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Home My WebLink About214-136MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2F-21 KUPARUK RIV UNIT 2F-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/16/2024 2F-21 50-029-23525-00-00 214-136-0 W SPT 6110 2141360 1528 2778 2769 2785 2814 265 396 378 367 4YRTST P Bob Noble 7/6/2024 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 2F-21 Inspection Date: Tubing OA Packer Depth 510 1980 1910 1910IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240707134531 BBL Pumped:2.5 BBL Returned:2.1 Friday, August 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 99 999 99 99 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 16:07:52 -08'00' MEMORANDUM TO: Jim Regg41 �7.tJZ,I P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 27, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2F-21 KUPARUK RIV UNIT 2F-21 Src: Inspector Reviewed By:q-� P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 217-21 API Well Number 50-029-23525-00-00 Inspector Name: Lou Laubenstein ' Permit Number: 214-136-0 Inspection Date: 5/23/2021 Insp Num: mitLOL210523132211 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-21 Type Inj r W JVD 6110 Tubing 2754 2757. 2776 2760 ---- PTD 2141360 -Type Test SPT Nest psi 1528 IA 860 2000 - 1960 - 1960 - I BBL Pumped: 21 _ BBL Returned: 1.8 OA 340 452 446 446 Interval 4YRTST p/F P Notes: Godd test Thursday, May 27, 2021 Page 1 of I leu 2'C-zi Regg, James B (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, July 15, 2020 8:39 AM To: Regg, James B (CED); Wallace, Chris D (CED); Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay Subject: KRU Non Witnessed MITIAs 7/13/20 Attachments: MIT KRU 2F PAD SI TESTS 07-13-20.xlsx; MIT KRU 1 D-38 SI TEST 07-13-20-.xlsx All, 'Te%i 71f 7(?i1z o Attached are Non Witnessed MITIA's performed in Kuparuk 7/13/20. Please let me know if you have any questions. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM co„ '> uq» STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regalffialaska.nov: AOGCC. InsoeclorsGDalaskaaovv phoebe.brooks0alaska.aov OPERATOR: ConoccPhillips Alaska Inc FIELD/UNIT/PAD: Kuparuk/KRU/2F Pad DATE: 07/13/20 OPERATOR REP: VanCamp / Weimer AOGCC REP: 60 Min. chris.wallaceicDalaska oov Well 2F-04 INTERVAL Cotler Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fail PTD 1831900 Typelnj N Tubing 2120 2125 2125 2125 Type Tesl P Packer TVD 5765 BBL Pump 2.5 IA 225 3300 3225 3200 Interval V Test psi 3000 BBL Return 2.2 OA 90 90 90 - 90 Result P Notes: MITIA to maximum anticipated injection pressure per AIO 28.074 Well 2F-14 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1831590 1 Typelnj N Tubing 1500 1550 1550 1550 Type Test P Packer TVD 5857 BBL Pump 2.0 IA 225 3325 3260 3250 Interval V Test psi 3000 BBL Return 2.0 OA 60 60 60 60 Result P Notes: MITIA to maximum anticipated injection pressure per AI02C.064 Well 2F-15 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD 83172!Typelnji N Tubing 1975 2025 2000 2000 Type Test P Packer TVD58703.0 IA 200 2760 2675 2650 Interval 4 Test psi15002.8 OA 20 20 20 20 Result P Notes: [1831770 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD N Tubing 2075 2075 2075 2075 Type Test P Packer TVD 5834 BBL Pump 3.0 IA 225 2860 2775 2750 Interval 4 Test psi 1500 BBL Return 2.8 OA 80 80 80 80 Result P Notes: Well 2F-21 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD 2141360 Type Inj N Tubing 2300 - 2300 2300 2300- Type Test P Packer TVD 6110 BBL Pump 2.4 - IA 275 1800- 1750 1725 - Interval 4 Test psi 1528 BBL Return 2.4 OA 140 - 255 270 - 270 - Result P Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Cotler Result Codes W=Water P=Perrone Test 1=Initial Test P=Fees G=Gas O= Other (describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V= Required by Valance 1=Inconclusive I = Induatnal Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 2F PAD SI TESTS 07-13-20 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 29,2016 TO: Jim Regg l of et Ill� P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F-21 FROM: Johnnie Hill KUPARUK RIV UNIT 2F-21 Petroleum Inspector Src: Inspector Reviewed B P.I.Suprvt We— NON-CONFIDENTIAL e—NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-21 API Well Number 50-029-23525-00-00 Inspector Name: Johnnie Hill Permit Number: 214-136-0 Inspection Date: 7/8/2016 Insp Num: mitJWH160826174214 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-21 Type Inj 3 W'TVD 6110 , Tubing 2613 - 2622 , 2612- 2613 - . 2553 . PTD 2141360 - Type Test SPT Test psi 1528 - IA 870 1990 - 1960 . 1930. 1910 Interval TST PAFP ✓ OA 322 408 381 362 _ 348' Notes: SCANNED JUN 2 3 2017, Monday,August 29,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,December 03,2015 TO: Jim Regg 12-Aq(/.< SUBJECT: Mechanical Integrity Tests P.I.Supervisor CONOCOPHILLIPS ALASKA INC 2F-21 FROM: Matt Herrera KUPARUK RIV UNIT 2F-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-21 API Well Number 50-029-23525-00-00 Inspector Name: Matt Herrera Permit Number: 214-136-0 Inspection Date: 11/29/2015 Insp Num: mitMFH151130102416 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-21 • Type Inj W -TVD 6110 Tubing I 2150 2150 2150 2150 PTD 2141360 " Type Test SPT Test psi 1528 - IA 774 3002 2945 . 2931 • Interval IINITAL P/F P OA 210 317 _ 318 320 • Notes: Initial MIT post conversion from producer to injector per Sundry 315-367.IA pressure tested to 3000 PSI Per CPAI Rep. SCANNED SEP 1 62016 Thursday,December 03,2015 Page 1 of 1 Brooks, Phoebe L (DOA) PTD-* 2-P1(369 136p From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, December 03, 2015 1:39 PM To: Brooks, Phoebe L (DOA) Subject: RE: Recent witnessed MITs at Kuparuk Attachments: 2F-21 schematic.pdf Here you go. -Kelly From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Thursday, December 03, 2015 1:32 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Recent witnessed MITs at Kuparuk Kelly/Brent, Will you send me the schematic for 2F-21 PTD#2141360? Thank you, n.. Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission SCANNED JAN 2 9 yulti 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, November 30, 2015 11:11 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Recent witnessed MITs at Kuparuk Attached are MIT forms for the tests performed yesterday in Kuparuk. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 1 KUP PROD 2F-21 ConocoPhillips m Well Attributes Max Angle&MD TD _11,.1„,,.._ I• Wellbore APIIUWI Field Name Wellbore Status Ind('I MD(1WK8) Act Btm MKS) [monilulkps 500292352500 KUPARUK RIVER UNIT PROD 92.50 20,004.29 20,274.0 ... .,.... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) ,,Rig Release Date HORIZONTAL-2F-21.8115/2015 30633 PM SSSV:NIPPLE Last WO: 27.50 12/3/2014 Verocal a hemanc(actual) 'Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O,REMOVED CS LOCK lehallf 8/15/2015 HANGER;23.3 - 'Ir W/GAUGES Casing Strings C Casing Description CONDUCTOR OD(in) ID(in) Top(EKE) Set Depth MB) Set Depth(TVD)...Whine(i...Grade Top Thread 20 18.430 280 143.0 143.0 164.00 H-40 Casing Description OD(in) ID(in) Top(EKE) Set Depth(ftKB) Set Depth(TVD)...Wt/Len II...Grade Top Thread SURFACE 10 3/4 9.950 26.2 3,996.4 3,027.4 45.50 L-80 HYD 563 Casing Description OD(in) ID(in) 'Top(MB) Set Depth(RKB) Set Depth(TV0)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 24.2 14,606.6 6,144.4 29.70 L-80 Hyd 563 ... ' . Casing Description OD(in) 10(in) Top(RKB) Set Depth MEI) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SLOTTED LINER 4 12 3.958 14,447.0 20,233.0 11.60 L-80 HYD 563 Liner Details • Nominal ID XO Reducing;582 * Top(MB) Top(TVD)(1tKB) Top Ind r) Item Des Com (in) 14,447.0 6,118.5 78.23 PACKER BAKER ZXP PACKER W/HRDE PROFILE 5.750 'A'M CONDUCTOR;28.0-1450 14466.9 6,122.4 78.76 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 5 14,469.7 6,123,0 78.83 HANGER BAKER"DG"FLEX LOCK LINER HANGER 4.790 NIPPLE;584.8 14,996.4 6,160.2 89.06 SWELL 'FREECAP I FSC-11 SWELL PACKER 3.958 PACKER 15,203.0' 6,160.9 89.78 SWELL FREECAP I FSC-11 SWELL PACKER 3.958 IPACKER GAS uFr;2794s I Tubing Strings Tubing Description String Ma...lb(in) Top(MB) Set Depth(it..Set Depth(TVDWft))(...(Wt(IGrade Top Connection II TUBING-Upper 41/2 31/2 2.992 23,3 14,400.4 6,108.5 9.301-80 EUE x31/2Aa 58.17 i I Completion Details Nominal ID Top(ftK8) Top(ND)(RKB) Top Incl(') Item Don Com (in) 23.3: HANGER CAMERON TUBING HANGER 3.900 SURFACE;26.2-3,9.96.4 582 58.2' 0.06 X0 Reducing XO,7,4-12"12.681-80 IBTM box x 3-12"9.38 L-80 2.940 EUE 8RD-Mod pin 564.6 564.4 3.21 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 SLEEVE;14145.6it: 14,145.8 6,048.3' 76.25 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE 2.812 FLOWTHRU SUB;141460 rit PROFILE 14,377.7 6,103.3_ 76.71 LOCATOR LOCATOR SUB 2.980 04,378.7 6,103.5 76.71 SEAL ASSY BAKER(80-40)PBR SEAL ASSY 2.980 IIITubing Description String Ma...ID(in) Top(f1KB) Set Depth(tt..Set Depth(TVD)(...Wt PbIR) Grade Top Connection II TUBING-Lower I 5I 4.0001 14,384.7 14,466.11 6,122.31 9.3011-80 'Top LOCATOR;14,377.7 Vir Completion Details Nominal ID SEAL ASSY;14.378 7-. _ Top(ftKB) Top(ND)(RKB) Top Incl r) Item Des Con, (in) PBR;14,384.7 8_l 14,384.7 6,104.9 76.75 PBR POLISHED BORE RECEPTACLE 4.000 WIi 14,408.8 6,110.4 77.23 PACKER BAKER PREMIER PRODUCTION PACKER 3.500 XOnawde;14,407.3 14,429.4 6,114.8 77.78 NIPPLE CAMCO D NIPPLE 2.750 PACKER;14,408.8 14,436.3 6,116.3 77.95 PLUG HALLIBURTON MIRAGE PLUG(NO SIGN OF PLUG 2.880 XO Threads,14,415.4 21132015) 5 14,444.9 6,118.0 78.18 SUB,NO-GO NO GO SUB:SPACED OUT 2'OFF LINER TOP 3.010 NIPPLE;14,428.4 14,446.0 6,118.3 78.21'SOS SHEAR OUT SUB 3.010 5 14,465.1 6,122.1 78.71 MULE SHOE MULE SHOE W/WLEG 3.000 PLUG;14,438.2 = Perforations&Slots IIShot SUB,NO-GO;14,444.8 . Dens Top(TVD) Btm(TVD) Dens SOS,14445.9 S. Top(RKB) _Eine(1tKB) (RKB) (ftKB) Zone Date t) Type Com .11. 14,529.0 14,945.2 6,133.5 6,159.3 11/26/2014 SLOTS SLOTTED LINER 15,274.2 20,201.4' 6,162.2 11/26/2014 SLOTS SLOTTED LINER MULE SHOE;14,465.1 Mandrel Inserts St Wr mi 'I on Top(ND) Valve Latch Port Size TRO Run N, Top(MB) (RKB) Make Model OD(in) Seri/ Type Type (in) (psi) Run Date Com 1 2,794.5 2,522.2 Cameron 134AF0 1 12 GAS LIFT DMY RK 0.000 0.0 8/6/2015 1 Notes:General&Safety End Date Annotation 2/13/2015 NOTE:DRIFTED TO 14475'I'81 degrees approx)no sign of Mirage Plug NOTE:The lower tubing is 3 1/2 OD not 5. I INTERMEDIATE;24,2-14,606.6___011 I L SLOTS;14,529.0-14,945.2-� 11111 Si SLOTS;19,2742.20,201.4 SLOTTED LINER;14,447.0- 20,233.0 ` . STATE OF ALASKAIII AL KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other StimulateAlter Casing r r Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Prod to WAG P 2.Operator Name: ' 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 214-136-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23525-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025657;ADL025666;ADL392364 KRU 2F-21 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 20274 feet Plugs(measured) None true vertical 6256 feet Junk(measured) None Effective Depth measured 20233 feet Packer(measured) 14409 true vertical 6255 feet (true vertical) 6114 Casing Length Size MD ND Burst Collapse CONDUCTOR 115 20 143 143 SURFACE 3970 11.8 3996 3028 INTERMEDIATE 14582 10.625 14607 6148 SLOTTED LINER 5786 6.55 20233 6255 Perforation depth: Measured depth: Slots: 14526-14945; 15274-202002 {r)\ ! $g 2 True Vertical Depth: 6136-6163;6165-6255 >G SCANNED PPP i i ,...u:(),O1 Tubing(size,grade,MD,and ND) 3.5, L-80, 14,400 MD, 6,122 TVD " :Oi Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PRODUCTION PACKER @ 14409 MD and 6114 TVD SSSV-Nipple @ MD=565 TVD=564 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 1303 71 Subsequent to operation 1980 897 1595 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I'• Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r 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: 315-367 Contact Darrell Humphrey/Bob Christensen Email n1139(c�conocophillips.com Printed Name L.bert D. Christen4çne: n Title NSK Production Engineering Specialist Signature t 659-7535 Date _ • II�l6/1� r7 %C, /`L RBDMS4kinV 182015 Form 10-404 Revised 5/2015 /� (/7' Submit Original Only • 2F-21 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/06/15 GAUGED TBG TO 2.83"TO 4000' SLM; DEPLOYED CATCHER. PULLED OV, SET DV @ 2794' RKB. MIT IA 3000 PSI, PASSED. PULLED CATCHER. IN PROGRESS. **MITIA pass: preT10=925/150/155, initial=950/3000/260, 15min=950/2940/260, 30min=950/2925/260** 11/14/15 Commenced Injection Service KUP PROD 0 2F-21 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Canocoe+Tkpy 500292352500 KUPARUK RIVER UNIT PROD 92.50 20,004.29 20,274.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-2F-21,8/15/20153:0633 PM SSSV:NIPPLE Last WO: 27.50 12/3/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O,REMOVED CS LOCK lehallf 8/15/2015 HANGER;23.3 I" W/GAUGES a Is ng Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth IRKS) Set Depth(TVD)... WULen(I...Grade Top Thread CONDUCTOR 20 18.430 28.0 143.0 143.0 164.00 H-40 • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • SURFACE 103/4 9.950 26.2 3,996.4 3,027.4 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 INTERMEDIATE 75/8 6.875 24.2 14,606.6 6,144.4 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)... Wt/Len(I...Grade Top Thread __.................__...__...._....__.................. ...,......... ............ -'SLOTTED LINER 4 1/2 3.958 14,447.0 20,233.0 11.60 L-80 HYD 563 Liner Details Nominal ID XO Redwing;56.2 * Top(ftKB) Top(TVD)(ftKB)_Top Incl(°) Item Des Cont (in) 14,447.0 6,118.5 78.23 PACKER BAKER ZXP PACKER W/HRDE PROFILE 5.750 AAA CONDUCTOR;2e.0-143.06ft 14,466.9 6,122.4 78.76'NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 11 14,469.7 6,123.0 78.83 HANGER BAKER"DG"FLEX LOCK LINER HANGER 4.790 NIPPLE;564.6 14,996.4 6,160.2 89.06 SWELL FREECAP I FSC-11 SWELL PACKER 3.958 PACKER 15,203.0 6,160.9 89.78 SWELL FREECAP I FSC-11 SWELL PACKER 3.958 PACKER Tubing Strings GAS LIFT;2,794.5 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING-Upper 41/2 31/2 2.992 23.3 14,400.4 6,108.5 9.30 L-80 TUE x31/2@)58.17 I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des cum in) 23.3 HANGER CAMERON TUBING HANGER 3.900 SURFACE;26.2-3,996.4 58.2 58.2 0.06 XO Reducing XO,2,4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 2.940 EUE 8RD-Mod pin 564.6 564.4 3.21 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 SLEEVE;14.1400- = - 14,145.8 6,048.3 76.25 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE 2.812 FLOW THRU SUB;14,146.0 PROFILE ); 14,377.7 6,103.3 76.71 LOCATOR LOCATOR SUB 2.980 14,378.7 6,103.5 76.71 SEAL ASSY BAKER(80-40)PBR SEAL ASSY 2.980 Tubing Description String Ma...ID(In) Top(ftKB) -Set Depth Ift..Set Depth(WD)(...Wt(lb/ft) Grade Top Connection it TUBING-Lower 1 5I 4.0001 14,384.7 14,466.11 6,122.3 9.301 L-80 I EUE LOCATOR;14,377.7it Completion Details Nominal ID SEAL ASSY;14,378.7- ;= Top(ftKB) Top(WD)(ftKB) Top Incl(°) Item Des Com I (in) PBR;14,384.7 r e. 14,384.7 6,104.9 76.75 PBR POLISHED BORE RECEPTACLE I 4.000 14,408.8 6,110.4 77.23 PACKER BAKER PREMIER PRODUCTION PACKER 3.500 xo Threads;14,407.31 14,429.4 6,114.8 77.78 NIPPLE CAMCO D NIPPLE 2.750 PACKER;14,408.8 m 14,436.3 6,116.3 77.95 PLUG HALLIBURTON MIRAGE PLUG(NO SIGN OF PLUG 2.880 XO Threads;14,415.4 2/13/2015) 11 14,444.9 6,118.0 78.18 SUB,NO-GO NO GO SUB:SPACED OUT 2'OFF LINER TOP 3.010 NIPPLE;14,429.4' 14,446.0 6,118.3 78.21 SOS SHEAR OUT SUB 3.010 14,465.1 6,122.1 78.71 MULE SHOE MULE SHOE W/WLEG 3.000 PLUG;14,436.2 Er Perforations&Slots Shot SUB,NO-GO;14,444.6 Dens Top(TVD) Blot(ND) (shotsk SOS;14,445.9 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Typo Cent 14,529.0 14,945.2 6,133.5 6,159.3 11/26/2014 SLOTS SLOTTED LINER III • 15,274.2- 20,201.4 6,162.2 11/26/2014 SLOTS SLOTTED LINER MULE SHOE;14,465.1 . Mandrel Inserts St ati -''I N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 2,794.5 2,522.2 Cameron 134AF0 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/6/2015 1 Notes:General&Safety End Date Annotation j 2/13/2015 NOTE:DRIFTED TO 14475'(-81 degrees approx)no sign of Mirage Plug IL NOTE:The lower tubing is 3 1/2 OD not 5. INTERMEDIATE;24.2-14,606.6 SLOTS;14,529.0-14,9452--- - SLOTS;15,274.2-20,201.4 SLOTTED LINER;14.447.0 20,233.0 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 22, 2015 Commissioner Cathy Foerstera ( 3� � 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, //ir „„,,e1 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 1 E,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 r.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 • OF Tye \� �7 4, THE STATE Alaska Oil and Gas ofALAS <:A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 WT,° { Main 907.279.1433 jUL Q 8 aS Fax 907.276 7542 SCp i� www aogcc.alaska gov Darrell Humphrey3 _ , NSK Production Engineering Specialist al ,4 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2F-21 Sundry Number: 315-367 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 DATED this � day of June, 2015 Encl. r i L. , STATE OF ALASKA A— ..,KA OIL AND GAS CONSERVATION COMMISSION '°��,� APPLICATION FOR SUNDRY APPROVALS ecC)C 20 AAC 25.280 1 Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Atter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other Prod to WAG 2 Operator Name 4 Current Well Class 5 Permit to Drill Number: ConocoPhillips Alaska, Inc.. Exploratory r Development pr.' 214-136-0 ' — 3 Address6 API Number Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-029-23525-00 • 7.If perforating, 8 Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exceptions Yes r No P KRU 2F-21 9.Property Designation(Lease Number) 10 Field/Pool(s) ADL 25627,25666,392364 . 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) 1 20274 - 6256 4 20233' - 6255' None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 143 20 143' 143' SURFACE 3970 11.8 3996' 3028' RECEIVED INTERMEDIATE 14582 10.625 14607' 6148' SLOTTED LINER 5786 6.55 20233' 6255' J U 1\ 1 5 2015 AOGGC Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size. Tubing Grade Tubing MD(ft) Slots 14526-14945, 15274-20202 Slots 6136-6163,6165-6255 3.5 L-80 14465 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) SLEEVE-BAKER CMU SLIDING SLEEVE W/2 813 NIPPLE PROF MD=14146 TVD=6052 ' SEAL ASSY-BAKER(80-40)PBR SEAL ASSY MD=14379 TVD=6107, PBR-POLISHED BORE RECEPTACLE MD=14385 TVD=6108, PACKER-BAKER PREMIER PRODUCTION PACKER MD=14409 TVD=6114 , 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 P 14 Estimated Date for Commencing Operations 15 Well Status after proposed work 7/1/2015 OIL r WINJ r WDSPL r Suspended r 16 Verbal Approval Date GAS r WAG r • GSTOR r SPLUG r Commission Representative. GINJ r- Op Shutdown r Abandoned r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Darrell Humphrey/Bob Christensen Email n1139(o�conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature a.-,& Phone,659-7535 Date . I I , is Commission Use Only Sundry Number Conditions of approval Notify Commission so that a representative may witness 31' -3(41 Plug Integrity r BOP Test r Mechanical Integrity Test I7Location Clearance r Other • .fes. j--e- w/71-h rc d BVI i-T—01- 1----- -4_ i...i i—t--d a f tr r s fa ld--, 1;p-el , r-,J e c f«,,, Spacing Exception Required? Yes❑ No [" Subsequent Form Required /9 4O 4 '/ APPROVED BY � /') oC) (� Approved by r COMMISSIONER THE COMMISSION Date b/ l Appr a RIl tl11\JA s tPr 12 months tram t e date of approval. Submit Form and Form 10-403 Revised 5/2015 1 L I ViN (Q 11J�1 VTL Gi 1 /15--- 67.7,7 RBDIor c nts m�P,UplirtS 2015 RECEIVED Darrell Humphrey/Robert Christensen JUN 15 2015 Production Engineering Specialist )PPVGreater Kuparuk Unit,NSK-69 �� PO Box 196105 ConocoPh i I I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 June 11, 2015 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 2F-21 from Oil production to Water Injection service. Enclosed you will find 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2F-21 (PTD 214-136). Also attached are supporting documentation, including a map of the target injection area, wellbore schematics, and a cement bond log. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Sincerely Darrell Humphrey Attachments Sundry applications Area Map Well schematics CBL r 1 • 2F-21 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alas Inc. requests approval to convert Kuparuk well 2F-21 (PTD#214-136) from an Oil Producer to a WAG injector. Kuparuk well 2F-21 was drilled in December 2014 from drillsite 2F Kuparuk, to exploit the A5 sand target on the southern flank of the Kuparuk field. The well was completed with slotted liner as a Kuparuk A sand producer over the interval of 14,529' MD to 14,945' MD and 15,274' MD to 20,201' MD. The well was pre-produced from February 2015 to June 2015, to produce a lifetime total of approximately 13MBO. Converting well 2F-21 to injection will provide water injection support to the offset Kuparuk producer 2E-01, which was drilled in November 2014 and put on production in January 2015. The 7- 5/8" casing was cemented with 107 bbls of Class G 15.8ppg cement on November 15, 2014. A CBL of the 2F-21 7-5/8" casing cement job was conducted on November 16, 2014. The CBL shows good cement bond from the bottom of the log at 11,680' MD up to 14,490' MD as indicated by the amplitude curve for a total cement bonded distance of 2,810' MD. A State-witnessed MIT-IA will be performed once well 2F-21 is converted to water injection, online, and stabilized. we I/ kt/ 5 permit/lel rO 6e qn /nie�tOr. �o fefr,- /et.,'et..., &Gel of . l' I • KUP PROD 2F-21 ConocoPhillips " Well Attributes Max Angle&MD TD Alaska,Inc.. Wellbore APvuWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) C......A'Idnip. 500292352500 KUPARUK RIVER UNIT PROD 92.50 20,004.29 20,274.0 .,. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date HORIZONTAL-2F-21 2/17/2015 10:32:30 AM SSSV:NIPPLE Last WO: 27.50 12/3/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason.GLV 0/0,SET FLOW-THRU SUB hipshkf 2/17/2015 HANGER.23.3 5,,:r; W/GAUGES II... Casing StringsII ,■ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread u CONDUCTOR 20 18.430 28.0 143.0 143.0 164.00 H-40 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 26.2 3,996.4 3,027.4 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 INTERMEDIATE 75/8 6.875 24.2 14,606.6 6,144.4 29.70 L-80 Hyd 563 "' "' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth ITVDI... WtlLen(I...Grade Top Thread SLOTTED LINER 4 1/2 3.958 14,447.0 20,233.0 11.60 L-80 HYD 563 Liner Details Nominal ID XO Reducing;58.2 * Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 14,447.0 6,118.5 78.23 PACKER BAKER ZXP PACKER W/HRDE PROFILE 5.750 'MA CONDUCTOR;28.0.743.0 14,466.9 6,122.4 78.76 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 14,469.7 6,123.0 78.83 HANGER BAKER"DG"FLEX LOCK LINER HANGER i 4.790 NIPPLE;564.6 -- 14,996.4 6,160.2 89.06 SWELL FREECAP I FSC-11 SWELL PACKER 3.958 • PACKER 15,203.0 6,160.9 89.78 SWELL 'FREECAP I FSC-11 SWELL PACKER 3.958 PACKER I Tubing Strings GAS LIFT,2,794.5 I- Tubing Description String Ma...ID(in( Top(ftKB) Set Depth(ft..f Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-Upper 41/2 31/2 2.992 233 14,4004 6,1085 9.30 L-80 EUE x31/2@58.17 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I') Item Des Com (in) 23.3 HANGER CAMERON TUBING HANGER 3.900 SURFACE;26.2.3,996.4 58.2 58.2 0.06 XO Reducing XO,Z,4-12"12.68 L-80 IBTM box x 3-1/2"9.38 L-80 2.940 EUE 8RD-Mod pin 564.6 564.4 3.21 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 SLEEVE;14,145.8- 14,145.8 6,048.3 76.25 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE 2.812 FLOW THRU SUB;14,146.0 PROFILE 14,377.7 6,103.3 76.71 LOCATOR LOCATOR SUB 2.980 14,378.7 6,103.5 76.71 SEAL ASSY BAKER(80-40)PBR SEAL ASSY 2.980 J Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth)TVD)(...Wt(INft) Grade Top Connection TUBING-Lower 5 4.000 14,384.7 14,466.1 6,122.3 9.30 L-80 EUE LOCATOR;14,377.7 / Completion De1: .. . iir A.a..�.rs - .,- . - •-. " : Nominal ID SEAL ASSY;14,378.7 Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Corn (In) PBR;14,384.7 14,384.7 6,104.9 76.75 PBR POLISHED BORE RECEPTACLE 4.000 _ 14,408.8 6,110.4 77.23 PACKER BAKER PREMIER PRODUCTION PACKER 3.500 X0 Threads;14,407.3 7 14,429.4 6,114.8 77.78 NIPPLE CAMCO D NIPPLE 2.750 PACKER;14,408.814,436.3 6,116.3 77.95 PLUG HALLIBURTON MIRAGE PLUG 2.880 XO Threads;74,415.4 14,444.9 6,118.0 78.18 SUB,NO-GO NO GO SUB:SPACED OUT 2'OFF LINER TOP 3.010 14,446.0 6,118.3 78.21 SOS SHEAR OUT SUB 3.010 NIPPLE;74,429.4 14,465.1 6,122.1 78.71 MULE SHOE MULE SHOE W/WLEG 3.000 PLUG;14,436.2 - Perforations&Slots Shot Den SUB,NO-GO;14,444.8 Top(ND) Btm(TVD) (shotsM Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SOS;14,445.9 14,529.0 14,945.2 6,133.5 6,159.3 11/26/2014 SLOTS SLOTTED LINER 15,274.2 20,201.4 6,162.2 11/26/2014 SLOTS SLOTTED LINER MULE SHOE;14.465.1 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ttKB) (ftKB) Make Model OD(in( Sery Type Type (in) (psi) Run Date Corn f 2.794.5 2,522.2 Cameron 134AF0 1 1/2 GAS LIFT OV RK 0.313 0.0 2/14/2015 1 Notes:General&Safety End Date Annotation NOTE The lower tubing Is 3 1/2 OD not 5. INTERMEDIATE;24.2-14,606.6 I SLOTS;14,529.0-14,845.2 • SLOTS;15.274.2-20,201.4 SLOTTED LINER;14,447.0- e 20,233.0 Kuparuk Well 2F-21 Conversion from Production to Water Injection Area of Review Well Summary Kuparuk well 2F-21 was drilled in December 2014 from drillsite 2F Kuparuk, to exploit the A5 sand target on the southern flank of the Kuparuk field. The well was completed with slotted liner as a Kuparuk A sand producer over the interval of 14,529' MD to 14,945' MD and 15,274' MD to 20,201' MD. The well was pre- produced from February 2015 to June 2015, to produce a lifetime total of approximately 13MBO. Converting well 2F-21 to injection will provide water injection support to the offset Kuparuk producer 2E- 01, which was drilled in November 2014 and put on production in January 2015. . Below, the Area of Review includes a description of the following: • Map with 1/4 mile radius shown around the target injection zone; • 2F-21 wellbore schematic; • The mechanical condition of the proposed injection well; and • 2F-21 7-5/8" 29.7 lb/ft casing CBL and interpretation of the cement quality of the subject well Area Map with 1/4 mile radius around target injection zone Kuparuk well 2F-21 is located in the Southwest quadrant of the drillsite 2F Kuparuk development. The map attached shows that there are no other wells located within a 1/4 mile radius of the 2F-21 penetration / of the Kuparuk A sands. Kuparuk well 2F-21 Wellbore Schematic Kuparuk well 2F-21 was completed with a single completion having a 3-1/2" 9.31b/ft L-80 tubing by 7-5/8" 29.71b/ft L-80 production casing. The surface hole was completed with 10-3/4"45.5 lb/ft L-80 casing. The horizontal production section was completed with 4-1/2" 11.6 lb/ft L-80 slotted liner over the intervals of 14,529' MD to 14,945' MD and 15,274' MD to 20,201' MD. The top of the Kuparuk A sand was encountered at 14,520' MD. The schematic for 2F-21 is attached. Mechanical Condition of Well to be Converted to Injection and MIT History (2F-21) The mechanical condition of Kuparuk well 2F-21 is good. The well is classified as a "Normal Well", meaning that the historical MIT-T and MIT-IA tests have passed. The most recent MIT-T was tested to 3,500psi on December 2, 2014. The most recent MIT-IA was tested to 3500psi on December 2, 2014. A State-witnessed MIT-IA will be performed once well 2F-21 is converted to water injection, online, and stabilized. 2F-21 CBL and interpretation of the cement quality of the subject well Well 2F-21 is located in a mixed injector/producer row in the drillsite 2F development. The 7-5/8" casing was cemented with 107 bbls of Class G 15.8ppg cement on November 15, 2014. A CBL of the 2F-21 7- 5/8" casing cement job was conducted on November 16, 2014. The CBL shows good cement bond from the bottom of the log at 11,680' MD up to 14,490' MD as indicated by the amplitude curve for a total cement bonded distance of 2,810' MD. From the drilling report of November 15, 2014: Line up to SLB,pump 5 bbls H2O&PT lines to 4000 psi. Pump 40 bbls CW100, 40 bbls 11.5 ppg Mudpush II. Drop bottom plug,pump 107 bbls of 15.8 ppg cement. Drop top plug&pump 10 bbl H2O. Swap to rig pumps for displacement. No returns observed. Displace cement with 656 bbls 10.5 ppg mud, 4.5 bpm, ICP 200 psi, FCP 850 psi. Bump plug&psi up 500 psi to 1350 psi, holding for 5 min. Bled off, floats tested good. CIP 19:13 hrs. Observed bottom plug rupture at 5458 strokes with 350 psi. Observed pump psi increase as cement was coming around the shoe from 350 to 900 psi. VI— - I-- ... , ...... .-.0. ........... , ....... ... 111.. ..... 2E-14 iii2E-16 . 1/.. 'K. ...***.. i ....... .......... N.,*2F-15 .......... .ill 2F-10 . ... • A . ; • ' ... .. "•• .. : : . ''• . .. .. : I . .. ... . •• :.•• • . .... . • 1 • •••„„. . . ..„ . . .„ • .• • • . : . .••• ' ...: i . i .. . ... %. F_12E-13 2E-15 '... i • 1 • • hi..................................—.................••••••••7 F-12: . . .'. 2F-14 a........................ :: • . • 2F-11 '‘,. ..• :i ... „ ..........•••••• ../.., :s • 2F-11AL2 .. • •.•.....* :::::%.1: • • . .••'. . : • ..• ••••• / ; ; • ..."' . . 2F-17 1'F8P.131 '. ..••••••• .•',.•• : : 2 -1t6 28.:09 .•••••• i . .. .....- 110' I • . 2F-19 /*/ 1 .. 2F-19PB2 /*/ I. _ 2F-19PB1 ..•..* \ i 2F-17L1-02 ./...** 2F-18L1-01% •• 1.2E-04PBi 2F-11A •••••••••• F-19AL2 2F-11AL.1:;:•• 1 . • . . ••:. . . • ,. kiciza ru k ..-::- .:: • • - ......-- : • .„: . . • • • • E 2F-17L1-01 2F-18L1-02 ., ( 2F-Uhit.....' i ! . : . • • 2F-17L1 • : 2F-18L1 : . • • : - 2F-19A t . : . . • • • .. . • . . . . . . • . . • : • , I . . . . . , . • : . , . . . , i . . . . , • . : . , • • . . . . , . . . • . : • • : I : • Kuparuk : ! . . ... • PA .. . ... ... • Legend 2G-17L1 41 • • STATUS,WELL_TYPE, FLUID_TYPE • 4— • *... 44 . • Producer: Oil %. .s ' • • • INJ: IWAG • . •••. i( • INJ: MWAG . . \ • • • INJ: PW • . G-17 • P+A • • 1/4 Mile Radius 411111latiquallillossiiiiimilmagoolualoilisilili : 2F-21 411411i.Unit Boundary e. • Participating Area Boundary " • — . 2F-21 • •2E-01 ConocoPhillips Alaska, Inc. Injection Swap Analysis 2F-21 1/4 Mile Radius 2G-17L1 N I 0 025 05 Miles RADIAL BOND HALLIBURTON LOG d Company N COP I LLI PS ALASK, INC Well u) 2F-21 , < z < Field KUPARUK RIVER UNIT CO ce Borough N SLOPE State ALASKA ce API No: 50-029-23525-00-00 Sera#: 901838389 Other Services U D EL Location: AT SURFACE: � 0 .< _, 171' FNL & 1731' FEL 0 z NONE o° L CO Sec:33 Twp:i 1 N Rge: 09E Permanent Datum MSL Elevation Cr Elevation Log Measured From RKB , 123.3 Ft_ above perm. datum KB_ 123.8' D.F_ 122.8' Drilling Measured From RKB G.L. 95.8' Date @ Time Logged 16-NOV-2014 @ 19:00 Type Fluid in Hole WBM Run No. ONE Density of Fluid 10.5 PPG Depth - Driller 14617' Fluid Level SURFACE Depth - Logger 14500' Cement Top Est Logged 11676' Bottom- Logged Interval 14500' Equipment/ Location 0609 / KUPARUK Top - Log Interval 550' Recorded by W. KEYES Max. Recorded Temp. NIA Witnessed by A_ LUNDO CEMENTING DATA Surface Protection Production Liner String String String ' Date/Time Cemented Primary I Squeeze Expected Compressive Strength psi@ hrsl psi psi@ hrs psi@ hrs psi@ hrs Cement Volume Cement Type I Weight / / / / = Formulation Mud Type/ Mud Wgt_ I i I I / Borehole Record Casing &Tubing Record Run Number Bit From ' To Size Weight From To 10 3/4' 45.50 SURFACE 3955' 7 518" 29.70# SURFACE 14617' i m , ' 11600 _____1.I II 4 , ' ta•i II?t 1.,'};'‘1 i.Al ' !# :4! 1 '' E,11 111M; I,�111';'''', ' {I I1I11 1 — ; . ; � 3 r f I�IJ iY{s lYl— ih IH1' .III { i (I . Y' III 1ii;,ii �� '� MI��I II p' I' ;IIf 711 111 ' 1 llllr{ ii — — — — -- — —— I „,ii:. 1..... . k iI Y''i11' g I Ti! 11 p 11MEI� ,1. a� 11650 C. � �` r � 1:.i. y 'f Y "�"�jj'Ij1l�' II � iil ii II I, I.' 1 .' 11 • • 'II 1 , 1 'I'll :,.. 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I:.; ii. :: ::I :k;I ■laassai�ias 14500 Iismisamimi• . :Issas•=ss i it i::€ :;: : : I------ -------- - :: -sass 111111............::.::::r:ic:W 340 TT(usec) 240 0 Amplitude(mV) 100 AVG Sector Amplitude 200 MSG 1200 SECTORS CCL Amplitude x10 0 150 -50 500 0 100 0 Gamma DAPI 150 0 iJ!11',,,.. ;!I:, I .: I ii:^l, i (GAPI) (mV) 10 MAX Sector Amplitude 3000 Line Tens(Ib) 0 0 150 MIN Sector Amplitude 0 150 HALLIBLillTON MAIN PASS 1 , , -1AILLIBURTOIA41 REPEAT PASS Database File 2f-21_rbt_16-nov-2014.db Dataset Pathname pass9 Presentation Format rbt_Ss Dataset Creation Sun Nov 16 23:34:43 2014 r'1,,,-1.--,,^1 1... n-'.-+h.6-r_-.,r......1-,.+w.n An 2-513 2, WELL LOG TRANSMITTAL DATA LOGGED \2../ /201 L( K.BENDER To: Alaska Oil and Gas Conservation Comm. November 24, 2014 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RErEIVEO Anchorage, Alaska 99501 DEC 05 2014. RE: Radial Bond Log : 2F-21 AOC Run Date: 11/16/2014 ACI CC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2F-21 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-23525-00 Radial Bond Log 1 Color Log 50-029-23525-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'1'1'BNTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 SCAMS i NOV 0 4 2016 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com I5 .eiøt.eét Date: Signed: ;1•44,2"2"174x-)4/') 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. 4 t,L- j 3 Well History File Identifier I Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: olor Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: Ili BY: Maria Date: . //,, �� ls/ vi', 1 1f p�.V Project Proofing BY: Maria Date: u,Jo/ic /s/ VII 1 1 1 Scanning Preparation aration x 30 = 1 a0 + 21 = TOTAL PAGES / 4/ (Count does not include cover sheet)BY: Maria Date: 0 /s/ 11/1 Production Scanning Stage 1 Page Count from Scanned File: I1-1";:9-%(Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES N(VI O10 BY: CO Date: (,� /J /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 0 NO TOTAL PAGES:LH i Digital version appended by: Meredith Michal Date: LJ/Z( /1 5' /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: I 9v Scanning is complete at this point unless rescanning is required. 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U U O N LL Ce Q '1, vl ( m m LL w Z LL it Q C Q Q ! IIHy E co 75 0 LL y W W N 2 1, Oco V LL /� d �n p... .0 To m Y� J " 1N N W N c to W E I N N N Z a) '', Ce a. O r r 1' I 0 cy, 0 coI Ci 1 it E 1 y W m o a V 0 • z v m E J Co Z Q O o '7)O N 1 1 11 ` N O cnJ J O m 2 U U O. � j r O O y G O y I I O ZS a H (s) E M U aa) o J ci) } c) E u Q`~r ,,,,- o N ° o o. 1 coV th a IE12 1 1 u. ~ o in o Z o co c 2 >> N To w z p a) EM o ~ E r 1 C O1 (.0 a) Cl)/ To I N U C co '1 itiTr\ 10 d p c o Qoc T fCO 0 Y TD o cll' •U n C n g m 0 Q z E o a) U I E U 1. 0 0 z p)as 0 1 CO CO y v v a) L p 0 CO c ® N N N Co Co 2 O el N o ; ni el N N N C W E �. � O a) NN N N 1.0 10 10 W N d a a) W o c _ ai > E aiaN a) F. N co 1 0 F `m ' VZ Co .. c 0 o o a Z Q c c 2 Z o co c Cl) c v - N U U U C a) U m J a) % a) CC U 0 L a . o o a m E . 00 E p m — E o 0 1 2 E . ayi E E a W w 0 — o a C0 0 o C 0 0 Guhl, Meredith D (DOA) From: Guo, Haibin [Haibin.Guo@conocophillips.com] Sent: Monday, March 23, 2015 4:14 PM To: Guhl, Meredith D (DOA); Little, Laird D.; Allsup-Drake, Sharon K Cc: Bettis, Patricia K(DOA) Subject: Re: [EXTERNAL]KRU 2F-21, PTD 214-136, Well Schematic, Geologic Markers, Logs Obtained Sharon, can you please send the well schematic of 2F-21 to Meredith? Thanks. -.0Lck.S0-c( 4AD 10-14°7 Laird, please send 2F-21 formation tops and geological markers to Meredith. - cLd99-0-'- + IQ-4"-4 Meredith, We ran all the logs as per PTD. Except the sonic log was replaced by a dedicated e-line RCBL because no returns during the intermediate casing cement job. This let us be able to evaluate the TOC before drill the production hole. So we have GR/RES and CBL for intermediate section; GR/RES/NEU/DEN for production section. I think the NEU/DEN should be added in box 21. Can you please help to mark them in? I think you should have all the logs already. If not, let me know I will get them to you as soon as I can. Thanks, Haibin On Mar 24, 2015, at 1:05 AM, Guhl, Meredith D (DOA) <meredith.BuhlOalaska.gov<mailto:meredith.guhlPalaska.gov» wrote: Haibin, A well schematic is required for KRU 2F-21, PTD 214-136, completed December 3, 2014. Also, please provide the complete list of formation tops and geologic markers encountered for Box 29. You may provide the schematic and list via email, and I will append it to the 10-407 form. Also, the PTD application for this well stated that neutron, density, and sonic would be run on the production section. However, in box 21 you only listed GR/Res and CBL for logs obtained. Were the additional logs run? Please provide an explanation for the discrepancy between the permit to drill application and the 10-407 form. Please provide the schematic, geologic markers, and an explanation about logs run by March 31, 2015. All data is due within 90 days of well completion. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 1 Iv n STATE OF ALASKA ALA—A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed: Abandon r Repair well r Plug Perforations r Perforate E Other WINJ to Prod 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 214-136-0 3.Address: 6.API Number: Stratigraphic r Service pr P. O. Box 100360,Anchorage,Alaska 99510 50-029-23525-00 7.Property Designation(Lease Number): 8 Well Name and Number: ADL 25267,25666,392364 KRU 2F-21 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 20274 feet Plugs(measured) None true vertical 6256 feet Junk(measured) None Effective Depth measured 20233 feet Packer(measured) 14146, 14379, 14385 true vertical 6255 feet (true vertical) 6052, 6107,6108 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 20 143 115 0 0 SURFACE 3970 11.8 3996 3028 0 0 INTERMEDIATE 14582 10.625 14607 6148 0 0 SLOTTED LINER 5786 6.55 20233 6255 0 0 0 0 0 0 0 0 Perforation depth: Measured depth. Slots 14526-14945, 15274-20202 RECEIVED True Vertical Depth: Slots 6136-6163,6165-6255 MAR 2 3 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 14465 MD, 6126 TVD /+QGCG Packers&SSSV(type,MD,and TVD) SLEEVE- BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE PROFILE @ 14146 MD and 6052 TVD SEAL ASSY-BAKER (80-40) PBR SEAL ASSY @ 14379 MD and 6107 TVD PBR-POLISHED BORE RECEPTACLE @ 14385 MD and 6108 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 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 2817 1559 76 1153 144 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 Pr 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 0 Exempt N/A Contact Bob Christensen/Darrell Humphrey Email n1139@conocophillips.com Printed Name Darrell R. Humphrey Title NSK Production Engineering Specialist Signature \ , 1 1 Phone:659-7535 Date Form 10-404 Revised 10/2012 ti rt �` �� Submit i fi O nal Only 3/z4/r S RBDMSi MAR 7 1 9(115 2F-21 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/20/15 Pre-produced injector brought online, production for greater than 30 days 02/14/15 MEASURE BHP @ 14,470' RKB (3020 PSI); ` • KUP PROD 2F-21 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) t erc,rrimillipn 500292352500 KUPARUK RIVER UNIT PROD 92.50 20,004.29 20274.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date HORIZONTAL-2F-21,2/17/2015 1832:30 AM SSSV:NIPPLE Last WO: 27.50 12/3/2014 Vesical schematic(actual) Annotation Depth(ORB) End Date Annotation last Mod By End Date Last Tag' Rev Reason:GLV C/O,SET FLOW-THRU SUB hipshkf 2/17/2015 HANGER.233 'I W/GAUGES Casing Strings 1:11 Ill Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 18.430 28.0 143.0 143.0 164.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth MB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 26.2 3,996.4 3,027.4 45.50 L-80 HYD 563 Casing Description OD lin) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 24.2 14,606.6 6,144.4 29.70 L-80 Hyd 563 trrCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread `'".... "'SLOTTED LINER 41/2 3.958 14,447.0 20,233.0 11.60 L-80 HYD 563 Liner Details Nominal ID XO Reducing;582 Top(ftKB) Top(TVD)(ftKB) Top Incl rt Item Des Com (in) 14,447.0 6,118.5 78.23 PACKER BAKER ZXP PACKER W/HRDE PROFILE 5.750 .NNf CONDUCTOR;28.0-143.06 �~ 14,466.9 6,122.4 78.76 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 14,469.7 6,123.0 78.83 HANGER BAKER"DG"FLEX LOCK LINER HANGER 4.790 NIPPLE;564.6 14,996.4 '6,160.2 89.06 SWELL FREECAP I FSC-11 SWELL PACKER ' 3.958 PACKER 15,203.0 6,160.9' 89.78 SWELL FREECAP I FSC-11 SWELL PACKER 3.958 PACKER liL� Tubing Strings GAS LIFT;2,794.5 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING-Upper 41/2 31/2 2.992 23.3 14.400.4 6,108.5 9.30 L-80 EUE x31/2@58.17 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) • 23.3 HANGER CAMERON TUBING HANGER 3.900 SURFACE;28.23.996.4 58.2 58.2 0.06 XO Reducing XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 2.940 EUE 8RD-Mod pin 564.6 564.4 3.21 NIPPLE CAMCO DS NIPPLE w(2.875"PROFILE 2.875 SLEEVE;14,1450- 14,145.8 6,048.3 76.25 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE 2.812 FLOW THRU SUB;14,146.0 PROFILE 14,377.7 6,103.3 76.71 LOCATOR LOCATOR SUB 2.980 14,378.7 6,103.5 76.71 SEAL ASSY BAKER(80-40)PBR SEAL ASSY 2.980 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-Lower 5 4.000 14,384.7 14,466.1 6,122.3 9.30 L-80 EUE LOCATOR;14,377.7 Completion Details Nominal ID SEAL ASSY;14,370.7.. Top(ftKB) Top(ND)(ftKB) Top Incl(1 Item Des Com (in) PER;14,364.7 14,384.7 6,104.9 76.75 PBR POLISHED BORE RECEPTACLE 4.000 14,408.8 6,110.4 7723 PACKER BAKER PREMIER PRODUCTION PACKER 3.500 Xo Threads;14,407.3 14,429.4 6,114.8 77.78 NIPPLE CAMCO D NIPPLE ' 2.750 PACKER;14,408.8 14,436.3 6,116.3 77.95 PLUG HALLIBURTON MIRAGE PLUG 2.880 XO Threads;14,415.4 14,444.9' 6,118.0 78.18 SUB,NO-GO NO GO SUB:SPACED OUT 2'OFF LINER TOP 3.010 14,446.0 6,118.3 78.21 SOS SHEAR OUT SUB 3.010 NIPPLE;14,429.4 14,465.1 6,122.1 78.71 MULE SHOE MULE SHOE W/WLEG 3.000 PLUG;14,436.2 Perforations&Slots Shot Dens SUB,NO-GO;14444.8 Top(TVD) Blot(ND) (shots# Top(ftKB) Btm(ftKB) (ftKB) (NM Zone Date t) Type Com SOS;14,445.9 14,529.0 14,945.2 6,133.5 6,159.3 11/26/2014 SLOTS SLOTTED LINER 15,274.2 20,201.4 6,162.2 11/26/2014' SLOTS SLOTTED LINER MULE SHOE;14,465.1 Mandrel Inserts St .ti ern Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1 2,794.5 2,522.2 Cameron 134AF0 11/2 GAS LIFT OV RK - 0.313. 0.0 2/14/2015 1 'Motes:General&Safety End Date Annotation LI I� NOTE:The lower tubing is 3 1/2 OD not 5. INTERMEDIATE;24.2-14,606.6 SLOTS;14529.0-14.945.2 SLOTS;15.274.2-20.201.4 SLOTTED LINER;14,447.0. 20,233.0 21 4138 25245 SchlumbergerDrilling & Measurements Transmittal #: 09JAN15-NG01 DATA LOGGED MWD/LWD Log Product Delivery BEND/I2 P R Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2F-21 Date Dispatched: 9-Jan-15 Job#: 14AKA0055 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A EcoScope* Resist 2" MD x x EcoScope* Resist 2"TVD x x EcoScope* Resist 5" MD x x EcoScope* Resist 5"TVD x x MircoScope* Resi 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.Rosot Conocophilips.com AlaskaPTSPrintCenterslb.com Cathaerine Roso Attn: Nathan Green ,�^ Fax: 907-273-4760 Received By: ►'/J 21 41 36 25245 NADConversion RECEIVED Kuparuk River Unit Kuparuk 2E Pad JAN 12 2015 2F-21 AOGCC Definitive Survey Report [N A D 2 7] 15 December, 2014 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 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 2F-21 Well Position +N/-S 0.00 usft Northing: 5,948,711.26 usft Latitude: 70°16'15.773 N +E.I-W 0.00 usft Easting: 517,501.07 usft Longitude: 149°51'30.459 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 95.80 usft Wellbore 2F-21 Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) (°) (nT) BGGM2014 10/10/2014 19.12 80.87 57,571 Design 2F-21 Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) C) 27.50 0.00 0.00 180.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description 81.26 816.35 2F-21-SRV#1 SLB-NSG+MSHOT(2F-21) GYD-GC-SS Gyrodata gyro single shots 870.71 3,925.70 2F-21-SRV#2-SLB-MWD+GMAG(2F-21 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,025.12 14,547.71 2F-21 SRV#3 SLB-MWD+GMAG(2F-21) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 14,615.84 20,193.85 2F-21-Srvy#4 MWD+IFR-AK-CAZ-SC(2F MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +NI-S +E/-W Northing Easting (usft) (°) C) (usft) (usft) (usft) (usft) 0.00 usft tool name 27.50 0.00 0.00 27.50 -95.80 0.00 0.00 5,948,711.26 517,501.07 UNDEFINED 81.26 0.11 322.73 81.26 -42.04 0.04 -0.03 5,948,711.30 517,501.03 GYD-GC-SS(1) 110.00 0.14 304.66 110.00 -13.30 0.08 -0.08 5,948,711.34 517,500.99 GYD-GC-SS(1) 20"x 24" ' 166.69 0.23 287.65 166.69 43.39 0.16 -0.24 5,948,711.41 517,500.82 GYD-GC-SS(1) 259.57 0.18 282.27 259.57 136.27 0.25 -0.56 5,948,711.50 517,500.50 GYD-GC-SS(1) 349.84 0.23 248.58 349.84 226.54 0.21 -0.87 5,948,711.46 517,500.19 GYD-GC-SS(1) 449.76 2.31 89.00 449.73 326.43 0.17 0.96 5,948,711.43 517,502.02 GYD-GC-SS(1) 542.15 3.30 87.66 542.01 418.71 0.31 5.47 5,948,711.58 517,506.54 GYD-GC-SS(1) 633.71 2.95 82.54 633.44 510.14 0.73 10.44 5,948,712.01 517,511.51 GYD-GC-SS(1) 724.38 3.90 81.83 723.94 600.64 1.47 15.81 5,948,712.76 517,516.87 GYD-GC-SS(1) 816.35 7.29 79.03 815.46 692.16 3.02 24.64 5,948,714.34 517,525.69 GYD-GC-SS(1) 12/16/2014 6:26:40PM Page 2 COMFASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/-S +E/-W Northing Easting (usft) (") (^) (usft) (usft) (usft) (usft) 11.00 usft tool name 870.71 8.35 82.37 869.32 746.02 4.20 31.94 5,948,715.53 517,532.99 MWD+IFR-AK-CAZ-SC(2) 966.66 10.19 87.42 964.01 840.71 5.51 47.32 5,948,716.88 517,548.37 MWD+IFR-AK-CAZ-SC(2) 1,059.35 13.69 90.68 1,054.68 931.38 5.75 66.48 5,948,717.16 517,567.53 MWD+IFR-AK-CAZ-SC(2) 1,151.24 16.74 96.43 1,143.35 1,020.05 4.14 90.51 5,948,715.61 517,591.56 MWD+IFR-AK-CAZ-SC(2) 1,246.23 19.81 107.40 1,233.56 1,110.26 -221 119.48 5,948,709.32 517,620.54 MWD+IFR-AK-CAZ-SC(2) 1,338.53 20.13 110.57 1,320.31 1,197.01 -12.47 149.28 5,948,699.14 517,650.36 MWD+IFR-AK-CAZ-SC(2) 1,431.04 20.91 113.66 1:406.95 1,283.65 -24.69 179.31 5,948,686.99 517,680.41 MWD+IFR-AK-CAZ-SC(2) 1,523.73 21.69 116.78 1.493.31 1,370.01 -39.05 209.76 5,948,672.70 517,710.89 MWD+IFR-AK-CAZ-SC(2) 1,615.25 23.62 122.73 1,577.78 1,454.48 -56.58 240.29 5,948,655.24 517,741.46 MWD+IFR-AK-CAZ-SC(2) 1,707.86 25.97 126.70 1,661.85 1,538.55 -78.74 272.16 5,948,633.16 517,773.38 MWD+IFR-AK-CAZ-SC(2) 1,801.42 27.39 131.24 1,745.46 1,622.16 -105.17 304.77 5,948,606.81 517,806.05 MWD+IFR-AK-CAZ-SC(2) 1,894.02 29.34 134.99 1826.94 1,703.64 -135.25 336.83 5,948,576.80 517,838.18 MWD+IFR-AK-CAZ-SC(2) 1,984.20 31.08 137.60 1,904.88 1,781.58 -168.06 368.15 5,948,544.07 517,869.57 MWD+IFR-AK-CAZ-SC(2) 2,076.95 33.88 143.26 1,983.13 1,859.83 -206.47 399.77 5,948,505.73 517,901.28 MWD+IFR-AK-CAZ-SC(2) 2,171.76 34.98 145.79 2,061.34 1,938.04 -250.13 430.86 5,948,462.16 517,932.47 MWD+IFR-AK-CAZ-SC(2) 2,263.83 36.37 149.81 2,136.14 2,012.84 -295.56 459.43 5,948,416.80 517,961.14 MW0+IFR-AK-CAZ-SC(2) 2,357.15 37.35 150.31 2,210.81 2,087.51 -344.06 487.37 5,948,368.36 517,989.18 MWD+IFR-AK-CAZ-SC(2) 2,44920 39.02 150.98 2,283.16 2,159.86 -393.66 51525 5,948,318.84 518,017.18 MWD+IFR-AK-CAZSC(2) 2,542.55 42.85 150.65 2.353.67 2,230.37 -447.04 545.08 5,948,265.53 518,047.13 MWD+IFR-AK-CAZ-SC(2) 2,635.66 47.27 150.48 2,419.42 2,296.12 -504.43 577.46 5,948,208.23 518,079.64 MWD+IFR-AK-CAZ-SC(2) 2,728.09 50.18 153.07 2,480.39 2,357.09 -565.64 610.28 5,948,147.10 518,112.60 MWD+IFR-AK-CAZ-SC(2) 2,820.46 52.50 155.15 2,538.09 2,414.79 -630.53 641.75 5,948,082.29 518,144.22 MWD+IFR-AK-CAZ-SC(2) 2,912.82 54.70 156.52 2,592.90 2,469.60 -698.35 672.17 5,948,014.54 518,174.79 MWD+IFR-AK-CAZ-SC(2) 3,006.08 56.88 155.54 2,645.32 2,522.02 -768.82 703.51 5,947,944.16 518,206.29 MWD+IFR-AK-CAZ-SC(2) 3,097.71 58.88 156.72 2,694.04 2,570.74 -839.78 734.90 5,947,873.27 518,237.84 MWD+IFR-AK-CAZ-SC(2) 3,191.13 60.68 158.59 2,741.06 2,617.76 -914.44 765.58 5,947,798.69 518,268.69 MWD+IFR-AK-CAZ-SC(2) 3,284.38 63.32 160.43 2,784.84 2,661.54 -991.56 794.38 5,947,721.64 518,297.67 MWD+IFR-AK-CAZ-SC(2) 3,375.58 66.29 162.41 2,823.66 2,700.36 -1,069.78 820.65 5,947,643.50 518,324.12 MWD+IFR-AK-CAZ-SC(2) 3,467.65 68.64 163.88 2,858.95 2,735.65 -1,151.16 845.30 5,947,562.18 518,348.95 MWD+IFR-AK-CAZ-SC(2) 3,559.84 70.05 163.37 2,891.46 2,768.16 -1,233.92 869.62 5,947,479.48 518,373.46 MWD+IFR-AK-CAZ-SC(2) 3,653.43 72.91 163.71 2,921.19 2,797.89 -1,319.02 894.76 5,947,394.45 518,398.80 MWD+IFR-AK-CAZ-SC(2) 3,745.44 72.59 164.02 2,948.47 2,825.17 -1,40343 919.18 5,947,310.11 518,423.41 MWD+IFR-AK-CAZ-SC(2) 3,838.76 71.85 162.92 2,976.97 2,853.67 -1,488.62 944.46 5,947,224.99 518,448.89 MWD+IFR-AK-CAZ-SC(2) 3,925.70 70.99 164.35 3,004.67 2,881.37 -1,567.68 967.68 5,947,145.98 518,472.29 MWD+IFR-AK-CAZ-SC(2) 3,996.00 71.01 162.83 3,027.56 2,904.26 -1,631.44 986.46 5,947,082.28 518,491.21 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-112 4,025.12 71.02 162.20 3,037.03 2,913.73 -1,657.71 994.73 5,947,056.03 518,499.55 MWD+IFR-AK-CAZ-SC(3) 4,119.19 70.97 163.30 3,067.67 2,944.37 -1,742.65 1,021.10 5,946,971.16 518,526.12 MWD+IFR-AK-CAZ-SC(3) 4,209.18 71.72 163.43 3,096.45 2,973.15 -1,824.34 1,045.51 5,946,889.54 518,550.71 MWD+IFR-AK-CAZ-SC(3) 4,302.08 72.42 163.32 3,125.05 3,001.75 -1,909.03 1,070.80 5,946,804.91 518,57620 MWD+IFR-AK-CAZ-SC(3) 12/16/2014 6:26:40PM Page 3 COMFASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System ,N1-3 +E/-w Northing Easting (usft) C) C) (usft) (usft) (usft) (usft) 50.00 usft tool name 4,397.93 72.29 163.68 3,154.11 3,030.81 -1,996.61 1,096.74 5,946,717.40 518,602.34 MWD+IFR-AK-CAZ-SC(3) 4,491.77 72.32 164.51 3,182.63 3,059.33 -2,082.59 1,121.24 5,946,631.49 518,627.04 MWD+IFR-AK-CAZ-SC(3) 4,588.48 72.38 163.70 3,211.95 3,088.65 -2,171.22 1,146.48 5,946,542.92 518,652.48 MWD+IFR-AK-CAZ-SC(3) 4,685.44 71.97 164.09 3,241.63 3,118.33 -2,259.90 1,172.09 5,946,454.31 518,678.29 MWD+IFR-AK-CAZ-SC(3) 4,781.57 71.89 163.84 3271.45 3,148.15 -2,347.74 1,197.33 5,946,366.55 518,703.73 MWD+IFR-AK-CAZ-SC(3) 4,876.91 71.92 163.44 3;301.06 3,177.76 -2,434.69 1,222.86 5,946,279.66 518,729.46 MWD+IFR-AK-CAZ-SC(3) 4,973.06 71.95 163.09 3,330.88 3,207.58 -2,522.23 1,249.18 5,946,192.19 518,755.98 MWD+IFR-AK-CAZ-SC(3) 5,069.13 71.86 164.40 3.360.72 3,237.42 -2,609.90 1,274.74 5,946,104.59 518,781.74 MWD+IFR-AK-CAZ-SC(3) 5,163.96 71.80 163.67 3,390.29 3,266.99 -2,696.52 1,299.52 5,946,018.03 518,806.72 MWD+IFR-AK-CAZ-SC(3) 5,260.74 71.86 163.48 3,420.47 3,297.17 -2,784.72 1,325.52 5,945,929.90 518,832.93 MWD+IFR-AK-CAZ-SC(3) 5,356.82 71.81 163.21 3.450.42 3,327.12 -2,872.18 1,351.69 5,945,842.51 518,859.29 MWD+IFR-AK-CAZ-SC(3) 5,453.62 71.74 162.64 3480.70 3,357.40 -2,960.07 1,378.68 5,945,754.69 518,886.49 MWD+IFR-AK-CAZ-SC(3) 5,548.60 71.78 162.47 3,510.43 3,387.13 -3,046.13 1,405.73 5,945,668.70 518,913.73 MWD+IFR-AK-CAZ-SC(3) 5,639.65 71.74 162.01 3,538.93 3,415.63 -3,128.49 1,432.11 5,945,586.42 518,940.30 MWD+IFR-AK-CAZ-SC(3) 5,732.18 71.75 160.67 3,567.91 3,444.61 -3,211.74 1,460.22 5,945,503.24 518,968.60 MWD+IFR-AK-CAZ-SC(3) 5,825.13 71.81 160.64 3,596.97 3,473.67 -3,295.04 1,489.47 5,945,420.01 518,998.04 MWD+IFR-AK-CAZ-SC(3) 5,916.70 71.73 161.40 3,625.62 3,502.32 -3,377.29 1,517.75 5,945,337.84 519,026.52 MWD+IFR-AK-CAZ-SC(3) 6,008.96 71.89 160.43 3.654.42 3,531.12 -3,460.12 1,546.41 5,945,255.09 519,055.36 MWD+IFR-AK-CAZ-SC(3) 6,101.15 71.87 160.74 3.683.09 3,559.79 -3,542.75 1,575.54 5,945,172.53 519,084.68 MWD+IFR-AK-CAZ-SC(3) 6,191.63 71.90 161.05 3,711.23 3,587.93 -3,624.01 1,603.68 5,945,091.34 519,113.01 MWD+IFR-AK-CAZ-SC(3) 6,286.75 71.83 160.57 3,740.83 3,617.53 -3,709.38 1,633.40 5,945,006.05 519,142.92 MWD+IFR-AK-CAZ-SC(3) 6,378.56 71.77 161.64 3769.51 3,646.21 -3,791.90 1,661.64 5,944,923.61 519,171.35 MWD+IFR-AK-CAZ-SC(3) 6,473.57 71.90 162.05 3,799.13 3,675.83 -3,877.68 1,689.77 5,944,837.90 519,199.68 MWD+IFR-AK-CAZ-SC(3) 6,565.34 71.77 160.85 3,827.74 3,704.44 -3,960.35 1,717.51 5,944,755.31 519,227.61 MWD+IFR-AK-CAZ-SC(3) 6,658.27 71.77 162.54 3,856.81 3,733.51 4,044.14 1,745.23 5,944,671.59 519,255.52 MWD+IFR-AK-CAZ-SC(3) 6,750.58 71.81 162.77 3,885.66 3,762.36 -4,127.84 1,771.37 5,944,587.96 519,281.85 MWD+IFR-AK-CAZ-SC(3) 6,841.75 71.68 162.36 3,914.22 3,790.92 -4,210.44 1,797.31 5,944,505.42 519,307.98 MWD+IFR-AK-CAZ-SC(3) 6,934.70 71.62 162.23 3,943.48 3,820.18 -4,294.49 1,824.14 5,944,421.45 519,335.01 MWD+IFR-AK-CAZ-SC(3) 7,027.95 71.66 162.29 3,972.85 3,849.55 -4,378.78 1,851.11 5,944,337.23 519,362.17 MWD+IFR-AK-CAZ-SC(3) 7,120.39 71.63 162.44 4,001.96 3,878.66 -4,462.40 1,877.69 5,944,253.68 519,388.94 MWD+IFR-AK-CAZ-SC(3) 7,213.55 71.66 161.98 4,031.30 3,908.00 -4,546.59 1,904.70 5,944,169.56 519,416.15 MWD+IFR-AK-CAZ-SC(3) 7,305.62 71.66 161.86 4,060.27 3,936.97 -4,629.67 1,931.83 5,944,086.55 519,443.46 MWD+IFR-AK-CAZ-SC(3) 7,398.58 71.35 160.85 4,089.76 3,966.46 .4,71320 1,960.01 5,944,003.10 519,471.83 MWD+IFR-AK-CAZ-SC(3) 7,490.75 71.46 160.60 4,119.15 3,995.85 -4,795.66 1,988.85 5,943,920.71 519,500.86 MWD+IFR-AK-CAZ-SC(3) 7,584.58 71.81 160.97 4.148.72 4,025.42 -4,879.75 2,018.15 5,943,836.70 519,530.36 MWD+IFR-AK-CAZ-SC(3) 7,677.74 72.01 159.46 4.177.64 4,054.34 -4,963.07 2,048.13 5,943,753.45 519,560.52 MWD+IFR-AK-CAZ-SC(3) 7,768.70 72.41 158.71 4,205.43 4,082.13 -5,043.98 2,079.05 5,943,672.63 519,591.63 MWD+IFR-AK-CAZ-SC(3) 7,860.26 72.47 159.17 4,233.06 4,109.76 -5,125.44 2,110.42 5,943,591.25 519,623.18 MWD+IFR-AK-CAZ-SC(3) 7,955.57 72.62 159.74 4,261.65 4,138.35 -5,210.58 2,142.32 5,943,506.19 519,655.28 MWD+IFR-AK-CAZ-SC(3) 8,048.36 72.82 162.19 4,289.21 4,165.91 -5,294.33 2,171.22 5,943,422.52 519,684.37 MWD+IFR-AK-CAZ-SC(3) 12/16/2014 6:26:40PM Page 4 COMFASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +NIS +VAN Northing Easting (usft) (l (^) (usft) (usft) (usft) (usft) 90.00 usft tool name 8,142.38 72.92 164.26 4,316.91 4,193.61 -5,380.35 2,197.15 5,943,336.57 519,710.50 MWD+IFR-AK-CAZ-SC(3) 8,234.19 73.03 165.12 4,343.79 4,220.49 -5,465.02 2,220.33 5,943,251.96 519,733.87 MWD+IFR-AK-CAZ-SC(3) 8,331.32 72.44 164.98 4,372.62 4,249.32 -5,554.63 2,244.25 5,943,162.41 519,758.00 MWD+IFR-AK-CAZ-SC(3) 8,429.13 71.89 164.70 4,402.58 4,279.28 -5,644.50 2,268.60 5,943,072.61 519,782.56 MWD+IFR-AK-CAZ-SC(3) 8,525.03 71.96 164.31 4,432.33 4,309.03 -5,732.35 2,292.96 5,942,984.82 519,807.12 MWD+IFR-AK-CAZ-SC(3) 8,619.70 71.96 164.28 4,461.65 4,338.35 -5,819.01 2,317.32 5,942,898.23 519,831.68 MWD+IFR-AK-CAZ-SC(3) 8,716.89 71.99 164.40 4,491.72 4,368.42 -5,908.00 2,342.27 5,942,809.31 519,856.83 MWD+IFR-AK-CAZ-SC(3) 8,811.52 71.99 164.15 4,520.98 4,397.68 -5,994.62 2,366.66 5,942,722.75 519,881.42 MWD+IFR-AK-CAZ-SC(3) 8,908.66 71.96 163.65 4,551.04 4,427.74 -6,083.37 2,392.28 5,942,634.07 519,907.24 MWD+IFR-AK-CAZ-SC(3) 9,003.89 71.96 163.72 4,580.53 4,457.23 -6,170.28 2,417.71 5,942,547.23 519,932.88 MWD+IFR-AK-CAZ-SC(3) 9,100.74 71.82 163.60 4,610.63 4,487.33 -6,258.61 2,443.61 5,942,458.97 519,958.98 MWD+IFR-AK-CAZ-SC(3) 9,195.23 71.80 162.95 4640.13 4,516.83 -6,344.58 2,469.44 5,942,373.07 519,985.01 MWD+IFR-AK-CAZ-SC(3) 9,284.94 71.90 162.64 4,668.08 4,544.78 -6,426.01 2,494.66 5,942,291.70 520,010.41 MWD+IFR-AK-CAZ-SC(3) 9,377.35 71.96 162.83 4,696.74 4,573.44 -6,509.91 2,520.73 5,942,207.88 520,036.68 MWD+IFR-AK-CAZ-SC(3) 9,470.78 71.99 162.32 4,725.65 4,602.35 -6,594.67 2,547.34 5,942,123.18 520,063.48 MWD+IFR-AK-CAZ-SC(3) 9,562.52 72.08 162.61 4,753.95 4,630.65 -6,677.88 2,573.63 5,942,040.04 520,089.96 MWD+IFR-AK-CAZ-SC(3) 9,657.27 72.05 162.46 4,783.12 4,659.82 -6,763.87 2,600.69 5,941,954.12 520,117.21 MWD+IFR-AK-CAZ-SC(3) 9,748.11 72.05 162.76 4,811.12 4,687.82 -6,846.34 2,626.51 5,941,871.72 520,143.23 MWD+IFR-AK-CAZ-SC(3) 9,841.58 72.02 162.81 4,839.95 4,716.65 -6,931.27 2,652.83 5,941,786.86 520,169.74 MWD+IFR-AK-CAZ-SC(3) 9,934.14 71.99 162.71 4,868.54 4,745.24 -7,015.35 2,678.92 5,941,702.85 520,196.02 MWD+IFR-AK-CAZ-SC(3) 10,026.48 71.97 162.43 4,897.11 4,773.81 -7,099.13 2,705.22 5,941,619.15 520,222.52 MWD+IFR-AK-CAZ-SC(3) 10,118.52 71.86 162.19 4,925.68 4,802.38 -7,182.48 2,731.81 5,941,535.86 520,249.29 MWD+IFR-AK-CAZ-SC(3) 10,211.07 71.96 162.19 4,954.42 4,831.12 -7,266.24 2,758.72 5,941,452.17 520,276.39 MWD+IFR-AK-CAZ-SC(3) 10,302.93 71.87 162.58 4,982.93 4,859.63 -7,349.47 2,785.14 5,941,369.01 520,303.01 MWD+IFR-AK-CAZ-SC(3) 10,395.84 71.87 161.99 5,011.85 4,888.55 -7,433.58 2,812.01 5,941,284.98 520,330.07 MWD+IFR-AK-CAZ-SC(3) 10,490.00 71.93 162.00 5,041.10 4,917.80 -7,518.70 2,839.67 5,941,199.93 520,357.93 MWD+IFR-AK-CAZ-SC(3) 10,586.12 71.96 162.08 5,070.89 4,947.59 -7,605.63 2,867.85 5,941,113.07 520,386.31 MWD+IFR-AK-CAZ-SC(3) 10,682.96 71.93 161.91 5,100.90 4,977.60 -7,693.19 2,896.31 5,941,025.58 520,414.97 MWD+IFR-AK-CAZ-SC(3) 10,778.42 71.96 161.80 5,130.49 5,007.19 -7,779.44 2,924.58 5,940,939.41 520,443.43 MWD+IFR-AK-CAZ-SC(3) 10,871.75 71.99 161.70 5,159.37 5,036.07 -7,863.73 2,952.37 5,940,855.20 520,471.42 MWD+IFR-AK-CAZ-SC(3) 10,963.94 72.17 161.50 5,187.73 5,064.43 -7,946.96 2,980.06 5,940,772.04 520,499.30 MWD+IFR-AK-CAZ-SC(3) 11,056.98 72.01 162.57 5,216.35 5,093.05 -8,031.17 3,007.36 5,940,687.90 520,526.79 MWD+IFR-AK-CAZ-SC(3) 11,150.69 71.98 161.92 5,245.31 5,122.01 -8,116.05 3,034.54 5,940,603.10 520,554.17 MWD+IFR-AK-CAZ-SC(3) 11,242.30 72.15 161.80 5,273.52 5,150.22 -8,198.87 3,061.68 5,940,520.34 520,581.49 MWD+IFR-AK-CAZ-SC(3) 11,335.08 72.14 161.57 5,301.97 5,178.67 -8,282.71 3,089.43 5,940,436.58 520,609.44 MWD+IFR-AK-CAZ-SC(3) 11,428.00 72.02 161.75 5,330.56 5,207.26 -8,366.63 3,117.25 5,940,352.73 520,637.45 MWD+IFR-AK-CAZ-SC(3) 11,520.79 72.01 162.18 5,359.21 5,235.91 -8,450.55 3,144.57 5,940,268.88 520,664.96 MWD+IFR-AK-CAZ-SC(3) 11,613.90 72.22 162.37 5,387.81 5,264.51 -8,534.96 3,171.55 5,940,184.55 520,692.13 MWD+IFR-AK-CAZ-SC(3) 11,705.68 72.59 163.66 5,415.55 5,292.25 -8,618.63 3,197.10 5,940,100.95 520,717.88 MWD+IFR-AK-CAZ-SC(3) 11,798.09 73.02 166.16 5,442.87 5,319.57 -8,703.85 3,220.08 5,940,015.78 520,741.05 MWD+IFR-AK-CAZ-SC(3) 12/16/2014 6:26:40PM Page 5 COMFASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/-S +E/-W Northing Smiting (usft) (") (") (usft) (usft) (usft) (usft) 130.00 usft tool name 11,891.17 73.04 168.18 5,470.04 5,346.74 -8,790.65 3,239.85 5,939,929.04 520,761.02 MWD+IFR-AK-CAZ-SC(3) 11,982.58 72.83 169.49 5,496.87 5,373.57 -8,876.38 3,256.77 5,939,843.36 520,778.14 MWD+IFR-AK-CAZ-SC(3) 12,075.85 72.31 171.00 5.524.81 5,401.51 -8,964.08 3,271.85 5,939,755.70 520,793.42 MWD+IFR-AK-CAZ-SC(3) 12,168.72 72.30 174.63 5.553.04 5,429.74 -9,051.84 3,282.91 5,939,667.97 520,804.69 MWD+IFR-AK-CAZ-SC(3) 12,260.70 72.86 176.00 5.580.58 5,457.28 -9,13931 3,290.08 5,939,580.53 520,812.06 MWD+IFR-AK-CAZ-SC(3) 12,352.13 73.15 178.21 5.607.31 5,484.01 -9,226.63 3,294.49 5,939,493.23 520,816.67 MWD+IFR-AK-CAZ-SC(3) 12,445.90 73.63 180.86 5,634.12 5,510.82 -9,316.47 3,295.22 5,939,403.40 520,817.61 MWD+IFR-AK-CAZ-SC(3) 12,538.80 74.05 183.33 5;659.98 5,536.68 -9,405.63 3,291.96 5,939,314.24 520,814.55 MWD+IFR-AK-CAZ-SC(3) 12,631.67 74.65 183.87 5,685.03 5,561.73 -9,494.88 3,286.34 5,939,224.99 520,809.15 MWD+IFR-AK-CAZ-SC(3) 12,724.30 75.00 184.77 5,709.28 5,585.98 -9,584.03 3,279.61 5,939,135.83 520,802.62 MWD+IFR-AK-CAZ-SC(3) 12,815.88 75.47 186.38 5;732.62 5,609.32 -9,672.16 3,271.00 5,939,047.69 520,794.22 MWD+IFR-AK-CAZ-SC(3) 12,909.47 76.01 187.07 5755.67 5,632.37 -9,762.24 3,260.38 5,938,957.59 520,783.81 MWD+IFR-AK-CAZ-SC(3) 13,003.63 76.15 187.49 5,778.33 5,655.03 -9,852.90 3,248.80 5,938,866.92 520,772.44 MWD+IFR-AK-CAZ-SC(3) 13,096.52 76.12 187.43 5;800.58 5,677.28 -9,942.32 3,237.09 5,938,777.48 520,760.94 MWD+IFR-AK-CAZ-SC(3) 13,188.97 76.18 186.95 5,822.72 5,699.42 -10,031.38 3,225.85 5,938,688.41 520,749.91 MWD+IFR-AK-CAZ-SC(3) 13,280.25 76.18 186.38 5844.52 5,721.22 -10,11942 3,215.57 5,938,600.35 520,739.83 MWD+IFR-AK-CAZ-SC(3) 13,372.64 76.15 186.73 5,866.61 5,743.31 -10,208.54 3,205.33 5,938,511.22 520,729.80 MWD+IFR-AK-CAZ-SC(3) 13,466.09 76.03 186.29 5.889.08 5,765.78 -10,298.66 3,195.04 5,938,421.08 520,719.73 MWD+IFR-AK-CAZ-SC(3) 13,558.31 76.06 186.11 5,911.32 5,788.02 -10,387.64 3,185.38 5,938,332.09 520,710.27 MWD+IFR-AK-CAZ-SC(3) 13,650.26 76.09 185.58 5,933.45 5,810.15 -10,476.42 3,176.29 5,938,243.29 520,701.39 MWD+IFR-AK-CAZ-SC(3) 13,742.97 76.09 185.79 5.955.73 5,832.43 -10,565.97 3,167.37 5,938,153.73 520,692.68 MWD+IFR-AK-CAZ-SC(3) 13,835.25 76.24 185.70 5.977.80 5,854.50 -10,655.12 3,158.40 5,938,064.57 520,683.92 MWD+IFR-AK-CAZ-SC(3) 13,928.16 76.12 185.53 5,999.99 5,876.69 -10,744.91 3,149.58 5,937,974.77 520,675.30 MWD+IFR-AK-CAZ-SC(3) 14,020.86 76.18 185.37 6,022.18 5,898.88 -10,834.51 3,141.03 5,937,885.16 520,666.96 MWD+IFR-AK-CAZ-SC(3) 14,113.19 76.30 184.16 6,044.15 5,920.85 -10,923.88 3,133.58 5,937,795.79 520,659.72 MWD+IFR-AK-CAZ-SC(3) 14,205.59 76.11 184.12 6,066.18 5,942.88 -11,013.38 3,127.10 5,937,706.28 520,653.45 MWD+IFR-AK-CAZ-SC(3) 14,299.19 76.23 184.66 6,088.55 5,965.25 -11,104.00 3,120.14 5,937,615.65 520,646.71 MWD+IFR-AK-CAZ-SC(3) 14,391.83 76.79 185.75 6,110.16 5,986.86 -11,193.71 3,111.97 5,937,525.93 520,638.74 MWD+IFR-AK-CAZ-SC(3) 14,484.97 79.23 187.45 6.129.51 6,006.21 -11,28420 3,101.49 5,937,435.42 520,628.48 MWD+IFR-AK-CAZ-SC(3) 14,547.71 81.42 188.70 6,140.06 6,016.76 -11,345.43 3,092.80 5,937,374.18 520,619.93 MWD+IFR-AK-CAZ-SC(3) 14,604.00 83.06 189.62 6,147.66 6,024.36 -11,400.49 3,083.93 5,937,319.11 520,611.18 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 14,615.84 83.40 189.81 6,149.06 6,025.76 -11,412.08 3,081.94 5,937,307.51 520,609.23 MWD+IFR-AK-CAZ-SC(4) 14,709.90 86.89 189.20 6,157.02 6,033.72 -11,504.50 3,066.47 5,937,215.07 520,593.97 MWD+IFR-AK-CAZ-SC(4) 14,804.76 89.06 188.88 6,160.37 6,037.07 -11,598.12 3,051.57 5,937,121.42 520,579.29 MWD+IFR-AK-CAZ-SC(4) 14,899.53 88.90 188.42 6,162.05 6,038.75 -11,691.79 3,037.32 5,937,027.72 520,565.26 MWD+IFR-AK-CAZ-SC(4) 14,994.39 89.04 187.54 6,163.76 6,040.46 -11,785.72 3,024.16 5,936,933.78 520,552.32 MWD+IFR-AK-CAZ-SC(4) 15,089.96 89.96 186.30 6164.59 6,04129 -11,880.59 3,012.64 5,936,838.89 520,541.02 MWD+IFR-AK-CAZ-SC(4) 15,184.52 90.23 185.70 6;164.44 6,041.14 -11,974.63 3,002.76 5,936,744.84 520,531.36 MWD+IFR-AK-CAZ-SC(4) 15,280.33 87.97 188.24 6,165.94 6,042.64 -12,069.70 2,991.14 5,936,649.74 520,519.96 MWD+IFR-AK-CAZ-SC(4) 15,374.59 86.72 186.69 6,170.31 6,047.01 -12,163.06 2,978.90 5,936,556.37 520,507.94 MWD+IFR-AK-CAZ-SC(4) 12/16/2014 6:26:40PM Page 6 COMFASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/S +E/-W Northing Fasting (usft) (^) (^) (usft) (usft) (usft) (usft) 169.00 usft tool name 15,469.97 87.90 187.34 6,174.78 6,051.48 -12,257.62 2,967.27 5,936,461.79 520,496.53 MWD+IFR-AK-CAZ-SC(4) 15,564.59 88.66 187.16 6,177.62 6,054.32 -12,351.44 2,955.33 5,936,367.95 520,484.81 MWD+IFR-AK-CAZ-SC(4) 15,655.63 88.97 186.43 6179.51 6,056.21 -12,441.82 2,944.56 5,936,277.56 520,474.26 MWD+IFR-AK-CAZ-SC(4) 15,750.39 88.69 186.43 6,181.44 6,058.14 -12,535.96 2,933.95 5,936,183.40 520,463.87 MWD+IFR-AK-CAZ-SC(4) 15,844.57 88.04 186.21 6,184.13 6,060.83 -12,629.53 2,923.59 5,936,089.81 520,453.72 MWD+IFR-AK-CAZ-SC(4) 15,939.82 87.94 185.92 6,187.47 6,064.17 -12,724.19 2,913.53 5,935,995.14 520,443.88 MWD+IFR-AK-CAZ-SC(4) 16,036.46 86.91 186.09 6,191.81 6,068.51 -12,820.20 2,903.43 5,935,899.12 520,434.01 MWD+IFR-AK-CAZ-SC(4) 16,131.54 86.59 183.82 6,197.20 6,073.90 -12,914.77 2,895.23 5,935,804.54 520,426.03 MWD+IFR-AK-CAZ-SC(4) 16,225.28 88.30 181.42 6.201.38 6,078.08 -13,008.31 2,890.95 5,935,711.00 520,421.97 MWD+IFR-AK-CAZ-SC(4) 16,320.57 87.90 179.13 6,204.54 6,081.24 -13,103.54 2,890.50 5,935,615.78 520,421.73 MWD+IFR-AK-CAZ-SC(4) 16,413.76 87.46 178.86 6,208.31 6,085.01 -13,196.64 2,892.13 5,935,522.70 520,423.58 MWD+IFR-AK-CAZ-SC(4) 16,509.31 87.11 179.05 6,212.84 6,089.54 -13,292.06 2,893.87 5,935,427.28 520,425.55 MWD+IFR-AK-CAZ-SC(4) 16,604.01 88.07 178.97 6,216.82 6,093.52 -13,386.66 2,895.51 5,935,332.70 520,427.40 MWD+IFR-AK-CAZ-SC(4) 16,695.76 89.79 180.87 6,218.54 6,095.24 -13,478.39 2,895.63 5,935,240.98 520,427.74 MWD+IFR-AK-CAZ-SC(4) 16,791.87 91.25 180.92 6,217.66 6,094.36 -13,574.48 2,894.13 5,935,144.89 520,426.46 MWD+IFR-AK-CAZ-SC(4) 16,887.00 90.61 180.08 6,216.12 6,092.82 -13,669.59 2,893.30 5,935,049.79 520,425.85 MWD+IFR-AK-CAZ-SC(4) 16,980.71 89.86 179.19 6,215.74 6,092.44 -13,763.30 2,893.90 5,934,956.09 520,426.67 MWD+IFR-AK-CAZ-SC(4) 17,075.12 89.65 178.78 6,216.14 6,092.84 -13,857.69 2,895.57 5,934,861.71 520,428.56 MWD+IFR-AK-CAZ-SC(4) 17,169.92 89.89 177.28 6,216.52 6,093.22 -13,952.44 2,898.83 5,934,766.99 520,432.04 MWD+IFR-AK-CAZ-SC(4) 17,265.58 91.17 175.44 6,215.63 6,092.33 -14,047.89 2,904.90 5,934,671.56 520,438.33 MWD+IFR-AK-CAZ-SC(4) 17,360.73 91.32 174.43 6,213.57 6,090.27 -14,142.65 2,913.30 5,934,576.83 520,446.95 MWD+IFR-AK-CAZ-SC(4) 17,455.27 89.24 173.31 6,213.11 6,089.81 -14,236.64 2,923.40 5,934,482.87 520,457.26 MWD+IFR-AK-CAZ-SC(4) 17,549.24 88.94 173.32 6,214.60 6,091.30 -14,329.96 2,934.33 5,934,389.59 520,468.42 MWD+IFR-AK-CAZ-SC(4) 17,644.62 87.56 173.40 6,217.51 6,094.21 -14,424.65 2,945.36 5,934,294.93 520,479.66 MWD+IFR-AK-CAZ-SC(4) 17,738.13 87.70 175.82 6,221.38 6,098.08 -14,517.66 2,954.13 5,934,201.95 520,488.65 MWD+IFR-AK-CAZ-SC(4) 17,832.78 87.53 178.58 6,225.32 6,102.02 -14,612.11 2,958.75 5,934,107.52 520,493.49 MWD+IFR-AK-CAZ-SC(4) 17,927.45 88.14 178.78 6.228.89 6,105.59 -14,706.68 2,960.93 5,934,012.96 520,495.89 MWD+IFR-AK-CAZ-SC(4) 18,021.47 88.81 180.58 6,231.40 6,108.10 -14,800.66 2,961.46 5,933,918.99 520,496.63 MWD+IFR-AK-CAZ-SC(4) 18,115.83 87.57 180.80 6,234.38 6,111.08 -14,894.97 2,960.32 5,933,824.70 520,495.71 MWD+IFR-AK-CAZ-SC(4) 18,210.47 89.71 181.28 6.236.62 6,113.32 -14,989.56 2,958.60 5,933,730.11 520,494.22 MWD+IFR-AK-CAZSC(4) 18,302.53 89.64 181.33 6,237.14 6,113.84 -15,081.60 2,956.51 5,933,638.08 520,492.34 MWD+IFR-AK-CAZ-SC(4) I 18,395.59 91.56 182.08 6,236.17 6,112.87 -15,174.60 2,953.74 5,933,545.07 520,489.78 MWD+IFR-AK-CAZ-SC(4) 18,491.05 91.23 180.93 6,233.85 6,110.55 -15,270.00 2,951.23 5,933,449.68 520,487.50 MWD+IFR-AK-CAZ-SC(4) 18,585.54 91.40 180.01 6,231.68 6,108.38 -15,364.46 2,950.46 5,933,355.23 520,486.94 MWD+IFR-AK-CAZ-SC(4) 18,680.26 91.15 178.93 6,229.57 6,106.27 -15,459.15 2,951.33 5,933,260.55 520,488.04 MWD+IFR-AK-CAZ-SC(4) 18,774.88 89.09 179.35 6,229.37 6,106.07 -15,553.76 2,952.75 5,933,165.96 520,489.68 MWD+IFR-AK-CAZ-SC(4) 18,868.29 89.00 178.84 6,230.93 6,107.63 -15,647.14 2,954.23 5,933,072.59 520,491.37 MWD+IFR-AK-CAZ-SC(4) 18,962.56 88.56 178.42 6,232.94 6,109.64 -15,741.36 2,956.48 5,932,978.38 520,493.84 MWD+IFR-AK-CAZ-SC(4) 19,055.89 88.93 178.56 6,234.98 6,111.68 -15,834.64 2,958.94 5,932,885.12 520,496.52 MWD+IFR-AK-CAZ-SC(4) 19,150.95 88.32 177.80 6,237.26 6,113.96 -15,929.62 2,961.96 5,932,790.15 520,499.76 MWD+IFR-AK-CAZ-SC(4) 12/16/2014 6:26:40PM Page 7 COMFASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical ND Below Map Map Depth Inclination Azimuth Depth System +N/-S +E/-w Northing Easting (usft) (^) (^) (usft) (usft) (usft) (usft) 210.00 usft tool name 19,246.32 87.46 179.35 6,240.77 6,117.47 -16,024.89 2,964.33 5,932,694.90 520,502.35 MWD+IFR-AK-CAZ-SC(4) 19,340.03 86.20 180.73 6,245.95 6,122.65 -16,118.46 2,964.26 5,932,601.34 520,502.50 MWD+IFR-AK-CAZ-SC(4) 19,434.63 87.83 180.50 6,250.88 6,127.58 -16,212.92 2,963.25 5,932,506.89 520,501.71 MWD+IFR-AK-CAZ-SC(4) 19,530.29 88.44 179.68 6,253.99 6,130.69 -16,308.53 2,963.10 5,932,411.29 520,501.78 MWD+IFR-AK-CAZ-SC(4) 19,624.88 87.25 180.19 6,257.55 6,134.25 -16,403.05 2,963.21 5,932,316.78 520,502.11 MWD+IFR-AK-CAZ-SC(4) 19,719.86 86.75 179.95 6,262.52 6,139.22 -16,497.90 2,963.09 5,932,221.94 520,502.21 MWD+IFR-AK-CAZ-SC(4) 19,814.56 90.14 178.89 6,265.09 6,141.79 -16,592.54 2,964.05 5,932,127.30 520,503.39 MWD+IFR-AK-CAZSC(4) 19,909.59 92.17 179.04 6,263.18 6,139.88 -16,687.53 2,965.77 5,932,032.33 520,505.33 MWD+IFR-AK-CAZSC(4) 20,004.29 92.51 178.95 6,259.31 6,136.01 -16,782.14 2,967.43 5,931,937.74 520,507.21 MWD+IFR-AK-CAZ-SC(4) 20,098.92 91.33 179.79 6,256.14 6,132.84 -16,876.71 2,968.46 5,931,843.18 520,508.47 MWD+IFR-AK-CAZ-SC(4) 20,193.85 89.72 180.82 6,255.27 6,131.97 -16,971.63 2,967.96 5,931,748.27 520,508.18 MWD+IFR-AK-CAZ-SC(4) 20,274.00 89.72 180.82 6,255.66 6,132.36 -17,051.77 2,966.81 5,931,668.13 520,507.22 PROJECTED to TD 41/2"x 6314" 12116/2014 6:26:40PM Page 8 COMFASS 5000.1 Build 65 E 4 Q ƒ\ (k\ a §7! § I a ®4 � 1 I \\¢) �! /\ 21Es 'Ili 3 0 � � U ? F- _ / 1111 3 RI I § k ( = c o o m 2 -0 8 \§ Q CDo § a co 22 03 4_, 2 � 7 222213 03 2go0 � � � 2 @J / � 2 E k / >, 2 � 4 . . ° @ it > 15 > m � k % co I El � El Li El 111 To m .. � % m 2 133 q E 0 J to d STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ E• WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service 0 , StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: December 3,2014• 214-136/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 October 21,2014 ' 50-029-23525-00- 4a.Location of Well(Governmental Section): 7.Date TD Reached: �5 b S 14.Well Name and Number: Surface: 172'FNL, 1731'FEL,Sec.33,T11N,R9E,UM November*2014 rt.a'� KRU 2F-21 . Top of Productive Horizon: 8. KB(ft above MSL): 123'RKB 15.Field/Pool(s): 892'FNL, 1346'FWL,Sec. 10,T1ON,R9E,UM GL(ft above MSL): 96'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1384'FNL, 1196'FWL,Sec. 15,T1ON, R9E, UM 20233'MD/6255'TVD Kupuruk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-517501 y- 5948711 Zone-4 20274'MD/6256'TVD • ADL 25657,25666,392364 , TPI: x-520630 y- 5937440 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-520507 y- 5931668 Zone-4 nipple @ 565'MD/565'TVD 2583,2587,2178 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) na (ft MSL) 1442'MD/1416'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,CBL not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 164# H-40 27' 115' 27' 115' 24" Driven 10.75" 45.5# L-80 26' 3996' 26' 3028' 13.5" 1590 sx DeepCRETE 7.625" 29.7# L-80 24' 14607' 24' 6148' 9.875" 518 sx Class G 4.5" 11.6# L-80 14480' 20233' 6128' 6255' 6.75" open hole slotted liner 24.Open to production or injection? Yes 0 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5"x 4.5" 14466' 14447'MD/6122'TVD slots from 14526'-14945'MD 6136'-6163'TVD slots from 15274'-20202'MD 6165'-6255'UQ._.Ei. r 1�D 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. EVC Was hydraulic fracturing used during completion? Yes El No 0 c j '1'. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED IT,rl JAN 022015 AOGGC _ 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No O If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 �S �� CONTINUED ON REVERSE '7Kd 326/I. ABC M i Submit Niginaonly 1S' vrt- 3/1`1 4 S U 29. GEOLOGIC MARKERS(List all formations and mar. .ncountered) 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1442' 1416' needed,and submit detailed test information per 20 AAC 25 071. Upper Kalubik 13487' 5893' Lower Kalubik 13932' 6001' Kuparuk C 14275' 6083' Kuparuk A6 14412' 6115' Kuparuk A5 14520' 6135' 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 /+ Contact. Haibin Guo @ 265-1487 Email Haibin.Guo@,conocophillips.com C-,a t' Printed Name G. L..AAlvoord Title Alaska Drilling Manager Signature � -6-£2 ( Phone 265-6120 Date i 2-(2.1 (n0 ( +- 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 o MI00 00 0 o' 00' 01ul N' N N CO N u1 r-I Tr N N CO CD 01 r-I M w CD CD M CO in N CO 01 01 01 0 1- 0 L--I N N ul Ln ul in in Ln VD CO - M CD i rr-I M M e--I r M 00 Ln 111 co I - o c 00 •:t• tD 01 O' 00 00 .--1 m coLo 00 N cr 01 CO 00 O O O r1 r1 N .-I N N co u1 CD CO co co co CO 0 II ' _ Tr-.-I N'IOIll MIN N u1 NI, N Ori, 1O co0000IN1 N, in �1cnIN'1N crI Ln N IOLn r-I, N' M N M' M cr , � Tr Tr 0 I� d' a-1 r-I r-I r-I r-I r-I .--I N ri COE LL 9- I 0i1 ' 1 � I V I `) � I a) I- 3 0 0 IO =al E YU I I "- U I 'L0 1 a Q0 0 Y . I o % 0 Y _ E c (n N - Eco O m Q Q co c Q Y Y Y Y C0_ Y L1 C01 5 Ce ID 2 2 2 2 7 2 I o o' aI a! 3 a aI = 0 = d .0 H 1-ho , miLD Y ,Y1Y Y ,H I 1Y 0 H C71 r- - LLI LL E NI 1 i , I N lL 20-1-'Sc 2-51S 2. WELL LOG TRANSMITTAL DATA LOGGED °c/201�{ K.BENDER To: Alaska Oil and Gas Conservation Comm. November 24, 2014 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 Oilr 0 5 2014 RE: Radial Bond Log : 2F-21 Run Date: 11/16/2014 A.GCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2F-21 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-23525-00 Radial Bond Log 1 Color Log 50-029-23525-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: , KUP PROD 2F-21 ConocoPhillips '- Well Attributes Max Angle&MD TD Alaska,11)c. Wellbore API/UWI Field Name Wellbore Status 'ncl1°) MD(ftKB) ActBtm(ftKB) conc.-4N' , 500292352500 KUPARUK RIVER UNIT PROD 92.50 20,004.29 20,274.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2F-21,2/1720151.32.30 AM SSSV:NIPPLE Last WO'. 27.50 12/32014 Vemcal schematic(actual) - - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date LLast Tag: Rev Reason:GLV C/O,SET FLOW-THRU SUB hipshkf 2/17/2015 HANGER,233 iij'be W/GAUGES • Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread l J CONDUCTOR 20 18.430 28.0 143.0 143.0 164.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...WVLen(I...Grade Top Thread • I SURFACE 103/4 9.950 262 3,996.4 3,027.4 45.50 L-80 HYD 563 Casing Description OD(in) SID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WI/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 24.2 14,606.6 6,144.4 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...•Wt/Len(I...Grade Top Thread m' 'SLOTTED LINER 4 1/2 3.958 14,447.0 20,233.0 11.60 L-80 HYD 563 Liner Details Nominal ID XO Reducing;58.2 li Top(ftKB) Top(ND)(ftKB) Top Incl(1 Item Des Corn (in) 14,447.0 6,118.5 7823 PACKER BAKER ZXP PACKER W/HRDE PROFILE 5.750 'M's CONDUCTOR.29.0-1430 14,466.9 6,122.4 78.76 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 14,469.7 6,123.0 78.83 HANGER BAKER"DG"FLEX LOCK LINER HANGER 4.790 NIPPLE;564.6 1 14,996.4 6,160.2 89.06 SWELL FREECAP I FSC-11 SWELL PACKER 3.958 ■ PACKER . 15,203.0 6,160.9 89.78 SWELL FREECAP I FSC-11 SWELL PACKER 3.958 Il PACKER Tubing Strings GAS LIFT;2,794.5. TubingDescription String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND) Wt INf[ Grade TopConnection III 9 1""" 1 1 TUBING-Upper 41/2 312 2.992 23.3 14,400.4 6,108.5 9.30 L-80 EUE x31/2@58.17 r (� Completion Details 1 'J Nominal ID i f■LS Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 23.3 HANGER CAMERON TUBING HANGER 3.900 SURFACE 26 2-3.906 4 58.2 58.2 0.06 XO Reducing XO,2',4-1/2"12.6#L-80)BTM box x 3-1/2"9.3#L-80 2.940 -- EUE 8RD-Mod pin 564.6 564.4 3.21 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 SLEEVE;14,145.6- 14,145.8 6,048.3 76.25 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 NIPPLE 2.812 FLOW THRU SUB;14,146.0 PROFILE 14,377.7 6,103.3 76.71 LOCATOR LOCATOR SUB- 2.980 14,378.7 6,103.5 76.71 SEAL ASSY BAKER(80-40)PBR SEAL ASSY 2.980 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-Lower 5 4.000 14,384.71 14,466.11 6,122.3 9.30 L-80 EUE LOCATOR;14,377.7 Completion Details Nominal ID SEAL ASSY;14.376.7 Top(ftKB) Top(ND)(ftKB) Top Incl(1 Item Des Corn (in) PBR;14,384.7 14,384.7 6,104.9 76.75 PBR POLISHED BORE RECEPTACLE 4.000 3 14 408.8 6,110.4 77.23 PACKER BAKER PREMIER PRODUCTION PACKER 3.500 XO Threads;14.407.3 I 14,429.4 6,114.8 77.78 NIPPLE CAMCO D NIPPLE 2750 PACKER;14.4068 W.1.114,436.3 6,116.3 77.95 PLUG HALLIBURTON MIRAGE PLUG 2.880 XO Threads;14A15.4 14,444.9 6,118.0 78.18 SUB,NO-GO NO GO SUB:SPACED OUT 2'OFF LINER TOP 3.010 ® 14,446.0 6,118.3 78.21 SOS SHEAR OUT SUB 3.010 NIPPLE;14.429.4 I 14,4651 6,1221 78.71 MULE SHOE MULE SHOE W/WLEG 3.000 III PLUG;14,436.2 gi Perforations&Slots Shot Den SUB,NO-GO;14,444.8 Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 606;14;445.9 14,529.0 14,945.2 6,133.5 6,159.3 11/26/2014 SLOTS SLOTTED LINER 111. 15,274.2 20,201.4' 6,162.2 11/26/2014 SLOTS SLOTTED LINER MULE SHOE,14,465.1 •. Mandrel Inserts St au on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 2,794.5 2,522.2 Cameron 134AF0 1 1!2 GAS LIFTOV RK 0.313 0.0"2/14/2015 Notes:General&Safety End Date Annotation NO1E.The lower tubing is 3 1/2 0D not 5. INTERMEDIATE;24.2-14,606.6 C SLOTS;14,529.0-14,945.2 7 40 RECEIVEE' MAR 2 5 2015 i----i SLOTS:15.274.2-20.2014 i SLOTTED LINER;14,447.0. 1 l AOGCC 20,2330 l ConocoPhiIIips Time Log & Summary Wel!view Web Reporting Report Well Name: 2F-21 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 9/24/2014 12:00:00 AM Rig Release: 9/28/2014 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/24/2014 24 hr Summary Finish cleaning rig. Prep rig for move disconnecting interconnects&unplugging electrical. Split modules& move boiler, motor, pump, pits,sub base,&pipe sheds to 2D pad. Stage modules at 2D while plywood& mats are moved to access road between 2D&2C. Move shop&rock washer to 2F pad. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Clean choke room, Iron Roughneck, draw works, cuttings box,cellar area, &drip pans. 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Prep rig for move, blow down steam &water. Disconnect interconnect lines&unplug electrical. 09:00 10:30 1.50 0 0 MIRU MOVE MOB P Pull rock washer&stage on 2E. Jack up pipe sheds. Pull boiler, motor,&pump modules staging on 2E. 10:30 12:00 1.50 0 0 MIRU MOVE MOB P Lay mats between 2E&2D pads. 12:00 21:00 9.00 0 0 MIRU MOVE MOB P Move boiler, motors, pump, pits,& pipe sheds to 2D pad for staging. Return&pull sub base off of 2E-01. Move sub to 2D pad for staging. 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Move shop&rock washer from 2E to 2F pad&stage. Simops move mats &plywood from 2E-2D road to 2D-2C road. 39/25/2014 Move mats&plywood from 2E-2D road to 2D-2C access road. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Pick up plywood&mats between 2E &2D pads. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Lay plywood between 2D&2C pads. 39/26/2014 Finish laying mats&plywood from 2D to 2C. Move modules&sub from 2D to 2C to stage. Start laying mats to 2F pad. Move pits, pumps, motor, &boilers modules to 2F pad. Lay mats on 2F access road for sub base. 00:00 10:00 10.00 0 0 MIRU MOVE MOB P Lay plywood&mats from 2D to 2C pad. Kick w/Drilling Table Top Drill @ 00:45 hrs. 10:00 12:00 2.00 0 0 MIRU MOVE MOB P Move boiler, motor,&pump modules from 2D to 2C pad. 12:00 16:00 4.00 0 0 MIRU MOVE MOB P Move sub base, pipe sheds, &pits from 2D to 2C pad. 16:00 19:00 3.00 0 0 MIRU MOVE MOB P Set mats at CPF-2&2F access road. Kick w/Drilling Table Top Drill @ 18:00 hrs. 19:00 20:15 1.25 0 0 MIRU MOVE MOB P Move boiler, motor, &pump modules to 2F pad. 20:15 00:00 3.75 0 0 MIRU MOVE MOB P Lay mats on 2F access road. Page 1 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/27/2014 24 hr Summary Remove plywood from 2C-2D access road. Lay mats&plywood on 2F access road. Move pipe sheds&pits from 2C to 2F pad. Move sub base from 2C to CPF-2. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Pick up plywood between 2C&2D pads. 12:00 21:00 9.00 0 0 MIRU MOVE MOB P Lay plywood&mats on 2F access ,road. 21:00 22:30 1.50 0 0 MIRU MOVE MOB P Move pipe sheds&pits to 2F pad. 22:30 00:00 1.50 0 0 MIRU MOVE MOB P Move sub base from 2C pad to CPF-2. 09/28/2014 Move sub base to 2F&mate up modules. Move ROC from 2E pad to 2F pad. Hook up lines&electrical. Release rig to Rig Maintenance @ 12:00 hrs.. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Move sub base from CPF-2 to 2F pad. 01:00 02:15 1.25 0 0 MIRU MOVE MOB P Spot sub on 2F pad. 02:15 02:45 0.50 0 0 MIRU MOVE MOB P Spot parts trailers. 02:45 03:45 1.00 0 0 MIRU MOVE MOB P Lay mats for modules. 03:45 05:45 2.00 0 0 MIRU MOVE MOB P Spot pits, pump, motor, boiler, & rockwasher modules. 05:45 06:30 0.75 0 0 MIRU MOVE MOB P Spot pipe sheds. 06:30 12:00 5.50 0 0 MIRU MOVE RURD P Plug in electrical interconnects. Hook up lines&work on rig acceptance checklist. Release rig @ 12:00 hrs. 10/18/2014 Move rig over 2F-21. Work on rig acceptance checklist. 12:00 14:00 2.00 0 0 MIRU MOVE MOB P PJSM, move and spot all modules to other side of pad near 2F-21. 02:00 04:30 2.50 0 0 MIRU MOVE MOB P Move&spot sub base over 2F-21. 04:30 07:00 2.50 0 0 MIRU MOVE MOB P Spot pits, pump, motor, &boiler modules, with sub base on 2F-21. 07:00 09:00 2.00 0 0 MIRU MOVE MOB P Spot pipe sheds. 09:00 10:15 1.25 0 0 MIRU MOVE MOB P Spot rock washer. 10:15 12:00 1.75 0 0 MIRU MOVE RURD P Work on rig acceptance checklist. 10/19/2014 Nipple up diverter. Load pipe shed with 5" DP&BHA. Take on spud mud.AOGCC diverter test. PU DP& stand back in derrick. P/U cleanout BHA. Attempt to PT high psi surface lines. Shock hose below rig floor failed. Start removing hose. Rig accepted @ 00:00 hrs. 00:00 06:00 6.00 0 0 MIRU MOVE NUND P PJSM, Nipple up diverter. SIMOPS, take on spud mud, load pipe shed with 5"drill pipe and calibrate gas _alarms. 06:00 10:00 4.00 0 0 MIRU MOVE RURD P PJSM, Cont to strap and tally 5"drill pipe and 5" HWDP. Page 2 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:15 0.25 0 0 MIRU MOVE BOPE P Perform diverter test: knife valve open=9 seconds, annular closed= 22 seconds. Accumulator test: system pressure=2900 psi, pressure after closing= 1800 psi,200 psi attained in 41 seconds, full pressure attained after 193 seconds. Five bottle nitrogen avg.=2000 psi. Tested all gas alarms and Totco alarms. Witness of test waived by Bob Noble. 10:15 12:00 1.75 0 0 MIRU MOVE NUND P Cameron Rep.energize fluid seals on conductor. SIM-OP perform pre-spud derrick inspection&prep handling tools for BHA. 12:00 14:15 2.25 0 0 MIRU MOVE PULD P Pick up 5" DP&rack back in derrick. 14:15 14:45 0.50 0 0 MIRU MOVE SFTY P De-ice derrick. 14:45 15:30 0.75 0 0 MIRU MOVE SFTY P Test rig emergency shutdown systems, all good. 15:30 16:30 1.00 0 0 MIRU MOVE PULD P Pick up 5" DP&rack back in derrick. 16:30 17:00 0.50 0 0 MIRU MOVE SFTY P Safety stand down, review recent top drive incident. Table top diverter drill. 17:00 18:00 1.00 0 0 MIRU MOVE PULD P Pick up 5"drill pipe& rack back in derrick. 18:00 18:45 0.75 0 0 MIRU MOVE PULD P Pick up 5" HWDP&stand back in derrick. 18:45 20:15 1.50 0 0 MIRU MOVE RURD P Lay down mouse hole. Mobilize BHA tools to the rig floor. 20:15 21:45 1.50 0 40 MIRU MOVE PULD P Pick up&make up clean out BHA as per SLB. 21:45 22:45 1.00 40 40 MIRU MOVE SEQP P Flood all lines, checking for leaks. Pressure test high psi surface equipment 250/5000 psi on chart. High psi shock hose under rig floor leaking. 22:45 23:45 1.00 40 40 MIRU MOVE SVRG P Service TDS, blocks&crown. SIM-OPS looks for replacement hose. 23:45 00:00 0.25 40 40 MIRU MOVE RGRP T Start removing high psi shock hose. 10/20/2014 Remove failed shock hose. Begin modifying existing high psi mud line for new shock hose. Load pipe shed& pick up 5"DP, racking back in derrick, for intermediate hole section. 00:00 02:30 2.50 40 40 MIRU MOVE RGRP T Measure shock hose, break connections. Welder survey task for modification. 02:30 03:00 0.50 40 40 MIRU MOVE SFTY P Safety stand down to review recent top drive incident on another rig in the feild. 03:00 07:00 4.00 40 40 MIRU MOVE RGRP T Continue to remove stand pipe shock hose&prep for modifications. Page 3 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 12:00 5.00 40 40 MIRU MOVE RURD P Load&strap 150 jts of 5"DP in pipe shed for intermediate hole section. SIM-OP move HWDP to ODS of derrick. Adjust drawworks brakes. P/U new shock hose&hook up to stand pipe. 12:00 12:30 0.50 40 40 MIRU MOVE SFTY T Remove ice from derrick. 12:30 13:00 0.50 40 40 MIRU MOVE RURD P Strap DP in pipe shed. 13:00 14:00 1.00 40 40 MIRU MOVE SFTY T Remove ice from derrick. 14:00 17:00 3.00 40 0 MIRU MOVE PULD P Lay down clean out assembly. Pick up 5" DP&rack back in derrick. 17:00 18:00 1.00 0 0 MIRU MOVE RURD P Measure rotary table for MPD. 18:00 19:00 1.00 0 0 MIRU MOVE RGRP T Change out forward/reverse switch for drawworks on console. 19:00 22:00 3.00 0 0 MIRU MOVE PULD P Finish picking up 5" DP for intermediate hole section. 22:00 22:30 0.50 0 0 MIRU MOVE RURD P Lay down mousehole&clear rig floor. 22:30 00:00 1.50 0 0 MIRU MOVE RGRP T Continue weld modification of mud line for new shock hose. 10/21/2014 Finish high psi mud line modifications&install new shock hose. MPI modifications&hydro test entire high psi mud line system. Pick up BHA 1 &clean out conductor. TOH, P/U BHA 2&drill to 630' MD 00:00 06:45 6.75 0 0 MIRU MOVE RGRP T Finish welding on high psi mud line& let cool. (work on MP2). Spill Drill @ 06:00 hrs CRT= 188 06:45 08:45 2.00 0 0 MIRU MOVE RGRP T Finish installing the shock hose. 08:45 09:15 0.50 0 0 MIRU MOVE RGRP T MPI new welds on high psi mud lines. Good. 09:15 09:30 0.25 0 0 MIRU MOVE SEQP T Pressure test high pressure mud lines to 5000 psi. Good. 09:30 10:00 0.50 0 40 MIRU MOVE PULD P Pick up BHA 1 &flood lines/conductor, checking for leaks. 10:00 12:15 2.25 40 171 SURFA( DRILL DRLG P Drill out conductor 40'-171' MD, 171' TVD, 450 gpm, 300 psi, 40 rpm,tq 0-1 K, PU 40K, SO 35K, ROT 40K 12:15 13:00 0.75 171 0 SURFA( DRILL TRIP P TOH f/ 171'-0'MD, check bit&orient motor. 13:00 13:30 0.50 0 0 SURFA( DRILL RURD P Mobilize SLB tools to rig floor.Adjust blower on TD. 13:30 14:45 1.25 0 121 SURFA( DRILL PULD P P/U BHA 2 as per SLB DD. 14:45 15:00 0.25 121 171 SURFA( DRILL TRIP P TIH f/121'-171' MD. 15:00 18:15 3.25 171 394 SURFA( DRILL DDRL P DD f/171'-394' MD,ADT 1.5, AST 0, 500 gpm,450 psi, 40 rpm, Tq 1-2K, PU 52K, SO 52K, ROT 52K. Spill Drill @ 17:30 hrs CRT= 105 sec 18:15 18:45 0.50 394 121 SURFA( DRILL TRIP P TOH f/394'-121'MD 18:45 19:45 1.00 121 214 SURFA( DRILL PULD P P/U NMFC's&saver sub. 19:45 20:00 0.25 214 394 SURFA( DRILL TRIP P TIH f/214'-394'MD. Page 4of41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 394 630 SURFA( DRILL DDRL P DDrill f/394'-630'MD,630'TVD,ADT 1.85,AST 1, Bit 3.36, Jars 3.36, 500gpm, 600psi,WOB 5-13K, 60 rpm,Tq on 2k, off 1K, PU 67K, SO 68K, ROT 67K, FO 78% 10/22/2014 Directional drill surface hole section from 630'to 2716'. 00:00 06:00 6.00 630 1,078 SURFA( DRILL DDRL P DDrill f/630'-1083' MD, 1078'TVD, ADT 3.30,AST 2.21, Bit 6.80, Jars 137.80, 500gpm, 910psi,WOB 20-25K, 70 rpm, Tq on 2-3k, off 1-2K, PU 67K, SO 67K, ROT 67K, FO 74%, ECD=9.70 06:00 12:00 6.00 1,078 1,629 SURFA( DRILL DDRL P DDrill f/1083'-1670' MD, 1629'TVD, ADT 3.43,AST 2.20, Bit 10.23,Jars 141.23,600gpm, 1050psi,WOB 5-10K, 70 rpm, Tq on 3-4k, off 3-4K, PU 80K, SO 73K, ROT 78K, FO 74%, ECD=9.85 12:00 18:00 6.00 1,629 2,252 SURFA( DRILL DDRL P DDrill f/1670'-2252' MD, 2125'TVD, ADT 3.56,AST 2.45, Bit 13.79,Jars 144.79,600 gpm, 1125psi,WOB 10-15K, 70 rpm, Tq on 4-6k, off 4-6K, PU 94K, SO 79K, ROT 86K, FO 74%, ECD=9.84 18:00 00:00 6.00 2,252 2,716 SURFA( DRILL DDRL P 10/23/2014 Directional drill surface hole section from 2716'to 4006'MD, 3031'TVD. OWFF&BROOH f/4006'-3646' MD. 00:00 06:00 6.00 2,716 3,178 SURFA( DRILL DDRL P DDrill f/2716-3178' MD, 2736'TVD, ADT 3.83,AST 2.27, Bit 20.87, Jars 151.87,618 gpm, 1500 psi,WOB 15-20K,80 rpm, Tq on 7-8k, off 4-5K, PU 104K, SO 84K, ROT 95K, FO 73%, ECD=10.03 06:00 12:00 6.00 3,178 3,510 SURFA( DRILL DDRL P DDrill f/3178'-3510'MD, 2877'TVD, ADT 3.77,AST 2.50, Bit 24.64, Jars 155.64,611 gpm, 1690 psi,WOB 15-20K, 80 rpm, Tq on 8-9k, off 5-6K, PU 102K, SO 84K, ROT 94K, FO 73%, ECD=10.1 12:00 19:45 7.75 3,510 4,006 SURFA( DRILL DDRL P DDrill f/3510'-4006'MD,3031'TVD, ADT 5.73,AST.50, Bit 30.37,Jars 161.37, 714 gpm,2100 psi,WOB 11-17K, 90 rpm,Tq on 5-11k, off 4-7K, PU 99K, SO 75K, ROT 83K, FO 70%, ECD=10.22 19:45 22:45 3.00 4,006 4,006 SURFA( CASING CIRC P CBU 3X @ 750 gpm,2175 psi, 90 rpm,Tq 4-6 K, PU 96K, SO 74K, ROT 76K, till hole clean&mud properties good. 22:45 23:15 0.50 4,006 4,006 SURFA( CASING OWFF P Monitor well,static. 23:15 00:00 0.75 4,006 3,646 SURFA( CASING REAM P BROOH f/4006'-3646'MD,750 gpm, 2200 psi, 80 rpm,Tq 5-6 K, PU 75K, SO 74K, ROT 77K, @ 800 fph. Page 5of41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/24/2014 24 hr Summary BROOH&lay down BHA 2.Attempt hanger dummy run. Rig up Volant CRT&run 10 3/4"casing as per detail to 2309' MD. 00:00 06:45 6.75 3,646 775 SURFA( CASING REAM P BROOH f/3646'-1515'MD, 750 gpm, 2200 psi, 80 rpm,Tq 7 K, @ 800 fph. Attempt to pull @ 1000 fph. Hole started to pack off. Revert back to 800 fph.. BROOH f/1515'-960'MD. 500 gpm. 850 psi. 80 rpm.Tq 2-4K @ 800 fph. BROOH f/960'-775'MD. 150-300 fph. 06:45 07:00 0.25 775 775 SURFA( CASING OWFF P Monitor well. Static. 07:00 08:30 1.50 775 221 SURFA( CASING REAM P Orient mud motor to high side. Pump HWDP out of hole f/775'-221' MD. 3.5 bpm. Act. disp=53.37 bbls. Calc disp=34.75 bbls 08:30 11:30 3.00 221 0 SURFA( CASING PULD P Lay down BHA as per SLB reps. 11:30 12:45 1.25 0 0 SURFA( CASING RURD P Clean and clear rig floor 12:45 14:00 1.25 0 0 SURFA( CASING SEQP T Attempt hanger dummy run. Hanger not landing on profile. Flush stack and attempt to land hanger.Again hanger failed to land in profile. 14:00 16:15 2.25 0 0 SURFA( CASING RURD P Rig up Volant CRT and casing equip. 16:15 21:15 5.00 0 1,478 SURFA( CASING PUTB P Make up and check float equipment. Run 10 3/4 L-80 45.5#Hydril 563 casing as per detail to 1478'MD 21:15 21:45 0.50 1,478 1,478 SURFA( CASING CIRC P Circ casing volume @1478' MD. Stage pump up f/2 bpm to 7 bpm. 150 psi. PU=75K SO=71 K 21:45 00:00 2.25 1,478 2,309 SURFA( CASING PUTB P Run 10 3/4 L-80 45.5#Hydril 563 casing as per detail f/1478'-2309 MD. PU=120K SO=90K. Calc disp=35 bbls.Act disp.=-6.39 10/25/2014 Continue to run 10 3/4"casing to 3996'MD.Attempt to land hanger, 9"high. Lay down hanger&landing joint. PU full joint for CIW emergency setting system. Circ and cond mud. Perform cement job. OWFF for 30 min, static. Nipple down diverter. 00:00 01:30 1.50 2,309 2,770 SURFA( CASING PUTB P Run 10 3/4 L-80 45.5#Hydril 563 casing as per detail f/2309'-2770' MD. PU=135K SO=93K. 01:30 02:45 1.25 2,770 2,770 SURFA( CASING CIRC P CBU staging up pumps to 6 bpm, 150 psi. 02:45 07:00 4.25 2,770 3,996 SURFA( CASING PUTB P RIH from 2770'-3996'MD, PU 155K, 90K,calculated displacement 69.3, actual 18.9 bbls. Total of 94 joints ran. 07:00 09:30 2.50 3,996 3,996 SURFA( CEMEN-CIRC P Circulate&condition mud for cement,staging up pumps to 6 bpm, 250 psi. 09:30 11:00 1.50 3,996 3,995 SURFA( CEMEN'PULD T Lay down 1 jt, make up hanger& landing joint.Attempt to land casing hanger. Stack out 9"high,working string&setting 100K down. PU 150K, SO 100K. 11:00 12:15 1.25 3,995 3,995 SURFA( CEMEN-CIRC P Circulate&condition mud for cement staging up pumps to 7 bpm, 150 psi. Page 6 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 13:15 1.00 3,995 3,996 SURFA( CEMEN-PULD T Lay down landing joint&hanger. Pick up joint#100. 13:15 15:00 1.75 3,996 3,996 SURFA( CEMEN'CIRC P CBU to condition mud for cement, staging up pumps to 7 bpm, 150 psi. 15:00 15:30 0.50 3,996 3,996 SURFA( CEMEN-RURD P Rig down Volant CRT. Rig up XO& cement head. 15:30 16:00 0.50 3,996 3,996 SURFA( CEMEN'SFTY P PJSM with all contractor for cement job.Continue to circulate @ 7 bpm, 150 psi. 16:00 16:30 0.50 3,996 3,996 SURFA( CEMEN CIRC P Batch up MP II, continue to circulate @ 7bpm, 150 psi. 16:30 16:45 0.25 3,996 3,996 SURFA( CEMEN SEQP P Pump 5bbls H2O, psi test lines 300/4000 psi on chart f/5 min. Good. 16:45 19:15 2.50 3,996 3,996 SURFA( CEMEN'CMNT P Pump 100 bbls 10.5 ppg MUDPUSH II @ 6 bpm, 100 psi. Drop bottom plug. Pump 530 bbls of 11ppg, DeepCRETE cement, 6 bpm,225 psi. Drop top plug ahead of tail cement. Pump 8 bbl tail cement& shut down. Confer with town. Pump 10 bbls H2O,shut down&swap to rig. 19:15 20:15 1.00 3,996 3,996 SURFA( CEMEN'CMNT P Displace cement with 9.6ppg mud w/ rig pumps @ 6 bpm, ICP 500 psi, FCP 750 psi,slow pumps to 3 bpm, 500 psi. bump plug with 3565 strokes. 130+bbls good cement return back to surface. Pressure up to 1200 psi&hold for 5 min. Check floats, Good. CIP at 20:15 hrs. 20:15 21:00 0.75 3,996 0 SURFA( CEMEN-WWWH P Flush conductor adapter,diverter system, &all lines. 21:00 21:30 0.50 0 0 SURFA( CEMEN OWFF P Monitor well, static. 21:30 00:00 2.50 0 0 SURFA(WHDBO NUND T Nipple down diverter&lift annular off conductor to install Cameron emergency system. Casing set in slips on rig floor with static weight of 145k. Sim-ops Clear rig floor and remove ice from derrick. 10/26/2014 N/D diverter system.Attempt to remove landing ring from conductor adapter,with no success. Receive approval to split&install new landing ring. Install CIW emergency set system. Cut casing joint. Finish N/D diverter system&stage outside cellar. Install multi-bowl adapter flange on cut casing.Wait on welds to cool as per procedure. 00:00 01:00 1.00 0 0 SURFA( CEMEN-RURD T Rig down cement head, rig up secondary restraint on surface annular. 01:00 04:00 3.00 0 0 SURFA(WHDBO NUND T CIW Reps. attempting to remove landing ring from conductor adapter. No success. Call&receive approvals to cut new landing ring, install on conductor,welding split landing ring in place. 04:00 05:30 1.50 0 0 SURFA( WHDBO NUND T Install new split landing ring on conductor,welding out split& tacking to conductor. Page 7 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 07:30 2.00 0 0 SURFA( WHDBO RURD T Rig down secondary restraint. Suck _out mud from casing joint to be cut. 07:30 10:30 3.00 0 0 SURFA( WHDBO NUND T Weld CIW emergency load set system to casing as per CIW _procedure. 10:30 11:30 1.00 0 0 SURFA( WHDBO NUND T Cut casing joint&lay down. Remove diverter riser. 11:30 16:30 5.00 0 0 SURFA( WHDBO NUND P N/D diverter system&remove from cellar. Sim-ops clear rig floor, load pipe shed with 159 jts. 5"DP,& _clean pits. 16:30 20:45 4.25 0 0 SURFA( WHDBO NUND T GBR welder prep casing stub,weld out T103 hanger, &wrap w/ insulation to cool slow as per CIW procedure. 20:45 22:30 1.75 0 0 SURFA( WHDBO NUND T Wait on T103 hanger welds to slow cool. Sim-op change out saver sub, service TD, &grease crown. 22:30 23:00 0.50 0 0 SURFA( WHDBO NUND T Wait on T103 hanger welds to slow cool. Sim-ops remove ice from derrick. 23:00 00:00 1.00 0 0 SURFA( WHDBO NUND T Wait on T103 hanger welds to slow cool. Sim-ops rig up&pick up 5" DP, racking back in derrick. 10/27/2014 Allow CIW T103 hanger to cool.Attempt to test weld void. Failed. Grind out and reweld T103 hanger.Allow to cool. 00:00 04:30 4.50 0 0 SURFA(WHDBO'NUND T Wait on T103 hanger welds to slow cool. Sim-ops rig up&pick up a total of 72 jts. 5"DP, racking back in derrick. Take on mud in pits.Work on MP2 04:30 09:30 5.00 0 0 SURFA(WHDBO NUND T Check well head temp. 146 degrees. Continue to allow well head to cool. Sim-ops move surface equip. from cellar door area. Remove conductor adapter spool from cellar.Stage RCD in cellar. 09:30 10:00 0.50 0 0 SURFA(WHDBO SEQP T Check well head temp. 85 degrees. Test welded void to 1800 psi. Failed, leaking on interior weld. Rig down test equip. 10:00 13:00 3.00 0 0 SURFA(WHDBO NUND T Prep to reweld well head. Rig up GBR welder. Grind out and reweld interior weld on well head. 13:00 21:00 8.00 0 0 SURFA(WHDBO NUND T Wait on T103 hanger welds to slow cool. Sim-ops clean rotary for new master bushings,work on modification of mud bucket drain line. of mud Work on MP2 21:00 23:00 2.00 0 0 SURFAt WHDBO NUND T Check well head temp.225 degrees. Continue to allow well head to cool. Sim-ops continue with mud bucket line modification, remove VR plugs from new well head spools. Page 8 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 SURFA( WHDBO NUND T Check well head temp. 204 degrees. Continue to allow well head to cool. Sim-ops continue with mud bucket line modification. Kick w/Drilling Table Top Drill& 23:00 hrs. 10/28/2014 Allow CIW T103 hanger to cool. Test weld void. Nipple up CIW multi-bowl system. N/U BOPE&MPD. Install MPD choke skid. Install new mud bucket return line. 00:00 07:00 7.00 0 0 SURFA( WHDBO NUND T Continue to allow well head to cool. Sim-ops continue with mud bucket line modification. 07:00 08:00 1.00 0 0 SURFA( WHDBO SEQP T Rig up and test welded void to 1800 psi/15 min. 08:00 09:30 1.50 0 0 SURFA( WHDBO NUND P Nipple up Cameron MBS well head and test seals to 5000 psi/10 min. 09:30 10:30 1.00 0 0 SURFA( CEMEN-NUND P Nipple up BOPE. 10:30 15:30 5.00 0 0 SURFA( CEMEN-RURD P Install RCD and control valve on annular 15:30 18:30 3.00 0 0 SURFA( CEMEN RURD T Rig down control valve and RCD. Rotate RCD 180°due to control valve interference with mouse hole. 18:30 19:30 1.00 0 0 SURFA( CEMEN-RURD P Spot MPD choke skid in substructure. 19:30 20:15 0.75 0 0 SURFA( CEMEN RURD P Torque flange bolts on RCD. Install control valve on RCD. 20:15 00:00 3.75 0 0 SURFA( CEMEN RURD P Install hoses on flow line and RCD. Continue to make electrical connections to choke skid. Rig up air system for control valve. Continue with mud bucket return line modification. Bring test plug and trip nipple to rig floor. 10/29/2014 Continue to install MPD system.Attempt to set trip nipple. Attempt to set test plug. ND BOPE. Dress burr in wellhead bore. NU BOPE. Perform BOPE shell test. Pressure test MPD system. 00:00 04:00 4.00 0 0 SURFA( CEMEN RURD P Install hoses on flow line and RCD. Continue to make electrical connections to choke skid. Continue with mud bucket return line modification. Measure and cut trip nipple 04:00 09:00 5.00 0 0 SURFA( CEMEN RURD P Rig specific custom fit trip nipple. Unable to lock in due to being unable to hold back up, misalignment of guide dogs. Remove trip nipple and weld D rings to provide leverage points. Page 9 of 41 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 0 0 (SURFA(WHDBO RURD T Attempt to set C1W test plug in well head. Required 4K top drive weight to seat plug. Pull plug and inspect. Observed two gashes in test plug 0-ring seal. Change out seal and reseat test plug using top drive weight. Pull test plug and inspect. Observed cut 0-ring seal and body damage. Ensure upper lockdowns are backed out. Rerun and pull test plug. Observe additional body damage to plug. 12:00 13:00 1.00 0 0 SURFA(WHDBO NUND T Nipple down BOPE and inspect wellhead. Observe burr 1/2"below upper lockdowns. 13:00 15:45 2.75 0 0 SURFA(WHDBO EQRP T Dress wellhead. Set test plug in wellhead. Good. Tighten gland nuts on wellhead. 15:45 17:45 2.00 0 0 SURFA(WHDBO NUND T Nipple up BOPE. Install turnbuckles and trip nipple. 17:45 19:30 1.75 0 0 SURFA(WHDBO BOPE P Rig up test equip. Perform BOPE body test. Test w/5"test jt. against annular preventer 250/3500 psi. 5 min.each 19:30 21:30 2.00 0 0 SURFA( CEMEN'RURD P Rig down test jt. Rig up pressure sensor on RCD. Install secondary retention line for remote operated valve on RCD. 21:30 00:00 2.50 0 0 SURFA( CEMEN-SEQP P Flood lines and perform pressure test on MPD system.Test 250/1500 psi for 10 min.Test#1, Shell test, Remaining tests conducted with 250/1000 psi. for 10 min. Test#2. BV6,drain valve, LT2, LT4.Test#3. BV3,BV4, BV5, LT1, LT3.Test#4. Chokes A&B. Test#5. BV1, BV2 10/30/2014 Complete MPD commissioning. Install cellar doors. Erect scaffold and rotate remote operated valve, install drip pan.Test BOPE. Change out seals on trip nipple. Install wear bushing. 00:00 01:30 1.50 0 0 SURFA( CEMEN"SEQP P Continue to test MPD manifold 250 psi low, 1000 psi high for 10 min each,Test#6 BV7,test#7 AV. Commision MPD system. R/D test equipment. SIMOPS-Weld cellar doors,fabricate gaurds for MPD manifold/autochoke. 01:30 04:00 2.50 0 0 SURFA( CEMEN-RURD P Pull RCD test plug, set trip nipple. 04:00 06:30 2.50 0 0 SURFA( WHDBO RURD P R/U BOPE test equipment, install 5" test joint. (SIMOPS C/O light in derrick, continue welding in cellar) 06:30 09:00 2.50 0 0 SURFA( CEMEN RURD P PJSM, R/U scaffolding in cellar to mount Katch Kan 09:00 12:00 3.00 0 0 SURFA( CEMEN-RURD P PJSM, Break and turn flowline valve to 90°on RCD,work on installing Katch Kan. Page 10 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 0 0 SURFA( CEMEN-RURD P PJSM, re-install Katch Kan, determine modifications required for fitment.. Remove Kan and take to shop for modification. 14:00 14:45 0.75 0 0 SURFA( WHDBO RURD P PJSM, R/U and fill lines to test BOPE. 14:45 20:00 5.25 0 0 SURFA( WHDBO BOPE P Test BOPE with 5"TJ to 250/3500 psi 5 min each charted.#1-Top pipe rams,Valve 1,12,13,14.#2-Upper IBOP, Manual kill,Valves 9,11, HCR kill.#3-Lower IBOP,Valves 5,8,10. #4-Dart valve,valves 4,6,7.#5-Floor valve&valve 2.#6-HCR choke,4" kill line, Demco valve.#7-Manual choke valve, HCR kill.#8-Annular preventer(250/3500).#9-Lower pipe rams.#10-Blind rams and valve 3. #11-HCR super choke, manual choke drawdown test. 20:00 20:30 0.50 0 0 SURFA(WHDBO BOPE P Accumulator test: System pressure= 3000 psi, Pressure after closing= 1800 psi, 200 psi attained=38 sec, Full pressure attained= 195 sec. 5 bottle N2 average=2100 psi. AOGCC Jim Regg Waived witness @ 13:15 by phone. 20:30 21:30 1.00 0 0 SURFAC WHDBO RURD P PJSM, R/D test equipment, install ball valve on closing side of annular preventer. Function test OK. 21:30 23:15 1.75 0 0 SURFA( CEMEN-RURD P PJSM, Pull trip nipple, C/O seals on trip nipple and attempt to re-install. Send nipple to shop and enlarge lifting holes to facilitate installation. Install Katch Kan drip pan. 23:15 23:30 0.25 0 0 SURFA( CEMEN-RURD P Set CIW wear bushing. Bushing ID=10.25" 23:30 00:00 0.50 0 0 SURFA( CEMEN RURD P Continue to set trip nipple. 10/31/2014 Complete trip nipple and Katch Kan install, M/U BHA#3 and single in. Cut/Slip. Drill cement to 3892' MD. Circ. Perform casing test.service rig. Rig up instrumentation air purge system. DrIg. on cement plugs. 00:00 02:30 2.50 0 0 SURFAC CEMEN'RURD P PJSM, Continue to set trip nipple, test with water no leaks. Install Katch Kan and blanket. SIMOPS- Mobilize BHA and XO's to rig floor. 02:30 04:45 2.25 0 114 SURFA( CEMEN"PULD P PJSM, M/U BHA to 114'MD. 04:45 05:30 0.75 114 114 SURFA( CEMEN PULD P PJSM, Load nuke tools. 05:30 08:00 2.50 114 743 SURFA( CEMEN-PULD P PJSM. M/U BHA to 734'MD. Change out jars 08:00 08:45 0.75 743 743 SURFA( CEMEN-DHEQ P Shallow pulse test MWD. 08:45 09:30 0.75 743 1,863 SURFA( CEMEN PULD P P/U 5"drill pipe to 1863'MD 09:30 11:30 2.00 1,863 1,863 SURFA( CEMEN"SLPC P PJSM. Slip and cut 65'drlg. line. 11:30 12:00 0.50 1,863 1,863 SURFA( CEMEN SVRG P Service top drive.Adjust brakes. 12:00 14:00 2.00 1,863 3,437 SURFA( CEMEN'PULD P PJSM. P/U 5"drill pipe to 3437'MD Page 11 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:15 0.25 3,437 3,622 SURFA( CEMEN-TRIPP RIH to 3622' MD. P/U=100K S/0=62 K 14:15 15:15 1.00 3,622 3,860 SURFA( CEMEN'COCF P Break circulation.Wash and ream cement stringers f/3622'MD t/3860' MD.40 rpm,Tq=10K,WOB=1-3K, 850 psi.400 gpm. 15:15 15:45 0.50 3,860 3,892 SURFA( CEMEN"COCF P DrIg. cement f/3860'MD t/3892'MD. WOB=3-5K,40 rpm, 8-14K tq, 900 psi. 15:45 16:15 0.50 3,892 3,892 SURFA( CEMEN'CIRC P Circulate and condition for casing test. 16:15 16:45 0.50 3,892 3,798 SURFA( CEMEN"RURD P Stand back one stand of drill pipe. Rig up to test casing. 16:45 17:45 1.00 3,798 3,789 SURFA( CEMEN'PRTS P Test casing to 3000 psi/30 min. Good. 17:45 18:15 0.50 3,789 3,892 SURFA( CEMEN"RURD P Rig down test equip. RIH one stand of drill pipe to 3892'MD. 18:15 18:45 0.50 3,892 3,892 SURFA( CEMEN SVRG P Service rig. 18:45 21:30 2.75 3,892 3,892 SURFA( CEMEN'EQRP T Install air purge on Totco RigSense instrumentation.Trouble shoot and commission. 21:30 00:00 2.50 3,892 3,910 SURFA( CEMEN DRLG P RIH. Drill cement f/3892'MD t/3905' MD.Tag cement plugs @ 3905'MD. DrIg. on plugs f/3905'MD to 3910' MD.450 gpm,775 psi,40-70 rpm, 9-12K tq, 50%flow out. 11/01/2014 Drill float track+20'new hole. Circ. Perform LOT. Displace to 9.6 ppg LSND mud. Conduct MPD finger printing. Modify bleeder line and flow line jets. Drlg(/4026'MD t/4065'MD 00:00 03:15 3.25 3,910 4,006 SURFA( CEMEN-DRLG P Drill float collar, shoe track and float shoe, clean out rat hole(/3910' MD t/4006' MD..450 gpm, 70 rpm, 6-15K tq,5-10K WOB. Kick w/drilling drill @02:30 hrs. CRT=60 sec. 03:15 03:45 0.50 4,006 4,026 SURFA( CEMEN-DDRL P DrIg. (/4006'MD t/4026'MD. ADT=.20, 5-8K WOB, 5-10K tq, 70 rpm,450 gpm, 1000 psi. 03:45 04:45 1.00 4,026 3,909 SURFA( CEMEN-CIRC P Stand back one stand DP to 4606' MD. Circ and cond mud.450 gpm, 1000 psi, 70 rpm, 5-9K tq, Stand back one stand to 3909'MD. 04:45 06:45 2.00 3,909 3,909 SURFA( CEMEN-LOT P Rig up and perform LOT. 13.2 ppg EMW. Rig down and blow down lines. 06:45 08:00 1.25 3,909 4,026 INTRM1 DRILL DISP P Run in hole to 4026'MD. Displace well to 9.6 ppg LSND mud.480 gpm, 113 spm, 60 rpm,8K tq, 08:00 09:00 1.00 4,026 3,814 INTRM1 DRILL CIRC P Perform SPR's. POOH to 3814'MD. SPR's @3993'MD, 3029'TVD,9.7 ppg mud wt., @ 08:09 hrs. #1 30 spm=100 psi.40 spm=100 psi. #2 30 spm=100 40 spm=150 psi. 09:00 12:00 3.00 3,814 3,814 INTRM1 DRILL RURD P Pull trip nipple. R/U bearing assy.. Perform MPD training w/crew. Install bearing assy. into RCD. Page 12 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:45 0.75 3,814 3,814 INTRM1 DRILL SFTY P Safekick MPD system operation meeting w/crew and Co-Rep. 12:45 13:45 1.00 3,814 3,814 INTRM1 DRILL SEQP P Establish choke skid finger print per MPD rep. @100, 200,400,&650 gpm through chokes"A"and"B"and bypass line. 13:45 14:30 0.75 3,814 3,814 INTRM1 DRILL RURD P Blow down MPD choke skid and lines. Plug return lines 14:30 16:30 2.00 3,814 3,906 INTRM1 DRILL RURD P Pull and lay down bearing assy.from RCD. Install and secure trip nipple. RIH to 3906' MD. 16:30 16:45 0.25 3,906 3,906 INTRM1 DRILL CIRC P Break circulation. 5 bpm,200 psi. 44%FO. 16:45 17:00 0.25 3,906 3,906 INTRM1 DRILL SFTY P Blow down top drive. Stab FOSV. Monitor well via open OA. Kick w/tripping drill CRT=70 sec 17:00 23:15 6.25 3,906 3,906 INTRM1 DRILL EQRP T Move bleed line and flow line jets to downstream of flow line knife valve. Sim-ops-Reseal Katch Kan and modify drain line on Katch Kan. Clean cellar and BOPE. Continue to monitor well via OA. 23:15 23:30 0.25 3,906 4,006 INTRM1 DRILL TRIP P RIH to 4006' MD. 23:30 00:00 0.50 4,026 4,065 INTRM1 DRILL DDRL P DDrill f/4026'-4065'MD, 3049'TVD, ADT.21,Total bit hrs=.41,Total Jar hrs=.41,453 gpm, 900psi,WOB 8-15K, 70 rpm, Tq on 7-11k, off 6K, PU 80K, SO 65K, ROT 70K, FO 54%, 11/02/2014 Drill intermediate hole section f/4065'MD t/5893' MD. CBU. Monitor well. Perform LOT. Drill intermediate hole section f/5893' MD t/6198' MD. 00:00 06:00 6.00 4,065 4,765 INTRM1 DRILL DDRL P DDrill f/4065-4756'MD,3263'TVD, ADT=4.78,Total bit hrs=5.19,Total Jar hrs=5.19, 650 gpm, 1900psi, WOB 7-10K, 140 rpm,Tq on 7K, off 3K, PU 77K, SO 65K, ROT 70K, FO 60%, ECD=11.0 Max gas=557 units SPR's @4241'MD TVD=3098' MW=9.6 ppg #1 30 spm=100 psi 40 spm=200 psi #2 30 spm=100 psi 40 spm=190 psi 06:00 12:00 6.00 4,765 5,331 INTRM1 DRILL DDRL P DDrill f/4756'-5331' MD, 3441'TVD, ADT=4.21,Total bit hrs=9.40, Total Jar hrs=9.40, 650 gpm, 1900psi, WOB 10-15K, 140 rpm,Tq on 7K, off 4K, PU 85K, SO 70K, ROT 78K, FO 60%, ECD=11.2 Max gas=180 units SPR's @4736'MD TVD=3256' MW=9.7 ppg #1 30 spm=130 psi 40 spm=200 psi #2 30 spm=125 psi 40 spm=200 psi Page 13 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 5,331 5,893 INTRM1 DRILL DDRL P DDrill f/5331-5893'MD, 3614'TVD, ADT=3.96,Total bit hrs=13.38, Total Jar hrs=13.38,650 gpm, 2025 psi, WOB 10-17K, 140 rpm,Tq on 9K, off 4-5K, PU 90K, SO 72K, ROT 80K, FO 60%, ECD=11.59 Max gas=134 units SPR's @5616'MD TVD=3510' MW=9.8 ppg 14:15 hrs. #1 30 spm=175 psi 40 spm=250 psi #2 30 spm=175 psi 40 spm=220 psi 18:00 18:45 0.75 5,893 5,893 INTRM1 DRILL CIRC P CBU.650 gpm, 2025 psi on upstroke, 525 gpm, 1300 psi on downstroke 18:45 19:30 0.75 5,893 5,805 INTRM1 DRILL OWFF P Stand back one stand DP. Monitor well. Static 19:30 20:30 1.00 5,805 5,805 INTRM1 DRILL LOT P Rig up test equip. Perform LOT. 12.2 EMW. Rig down and blow down lines. 20:30 00:00 3.50 5,893 6,198 INTRM1 DRILL DDRL P RIH one stand. DDrill f/5893'-6198' MD, 3714'TVD,ADT=2.19, Total bit hrs=15.57, Total Jar hrs=15.57, 644 gpm,2100 psi,WOB 12-15K, 150 rpm,Tq on 9K, off 4K, PU 90K, SO 72K, ROT 80K, FO 60%, ECD=11.92 Max gas=58 units 11/03/2014 Drill intermediate hole section f/6198'MD t/7840' MD. Experience slight pack off. Monitor well. CBU. Drill intermediate hole section f/7295'MD t/7840'MD 00:00 06:00 6.00 6,198 6,636 INTRM1 DRILL DDRL P DDrill f/6198'-6636'MD, 3848'TVD, ADT=3.92,Total bit hrs=19.49,Total Jar hrs=19.49, 650 gpm,2150 psi, WOB 15-20K, 150 rpm,Tq on 9K, off 5K, PU 88K, SO 70K, ROT 78K, FO 60%, ECD=11.78 Max gas=52 units SPR's @6298'MD TVD=3742' MW=9.8 ppg 01:00 hrs #1 30 spm=190 psi 40 spm=250 psi #2 30 spm=190 psi 40 spm=230 psi 06:00 12:00 6.00 6,636 7,006 INTRM1 DRILL DDRL P DDrill f/6636'-7006'MD, 3964'TVD, ADT=3.72,Total bit hrs=23.21, Total Jar hrs=23.21,675 gpm, 2330 psi, WOB 15-23K, 160 rpm, Tq on 9K,off 5K, PU 90K, SO 70K, ROT 80K, FO 60%, ECD=11.50 Max gas=52 units SPR's @7004'MD TVD=3960' MW=9.8 ppg 11:15 hrs #1 30 spm=200 psi 40 spm=300 psi #2 30 spm=200 psi 40 spm=290 psi Page 14 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:15 3.25 7,006 7,295 INTRM1 DRILL DDRL P DDrill f/7006'-7295'MD,4055'TVD, ADT=2.45,Total bit hrs=25.66, Total Jar hrs=25.66,675 gpm,2500 psi, WOB 10-22K, 160 rpm,Tq on 11K, off 5K, PU 95K, SO 74K, ROT 84K, FO 60%, ECD=11.94 Max gas=50 units SPR's @7189'MD TVD=4022' MW=9.8 ppg 14:00 hrs #1 30 spm=260 psi 40 spm=320 psi #2 30 spm=250 psi 40 spm=320 psi 15:15 15:45 0.50 7,295 7,295 INTRM1 DRILL OWFF T Observed indications of pack off. Slow pumps and rotary. P/U to tool joint and monitor well. Slight flow to static. Stand back one stand in derrick. 15:45 16:30 0.75 7,295 7,295 INTRM1 DRILL CIRC T CBU. Stage pumps up from 84 gpm to 675 gpm. Increase in cuttings load at BUS. Decrease in ECD of.4 ppg after circulation. 16:30 18:00 1.50 7,295 7,375 INTRM1 DRILL DDRL P DDrill f/7295'-7375'MD,4081'TVD, ADT=.78, Total bit hrs=26.44, Total Jar hrs=26.44,673 gpm, 2550 psi, WOB 15-32K, 160 rpm, Tq on 11K, off 5.5K, PU 97K, SO 75K, ROT 85K, FO 60%, ECD=11.52 Max gas=46 units 18:00 00:00 6.00 7,375 7,840 INTRM1 DRILL DDRL P DDrill f/7375'-7840'MD,4225'TVD, ADT=3.58,Total bit hrs=30.02, Total Jar hrs=30.02,690 gpm, 2750 psi, WOB 20-32K, 160 rpm, Tq on 12K, off 6K, PU 109K, SO 82K, ROT 94K, FO 60%, ECD=11.45 Max gas=52 units 11/04/2014 Drill intermediate hole section f/7840' MD t/8024' MD. Experience pack off @7975'MD.Well flowing on connection.. Monitor well. Drill intermediate hole section f/8024' MD t/8305' MD. Pack off w/back reaming. Monitor well. CBU. Drill intermediate hole section f/8305' MD t/9235 00:00 02:00 2.00 7,840 8,024 INTRM1 DRILL DDRL P DDrill f/7840'-8024'MD,4280'TVD, ADT= 1.29,Total bit hrs=31.63,Total Jar hrs=31.63, 690 gpm,2700 psi, WOB 20-30K, 160 rpm,Tq on 13K, off 7K, PU 114K, SO 84K, ROT 96K, FO 60%, ECD=11.37 Max gas=52 units. Observed pack off @ 7975' MD. SPR's @7931'MD TVD=4252' MW=9.8 ppg #1 30 spm=290 psi 40 spm=350 psi #2 30 spm=280 psi 40 spm=350 psi 02:00 03:15 1.25 8,024 8,024 INTRM1 DRILL OWFF T Observe well flowing on connection. Monitor well. Flow diminished to static, Flow back total of 9.5 bbls. Page 15 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 07:30 4.25 8,024 8,307 INTRM1 DRILL DDRL P DDrill f/8024'-t/8307'MD,4363' TVD,ADT=3.35,Total bit hrs=34.98, Total Jar hrs=34.98,690 gpm,2750 psi,WOB 20-30K, 160 rpm,Tq on 13K, off 7K, PU 110K, SO 80K, ROT 91K, FO 60%, ECD=11.41 Max gas=102 units. 07:30 08:00 0.50 8,307 8,307 INTRM1 DRILL REAM T Hole packing off while back reaming stand @8275 MD. Reduce pump rate and work stand. Regain full returns at reduced rate of 600 gpm. Ream full stand back to 8305 MD. Lost 36 bbls. mud while drilling and reaming stand. 08:00 08:30 0.50 8,307 8,307 INTRM1 DRILL OWFF T Monitor well. Gain 4 bbls/30 mins 08:30 09:15 0.75 8,307 8,307 INTRM1 DRILL CIRC T CBU @ 8307'MD. 580 gpm,2100 psi, 160 rpm,Tq=8K, FO 57%, Stage pumps up to 685 gpm,2800 psi 09:15 12:00 2.75 8,307 8,440 INTRM1 DRILL DDRL P DDrill f/8307'-t/8440'MD,4403' TVD,ADT= 1.68, Total bit hrs=36.66, Total Jar hrs=36.66,690 gpm,2850 psi,WOB 18-23K, 160 rpm,Tq on 12K, off 7K, PU 110K, SO 80K, ROT 91K, FO 60%, ECD=11.25 Max gas=102 units. 12:00 18:00 6.00 8,440 8,785 INTRM1 DRILL DDRL P DDrill f/8440'-t/8785'MD,4511' TVD,ADT=4.23,Total bit hrs=40.89, Total Jar hrs=40.89,659 gpm, 2550 psi,WOB 10-20K, 160 rpm, Tq on 12K,off 8K, PU 108K, SO 76K, ROT 90K, FO 59%, ECD=11.17 Max gas=49 units. 18:00 00:00 6.00 8,785 9,235 INTRM1 DRILL DDRL P DDrill(/8785'-t/9235'MD,4651' TVD,ADT=4.23,Total bit hrs=40.89, Total Jar hrs=40.89,660 gpm, 2675 psi,WOB 16-20K, 160 rpm,Tq on 13K, off 8K, PU 106K, SO 74K, ROT 87K, FO 59%, ECD=11.39 Max gas=45 units. SPR's @8873'MD TVD=4582' MW=9.8 ppg #1 30 spm=260 psi 40 spm=320 psi #2 30 spm=260 psi 40 spm=300 psi 11/05/2014 Drill intermediate hole section f/9235'MD t/9356'MD. Experience pack off on backream @9340' MD. Stage flow rate up to regain circulation. Drill intermediate hole section f/9356' MD t/10466'MD. 00:00 01:15 1.25 9,235 9,356 INTRM1 DRILL DDRL P Drilled f/9235'to 9356', TVD=4688'. ADT=1.03 hrs. Bit hrs=46.37,Jars hrs=46.37, P/U= 104k, S/O=72k ROT=90k,Tq on= 13k,Tq off=8K, ECD= 11.70, Flow out=59%, WOB=12-18K, RPM= 160, Pump @ 660 gpm=2700 psi. Max gas=55 units Page 16 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 05:00 3.75 9,356 9,356 INTRM1 DRILL CIRC T Hole packed off @ 9340'MD. The ECD increased to 12.85 and lost all returns. Rack back one stand to 9263'. Established circulation @ 1 bpm and staged pumps up to 500 gpm= 1750 psi,washed down 9356' @ 30 rpm's, Tq-7k. Lost 140 bbls to hole. 05:00 12:00 7.00 9,356 9,726 INTRM1 DRILL DDRL P Drilled f/9356'to 9726',TVD=4800'. ADT=4.96 hrs. Bit hrs=51.33,Jars hrs=51.33, P/U= 112k, S/0=75k ROT=92k,Tq on= 14k, Tq off=9K, ECD=11.44, Flow out=59%, WOB=8-13K, RPM= 160, Pump @ 660 gpm=2700 psi. Max gas=38 units. Begin pumping sweeps—9500',with 15 bbls LSND, 15 bbls of H2O, 3 pbb SAPP and 55 gal of Drillzone to help clean BHA. Obtained SPR's @ 9390'MD,TVD= 4699'MW=9.9 ppg. MP#1 30 spm=325 psi,40 spm=400 psi, MP#2 30 spm=320 psi,40 spm= 390 psi 12:00 18:00 6.00 9,726 10,096 INTRM1 DRILL DDRL P DDrill f/9726'-t/10096'MD,4912' TVD,ADT=4.44,Total bit hrs=55.77, Total Jar hrs=55.77, 655 gpm,2700 psi,WOB 10-12K, 160 rpm, Tq on 14K, off 9K, PU 114K, SO 75K, ROT 94K, FO 58%, ECD=11.1 Max gas=114 units. SPR's @9817'MD TVD=4836' MW=9.8+ppg #1 30 spm=270 psi 40 spm=320 psi #2 30 spm=280 psi 40 spm=370 psi 18:00 00:00 6.00 10,096 10,466 INTRM1 DRILL DDRL P DDrill f/10096'-t/10466'MD,5031' TVD,ADT=4.17,Total bit hrs=59.94, Total Jar hrs=59.94,655 gpm,2800 psi,WOB 10-12K, 160 rpm,Tq on 12K, off 9K, PU 160K, SO 105K, ROT 129K, FO 59%, ECD=11.22 Max gas=114 units. Increase in string weights due to weight indicator adjustment. 11/06/2014 Drill intermediate hole section f/10466'MD t111867'MD. Change swab and liner on#1 mud pump. Drill intermediate hole section f/11867'MD t/11961'MD. Page 17 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 10,466 10,849 INTRM1 DRILL DDRL P DDrill f/10466'-t/10849'MD, 5150' TVD, ADT=4.58, Total bit hrs=64.52, Total Jar hrs=64.52,660 gpm, 2900 psi,WOB 5-15K, 160 rpm, Tq on 13K, off 10K, PU 160K, SO 105K, ROT 130K, FO 59%, ECD=11.15 Max gas=157 units. Obtained SPR's @ 10582' TVD=5061, MW=9.8 ppg, 02:00 Hours MP#1: 30 spm=320 psi, 40 spm= 400 psi MP#2: 30 spm=320 psi,40 spm= 410 psi 06:00 12:00 6.00 10,849 11,220 INTRM1 DRILL DDRL P DDrill f/10849'-t/11220'MD, 5291' TVD,ADT=4.42,Total bit hrs=68.94, Total Jar hrs=68.94, 680 gpm, 3100 psi,WOB 5-15K, 160 rpm, Tq on 15K, off 11K, PU 171K, SO 106K, ROT 131K, FO 59%, ECD=11.20 Max gas=264 units. Total losses for tour=113 bbls. Obtained SPR's @ 11212' TVD=5261, MW=9.8 ppg, 11:30 Hours MP#1: 30 spm=300 psi,40 spm= 400psi MP#2: 30 spm=300 psi,40 spm= 400 psi 12:00 18:00 6.00 11,220 11,631 INTRM1 DRILL DDRL P DDrill f/11220'-t/11631'MD, 5390' TVD,ADT=4.40, Total bit hrs=73.34, Total Jar hrs=73.34, 699 gpm, 3300 psi,WOB 11-15K, 160 rpm, Tq on 16K, off 11K, PU 169K, SO 109K, ROT 133K, FO 60%, ECD=11.23 Max gas=116 units. 18:00 21:00 3.00 11,631 11,867 INTRM1 DRILL DDRL P DDrill f/11631'-t/11867'MD, 5461' TVD, ADT=2.64, Total bit hrs=75.98, Total Jar hrs=75.98, 699 gpm, 3125 psi,WOB 10-16K, 160 rpm, Tq on 16K, off 11K, PU 175K, SO 109K, ROT 133K, FO 60%, ECD=11.21 Max gas=92 units. 21:00 22:00 1.00 11,867 11,867 INTRM1 DRILL RGRP T Change liner and swab on#1 mud pump/#3 mud end. Circulate and reciprocate pipe.415 gpm, 1300 psi, 100 rpm, 12K tq, FO 49% Page 18of41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 11,867 11,961 INTRMI DRILL DDRL P DDrill f/11867'-t/11961'MD,5487' TVD,ADT= 1.04, Total bit hrs=77.02, Total Jar hrs=77.02,663 gpm, 3000 psi,WOB 10-15K, 160 rpm,Tq on 15.5K, off 11K, PU 178K, SO 108K, ROT 135K, FO 59%, ECD=11.25 Max gas=103 units Total losses for tour=198 bbls. Obtained SPR's @ 11867' TVD=5460, MW=9.8 ppg,22:00 Hours MP#1: 30 spm=340 psi,40 spm= 420psi MP#2: 30 spm=340 psi,40 spm= 440 psi. 11/07/2014 Drill intermediate hole section to 12238'MD. CBU x3. TOH on elevators. CBU @ 4003'MD.Install RCD bearing assy. @3952'MD.Tune MPD choke manifold. Perform MPD training w/crew. 00:00 03:30 3.50 11,961 12,238 INTRM1 DRILL DDRL P DDrill f/11961'-t/12238'MD, 5571' TVD,ADT=3.17, Total bit hrs=80.19, Total Jar hrs=80.19,700 gpm, 3276 psi,WOB 8-12K, 160 rpm,Tq on 16K, off 11K, PU 180K, SO 107K, ROT 135K, FO 59%, ECD=11.18 Max gas=239 units 03:30 06:30 3.00 12,238 11,960 INTRM1 DRILL CIRC P Circulate and condition mud for short trip.700 gpm, 160 rpm, 3275 psi. Tq=11 K. Stand back a stand every bottoms up. Obtained SPR's @ 12238' TVD=5571, MW=9.8+ppg, 03:45 Hours MP#1: 30 spm=260 psi,40 spm= 400psi MP#2: 30 spm=255 psi,40 spm= 400 psi. 06:30 07:45 1.25 11,960 11,960 INTRM1 DRILL OWFF P Blow down top drive. Monitor well. Static. 07:45 15:45 8.00 11,960 4,003 INTRM1 DRILL WPRT P POOH on elevators. f/11960' MD t/4003'MD. PU 140K SO 97K. Cal. disp=64.15 bbls.Act disp=73 15:45 16:00 0.25 4,003 4,003 INTRM1 DRILL OWFF P Monitor well. Static. 16:00 16:30 0.50 4,003 4,003 INTRM1 DRILL CIRC P CBU @ 530 gpm., 1250 psi,60 rpm, FO=55% 16:30 20:00 3.50 4,003 3,952 INTRMI DRILL RURD P Rack back one stand DP. Blow down top drive.Connect MPD return lines, relocate jet line and bleeder line. Stab spare RCD bearing assy. on stand and rack back in derrick. Stab working bearing assy. Pull trip nipple. Install bearing assy. into RCD. Page 19 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 3,952 3,952 INTRM1 DRILL OTHR P Walk through MPD flow chart w/ Safe Kick Reps.Tune MPD choke manifold w/flow rates of 100,475 and 700 gpm. Train crew on MPD operation and practices. Function test BOPE. 11/08/2014 Con't to train crews on MPD operations.TIH.to 8200'MD.CBU. Cont TIH to btm.. Circ and Gond mud for drilling HRZ. Drill intermediate hole section using MPD f/12238'MD t/12778' MD 00:00 01:45 1.75 3,952 3,997 INTRM1 DRILL OTHR P Walk through MPD flow chart w/ Safe Kick Reps. Train crew on MPD operation and practices. 01:45 06:00 4.25 3,997 8,200 INTRM1 DRILL WPRT P Blow down top drive.TIH f/3997'MD t/8200'MD @ 2000'/hr. Fill pipe every 20 stands 06:00 08:00 2.00 8,200 8,200 INTRM1 DRILL CIRC P CBU. Stage pumps from 3 bpm,400 psi to 7 bpm 2950 psi.60 rpm. Tq=9-10K. FCP=2750 psi. 08:00 11:15 3.25 8,200 12,148 INTRM1 DRILL WPRT P TIH f/8200'MD t/12148'MD @ 2000 fph. Fill pipe every 20 stds. Cal. disp=66 bbls Act disp=58 bbls. 11:15 11:45 0.50 12,148 12,238 INTRM1 DRILL REAM P Break circ. @ 3 bpm.Wash and ream f/12148' MD t/12238'MD. 3 bpm, 500 psi,40 rpm 15K tq, PU 173 K, SO 87K, Rot 127K 11:45 13:00 1.25 12,238 12,238 INTRM1 DRILL CIRC P Circ @ 12238"MD.650 gpm, 3100 psi,90 rpm, 13K tq, FO 84% 13:00 15:15 2.25 12,238 12,238 INTRM1 DRILL DISP P Displace well to 9.6 ppg LSND treated w/HRZ stability additives. 15:15 16:00 0.75 12,238 12,238 INTRM1 DRILL CIRC P Obtained SPR's using MPD procedure @ 12238'TVD=5571, MW=9.6 ppg, 15:30 hrs MP#1: 30 spm=296 psi,40 spm= 350psi MP#2: 30 spm=312 psi,40 spm= 377 psi. 16:00 18:00 2.00 12,238 12,372 INTRM1 DRILL DDRL P DDrill w/MPD f/12238'-t/12372'MD, 5610'TVD,ADT= 1.48,Total bit hrs=81.67,Total Jar hrs=81.67, 647 gpm, 2675psi,WOB 7-9K, 160 rpm, Tq on 20K, off 14K, PU 187K, SO 101K, ROT 130K, FO 62%, ECD=10.69 Max gas=209 units. Hold 10.8 ppg EMW on connections. 18:00 00:00 6.00 12,372 12,778 INTRM1 DRILL DDRL P DDrill w/MPD f/12372'-t/12778'MD, 5721'TVD,ADT=4.86,Total bit hrs=86.53,Total Jar hrs=86.53, 650 gpm,2650psi,WOB 7-12K, 160 rpm, Tq on 18-20K, off 15K, PU 187K, SO 101K, ROT 130K, FO 65%, ECD=10.80 Max gas=567 units. Hold 10.8 ppg EMW on connections. 11/09/2014 Drill intermediate hole section using MPD f/12778 t/14276'MD Page 20 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 12,778 13,072 INTRM1 DRILL DDRL P DDrill w/MPD f/12778'-t/13072'MD, 5792'TVD,ADT=4.63, Total bit hrs=91.16, Total Jar hrs=91.16, 647 gpm, 2700psi,WOB 10-15K, 160 rpm, Tq on 17-18K, ROT 140K, FO 65%, ECD=10.74 Max gas=915 units. Hold 11.0 ppg EMW on connections. Obtained SPR's using MPD procedure© 12885 TVD=5748, MW=9.6+ppg, 01:35 hrs MP#1: 30 spm=400 psi,40 spm= 440 psi MP#2: 30 spm=336 psi, 40 spm= 480 psi. 06:00 12:00 6.00 13,072 13,442 INTRM1 DRILL DDRL P DDrill w/MPD f/13072'-t113442' MD, 5880'TVD,ADT=4.85, Total bit hrs=96.01, Total Jar hrs=96.01, 675 gpm, 2990 psi,WOB 10-15K, 160 rpm, Tq on 16-18K, , ROT 140K, FO 65%, ECD=10.92 Max gas=500 units. Hold 11.0 ppg EMW on connections. 12:00 18:00 6.00 13,442 13,871 INTRM1 DRILL DDRL P DDrill w/MPD f/13442'-t113871' MD, 5985'TVD, ADT=4.66, Total bit hrs=100.67,Total Jar hrs=100.67, 673 gpm, 3050 psi,WOB 10-15K, 160 rpm, Tq on 18-21 K, Tq off 15K, ROT 140, FO 64%, ECD=10.99 Max gas=190 units. Hold 11.0 ppg EMW on connections. Obtained SPR's using MPD procedure @ 13533'TVD=5903, MW=9.7 ppg, 13:10 hrs MP#1: 30 spm=358 psi,40 spm= 448 psi MP#2: 30 spm=357 psi,40 spm= 443 psi. 18:00 00:00 6.00 13,871 14,276 INTRM1 DRILL DDRL P DDrill w/MPD f/13871'-t114276' MD, 6082'TVD,ADT=4.67, Total bit hrs=105.34,Total Jar hrs=105.34, 675 gpm, 3150 psi,WOB 10-15K, 160 rpm, Tq on 19K, Tq off 17K, ROT 140, FO 65%, ECD=11.02 Max gas=387 units. Hold 11.0 ppg EMW on connections. 11/10/2014 TD intermediate hole section @ 14617'MD. CBU x3.Weight up mud to 10.9 ppg as per MPD schedule. Strip out of hole to 14021' MD Page 21 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 14,276 14,617 INTRM1 DRILL DDRL P DDrill w/MPD f/14276' t/14617'MD, 6150'TVD,ADT=3.65,Total bit hrs=105.34,Total Jar hrs=108.99, 675 gpm, 3125 psi,WOB 5-10K, 160 rpm, Tq on 20K,Tq off 16K, ROT 139K, FO 65%, ECD=10.96 Max gas=444 units. Hold 11.0 ppg EMW on connections. Obtain SPR's @ 14617'MD TVD=6125, MW= 10.7+ ppg,4:45 hours. MP#1: 30 spm= 580 psi,40 spm=630 psi. MP#2: 30 spm=560 psi,40 spm=610 psi. 05:00 08:45 3.75 14,617 14,460 INTRM1 CASING CIRC P iCBU X 3 @ 675 gpm=3000 psi, rotate @ 160 rpm's w/16K Tq. ROT 140K. Standing one stand back every BU to 14554'MD.Adjusting MPD choke to maintain 11.00 ppg EWM bottom hole pressure. 08:45 10:00 1.25 14,460 14,460 INTRM1 CASING CIRC P ,While continuing to CBU pumping at 1675gpm, prep pits for increasing MW to 10.9 ppg. Dump mud to rockwasher to make room for spike fluid. 10:00 12:00 2.00 14,460 14,460 INTRM1 CASING CIRC P Circ and weight up mud system f/9.8 ppg t/10.9 ppg using 4 stage circ. schedule.Weight up f/9.8 ppg t/10 ppg maintaining 11.0 ppg ECD w/ MPD pump schedule.600 gpm,2580 psi, FO=59%, 40 rpm,Tq=14-15K, PU 144K, 12:00 13:30 1.50 14,460 14,460 INTRM1 CASING CIRC P Weight up f/10.0 ppg t/10.3 ppg maintaining 11.0 ppg ECD w/MPD pump schedule. 550 gpm,2225 psi, FO=54%, 40 rpm,Tq=14-15K, PU 144K, 13:30 13:45 0.25 14,460 14,460 INTRM1 CASING CIRC P Prep pits for third stage of weight up.Reduce pump rate to 500 gpm. due to ECD @11.17 ppg. _ECD=11.11 ppg @ 500 gpm. 13:45 15:30 1.75 14,460 14,460 INTRM1 CASING CIRC P Weight up f/10.3 ppg t/10.6 ppg maintaining 11.11 ppg ECD w/MPD pump schedule.450 gpm,2000 psi, FO=53%, 40 rpm,Tq=15K, PU 144K, 15:30 15:45 0.25 14,460 14,460 INTRM1 CASING CIRC P Weight up suction pit to 10.9 ppg and prep pits for final stage of weight up. Reduce pump rate to 425 gpm _due to 11.4 ppg ECD. 15:45 19:00 3.25 14,460 14,460 INTRM1 CASING CIRC P Weight up f/10.6 ppg t/10.9 ppg maintaining 11.6 ppg ECD w/MPD pump schedule. Starting pump rate 425 gpm, 1600 psi, F0=48%, 20 rpm, Tq=15K, Ending pump rate 200 gpm, 550 psi,20 rpm, FO=20%, Tq=16K., 19:00 19:15 0.25 14,460 14,460 INTRM1 CASING SFTY P PJSM for changeing out RCD bearing assy. Page 22 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 20:15 1.00 14,460 14,460 INTRMI CASING SEQP P Change out RCD bearing assy. as per Safe Kick reps. 20:15 20:45 0.50 14,460 14,460 INTRM1 CASING SFTY P Perform AAR on changing out RCD bearing assy.. 20:45 21:15 0.50 14,460 14,617 INTRM1 CASING REAM P PJSM.Wash and ream to TD. 14460' MD to 14617' MD. No fill. 125 gpm, 400 psi, 30 rpm, 15K tq, FO 20% 21:15 22:15 1.00 14,617 14,617 INTRM1 CASING OWFF P Line up and perform dynamic/static flow check. Static. 22:15 22:30 0.25 14,617 14,617 INTRMI CASING SEQP P Obtain SPR's. Line up to strip out of hole. Enter pressure values into Safe Kick system for stripping out of hole. 22:30 00:00 1.50 14,617 14,021 INTRM1 CASING TRIP P Strip out of hole as per trip schedule f/14617'MD t/14093'MD. 50K over pull @14075'MD.Attempt to work through tight spot. RIH to 14096'MD. M/U top drive. Pump out of hole f/14096'MD t/14021'MD. PU 185K, SO 95K. 200 gpm,600 psi. Calc. Disp=3.75 bbls.Act Disp=24.85 bbls. Lost 21 bbls adjusting choke settings. RIH to 14093'MD. Strip out of hole to 14021'MD. 11/11/2014 Strip out of hole w/MPD f/14093'-3907'MD. Slip&cut drill line. Continue POOH w/MPD to HWDP. Pull bearing assembly at HWDP&install trip nipple. Lay down BHA. Change upper rams to 7 5/8". Rig up to test BOPE. 00:00 03:45 3.75 14,021 11,867 INTRM1,CASING TRIP P POOH f/14093'to 11867'. Observed 50K-70K overpull @ 14093', 13837' and 13506'.Worked through tight spots,went back down and pulled back through them, overpull was gone. P/U=205K, S/0=95K 03:45 04:15 0.50 11,867 11,867 INTRM1 CASING CIRC P Pump 13.0 ppg pill @ 3 bpm,400 psi, FO 20%,&blow down TD. 04:15 10:30 6.25 11,867 3,907 INTRM1 CASING TRIP P POOH f/11867'-3907'MD, 11867'-7700 @ 2000 fph,7700'-3907' @ 3800 fph, PU 100K, SO 80K, calculated displacement 82.5, actual 177.7 bbls. 10:30 10:45 0.25 3,907 3,907 INTRM1 CASING RURD P Clear&clean rig floor. Kick w/Tripping Drill CRT=90 sec. 10:45 12:30 1.75 3,907 3,907 INTRM1 CASING SLPC P Slip&cut 74'of drill line&service rig. 12:30 14:00 1.50 3,907 1,863 INTRMI CASING TRIP P POOH f/3909'-1863'MD, PU 95k, SO 80K, calculated displacement 17, actual 30.5 bbls. 14:00 14:15 0.25 1,863 1,863 INTRM1 CASING OWFF P Monitor well,static. 14:15 16:00 1.75 1,863 1,863 INTRM1 CASING SEQP P Blow down MPD manifold&lines, pull RCD,&install trip nipple. Line up mud bucket returns, hole fill, & flow lines. Remove MPD lines& plug. 16:00 17:00 1.00 1,863 732 INTRMI CASING TRIP P POOH 1863'-732'MD, laying down ghost reamer. 17:00 17:15 0.25 732 732 INTRM1 CASING OWFF P Monitor well,static. Page 23 of 41 r- Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 17:30 0.25 732 548 INTRM1 CASING TRIP P POOH 732'-548'MD,standing back HWDP. 17:30 17:45 0.25 548 548 INTRM1 CASING CIRC P Circulate @ 500 gpm,850 psi, FO 50%to downlink MWD tools as per SLB. 17:45 18:00 0.25 548 276 INTRM1 CASING TRIP P POOH 548'-276', standing back remaining HWDP. 18:00 20:15 2.25 276 0 INTRM1 CASING PULD P Lay down BHA as per SLB. 20:15 20:45 0.50 0 0 INTRM1 CASING RURD P Clear&clean rig floor. 20:45 21:30 0.75 0 0 INTRMI CASING WWWH P Flush stack with stack washer. 21:30 22:45 1.25 0 0 INTRMI CASING BOPE P Change out upper rams to 7 5/8" solid body rams. 22:45 00:00 1.25 0 0 INTRM1 WHDBO RURD P Pull wear ring, set test plug, &rig up to test. 11/12/2014 Test BOPE,witnessed by AOGCC Rep Lou Grimaldi. Rig up casing running equipment. Run 7 5/8"casing as per detail to 2182'MD. CBU @ 1329'&2182' MD. 00:00 00:30 0.50 0 0 INTRM1 WHDBO RURD P PJSM, Cont to rig up to test BOPE. 00:30 06:00 5.50 0 0 INTRM1 WHDBO BOPE P Test BOPE w/7-5/8"test joint to 250/3500 psi for 5 minutes each. Test #1:top pipe rams, CV 1,12,13,14 and manual kill.Test#2: upper IBOP, HCR kill, CV 9 and 11. Test#3: Lower IBOP, CV 5,8 and 10. Test#4: Dart valve, CV 4,6 and 7. Test#5:floor valve and CV 6. Test #6: HCR choke and 4"kill line Demco. Test#7: Manual choke and HCR kill. Test#8:Annular 250/2500 psi.Test#9:4"test joint. lower pipe rams. Test#10: Blind rams(failed) Test annular w/4"test joint to 250/2500 psi.Accumulator test: System pressure=3000 psi, pressure after closing= 1800 psi,200 psi attained after 47 seconds,full pressure attained after 201 seconds. Five bottle nitrogen avg=2000 psi. BOPE test witnessed by AOGCC Rep Lou Grimaldi. 06:00 07:00 1.00 0 0 INTRM1 WHDBO BOPE T Discuss 2nd barrier options for opening blind ram doors with town staff. decision made to set test plug w/4"test joint, close lower rams and test to 250/3500 psi(tested barrier) Stab floor valve(tested barrier) SIMOPS, blow down choke, choke manifold, kill line and top drive. 07:00 08:15 1.25 0 0 INTRMI WHDBO BOPE T PJSM, rig up,set test plug w/4"test joint. Test lower 3-1/2"X 6"rams to 250/3500 psi;for 2nd barrier. 08:15 10:30 2.25 0 0 INTRM1 WHDBO BOPE T PJSM,Open blind ram doors, OWFF through annulus. 10:30 11:15 0.75 0 0 INTRM1 WHDBO BOPE T Change out rubber elements on blind rams. Page 24 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 11:45 0.50 0 0 INTRM1 WHDBO BOPE T Install blind rams. 11:45 12:45 1.00 0 0 INTRM1 WHDBO BOPE T Rig up to test blind rams and choke line. 12:45 13:15 0.50 0 0 INTRM1 WHDBO BOPE T Test blind rams&choke line to 250/3500 psi for 5 min each. 13:15 13:30 0.25 0 0 INTRM1 WHDBO RURD P Rig down test equipment&blow down all lines. 13:30 14:00 0.50 0 0 INTRM1 CASING RURD P Remove split bushings&install master bushings. Perform dummy run with hanger&landing joint. 14:00 15:30 1.50 0 0 INTRM1 CASING RURD P Rig up CRT&handling equipment to run 7 5/8"casing. 15:30 20:30 5.00 0 1,329 INTRM1 CASING PUTB P PJSM; run 7.625", 29.7#, L-80, Hyd 563 casing to 1329'MD. Calculated displacement 13.68, actual .7 bbls, SO 60K. 20:30 21:30 1.00 1,329 1,329 INTRM1 CASING CIRC P CBU 2X,stage up pumps f/1-3.5 bpm, 90-120 psi, 1.4 bbls loss while circulating. 21:30 23:30 2.00 1,329 2,182 INTRM1 CASING PUTB P Run 7.625", 29.7#, L-80, Hyd 563 casing to 1329'-2182'MD. Calculated displacement 22.8, actual 1.75 bbls, PU 78K, SO 75K. 23:30 00:00 0.50 2,182 2,182 INTRM1 CASING CIRC P CBU staging up pumps 1-2.5 bpm, 90-110 psi. 3.85 bbls loss. 11/13/2014 RIH w/7 5/8"casing f/2182'-3993'MD.C&C mud from 10.9- 10.5 ppg. RIH 3993'-5998'MD.Wash f/ 5998'-6211', conditioning mud to reduce losses. Continue RIH f/6211'-7066'MD. 00:00 04:00 4.00 2,182 3,993 INTRM1 CASING PUTB P PJSM, Cont RIH w/7-5/8"Hyd 563 casing f/2182'to 3993'. Slow running speed down to 1000 fph due to losing fluid. Filling pipe every 10 joints. Actual displacement=2.45 bbls. Calculated displacement= 19.6 bbls. S/O=90K. 04:00 09:45 5.75 3,993 3,993 INTRM1 CASING CIRC P Break circulate @ 3993'MD, 1-3.5 bpm, 110-220 psi,3-30%FO. Reduce MW f/10.9 to 10.5 ppg. SO 90K, Total losses 103.9 bbls. Fire Drill CRT= 120 sec @ 07:00 hrs. 09:45 12:00 2.25 3,993 4,763 INTRM1 CASING PUTB P PJSM, continue to RIH f/3993'- 4763'MD, 500-600 fph,fill every 10 joints, SO 93K, calculated displacement 7.76,actual 23.8 bbls. Wellbore breathing, 16.04 bbls gained. 12:00 16:15 4.25 4,763 5,998 INTRM1 CASING PUTB P PJSM,continue to RIH f/4763'- 5998'MD, 500-600 fph,fill every 10 joints, SO 93K.calculated displacement 63.84, actual 5.95 bbls. 16:15 20:45 4.50 5,998 6,211 INTRM1 CASING WASH P Wash f/5998'-6211' MD, stage up pumps 1-2 bpm, 210-200 psi, 50 fph, FO 1-23%.Total losses 107.32 bbls. Table Top Fire Drill. Page 25 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:00 0.25 6,211 6,211 INTRM1 CASING OWFF P Monitor well, observe wellbore breathing. Perform exhale test to determine flow decreasing. 23 bbls bled back. 21:00 00:00 3.00 6,211 7,066 INTRM1 CASING PUTB P Continue RIH f/6211'-7066'MD, SO 98K, Total calculated displacement for casing run 75.21,total actual -38.72 bbls. Total losses 185 bbls for 24 hrs. 11/14/2014 Continued RIH w/7 5/8"intermediate casing f/7066'-13342' MD,271bbls. losses. 00:00 14:45 14.75 7,066 11,538 INTRM1 CASING PUTB P PJSM, continue RIH w/7 5/8",29.7 lbs, L-80, Hyd 563 casing f/ 7066-11538'MD, 500-400 fph, SO 103K. 14:45 15:30 0.75 11,538 11,538 INTRM1 CASING PUTB T Change out bad box on joint 268 (43.16'),with joint 345(42.23'). 15:30 00:00 8.50 11,538 13,342 INTRM1 CASING PUTB P Continue RIH f/11538'-13342'MD, 300 fph, PU 250K, SO94K, calculated displacement 27.6, actual -132 bbls. 11/15/2014 RIH w/7 5/8"casing intermediate casing to TD,working through tight spots. MU hanger, landing joint& cement head. Cement as per SLB, bump plug&psi to 1350 psi for 5 min. CIP& 19:13 hrs. Monitor well. Set 7 5/8"pickoff &test to 5000 psi for 5 min. Rig up to lay down 5"DP. 00:00 02:00 2.00 13,342 13,812 INTRMI CASING PUTB P PJSM, continue to RIH w/7 5/8", 29.7#, L-80, Hyd 563 casing from 13342'-13812' MD.Work through tight spots 13620'-13650'MD, 13730'-13740' MD, PU 255K, SO 95K. 02:00 02:45 0.75 13,812 13,812 INTRM1 CASING CIRC P Stage up pump.5-1 bpm,275-500 psi, FO 0%, PU 255K, SO 95K. 02:45 05:30 2.75 13,812 13,898 INTRM1 CASING PUTB P RIH f/13812'-13898'MD,working through tight hole. 05:30 13:30 8.00 13,898 14,579 INTRM1 CASING PUTB P RIH f/13898'-14579' MD,working through tight hole, 1.5 bpm, 500 psi, FO 0%, PU 255K, SO 75K.While washing down, attempting to establish circulation, pumped away 716 bbls. 13:30 14:00 0.50 14,579 14,607 INTRM1 CASING HOSO P Make up hanger&landing joint. Wash down @ 1.5 bpm, 525 psi. 14:00 14:30 0.50 14,607 14,607 INTRMI CEMEN-RURD P PJSM, rig down Volant CRT&rig up cement head. 14:30 15:15 0.75 14,607 14,607 INTRM1 CEMEN"CIRC P Stage up pump from 1.5-4 bpm, 525-650 psi, PU 255K, SO 98K. Attempt to gain circulation, pumping away an additional 160 bbls for a total of 876 bbls trying to establish circulation. 15:15 15:30 0.25 14,607 14,607 INTRM1 CEMEN-SFTY P PJSM,w/SLB for cement job. Page 26 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:45 1.25 14,607 14,607 INTRM1 CEMEN'CMNT P Line up to SLB, pump 5 bbls H2O& PT lines to 4000 psi. Pump 40 bbls CW100,40 bbls 11.5 ppg Mudpush II. Drop bottom plug, pump 107 bbls of 15.8 ppg cement. Drop top plug& pump 10 bbl H2O. Swap to rig pumps for displacement. No returns observed. 16:45 19:30 2.75 14,607 14,607 INTRM1 CEMEN CMNT P Displace cement with 656 bbls 10.5 ppg mud,4.5 bpm, ICP 200 psi, FCP 850 psi. Bump plug&psi up 500 psi to 1350 psi, holding for 5 min. Bled off,floats tested good. CIP 19:13 hrs. Observed bottom plug rupture at 5458 strokes with 350 psi. Observed pump psi increase as cement was coming around the shoe from 350 to 900 psi. 19:30 20:00 0.50 14,607 14,607 INTRM1 CEMEN-OWFF P Monitor well, observe slight flow decreasing. 20:00 21:00 1.00 14,607 14,607 INTRM1 CEMEN-RURD P Rig down&lay down cement head& landing joint. 21:00 22:15 1.25 14,607 14,607 INTRM1 CEMEN WWSP P Set 7 5/8"pack off as per CIW Rep. 22:15 22:45 0.50 14,607 0 INTRM1 CEMEN'PRTS P Test 7 5/8"pack off, 5000 psi for 10 min, Drilling Supervisor witnessed. 22:45 00:00 1.25 0 0 INTRM1 CEMEN'RURD P Clear&clean rig floor, rig up 5"DP handling equipment, &finish loading 4"DP in shed. 11/16/2014 Lay down 5"DP from derrick. Flush&freeze protect 10 3/4"X 7 5/8"annulus. Rig up and RIH w/a-line& tractor to RCBL in 7 5/8"casing to 14500'MD. 00:00 04:00 4.00 0 0 INTRM1 CEMEN'PULD P Lay down 5"DP from derrick. 04:00 06:00 2.00 0 0 INTRM1 CEMEN RURD P Change out saver sub on TD to 4" XT39. Spill Drill CRT= 130 sec. @ 06:00 hrs. 06:00 08:00 2.00 0 0 INTRM1 CEMEN"PULD P Lay down 5" DP from derrick. 08:00 11:00 3.00 0 0 INTRM1 CEMEN'FRZP P PT lines to 2500 psi, good. Flush 10.75"X 7.625"annulus,with 175 bbls.fresh H2O, ICP 300 psi, FCP 800 psi. Pump 91 bbls Isotherm diesel, ICP 700 psi, FCP 1200 psi. Initial shutin pressure 2 psi, final shutin pressure 10 psi. Sim-ops, lay down 5"DP from derrick. 11:00 13:45 2.75 0 0 INTRM1 CEMEN'PULD P Lay down 5"DP from derrick. 13:45 14:30 0.75 0 0 INTRM1 CEMEN'RURD P Clear&clean rig floor. 14:30 15:15 0.75 0 0 INTRM1 CEMEN-RURD P Change out handling equipment to 4"XT39. 15:15 15:45 0.50 0 0 INTRM1 CEMEN-RURD P Spot HES e-line unit at bottom of beaver slide. 15:45 17:00 1.25 0 0 INTRM1 CEMEN-QEVL P Rig up a-line tools in mobile unit. Spill Drill CRT=105 sec. @ 18:30 hrs. Page 27 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:15 1.25 0 0 INTRM1ICEMEN-QEVL P Mobilize e-line tools to rig floor, rig up sheaves, test tools @ rig floor. 18:15 19:00 0.75 0 0 INTRM1 CEMEN-QEVLP Reconfigure signal between GyroData tractor&HES e-line tools. 19:00 19:15 0.25 0 0 INTRM1CEMEN-QEVL P Retest e-line tools at rig floor, good. 19:15 00:00 4.75 0 14,500 INTRM1 CEMEN-QEVL P RIH with eline&tractor to RCBL to 14500' MD. OA 580 psi @ 24:00 hrs. 11/17/2014 Finish RCBL& rig down e-line. 7 5/8"casing TOC @ 11680' MD. PU 69 stands of 4"DP&rack back in derrick. C/O upper rams to 3.5"X6"VBR. Rig up&test BOPE. Make up BHA 4 00:00 02:45 2.75 14,500 0 INTRM1 CEMEN-QEVL P PJSM, POOH w/RCBL on HES E-line&tractor. TOC @- 11,680' MD. SIMOPS, strap and tally 4"drill pipe. 02:45 03:30 0.75 0 0 INTRM1 CEMEN-QEVL P PJSM, Rig down HES E-line as per Halliburton rep. 03:30 04:00 0.50 0 0 INTRM1 CEMEN RURD P Change out bell guide on TD f/5"to 4". 04:00 10:45 6.75 0 0 INTRM1 CEMEN"PULD P Pick up&rack back 69 stands of 4" DP in derrick. Fire Drill CRT= 180 sec @ 06:00 hrs 10:45 11:15 0.50 0 0 INTRM1 CEMEN RURD P Lay down mouse hole&clear rig floor. 11:15 13:15 2.00 0 0 INTRM1 CEMEN BOPE P Change out upper rams from 7 5/8" solid body to 3 1/2"X 6"VBR's. 13:15 14:00 0.75 0 0 INTRM1 WHDBO RURD P Rig up to test BOPE. 14:00 21:00 7.00 0 0 INTRM1 WHDBO BOPE P PJSM, test BOPE w/4"test joint to 250/3500 psi for 5 min each. Test 3.5"&4.5"test joints with annular, upper&lower VBR's.#1 Top VBR's, CV 1,12,13, 14, &manual kill line valve;#2 upper IBOP, HCR kill, CV's 9,11;#3 lower IBOP, CV's 5,8& 10; #4 dart valve, CV's 4,6&7;#5 FSV &CV 2;#6 HCR choke, kill line 4" Demco;#7 Manual choke&HCR kill;#8 annular;#9 lower VBR's;#10 blind rams&CV 3;#11 Hydraulic& manual choke draw down. Accumulator test initial system 3000 psi; after closure 1850 psi; 200 psi attained in 42 seconds; full psi attained in 185 sec. 5 nitrogen bottles averaged 2100 psi. Annular test w/4.5"joint fail, psi bled off&retested good. Annular test w/3.5"joint fail, leak at pump in sub tightened&retest good. Accumulator test fail for recovery time, retest good. Witness waived by AOGCC Jeff Jones 11-16-14 @ 17:00 hrs. via email. 21:00 21:45 0.75 0 0 INTRM1 WHDBO RURD P Rig down test equipment&blow down lines. Page 28 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:30 0.75 0 0 INTRM1 CEMEN'RURD P Set wear bushing,split mater bushings, &mobilize SLB tools to rig floor. 22:30 00:00 1.50 0 123 INTRM1 CEMEN'PULD P Pick up BHA 4 as per SLB. OA 15 psi. 11/18/2014 M/U BHA 4 as per SLB. Shallow hole test tools. RIH picking up 4" DP t/ 14400'MD. CBU,treating mud as needed to drill out float/shoe. Pressure test 7-5/8"casing to 3500 psi for 30 minutes. Slip&cut drill line. Wash down tagging cement plugs @ 14514'MD and drill out shoe track to 14600'MD. 00:00 02:00 2.00 123 408 INTRM1 CEMEN'PULD P Continue picking up BHA 4 as per SLB DD. 02:00 03:30 1.50 408 2,301 INTRM1 CEMEN-PULD P PJSM, single in the w/4"DP from 408'-2301' MD, filling DP every 20 stands. 03:30 03:45 0.25 2,301 2,301 INTRM1 CEMEN'DHEQ P Shallow pulse test MWD,210 gpm, 1000 psi, FO 43%.Test good. 03:45 13:15 9.50 2,301 14,414 INTRM1 CEMEN'PULD P Continue to single in the hole from 2301'-14414'MD, PU 150K, SO 95K. Kick w/Trippping Drill CRT=89 sec @ 09:00 hrs. 13:15 13:30 0.25 14,414 14,506 INTRMI CEMEN COCF P Wash&ream from 14414'-14506' MD, 250 gpm,2350 psi, 90rpm,Tq 11K, PU 150K, SO 95K, ROT 110K. 13:30 16:45 3.25 14,506 14,506 INTRMI CEMEN CIRC P Circulate&condition mud for casing psi test,230 gpm, 2050 psi. 16:45 17:15 0.50 14,506 14,506 INTRM1 CEMEN-RURD P Blow down TD&rig up to test casing. 17:15 18:00 0.75 14,506 14,506 INTRM1 CEMEN'PRTS P Test 7 5/8"intermediate casing to 3500 psi, charted, for 30 min. Rig down test equipment. 18:00 19:30 1.50 14,506 14,506 INTRM1 CEMEN"SLPC P PJSM, slip&cut 65'of drill line. 19:30 21:00 1.50 14,506 14,506 INTRM1 CEMEN SEQP P Rack back one stand&pick up 3 singles of 4" DP. Stab back up RCD on spare stand&rack back. RIH with original stand. 21:00 00:00 3.00 14,506 14,600 INTRM1 CEMEN-DRLG P Wash down and tag up on cement plugs @ 14514' MD. Drill out float& shoe track f/14514'-14600'MD, 6148'TVD, ADT 2.83, Bit 2.83,Jars 2.83, PU 155K, SO 95K, ROT 110K, Tq on 10K,off 9K, ECD 11.85, FO 37%,WOB 6-7K, rpm 60K, gpm 210,2050 psi. SPR @ 14500'MD,6134'TVD, MW 10.5 ppg,21:00 hrs. #1 @ 20=600 psi; @ 30=845 psi #2 @ 20=585 psi; @ 30=850 psi 11/19/2014 Continue drilling shoe track&20'of new hole. CBU&rig up for FIT. Perform FIT/LOT to 16.00 ppg. Rig up MPD&test all lines. Displace well to 10.0 ppg FloPro NT. Monitor well. Drill ahead as per plan. 00:00 01:15 1.25 14,600 14,637 INTRM1 CEMEN-DRLG P PJSM,drill out shoe&20'new hole, f/14600'-14637'MD,6148 TVD,ADT .35, bit 4.15,jars 4.15, PU 155K, SO 95K, ROT 110K, TQ on 15K, off 13K, ECD 11.85, FO 37%,WOB 10K,210 gpm, 2050 psi. Page 29 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:30 0.25 14,637 14,601 INTRM1 CEMEN-REAM P Ream through shoe track 3X, 14637'-14601'MD. 01:30 03:00 1.50 14,601 114,601 INTRM1 CEMEN"CIRC P CBU,230 gpm,2410 psi, FO 36%, 40 rpm,TQ 13K, PU 155K, SO 105K, ROT 130K 03:00 03:30 0.50 14,601 14,601 INTRM1 CEMEN'RURD P Rig up test equipment for FIT. 03:30 03:45 0.25 14,601 14,601 INTRM1 CEMEN-FIT P Pressure up, .5bpm, 1760 psi,shut in with 1740 psi, observing for 10 min. 1605 psi final pressure. Bleed off. EMW with 10.5 ppg mud at 14637' MD,6151'TVD, 16.0 ppg. 03:45 04:00 0.25 14,601 14,601 PROD1 DRILL RURD P Rig down&blow down test equipment&lines. 04:00 07:00 3.00 14,601 14,601 PROD1 DRILL SEQP P Remove trip nipple, install RCD, hook up lines, &function test. 07:00 09:30 2.50 14,601 14,637 PROD1 DRILL DISP P Displace to 10.0 ppg FlowPro NT mud, 240 gpm, ICP 3250 psi, FO 137%, 80 rpm,TQ 15K, FCP 2800 psi,TQ 10K, PU 155K, SO 105K, ROT 155K. SPR @ 14637'MD, 6151'TVD, MW 10.00 ppg, 09:15 hrs. #1 @ 20=760; @30=1020psi #2 @ 20=690; @30=960psi 09:30 10:00 0.50 14,637 14,637 PROD1 DRILL OWFF P Monitor well with MPD chokes shut in 0 psi. 10:00 12:00 2.00 14,637 14,764 PROD1 DRILL DDRL P Directional drill f/14637'-14764'MD, 6166'TVD,ADT 1.33, bit 1.68,jars 1.68, PU 150K, SO 87K, ROT 113K, TQ on 10-11K, off 8K, ECD 11.43, FO 36%,WOB 10-15K, 240 gpm, 2780 psi, max gas 20. 12:00 18:00 6.00 14,764 15,228 PROD1 DRILL DDRL P Directional drill f/14764'-15228'MD, 6164'TVD,ADT 3.29, bit 5.6,jars 5.6, PU 150K, SO 84K, ROT 119K, TQ on 11K, off 7K, ECD 11.52, FO 37%,WOB 12-15K,245 gpm,2800 psi, max gas 26. 18:00 20:45 2.75 15,228 15,359 PROD1 DRILL DDRL P Directional drill f/15228'-15359' MD, 6163'TVD,ADT 1.5, bit 7.1,jars 7.1, PU 148K, SO 83K, ROT 118K, TQ on 11K, off 8-9K, ECD 11.57, FO 38%,WOB 13-16K,245 gpm, 2850 psi, max gas 26. SPR @ 15264' MD, 6164 TVD, MW 10.1, 19:30 hrs #1 @ 20=600; @30=890psi #2 @ 20=600; @30=900psi 20:45 22:30 1.75 15,359 14,600 PROD1 DRILL REAM T PJSM, BROOH to shoe for phase 3 weather conditions,f/15359'-14600' MD, 244 gpm, 2700 psi, 90 rpm,TQ 8-9K, PU 150K, SO 87K, ROT 113K, calculated fill 14.02, actual 13.01 bbls. Page 30 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 14,600 14,600 PROD1 DRILL CIRC T CBU,240 gpm, 2600 psi,20 rpm, PU 121K, SO 111K, ROT 110K. Kick w/Drilling Drill,Table Top, @ 23:00 hrs. OA 10 psi. 11/20/2014 Continue to wait on weather due to Phase III conditions. Break circulation every.5-1 hr&monitor well through MPD's closed chokes. Circulate surface to surface to get even 10.1 ppg in&out. 00:00 05:45 5.75 14,600 14,600 PROD1 DRILL CIRC T Wait on weather. Break circulation every hour @ 2 bpm,600 psi, FO 15%. Monitor well with MPD chokes closed 9-32 psi. Spill Drill CRT 160 sec @ 05:00 hrs. 05:45 11:00 5.25 14,600 14,600 PROD1 DRILL CIRC T Observe choke psi gradually increase from 9-32 psi. Observe 9.9ppg MW out when breaking circulation. Circulate to get 10.1 ppg MW in&out 200-140 gpm, 1820-1090 psi, FO 31-24%. 11:00 20:00 9.00 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr @ 140 gpm, 1000 psi, FO 16%. Monitor well through MPD closed chokes 7 psi. SPR's @ 14604'MD, 6148'TVD, MW 10.1 ppg, 11:00 hrs. #1@ 20=640 @ 30=920 psi #2@ 20=640 @ 30=930 psi 20:00 22:00 2.00 14,600 14,600 PROD1 DRILL CIRC T Circulate surface to surface. 150 gpm, 1100 psi, FO 20%. Obtain even mud weights @ 10.1 in/out. 22:00 00:00 2.00 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr @ 140 gpm, 1000 psi, FO 16%. Monitor well through MPD closed chokes 7 psi. SPR's @ 14604'MD,6148'TVD, MW 10.1 ppg, 11:00 hrs. #1@ 20=640 @ 30=920 psi #2@ 20=640 @ 30=930 psi 11/21/2014 Continue to wait on weather due to Phase III conditions. Break circulation every 1/2 hr&monitor well through MPD's closed chokes. Circulate S/S&B/U to get even 10.1 ppg in&out. 00:00 10:15 10.25 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr,30bbls @ 140 gpm, 1275 psi, FO 13%. Monitor well through MPD closed chokes. 10:15 13:30 3.25 14,600 14,600 PROD1 DRILL CIRC T Circulate surface to surface @ 140 gpm, 1400 psi, FO 13%,40 rpm,Tq 8-10 K, PU 114K, SO 107K, ROT 112K, 13:30 16:30 3.00 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr,30bbls @ 140 gpm, 1100 psi, FO 13%. Monitor well through MPD closed chokes. Table Top Kick w/Tripping Drill @ 15:00 hrs. 16:30 19:00 2.50 14,600 14,600 PROD1 DRILL CIRC T CBU @ 140 gpm, 1100 psi, FO 13%, 40 rpm,Tq 8-10K, PU 114K, SO 107K, ROT 112K SPR's @ 14595'MD,6148'TVD, MW 10.1 ppg @ 19:00 hrs. #1 @ 20=630 @ 30=920 psi #2@20=640@30=910 psi Page 31 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 00:00 5.00 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr, 30bbls @ 140 gpm, 1100 psi, FO 13%. Monitor well through MPD closed chokes. 11/22/2014 Continue to wait on weather due to Phase III conditions. Break circulation every 1/2 hr&monitor well through MPD's closed chokes. Circulate B/U's to get even 10.1 ppg in&out.TIH f/14600'-15359' MD,6136'TVD& CBU. DD f/15359'-15550'MD, 6180'TVD. RCD observed leaking. Monitor well. Remove leaking RCD&begin install of spare RCD. 00:00 01:00 1.00 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr, 30bbls @ 140 gpm, 1025 psi, FO 13%. Monitor well through MPD closed chokes. 01:00 04:45 3.75 14,600 14,600 PROD1 DRILL CIRC T CBU @ 140 gpm, 1025 psi, FO 13%, 40 rpm, Tq 8-10K, PU 114K, SO 107K, ROT 112K SPR's @ 14595'MD,6148'TVD, MW 10.2 ppg @ 04:45 hrs. #1 @20=780@30= 1000 psi #2@20=780@30= 1020 psi 04:45 12:00 7.25 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr, 30bbls @ 140 gpm, 1150 psi, FO 13%. Monitor well through MPD closed chokes. 12:00 15:30 3.50 14,600 14,600 PROD1 DRILL CIRC T CBU @ 200 gpm, 1975 psi,60 rpm, Tq 7-8K, PU 115K, SO 105K, ROT 112K 15:30 16:45 1.25 14,600 14,600 PROD1 DRILL CIRC T Circulate every.5 hr, 30bbls @ 140 gpm, 1025 psi, FO 13%. Monitor well through MPD closed chokes. 16:45 17:45 1.00 14,600 15,359 PROD1 DRILL TRIP T TIH f/14600'-15359'MD, PU 117K, SO 80K 17:45 20:00 2.25 15,359 15,359 PROD1 DRILL CIRC T CBU @ 220 gpm,2450 psi, 100 rpm, Tq 10K, PU 115K, SO 105K, ROT 112K SPR's @ 15355'MD,6136'TVD, MW 10.1 ppg, 19:45 hrs. #1 @20=610; @ 30=920 psi #2 @ 20=640; @ 30=900 psi 20:00 22:00 2.00 15,359 15,550 PROD1 DRILL DDRL P Directional drill f/15359'-15550'MD, 6180'TVD,ADT 1.59, bit 8.69,jars 8.69, PU 160K, SO 80K, ROT 109K, TQ on 12-15K, off 10K, ECD 11.82, FO 38%,WOB 6-10K,240 gpm, 2775 psi. 22:00 22:15 0.25 15,550 15,550 PROD1 DRILL OWFF T RCD leaking. Monitor well, static. 22:15 00:00 1.75 15,550 15,550 PROD1 DRILL SEQP T PJSM, blow down TD, rack back stand, remove leaking RCD, make up stand with spare RCD pre-installed., &begin to seat RCD into MPD head. 11/23/2014 Finish installing spare RCD&check for leaks. Directional Drill with rotary drilling assembly in 6%"production hole from 15550'-17192'MD. 00:00 01:00 1.00 15,550 15,550 PROD1 DRILL SEQP T Continue to installing spare RCD. Line up&circulate to check MPD equipment for leaks. Page 32 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 01:00 06:00 5.00 15,550 15,973 PROD1 DRILL DDRL P Directional drill f/15550'-15973'MD, 6188'TVD,ADT 3.38, bit 12.07,jars 12.07, PU 150K, SO 83K, ROT 115K, 140 rpm,TQ on 11K, off 8K, ECD 11.93, FO 43%,WOB 10-12K, 240 gpm, 2960 psi. SPR's @ 15735'MD,6181'TVD, MW 10.1 ppg, 03:15 hrs. #1 @ 20=675; @ 30=980 psi #2 @ 20=690; @ 30=975 psi Spill Drill CRT= 120 sec @ 04:00 hrs. 06:00 12:00 6.00 15,973 16,067 PROD1 DRILL DDRL P Directional drill f/15973'-16067' MD, 6192'TVD,ADT 5.14, bit 17.21,jars 17.21, PU 150K, SO 83K, ROT 115K,100-140 rpm, TQ on 10K, off 8K, ECD 11.66, FO 40%,WOB 10-12K,240 gpm,2800 psi. 12:00 18:00 6.00 16,067 16,589 PROD1 DRILL DDRL P Directional drill f/16067'-16589'MD, 6216'TVD,ADT 4.73, bit 21.94,jars 21.94, PU 155K, SO 79K, ROT 110K, 140 rpm,TQ on 11-12K,off 8-9K, ECD 11.92, FO 42%,WOB 8-10K, 240 gpm,2950 psi. SPR's @ 16492'MD,6210'TVD, MW 10.2 ppg, 16:45 hrs. #1 @ 20=650; @ 30=940 psi #2 @ 20=700; @ 30= 1030 psi 18:00 00:00 6.00 16,589 17,192 PROD1 DRILL DDRL P Directional drill f/16589'-17192'MD, 6217'TVD,ADT 4.48, bit 26.42,jars 26.42, PU 156K, SO 75K, ROT 114K, 140 rpm,TQ on 11K, off 9K, ECD 12.0, FO 42%,WOB 8-11K, 240 gpm, 3000 psi. SPR's @ 17152'MD,6216'TVD, MW 10.2 ppg, 23:30 hrs. #1 @ 20=680; @ 30= 1010 psi #2 @ 20=690; @ 30= 1000 psi 11/24/2014 Directional Drill with rotary drilling assembly in 6'/4'production hole from 17192'-18927'MD, 6232'TVD. 00:00 06:00 6.00 17,192 17,639 PROD1 DRILL DDRL P Directional drill f/17192'-17639' MD, 6227'TVD,ADT 4.38, bit 30.80,jars 30.80, PU 154K, SO 80K, ROT 114K, 140 rpm,TQ on 12K, off 9K, ECD 12.02, FO 42%,WOB 10K,240 gpm, 3050 psi. Fire Drill CRT=60 sec @ 05:00 hrs. 06:00 12:00 6.00 17,639 18,157 PROD1 DRILL DDRL P Directional drill f/17639'-18157'MD, 6234'TVD,ADT 3.99, bit 34.79,jars 34.79, PU 155K, SO 79K, ROT 113K, 140 rpm,TQ on 12K, off 9K, ECD 12.14, FO 42%,WOB 8-12K, 240 gpm, 3160 psi. SPR's @ 17719'MD,6217'TVD, MW 10.2 ppg, 06:00 hrs. #1 @ 20=700; ©30= 1060 psi #2 @ 20=720; @ 30= 1040 psi Page 33 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 18:00 6.00 18,157 18,571 PROD1 DRILL DDRL P Directional drill f/18157'-18571'MD, 6232'TVD,ADT 4.8, bit 39.59,jars 39.59, PU 160K, SO 80K, ROT 109K, 140 rpm,TQ on 12K,off 10K, ECD 12.10, FO 42%,WOB 4-5K, 240 gpm, 3150 psi. SPR's @ 18291'MD,6241'TVD, MW 10.2+ppg, 13:15 hrs. #1 @ 20=700; @ 30=990 psi #2 @ 20=720; @ 30= 1000 psi 18:00 00:00 6.00 18,571 18,927 PROD1 DRILL DDRL P Directional drill f/18571'-18927' MD, 6232'TVD,ADT 3.6, bit 43.19,jars 43.19, PU 156K, SO 76K, ROT 109K, 140 rpm, TQ on 11-12K, off 9-10K, ECD 12.42, FO 42%,WOB 8-10K,240 gpm, 3300 psi. Kick w/Drilling CRT=77 sec @ 23:00 hrs. SPR's @ 18855'MD, 6226'TVD, MW 10.5 ppg, 23:00 hrs. #1 @20=700; @ 30= 1160 psi #2@20=725; @30= 1100 psi 11/25/2014 Directional Drill with rotary drilling assembly in 6%"production hole from 18927'-20274' MD. 6256'TVD. CBU 00:00 06:00 6.00 18,927 19,326 PROD1 DRILL DDRL P Directional drill f/18927'-19326'MD, 6242'TVD,ADT 3.99, bit 47.18,jars 47.18, PU 156K, SO 74K, ROT 111K, 140 rpm,TQ on 12K,off 10K, 10.5 ppg MW, ECD 12.50, FO 42%, WOB 8-10K, 240 gpm, 3300 psi. Kick w/Drilling CRT= 120 sec @ 00:30 hrs. OA=575 psi @ 05:00 hrs 06:00 12:00 6.00 19,326 19,750 PROD1 DRILL DDRL P Directional drill f/19326'-19750' MD, 6263'TVD,ADT 4.05, bit 51.23,jars 51.23, PU 160K, SO 71K, ROT 111K, 140 rpm,TQ on 12K, off 10K, 10.5 ppg MW, ECD 12.56, FO 42%, WOB 8-10K,240 gpm, 3400 psi. SPR's @ 19416'MD,6248'ND, MW 10.5 ppg, 07:00 hrs. #1 @ 20=760; @ 30= 1080 psi #2 @ 20=780; @ 30= 1120 psi 12:00 18:00 6.00 19,750 20,179 PROD1 DRILL DDRL P Directional drill f/19750'-20179' MD, 6255'TVD,ADT 4.62, bit 55.85,jars 55.85, PU 167K, SO 63K, ROT 109K, 140 rpm,TQ on 12K, off 11K, 10.5 ppg MW, ECD 12.51, FO41%, WOB 5-7K, 238 gpm, 3500 psi. SPR's @ 19894'MD,6272'TVD, MW 10.5 ppg, 14:00 hrs. #1 @20=710; @ 30= 1130 psi #2@20=730; @30= 1120 psi Page 34 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:30 3.50 20,179 20,274 PROD1 DRILL DDRL P Directional drill f/20179'-20274'MD, 6256'TVD,ADT 2.66, bit 58.51,jars 58.51, PU 167K, SO 63K, ROT 109K, 140 rpm, TQ on 12K, off 11K,10.5 ppg MW, ECD 12.71, FO 41%,WOB 5-7K,238 gpm, 3500 psi. TD of production hole section @ 20274' MD, 6256'TVD. 21:30 00:00 2.50 20,274 20,274 PROD1 CASING CIRC P CBU x 2.240 gpm, 3450 psi,80 rpm, 10K Tq. PU 115K, SO 103K, ROT 110K. FO 41% SPR's @ 20172'MD,6255'TVD, MW 10.5 ppg,24:00 hrs. Losses for tour=17 bbls. #1 @ 20=860; @ 30= 1200 psi #2@20=910; @30= 1300 psi OA=540 psi 11/26/2014 Circulate. Perform pressure finger printing procedure. Back ream to shoe. CBU x2. Perform pressure finger printing procedure. Monitor well. Strip out of hole as per trip schedule. 00:00 02:00 2.00 20,274 PROD1 CASING CIRC P Stand back one stand of DP. Cont to circulate. 240 gpm, 3350 psi, 80 rpm, 10K tq. 02:00 03:30 1.50 20,182 20,182 PROD1 CASING OWFF P Blow down top drive. Shut in well and monitor pressure build up in 15 min intervals. First build up 101 psi max. Bleed off 2 bbls mud. Second build up 61 psi max. Bleed to 0 psi.Third build up 36 psi max. Bleed to 0 psi. Fourth build up 14 psi max. 03:30 12:00 8.50 20,182 16,306 PROD1 CASING REAM P Back ream out of hole f/20182'MD t/16306'MD. 10.5 ppg MW, 220 gpm, 2950 psi, 100-130 rpm, 10-12K tq, PU 115K, Rot 110K. Close MPD choke during connections to monitor pressure. 12:00 16:15 4.25 16,306 14,600 PROD1 CASING REAM P Back ream out of hole f/16306'MD t/14600' MD. 10.5 ppg MW, 220 gpm, 3125 psi,130 rpm, 8-9K tq, 41%FO, PU 115K, SO 95K, Rot 112K. Close MPD choke during connections to monitor pressure. 16:15 19:15 3.00 14,600 14,600 PROD1 CASING CIRC P CBU x2, 10.5 ppg MW, 215 gpm, 100 rpm, 7-8K tq, PU 115K, SO 108K, Rot 112K. 19:15 20:15 1.00 14,600 14,600 PROD1 CASING OWFF P Blow down top drive. Shut in well and monitor pressure build up in 15 min intervals. First build up 75 psi max. Bleed off 1.2 bbls mud. Second build up 36 psi max. Bleed to 0 psi.Third build up 16 psi max. Bleed to 0 psi. 20:15 22:00 1.75 14,600 14,600 PROD1 CASING OWFF P Monitor well at annulus valve. Static. Drop 2"rabbit 22:00 00:00 2.00 14,600 12,712 PROD1 CASING TRIP P Strip out of hole as per trip schedule f/14600'MD t/12712'MD. PU 155K, SO 99K. Calc disp=10.8 bbls.Act disp=18.2 bbls. Page 35 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/27/2014 24 hr Summary Strip out of hole, lay down BHA. Lay down 60 jts DP. PU 4 1/2"lower completion. 00:00 09:45 9.75 12,712 597 PROD1 CASING TRIP P Strip out of hole as per trip schedule f/12712'MD t/597'MD. PU 153K, SO 99K. Calc disp=79.3 bbls.Act disp=120.4 bbls. 09:45 10:15 0.50 597 597 PROD1 CASING OWFF P Shut in MPD choke. Monitor for pressure build up. No pressure gain. Sim-ops. Clear rig floor, Conduct PJSM for removing RCD bearing assy and installing trip nipple. 10:15 10:45 0.50 597 597 PROD1 CASING SEQP P Blow down all MPD lines 10:45 11:45 1.00 597 597 PROD1 CASING SEQP P Pull RCD bearing assy. Install trip nipple. 11:45 12:15 0.50 597 597 PROD1 CASING SEQP P Line up flow line. Fill BOP stack w/mud, check for leaks. 12:15 15:30 3.25 597 0 PROD1 CASING PULD P Lay down BHA. Remove nukes as per SLB. 15:30 16:00 0.50 0 0 PROD1 CASING RURD P Clean and clear rig floor of tools. 16:00 16:30 0.50 0 0 PROD1 CASING RURD P Install mouse hole, change elevators. Rig up to lay down DP in mousehole. 16:30 18:00 1.50 0 0 PROD1 CASING PULD P Lay down 60 jts 4"drill pipe in mousehole. 18:00 19:45 1.75 0 0 COMPZ CASING RURD P Rig up to run 4 1/2"lower completion 19:45 00:00 4.25 0 4,457 COMPZ CASING PUTB P Pick up 4 1/2", 11.6 ppf, L-80, Hydril 563 slotted lower completion to 4457' MD. PU 65K, SO 58K, Calc disp= 19.6 bbls.Act disp=15.47 bbls 11/28/2014 PU 4 1/2'slotted lower completion. RIH w/liner on DP to 7780'MD. Circ and wait on orders. Cont to RIH w/ 'inert to 14593' MD. Brk circ. PU 19 stds 4"HWDP.Con't to RIH w/liner to 18917'MD. 00:00 02:00 2.00 4,457 5,748 COMPZ CASING PUTB P Pick up 4 1/2", 11.6 ppf, L-80, Hydril 563 slotted lower completion f/4457' MD t/5792'MD. PU 71K, SO 61K, 02:00 03:00 1.00 5,748 5,792 COMPZ CASING PULD P Change elevators. PU liner hanger/ZXP liner top packer assy. Mix and allow to set Pal Mix. PU 72K SO 62K 03:00 03:15 0.25 5,792 5,792 COMPZ CASING RURD P Rig down casing equip. 03:15 03:30 0.25 5,792 5,792 COMPZ CASING SFTY P PJSM for RIH 03:30 06:00 2.50 5,792 7,780 COMPZ CASING RUNL P RIH w/4 1/2", 11.6 ppf, L-80, Hydril 563 slotted lower completion on DP f/5792'MD t/7780'MD. 06:00 06:15 0.25 7,780 7,780 COMPZ CASING OWFF P Monitor well on trip tank.Static. 06:15 08:45 2.50 7,780 7,780 COMPZ CASING CIRC P Circ @ 3 bpm, 200 psi.Returns @ 10.1 ppg.Weight up to 10.5 ppg. Wait on orders from town concerning swell packer placement. 08:45 15:15 6.50 7,780 14,593 COMPZ CASING RUNL P Blow down TD. RIH w/4 1/2", 11.6 ppf, L-80, Hydril 563 slotted lower completion on DP f/7780'MD t/14593'MD. PU 142K SO 80K. 15:15 16:45 1.50 14,593 14,593 COMPZ CASING CIRC P Brk circ. Stage pump up to 4 bpm, 800 psi Page 36 of 41 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:45 17:00 0.25 14,593 14,593 COMPZ CASING OWFF P Blow down TD. Monitor well. Static 17:00 19:30 2.50 14,593 14,593 COMPZ CASING PULD P Pick up and stand back 19 stds 4" HWDP 19:30 00:00 4.50 14,593 18,917 COMPZ CASING RUNL P RIH w/4 1/2", 11.6 ppf, L-80, Hydril 563 slotted lower completion on DP f/14593'MD t/18917'MD. PU 142K SO 80K. Fill pipe @ 15730'MD and 18917'MD. Total calc disp=80.72 Total act disp=72.2 11/29/2014 RIH w/liner to 20233' MD. Set and release from hanger. Set and test liner top packer. Displace well to 10.5 ppg brine. Cut drilling line. TOH.Rig up to run upper completion 00:00 01:45 1.75 18,917 20,233 COMPZ CASING RUNL P RIH w/4 1/2", 11.6 ppf, L-80, Hydril 563 slotted lower completion on DP f/18917' MD t/20233'MD. PU 190K SO 93K.Total calc disp=92.05 Total act disp=84.1 01:45 02:45 1.00 20,233 20,233 COMPZ CASING OWFF P Monitor well. Static 02:45 04:30 1.75 20,233 20,233 COMPZ CASING PACK P Drop 1.5"phenolic ball. Pump on seat @ 3bpm, 1000 psi. Ball on seat @1080 stks. Pressure up to 3000 psi to set liner hanger.Slack off and set down 60Kwt. Pressure up to 3500 psi./5 min. Bleed pressure off and pick up to 200K. Did not release from hanger. Set down 60K wt. Pressure up to 4000 psi. Bleed pressure off. PU and release from hanger. PU=180K.PU and clear rotating dog sub. Rotate 10 rpm. Set down 40K wt.to set liner top packer. 04:30 04:45 0.25 20,233 20,233 COMPZ CASING PRTS P Test liner top packer to 1500 psi. Record on chart for 15 min. 04:45 05:15 0.50 20,233 14,440 COMPZ WELLPF PULD P Lay down 2 jts. DP to 14440'running tools depth. Blow down circulating lines 05:15 05:30 0.25 14,440 14,440 COMPZ WELLPF CIRC P Break circ.4 BPM 1300 psi. Line up trucks to displace well to 10.5 ppg filtered NACL/NABR brine. 05:30 06:00 0.50 14,440 14,440 COMPZ WELLPF SFTY P PJSM on displacing well to 10.5 ppg brine. Clean suction screens on mud pumps. 06:00 09:30 3.50 14,440 14,440 COMPZ WELLPF DISP P Displace well to 10.5 ppg brine. 5 bpm, 1300 psi. No gains, no losses. Pumped a total of 940 bbls. brine. 09:30 10:00 0.50 14,440 14,440 COMPZ WELLPF OWFF P Monitor well. Static. 10:00 12:00 2.00 14,440 14,383 COMPZ WELLPF SLPC P Lay down 2 jts DP. Slip and cut 84' drilling line. Service rig and top drive. 12:00 13:15 1.25 14,383 13,179 COMPZ WELLPF TRIP P POOH f/14383'MD t/13179'MD. PU 205K. Calc disp=8.78 bbls. Act disp=6.36 bbls. SPR's @ 13179'MD,5819'TVD, MW 10.5 ppg, 13:00 hrs. #1 @20= 100; @ 30=310 psi #2 @ 20= 120; @ 30=290 psi Page 37 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 14:00 0.75 13,179 13,179 COMPZ WELLPF OWFF P Monitor well due to improper displacement. Static. Clean trip tank and fill. 14:00 20:15 6.25 13,179 0 COMPZ WELLPF TRIP P POOH f/13179'MD t/528' MD.. Lay down 15 jts DP and running tool.Calc disp=89.98 bbls Act disp=93.82 bbls. 20:15 22:00 1.75 0 0 COMPZ RPCOM RURD P Clean and clear rig floor, pull wear ring, flush BOPE. Blow down top drive. 22:00 22:30 0.50 0 0 COMPZ RPCOM OTHR P Perform tubing hanger dummy run. RKB=23.27' 22:30 23:15 0.75 0 0 COMPZ CASING SFTY P PJSM-Rig up to run 3 1/2"tubing 23:15 00:00 0.75 0 100 COMPZ RPCOM PUTB P PU 3 1/2". 9.3#, L-80 EUE upper completion. MU WLEG assy, Mirage Plug assy,packer assy and one jt. tbg. 11/30/2014 Attempt to test auto fill sub and Mirage plug. No good. Rig down test equip.Wait on orders. Rig up test equip.Attempt to test auto fill sub and Mirage sub. No good. Lay down completion equip.Clear floor. Lay down 4"DP. Rig up to test BOPE 00:00 01:15 1.25 100 100 COMPZ RPCOM PUTB T While making up on Mirage Plug middle sub backed out. Check tolerances and tighten middle sub. 01:15 03:00 1.75 100 100 COMPZ RPCOM PRTS T Rig up test equip to check auto fill sub. Close annular and pump down kill line w/charge pump. Slight returns w/50 psi. Switch to mud pump @ 2 spm,200 psi. Insufficient flow through auto fill sub. RU to pressure test Mirage plug and auto fill sub. Pressure up to 300 psi using test pump. Not holding pressure and slight flow out. Increase pressure to 500 psi w/same results. Consult w/completions engineer 03:00 03:30 0.50 100 100 COMPZ RPCOM RURD T Rig down test equip. Blow down kill line. 03:30 04:30 1.00 100 70 COMPZ RPCOM PULD T Lay down one jt.tbg.Wait on orders 04:30 05:45 1.25 70 100 COMPZ RPCOM PRTS T PU one jt.tbg. Rig up test equip. Close annular and pump 1.4 bbls down kill line 300 psi. Still insufficient flow through auto fill sub. RU to pressure test Mirage plug and auto fill sub. Pressure up to 300 psi using test pump. Not holding pressure and slight flow out. Increase pressure to 500 psi w/same results. 05:45 06:00 0.25 100 100 COMPZ RPCOM RURD T Rig down test equip. Blow down kill line. 06:00 06:30 0.50 100 0 COMPZ RPCOM PULD T Lay down 3 1/2". 9.3#, L-80 EUE upper completion. Lay down WLEG assy, Mirage Plug assy, packer assy and one jt. tbg. 06:30 07:45 1.25 0 0 COMPZ RPCOM RURD T Rig down csg equip. Clear rig floor, pu drill pipe thread protectors Page 38 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 22:15 14.50 0 0 COMPZ RPCOM PULD IP Lay down drill pipe in mousehole/ Monitor well on trip tank. 22:15 00:00 1.75 0 0 COMPZ WHDBO RURD P Rig up to test BOPE 12/01/2014 Test BOPE. PU auto fill sub, Mirage plug and packer assy's.Test Mirage plug to 350 psi. PU 3 1/2"lower completion 00:00 06:00 6.00 0 0 COMPZ WHDBO BOPE P PJSM,test BOPE w/3.5"&4.5" test joints to 250/3500 psi for 5 min each on annular, upper&lower VBR's.#1 Top VBR's, CV 1,12,13, 14, &manual kill line valve;#2 upper IBOP, HCR kill, CV's 9,11;#3 lower IBOP, CV's 5,8& 10;#4 dart valve, CV's 4,6&7;#5 FSV&CV 2;#6 HCR choke, kill line 4" Demco;#7 Manual choke& HCR kill;#8 annular;#9 lower VBR's;#10 blind rams&CV 3;#11 Hydraulic& manual choke draw down. Accumulator test initial system 3000 psi; after closure 1800 psi; 200 psi attained in 43 seconds; full psi attained in 186 sec. 5 nitrogen bottles averaged 2000 psi. No failures Witness waived by AOGCC Bob Noble verbally 11-30-14 @ 10:30 hrs. 06:00 06:30 0.50 0 0 COMPZ WHDBO RURD P Rig down test equip. Blow down choke and kill lines. 06:30 07:00 0.50 0 0 COMPZ RPCOM RURD P Rig up csg. equip. Change elevators and make up safety valve to X-O. 07:00 08:00 1.00 0 100 COMPZ RPCOM PUTB P PU Mirage plug, auto fill and Premier packer assy's. PU one jt. 3 1/2"tbg. 08:00 09:00 1.00 100 100 COMPZ RPCOM PRTS P RU test equip. Test Mirage plug to 350 psi. Charted for 10 mins. 09:00 12:00 3.00 100 2,069 COMPZ RPCOM PUTB P PU 3 1/2" EUE 8rd Mod 9.3#L-80 upper completion string as per detail f/100' MD to 2069' MD. Fill pipe every 15 jts. PU 46K SO 47K. Calc disp=7.28 bbls Act disp=9.64 bbls 12:00 00:00 12.00 2,069 12,698 COMPZ RPCOM PUTB P PU 3 1/2"EUE 8rd Mod 9.3#L-80 upper completion string as per detail f/2069' MD t/4249' MD. Fill pipe every 15 jts. From 4249'MD to 4706' MD cease filling pipe to determine if auto fill sub is functioning. Calc disp=1.54 bbls. Act disp=5.1 bbls. MD. Repeat not filling pipe from 4706' MD to 5163' MD Calc disp=1.54 bbls. Act disp=5.1 bbls. Determine that auto fill sub not functioning. Fill pipe w/8 bbls. Con't PU upper completion f/5163'MD t112698' MD filling every 15 jts. PU 108K SO 54K Calc Disp=43.39 bbls Act Disp=40.41 bbls Page 39 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/02/2014 24 hr Summary PU 3 1/2"lower completion to 14466'MD. Set packer. Space out. Circ inhibited brine. Land tubing. RILDS Test annulus and tubing as per program. Shear SOV. Install two way check.Test hanger seals. Test TWC and hanger from direction of flow. N/D MPD equipment. Clean&inspect all ram cavities/ram elements. 00:00 02:30 2.50 12,698 14,466 COMPZ RPCOM PUTB P PU 3 1/2"EUE 8rd Mod 9.3#L-80 upper completion string as per detail f/12698' MD to 14466'MD. Fill pipe every 15 jts. PU 120K SO 50K. Calc disp=6.3 bbls Act disp=6 bbls 02:30 03:00 0.50 14,466 14,466 COMPZ RPCOM RURD P Rig up lines for testing&circulating. 03:00 03:30 0.50 14,466 14,466 COMPZ RPCOM OWFF P Monitor well,static. 03:30 04:00 0.50 14,466 14,466 COMPZ RPCOM PRTS P Pressure up on auto fill to 1250 psi, charted for 15 min. Close annular, test auto fill to 300 psi,good. 04:00 05:00 1.00 14,466 14,466 COMPZ RPCOM PACK P Pressure up to 2800 psi on tubing to set packer. Hold psi for 30 min. 05:00 05:30 0.50 14,466 14,466 COMPZ RPCOM PRTS P Pressure test packer to 1500 psi 10 min on chart. 05:30 07:45 2.25 14,466 14,441 COMPZ RPCOM HOSO P Pressure up to 1000 psi&PU to release sealbore from PBR. Lay down 3 jts of 3.5"tubing. PU 4.19" pup jt,XO, 1 jt.4.5"tubing, & hanger. 07:45 08:00 0.25 14,441 14,441 COMPZ RPCOM RURD P Rig up circulating lines 08:00 10:15 2.25 14,441 14,441 COMPZ RPCOM CRIH P Spot inhibited brine @ 5 bpm, 980 psi,397 bbls of 10.5 ppg, 1.5% Conqor 303A,& 120 bbls of 10.5 ppg unhibited brine. 10:15 11:00 0.75 14,441 14,466 COMPZ RPCOM THGR P Blow down lines. Land tubing hanger, observe seals entering PBR 5-6K weight. PU 120k, SO 50K. RILDS. 11:00 11:30 0.50 14,466 14,466 COMPZ RPCOM PRTS P Test upper hanger seals to 250 for 5 min. &5000 psi for 10 min, witnessed by Company Man. 11:30 11:45 0.25 14,466 14,466 COMPZ RPCOM PRTS P Pressure test seal bore&PBR to 1000 psi. 11:45 12:15 0.50 14,466 14,466 COMPZ RPCOM OWFF P Monitor well, static. 12:15 12:45 0.50 14,466 14,466 COMPZ RPCOM RURD P Rig up circulating lines in cellar& mezzanine. 12:45 14:45 2.00 14,466 14,466 COMPZ RPCOM PRTS P Pressure test tubing 3000&3500 psi, 30 min each on chart. Bleed tubing to 2500 psi. Pressure test IA to 3500 psi for 30 min on chart. Bleed pressure from tubing to observe SOV sheared. 14:45 15:00 0.25 14,466 14,466 COMPZ WHDBO MPSP P Set TWC per CIW rep&test to 2750 psi for 5 min. on chart, in direction of flow. 15:00 15:30 0.50 14,466 0 COMPZ WHDBO NUND P Rig down&blow down all lines. Switch from shore power to rig generators @ 15:15 hrs. 15:30 16:00 0.50 0 0 COMPZ WHDBO OWFF P Monitor well,static. 16:00 20:45 4.75 0 0 COMPZ WHDBO SEQP P Clean&rig down MPD lines &equipment; remove scaffolding, clean&clear cellar. Page 40 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 00:00 3.25 0 0 COMPZ WHDBO NUND P PJSM, open ram doors, clean& inspect all rams,change out lower rams. 12/03/2014 N/D BOPE&N/U tree. PT tubing hanger X void to 5000 psi. Freeze protect IA&U-tube. Set BPV&test to 1000 psi. RDMO. 00:00 02:30 2.50 0 0 COMPZ WHDBO NUND P PJSM, nipple down BOPE. 02:30 05:00 2.50 0 0 COMPZ WHDBO NUND P PJSM, nipple up adapter flange as per CIW. 05:00 05:30 0.50 0 0 COMPZ WHDBO PRTS P PJSM, pressure test tubing hanger X adaper void to 250 psi for 5 min& 5000 psi for 10 min.Witnessed by CPAI Supervisor. 05:30 08:30 3.00 0 0 COMPZ WHDBO NUND P PJSM, nipple up tree as per CIW. Break apart and reorient wing valve as per schematic. 08:30 09:30 1.00 0 0 COMPZ WHDBO PRTS P PJSM, rig up and test tree 250 psi for 5 min&5000 psi for 10 min. 09:30 10:15 0.75 0 0 COMPZ WHDBO FRZP P PJSM, rig up scaffolding around well head. 10:15 10:30 0.25 0 0 COMPZ WHDBO FRZP P PJSM, rig up circulating lines. 10:30 11:00 0.50 0 0 COMPZ WHDBO MPSP P PJSM, remove BPV. 11:00 12:00 1.00 0 0 COMPZ WHDBO FRZP P PJSM, PT lines to 2500 psi, pump 95 bbls of diesel,2 bpm, ICP 600 psi, FCP 1000 psi. 12:00 13:30 1.50 0 0 COMPZ WHDBO FRZP P Line up&u-tube diesel freeze protect 13:30 14:30 1.00 0 0 COMPZ WHDBO FRZP P Rig down circulating lines, rig up lubricator. 14:30 15:30 1.00 0 0 COMPZ WHDBO MPSP P Test lubricator to 1500 psi&set BPV as per CIW. PT lines&test BPV to 1000 psi for 5 min.on chart with LRS. 15:30 16:00 0.50 0 0 COMPZ WHDBO OTHR P Rig down scaffolding. 16:00 17:45 1.75 0 0 COMPZ WHDBO NUND P Remove annulus valves&install blanking flanges. Secure well. 17:45 18:00 0.25 0 0 DEMOB MOVE RURD P Blow down lines&prep for rig move. Rig release at 18:00 hrs. Page 41 of 41 NADConversion Kuparuk River Unit Kuparuk 2E Pad 2F-21 Definitive Survey Report N A D 2 7 15 December, 2014 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 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 2F-21 Well Position +N/-S 0.00 usft Northing: 5,948,711.26 usft Latitude: 70°16'15.773 N +EI-W 0.00 usft Easting: 517,501.07 usft Longitude: 149°51'30.459 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 95.80 usft Wellbore 2F-21 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°l (nT) BGGM2014 10/10/2014 19.12 80.87 57,571 Design 2F-21 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (1 27.50 0.00 0.00 180.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description 81.26 816.35 2F-21-SRV#1 SLB-NSG+MSHOT(2F-21) GYD-GC-SS Gyrodata gyro single shots 870.71 3,925.70 2F-21-SRV#2-SLB-MWD+GMAG(2F-21 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,025.12 14,547.71 2F-21 SRV#3 SLB-MWD+GMAG(2F-21) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 14,615.84 20,193.85 2F-21-Srvy#4 MWD+IFR-AK-CAZ-SC(2F MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/-S +E/-W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) 0.00 usft tool name 27.50 0.00 0.00 27.50 -95.80 0.00 0.00 5,948,711.26 517,501.07 UNDEFINED 81.26 0.11 322.73 81.26 -42.04 0.04 -0.03 5,948,711.30 517,501.03 GYD-GC-SS(1) 110.00 0.14 304.66 110.00 -13.30 0.08 -0.08 5,948,711.34 517,500.99 GYD-GC-SS(1) 20"x 24" 166.69 0.23 287.65 166.69 43.39 0.16 -0.24 5,948,711.41 517,500.82 GYD-GC-SS(1) 259.57 0.18 282.27 259.57 136.27 0.25 -0.56 5,948,711.50 517,500.50 GYD-GC-SS(1) 349.84 0.23 248.58 349.84 226.54 0.21 -0.87 5,948,711.46 517,500.19 GYD-GC-SS(1) 449.76 2.31 89.00 449.73 326.43 0.17 0.96 5,948,711.43 517,502.02 GYD-GC-SS(1) 542.15 3.30 87.66 542.01 418.71 0.31 5.47 5,948,711.58 517,506.54 GYD-GC-SS(1) 633.71 2.95 82.54 633.44 510.14 0.73 10.44 5,948,712.01 517,511.51 GYD-GC-SS(1) 724.38 3.90 81.83 723.94 600.64 1.47 15.81 5,948,712.76 517,516.87 GYD-GC-SS(1) 816.35 7.29 79.03 815.46 692.16 3.02 24.64 5,948,714.34 517,525.69 GYD-GC-SS(1) 12/16/2014 6:26:40PM Page 2 COMPASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit ND Reference: rig:95.8+27.5 @ I23.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +NI-S +EI-W Northing Easting (usft) (^) Cl (usft) (usft) (usft) (usft) 11.00 usft tool name 870.71 8.35 82.37 869.32 746.02 4.20 31.94 5,948,715.53 517,532.99 MWD+IFR-AK-CAZ-SC(2) 966.66 10.19 87.42 964.01 840.71 5.51 47.32 5,948,716.88 517,548.37 MWD+IFR-AK-CAZ-SC(2) 1,059.35 13.69 90.68 1,054.68 931.38 5.75 66.48 5,948,717.16 517,567.53 MWD+IFR-AK-CAZ-SC(2) 1,151.24 16.74 96.43 1,143.35 1,020.05 4.14 90.51 5,948,715.61 517,591.56 M1ND+IFR-AK-CAZ-SC(2) 1,246.23 19.81 107.40 1,233.56 1,110.26 -2.21 119.48 5,948,709.32 517,620.54 MWD+IFR-AK-CAZ-SC(2) 1,338.53 20.13 110.57 1,320.31 1,197.01 -12.47 149.28 5,948,699.14 517,650.36 MWD+IFR-AK-CAZ-SC(2) 1,431.04 20.91 113.66 1,406.95 1,283.65 -24.69 179.31 5,948,686.99 517,680.41 MWD+IFR-AK-CAZ-SC(2) 1,523.73 21.69 116.78 1,493.31 1,370.01 -39.05 209.76 5,948,672.70 517,710.89 MWD+IFR-AK-CAZ-SC(2) 1,615.25 23.62 122.73 1,577.78 1,454.48 -56.58 240.29 5,948,655.24 517,741.46 MWD+IFR-AK-CAZ-SC(2) 1,707.86 25.97 126.70 1,661.85 1,538.55 -78.74 272.16 5,948,633.16 517,773.38 MWD+IFR-AK-CAZ-SC(2) 1,801.42 27.39 131.24 1,745.46 1,622.16 -105.17 304.77 5,948,606.81 517,806.05 MWD+IFR-AK-CAZ-SC(2) 1,894.02 29.34 134.99 1,826.94 1,703.64 -135.25 336.83 5,948,576.80 517,838.18 MWD+IFR-AK-CAZ-SC(2) 1,984.20 31.08 137.60 1,904.88 1,781.58 -168.06 368.15 5,948,544.07 517,869.57 MWD+IFR-AK-CAZ-SC(2) 2,076.95 33.88 143.26 1,983.13 1,859.83 -206.47 399.77 5,948,505.73 517,901.28 MWD+IFR-AK-CAZ-SC(2) 2,171.76 34.98 145.79 2,061.34 1,938.04 -250.13 430.86 5,948,462.16 517,932.47 MWD+IFR-AK-CAZ-SC(2) 2,263.83 36.37 149.81 2,136.14 2,012.84 -295.56 459.43 5,948,416.80 517,961.14 MWD+IFR-AK-CAZ-SC(2) 2,357.15 37.35 150.31 2,210.81 2,087.51 -344.06 487.37 5,948,368.36 517,989.18 MWD+IFR-AK-CAZ-SC(2) 2,449.20 39.02 150.98 2,283.16 2,159.86 -393.66 515.25 5,948,318.84 518,017.18 MWD+IFR-AK-CAZ-SC(2) 2,542.55 42.85 150.65 2,353.67 2,230.37 -447.04 545.08 5,948,265.53 518,047.13 MWD+IFR-AK-CAZ-SC(2) 2,635.66 47.27 150.48 2,419.42 2,296.12 -504.43 577.46 5,948,208.23 518,079.64 MWD+IFR-AK-CAZ-SC(2) 2,728.09 50.18 153.07 2,480.39 2,357.09 -565.64 610.28 5,948,147.10 518,112.60 MWD+IFR-AK-CAZ-SC(2) 2,820.46 52.50 155.15 2,538.09 2,414.79 -630.53 641.75 5,948,082.29 518,144.22 MWD+IFR-AK-CAZ-SC(2) 2,912.82 54.70 156.52 2,592.90 2,469.60 -698.35 672.17 5,948,014.54 518,174.79 MWD+IFR-AK-CAZ-SC(2) 3,006.08 56.88 155.54 2,645.32 2,522.02 -768.82 703.51 5,947,944.16 518,206.29 MWD+IFR-AK-CAZ-SC(2) 3,097.71 58.88 156.72 2,694.04 2,570.74 -839.78 734.90 5,947,873.27 518,237.84 MWD+IFR-AK-CAZ-SC(2) 3,191.13 60.68 158.59 2,741.06 2,617.76 -914.44 765.58 5,947,798.69 518,268.69 MWD+IFR-AK-CAZ-SC(2) 3,284.38 63.32 160.43 2,784.84 2,661.54 -991.56 794.38 5,947,721.64 518,297.67 MWD+IFR-AK-CAZ-SC(2) 3,375.58 66.29 162.41 2,823.66 2,700.36 -1,069.78 820.65 5,947,643.50 518,324.12 MVVD+IFR-AK-CAZ-SC(2) 3,467.65 68.64 163.88 2,858.95 2,735.65 -1,151.16 845.30 5,947,562.18 518,348.95 MWD+IFR-AK-CAZ-SC(2) 3,559.84 70.05 163.37 2,891.46 2,768.16 -1,233.92 869.62 5,947,479.48 518,373.46 MWD+IFR-AK-CAZ-SC(2) 3,653.43 72.91 163.71 2,921.19 2,797.89 -1,319.02 894.76 5,947,394.45 518,398.80 MVVD+IFR-AK-CAZ-SC(2) 3,745.44 72.59 164.02 2,948.47 2,825.17 -1,403.43 919.18 5,947,310.11 518,423.41 MWD+IFR-AK-CAZ-SC(2) 3,838.76 71.85 162.92 2,976.97 2,853.67 -1,488.62 944.46 5,947,224.99 518,448.89 MVVD+IFR-AK-CAZ-SC(2) 3,925.70 70.99 164.35 3,004.67 2,881.37 -1,567.68 967.68 5,947,145.98 518,472.29 M1ND+IFR-AK-CAZ-SC(2) 3,996.00 71.01 162.83 3,027.56 2,904.26 -1,631.44 986.46 5,947,082.28 518,491.21 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 4,025.12 71.02 162.20 3,037.03 2,913.73 -1,657.71 994.73 5,947,056.03 518,499.55 MWD+IFR-AK-CAZ-SC(3) 4,119.19 70.97 163.30 3,067.67 2,944.37 -1,742.65 1,021.10 5,946,971.16 518,526.12 MWD+IFR-AK-CAZ-SC(3) 4,209.18 71.72 163.43 3,096.45 2,973.15 -1,824.34 1,045.51 5,946,889.54 518,550.71 MWD+IFR-AK-CAZ-SC(3) 4,302.08 72.42 163.32 3,125.05 3,001.75 -1,909.03 1,070.80 5,946,804.91 518,576.20 MWD+IFR-AK-CAZ-SC(3) 12/16/2014 6:26:40PM Page 3 COMPASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 c 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/-S +E/-W Northing Fasting (usft) C) C) (usft) (usft) (usft) (usft) 50.00 usft tool name 4,397.93 72.29 163.68 3,154.11 3,030.81 -1,996.61 1,096.74 5,946,717.40 518,602.34 MWD+IFR-AK-CAZ-SC(3) 4,491.77 72.32 164.51 3,182.63 3,059.33 -2,082.59 1,121.24 5,946,631.49 518,627.04 MWD+IFR-AK-CAZ-SC(3) 4,588.48 72.38 163.70 3,211.95 3,088.65 -2,171.22 1,146.48 5,946,542.92 518,652.48 MWD+IFR-AK-CAZ-SC(3) 4,685.44 71.97 164.09 3,241.63 3,118.33 -2,259.90 1,172.09 5,946,454.31 518,678.29 MWD+IFR-AK-CAZ-SC(3) 4,781.57 71.89 163.84 3,271.45 3,148.15 -2,347.74 1,197.33 5,946,366.55 518,703.73 MWD+IFR-AK-CAZ-SC(3) 4,876.91 71.92 163.44 3,301.06 3,177.76 -2,434.69 1,222.86 5,946,279.66 518,729.46 MWD+IFR-AK-CAZ-SC(3) 4,973.06 71.95 163.09 3,330.88 3,207.58 -2,522.23 1,249.18 5,946,192.19 518,755.98 MWD+IFR-AK-CAZ-SC(3) 5,069.13 71.86 164.40 3,360.72 3,237.42 -2,609.90 1,274.74 5,946,104.59 518,781.74 MWD+IFR-AK-CAZ-SC(3) 5,163.96 71.80 163.67 3,390.29 3,266.99 -2,696.52 1,299.52 5,946,018.03 518,806.72 MWD+IFR-AK-CAZ-SC(3) 5,260.74 71.86 163.48 3,420.47 3,297.17 -2,784.72 1,325.52 5,945,929.90 518,832.93 MWD+IFR-AK-CAZ-SC(3) 5,356.82 71.81 163.21 3,450.42 3,327.12 -2,872.18 1,351.69 5,945,842.51 518,859.29 M1ND+IFR-AK-CAZ-SC(3) 5,453.62 71.74 162.64 3,480.70 3,357.40 -2,960.07 1,378.68 5,945,754.69 518,886.49 MWD+IFR-AK-CAZ-SC(3) 5,548.60 71.78 162.47 3,510.43 3,387.13 -3,046.13 1,405.73 5,945,668.70 518,913.73 MWD+IFR-AK-CAZ-SC(3) 5,639.65 71.74 162.01 3,538.93 3,415.63 -3,128.49 1,432.11 5,945,586.42 518,940.30 MWD+IFR-AK-CAZ-SC(3) 5,732.18 71.75 160.67 3,567.91 3,444.61 -3,211.74 1,460.22 5,945,503.24 518,968.60 MWD+IFR-AK-CAZ-SC(3) 5,825.13 71.81 160.64 3,596.97 3,473.67 -3,295.04 1,489.47 5,945,420.01 518,998.04 MWD+IFR-AK-CAZ-SC(3) 5,916.70 71.73 161.40 3,625.62 3,502.32 -3,377.29 1,517.75 5,945,337.84 519,026.52 MWD+IFR-AK-CAZ-SC(3) 6,008.96 71.89 160.43 3,654.42 3,531.12 -3,460.12 1,546.41 5,945,255.09 519,055.36 MWD+IFR-AK-CAZ-SC(3) 6,101.15 71.87 160.74 3,683.09 3,559.79 -3,542.75 1,575.54 5,945,172.53 519,084.68 MWD+IFR-AK-CAZ-SC(3) 6,191.63 71.90 161.05 3,711.23 3,587.93 -3,624.01 1,603.68 5,945,091.34 519,113.01 MWD+IFR-AK-CAZ-SC(3) 6,286.75 71.83 160.57 3,740.83 3,617.53 -3,709.38 1,633.40 5,945,006.05 519,142.92 MWD+IFR-AK-CAZ-SC(3) 6,378.56 71.77 161.64 3,769.51 3,646.21 -3,791.90 1,661.64 5,944,923.61 519,171.35 MWD+IFR-AK-CAZ-SC(3) 6,473.57 71.90 162.05 3,799.13 3,675.83 -3,877.88 1,689.77 5,944,837.90 519,199.68 MWD+IFR-AK-CAZ-SC(3) 6,565.34 71.77 160.85 3,827.74 3,704.44 -3,960.35 1,717.51 5,944,755.31 519,227.61 MWD+IFR-AK-CAZ-SC(3) 6,658.27 71.77 162.54 3,856.81 3,733.51 -4,044.14 1,745.23 5,944,671.59 519,255.52 MWD+IFR-AK-CAZ-SC(3) 6,750.58 71.81 162.77 3,885.66 3,762.36 -4,127.84 1,771.37 5,944,587.96 519,281.85 MWD+IFR-AK-CAZ-SC(3) 6,841.75 71.68 162.36 3,914.22 3,790.92 -4,210.44 1,797.31 5,944,505.42 519,307.98 M1A/D+IFR-AK-CAZ-SC(3) 6,934.70 71.62 162.23 3,943.48 3,820.18 -4,294.49 1,824.14 5,944,421.45 519,335.01 MWD+IFR-AK-CAZ-SC(3) 7,027.95 71.66 162.29 3,972.85 3,849.55 -4,378.78 1,851.11 5,944,337.23 519,362.17 MWD+IFR-AK-CAZ-SC(3) 7,120.39 71.63 162.44 4,001.96 3,878.66 -4,462.40 1,877.69 5,944,253.68 519,388.94 MWD+IFR-AK-CAZ-SC(3) 7,213.55 71.66 161.98 4,031.30 3,908.00 -4,546.59 1,904.70 5,944,169.56 519,416.15 MWD+IFR-AK-CAZ-SC(3) 7,305.62 71.66 161.86 4,060.27 3,936.97 -4,629.67 1,931.83 5,944,086.55 519,443.46 MVVD+IFR-AK-CAZ-SC(3) 7,398.58 71.35 160.85 4,089.76 3,966.46 -4,713.20 1,960.01 5,944,003.10 519,471.83 MWD+IFR-AK-CAZ-SC(3) 7,490.75 71.46 160.60 4,119.15 3,995.85 -4,795.66 1,988.85 5,943,920.71 519,500.86 MWD+IFR-AK-CAZ-SC(3) 7,584.58 71.81 160.97 4,148.72 4,025.42 -4,879.75 2,018.15 5,943,836.70 519,530.36 MWD+IFR-AK-CAZ-SC(3) 7,677.74 72.01 159.46 4,177.64 4,054.34 -4,963.07 2,048.13 5,943,753.45 519,560.52 MWD+IFR-AK-CAZ-SC(3) 7,768.70 72.41 158.71 4,205.43 4,082.13 -5,043.98 2,079.05 5,943,672.63 519,591.63 MWD+IFR-AK-CAZ-SC(3) 7,860.26 72.47 159.17 4,233.06 4,109.76 -5,125.44 2,110.42 5,943,591.25 519,623.18 MWD+IFR-AK-CAZ-SC(3) 7,955.57 72.62 159.74 4,261.65 4,138.35 -5,210.58 2,142.32 5,943,506.19 519,655.28 MWD+IFR-AK-CAZ-SC(3) 8,048.36 72.82 162.19 4,289.21 4,165.91 5,294.33 2,171.22 5,943,422.52 519,684.37 MWD+IFR-AK-CAZ-SC(3) 12/16/2014 6:26:40PM Page 4 COMPASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig.95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N1-S +El-W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) 90.00 usft tool name 8,142.38 72.92 164.26 4,316.91 4,193.61 -5,380.35 2,197.15 5,943,336.57 519,710.50 MWD+IFR-AK-CAZ-SC(3) 8,234.19 73.03 165.12 4,343.79 4,220.49 -5,465.02 2,220.33 5,943,251.96 519,733.87 MWD+IFR-AK-CAZ-SC(3) 8,331.32 72.44 164.98 4,372.62 4,249.32 -5,554.63 2,244.25 5,943,162.41 519,758.00 MWD+IFR-AK-CAZ-SC(3) 8,429.13 71.89 164.70 4,402.58 4,279.28 -5,644.50 2,268.60 5,943,072.61 519,782.56 MWD+IFR-AK-CAZ-SC(3) 8,525.03 71.96 164.31 4,432.33 4,309.03 -5,732.35 2,292.96 5,942,984.82 519,807.12 MWD+IFR-AK-CAZ-SC(3) 8,619.70 71.96 164.28 4,461.65 4,338.35 -5,819.01 2,317.32 5,942,898.23 519,831.68 MWD+IFR-AK-CAZ-SC(3) 8,716.89 71.99 164.40 4,491.72 4,368.42 -5,908.00 2,342.27 5,942,809.31 519,856.83 MWD+IFR-AK-CAZ-SC(3) 8,811.52 71.99 164.15 4,520.98 4,397.68 -5,994.62 2,366.66 5,942,722.75 519,881.42 MWD+IFR-AK-CAZ-SC(3) 8,908.66 71.96 163.65 4,551.04 4,427.74 -6,083.37 2,392.28 5,942,634.07 519,907.24 MWD+IFR-AK-CAZ-SC(3) 9,003.89 71.96 163.72 4,580.53 4,457.23 -6,170.28 2,417.71 5,942,547.23 519,932.88 MWD+IFR-AK-CAZ-SC(3) 9,100.74 71.82 163.60 4,610.63 4,487.33 -6,258.61 2,443.61 5,942,458.97 519,958.98 MWD+IFR-AK-CAZ-SC(3) 9,195.23 71.80 162.95 4,640.13 4,516.83 -6,344.58 2,469.44 5,942,373.07 519,985.01 MWD+IFR-AK-CAZ-SC(3) 9,284.94 71.90 162.64 4,668.08 4,544.78 -6,426.01 2,494.66 5,942,291.70 520,010.41 MWD+IFR-AK-CAZ-SC(3) 9,377.35 71.96 162.83 4,696.74 4,573.44 -6,509.91 2,520.73 5,942,207.88 520,036.68 MWD+IFR-AK-CAZ-SC(3) 9,470.78 71.99 162.32 4,725.65 4,602.35 -6,594.67 2,547.34 5,942,123.18 520,063.48 MWD+IFR-AK-CAZ-SC(3) 9,562.52 72.08 162.61 4,753.95 4,630.65 -6,677.88 2,573.63 5,942,040.04 520,089.96 MWD+IFR-AK-CAZ-SC(3) 9,657.27 72.05 162.46 4,783.12 4,859.82 -6,763.87 2,600.69 5,941,954.12 520,117.21 MWD+IFR-AK-CAZ-SC(3) 9,748.11 72.05 162.76 4,811.12 4,687.82 -6,846.34 2,626.51 5,941,871.72 520,143.23 MWD+IFR-AK-CAZ-SC(3) 9,841.58 72.02 162.81 4,839.95 4,716.65 -6,931.27 2,652.83 5,941,786.86 520,169.74 MWD+IFR-AK-CAZ-SC(3) 9,934.14 71.99 162.71 4,868.54 4,745.24 -7,015.35 2,678.92 5,941,702.85 520,196.02 MWD+IFR-AK-CAZ-SC(3) 10,026.48 71.97 162.43 4,897.11 4,773.81 -7,099.13 2,705.22 5,941,619.15 520,222.52 MWD+IFR-AK-CAZ-SC(3) 10,118.52 71.86 162.19 4,925.68 4,802.38 -7,182.48 2,731.81 5,941,535.86 520,249.29 MWD+IFR-AK-CAZ-SC(3) 10,211.07 71.96 162.19 4,954.42 4,831.12 -7,266.24 2,758.72 5,941,452.17 520,276.39 MWD+IFR-AK-CAZ-SC(3) 10,302.93 71.87 162.58 4,982.93 4,859.63 -7,349.47 2,785.14 5,941,369.01 520,303.01 MWD+IFR-AK-CAZ-SC(3) 10,395.84 71.87 161.99 5,011.85 4,888.55 -7,433.58 2,812.01 5,941,284.98 520,330.07 MWD+IFR-AK-CAZ-SC(3) 10,490.00 71.93 162.00 5,041.10 4,917.80 -7,518.70 2,839.67 5,941,199.93 520,357.93 MWD+IFR-AK-CAZ-SC(3) 10,586.12 71.96 162.08 5,070.89 4,947.59 -7,605.63 2,867.85 5,941,113.07 520,386.31 MWD+IFR-AK-CAZ-SC(3) 10,682.96 71.93 161.91 5,100.90 4,977.60 -7,693.19 2,896.31 5,941,025.58 520,414.97 MWD+IFR-AK-CAZ-SC(3) 10,778.42 71.96 161.80 5,130.49 5,007.19 -7,779.44 2,924.58 5,940,939.41 520,443.43 MWD+IFR-AK-CAZ-SC(3) 10,871.75 71.99 161.70 5,159.37 5,036.07 -7,863.73 2,952.37 5,940,855.20 520,471.42 MWD+IFR-AK-CAZ-SC(3) 10,963.94 72.17 161.50 5,187.73 5,064.43 -7,946.96 2,980.06 5,940,772.04 520,499.30 MWD+IFR-AK-CAZ-SC(3) 11,056.98 72.01 162.57 5,216.35 5,093.05 -8,031.17 3,007.36 5,940,687.90 520,526.79 MWD+IFR-AK-CAZ-SC(3) 11,150.69 71.98 161.92 5,245.31 5,122.01 -8,116.05 3,034.54 5,940,603.10 520,554.17 MWD+IFR-AK-CAZ-SC(3) 11,242.30 72.15 161.80 5,273.52 5,150.22 -8,198.87 3,061.68 5,940,520.34 520,581.49 MWD+IFR-AK-CAZ-SC(3) 11,335.08 72.14 161.57 5,301.97 5,178.67 -8,282.71 3,089.43 5,940,436.58 520,609.44 MWD+IFR-AK-CAZ-SC(3) 11,428.00 72.02 161.75 5,330.56 5,207.26 -8,366.63 3,117.25 5,940,352.73 520,637.45 MWD+IFR-AK-CAZ-SC(3) 11,520.79 72.01 162.18 5,359.21 5,235.91 -8,450.55 3,144.57 5,940,268.88 520,664.96 MWD+IFR-AK-CAZ-SC(3) 11,613.90 72.22 162.37 5,387.81 5,264.51 -8,534.96 3,171.55 5,940,184.55 520,692.13 MWD+IFR-AK-CAZ-SC(3) 11,705.68 72.59 163.66 5,415.55 5,292.25 -8,618.63 3,197.10 5,940,100.95 520,717.88 MWD+IFR-AK-CAZ-SC(3) 11,798.09 73.02 166.16 5,442.87 5,319.57 -8,703.85 3,220.08 5,940,015.78 520,741.05 MWD+IFR-AK-CAZ-SC(3) 12/16/2014 6:26:40PM Page 5 COMPASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/-S +E/-W Northing Fasting (usft) (°) (°) (usft) (usft) (usft) (usft) 130.00 usft tool name 11,891.17 73.04 168.18 5,470.04 5,346.74 -8,790.65 3,239.85 5,939,929.04 520,761.02 MWD+IFR-AK-CAZ-SC(3) 11,982.58 72.83 169.49 5,496.87 5,373.57 -8,876.38 3,256.77 5,939,843.36 520,778.14 MWD+IFR-AK-CAZ-SC(3) 12,075.85 72.31 171.00 5,524.81 5,401.51 -8,964.08 3,271.85 5,939,755.70 520,793.42 MWD+IFR-AK-CAZ-SC(3) 12,168.72 72.30 174.63 5,553.04 5,429.74 -9,051.84 3,282.91 5,939,667.97 520,804.69 MWD+IFR-AK-CAZ-SC(3) 12,260.70 72.86 176.00 5,580.58 5,457.28 -9,139.31 3,290.08 5,939,580.53 520,812.06 MWD+IFR-AK-CAZ-SC(3) 12,352.13 73.15 178.21 5,607.31 5,484.01 -9,226.63 3,294.49 5,939,493.23 520,816.67 MWD+IFR-AK-CAZ-SC(3) 12,445.90 73.63 180.86 5,634.12 5,510.82 -9,316.47 3,295.22 5,939,403.40 520,817.61 MWD+IFR-AK-CAZ-SC(3) 12,538.80 74.05 183.33 5,659.98 5,536.68 -9,405.63 3,291.96 5,939,314.24 520,814.55 MWD+IFR-AK-CAZ-SC(3) 12,631.67 74.65 183.87 5,685.03 5,561.73 -9,494.88 3,286.34 5,939,224.99 520,809.15 MWD+IFR-AK-CAZ-SC(3) 12,724.30 75.00 184.77 5,709.28 5,585.98 -9,584.03 3,279.61 5,939,135.83 520,802.62 MWD+IFR-AK-CAZ-SC(3) 12,815.88 75.47 186.38 5,732.62 5,609.32 -9,672.16 3,271.00 5,939,047.69 520,794.22 MWD+IFR-AK-CAZ-SC(3) 12,909.47 76.01 187.07 5,755.67 5,632.37 -9,762.24 3,260.38 5,938,957.59 520,783.81 MWD+IFR-AK-CAZ-SC(3) 13,003.63 76.15 187.49 5,778.33 5,655.03 -9,852.90 3,248.80 5,938,866.92 520,772.44 MWD+IFR-AK-CAZ-SC(3) 13,096.52 76.12 187.43 5,800.58 5,677.28 -9,942.32 3,237.09 5,938,777.48 520,760.94 MWD+IFR-AK-CAZ-SC(3) 13,188.97 76.18 186.95 5,822.72 5,699.42 -10,031.38 3,225.85 5,938,688.41 520,749.91 MWD+IFR-AK-CAZ-SC(3) 13,280.25 76.18 186.38 5,844.52 5,721.22 -10,119.42 3,215.57 5,938,600.35 520,739.83 MWD+IFR-AK-CAZ-SC(3) 13,372.64 76.15 186.73 5,866.61 5,743.31 -10,208.54 3,205.33 5,938,511.22 520,729.80 MWD+IFR-AK-CAZ-SC(3) 13,466.09 76.03 186.29 5,889.08 5,765.78 -10,298.66 3,195.04 5,938,421.08 520,719.73 MWD+IFR-AK-CAZ-SC(3) 13,558.31 76.06 186.11 5,911.32 5,788.02 -10,387.64 3,185.38 5,938,332.09 520,710.27 MWD+IFR-AK-CAZ-SC(3) 13,650.26 78.09 185.58 5,933.45 5,810.15 -10,476.42 3,176.29 5,938,243.29 520,701.39 MWD+IFR-AK-CAZ-SC(3) 13,742.97 76.09 185.79 5,955.73 5,832.43 -10,565.97 3,167.37 5,938,153.73 520,692.68 MWD+IFR-AK-CAZ-SC(3) 13,835.25 76.24 185.70 5,977.80 5,854.50 -10,655.12 3,158.40 5,938,064.57 520,683.92 MWD+IFR-AK-CAZ-SC(3) 13,928.16 76.12 185.53 5,999.99 5,876.69 -10,744.91 3,149.58 5,937,974.77 520,675.30 MWD+IFR-AK-CAZ-SC(3) 14,020.86 76.18 185.37 6,022.18 5,898.88 -10,834.51 3,141.03 5,937,885.16 520,666.96 MWD+IFR-AK-CAZ-SC(3) 14,113.19 76.30 184.16 6,044.15 5,920.85 -10,923.88 3,133.58 5,937,795.79 520,659.72 MWD+IFR-AK-CAZ-SC(3) 14,205.59 76.11 184.12 6,066.18 5,942.88 -11,013.38 3,127.10 5,937,706.28 520,653.45 MWD+IFR-AK-CAZ-SC(3) 14,299.19 76.23 184.66 6,088.55 5,965.25 -11,104.00 3,120.14 5,937,615.65 520,646.71 MWD+IFR-AK-CAZ-SC(3) 14,391.83 6\.,g 76.79 185.75 6,110.16 5,986.86 -11,193.71 3,111.97 5,937,525.93 520,638.74 MWD+IFR-AK-CAZ-SC(3) 14,484.97/ 79.23 187.45 6,129.51 6,006.21 -11,284.20 3,101.49 5,937,435.42 520,628.48 MWD+IFR-AK-CAZ-SC(3) 14,547.71 81.42 188.70 6,140.06 6,016.76 -11,345.43 3,092.80 5,937,374.18 520,619.93 MWD+IFR-AK-CAZ-SC(3) 14,604.00 83.06 189.62 6,147.66 6,024.36 -11,400.49 3,083.93 5,937,319.11 520,611.18 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9.7/8" 14,615.84 83.40 189.81 6,149.06 6,025.76 -11,412.08 3,081.94 5,937,307.51 520,609.23 MWD+IFR-AK-CAZ-SC(4) 14,709.90 86.89 189.20 6,157.02 6,033.72 -11,504.50 3,066.47 5,937,215.07 520,593.97 MWD+IFR-AK-CAZSC(4) 14,804.76 89.06 188.88 6,160.37 6,037.07 -11,598.12 3,051.57 5,937,121.42 520,579.29 MWD+IFR-AK-CAZSC(4) 14,899.53 88.90 188.42 6,162.05 6,038.75 -11,691.79 3,037.32 5,937,027.72 520,565.26 MWD+IFR-AK-CAZ-SC(4) 14,994.39 89.04 187.54 6,163.76 6,040.46 -11,785.72 3,024.16 5,936,933.78 520,552.32 MWD+IFR-AK-CAZ-SC(4) 15,089.96 89.96 186.30 6,164.59 6,041.29 -11,880.59 3,012.64 5,936,838.89 520,541.02 MWD+IFR-AK-CAZ-SC(4) 15,184.52 90.23 185.70 6,164.44 6,041.14 -11,974.63 3,002.76 5,936,744.84 520,531.36 MWD+IFR-AK-CAZ-SC(4) 15,280.33 87.97 188.24 6,165.94 6,042.64 -12,069.70 2,991.14 5,936,649.74 520,519.96 MWD+IFR-AK-CAZ-SC(4) 15,374.59 86.72 186.69 6,170.31 6,047.01 -12,163.06 2,978.90 5,936,556.37 520,507.94 MWD+IFR-AK-CAZ-SC(4) 12/16/2014 6:26:40PM Page 6 COMPASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5©123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/-5 +E/-W Northing Easting (usft) (°j (°) (usft) (usft) (usft) (usft) 169.00 usft tool name 15,469.97 87.90 187.34 6,174.78 6,051.48 -12,257.62 2,967.27 5,936,461.79 520,496.53 MWD+IFR-AK-CAZ-SC(4) 15,564.59 88.66 187.16 6,177.62 6,054.32 -12,351.44 2,955.33 5,936,367.95 520,484.81 MWD+IFR-AK-CAZ-SC(4) 15,655.63 88.97 186.43 6,179.51 6,056.21 -12,441.82 2,944.56 5,936,277.56 520,474.26 MWD+IFR-AK-CAZ-SC(4) 15,750.39 88.69 186.43 6,181.44 6,058.14 -12,535.96 2,933.95 5,936,183.40 520,463.87 MWD+IFR-AK-CAZ-SC(4) 15,844.57 88.04 186.21 6,184.13 6,060.83 -12,629.53 2,923.59 5,936,089.81 520,453.72 MWD+IFR-AK-CAZ-SC(4) 15,939.82 87.94 185.92 6,187.47 6,064.17 -12,724.19 2,913.53 5,935,995.14 520,443.88 MWD+IFR-AK-CAZ-SC(4) 16,036.46 86.91 186.09 6,191.81 6,068.51 -12,820.20 2,903.43 5,935,899.12 520,434.01 M1N13+IFR-AK-CAZ-SC(4) 16,131.54 86.59 183.82 6,197.20 6,073.90 -12,914.77 2,895.23 5,935,804.54 520,426.03 MWD+IFR-AK-CAZ-SC(4) 16,225.28 88.30 181.42 6,201.38 6,078.08 -13,008.31 2,890.95 5,935,711.00 520,421.97 MWD+IFR-AK-CAZ-SC(4) 16,320.57 87.90 179.13 6,204.54 6,081.24 -13,103.54 2,890.50 5,935,615.78 520,421.73 MWD+IFR-AK-CAZ-SC(4) 16,413.76 87.46 178.86 6,208.31 6,085.01 -13,196.64 2,892.13 5,935,522.70 520,423.58 MWD+IFR-AK-CAZ-SC(4) 16,509.31 87.11 179.05 6,212.84 6,089.54 -13,292.06 2,893.87 5,935,427.28 520,425.55 MWD+IFR-AK-CAZ-SC(4) 16,604.01 88.07 178.97 6,216.82 6,093.52 -13,386.66 2,895.51 5,935,332.70 520,427.40 MWD+IFR-AK-CAZ-SC(4) 16,695.76 89.79 180.87 6,218.54 6,095.24 -13,478.39 2,895.63 5,935,240.98 520,427.74 M1ND+IFR-AK-CAZ-SC(4) 16,791.87 91.25 180.92 6,217.66 6,094.36 -13,574.48 2,894.13 5,935,144.89 520,426.46 MWD+IFR-AK-CAZ-SC(4) 16,887.00 90.61 180.08 6,216.12 6,092.82 -13,669.59 2,893.30 5,935,049.79 520,425.85 MWD+IFR-AK-CAZ-SC(4) 16,980.71 89.86 179.19 6,215.74 6,092.44 -13,763.30 2,893.90 5,934,956.09 520,426.67 MWD+IFR-AK-CAZ-SC(4) 17,075.12 89.65 178.78 6,216.14 6,092.84 -13,857.69 2,895.57 5,934,861.71 520,428.56 MWD+IFR-AK-CAZ-SC(4) 17,169.92 89.89 177.28 6,216.52 6,093.22 -13,952.44 2,898.83 5,934,766.99 520,432.04 MWD+IFR-AK-CAZ-SC(4) 17,265.58 91.17 175.44 6,215.63 6,092.33 -14,047.89 2,904.90 5,934,671.56 520,438.33 MWD+IFR-AK-CAZ-SC(4) 17,360.73 91.32 174.43 6,213.57 6,090.27 -14,142.65 2,913.30 5,934,576.83 520,446.95 MWD+IFR-AK-CAZ-SC(4) 17,455.27 89.24 173.31 6,213.11 6,089.81 -14,236.64 2,923.40 5,934,482.87 520,457.26 MWD+IFR-AK-CAZ-SC(4) 17,549.24 88.94 173.32 6,214.60 6,091.30 -14,329.96 2,934.33 5,934,389.59 520,468.42 MWD+IFR-AK-CAZ-SC(4) 17,644.62 87.56 173.40 6,217.51 6,094.21 -14,424.65 2,945.36 5,934,294.93 520,479.66 MWD+IFR-AK-CAZ-SC(4) 17,738.13 87.70 175.82 6,221.38 6,098.08 -14,517.66 2,954.13 5,934,201.95 520,488.65 MWD+IFR-AK-CAZ-SC(4) 17,832.78 87.53 178.58 6,225.32 6,102.02 -14,612.11 2,958.75 5,934,107.52 520,493.49 MWD+IFR-AK-CAZ-SC(4) 17,927.45 88.14 178.78 6,228.89 6,105.59 -14,706.68 2,960.93 5,934,012.96 520,495.89 M1N3+IFR-AK-CAZ-SC(4) 18,021.47 88.81 180.58 6,231.40 6,108.10 -14,800.66 2,961.46 5,933,918.99 520,496.63 MWD+IFR-AK-CAZ-SC(4) 18,115.83 87.57 180.80 6,234.38 6,111.08 -14,894.97 2,960.32 5,933,824.70 520,495.71 M1ND+IFR-AK-CAZ-SC(4) 18,210.47 89.71 181.28 6,236.62 6,113.32 -14,989.56 2,958.60 5,933,730.11 520,494.22 MWD+IFR-AK-CAZ-SC(4) 18,302.53 89.64 181.33 6,237.14 6,113.84 -15,081.60 2,956.51 5,933,638.08 520,492.34 MWD+IFR-AK-CAZ-SC(4) 18,395.59 91.56 182.08 6,236.17 6,112.87 -15,174.60 2,953.74 5,933,545.07 520,489.78 MWD+IFR-AK-CAZ-SC(4) 18,491.05 91.23 180.93 6,233.85 6,110.55 -15,270.00 2,951.23 5,933,449.68 520,487.50 MWD+IFR-AK-CAZ-SC(4) 18,585.54 91.40 180.01 6,231.68 6,108.38 -15,364.46 2,950.46 5,933,355.23 520,486.94 MWD+IFR-AK-CAZ-SC(4) 18,680.26 91.15 178.93 6,229.57 6,106.27 -15,459.15 2,951.33 5,933,260.55 520,488.04 MWD+IFR-AK-CAZ-SC(4) 18,774.88 89.09 179.35 6,229.37 6,106.07 -15,553.76 2,952.75 5,933,165.96 520,489.68 MWD+IFR-AK-CAZ-SC(4) 18,868.29 89.00 178.84 6,230.93 6,107.63 -15,647.14 2,954.23 5,933,072.59 520,491.37 MWD+IFR-AK-CAZ-SC(4) 18,962.56 88.56 178.42 6,232.94 6,109.64 -15,741.36 2,956.48 5,932,978.38 520,493.84 MWD+IFR-AK-CAZ-SC(4) 19,055.89 88.93 178.56 6,234.98 6,111.68 -15,834.64 2,958.94 5,932,885.12 520,496.52 MWD+IFR-AK-CAZ-SC(4) 19,150.95 88.32 177.80 6,237.26 6,113.96 -15,929.62 2,961.96 5,932,790.15 520,499.76 MWD+IFR-AK-CAZ-SC(4) 12/16/2014 6:26:40PM Page 7 COMPASS 5000.1 Build 65 Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2F-21 Project: Kuparuk River Unit TVD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: rig:95.8+27.5 @ 123.30usft(Doyon 141) Well: 2F-21 North Reference: True Wellbore: 2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21 Database: OAKEDMP2 Survey Measured Vertical TVD Below Map Map Depth Inclination Azimuth Depth System +N/-S +EI-W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) 210.00 usft tool name 19,246.32 87.46 179.35 6,240.77 6,117.47 -16,024.89 2,964.33 5,932,694.90 520,502.35 MVVD+IFR-AK-CAZ-SC(4) 19,340.03 86.20 180.73 6,245.95 6,122.65 -16,118.46 2,964.26 5,932,601.34 520,502.50 MWD+IFR-AK-CAZ-SC(4) 19,434.63 87.83 180.50 6,250.88 6,127.58 -16,212.92 2,963.25 5,932,506.89 520,501.71 MWD+IFR-AK-CAZ-SC(4) 19,530.29 88.44 179.68 6,253.99 6,130.69 -16,308.53 2,963.10 5,932,411.29 520,501.78 MWD+IFR-AK-CAZ-SC(4) 19,624.88 87.25 180.19 6,257.55 6,134.25 -16,403.05 2,963.21 5,932,316.78 520,502.11 MWD+IFR-AK-CAZ-SC(4) 19,719.86 86.75 179.95 6,262.52 6,139.22 -16,497.90 2,963.09 5,932,221.94 520,502.21 MWD+IFR-AK-CAZ-SC(4) 19,814.56 90.14 178.89 6,265.09 6,141.79 -16,592.54 2,964.05 5,932,127.30 520,503.39 MWD+IFR-AK-CAZ-SC(4) 19,909.59 92.17 179.04 6,263.18 6,139.88 -16,687.53 2,965.77 5,932,032.33 520,505.33 MWD+IFR-AK-CAZ-SC(4) 20,004.29 92.51 178.95 6,259.31 6,136.01 -16,782.14 2,967.43 5,931,937.74 520,507.21 MWD+IFR-AK-CAZ-SC(4) 20,098.92 91.33 179.79 6,256.14 6,132.84 -16,876.71 2,968.46 5,931,843.18 520,508.47 MWD+IFR-AK-CAZ-SC(4) 20,193.85 89.72 180.82 6,255.27 6,131.97 -16,971.63 2,967.96 5,931,748.27 520,508.18 MWD+IFR-AK-CAZ-SC(4) 20,274.00 89.72 180.82 6,255.66 6,132.36 -17,051.77 2,966.81 5,931,668.13 520,507.22 PROJECTED to TD 4112"x6-314" 12/16/2014 6:26:40PM Page 8 COMPASS 5000.1 Build 65 Cement Detail Report •a 2F-21 ConocoPhil lips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 9/24/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/15/2014 15:30 11/15/2014 19:30 2F-21 Comment Line up to SLB, pump 5 bbls H2O&PT lines to 4000 psi. Pump 40 bbls CW100,40 bbls 11.5 ppg Mudpush II. Drop bottom plug, pump 107 bbls of 15.8 ppg cement. Drop top plug&pump 10 bbl H20. Swap to rig pumps for displacement. Displace cement with 656 bbls 10.5 ppg mud,4.5 bpm, ICP 200 psi, FCP 850 psi. Bump plug&psi up 500 psi to 1350 psi,holding for 5 min. Bled off,floats tested good.CIP 19:13 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 11,660.0 14,617.0 No Yes Yes Cement Q Pump Mit(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 5 5 850.0 950.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to SLB, pump 5 bbls H2O&PT lines to 4000 psi. Pump 40 bbls CW100,40 bbls 11.5 ppg Mudpush II. Drop bottom plug, pump 107 bbls of 15.8 ppg cement. Drop top plug&pump 10 bbl H20. Swap to rig pumps for displacement. Displace cement with 656 bbls 10.5 ppg mud,4.5 bpm, ICP 200 psi, FCP 850 psi. Bump plug&psi up 500 psi to 1350 psi, holding for 5 min. Bled off,floats tested good.CIP 19:13 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 9,745.0 10,792.0 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.33 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 10,792.0 11,839.0 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 11,839.0 14,617.0 518 G 107.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 89.1 7.50 1,445.0 Additives Additive Type Concentration Conc Unit label Retarder 0.2 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.3 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control _ D167 _ 0.01 gal/sx Additive Type Concentration Conc Unit label CemNet D974 Page 1/1 Report Printed: 12/24/2014 Cement Detail Report ►a 2F-21 ConocoPh'iltiips Aixkn String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/24/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/25/2014 16:45 10/25/2014 20:15 2F-21 Comment Pump 5bbls H2O, psi test lines 300/4000 psi on chart f/5 min. Good. Pump 100 bbls 10.5 ppg MUDPUSH II @ 6 bpm, 100 psi. Drop bottom plug. Pump 530 bbls of 11 ppg, DeepCRETE cement,6 bpm, 225 psi. Drop top plug ahead of tail cement. Pump 8 bbl tail cement&shut down. Confer with town. Pump 10 bbls H2O,shut down&swap to rig. Displace cement with 9.6ppg mud w/rig pumps @ 6 bpm, ICP 500 psi, FCP 750 psi, slow pumps to 3 bpm, 500 psi. bump plug with 3565 strokes. Pressure up to 1200 psi&hold for 5 min.Check floats,Good.CIP at 20:15 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 30.0 4,006.0 No 140.0 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) 5 7 7 750.0 1,200.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Top plug dropped ahead of tail cement. Pumped 8 bbls tail before shutting down. Swapping to H2O,then displacing with 9.6 ppg mud from rig.TOC inside casing should be—3821'. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 100.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Surface Cement 30.0 4,006.0 1,590 G 541.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.75 11.00 94.1 0.00 50.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant LT D185 0.07 gal/sx Page 1/1 Report Printed: 12/24/2014 214136 25162 ConocoPhil!ips RECEIVED TRANSMITTAL DEC 11 2014 CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender AOGCC ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 DATA LOGGED t2 h 5/2014 RE: 2F-21 K BENDER DATE: 012/11/2014 Tr, ansmitted: Kuparuk River Unit, Alaska {�2F-21 I�1 hardcopy report and 1 CD r CANRIG Final well report mud logging data for 2F-21, 12/5/2014; 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, Formation log MD&TVD ;Gas ratio MD&TVD n n � 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.Lemkeca)COP.com CC: 2F-21 transmittal folder, production well files, eSearch 6Receipt: MAL-#7.42L7/) 6144it: 615-Technical Data Management I ConocoPhillips 'Anchorage, Alaska I Ph: 907265.6947 m_'rt y. y^�a-rvmn. - --'° ani•. ., .. ., wa„ - - .. ...--... z A 'f_ 333 lve;t Se ve! tr 3 e ry -` Ci(l\'1.12`.o �; .;N T .a 1Z\I-.1 K°„_,.._ Ancbcrcge Alaska ve 995G'-357_ =r a,_.f.."i ''j r, CO? S17 '7r-' „ /-L-1, 1°' G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2F-21 ConocoPhillips Alaska, Inc. Permit No: 214-136 Surface Location: 171' FNL, 1731' FEL, SEC. 33, T11N, R9E, UM Bottomhole Location: 1444' FNL, 4115' FEL, SEC. 15, T10N, R9E, 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, R4) Pt_t.,5L- Cathy P. Foerster Chair DATED this 2.S day of September, 2014. . __ ...._ .-. RECEWED STATE OF ALASKA SEP 0 5 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL . OGCC 20 AAC 25.005 1a Type of Work: 1 b Proposed Well Class Development-Oil ❑ Service-Win) ❑, Single Zone ❑✓ 1 c Specify if well is proposed for Drill Q' Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redd! ❑ 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. K'lk.•, 2F-21. 3 Address 6 Proposed Depth 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD 20213'• TVD 6224' • 4a Location of Well(Governmental Section): 7.Property Designation(Lease Number)y Kuparuk River Field ' Surface 171'FNL, 1731'FEL, Sec.33,T11 N, R9E, UM • ADL 25657,25666,4264 A Kupruk River Pool• Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date: 1101'FNL, 3938'FEL,Sec 10,T1ON, R9E, UM 2583,2587,2178 9/30/2014 Total Depth: 9.Acres in Property 14 Distance to 1444'FNL,4115'FEL, Sec 15,T1ON, R9E, UM - 2560 Nearest Property 1444' 4b Location of Well(State Base Plane Coordinates-NAD 27). 10.KB Elevation above MSL; , 124 feet 15 Distance to Nearest Well Open Surface:x- 517501 y- 5948711 Zone- 4. GL Elevation above MSL• , 96 feet to Same Pool. 2F-19A,1697 16 Deviated wells: Kickoff depth • 500 • ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle . 90° deg Downhole.3200 psig. Surface'2885 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) 40" 20" 94# K-55 Welded 80' 28' 28' 108' 108' pre-installed 13.5" 10.75" 45.5# L-80 Hydril 563 3859' 26' 26' 3885' 3016' 1521 sx DeepCRETE,195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 14558' 24' 24' 14582' 6152' 428 sx Class G 6 75" 4.5" 11.6# L-80 Hydril 563 5781' 14432' 6134' 20213' 6224' 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 Conductor/Structural Surface Intermediate Production Liner 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 0• 20 AAC 25.050 requirements ❑✓ 21 Verbal Approval: Commission Representative: Date: 22 I hereby certify that the foregoing is true and correct. Contact Haibin Guo @ 265-1487 ' Email Haibin.GuoCo�cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature ., CVL Phone 265-6021 Date cj(+-(2p 14- / Commission Use Only Permit to Drill API Number Permit Approvvaal1^ /' See cover letter Number: C�I w — )3(0 50- 0 Z.q a 3 5 5 —00—00 Date I \'r✓ll ' 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 121" Other: e6 p -re5 t 'k) 3506 P 5- 1 Samples req'd: Yes UNo 2Mud log req'd Yes❑ No g lnrr fin i'SS t61 ,/1n,�7=-114 $tu it- H2S measures: Yes No Directional svy req'd: Yes g No❑ i— n(cwr`rc dd�f 4-C�n Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No Er �t �r`d,Ze' J P R V B THE 9 / / Approved by �7 � -� ~'" COMMISS�I f i N Date: ! _as--/ Form 10-401 (Re4ised 10/2012 This permit is validfdrEintLii/LnDlletfa� pproval(20 AAC 25.005(g)) VI. 8125-! I4• �Oi��iy 4 RECE ' ConocoPhillips Alaska, Inc. f D Post Office Box 100360 SEP 0 5 2014 111.17 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 AOGCC September 02,2014 AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 2F-21,Kuparuk A5 Sand Water Injector Dear Commissioner: I ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots pre-produce water injector well from the 2F pad. The expected spud date for this well is September 30th,2014. It is planned to use Rig Doyon 141. 2F-21 is planned to be a horizontal Kuparuk A5 sand pre-produced water injector. The surface section will be drilled with 13-3/8"bit and run 10-3/4"casing to+/-3,885'MD/3,016'TVD. The intermediate section will be drilled with 9- 7/8"bit and run 7-5/8"liner to+/- 14,582'MD/6,152'TVD in A5 sand.Managed Pressure Drilling(MPD)technology will be utilized to assist with providing stability through the HRZ and Kalubik shale. The production section will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/-20,213'MD/6,224'TVD.MPD will be used in this hole section to prevent wellbore breathing and losing fluid.The upper completion will be run on 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 Haibin Guo at 265-1487 (Haibin.GuoAConocoPhillips.com)or Chip Alvord at 265-6120. Sincerely, •-t..0,/- Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2F-21 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2F-21 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth, Location at Surface 171'FNL, 1731'FEL, Sec 33, T 11N,R009E,UM NGS Coordinates RKB Elevation 123.8'AMSL Northings: 5,948,711.26' Eastings: 517,501.07' Pad Elevation 95.8'AMSL Location at Intermediate 1101' FNL,3938'FEL,Sec 10,T1ON,R009E,UM Casing NGS Coordinates Measured Depth, RKB: 14,582' Northings: 5,937,230.5' Eastings: 520,626.81' Total Vertical Depth, RKB: 6,152' Total Vertical Depth, SS: 6,028' Location at Total Depth 1444' FNL, 4115'FEL, Sec 15,T1ON,R009E,UM NGS Coordinates Measured Depth, RKB: 20,213' Northings: 5,931,607.83' Eastings: 520,476.82' Total Vertical Depth, RKB: 6,224' Total Vertical Depth, SS: 6,100' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated.the application for a Permit to Drill(Form 10--10/)Hurst (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well, Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail, or (B)state that the applicant is the only affected owner The Applicant is the only affected owner. The BHL location is on Lease ADL 392364, 2,560 acres. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each oldie 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(BOPF)as required by 20 AAC 25 035,20 AAC 25.036,or 20 AAC 25 037,as applicable; Please reference BOP schematics on file for Doyon 141. / TJRIGINAL Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient, Estimated reservoir pressure is 3200 psi/10.0 ppg at A5 sand (minimum 2700psi/8.5ppg and maximum 3500 psi/10.9 ppg). The maximum potential surface pressure (MPSP)while drilling 2F-21 is calculated using an estimated maximum reservoir pressure of 3,500 psi (10.9 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A5 sand at 6,152' TVD (WP04): A Sand Estimated. BHP = 3,500 psi A Sand estimated depth(WP06) =6,152' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 615 psi (6,152' TVD * 0.10 psi/ft) MPSP =BHP—gas column =2,885 psi (3,500 psi—615 psi) (B)data on potential gas=ones, The well bore is not expected to penetrate any gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation=ones,and=ones that have a propensity for differential sticking, See attached 2F-21 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25 03009: A procedure is on file with the commission for performing LOT's. ORIGINAL Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any 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) Size (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 40 94 K-55 Welded 80 28 108/108 Cemented to surface Cement to Surface with 10-3/4 1'2 45.5 L-80 H56311 3,859 26 3,885/3,016 1,521 sx DeepCRETE Lead 11.0 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 14 558 24 14,582/6,152 428 sx Class G at 15.8 ppg w/TOC at 563 13,000'MD 4 1/2 6-3/4 11.6 L-80 Hydril 5,781 14,4321 6,134 20,213/6,224 Open hole slotted liner 563 Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); 5-cc a,tfacnrd �l wy ,-� �►-, c f cl t�z fry /-o etc Please reference diverter schematic on file for Doyon 141. ave a - 1/25-/ t Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 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 Mud System Spud Mud LSND FLO-PRO NT Density 8.8-9.4 9.5- 10.5 10.3- 10.5 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. ORIGINAL Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A-Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the folouvng items,except for an rtes: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. 1. MIRU Doyon 141 on 2F-21 conductor. 2. NU and function test diverter system and prepare spud mud. 3. Spud and directionally drill 13-1/2"hole to the 10-3/4" surface using point at+/-3,885' MD/3,016' TVD according to the directional plan. Run MWD/LWD(GR/RES)logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 10-3/4"45.5#L-80 casing.Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. 5. Nipple down diverter and install wellhead and test._Nipple up BOPE and test to 3,500psi.,Chart and record results. 6. PU and RIH 9-7/8"drilling BHA with MWD/LWD(GR/RES)logging tools. Pressure test 10-3/4"casing to 2500 psi x 30 min. Chart and record results. 7. Drill out cement and 20'of new formation.Perform LOT.Minimum acceptable leak-off for drilling ahead is 12.5 ppg EMW. 8. Directionally drill 9-7/8"hole to casing point at+/-14,582' MD/6,152' TVD.Use Manage Pressure Drilling (MPD)technology to assist HRZ and Kalubik shale stability. 9. Change upper rams for 7-5/8"casing and test to 3,500psi. Chart and record results. 10. Run 7-5/8"47#L-80 casing and cement(TOC at+/-13,000' MD). 11. PU and RIH 6-3/4"production hole BHA with MWD/LWD(GR/RES/NEU/DEN/Sonic)logging tools. 12. Engage the pump to activate the sonic log for TOC evaluation of 7-5/8"casing. 13. Tag TOC in casing. Pressure test 7-5/8"casing to 3,500 psi x 30 min. Chart and record results. 14. Drill out cement and 20' new formation and perform LOT. Minimum acceptable leak-off for drilling ahead is 12.5 ppg EMW. 15. Directionally drill 6-3/4"production hole to TD at+/-20,213' MD/6,224' TVD. 16. Run lower completion of 4-1/2"slotted liner, liner top hanger/packer and swell packers for zonal isolation. ORIGINAL 17. Run upper completion of 3-V2, 9.3#,L-80 EUE tubing with GLMs. Space out and land hanger. 18. Test tubing and tubing-casing annulus separately to 3500 psi x 30 min. Chart and record the results. 19. ND BOP and NU X-MAS tree. Test tree and freeze protect annulus. 20. Rig down and move out rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the folloticrng items,except for an item already on file with the commission and identified in the application (14)a general description of hair the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorcation under 20 AAC 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 Well Schematic Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Cement Program ORIGINAL 2F-2-1 INJECTOR SCHEMATIC, (Primary) (Pre-Produce) L 4-1/2"Tubing Hanger/Tree Under Completion ' 1)Tubing Hanger,4'/z'IBTM 20"Conductor to-110' 2)4-'/2'12.6#/ft IBT-M Tubing(1 jts) 3) XO 4-1/"12.6#IBT-M x 3-'/2'9.3#EUE-8rd-M L-80 4)3-'/z'DS Nipple Profile 2.875" . .iii 3-1/2"DS Landing Nipple 5)3-'/2'X 1.5"Camco MMG GLM w/Dummy(x pcs) iiii' 6)3-%"X 1.5"Camco MMG GLM w/DCR-1 (2500 psi casing to tbg shear) 7)Baker CM Sliding Sleeve w/2.813 DS Nipple Profile 65° Dev at 3300 8)Baker Premier Packer w/PBR ftM D / 2822 ftTVD 9)HES Disappearing Plug(Mirage)w/Auto Fill Sub 10)3-'/"DS Nipple Profile 2.75" 11)BOT 80-40 GBH locator(-12 ft seal to seal, 18 seals travel) 73° Dev start at 3578 ftMD Lower Completion e'� 11)Baker 4.5 X 7-5/8"HRD ZXP Liner top Packer A 10-3/4"45.5#L-80 Hydril563 Surface Casing Baker4.5"RS Nipple Hydril-563 BxB @ 3885'MD/3016'TVD Baker 4.5"x 7-5/8"Flex Lock Liner Hanger Hydril-563 cemented to surface 12)4-1/2",11.6#/ft,Hydril-563 Blank Liner 3'/="MMG GLM x 1.5"OD 13)4'/2',11.6#/ft,Hydril-563 Slotted Liner 14)4-1/2",11.6#/ft,Hydril-563 Blank Liner 15)Freecap I FSC-11 6.38"OD Swell Packer 16)4-W,11.6#/ft,Hydril-563 Blank Liner 17)4-W,11.6#/ft,Hydril-563 Slotted Liner 18)4-W,11.6#/ft,Hydril-563 Blank Liner 19)Freecap I FSC-11 6.38"OD Swell Packer /11 3-1/2" 9.3#L-80 EUE 8RD-MOD 20)4'/2',11.6#/ft,Hydril-563 Blank Liner Tubing 21)4'/2',11.6#/ft,Hydril-563 Slotted Liner 22)4-Y2",11.6#/ft,Hydril-563 Blank Liner 23)Freecap I FSC-11 6.38"OD Swell Packer 24)4-"A",11.6#/ft,Hydril-563 Slotted Liner 25) X0 4'/4",12.6#/ft,Hydril-563 x IBT-M 26)4'/2'IBT-M Orange Peel Shoe Planned TOC @ +/-13000'MD Baker CM Sliding Sleeve Baker Premier Packer w/ PBR @14382' HRZ 12819/5710 73° `i `:, \QAli. A7 7-5/8"Flex Lock Liner Hanger/ZXP Top Packer 6.38"x 4-1/2"Swell Packer 6-3/4" Hole TD Kalubik 13455/5876 73° x@14432' @ 20213'MD/ - 6224'TVD Top C 14120/6072 75° 1!.i..i. 44'.* V ' III A5 14582/6152 85° ■ ■ 3'/s"2.75"DS Nipple �•_..i.=,_._ 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"11.6#L-80 Hydril-563 Slotted Liner 3'/"HES Mirage @ 14582'MD/6152'TVD(85°) 4'/2"Orange Disappearing Plug •-5630 ft Hz!Section Peel Shoe NOTE:Swell Packer will be adjusted as necessary ORIGINAL j 1.0:90:$110£-90-“OZj ll1N31VA 01.41Z6S99f00L Ay' LOS IOOZX4blOOd/VA f 7 a.ntlea-tw ee, 3 0l al _ i • �1, ry i S:lS _ fit!! Q.. '0M0 HOLHN ON £§ ary: j ,, _ 1. 1 Y __ ! o--ate_. — - .o-.aSc j $ k I.b.0!! t .b.Yt I .b.Y .0-.Y ...as .b.m .0-.MI .b.a i 1 e i,-� ' A 1 I 1 i : _9 I -Jel 41 I ftII It C)W CEJ t .Y , ` T 4 I (f) p, t!1 I - II• O .--.- I 1 '1E111 Rh ,.,, .., 1--i I II I $ F ! 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' l I a m I U Q I u ti i I e • DI 2F-21 wpO4.1 7.045 Plan Summary SURVEY PROGRAM L�pth From Depth To Survey/Plan Tool 28.00 925.00 2F-21wp04.1 (Plan:2F-21) GYD-GC-SSi / 925.00 1925.00 2F-21wp04.1 (Plan:2F-21) MWD - 4am 925.00 3885.33 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK CAZ SC 2000 3885.33 5385.33 2F-21wp04.1 (Plan:2F-21) MWD 3885.33 14581.55 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SCN 14581.55 16081.55 2F-21wp04.1 (Plan:2F-21) MWD \ /, 0- 14581.55 20213.40 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC -4000 .. -6000 N CASING DETAILS 4000I _macro TVD MD Name Size fzom 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 11200 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 1600° 6223.80 20213.40 4-1/2"x6-3/4" 4-1/2 i-- 1 Top Ugnu(Ugnu C) B2 B 1 A6 A5 L O - - 20"x 42" To)T-3 Sand y 5- Top W Sak D Top Ga .5 10000 10-3/4"x 13-1/2" I I 1 o K-1-5K- Top W Sak Al 7-5/8"z 9-7/8" ---''''''4O ''"4p'0 -a 0 ' Ill �O 7-5/8"x 9-7/8" 4-1/2"%6-3/4" /� N CO O O O\ _ I - y OmOOO0 Base Permafrost K1• ^ o 0 0 i - r p Base HRR ' - O2. 0,1��m ® oI CPU OM,CO ' Base W Sak Top HRZ I - II 0 1111 1111 I I I I_' I 0 IIIIIIIgl '0 .' 4500 9000 13500 180004-1/2"' 6-3/4" 0 2500 5000 7500 10000 12500 15x'50 17500 20"x 42" 10-3/4"z 13-1/2" Measured Depth Horizontal Departure 0 `a - 5 - 330 _ 30 o A� RL7=02;2F-2F -2F-19A 'ill • • - 300 , 00 a 60 ,'w-1,71:.01.2F 9ALY 2F-19 - u) * ' ` 2F19AL3'2F-14 ' d _ ,i� F 7L7s ` Ipp +//41 '�' •c 30 ,, I \-2117, 2F-19PB1 270 90 , - III .,� 4900 - - 2F-19P82 soo - 2F-15 se.- ..00 5 240` - 120 U _ - _.... � 9,999- ago 0 I I 1 I I 1 I I I I 1 I I I 1 I I I I I I I I 1 I 1 1 1 +:�f' 0 2500 5000 7500 10000 12500 15000 17500 20000 210 - 150 15030 - 180 15400 17100 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 -82T-3 Sand 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,90°TF,for 148.34' 10 3 598.34 2.23 90.00 598.30 0.00 2.88 1.50 90.00 0.49 Start 2.5°/100'DLS,0°TF,for 506.66' K-15 4 1105.00 14.89 90.00 1098.30 0.00 78.13 2.50 0.00 13.22 Adjust TF to 81.54°,for 284.42' I-1421 8 5 1389.42 17.39 114.19 1371.80 -17.43 153.54 2.50 81.54 43.16 Hold for 100' Base Permafrost 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 Start 3°/100'DLS,58.28°TF,for 2088.38' 1809.8 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 Hold for 10415.05' 813992.85 72.61 166.54 6036.55-10916.73 3069.83 0.00 0.0011278.70 Start 4°/100'DLS,60.66°TF,for 588.7' Top Ugnu(Ugnu C) 914581.55 85.00 187.00 6151.80-11489.02 3099.91 4.00 60.6611847.84 2F-21 02May14 HG T1 Hold for 20' 1014601.55 85.00 187.00 6153.54-11508.80 3097.48 0.00 0.0011866.92 Start 2.5°/100'DLS,9.49°TF,for 150.72' -2521.8 11 14752.27 88.72 187.62 6161.80-11658.4 3078.33 2.50 9.4912010.77 Hold for 535.71' Top W Sak D 12 15287.98 88.72 187.62 6173.80-12188.89 3007.31 0.00 0.00 12521.95 2F-21 22Oct13 PB T2 Start 2°/100'DLS,-84°TF,for 296.02' -2856.8 W Sak A7 1315584.00 89.34 181.73 6178.82-12483.75 2983.19 2.00 -84.0012808.48 Hold for 1128.74' 2 1416712.74 89.34 181.73 6191.80-13611.90 2949.07 0.00 0.0013914.60 2F-21 22Oct13 PB T3 Start 2°/100'DLS,-70.78°TF,for 103.86' 1516816.60 90.03 179.77 6192.37-13715.74 2947.70 2.00 -70.7814016.72 Hold for 1296.32' 1618112.92 90.03 179.77 6191.80-15012.05 2952.88 0.00 0.0015295.22 2F-21 22Oct13 PB T4 Start 2°/100'DLS,143.72°TF,for 56.47' 17 18169.39 89.11 180.44 6192.22-15068.52 2952.78 2.00 143.7215350.86 Hold for 2044.01' 18 20213.40 89.11 180.44 6223.80-17112.23 2937.11 0.00 0.0017362.46 2F-21 22Oct13 PB T5 TD:20213.4'MD,6223.8'TVD Base W Sak - C-4 A5 Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 T M Depth Reference: Plan:95.8+28 @ 123.80usft(Doyon 141) Magnetic Model Date: 03-Oct-14 System(SS)Reference: Mean Sea Level Magnetic c Direction a True Y To convert a Magnetic D rection to a True Direction,Add 19.13°East Ground Level/Mud Line: 95.80 Rig: Doyon 141 trror creating xbL parser for script. 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ORIGINAL c a 1 co a CC O r2'-' co E 0 — C—' x C C 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 Y C- CZ N N N N N N N N N N N N CO N N N CU 0 N 42 N N N N N CO (C W CC CC CLCY CL CC CC W K CLCYCC CC CC CC CCCC CC CLCC CC CC 2 2 CC i Q z co `0 0 0 0 0 0 0 0 0 0 0 0 0 000000 000000 0 a 'CU m 'm 'm 'm 'm 'm m 'm 'm 'm 'm 'm m 'm 'm 'm 'm 'm m 'm 'm 'm 'm '(a m Q to 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 Cn N 0 Cl) N N CO NN CO N CO CO CO CO CO CO CO CO CO N CO CO CO N N N N Cl) CO co CO CO CO CO CO CO CO CO CO CO CO 61 CO 65 CO CO CO 00 CO CO CO CO CO CO CO a a CL LL n_ a a CL CL CL LL CL a a a a a CL LL LL CI. O d 0- a .0 Ow C O O C.) a 0mE ` ` ` ` `o ` U U U oCU U U `) o U U U U 0 CU U ° oU V` 0 ° 0 U ) 0 CO E CU c , c , c , c , c (, cC, cCcCc , C „ C , C , c U C LL o LL CO LL N LL CO LL CO LL N LL CO LL CO LL CO LL CO LL CO LL 61 LL 00 ,) N ,) N ,) N ,) N ,) J) ,) N ,) N ,) N N N 0) N 0) N O) N 0) U) E U O U U U U U U U 0 U U O U U 0 U E C c c c c c c c C C C C C E c0 N 2 N N N N N N N N N N N 10 N 2 N N 0) (0 0) (0 0) CO N Z CU C (0 . (0 C (0 C N C CO C CU C CU CO . N C N C CO C CU C (0 O 0) N 0) N 0) N 0) N N O 0) O 0 N o N 0) O 0) N N O O) N 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 0 co co O) O O O — O O M N 00 CO O D) CO t• 1� tO N V N CU CO M _ O t- CO V M V 1` CO M V CO N CO M N C) V N N N U O N (O 0) tO N t0 N t0 N 60 N O CO CO CO V Co O CO. CO CO M CO C 0 CO CO CD N V CO CO CO CO CO CO CO CO O O) O) O M C) Ni co CO N CO N ` U V .- s- r . . . . . . s- s- N t- N (0 (0 CU Li- t) 0 0 0 0 0 0 C. 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 000000 O O O O O O 000000 O o 6 0 6 o o CO o 6 0 6 0 6 o 6 o 0 0 0 o 6 o 0 o 6 o • -15, t0 N O N O CO N CO N t0 N CO N CO 1� t0 CO CO CO CO 1� CO O CO N CO „ te' N V CO M O O O O O O O O O V CO t- CO t- 1..... M CO M R ti", N 00 ,_ ,_ y 0 7 p� V ✓ CO co M O .- N t` CO N 1- N. CA CO V O V CP N CO CO N V CO V C N W CD O V O W 0 0 0 0 0 CI) N N CO V O N CO (O CO CO 01 O 0 V V CA (O O CA O CA t7 t] O C) V V ti CO 1` N CO CO to (O CO (O CO N CO CO N CO CO CO CO CO CO CO (O CO N N CO CO N N N t- CO N M M M a` co ,- ,- N N N N NINNNNN NN 05 c W a co 0 O CD CO CO O N N- CD N. (0 N. C n I CO N O CO 0 0 O CO 0 N- O CO O N .O V O V CO CO CO CO CO CO 0 N CO 1` CO COC-CO CO 0 O CO o M CO CO M V 01 V Di V Oi V Oi V V 01 CO CO CO (O CO CO CO Cn C) C(1 La o O LN CA N CO V V V V O N V V V V V N- V O) V V03 N O.Z{' 0 V CO CO 0 _ _ _ _ N N V CO .- co •- CO M CO co Q 2 0 N d V E N V N N CO .- M ,- M M 1- M CO 0-- (0 V N- CO V0 N N CA Cr CA C CO CC) CO C) CO T N CA N C) N 0) N M 1� N CO N C 1,- N 1` 1' 0) O D) E CU COV V O CO n CO 1. CO r CO n N co O O CO O CA N Oi N C) CO C7 N 7 U CO CO CO CO N- N- r N. N. N. N- r V V 0) CA M M N M CO CO V V V •C E N y O t- N N N N NNNNNN NN (0 2 N O .0 ca O a 0 d r3 co CD CO CO 0 N N- 0.- 1 C N. CO N O CO O O O CO 0 Q 0 CO 0 CL d D O a V CO CO CD T- (O ' CO Co O N CO r CO CO CO - CO O O CO O GL C4 N y hN CO CO V OV OV OV Oi V V Di CO CO CO CO CO CD CO CO Oi CO A N co V V V V O N V V V V V N V CO V V FS o m a to 7 O Cr t0 O C.NI V CO ,— CO (° M t0 CO O _ ‘.- ..- _ N • Nw a 2 LL 2 NL• `4 0 r N a. C O r ? E N .T. N NI (0 LL N.. 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N r--� Co G CO = Q x U) C) 2 T. o C Ut Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y ..NC • C- N N N N N N N N N N N N N N N N N N N N N N H_1 0 N V_ et =' m • 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 Q o. o 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 co cn N N N N N N N N N N N N N N N N N N N N N N MOW Co N N N N N Cl) N N N N N N N N N N N N N N N N N N N CO CO CU 01 CO CO CO CO CO CU CO CO C0 C0 C0 0 CO C0 CU CO C0 CO CO CO CO a a a a. a a a a a a a a a a a a a a a CL d CL a a a ..0 CL C O o u a O m E `o m `0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 `o U) `o `,13 o` o t o ti 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U 0 U v v O m E o c C0 c C0 c CO c CO C C0 C N c N C0 CO CO CO o c CO coo U 2 C LL (6 LL CO LL N LL El LL 0 LL O LL CO LL LL LL LL LL LL f6 LL N CL Li- g L N y 4) O N N N U) N O N O N o N U) O U) U) U) N N O N O N G () o 0 p o 0 2 0 c) 0 () .0 o 0 U U c) U U U p o p U o E C C C C C C C C C C C C C C C C E CO U) N U) CO U) CO U) CO U) CO U) N U) W l6 CO C0 CO CO U) CO N CO N O CU C (0 ' O C O C co C co C O C O O O N N CO C l6 C co N 6 U) O N O U) O N O N O N O N O U) N N N U) U) O U) O N N 00000 000000 00000 000000 000 V N V V I,- I,- CO N. 6) N. CO V CO 'R CO 0 O C) 0 0) 00 W N N N 0) 0 N N N C) 0) 0) 6) 0) r N. N- r C) V C) V I,- O C) L CO CO V CO I,- CO I,- CO r C) O C) 6) CO CO CO CO CO N CO CO CO N C 0 .13 - - N .-,,.1; V N O N C) r OC) r N N N N N N N N N 7 E VLdL 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 a 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 C 6O 6 O 6 O 6 O U O U O 6 O u) 6 u7 u) 6 N N 6 6 6 6 6 O O O O L N CO N U) N )O N. LO N- )O N. LO N. LO N- N I- N r n n O r O N Cq a (O co 6 co LO N N N N NN N N N N N CO N COC) 10 y N r r r r r r r r r r CI p� V CO V W I� I,- )O 11- U) CO CO CO CO V N V N N C LO r LO N I,- CO N N N N O N CD N CO O r N r I- 01 N- 01 N O co y M co M co co 0 O O O 0 O O O O O co co co co M co co M M r- a a r r r r «) LT a U) co 0 CO O CD O CD 0 C) 0 0 0 0 0 0) 0 CO n I,- I,- N- N C) CO C) CO CO M a CO 0 CO 0 CO CO r CO r CO N- O I- CO N- I,- r r r r r 0 r 0 V 0) Cn O 6 C) (O O (O O (O O (O O (O O N N N N N V Co V' m N a O L V t co co C) CD C) CO C) CO CO CD (O (O (O CO CO V CO V CO N m N .$ LC) co Lo co l0 N N N N N N NNNNNN N N C7 Q CU y N r r r r r r r r r r o- a) V C) V CO CO CO 0) CO 0) CO O CO C) I- I,- I,- n I,- N r N r 1` C 0 CO 0 O 0 C) 7 O V O 7 0) V 0) V 0) 0) 01 0 0) 0 r 0 r O • EN CC) C) 6C U V CO V CO V CO V O V CO r I` r N- N- m N O W O N O C) C V V V V 0 co co co O O O O 0 O 10 10 6 10 CO CO (O (O Ln C) C E CU N r r r r o N _C CO a o (O ^ O (D O (O 0 0) 0 6) O 0) O C)) O CO N. I� N. N. I- C) CO C) CO CO 0. O a CO 0 CO 0 CO CO I,- CO n CO i� CO I,- CO I,- N- I,- N- I,- n r 0 r O Z. a 112 L O) CO CO CO C) CO O CO O CO O CO O CO O N N N N N V 6 4 N N C 4 = y 4,a O O V r C) CO C) CO C) CD C) N C) (N NO N N `EN' N N N N N nC) E o WA rr r rrr r r .- r cm taO .-- 11 N L▪ N L $ c:1 d O t ? r E CU N C N R i7 LL O N N O N cc a r o rn N ) O. 7 N 0) 0 0 U) Li_ CL N N C d N d R . N L U E R w Z N o a o c m c r2 A O l0 t g a 0 a 0 0 0 0 0 0 0 o n. W dN N Q Cp a 7 V d J J J I.-, J J J J m m J J J m lb m m N aL O 3 N- r r n N W CO CO a d Q Q Q a d da. co Q. z, N a . J r r r r J J r r r r 0 0 0 0 0 0 0 O r Q) E Y M $ U) � LL LL LL LL CO CO IL LL LL LL 7 7 < CCA/ .X N N N N N O LL LL N N N N N N O '- N N N N N N N et- o ' r r r 1 1 1 i C CL O N (C Z N O O O O LL LL N N O O O O ' ' a N ' 1N 1 N N U) N O L 0 a0 U) N N O7 00 N J J J m m m m N J J J J J =1 =1 =1 = '=1 :10- 0- Q Q Q Q d <L d U) GC O N N- N- N. N. I,. OO CO CO N CO 0 N N ) C CO 0COCD ) CO 0CO) 0 ) 01 0) C� -0 y O NE N E y Z 'y O N N N IL IL IL LL LL IL LL LL LL LL LL LL LL IL IL IL LL LL LL LL LL IL LL IL N d U1 E N N N N N NNNNNN N N N N N N N N N N N N N Q -O d CO Co i i i i i i N U) • :a Z a n n n N- n co co co co co ro co co m co C) Q) Q) 0 O C) co cm rn Co T O co Y C 0w K K 0 LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL IL LL LL U CL O C > w C C Cl) U NNNNN NNNNNN NNNNN N N N N N N N N 1- CC a) CO OflGJNAL N ." R = cco o a I ;.- C.; > 0 C c4 x R yam, .1 as h 0, R z Q 0 C. 's is+ O u O C O U H N N N Y Y Y (n C Q Q Q (.) LL LL LL • 0 0 0 0 0 0 } t0 r O et a p) a3 as a a T Q) 0 2 ir m aa) 0 co Q o v v v v v v v a 0 0 0 0 0 o O 3 O. 3 3 3 3 3 w c N N N N N N N N a) I LL LL LL LL LL lL LL U N ` y N N N N N N N E N a a 0 C 3 r O O co M l0 O m C . N O O M M 0 t0 LO sr c N N t0 M 0 'p 0) N 3 N N CO CO CO O. Op U LL O w O O) CO CO N 0 O N N F- V ti LO- •ctrco 0 o m u E a 0 m E ,,i v y 'c CU $ o m o 2 O O O M M t0 t0 Z 4i CL N 0 0) L O. CO O O O M M tO t0 , O O C tF C L _ 0O l0 tO N t0 4) C — O` 'N 0 E `C N ON) a, cCO CO 59 o_ .1 0 a) a) L N m N a L. LL M M O 't6 al L N0) N a) z.:-.) Q O v N o w v cci w ca o c m NO e @ y N U a) v I.I. O C 0 O N v T. ol N 3 N O ti `m ) 8c o 2 .N E N Y <13 `o Ti m a O O N C m Li U CO O o a f0 5 0 i+ a) c N MO C a U a. N N N Q W DTrJNAL ConocoPhiIaipss 2F-21 wp04. 1 Schlumberger aska21.4 N ...tali LL LL 300 I ''IIit, 011 +il�r !j I VI --'1111,1j11 1m1..a(1 Ill! �p o A r i I f NI if 1,14 l lll ` ,1 �l m _ J1f)v1 150— al v P 1 m v _ j)111 ��mutl 0 r\. I I I I 1 I I I I I i I I i i i I I I I 1 I I I 0 3000 6000 9000 12000 15000 18000 ss Equivelant Magnetic Distance Measured Depth Displayed interval could be less than entire range: 28.00 To 20213.40 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 28.00 To 20213.40 Results Limited By: Centre Distance:2218.54 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 925.00 2F-21wp04.1 (Plan:2F-21) GYD-GC-SS 925.00 1925.00 2F-21wp04.1 (Plan:2F-21) MWD 925.00 3885.33 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC 3885.33 5385.33 2F-21wp04.1 (Plan:2F-21) MWD 3885.33 14581.55 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC 14581.55 16081.55 2F-21wp04.1 (Plan:2F-21) MWD 14581.55 20213.40 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"x 6-3/4" 4-1/2 LEGEND --0- 3S-08C Doyon 141,3S-08C,3S-08C-to delete incorrect VO 2F-15,2F-15,2F-15 VI --X- 2F-19,2F-19,2F-19 V2 -X- Plan:2E-01,Plan:2E-01,2E-01wp05 VO -X- 2F-16,2F-16,2F-16 V1 -A- 2F-19,2F-19A,2F-19A VO -9- 2F-09,2F-09,2F-09 V1 2F-17,2F-17,2F-17 V3 2F-19,2F-19AL1,2F-19AL1 VO - — 2F-10,2F-10,2F-10 V7 -e- 2F-17,2F-17L1,2F-17L1 VO -A- 2F-19,2F-19AL2,2F-19AL2 VO -9- 2F-11,2F-11,2F-11 V1 -6- 2F-17,2F-17L1-01,2F-17L1-01 VO -e- 2F-19,2F-19AL3,2F-19AL3 VO - 2F-11,2F-11A,2F-11A VO --X-- 2F-17,2F-17Lt-02,2F-17L1-02 VO -B- 2F-19,2F-19PB1,2F-19PB1 V5 -13- 2F-11,2F-11AL1,2F-11AL1 VO -X- 2F-18,2F-18,2F-18 VO - - 2F-19,2F-19PB2,2F-19PB2 V3 - 2F-11,2F-11AL2,2F-11AL2 VO -A- 2F-18,2F-18L1,2F-18L1 VO -B- Plan:2F-22('tween 11&12),Plan:2F-22,2F-22wp07 VO -e-- 2F-12,2F-12,2F-12 V1 -X- 2F-18,2F-18L1-01,2F-18L1-01 VO -8- 2F-21wp04.1 2F-13,2F-13,2F-13 V1 -e- 2F-18,2F-18L1-02,2F-18L1-02 VO -01- 2F-14,2F-14,2F-14 V1 -0- 2F-18,2F-18PB1,2F-18PB1 VO ORIGINAL ConocoPhillliipss 2F-21 wp04. 1 Schlumberger Alaska if i. e 1 N N N N 7 y / I 1 O 1 i( a 1 O 2 c 0) U I I 0Equivelant Magnetic Distance I ag1 1 I I I I 1 I I I I I 1 I 1 I I I ill 1 I I I 0 500 1000 1500 2000 2500 3000 350C Measured Depth Displayed interval could be less than entire range: 28.00 To 20213.40 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 28.00 To 20213.40 Results Limited By: Centre Distance:2218.54 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 925.00 2F-21wp04.1 (Plan:2F-21) GYD-GC-SS 925.00 1925.00 2F-21wp04.1 (Plan:2F-21) MWD 925.00 3885.33 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC 3885.33 5385.33 2F-21wp04.1 (Plan:2F-21) MWD 3885.33 14581.55 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC 14581.55 16081.55 2F-21wp04.1 (Plan:2F-21) MWD 14581.55 20213.40 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"x 6-3/4" 4-1/2 LEGEND —0— 3S-08C Doyen 141,3S-08C,3S-08C-to delete incorrect VO 2F-15,2F-15,2F-15 V1 — 2F-19,2F-19,2F-19 V2 —X-- Plan:2E-01,Plan:2E-01,2E-01wp05 VO — — 2F-16,2F-16,2F-16 V1 —A— 2F-19,2F-19A,2F-19A VO - 2F-09,2F-09,2F-09 V1 —0— 2F-17,2F-17,2F-17 V3 _e_ 2F-19,2F-19AL1,2F-19AL1 VO —1-- 2F-10,2F-10,2F-10 V1 $ 2F-17,2F-17L1,2F 17L1 VO -A- 2F-19,2F-19AL2,2F-19AL2 VO -9- 2F-11,2F-11,2F-11 V1 -9-- 2F-17,2F-17L1-01,2F-17L1-01 VO -0- 2F-19,2F-19AL3,2F-19AL3 VO 2F-11,2F-11A,2F11AVO — 2F-17,2F-17L1-02,2F-17L1-02 VO -13- 2F-19,2F-19PB1,2F-19PB1 V5 -s'- 2F-11,2F-11AL1,2F-11AL1 VO 2F-18,2F-18,2F-18 VO --X— 2F-19,2F-19PB2,2F-19PB2 V3 4t— 2F-11,2F-11AL2,2F-11AL2 VO -A- 2F-18,2F 18L1,2F 18L1 VO -9-- Plan:2F-22(7ween 11&12),Plan:2F-22,2F-22wp07 VO -e- 2F-12,2F-12,2F-12 V7 —X— 2F-18,2F-18L1-01,2F-18L1-01 VO -9- 2F-21 wp04.1 4E— 2F-13,2F-13,2F-13 V1 -e-- 2F-18,2F-18L1-02,2F-18L1-02 VO —'0— 2F-14,2F-14,2F-14 V1 2F-18,2F-18PB1,2F-18PB1 VO ORI3INAL - Sec ID Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target lb 45U 1 00 0.00 0.00 28.00 0.00 0.00 0.00 0.0 0.00 2F-21wp04.1 3 598.34 2.23 90.00 598.30 0.00 0.00 0.00 2.88 1.50 90.00 0.49 450 600 28.00 To 20213.40 4 1105.00 14.89 90.00 1098.30 0.00 78.13 2.50 0.00 13.22 600 800 5 1389.42 17.39 114.19 1371.80 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1000 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 16:39.September 03 2014 -111 9 14581.55 85.00 187.00 6151.80 11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG TI 1000 1200 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11866.92 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY PROGRAM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 220ct13 PB T2 .011 From Depth To Survey/Kan Tool 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 _ _ _ 2900 925.00 2.-2..9001(Plan:2.21) G`113-GC-SS 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220ct13 PB 13 1400 1600 925.00 1925.00 2F-21wp001(Plan:2.21) MWD 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925.00 3885.33 2.21wp04,(Plan:2F-z1) MWwlm-,ix-C0.2-SC 16 18112.92 90.03 179.77 6191.60 -15012.05 2952.88 0.00 0.00 15295.22 2F-21 220ct13 PB T4 1600 1800 3885.33 5395.23 2F-21wp04.,(Plan:2F-21) MWD 3885.33 ,4581.55 2.2.0001(Plan:2.21) MW13.IF13d1(-CA2-SC 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 14581.55 15081.55 2.21wp001(Ran:2.21) MWD 18 20213.40 89.11 180.44 6223.80 -17112.23 2937.11 0.00 0.00 17362.46 2F-21 220ct13 PB 15 1800 2600 14581 55 20213 00 2.21wp0A1(Ran:2.21) MWMIF11-AKCAZ-SC CASING DETAILS 2600 3300 ND MD Name Size 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/84100 -----"- 4900 6223.80 20213.40 4-1/2'x 6-3/4" 4-1/2 4900 5600 12F-o915600 6400 \ .0/360 6400 7100 7100 7900 2a 7900 9400 30/330 - 472 J- ,-��ss 30 9400 11000 " -11 j 61,014,0'0 ��„` ` 11000 12500 rP--/.., /t -a_ .41c0, 0-4.11?*,„• 01N10,t y`` 12500 14100 165 `a ijlita� 411.41.•4 �p 14*.c:�.'�� 14100 15600 / 1511 t�4*.e a,,. `.'..I.�f).,. �..t • 15600 17100 2.16 .�iase � s • * 4 ' li , a 17100 18700 60/300 d; (�- yp/,/p/ �'/'• 60 18700 20213 "�� •/•j~•e' �� 'moi 7-1::_z � •, `` NN• �� 2F-15 -�I��9.'�5. l`��#/ r 1 1,F�!Jiit tT 9 A 90 wI►n•11iltIr /�l 1141 �....�`%�,��Qe�i,• _ w� ♦ e x�y l) �4 1 ^1 ki.4 P Illifit lithilia-,4,40..litiliti.44kt *,-'_ititiitifi %* \I \\'11 -90/270 �mili r etilli r,: 'fit►, ; / -.. 90 12F-1 7L1•021 10 IILI►I �� ±►� i t,,� vim` ' 1R -.424.4.10,00 I2F17L1 o1I ,qq�� / ' +�`• li p�� ., ` ,Wry Ir; Y�' � :►r "` x®4414 �fJi�g`a` I2Fnur-== 41111.11\t" ,�, �.��°o /�� .,,��/i t,►,�V� it,'i.! r' I2F 1iI 111-",t i; � -•_...:' ,w, ji�Irl/I��$ri�l• /®,1. i ..Vi1:$ -91,II 1bi-• A \ \ ,-,-::;,. .-..::---,-,•.:V 44......,.-•:."---'----....', .. . Ii :.101.1.;. -120/240 *16: 4/.1;; �--�''•" 1/:,-4,r,`, ; 120 4'/SSl�: + sir a.a� 7irnm2u ,s' :.: 00:e.,, /:-,:::-.114'.: x r yd ,a �i ----s.:1',.;,,-%.;,-.44. t: i 1.1. I2F-22wp07I 5!! `• J� "'sw�1 ��.. 4.•• r," :i.--1....'-'4'w 150/210 " 1...://moi< (`17- p: y150 I2F-13 2F-19AL1 ---r /��-"F(lAs y"ak, :i,,.: - 12F-191--I2F10PB21=,-�, '-1180-,180 I2F-19AL2j 12F-19PB1I I2F-19AL3I /2F-19AI `I2F-14I ▪ WOK Sou III.39.90,18.00C wee..5.93000 -tr C.II.S-11A1.1.C.I1,u1 50 $ a.l .12 51 $ 5 1: -- 5 $ 4.1 $ 2F 21,0P.a 2F-01.P..:28.01,250/5205 09 -e- 5M2 2F-n,2F-!MU. 11 Y0 .2- a Co. a 09 5-51 , .5-1,3 $ 5 O,VD -@• a19.5-19212.5.1921200 •3(- 2502.SOe.2.09 V, -tr 012,WIZ 2..12 51 -d- 5 -6- Sis.V11.102.OF 121.1-02 -A- 2.191 5.1901.1.5-19013 50 $ 2F10.2F.10.F 90 51 $ 5 5.19.01351 -!E 5 -I- 5 WO,2F-12901.051 -94 5 -X- 2,11,C41.S.0 VI -}• 2F-I4,844.04451 $ 5 02.5-1111.0250 $ S - $ 5 19. $ 2F F.0110,OF11A VD $ 5VI 1S.5..2FI90 513.2.•145.1259 $ 2F 155 I54,2.19050 j(- Pien.2 an5ewlU312),Plan.xF-a.x.05202510 ORIGINAL Northing(3000 usft/in) I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I I l I 1 l 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 I l 1 1 1 -0 - CI - - Cl- - _ W _ — N — cti - L2 — Y - J - N - - a - LL�N O - ti LL , 3 N N C- ��Q J J O - C a a a Lu - 7 LL LL LL LL 4 _o p7 O iV i N N N N p, - O M c7 V - v C1 - In LL . . - co c - O LL CV N - c 0N 7- . 0 N O y CO m J - -a CO D m m m _ c71) .: J J - 0 It N W ,- - CI) LL LL �.i_ O N N N CV N - O O J F N - ZE CZ - 07; °- _ H C /1 N — S 3 - U Q I I I I I I I I I I I Y. I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 1 it (u1/llsn 000E) Bulyl.ioN ORIGINAL_ Sec ID Inc Azi TVD 4N/-S +E/-W Dleg TFace 23 4 VSect Target 2bU, s� 1 00 0.00 0.00 28.00 0.00 0.00 0.00 0.0 0.00 2F-21 wp04.1 3 598.34 2.23 90.00 598.30 0.00 0.00 0.00 0.00 2.88 1.50 90.00 0.49 450 600 4 1105.00 14.89 90.00 1098.30 0.00 78.13 2.50 0.00 13.22 600 800 28.00 To 500.00 5 1389.42 17.39 114.19 1371.80 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1000 - µ 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 dtrCt. ,,y_,t ; 'n x +:.::„...,::::.„,„4:„:, 9 14581.55 85.00 187.00 6151.80 -11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG T1 1000 1200 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11866.92 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY PROGRAM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 220ct13 PB T2 >epN Fmm 0ap1n To r.37,;1..", Tool 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 2805 e2s.9D (Pan:2Fa1) Gv0-Goss 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220ct13 PB T3 1400 1600 925.00 1925.00 2F-21w9041(Plan:2F-21) MWG 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925.00 380.5.33 2F21wp041(Plan:2F-21) MwwiFR-ac-cA8-sc 16 18112.92 90.03 179.77 6191.80 -15012.05 2952.88 0.00 0.00 15295.22 2F-21 220ct13 PB T4 1600 1800 3885.33 5385.33 2F-21wp04.1(wan:2F-21) MWD 3885.33 14581.55 2F-21wp04.1(Nam 2F-21) MW0.1F13-,ixcAz-sc 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 14581.55 18081.55 2F21wp04.1(Plan:2Fa1) MWD 18 20213.40 89.11 180.44 6223.80 -17112.23 2937.11 0.00 0.00 17362.46 2F-21 220ct13 PB T5 1800 2600 14581.55 20213.40 2F-21wp04.1(wan:2F.21) { 1) MWD.IFR-AKAZ-9C CASING DETAILS 2600 3300 TVD MD Name Size 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 4100 4900 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"x 6-3/4" 4-1/2 4900 _ 5600 5600 6400 0/360 6400 7100 7100 - 7900 '% 75 7900 9400 -30/330 70 30 9400 11000 65 11000 12500 \ \ 60 12500 14100 roil" % 14100 15600 50 „ 15600 17100 �5 17100 18700 60/300 080 \ \ 60 18700 20213 /107 1351, ilit _ 20 1 \ \ \ �\ 'i }i �1�,,,,,:`,S,::,‘,:0,,\ 'I {lei ;iii 1 I i i. 1 �' II 1 I I � 1 1I ��11 �� ' 1 i11i 1�1� ;� 1 111 1I� 1 � �'�; i;i 111 111 1;1 ; I I I I 1 1 11'I iill 1 • ll\l 1\1' 1 �'� 1 11 1�1 ; i� I I iii 90/270 1111 I I i111 1111 1111 111 � '' ; l 1: 11' I'I 111111 111 X71 'l' 90 ;,, ,I 11,;, 1;1; II11 ;1;1 ;,1 ,ii ,11;111111111 111 I�1 �; i1� 111 ;`111;11 1;' ,,1,1} ;,i! 1t1`i , 1� 1;11 II;1 IIi 1i lIl 1 1 v\1 „ �� 1 ' //IN 1/, t� it. ' ijj f /1ll 1 \ :-'---i \\ ,- 120/240 1;1100, /4 120 \\ - -- �- z1 ti70 � �; -150/210 ; 150 75 , --- 2,',----.%- -180 -180/180 aloe!mom.Vp -A- 2,11.6-11.461.2E-1,461 VS $ F 2F -8- 2F 2F-15961 6o 8- aF-a1.F54.1 -a- F▪ a E01,0VO 2 60 -s- 2F $ 27 1- 2,19. ▪ 2F 2F ,3,03IIV -A- 2,1121.2,2,11812 ''4 -n- -a 2F 49- a � 2F,12,2F-112F 19 VI 4E- 2F- -- 2F ,V. it- 25 21SFa'.2 oa Vs -34- 2F -E 2F -$ s 2 .0265 $ 2F -s 2F -0- 2F n.2F-118,2F.11A W $ 0815.2,15,2,15 V1 $ 2.16.08-142,14w�}�./i $ 2F 19,2F 196,OF 100 VI l(- 61aa2F-22(.aan11612),Man'.2F-22.2F22.7o710 Sec ID Inc Azi ND +N/-S +E/-W DIeg TFac VSect Target I Lb 43U 1 00 0.00 0.00 28.00 0.00 0.00 0.00 0.01 0.00 2F-21vvp04.1 2 3 a.00 0.00 0.00 450.00 598.34 2.23 90.00 598.30 0.00 0.00 0.00 0.00 0.00 2.88 1.50 90.00 0.00 0.49 450 600 500.00 To 1000.00 4 1105.00 14.89 90.00 1098.30 0.00 78.13 2.50 0.00 13.22 600 800 5 1389.42 17.39 114.19 1371.80 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.60 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1000 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 Atiolfhassigagr_2014 9 14581.55 85.00 187.00 6151.80 -11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG T1 1000 ` 1200 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11866.92 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY PROGRAM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 22Oct13 PB T2 Depth From Depth t0 Survey/Plan Tool 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 ,,., 2300 925.00 2F-21wp041(Plan:2F.21) GYD-ccss 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220c113 PB T3 1400 . -- 1600 92500 1925.00 2F21wp04.1(Plan:2F-21) MWD 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925.00 335.33 2F21wp041(Plan:2F-21) MWD,IFR-accA2-66 16 18112.92 90.03 179.77 6191.80 -15012.05 2952.88 0.00 0.00 15295.22 2F-21 22Oct13 PB T4 3885 33 45885.55 2F21wp04.1(Plan:2F-21) MWD 1600 1800 3835.33 16561.s5 30.21wp04.1(388n:2F-21) MwD.1F12axcazsc 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 14581.55 16081.55 2F-21wp04.I(Pla4:2F-21) MWD 18 20213.40 89.11 180.44 6223.80 -17112.23 2937.11 0.00 0.00 17362.46 2F-21 22Oct13 PB T5 1800 2600 14561.55 20213.40 2F21Vry04.1(Plan:2F-21) MWD.IFR-A2CA2-$C CASING DETAILS 2600 3300 TVD MD Name Size 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 4100 4900 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"x 6-3/4" 4-1/2 4900 5600 5600 6400 0/360 6400 7100 - - 7100 7900 75 * 7900 9400 -30/330 70 30 9400 11000 moo/ -% 65 11000 12500 60 12500 14100 ��d� �ti - 55 �` 14100 15600 /' �/00,-,„9.4.-.4,-,...---0, 4.7 :I z�•y�• ,�� m�C i \ 15600 17100 E117717,,--;'17.'-'4";" �; i4";" ��+/ \ 'ii:` s1. 7100 18700 `,V4.;,,,,,,- is 1 -60/300 /, / �� „ ,i 4 , %?z f'�.j; �., 60 18700 20213 li,� ,y4,,;� = Yors ;-- �. lir A A ° 44 G�n� 0 \„\ \ I fl 0 Sj C 14‘e*/„/1:;°II/'Alf,7--,-,,,--;- --- - ' .441/4404, 4,,, , ,tAri•. itkis."4,40:0„:,-_-1-4, „O.---_, I,/ , `4.`4'1.1t,ttiti*:7,=•'="!--,---_7 '-,.\ • � 4141/1141fitielbte,SW4t ! gill. (�/ /// 1 1\ t \1\\ li';''. -90/270 I . 141H�� I �, I , • • 90 • �\111 , V / III I 111 1 \, /�� 11 � 111 tT'�i?,124- 'i �1: //r//f ��lli1eC z%,120/240 ,i, t& -a„ sij�, 120 \:: ',. pp--gaZittlittratt - ."/ / "11, ..,-.2" ,',,,::„: 01011=1,1411 ,...„„00S0,1/// ;:i441111111b-'711110411.1:1F1114; ';3 150 -150/210 -180/180 %mCO2,141,38 oac,90328.to dens P.m.. -} 23.11.5-118.1,a-11a.1 V0 $ iF-1e,Wm,2F-16 VI $ x,19,23.,6.1,25-16L,80 23 xF-79..1 V0 $ 2,218702.1 $ n ,01w796Vo $ 2,11, V9 -} 5 $ 2,18, 9 5 "3€ 5 -A- 23 -A- 23 - -A- 5 -A- 5 $ 51x.231a23�oVn $ a,e.25.73.a73w iE 5 .} 25-19,a7efin,S2P91Vow 4E 5 19,2F 151.91.W 19PB1 05 4i -a 2F-1,.23-1�a51 V1 $ W.15,2F.15.a,s V1 $ S..a,a 2£.12vo2,2wh - -!E 2F19,2F 1.899¢,19 4,i V3 -A- 2-383266 00 - Sec D Inc Azi TVD +W-S +E/-W Dleg TFac VSect Target 1tf 4U 1 MO 0 3 598.34 2.23 90.00 598.30 0.000.00 2F-21 w 04.1 2 .00 0:90 0.00 450.00 0.00 0.00 0.00 0.000 2.88 1.50 90 0049 450 600 1000.00 To 2000.00 4 1105.00 14.89 90.00 1098.30 0.00 78.13 2.50 0.00 13.22 600 800 5 1389.42 17.39 114.19 1371.80 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1000 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 °S 9 14581.55 85.00 187.00 6151.80 -11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG Ti 1U:374 'p- 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11886.92 1000 1200 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY PROGRAM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 220L113 PB T2 5epu From Depth r0 Survey Plan roof 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 __.__-__ 28.00 925 DO 2F-21wp0a1 Man:2F-21) cv.Gcss 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220ct13 PB T3 1400 1600 925.09 192500 2F-21 wp04.1(Plan,2F-21) MWD 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925 00 3830 2F-21wp0a1(Pian:2Fa1) MwD.IFa-AKcAz-sc 16 18112.92 90.03 179.77 6191.80 -15012.05 2952.88 0.00 0.00 15295.22 2F-21220ct13 PB T4 1600 1800 388533 538533 2F-21 wm04.1(PIan:2F-21) MWD 388533 1,3581 55 2,21 wp00.1(PSM:2F-21) MWDrUe411(CO2-sc 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 14581 55 18081.55 2F-21wpO11(Plan:2F-21) MWD 18 20213.40 89.11 180.44 6223.80 -17112.23 2937.11 0.00 0.00 17362.46 2F-2122Gct13 PB T5 1800 2600 14581.55 20213.40 2F-21wp0a1(PeaW.IFA :2F-21) MD •Ax-GALSG CASING DETAILS 2600 3300 TVD MD Name Size 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 4100 4900 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"x 6-3/4" 4-1/2 Different 4900 5600 X 4r Y Axes Scales 5600 6400 0/360 6400 7100 7100 7900 10"01.150 7900 9400 -30/330 140 \30 9400 11000 130 11000 12500 A0�4��;oG 120 12500 14100 [2F-161 ii$A#AliteS. 4 �� •��;,`*t 0 IIIIIIIE 110 14100 15600 I 1 10 0 15600 17100 irA ' 90 17100 18700 -60/300 �v %4%%% 60 18700 - 20213 ,:','"-*;',41..4604.440 lii atekiiii . �2F-151 ,/�'��I' ��b��i��4��•��ti�� ►-,-,' ,...--03:1011., i' jai 11 104hr- 'MIjl f �_i'04;44:-.1Y. w.4; :-.1Y. I2F17L1 o2I �ai,.i�,bH�►, /w�l� ,��, /� hetidFbv 14tj i/ \1 , ;: ;a a .a, 11; 2F-17L1.01 1 - s m�,,,o, , , C 1 ll,'. 12F-17Lr Ll ►dei` ,..`�pfi 1 1 VI ,, i I I I 1 J I I2F-17I ,fdr�M.��'�0-0. ��,. �l ik,1d� 1�V'wV®tlst 1 , \ t' \ 441.......•"r--ts..t.;:tev,0 ,i.4.1,......--,,..iiit,-,,...,,A,,,•N:,,,,, ,,,,,,„?..06.1.14„,..,..lzml,,,.,s,\.,,,, 4 I , /ii, ?-1.///4 lig* ,. ki V 4'Pia.tiSwiy ► �� / I A. � /'/ ��. �� . �- �Vt.s,lb 211:004j? / , � . •,,,..:14-....-01,.."..........„...., w. I . � j eI fells;ar«yw"°"' l : � 4.i� rl ��/j 120 -120/240 .:.:..-.�.��... j� � �%`, 7- 4 �� i� � \ 1 ,-- ,'�/illip - . Ii • a'a .l► gl 1 i•I///' I2F-194. R.40*---40 6/7// •\tle 4ir f�: re.i, -150 7 : . i i., yea.'IDs= 42,;0 150 12F-22wr oif.,, )1 fi/! :ivh.-= c►= -'1629 �f2F-19RB2I I2F-19PB1I _4 R,.: 12F-19AL1 I I2F-19AL2I I2F-19AL3I 12F.141 180/180 $ ss e favO -IS- 2.,,.2nuD.211.140 $ a 2141,18 VI -9- x 2.1.120 $ CO., a.19.1,a 10.120 $ awp 2109.1 -a- a 01,P.'2E-01.2E-01w235 VO„ ft.. -A 2,11, 11.12.211.2 VO 't 2 17,VI 7,if-12 V9 -Et- C $ 2 10.V 10.2,2-tau vo -F 2 03,2-09.200 W -fr 2 12,2F 12,2F 12 VI -6- 2 -A- aIt 2F 100 02,PFAIL10a A- 2.102..2-10.0 vo 2F $ 2.142.10 W $ ala.aro.2 10 W 4E a $- 2 Pel,2nre,v0W - 2 9f a -X- VII..211,2F II VI $ 2 a14,244 V1 -EF 2-n.a,nw2.21710zw $- a $ 2F12,V1rea2-Ir0zva $ CII.2-11.,2F11410 $ 22.244 a..e 21 $ 22.2142-few- $ 21e.a12 2F10P V0 -)(- we.zFa rI...enelzl,P�.n.2F-zz.2F-Et•�]v0 IGINAL Sec D Inc Azi TVD +W-S -rE/-W Dleg TFac VSect Target 225 40U 1 00 0.00 0.00 28.00 0.00 0.00 0.00 0.0 0.00 • 2F-21wp04.1 2 3 00 0.00 0.00 450.00 598.34 2.23 90.00 598.30 0.00 0.00 0.00 0.00 0.00 2.88 1.50 90.00 0.00 0.49 450 600 2000.00 To 3000.00 4 1105.00 14.89 90.00 1098. 0.00 78.13 2.50 1.54 13.22 600 800 5 1389.42 17.39 114.19 1371.8080 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1 000 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 10:38 Seat 9 14581.55 85.00 187.00 6151.80 -11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG T1 1000 1200 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11866.92 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY PROGRAM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 220ct13 PB T2 MOP From 09001 m sv,v10rm1an Tool 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 28.00 92500 2,21m:051(Ma1:2F.21) G`113-GC-SS 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220ct13 PB T3 1400 1600 925.00 1925.99 2F21wp0a1(Nam 2,21) MWO 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925 00 3885.33 2F2161000.1(Plan:2F21) Mwa1913-aN caz-x 16 18112.92 90.03 179.77 6191.80 -15012.05 2952.88 0.00 0.00 15295.22 2F-21 220c113 PB T4 3885.33 1558,55.33 2F-21,00 ,2161 41(r man:2,21) Mwm.im.accaz-sc 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 1600 1800 14581.55 18091.55 2F-21wp94.1(Pan:2F-21) MWD 18 20213.40 89.11 180.44 6223.80 -17112.23 2937.11 0.00 0.00 17362.46 2F-21 220ct13 PB 15 1800 2600 14581.55 20213 40 2,21w9051(Plan:2,21) MM...AN-M-5C CASING DETAILS 2600 3300 TVD MD Name Size 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 4100 4900 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"x6-3/4" 4-1/2 Different 4900 5600 X 4n Y Ares$cases 5600 6400 0/360 6400 7100 7100 7900 22 7900 9400 -30/330 ■210 30 9400 11000 ,/;d000011111111111 195 11000 12500 180 �, 1250010 14100 ~ 14100 15600 15600 17100 17100 18700 -60/300 0,01111111111111115650 120 .;., ,:::, >'' \ 60 18700 20213 10 /1/ 4if60 4 %%\\1 1:' \tilt 1111111111111 /, ':%- \\ 111111111 -90/270 [(ft( 90 ��INIII kt\t\t"tt 4 j 460 Nit //‘6\11A/mitli1109 41111111111:1t -120 240 150 jj 120 � �� 1 � c4f 18 .iii /ice . 95 7.t/, -150/210 :'?",;;%:%„)%',„...:i �'�'_-/,11,h`,``µ:_ 150 12F-19PB21 -t80/180 r2F-19PB1I 12F-19AL2I 12F-19AL3I -9- 3.5e59T.101,33-005,3906C 10 011591,60005 V0 -a 2F-11.2-11261.2-11231 v0 -$- W.M. .0585.1831 $ a --f- 85 $ 5a.0a.1 $ w 85,.905 vo 6" 85.11 5.1122.2511232w i- 5-v,85.17.2-1761 $ 85 le,w mu 01,2F18118I SO $ 85.19,a,9u2,5 MI5 VO -x- 85 -dr 2512.5 12.2512 n -fr 2-11.85-16.1,2516.1 w 85 -� 85.19.85-,wu,a1,MAW VO $ 85.0585.10.a-7000 $ 85-10.54.2.uW - 2 .51.5.1310161 $ 2F.,a50291.a�1291vow -NE 5 5.W 1581.2F 1581 VS -j(- 85 11,5 11.51100 i- 8504.5.M.5.1417 $ la 5-.85-,6.51.9E 01058 - - 8 1� $ aM2PM(159.5�,99exw $ anaaw $ 85. .,, a.0,. 18.85-085 00 $85-18 5 5.85.law �(-a.,ei(V'Sj iaef6v_-7._a[ na.20,...nn81z).Mao:zEa.2Eaa.a0,v0 Sec ID Inc Azi TVD +N/-S 4E/-W Dl eg TFac VSect Target 1 00 0.00 0.00 28.00 0.00 0.00 0.00 0.0. 0.00 2F-21 Wp04.1 2 1.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 009 450 600 3 598.34 2.23 90.00 598.30 0.00 2.88 1.50 90.00 0.49 3000.00 To 5000.00 4 1105.00 14.89 90.00 1098.30 0.00 78.13 2.50 0.00 13.22 600 800 5 1389.42 17.39 114.19 1371.80 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1000 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 10:39,September 04 2014 9 14581.55 85.00 187.00 6151.80 -11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG T1 1000 1200 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11866.92 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY PROGRAM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 220ct13 PB 72 1ep2h From Depth 3o Survey/Plan Tool 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 28.00 92500 2F-21wp0Q1(Plan:2F-21) GYG-GCsS 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220ct13 PB 73 1400 " 1600 925.00 1926.00 2F-21wp04.1(Plan)2F-21) MWD 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925.00 2895.32F-21wp041(Plan:2F-21) MWI3.IFA-aK-caz-sc 16 18112.92 90.03 179.77 6191.80 -15012.05 2952.88 0.00 0.00 15295.22 2F-21 220ct13 PB 74 3885.33 5385.353 2,21‘,04.1(Plan:2F-21) MWO 1600 1800 3805.33 14581.55 2F-21wp04.1(5'00.:2F21) MWI3.IFR-ax-c02.sc 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 14581.55 19091.55 2F-21wp04.1(Plan:2F-21) MWO 18 W 20213.40 89.11 180.44 6223.80 -17112.23 2937.11 0.00 0.00 17362.46 2F-21 220ct13 PB T5 1800 2600 14581.55 20213.40 2F-21wp04.1(Plan:2F-21) MO.IFTWO,CAZ-SC CASING DETAILS 2600 3300 TVD MD Name Size 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 103/4"x 13-1/2" 10-3/4 4100 4900 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"x 6-3/4" 4-1/2 biI fereoc 4900 """"_.._ 5600 5600 6400 X 4 Y States 0/360 6400 �"- 7100 -- 7100 7900 -300 7900 9400 30/330 30 9400 ---- 11000 260 11000 12500 �� _- 240 12500 14100 _-- 220 \ 14100 15600 200 , �� 15600 17100 40/7 :, "� 180 17100 18700 -60/300 � = 60 18700 --."_,_" 20213 141 \\\\\\\ �� '� 12 ,►;�• /if10 1l7", - ' 90/270 ` { . 47: ''' ''''\ \\'' '‘,) ‘'}'\1,' 1/1$01',,•,',%,,.i/,,I,,', (4.084'°4 t; n I\\\\,2, �),p ,. ;90 ii III ir 1111 \\•, :r """: ill i i i i,, ,1,i,i, ,,...;,,,,,,,,,,,,,,:ii...t.i.i.:1:iviti:...,i,,;.,..,:;,,,..„.:1„...:-;.. 2 \\\ 'S 0:01,62.4*' '\ , \ 61 a I2F-191 1 1/(( �� 111 80\IN I I III N I lir 01 I I I''' �. 'I2F-19PB2I ,�\\S\1\\\\\k .�.. -/./ ,,,,,,....--.- - � V j:..;- 2F-19 i I 1 Na,,,,mow. „ [2F-19AL3I , . 141 tht��`�. .:�� 11�I2F-19AL2I \‘‘S' VA wwgyp A\, �'. 1, 16 i ;,,!...76,.,,,,0.-,,,,,,,,,,,,��.A� ? [25.'19 A' ` .w` _�s•120 120/240 , \� w °�� \\S 181 .11.3. �e;;�; sties ;„O�o.< �� 200 _ �`x�\�,N!... ��r._ 220 '�q•4�` .� < 240 e /M19A;�� `�~�- 150/210 :f;1�`a \�\,\ , " `- 150 -180/180 I- 38 Owen 141..MC.O&545.M men wcna4 VS -A- 2F.11.00.1144,.2F-,,.LI V9 $ 00-19,00-16,2F161/1 -e- 2 + 2P •e• 2F-216259.1 -e• p . E O,.p05 Y9 4* 2F VO -s F •EF 2F IS,212;41.2,1204„9 -e- 2F a:.19V12:u-199a a 44- 2F -A- 2F -e- 2F -o- -o- 2F 2F-1943 Y9 ÷ 27 4* 2,a.r-16,25 3 VI -3- 2- -� 2F 150 - 2F w 2F 19P131.2,121.81 55 -*- 2F -.- 2F,..2F,4.2,.Y1 -e- 42VO -B- 2F 2F "e- 2F 11:211az;,:w + 2F-15.2,15.2F,5w a 2 1a:u.la2,12VO , .,�,�. �c Nen 2,22 a ;:,zxP"2F-2.2F .p0,0 ORIG�N��L II. 0121311131FIMI Sec ID Inc Azi TVD +N/-S +E/-W Dleg TFac VSect Target 1 00 0.00 0.00 28.00 0.00 0.00 0.00 0.0. 0.00 2F-21 wp04.1 2 3 598.34 2.23 90.00 598.30 0.00 0.00 2.88 1.50 90.00 0.00 0.49 450 600 5000.00 To 14581.55 4 1105.00 17.39 90.00 137 .80 0.00 78.13 2.50 0.00 13.22 600 800 5 1389.42 17.39 114.119 1371.80 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1000 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 10:40,September 04 2014 9 14581.55 85.00 187.00 6151.80 -11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG T1 1000 1200 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11866.92 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY enoaeeM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 220ct13 PB T2 9wth From Depth To Survey/Mon Tod 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 28.00 925.00 2F-21we041(Pim:2F-21) ere-cess 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220ct13 PB T3 1400 1600 925.00 1925.00 2F2,wp041(Plow 2-21) MWD 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925.00 3885.33 2F21wp04.1(Flee:zFzl) 9rv+D.im88.c82-sc 16 18112.92 90.03 179.77 6191.80 -15012.05 2952.88 0.00 0.00 15295.22 2F-21 220ct13 PB T4 3885.33 5385.33 2F-21w04.1(Mon:Val)41) MWD 1600 1 80 Vl/o 3885.33 14581.55 2F21w0041(n-:2621) MWD.lFF1418{82-8c 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 14591.55 19091.55 2F-21wp0<1(Mon:2641) MWD 18 20213.40 89.11 180.44 6223.80 -17112.23 2937.11 0.00 0.00 17362.46 2F-21 220ct13 PB T5 14591.55 20213.40 2f-21,4;04.1(Flaw 2F-21) MWD/W11-0XCK8080 0 26060 0 CASING DETAILS 2600 3300 TVD MD Name Site 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 4100 4900 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"a 6-3/4" 4-1/2 Different 4900 5600 ?C 4 V Axes$+cares 5600 6400 0/360 6400 7100 7100 7900 450 7900 9400 -30/330 420 30 9400 11000 • 11000 ' " 12500 000 360 12500 14100 330 n $\ . 14100 15600 �� 15600 17100 270 17100 18700 -60/300 -60 18700 20213 _ 240 1111 i711 1111 912::::,,, 2� 1!:‘,,j''''' �1 �,//,,r� N, ,r�i \ 47,4,,,, tl ,� I f� 111��1 �t�, tritit , 11 i1I( 1 ��,�v� 1 �� \� -90/270' ki ��aU)iJJfr ,. �91f l !IT,11 %11\11 ft is. ''''„<, i',",/ , -120/240 ,, 120 .�.., �.,.: .. 270 :._ 300 330 -- 360 390 -150/210 420 150 450 -180/180 $- 9903C Owen 101,3909C.2902Gro O loiv kvmen vo -tr 2,11,2,11211,00-11311 50 $ 3 $ 3 20111 20 319.3-,9661.2019n61 V0 '� 00 21wp0a 1 $ PI E-01vp05 V0 $ 3 3.11012.20.1141250 f 3 31122 $ OF-IS,3181,01.26.181,0120 $ 3 V 111,00 VO -X- OF -Ar 2612.3-12.3.1220 -, 3n,0012.1,OF-ll1W "- 3-1e.001811{2.26.18612220 -4 3 $ 2F 3.14340 Vi $ 3.u.00.1%26.13 Al 41e 3 -g-" 3 00-1OFE1Vo j(- 3,9.01900,.3.,924 VS -X- 310,2F-11,3-11 N -g- 2F 3-14,3+.V1 $ 31.3111122,2F 111122 VP $ 3.12.319.3.19 V2 $ 3 311.311226.11659 315.31%31ew 310.00-1%34: j R i G 0T 1a- VOL ... Pam 2¢22 1,1.,z,%.n2F22,2F�1V9 1 Sec ID Inc Azi TVD +N/-S +E/-W DIeg TFac VSect Target 1 00 0.00 0.00 28.00 0.00 0.00 0.00 0.0 0.00 2F-210,04.1 2 3 598.34 2.2390.00 598.30 0.00 0.00 2.88 1.50 90.00 0.00 0.49 450 600 14581.55 To 20213.40 4 1105.00 14.89 90.00 1098.30 0.00 78.13 2.50 0.00 1322 600 800 5 1389.42 17.39 114.19 1371.80 -17.43 153.54 2.50 81.54 43.16 6 1489.42 17.39 114.19 1467.23 -29.68 180.80 0.00 0.00 59.84 7 3577.80 72.61 166.54 2923.89 -1250.78 755.93 3.00 58.28 1360.63 800 1000 l4te ' 8 13992.85 72.61 166.54 6036.55 -10916.73 3069.83 0.00 0.00 11278.70 ~�- fi}y f ",2{.:-tq+„ f„' ,,1 9 14581.55 85.00 187.00 6151.80 -11489.02 3099.91 4.00 60.66 11847.84 2F-21 02May14 HG Ti 1000 1200 •-" *- . - 10 14601.55 85.00 187.00 6153.54 -11508.80 3097.48 0.00 0.00 11866.92 11 14752.27 88.72 187.62 6161.80 -11658.04 3078.33 2.50 9.49 12010.77 1200 1400 SURVEY PROGRAM 12 15287.98 88.72 187.62 6173.80 -12188.89 3007.31 0.00 0.00 12521.95 2F-21 220c113 PB T2 22,81 From Devin To solveymrn tool 13 15584.00 89.34 181.73 6178.82 -12483.75 2983.19 2.00 -84.00 12808.48 2890 92500 2F-21.9041 Men:2F.21) Gvo-ccss 14 16712.74 89.34 181.73 6191.80 -13611.90 2949.07 0.00 0.00 13914.60 2F-21 220ct13 PB T3 1400 1600 925.00 1925.00 2F-21w1041(Ren:2F-21) MWD 15 16816.60 90.03 179.77 6192.37 -13715.74 2947.70 2.00 -70.78 14016.72 925.00 3885.22 2F-210pU41(Rrl:2F-21) rWD.im-AKcnzsc 16 18112.92 90.03 179.77 6191.80 -15012.05 2952.88 0.00 0.00 15295.22 2F-21 220ct13 PB T4 1600 1800 3885.33 518513 2F-2wp041(Men:2F-21) MWD 3885.33 10581.55 2F-2,wp00.1(Fr1:2F-21) MWD"IF11014({AzsC 17 18169.39 89.11 180.44 6192.22 -15068.52 2952.78 2.00 143.72 15350.86 16581.55 18031.55 W4109041(R-:2231) MWD 18(R20213.40 89.11 180.44 6223.80 -1711223 2937.11 0.00 0.00 17362.46 2F-21 220ct13 PB T5 1800 2600 16591.55 20213.00 2F-210,941 en:2231) MWD.IFa A-GAZSC CASING DETAILS 2600 3300 TVD MD Name Size 3300 4100 110.00 110.00 20"x 42" 20 3015.80 3885.33 10-3/4"x 13-1/2" 10-3/4 4100 4900 6151.80 14581.55 7-5/8"x 9-7/8" 7-5/8 6223.80 20213.40 4-1/2"a6-3/4" 4-1/2 Different 4900 5600 X 4,Y Axes Scales 5600 6400 0/360 6400 7100 7100 7900 y' 900 -- -- 7900 9400 -30/330 840 30 9400 11000 -; 780 11000 12500 12500 14100 660 14100 15600 ice _ 600 15600 17100 540 17100 18700 60 i 300, -60 18700 20213 oo� 1,,,,, // 1.I 4i " ill‘tiii 1 1 ,(\\(\\\ 90/270,, so \0 " ;1 � h1\\�i ! 1:., \,\\ ,N \ ,N �'x': 311 7\\ . 42 1 -120/240 481 120 548 600 660 720 _: 780 � 150/210 4'.4840 150 900 -180/180 t 3,08C Ooyon 191,13.Om.ss-aeCa 0eble Imam 20 4- 2,11, $ 60 -0- 2 -} 60 $ 22 2.00 -0- P E 01.06 VO $ 2211,2211212,2211212 20 f 2 $ 2218,22t.1-01,2F 0V10110 $ 2218,2279212,6010212 26 iE 2 -6- 60.12.60.12 8.12 01 -� 2 -� 2F-10 221811.02,22.1918210 -er 2.10,210260.6.1021220 $ 28.6010.00100 $ 60 22.13,60.150 -(- 60 ♦ 60 120 -X- 60 19,W19291.22 19001 V5 -)(- 60 ♦ 22.12,2210 22.10 21 -a- 2,10.2-1000x.2210102. $ 2219,2210,220 e W 29 ÷ 22"10,2219(.x.2.19202 v3 $ 211.60112.6x112 w $ 2-18.2211,60.120 O 2102-102-180 n }-� 1 /FS R - w.2arn....11s1zI.0..:22-a.zrzz.2ov v0 • ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2F Pad Plan: 2F-21 Plan: 2F-21 Plan: 2F-21wp04.1 Error Ellipse Survey Report 03 September, 2014 ORIGINAL Schlumberger Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2F-21 Project: Kuparuk River Unit TVD Reference: Plan:95.8+28 @ 123.80usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Plan:95.8+28 @ 123.80usft(Doyon 141) Well: Plan:2F-21 North Reference: True Wellbore: Plan:2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21wp04.1 Output errors are at 1.00 sigma Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2F Pad Site Position: Northing: 5,949,092.38 usft Latitude: 70°16'20.892 N From: Map Easting: 1,657,424.77 usft Longitude: 149°51'44.755 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.13° Well Plan:2F-21 Well Position +N/-S 0.00 usft Northing: 5,948,461.80 usft Latitude: 70°16'14.687 N +E/-W 0.00 usft Easting: 1,657,533.28 usft Longitude: 149°51'41.637 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 95.80 usft Wellbore Plan:2F-21 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 10/3/2014 19.13 80.87 57,572 Design 2F-21wp04.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (') 28.00 0.00 0.00 170.26 Survey Tool Program Date 9/3/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 925.00 2F-21wp04.1(Plan:2F-21) GYD-GC-SS Gyrodata gyro single shots 925.00 1,925.00 2F-21wp04.1 (Plan:2F-21) MWD MWD-Standard 925.00 3,885.33 2F-21wp04.1(Plan:2F-21) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,885.33 5,385.33 2F-21wp04.1 (Plan:2F-21) MWD MWD-Standard 3,885.33 14,581.55 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 14,581.55 16,081.55 2F-21wp04.1 (Plan:2F-21) MWD MWD-Standard 14,581.55 20,213.40 2F-21wp04.1 (Plan:2F-21) MWD+IFR-AK-CAZ-SC MWD+IFR AKCAZSCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral - vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft), (usft) (usft) (usft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 110.00 0.00 0.00 110.00 0.20 0.00 020 0.00 1.15 0.01 0.01 0.20 020 0.00 GYD-GC-SS(1,1) 450.00 0.00 0.00 450.00 0.56 0.00 0.56 0.00 1.15 0.03 0.03 0.56 0.56 0.00 GYD-GC-SS(1,1) 598.34 223 90.00 598.30 0.71 0.00 0.71 0.00 1.16 0.05 0.05 0.71 0.71 0.88 GYD-GC-55(1,1) 9/3/2014 4:27:32PM Page 2 COMPASS 5000.1 Build 65 Q1G1NAL Schlumberger Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2F-21 Project: Kuparuk River Unit TVD Reference: Plan:95.8+28 @ 123.80usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Plan:95.8+28©123.80usft(Doyon 141) Well: Plan:2F-21 North Reference: True Wellbore: Plan:2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21wp04.1 Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (^) P1 (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (1 1,105.00 14.89 90.00 1,098.30 1.13 -0.02 1.28 0.04 1.15 0.16 0.17 1.28 1.18 91.19 MWD(1,2) 1,389.42 17.39 114.19 1,371.80 1.31 0.00 1.99 0.15 1.16 0.25 0.30 2.03 1.33 99.38 MWD(1,2) 1,489.42 17.39 114.19 1,467.23 1.39 0.00 2.38 0.20 1.17 029 0.36 2.41 1.40 102.82 MWD(1,2) 3,577.80 72.61 166.54 2,923.89 2.86 -0.77 8.97 -0.19 2.32 1.04 1.30 9.20 2.98 153.08 MWD+IFR-AK-CAZ-SC(2,2) 3,885.33 72.61 166.54 3,015.80 3.29 -0.77 10.74 -0.05 2.69 1.10 1.43 10.94 321 155.30 MWD(2,3) 13,992.85 72.61 166.54 6,036.55 18.10 -0.77 61.64 -0.19 17.22 4.01 10.98 61.64 7.19 165.87 MWD+IFR-AK-CAZ-5C(3,3) 14,581.55 85.00 187.00 6,151.80 18.52 -3.25 59.82 -3.83 18.14 4.15 11.64 63.92 7.34 166.23 MWD(3,4) 14,601.55 85.00 187.00 6,153.54 18.52 -325 59.96 -3.80 18.14 4.15 11.65 64.05 7.34 166.27 MWD(3,4) 14,752.27 88.72 187.62 6,161.80 1824 -3.93 60.84 -3.74 18.15 4.16 11.72 65.10 7.35 166.63 MWD(3,4) 15,287.98 88.72 187.62 6,173.80 18.43 -3.93 65.28 -3.12 18.34 4.17 11.96 69.22 7.82 168.05 MWD(3,4) 15,584.00 89.34 181.73 6,178.82 18.59 -4.05 69.81 -1.56 18.54 4.18 12.12 71.63 8.08 168.70 MWD(3,4) 16,712.74 89.34 181.73 6,191.80 18.60 -4.04 66.72 -2.85 18.55 4.19 13.34 68.76 7.99 167.65 MWD+IFR-AK-CAZ-SC(4,4) 16,816.60 90.03 179.77 6,192.37 18.59 -4.19 67.53 -2.42 18.59 4.19 13.42 69.03 8.03 167.71 MWD+IFR-AK-CAZ-SC(4,4) 18,112.92 90.03 179.77 6,191.80 1923 -4.19 71.62 -2.42 19.23 4.19 14.42 72.98 8.67 168.60 MWD+IFR-AK-CAZ-SC(4,4) 18,169.39 89.11 180.44 6,192.22 19.33 -3.98 71.60 -2.58 19.27 4.19 14.47 73.12 8.68 168.63 MWD+IFR-AK-CAZ-SC(4,4) 20,213.40 89.11 180.44 6,223.80 20.85 -3.98 79.07 -2.58 20.79 4.21 16.16 80.35 9.83 170.11 MWD+IFR-AK-CAZ-SC(4,4) Casing Points r Measured Vertical ' ' Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C') 20,213.40 6,223.80 4-1/2"x 6-3/4" 4-1/2 6-3/4 3,885.33 3,015.80 10-3/4"x 13-1/2" 10-3/4 13-1/2 14,581.55 6,151.80 7-5/8"x 9-7/8" 7-5/8 9-7/8 110.00 110.00 20"x 42" 20 42 Formations Measured Vertical ,, Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 824.81 823.80 Top T-3 Sand 0.00 1,009.78 1,005.80 K-15 0.00 1,441.82 1,421.80 Base Permafrost 0.00 1,856.44 1,809.80 Top Ugnu(Ugnu C) 0.00 2,750.12 2,521.80 Top W Sak D 0.00 3,383.40 2,856.80 Top W SakA1 0.00 3,784.95 2,985.80 Base W Sak 0.00 12,819.23 5,685.80 Top HRZ 0.00 13,454.98 5,875.80 Base HRZ 0.00 13,826.39 5,986.80 K-1 0.00 14,119.76 6,071.80 Top C-4 0.00 14,147.59 6,078.80 B2 0.00 14,155.74 6,080.80 B1 0.00 14,381.64 6,126.80 A6 0.00 14,581.55 6,151.80 A5 0.00 9/3/2014 4:27:32PM Page 3 COMPASS 5000.1 Build 65 ORIGINAL. Schlumberger Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2F-21 Project: Kuparuk River Unit TVD Reference: Plan:95.8+28 @ 123.80usft(Doyon 141) Site: Kuparuk 2F Pad MD Reference: Plan:95.8+28 @ 123.80usft(Doyon 141) Well: Plan:2F-21 North Reference: True Wellbore: Plan:2F-21 Survey Calculation Method: Minimum Curvature Design: 2F-21wp04.1 Output errors are at 1.00 sigma Database: OAKEDMP2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 450.00 450.00 0.00 0.00 KOP:Start 1.5°/100'DLS,90°TF,for 148.34' 598.34 598.30 0.00 2.88 Start 2.5°l100'DLS,0°TF,for 506.66' 1,105.00 1,098.30 0.00 78.13 Adjust TF to 81.54°,for 284.42' 1,389.42 1,371.80 -17.43 153.54 Hold for 100' 1,489.42 1,467.23 -29.68 180.80 Start 3°/100'DLS,58.28°TF,for 2088.38' 3,577.80 2,923.89 -1,250.78 755.93 Hold for 10415.05' 13,992.85 6,036.55 -10,916.73 3,069.83 Start 4°/100'DLS,60.66°TF,for 588.7' 14,581.55 6,151.80 -11,489.02 3,099.91 Hold for 20' 14,601.55 6,153.54 -11,508.80 3,097.48 Start 2.5°/100'DLS,9.49°TF,for 150.72' 14,752.27 6,161.80 -11,658.04 3,078.33 Hold for 535.71' 15,287.98 6,173.80 -12,188.89 3,007.31 Start 2°/100'DLS,-84°TF,for 296.02' 15,584.00 6,178.82 -12,483.75 2,983.19 Hold for 1128.74' 16,712.74 6,191.80 -13,611.90 2,949.07 Start 2°/100'DLS,-70.78°TF,for 103.86' 16,816.60 6,192.37 -13,715.74 2,947.70 Hold for 1296.32' 18,112.92 6,191.80 -15,012.05 2,952.88 Start 2°/100'DLS,143.72°TF,for 56.47' 18,169.39 6,192.22 -15,068.52 2,952.78 Hold for 2044.01' 20,213.40 6,223.80 -17,112.23 2,937.11 TD:20213.4'MD,6223.8'TVD Checked By: Approved By: Date: 9/3/2014 4:27:32PM R i I NJ I\ L COMPASS 5000.1 Build 65 Pool Report lIR IGINAL <-88888$8 I O ,,88888§§0 O omm21.,-. 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InN 068 0 O m '\ CD Q Ch i T a) Fo, Q 00091 y ,00058 io cp, Q /Y� N ill- 0 0 0 CL H 2F-19A ---- ,�j 11V6L-3 2F-1W 0 r N ' T I C1V6 L-3z N - o Z 1V6L-3ZI -o rn it IZO-L78t-dZI ii O CD r LI)) t- N O T T N N CO CO m CDCO �e3i1ieA co CO anal ORIGINAL 2F-21 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 magnet interference.Drill with great care at the depth where Clearance Factor close to 1.5. 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 speed to avoid surging or swabbing. High ECD and wellbore breathing Low Condition mud prior to trips. Monitor MPD and PWD to with higher MW's required control ECD. Pump and rotate out on trips as needed. Lost circulation Low Use MPD and PWD to control ECD. 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,pre-treatment with lost circulation material, stabilized BHA,proper mud weight,PWD monitor ECD. Abnormal Reservoir Pressure Moderate Use MPD to monitor BHP in A&C sand.Reservoir pore pressure is estimated at 10.0 ppg.But there is chance of over pressured pay zone due to the offset well water injection. Well 2E-01 will be drilled just before of 2F-21 in the same reservoir block.Re-estimate the formation pressure based on 2E-01 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. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Moderate Use MPD to monitor BHP.Reservoir pore pressure is estimated at 10.0 ppg.But there is chance of over Ipressured `f /1 presssurejd� pay zone due to the offset water injection. Well �� ` I Prepared by Haibin Guo • 2E-01 will be drilled just before of 2F-21 in the same reservoir block.Re-estimate the formation pressure based on 2E-01 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. Lost Circulation Moderate Use MPD and PWD to control ECD. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Stuck pipe Low Good hole cleaning,pre-treatment with lost circulation material,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Low Control trip speeds,monitor proper hole fill while tripping,good hole cleaning.Pump or back ream out if necessary. iRINALIG Prepared by Haibin Guo 2F-21 CemCADE Preliminary Job Design Schlumberger 10 3/4" Surface Casino V3 Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 4311' MD. Client:CPAI Revision Date:September 2,2014 Prepared by:Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time: -260 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11.00 ppg -1.91 ft3/100 lb sk Mobile:(907)223-8916 email:jhouston2@slb.com 1.339 ft3/ft x 110 x 1.0 (0%excess) = 148 ft3 0.3637 ft3/ft x (1442-110) x 3.50 (250%excess) = 1696 ft3 < TOC at Surface 0.3637 ft3/ft x (3385-1442) x 1.50 (50%excess) = 1060 ft3 1696 ft3+ 1060 ft3+ 148 ft3= 2904 ft3 2904 ft3/ 1.91 ft3/sk= 1521 sks(1530 sks) Have additional DeepCRETE on location for Top Out stage, if necessary, Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x (3885-3385) x 1.50 (50%excess) = 273 ft3 0.54000 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/1.63 ft3/sk= 195 sks Round up to 205 sks BHST= 83°F, Estimated BHCT=76°F. (Based on 2.1 °F/100 ft.from surface) PUMP SCHEDULE < Base of Permafrost at Stage Cumulative 1,442'MD(-1,422'TVD) Pump Rate Stage Time Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 7.0 100.0 14.3 14.3 Pause 0.0 0.0 5.0 19.3 11 ppg DeepCRETE 7.0 517.0 73.9 93.2 Surface Tail 7.0 56.3 8.0 < Top of Tail at DeepCRETE Slurry 101.2 3385'MD Pause 0.0 0.0 5.0 106.2 Fresh Water 7.0 10.0 1.4 107.6 Pause 0.0 0.0 5.0 112.6 Mud 8.0 345.9 43.2 155.8 Mud 3.0 10.0 3.3 159.1 MUD REMOVAL < 10 3/4",45.5#casing in 13.5"OH Expected Mud Properties:9.5 ppg, Pv<20, Ty<20 Spacer Properties:10.5 ppg MudPUSH* II, Pv= 17-21, Ty=20-25 TD at 3885'MD Centralizers: As per CPAi program. (3016'TVD) Mark of Schlumberger UFdG1NAL 2F-21 CemCADE Preliminary Job Design Schlumberger 7 5/8" Intermediate v3 Preliminary Job Design based on limited input data.For estimate purposes only. Rig:Doyon 141 Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date:September 2,2014 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time: -240 min. (pump time plus 120 min.) Phone: (907)263-4207 15.8 ppg Class G +adds- 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.com Annular Volume: 0.2148 ft3/ft x (14582'- 13000') x 1.4 (40%excess) = 476 ft3 Shoe Volume: 0.2394 ft3/ft x 80' x 1.00 (no excess) = 20 ft3 Totals: 476 ft3+20 ft3= 496 ft3 496 ft3/ 1.16 ft3/sk= 428 sks(440 sks) BHST= 149 °F, Estimated BHCT= 118 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time 10 3/4",45.5# Stage (bpm) Volume (min) Time (bbl) (min) at 3885'MD CW100 7.0 40.0 5.7 5.7 MUDPUSH II 7.0 40.0 5.7 11.4 Pause 0.0 0.0 5.0 16.4 Tail Slurry 7.0 88.4 12.6 29.0 Pause 0.0 0.0 5.0 34.0 Fresh Water 7.0 10.0 1.4 35.4 Top of Tail at end of pumping Pause 0.0 0.0 5.0 40.4 < 13000'MD Mud 7.0 645.9 92.3 132.7 Mud 3.0 10.0 3.3 136.0 MUD REMOVAL 9 7/8"OH Recommended Mud Properties:10.0 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties:11.5 ppg MudPUSH* II, Pv=25-30, Ty=30 -40 Centralizers: As per CPAi program 7 5/8"29.7# TD at-14582'MD (6153'TVD) Mark of Schlumberger 0 NAL Ferguson, Victoria L (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Thursday, September 25, 2014 3:16 PM To: Ferguson,Victoria L(DOA) Subject: RE:2F-21(PTD 214-136) Diverter Route Attachments: Diverter Route for AOGCC.pdf Victoria,see the attachment. Hopefully this is what you want to see. If anything else you need let me know. Can you let me know the API#of this well? Thanks. Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent:Thursday, September 25, 2014 1:55 PM To: Guo, Haibin Subject: [EXTERNAL]RE: 2F-21(PTD 214-136) Diverter Route Haibin, This is a generalized diverter route plan. We need to see how the rig will sit and the route of the diverter on 2F pad. Every pad is different in terms of road access, ignition sources and a suitable discharge area for the diverter. Please obtain a map of the pad and have the rig and the planned diverter route sketched on with dimensions. 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 qov CONFIDENTIALI1Y 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 Victoria Ferguson at (907)793-1247 or Victoria.Ferguson@alaska.gov From: Guo, Haibin [mailto:Haibin.Guo©conocophillips.com] Sent: Wednesday, September 24, 2014 2:00 PM 1 To: Ferguson, Victoria L(DOA) Subject: RE: 2F-21(PTD 214-136) Victoria, See the diverter route on Doyon 141 and the approximate length as attached. Hopefully it is what you are looking for. The estimated reservoir pressure is most likely about 3200psi(10.0ppg).That's the reason we plan to use 10.3-10.5ppg MW. 3500psi is the estimated possible maximum pressure,the chance to see that pressure is low. If you need anything else let me know. Thanks. Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson©aalaska.gov] Sent: Wednesday, September 24, 2014 11:11 AM To: Guo, Haibin Subject: [EXTERNAL]2F-21(PTD 214-136) Haibin, Please provide a schematic of the diverter route from the Doyon 141 on the pad. Include approximate diverter length dimensions. The maximum reservoir pressure of 3500 psi(10.9 ppg) is outlined in your application. However,the mud density is shown as 10.3-10.5 ppg EMW. Why doesn't the range on your mud program cover the maximum reservoir pressure? The maximum reservoir pressure of 3500 psi should be shown on the Permit to Drill Application(10-401)form. I will correct. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 victoria ferqusonalaska qov 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 Victoria Ferguson at(907)793-1247 or Victoria.Ferguson©alaska.gov 2 adrd ,warm.. ...un+., 0610.6w0 01 i , i i 1 i 1111 yy ypii I o IOil yix p 1 N i yQQ8 q N O I 3' NU MATCH DNC. i 1 160'-.• I ro•-0- ro'-0- ro'-.• YO'K'• 1 T Jl u #. 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I i.1 i E n t i II II .1::: Nil 1 A 3 C;; i �r . ---- _-- •--------- 1 ' NI ! ® mem 7 ® $1Egi J h i-1„.- - t FM 111 1 i li 1 — j ] 3 4 v�a _ NI.s 1 i Bettis, Patricia K (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Monday, September 15, 2014 3:18 PM To: Bettis, Patricia K (DOA) Cc: Cecil-Cockwell, Tess M Subject: RE: KRU 2F-21: Permit to Drill Application Patricia, We are planning for a 3 months pre-produce to clean up the well. Any question about the permit let me know. Thanks. Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell: 907.227.6048 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, September 15, 2014 3:05 PM To: Guo, Haibin Subject: [EXTERNAL]KRU 2F-21: Permit to Drill Application Good Afternoon Haibin, Does ConocoPhillips plan to pre-produce KRU 2F-21 and if so, for what duration? 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: K2u1/4 ,2F- 2.1 PTD: ), l - I'bC _Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: K .J- (kJ Ek7 POOL: i v pc.ir A.1.04T-` bAl -4 RI\ a ) Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS I 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 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by J (Company Name) in the attached application, the following well logs are Well Logging,n also required for this well: Requirements 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. Revised 4/2014 Co co O) 0 a) a -o N N 7 a) 0 ui E a) 0) -° m C a - C c a Tu C Co Q o a t O U N a) 2 co 0 co 3 w w c p Cr) 0) CL c o O 6 a a 'rn co (o 7 c N 6 O o = O O 12 ui D O in w C m :E dN 3 C 0 0 C O o c Co 7 C -1- ,- 3 Q v a) E O ' o o = a Coa Nm O • a C c _ _ a 00 p 0 a) _ ,- o 0 0) _c o53 o C 4 = 0) O > N O o V N "O C C� >� a) C' 7 (D co C p C N N W ` N - U U = O C a 6 Co o p m n r M 'O O = a) 3 .....- c a N E a O Q7 Co c N N co N C J Co a' - = co Cl) 7 0 Co 0 7 Co .0 0 o a) N a O 7 a) - 7 ,-- a) D < r N 3 a m o '� m m m o . 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ON U O coce C OMO Ci ,_ O) 0 (f) 0 (p O N N d `� CB E rn rn c E J N N a) m o C C 0 s- W OIC a CO a -1 0 a s 0 y a a a w a s Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history the. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. FINAL WELL REPORT SURFACE LOGGING DATA 2F-21 Kuparuk River Unit Provided by: Approved by: Phil Bottrell Compiled by: Tollef Winslow Greg Hammond E l i j a h C a l l a n Distribution: 12/5/2014 Intermediate T.D. Date: 11/10/2014 KRU 2F-21 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................7 3.1 Lithostratigraphy .............................................................................................................................7 3.2 Mudlog Summary............................................................................................................................8 3.2.1 Base of West Sak....................................................................................................................8 3.2.2 HRZ (K-2 Marker)..................................................................................................................22 3.2.3 Kalubik...................................................................................................................................24 3.2.4 Kuparuk C (Top C4) ..............................................................................................................27 3.2.5 B2 Sand.................................................................................................................................28 3.2.6 A6 Sand.................................................................................................................................29 3.2.7 A5 Sand.................................................................................................................................30 3.3 Gas Event Summary.....................................................................................................................31 3.3.1 Connection Gas.....................................................................................................................31 3.3.2 Trip/Downtime Gas................................................................................................................32 3.4 Sampling Program / Sample Dispatch..........................................................................................32 4 PRESSURE / FORMATION STRENGTH DATA.................................................................................33 4.1 Pore Pressure Evaluation.............................................................................................................33 4.2 Pore Pressure Plot........................................................................................................................34 4.3 Quantitative Methods....................................................................................................................35 5 DRILLING DATA..................................................................................................................................36 5.1 Survey Data..................................................................................................................................36 5.2 Bit Record.....................................................................................................................................42 5.3 Mud Record ..................................................................................................................................43 6 SHOW REPORTS ...............................................................................................................................44 7 DAILY REPORTS ................................................................................................................................48 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Data CD KRU 2F-21 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Level 1 Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 Effective Circulating Density (ECD) Schlumberger 0 Hook Load / Weight on bit WITS from Totco 0 Mud Flow In RigWatch Calculated 0 Mud Flow Out Nabors 9ES 0 Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 Mudlogging Unit DAC box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss WITS from Totco 0 Pump Pressure WITS from Totco 0 Pump stroke counters WITS from Totco 0 Rate of Penetration RigWatch Calculated 0 RPM WITS from Totco 0 Torque WITS from Totco 0 1.2 Crew Unit Type : Arctic Steel Unit Number : ML056 Geologists Years1 Days2 Sample Catchers Years Days2 Tollef Winslow 6 19 Larry Turner 14 11 Greg Hammond 4 19 Dean Kekaualua 9 7 Elijah Callan 0.5 17 1 Years experience as Logging Geologist 2 Days at wellsite between spud and total depth of well KRU 2F-21 3 2 WELL DETAILS 2.1 Well Summary General Well Information Well: 2F-21 API Index #: 50-029-23525-00-00 Field: Kuparuk River Unit Permit to Drill: 214-136 Borough: North Slope Surface Co- Ordinates: 171’ FNL, 1731’ FEL, SEC. 33, T11N, R9E, UM State: Alaska Ground Elevation: 96’ MSL Classification: Single Zone Water Injector RT Elevation: 124’ AMSL Rig Name / Type: Doyon 141 / Arctic Land Triple Spud Date: October 15, 2014 Target: Kuparuk A5 Target Depth: 14520’ MD / 6135’ TVD Days Drilling Intermediate: 10 Intermediate TD Date: November 10, 2014 Intermediate TD Depth: 14617’ / 6152’ Intermediate TD Formation: Kuparuk A5 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD ft TVDSS ft TD Formation Mud Weight ppg Dev. oinc Casing/ Liner MD ft TVDSS ft FIT / LOT ppg 13.5” 4006 2907 Base W Sak 8.6 71.04 10.75” 3996 2904 13.2 9.875” 14617 6029 Kuparuk A5 9.8 81.42 7.625” 14607 6149 - KRU 2F-21 4 2.3 Daily Activity Summary October 27, 2014: Continue to pick up drill pipe. Move surface equipment from cellar; stage rotating head in cellar; test weld; weld fail; re-weld; continue wellhead work. Canrig unit spotted and powered up; continuing rig-up. October 28, 2014: Continue cleaning rig; fabricate and install new mud bucket line, work on mud pump 2; test welded void; prep and nipple up new wellhead and BOP; install rotating head and control valve on BOP; rig down control value, rotate 180, reinstall; install hoses, connect air and hydraulic fittings, continue to wire up 600v in cellar; pick up test plug and trip nipple to rig floor; continue to rig up in cellar October 29, 2014: Continue to rig up MPD equipment; continue to weld on mud bucket line. Measure and cut trip nipple; attempt to install; would not line up properly to lock in; pull same; weld D rings on same. Attempt to set test plug; had to set 4 klbs on plug to seat; pull plug per Cameron rep; noticed 2 gashes in test plug O ring; change out O-ring; set test plug using weight to seat; pull test plug and observed 1 gash in O-ring; suspect is the upper lockdown. Re-run test plug; observed gash in test plug O-ring; back out all upper lockdowns; run test plug and observed more scarring at 24' MD. Decision was made to nipple down BOPE at casing spool to inspect wellhead; wellhead had burr in profile; Cameron rep repaired same; rerun test plug in profile (good); tighten gland nuts on wellhead. Nipple up BOPE; install turnbuckles and trip nipple. Rig up for body test on BOPE; test annular with 5" test joint to 250/3500 psi for 5 min on chart; rig down test joint; rig up pressure sensor on RCD and secondary retention lines on RCD; flood lines; initial test on RCD and manifold body to 250/1500 psi for 10 min on chart; test all valves on MPD skid 250/1000 psi for 10 min on chart. October 30, 2014: Continue to test MPD manifold; rig down test equipment; pull test plug; set trip nipple. Rig up BOPE test equipment; install 5" test joint; rig up scaffolding in cellar; break and turn flowline valve to 90 degrees on RDC; install Katch Kan on BOPE. Test BOPE. Rig down test equipment; install valve on annular on closed side; function test. Pull trip nipple; change out seals on same; attempt to install; decision was made to make bigger holes for easier installation. Set wear bushing 10.25" ID. Continue to set trip nipple. October 31, 2014: Continue to set trip nipple; test; install Katch Kan blanket. Make up BHA; load nukes; continue to make up BHA; shallow pulse test. Single in hole to 1863'. Slip and cut drilling line; adjust brakes; lubricate rig. Single in hole to 3437'; run in from derrick to 3622'; break circulation; wash and ream cement stringers to 3860'; drill cement to 3892'. Circulate hole clean; even mud weight in/out. Rack back one stand; rig up to test casing. Test casing to 3000 psi/30 min; rig down test equipment. Rig up air purge hoses on Totco screen; troubleshoot. Run in; tag cement; drill cement to 3905'; tag plug and float equipment; drill to 3910'. November 1, 2014: Continue drilling float equipment and cement to casing shoe at 3997’. Drill 20’ new hole to 4026’. Rack back one stand to 4006’; circulate and condition; rack back one stand to 3909’. Perform LOT to 13.2 ppg EMW. Displace well to 9.6 LSND mud. Lay down working joint; rack back 2 stands to 3814’. Pull trip nipple; rig up RCD and training in pipe shed; set RCD on rotating head. MPD system discussion; establish fingerprint for MPD; blow down MPD choke, lines, and return lines. Pull RCD head to rig floor; remove KRU 2F-21 5 from stump; install trip nipple and secure; pick up stand and run in to 3906’. Break circulation. Rig troubleshooting. Run in to 4006’; ream and tag bottom. Drill from 4026’ to 4065’. November 2, 2014: Drill from 4065’ to 5893’. Ream stand; survey on bottom; circulate bottoms up; even mud weight in/out; rack back stand; blow down top drive; monitor well. Perform FIT test to 12.2 ppg EMW. Drill from 5893’ to 6198’. November 3, 2014: Drill from 6198' to 7295'. Observed pump pressure and torque increase; pick up off bottom; slow pumps and rotation; pick up to tool joint; observe well for flow for 15 min (slight to none); decision made to rack back and circulate bottoms up. Circulate bottoms up; increased cuttings load at shakers; ECDs dropped 0.4 after circulation; decision made to drill ahead. Drill from 7295' to 7840'. November 4, 2014: Drill from 7840’ to 8024’. Observed well flowing on connection; monitor well; flowed back 9.5 bbl before becoming static; well packed off at 7975’ while drilling. Drill from 8024’ to 8305’; hole packing off on back reaming stand at 8275’; reduce pump rate working stand and regain full returns at reduced pump rate; ream full stand back to 8307’; lost 36 bbl while drilling and back reaming stand. Monitor well; gained 4 bbl in 30 min. Circulate bottoms up at 8307’. Drill from 8307’ to 9235’. November 5, 2014: Drill from 9235’ to 9356’. Hole packing off at 9340’; rack back one stand to 9263’; regained circulation at 9194’; stage pumps and wash to bottom; flow 55%; lost 140 bbl to hole. Drill from 9356’ to 10466’. November 6, 2014: Drill from 10466’ to 11867’. Change out liner and swab on mud pump #1; circulate and reciprocate pipe. Drill from 11867’ to 11961’. November 7, 2014: Drill from 11961’ to 12238’. Circulate bottoms up three times. Blow down top drive; monitor well for 30 min. Pull out of hole on elevators from 11960’ to 4003’. Monitor well. Circulate bottoms up. Rack back stand; blow down top drive. Rig up MPD system; walk through mud flow chart with safekick rep; tune in MPD choke with rep; pump to establish baseline pressures and speed; practice ramp up/down per MPD rep. November 8, 2014: Walk through MPD lines and practice ramping up/down pumps; blow down top drive. Trip in hole from 3997’ to 8200’ @ 2000 ft/hr, filling every 20 stands; circulate bottoms up; continue to trip in to 12148’. Break circulation; wash and ream from 12148’ to 12238’; circulate bottoms up. Displace well from 9.8 ppg to 9.6 ppg per mudman. Get slow pump rates. Drill from 12238’ to 12778’. November 9, 2014: Drill from 12778’ to 14276’ November 10, 2014: KRU 2F-21 6 Drill from 14276’ to 14617’. Circulate bottoms up x3; rack back one stand each bottoms up; adjust MPD choke to maintain 11.0 ECD. Start weighting up mud system from 9.8 ppg to 10.9 ppg by bleeding in 14.0 ppg spike fluid in three stages; adjust MPD choke and pump pressure to maintain 11.0 ECD. Monitor well while rotating. Change out rotating head per MPD rep. Blow down top drive; line up to pump across top of hole via MPD choke; line up to strip out of hole. Pull out of hole from 14617’ to 14093’; make up top drive and pump out to 14021’. November 11, 2014: Pull out of hole from 14093’ to 11867’. Pump 13.0 ppg slug; blow down top drive. Pull out from 11867’ to 3907’; hold pressure with MPD. Clean and clear rig floor; slip and cut 74’ drilling line; service rig. Pull out of hole from 3909’ to 1863’. Blow down MPD choke manifold and lines; pull rotating head and remove from stump; install trip nipple; line up mud bucket and hole fill lines; line up flow line; remove MPD return lines. Lay down ghost reamer; continue to pull out from 1863’ to 732’; monitor well (static); rack back HWDP to 548’; downlink MWD tools. Blow down top drive; pull out from 548’ to 276’; rack back last stand HWDP; lay down flex collars; remove sources; lay down BHA; break bit; lay down powerdrive. Clean and clear rig floor; lay down MWD tools. Rig up and flush stack; blow down top drive; rig down stack washer. Change out upper rams to 7-5/8” solid body rams; pull wear ring; set test plug; rig up to test BOPE. KRU 2F-21 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to picks by the CPAI geologist. PROGNOSED LWD PICK FORMATION / HORIZON MD ft TVDSS ft MD ft TVDSS ft Top T-3 Sand 825 -700 804 -680 K-15 Marker 1,010 -882 1,014 -888 Base Permafrost 1,443 -1,298 1,476 -1,326 Top Ugnu (Ugnu C) 1,861 -1,685 1,801 -1,623 Top W Sak (W Sak D) 2,779 -2,403 2,727 -2,358 Top W Sak A1 3,507 -2,755 3,473 -2,739 Base W Sak 3,915 -2,879 3,720 -2,818 Fault 1 5,700 -3,433 - - Fault 2 12,053 -5,515 12,150 -5,420 Top HRZ (K-2 Marker) 12,475 -5,513 12,553 -5,540 Upper Kalubik (Base HRZ) 13,390 -5,734 13,487 -5,770 Lower Kalubik (K-1 Marker) 13,918 -5,862 13,932 -5,878 Fault 3 14,183 -5,933 - - Kuparuk C (Top C4) 14,245 -5,942 14,275 -5,960 B2 14,270 -5,950 14,297 -5,965 B1 14,280 -5,952 - - A6 14,480 -5,993 14,412 -5,992 A5 14,619 -6,016 14,520 -6,012 KRU 2F-21 8 3.2 Mudlog Summary 3.2.1 Base of West Sak 3720’ MD to 12,544' MD (-2818’ TVDSS to -5538' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 277 10 108 657 0 55 Lithology Sandy siltstone/claystone (4006' - 4150') = olive gray to medium dark gray; clumpy clayey siltstone to mushy silty claystone to pasty claystone; poorly to non cohesive; poorly to non adhesive; commonly expansive; weak to sectile to soft crumbly; massive structureless cuttings; gritty to sucrosic to smooth texture; interbedded and embedded with loose sand; upper very fine to lower fine; well sorted; subangular to well rounded; colorless quartz predominant with abundant gray to black lithics and smoky quartz; salt and pepper appearance; trace to rare yellowish gray soft sucrosic devitrified tuff; weak to no odor; trace to spotty stain; spotty moderate greenish yellow and yellowish gold sample fluorescence; pale greenish yellowish white cut fluorescence; moderate bright yellow residual cut; no visible cut or residual cut. Claystone/siltstone (4150’ - 4260’) = olive gray to dark gray with brownish hues; mushy to stiff; soft to sectile; poorly to moderately cohesive; weakly to non adhesive; massive hydrophilic cuttings; no apparent structure; gritty to clayey to sucrosic texture; silty claystone predominant; grades to both smooth claystone and sandy silty claystone; associated sands very fine to fine with salt and pepper appearance; trace soft sucrosic yellowish gray tuff; scattered weakly calcareous; moderate odor; trace stain; scattered yellowish gold to gold fluorescence; weak to moderate pale to milky yellowish white slow to streaming cut fluorescence; transparent dark straw visible cut; moderate yellow residual cut fluorescence; weak amber residual visible cut. Claystone/siltstone (4260' - 4330') = olive gray to medium dark gray; brownish hues; lumpy to mushy to stiff; sectile to soft; moderately cohesive; weakly to moderate adhesive; massive cuttings; no apparent structure; smooth to gritty; sands as above; weak to moderate odor; trace stain; trace to spotty dull gold fluorescence; weak to moderate milky yellowish white streaming cut fluorescence; transparent straw visible cut; moderate to strong bright yellow residual cut fluorescence; pale straw to amber residual visible cut. Claystone/siltstone (4330' - 4395') = olive gray; mushy to clumpy; soft to weakly sectile; non cohesive; weakly adhesive; structureless massive cuttings; smooth clayey texture predominant with silty to gritty; no stain; weak to moderate odor; trace dull gold fluorescence; weak milky yellowish white cut fluorescence; no visible cut; weak bright yellow residual cut fluorescence; no residual visible cut. Sand (4395' - 4420') = olive gray with olive black and dark gray; brownish hue; lower fine to lower medium; rare upper medium to coarse; grades to silt; well sorted; colorless transparent quartz predominant; abundant gray to black lithics; common greenish gray lithics; rare reddish brown volcanic lithics; salt and pepper appearance; subangular to angular predominant; scattered subround to rounded; moderate sphericity; scattered pinpoint free oil; scattered stain; moderate to strong odor; patchy to even moderate bright yellow fluorescence; moderate yellowish white slowly streaming cut fluorescence; very pale transparent straw visible cut; moderate yellowish gold residual cut fluorescence; very pale straw residual visible cut. KRU 2F-21 9 Claystone/siltstone (4420' - 4550') = olive gray to light olive gray; soft; poorly indurated; cohesive; clumpy to lumpy consistency; stiff to elastic tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey, some gritty texture; massive structure; sand, lower fine, well sorted, moderate sphericity, sub angular, transparent quartz; sand stringers, slight oil odor, no grain stain, 5% sample patchy golden yellow fluorescence, immediate streaming bright white cut fluorescence, light amber visual cut; medium light amber visual residual cut; bright yellow residual fluorescence, no oil at shakers Claystone/siltstone (4450' - 4700') = olive gray to light olive gray; soft; poorly indurated; cohesive, slightly adhesive; clumpy to lumpy consistency; stiff to elastic tenacity; earthy fracture; massive cuttings habit; dull to earthy luster; clayey to silty to gritty texture; massive structure; sand, upper fine to lower fine, spherical to sub discoidal, sub round to sub angular, unconsolidated, translucent or transparent quartz, rare pyrite; tuffaceous clay, white to very light gray, soft, poorly indurated, cohesive, clumpy consistency, stiff tenacity, earthy fracture, massive cuttings habit, earthy luster, clayey texture, massive structure, free oil in tuffaceous clay, slight odor, 30%bright yellow sample fluorescence, immediate streaming bright white cut fluorescence, clear white light cut, light yellow residual fluorescence, no residual cut fluorescence, no oil at shakers, some sand grains also have same oil characteristics without free oil; porosity and permeability visually fair. Claystone/siltstone (4700' - 4800') = olive gray to light olive gray; soft; poorly indurated; cohesive; clumpy to lumpy consistency; stiff to elastic tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey, some gritty texture; massive structure; sand, lower fine, well sorted, moderate sphericity, sub angular, transparent quartz; sand stringers; 20% bright yellow orange sample fluorescence; immediate bright streaming white cut fluorescence, very light amber white light cut, bright yellow residual cut fluorescence, light brown residual cut fluorescence. Claystone/siltstone (4800' - 4900') = olive gray to light olive gray; soft; poorly indurated; cohesive, slightly adhesive; clumpy to lumpy consistency; stiff to elastic tenacity; earthy fracture; massive cuttings habit; dull to earthy luster; clayey to silty to gritty texture; massive structure; sand, upper fine to lower fine, spherical to sub discoidal, sub round to sub angular, unconsolidated, translucent or transparent quartz; 20% bright yellow sample fluorescence; immediate bright streaming white cut fluorescence, very light amber white light cut, bright yellow residual cut fluorescence, light brown residual cut fluorescence. Siltstone/claystone (4900' - 5000') = olive gray to light olive gray; soft; poorly indurated; cohesive and adhesive; clumpy to lumpy consistency; stiff to elastic tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; massive structure; sand, lower fine to upper very fine, occasional medium; spherical to sub discoidal; sub angular to sub round; well to moderately well sorted; unconsolidated; texturally immature; compositionally sub mature; quartz, translucent to transparent; black lithics; predominately siltstone; free oil in 4950' sample, slight oil odor, 10% to 20% of sand grains light brown oil stain, 40% to 50% patchy bright yellow sample fluorescence, instantaneous streaming bright white cut fluorescence, very light amber cut, bright yellow residual cut fluorescence, no visual residual cut; porosity and permeability visually good. Siltstone/claystone (5000' - 5150') = olive gray to light olive gray; soft; poorly indurated; cohesive and adhesive; clumpy to lumpy consistency; stiff to elastic tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; massive structure; sand, lower fine to upper very fine, occasional medium; spherical to sub discoidal; sub angular to sub round; well to moderately well sorted; unconsolidated; texturally immature; compositionally sub mature; quartz, translucent to transparent; black lithics; trace pyrite; mostly siltstone; slight oil odor; no grain stain; 20% - 40% bright golden yellow sample fluorescence; instantaneous streaming bright white cut fluorescence; very light amber cut; bright yellow residual cut; porosity and permeability visually fair. Siltstone/claystone (5150' - 5300') = olive gray to light olive gray; soft; poorly indurated; cohesive and adhesive; lumpy to clumpy consistency; stiff to elastic tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; massive structure; predominately siltstone; sand, lower KRU 2F-21 10 fine to upper fine, spherical to sub discoidal, sub angular to sub rounded, well to moderately well sorted, unconsolidated, texturally immature, compositionally sub mature, translucent or transparent quartz, black lithics, pyrite; grayish white volcanic tuff; very faint oil odor; no grain staining; 20% - 40%bright golden yellow or yellow orange sample fluorescence; no grain stain; instantaneous streaming white cut fluorescence; very light amber cut; very light amber residual cut; bright yellow residual cut fluorescence; porosity and permeability visually good. Siltstone/claystone (5300' - 5400') = olive gray to light olive gray; soft; poorly indurated; cohesive and adhesive; lumpy to clumpy consistency; stiff to elastic tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; massive structure; predominately siltstone; sand, lower fine to upper fine, some upper to lower coarse, sub angular to sub round, well to moderately well sorted, unconsolidated; texturally immature, compositionally sub mature, translucent or transparent quartz, black lithics, black or translucent chert; slight to faint oil odor; 10% quartz grains light brown oil stain; instantaneous blooming to streaming bright white cut fluorescence; no cut fluorescence; no residual cut fluorescence; bright yellow residual cut fluorescence; porosity and permeability visually good. Siltstone/claystone (5400' - 5450') = olive gray to light olive gray; soft; poorly indurated; cohesive and adhesive; lumpy to clumpy consistency; stiff to elastic tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; massive structure; very slight oil odor; no grain stain; 20% bright golden yellow sample fluorescence; instantaneous blooming to streaming cut fluorescence; no visual cut; no visual residual cut; bright golden yellow residual cut fluorescence. Sand (5450' - 5500') = olive gray to light olive gray; upper fine to lower fine, occasional lower medium; spherical to sub discoidal; sub round to subangular; well to moderately well sorted; unconsolidated; texturally immature; compositionally sub mature; quartz, translucent or transparent; slight oil odor; no grain stain; 35% bright golden yellow sample fluorescence; streaming white cut fluorescence; clear visual cut; no visual residual cut; bright yellow residual fluorescence cut; porosity and permeability visually good. Siltstone/claystone (5500' - 5660') = olive gray to light olive gray; soft; poorly indurated; stiff to elastic; earthy or planar fracture; massive cuttings habit; earthy to dull luster; silty to gritty to clayey texture; massive structure with occasional carbonaceous laminations within some siltstone, entrained carbonaceous material; sand, lower fine to upper fine, spherical to sub discoidal, sub angular to sub round, well to moderately well sorted, unconsolidated, texturally immature, compositionally sub mature, quartz, translucent or transparent, black lithics, trace to rare pyrite; very slight oil odor; no grain stain; 10% scattered golden yellow sample fluorescence, 5% scattered bright yellow sample fluorescence; streaming bright yellow cut fluorescence; no visual cut; no visual residual cut; bright yellow residual fluorescence; porosity and permeability sand visually good. Claystone/siltstone (5660' - 5780') = olive gray with light olive gray grading to dark gray; soft to clumpy; mushy to sectile; moderately cohesive; weakly adhesive to tacky; soft to malleable to crumbly; irregular fracture; massive cuttings; no apparent structure; silty to gritty clayey texture; interbedded and embedded with fine to very fine sand grading to coarse silt; colorless quartz predominant; abundant gray to black lithics; trace muscovite; rare microcrystalline pyrite; rare moderate brown volcanic lithics; subangular to angular; non calcareous overall; rare medium to very coarse sized blocky to elongate opaque to translucent calcite crystal fragments; no odor; no visible stain; trace pinpoint gold fluorescence; weak yellowish white cut fluorescence; no visible cut; pale bright yellow residual cut fluor. Claystone/siltstone (5780' - 5820') = olive gray to dark olive gray and medium dark gray; mushy to clumpy; soft to crumbly; moderately to poorly cohesive; massive cuttings and structure; gritty to silty to clayey texture; loose and embedded sand as above; poor indicators as above. Sand (5820' - 5890') = olive gray to dark gray; salt and pepper appearance; lower fine to lower medium; very rare very coarse rounded grains; well sorted; subangular to angular with occasional subround; moderate to high sphericity; transparent to translucent colorless quartz predominant; abundant gray to KRU 2F-21 11 black lithics; scattered smoky quartz and dark greenish gray lithics; very rare reddish brown volcanics; occurs as loose grains with scattered brittle grain supported sandstone fragments; non to weakly calcareous; rare dull gold pinpoint fluorescence; very weak pale yellow cut fluorescence; no other oil indicators. Claystone/siltstone (5890' - 6040') = olive gray with light olive gray to dark gray sands; occasional medium dark gray to dark gray shaly siltstone fragments; mushy to pasty; very soft to sectile; poorly cohesive; moderately adhesive; siltstones crumbly to dense; massive to irregular planar cuttings; internally structureless; smooth to gritty texture; non to weakly calcareous; interbedded and embedded with lower fine to lower medium sands; trace crunchy grain supported very fine to fine grained sandstone fragments with calcareous cement; rare dull gold pinpoint fluorescence; no fluorescence overall; trace fragments of silty very fine grained sandstone with moderate gold fluorescence, moderate streaming yellowish white cut fluorescence, dull to moderate yellowish gold residual cut fluorescence, no visible cut or residual cut. Claystone (6040' - 6100') = olive gray to olive black; mushy to clumpy; soft to malleable to sectile; poorly to moderately cohesive; moderately adhesive; tacky; irregular to earthy planar fracture in firmer cuttings; massive to subtly bedded structure; smooth to gritty clayey texture; loose and embedded very fine to fine grained sands as above; trace to spotty moderate dull yellowish gold fluorescence; very weak odor. Claystone/siltstone (6100' - 6210') = olive black to olive gray; mushy to clumpy soft to sectile silty claystone to soft crumbly clayey siltstone; irregular fracture; massive cuttings and structure; smooth to gritty texture; occasional crumbly to soft brittle dark gray platy sucrosic siltstone; associated sands very fine to fine grained grading from coarse silt, quartzose with abundant gray to black lithics; rare muscovite; trace brittle grain supported silty sandstone fragments; weakly to moderately calcareous overall; very rare stain; weak odor; trace pinpoint dull yellowish gold fluorescence; very weak slow yellowish white cut fluorescence; no visible cut; very weak yellowish white residual cut fluorescence; no visible residual cut. Claystone (6210' - 6270') = olive gray; mushy to pasty; soft to sectile; poorly cohesive; moderately adhesive; expansive; irregular fracture in silty fragments; massive cuttings; no apparent structure; smooth to silty to gritty texture; very fine to fine sand grading from coarse silt as above; rare muscovite; moderately to weakly calcareous; poor oil indicators as above. Claystone/siltstone (6270' - 6360') = olive gray to olive black; mushy to clumpy; soft to sectile; malleable; massive cuttings; no apparent structure; smooth to gritty texture; poorly cohesive; weakly to moderately adhesive; very fine lithic subquartzose very fine to fine sands and coarse silt; moderately calcareous; trace pinpoint dull gold fluorescence with very weak cut fluorescence; no other oil indicators in bulk sample; rare silty sandstone fragments with moderate gold fluorescence; moderate streaming yellowish white cut fluorescence, dull to moderate yellowish gold residual cut fluorescence, no visible cut or residual cut. Claystone (6360' - 6410') = olive gray; mushy to pasty; soft to weakly sectile; expansive; poorly cohesive; tacky; malleable; massive cuttings; smooth to silty texture; no apparent structure; loose and embedded very fine to fine lithic subquartzose sand and coarse silt; non to weakly calcareous; rare pinpoint dull gold fluorescence; no other oil indicators. Claystone/siltstone (6410' - 6500') = olive gray to olive black; mushy to clumpy; malleable to soft crumbly to sectile; poorly to moderately cohesive; moderately adhesive; expansive; massive cuttings; massive structure; smooth to gritty texture; sucrosic texture in siltier fragments; occasional irregular platy soft shaly siltstone fragments; very fine to fine grain quartz and gray to black lithic sand; trace muscovite; rare microcrystalline pyrite; non to weakly calcareous overall; rare blocky to prismatic opaque to translucent void- filling calcite crystals; trace pinpoint dull gold fluorescence; no other oil indicators Claystone/siltstone (6500' - 6550') = olive gray; mushy to pasty; soft to sectile and malleable; occasional crumbly to brittle silty fragments; irregular fracture and cuttings habit predominant; occasional platy siltstones; smooth to gritty to silty sucrosic texture; massive structure; very fine to fine grain quartz and KRU 2F-21 12 gray to black lithic sand; trace muscovite; rare microcrystalline pyrite; non to weakly calcareous overall; trace pinpoint dull gold fluorescence; no other oil indicators. Siltstone/claystone (6550' - 6650') = olive gray to light olive gray; soft; stiff to flexible to crunchy tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; massive structure; formation tends more towards silt than clay; sand, upper very fine to lower fine, spherical to sub discoidal, sub angular to sub round, well to moderately well sorted, quartz with gray and black lithics, rare microcrystalline pyrite; no oil odor; no grain stain; pin point dull gold yellow sample fluorescence; very slow dull white streaming cut; no other oil indicators. Claystone/siltstone (6650' - 6750') = olive gray; soft; poorly indurated; cohesive and adhesive; clumpy to lumpy; stiff to elastic to sectile tenacity; earthy to open fracture; massive cuttings habit; dull to earthy luster; clayey to silty to gritty texture; massive structure; sand, upper very fine to lower fine, spherical to sub discoidal, sub angular to sub round, well to moderately well sorted, quartz with gray and black lithics, rare microcrystalline pyrite; no oil odor; no grain stain; pin point dull gold yellow sample fluorescence; very slow dull white streaming cut; no other oil indicators. Siltstone/claystone (6750' - 6850') = olive gray to light olive gray; soft; stiff to flexible to crunchy tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; massive structure; formation tends more towards silt than clay; sand, upper very fine to lower fine, spherical to sub discoidal, sub angular to sub round, well to moderately well sorted, quartz with gray and black lithics, rare microcrystalline pyrite; no oil odor; no grain stain; pin point dull gold yellow sample fluorescence; very slow dull white streaming cut; no other oil indicators. Claystone/siltstone (6850' - 6950') = olive gray; soft; poorly indurated; cohesive and adhesive; clumpy to lumpy; stiff to elastic to sectile tenacity; earthy to open fracture; massive cuttings habit; dull to earthy luster; clayey to silty to gritty texture; massive structure; sand, upper very fine to lower fine, spherical to sub discoidal, sub angular to sub round, well to moderately well sorted, quartz with gray and black lithics, rare microcrystalline pyrite; no oil odor; no grain stain; pin point dull gold yellow sample fluorescence; very slow dull white streaming cut; no other oil indicators. Siltstone/claystone (6950' - 7050') = olive gray; soft; poorly indurated; stiff to elastic to flexible tenacity; earthy to open fracture; massive cuttings habit; earthy to dull luster; silty to gritty to clayey texture; massive structure; sand, upper very fine to lower fine, spherical to sub discoidal, sub angular to sub round, well to moderately well sorted, quartz with gray and black lithics, rare microcrystalline pyrite; no oil odor; no grain stain; pin point dull gold yellow sample fluorescence; very slow dull white streaming cut; no other oil indicators. Sandy Siltstone/claystone (7050' - 7150') = olive gray to brownish gray; soft to firmly friable with poor to moderate induration; stiff to elastic tenacity; massive cutting habit; silty to clayey texture with some grittiness; earthy and dull luster; moderate cohesiveness with moderate to good adhesiveness; consistency is clumpy and lacks bedding; abundant quartz and lithics with sparse muscovite, pyrite and zeolite; sand is upper fine grained with occasional lower coarse; low to high sphericity; angular to sub rounded; texturally immature and compositionally sub-mature; 50% quartz 40% lithics 10% accessory minerals as mentioned above oil; no scent present; trace staining with a light brown color; trace florescence with even distribution; dull yellow to bright orange; no other oil indicators. Claystone/siltstone (7150' - 7250') = medium light gray to medium gray; soft to easily friable with poor induration; crumbly tenacity; massive cutting habit; texture is clayey to silty interspersed with fine grained accessory minerals; luster is dull to earthy; cohesiveness is poor with mild adhesiveness; clumpy to curdy consistency lacking any bedding; decreasing accessory minerals with depth; oil; no scent; light brown trace staining; trace fluorescence with even distribution and faint yellow intensity; no other oil indicators. Claystone/siltstone (7250' - 7300') = medium light gray to medium gray; soft to friable; poor to moderate KRU 2F-21 13 induration; crumbly to pulverant tenacity; massive cutting habit; clayey to silty texture with earthy to dull luster; moderate cohesiveness and adhesiveness; lumpy to clumpy consistency with no bedding; siltstone, medium light gray to medium gray, friable to moderately hard, moderate to well induration, brittle tenacity with platy to flaky cutting habit, silty to granular with an earthy to dull luster, no evidence of bedding, accessory minerals rare. Oil; no odor; no staining; very faint dull yellow over small percentage of sample; Claystone/siltstone (7300' - 7420') = dark gray to olive gray; clumpy to mushy; malleable to soft crumbly to sectile; poorly to moderately cohesive; moderately adhesive; massive cuttings with earthy fracture predominant; occasional irregular platy cuttings with rough planar fracture; earthy to dull luster; silty to gritty to sucrosic texture; massive structure predominant; rare siltstone fragments with subtle microbedding and light olive gray tuff microlamina; trace soft amorphous expansive tuff fragments; rare irregular to prismatic translucent calcite; scattered fine to very fine quartzose sand with abundant gray to black lithics, trace muscovite and biotite, and rare microcrystalline pyrite; very rare fine to very fine grained brittle calcareous sandstone fragments; rare dull pinpoint fluorescence; no other oil indicators. Claystone/siltstone (7420' - 7570') = olive black to olive gray and dark gray; mushy to curdy; malleable to soft crumbly and sectile; weakly to moderately adhesive; poorly to moderately cohesive; massive cuttings with earthy to amorphous fracture predominant; occasional irregular platy cuttings with irregular platy fracture; earthy to dull luster with trace vitreous microsparkle from micas; gritty to silty to clayey texture; massive structure predominant; rare brittle siltstone fragments with subtle microbedding; scattered fine to very fine sand, quartz predominant, abundant gray to black lithics, trace muscovite and biotite, rare dark greenish gray lithics, very rare microcrystalline pyrite; rare irregular to pris- matic calcite fragments; very rare very coarse to coarse sand grains; scattered weakly calcareous overall; no odor; no stain; no bulk fluorescence; rare very fine silty sandstone fragments with moderate even gold fluorescence, weak slow streaming yellowish white cut fluorescence becoming moderate to strong when crushed, moderate bright yellow residual cut fluorescence; no visible cut or residual cut. Claystone/siltstone (7570' - 7650') = dark gray to olive gray and olive black; clumpy to mushy; malleable to soft crumbly to sectile; moderately to poorly cohesive; poorly to moderately adhesive; massive cuttings with earthy to amorphous fracture predominant; scattered irregular platy cuttings with rough planar fracture; earthy to dull luster; gritty clayey to silty texture; platy siltstone cuttings sucrosic; massive structure; scattered quartz and lithic very fine to fine grained sands; weakly calcareous overall; no oil indicators with rare silty sandstone fragments as above. Siltstone/claystone (7650' - 7750') = olive gray to olive black and dark gray; mushy to clumpy malleable to sectile claystone grading to soft crumbly clayey siltstone; poorly cohesive; poorly adhesive siltstone to moderately adhesive claystone; massive cuttings; no apparent structure; earthy luster; silty to gritty texture; common disaggregated coarse silt and very fine to fine grained sand; quartz predominant with abundant gray to black lithics; scattered weakly to non calcareous; no oil indicators. Siltstone/claystone (7750' - 7840') = olive black to olive gray; disaggregated clumps of crumbly siltstone and very fine to fine grained sand predominant; soft curdy silty claystone abundant; irregular to amorphous fracture; massive cuttings grading to loose grains; silts poorly cohesive and non adhesive; clays moderately cohesive and tacky; earthy luster; gritty to silty texture; colorless quartz predominant; gray to black lithics abundant; trace opaque moderate reddish brown volcanic lithics; trace muscovite; rare microcrystalline pyrite; very rare hard pyrite cemented coarse siltstone fragments; scattered weakly to non calcareous; no oil indicators. Siltstone/claystone (7840' - 7950') = olive black to dark gray and olive gray; disaggregated crumbly silt and very fine sand clumps predominant; abundant curdy to mushy clayey siltstone to silty claystone; scattered weak brittle to easily friable siltstone fragments; poorly cohesive; non to poorly adhesive; massive cuttings predominant; occasional irregular platy to wedgelike cuttings; earthy luster; silty to gritty texture; structureless predominant; common subtle aligned grains in coherent siltstone fragments; KRU 2F-21 14 colorless transparent to translucent quartz predominant; abundant gray to black lithics; rare moderate opaque reddish brown volcanic lithics; rare dark greenish gray lithics; trace soft light olive gray to yellowish gray sandy tuff fragments; non to weakly calcareous; no oil indicators. Siltstone/claystone (7950' - 8050') = olive gray to dark gray and olive black; disaggregated crumbly silt and very fine to fine grained sand predominant; abundant mushy to curdy silty claystone grading to clayey siltstone; occasional to common weak brittle to easily friable siltstone; poorly to non cohesive; non adhesive overall with tacky claystones; loose silty clumps and massive cuttings predominant; occasional platy and rare elongate sub-shaly cuttings; earthy luster; silty to gritty clayey texture; no apparent structure; mineralogy of silt and sand as above; trace mushy devitrified tuff fragments; rare brittle crunchy light olive gray very fine to fine grained sandstone fragments; non to scattered weakly calcareous; no oil indicators. Siltstone/claystone (8050' - 8150') = medium gray to medium dark gray; soft to friable; poor to well induration with stiff to flexible tenacity; massive cutting habit; clayey to gritty texture with frequent interspersed sand grains; luster is earthy to dull; good cohesiveness and adhesiveness; lumpy to clumpy consistency with no evidence of bedding; oil; no odor present; trace staining with light brown color; even trace fluorescence with dull straw color; no other oil indicators. Siltstone (8150' - 8250') = light gray to medium gray; friable to hard; moderate to well induration; pulverant to brittle tenacity; massive to platy cutting habit silty to granular texture with an earthy to dull luster; no evidence of bedding; accessory minerals range from very fine to upper fine; mineralogy includes abundant zeolite, sparse translucent quartz. Rare calcite and muscovite; overall sample is weakly calcareous and has a moderate reaction to HCl; oil; no odor or stain present; evenly dispersed faint yellow florescence with isolated patches of bright orange; no other oil indicators. Siltstone (8250' - 8350') = light olive gray to medium light gray; soft to easily friable with few moderately hard fragments; stiff to elastic tenacity; cutting habit is massive with sparse platy fragments; silty to granular texture with a dull to earthy luster; overall lack of HCl reactivity; zeolite common and evenly interspersed; quartz and calcite rare; oil; no odor evident; no visible staining; evenly disbursed dull yellow fluorescence with increased depth; no other oil indicators Siltstone/claystone (8350' - 8450') = light gray to medium light gray; soft to friable hardness with rare fragments of moderate hardness; induration is poor to occasionally well; stiff to flexible tenacity within massive cuttings and brittle to crumbly within platy cuttings; clayey to gritty texture with rare granular fragments; luster appears earthy to dull with occasional sub-vitreous faces along zeolite cleavage planes; accessory minerals include a decreased amount of zeolites and lack of quartz and calcite; no evidence of HCl reactivity; claystone, medium light gray to medium gray, friable to moderately hard, induration is moderate to well with stiff to flexible tenacity, massive cutting habit, clayey to silty texture with some granular fragments, dull to earthy luster, good to excellent cohesiveness and adhesiveness, lumpy consistency with lack of bedding, rare vitreous muscovite, no evidence of HCl reactivity. Oil; no odor present; no evidence of staining; evenly distributed dull yellow fluorescence over 30% of sample; no other oil indicators. Claystone/siltstone (8450' - 8550') = light olive gray to medium light gray; induration moderate to well with a moderate hardness; stiff to flexible tenacity; cutting habit is massive; clayey to silty texture with occasional grittiness; luster is dull to earthy; cohesiveness is very good with strong adhesive properties; lumpy to clumpy consistency lacking any bedding; accessory minerals scant with few quartz, zeolite, and muscovite grains; increasing grain size with depth, siltstone, light olive gray to medium light gray, soft to firmly friable with moderate to poor induration; tenacity is stiff to elastic with a massive cutting habit; texture is silty; earthy and dull luster; mineralogy includes quartz, calcite, zeolite, and muscovite with grains ranging from upper fine to lower medium; oil; no odor present; no visible stain; very dull green trace fluorescence evenly distributed in 10% of sample; no other oil indicators. KRU 2F-21 15 Siltstone (8550' - 8650) = light olive gray to brownish gray; easily friable to friable with moderate induration; tenacity is stiff to elastic; cutting habit is massive; texture is silty to gritty and has an earthy to dull luster; consistency is clumpy with no evidence of bedding; accessory mineral occurrence slightly increases with depth and include very fine to upper fine quartz, zeolite and muscovite; oil; no odor present; light brown staining on 20% of sample; evenly distributed dull light yellow fluorescence; no other oil indicators Siltstone (8650' - 8710') = olive gray to dark gray; mushy to clumpy; crumbly silts and expansive malleable clayey silts; massive cuttings and loose silt; scattered dense crumbly to friable siltstone fragments; occasional soft silty claystone; earthy luster; silty to gritty texture with some smooth clay; no apparent structure; scattered to trace very fine grained lithic subquartzose sands; rare mushy tuff fragments; non to scattered weakly calcareous; no oil indicators. Siltstone (8710' - 8770') = olive gray; mushy to slimy disintegrated hydrophilic clayey silts; non cohesive; non to weakly adhesive; crumbly to pulverulent tenacity; massive cuttings and loose silt; rare coherent dense friable siltstone fragments; silty to gritty texture; no apparent structure; non to scattered weakly calcareous; decreasing clay and sand content; no oil indicators. Siltstone (8770' - 8850') = olive black to olive gray; curdy to mushy; soft malleable to crumbly; massive cuttings with abundant disaggregated silt; silty to gritty clayey texture; no apparent structure; occasional dense platy sub-shaly siltstone fragments with irregular planar fracture; trace very fine to fine grained sands quartzose with abundant gray to black lithics and rare opaque moderate reddish brown volcanic lithics; rare soft light olive gray to yellowish gray devitrified tuff; very rare microcrystalline pyrite and pyrite cemented siltstone; scattered weakly calcareous; no oil indicators. Siltstone (8850' - 8930') = olive black to dark gray; clumpy to mushy; crumbly silts and malleable clayey silt and silty clay; disaggregated silt predominant with abundant massive cuttings; no apparent structure; gritty to silty texture; scattered dense brittle to friable sub-shaly siltstone fragments with irregular planar fracture and platy to wedgelike to elongate cuttings; trace fine to very fine grained sands; scattered weakly calcareous; no oil indicators. Siltstone (8930' - 9000') = olive gray to dark gray and olive black; clumpy to curdy to mushy; soft crumbly to malleable cuttings; abundant disaggregated silt; massive cuttings; no apparent structure; silty to gritty clayey texture; no apparent structure; generally becoming more clayey with depth; scattered dense brittle siltstone fragments with irregular planar fracture, platy to wedgelike to elongate cuttings, and sucrosic luster; rare light olive gray crumbly tuffaceous sandy siltstone fragments; trace fine muscovite; scattered moderately to weakly calcareous; no oil indicators. Siltstone (9000' - 9080') = olive black to dark gray and olive gray; clumpy to mushy; soft crumbly to malleable to weakly sectile; abundant disaggregated silt; massive to amorphous cuttings; structureless predominant; trace carbonaceous microlamina; common dense brittle sub-shaly siltstone fragments with platy to wedgelike cuttings; trace muscovite; rare microcrystalline pyrite; rare fibrous to finely prismoidal zeolite; scattered to abundantly moderately calcareous; no oil indicators. Siltstone (9080' - 9200') = olive black to dark gray; curdy to mushy; malleable to soft crumbly; massive amorphous hydrophilic clayey siltstone cuttings predominant; abundant disaggregated silt and fine to very fine sand; common to occasional dense brittle to weakly friable shaly platy to wedgelike cuttings; structureless predominant; occasional subtle mineral orientation in firmer siltstone; trace carbonaceous microlamina; trace to scattered light olive gray to yellowish gray mushy devitrified tuff and soft tuffaceous sandy siltstone fragments; rare fibrous to irregularly prismoidal light gray zeolite; very rare microcrystalline pyrite; moderately to scattered very calcareous; no oil indicators. Siltstone/claystone (9200' - 9260') = olive black to dark gray; mushy to curdy; malleable to soft crumbly to mushy sectile; massive silty clay and clayey silt cuttings predominant; abundant disaggregated silt and KRU 2F-21 16 fine sand; common dense platy to wedgelike shaly siltstone; earthy to sucrosic luster; no apparent structure; trace mushy tuff; rare yellowish gray fibrous zeolite; weakly calcareous; no oil indicators. Siltstone/sandy siltstone (9260' - 9350') = olive black to medium dark gray; crumbly disaggregated silt and fine to very fine grained sand predominant; common mushy to clumpy massive clayey siltstone; scattered dense brittle platy to wedgelike shaly siltstone; trace grain supported brittle crumbly sandy siltstone; massive structure predominant; occasional microbedding and mineral orientation; sands predominantly colorless quartz with abundant gray to black lithics, trace dark greenish gray and yellowish gray lithics, and rare biotite; trace opaque to translucent irregular calcite fragments; rare dark yellowish brown calcareous tuff; non to scattered weakly calcareous overall. Siltstone (9350' - 9450') = medium light gray to medium gray; friable to moderately hard; induration is poor with some fragments approaching moderate to well; massive cuttings appear silty while platy cuttings are silty to gritty in texture; overall luster is dull to earthy; less consolidated fragments appear mushy while highly consolidated fragments appear stiff; accessory minerals are limited with infrequent lower fine to lower medium zeolite and quartz. No oil indicators. Sandy siltstone (9450' - 9550') = light olive gray to medium light gray; soft to moderately hard; induration is poor with few moderate fragments; tenacity malleable to brittle; cutting habit is massive with occasional platy fragments; texture ranges from silty to granular; overall sample lacks evidence of bedding; lower very fine to lower fine grained sand is common and evenly interspersed in up to 75% of sample; sand sphericity is low to medium while angularity is sub-rounded to angular; mineralogy includes quartz, zeolite, calcite, and rare muscovite; oil; no odor present; faint light brown staining in less than 10% of sample; evenly distributed dull yellow fluorescence over 50% of sample; no other oil indicators. Sandy siltstone/sand (9550' - 9650') = light olive gray to medium light gray; unconsolidated to friable; induration is poor to very poor; tenacity is crumbly with rare and interspersed brittle fragments which have a platy cutting habit; overall sample has a massive cutting habit; silty to granular texture; luster is earthy to dull; no evidence of bedding present; sand, light gray to medium light gray, very fine to fine grained, sphericity is low to high with sub-angular to sub-rounded grains, very poor to poorly sorted, unconsolidated to friable with no evidence of cement, texturally immature and compositionally sub-mature, mineralogy includes 50% quartz 20% lithics, frequent medium grained calcite with a grayish yellow to light gray color. Oil; no odor present; very rare light brown staining; evenly distributed faint yellow fluorescence over 20% of sample; no other oil indicators. Sandy siltstone/sand (9650' - 9750') = brownish gray to light olive gray; soft to easily friable; very poor to moderate induration; elastic to flexible tenacity with rare brittle fragments; cutting habit is predominantly massive with scant pieces of platy siltstone; texture is silty to granular with an earthy to dull luster; no evidence of bedding; sand, light gray to medium gray, very fine to lower medium grained, low to high sphericity, very angular to subrounded, moderate to well sorted, friable to unconsolidated; no evidence of cement; texturally and compositionally sub-mature, quartz is predominantly sub-rounded with conchoidal fracture and appears translucent to opaque, calcite is frequent and ranges from yellowish gray to medium light gray with conchoidal fracture, biotite, muscovite, and zeolite very rare, oil; no odor present; 20% light brown staining; evenly distributed dull yellow fluorescence over 20% of sample; no other oil indicators. Sandy siltstone (9750' - 9850') = medium light gray to medium gray; soft to firmly friable; poor to moderate induration; stiff to elastic tenacity; massive cutting habit; silty to gritty texture with an earthy to dull luster; no evidence of bedding; interspersed very fine to upper fine sand grains common consisting of quartz, calcite, very rare muscovite and biotite; oil; no odor present; rare light brown staining on less than 10%; trace dull yellow fluorescence evenly disbursed; no other oil indicators. Sandy siltstone (9850' - 9950') = light gray to medium light gray; soft to friable with poor to moderate induration; tenacity is pulverant to crumbly with many fine grain size fragments; silty to granular texture; luster is earthy to dull; no evidence of bedding; mineralogy includes quartz calcite, and sparse muscovite, KRU 2F-21 17 sand grains display normal grading with depth; overall sample is non-reactive to HCl: oil; no odor present; rare light brown staining; evenly distributed dull yellow fluorescence over 20% of sample; no other oil indicators. Siltstone (9950' - 10050') = olive gray to olive black to dark gray; mushy to disintegrating gelatinous clayey siltstone to disaggregated silt and sand with scattered dense friable siltstone; coherent fragments malleable to tough brittle; irregular fracture; massive to amorphous cuttings; gritty to silty in smooth clayey matrix textures; no apparent structure; cleaner silt grades to very fine quartz and gray to black lithic sand; trace mushy light olive gray to yellowish gray tuff; rare microcrystalline pyrite; non to trace weakly calcareous; no oil indicators. Siltstone (10050' - 10150') = olive black to dark gray; mushy clumpy to soft crumbly; trace dense; irregular to planar fracture; common parting along microbedding; massive to flaky cuttings predominant; scattered wedgelike to elongate dense sub-shaly cuttings; earthy to sucrosic luster; gritty to silty with occasional clayey texture; massive to thinly bedded structure with trace carbonaceous microlamina; trace soft pasty yellowish gray devitrified tuff; common moderate reaction to HCl; trace moderate yellowish gold pinpoint fluorescence; no cut fluorescence or other oil indicators. Sandy siltstone (10150' - 10270') =olive black with dark gray to grayish black; soft crumbly clayey to clean siltstone predominant; common mushy silty claystone to clayey siltstone; trace to scattered dense friable shaly siltstone; grades to carbonaceous siltstone with abundant blackish hue and occasional carbonaceous microlamina; massive to irregular wedgelike cuttings; abundant disaggregated silt and fine to very fine sand; earthy texture; silty to gritty to sucrosic texture; massive structure predominant with common flaky parting along microbedding planes and subtle microlamina; rare soft mushy yellowish gray tuff; associated sands predominantly colorless transparent to translucent quartz with abundant gray to black lithics, angular to sub- round, well sorted, sub-discoidal to spheroidal; common moderate to weak reaction to HCl; trace pinpoint mineral fluorescence; no oil indicators. Siltstone (10270' - 10400') = olive black to dark gray; soft crumbly to stiff friable siltstone predominant; occasional mushy to slimy clumpy hydrophilic silty claystone; occasional to scattered dense friable to weak brittle shaly siltstone; grades to carbonaceous siltstone with abundant blackish hue and trace to occasional carbonaceous microlamina; massive to irregular wedgelike cuttings predominant; scattered elongate to flaky cuttings; earthy luster; abundant disaggregated silt and fine to very fine sand; silty to gritty texture; massive structure predominant with common irregular to flaky parting along microbedding planes; occasional subtle microlamina; rare to trace mushy to firm crumbly light olive gray to yellowish gray devitrified tuff with earthy to waxy luster; sand predominantly color- less quartz with abundant gray to black lithics and rare opaque moderate reddish brown volcanic lithics; scattered weakly to moderately calcareous; trace to very rare pinpoint mineral fluorescence; no oil indicators. Siltstone (10400' - 10520') = olive black to dark gray; firm friable to soft crumbly with occasional dense brittle; scattered expansive mushy clay; grades to carbonaceous siltstone with abundant to black hue and scattered to occasional carbonaceous microlamina; massive to irregular flaky to wedgelike cuttings; abundant disaggregated silt and fine to very fine sand; silty to granular texture with occasional smooth to slimy hydrated clay; massive structure with common parting along microbedding; scattered soft waxy devitrified light olive gray tuff; rare muscovite; non to trace very weakly calcareous; very rare mineral fluorescence; no oil indicators. Siltstone/carbonaceous siltstone (10520' - 10600') = olive black to grayish black with scattered olive gray; abundant black hue; soft crumbly to firm friable with pulverulent fines; massive to irregular planar to splintery cuttings; carbonaceous content increasing from overlying interval; common carbonaceous microlamina; scattered to trace fine to very fine sand; silty to granular texture; massive to finely bedded structure; scattered soft mushy yellowish gray to light olive gray waxy tuff; non to trace weakly calcareous; no oil indicators. KRU 2F-21 18 Siltstone/carbonaceous siltstone (10600' - 10700') = olive black to dark gray and grayish black; firm friable to dense brittle with pulverulent fines in siltstone with scattered mushy soft clay; massive to irregular planar to elongate splintery cuttings; abundantly carbonaceous with occasional carbonaceous microlamina; common microbedding and flaky fissility; thinly bedded to massive structure; trace to rare very fine to fine sand; scattered to trace yellowish gray to light olive gray devitrified mushy expansive tuff with rare firm crumbly moderately calcareous tuff; non to scattered weakly calcareous; no oil indicators; abundant nutplug mud additive contamination in samples. Siltstone (10700' - 10800') = grayish black to olive black; soft crumbly to firm friable with scattered dense brittle; irregular to earthy planar fracture; massive to rounded tabular to finely flaky splintery cuttings; abundant disaggregated siltstone; earthy luster; granular to gritty to silty texture; massive to thinly laminated structure; common carbonaceous microlamina; generally less carbonaceous than above; occasional parting along microbedding; scattered to common fine to very fine colorless quartz and gray to black lithic sand with rare moderate reddish brown volcanic lithics; trace soft yellowish gray tuff and rare dense calcareous tuff; very rare pinpoint mineral fluorescence; non to rare weakly calcareous; no oil indicators. Siltstone/sand (10800' - 10850') = medium light gray to medium gray; hardness ranges from soft to moderately hard; cutting habit is massive to platy with massive fragments having poor induration and platy fragments having moderate to well induration; dense to crumbly tenacity; clayey to granular texture; dull to earthy luster; sand is upper very fine to fine grained; mineralogy is predominantly quartz with frequent lithics; no oil indicators. Sand (10900' - 11000') = light gray to medium light gray; upper fine to lower medium grained; low to high sphericity; angular to rounded; well to very well sorted; sample is unconsolidated with no evidence of cement; texturally sub-mature and compositionally mature; translucent to opaque quartz with conchoidal fracture is predominant; grayish black to black lithics evenly interspersed; calcite is infrequent but evenly occurring with opaque light gray color and poor cleavage; rare biotite with perfect cleavage and micaceous fracture; very rare pale red purple volcanics with low sphericity and well roundedness; very rare grayish yellow welded tuff fragments with massive habit and firmly friable to moderate hardness; oil; no odor present; very rare and trace light brown staining; evenly distributed dull orange pin points over 30% of sample; cut displayed a single very faint yellow streamer; no other oil indicators. Sand/siltstone (11000' - 11100') = light gray to medium gray; fine grained; medium to high sphericity with subrounded to rounded grains; very well sorted with very coarse tuff fragments evenly distributed; unconsolidated with evidence of silica cement irregular but isolated fragments; no matrix material present; texturally and compositionally mature; 70% well rounded translucent to smokey quartz, 15%olive black to brownish black lithics, 10% welded tuff, 5% rare and scattered calcite and biotite; siltstone comprises less than 10% of overall sample, light gray to medium light gray, friable to moderately hard, dense to crumbly tenacity, massive to platy cutting habit with an earthy to dull luster, no evidence of bedding. Oil; no odor present; no visible staining; evenly distributed orange pin points over 10% of sample; no other oil indicators. Sand/siltstone (11100' - 11250') = very light gray to medium light gray; fine grained; medium to high sphericity; sub angular to rounded; well to very well sorted; sample is highly unconsolidated with scant fragments of siliceously cemented sand grains; texturally sub-mature and compositionally mature; mineralogical composition is primarily quartz with dark gray to black lithics; welded tuff common; white to opaque rounded calcite occurs occasionally with upper fine to lower medium grain size; occasional biotite with perfect cleavage and rare pyrite with no cleavage; siltstone, soft to firmly friable with poor to moderate induration, brittle to crumbly tenacity, cutting habit is massive to platy, silty to gritty texture with an earthy to dull luster, platy cuttings are harder with visible microlamina. Oil; no odor or visible stain present; fluorescence is dull yellow on siltstone and dull orange on sand; orange fluorescence is pinpointed while yellow is patchy; immediate faint yellow bloom; no cut or residue visible in white light; residue fluorescence is trace dull yellow; no other oil indicators. KRU 2F-21 19 Sand/siltstone (11250' - 11400') = very light gray to medium light gray; upper very fine to lower fine grained; high sphericity and sub-rounded to rounded; very well sorted and unconsolidated; rare silica cemented fragments; texturally and compositionally mature; mineralogy is predominantly quartz with abundant lithics; sporadic muscovite with perfect cleavage and pearly luster; occasional white opaque calcite; rare biotite with perfect cleavage; consistent but highly sparse pyrite; siltstone, medium light gray, soft to friable, poor to moderate induration, elastic to flexible, tenacity, massive cutting habit with rare platy fragments. Silty to granular texture with an earthy to dull luster. Oil; no odor present; rare light brown staining; dull pin point orange fluorescence over 10% of sample; no other oil indicators. Sand/siltstone (11400' - 11500') = olive gray to dark gray; upper very fine to upper fine; grades to lower very fine and silt; trace medium; well sorted; subangular to subround with scattered well rounded; spheroidal to sub discoidal; occurs in sample as loose sand with occasional mushy hydrated silt matrix; transparent to translucent colorless quartz predominant; common to abundant gray to black lithics; trace microcrystalline pyrite; trace biotite and muscovite; rare dark greenish gray lithics; very rare jasper; non calcareous overall; common firm crumbly to malleable siltstone with occasional crunchy moderately calcareous sandy siltstone fragments; siltstone cuttings massive to tabular with no apparent structure and earthy luster; silt occasionally grades to slightly carbonaceous; rare pinpoint mineral fluorescence; no oil indicators. Sandy siltstone/claystone (11500' - 11600') = olive black to dark gray; clumpy to mushy; malleable to soft crumbly; samples heavily reworked with abundant embedded nutplug; expansive clayey silt predominant; common disaggregated silt; occasional loose sand; scattered coherent siltstone; irregular to ambiguous fracture; massive to amorphous cuttings; earthy luster; silty to clayey texture; massive structure; sand predominantly quartz with common to abundant gray to black lithics; trace microcrystalline pyrite; non calcareous overall with rare weak to moderate reaction to HCl; rare pinpoint mineral fluorescence; no oil indicators. Siltstone/claystone (11600' - 11700) = olive black to olive gray and medium dark gray; dense friable to soft crumbly siltstone predominant; common mushy to gelatinous expansive hydrophilic clay; irregular to earthy planar fracture; rounded tabular to wedgelike to irregular siltstone cuttings; massive amorphous claystone; silty to gritty texture; massive to thinly bedded structure; trace fine carbonaceous micro-lamina; scattered very fine to fine and trace medium sand, quartzose with common gray to black lithics and rare dark greenish gray lithics; trace microcrystalline pyrite; very rare soft devitrified tuff; non to trace weakly calcareous; very rare pinpoint mineral fluorescence; no oil indicators; abundant nutplug sample contamination. Siltstone/claystone (11700' - 11800') = olive black to medium dark gray; soft crumbly to weak friable siltstone with expansive mushy silty claystone; irregular to earthy to planar fracture; massive to platy to flaky cuttings; earthy to dull luster; silty to gritty clayey texture; massive structure predominant; common parting along microbedding; trace thin carbonaceous microlamina; common to abundant disaggregated silt and hydrated clay; common to scattered very fine to fine grained quartzose and gray to black lithic sand; trace microcrystalline pyrite fragments; very rare mushy devitrified tuff; non to rare weakly calcareous; very rare pinpoint mineral fluorescence; no oil indicators. Siltstone/claystone (11800' - 11900') = olive black to medium dark gray; mushy clumpy to soft crumbly to weak friable siltstone predominant; common expansive mushy to clumpy to disintegrating hydrophilic clay; massive to irregular tabular cuttings; irregular to earthy planar fracture; silty to gritty texture; pre- dominantly structureless with occasional microbedding; scattered to locally abundant very fine to fine grained sand, transparent colorless quartz predominant, gray to black lithics abundant, subangular to subround, occurring as loose grains with no apparent matrix; scattered crunchy sandy siltstone fragments; rare mushy tuff; trace carbonaceous microlamina; non calcareous; no oil indicators. Siltstone/carbonaceous siltstone (11900' - 12030') = olive black to grayish black with trace olive gray; KRU 2F-21 20 soft mushy to crumbly silts interbedded with firm flexible carbonaceous siltstone; scattered pasty expansive clay; planar to earthy to irregular fracture with splintery fines; flaky to irregular tabular to massive cuttings; earthy to dull luster; silty to clayey with gritty texture; thinly bedded to massive structure with abundant carbonaceous microlamina; occasional to scattered sand decreasing through interval, very fine to fine with scattered medium grains, quartz predominant with common gray to black lithics; trace to scattered light olive gray to yellowish gray soft mushy to crumbly devitrified tuff; rare to trace microcrystalline pyrite fragments; even moderately to weakly calcareous; trace pinpoint dull gold fluorescence; no cut; no other oil indicators. Siltstone/carbonaceous siltstone (12030' - 12140') = olive black to dark gray and grayish black; firm flexible to friable carbonaceous siltstone interbedded with mushy to dense to brittle siltstone and soft pasty expansive clay; planar to earthy fracture with hackly to splintery fines; flaky to platy to irregular tabular and massive cuttings; earthy to dull luster; silty to gritty to mottled texture; massive structure predominant with abundant carbonaceous microlamina and common microbedding parting; trace quartz and gray to black lithic fine to very fine grained sand; trace to rare light olive gray soft crumbly to mushy waxy devitrified tuff; very rare fine microcrystalline pyrite fragments; very rare biotite; even weakly to moderately calcareous; no oil indicators. Siltstone/carbonaceous siltstone (12140' - 12240') = olive black to dark gray; soft crumbly to dense brittle siltstone grading to and interbedded with firm to dense flexible carbonaceous siltstone; becoming less carbonaceous through interval; common soft to mushy silt clay and clayey silt; common disaggregated silt; trace increasing to common fine to very fine lithic sub quartzose sand; irregular to planar to earthy fracture; massive to irregular wedgelike to flaky cuttings; silty to gritty texture; abundant decreasing to common carbonaceous microlamina; massive to thinly bedded structure; trace prismatic to irregular blocky calcite; evenly moderately to strongly calcareous; no oil indicators. Siltstone/Carbonaceous Siltstone (12240' - 12350') = olive black to dark gray with scattered olive gray; soft crumbly to dense friable interbedded and gradational microbedded to massive siltstone and microlaminated carbonaceous siltstone; earthy planar to irregular fracture; massive to blocky cuttings with abundant to predominant disaggregated silt and carbonaceous material; earthy to dull luster; gritty to silty texture; scattered very fine to fine grained quartz and gray to black lithic sand; trace increasing to common prismatic void-filling calcite crystals and irregular crystalline clumps up to 1mm; trace to rare soft yellowish gray devitrified tuff; spotty dull yellow grain fluorescence; predominantly mineral fluorescence; very weak slow yellowish white cut fluorescence; weak light yellow residual cut fluorescence; no other oil indicators. Siltstone/Carbonaceous Siltstone (12350' - 12550') = olive black to grayish black with scattered olive gray to very light gray; soft crumbly to dense friable interbedded and gradational massive to microbedded and microlaminated carbonaceous siltstone; becoming more carbonaceous with depth; earthy planar to irregular fracture; abundant splintery fracture in carbonaceous fines; massive to blocky to flaky cuttings; abundant disaggregated silt and carbonaceous material; dull to earthy luster; scattered to trace transparent to translucent colorless quartz and gray to black lithic sand; common to locally abundant prismatic crystals and irregular fragments to 1mm of void-filling calcite; rare laminated calcite/siltstone fragments; rare light yellowish gray to light olive gray mushy devitrified tuff increasing to trace with depth; very rare microcrystalline pyrite; spotty dull to moderate yellow fluorescence; predominantly mineral fluorescence; slow streaming dull to moderate milky yellowish white cut fluorescence; weak to moderate bright yellow residual cut fluorescence; no visible cut or residual cut. KRU 2F-21 21 Gas Peaks Depth ft Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 4225 218 41352 778 219 60 77 47 33 4404 657 117651 2992 755 271 346 189 157 4601 156 30826 312 93 46 68 45 39 4693 158 30180 332 94 49 68 63 47 4770 134 25332 268 86 53 89 51 49 4891 153 29022 406 94 49 77 57 49 5390 133 25619 1012 426 131 138 87 72 5489 102 18051 603 169 73 87 59 53 9355 113 25659 639 82 17 4 4 1 10808 214 35234 3711 1728 214 508 99 120 10981 245 39937 4401 1984 242 572 122 148 11279 227 36416 4328 1851 222 515 127 154 11839 212 33648 3626 1283 146 294 78 82 11914 123 19941 2051 625 72 131 33 42 12048 239 37594 4722 1261 119 197 56 47 12233 212 33815 3902 1467 145 285 60 58 12351 370 55339 5321 2048 209 422 88 94 12389 567 93118 9688 3638 359 725 134 141 12443 323 56351 5558 2181 214 448 93 92 12542 170 27232 2807 1223 136 292 76 71 KRU 2F-21 22 3.2.2 HRZ (K-2 Marker) 12,544’ MD to 13,488’ MD (-5538' TVDSS to -5769' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 150 14 81 915 71 139 Lithology Carbonaceous Siltstone (12550' - 12650') = olive black to grayish black; very soft crumbly silt and firm flexible to friable carbonaceous material; trace dense crumbly siltstone; earthy to planar fracture along mircolamina predominant; abundant splintery fracture in carbonaceous lamina; massive to irregular tabular to flaky cuttings; earthy to dull luster; silty texture; rare very fine lithic subquartzose sand; trace to rare void-filling calcite crystals primarily as prismatic masses to 1mm laminated between carbonaceous siltstone; scattered light olive gray to yellowish gray hydrated mushy to slimy devitrified tuff occurring as amorphous lumps and occasional crumbly clumps; predominantly non-calcareous; rare pinpoint mineral fluorescence; no to very weak cut fluorescence; very weak dull yellow residual cut fluorescence; no visible cut or residual cut. Carbonaceous Siltstone (12650' - 12800') = olive black to grayish black with scattered olive gray; very soft crumbly silt and firm flexible to soft friable carbonaceous material; earthy to planar fracture along microlamina predominant; common irregular fracture in siltier fragments; common splintery fracture in carbonaceous fines; massive to irregular tabular to flaky cuttings; dull to earthy luster; silty texture; very rare very fine sand; non-calcareous overall with rare void-filling calcite occurring as prismatic masses up to 1mm thick laminated between carbonaceous siltstone and as irregular fragments; scattered light olive gray to yellowish gray hydrated mushy to slimy devitrified tuff in soft crumbly clumps and amorphous lumps; trace pinpoint mineral fluorescence from calcite and tuff; trace dull background fluorescence; very weak yellowish white cut fluorescence with weak slow streamers; no visible cut; weak dull yellow residual cut fluorescence; no visible residual cut. Carbonaceous Siltstone (12800' - 12950') = olive black to grayish black; very soft crumbly to mushy silt and firm flexible to soft friable to moderately dense crumbly carbonaceous material; earthy to planar fracture along microlamina predominant; occasional irregular fracture in siltier fragments; common splintery to hackly fracture in carbonaceous material; irregular tabular to massive cuttings with flaky to splintery carbonaceous fines; dull to earthy luster; silty to matte texture; non to scattered weakly calcareous overall; trace to rare void-filling calcite prismatic crystals and fragments laminated with carbonaceous silt; scattered light olive gray to yellowish gray tuff occurring as mushy to soft crumbly to weakly brittle irregular clumps; very rare fragments up to 1mm of microcrystalline pyrite; trace pinpoint predominantly mineral fluorescence; very weak slow yellowish white cut fluorescence; no visible cut; very weak dull yellowish residual cut fluorescence; no visible residual cut. Carbonaceous Siltstone (12950' - 13100') = olive black to brownish black; easily friable to firmly friable; induration is moderate to poor with a dense to crumbly tenacity; cutting habit platy to flaky with smaller fragments predominantly flaky; texture is silty to gritty; overall luster is earthy with occasional vitreous microcrystalline faces; larger fragments display prominent microbedding and are easily fractured along bedding planes; devitrified tuff rare and appears in clumps, yellowish gray to light gray color, very soft and disintegrates easily with no apparent bedding; occasional but well interspersed columnar like calcite with splintery fracture; rare but frequent pyrite with lack of cleavage and massive habit. Oil; no odor present; no visible staining; faint yellow fluorescence with patchy distribution over 20% of sample; no other oil indicators. KRU 2F-21 23 Carbonaceous Siltstone/Claystone (13100' - 13250') = olive black to brownish black; firmly friable to moderately hard; moderate to well induration with dense to brittle tenacity; cutting habit is platy to flaky with smaller fragments predominantly flaky; silty to gritty texture with occasional grittiness; dull to earthy luster with some vitreous quality on larger cuttings; microlamina are common with frequently interbedded carbonaceous material; fine fragments have a hackly fracture while large fragments appear more conchoidal; finer fragments less than 1mm compose 80% of sample and decrease with depth while larger fragments up to 8mm increase with depth; claystone, light gray to medium light gray, firmly friable to moderately hard, induration well to very well with dense tenacity, cutting habit tabular to wedgelike, clayey to silty texture with waxy to earthy luster, good cohesiveness with poor adhesive properties, consistency is stiff and lacks bedding, yellowish tuff fragments are rare and decrease with depth, mineralogy includes occasional white opaque calcite, translucent fine grained quartz grains, and scarce but regular fine grained pyrite. Oil; no odor present; dull yellow patchy distribution over 30% of sample; immediate dull yellow cut fluorescence; no visible cut in white light; dull yellow residue fluorescence. Carbonaceous Siltstone (13250' - 13400') = olive black to brownish black; friable to moderately hard with moderate to well induration; tenacity is dense to crunchy; platy to flaky cutting habit with abundant very fine to medium siltstone fragments; texture is silty to gritty with some sucrosic properties; earthy to dull luster; prominent microbedding with common intertonguing carbonaceous material; claystone, light gray to medium light gray, firmly friable to hard with very well induration, dense to brittle tenacity, wedgelike cutting habit, luster is waxy to earthy with good cohesiveness, microbedding visible in some clay fragments. Clay occurrence decreases with depth; yellowish gray tuff infrequent. White to yellowish gray calcite with fibrous crystal form, regular but sparse pyrite with poor cleavage, rare very fine to fine grained translucent quartz; oil; no odor or staining evident; evenly distributed dull yellow fluorescence over 30% of sample; immediate blooming faint yellow fluorescent cut; cut and residue invisible in white light; residue fluorescence faint yellow; no other oil indicators. Carbonaceous Siltstone (13400' - 13500') = brownish black to grayish black; easily friable to firmly friable with moderate induration; tenacity is brittle to crunchy; dull to earthy luster; cutting habit massive to flaky; fragments have an even size distribution ranging from fine to very course grained with some very fine pebble size cuttings; texture is silty to gritty and has an earthy to dull luster; bedding is very good in larger fragments decreased amount of carbonaceous material with depth; occasional claystone and tuff fragments; scant pyrite up to 1mm in size and very rare translucent quartz. Oil; no odor present; no stain evident; trace dull orange fluorescence over 20% of sample; immediate blooming dull white cut fluorescence; no color in cut with white light; faint yellow residue fluorescence with lack of color in white light. Gas Peaks Depth ft Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 12625 174 28117 2625 1176 141 310 94 85 12718 192 31695 3184 1313 151 331 74 68 12818 915 129297 18465 7436 887 1776 386 313 12936 494 79823 9307 3650 454 956 248 210 13008 193 30485 3349 1562 227 496 131 129 13101 201 32091 3441 1582 224 493 133 128 13146 178 28503 3021 1379 193 425 116 111 13363 239 39162 3919 1726 225 506 146 133 13454 189 31321 3059 1325 167 379 112 100 KRU 2F-21 24 3.2.3 Kalubik 3.2.3.1 Upper Kalubik 13,488’ MD to 13,946' MD (-5769' TVDSS to -5875' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 161 11 93 135 48 84 Lithology Carbonaceous Siltstone (13500' - 13650') = olive black to brownish black; firmly friable to moderately hard with moderate to good induration; tenacity is dense to brittle tenacity; cutting habit is massive to flaky; silty to gritty texture with and earthy to dull luster with occasional vitreous faces; larger fragments display very fine and well defined lamina; carbonaceous material appears to decrease with depth; accessory minerals include scant pyrite, highly weathered and rounded translucent quartz, and occasional calcite with poor cleavage. Welded tuff very rare with yellowish gray color, fragments are hard to very hard with very well induration, grains range from medium to very fine pebbles in size; oil; no odor or stain evident; trace dull yellow fluorescence evenly disbursed over 10% of sample; very faint yellow blooming cut fluorescence; no color visible in white light of cut or residue; residue fluorescence is very faint dull yellow. Carbonaceous Siltstone/Siltstone (13650' - 13800') = brownish gray to olive black; easily friable to hard with moderate to well induration; tenacity is brittle to crumbly with silty to granular texture; cutting habit is massive to platy with occasional wedge- like fragments; overall sample is earthy to dull; abundant and well defined microlamina visible in larger silt particles which easily fracture along bedding planes; siltstone, light gray to medium light gray, soft to moderately hard with moderate to very well indurated, tenacity is dense to brittle with silty to microgranular texture, luster is dull to earthy with fresh surfaces exhibiting micro-sparkling luster; mineralogy includes abundant medium to fine grained pyrite, highly weathered quartz common; oil: trace pinpoint fluorescence, primarily mineral fluorescence from tuff, slow very weak dull yellowish white to no cut fluorescence, weak dull yellowish white to no residual cut fluorescence, no visible cut or residual cut. Carbonaceous Siltstone (13800' - 13920') = grayish black to olive black with scattered medium dark gray and light olive gray; firm brittle to crumbly to soft friable; irregular to rough planar fracture; massive to irregular wedgelike to platy cuttings; dull to earthy luster with very rare microsparkle; gritty to silty to matte texture; massive evenly carbonaceous siltstone predominant with common silty microlamina; trace to scattered tuff occurs as firm crumbly sucrosic devitrified flakes and irregular clumps, dense to moderately hard brittle welded fragments with silt-sized volcanic fragments, and soft crumbly waxy fragments; trace to rare quartzose very fine to coarse grain sized sand; trace microcrystalline pyrite with very rare dodecahedral crystals; rare biotite and muscovite flakes; very rare opaque moderate reddish brown volcanic lithics; trace dull yellow fluorescence, predominantly tuff mineral fluorescence; very weak dull yellowish white to no cut fluorescence; very weak dull yellowish white to no residual cut fluorescence; no visible cut or residual cut. Carbonaceous Siltstone (13920' - 14100') = grayish black to olive black with scattered medium dark gray and olive gray with trace light olive gray; firm to dense brittle to crumbly to soft and firm friable; irregular to earthy planar fracture; massive to irregular wedgelike and tabular to platy cuttings; dull to earthy luster with rare microsparkle; silty to gritty to matte texture; massive to thinly bedded carbonaceous siltstone predominant with common to abundant silty microlamina; occasional non-carbonaceous sub-shaly KRU 2F-21 25 siltstone; trace tuff occurs as firm crumbly to soft shaly brittle sucrosic devitrified flakes and dense to moderately hard brittle silty welded clumps; trace fine to medium grain sized fragments microcrystalline pyrite; pyrite occasionally contains intergrowths of milky quartz; rare fine grain to granule sized quartz sand, rarely lithified within carbonaceous silt lamina; rare muscovite and biotite flakes; very rare fine prismatic calcite crystals and thin fracture filling blocks; trace dull yellowish to greenish fluorescence primarily from minerals and tuff; no to weak dull yellowish white cut fluorescence; no to weak dull yellowish residual cut fluorescence; no visible cut or residual cut. Gas Peaks Depth ft Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 13692 127 23415 2143 888 115 257 76 61 13736 135 25997 2327 996 129 296 89 74 13931 130 23508 1958 763 99 201 62 55 KRU 2F-21 26 3.2.3.2 Lower Kalubik 13,946 MD to 14,275' MD (-5875' TVDSS to -5958’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 150 35 88 387 45 72 Lithology Carbonaceous Siltstone (13920' - 14100') = grayish black to olive black with scattered medium dark gray and olive gray with trace light olive gray; firm to dense brittle to crumbly to soft and firm friable; irregular to earthy planar fracture; massive to irregular wedgelike and tabular to platy cuttings; dull to earthy luster with rare microsparkle; silty to gritty to matte texture; massive to thinly bedded carbonaceous siltstone predominant with common to abundant silty microlamina; occasional non-carbonaceous sub-shaly siltstone; trace tuff occurs as firm crumbly to soft shaly brittle sucrosic devitrified flakes and dense to moderately hard brittle silty welded clumps; trace fine to medium grain sized fragments microcrystalline pyrite; pyrite occasionally contains intergrowths of milky quartz; rare fine grain to granule sized quartz sand, rarely lithified within carbonaceous silt lamina; rare muscovite and biotite flakes; very rare fine prismatic calcite crystals and thin fracture filling blocks; trace dull yellowish to greenish fluorescence primarily from minerals and tuff; no to weak dull yellowish white cut fluorescence; no to weak dull yellowish residual cut fluorescence; no visible cut or residual cut. Carbonaceous Siltstone (14100' - 14275') = grayish black to olive black with scattered medium dark gray and trace medium to medium bluish gray; firm to dense brittle to soft crumbly to firm friable; irregular to earthy planar with occasional splintery fracture; massive to irregular tabular to platy cuttings; dull to earthy luster; thinly bedded to massive carbonaceous siltstone with common silty microlamina predominant; scattered non-calcareous soft friable to firm brittle non-carbonaceous shaly siltstone; rare tuff occurs as moderately hard welded silty clumps, thin lamina within carbonaceous siltstone, and as soft crumbly devitrified fragments; trace fine grain sized microcrystalline pyrite; trace well rounded fine to coarse grained quartz sand; rare muscovite and biotite flakes; very rare moderate orangish brown opaque volcanic lithics; scattered to locally abundant colorless to yellowish brown calcite occurring as loose prismatic crystals and inter-grown void-filling chunks laminated between carbonaceous siltstone; trace to scattered tuff and mineral fluorescence; weak dull yellowish white cut fluorescence; weak dull yellowish white residual cut fluorescence; no visible or residual cut. Gas Peaks Depth ft Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 14065 387 61862 5273 1947 224 443 110 99 14195 101 17429 1558 748 91 222 58 55 KRU 2F-21 27 3.2.4 Kuparuk C (Top C4) 14,275’ to 14297' MD (-5960’ to -5965’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 132 59 107 444 59 314 Lithology Sand/Siltstone (14275' - 14380') = olive black to dark yellowish brown; lower fine to upper medium; 90% transparent colorless quartz; well sorted; moderate to high sphericity; subangular to sub- round; very rare well rounded coarse to very coarse grains; trace patchy siderite grain coating; rare dark green glauconite; rare microcrystalline pyrite; very rare crunchy very fine grained silty sandstone; trace calcite crystals as above; common to abundant carbonaceous siltstone and siltstone as above; scattered hard siliceous shale; very rare tuff; weak odor; common stain; patchy very weak dull yellowish gold fluorescence; moderate to strong milky yellowish white cut fluorescence; very pale straw visible cut; moderate to strong bright yellow residual cut fluorescence; weak to moderate amber residual visible cut. Gas Peaks Depth Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 14295 444 61655 7950 3682 422 865 216 221 KRU 2F-21 28 3.2.5 B2 Sand 14,297 to 14,412’ MD (-5965’ to -5992’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 129 43 94 413 90 175 Lithology Sand/Siltstone (14275' - 14380') = olive black to dark yellowish brown; lower fine to upper medium; 90% transparent colorless quartz; well sorted; moderate to high sphericity; subangular to sub-round; very rare well rounded coarse to very coarse grains; trace patchy siderite grain coating; rare dark green glauconite; rare microcrystalline pyrite; very rare crunchy very fine grained silty sandstone; trace calcite crystals as above; common to abundant carbonaceous siltstone and siltstone as above; scattered hard siliceous shale; very rare tuff; weak odor; common stain; patchy very weak dull yellowish gold fluorescence; moderate to strong milky yellowish white cut fluorescence; very pale straw visible cut; moderate to strong bright yellow residual cut fluorescence; weak to moderate amber residual visible cut. Carbonaceous Siltstone/Sand (14380' - 14530') = olive black to grayish black to dark yellowish brown; firm crumbly to weakly brittle; irregular planar to splintery fracture; flaky to massive cuttings; silty to gritty texture; thinly bedded to massive with common microlamina; abundant decreasing to common sand; lower fine to lower medium; 90% transparent colorless quartz; well sorted; moderate to high sphericity; subangular to subround; rare very well rounded upper medium to coarse grains; scattered patchy siderite grain coating; trace microcrystalline pyrite; very rare glauconite; very rare prismatic calcite fragments; trace dull greenish yellow mineral fluorescence; patchy to scattered very weak dull yellowish sample fluorescence; instant moderate milky yellowish white cut fluorescence; very pale straw visible cut; moderate bright yellow residual cut fluorescence; weak to moderate dark straw residual cut. Gas Peaks Depth Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 14357 196 32299 3480 1567 185 388 99 100 14390 249 40547 4207 1843 222 458 101 106 KRU 2F-21 29 3.2.6 A6 Sand 14,412’ to 14,520’ MD (-5992' to -6012’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 129 63 94 286 85 180 Lithology Carbonaceous Siltstone/Sand (14380' - 14520') = olive black to grayish black to dark yellowish brown; firm crumbly to weakly brittle; irregular planar to splintery fracture; flaky to massive cuttings; silty to gritty texture; thinly bedded to massive with common microlamina; abundant decreasing to common sand; lower fine to lower medium; 90% transparent colorless quartz; well sorted; moderate to high sphericity; subangular to subround; rare very well rounded upper medium to coarse grains; scattered patchy siderite grain coating; trace microcrystalline pyrite; very rare glauconite; very rare prismatic calcite fragments; trace dull greenish yellow mineral fluorescence; patchy to scattered very weak dull yellowish sample fluorescence; instant moderate milky yellowish white cut fluorescence; very pale straw visible cut; moderate bright yellow residual cut fluorescence; weak to moderate dark straw residual cut. Gas Peaks Depth Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 14453 255 40065 4457 2043 246 519 127 136 14482 286 44117 4981 2357 281 594 145 151 KRU 2F-21 30 3.2.7 A5 Sand 14,520 to 14,617 (-6012 to -6029 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 129 10 93 2294 129 1206 Lithology Sandstone (14520’ - 14617') = olive gray to dark gray to grayish black; upper very fine, occasional lower fine and lower very fine grain; spherical to sub discoidal: round to sub rounded; well sorted; friable; indeterminate matrix; grain supported; texturally sub mature; compositionally sub mature; translucent and transparent quartz; trace microcrystalline pyrite; show: fair oil odor; 80% light brown oil stain; patchy to scattered dull yellow sample fluorescence; instant streaming milky white cut fluorescence; light amber visible cut; medium dark brown visible residual cut; bright golden yellow residual fluorescence; porosity and permeability visually good. Gas Peaks Depth Total Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 14548 1810 178547 38729 22247 2558 5578 1185 1217 14571 2295 214282 48322 28811 3341 7116 1517 1552 14602 1226 119914 25137 13808 1550 3348 729 765 14617 1407 117164 26028 15116 1759 3760 825 851 . KRU 2F-21 31 3.3 Gas Event Summary 3.3.1 Connection Gas Depth MD ft TVD ft MW MAX Gas units Above BG units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 4026 3037 9.7 83 16545 345 141 60 70 32 32 4945 3322 9.6 111 27 20650 312 85 47 62 52 43 5040 3351 9.6 140 25 26035 537 25 70 90 58 53 7187 4022 9.8 32 5 7280 4051 9.8 70 50 7371 4080 9.8 46 25 7464 4109 9.8 62 40 12810 153 13 0 6 4 6 7556 4138 9.8 35 13 7648 4167 9.8 52 28 11054 139 11 2 2 4 4 7746 4197 9.8 52 24 11037 143 14 4 1 1 3 8023 4280 9.8 188 150 39864 356 14 4 0 0 0 8116 4307 9.8 102 70 21917 229 14 14 8 10 8 8210 4335 9.8 77 46 8947 94 20 0 15 8 6 8293 4360 9.8 65 30 13946 255 26 5 10 5 7 8439 4404 9.8 47 24 8498 4422 9.8 49 25 11095 136 27 3 0 0 9 8639 4466 9.8 30 6 8712 4488 9.8 36 11 9072 4600 9.8 45 24 10251 212 26 4 0 4 0 9415 4706 9.8 33 8 9521 4739 9.8 37 10 9596 4762 9.8 24 7 9695 4793 9.8 22 7 9870 4847 9.8 20 4 3918 164 64 9 11 7 8 10465 5031 9.8 168 58 27358 3532 1393 147 278 24 37 10752 5120 9.8 157 110 25881 2954 1180 122 280 50 55 10934 5176 9.8 90 35 11006 5198 9.8 80 5 11099 5227 9.8 107 40 11186 5254 9.85 106 56 11282 5283 9.8 77 33 11403 5321 9.8 116 46 17439 1840 827 102 259 79 91 11495 5349 9.8 107 40 16042 1536 647 86 212 62 71 11587 5377 9.85 92 40 11678 5404 9.85 82 30 13268 1104 406 50 121 37 43 11771 5432 9.8 82 35 14384 1174 417 52 119 27 41 12513 5655 9.65 163 54 24587 2440 1008 110 237 55 53 KRU 2F-21 32 3.3.2 Trip/Downtime Gas Depth MD ft TVD ft Pumps Off hours MW MAX Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 4026 3037 15 9.6 18 3874 33 10 0 0 0 0 5890 3616 2 9.75 52 8307 4364 0.5 9.8 135 29304 305 17 4 0 4 4 12238 5571 29 9.8 1505 167403 25295 7901 705 1222 230 194 14617 3.4 Sampling Program / Sample Dispatch No samples were retained for this well. KR U 2 F - 2 1 33 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Th e w e l l w a s d r i l l e d s l i g h t l y u n d e r b a l a n c e d a s w a s i n d i c a t e d b y c o n n e c t i o n g a s s e s . M a n a g e d P r e s s u r e D r i l l i n g w a s u s e d f r o m 1 2 2 38’ MD to 14 6 1 7 ’ M D . 4. 1 P o r e P r e s s u r e E v a l u a t i o n In t e r v a l T o p s Po r e P r e s s u r 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 ft TV D S S Ft Mi n pp g Ma x pp g Tr e n d Trend Indicators Ba s e W S a k C l y s t 5 5 % S l t s t / S d 4 5 % 3 7 2 0 - 2 8 1 8 1 0 . 2 4 1 3 . 2 3 I N C R E A S E C G , B G , E C D , M W To p H R Z ( K - 2 M a r k e r ) C S l t s t 9 0 % C l y s t 1 0 % 12 , 5 5 4 - 5 5 3 8 1 0 . 6 5 1 1 . 0 6 I N C R E A S E C G , B G , E C D , M W Up p e r K a l u b i k C S l t s t 9 0 % S l t s t 1 0 % 1 3 , 4 8 8 - 5 7 6 9 1 0 . 8 8 1 1 . 0 4 SL I G H T IN C R E A S E CG, BG, ECD, MW Lo w e r K a l u b i k ( K - 1 Ma r k e r ) CS l t s t 9 5 % S l t s t 5 % 1 3 , 9 4 6 - 5 8 7 5 1 0 . 9 5 1 1 . 0 6 E V E N C G , B G , E C D , M W Ku p a r u k C ( T o p C 4 ) S d 5 5 % C S l t s t 4 5 % 14 , 2 7 5 - 5 9 6 0 1 0 . 9 8 1 1 . 0 1 E V E N C G , B G , E C D , M W B2 S d 8 0 % S l t s t 2 0 % 1 4 , 2 9 7 - 5 9 6 5 1 0 . 9 0 1 1 . 0 0 E V E N C G , B G , E C D , M W A6 C S l t s t / S l t s t 6 5 % S d 4 5 % 1 4 , 4 1 2 -5 9 9 2 1 0 . 9 0 1 1 . 0 1 E V E N C G , B G , E C D , M W A5 S s t 8 0 % C S l t s t 2 0 % 1 4 , 5 2 0 - 6 0 1 2 1 0 . 9 2 1 0 . 9 8 E V E N C G , B G , E C D , M W NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i l t s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f , C S l t s t = C a r b o n a c eous Siltstone KRU 2F-21 34 4.2 Pore Pressure Plot Pore Pressure Gradient HRZ Upper Kalubik Lower Kalubik B2 SandA6 SandA5 Sand Base West Sak Kuparuk CShow #1 Show #2 Show #3 3700 4700 5700 6700 7700 8700 9700 10700 11700 12700 13700 14700 8.5 9 9.5 10 10.5 11 11.5 12 12.5 13 Pore Pressue (ppg) Me a s u r e d D e p t h ( f t ) KRU 2F-21 35 4.3 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD, and then modified using the indicators described above, DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD – (0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. KRU 2F-21 36 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 81.26 0.11 322.73 81.26 0.06 -0.05 -0.06 0.14 166.69 0.23 287.65 166.69 0.18 -0.26 -0.18 0.18 259.57 0.18 282.27 259.57 0.27 -0.58 -0.27 0.06 349.84 0.23 248.58 349.84 0.23 -0.89 -0.23 0.14 449.76 2.31 89.00 449.73 0.19 0.94 -0.19 2.53 542.15 3.30 87.66 542.01 0.33 5.46 -0.33 1.07 633.71 2.95 82.54 633.44 0.75 10.43 -0.75 0.49 724.38 3.90 81.83 723.94 1.49 15.79 -1.49 1.05 816.35 7.29 79.03 815.46 3.04 24.62 -3.04 3.70 870.71 8.35 82.37 869.32 4.22 31.92 -4.22 2.12 966.66 10.19 87.42 964.01 5.53 47.30 -5.53 2.09 1059.35 13.69 90.68 1054.68 5.77 66.47 -5.77 3.84 1151.24 16.74 96.43 1143.34 4.16 90.50 -4.16 3.70 1246.23 19.81 107.40 1233.56 -2.19 119.47 2.19 4.84 1338.53 20.13 110.57 1320.31 -12.45 149.26 12.45 1.22 1431.04 20.91 113.66 1406.95 -24.67 179.29 24.67 1.44 1523.73 21.69 116.78 1493.32 -39.02 209.73 39.02 1.48 1615.25 23.62 122.73 1577.78 -56.56 240.26 56.56 3.27 1707.86 25.97 126.70 1661.85 -78.71 272.13 78.71 3.11 1801.42 27.39 131.24 1745.46 -105.15 304.74 105.15 2.65 1894.02 29.34 134.99 1826.94 -135.23 336.81 135.23 2.85 1984.20 31.08 137.60 1904.88 -168.05 368.14 168.05 2.42 2076.95 33.88 143.26 1983.13 -206.46 399.76 206.46 4.45 2171.76 34.98 145.79 2061.33 -250.11 430.85 250.11 1.90 2263.83 36.37 149.81 2136.13 -295.54 459.42 295.54 2.96 2357.15 37.35 150.31 2210.80 -344.05 487.35 344.05 1.10 2449.20 39.02 150.98 2283.15 -393.65 515.24 393.65 1.87 2542.55 42.85 150.65 2353.66 -447.04 545.07 447.04 4.11 KRU 2F-21 37 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 2635.66 47.27 150.48 2419.41 -504.42 577.45 504.42 4.75 2728.09 50.18 153.07 2480.38 -565.63 610.27 565.63 3.79 2820.46 52.50 155.15 2538.09 -630.51 641.74 630.51 3.07 2912.82 54.70 156.52 2592.89 -698.34 672.15 698.34 2.66 3006.08 56.88 155.54 2645.32 -768.80 703.49 768.80 2.49 3097.71 58.88 156.72 2694.04 -839.77 734.89 839.77 2.44 3191.13 60.68 158.59 2741.06 -914.43 765.56 914.43 2.59 3284.38 63.32 160.43 2784.84 -991.55 794.36 991.55 3.32 3375.58 66.29 162.41 2823.66 -1069.76 820.64 1069.76 3.80 3467.65 68.64 163.88 2858.95 -1151.14 845.28 1151.14 2.95 3559.84 70.05 163.37 2891.47 -1233.90 869.60 1233.90 1.61 3653.43 72.91 163.71 2921.19 -1319.00 894.74 1319.00 3.08 3745.44 72.59 164.02 2948.48 -1403.41 919.16 1403.41 0.47 3838.76 71.85 162.92 2976.97 -1488.60 944.44 1488.60 1.37 3925.70 70.99 164.35 3004.68 -1567.67 967.66 1567.67 1.85 3995.95 71.04 162.82 3027.53 -1631.38 986.44 1631.38 2.06 4025.12 71.02 162.20 3037.01 -1657.69 994.73 1657.69 2.01 4119.19 70.97 163.30 3067.65 -1742.63 1021.10 1742.63 1.11 4209.18 71.72 163.43 3096.43 -1824.33 1045.51 1824.33 0.84 4302.08 72.42 163.32 3125.03 -1909.02 1070.80 1909.02 0.76 4397.93 72.29 163.68 3154.09 -1996.60 1096.74 1996.60 0.38 4491.77 72.32 164.51 3182.61 -2082.58 1121.24 2082.58 0.84 4588.48 72.38 163.70 3211.93 -2171.21 1146.48 2171.21 0.80 4685.44 71.97 164.09 3241.61 -2259.89 1172.08 2259.89 0.57 4781.57 71.89 163.84 3271.43 -2347.72 1197.33 2347.72 0.26 4876.91 71.92 163.44 3301.04 -2434.68 1222.85 2434.68 0.40 4973.06 71.95 163.09 3330.86 -2522.22 1249.17 2522.22 0.35 5069.13 71.86 164.40 3360.70 -2609.88 1274.74 2609.88 1.30 5163.96 71.80 163.67 3390.27 -2696.51 1299.52 2696.51 0.73 5260.74 71.86 163.48 3420.45 -2784.71 1325.52 2784.71 0.20 5356.82 71.81 163.21 3450.40 -2872.17 1351.68 2872.17 0.27 5453.62 71.74 162.64 3480.68 -2960.06 1378.68 2960.06 0.56 KRU 2F-21 38 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 5548.60 71.78 162.47 3510.41 -3046.12 1405.72 3046.12 0.18 5639.65 71.74 162.01 3538.91 -3128.48 1432.10 3128.48 0.48 5732.18 71.75 160.67 3567.89 -3211.73 1460.22 3211.73 1.38 5825.13 71.81 160.64 3596.95 -3295.03 1489.46 3295.03 0.07 5916.70 71.73 161.40 3625.60 -3377.28 1517.75 3377.28 0.79 6008.96 71.89 160.43 3654.40 -3460.11 1546.41 3460.11 1.01 6101.15 71.87 160.74 3683.07 -3542.74 1575.53 3542.74 0.32 6191.63 71.90 161.05 3711.21 -3624.00 1603.68 3624.00 0.33 6286.75 71.83 160.57 3740.81 -3709.37 1633.39 3709.37 0.49 6378.56 71.77 161.64 3769.49 -3791.89 1661.64 3791.89 1.11 6473.57 71.90 162.05 3799.11 -3877.67 1689.76 3877.67 0.43 6565.34 71.77 160.85 3827.72 -3960.33 1717.50 3960.33 1.25 6658.27 71.77 162.54 3856.79 -4044.13 1745.22 4044.13 1.73 6750.58 71.81 162.77 3885.64 -4127.83 1771.37 4127.83 0.24 6841.75 71.68 162.36 3914.20 -4210.43 1797.31 4210.43 0.45 6934.70 71.62 162.23 3943.46 -4294.48 1824.14 4294.48 0.15 7027.95 71.66 162.29 3972.83 -4378.77 1851.10 4378.77 0.07 7120.39 71.63 162.44 4001.94 -4462.39 1877.68 4462.39 0.16 7213.55 71.66 161.98 4031.28 -4546.58 1904.70 4546.58 0.47 7305.62 71.66 161.86 4060.25 -4629.66 1931.82 4629.66 0.12 7398.58 71.35 160.85 4089.74 -4713.19 1960.00 4713.19 1.08 7490.75 71.46 160.60 4119.13 -4795.65 1988.84 4795.65 0.28 7584.58 71.81 160.97 4148.69 -4879.74 2018.15 4879.74 0.53 7677.74 72.01 159.46 4177.62 -4963.06 2048.12 4963.06 1.56 7768.70 72.41 158.71 4205.41 -5043.97 2079.04 5043.97 0.90 7860.26 72.47 159.17 4233.04 -5125.43 2110.41 5125.43 0.48 7955.57 72.62 159.74 4261.63 -5210.57 2142.32 5210.57 0.59 8048.36 72.82 162.19 4289.19 -5294.32 2171.21 5294.32 2.53 8142.38 72.92 164.26 4316.89 -5380.34 2197.14 5380.34 2.11 8234.19 73.03 165.12 4343.77 -5465.01 2220.32 5465.01 0.90 8331.32 72.44 164.98 4372.60 -5554.62 2244.25 5554.62 0.62 8429.13 71.89 164.70 4402.55 -5644.49 2268.60 5644.49 0.62 KRU 2F-21 39 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 8525.03 71.96 164.31 4432.31 -5732.34 2292.95 5732.34 0.39 8619.70 71.96 164.28 4461.63 -5819.00 2317.32 5819.00 0.03 8716.89 71.99 164.40 4491.70 -5907.99 2342.27 5907.99 0.12 8811.52 71.99 164.15 4520.96 -5994.61 2366.66 5994.61 0.25 8908.66 71.96 163.65 4551.02 -6083.36 2392.27 6083.36 0.49 9003.89 71.96 163.72 4580.51 -6170.26 2417.71 6170.26 0.07 9100.74 71.82 163.60 4610.61 -6258.60 2443.61 6258.60 0.19 9195.23 71.80 162.95 4640.11 -6344.57 2469.44 6344.57 0.65 9284.94 71.90 162.64 4668.05 -6426.00 2494.66 6426.00 0.35 9377.35 71.96 162.83 4696.72 -6509.89 2520.73 6509.89 0.21 9470.78 71.99 162.32 4725.63 -6594.66 2547.33 6594.66 0.52 9562.52 72.08 162.61 4753.92 -6677.87 2573.63 6677.87 0.32 9657.27 72.05 162.46 4783.10 -6763.86 2600.68 6763.86 0.15 9748.11 72.05 162.76 4811.10 -6846.33 2626.51 6846.33 0.31 9841.58 72.02 162.81 4839.93 -6931.26 2652.82 6931.26 0.06 9934.14 71.99 162.71 4868.52 -7015.34 2678.91 7015.34 0.11 10026.48 71.97 162.43 4897.09 -7099.12 2705.22 7099.12 0.29 10118.52 71.86 162.19 4925.66 -7182.47 2731.80 7182.47 0.28 10211.07 71.96 162.19 4954.40 -7266.23 2758.71 7266.23 0.11 10302.93 71.87 162.58 4982.91 -7349.46 2785.14 7349.46 0.42 10395.84 71.87 161.99 5011.82 -7433.57 2812.00 7433.57 0.60 10490.00 71.93 162.00 5041.08 -7518.69 2839.67 7518.69 0.06 10586.12 71.96 162.08 5070.87 -7605.62 2867.85 7605.62 0.09 10682.96 71.93 161.91 5100.88 -7693.18 2896.31 7693.18 0.17 10778.42 71.96 161.80 5130.47 -7779.43 2924.57 7779.43 0.11 10871.75 71.99 161.70 5159.35 -7863.72 2952.37 7863.72 0.11 10963.94 72.17 161.50 5187.71 -7946.95 2980.05 7946.95 0.28 11056.98 72.01 162.57 5216.33 -8031.16 3007.36 8031.16 1.11 11150.69 71.98 161.92 5245.29 -8116.04 3034.54 8116.04 0.66 11242.30 72.15 161.80 5273.50 -8198.86 3061.67 8198.86 0.22 11335.08 72.14 161.57 5301.95 -8282.70 3089.42 8282.70 0.24 11428.00 72.02 161.75 5330.54 -8366.62 3117.24 8366.62 0.23 KRU 2F-21 40 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 11520.79 72.01 162.18 5359.19 -8450.54 3144.57 8450.54 0.44 11613.90 72.22 162.37 5387.78 -8534.95 3171.54 8534.95 0.30 11705.68 72.59 163.66 5415.53 -8618.61 3197.10 8618.61 1.40 11798.09 73.02 166.16 5442.85 -8703.84 3220.08 8703.84 2.63 11891.17 73.04 168.18 5470.02 -8790.64 3239.84 8790.64 2.08 11982.58 72.83 169.49 5496.85 -8876.37 3256.77 8876.37 1.39 12075.85 72.31 171.00 5524.79 -8964.07 3271.84 8964.07 1.64 12168.72 72.30 174.63 5553.02 -9051.83 3282.91 9051.83 3.72 12260.70 72.86 176.00 5580.56 -9139.30 3290.07 9139.30 1.55 12352.13 73.15 178.21 5607.29 -9226.62 3294.49 9226.62 2.33 12445.90 73.63 180.86 5634.10 -9316.46 3295.22 9316.46 2.76 12538.80 74.05 183.33 5659.96 -9405.62 3291.95 9405.62 2.59 12631.67 74.65 183.87 5685.01 -9494.87 3286.34 9494.87 0.85 12724.30 75.00 184.77 5709.26 -9584.02 3279.60 9584.02 1.01 12815.88 75.47 186.38 5732.60 -9672.15 3271.00 9672.15 1.78 12909.47 76.01 187.07 5755.65 -9762.23 3260.38 9762.23 0.92 13003.63 76.15 187.49 5778.30 -9852.89 3248.79 9852.89 0.46 13096.52 76.12 187.43 5800.56 -9942.31 3237.08 9942.31 0.07 13188.97 76.18 186.95 5822.69 -10031.40 3225.85 10031.37 0.51 13280.25 76.18 186.38 5844.50 -10119.40 3215.56 10119.40 0.61 13372.64 76.15 186.73 5866.59 -10208.50 3205.32 10208.53 0.37 13466.09 76.03 186.29 5889.06 -10298.70 3195.04 10298.65 0.47 13558.31 76.06 186.11 5911.30 -10387.60 3185.37 10387.63 0.19 13650.26 76.09 185.58 5933.43 -10476.40 3176.28 10476.41 0.56 13742.97 76.09 185.79 5955.71 -10566.00 3167.37 10565.96 0.22 13835.25 76.24 185.70 5977.78 -10655.10 3158.40 10655.11 0.19 13928.16 76.12 185.53 5999.97 -10744.90 3149.57 10744.90 0.22 14020.86 76.18 185.37 6022.16 -10834.50 3141.02 10834.50 0.18 14113.19 76.30 184.16 6044.13 -10923.90 3133.57 10923.86 1.28 14205.59 76.11 184.12 6066.16 -11013.40 3127.10 11013.36 0.21 14299.19 76.23 184.66 6088.53 -11104.00 3120.14 11103.98 0.57 14391.83 76.79 185.75 6110.14 -11193.70 3111.97 11193.70 1.29 KRU 2F-21 41 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 14484.97 79.23 187.45 6129.49 -11284.20 3101.49 11284.19 3.17 14547.71 81.42 188.70 6140.04 -11345.40 3092.80 11345.42 4.01 KR U 2 F - 2 1 42 5. 2 Bi t R e c o r d BH A Bi t Si z e Ma k e Ty p e / S # Je t s / T F 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 Avg. PP (psi) Wear 3 # 2 9 . 8 7 5 " S m i t h MS i 5 1 9 M T JH 9 4 8 7 3x 1 4 , 2 x 1 5 0. 7 9 6 40 0 6 ’ / 30 3 0 ’ 10 6 1 1 ’ 1 0 8 . 9 9 1 0 6 . 7 1 3 . 6 1 5 3 . 3 2 4 5 6 0-1-CT-S-X-IN-NO-TD KR U 2 F - 2 1 43 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O De p t h Da t e MD TV D MW pp g Te m p F VI S s/ q t PV YP Ge l s FL cc FC cc So l s % O/ W Ra t i o Sd % pH Cl ml/l Ca ml/l Dr i l P l e x 10 / 2 6 / 2 0 1 4 40 0 6 ’ 30 3 3 ’ 9. 6 60 N/ A 23 43 18 / 2 8 / 3 8 - - 7. 5 /9 2 0. 2 5 10.7 700 20 10 / 2 7 / 2 0 1 4 40 0 6 ’ 30 3 3 ’ 9. 6 74 N/ A 15 20 19 / 2 8 / 3 2 - - 7. 5 /9 2 0. 2 5 11.0 700 20 10 / 2 8 / 2 0 1 4 40 0 6 ’ 30 3 3 ’ 9. 6 76 N/ A 14 14 18 / 2 7 / 3 1 - - 7. 5 /9 2 0. 2 5 11.0 700 20 10 / 2 9 / 2 0 1 4 40 0 6 ’ 30 3 3 ’ 9. 6 74 N/ A 14 14 18 / 2 7 / 3 1 - - 7. 5 /9 2 0. 2 5 11.0 700 20 10 / 3 0 / 2 0 1 4 40 0 6 ’ 30 3 3 ’ 9. 6 62 53 15 16 14 / 2 5 / 2 9 - - 7. 5 /9 2 0. 2 5 10.5 700 20 10 / 3 1 / 2 0 1 4 40 0 6 ’ 30 3 3 ’ 9. 6 70 71 14 12 10 / 2 1 / 2 5 - - 7. 5 /9 2 0. 2 5 10.6 700 20 LS N D 11 / 1 / 2 0 1 4 40 2 6 ’ 30 3 3 ’ 9. 6 62 60 12 25 10 / 1 2 / 1 3 - 2/ - 6 3/ 9 1 0. 1 9.6 470 64 11 / 2 / 2 0 1 4 59 2 8 ’ 36 3 0 ’ 9. 8 80 58 14 33 14 / 1 8 / 2 1 4. 2 1/ - 6. 7 5 4/ 9 0 0. 1 10.1 400 40 11 / 3 / 2 0 1 4 76 4 8 ’ 41 5 8 ’ 9. 8 98 58 14 30 12 / 1 4 / 1 6 3. 9 1/ - 8. 7 5 3/ 8 8 0. 1 9.8 450 40 11 / 4 / 2 0 1 4 89 9 6 ’ 45 7 6 ’ 9. 8 10 2 52 11 24 8/ 1 0 / 1 1 4. 1 1/ - 8. 5 3/ 8 9 0. 1 9.6 400 40 11 / 5 / 2 0 1 4 10 2 8 3 ’ 49 7 5 ’ 9. 8 10 0 55 13 24 9/ 1 1 / 1 2 3. 8 1/ - 9 3/ 8 8 0. 1 9.5 480 40 11 / 6 / 2 0 1 4 11 8 6 3 ’ 54 6 0 ’ 9. 8 10 5 55 12 26 9/ 1 1 / 1 3 3. 9 1/ - 8. 5 3/ 8 9 0. 1 9.7 400 40 11 / 7 / 2 0 1 4 12 2 3 8 ’ 55 8 6 ’ 9. 8 94 56 12 26 10 / 1 1 / 1 2 3. 5 1/ - 8 3/ 8 9 0. 1 9.6 440 32 11 / 8 / 2 0 1 4 12 5 7 9 ’ 56 6 9 ’ 9. 6 99 50 11 23 9/ 1 2 / 1 5 3. 4 1/ - 8 3/ 8 9 0. 1 9.5 720 40 11 / 9 / 2 0 1 4 14 6 0 3 ’ 60 3 2 ’ 9. 8 10 8 48 12 26 10 / 1 3 / 1 5 3. 2 1/ 1 8 4/ 8 8 0. 1 9.9 950 52 11 / 1 0 / 2 0 1 4 14 6 1 7 ’ 61 2 1 ’ 10 . 9 12 0 51 14 30 13 / 1 4 / 1 6 3 1/ 1 12 4/ 8 4 0. 1 9.5 790 36 11 / 1 1 / 2 0 1 4 14 6 1 7 ’ 61 2 1 ’ 11 . 1 12 0 51 14 31 13 / 1 4 / 1 5 3 1/ 1 12 . 7 5 4/ 8 3 0. 1 9.5 800 36 Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o n t e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y WL = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t T e m p = T e m p e r a t u r e KRU 2F-21 44 6 SHOW REPORTS KRU 2F-21 45 KRU 2F-21 46 KRU 2F-21 47 KRU 2F-21 48 7 DAILY REPORTS