedding; scattered firm flexible carbonaceous material; trace to scattered soft white or yellowish gray devitrified ash; occasionally grading to a carbonaceous shale; scattered coarse sand grains; often inter-bedded with soft claystone; 10% to 25% soft yellow sample fluorescence observed. Claystone (8635-8690) = light gray to medium gray to slight brownish gray; mushy to pasty consistency; moderately cohesive; slightly to moderately adhesive when prodded; earthy to waxy luster; silty to gritty texture; no visible structures present; scattered brownish black splintered lithic fragments scattered throughout; 5% soft yellow sample fluorescence due to inter-bedded carbonaceous siltstone. Siltstone (8695-8760) = dark gray to medium gray; pasty to slightly clumpy throughout sample interval; low to moderately cohesive; poor to non adhesive; dull earthy luster; clayey intergrades between silty claystone and clayey siltstone, with increasing silt and decreasing clay with depth; silty to gritty to locally clayey texture; gritty texture varies due to increase in amount of reworked sand and accessory minerals; no visible sample fluorescence was observed. Sand (8765-8835) = clear to translucent, with white, milky white and gray hues; predominantly quartz grain sand matrix with common dark colored lithic fragments throughout; upper very fine to lower fine grained sand; well to moderately sorted throughout; well rounded to sub-rounded, with some sub-angular to angular; frosted surface abrasion, occasionally polished; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystones and clayey siltstones; no visible sample fluorescence. 2E-02 14 U Kalubik (Base HRZ) to L Kalubik (K-1 Marker) (8,871’ to 9,067’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 251 13 146 1152 377 641 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 9050 1152 142084 15845 16283 745 1970 480 539 Individual sample descriptions are as follows: Carbonaceous Shale (8840-8915) = black to very dusky red and brownish black; slightly stiff to somewhat firm; mostly brittle; planar to irregular fracture; flaky to slightly flaky cuttings habit; resinous to slightly waxy luster; predominantly smooth texture; thicker beds of carbonaceous shale inter-bedded with thinner beds of sandy siltstones and loose uncemented quartz grains with very thin lenses of very fine, friable, siliceous cemented sandstones; very faint sample fluorescence was observed in the sandstone fragments; no solvent cut. Siltstone (8920-9025) = medium dark gray to olive gray to brownish gray overall; tenacity is dense crumbly to slightly brittle; tabular to platy cuttings habit; waxy dull to slightly greasy; silty to gritty texture; thin dark brown micro-laminae; very slightly to non calcareous; very thick beds of siltstones inter-bedded with thinner beds of carbonaceous shale and loose uncemented quartz sand; some very thin lenses of very fine grained, friable sandstones were also observed; the sandstones have a bright yellow sample fluorescence; however, there is no solvent cut; the fluorescent sandstones only represent about 5% of the overall sample content; no other oil indicators were observed; pyrite was observed throughout the sample, mainly in crystalline form. Sand/Sandstone (9030-9115) = clear to translucent with some white, light bluish gray, and light gray hues; predominantly quartz grain sand matrix; lower very fine to upper medium grain; well sorted throughout; mostly well rounded to sub-rounded with some sub-angular; moderate to high sphericity; very thin lenses of loose uncemented sand and very fine grained siliceous cemented sandstones inter-bedded with very thick beds of dense siltstones with lesser amounts of carbonaceous shales; no mineral fluorescence, except for the very thin sandstones which make up less than 5% of the overall sample concentration; no solvent cut. 2E-02 15 L Kalubik (K-1 Marker) to C (Top C4) (9,067’ to 9,512’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 359 38 159 826 197 324 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 9087 826 99254 11292 13012 522 1390 331 383 Individual sample descriptions are as follows: Carbonaceous Shale (9120-9180) = blackish red, black, dusky red; slightly stiff to mostly firm; predominantly mostly planar, with some irregular; flaky to slightly platy cuttings habit; resinous to slightly waxy luster; predominantly smooth texture; thicker beds of carbonaceous shale inter-bedded with thinner beds of sandy siltstones and loose uncemented quartz grains; no visible sample fluorescence was observed. Siltstone (9185-9265) = dark gray to grayish black to medium dark gray; moderately firm to somewhat stiff; mostly brittle with some slightly dense in places; irregular fracture; amorphous cuttings habit; dull to somewhat waxy; very thick beds of siltstones inter-bedded with thinner beds of carbonaceous shale and loose uncemented quartz sand; some very thin lenses of very fine grained, friable sandstones were also observed; no visible sample fluorescence was observed; pyrite was observed throughout the sample, mainly in crystalline form. Sand/Sandstone (9270-9345) = translucent to clear, with some white, light gray, and pale yellow orange hues; mostly quartz grain sand matrix with dark colored lithic fragments throughout; lower very fine to upper medium grain; well sorted throughout; mostly well rounded to sub-rounded with some sub-angular; moderate to high sphericity; very thin lenses of loose uncemented sand and very fine grained siliceous cemented sandstones inter-bedded with very thick beds of dense siltstones with lesser amounts of carbonaceous shales; no mineral fluorescence. Siltstone (9350-9415) = dark gray, with brownish black and brownish gray; slightly firm to stiff; crumbly to brittle; mostly irregular fracture; amorphous cuttings habit; dull to somewhat waxy; very thick beds of siltstones inter-bedded with thinner beds of carbonaceous shale and loose uncemented quartz sand; some very thin lenses of very fine grained, friable sandstones were also observed; no visible sample fluorescence was observed; pyrite was observed throughout the sample. Sand/Sandstone (9425-9495) = clear to translucent with some milky white, bluish gray, and light gray hues; predominantly quartz grain sand matrix; lower very fine to upper medium grain; well sorted throughout; well rounded to sub-rounded with some sub-angular; moderate to high sphericity; very thin lenses of loose uncemented sand and very fine grained siliceous cemented sandstones inter-bedded with very thick beds of dense siltstones with lesser amounts of carbonaceous shales; no mineral fluorescence. 2E-02 16 C (Top C4) to B2 (9,512’ to 9,562’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 222 64 158 322 257 259 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9562 322 45469 4529 1955 212 547 168 180 Individual sample descriptions are as follows: Siltstone (9500-9575) = brownish black, dark gray, black, and blackish brown; stiff; stiff to somewhat brittle; mostly irregular fracture; amorphous cuttings habit; greasy to somewhat dull luster; very silty texture, with some slightly gritty in places; thicker beds of siltstones inter-bedded with thinner beds of carbonaceous shale and loose uncemented quartz sand; some very thin lenses of very fine grained, friable sandstones were also observed; no visible sample fluorescence was observed; abundant crystalline pyrite throughout the sample. 2E-02 17 B2 to A6 (9,562’ to 9,851’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 309 65 169 1106 217 646 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 9741 1106 185784 18935 14950 694 1598 396 409 Individual sample descriptions are as follows: Sand/Sandstone (9580-9655) = translucent to clear, with some light gray, white and pale yellow orange hues; mostly quartz grain sand matrix with dark colored lithic fragments throughout; lower very fine to upper medium grain; well sorted throughout; mostly well rounded to sub-rounded with some sub-angular; moderate to high sphericity; very thin lenses of loose uncemented sand and very fine grained siliceous cemented sandstones inter-bedded with very thick beds of dense siltstones with lesser amounts of carbonaceous shales; no mineral fluorescence. Carbonaceous Shale (9660-9720) = dusky red, blackish red, and black; stiff to mostly firm; predominantly mostly planar, with some irregular; flaky to slightly platy cuttings habit; resinous to slightly waxy luster; predominantly smooth texture; thinner beds of carbonaceous shale inter-bedded with thinner beds of sandy siltstones and loose uncemented quartz grains; no visible sample fluorescence was observed. Sand/Sandstone (9725-9805) = clear to translucent with some milky white, light greenish gray, and light gray; predominantly quartz grain sand matrix; lower very fine to upper medium grain; well sorted throughout; well rounded to sub-rounded with some sub-angular; moderate to high sphericity; very thin lenses of loose uncemented sand and very fine grained siliceous cemented sandstones inter-bedded with very thick beds of dense siltstones with lesser amounts of carbonaceous shales; very pale yellow mineral fluorescence, approximately 10% to 15%; no solvent cut. Siltstone (9810-9890) = blackish brown, brownish black, black, very dark gray; stiff to somewhat brittle; mostly irregular fracture; amorphous cuttings habit; greasy to somewhat dull luster; very silty texture, with some slightly gritty in places; thicker beds of siltstones inter-bedded with thinner beds of carbonaceous shale and loose uncemented quartz sand; some very thin lenses of very fine grained, friable sandstones were also observed; no visible sample fluorescence was observed; abundant crystalline pyrite was observed throughout the sample. 2E-02 18 A6 to A5 (9,851’ to 10,018’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 270 7.2 106 1062 371 614 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 9917 1062 179600 19255 11782 878 2055 500 570 Individual sample descriptions are as follows: Sandstone/Sand (9895-9965) = clear to translucent, white, light gray to dark gray, and light greenish gray hues; predominantly quartz grain sand; lower very fine to upper medium grain; well sorted throughout; well rounded to sub-rounded with some sub-angular; moderate to high sphericity; very thin lenses of loose uncemented sand and very fine grained siliceous cemented sandstones inter-bedded with very thick beds of dense siltstones with lesser amounts of carbonaceous shales; very pale yellow mineral fluorescence; no solvent cut. 2E-02 19 A5 to Intermediate Casing point (10,018’ to 10,065’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 68 17 49 873 372 637 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 10054 873 99519 13840 18625 647 1555 382 419 Individual sample descriptions are as follows: Siltstone (9965-10065) = blackish brown, brownish black, black, very dark gray; very stiff to somewhat brittle; mostly irregular fracture; amorphous cuttings habit; greasy to somewhat dull luster; very silty texture, with some slightly gritty in places; thicker beds of silt- stones inter-bedded with thinner beds of carbonaceous shale and loose uncemented quartz sand; some very thin lenses of very fine grained, friable sandstones were also seen; trace larger individual quartz grains; abundant crystalline pyrite scattered throughout sample; 5% soft yellow fluorescence; no solvent cut. 2E-02 20 3.3 Connection Gases 1 unit = 0.05% Methane Equivalent Depth Gas over BGG (feet) (units) (No connection gases were observed.) 3.4 Trip (Wiper) Gases 1 unit = 0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) No trips were made 2E - 0 2 21 3. 5 G a s P e a k s & A s s o c i a t e d M u d D a t a De p t h (M D / T V D ) To t a l Ga s (u n i t s ) C1 (p p m ) C2 (p p m ) C3 (p p m ) iC 4 (p p m ) nC 4 (p p m ) iC 5 (p p m ) nC 5 (p p m ) Mu d W e i g h t s w i t h a s s o c i a t e d s h o w (p p g ) Mud Temp. Out (°F) 81 7 3 / 5 6 3 4 9 7 8 1 5 4 2 1 0 1 5 0 5 0 1 0 3 0 3 1 1 4 1 1 6 1 7 2 9 4 2 4 3 88 1 3 / 5 8 5 7 1 1 7 9 1 7 8 7 5 5 2 0 1 4 7 1 6 1 6 4 8 2 8 2 0 5 2 4 8 8 5 2 0 90 5 0 / 5 9 3 2 1 1 5 2 1 4 2 0 8 4 1 5 8 4 5 1 6 2 8 3 7 4 5 1 9 7 0 4 8 0 5 3 9 90 8 7 / 5 9 4 2 8 2 6 9 9 2 5 4 1 1 2 9 2 1 3 0 1 2 5 2 2 1 3 9 0 3 3 1 3 8 3 97 4 1 / 6 0 5 2 1 1 0 6 1 8 5 7 8 4 1 8 9 3 5 1 4 9 5 0 6 9 4 1 5 9 8 3 9 6 4 0 9 99 1 7 / 6 0 7 5 1 0 6 2 1 7 9 6 0 0 1 9 2 5 5 1 1 7 8 2 8 7 8 2 0 5 5 5 0 0 5 7 0 10 0 5 4 / 6 0 9 4 8 7 3 9 9 5 1 9 1 3 8 4 0 1 8 6 2 5 6 4 7 1 5 5 5 3 8 2 4 1 9 2E-02 22 3.6 Sampling Program / Sample Dispatch Samples were collected at 50’ intervals for mudlogging purposes only. No samples were bagged/boxed on this well. 2E - 0 2 23 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Ba s e d o n a r e g i o n a l p r e s s u r e g r a d i e n t , t h e p o r e p r e s s u r e g r a d i e n t ( P P G ) i s e s t i m a t e d t o b e 0 . 4 5 5 p s i / f t , o r 8 . 8 p p g i n t h e t a r g et sand. 4. 1 P o r e P r e s s u r e G r a d i e n t E v a l u a t i o n In t e r v a l T o p s P o r e P r e s s u r e ( E M W ) Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) MD (f t ) TV D (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators Ba s e W . S a k C l y s t 7 0 % Sl t s t 2 0 % , S d 10 % 4, 0 2 8 3 , 1 7 3 - 3 , 0 4 0 9 . 8 9 . 8 E v e n B G , E C D To p H R Z ( K - 2 Ma r k e r Sl t s t 7 0 % Cl y s t 2 0 % , S d 10 % 8, 2 5 3 5 , 6 6 7 - 5 , 5 3 0 1 0 . 0 9 . 9 D o w n B G , E C D U K a l u b i k ( B a s e HR Z ) Sl t s t 7 0 % Sd 2 0 % , Cb S h 1 0 % 8, 8 7 1 5 , 9 0 6 - 5 , 7 4 2 9 . 9 1 0 . 1 U p B G , E C D L K a l u b i k ( K - 1 Ma r k e r ) Sl t s t 5 0 % Sd 3 0 % , Cb S h 2 0 % 9, 0 6 7 5 , 9 3 7 - 5 , 8 0 6 9 . 9 1 0 . 1 U p B G , E C D C ( T o p C 4 ) S l t s t 8 0 % Cl y s t 1 0 % , S d 10 % 9, 5 1 2 6 , 0 2 4 - 5 , 8 9 1 1 0 . 1 1 0 . 1 E v e n B G , E C D B2 S l t s t 5 0 % Sd 2 0 % , Cb S h 2 0 % , Sn d s t 1 0 % 9, 5 6 2 6 , 0 3 1 - 5 , 8 9 8 1 0 . 1 1 0 . 1 E v e n B G , E C D B1 S l t s t 5 0 % Sd 2 0 % , Cb S h 2 0 % , Sn d s t 1 0 % 9, 5 6 2 6 , 0 3 1 - 5 8 9 8 1 0 . 1 1 0 . 1 E v e n B G , E C D A6 S l t s t 4 0 % Sn d s t 3 0 % , Cb S h 2 0 % , Sd 1 0 % 9, 8 5 1 6 , 0 6 6 - 5 , 9 3 3 1 0 . 1 1 0 . 1 E v e n B G , E C D A5 S l t s t 7 0 % Sn d s t 1 0 % , Cb S h 1 0 % , Sd 1 0 % 10 , 0 1 8 6 , 0 8 9 - 5 , 9 5 6 1 0 . 1 1 0 . 1 E v e n B G , E C D NO T E : S d = S a n d , C l s t = C l a y s t o n e / C l a y , S l t s t = S i l t s t o n e , S n d s t = Sa n d s t o n e , S h = S h a l e , C s C o n g l o m e r a t e S a n d , C g = C o n g l o m e r a te 2E - 0 2 24 4. 2 Q u a n t i t a t i v e M e t h o d s Th e p r i m a r y i n d i c a t o r s u s e d f o r P P G e v a l u a t i o n w e r e g a s t r e n d s re l a t i v e t o m u d w e i g h t ( M W ) a n d e f f e c t i v e c i r c u l a t i n g d e n s i t y ( E CD), including in c r e a s e s i n b a c k g r o u n d g a s ( B G ) , a p p e a r a n c e a n d t r e n d s o f c o n n e c t i o n ga s ( C G ) , a n d m a g n i t u d e s o f t r i p g a s ( T G ) a n d w i p e r g a s ( WG). Regional po r e p r e s s u r e t r e n d s f r o m s o n i c d a t a , p r o v i d e d b y C o n o c o P h i l l i p s , an d s u r f a c e m a n i f e s t a t i o n s o f h o l e c o n d i t i o n s w e r e a l s o c o n s i dered. As a r e f e r e n c e , P P G i s c a l c u l a t e d i n i t i a l l y w i t h a f o r m u l a p r ov i d e d b y E p o c h , a n d t h e n m o d i f i e d us i n g t h e i n d i c a t o r s d e s c r i b e d above, and DXC and re s i s t i v i t y ( R E S ) d a t a . T h e f o r m u l a u s e s D X , E C D , a n d B G a s m e a s u r e d b y t o t a l d i t c h g a s : P P G = E C D – ( 0 . 6 - ( ( . 0 0 1 * T L G S U ) + ( 0 . 0 5 * D X ) ) ) Th e f o r m u l a h a s c e r t a i n l i m i t a t i o n s , s u c h t h a t i t d o e s n o t a l l o w f o r a P P G m o r e t h a n 1 p p g l e s s t h a n t h e E C D , a n d T L G S U m u s t b e differentiated fr o m s h o w g a s a n d g a s c a r r i e d f r o m o v e r p r e s s u r e z o n e s , a n d i s d e p e n d e n t o n r e l i a b l e D X d a t a . H o w e v e r , t h e f o r m u l a p r o v e d u s e f ul in helping fo r m u l a t e a P P G r a n g e , w h e n e s t i m a t i n g t r e n d s , a s w i t h D X C d a t a , w i t h d a t a p o i n t s i n s h a l e i n t e r v a l s . 2E-02 25 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 90.00 0.10 251.09 90.00 0.03 -0.03 -0.07 0.11 182.00 0.29 301.04 182.00 -0.06 0.07 -0.35 0.26 275.00 0.23 276.10 275.00 -0.18 0.21 -0.74 0.14 367.00 0.41 278.11 367.00 -0.23 0.28 -1.25 0.20 461.00 0.21 336.31 461.00 -0.42 0.48 -1.65 0.37 552.00 0.18 241.99 552.00 -0.50 0.57 -1.84 0.32 614.00 0.39 225.67 613.99 -0.30 0.37 -2.08 0.36 645.00 0.53 223.79 644.99 -0.12 0.20 -2.25 0.45 737.00 1.09 224.75 736.98 0.84 -0.73 -3.16 0.61 830.00 2.21 232.75 829.94 2.63 -2.45 -5.21 1.23 922.00 5.58 243.67 921.72 5.87 -5.50 -10.64 3.73 1,015.00 8.25 243.02 1,014.03 11.25 -10.54 -20.64 2.87 1,107.00 12.30 238.76 1,104.54 19.83 -18.62 -34.90 4.48 1,153.00 14.07 237.56 1,149.33 25.67 -24.16 -43.81 3.89 1,200.00 17.40 236.11 1,194.56 33.03 -31.14 -54.47 7.13 1,224.30 18.13 238.02 1,217.70 37.27 -35.17 -60.69 3.84 1,318.77 19.56 237.62 1,307.10 54.42 -51.43 -86.52 1.52 1,411.19 20.96 238.05 1,393.80 72.38 -68.46 -113.61 1.52 1,503.27 21.14 239.73 1,479.74 90.45 -85.55 -141.93 0.68 1,595.46 23.35 239.30 1,565.06 109.19 -103.25 -172.00 2.40 1,689.80 23.12 240.89 1,651.75 128.86 -121.81 -204.25 0.71 1,783.07 29.62 237.85 1,735.28 151.29 -143.01 -239.81 7.12 1,829.07 30.75 237.43 1,775.04 164.34 -155.39 -259.34 2.50 1,876.26 31.60 236.78 1,815.41 178.32 -168.66 -279.85 1.94 1,969.05 33.28 235.61 1,893.72 207.45 -196.36 -321.20 1.93 2,019.33 37.05 234.27 1,934.82 224.91 -213.00 -344.89 7.65 2,060.30 39.08 234.74 1,967.07 240.28 -227.66 -365.46 5.01 2,154.26 37.86 234.39 2,040.64 275.81 -261.55 -413.08 1.32 2,245.09 41.03 235.00 2,110.77 310.77 -294.89 -460.18 3.52 2,339.46 44.39 234.79 2,180.10 349.38 -331.70 -512.53 3.56 2,431.68 49.03 232.76 2,243.32 390.94 -371.39 -566.64 5.28 2,479.57 51.28 231.42 2,274.01 414.53 -393.98 -595.64 5.17 2,522.72 52.79 231.30 2,300.55 436.69 -415.22 -622.21 3.51 2,615.93 53.90 231.91 2,356.20 485.14 -461.66 -680.82 1.30 2E-02 26 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 2,708.24 53.43 232.38 2,410.89 532.80 -507.30 -739.53 0.65 2,802.68 56.22 232.79 2,465.29 581.80 -554.19 -800.84 2.98 2,894.14 55.47 232.31 2,516.64 629.89 -600.21 -860.93 0.93 2,986.15 55.19 232.20 2,568.98 678.27 -646.53 -920.76 0.32 3,079.33 54.68 232.10 2,622.51 727.15 -693.33 -980.99 0.55 3,172.18 53.78 232.84 2,676.78 775.10 -739.23 -1,040.73 1.17 3,262.76 55.01 231.61 2,729.52 822.22 -784.34 -1,098.93 1.75 3,355.72 53.81 231.92 2,783.62 871.04 -831.13 -1,158.31 1.32 3,449.61 55.28 231.16 2,838.08 920.68 -878.70 -1,218.19 1.70 3,541.30 54.83 231.06 2,890.60 969.87 -925.88 -1,276.69 0.50 3,635.63 55.64 230.13 2,944.39 1,021.13 -975.08 -1,336.56 1.18 3,726.21 55.25 231.03 2,995.77 1,070.48 -1,022.45 -1,394.19 0.92 3,818.80 54.78 231.78 3,048.85 1,119.84 -1,069.77 -1,453.48 0.84 3,911.61 53.55 232.06 3,103.19 1,168.29 -1,116.18 -1,512.70 1.35 4,005.59 53.26 232.39 3,159.22 1,216.56 -1,162.40 -1,572.34 0.42 4,080.12 53.04 232.60 3,203.91 1,254.50 -1,198.71 -1,619.65 0.37 4,127.21 53.17 233.01 3,232.18 1,278.30 -1,221.47 -1,649.65 0.75 4,223.18 53.19 233.99 3,289.70 1,326.12 -1,267.17 -1,711.41 0.82 4,317.23 53.03 233.10 3,346.16 1,372.90 -1,311.86 -1,771.91 0.78 4,408.54 53.07 233.29 3,401.04 1,418.63 -1,355.58 -1,830.34 0.17 4,503.42 52.98 233.49 3,458.11 1,465.93 -1,400.78 -1,891.18 0.19 4,593.75 52.49 233.80 3,512.81 1,510.54 -1,443.40 -1,949.08 0.61 4,686.74 52.45 233.92 3,569.45 1,556.08 -1,486.89 -2,008.63 0.11 4,781.01 52.46 234.06 3,626.90 1,602.11 -1,530.83 -2,069.09 0.12 4,872.05 52.35 233.51 3,682.44 1,646.73 -1,573.45 -2,127.29 0.49 4,965.22 52.30 232.85 3,739.39 1,692.96 -1,617.65 -2,186.32 0.56 5,057.33 52.48 231.93 3,795.60 1,739.48 -1,662.18 -2,244.13 0.82 5,148.60 52.96 231.60 3,850.88 1,786.39 -1,707.12 -2,301.17 0.60 5,242.26 52.93 232.43 3,907.32 1,834.42 -1,753.12 -2,360.08 0.71 5,335.97 52.94 232.63 3,963.80 1,881.96 -1,798.61 -2,419.43 0.17 5,429.57 52.91 232.12 4,020.23 1,929.58 -1,844.20 -2,478.57 0.44 5,520.26 53.05 231.73 4,074.84 1,976.20 -1,888.86 -2,535.58 0.38 5,613.49 53.06 231.12 4,130.87 2,024.66 -1,935.32 -2,593.83 0.52 5,706.18 52.92 230.37 4,186.67 2,073.47 -1,982.15 -2,651.14 0.66 5,798.29 53.00 230.35 4,242.15 2,122.32 -2,029.06 -2,707.76 0.09 5,892.61 52.97 230.43 4,298.93 2,172.33 -2,077.07 -2,765.78 0.07 5,983.98 52.92 230.72 4,353.99 2,220.58 -2,123.38 -2,822.10 0.26 6,075.42 52.95 231.55 4,409.11 2,268.32 -2,169.17 -2,878.92 0.73 2E-02 27 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 6,169.20 52.98 232.56 4,465.59 2,316.38 -2,215.20 -2,937.95 0.86 6,261.89 52.98 232.68 4,521.40 2,363.33 -2,260.13 -2,996.76 0.10 6,354.13 52.99 232.97 4,576.93 2,409.86 -2,304.63 -3,055.44 0.25 6,448.00 52.95 232.71 4,633.46 2,457.18 -2,349.90 -3,115.17 0.23 6,539.90 52.88 231.77 4,688.88 2,504.07 -2,394.79 -3,173.12 0.82 6,632.46 52.95 231.25 4,744.69 2,552.01 -2,440.74 -3,230.92 0.45 6,724.08 52.92 230.86 4,799.91 2,599.92 -2,486.70 -3,287.78 0.34 6,817.41 52.93 230.94 4,856.18 2,648.88 -2,533.66 -3,345.56 0.07 6,908.00 52.98 231.55 4,910.75 2,696.08 -2,578.92 -3,401.95 0.54 7,003.15 52.88 231.96 4,968.11 2,745.13 -2,625.92 -3,461.58 0.36 7,092.73 52.77 231.95 5,022.24 2,791.05 -2,669.91 -3,517.79 0.12 7,188.45 52.85 232.10 5,080.10 2,840.04 -2,716.83 -3,577.90 0.15 7,280.49 53.11 231.62 5,135.51 2,887.41 -2,762.21 -3,635.69 0.50 7,371.75 53.58 231.61 5,190.00 2,934.85 -2,807.67 -3,693.08 0.52 7,464.59 53.57 231.99 5,245.12 2,983.07 -2,853.87 -3,751.79 0.33 7,558.61 53.55 231.64 5,300.96 3,031.87 -2,900.62 -3,811.24 0.30 7,651.73 53.41 231.52 5,356.38 3,080.39 -2,947.13 -3,869.87 0.18 7,744.47 54.98 230.93 5,410.64 3,129.51 -2,994.23 -3,928.51 1.77 7,837.45 57.04 230.08 5,462.61 3,180.59 -3,043.27 -3,987.98 2.34 7,930.40 58.58 229.49 5,512.13 3,233.45 -3,094.06 -4,048.05 1.74 8,022.45 59.54 229.01 5,559.46 3,287.04 -3,145.60 -4,107.86 1.14 8,115.79 62.43 229.25 5,604.73 3,342.57 -3,199.00 -4,169.58 3.10 8,209.20 65.41 228.18 5,645.79 3,400.09 -3,254.36 -4,232.61 3.35 8,298.43 68.08 227.16 5,681.02 3,457.37 -3,309.56 -4,293.21 3.17 8,393.31 70.80 225.22 5,717.72 3,531.07 -3,381.46 -4,345.80 3.34 8,486.36 70.13 225.62 5,748.84 3,594.76 -3,443.01 -4,408.26 0.83 8,579.02 70.79 226.07 5,779.83 3,657.74 -3,503.84 -4,470.92 0.85 8,671.87 70.72 225.12 5,810.43 3,721.23 -3,565.18 -4,533.54 0.97 8,762.85 70.94 225.15 5,840.31 3,783.94 -3,625.80 -4,594.45 0.24 8,855.55 70.88 224.47 5,870.63 3,848.20 -3,687.95 -4,656.19 0.70 8,949.24 71.14 223.98 5,901.11 3,913.81 -3,751.44 -4,717.98 0.57 9,041.21 73.30 222.67 5,929.20 3,979.57 -3,815.15 -4,778.06 2.71 9,134.03 75.39 221.06 5,954.24 4,048.17 -3,881.70 -4,837.69 2.80 9,224.13 77.64 219.89 5,975.25 4,116.76 -3,948.35 -4,894.56 2.80 9,318.27 79.75 219.36 5,993.71 4,189.87 -4,019.45 -4,953.43 2.31 9,410.01 81.02 217.89 6,009.03 4,262.46 -4,090.11 -5,009.89 2.10 9,503.22 82.12 216.46 6,022.70 4,337.83 -4,163.58 -5,065.60 1.92 9,597.65 82.78 214.56 6,035.10 4,415.88 -4,239.77 -5,119.97 2.11 2E-02 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 9,689.12 83.22 212.31 6,046.25 4,493.33 -4,315.53 -5,169.98 2.49 9,783.69 83.02 209.50 6,057.58 4,575.52 -4,396.08 -5,218.20 2.96 9,876.21 82.41 205.77 6,069.32 4,658.24 -4,477.37 -5,260.76 4.05 9,968.62 81.97 202.00 6,081.88 4,743.18 -4,561.07 -5,297.83 4.07 10,001.20 82.03 201.24 6,086.42 4,773.57 -4,591.06 -5,309.72 2.32 2E - 0 2 29 5. 2 B i t R e c o r d Bi t # Si z e M a k e Ty p e / Se r i a l # Je t s / TF A De p t h I n MD / T V D To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) Av g . WO B (K l b s ) Av g RP M Av g PP (p s i ) Wear BHA # 1 9 7 / 8 ” S e c u r i t y PD C / 11 7 1 0 8 7 8 5x 1 3 , 1x 1 4 4, 1 5 1 ’ 5 , 9 1 4 ’ 4 1 . 1 1 5 6 . 9 8 . 9 1 4 2 2 5 1 7 0- 1 - B T - S - X - 1 / 1 6 - W T - T D 1 2E - 0 2 30 5. 3 M u d R e c o r d C o n t r a c t o r : M I S W A C O Mu d T y p e : D r i l l P l e x Da t e D e p t h / T V D M W V I S P V Y P G e l s F L F C S o l O / W S d A l k C l C a ECD (at TD’s) 8/ 5 / 2 0 1 4 4 , 1 5 1 ’ 9 . 8 4 7 2 2 1 1 5 / 6 / 6 — — 9 - / 9 1 0 . 5 2 . 0 6 0 0 2 0 — 8/ 6 / 2 0 1 4 5 , 9 9 9 ’ 9 . 7 5 3 1 3 2 5 1 1 / 1 2 / 1 3 4 . 8 1 7 3 / 9 0 0 . 2 5 0 . 2 4 7 2 0 4 5 1 0 . 9 9 8/ 7 / 2 0 1 4 7 , 9 0 3 ’ 1 0 . 1 5 7 1 7 3 4 1 5 / 2 8 / 3 7 2 . 8 1 1 1 4 / 8 6 0 . 5 0 . 4 6 7 0 0 4 0 1 1 . 3 6 8/ 8 / 2 0 1 4 1 0 , 0 6 5 ’ 1 0 . 1 4 1 1 1 1 9 7 / 1 0 / 1 4 3 . 3 1 7 3 / 9 0 0 . 5 0 . 4 7 6 6 0 6 0 1 0 . 9 0 8/ 9 / 2 0 1 4 1 0 , 0 6 5 ’ 1 0 . 1 4 1 1 1 2 5 1 0 / 1 3 / 1 7 2 . 9 1 8 . 5 3 / 8 9 0 . 5 0 . 6 6 0 0 6 0 — 8/ 1 0 / 2 0 1 4 1 0 , 0 6 5 ’ 1 0 . 0 4 4 1 3 1 8 7 / 8 / 9 3 . 3 1 7 . 5 3 / 9 0 0 . 5 0 . 6 6 2 0 6 0 — Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h O / W = O i l t o W a t e r r a t i o C a = C a l c i u m ( H a r d n e s s ) VI S = F u n n e l V i s c o s i t y F L = F i l t r a t e ( F l u i d ) L o s s S d = S a n d C o n t e n t ( % ) E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y PV = P l a s t i c V i s c o s i t y F C = F i l t e r C a k e A l k = A l k a l i n i t y YP = Y i e l d P o i n t S o l = S o l i d s ( % ) C l = C h l o r i d e s 31 6 MORNING REPORTS ConocoPhillips Alaska, Inc. 2E-02 Daily Geologic Report Report for: Phillip Bottrell Date: 8/07/2014 Time: 05:00 Current Depth (MD): 6,491’ Current Depth (TVD): 4,661 Current Operations:Drilling Ahead 24 hr Footage (MD): 2,340’ Drilling Parameters ROP: Current: 165 Max: 374 Torque: Current:9216 Max: 12142 WOB: Current 6.2 Max: 18 RPM: Current:130 Max: 162 PP: Current: 2460 Max: 2509 Lag: Strokes: 4535 Time: 15.06min Surf-Surf: Strokes:5611 Time: 18.64min ECD: Current: Max: Mud Properties @ 4151’ MW: 9.7 FV: 53 PV:13 YP:25 FL: 4.8 Gels: 11/12/13 Sol: 7 pH:9.7 Cl-:720 Ca++: 45 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 42 137 4,660’ LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection Gases NA C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 30% claystone, 60% siltstone, 10% sand Last 24 hrs: Operational Summary: Drill from 4151’ MD to 6491’ MD at time of report. Failures: Chromatograph and RigWatch ConocoPhillips Alaska, Inc. 2E-02 Daily Geologic Report Report for: Phillip Bottrell Date: 8/08/2014 Time: 05:00 Current Depth (MD): 8,829’ Current Depth (TVD): 5,808’ Current Operations:Drilling Ahead 24 hr Footage (MD): 2,338’ Drilling Parameters ROP: Current: 157 Max: 381 Torque: Current:10477 Max: 15176 WOB: Current 9.1 Max: 21 RPM: Current:162 Max: 144 PP: Current: 2707 Max: 3092 Lag: Strokes: 6165 Time: 20.15min Surf-Surf: Strokes:7655 Time: 25.01min ECD: Current: Max: Mud Properties @ 4151’ MW: 10.1 FV: 57 PV:17 YP:34 FL: 2.8 Gels: 15/28/37 Sol: 11 pH:10.0 Cl-:700 Ca++: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 270 1044 8,446’ LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection Gases NA C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 10% claystone, 80% siltstone, 10% sand @ 8700’ Last 24 hrs: Operational Summary: Drill from 6,491’ MD to 8,829’ MD at time of report. Failures: n/a ConocoPhillips Alaska, Inc. 2E-02 Daily Geologic Report Report for: Phillip Bottrell Date: 8/09/2014 Time: 05:00 Current Depth (MD): 10,065’ Current Depth (TVD): 6,095’ Current Operations:Pulling Out of Hole 24 hr Footage (MD): 1,236’ Drilling Parameters ROP: Current: 147 Max: 358 Torque: Current:13144 Max: 18031 WOB: Current 13.6 Max: 22 RPM: Current:158 Max: 162 PP: Current: 2959 Max: 3133 Lag: Strokes: 7015 Time: 22.70min Surf-Surf: Strokes:7655 Time: 25.01min ECD: Current: Max: Mud Properties @ 4151’ MW: 10.1 FV: 41 PV:11 YP:19 FL: 3.3 Gels: 7/10/14 Sol: 7 pH:9.9 Cl-:660 Ca++: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 507 1152 9050 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection Gases NA C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 50% siltstone, 20% sand, 20% sandstone, 10% carbonaceous shale @ 10065’ Last 24 hrs: Operational Summary: Drill from 8,829’ MD to 10,065’ MD; begin to pull out of hole. Failures: n/a ConocoPhillips Alaska, Inc. 2E-02 Daily Geologic Report Report for: Phillip Bottrell Date: 8/10/2014 Time: 05:00 Current Depth (MD): 10,065’ Current Depth (TVD): 6,095’ Current Operations:Running Casing in Hole 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 4151’ MW: 10.1 FV: 41 PV:11 YP:25 FL: 2.9 Gels: 10/13/17 Sol: 8.5 pH:9.9 Cl-:600 Ca++: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection Gases NA C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new lithology Last 24 hrs: Operational Summary: Finish pulling out of hole; test rams for running casing; begin to run casing Failures: n/a ConocoPhillips Alaska, Inc. 2E-02 Daily Geologic Report Report for: Phillip Bottrell Date: 8/11/2014 Time: 05:00 Current Depth (MD): 10,065’ Current Depth (TVD): 6,095’ Current Operations: 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 4151’ MW: 10.0 FV: 44 PV:13 YP:18 FL: 3.3 Gels: 7/8/9 Sol: 3.3 pH:7.5 Cl-:620 Ca++: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection Gases NA C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: No new lithology Last 24 hrs: Operational Summary: Run casing; pump cement. Failures: n/a
