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208-016
New Plugback Esets 7/3/2024 Well Name API Number PTD Number ESet Number Date 1D-141A PB1 50-029-22967-73-00 208-016 T39107 7-16-2008 1D-141APB2 50-029-22967-74-00 208-016 T39108 7-16-2008 1D-141APB3 50-029-22967-75-00 208-016 T39109 7-16-2008 2K-08APB2 50-103-20111-71-00 211-049 T39110 6-13-2011 2K-08APB3 50-103-20111-71-00 211-049 T39111 6-13-2011 2K-08B PB1 50-103-20111-73-00 211-152 T39112 2-15-2012 2K-08B PB2 50-103-20111-74-00 211-152 T39113 2-15-2012 2K-08B PB3 50-103-20111-75-00 211-152 T39114 2-15-2012 3K-105L1 PB1 50-029-23479-72-00 212-166 T39115 3-12-2013 3K-105L1 PB2 50-029-23479-73-00 212-166 T39116 3-12-2013 3K-105L1 PB3 50-029-23479-74-00 212-166 T39117 3-12-2013 SP22-FN01 PB3 50-629-23478-72-00 212-162 T39118 3-20-2013 V-214 PB2 50-029-23275-71-00 205-134 T39119 1-29-2007 V-214 PB3 50-029-23275-72-00 205-134 T39120 1-29-2007 V-214 PB4 50-029-23275-73-00 205-134 T39121 1-29-2007 1D-141A PB1 50-029-22967-73-00 208-016 T39107 7-16-2008 1D-141A PB2 50-029-22967-74-00 208-016 T39108 7-16-2008 1D-141A PB3 50-029-22967-75-00 208-016 T39109 7-16-2008 Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 11 B Ͳ16 A 5 0 Ͳ02 9 Ͳ22 4 5 7 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 7 ͲDe c Ͳ23 0 1 21 D Ͳ13 0 5 0 Ͳ02 9 Ͳ22 8 1 5 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲDe c Ͳ23 0 1 31 D Ͳ14 1 A 5 0 Ͳ02 9 Ͳ22 9 6 7 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲDe c Ͳ23 0 1 41 H Ͳ10 2 5 0 Ͳ02 9 Ͳ23 5 8 0 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 4 ͲJa n Ͳ24 0 1 51 Y Ͳ06 A 5 0 Ͳ02 9 Ͳ20 9 5 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 0 ͲFe b Ͳ24 0 1 62 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 9 0 9 1 7 6 6 9 3 K u p a r u k R i v e r P e r f o r a t i o n R e c o r d F i e l d Ͳ Fi n a l 2 6 ͲFe b Ͳ24 0 1 72 C Ͳ12 5 0 Ͳ02 9 Ͳ21 2 2 2 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲDe c Ͳ23 0 1 82 F Ͳ15 5 0 Ͳ02 9 Ͳ21 0 4 8 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲFe b Ͳ24 0 1 92 U Ͳ05 5 0 Ͳ02 9 Ͳ21 2 8 1 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d & P r o c e s s e d 8 ͲDe c Ͳ23 0 1 10 2 W Ͳ01 5 0 Ͳ02 9 Ͳ21 2 7 3 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲDe c Ͳ23 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 7 5 T3 8 5 7 6 T3 8 5 7 7 T3 8 5 7 8 T3 8 5 7 9 T3 8 5 8 0 T3 8 5 8 1 T3 8 2 8 2 T3 8 5 8 3 T3 8 5 8 4 21 8 - 1 5 5 19 7 - 1 8 3 20 8 - 0 1 6 21 7 - 0 9 7 19 7 - 1 3 4 22 3 - 0 9 2 18 4 - 2 0 6 18 3 - 1 7 2 18 5 - 0 1 8 18 5 - 0 1 0 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h G u h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 1 9 : 5 8 - 0 9 ' 0 0 ' 1D Ͳ14 1 A 208 -016 ! "##$ % & '()'(' )) " ( )'*"+,-'( )'* +,-.& ) ) ' ' ' ./ ' )' )''' 0 !' ( ) ! (.(( ! '(' ) (' 1 )) 23 3 +( ) '4( ./ '(' ( ( ) '( ( )!' ' ' . 5+ ! + ! # 26$#2$ 6 )4 41 . 4 + ! 5( 7 ! 48' ( By Samantha Carlisle at 8:48 am, Mar 30, 2021 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.03.27 06:40:14-08'00' Foxit PhantomPDF Version: 10.1.0 Roger Mouser !"# $#$%& '( #)*+,*+" "( "' "- +. +/ + ($ ! "!#!$%%&'&&'()%!&%*%!(*+%'*,- !& &%&!-#- &- &%&!!"!'$%%&'&&((%%%!'(%$&'+!#*,- !& &%&!(- &- &%&!!."!!*$%%&'&---)%%&%(!)('$&-*,- !& &%&!$!- &- &%&!&/"-!-$%!%-&%&))%%!'*&!'0 &!,# &* &%!'*- &# &%&!&1"#!$%!%-&%)'%%%&!*!$!%-#,$ !%,) -! &%&%&- &# &%&!& "&%*$%!%-&%$!*%%&%$!*))(,%$!&,- &- &%&!*!- &- &%&!& "-)$%!%-&%&&)%%!'$!%!-%,%&%&(,- &- &%&!')- &- &%&! #"-%# $%!%-&%$$$%% &%)!-& &%+$%2 #*, - &# &%&! !% - &# &%&! Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-01 50-029-20590-00 906681181 Kuparuk River Production Profile Field & Processed 26-Sep-20 0 1 2 1A-07 50-029-20658-00 906722930 Kuparuk River Leak Detect Log Field- Final 27-Sep-20 0 1 3 1A-07 50-029-20658-00 n/a Kuparuk River Leak Detect Log Field- Final 12-Sep-20 0 1 4 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 11-Sep-20 0 1 5 1A-24 50-029-22984-00 906701351 Kuparuk River Multi Finger Caliper Field & Processed 10-Sep-20 0 1 6 1D-118 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 13-Sep-20 0 1 7 1D-118 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 14-Sep-20 0 1 8 1D-141A 50-029-22967-01 906685052 West Sak Packer Setting Record Field- Final 30-Sep-20 0 1 9 1H-116 50-029-23594-00 9067722868 Kuparuk River Injection Profile Field & Processed 21-Sep-20 0 1 10 1H-113 50-029-23588-00 906714570 Kuparuk River Injection Profile Field & Processed 19-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/07/2020 PTD: 2080160 E-Set: 34327 12/07/2020Abby Bell Abby Bell MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg m, ghlro� DATE: 8/22/2020 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Casing Repair Petroleum Inspector KRU 1D-141 A ConocoPhillips Alaska Inc. PTD 2080160; Sundry 319-563 8/19/2020: 1 arrived at location and met with Patrick Van Camp with ASRC Energy Services who was filling in for Roger Mouser (CPAI). We talked about the casing repair and went to look at the well. I documented the repair with pictures and inspected the casing patch. The casing patch was installed approximately 10 inches below the top of the surface casing hanger flutes and continued down for 8.75 feet. The welds all appeared to have good penetration with no visible issues that would affect the integrity of the repair. I could see no signs of any issues to be concerned with regarding the casing patch so I thanked Mr. Van Camp and left location. Attachments: Photos (7) 2020-0819_Surface_Casing Repair _KRU_1D-141A_gc.docx Page 1 of 5 r � 00 O N cn D cu aQ) Q X r (1) Y r O O O �U �U Y o I v L � Q •� N Q C �U U c C� O U >, o V O m O N O N 00 X U O .b U bA _Q .t Q t�4 � O N N th ca .J ca u 4d& A t 1 � � EL I`�t,, •S Ilrlu�Fa Ia OL d L —� 1 Sw) �C41 rn m U 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9915 feet N/A feet true vertical 3751 feet N/A feet Effective Depth measured 9915 feet 5375 feet true vertical 3715 feet 3533 feet Perforation depth Measured depth 6029'-9915'feet True Vertical depth 3774'-3751'feet Tubing (size, grade, measured and true vertical depth)2-7/8" L-80 5393' MD 3542' TVD SSSV - none Packers and SSSV (type, measured and true vertical depth)Seal Assembly Baker Bonded 5375' MD 3533' TVD 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Pat Van Camp Contact Name:Roger Winter/Roger Mouser Authorized Title:Well Integrity Field Supervisor Contact Email:N1927@conocophillips.com Contact Phone: SC Patch WINJ WAG N/A Water-Bbl MD 116' 502' N/A Oil-Bbl measured true vertical Packer P.O. Box 100360 Anchorage AK 99510 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs 3. Address: 4. Well Class Before Work: N/A Representative Daily Average Production or Injection Data N/AN/A Casing Pressure Tubing Pressure ADL0025650 N/A N/A KRU 1D-141A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-016 50029229670100 N/A N/A Junk measured 5. Permit to Drill Number: N/A Kuparuk River Field/West Sak Oil Pool Casing Structural 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-563 N/A Size Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: Liner Length 76' 461' 6330' 5344' 16" 10-3/4" 7-5/8" 5-1/2" 6371' 5384' TVD 116' 502' 3800' 3537' Burst ConocoPhillips Alaska, Inc 2. Operator Name Senior Engineer:Senior Res. Engineer: Collapse t Fra 208 6. A G L PG 50 0, R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:36 pm, Aug 26, 2020 Pat Van Camp Digitally signed by Pat Van Camp Date: 2020.08.26 16:19:06 -08'00' RBDMS HEW 8/27/2020 SFD 9/1/2020 SFD 9/1/2020DSR-8/27/2020 9,926' VTL 02/18/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 26, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the 7-5/8” SC patch and conductor re-installation over a known surface casing leak on KRU 1D-141A (PTD 208-016). Please contact Roger Mouser, Roger Winter or myself at 659-7506 if you have any questions. Sincerely, Pat Van Camp for Roger Mouser/Roger Winter CPAI WI Field supervisor Office (907) 659-7506 Cell (907) 943-1055 N1927@ COP.com Pat Van Camp Digitally signed by Pat Van Camp Date: 2020.08.26 16:18:30 -08'00' Date Event Summary Executive Summary Repaired known leak in 7-5/8" SC with patch. MITOA passed to 1800 psi and installed 16" conductor 11/19/19 (AC EVAL) : SCLD (LEAK ESTIMATED NEAR SURFACE), IC POT (PASSED), IC PPPOT (PASSED) 07/18/20 (SC REPAIR PREP) IN PROGRESS. CUT/REMOVED 8'10 OF X-65 16" CONDUCTOR. 07/19/20 (SC REPAIR PREP) IN PROGRESS, CUT AND REMOVED 7'-8" (92") OF 10" ROCK SCREEN. PREPARED SC FOR LEAK HUNT BY DHD. 07/20/20 (SC Repair prep) Locate surface casing leak, Drill and tap surface casing, Test to 300 psi, All ok, Clean and identify areas for MT/UT testing. 07/29/20 (SC REPAIR) MEASURE FOR SLEEVE & CONDUCTOR 08/17/20 (SC REPAIR) IN PROGRESS WELDED A & B BANDS 08/18/20 (SC REPAIR) WELD 6' 6" .500" WALL 5L-X65 SURFACE CASING SLEEVE TO A & B BANDS. OVERALL LENGTH OF SLEEVE 84.75". 08/19/20 (SC Repair)MITOA Passed to 1800 psi, Insulator wrapped SC repair with Denso wrap. 08/20/20 (SC Repair) Install and weld conductor Submit to: OOPERATOR: FFIELD /UNIT /PAD: DDATE: OOPERATOR REP: AAOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 208-016 Type Inj Tubing 33 33 33 33 Type Test P Packer TVD 3533 BBL Pump 0.7 IA 17 17 17 17 Interval O Test psi 1800 BBL Return 0.7 OA 0 1800 1765 1765 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: CPAI Kuparuk / KRU / 1D PAD Mike Beck / Pat Van Camp 08/19/20 Notes:MITOA Post SC patch install - Non Witnessed Notes: Notes: Notes: 1D-141A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechan i cal In tegr i ty Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)1D-141A 10-426.xlsx Annular Communication Surveillance 23 Well Name:11D-141 Start Date:23-May-2020 21 Days:90 End Date:21-Aug-2020 50 60 70 80 90 100 110 120 130 140 150 0 50 100 150 200 250 300 23-May-2026-May-2029-May-201-Jun-204-Jun-207-Jun-2010-Jun-2013-Jun-2016-Jun-2019-Jun-2022-Jun-2025-Jun-2028-Jun-201-Jul-204-Jul-207-Jul-2010-Jul-2013-Jul-2016-Jul-2019-Jul-2022-Jul-2025-Jul-2028-Jul-2031-Jul-203-Aug-206-Aug-209-Aug-2012-Aug-2015-Aug-2018-Aug-2021-Aug-20Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 23-May-20Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1D-141A lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced Poglm & Patch Assembly 11/5/2018 1D-141A fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 116.0 Set Depth (TVD)… 116.0 Wt/Len (l… 151.50 Grade X-65 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 10.05 Top (ftKB) 41.0 Set Depth (ftKB) 502.0 Set Depth (TVD)… 502.0 Wt/Len (l… 40.50 Grade J-55 Top Thread BTC Casing Description PRODUCTION 7.625"x7" OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 41.2 Set Depth (ftKB) 6,371.0 Set Depth (TVD)… 3,800.1 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description WINDOW A OD (in) 6 1/2 ID (in) 5.50 Top (ftKB) 5,503.0 Set Depth (ftKB) 5,512.0 Set Depth (TVD)… 3,601.9 Wt/Len (l… 26.00 Grade Top Thread To A S/T Casing Description PRODUCTION 5.5" OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 39.5 Set Depth (ftKB) 5,384.3 Set Depth (TVD)… 3,537.4 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Casing Description D-SAND LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,371.8 Set Depth (ftKB) 9,915.0 Set Depth (TVD)… 3,751.2 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,371.83,531.1 59.48 PACKER HRD ZXP LINER TOP PACKER 5.500 5,390.8 3,540.7 59.75 NIPPLE RS PACKOFF SEAL NIPPLE 4.880 5,393.7 3,542.1 59.74 HANGER FLEXLOCK LINER HANGER 4.840 5,405.2 3,547.9 59.71 SBE 80-40 CASING SEAL BORE EXTENSION 4.000 9,875.8 3,751.1 90.07 XO Reducing CROSSOVER 4.5x3.5" 3.500 Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 13.5 Set Depth (ft… 5,392.7 Set Depth (TVD) (… 3,541.6 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 13.5 13.5 0.00 HANGER Vetco Gray 11" x 4-1/2" w/ 4.909" MCA Top Connection (drifted 3.885") 2.875 475.2 475.2 1.07 SAFETY VLV 2-7/8" Camco "DS" Nipple w/ 2.313" "D" Profile 2.313 5,120.4 3,401.2 59.28 GAUGEBaker 2-7/8" Guardian Gauge Carrier EUE 2.441 5,329.4 3,509.3 58.86 NIPPLE 2-7/8" Camco "DS" Nipple w/ 2.250" "D" Profile 2.250 5,374.0 3,532.2 59.51 LOCATOR Seal Assembly Locator O.D. 4.51" I.D. 3.00" 3.000 5,375.2 3,532.8 59.53 SEAL ASSY Baker Bonded Seal Assembly O.D. 4.00" I.D. 3.75" 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 6,029.09,915.03,774.33,751.2 WS D, 1D-141A 3/24/2008 32.0SLOTSSLOTTED LINER Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 3,139.82,398.2Camco KBMG M-2 1 GAS LIFT GLV BK 0.1561,320.06/30/2008 2 5,287.0 3,487.2 Camco KBMG M-2 1GAS LIFT OPEN 7/29/2016 Notes: General & Safety End Date Annotation 3/21/2008 NOTE: WELL SIDETRACKED TO 'A' 3/24/2008 NOTE: 1D-141 &1D-141L1 ABANDONED & SIDETRACKED ABOVE 1D-141L1 11/29/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1D-141A, 11/30/2019 7:43:11 AM Vertical schematic (actual) D-SAND LINER; 5,371.8- 9,915.0 SLOTS; 6,029.0-9,915.0 PRODUCTION 7.625"x7"; 41.2- 6,371.0 WINDOW A; 5,503.0-5,512.0 PRODUCTION 5.5"; 39.5- 5,384.3 SEAL ASSY; 5,375.2 LOCATOR; 5,374.0 NIPPLE; 5,329.4 GAS LIFT; 5,287.0 GAUGE; 5,120.4 GAS LIFT; 3,139.9 SURFACE; 41.0-502.0 SAFETY VLV; 475.2 CONDUCTOR; 40.0-116.0 HANGER; 13.5 KUP PROD KB-Grd (ft) 37.85 Rig Release Date 9/21/2000 1D-141A ... TD Act Btm (ftKB) 9,925.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292296701 Wellbore Status PROD Max Angle & MD Incl (°)MD (ftKB) WELLNAME WELLBORE Annotation Last WO: End Date 3/24/2008 H2S (ppm) 70 Date 11/10/2014 Comment SSSV: NIPPLE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9915 feet N/A feet true vertical 3751 feet N/A feet Effective Depth measured 9915 feet 5375 feet true vertical 3715 feet 3533 feet Perforation depth Measured depth 6029'-9915'feet True Vertical depth 3774'-3751'feet Tubing (size, grade, measured and true vertical depth)2-7/8" L-80 5393' MD 3542' TVD SSSV - none Packers and SSSV (type, measured and true vertical depth)Seal Assembly Baker Bonded 5375' MD 3533' TVD 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Pat Van Camp Contact Name:Roger Winter/Roger Mouser Authorized Title:Well Integrity Field Supervisor Contact Email:N1927@conocophillips.com Contact Phone: ConocoPhillips Alaska, Inc 2. Operator Name Senior Engineer:Senior Res. Engineer: CollapseBurst 6371' 5384' TVD 116' 502' 3800' 3537' 16" 10-3/4" 7-5/8" 5-1/2" Authorized Signature with date: Authorized Name: Liner Length 76' 461' 6330' 5344' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-563 N/A Size Conductor Surface Intermediate Production Junk measured 5. Permit to Drill Number: N/A Kuparuk River Field/West Sak Oil Pool Casing Structural N/A N/A KRU 1D-141A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-016 5.00292E+13 N/A N/A 3. Address: 4. Well Class Before Work: N/A Representative Daily Average Production or Injection Data N/AN/A Casing Pressure Tubing Pressure ADL0025650 Oil-Bbl measured true vertical Packer P.O. Box 100360 Anchorage AK 99510 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs SC Patch WINJ WAG N/A Water-Bbl MD 116' 502' N/A t Fra 208 6. A G L PG 50 0, R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:50 pm, Aug 21, 2020 Pat Van Camp Digitally signed by Pat Van Camp Date: 2020.08.21 14:37:17 -08'00' VTL 02/18/2021 DSR-8/21/2020 9926 319-562 50-029-22967-01-00 SFD 8/31/2020 SFD 8/31/2020RBDMS HEW 8/24/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 21, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the 7-5/8” SC patch and conductor re-installation over a known surface casing leak on KRU 1D-141A (PTD 208-016). Please contact Roger Mouser, Roger Winter or myself at 659-7506 if you have any questions. Sincerely, Pat Van Camp for Roger Mouser/Roger Winter CPAI WI Field supervisor Office (907) 659-7506 Cell (907) 943-1055 N1927@ COP.com Pat Van Camp Digitally signed by Pat Van Camp Date: 2020.08.21 14:36:27 -08'00' Date Event Summary Executive Summary Repaired known leak in 7-5/8" SC with patch. MITOA passed to 1800 psi and installed 16" conductor 11/19/19 (AC EVAL) : SCLD (LEAK ESTIMATED NEAR SURFACE), IC POT (PASSED), IC PPPOT (PASSED) 07/18/20 (SC REPAIR PREP) IN PROGRESS. CUT/REMOVED 8'10 OF X-65 16" CONDUCTOR. 07/19/20 (SC REPAIR PREP) IN PROGRESS, CUT AND REMOVED 7'-8" (92") OF 10" ROCK SCREEN. PREPARED SC FOR LEAK HUNT BY DHD. 07/20/20 (SC Repair prep) Locate surface casing leak, Drill and tap surface casing, Test to 300 psi, All ok, Clean and identify areas for MT/UT testing. 07/29/20 (SC REPAIR) MEASURE FOR SLEEVE & CONDUCTOR 08/17/20 (SC REPAIR) IN PROGRESS WELDED A & B BANDS 08/18/20 (SC REPAIR) WELD 6' 6" .500" WALL 5L-X65 SURFACE CASING SLEEVE TO A & B BANDS. OVERALL LENGTH OF SLEEVE 84.75". 08/19/20 (SC Repair)MITOA Passed to 1800 psi, Insulator wrapped SC repair with Denso wrap. 08/20/20 (SC Repair) Install and weld conductor Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1D-141A lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced Poglm & Patch Assembly 11/5/2018 1D-141A fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 116.0 Set Depth (TVD)… 116.0 Wt/Len (l… 151.50 Grade X-65 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 10.05 Top (ftKB) 41.0 Set Depth (ftKB) 502.0 Set Depth (TVD)… 502.0 Wt/Len (l… 40.50 Grade J-55 Top Thread BTC Casing Description PRODUCTION 7.625"x7" OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 41.2 Set Depth (ftKB) 6,371.0 Set Depth (TVD)… 3,800.1 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description WINDOW A OD (in) 6 1/2 ID (in) 5.50 Top (ftKB) 5,503.0 Set Depth (ftKB) 5,512.0 Set Depth (TVD)… 3,601.9 Wt/Len (l… 26.00 Grade Top Thread To A S/T Casing Description PRODUCTION 5.5" OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 39.5 Set Depth (ftKB) 5,384.3 Set Depth (TVD)… 3,537.4 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Casing Description D-SAND LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,371.8 Set Depth (ftKB) 9,915.0 Set Depth (TVD)… 3,751.2 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,371.83,531.1 59.48 PACKER HRD ZXP LINER TOP PACKER 5.500 5,390.8 3,540.7 59.75 NIPPLE RS PACKOFF SEAL NIPPLE 4.880 5,393.7 3,542.1 59.74 HANGER FLEXLOCK LINER HANGER 4.840 5,405.2 3,547.9 59.71 SBE 80-40 CASING SEAL BORE EXTENSION 4.000 9,875.8 3,751.1 90.07 XO Reducing CROSSOVER 4.5x3.5" 3.500 Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 13.5 Set Depth (ft… 5,392.7 Set Depth (TVD) (… 3,541.6 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 13.5 13.5 0.00 HANGER Vetco Gray 11" x 4-1/2" w/ 4.909" MCA Top Connection (drifted 3.885") 2.875 475.2 475.2 1.07 SAFETY VLV 2-7/8" Camco "DS" Nipple w/ 2.313" "D" Profile 2.313 5,120.4 3,401.2 59.28 GAUGEBaker 2-7/8" Guardian Gauge Carrier EUE 2.441 5,329.4 3,509.3 58.86 NIPPLE 2-7/8" Camco "DS" Nipple w/ 2.250" "D" Profile 2.250 5,374.0 3,532.2 59.51 LOCATOR Seal Assembly Locator O.D. 4.51" I.D. 3.00" 3.000 5,375.2 3,532.8 59.53 SEAL ASSY Baker Bonded Seal Assembly O.D. 4.00" I.D. 3.75" 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 6,029.09,915.03,774.33,751.2 WS D, 1D-141A 3/24/2008 32.0SLOTSSLOTTED LINER Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 3,139.82,398.2Camco KBMG M-2 1 GAS LIFT GLV BK 0.1561,320.06/30/2008 2 5,287.0 3,487.2 Camco KBMG M-2 1GAS LIFT OPEN 7/29/2016 Notes: General & Safety End Date Annotation 3/21/2008 NOTE: WELL SIDETRACKED TO 'A' 3/24/2008 NOTE: 1D-141 &1D-141L1 ABANDONED & SIDETRACKED ABOVE 1D-141L1 11/29/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1D-141A, 11/30/2019 7:43:11 AM Vertical schematic (actual) D-SAND LINER; 5,371.8- 9,915.0 SLOTS; 6,029.0-9,915.0 PRODUCTION 7.625"x7"; 41.2- 6,371.0 WINDOW A; 5,503.0-5,512.0 PRODUCTION 5.5"; 39.5- 5,384.3 SEAL ASSY; 5,375.2 LOCATOR; 5,374.0 NIPPLE; 5,329.4 GAS LIFT; 5,287.0 GAUGE; 5,120.4 GAS LIFT; 3,139.9 SURFACE; 41.0-502.0 SAFETY VLV; 475.2 CONDUCTOR; 40.0-116.0 HANGER; 13.5 KUP PROD KB-Grd (ft) 37.85 Rig Release Date 9/21/2000 1D-141A ... TD Act Btm (ftKB) 9,925.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292296701 Wellbore Status PROD Max Angle & MD Incl (°)MD (ftKB) WELLNAME WELLBORE Annotation Last WO: End Date 3/24/2008 H2S (ppm) 70 Date 11/10/2014 Comment SSSV: NIPPLE Annular Communication Surveillance 23 Well Name:11D-141 Start Date:23-May-2020 21 Days:90 End Date:21-Aug-2020 50 60 70 80 90 100 110 120 130 140 150 0 50 100 150 200 250 300 23-May-2026-May-2029-May-201-Jun-204-Jun-207-Jun-2010-Jun-2013-Jun-2016-Jun-2019-Jun-2022-Jun-2025-Jun-2028-Jun-201-Jul-204-Jul-207-Jul-2010-Jul-2013-Jul-2016-Jul-2019-Jul-2022-Jul-2025-Jul-2028-Jul-2031-Jul-203-Aug-206-Aug-209-Aug-2012-Aug-2015-Aug-2018-Aug-2021-Aug-20Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 23-May-20Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Submit to: OOPERATOR: FFIELD /UNIT /PAD: DDATE: OOPERATOR REP: AAOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 208-016 Type Inj Tubing 33 33 33 33 Type Test P Packer TVD 3533 BBL Pump 0.7 IA 17 17 17 17 Interval O Test psi 1800 BBL Return 0.7 OA 0 1800 1765 1765 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: CPAI Kuparuk / KRU / 1D PAD Mike Beck / Pat Van Camp 08/19/20 Notes:MITOA Post SC patch install - Non Witnessed Notes: Notes: Notes: 1D-141A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechan i cal In tegr i ty Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)1D-141A 10-426.xlsx THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D -141A Permit to Drill Number: 208-016 Sundry Number: 319-563 Dear Mr. Mouser: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Enclosed is the approved application for the 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, VChaPrice DATED this ` day of December, 2019. RB®MS? `DEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RAECESIVEED DEC 12 2019 07'S I7.1111tI A®Gcc I. Type of Request: Abandon Ll Plug Perforations ❑ Fracture Stimulate LJ Repair Well Ld Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑� Other: ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllll s Alaska Inc. Exploratory ❑ Development ❑' Stratigraphic ❑ Service ❑ 20$-016 ' 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50029229670100 ` 7. If perforating: N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No KRU 1D -141A ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025650 ' Kuparuk River Field /West Salk f 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9915' 3751' 6029' 3774' Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 116' 116' Surface 461' 103/4" 502' 502' Intermediate 6,330' 75/8" 6371' 3,800' Production 5,344' 51/2" 5,384' 3,537' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 60291- 9915' 3774'-3751' 2 7/8" L-80 5393' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HDR ZXP Liner Top Packer 12 7/8" Cameo "DS" Nipple w/ 2.313 "D" Profile 5372' MD, 3531' TVD / 475' MD, 475' TVD 12. Attachments: Proposal Summary O Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 3/5/2020 15. Well Status after proposed work: Commencing Operations: OIL 0 WIND ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Mouser Contact Name: Roger Mouser / Roger Winter Authorized Title: Well I. tegrity Field Supervisor Contact Email: N1927@conocophilliei.com Contact Phone: 907-659-7506 Authorized Signature: Date: 12/10/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: iJYla,fO Cl0 C (i yil P r,,// RBDMS��N DEC 19 ZOt� ,,,, Post Initial Injection MIT Req'd? Yes ❑ No T Required? Yes r-1NoSubsequent Form Required: to — �/ O Spacing ExceptionVby \1/ \ APPROVED Approvu, COMMISSIONER `7 \ THE COMMISSION Date: � Foi 3 Revised 4/ / 17 I' 1 /zl�/y Submit Farm and Approved applicatio o t . Late of approval. �/ �?��/� Attachments in Duplicat '%iii I79LI /Q ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 10, 2019 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1D -141A (PTD 208-016) to repair the production casing (7 5/8" casing) leak that is estimated to be near surface. Please contact Roger Winter or myself at 659-7506 if you have any questions. Sincerely, X1 )�?� Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Loepp, Victoria T (CED) From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Tuesday, December 17, 2019 8:29 AM To: Loepp, Victoria T (CED) Cc: Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 1 D-141A(PTD 208-016, Sundry 319-563) Repair PC leak Victoria, Operations noted that the 7.625" OA on 1D-141 would not hold pressure. In November 2019 DHD was dispatched to conduct diagnostics & subsequently failed a Surface Casing Leak detect. Slickline was then mobilized & the well was secured w/ a mechanical lug in the 2.875" Tubing. A Combo MIT of the 2.875" tubing by 5.5" production casing Passed ✓ thus rovl� integrity of the 5.5" production casing, packer mechanical plug. A draw down test of the 2.875" tubing & 5.5" production casing also passed proving integrity in direction of flow. Roger Winter/Roger Mouser Wells Supervisor NSK 69 Wells Group Office 206 F Wing Office # 659-7506 Cell # 943-1055 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, December 16, 2019 2:15 PM To: NSK Well Integrity Field Supv <N1927@conocophillips.com> Subject: [EXTERNAL]KRU 1D-141A(PTD 208-016, Sundry 319-563) Repair PC leak Roger, Has an MIT -IA been performed? What is the integrity of the 5.5" casing? What leads you to believe there is a shallow PC leak? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(c?alaska.00v 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 Loepp at (907)793-1247 or Victoria.Loeoo@alaska.gov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. Kuparuk Well 1D -141A (PTD 208-016) SUNDRY NOTICE 10-403 APPROVAL REQUEST 12-10-19 This application for Sundry approval for Kuparuk well 1D -141A is to repair the leak identified in the 7 5/8" casing to regain integrity in the OA. With approval, the production casing repair will require the following general steps: 1. Secure well for repair operations. 2. Excavate as needed for access. Build 9' cellar or excavate for shore /shield box. 3. Tap conductor and drain fluids. Several taps will be made to ensure adequate purge gas flow inside the conductor annulus. Install nitrogen purge fittings on conductor & OA if needed. 4. Cut windows in the 16" conductor for inspection 5. Remove cement between the conductor and 10'/4" rock screen (surface casing) 6. Cut windows into the 10 3/4" rock screen 7. Remove the cement between the 10'/4" rock screen and the 7 5/8" production casing 8. Inspection of 7 5/8" production casing for damage and penetrations by Kakivik. 9. Remove complete 16" conductor and 10'/4" rock screen for production casing inspection 10. Identify leak point. Kakivik to complete final U/T & M/T inspection and patch length determination 11. Prepare welding repair plan as per Mechanical Engineer's direction (seal weld / sleeve / patch, cooper heat or other). 12. Repair casing and Inspect welds. 13. Perform tests to confirm no fluid / gas to surface. 14. Cover with corrosion protection materials 15. Install new conductor casing 16. File 10-404 with the AOGCC post repair. Loepp, Victoria T (CED) From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Tuesday, December 17, 2019 8:29 AM To: Loepp, Victoria T (CED) Cc: Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 1 D-141A(PTD 208-016, Sundry 319-563) Repair PC leak Victoria, Operations noted that the 7.625" OA on 1D-141 would not hold pressure. In November 2019 DHD was dispatched to conduct diagnostics & subsequently failed a Surface Casing Leak detect. Slickline was then mobilized & the well was secured w/ a mechanical plug in the 2.875" Tubing. A Combo MIT of the 2.875" tubing by 5.5" production casing Passed thus proving integrity of the 5.5" production casing, packer & mechanical plug. A draw down test of the 2.875" tubing & 5.5" production casing also passed proving integrity in direction of flow. Roger Winter/Roger Mouser Wells Supervisor NSK 69 Wells Group Office 206 F Wing Office # 659-7506 Cell # 943-1055 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, December 16, 2019 2:15 PM To: NSK Well Integrity Field Supv <N1927@conocophillips.com> Subject: [EXTERNAL]KRU 1D-141A(PTD 208-016, Sundry 319-563) Repair PC leak Roger, Has an MIT -IA been performed? What is the integrity of the 5.5" casing? What leads you to believe there is a shallow PC leak? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppaalaska.go 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. It 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 Loepp at (907)793-1247 or Victoria Loeoo@alaska aov RECEIVED III III STATE OF ALASKA AUG 24 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend fl Perforate Il Other Stimulate Alter Casing Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well p Re-enter Susp Well r Other: Tubing Patch 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ( Exploratory fl 208-016 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22967-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025650 KRU WSAK 1D-141A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 9915' feet Plugs(measured) None true vertical 3751' feet Junk(measured) None Effective Depth measured 9915' feet Packer(measured) 0 /" true vertical 3751' feet (true vertical) 0 i� Casing Length Size MD TVD Burst Collapse Conductor 76' 16" 116' 116' Surface 461' 10 3/4" 502' 502' Production 6330' 7 5/8" 6371' 3800' Production 5344' 5 1/2" 5384' 3537' Perforation depth: Measured depth: Slotted liner from 6029'-9915' JAN 3 1 `2017 True Vertical Depth: Slotted liner from 3774'-3751' SCANNED Tubing(size,grade,MD,and TVD) 2 7/8", L-80, 5393' MD, 3542'TVD 3 section tubing patch with Concentric GLM from 5242'-5305' Packers&SSSV(type,MD,and TVD) SSSV= None Baker Bonded Seal Assembly, 5375' MD, 3533'TVD 12.Stimulation or cement squeeze summary: N/A 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 N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory [ Development 1 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F.7 Gas r WDSPL fl 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: N/A Contact Brent Rogers/Kelly Lyons Email: N1617(q conocophillips.com Printed Name ifyielmBrent Rogers Title: Problem Well Supervisor Signature Phone: 659-7224 Date August 18,2016 vr(- 4- 4, Form 10-404 Revised 5/2015 RBDMS (/V A' 252O abmit Original Only • • RECEIVED ConocoPhillips AUG 24 2016 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 August 22, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU well 1D-141A (PTD 208-016). This report is for a patch, including a concentric GLM and OV, set to repair a tubing leaks above the top packer. After the patch was set, all of the testing passed proving integrity had been restored. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, /161/4/5 Brent Rogers Problem Well Supervisor Attachments • 1D-141 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/30/16 SET 2 7/8"LOWER PARAGAON II PACKER @ 5305'RKB(SER#CPP287006,2.29"OD, 1.38"ID,3.56'LIH).SET 2 7/8"TTS TEST TOOL IN PACKER. LRS CIRC'd OUT W/144 BBL SW&87 BBL DIESEL&U-TUBED, PERFORMED CMIT-TxIA TO 2000#. PASSED. PULLED 2 7/8"TTS TEST TOOL.SET 2 7/8"POGLM UPPER SECTION W/K2 PACKER.(ANCHOR LATCH SER#CPAL287008,28'LIH,2.26"MAX OD, 1.08"MIN ID,28.5'MOE TO MOE: UPPER ELEMENT SET @ 5276.5'RKB.***JOB IN PROGRESS. BEGIN CMIT-TxIA TO 2000#PRE: 150/75/100 INITIAL:2000/1950/120 15 min: 1930/1880/120 30 min: 1910/1860/120 PASSED 07/31/16 SET K2 PACKER TEST TOOL IN TOP OF POGLM @ 5270'SLM. LRS ATTEMPTED MIT-T TO 2000#. FAILED. PULLED&RESET TEST TOOL. REPEAT MIT-T TO 2000#, FAILED. RAN D&D HOLEFINDER SEVERAL TIMES TO LOCATE LEAK:APPEARS TO BE BETWEEN 5245'-5257'RKB.***TEST TOOL LEFT IN HOLE.***JOB IS POSTPONED PENDING NEW PROGRAM. 08/01/16 PULLED TEST TOOL @ 5276'RKB.READY FOR PATCH EXTENSION. 08/09/16 ATTEMPT TO SET 35'9"PATCH ASSEMBLY ON POGLM @ 5276'RKB, PRE SET PATCH @ 1092'SLM. IN PROGRESS. 08/10/16 RECOVER 35'9"PATCH @ 1500'SLM,ATTEMPT TO BRUSH&FLUSH TBG, UNABLE TO WORK PAST 3080'SLM. CLEAN UP TBG W/BRUSH&PRONG BRUSH IN SIDE OF UPPER K-2 PACKER @ 5276'RKB,SET 359"PATCH ASSEMBLY W/2-K PACKER SPACER PIPE&STINGER @ 5240'RKB,GOOD TBG TEST,SET 2 7/8 TBG STOP @ 5240' RKB. COMPLETE. PRESSURE TBG TO 2000 PSI 3.1 BBLS IA/OA=650/100, LOSE 100 PSI IN 10 MIN BUMP UP PRESSURE.1 BBLS T/I/O=2050/650/100, 15 MIN T/I/O=2025/650/100,30 MIN 2000/650/100,45 MIN 2000/650/100,*******PASS******, 08/12/16 PULLED 2 1/2 TBG STOP @ 5234'SLM. PULLED UPPER 35'9"K-2 PATCH ASSEMBLY @ 5236'SLM.JARRED ON K-2 PACKER&POGLM ASSEMBLY FOR 2.25 HRS.WITH NO MOVEMENT. IN PROGRESS. 08/13/16 PULLED 28'POGLM @ 5276'RKB, REDRESSED POGLM @ WIRE LINE SHOP FLUSHED IA W/20 BBL'S DSL, BRUSH TBG&LOWER PARAGON PACKER @ 5305'RKB, RESET 28' POGLM @ 5276'RKB,SET UPPER 35'9"PATCH ASSEMBLY @ 5242'RKB, MIT TBG PASS, FLUSHED TBG WITH 20 BBL'S DSL,SET 2 7/8 TBG STOP ON K-2 PACKER @ 5242'RKB.COMPLETE. PUMPED 15 BBLS TO PRESSURE TBG UP TO 2000 PSI START MITT PRE T/I/0=300/500/80, INITIAL T/I/O=2025,500/80, 15 MIN T/I/O=1975/500/80,30 MIN T/I/O= 1950/500/80******PASS***** 08/17/16 (AC EVAL)TIFL Passed. Initial T/I/O=200/1050/105, IA FL @ 5287'ST#2 OV. SI WV and AL,stacked TxIA for 30 min to T/I/O=800/770/95. Bled AL line. Bled IA for 38 min to T/I/O= 800/280/85, IA FL©5287'. 15 min monitor:800/280/85. 30 min monitor:800/280/85, IA FL @ 5287'. 45 min monitor:800/280/85. 60 min monitor:800/280/85, IA FL @ 5287'. Final T/I/O=800/280/85. Summary A 28'patch consisting of a Paragon II lower packer and an upper K-2 packer were set with a concentric GLM and OV. During testing another hole was identified above the existing patch. A 35'patch extension was set and all testing passed. The tubing patch is a total of 63'from 5242'5305'. KUP PROD • 1D-141A Conoco Phillips a a 1 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UM Field Name Wellbore Status eel(°) MD(NKB) Act Elm(WKB) R ta4rtipfai)tc 500292296701 WEST SAK PROD 9,925.0 °•• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10.1414 8/172016 550'11 PM SSSV:NIPPLE 70 11/10/2014 Last WO: 3/24/2008 37.85 9/21/2000 Vertical schemacc(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O,SET PATCH&H2S pproven 8/17/2016 HANGER:13.5 i1Y)y4... Casing Strings Casing Description OD(In) ID In Top ftKB) Set Depth(WEI) Set Depth TVD Wellen I...Grade Top Thread CONDUCTOR 16 15.062 40.0 1(6.0 116.0 151.50 X-65 WELDED Casing Description OD(In) ID(In) Top(NHB) Set Depth(ttKB) Set Depth(TOO)...We/Len(I...Grade Top Thread SURFACE (03/4 10.050 41.0 502.0 502.0 40.50 J-55 BTC (--�. Casing Description OD(In) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thenad PRODUCTION 7.625'7(7" 7518 6.875 41.2 6,371.0 3,800.1 29.70 L-80 BTC-MOD Casing Description OD(In) ID(in) Top(61419) Set Depth(8KB) Set Depth(TVD)...Wt/Len p...Grade Top ThreadWINDOWA 61/2 5.500 5.503.0 5,512.0 3,601.9 26.00 TDASir Casing Description PRODUCTION 5.5' OD(In) ID(In) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...WI/Len(1..,Grade Top Thread 5 1/2 4.950 39.5 5,384.3 3,537.4 15.50 L-80 BTCM Casing Description OD(in) ID(In) Top(ttKB) Set Depth(NKB) Set Depth(TVD)...We/Len(I...Grade Top Thread D-SAND LINER 4 1/2 3.476 5.371.8 9,915.0 3,751.2 11.60 L-80 BTC Liner Details f Nominal ID CONDUCTOR;40.0-116.0 I�: Top(ttKB) Top(TVD)(NKB) Top Incl P) Rem Dec Com (In) 5,371.8 3.531,1 59,48 PACKER HRD ZXP LINER TOP PACKER 5.500 SAFETY VLv;475.2 5,390.8 3.540.7 59.75 NIPPLE RS PACKOFF SEAL NIPPLE 4.880 SURFACE 4t0-502.0-4 5,393.7 3.542.1 59.74 HANGER FLEXLOCK LINER HANGER 4.840 5,405.2 3,547.9 59.71 SBE 80-40 CASING SEAL BORE EXTENSION 4000' 9,875.8 3,751.1 9007 XO Reducing CROSSOVER 4.5x3.5" 3.500 Tubing Strings Tubing DescrIptIon String Ma...ID(In) Top(ttKB) Set Depth(ft...Set Depth(TVD)(...WI(Ibrtt) Grade Top Cenneetlen TUBING 27/8 2.441 13.5 5,392.7 3,541.6 6.50 L-80 EUE GAS LIFT,3.139.9 Completion Details Nominal 10 Top(ttKB) Top(TVD)(RKB) Top Incl(°) Item Des Com (In) ■ 13.5 13.5 0.00 HANGER Vetco Gray 1 i"x 4-1/2"w/4.909"MCA Top Connection 2.875 (drifted 3.885") 475.2 475.2 1.07 SAFETY VLV 2-7/8"Camco"DS"Nipple W/2.313""0"Profile 2.313 GAUGE;5,120.4 5,120.4 3,401.2 59.28 GAUGE Baker 2-7/8"Guardian Gauge Carder EUE 2.441 5,329.4 3,509.3 58.86 NIPPLE 2-7/8"Cameo"DS"Nipple w/2.250"'Ti"Profile 2.250 SLIP STOP,5,239.0 5,3740 3,532.2 59.51 LOCATOR Seal Assembly Locator O.D.4.51"I.D.3.00" 3.000 PACKER:5.240.0 1 5,375.2 3,532.8 59.53 SEAL ASSY Baker Bonded Seal Assembly 0.D.4.00"I.D.3.75" 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top MKS) MKS, (°I Des Com Run Date ID(In) 5,239.0 3,462.2 58.73 SLIP STOP 2 7/8"SLIP STOP 8/13/2016 GAS LIFT;5,287.0" 5.240.0 3,462.7 58.73-PACKER 35'9" 8/13/2016 1.810 POGLM;5,276.5 • I K-2 PACKER SPACER&STINGER 5,276.5 3.481.7 58.47 POGLM POGLM OVER ST 42,LOWER ELEMENT Ig 5,305' 8/13/2016 4 3/16"PORT SIZE NIPPLE;5,329.4 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shoMlf 1111 Top(RKB) atm(ftKB) , (ttKB) (ttKB) Zone Date t) Type Com _1 6,029.0 9,915.0 3,774.3 3,751.2 WS D,ID- 3/24/2008 32.0 SLOTS SLOTTED LINER 141A Mandrel Inserts LOCATOR:5.374.0 ( St all SEAL ASSY;5,375 2 'rl'.� ) on Top(ND) Valve Latch Pod Sloe TRO Run PRO WCTION 5.339.5-S ' f� i N Top(RKB) _ (NKB) Make Model OD(In) Sen Type Type (in) (psi) Run Date Com 5.384.3 III "1 3,139.8 2,398.2 Camco KBMG ' 1 Gas Lift •GLV BK 0.156 1,320.0 6/30/2008 M-2 2 5,287.0 3,487.2 Camco KBMG M-2 1 Gas Lift OPEN 7/29/2016 [ t I. 'I Notes:General&Safety End Data Annotation 3/21/2008 NOTE:WELL SIDETRACKED TO'A' 3/24/2008 NOTE:10.141&1D-(41L1 ABANDONED&SIDETRACKED ABOVE 1D-141L1 11/29/2010 NOTE:View Schematic W/Alaska Schemaoc9.0 WINDOW A.5.503.0-5,512.0 1 • -4- -e -' PRODUCTION 7.625'57",41.2- 9,371.0L_yr SLOTS;6.028.0-9,915.0 , 0-SAND LINER;5,371.84 9,915.0 4ne r- t.Cv • • 2-Gp IN-1 WELL LOG TRANSMITTAL#903072690 To: Alaska Oil and Gas Conservation Comm. March 4, 2016 Attn.: Makana BenderRECEIVED) 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 MAR 08 Vii) M;K.BENDER ,, OGCC RE: Gas Lift Survey: 1D-141A Run Date: 1/21/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 FRS_ANC@halliburton.com 1D-141A Digital Data in LAS format,Digital Log Image file •- --- 1 CD Rom 50-029-22967-01 Gas Lift Survey(Field Print) 1 color log 50-029-22967-01 SCANNED 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: f4LnJ I5e,4 ' • u i 1)-141 rA 76,6 I6U Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, February 26, 2016 4:11 PM ��,� z14-42( (o To: Regg,James B (DOA) ' - "l Cc: NSK Fieldwide Operations Supt Subject: 1D AOGCC inspector deficiency reports response Attachments: 1D Deficiencies reports 02-26-16.pdf Jim-enclosed is ConocoPhillips response to the deficiencies noted by the AOGCC inspector during the 2/22/16 SVS testing on 1D pad. Please let me know if any further action is needed. Darrell Humphrey I Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) SCANNED SEP 2 3z016 I<Ark - 14 I A • • pr6 -z`'` "` ' ConocoPhillips Alaska AOGCC EXCEPTION REPORT Location: 1D Pad Date: 02/22/16 AOGCC Inspector: Guy Cook Instructions:All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered Into the'Action Taken'section below. Note-Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: 1D-02 -Possible SSV bonnet seal leak. Choke stem leak, packing needs to be tightened or replaced. This 1D-10.-Choke stem leak, packing needs tightened or replaced. 1D-110-Choke stem leak, packing needs tightened or replaced. Ik 1D-141 -SSV barrel leaking hydraulic fluid from plug Action Taken to Correct Problem: Date: 02/26/16 Initials: JRH 1 D-02 choke has been inspected and rebuilt Date: 02/26/16 Initials: JRH 1D-10 choke has been inspected and rebuilt 1D-110 choke was visualy inspected. No apparent leaks. Snoop Date: 02/26/16 Initials: JRH tested the stem and actuated, then used snoop again. No leaks ,00< 1 D-141 SSV barred was serviced by the valve crew. No longer Date: 02/26/16/ Initials: JRH ‘k) leaking. Date: Initials: Date: Initials: Return completed form to Prod. Engr.Specialist: n 1139Ca conocophillips.com Distribution: CPF IDSLT CPF OPS Supv Prod. Engr. Specialist G.C. CPF1&2 Ops Supt CPF3 Ops&DOT Pipelines Supt NSK Fieldwide Operations Supt • • State of Alaska )3� Oil and Gas Conservation Commission "AM'It, Deficiency Report Location: /J1 (1 ^ /2//A - Date: 2/ z.-) PTD: PTD: Zai I I;D Operator: atA-04 s / �y 11Tps• Type Inspection: 5 vs- Operator Rep: 7).A-HM / (��d 6 Inspector: Ik-- '3 u o© Position: SUS v u� Op. Phone: 65-57—222- I Correct by(date): Z/Z� /1z Op. Email: Follow Up Req'd: e-5 Detailed Detailed Description of Deficiencies Date Corrected 5,5v 64-rev,/ /.edie-r . kidePro v•cia Operator Rep Signatures: �'' AOGCC Inspector *After signing,a copy of this form' o be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 04/2015 DATA SUBMITTAL COMPLIANCE REPORT 1/2812010 Permit to Drill 2080160 Well Name/No. KUPARUK RIV U WSAK 1D-141A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22967-01-00 MD 9926 TVD 3751 Completion Date 3/25/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: GR/RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og induction/Resistivity 25 Col 3596 3751 Open 6/19/2008 TVD DGR, EWR og Induction/Resistivity 25 Col 5502 9925 Open 6/19/2008 MD ROP, DGR, EWR og Induction/Resistivity 25 Col 5502 6680 Open 6/19/2008 PB1 MD ROP, DGR, EWR og Induction/Resistivity 25 Col 3596 3775 Open 6/19/2008 PB1 TVD DGR, EWR ~ Log Induction/Resistivity 25 Col 5502 7033 Open 6/19/2008 P62 MD ROP, DGR, EWR ~ og InductionlResistivity 25 Col 3596 3774 Open 6/19/2008 P62 TVD DGR, EWR og Induction/Resistivity 25 Col 5502 6360 Open 6!19/2008 PB3 MD ROP, DGR, EWR I ;,Log Induction/Resistivity 25 Col 3596 3784 Open 6/19/2008 PB3 TVD DGR, EWR ED C 16467 See Notes 0 0 6/19/2008 TVD and MD logs in PDF, EMF and CGM ED C 16468 See Notes 0 0 6/19/2008 PB1 TVD and MD logs in PDF, EMF and CGM ED C 16469 See Notes 0 0 6/19/2008 P62 TVD and MD logs in PDF, EMF and CGM ED ~- 16470 See Notes 0 0 6/19/2008 I PB3 TVD and MD logs in I PDF, EMF and CGM pt LIS Verification 5472 9925 Open 6/19/2008 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP ED C Lis 16471 LIS Verification 5472 9925 Open 6/19/2008 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP r 1 L J DATA SUBMITTAL COMPLIANCE REPORT 1128/2010 Permit to Drill 2080160 Well Name/No. KUPARUK RIV U WSAK 1D-141A Operator CONOCOPHILLIPS ALASKA INC MD 9926 TVD 3751 Completion Date 3/25/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-22967-01-00 UIC N LIS Verification I ED C Lis 16472 LIS Verification LIS Verification LIS Verification I ED C Lis 16473 LIS Verification ED C Lis 16474 LIS Verification LIS Verification C Lis 16610~nduction/Resistivity LIS Verification C Lis 16611 /Induction/Resistivity LIS Verification D C Lis 16612~Induction/Resistivity 5472 6680 Open 6/19/2008 P61 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP 5472 6680 Open 6/19/2008 PB1 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP 5472 7033 Open 6/19/2008 PB2 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP 5472 6360 Open 6/19/2008 P63 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP 5472 7033 Open 6/19/2008 PB2 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP 5472 6360 Open 6/19/2008 P63 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP 5472 6680 Open 7/16/2008 PB1 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP REDO 5472 6680 Open 7/16/2008 P61 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP REDO 5472 6499 Open 7/16/2008 P62 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP REDO 5472 6499 Open 7/16/2008 PB2 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP REDO 5472 6125 Open 7/16/2008 PB3 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP REDO 5472 6125 Open 7/16/2008 P63 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP REDO • DATA SUBMITTAL COMPLIANCE REPORT 1/28/2010 Permit to Drill 2080160 Well Name/No. KUPARUK RIV U WSAK 1 D-141A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22967-01-00 MD 9926 TVD 3751 Completion Date 3!25/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ~=C"og Induction/Resistivity ~~~. 25 Col 3596 3775 Open 8/8/2008 P61 TVD DGR, EWR og Induction/Resistivity ~~~;~ 25 Col 5502 6680 Open 8/8/2008 PB1 MD ROP, DGR, EWR og Induction/Resistivity VZc~ 25 Col 3596 3775 Open 8/8/2008 P62 TVD DGR, EWR og InductionJResistivity vQc.~ 25 Col 5502 6680 Open 8/8/2008 PB2 MD ROP, DGR, EWR og Induction/Resistivity ~~~ 25 CoI 3596 3775 Open 8/8/2008 P63 TVD DGR, EWR Log Induction/Resistivity 1Z.E a 25 Col 5502 6680 Open 8/8/2008 P63 MD ROP, DGR, EWR D C 16707` See Notes 0 0 8/8/2008 TVD and MD of EWR logs in PDS, EMF and CGM graphics g Pressure 5 Blu 5500 5800 Case 2/13/2009 FBHP, Spin, Den, Temp, Pres, GR, CCL 21-Jan- 2009 ED C Pds 17820 Pressure 5500 5800 Case 2/13/2009 FBHP, Spin, Den, Temp, i Pres, GR, CCL 21-Jan- 2009 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y / N Chips Received? Y / N Formation Tops Y / N Analysis Y / N Received? • • Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/2812010 Permit to Drill 2080160 Well Name/No. KUPARUK RIV U WSAK 1D-141A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22967-01-00 MD 9926 ND 3751 Completion Date 3/25/2008 Completion Status 1-OIL Current Status 1-OILS I _ UIC N Compliance Reviewed By: _ _ ____ Date: _~~ ~~~ ~ ~ 02/09/09 y . r..~ `,"~~ r_..4.., Schlumberger -DCS 2525 Gambell Street, Suite 400 , ; , .. Anchorage, AK 99503-2838 ATTN: Beth NO.5063 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk •I Well Job # Log Description Date BL Color CD iL-13 11978475 PRODUCTION PROFILE ~- L `j 08/16/08 1 1 2A-26 AZJZ-00010 USIT ~- Zj 01/16/09 1 1 1D-141A ANHY-00041 FLOWING BHP -Q 01/21/09 1 1 3K-15 B04C-00004 INJECTION PROFILE _ ~ 01/21/09 1 1 E-105 AZED-00019 INJECTION PROFILE "- 01/23/09 1 1 1E-119 AYS4-00023 INJECTION PROFILE U 01/23/09 1 1 3J-01 AYS4-00024 INJECTION PROFILE , 'r - 01/24/09 1 1 2V-06 AZED-00022 INJECTION PROFILE /$~- 1 01/26/09 1 1 2K-22 AZED-00024 LDL - ~ ~-,~ f 01/28/09 1 1 2L-301 AZED-00025 SBHP SURVEY 01/29/09 1 1 1 R-03A ANHY-00045 INJECTION PROFILE 1- ' ~- ~ ~ 02/09/09 1 1 2B-11 AZED-00028 INJECTION PROFILE 02/01/09 1 1 2F-16 AZED-00029 INJECTION PROFILE U 02/02/09 1 1 3J-OS AZED-00030 INJECTION PROFILE 02/03/09 1 1 3G-07A AYS4-00033 PRODUCTION PROFILE j ~ 02/04/09 1 1 1 D-03 ANHY-00042 LDL ~ - 02/05/09 1 1 g Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. J ~' • • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 SEP 0 2 2008 August 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: REC~, V L.~ ao$_at~ \9' 141 ~ 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 a 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 cement top jobs were performed between June 23, 2008 and August 24, 2008. The corrosion inhibitor/sealant was pumped on August 27, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ~/f i~% ~' M.J. oveland ConocoPhillips Well Integrity Projects Supervisor Alaska {ail & Gas Cons. Commissiar~ Anchorage • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/27/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-23 191-CJ09 12" na 12" na 6.80 8/27/2008 1A-24 200-1'81 6" na 6" na 2.55 8/27/2008 1A-28 191-002 8" na 8" na 1.70 8/27/2008 1 B-13 194-055 24" na 24" na 8.50 8/27/2008 1 B-15a 204-256 SF na SF na 8.50 8/27!2008 1 B-16 194-037 21' 8" 4.00 25" 8/24!2008 6.80 8/27/2008 1 B-17 194-045 6' S" 1.00 28" 8/24/2008 5.10 8/27/2008 1 D-134 198-111 SF na SF na 2.55 8/27/2008 1 D-135 197-184 SF na SF na 1.70 8/27/2008 1 D-141 a 208-016 16' 1.40 3' 6/23/2008 9.35 8/27/2008 ~~ ~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1 D-141 A PB 1 +PB2+PB3 Redo AK-MW-547770 June 14, 2008 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-141A PB1+pB2+pB3 Redo 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-22967-73,74,75 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-22967-73, 74, 75 Digital Log Images 1 CD Rom 50-029-22967-73,74,75 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd.- Anchorag~; ~Al~ska 99518 Date: ur. Ia ~' !i Signed: ( ~/L.-- ~a~ o~~ i~~a~ ~ w dVLLL L®G TRAl~1SMITTAL To: State of Alaska June 23, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1D-141A PB1 Redo AK-MW-547770 1 LDWG formatted CD Rom with verification listing. API#: 50-029-22967-73 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, :Alaska .99518 __. I Date: Signed: ~ ~ WELL L®G TRANSMITTAL, To: State of Alaska June 23, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1D-141A PB2 Redo AK-MW-547770 1 LDWG formatted CD Rom with verification listing. API#: 50-029-22967-74 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: , ... ._ Signed: ~_ ~O~-O/~o ~l~Gl WELL L®G TRANSMITTAL To: State of Alaska June 23, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1D-141A PB3 Redo AK-MW-547770 1 LDWG formatted CD Rom with verification listing. API#: 50-029-22967-75 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: -- y Signed: ~G~-GYM ~ /~lo/~ • • WLLL L®G TRANSMITTAL To: State of Alaska June 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1D-141A+PB1+PB2+PB3 AK-MW-547770 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-141A+PBl+PB2+PB3 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 5 0-029-22967-01, 70, 71, 72 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-22967-01,70,71,72 Digital Log Images 1 CD Rom 50-029-22967-01,70,71,72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 tf Date: - Si ed: ~, `~ rli~~yl~~ Sn ~, i ~~ • WELL LOG TRANSMITTAL • To: State of Alaska June 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1 D-141 A AK-MW-547770 1 LDWG formatted CD Rom with verification listing. API#: 50-029-22967-01 PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: j a ~ ~. Signed: ~ ~/ ~'/~___.- ~~,~_~~~ ~ /b ~~~1 • WELL LOG TRANSMITTAL To: State of Alaska June 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1 D-141 A PB 1 AK-MW-547770 1 LDWG formatted CD Rom with verification listing. API#: 50-029-22967-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: '''L~' Si ed: ~. 'U~"~~ • WELL L®G TRANSMITTAL To: State of Alaska June 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1 D-141 A PB2 AK-MW-547770 1 LDWG formatted CD Rom with verification listing. API#: 50-029-22967-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _~~ ~: fi Signed: ~ ~-~' • WELL LOG TRANSMITTAL To: State of Alaska June 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1D-141A PB3 AK-MW-547770 1 LDWG formatted CD Rom with verification listing. API#: 5 0-029-22967-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska,99S.18 __ _ ~. e __ ~ - ~ ' ~ ~~ ~ ~~ Date: Signed: ~~~ /~ ~~°iS C~ ~ ~~~ ~~~ ~ au r ConocoPhillips May 12, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~ MAY 1 6 ZC~08 A~as~a Qil & Gas Gons, Car~rrri sior~ F>: ~-<°, .__ Anchorage Subject: Well Completion Reports for 1 D-141 A, 1 D-141 and 1 D-141 L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the West Sak well 1 D-141A. Also attached are the reports for the P&A operations for 1 D-141 and 1 D-141 L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ( ~;,:~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RTlskad STATE OF ALASKA ~ MAY 1 6 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION ;~O~Ska Oil & G s o Commission WELL COMPLETION OR RECOMPLETION REPORT AN[,~, s' 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: March 25, 2008 12. Permit to Drill Number. 208-016 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 10, 2008 13. API Number: 50-029-22967-01 4a. Location of Well (Governmental Section): Surface: 14' FSL, 596' FEL, Sec. 14, T11N, R10E, UM 7. Date TD Reached: March 20, 20 14. Well Name and Number: 1D-141A , Top of Productive Horizon: 1264' FNL, 1960' FEL, Sec. 24, T11 N, R10E, UM 8. KB (ft above MSL):///.~ 3$=R1lB Ground (ft MSL): 70~LY1~AMSL 5. Field/Pool(s): Kuparuk River Field Total Depth: 295' FSL, 1983' FEL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): s• 9915' MD / 3751' TVD West Sak Oil Pool ` 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560490 y- 5959678 • Zone- 4 10. Total Depth (MD + TVD): 9926' MD / 351' TVD ~ 16. Property Designation: ADL 25650 • TPI: x- 564418 y- 5958433 Zone- 4 Total Depth: x- 564428 - 5954712 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 502' MD / 502' TVD 17. Land Use Permit: ALK 468 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1735' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 5502 /KA f~ GR/RES ~"T7~~'D i~irg• 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 151.5# X-65 Surf. 110' Surf. 110' 24" 135 sx AS I 10.75" 40.5# J-55 Surf. 502' Surf. 502' 12.25" 126 sx LiteCRETE 7 5!8" 29.7# L-80 Surf. 5502' Surf. 3597' 9.875" 540 sx ASIA Lite, 49o sx Class G 5.5" 15.5# L-80 Surf. 5384' Surf. 3537' 6.75" 4.5" 11.6# L-80 5371' 9915' 3531' 3751' 6.75" blank/slotted liner . t4.O''v 23. Open to production or injection? Yes No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pe oration Size and Number): SIZE DEPTH SET (MD) PACKER SET 2-7/8" 5415' 5372' 5371'-6029' MD 3531'-3774' TVD blank liner • 6029'-9915' MD 3774'-3751' TVD slotted liner 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes ^ No r 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. ~ - •-!,,--, •2 ~ . v NONE ~ ~_~~~ Form 10-407 Revised 2/2007 ~rf ~ ~~ ~ L CONTINUED ON REVERSE SIDE 5 ~~~., ,it11. ~ ~ DOB `cam„ 'S' • !~' o$ arri~ ~- ~ _ r/ 28. GEOLOGIC MARKERS (List all formations and m ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1917' 1735' needed, and submit detailed test information per 20 AAC 25.071. West Sak D 6000' 3770' West Sak C 9926' 3751' West Sak B 9926' 3751' 1 D-141APB1 TD 6680' 3776' N/A 1 D-141AP62 TD 7033' 3774' 1 D-141 AP63 TD 6360' 3784' Formation at total depth: Kuparuk D 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 ~~ Printed Name Rand omas Title: Drilling Team Leader Signature 1 _. e Z ~ S ~ $ 3 ~ Date ~ ~ r 2./o Z INSTRUCTIONS Sharon Allsup-Drake 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 2/2007 ~I C~ KRU 1 D-141A Conr~~t~Phillips Alaska, Inc» F i D 1141 A -- --- --- _ I APL• 150n2922967n1 I Well Tvoe: I PROD I Anale la) TS: I dea (a) ~ ConacoPhilps Time Log Summary WelN7ew Web ReportPng Well Name: 1 D-141 Job Type: DRILLING SIDETRACK __ _ - _ Time Lo_~ - --- - - - _ Date From To _, Dur _ S, De th E Depth Phase Code Subcode T COM 02/26/2008 14:30 18:00 3.50 0 0 0 _ MOVE DMOB P Demob Doyon 15 Rig & Prep to Move f/ 3C Pad to 1 D Pad; Skid Floor, Warm H draulic S stems; Clean Pits 18:00 00:00 6.00 0 0 0 MOVE DMOB P Demob Rig & Prep to Move f/ 3C Pad to 1 D Pad; Move Off Well, Pick up Mattin Boards, Clean Pad 02/27/2008 00:00 01:30 1.50 0 0 0 MOVE DMOB P Break Modules Apart, P/U Mats and Pre are to Move Off Location 01:30 04:30 3.00 0 0 0 MOVE MOB P Move f/ 3C to Corner of 3C Access & Oliktok Road 1.4 Miles 04:30 08:30 4.00 0 0 0 MOVE WOCC NP Wait on CPF3 &STP Crew Change 08:30 16:30 8.00 0 0 0 MOVE MOB T Hinge Broke on Rig Floor Module Movin S stem 16:30 20:30 4.00 0 0 0 MOVE WOCC NP Wait on CPF3 &STP Crew Change 20:30 00:00 3.50 0 0 0 MOVE MOB P Move f/ Corner of 3C Access to CPF 3 (1 Mile); Wait on Traffic & Fuel Doyon 15 Equipment on 3C (1.0 Miles); Begin Moving to Kuparuk Drilling Warehouse 02/28/2008 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Move Both Modules f/CPF 3 to Kuparuk Drilling Tools Warehouse (4.2 Miles 05:00 08:30 3.50 0 0 MIRU MOVE WOCC NP Wait on CPF 3 &STP Crew Change 08:30 10:30 2.00 0 0 MIRU MOVE RGRP T Replace Hydraulic Motor on Pit Module Movin S stems 10:30 16:30 6.00 0 0 MIRU MOVE MOB P Move f/ Tool Support Warehouse to KCC 3.7 Miles 16:30 18:30 2.00 0 0 MIRU MOVE WOCC NP Wait for Crew Change 18:30 21:30 3.00 0 0 MIRU MOVE MOB P Move f/ KCC to 1 D Pad (3.1 Miles) 21:30 00:00 2.50 0 0 MIRU MOVE OTHR P Laying Rig Mats, & Herculite; Adjusting Layouot for Rig w/ Vetco Gra Re 02/29/2008 00:00 01:00 1.00 0 0 MIRU MOVE PSIT P Move the drilling module up onto the mats, s uare u with well 1 D-141 . 01:00 02:00 1.00 MIRU MOVE OTHR P Shovel behind well 1D-141 and prepare area for stom er feet. 02:00 03:00 1.00 0 0 MIRU MOVE OTHR P Call the drill site operator. Remove a support scissor for flow lines behind the rig (which is in the way of the stomper foot on the driller's side of sub . ',,,,,'[ nrt 31 ~, ~. Time Logs .Date From To Dur S.-De th E. Depth Phase Code..: Subcode T_ COM _.__ 02/29/2008 03:00 06:00 3.00 0 0 MIRU MOVE PSIT ~ P Move rig. over well 1 D-141, close doors on the cellarset drilling module down. Level and shim area for stomper feet. Add more mattin for it module. 06:00 07:00 1.00 0 0 MIRU MOVE OTHR P Pre load stomper feet w/ 750 psi. Check well center-OK. 07:00 07:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving pit module. 07:15 09:00 1.75 0 0 MIRU MOVE PSIT P Move the pit module onto the matting boards. Maneuver and align up along side of the drilling module (within a foot and arallel .Set module down. 09:00 09:45 0.75 0 0 MIRU MOVE PSIT P Turn tires of the pit module to mate up with the drilling module. Move and set pit module. .Note: Moving shop, two small camps, and change house from 3C ad to 1 D ad. 09:45 10:00 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting for skidding the rig floor into the drilling position. Note: Continue moving shop, two small camps and change house from 3C ad to 1 D ad. 10:00 11:00 1.00 0 0 MIRU MOVE PSIT P Skid the rig floor into the drilling. position. Center over the well. Note: Continue moving shop, two small. camps, and change house from 3C ad to 1 D ad. 11:00 12:00 1.00 0 0 MIRU MOVE RURD P Rig up steam lines to the rig floor. Rig up beaver slide. Rig up steam for all of the rig. Note: Continue moving shop, two small camps, and change house from 3C ad to 1 D ad. 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Berm around the rig. Spread herculite for the rockwasher. lay plywood in cellar area. Cleanup rig after rig move. Spot the company man/toolpusher camp, spot truck shop, spot the change house. Note: Continue moving shop, two small camps, and change house from 3C pad to 1 D pad. On pad @ approx 1700 hrs. Note: Moving rockwasher and parts houses from 3C pad to 1 D pad. Note: Doyon 15 Rig acceptance after rig move f/ 3C-14 to 1 D-141 is 1530 hrs 2/29/2008. Time was adjusted: back 8 hours for waiting on field wide crew chap es Burin move. 18:00 18:15 0.25 0 0 MIRU MOVE SFTY P Prejob safety meeting. Note: Moving rockwasher and parts houses from 3C pad to 1 D pad. 13.1 mile move, ad to ad. ?g~~ 2nt ~1 I ~ Time Logs- __-- - _-- -_ __-_ _ Depth Phase Code Subcode T COM _ From To Dur S De th E. Date _ 02/29/2008 18:15. 22:00 .3.75 0 _ 0 MIRU MOVE RURD P Continue filling in the cellar area with plywood. Filling gaps with insulation in cellar (two wells in the cellar- # 3 and #111). Working on steam Iines.Rig up mud lines under the rig floor. Connect shock hose in mezzanine. Spot the rockwasher and rig up same. Change gaskets inflow line dresser sleeve. Rig up lines from the choke manifold to the pits. Pull the braces in the pipe shed. Clean up as needed after the rig move. 22:00 23:30 1.50 0 0 MIRU MOVE RURD P Well sign information changed on well sign. Permit in the dog house. Work on rig acceptance check list. Install ground clamp on wellhead. Pull VR plug on the annulus valve (7-5l8" x 4-1/2" . 23:30 00:00 0.50 0 0 MIRU MOVE RURD P Install second annulus valve. Install flange on the horizontal tubing wing valve. Continue to rig up the rockwasher. Note: Doyon 15 Rig floor to top of multibowl= 36.95', to 4-1/2" LDS= 37.10', to bowl energize screws 40.65', to the top flutes of the 7-5/8" hanger. Difference of 11.7' from Nordic 3 original measurements. Note :Nordic 3 Rig floor to top of multibowl = 25.25', to 4-1/2" LDS = 25.40'. Rig up berm and 400 bbl horizontal tank for dis lacement. 03/01/2008 00:00 01:30 1.50 0 0 MIRU MOVE RURD P Rigging up lines on the annulus and tubing for upcoming displacement. Rigging up a 400 bbl displacement tank and hardline to rig. Continue to rig up the rockwasher. Note: Doyon 15 Rig floor to top of multibowl= 36.95', to 4-1/2" LDS= 37.10', to bowl energize screws 40.65', to the top flutes of the 7-5/8" hanger. Difference of 11.7' from Nordic 3 original measurements. Note :Nordic 3 Rig floor to top of multibowl = 25.25', to 4-1/2" LDS = 25.40'. Rig up berm and 400 bbl horizontal tank for dis lacement. 01:30 04:00 2.50 0 0 MIRU MOVE RURD P Put 290 bbls of 9.5 ppg brine in the pits. Plump diesel to the test pump for pressure testing hardline. Blow air through secondary kill line from mud pumps-OK. Rig up chart recorder for the annulus and tubin in the cellar. ?age 3 of ~1 ~~ Time_L_ogs _ _ _-- -- __- - ur 5 Depth E. Depth Phase Code Subcode T COM Date From To D 03/01/2008 04:00 06:00 _ 2.00 0 0 MIRU MOVE KURD P Rig up a portable heater for the choke skid/house. Install a 4k guage on the choke manifold. Thaw out a 2" hose to be used to connect to choke house. Fill pits w/another 290 bbls of 9.5 ppg brine. 06:00 .08:30 2.50 0 0 SURFA WELC OTHR P Rig up lubricator to pull 4" BVP with Vetco Gray rep. Pull BPV. Appears to have only 20 psi below the BPV and the same on the annulus. 08:30 12:00 3.50 0 0 SURFA WELCT OTHR P Continue to rig up to flush well with hot seawater (8.5 ppg). Blow air through lines to tank. Fill lines w/diesel, then test to 300 psi and 3000 psi. Changed out some guages and needle valve and 2" chicksans on the hard line. 12:00 12:15- 0.25 0 0 SURFA WELCT ' SFTY P PJSM prior to flushing the well 12:15 12:45 0.50 0 0 SURFA WELCT OTHR P Fill line from pumps to the annulus valve w/ 8.5 ppg/ 110 deg. Pressure test lines to 2500 si, OK. 12:45 20:15 7.50 0 0 SURFA WELCT CIRC P Flush well w/ 110 deg, 8.5 ppg seawater. Pumping w/ rig pump down the 7-5/8" x 4-1/2"annulus., taking returns up the 4-1/2" 12.6 ppf L-80 NSCT tubing to a 400 bbls open top horizontal tank. Using wells group choke skid in line to control pressures. Gauging volumes returned. Pumped 70 bbls before returns to the tank. Pumping 2 bpm w/ 300 - 650 psi. Maintained Well Back Pressure at 200 - 270 Psi; At 145 Bbls Pumped Lost Returns to Choke Skid due to Hose Plugging w/Sludge; Finished pumping a total of 320 Bbls of Hot Sea Water and Changed to Second Truck; Shut in Well w/ 600 Psi on Both Tubing and Annulus Gauges probably trapped pressure); Pumped 270 Bbls more of 8.5 ppg/ 110 deg Hot Sea Water @ 2 bpm w/ 820 - 1.120 Psi ;For Second truckload Mainteined Well Back Pressure at 600 - 650 Psi; Shut In Well After Fult Displacement to Sea Water; 350 Psi on Annulus & 350 Psi on Tubing Gauges. Lost 80 bbls of seawater to the formation Burin dis lacement. 20:15 20:45 0.50 0 SURFA WELC OTHR P Blow down choke line to tank. 20:45 21:15 0.50 SURFA WELCT OTHR P Bleed off through choke line to the horizontal tank. Shut in well with 50 si on both the tubin and annulus. ~~ Time Logs Date From To Dur 5 De th E. De~t_h Phase Code Subcode T COM __ 03/01/2008 21:15 22:45 1.50 SURFA WELC OTHR P Monitor well. Pressure stabilized at 85 psi. Calculated kill weight fluid @ 9 ppg. 3634' TVD w/ 8.5 ppg fluid & 85 si. 22:45 23:15 0.50 SURFA WELC CIRC P Start pumping 9.5 brine down annulus taking returnsup the tubing. Pumping 2 bpm w/ 340 psi, holding 230 psi on tubing while pumping down the annulus. Pumped a total of 25 bbls of fluid. Choke manifold pressure lower than tubing pressure. Shut down um in . 23:15 00:00 0.75 SURFA WELCT OTHR P Trouble shoot pressure problem. Change guages, inspected hardline, checked low torque valves, changed a 2" hose. Note: Suspect a problem w/ 2" hose. Found a rock inside of the hose. 03/02/2008 00:00 01:30 1.50 0 0 SURFA WELC KLWL P Killed Wetl by Reversing 240 Bbls of 9.5 PPG Brine @ 2 BPM to Displace 8.5 PPG Sea Water 01:30 02:00 0.50 0 0 SURFA WELCT OTHR P Shut in Well and Bleed Off Tubular Pressures; Monitor Well for Activity (Static); Blow Down Choke Skid & Lines 02:00 03:45 1.75 0 0 SURFA WELCT CIRC P Bull Head 150 Bbl (B & D Lateral Volumes) of 9.5 Ppg Brine into Formation (ICP = 870; FCP = 910) Pum in 1.5 b m. 03:45 04:30 0.75 0 0 SURFA WELC OTHR P Bleed Off Pressure Through Rig Choke Manifold t/ Poor Bo De asser 04:30 05:30 1.00 0 0 SURFA WELCT CIRC P Reverse Circ Through Rig Choke 221 Bbl 3 BPM w/ 260 PSI Surf t/ Su 05:30 07:30 2.00 0 0 SURFA WELC OWFF P Shut down, bleed lines and blow down lines. Monitor Tubing; Appeared to be Flowing Diesel w/slight Vacuum on Annulus ("U" tubing). Died down and sto ed flowin .Static. 07:30 09:45 2.25 0 0 SURFA WELCT OTHR P Set BPV w/ Lubricator. Rig down lubricator. 09:45 10:00 0.25 0 SURFA WELCT SFTY P Pre job safety meeting on nippling down tree. 10:00 11:00 1.00 0 0 SURFA WELCT NUND P Nipple Down Tree 11:00 20:30 9.50 0 0 SURFA WELCT NUND P Nipple Up BOPE; Change lower pipe rams f/ 2-7/8" to 4 1/2" X 7" variables on Bottom. Attach riser, hole fill, flowline, install dri an. 20:30 22:00 1.50 0 0 SURFA WELCT OTHR P Rig up testing equipment to test with a 4-1/2" test 'oint. ~,~~. ~ ~ Time Logs _ _ _ ____ ___ COM __ Date From To Dur S _Depth E. De th Phase Code Subcode T 03/02/2008 22:00 00:00 2.00 0 0 SURFA WELCT BOPE _ P Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Tested to 250 psi low and 3000 psi high. Hold each test 5 minutes. Tested lower pipe rams (4-1/2" x 7" variables) with 4-1/2" test joint, and upper IBOP on the top drive. Tested the accumulator. Initial system pressure 3150 psi, manifold pressure 1500 psi. After closing 1500 psi, 200 psi build up in 51 seconds, and 3 minutes 44 seconds for full charge. 5 bottles avera a ressure 2400 si. 03/03/2008 00:00 07:00 7.00 0 0 SURFA WELL BOPE P Continue to Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Tested to 250 psi low and 3000 psi high. Hold each test 5 minutes. Tested lower pipe rams (4-1/2" x 7" variables) with 4-1/2" test joint, and upper IBOP on the top drive. Test upper pipe rams, and annular. Blind rams were tested. All kill line valves and choke line valves. Choke manifold was tested. All tests passed to this point. Oteco gasket on choke line leaked, replaced gasket. Manual valve on choke line leaked through grease fitting, tightened fitting and tested OK. 07:00 07:45 0.75 0 0 SURFA WELC OTHR P Rig down testing equipment, drain stack, blow down choke manifold. 07:45 08:30 0.75 0 0 SURFA WELL OTHR P Pull Test Tool & Plug per Vetco Grey Re 08:30 09:30 1.00 0 0 SURFA WELC. OTHR P Pull BPV. 09:30 10:00 0.50 0 SURFA RPCO RURD P Rig up to reverse circulate. Will pump down 7-5/8" x 4-1/2" annulus taking returns down the flowline. 10:00 12:00 2.00 0 0 SURFA RPCOh CIRC P Reverse Through Secondary Kill Line as Follows: 30 bbls @ 1 BPM w/ 40 Psi; then Increased Rate to 2 BPM @ 90 Psi; at 90 Bbl Pumped -- 2 BPM @ 100 Psi; at 200 Bbl pumped - 2 BPM @ 90 Psi; Max Gas 1252 Units; Pum ed 236 Bbls Total 12:00 12:45 0.75 0 0 SURFA RPCO RURD P Blow Down Circulating Lines & rig down. R/U to Lay Down 4 1/2" Tubing er Cerntrilift &GBR 12:45 13:00 0.25 0 0 SURFA RPCO SFTY P PJSM for Laying Down 4 1/2" Tubing 13:00 14:00 1.00 0 0 SURFA RPCO PULD P RIH w/ Landing Jt but Unable to Make Up; P/U T-Bar and Install Test Valve; P/U Ladning Jt. and M/U to Hanger; Back Out Lock Down Screws 14:00 14:30 0.50 0 0 SURFA RPCOti SFTY P PJSM on Pulling Hanger, Heat Trace, and ESP Cables w/ Centrilift, Ra chem, GBR ?age & of 3I Time Lo s - -- - 8 ---- - - -- Dame From To Dur S De th_ E. De th Phase Code Subcode T_ COM _ _ _ 03/03/2008 14:30 14:45 0.25 5,471 5,445 SURFA RPCOh PULD P Pull Hanger t/ Floor. & Remove Penetrators; P/U 140k, S/O 112k. Remove penetrators through the han er. 14:45 15:15 0.50 5,445 5,445 SURFA RPCOti PULD P Lay down landing joint. Monitor well via the tri tank. 15:15 16:15 1.00 5,445 5,277 SURFA RPCOti PULD P Lay down Vetco offset hanger (2.01') w/ full jt of 4-1/2" NSCT (38.37) . 4-1/2" NSCT Pup jt (2.27') , 4-1/2" NSCT space out sub (1.1 T) Lay down the next 4 'ts Total of 5 full 'ts out. 16:15 17:30 1.25 5,277 5,277 SURFA RPCOb RURD P Rig up sheave for heat trace cable. Sheave f/ ESP. Install trunk on ESP sheave for environmental concerns while reelin in ESP cable. 17:30 19:30 2.00 5,277 4,350 INTRM1 RPCO TRIP P POOH w/ 4-1/2" 12.6 ppf L-80 NSCT tubing w/ heat trace and ESP cable and clamps/bands. Monitor well on the tri tank. Total of 35 'ts out of the hole. 19:30 19:45 0.25 4,350 4,350 INTRM1, RPCOh SFTY P BOP drill with post drill safety meetin . 19:45 00:00 4.25 4,350 3,108 INTRM1 RPCOh TRIP P Continue to POOH w/ 4-1/2" 12.6 ppf L-80 NSCT tubing w/ heat trace and ESP cable and clamps/bandso Monitor well on the trip tank. Total of 75 jts out of the hole @ midnight. Calculated fill 17 bbls, actual 24 bbls, 4 bbls over calculated/ 9.5 hour time eriod. 03/04/2008 00:00 06:00 6.00 3,108 815 INTRM1 RPCOti PULD P POOH w/4-1/2" 12.6 ppf L-80 NSCT tubing w/ heat trace and ESP cable and clamps/bands. Monitor well on the trip tank. Total of 149 jts out of the hole. Stra tubin in the shed. 06:00 07:45 1.75 815 168 INTRM1 RPCO PULD P POOH w/ 4-1/2" 12.6 ppf L-80 NSCT tubing w/ heat trace and ESP cable and clamps/bands. Monitor well on the trip tank. Total of 170 jts out of the hole. 07:45 08:00 0.25 168 149 INTRM1 RPCOti PULD P UD Camco KBG-2-LS GLM & Attached Pu Jts 08:00 08:45 0.75 149 0 INTRM1 RPCOti PULD P POOH w/ Slotted Nipple (Damaged), Seal Section, Gearbox, ESP Motor, & Centralizer 08:45 11:00 2.25 0 0 INTRM1 RPCOh RURD P R/D ESP Sheave, Heat Trace Sheave, UD ESP Assembly per Baker Centrilift Re 11:00 12:00 1.00 0 0 INTRM1 RPCOh PULD P UD Baker Tools, GBR Tools, and .Heat Trace S ool 12:00 12:30 0.50 0 0 INTRM1 WELCT OTHR P R/U to Test BOPE w/ 4" test Jt. Make u Vetco test lu , RIH & Flood Stack 12:30 13:00 0.50 0 0 INTRM1 WELC BOPE P Test Plug & Blind Rams to 250 / 3000 Good . 13:00 15:30 2.50 0 0 INTRM1 WELCT OTHR P Drain Stack & Change Lower Rams to 3 1 /2" X 6" and U er Rams to 2 7/8". P~ e ' of ~~ , I Time Logs --- _ - - ' Dur S. Depth E. Depth Phase Code _Suhcode T COM_ __ Da#e From To 03/04/2008 .15:30 _ 19:00 _ 3.50 0 0 INTRM1 WELC BOPE P Test BOPE; Chart test. AOGCC notified of test. Lower Rams w/ 4" DP 250 / 3000; Lower Rams w/ 5 1/2" Tubing 250 / 3000; Annular Preventer w/ 51/2" Tubing to 250 / 3000;. Upper Rams w/ 2 7/8" Tubing 250 / 3000; Annular Preventer w/ 2 7/8" tubing to 250 / 3000 All Passed . 19:00 19:30 0.50 0 0 INTRM1 WELL OTHR P Blow down choke manifold, kill line and choke line. Rig down testing e ui ment. 19:30 20:00 0.50 0 0 INTRM1 WELC OTHR P Pull test plug. Set Vetco Gray wear bushing (1.96' long, 10-3/4" OD x 7-13/16" I D 20:00 20:45 0.75 0 0 INTRM1 RPCOb RURD P Rig up to pickup and make up 2-7l8" 20:45 21:00 0.25 0 0 INTRM1 RPCOh SFTY P Pre job safety meeting prior to picking up 2-7/8" 6.4 ppf, L-80 Hydril 511 tubin stin erfor lu in 1D-141. 21:00 23:00 2.00 0 1,061 INTRM1 RPCO PULD P Pickup/Makeup to 800 ft Ibs 36 joints of tubing tail 2-7/8" 6.4 ppf, L-80, hydril 511. Drifted to 2". Lost 1.5 bbls while running in the hole w/ 2-7/8" dp. Note: ID 2.441 inch, capacity .00579 b f. 23:00 00:00 1.00 1,061 1,342 INTRM1 RPCOh PULD P Pickup/Makeup 4" DP (XT-39) 4" 14 ppf, S-135. Drifted to 2.34". Note: ID 2-9/16" inch, capacity .0105 b f. 03/05/2008 00:00 03:45 3.75 1,342 5,589 INTRM1 DRILL TRIP P RIH w/ 2 7/8"mule Shoe on 4" DP f/ 1342' - 5589' MD; Tagged Obstruction 5589 03:45 06:45 3.00 5,589 5,599 INTRM1 DRILL CIRC P CBU 210 GPM / 500 PSI @ 5589' MD and Attempt to Work Through Obstruction; Worked /Washed String Down to 5599' MD; P/U 140, S/O 103, 336 GPM / 1120 PSI 06:45 07:00 0,25 5,599 5,599 INTRMI DRILL CIRC P Pump 30 bbl 9.5 PPG 300 Vis Sweep w/Moderate Cuttings Increase (Mostly Sand 07:00 08:00 1.00 5,599. 5,608 INTRM1 DRILL TRIP P Contine to Work String Through Tight Spot f/ 5596' - 5608' MD; Worked Past Obstruction @ 5608 and Seemed Better; Circ'ed @ 420 GPM / 1380 PSI; Max Gas 4047 Units, Average Gas 150 Units Over Interval 08:00 08:15 0.25 5,608 5,608 INTRM1 DRILL CIRC P Pump 30 Bbl 9.5 PPG 300 Vis Sweep w/ Moderate Cuttings Increase (Mostly Sand - J- 1 ?ay~• H of 31 • Time Logs ___ __ _ _ _ Date From _ To Dur 5. De th E. D_e tp h Phase Code Subcode T COM._____ __ 03/05/2008 08:15 12:00 .3.75 5,608 5,713 INTRM1 DRILL CIRC P Wash-Down in First hole Section f/ 5608' - 5745' MD; 610 GPM / 3150 PSI; P/U 145, S/O 100; Back Washed 90' and Hole Sloughed In @ 5650' MD; Washed Back in f/ 5650' - 5713' MD and Bottomed Out; Max Gas 2590 Units; Average Gas 200 -400 Units Over Interval; Noticed Thumb Sized Cement Comin Over Shakers 12:00 12:30 0.50 5,713 . 5,605 INTRMI CEME OTHR P POOH f/ 5713' - 5605' MD; Work Pipe to Find Window; Past Window Area @ 5605' MD; 545 GPM / 2500 Psi 12:30 14:30 2.00 5,605 5,713 INTRM1 CEME OTHR P Wash Down in Second Hole Section f/ 5605' - 5650' MD; Very Rough Drag & Taking Weight; 545 GPM / 2500 Psi; POOH to 5605' MD & Work Pipe to Locate Window; Worked Window Area f/ 5592' - 5622' MD; Found Ledge and Fell Through Into First Hole Section @ 5605' MD; RIH t/ 5713' MD; Max Gas Observed 1277 Units; Average Gas 200 Units Over Interval; Note: A eared to be Back in Main Wellbore 14:30 15:00 0.50 5,713 5,663 INTRM1 CEME OTHR P Contiued to Wash Down f/ 5713' - 5723'; Back Washed t/ 5663' While Workin Pi e 15:00 15:30 0.50 5,663 5,663 INTRM1 CEME CIRC P Pumped 30 Bbl 9.8 PPPG 300 Vis Sweep, 20 Bbl 9.8 PPG Brine, Followed by 30 Bbl 9.8 PPG 300 Vis Sweep; Lost Retuns After Second Sweep Turned Corner; Hole Packed Off 15:30 17:00 1.50 5,663 -5,385 INTRM1 CEME OTHR P POOH f/ 5663' - 5385' MD; Couldn't Go Down Lost 15 -20 K String Weight Due to Packing Off; Worked Tight Hole and Re establish Circulation @ 42 GPM / 360 Psi; Stage Pumps up to 460 GPM 560 Psi 17:00 18:00 1.00 5,385 5,673 INTRM1 CEME OTHR P Wash Down in First Hole Section f/ 5385' - 5673' MD; 200 GPM / 500 Psi; Circulate Bottoms up after Every Stand; Max Gas Observed 1200 Units after Pum s Shut Off and Restarted a s Time Logs _ Date From To Dur 5. De th E. De th Pha_se_ Code Subcode T COM 03/05/2008 18:00 21:15 3.25 5,673 5,690 INTRM1 DRILL CIRC P Continue to work through obstructions, washing down f/ 5673' to 5690'. Stage pump rate up to 336 gpm w/ 850 psi, then 483 gpm w/ 1750 psi. Pump a 30 bbl sweep (300 vis/ 9.8 ppg) with no increase in cuttings. Pumped another sweep @ 5690' with no increase in cuttings. PU wt 145k, SO wt 105k. Note: AOGCC inspector John Crisp was notified that we are only able to get to 5690' and will cement a balanced plug (11 ppg cement) w/ top of cement planned to be 5381' (150' above top of 7-5/8" x 7" x-o) with pipe out of the hole. 21:15 22:15 1.00 5,690 5,690 INTRM1 CEME OTHR P Lay down (2) joints of 4"drill pipe Qt# 149 and #150).. Blow down top drive. Ri u head in and 2" cementin line. 22:15 23:00 0.75 5,690 5,690 INTRM1 CEME OTHR P Circulate @ 336 bpm w/ 920 psi. Staged pumps up to 400 gpm w/ 1220 psi. Held pre job safety meeting w/ Dowell and ASRC truck drivers and d~illin crew foi- cement 'ob. 23:00 23:45 0.75 5,690 5,690 INTRM1 CEME PLUG P Switch over to Dowell: Dowell mix and pump 5 bbls of MudPush II (10 ppg), test lines to 3000 psi, follow with 14 more bbls of MudPush II @ 10 ppg (Total of 19 bbls), mix and pump 13 bbls (22 sx) of arctic set LiteCRETE 11 ppg (3.35 cu ft/sx yield) (11.374 gal/sx mix water}, follow with another 3 bbls of MudPush II 10 23:45. 00:00 0.25 5,690 5,690 INTRM1 CEME DISP P Rig displace cement to balance with top of cement @ 5376' with pipe in the hole (5381' with pipe out of the hole). Displace, pumping 4 bpm w/ 410 psi for 35 bbls pumped, then slowed to 2.5 bpm w/ 240 psi until 45 bbls were pumped (Cut short 5 bbls of calculated 50 bbls.). Shut down, cement is balanced. CIP 0005 hrs 3/6/2008. 03/06/2008 00:00 00:15 0.25 5,690 5,654 INTRM1 CEME OTHR P Break off a single of 4"drill pipe and put in the mouse hole. Change elevators to 4". 00:15 01:15 1.00 5,654 4,900 INTRM1 CEME TRIP P Pull out of the hole 8 stands of 4"drill i e. PU wt 120k, SO wt 100k. 01:15 02:00 0.75 4,900 4,900 INTRM1 CEME CIRC P Circulate 800 gpm w/ 3460 psi to clean drill pipe. No cement noticed at the shakers. Maydbe some mud push. Circulated 738 bbls. 02:00 02:15 0.25 4,900 4,900 INTRM1 CEME CIRC P Obtain slow pump rates with both um s. Monitor well- static. 02:15 02:30 0.25 4,900 4,811 INTRM1 -CEME TRIP P Pull one stand of4"drill pipe 02:30 02:45 0.25 4,811 4,811 INTRM1 RIGMN SFTY P Pre job safety meeting on slip and cut drillin line. P3~e iD of 31 Time Logs ur 5 Depth. E. De th Phase Code Suhcode T_ COM .. __ _ From To D DatE __ 03/06/2008 02:45 04:30 _ 1.75 4,811 4,81.1 INTRM1 RIGMN SVRG P Slip and cut 112' of 1-3/8"drilling line. 04:30 05:00. 0.50 4,811 4,811 INTRM1 RIGMN SVRG P Service Rig 05:00 06:45 1.75 4,811 4,811 INTRM1 RIGMN SVRG P Change 4" XT-39 saver sub on the top drive. 06:45 07:00 0.25 4,811 4,811 INTRM1 CEME CIRC P Circulate bottom's up prior to pulling out of the hole. Pumping 800 gpm w/ 3500 si. 07:00 07:15 0.25 4,811 4,811 INTRM1 CEME OTHR P Monitor well, static. 07:15 07:30 0,25 4,811 4,811 INTRM1 CEME OTHR P Install stripper rubbers and air slips. Blow down the to drive. 07:30 11:00 3.50 4,811 0 INTRM1 CEME TRIP P POOH w/ 4" Dp & 2 7/8" Tubing f/ 4811' - 0.0' MD; Found last 2 Jts & Bent Mule Shoe Jt still in hole due to broken threads (88.31' of 2 7/8" 6.5 PPF Hydril 511 tubing Left in Hole) last jt out of hole was also bent with a dent T u from Pin. 11:00 11:30 0.50 0 0 INTRM1 CEMEP OTHR P Clean and Clear Rig Floor; UD GBR Tubing Running Tools. Change elevators. 11:30 13:00 1.50 0 286 INTRM1 RPCO PULD P PU BHA to tag cement and clean out to 5521'. 13:00 16:00 3.00 286 2,632 INTRM1 RPCOti PULD P Pickup/makeup 4"drill pipe and single in the hole. Rabbit to 2-1/2" Picked up 75 'ts from the i e shed. 16:00 16:15 0.25 2,632 2,632 INTRM1 RPCO CIRC P Attempt to circulate bottom's up. Pumping 600 gpm w/ 2600 psi. Observed high pump pressre after um in 240 strokes. 16:15 16:45 0.50 2,632 2,632 INTRM1 RPCO OTHR T Trouble shooting high pump pressure issue. Blow down the top drive and mud um .Line is clear. 16:45 17:30 0.75 2,632 2,632 INTRM1 RPCO CIRC T Rig up to reverse circulate. Attempt to reverse circulate by pumping through the kill line w/ annular preventer closed. Trapped pressure was observed a ain. 17:30 20:30 3.00 -2,632 0 INTRM1 RPCOh TRIP T Drop a hollow 1.9" OD rabbit with 110' of wire tail. Pull. out of the hole wet. Retrieve hollow rabbit when at the top of flex drill collars. Found a plastic rabbit at the non-mag bit sub. Top side of plastic rabbit was 2.3" OD and bottom of rabbit was 2.04". Pictures osted to the "X" drive. 20:30 21:00 0.50 0 0 INTRM1 RPGOh OTHR T Remove the 2.3" x 2.04" rabbit from the bit sub. 21:00 23:00 2.00 0 2,632 INTRM1 RPCO TRIP T Make up BHA #1, run in the hole w/ 25 stands of 4"drill pipe from the derrick. 23:00 23:15 0.25 2,632 2,632 INTRM1 RPCO CIRC P Make a top drive connection. Circulate 800 m w/ 2640 si. Fagg: j1 i:F ~1 i Time Logs Date From To__ Dur S Depth E. De th Pha Code _Subcode T ~QM _ ____ _ 03/06/2008 23:15 00:00 0.75 2,632 3,290 INTRM1 RPC014 PULD P Pickuplmakeup 4" drill pipe and single in the hole. Rabbit to 2.34". Picked up 21 jts from the pipe shed (Total of 32 stands in the hole). 03/07/2008 00:00 02:00 2.00 3,290 4,792 tNTRM1 RPCOA~ TRIP P Con't to Single in f/ 3290' - 4792' MD; Monitor Dis lacement on Tri Tank 02:00 02:30 0.50 4,792 4,792 INTRM1 RPCO CIRC P CBU @ 765 GPM / 3550 Psi; Max Gas 4 Units 02:30 04:00 1.50 4,792 5,359 INTRM1 RPCO TRIP P_ Con't to Single in f/ 4792' - 5359' MD; P/U 140, S/O 105 04:00 04:15 0.25 5,359 5,359 INTRM1 RPCOh CIRC P __ Circulate BU @ 5359'. Mud push circulated out of hole, no apparent cement 04:15 04:30 0.25 5,359 5,450 INTRM1 RPCO OTHR P Wash Down f/ 5359' - 5450' MD; 170 GPM /450 Psi. Mud push circulated out of hole, no a arent cement. 04:30 05:15 0.75 5,450 5,450 INTRM1 DRILL CIRC P Circulate @ 750 GPM / 3450 Psi. Mud push circulated out of hole, no a arent cement. 05:15 05:30 0.25 5,450 5,530 INTRM1 DRILL OTHR P Washed Down f/ 5450 - 5530' MD; Tagged XO on Depth. Mud push circulated out of hole, no apparent cement. 05:30 06:30 1.00 5,530 . 5,530 INTRM1 DRILL. CIRC P Circ & Cond Mud Mud; 650 GPM / 2980 Psi. While pumping PU wt 140k, SO wt 100k. 06:30 07:30 1.00 5,530 5,530 INTRM1 DRILL RURD P Blow Down Top Drive; R/U to Test Casin 07:30 07:45 0.25 5,530 5,530 INTRMI DRILL OTHR P Test 7 5/8" Casing; Start @ 1/2 bbl/min Pressure Broke Over @ 560 Psi; Shut In @ 3.8 bbls Pumped w/ 420 Psi; 420 Psi Held f/ 10 Minutes 07:45 08:30 0.75 5,530 5,530 INTRM1 DRILL CIRC P Establish Injection Rate f/ 7 5/8" Casing; 1 Bpm Pressure Peaked @ 740 Psi; 1 1/2 Bpm Pressure Peaked @ 780 Psi Then Broke Over and Maintined 750 Psi; Bled 5 Bbl Back to Trip Tank. Pumped a total of 23 bbls to the formation. 08:30 08:45 0.25 5,530. 5,530 INTRMI DRILL OTHR P . Blow Down Test Equipment and Kill Line 08:45 09:00 0.25 5,530 5,530 INTRM1 DRILL OWFF P OWFF (Static) 09:00 10:00 1.00 5,530 5,530 INTRM1 DRILL CIRC P CBU X 3.5; 730 GPM / 3550 Psi; Hea Cuttin s Increase on First BU 10:00 10:15 0.25 5,530 5,530 INTRM1 DRILL OWFF P OWFF (Static) 10:15 13:1.5 ..3.00 5,530 285 INTRM1 DRILL TRIP P . POOH f/ 5530 - 285' MD; P/U 148, S/O 110, Rot 128 13:15 14:15 1.00 285 0 INTRM1 DRILL .PULD P L/D BHA#1, Mill?Scraper 14:15 14:45 0.50 0 0 INTRM1 DRILL OTHR P Clean & clear Rig Floor 14:45 15:00 0:25 0 0 INTRM1 DRILL PULD P P/U BHA #2; Retainer Pa {k, 12c:i31 i Time Logs Date _ From To Dur__ S De th E. Depth Phase Code Subcode _ T COM_ _ _ 03/07/2008 15:00 18:00 3.00 0 4,042 INTRM1 DRILL TRIP P RIH f/ 0 - 4042' MD; String Speed 70 FPM f/ 0 - 3996 MD, then 60 PFM t/ 4042' MD; P/U 140, S/O 100, 18:00 23:00 5.00 4,042 5,530. INTRM1 RPCOh TRIP P Continue to rum Baker K-1 retainer (Comm No. H400-21-4322) from 4042' to 4800' with running speed ` 60'/minutes, then contiue running from 4800' to 5530' @ 10'/minutes. Wash down as needed, pumping 2 bpm w/ 170 psi. Tagged. up on depth on 7-5/8" x 7" crossover 5530'. 23:00 23:45 0.75 5,530 5,522 INTRM1 RPCOh TRIP P Pickup and set retainer with bottom @ 5522.37'. PU wt 150k, SO wt 103k. Picku and re veri de th. 23:45 00:00 0.25 5,522 5,517: INTRM1 RPCO CIRC P Circulate bottom's up priorto testing casing. Mud wt 9.8 ppg. Pumping 420 m w/ 1300 si. 03/08/2008 00:00 00:45 0.75 5,517 5,517 INTRMI RPCO £IRC P Stand back stand # 59. Lay down 15' pup, makeup hQadpin on (15') 4"pup joint. Makeup stand #59, run in the hole, break off top single of 4", makeup the 15' pup jt w/ 2" 1502 female threads on head in. 00:45 01:30 0.75. 5,517 5,517 INTRM1 CASINC RURD P Rig up to test the 7-5/8" 29.7 ppf L-80 BTC-M casin . 01:30 03:15 1.75 5,517 5,517 INTRM1 CASIN DHEQ P Test casing to 3000 psi. Chart test. Hold test for 30 minutes, good test, lost 40 psi in 30 minutes..Pumped a total of 3 bbls with 3 bbls bleed back. Tested w/ 9.8 ppg brine. Bottom of retainer @ 5522' ,top @ 5520' (3600' TVD . 03:15. 04:15 1.00 5,517 5,517 INTRM1 CASIN DHEQ P Slack off, set 14k on the BakerK-1 retainer (Comm No. H400-21-4322) @ 5520.37 (TVD 3600') .Perform infectivity test below retainer with top side open to atmosphere. Pumped @ 1 bpm w/ 770 psi, 1-1/2 bpm w/ 800 psi, 2 bpm w/ 820 psi. Shut down after pumping 65 bbls. Pressure bleed off#o 625 psi static. Bleed off the rest of the pressure, then pull out of retainer. PU wt 152K, SO wt 104k. 04:15 04:45 0.50 5,517 5,517. 1NTRM1 CEME~ DTHR P Adjust pressure on the annular to be able to strip through with 500 psi on the 7-5/8" casing x 4"drill pipe. Regulator on rig floor reading 750 psi and gauge at the accumulator was reading 525 psi. Was able to slack off and set 14k on the retainer. With the annular shut:. PU wt 160k, SO wt 93k. 04:45 05:00 -0.25 5,517 5,517 INTRM1 CASINf DHEQ P Perform a 5 minute test to 2000 psi on the 7-5/8" x 4" annulus after pulling out of retainer. OK. P~gc 1~ ef:;t Time Logs_ __ Da e From To Dur S- D~th E. Depth_Phase Code_ Subcode_ T COM _ ___ 03/08/2008 05:00 06:00 1.00 5,517 5,517 INTRM1 CEME CIRC P Displace 9.5 ppgbrine in the hole to 8.4 ppg seawater. Pumping 7 bpm w/ 750 psi initial, 550 psi final circulating ressure. 06:00' 06:30. 0.50 5,517 5,517 INTRM1 CEME OTHR P Monitor well (Static) 06:30 07:30 1.00 5,517 5,517 INTRM1 RIGMN SVRG P Rig Service 07:30 08:00 0.50 5,517 5,517 INTRM1 CEME CIRC P Circ @ 615 GPM / 2510 Psi for 2X BU 08:00 09:00 1.00 5,517 5,517 INTRM1 CEME RURD P B/D Top Drive & Cement Lines; R/U Doyon Lines t/ P/A B & D Lateral w/ 15.8 PPG Cement 09:00 10:00 1.00 5,517 5,517 INTRM1 CEME OTHR P Obtain Injection Rate of 2 BPm w/ 900 Psi Below Retainer; Adjust Annular Preventer Pressure to Allow for DP Movement "Stripping" for Circulating Cement Prior to Stinging Into Retainer; Perform Test Run P/U 155, S/O 92 10:00 10:30 0.50 5,517 5,517 INTRM1 CEME WOEQ T Wait on Dowell/Schlumberger to Arrive f/ Deahorse; Problem w/ Cement Test Caused Delay Unitl Proper Recipie & Successful Test 10:30 11:30 1.00 5,517 5,517 INTRM1 CEME RURD P R/U Dowell/Schlumberger and Trucks for Cementin Well Laterals. 11:30 12:00 0.50 5,517 5,517 INTRM1 CEME SFTY P PJSM on Cementing Well w/ Dowell, PEAK, ASRC, Doyon Crew, & CPAI Re s 12:00 12:15 0.25 5,517 5,517 INTRM1 CEME CIRC P Dowell Pressure Test Cement Lines t/ 3000 PSI; Then Pump 15 Bbl Fresh Water Ahead of Cement Taking Returns Through Choke Line holding 200 to 350 psi back pressure on annulus. 12:15 12:30 0.25 5,517 5,517 INTRM1 CEME CIRC P Follow Water Spacer Down Drill String w/ 43 Bbl of Class G Cement; Maintain 200 - 330 Psi Back Pressure w/ Choke; Stop Pumps and Re-enter Retainer, Pressure annulus to 500 si. 12:30 14:00 1.50 5,517 5,517 INTRM1 CEME CIRC P Pumped 148 Bbl of 15.8. Ppg Cement @ 2 BPM w/ 500 Psi Max; Then 1 1/2 BPM w/ 330 Psi Max, Then 1 Bpm w/ 260 Psi Max; Called Well Engineer and Decided to Displace w/ Water and WOC to Thicken. 14:00 15:00 1.00 5,517 5,517 INTRM1 CEME DISP P Started Displacing Drill String Volume (58 Bbl) w/ Fresh Water; @ 28 Bbls Displaced Pressure Increased f/ Original Injection of 2 BPM / 1000 Psi to 1/2 BPM 11175 Psi;. Total Cement Volume Pumped 191.6 Bbls - 927 Sacks, After shut down well held 1150 psi and then dropped to 1000 psi after 5 min. (Note; Total calculated volume below Retainer for both laterals and main bore = 177.8 bbls), AOGCC John Cris waived witness of s ueeze 'ob. Pagt, 1d cf ~1~ Time Lois _ S. De th E. Depth Phase_ Code Subcode T COM __ Dae From To Dur 03/08/2008 15:00 16:30 _ 1.50 5,517 5,517 INTRM1 DRILL CIRC P Pull out of Retainer w/ 1000 psi on drill pipe, Reversed 2X String Volumes, pumping 11 bpm w/ 1930 psi, w/ Trace Cement Returns then Circulate Bottoms Up X3 the long way, pumping 10.5 bpm w/ 1370 psi - no cement observed on btm's while circ the long wa /Blow Down Choke & Kill Lines. 16:30 16:45 0.25 5,517 5,517 INTRM1 DRILL SFTY P Pre job safety meeting on displacing well from 8.4 ppg to 9.5 ppg Mineral Oil Base Mud. 16:45 17:15 0.50 5,517 5,517 INTRM1 DRILL CIRC P Displace Well Fluid f/ 8.4 PPG Sea Water to 9.5 PPG OBM. Pumping 10.5 bpm w/ initial circulating pressure of 1520 psi and final circulating pressure of 2460 psi. Record slow um rates. 17:15 18:00 0.75 5,517 5,517 INTRM1 DRILL RURD P Rig down cementing equipment. Blow down lines. monitorwell static. 18:00 21:00 3.00 5,517 0 INTRM1 DRILL TRIP P Pull out of the hole with Baker Model K-1 Running tool. Lay down running tool. Monitor well on the trip tank. Pro er dis lacmenet. 21:00 21:30 0.50 0 0 INTRM1 DRILL OTHR P Move a stand of 4" heavy weight drill pipe and a stand of heavy weight drill pipe with the jars to the off driller's side of the derrick. 21:30 21:45 0.25 0 0 INTRM1 MOVE OTHR P Clear rig floor. 21:45 22:00 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up/making up 15 stands of hybrids (2 jts of 5'° DC + (1) 4" HWDP on top) for weight @ the to of the hole Push i e . 22:00 00:00 2.00 0 0 INTRM1 DRILL PULD P Pickup/makeup/standback in the derrick 15 stands of hybrid's (2 jts of 5" DC + (1) 4" HWDP on top). Drifted to 2". 03/09/2008 00:00 00:30 0.50 0 0 PROD1 STK PULD P Bring Baker Whipstock Assy to Rig Floor 00:30 00:45 0.25 0 0 PROD1 STK OTHR P PJSM for M/U BHA #3 w/ Baker Fishin Re & Ri Crew 00:45 01:30 0.75 0 69 PROD1 STK PULD P M/U Mills & Whipstock Assy per Baker Re 01:30 02:00 0.50 69 69 PROD1 STK OTHR P Orient Whipstock to MWD Toolface 02:00 03:00 1.00 69 69 PROD1 STK OTHR P Daylight Savings Time Adjust Clocks Forward 1 Hour 03:00 03:30 0.50 69 69 PROD1 STK OTHR P Orient Whipstock to MWD Toolface 03:30 04:45 1.25 69 206 PROD1 STK PULD P P/U Remainder of BHA #3 04:45 06:00 1.25 206 206 PROD1 STK OTHR P Up load & Test MWD Equipment 06:00 07:00 1.00 206 300 PROD1 STK OTHR P P/U 1st Stand & Shallow Test MWD Pum in 270 m. 07:00 11:00 4.00 300 5,256 PROD1 STK WPST P P/U & RIH w/ Whipstock (BHA #3) f/ 300' - 5256' MD; 71 SPM 3030 Psi r~1y~'. S~ of ~i ~ Time Lags` _ Date From To Dur S. th E. De ttr Phase C e Subcade T COM 03/09/2008 11:00 11:30 0.50 .5,256 5,302 PROD1 STK OTHR _ P Mad Pass to Confirm Top of Ugnuf/ 5256' - 5302' MD (Gamma Ray depth 5179' to 5225') Pumping 300 gpm w/ 3070 si. Lo seed 100'/hr 11:30 12:30 1.00 5,302 5,520 PROD1 STK WPST P RIH f/ 5302' - 5520' MD; Tagged Retainer @ 5520' MD; Set Whipstock @ 5520' MD w/ 22L Tool Face; and Sheared Mill w/ 45K Down; 71 SPM @ 2990 Psi; P!U 168, Rot 158, S/O 140; To of Whi stock 5502' MD 12:30 12:45 0.25 5,520 5,256 PROD1 WELCT OTHR P POOH w/ 3 Stds f/ 5520' - 5256' MD & P/U Retrievamatic Storm Packer 12:45 13:45 1.00 5,256 5,320 PROD1 WELCT OTHR P M/U Storm Packer and RIH f/ 5256' - 5320'; Packer Came Unscrewed @ 3 1/2 X 2 7/8 Mandrel and Equalizing valve Came Out of Hole; Top of Packer Set 79' MD; Baker Hand Called BOT Deadhorse for Guidance 13:45 14:45 1.00 79 0 PROD1 WELCT OTHR T P/U Equalizing Valve and Attempt to Screw On to Packer; Attempt Successful; Sheared Twin Thread Safe Joint as Planned; 14:45 15:00 0.25 0 0 PROD1 WELCT OTHR P Blow Down Top Drive and Mud Lines / Pressure Test Packer U 500 Psi f/ 5 Minutes Good) 15:00 16:00 1.00 0 0 PROD1 WELCT OTHR P Blow down kill line and choke line. Drain stack, rig down elevators, Pick up slings for secondary lines to secure stack- alon with the brid a crane. 16:00 19:30 3.50 0 0 PROD1 WELCT NUND P Remove flow line, bell nipple, and drip pan. Remove choke hose. Remove bolts to wellhead and set stack back towards pipe shed. Remove the rig's annulus valve from wellhead. Remove Vetco/Gray wellhead from the 7-5/8" casin han er. 19:30 21:00 1.50 0 0 INTRM1 WELC NUND P Install new Vetco/Gray wellhead with new graylock seal sub. Energize the lockdown screws to 300 ft lbs. Note: Wellhead Orientation Witnessed by DS-1 D DSO Greg Whitehead -Would like all Wellhead valves rotated 180 de s. Will be rformed ost ri . 21:00 21:45 0.75 0 0 PROD1 WELCT ROPE P Test void to 250 psi and 1000 psi for 10 minutes each. Good Test. Witness test with Vetco Gray and Conoco Philli s re resentative. 21:45 00:00 2.25 0 0 PROD1 WELC NUND P Nipple up BOP stack. Rig down secondary slings for securing stack during change out of wellhead. Attatch choke line, bell ni le and flow line. 03/10/2008 00:00 01:00 1.00 0 0 PROD1 WELC NUND P Cont'd N!U BOP 01:00 02:30 1.50 0 0 PRODi VvELC OTHR P R/U f/ BOPE Test Page i6 of 31 Time Logs Date From To Dur 5. De th E: De th Phase Code Subcade l' COM , 03/10/2008 02:30 11:00 8.50 0 0 PROD1 WELCT ROPE P Test BOPE. Witness of test waived by AOGCC inspector John Crisp. Test 250 low and 3000 Psi high. Hold each test 5 minutes. Chart tests. Tested all valves in the choke manifold, all kill line valves and choke line valves. Test floor safety valve an IBOP. Test top drive upper and lower IBOP. Tested annular with 5-1/2" test joint. Tested lower pipe rams (3-1/2" x 6" variables) with 5-1/2", 5", 4-1/2", and 4". Tested blind rams. Tested Gas and H2S alarms. All tests assed. 11:00 11:30 0.50 0 0 PROD1 RIGMN SVRG P Service Rig; Replace Broken Koomey Line 11:30 13:15 1.75 0 0 PROD1 WELCT BOPE P Test accumulator: 200 Psi Increase in 35 seconds, and Full Chargein 2 minutes and 56 seconds.; Test Annular Preventer and Upper 2 7/8" Pipe Rams w/ 2 7/8" Test Jt. to 250 si low and 3000 Psi hi h. 13:15 14:15 1.00 0 0 PROD1 WELC OTHR P Rig Down BOPE Testing Equipment; R/U to Retrieve Storm Packer 14:15 16:15 2.00 79 0 PROD1 WELCT TRIP P M/U and Rlh w/ Overshot to Retrieve "Retrievamatic" Storm Packer; Packer Retrieved 16:15 16:45 0.50 0 5,349 PROD1 WELCT OTHR P Lay down BOT Tools (Retrievamatic) . 16:45 17:30 0.75 5,349 5,502 PROD1 STK TRIP P RIH f/ 5349' - 5502' MD; Tagged Whi stock 5502 17:30 23:30 6.00 5,502 5,536 PROD1 STK WPST P Mill Window in 7 5/8" Casing. PU wt 173k, SO wt 142k, Rot wt 158k. Pumping 300 gpm w/ 3070 psi. Whipstock set @ 22 Degrees Left. Mill from TOW @ 5502' to Bottom of window @ 5515.61', then to 5521' with upper mill (6-3/4") at the bottom of window, then full guage hole to 5536.6' (3613.4' TVD). Pump a high vis sweep (9.5 ppg/ 300 vis) while milling @ 5510': Slight increase in metal cuttings. Pump a high vis sweep (9.5 ppg/ 300 vis) while milling @ 5516'. Slight increase in metal cuttin s. 23:30 00:00 0.50 5,536 5,536 PROD1 STK WPST P Work through window. Pumping 305 gpm w/ 2970 psi. Rotating 120 rpm w/ 5-6k ft Ibs of torque. PU wt 170k, SO wt 142k. Note: Had 10k overpull at 5509'. Worked until no roblem. 03/11/2008 00:00 00:15 0.25 5,536 5,536 PROD1 STK WPST P Continue working mills thru window ( pumping 305 gpm, 3020 psi. PU wt 170k, So wt 142k. 00:15 01:15 1.00 5,536 5,536 PROD1 STK CIRC P Pump 35 bbl 9.5 ppg 300 vis sweep @ 321 m, 3530 si lus 3 bottoms u . Page '17 of 31 ~ M ~~ C J Time Logs _ __ Date From To Dur 5 De th E. De th Phase Code Subcode T COM 03/11/2008 01:15 02:00 0.75 5,536 5,470 PROD1 STK TRIP P Pull up into casing for formation integrity test. Blow down top drive and ri u for FIT test. 02:00 02:30 0.50 5,470 5,470 PROD1 STK OTHR P Perform FIT test to 12.2 ppg EMW. 02:30 02:45 0.25 5,470 5,470 PROD1 STK OWFF P Monitor well -static 02:45 04:00 1.25 5,470 4,884 PROD1 STK TRIP P Pump dry job and trip out of hole. Monitoring well via trip tank and recordin wei hts eve 10 stands. 04:00 05:15 1.25 4,884 4,884 PROD1 STK TRIP T Replace two hoses on iron roughneck. Circulating over the top of the hole and monitoring via trip tank. Lost 1/2 bbl durin re airs 05:15 07:30 2.25 4,884 220 PROD1 STK TRIP P Trip out of hole to BHA 07:30 08:30 1.00 220 120 PROD1 STK PULD P Lay down BHA -milling assembly 08:30 08:45 0.25 120 120 PROD1 STK PULD P Down load MWD 08:45 09:15 0.50 120 0 PROD1 STK PULD P Continue laying down BHA 09:15 10:00 0.75 0 0 PROD1 STK PULD P Clear rig floor of milling tools. PU tools for drillin BHA 10:00 10:45 0.75 0 0 PROD1 STK CIRC P Flush stack, kill and choke lines. Blow down to drive and lines 10:45 12:00 1.25 0 100 PROD1 DRILL PULD P Pick up and make up BHA #3 12:00 12:45 0.75 100 100 PROD1 DRILL PULD P Orient motor and load dowload to MWD. 12:45 13:30 0.75 370 370 PROD1 DRILL PULD P Finish making up BHA #3 13:30 13:45 0.25 370 550 PROD1 DRILL TRIP P Trip in hole. Stop for shallow pulse test. Pumped 280 gpm @ 2500 psi - tested ood. 13:45 15:45 2.00 550 5,490 PROD1 DRILL TRIP P Trip in hole. Rotated string while BHA passed port collar, did not see any obstructions. Hole took proper dis lacement durin tri . 15:45 16:45 1.00 5,490 5,536 PROD1 DRILL TRIP P Obtain drilling parameters, clean hole ECD 10.7 ppg. Orient toolface and slack off thru window, no obstructions. Ta bottom on de th. 16:45 18:00 1.25 5,536 5,610 PROD1 DRILL DDRL P Drilling D sand lateral. 18:00 00:00 6.00 5,610 5,780 PROD1 DRILL DDRL P Drilling D sand lateral. 03/12/2008 00:00 01:00 1.00 5,780 5,814 PROD1 DRILL DDRL P Drilling D sand lateral. W06=14-15, RPM=40, Flow rate=304, Stand pipe pressure=3810, PU wt=140, SO wt=120, On bottom torque=4-5, Off bottom torque=5-6, ECDs=10.54, Total as= 01:00 03:15 2.25 5,814 5,814 PROD1 DRILL DDRL T Top drive not working, troubleshoot. Topdive control house too cold. Warmed up room and reset com uters. F'~ge 1 ~ of 31 i J Time Logs _ Date From To Dur S De th E. Depth Phase Code Subcode T COM 03/12/2008 03:15 06:00 2.75 5,814 5,865 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=8-10, RPM=50, Flow rate=304, Stand pipe pressure=3710, PU wt=150, SO wt=110, On bottom torque=5-6, Off bottom torque=5-6, ECDs=10.54, Total as= 06:00 12:00 6.00 5,865 6,182 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=6-10, RPM=80, Flow rate=300, Stand pipe pressure=3800, PU wt=150, SO wt=112, On bottom torque=6, Off bottom torque=5, ECDs=10.73, Total as= 12:00 18:00 6.00 6,182 6,538 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=6-10, RPM=90, Flow rate=290, Stand pipe pressure=3300, PU wt=, SO wt=, On bottom torque=6, Off bottom torque=5, ECDs=, Total as=120 18:00 20:30 2.50 6,538 6,680 PROD1 DRILL DDRL P Drilling D sand lateral. Drilled out the top of the zone. Pull back for sidetrack. WOB=8-10, RPM=80, Flow rate=319, Stand pipe pressure=3890, PU wt=150, SO wt=105, On bottom torque=6, Off bottom torque=6, ECDs=10.54, Total as=65 20:30 21:00 0.50 6,680 6,474 PROD1 DRILL TRIP T Drilled out of zone. POOH for open hole sidetrack. 21:00 22:00 1.00 6,474 6,500 PROD1 DRILL DDRL T Trough for sidetrack pumping 308 gpm @ 3540 psi. Well took 25 bbls fluid while troughing, mud weight 9.3 ppg. Reduce flow rate to 305 gpm and begin reducing mud weight in .1 ppg increments. 22:00 00:00 2.00 6,500 6,659 PROD1 DRILL DDRL T Drilling D sand lateral. Mud weight 9.1 ppg. Well still taking small amount of fluid when pumps start and giving fluid back when pumps are off. Continue reducing mud weight to 9.0 ppg. WOB=O-4, RPM=O, Flow rate=285, Stand pipe pressure=3230, PU wt=152, SO wt=110, On bottom torque=5-6, Off bottom torque=6, ECDs=10.31, Total as=98 03/13/2008 00:00 06:00 6.00 6,659 6,759 PROD1 DRILL DDRL P Drilling D sand lateral. Mud weight 9.0 ppg. No losses or gains. WOB=2-10, RPM=80, Flow rate=288, Stand pipe pressure=3050, PU wt=150, SO wt=110, On bottom torque=6-7, Off bottom torque=6, ECDs=10.22, Total as=159 06:00 12:00 6.00 6,759 6,891 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=6-10, RPM=80, Flow rate=300, Stand pipe pressure=3460, PU wt=150, SO wt=110, On bottom torque=, Off bottom torque=6, ECDs=10.00, Total as= Pa~}e 19 of 31 _ Time Lois __ D e From To Dur S De th E. De th Phase Code Subcode T COM 03/13/2008 12:00 14:15 2.25 6,891 7,033 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=6-10, RPM=80, Flow rate=300, Stand pipe pressure=3460, PU wt=150, SO wt=110, On bottom torque=6-7, Off bottom torque=6, ECDs=10.10, Total as=235 14:15 15:15 1.00 7,033 7,033 PROD1 DRILL CIRC T Having trouble getting the assembly to turn and drop to avoid close approach with 1 D-32. Circulate while discussing options. Decision made to pull back and sidetrack. 15:15 15:30 0.25 7,033 7,033 PROD1 DRILL OWFF T Monitor well -static 15:30 16:45 1.25 7,033 6,087 PROD1 DRILL TRIP T Pull up to new sidetrack location 16:45 18:00 1.25 6,087 6,100 PROD1 DRILL DDRL T Trough for sidetrack (140 right), um in 310 m 3410 si. 18:00 20:30 2.50 6,100 6,125 PROD1 DRILL DDRL T Continue troughing for sidetrack, pumping 305 gpm @3020 psi. Kicked off at 6125' M D 20:30 00:00 3.50 6,125 6,225 PROD1 DRILL DDRL T Drilling D sand lateral. WOB=4-12, RPM=O, Flow rate=290, Stand pipe pressure=2900, PU wt=140, SO wt=110, On bottom torque=0, Off bottom torque=6, ECDs=9.70, Total as=178 03/14/2008 00:00 00:45 0.75 6,225 6,228 PROD1 DRILL DDRL T Drilling D sand lateral. BHA not steering as expected. It is building angle when pointed down. Prepare to TOOH for BHA. WOB=4-12, RPM=O, Flow rate=290, Stand pipe pressure=2900, PU wt=140, SO wt=110, On bottom torque=0, Off bottom torque=6, ECDs=9.96, Total as=55 00:45 01:00 0.25 6,228 6,228 PROD1 DRILL OWFF T Monitor well -static 01:00 02:15 1.25 6,228 5;500 PROD1 DRILL TRIP T Pump out of hole to shoe. Pump at 320 gpm, 2975 psi. PU wt 140k, SO wt 110k. Monitoring well via active s stem. 02:15 02:45 0.50 5,500 5,100 PROD1 DRILL TRIP T Pull out of hole on elevators, monitorin well via tri tank. 02:45 03:15 0.50 5,100 5,100 PROD1 DRILL CIRC T Pump 20 bbl 11.1 ppg dry job, blow down to drive. 03:15 06:00 2.75 5,100 365 PROD1 DRILL TRIP T Pull out of hole on elevators to BHA, monitorin well via tri tank. 06:00 06:15 0.25 365 365 PROD1 DRILL OWFF T Monitor well -static 06:15 06:45 0.50 365 0 PROD1 DRILL TRIP T Pull out of hole w/BHA #3. Stand back HWDP, ~ars and flex collars 06:45 07:00 0.25 0 0 PROD1 DRILL PULD T Check orientation of motor. Found it to be off by 64 degrees to the left from what was run in hole. 07:00 07:45 0.75 0 0 PROD1 DRILL PULD T Download MWD P~~~ ~T3 of 31 r~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/14/2008 07:45 08:15 0.50 0 0 PROD1 DRILL PULD T Change out pulser 08:15 09:30 1.25 0 0 PROD1 DRILL PULD T Continue to lay down BHA. Checking torque on connections before breaking. No loose connections found. MWD connection (above directional tools) was found to be 4000# over original torque and the protector collar on the motor had backed off. One jet was lu ed. 09:30 10:00 0.50 0 0 PROD1 DRILL PULD T Clear and clean rig floor. 10:00 11:45 1.75 0 0 PROD1 DRILL PULD T Make up BHA #4. Rerun bit, new motor w/kick pad and new mwd. Orient MWD with motor (offset 223.10 . 11:45 12:15 0.50 0 0 PROD1 DRILL PULD T Upload MWD. 12:15 12:45 0.50 0 369 PROD1 DRILL RURD T Continue to make up BHA per directional driller. 12:45 13:00 0.25 369 542 PROD1 DRILL TRIP T Trip in hole 13:00 13:15 0.25 542 542 PROD1 DRILL DHEO T Shallow pulse test MWD pumping 300 m, 1640 si -test ood 13:15 15:45 2.50 542 5,439 PROD1 DRILL TRIP T Tripping in hole. rotated slowly while passing port collar. Hole took proper displacement during trip. Blow down to drive. 15:45 17:15 1.50 5,439 5,439 PROD1 RIGMN SVRG T Slip and cut drilling line 17:15 18:15 1.00 5,439 5,439 PROD1 RIGMN SVRG P Service topdrive, blocks and crown. Recalibrate crown-o-matic 18:15 18:30 0.25 5,439 5,816 PROD1 DRILL TRIP T Trip in hole. Stop for surveys as per DD for cassandra corrections. Hole took 50 bbls when um in u surve . 18:30 19:00 0.50 5,816 5,816 PROD1 DRILL OWFF T Monitor well -breathing. Hole quickly returned 15 bbls and then flow dro ed. 19:00 20:30 1.50 5,816 5,816 PROD1 DRILL CIRC T Circulate bottoms up while reciprocating and rotating pipe. Pumping @ 319 gpm, 2780 psi, 40 rpm. Max gas on bottoms up 217 units. 20:30 21:45 1.25 5,816 6,228 PROD1 DRILL TRIP T Trip in hole. Stop for surveys as per DD for cassandra corrections. 21:45 00:00 2.25 6,228 6,333 PROD1 DRILL DDRL T Drill D sand lateral. WOB=6-8, RPM=40, Flow rate=297, Stand pipe pressure=2400, PU wt=148, SO wt=108, On bottom torque=0, Off bottom torque=5-6, ECDs=9.86, Total as=177 Page 2~ czf 31 ! • • Time Logs _ Date From To Dur S. Depth E. De th Phase Code Subcode T COM 03/15/2008 00:00 00:30 0.50 6,333 6,360 PROD1 DRILL DDRL T Drill D sand lateral. BHA not steering as expected. Assembly built 1degree of left turn over 30' while toolface was pointed right. Stopped drilling to discuss options. Decision made to come out of hole and inspect BHA. WOB=6-10, RPM=60, Flow rate=290, Stand pipe pressure=2460, PU wt=148, SO wt=108, On bottom torque=6-7, Off bottom torque=5-6, ECDs=9.99, Total as=50 00:30 02:45 2.25 6,360 5,500 PROD1 DRILL REAM T Pick up off bottom and backream out to window 02:45 03:00 0.25 5,500 5,500 PROD1 DRILL OWFF T Monitor well -static 03:00 03:45 0.75 5,500 4,494 PROD1 DRILL TRIP T Pull out of hole on elevators, monitorin well via tri tank. 03:45 04:15 0.50 4,494 4,494 PROD1 DRILL CIRC T Pump 11 ppg 15 bbl dry job, blow down to drive and clear ri floor. 04:15 05:30 1.25 4,494 1,679 PROD1 DRILL TRIP T Pull out of hole on elevators. monitorin well via tri tank. 05:30 06:00 0.50 1,679 1,679 PROD1 RIGMN SVRG T Replace hydraulic hose on iron rou hneck 06:00 07:00 1.00 1,679 369 PROD1 DRILL TRIP T Pull out of hole on elevators to BHA. Monitorin well via tri tank. 07:00 07:45 0.75 369 94 PROD1 DRILL TRIP T Pull and stand back HWDP, jars and flex collars. 07:45 08:00 0.25 94 0 PROD1 DRILL PULD T Check orientation of motor. RIH at 243, came out at 157. 86 degree than e. 08:00 08:30 0.50 0 0 PROD1 DRILL PULD T Download MWD 08:30 08:45 0.25 0 0 PROD1 DRILL PULD T Lay down BHA 08:45 09:00 0.25 0 0 PROD1 RIGMN SVRG T Verify rig tong torque via roughneck. Tor ue calibration ood. 09:00 09:15 0.25 0 0 PROD1 DRILL PULD T Lay down remaining BHA. Stabilizer to MWD 3-1 /2" IF connection was made u to 10k and broke at 19k. 09:15 10:15 1.00 0 0 PROD1 DRILL PULD T Pick up and make up BHA #5. Increase torque on connections to 11 k. Orient MWD w/motor 185.1 10:15 10:45 0.50 0 0 PROD1 DRILL PULD T Upload MWD 10:45 11:15 0.50 0 369 PROD1 DRILL PULD T Continue to make up BHA #5. 11:15 12:00 0.75 369 558 PROD1 DRILL TRIP T Trip in hole and shallow pulse test MWD. ABI not working. Pump 300 m, 1780 si. 12:00 14:00 2.00 558 5,800 PROD1 DRILL TRIP T Trip in hole with drill pipe. Hole took 5 bbls over calculated dis lacement. 14:00 16:00 2.00 5,800 6,000 PROD1 DRILL TRIP T Trip in hole obtaining checkshot surveys in each of the 4 quadrants @ 5800', 5900' and 6000' MD Wage ~2 of 31 • i Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/15/2008 16:00 16:30 0.50 6,000 6,376 PROD1 DRILL TRIP T Trip in hole looking for main wellbore. Got in the wrong wellbore and did not to bottom. Sto ed tri in . 16:30 16:45 0.25 6,376 6,125 PROD1 DRILL TRIP T Pull out of hole to try and find main wellbore 16:45 17:45 1.00 6,125 6,125 PROD1 DRILL TRIP T Working string in attempt to find main wellbore. Kicked off an unintentional sidetrack. 17:45 18:00 0.25 6,125 6,220 PROD1 DRILL DDRL T Drilling D sand lateral. WOB=O-6, RPM=O, Flow rate=290, Stand pipe pressure=2500, PU wt=148, SO wt=105, On bottom torque=6-7, Off bottom torque=5-6, ECDs=9.90, Total as= 18:00 00:00 6.00 6,220 6,360 PROD1 DRILL DDRL T Drilling D sand lateral. WOB=2-6, RPM=50, Flow rate=300, Stand pipe pressure=2560, PU wt=148, SO wt=110, On bottom torque=6-7, Off bottom torque=5-6, ECDs=9.82, Total as=108 03/16/2008 00:00 06:00 6.00 6,360 6,471 PROD1 DRILL DDRL T Drill D sand lateral. WOB=3-6, RPM=50, Flow rate=, Stand pipe pressure=2910, PU wt=140, SO wt=108, On bottom torque=6-7, Off bottom torque=6-7, ECDs=9.90, Total as=110 06:00 12:00 6.00 6,471 6,790 PROD1 DRILL DDRL T Drill D sand lateral. WOB=6-8, RPM=50, Flow rate=300, Stand pipe pressure=2680, PU wt=150, SO wt=112, On bottom torque=6, Off bottom torque=6-7, ECDs=10.05, Total as=143 12:00 16:00 4.00 6,790 7,033 PROD1 DRILL DDRL T Drill D sand lateral. WOB=6-8, RPM=50, Flow rate=320, Stand pipe pressure=3000, PU wt=150, SO wt=112, On bottom torque=6, Off bottom torque=6-7, ECDs=10.28, Total as=154 16:00 18:00 2.00 7,033 7,112 PROD1 DRILL DDRL P Drill D sand lateral. WOB=6-8, RPM=50, Flow rate=320, Stand pipe pressure=3000, PU wt=150, SO wt=112, On bottom torque=6, Off bottom torque=6-7, ECDs=10.28, Total gas=154 Reached depth where BHA #3 failed, sto ed recordin trouble time. 18:00 23:00 5.00 7,112 7,241 PROD1 DRILL DDRL. P Drill D sand lateral. WOB=6-8, RPM=50, Flow rate=319, Stand pipe pressure=3080, PU wt=150, SO wt=105, On bottom torque=6, Off bottom torque=6, ECDs=10.24, Total as=143 ~~g~ ~3 cif 31 Time Logs I Date From To Dur S. De th E. De th Phase Code Subcode T COM _ 03/16/2008 23:00 00:00 1.00 7,241 7,223 PROD1 DRILL CIRC P Anticipate problems reaching TD with motor. Decision to trip and replace motor with geo-pilot. Rack back stand and pump 30 bbl hi-vis sweep at 321 gpm, rotating 60 rpm and reciprocating i e 90' 03/17/2008 00:00 00:15 0.25 7,223 7,223 PROD1 DRILL CIRC P Circulating sweep out of hole, rotating 60 rpm and reciprocating pipe 90'. Observed 20% cuttings increase when swee returned. 00:15 00:30 0.25 7,223 7,223 PROD1 DRILL OWFF P Monitor well -static 00:30 02:30 2.00 7,223 5,439 PROD1 DRILL TRIP P Pull out of hole on elevators. Monitoring well via trip tank. Records weights every 10 stands. Slight overpull coming thru window. Weights: @ 7223' MD PU wt 155k, SO wt 108k, 5439' MD PU wt 140k, SO wt 110k. 02:30 02:45 0.25 5,439 5,439 PROD1 DRILL OWFF P Monitor well -static 02:45 03:00 0.25 5,439 5,439 PROD1 DRILL CIRC P Pump 15 bbl 11.1 ppg dry job and blow down to drive. 03:00 05:30 2.50 5,439 360 PROD1 DRILL TRIP P Pull out of hole on elevators. Monitoring well via trip tank. Record wei hts eve 10 stands. 05:30 06:00 0.50 360 360 PROD1 DRILL OWFF P Monitior well -static., Clean rig floor. 06:00 06:30 0.50 360 80 PROD1 DRILL PULD P Lay down BHA #5 06:30 07:45 1.25 80 80 PROD1 DRILL PULD P Download MWD 07:45 08:45 1.00 80 0 PROD1 DRILL PULD P Continue laying down BHA and MWD 08:45 09:00 0.25 0 0 PROD1 DRILL PULD P Clear and clean rig floor 09:00 10:30 1.50 0 80 PROD1 DRILL PULD P Pick up and make up BHA #6 eo- ilot 10:30 11:30 1.00 80 80 PROD1 DRILL PULD P Upload MWD 11:30 12:00 0.50 80 386 PROD1 DRILL PULD P Continue making up BHA. 12:00 12:15 0.25 386 557 PROD1 DRILL TRIP P Trip in hole with geo-pilot 12:15 12:30 0.25 557 557 PROD1 DRILL DHEQ P Shallow test MWD pumping 300 gpm @1460 psi, rotating 30 rpm -tested ood. 12:30 14:15 1.75 557 5,438 PROD1 DRILL TRIP P Trip in hole monitoring well via trip tank. Hole taking proper displacement. Rotated ast ort collar. 14:15 14:45 0.50 5,438 5,438 PROD1 DRILL DHEQ P Fill pipe and test MWD. Pump 277 gpm @ 1990 psi -good test. PU wt 13k, SO wt 118k. Blow down to drive. 14:45 15:00 0.25 5,438 5,438 PROD1 RIGMN SFTY P PJSM -changing out saver sub. 15:00 16:30 1.50 5,438 5,438 PROD1 RIGMN SVRG P Change out saver sub and dies in rabbet. Page 24 of 3't !i i Time Lo s Date From To Dur S De th E. De th Phase Code Subcode T COM 03/17/2008 16:30 17:00 0.50 5,438 5,438 PROD1 RIGMN SVRG P Service top drive, crown and drawworks. 17:00 17:45 0.75 5,438 6,097 PROD1 DRILL TRIP P Trip in hole monitoring well via trip tank. Hole takin ro er dis lacement. 17:45 18:30 0.75 6,097 6,282 PROD1 DRILL TRIP P Trip in hole, making top drive connection and taking surveys for Cassandra corrections. 18:30 19:30 1.00 6,282 7,129 PROD1 DRILL TRIP P Trip in hole on elevators. Wash and ream thru tight spot, 6421' - 6470' MD. Pump 302 gpm, 2400 psi, 50 rpm. Pu wt 145k SO wt 108k 19:30 20:00 0.50 7,129 7,240 PROD1 DRILL TRIP P Trip in hole ,making top drive connection and taking surveys for Cassandra corrections. 20:00 00:00 4.00 7,241 7,558 PROD1 DRILL DDRL P Drilling D sand lateral with geo-pilot. WOB=3, RPM=90, Flow rate=305, Stand pipe pressure=2610, PU wt=150, SO wt=108, On bottom torque=6-7, Off bottom torque=5-6, ECDs=10.29, Total as= 03/18/2008 00:00 06:00 6.00 7,558 7,566 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=3-6, RPM=60-120, Flow rate=260-310, Stand pipe pressure=2580, PU wt=150, SO wt=108, On bottom torque=6-7, Off bottom torque=5-6, ECDs=10.34, Total as= 06:00 12:00 6.00 7,566 7,706 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=6-12, RPM=120, Flow rate=319, Stand pipe pressure=2650, PU wt=150, SO wt=105, On bottom torque=6-7, Off bottom torque=5-6, ECDs=10.35, Total as= 12:00 18:00 6.00 7,706 7,968 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=2-4, RPM=120, Flow rate=321, Stand pipe pressure=2750, PU wt=150, SO wt=105, On bottom torque=6-7, Off bottom torque=5-6, ECDs=10.42, Total as= 18:00 00:00 6.00 7,968 8,116 PROD1 DRILL DDRL P Drilling D sand lateral. WOB=6-8, RPM=120, Flow rate=320, Stand pipe pressure=2780, PU wt=150, SO wt=105, On bottom torque=6, Off bottom torque=7, ECDs=10.43, Total as= 03/19/2008 00:00 06:00 6.00 8,116 8,222 PROD1 DRILL DDRL P Drill D sand lateral. DD & geologist steering toward bottom of pay to find cleaner sands w/o concretions. WOB=4, RPM=120, Flow rate=325, Stand pipe pressure=2850, PU wt=150, SO wt=105, On bottom torque=6, Off bottom torque=4, ECDs=10.44, Totat as= Pig 25 off 3~~ • Time Logs __ _ Date _ From To Dur S De th E. De th Phase Code Subcode T COM 03/19/2008 06:00 12:00 6.00 8,222 8,813 PROD1 DRILL DDRL P Drill D sand lateral. WOB=4-5, RPM=120, Flow rate=321, Stand pipe pressure=3000, PU wt=158, SO wt=100, On bottom torque=7, Off bottom torque=7, ECDs=, Total as=208 12:00 18:00 6.00 8,813 9,094 PROD1 DRILL DDRL P Drill D sand lateral. WOB=4-5, RPM=120, Flow rate=321, Stand pipe pressure=2950, PU wt=158, SO wt=100, On bottom torque=7, Off bottom torque=6, ECDs=10.76, Total as=114 18:00 00:00 6.00 9,094 9,563 PROD1 DRILL DDRL P Drill D sand lateral. WOB=5, RPM=120, Flow rate=325, Stand pipe pressure=3140, PU wt=162, SO wt=95, On bottom torque=7-8, Off bottom torque=7, ECDs=11.00, Total as= 03/20/2008 00:00 03:00 3.00 9,563 9,926 PROD1 DRILL DDRL P Drilling D sand lateral. Lost 700 psi of stand pipe pressure 75' from TD. Checked surface equipment and drilled to TD. 03:00 03:45 0.75 9,926 9,926 PROD1 DRILL CIRC P Took slow pump rates and pumped swee . Watchin SPP close) . 03:45 04:15 0.50 9,926 9,844 PROD1 DRILL REAM P Start Back reaming out of hole when sweep out the bit. Back ream at 3 fpm until sweep should have been at surface. No sign of sweep. Lost another 300 psi of SPP. Pumping 330 m, 1570 si, rotatin 120 r m 04:15 04:45 0.50 9,844 9,750 PROD1 DRILL TRIP T Pump out of hole at reduced rate to clear sweep and look for wash out, not rotating. Pumping 200 gpm, 800 psi. Monitorin hole fill via actives stem. 04:45 05:00 0.25 9,750 9,656 PROD1 DRILL TRIP T Monitor well -static. Pull on elevators looking for wash out. Monitoring well via tri tank, hole swabbin . 05:00 06:00 1.00 9,656 9,127 PROD1 DRILL TRIP T Pump out of hole at reduced rate, looking for wash out. 84 gpm, 350 psi. Monitorin well via active s stem. 06:00 06:30 0.50 9,127 9,127 PROD1 DRILL TRIP T Located wash out on middle joint, stand 94, approx 2' below tool joint. Replace bad joint, make top drive connection and establish circulation at 320 m, 3050 si. 06:30 07:15 0.75 9,127 9,925 PROD1 DRILL TRIP P Trip in hole on elevators. Monitoring displacement via trip tank. Pumps off rotatin wt 13k, PU wt 165k, SO wt 8k 07:15 07:30 0.25 9,925 9,925 PROD1 DRILL CIRC P Establish circulation. Compare SPP pressure to before wash out - ok. 321 gpm / 3170 psi. Obtain slow pump rates. 07:30 10:00 2.50 9,925 8,722 PROD1 DRILL REAM P BROOH. 15-20 fpm, RPM=120, Flow rate=320, Stand pipe pressure=2880, PU wt=160, SO wt=100, Off bottom for ue=6-7, ECDs=10.59, Total as= 3~ags 2~ ~f 31 Time Logs _ Date From To Dur S. De th E. De th Ph e Coe Subcode T COM 03/20/2008 10:00 12:00 2.00 8,722 7,691 PROD1 DRILL REAM P BROOH. 35-40 fpm, RPM=120, Flow rate=321, Stand pipe pressure=2770, PU wt=150, SO wt=102, Off bottom for ue=6, ECDs=10.42, Total as= 12:00 16:15 4.25 7,691 5,705 PROD1 DRILL REAM P BROOH. 35-40 fpm, lost 15 bbls, stopped pumps and monitored well. Well is breathing. RPM=120, Flow rate=321, Stand pipe pressure=2530, PU wt=140, SO wt=112, Off bottom for ue=5-6, ECDs=, Total as= 16:15 16:30 0.25 5,705 5,705 PROD1 DRILL OWFF P Monitor well, flowing back -rate slowin . 16:30 16:45 0.25 5,705 5,437 PROD1 DRILL TRIP P Pull out of hole on elevators, monitoring well via trip tank. PU wt 140k, SO wt 115k. Calculated hole fill 24.3 bbls, actual 46.5 bbls, lost 22 tills. 16:45 17:00 0.25 5,437 5,437 PROD1 DRILL TRIP P Monitor well -static 17:00 18:00 1.00 5,437 5,437 PROD1 DRILL CIRC P Rotate and reciprocate pipe while pumping hi-vis sweep. Observed 20% increase in cutting when sweep returned. Pum 321 m / 2490 si. 18:00 19:00 1.00 5,437 5,437 PROD1 DRILL CIRC P Rotate and reciprocate pipe while pumping total 5 bottoms up. Pump 321 m / 2490 si. 19:00 19:15 0.25 5,437 5,437 PROD1 DRILL OWFF P Monitor well -static. Blow down top drive. 19:15 20:00 0.75 5,437 5,437 PROD1 RIGMN SVRG P Service rig. Grease & inspect top drive, blocks, and crown. Monitor hole fill via tri tank. 20:00 22:00 2.00 5,437 9,925 PROD1 DRILL TRIP P Trip in hole on elevators. Fill pipe every 25 stands, record weights every 10 stands, monitoring displacement via trip tank. PU wt 155k, SO wt 95k, rotatin wt 125k, 7k ftlbs for ue. 22:00 00:00 2.00 9,925 9,925 PROD1 DRILL CIRC P Rotate and reciprocate while pumping swee .320 m / 3270 si, 100 r m. 03/21/2008 00:00 01:00 1.00 9,925 9,925 PROD1 DRILL CIRC P Circulate sweep out of hole pumping 320 gpm, 3270 psi, rotating 100 rpm, off bottom for ue 7-8k. 01:00 02:00 1.00 9,925 9,925 PROD1 DRILL CIRC P Displace well over to SFOBM. Pump 320 gpm, 3100 psi, rotating 100 rpm, off bottom torque 7k, PU wt 160k, SO wt 90k, rot wt 125k 02:00 02:15 0.25 9,925 9,925 PROD1 DRILL OWFF P Monitor well -static. Obtain slow um rates 02:15 04:30 2.25 9,925 5,438 PROD1 DRILL TRIP P Pull out of hole on elevators. Monitor well via trip tank. Record weights every 5 stands. Dropped 1-7/8" rabbit on the wa out of hole. 04:30 05:15 0.75 5,438 5,438 PROD1 DRILL CIRC P Spotted SFOBM w/3% tubes in casing and um ed d 'ob. 05:15 05:30 0.25 5,438 5,438 PROD1 DRILL SFTY P PJSM -laying down drill pipe. gage 27 caf 3'4 • Time Logs _ __ _~ Date From To Dur S De th E De th Ph e Coe Subcode T COM 03/21/2008 05:30 09:45 4.25 5,438 368 PROD1 DRILL TRIP P Pull out of hole on elevators laying down drill pipe.. Monitor well via trip tank. Record weights every 5 stands. Dro ed drill i e wi er. 09:45 10:00 0.25 368 368 PROD1 DRILL OWFF P Monitor well -static 10:00 11:30 1.50 368 0 PROD1 DRILL PULD P Lay down BHA and recovered rabbit and drill i e wi er. 11:30 12:30 1.00 0 0 PROD1 DRILL PULD P Download MWD 12:30 13:30 1.00 0 0 PROD1 DRILL PULD P Lay down remaining BHA. Trip out hole fill: calculated 60.67 bbls, actual 80.50 bbls, lost 19.83 bbls to hole. 13:30 14:30 1.00 0 0 COMPZ CASIN( RURD P Clear rig floor and rig up GBR 4-1/2" tools. 14:30 14:45 0.25 0 0 COMPZ CASIN SFTY P PJSM -running 4-1/2" liner 14:45 19:00 4.25 0 4,482 COMPZ CASIN RUNL P Run 4-1 /2" slotted liner. 19:00 19:30 0.50 4,482 4,551 COMPZ CASINC RUNL P Pick up and make up hanger, packer and liner runnin tool. 19:30 19:45 0.25 4,551 4,551 COMPZ CASIN( RURD P Rig down GBR liner running tools. 19:45 22:45 3.00 4,551 9,925 COMPZ CASIN RUNL P Run liner to TD on drill pipe. Record weigths every 10 stands. Monitor dis lacement via tri tank. 22:45 23:30 0.75 5,363 5,363 COMPZ CASINC RUNL P Pick up to 9877 and drop 1-3/4" ball. Pump ball down at 126 gpm / 500 psi. Reduce rate to 63 gpm / 270 psi before seating ball. Ball on seat at 398 strokes. Set hanger and packer per BOT re . 23:30 23:45 0.25 5,363 5,363 COMPZ CASINC DHEO P Test packer to 2500 psi for 10 minutes. Pressure held. 23:45 00:00 0.25 5,363 5,353 COMPZ CASINC RUNL P Release hanger, pick up to engage dogs. Set down to block weight. Pick up and while rotating 30 rpm set down to block weight, twice. PU wt 160k, SO wt 110k. 03/22/2008 00:00 00:15 0.25 5,353 5,353 COMPZ CASIN CIRC P Circulate bottoms up pumping 450 m / 2550 si. 00:15 00:45 0.50 5,353 5,353 COMPZ CASINC OTHR P Monitor well -static. Drop drill pipe wi er. 00:45 05:15 4.50 5,353 60 COMPZ CASINC RUNL P Pull out of hole with drill pipe and liner running tools. Laying down drill pipe to shed. Monitor hole fill via tri tank. 05:15 05:30 0.25 60 0 COMPZ CASIN RURD P Lay down liner running tool per BOT re .Close blind rams. 05:30 06:00 0.50 0 0 COMPZ CASINC OTHR P Lay down 7 stands of drill pipe from derrick. 06:00 06:45 0.75 0 0 COMPZ CASIN RURD P Open blind rams and pull wear bushing. Lay down Baker tools and clear ri floor. 06:45 07:15 0.50 0 0 COMPZ CASIN OTHR P Retrieve drill pipe wiper from Baker runnin tool. dare 2~ oaf 39 • Time Logs ~_ I data Frnm Tn ni it S rlanth F Ilanth Phaca ('nria ~i ihnnrie T (;C)M 03/22/2008 07:15 08:00 0.75 0 0 COMPZ CASIN< RURD P Rig up GBR 5-1 /2" casing tools 08:00 09:00 1.00 0 0 COMPZ RIGMN SVRG P Service top drive, blocks and drawworks. 09:00 09:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM -running 5-1/2" tie-back string. 09:15 19:00 9.75 0 0 COMPZ CASIN RNCS P Run 5-1/2" casing string. Monitor displacement via trip tank and record weights every 10 joints. Stab seals into seal bore and calculate spaceout. PU wt 132k SO wt 112k 19:00 19:15 0.25 0 0 COMPZ CASIN( DHEQ P Pressure up annulus to confirm seals in lace - ressure held. 19:15 22:15 3.00 0 0 COMPZ CASIN RURD P Unstab seals and space out. Land hanger to check space out. Pick up till 2.5' above liner top. Rig up and PJSM for pumping corrosion inhibited brine and freeze protect diesel down annulus. 22:15 00:00 1.75 0 0 COMPZ CASIN CIRC P Reverse in 60 bbls of corrosion inhibited brine and 30 bbls of diesel into 7-5/8" x 5-1/2" annulus. Hold back pressure on casing via bleeder valve (willis choke). Lost 2 bbls to the formation. 03/23/2008 00:00 00:30 0.50 0 0 COMPZ CASIN( RNCS P Land 5-1 /2" tie-back casing and run in lock down screws. 00:30 00:45 0.25 0 0 COMPZ CASIN DHEQ P Test upper and lower hanger seals to 5000 si for 10 min -tested ood. 00:45 01:30 0.75 0 0 COMPZ CASINC RURD P Lay down landing joint and rig down freeze protect equipment. Flush diesel from um lines and stack. 01:30 01:45 0.25 0 0 COMPZ WELC SFTY P PJSM - BOPE test 01:45 02:15 0.50 0 0 COMPZ WELCT BOPE P Rig up for BOPE test. 02:15 06:00 3.75 0 0 COMPZ WELCT BOPE P Test BOPE with 2-7/8" test joint. Low 205 psi /high 3000 psi. Wintess of test waived by AOGCC Bob Noble. 35 components tested and passed. Koomey drawdown starting pressure 3000 psi, 1450 psi after functioning. 42 sec 200 psi build back and 3 min 24 sec build back to 3000 psi. 5 bottle avers a 2500 si. 06:00 07:30 1.50 0 0 COMPZ WELCT BOPE P Rig down BOPE test equipment. blow down to drive and lines. 07:30 08:15 0.75 0 0 COMPZ RPCO RURD P Clear and clean rig floor. 08:15 08:45 0.50 0 0 COMPZ RPCOh RURD P Rig up GBR 2-7/8" handling equipment 08:45 10:45 2.00 0 0 COMPZ RPCO RURD P Pick up and rig up gauge wire, heat trace and sheaves. (lost 1.5 bbls to hole 10:45 11:00 .0.25 0 0 COMPZ RPCOti SFTY P PJSM -running 2-7/8" completion strin . C\ J • Time Logs i __ Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/23/2008 11:00 12:00 1.00 0 290 COMPZ RPCOti RCST P Run in hole with 2-7/8" tubing. Monitorin dis lacement via tri tank. 12:00 15:00 3.00 290 290 COMPZ RPCO PULD P Conection control line to gauge carrier. Test temperature gauge with heat gun and erform conductivi test. 15:00 15:30 0.50 290 376 COMPZ RPCOI~ RCST P Run in hole with 2-7/8" tubing. Monitoring displacement via trip tank. Stacked out on 2.07' space out pup used in 5-1/2" casin strip . 15:30 17:30 2.00 376 290 COMPZ RPCOh RCST T Pull out of hole to gauge carrier. Measured carrier, OD 4-13/16". 5-1/2" casing pups drifted to 4.85. Found set screw protruding approximately 1/8" from carrier. Filed off set screw. 17:30 18:00 0.50 290 386 COMPZ RPCO RCST T Run in hole with gauge carrier past s ace out u . PU wt 75k SO wt 75k. 18:00 21:00 3.00 386 2,128 COMPZ RPCOh RCST P Run in hole with 2-7l8" tubing and gauge wire. Monitoring displacement via tri tank. 21:00 21:45 0.75 2,128 2,128 COMPZ RPCOh RCST T Repair gauge wire spooler. 21:45 22:00 0.25 2,128 2,200 COMPZ RPCOb RCST P Run in hole with 2-7/8" tubing. Monitorin dis lacement via tri tank. 22:00 23:00 1.00 2,200 2,200 COMPZ RPCO RURD P Rig up for running heat trace. 23:00 00:00 1.00 2,200 2,616 COMPZ RPCOh RCST P Run in hole with 2-7/8" tubing, gauge wire and heat trace. Monitoring displacement via trip tank. PU wt 88k SO wt 88k 03/24/2008 00:00 06:00 6.00 2,616 4,080 COMPZ RPCO RCST P Run in hole with 2-7/8" tubing, gauge wire and heat trace. Monitoring displacement via trip tank. PU wt 90k SO wt 90k 06:00 12:00 6.00 4,080 5,074 COMPZ RPC06 RCST P Run in hole with 2-7/8" tubing, gauge wire and heat trace. Monitoring displacement via trip tank. PU wt 98k SO wt 90k 12:00 13:30 1.50 5,074 5,420 COMPZ RPCOh RCST P Run in hole with 2-7/8" tubing, gauge wire and heat trace. Monitoring displacement via trip tank. PU wt 100k SO wt 95k 13:30 14:00 0.50 5,420 5,420 COMPZ RPCOti RURD P Rig down control sheaves from derrick 14:00 14:45 0.75 5,420 5,430 COMPZ RPCO RCST P Run in hole with 2-7/8" tubing, gauge wire and heat trace. Monitoring displacement via trip tank. PU wt 100k SO wt 95k 14:45 15:15 0.50 5,430 5,452 COMPZ RPCOCV RCST P Rig up head pin, establish circulation .5 bpm / 150 psi. Slack off and observe seals enter liner top @ 5434' MD. Bleed off pressure and run in till to in on no o located at 5418' MD' 15:15 16:45 1.50 5,452 5,369 COMPZ RPCO HOSO P Pull out of hole and space out. Pick up hanger, landing joint and install head in on landin 'oint. Wage 3Cs of 31 • Time Logs __ ~ __ Date From To Dur S De th E. Depth Phase Code Subcode T COM _ 03/24/2008 16:45 19:15 2.50 5,369 5,369 COMPZ RPCO RCST P Install penetrators in hanger and splice cables. Rig down running tools and lay down sheaves ands ools. 19:15 20:00 0.75 5,369 5,369 COMPZ RPCOh DHEO P Test gauge wire and heat trace. Gauge tester failed, only tested conductivi 20:00 22:00 2.00 5,377 5,377 COMPZ RPCOh RURD P Rig up and displace tubing and 5-1/2" x 2-7/8" annulus to corrosion inhibited brine. Held seal assembly 2' above seal bore. 22:00 22:45 0.75 5,377 5,397 COMPZ RPCO RCST P Drain stack and pick up to inspect hanger seals. replaced 2 seals. Landed tubing and ran in lock down screws. 22:45 23:30 0.75 0 0 COMPZ RPCOh DHEQ P Rig up and test 5-1/2" x 2-7/8" annulus to 1000 si - ressure held 23:30 00:00 0.50 0 0 COMPZ RPCOh RURD P Back out and lay down landing joint. Install 2-wa check valve. 03/25/2008 00:00 05:00 5.00 0 0 COMPZ RPCO NUND P Nipple down BOPE, cleaning pits. 05:00 07:15 2.25 0 0 COMPZ RPCO NUND P Nipple up tree. Test adapter between tree and wellhead to 4900 psi for 5 min. 07:15 07:45 0.50 0 0 COMPZ RPCOb OTHR P Install two way check. Test tree for 5 minutes. Pull two way check, install tree ca . 07:45 08:45 1.00 0 0 COMPZ RPCO6 RURD P Rig up to displace well from 9.3 ppg brine to 7 ppg diesel for freeze rotection. 08:45 09:00 0.25 0 0 COMPZ RPCO SFTY P Pre job safety meeting on the dis lacement freeze rotection . 09:00 11:00 2.00 0 0 COMPZ RPCOh FRZP P Pressure test lines to 1500 psi. Dispalce 2-718" tubing and 5-1/2" x 2-7/8"annulus with diesel to 3167'. Final circulating rate of 2 bpm w/ 490 psi. Pumped 83 bbls total. Shut in tubing and annulus pressure was 175 si. Outer annulus on a vacum. 11:00 11:15 0.25 0 0 COMPZ RPCO RURD P Blow down and rig down circulating e ui ment. 11:15 13:30 2.25 0 0 COMPZ RPCOti OTHR P Install back pressure valve using lubricator. Install blank flanges on annulus valve. Cleaning pits. Note: Rig released 1330 hrs 3-25-2008 for move to 1 C-172A a rox 5.6 miles .. #~~€~~ 31 of 31 ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-141 A 50-029-22967-01 Definitive Survey Report 04 April, 2008 ..: .. '_~'- .. ~ ~ _. Sperry Drilling Services ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: 1D-141A @ 111.SOft (D15 (70.7+40.8)) Site: Kuparuk 1D Pad MD Reference: 1D-141A @ 111.50ft (D15 (70.7+40.8)) Well: 1D-141 North Reference: True - Wellbore: 1D-141A Survey Calculation Method: Minimum Curvature Design: 1D-141A Database: EDM Alaska Prod v16 - ~ 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 1 D-141 Well Position +NI-S 0.00 ft Northing: 5,959,678.83 ft Latitude: 70° 18' 1.455 N +E/-W 0.00 ft Easting: 560,490.62 ft Longitude: 149° 30' 36.290 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70 ft Wellbore 1D-141A _, ', Magnetics Model Name Sample Date Declin ation Dip Angle Field Strength BGGM2 007 311 VZ008 17.54 79.75 S 27d I Design 1D-141A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,119.69 ~ i Vertical Section: Depth From (ND) +N/-S +E/-W Direction (ft) (ftl fft) (°) 40.80 0.00 G.00 180.00 Survey Program Date From To Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date ~ 105.45 646.551D-141PB1gyro(1 D-141PB1) CB-GYRO-SS Camera based gyro single shot 04/04/2008 681.46 5,486.19 1D-141PB1 (1D-14 1PB1) MWD MWD-Standard 04!04/2008 5,502.00 6,119.69 1D-141AP61 MWD+SAG+CA+II FR+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 04/04/2008 6,125.00 9,887.38 1D-141A MWD+SAG+CA+IIFR+MSA+M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 04/04/2008 Survey Map Map Vertical MD Inc Axl TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (~) (°) (ft) (ft) (ft) (n) (ft) (ft) ( °I100') (ft) Survey Tool Name 4J.o0 O.GO u.GG 40.oG _ _ -r u.i0 .. - U.UO G.uU - - - - S,yob,bi o.o.i ~ - - - - . :~bJ,4`.iU.ti1 O.vO O.uU UHUEFINED 105.45 0.10 330.50 105.45 -0.OS 0.05 -0.03 5,959,678.88 560,490.59 0.15 -0.05 CB-GYRO-SS (1) 200.45 0:30 315.40 200.45 88.95 0.30 -0.24 5,959,679.13 560,490.37 0.22 -0.30 CB-GYRO-SS (1) 295.45 0.30 25.10 295.45 183.95 0.70 -0.31 5,959,679.53 560,490.30 0.36 -0.70 CB-GYRO-SS (1) 318.45 0.30 303.60 318.45 206.95 0.79 -0.34 5,959,679.62 560,490.28 1.70 -0.79 CB-GYRO-SS (1) 348.45 0.30 303.00 348.45 236.95 0.87 -0.47 5,959,679.70 560,490.14 0.01 -0.87 CB-GYRO-SS (1) 390.45 0.00 0.00 390.45 278.95 0.93 -0.56 5,959,679.76 560,490.05 0.71 -0.93 CB-GYRO-SS (1) - 414.45 0.40 346.80 414.45 302.95 1.02 -0.58 5,959,679.84 560,490.03 1.67 -1.02 CB-GYRO-SS (1) 460.45 0.40 31.60 460.45 348.95 1.31 -0.53 5,959,680.13 560,490.08 0.66 -1.31 CB-GYRO-SS (1) 493.45 1.90 38.60 493.44 381.94 1.83 -0.13 5,959,680.66 560,490.47 4.56 -1.83 CB-GYRO-SS (1) 530.45 1.10 32.00 530.43 418.93 2.62 0.44 5,959,681.45 560,491.04 2.21 -2.62 CB-GYRO-SS (1) 4/4/2008 2:36:19PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Protect: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1D-141 Wellbora: 1D-141A Design: 1D-141A Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1 D-141 1 D-141A @ 111.SOft (D15 (70.7+40.8)) 1 D-141A @ 111.SOft (D15 (70.7+40.8)) True Minimum Curvature EDM Alaska Prod v16 Map Map Vertical MD Inc Azl TVD TVDSS +N!-S +E/-W Northing Easting DLS Section lft) (~) (~) (ft) (ft) (ftl Ift) (ft) (ft) (°/100') (ft) Survey Tool Name 549.45 1.20 35.20 549.42 437.92 2.93 O.oS 5,a59,otlt.77 500,491.25 u.oa -2.93 C6-Grkv-JJ t1! 587.45 3.10 111.90 587.40 475.90 2.87 1.83 5,959,681.72 560,492.43 8.04 -2.87 CB-GYRO-SS (1) 646.45 6.40 116.60 646.19 534.69 0.81 6.26 5,959,679.69 560,496.87 5.63 -0.81 CB-GYRO-SS (t) 681.46 8.31 120.17 680.91 569.41 -1.34 10.19 5,959,677.57 560,500.82 5.61 1.34 MWD (2) 714.62 8.45 119.15 713.71 602.21 -3.73 14.39 5,959,675.22 560,505.04 0.62 3.73 MWD (2) 748.20 9.27 116.77 746.89 635.39 -6.15 18.96 5,959,672.83 560,509.62 2.67 6.15 MWD (2) 777.47 10.62 117.25 775.72 664.22 -8.45 23.46 5,959,670.57 560,514.15 4.62 8.45 MWD (2) 811.34 11.84 116.08 808.94 697.44 -11.40 29.36 5,959,667.66 560,520.06 3.66 11.40 MWD (2) 843.66 13.99 112.15 840.45 728.95 -14.33 35.95 5,959,664.79 560,526.68 7.18 14.33 MWD (2) 873.61 17.20 110.68 869.29 757.79 -17.26 43.45 5,959,661.92 560,534.21 10.80 17.26 MWD (2) 908.63 20.11 109.71 902.47 790.97 -21.12 53.97 5,959,658.14 560,544.75 8.36 21.12 MWD (2) 940.81 20.54 110.98 932.64 821.14 -25.01 64.45 5,959,654.34 560,555.26 1.91 25.01 MWD (2) 970.89 21.52 110.46 960.72 849.22 -28.83 74.54 5,959,650.60 560,565.38 3.32 28.83 MWD (2) 1,005.44 23.24 111.69 992.67 881.17 -33.56 86.81 5,959,645.97 560,577.69 5.16 33.56 MWD (2) 1,037.35 24.13 112.22 1,021.89 910.39 -38.36 98.70 5,959,641.27 560,589.62 2.87 38.36 MWD (2) 1,067.31 24.70 111.43 1,049.17 937.67 -42.96 110.20 5,959,636.76 560,601.15 2.19 42.96 MWD (2) 1,163.67 26.43 113.69 1,136.09 1,024.59 -58.93 148.58 5,959,621.10 560,639.66 2.06 58.93 MWD (2) 1,259.90 30.34 115.14 1,220.74 1,109.24 -77.87 190.21 5,959,602.50 560,681.43 4.13 77.87 MWD (2) 1,355.72 33.44 116.08 1,302.09 1,190.59 -99.76 235.84 5,959,580.98 560,727.24 3.26 99.76 MWD (2) 1,452.67 33.40 114.53 1,383.01 1,271.51 -122.59 284.11 5,959,558.54 560,775.68 0.88 122.59 MWD (2) 1,549.88 35.63 111.32 1,463.11 1,351.61 -143.99 334.84 5,959,537.55 560,826.58 2.96 143.99 MWD (2) 1,646.69 39.28 112.00 1,539.95 1,428.45 -165.73 389.54 5,959,516.25 560,881.45 3.79 165.73 MWD (2) 1,742.09 42.92 113.31 1,611.83 1,500.33 -189.91 447.40 5,959,492.55 560,939.49 3.92 189.91 MWD (2) 1,838.15 44.12 113.98 1,681.48 1,569.98 -216.44 507.99 5,959,466.50 561,000.28 1.34 216.44 MWD (2) 1,934.22 44.49 113.15 1,750.23 1,638.73 -243.27 569.49 5,959,440.18 561,062.00 0.72 243.27 MWD (2) 2,030.35 48.00 116.14 1,816.71 1,705.21 -272.26 632.56 5,959,411.70 561,125.29 4.29 272.26 MWD (2) 2,126.80 51.41 113.67 1,879.08 1,767.58 -303.19 699.28 5,959,381.30 561,192.25 4.04 303.19 MWD(2) 2,223.14 55.85 113.16 1,936.20 1,824.70 -334.00 770.45 5,959,351.07 561,263.66 4.63 334.00 MWD (2) 2,318.81 59.53 111.66 1,987.33 1,875.83 -364.80 845.19 5,959,320.88 567,338.64 4.07 364.80 MWD (2) 2,413.93 60.15 107.25 2,035.13 1,923.63 -392.17 922.71 5,959,294.13 561,416.37 4.06 392.17 MWD (2) 2,509.34 60.67 106.35 2,082.25 1,970.75 -416.15 1,002.14 5,959,270.80 561,495.98 0.98 416.15 MWD (2) 2,605.40 60.88 106.69 2,129.15 2,017.65 -439.99 1,082.51 5,959,247.61 561,576.53 0.38 439.99 MWD (2) 2,700.89 61.36 107.31 2,175.27 2,063.77 -464.44 1,162.47 5,959,223.81 561,656.68 0.76 464.44 MWD(2) 2,796.49 60.58 104.62 2,221.67 2,110.17 -487.43 1,242.82 5,959,201.46 561,737.21 2.59 487.43 MWD (2) 2,892.79 59.47 103.82 2,269.78 2,158.28 -507.93 1,323.68 5,959,181.62 561,818.22 1.36 507.93 MWD (2) 2,989.04 58.76 103.50 2,319.19 2,207.69 -527.43 1,403.95 5,959,162.76 561,898.63 0.79 527.43 MWD (2) 3,084.63 57.96 105.90 2,369.34 2,257.84 -548.08 1,482.66 5,959,142.76 561,977.50 2.30 548.08 MWD (2) 3,180.93 59.65 105.81 2,419.21 2,307.71 -570.58 1,561.90 5,959,120.90 562,056.91 1.76 570.58 MWD (2) 3,277.10 58.12 106.87 2,468.91 2,357.41 -593.74 1,640.90 5,959,098.38 562,136.09 1.85 593.74 MWD (2) 3,373.89 60.56 106.90 2,516.26 2,406.76 -617.92 1,720.57 5,959,074.84 562,215.94 2.52 617.92 MWD (2) 4/4/2008 2:36:19PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: 1D-141A @ 111.SOft (D15 (70.7+40.8)) Site: Kuparuk 1D Pad MD Reference: 10-141A @ 111.SOft (D15 (70.7+40.8)) Well: 1D-141 North Reference: True Wellbore: 1D-141A Survey Calculation Method: Minimum Curvature Design: 1D-141A Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Axi TVD TVDSS +N/-S +Ef-W Northing Easting DLS Section (ft) (~) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name i 3,469.90 59s2 iv6.64 2,566.35 2,454.85 -642.u3 1,is06.09 5,555,051.37 562,2a5.o4 1.29 642.03 M'vVD t2~ 3,566.00 59.39 107.38 2,615.34 2,503.84 -666.36 1,879.10 5,959,027.68 562,374.85 0.49 666.36 MWD (2) 3,662.85 59.40 107.46 2,664.65 2,553.15 -691.33 1,958.64 5,959,003.36 562,454.57 0.09 691.33 MWD (2) 3,758.65 60.67 106.53 2,712.49 2,600.99 -715.59 2,038.00 5,958,979.73 562,534.12 1.58 715.59 MWD (2) 3,855.13 61.02 106.30 2,759.50 2,648.00 -739.40 2,118.82 5,958,956.58 562,615.12 0.42 739.40 MWD (2) 3,951.44 60.98 105.98 2,806.19 2,694.69 -762.82 2,199.74 5,958,933.81 562,696.21 0.29 762.82 MWD(2) 4,048.08 61.10 106.62 2,852.98 2,741.48 -786.55 2,280.89 5,958,910.74 562,777.55 0.59 786.55 MWD (2) 4,144.45 59.87 106.08 2,900.46 2,788.96 -810.16 2,361.36 5,958,887.78 562,858.20 1.37 810.16 MWD (2) 4,240.41 59.61 105.60 2,948.82 2,837.32 -832.79 2,441.10 5,958,865.80 562,938.11 0.51 632.79 MWD (2) 4,336.22 60.46 104.93 2,996.67 2,885.17 -854.64 2,521.17 5,958,844.60 563,018.35 1.07 854.64 MWD (2) 4,431.89 58.75 106.66 3,045.08 2,933.58 -877.09 2,600.57 5,958,822.79 563,097.92 2.37 877.09 MWD (2) 4,528.51 58.54 106.72 3,095.35 2,983.85 -900.78 2,679.61 5,958,799.73 563,177.14 0.22 900.78 MWD (2) 4,624.58 58.80 106.32 3,145.30 3,033.80 -924.12 2,758.28 5,958,777.04 563,255.99 0.45 924.12 MWD (2) 4,719.45 58.69 107.40 3,194.53 3,083.03 -947.64 2,835.90 5,958,754.14 563,333.78 0.98 947.64 MWD (2) 4,816.43 59.02 106.89 3,244.69 3,133.19 -972.10 2,915.21 5,958,730.32 563,413.28 0.56 972.10 MWD (2) 4,911.88 58.61 107.64 3,294.11 3,182.61 -996.34 2,993.19 5,958,706.71 563,491.44 0.80 996.34 MWD (2) 5,007.61 59.20 105.81 3,343.55 3,232.05 -1,019.92 3,071.69 5,958,683.76 563,570.12 1.75 1,019.92 MWD (2) 5,105.00 59.33 105.41 3,393.33 3,281.83 -1,042.45 3,152.31 5,958,661.89 563,650.92 0.38 1,042.45 MWD (2) 5,200.38 59.01 105.24 3,442.21 3,330.71 -1,064.09 3,231.30 5,958,640.88 563,730.07 0.37 1,064.09 MWD (2) 5,294.22 58.34 105.58 3,491.00 3,379.50 -1,085.39 3,308.58 5,958,620.21 563,807.51 0.78 1,085.39 MWD (2) 5,390.16 59.75 104.29 3,540.34 3,428.84 -1,106.59 3,388.07 5,958,599.65 563,887.17 1.87 1,106.59 MWD (2) 5,486.19 59.50 104.23 3,588.90 3,477.40 -1,127.00 3,468.37 5,958,579.89 563,967.62 0.27 7,127.00 MWD (2) 5,502.00 59.83 104.97 3,596.89 3,485.39 -1,130.44 3,481.57 5,958,576.56 563,980.85 4.55 1,130.44 MWD+IFR-AK-CAZ-SC (3) 5,531.65 61.28 104.16 3,611.46 3,499.96 -1,136.93 3,506.56 5,958,570.27 564,005.88 5.44 1,136.93 MWD+IFR-AK-CAZ-SC (3) 5,559.63 62.30 103.41 3,624.69 3,513.19 -1,142.80 3,530.51 5,958,564.59 564,029.87 4.34 1,142.80 MWD+IFR-AK-CAZ-SC (3) 5,580.58 62.00 102.86 3,634.48 3,522.98 -1,147.01 3,548.55 5,958,560.53 564,047.95 2.73 1,147.01 MWD+IFR-AK-CAZ-SC (3) 5,610.34 61.80 102.08 3,648.49 3,536.99 -1,152.68 3,574.18 5,958,555.07 564,073.62 2.41 1,152.68 MWD+IFR-AK-CAZ-SC (3) 5,641.78 63.97 101.27 3,662.82 3,551.32 -1,158.34 3,601.58 5,958,549.63 564,101.07 7.27 1,158.34 MWD+IFR-AK-CAZ-SC (3) 5,673.51 65.19 100.47 3,676.44 3,564.94 -1,163.75 3,629.73 5,958,544.45 564,129.25 4.47 1,163.75 MWD+IFR-AK-CAZ-SC (3) 5,701.79 66.41 99.78 3,688.04 3,576.54 -1,168.28 3,655.12 5,958,540.12 564,154.67 4.85 1,168.28 MWD+IFR-AK-CAZ-SC (3) 5,732.13 67.57 102.17 3,699.90 3,588.40 -1,173.60 3,682.53 5,958,535.02 564,182.13 8.20 1,173.60 MWD+IFR-AK-CAZ-SC (3) 5,763.66 69.45 105.19 3,711.45 3,599.95 -1,180.54 3,711.03 5,958,528.31 564,210.68 10.72 1,180.54 MWD+IFR-AK-CAZ-SC (3) 5,793.64 71.63 108.37 3,721.44 3,609.94 -1,188.70 3,738.09 5,958,520.37 564,237.80 12.36 1,188.70 MWD+IFR-AK-CAZ-SC (3) 5,824.51 72.97 110.11 3,730.82 3,619.32 -1,198.40 3,765.85 5,958,510.90 564,265.63 6.90 1,198.40 MWD+IFR-AK-CAZ-SC (3) 5,856.25 74.23 114.28 3,739.79 3,628.29 -1,209.90 3,794.03 5,958,499.63 564,293.91 13.21 1,209.90 MWD+IFR-AK-CAZ-SC (3) 5,900.33 75.93 117.50 3,751.14 3,639.64 -1,228.50 3,832.34 5,958,481.34 564,332.36 8.04 1,228.50 MWD+IFR-AK-CAZ-SC (3) 5,943.96 78.66 119.22 3,760.74 3,649.24 -1,248.71 3,869.79 5,958,461.42 564,369.97 7.34 1,248.71 MWD+IFR-AK-CAZ-SC (3) 5,987.70 80.79 122.45 3,768.54 3,657.04 -1,270.77 3,906.74 5,958,439.67 564,407.08 6.75 1,270.77 MWD+IFR-AK-CAZ-SC (3) 6,031.75 83.19 123.06 3,774.68 3,663.18 -1,294.37 3,943.42 5,958,416.36 564,443.95 5.62 1,294.37 MWD+IFR-AK-CAZ-SC (3) 6,075.66 85.52 124.83 3,779.00 3,667.50 -1,318.77 3,979.66 5,958,392.26 564,480.39 6.65 1,318.77 MWD+IFR-AK-CAZ-SC (3) 4/4/2008 2:36:19PM Page 4 COMPASS 2003.18 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1D-141 Wellbore: 1 D-141A Design: 1 D-141A Survey ConocoPhillips or its affiliates Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference.: North Reference: Survey Calculation Method: Database: Well 1 D-141 1 D-141A @ 111.50ft (D15 (70.7+40.8)) 1D-141A @ 111.50ft (D15 (70.7+40.8)) True Minimum Curvature EDM Alaska Prod v16 Map Map Vertical MD Inc Azi ND NDSS +N!-S +FJ-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 6,119.69 87.36 726.67 3,787.73 3,670.23 -7,344.45 4,015.32 5,958,3uu.iio 564,516.25 5.90 1,344.45 MVVt)+IFR-AK-CAC-SC (3) 6,125.00 87.98 126.88 3,781.95 3,670.45 -1,347.62 4,019.57 5,958,363.74 564,520.52 12.33 1,347.62 MWD+IFR-AK-CAZ-SC (4) 6,173.36 80.37 130.43 3,786.85 3,675.35 -1,377.64 4,057.12 5,958,334.03 564,558.30 17.35 1,377.64 MWD+IFR-AK-CAZ-SC (4) 6,205.26 80.84 131.97 3,792.06 3,680.56 -1,398.37 4,080.79 5,958,313.49 564,582.15 4.99 1,398.37 MWD+IFR-AK-CAZ-SC (4) 6,235.24 83.02 134.53 3,796.27 3,684.77 -1,418.70 4,102.41 5,958,293.33 564,603.92 11.15 1,418.70 MWD+IFR-AK-CAZ-SC (4) 6,264.54 86.01 137.32 3,799.07 3,687.57 -1,439.65 4,122.69 5,958,272.54 564,624.37 13.93 1,439.65 MWD+IFR-AK-CAZ-SC (4) 6,293.92 89.72 140.17 3,800.16 3,688.66 -1,461.72 4,142.05 5,958,250.64 564,643.90 15.92 7,461.72 MWD+IFR-AK-CAZ-SC (4) 6,331.59 90.40 141.56 3,800.13 3,688.63 -1,490.94 4,165.82 5,958,221.61 564,667.91 4.11 1,490.94 MWD+IFR-AK-CAZ-SC (4) 6,361.60 89.60 144.03 3,800.13 3,688.63 -1,514.84 4,183.97 5,958,197.86 564,686.24 8.65 1,514.84 MWD+IFR-AK-CAZ-SC (4) 6,390.61 91.82 147.28 3,799.77 3,688.27 -1,538.79 4,200.33 5,958,174.05 564,702.80 13.57 1,538.79 MWD+IFR-AK-CAZ-SC (4) 6,435.28 94.86 152.40 3,797.16 3,685.66 -1,577.32 4,222.73 5,958,135.70 564,725.50 13.31 1,577.32 MWD+IFR-AK-CAZ-SC (4) 6,478.54 93.07 155.32 3,794.17 3,682.67 -1,616.06 4,241.74 5,958,097.12 564,744.82 7.90 1,616.06 MWD+IFR-AK-CAZ-SC (4) 6,520.13 90.37 157.50 3,792.92 3,681.42 -1,654.15 4,258.37 5,958,059.17 564,761.76 8.34 1,654.15 MWD+IFR-AK-CAZ-SC (4) 6,564.32 88.92 160.42 3,793.20 3,681.70 -1,695.39 4,274.23 5,958,018.06 564,777.95 7.38 1,695.39 MWD+IFR-AK-CAZ-SC (4) 6,608.40 88.67 164.50 3,794.72 3,682.62 -1,737.40 4,287.51 5,957,976.16 564,791.57 9.27 7,737.40 MWD+IFR-AK-CAZ-SC (4) 6,652.54 88.61 168.36 3,795.17 3,683.67 -1,780.29 4,297.86 5,957,933.36 564,802.26 8.74 1,780.29 MWD+IFR-AK-CAZ-SC (4) 6,697.41 91.02 172.20 3,795.32 3,683.82 -1,824.50 4,305.44 5,957,889.22 564,810.19 10.10 1,824.50 MWD+IFR-AK-CAZ-SC (4) 6,741.58 92.87 176.07 3,793.82 3,682.32 -1,868.41 4,309.95 5,957,845.36 564,815.05 9.71 7,868.41 MWD+IFR-AK-CAZ-SC (4) 6,785.64 91.82 179.38 3,792.01 3,680.51 -1,912.39 4,311.69 5,957,801.39 564,817.15 7.88 1,912.39 MWD+IFR-AK-CAZ-SC (4) 6,829.59 90.28 182.12 3,791.21 3,679.71 -7,956.32 4,311.12 5,957,757.46 564,816.93 7.15 1,956.32 MWD+IFR-AK-CAZ-SC (4) 6,873.74 89.72 185.42 3,791.21 3,679.71 -2,000.37 4,308.21 5,957,713.39 564,814.38 7.58 2,000.37 MWD+IFR-AK-CAZ-SC (4) 6,917.53 88.83 188.55 3,791.76 3,680.26 -2,043.83 4,302.89 5,957,669.90 564,809.41 7.43 2,043.83 MWD+IFR-AK-CAZ-SC (4) i 6,961.53 88.67 192.33 3,792.72 3,687.22 -2,087.08 4,294.92 5,957,626.59 564,801.79 8.60 2,087.08 MWD+IFR-AK-CAZ-SC (4) 7,005.41 88.30 195.94 3,793.88 3,682.38 -2,129.61 4,284.21 5,957,583.98 564,791.42 8.27 2,129.61 MWD+IFR-AK-CAZ-SC (4) 7,049.74 90.35 200.35 3,794.40 3,682.90 -2,171.72 4,270.41 5,957,541.76 564,777.96 10.97 2,171.72 MWD+IFR-AK-CAZ-SC (4) 7,094.49 94.66 203.12 3,792.45 3,680.95 -2,213.23 4,253.86 5,957,500.12 564,761.75 11.44 2,213.23 MWD+IFR-AK-CAZ-SC (4) 7,138.84 94.56 204.01 3,788.88 3,677.38 -2,253.75 4,236.19 5,957,459.46 564,744.41 2.01 2,253.75 MWD+IFR-AK-CAZ-SC (4) 7,184.85 93.58 203.42 3,785.62 3,674.12 -2,295.77 4,217.73 5,957,417.30 564,726.29 2.48 2,295.77 MWD+IFR-AK-CAZ-SC (4) 7,274.03 94.88 201.97 3,779.04 3,667.54 -2,377.82 4,183.42 5,957,334.99 564,692.64 2.18 2,377.82 MWD+IFR-AK-CAZ-SC (4) 7,368.82 92.22 201.02 3,773.17 3,661.67 -2,465.84 4,148.76 5,957,246.70 564,658.69 2.98 2,465.84 MWD+IFR-AK-CAZ-SC (4) 7,471.45 92.29 199.09 3,771.49 3,659.99 -2,505.85 4,134.75 5,957,206.58 564,644.41 4.53 2,505.85 MWD+IFR-AK-CAZ-SC (4) 7,462.48 91.97 195.94 3,769.60 3,658.10 -2,554.47 4,118.80 5,957,157.84 564,629.46 6.20 2,554.47 MWD+IFR-AK-CAZ-SC (4) 7,507.38 92.10 192.79 3,768.00 3,656.50 -2,597.94 4,107.67 5,957,114.29 564,618.68 7.02 2,597.94 MWD+IFR-AK-CAZSC (4) 7,551.57 91.42 190.55 3,766.65 3,655.15 -2,641.19 4,098.74 5,957,070.97 564,610.09 5.30 2,641.19 MWD+IFR-AK-CAZ-SC (4) 7,596.61 91.42 189.92 3,765.53 3,654.03 -2,685.50 4,090.74 5,957,026.60 564,602.45 1.40 2,685.50 MWD+IFR-AK-CAZ-SC (4) 7,620.34 90.99 189.93 3,765.03 3,653.53 -2,708.87 4,086.65 5,957,003.20 564,598.55 1.81 2,708.87 MWD+IFR-AK-CAZ-SC (4) 7,650.24 91.24 190.44 3,764.45 3,652.95 -2,738.29 4,081.36 5,956,973.74 564,593.50 1.90 2,738.29 MWD+IFR-AK-CAZ-SC (4) 7,693.78 91.92 189.84 3,763.25 3,651.75 -2,781.14 4,073.70 5,956,930.84 564,586.19 2.08 2,781.14 MWD+IFR-AK-CAZ-SC (4) 7,720.35 90.60 188.48 3,762.66 3,651.16 -2,807.36 4,069.47 5,956,904.59 564,582.17 7.13 2,807.36 MWD+IFR-AK-CAZ-SC (4) 7,743.27 69.82 187.83 3,762.58 3,651.08 -2,830.05 4,066.22 5,956,881.88 564,579.10 4.43 2,830.05 MWD+IFR-AK-CAZ-SC (4) 4/4/2008 2:36:19PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: 1D-141A @ 111.50ft (D15 (70.7+40.8)) Site: Kuparuk 1D Pad MD Reference: iD-141A @ 111.SOft (D15 (70.7+40.8)) Well: 1D-141 North Reference: True Wellbore: 1D-141A Survey Calculation Method: Minimum Curvature Design: 1D-141A Database:. EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azt TVD TVDSS +N/-S +E!-W Northing Easting DLS Section lft) (°) (°) (ft) lh1 Ift) (tt) (ft) (ft) (°1100') (ft) Survey Tool Name 7,786.43 92.66 190.88 3,761.65 3,650.15 -2,872.07 x,059.21 5,956,839.26 tma,5i2.a3 9.65 2,872.61 IvYv`vD+IrR-i~K-CAZ-SC (4) 7,631.64 91.30 190.40 3,760.08 3,648.58 -2,917.02 4,050.87 5,956,794.79 564,564.45 3.19 2,917.02 MWD+IFR-AK-CAZ-SC (4) 7,876.34 90.50 189.84 3,759.38 3,647.88 -2,961.02 4,043.01 5,956,750.74 564,556.95 2.18 2,961.02 MWD+IFR-AK-CAZ-SC (4) 7,921.46 90.25 187.82 3,759.09 3,647.59 -3,005.60 4,036.09 5,956,706.10 564,550.38 4.51 3,005.60 MWD+IFR-AK-CAZ-SC (4) 7,967.46 90.00 185.60 3,758.99 3,647.49 -3,051.28 4,030.71 5,956,660.38 564,545.38 4.86 3,051.28 MWD+IFR-AK-CAZ-SC (4) 8,012.40 90.50 183.93 3,758.79 3,647.29 -3,096.06 4,026.98 5,956,615.58 564,542.01 3.88 3,096.06 MWD+IFR-AK-CAZ-SC (4) 8,057.49 89.57 185.34 3,758.76 3,647.26 -3,141.01 4,023.34 5,956,570.61 564,538.73 3.75 3,141.01 MWD+IFR-AK-CAZ-SC (4) 8,104.60 90.07 184.47 3,758.91 3,647.41 -3,187.94 4,019.31 5,956,523.65 564,535.08 2.13 3,187.94 MWD+IFR-AK-CAZ-SC (4) 8,163.35 89.51 183.45 3,759.13 3,647.63 -3,246.55 4,015.25 5,956,465.02 564,531.49 1.98 3,246.55 MWD+IFR-AK-CAZ-SC (4) 8,212.05 90.37 182.23 3,759.18 3,647.68 -3,295.19 4,012.84 5,956,416.36 564,529.47 3.06 3,295.19 MWD+IFR-AK-CAZ-SC (4) 8,305.99 90.68 181.50 3,758.32 3,646.82 -3,389.07 4,009.78 5,956,322.47 564,527.17 0.84 3,389.07 MWD+IFR-AK-CAZ-SC (4) 8,399.69 89.63 184.81 3,758.06 3,646.56 -3,482.62 4,004.63 5,956,228.89 564,522.77 3.71 3,482.62 MWD+IFR-AK-CAZ-SC (4) 8,493.92 90.31 183.88 3,758.11 3,646.61 -3,576.58 3,997.49 5,956,134.89 564,516.36 1.22 3,576.58 MWD+IFR-AK-CAZ-SC (4) 8,587.11 90.99 181.88 3,757.05 3,645.55 -3,669.64 3,992.81 5,956,041.80 564,512.45 2.27 3,669.64 MWD+IFR-AK-CAZ-SC (4) 8,679.62 90.81 177.57 3,755.60 3,644.10 -3,762.11 3,993.25 5,955,949.34 564,513.64 4.66 3,762.11 MWD+IFR-AK-CAZ-SC (4) 8,724.34 89.94 174.46 3,755.31 3,643.81 -3,606.72 3,996.36 5,955,904.77 564,517.11 7.22 3,806.72 MWD+IFR-AK-CAZ-SC (4) 8,769.32 90.25 171.41 3,755.23 3,643.73 -3,851.35 4,001.89 5,955,860.19 564,523.00 6.82 3,851.35 MWD+IFR-AK-CAZ-SC (4) 8,813.42 92.29 170.89 3,754.26 3,642.76 -3,894.91 4,008.67 5,955,816.68 564,530.13 4.77 3,894.91 MWD+IFR-AK-CAZ-SC (4) 8,857.47 90.43 173.78 3,753.21 3,641.71 -3,938.55 4,014.54 5,955,773.10 564,536.35 7.80 3,938.55 MWD+IFR-AK-CAZ-SC (4) 8,901.84 91.54 175.67 3,752.45 3,640.95 -3,982.72 4,018.62 5,955,728.97 564,540.79 4.94 3,982.72 MWD+IFR-AK-CAZ-SC (4) 8,945.32 89.32 179.13 3,752.12 3,640.62 -0,026.15 4,020.59 5,955,685.56 564,543.11 9.45 4,026.15 MWD+IFR-AK-CAZ-SC (4) 8,990.30 88.46 181.65 3,752.99 3,641.49 -0,071.11 4,020.29 5,955,640.60 564,543.16 5.92 4,071.11 MWD+IFR-AK-CAZ-SC (4) 9,035.30 90.81 184.56 3,753.28 3,641.78 -4,116.04 4,017.85 5,955,595.66 564,541.09 8.31 4,116.04 MWD+IFR-AK-CAZ-SC (4) 9,080.36 90.25 186.39 3,752.86 3,641.36 -0,160.89 4,013.55 5,955,550.78 564,537.15 4.25 4,160.89 MWD+IFR-AK-CAZ-SC (4) 9,149.89 88.58 185.90 3,753.57 3,642.07 -0,230.01 4,006.11 5,955,481.61 564,530.27 2.50 4,230.01 MWD+IFR-AK-CAZ-SC (4) 9,243.83 90.25 185.46 3,754.53 3,643.03 -0,323.48 3,996.81 5,955,388.07 564,521.72 1,84 4,323.48 MWD+IFR-AK-CAZ-SC (4) 9,337.43 89.26 187.59 3,754.93 3,643.43 -4,416.47 3,986.18 5,955,295.01 564,511.84 2.51 4,416.47 MWD+IFR-AK-CAZ-SC (4) 9,430.92 90.19 190.21 3,755.38 3,643.88 -4,508.82 3,971.72 5,955,202.55 564,498.12 2.97 4,508.82 MWD+IFR-AK-CAZ-SC (4) 9,524.87 90.19 188.61 3,755.07 3,643.57 -4,601.51 3,956.36 5,955,109.76 564,483.51 1.70 4,601.51 MWD+IFR-AK-CAZ-SC (4) 9,618.95 90.31 188.55 3,754.66 3,643.16 -0,694.53 3,942.32 5,955,016.63 564,470.22 0.14 4,694.53 MWD+IFR-AK-CAZ-SC (4) 9,712.66 90.62 187.57 3,753.90 3,642.40 -4,787.31 3,929.18 5,954,923.76 564,457.83 1.10 4,787.31 MWD+IFR-AK-CAZ-SC (4) 9,806.62 91.55 189.26 3,752.12 3,640.62 -0,880.24 3,915.43 5,954,830.73 564,444.84 2.05 4,880.24 MWD+IFR-AK-CAZ-SC (4) 9,887.38 89.82 188.67 3,751.15 3,639.65 -0,960.00 3,902.85 5,954,750.88 564,432.90 2.26 4,960.00 MWD+IFR-AK-CAZ-SC (4) 9,925.80 89.82 188.67 3,751.27 f 3,639.77 -4,997.99 3,897.06 5,954,712.85 564,427.41 0.00 4,997.99 PROJECTED to TD 4/4/2008 2:36:19PM Page 6 COMPASS 2003.16 Build 42F ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-141APB1 50-029-22967-70 ~. ~~ '~ ,_r Definitive Survey Report 04 April, 2008 ~' Sperry Drilling Services i ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1D Pad MD Reference: Well: 1D-141 North Reference: Wellbore: 1D-141APB1 Survey Calculation Method: Design: 1D-141APB1 Database: Well 1 D-141 I D-141A @ 111.SOft (D15 (70.7+40.8)) I D-141A @ 111.50ft (D15 (70.7+40.8)) True Minimum Curvature EDM Alaska Prod v16 i -- __ '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 1D-141 Well Position +NIS 0.00 ft Northing: 5,959,678.83 ft Latitude: 70° 18' 1.455 N +EI-W 0.00 ft Easting: 560,490.62 ft Longitude: 149° 30' 36.290 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70ft Wellbore 1D-141APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2u07 10;312007 1 10 79J4 BGGM2007 3/112008 17.y4 73.75 ~ Design 1D-141APB1 Audit Notes: I Version: 1.0 Phase: ACTUAL Tie On Depth: 5,486.19 Vertical Section: Depth From (TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (°) I 40.80 0.00 0.00 180.00 Survey Program Date From To (ft) (h) Survey (Wellbore) 105.45 646.551D-141P61gyro(1D-141P61) 681.46 5,486.19 1D-141PB1 (1D-141PB1) 5,502.00 6,633.72 1D-141AP61 MWD+SAG+CA+IIFR+MS Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 57,259 57.274 J Survey Start Date 04/04/2008 04/04/2008 04/04/2008 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (tt) Survey Tool Name ~ 4u,tiu O.uu u.u0 4U. W7 -7u.7U uA0 u.uu 5,b5b,o7d.bs 5ou,4bQ.o2 uuu u.uU UNDEFINED 105.45 0.10 330.50 105.45 -6.05 0.05 -0.03 5,959,678.88 560,490.59 0.15 -0.05 CB-GYRO-SS (1) 200.45 0.30 315.40 200.45 88.95 0.30 -0.24 5,959,679.13 560,490.37 0.22 -0.30 CB-GYRO-SS (1) 295.45 0.30 25.10 295.45 183.95 0.70 -0.31 5,959,679.53 560,490.30 0.36 -0.70 CB-GYRO-SS (1) 318.45 0.30 303.60 318.45 206.95 0.79 -0.34 5,959,679.62 560,490.28 1.70 -0.79 CB-GYRO-SS (1) 348.45 0.30 303.00 348.45 236.95 0.87 -0.47 5,959,679.70 560,490.14 0.01 -0.87 CB-GYRO-SS (1) 390.45 0.00 0.00 390.45 278.95 0.93 -0.56 5,959,679.76 560,490.05 0.71 -0.93 CB-GYRO-SS (1) 414.45 0.40 346.80 414.45 302.95 1.02 -0.58 5,959,679.84 560,490.03 1.67 -1.02 CB-GYRO-SS (1) 460.45 0.40 31.60 460.45 348.95 1.31 -0.53 5,959,680.13 560,490.08 0.66 -1.31 CB-GYRO-SS (1) 493.45 1.90 38.60 493.44 387.94 1.83 -0.13 5,959,680.66 560,490.47 4.56 -1.83 CB-GYRO-SS (1) 530.45 1.10 32.00 530.43 418.93 2.62 0.44 5,959,681.45 560,491.04 2.21 -2.62 CB-GYRO-SS (1) 4/4/2008 2:29:14PM Page 2 COMPASS 2003.16 Build 42F • ConocoPhillips or its affiliates Definitive Survey Report 'Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1D-141 Wellbore: 1D-141AP61 Design: 1D-141AP61 Survey Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: MD Inc Azi ND NDSS +N/-S +E/-W (ft) (°) (°) Ift) Ift) (ft) (ft) 549.45 1.10 X5.10 549.42 457.92 1.83 0. 587.45 3.10 111.90 587.40 475.90 2.87 1. 646.45 6.40 116.60 646.19 534.69 0.81 6. 681.46 8.3i 120.17 680.91 569.41 -1.34 10. 714.62 8.45 119.15 713.71 602.21 -3.73 14. 748.20 9.27 116.77 746.89 635.39 -6.15 18. 777.47 10.62 117.25 775.72 664.22 -8.45 23. 811.34 11.84 116.08 808.94 697.44 -11.40 29. 843.66 13.99 112.15 840.45 728.95 -14.33 35. 873.61 17.20 110.68 869.29 757.79 -17.26 43. 908.63 20.11 109.71 902.47 790.97 -21.12 53. 940.81 20.54 110.98 932.64 821.14 -25.01 64. 970.89 21.52 110.46 960.72 849.22 -28.83 74. 1,005.44 23.24 111.69 992.67 881.17 -33.56 86. 1,037.35 24.13 112.22 1,021.89 910.39 -38.36 98. 1,067.31 24.70 111.43 1,049.17 937.67 -42.96 110. 1,163.67 26.43 113.69 1,136.09 1,024.59 -58.93 148. 1,259.90 30.34 115.14 1,220.74 1,109.24 -77.87 190. 1,355.72 33.44 116.08 1,302.09 1,190.59 -99.76 235. 1,452.67 33.40 114.53 1,383.01 1,271.51 -122.59 284. 1,549.88 35.63 111.32 1,463.11 1,351.61 -143.99 334. 1,646.69 39.28 112.00 1,539.95 1,428.45 -165.73 389. 1,742.09 42.92 113.31 1,611.83 1,500.33 -189.91 447. 1,838.15 44.12 113.98 1,681.48 1,569.98 -216.44 507. 1,934.22 44.49 113.15 1,750.23 1,638.73 -243.27 569. 2,030.35 48.00 116.14 1,816.71 1,705.21 -272.26 632. 2,126.80 51.41 113.67 1,879.08 1,767.58 -303.19 699. 2,223.14 55.85 113.16 1,936.20 1,824.70 -334.00 770. 2,318.81 59.53 111.66 1,987.33 1,875.83 -364.80 845. 2,413.93 60.15 107.25 2,035.13 1,923.63 -392.17 922. 2,509.34 60.67 106.35 2,082.25 1,970.75 -416.15 1,002. 2,605.40 60.88 106.69 2,129.15 2,017.65 -439.99 1,082. 2,700.89 61.36 107.31 2,175.27 2,063.77 -464.44 1,162. 2,796.49 60.58 104.62 2,221.67 2,110.17 -087.43 1,242. 2,892.79 59.47 103.82 2,269.78 2,158.28 -507.93 1,323. 2,989.04 58.76 103.50 2,319.19 2,207.69 -527.43 1,403. 3,084.63 57.96 105.90 2,369.34 2,257.84 -548.08 1,482. 3,180.93 59.65 105.81 2,419.21 2,307.71 -570.58 1,561. 3,277.10 58.12 106.87 2,468.91 2,357.41 -593.74 1,640. 3,373.89 60.56 106.90 2,516.26 2,406.76 -617.92 1,720. Map Northing (ft) 65 5,959,681.77 83 5,959,681.72 26 5,959,679.69 19 5,959,677.57 39 5,959,675:22 96 5,959,672.83 46 5,959,670.57 36 5,959,667.66 95 5,959,664.79 45 5,959,661.92 97 5,959,658.14 45 5,959,654.34 54 5,959,650.60 81 5,959,645.97 70 5,959,641.27 20 5,959,636.76 58 5,959,621.10 2t 5,959,602.50 84 5,959,580.98 11 5,959,558.54 84 5,959,537.55 54 5,959,516.25 40 5,959,492.55 99 5,959,466.50 49 5,959,440.18 56 5,959,411.70 28 5,959,381.30 45 5,959,351.07 19 5,959,320.88 71 5,959,294.13 14 5,959,270.80 51 5,959,247.61 47 5,959,223.81 82 5,959,201.46 68 5,959,181.62 95 5,959,162.76 66 5,959,142.76 90 5,959,120.90 90 5,959,098.38 57 5,959,074.84 Well 1 D-141 1 D-141A @ 111.50k (D15 (70.7+40.8)) 1 D-141A @ 111.50ft (D15 (70.7+40.8)) True Minimum Curvature EDM Alaska Prod v16 Map Vertical Fasting DLS Section (ft) (°/100') (ft) Survey Tool Name 560,491.15 0.63 -2.93 GB-GiRIi-Ja (1/ 560,492.43 8.04 -2.87 CB-GYRO-SS (1) 560,496.87 5.63 -0.81 CB-GYRO-SS (t) 560,500.82 5.61 1.34 MWD (2) 560,505.04 0.62 3.73 MWD (2) 560,509.62 2.67 6.15 MWD (2) 560,514.15 4.62 8.45 MWD (2) 560,520.06 3.66 11.40 MWD (2) 560,526.68 7.18 14.33 MWD (2) 560,534.21 10.80 17.26 MWD (2) 560,544.75 8.36 21.12 MWD (2) 560,555.26 1.91 25.01 MWD (2) 560,565.38 3.32 28.83 MWD (2) 560,577.69 5.16 33.56 MWD (2) 560,589.62 2.87 38.36 MWD (2) 560,601.15 2.19 42.96 MWD (2) 560,639.66 2.06 58.93 MWD (2) 560,681.43 4.13 77.87 MWD (2) 560,727.24 3.28 99.76 MWD (2) 560,775.68 0.88 122.59 MWD (2) 560,826.58 2.96 143.99 MWD (2) 560,881.45 3.79 165.73 MWD (2) 560,939.49 3.92 189.91 MWD (2) 561,000.28 1.34 216.44 MWD (2) 561,062.00 0.72 243.27 MWD (2) 561,125.29 4.29 272.26 MWD (2) 561,192.25 4.04 303.19 MWD (2) 561,263.66 4.63 334.00 MWD (2) 561,338.64 4.07 364.80 MWD (2) 561,416.37 4.06 392.17 MWD (2) 561,495.98 0.98 416.15 MWD (2) 561,576.53 0.38 439.99 MWD (2) 561,656.68 0.76 464.44 MWD (2) 561,737.21 2.59 487.43 MWD (2) 561,818.22 1.36 507.93 MWD (2) 561,898.63 0.79 527.43 MWD (2) 561,977.50 2.30 548.08 MWD (2) 562,056.91 1.76 570.58 MWD (2) 562,136.09 1.85 593.74 MWD (2) 562,215.94 2.52 617.92 MWD (2) 4/4/2008 2:29:14PM Page 3 COMPASS 2003.16 Build 42F Conoco Phillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc . Local Go-ordi nate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: 1D-1 41A @ 1 11.SOft (D15 (70.7+40.8)) Site Kuparuk 1D Pad MD Reference: iD-1 41A @ 1 11.SOft (D15 (70.7+40.8)) Well: 1D-1 41 North Referen ce: True Wellbore: 1D-1 41APB1 Survey Calcu lation Method: Minimum Curvature Design: 1D-1 41APB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azl ND NDSS +N!-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,459.au 59.32 106.84 2,566.35 2,454.85 -642.03 i,8u0.u9 5,95ti,u51.37 562,295.64 1.29 642.03 MWD (2f 3,566.00 59.39 107.38 2,615.34 2,503.84 -666.36 1,879.10 5,959,027.68 562,374.85 0.49 666.36 MWD (2) 3,662.85 59.40 107.48 2,664.65 2,553.15 -691.33 1,958.64 5,959,003.36 562,454.57 0.09 691.33 MWD (2) 3,758.65 60.67 106.53 2,712.49 2,600.99 -715.59 2,038.00 5,958,979.73 562,534.12 1.58 715.59 MWD (2) 3,855.13 61.02 106.30 2,759.50 2,648.00 -739.40 2,118.82 5,958,956.58 562,615.12 0.42 739.40 MWD (2) 3,951.44 60.98 105.98 2,806.19 2,694.69 -762.82 2,199.74 5,958,933.81 562,696.21 0.29 762.82 MWD (2) 4,048.08 61.10 106.62 2,852.98 2,741.48 -786.55 2,280.89 5,958,910.74 562,777.55 0.59 786.55 MWD (2) 4,144.45 59.87 106.08 2,900.46 2,788.96 -810.16 2,361.36 5,958,887.78 562,858.20 1.37 810.16 MWD(2) 4,240.41 59.61 105.60 2,948.82 2,837.32 -832.79 2,441.10 5,958,865.80 562,938.11 0.51 832.79 MWD (2) 4,336.22 60.46 104.93 2,996.67 2,885.17 -854.64 2,521.17 5,956,844.60 563,018.35 1.07 854.64 MWD (2) 4,431.89 58.75 106.66 3,045.08 2,933.58 -877.09 2,600.57 5,958,822.79 563,097.92 2.37 877.09 MWD (2) 4,528.51 58.54 106.72 3,095.35 2,983.85 -900.78 2,679.61 5,958,799.73 563,177.14 0.22 900.78 MWD (2) 4,624.58 58.80 106.32 3,145.30 3,033.80 -924.12 2,758.28 5,958,777.04 563,255.99 0.45 924.12 MWD (2) 4,719.45 58.69 107.40 3,194.53 3,083.03 -947.64 2,835.90 5,958,754.14 563,333.78 0.98 947.64 MWD (2) 4,816.43 59.02 106.89 3,244.69 3,133.19 -972.10 2,915.21 5,958,730.32 563,413.28 0.56 972.10 MWD (2) 4,911.88 58.61 107.64 3,294.11 3,182.61 -996.34 2,993.19 5,958,706.71 563,491.44 0.80 996.34 MWD (2) 5,007.61 59.20 105.81 3,343.55 3,232.05 -1,019.92 3,071.69 5,958,683.76 563,570.12 1.75 1,019.92 MWD (2) 5,105.00 59.33 105.41 3,393.33 3,281.83 -1,042.45 3,152.31 5,958,661.89 563,650.92 0.38 1,042.45 MWD (2) 5,200.38 59.01 105.24 3,442.21 3,330.71 -1,064.09 3,231.30 5,958,640.88 563,730.07 0.37 1,064.09 MWD (2) 5,294.22 58.34 105.58 3,491.00 3,379.50 -1,085.39 3,308.58 5,958,620.21 563,807.51 0.78 1,085.39 MWD (2) 5,390.16 59.75 104.29 3,540.34 3,428.84 -1,106.59 3,388.07 5,958,599.65 563,887.17 1.87 1,106.59 MWD (2) 5,486.19 59.50 104.23 3,588.90 3,477.40 -1,127.00 3,468.37 5,958,579.89 563,967.62 0.27 1,127.00 MWD (2) 5,502.00 59.83 104.97 3,596.89 3,485.39 -1,130.44 3,481.57 5,958,576.56 563,980.85 4.55 1,130.44 MWD+IFR-AK-CAZ-SC (3) 5,531.65 61.28 104.16 3,611.46 3,499.96 -1,136.93 3,506.56 5,958,570.27 564,005.88 5.44 1,136.93 MWD+IFR-AK-CAZ-SC (3) 5,559.63 62.30 103.41 3,624.69 3,513.19 -1,142.80 3,530.51 5,958,564.59 564,029.87 4.34 1,142.80 MWD+IFR-AK-CAZ-SC (3) 5,580.58 62.00 102.86 3,634.48 3,522.98 -1,147.01 3,548.55 5,958,560.53 564,047.95 2.73 1,147.01 MWD+IFR-AK-CAZ-SC (3) 5,610.34 61.80 102.08 3,648.49 3,536.99 -1,152.68 3,574.18 5,958,555.07 564,073.62 2.41 1,152.68 MWD+IFR-AK-CAZ-SC (3) 5,641.78 63.97 101.27 3,662.82 3,551.32 -1,158.34 3,601.58 5,958,549.63 564,101.07 7.27 1,158.34 MWD+IFR-AK-CAZ-SC (3) 5,673.51 65.19 100.47 3,676.44 3,564.94 -1,163.75 3,629.73 5,958,544.45 564,129.25 4.47 1,163.75 MWD+IFR-AK-CAZ-SC (3) 5,701.79 66.41 99.78 3,688.04 3,576.54 -1,168.28 3,655.12 5,958,540.12 564,154.67 4.B5 1,168.28 MWD+IFR-AK-CAZ-SC (3) 5,732.13 67.57 102.17 3,699.90 3,588.40 -1,173.60 3,682.53 5,958,535.02 564,182.13 8.20 1,173.60 MWD+IFR-AK-CAZ-SC (3) 5,763.66 69.45 105.19 3,711.45 3,599.95 -1,180.54 3,711.03 5,958,528.31 564,210.68 10.72 1,180.54 MWD+IFR-AK-CAZ-SC (3) 5,793.64 71.63 108.37 3,721.44 3,609.94 -1,188.70 3,738.09 5,958,520.37 564,237.80 12.36 1,188.70 MWD+IFR-AK-CAZ-SC (3) 5,824.51 72.97 110.11 3,730.82 3,619.32 -1,198.40 3,765.85 5,958,510.90 564,265.63 6.90 1,198.40 MWD+IFR-AK-CAZ-SC (3) 5,856.25 74.23 114.28 3,739.79 3,628.29 -1,209.90 3,794.03 5,958,499.63 564,293.91 13.21 1,209.90 MWD+IFR-AK-CAZ-SC (3) 5,900.33 75.93 117.50 3,751.14 3,639.64 -1,228.50 3,632.34 5,958,481.34 564,332.36 8.04 1,228.50 MWD+IFR-AK-CAZ-SC (3) 5,943.96 78.66 119.22 3,760.74 3,649.24 -1,248.71 3,869.79 5,958,461.42 564,369.97 7.34 1,248.71 MWD+IFR-AK-CAZ-SC (3) 5,987.70 80.79 122.45 3,768.54 3,657.04 -1,270.77 3,906.74 5,958,439.67 564,407.08 8.75 1,270.77 MWD+IFR-AK-CAZ-SC (3) 6,031.75 83.19 123.06 3,774.68 3,663.18 -1,294.37 3,943.42 5,958,416.36 564,443.95 5.62 1,294.37 MWD+IFR-AK-CAZ-SC (3) 6,075.66 85.52 124.83 3,779.00 3,667.50 -1,318.77 3,979.66 5,958,392.26 564,480.39 6.65 1,318.77 MWD+IFR-AK-CAZ-SC (3) 4/4/2008 2:29:14PM Page 4 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site Kuparuk 1D Pad Well: 1D-141 Wellbore: 1D-141APB1 Design: 1D-141APB1 Survey MD Inc lft) (°) 6,1-19.69 87.36 6,164.06 92.52 6,208.65 90.76 6,237.92 89.53 6,280.62 89.90 6,323.66 89.15 6,367.63 88.29 6,410.72 90.23 6,453.64 88.92 6,495.66 88.71 6,519.84 90.14 6,563.67 93.04 6,607.44 92.85 6,633.72 93.81 Azi (°) 126.61 128.40 130.88 133.71 137.63 140.58 143.83 148.38 151.58 154.48 156.66 159.08 163.25 166.49 ND NDSS fft) (ftl 3,781.73 3,670.23 3,781.78 3,670.28 3,780.50 3,669.00 3,780.43 3,668.93 3,780.64 3,669.14 3,781.00 3,669.50 3,781.98 3,670.48 3,782.54 3,671.04 3,782.85 3,671.35 3,783.72 3,672.22 3,783.97 3,672.47 3,782.75 3,671.25 3,780.50 3,669.00 3,778.97 3,667.47 6,680.00 93.81 166.49 3,775.90 3,664.40 ConocoPhillips or its affiliates Definitive Survey Report Local Co-ordinate Reference: `/Vell 1D-141 ND Reference: 1D-141A @ 1 11.SOk (D15 (70.7+40.8)) MD Reference: 1 D-141A @ 1 11.50ft (D15 (70.7+40.8)) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska Prod v16 Map Map Vertical +NI-S +E/-W Northing Easting DLS Section (ft) (ft) (ft) (ft) (`/100') (ft) Survey Tool Name -1,saa.a5 4,015.32 5,958,366.88 564,51015 5.ti0 1,3aa.a5 MvYL+il=k-Ali-CAZ-SG (3) -1,371.47 4,050.49 5,958,340.14 564,551.63 12.27 1,371.47 MWD+IFR-AK-CAZ-SC (3) -1,399.90 4,084.81 5,958,311.99 564,586.18 6.82 1,399.90 MWD+IFR-AK-CAZ-SC (3) -1,419.59 4,106.46 5,958,292.47 564,607.98 10.54 1,419.59 MWD+IFR-AK-CAZ-SC (3) -1,450.13 4,136.29 5,958,262.18 564,638.06 9.22 1,450.13 MWD+IFR-AK-CAZ-SC (3) -1,482.66 4,164.47 5,958,229.88 564,666.49 7.07 1,482.66 MWD+IFR-AK-CAZ-SC (3) -1,517.39 4,191.40 5,956,195.37 564,693.70 7.64 1,517.39 MWD+IFR-AK-CAZ-SC (3) -1,553.15 4,215.42 5,958,159.81 564,718.00 11.48 1,553.15 MWD+IFR-AK-CAZ-SC (3) -1,590.30 4,236.89 5,958,122.84 564,739.77 8.06 1,590.30 MWD+IFR-AK-CAZ-SC (3) -1,627.74 4,255.94 5,958,085.56 564,759.12 6.92 1,627.74 MWD+IFR-AK-CAZ-SC (3) -1,649.75 4,265.94 5,958,063.63 564,769.29 10.78 1,649.75 MWD+IFR-AK-CAZ-SC (3) -1,690.33 4,282.44 5,958,023.19 564,786.12 8.62 1,690.33 MWD+IFR-AK-CAZ-SC (3) -1,731.69 4,296.55 5,957,981.94 564,800.56 9.52 1,731.69 MWD+IFR-AK-CAZ-SC (3) -1,757.02 4,303.40 5,957,956.68 564,807.61 12.84 1,757.02 MWD+IFR-AK-CAZ-SC (3) -1,801.92 4,314.19 5,957,911.87 564,818.76 0.00 1,801.92 PROJECTED to TD 4/4/2008 2:29:14PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-141 APB2 50-029-22967-72 ~:j°~ .~ ~ .. - Definitive Survey Report 04 April, 2008 W~ ` ~~ :' Sperry Drilling Services • ConocoPhillips or its affiliates Definitive Suivey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1D Pad MD Reference: Well: 1D-141 North Reference: Wellbore: 1D-141APB2 Survey Calculation Method: Design : 1 D-141 AP62 Database: Well 1 D-141 1D-141A @ 111.50ft (D15 (70.7+40.8)) 1 D-141A @ 111.50ft (D15 (70.7+40.8}) True Minimum Curvature EDM Alaska Prod v16 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US Sfate 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 - - 1 D-141 Well Position +NI-S 0.00 ft Northing: 5,959,678.83 ft Latitude: 70° 18' 1.455 N +E/-W 0.00 ft Easting: 560,490.62 ft Longitude: 149° 30' 36.290 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70 ft Wellbore 1D-141AP62 Magnetics Model Name Sample Date Declinatlon Dlp Angle Field Strength 6GGM2007 3/11/2008 17.94 7975 57274 Desi9^ 1D-141AP82 ..._..... _._. ..~ ~ _.... -......... .. Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,495.66 ', Vertical Section: Depth From (TVD) +N/-S +FJ-W Direction ~ (tt) (tt) (ft) (~) ~ 40.50 0 00 0.00 160.00 Survey Program Date ', From To Survey (tt) (ft) Survey (Wellbore) Tool Name Description Start Date ~ 105.45 646.55 1 D-141 P61 gyro (1 U-141 P81} CB-GYRO-SS Camera based gyro single shot 04/04/2008 681.46 5,486.19 1D-141P61 (1D-141PB1) MWD MWD-Standard 04/04/2008 5,502.00 6,495.66 1 D-141APB1 MWD+SAG+CA+IIFR+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 04/04/2008 i 6,500.00 6,983.76 1 D-141APB2 MWD+SAG+CA+IIFR+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 04/04/2008 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.80 0.00 0.00 40.80 -70.70 0.00 0.00 5,959,678.83 560,490.62 0.00 0.00 UNDEFINED 105.45 0.10 330.50 105.45 -6.05 0.05 -0.03 5,959,678.88 560,490.59 0.15 -0.OS CB-GYRO-SS (1) 200.45 0.30 315.40 200.45 86.95 0.30 -0.24 5,959,679.13 560,490.37 0.22 -0.30 CB-GYRO-SS (1) 295.45 0.30 25.10 295.45 183.95 0.70 -0.31 5,959,679.53 560,490.30 0.36 -0.70 CB-GYRO-SS (1) 318.45 0.30 303.60 318.45 206.95 0.79 -0.34 5,959,679.62 560,490.28 1.70 -0.79 CB-GYRO-SS (1) 348.45 0.30 303.00 348.45 236.95 0.87 -0.47 5,959,679.70 560,490.14 0.01 -0.87 CB-GYRO-SS (1) 390.45 0.00 0.00 390.45 278.95 0.93 -0.56 5,959,679.76 560,490.05 0.71 -0.93 CB-GYRO-SS (1) 414.45 0.40 346.80 414.45 302.95 1.02 -0.58 5,959,679.84 560,490.03 1.67 -1.02 CB-GYRO-SS (1) 460.45 0.40 31.60 460.45 348.95 1.31 -0.53 5,959,680.13 560,490.08 0.66 -1.31 CB-GYRO-SS (1) 493.45 1.90 38.60 493.44 361.94 1.83 -0.13 5,959,680.66 560,490.47 4.56 -1.83 CB-GYRO-SS (1) 530.45 1.10 32.00 530.43 418.93 2.62 0.44 5,959,681.45 560,491.04 2.21 -2.62 CB-GYRO-SS (1) 4/4/2008 2:32:39PM Page 2 COMPASS 2003.16 Build 42F Conoco Phillips or its affiliates Definitive Survey Report Company: ConocoPhillips(A laska) Ina Local Co-ordi nate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: ID-1 41A @ 1 11.50ft (D15 (70.7+40.8)) Site: Kuparuk 1D Pad MD Reference: 1D-1 41A @ 1 11.50ft (D15 (70.7+q0.8)) Well: 1D-1 41 North Referen ce: True Wellbore: 1D-1 41AP82 Survey Calcu lation Method: Minimum Curvature Design: 1D-1 41AP62 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc AzI ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (tt) (°1100') (ft) Survey Tool Name 549.45 1.20 35.20 545.42 437.52 2.93 0.65 5,959,681.77 560,491.25 u.63 -2.93 CB-GYRO-SS (1) ~ 587.45 3.10 111.90 587.40 475.90 2.87 1.83 5,959,681.72 560,492.43 8.04 -2.87 CB-GYROSS (1) 646.45 6.40 116.60 646.19 534.69 0.81 6.26 5,959,679.69 560,496.87 5.63 -0.81 CB-GYRO-SS (1) 681.46 8.31 120.17 680.91 569.41 -1.34 10.19 5,959,677.57 560,500.82 5.61 1.34 MWD (2) 714.62 8.45 119.15 713.71 60221 x.73 14.39 5,959,675.22 560,505.04 0.62 3.73 MWD (2) 748.20 9.27 116.77 746.89 635.39 -6.15 18.96 5,959,672.83 560,509.62 2.67 6.15 MWD (2) 777.47 10.62 117.25 775.72 664.22 -8.45 23.46 5,959,670.57 560,514.15 4.62 8.45 MWD (2) 811.34 11.84 116.08 808.94 697.44 -11.40 29.36 5,959,667.66 560,520.06 3.66 11.40 MWD (2) 843.66 13.99 112.15 840.45 728.95 -14.33 35.95 5,959,664.79 560,526.68 7.18 14.33 MWD (2) 873.61 17.20 110.68 869.29 757.79 -17.26 43.45 5,959,661.92 560,534.21 10.80 17.26 MWD (2) 908.63 20.11 109.71 902.47 790.97 -21.12 53.97 5,959,658.14 560,544.75 8.36 21.12 MWD (2) 940.81 20.54 110.98 932.64 821.14 -25.01 64.45 5,959,654.34 560,555.26 1.91 25.01 MWD (2) 970.89 21.52 110.46 960.72 849.22 -28.83 74.54 5,959,650.60 560,565.38 3.32 28.83 MWD (2) 1,005.44 23.24 111.69 992.67 881.17 -33.56 86.81 5,959,645.97 560,577.69 5.16 33.56 MWD (2) 1,037.35 24.13 112.22 1,021.89 910.39 -38.36 98.70 5,959,641.27 560,589.62 2.87 38.36 MWD (2) 1,067.31 24.70 111.43 1,049.17 937.67 -42.96 110.20 5,959,636.76 560,601.15 2.19 42.96 MWD (2) 1,163.67 26.43 113.69 1,136.09 1,024.59 -58.93 148.58 5,959,621.10 560,639.66 2.06 58.93 MWD (2) 1,259.90 30.34 115.14 1,220.74 1,109.24 -77.87 190.21 5,959,602.50 560,681.43 4.13 77.87 MWD (2) 1,355.72 33.44 116.08 1,302.09 1,190.59 -99.76 235.84 5,959,580.98 560,727.24 3.28 99.76 MWD (2) 1,452.67 33.40 114.53 1,383.01 1,271.51 -122.59 284.11 5,959,558.54 560,775.68 0.88 122.59 MWD (2) 1,549.88 35.63 111.32 1,463.11 1,351.61 -143.99 334.84 5,959,537.55 560,826.58 2.96 143.99 MWD (2) 1,646.69 39.28 112.00 1,539.95 1,428.45 -165.73 389.54 5,959,516.25 560,881.45 3.79 165.73 MWD (2) 1,742.09 42.92 113.31 1,611.83 1,500.33 -189.91 447.40 5,959,492.55 560,939.49 3.92 189.91 MWD (2) 1,838.15 44.12 113.98 1,681.48 1,569.98 -216.44 507.99 5,959,466.50 561,000.28 1.34 216.44 MWD (2) 1,934.22 44.49 113.15 1,75023 1,638.73 -243.27 569.49 5,959,440.18 561,062.00 0.72 243.27 MWD (2) 2,030.35 48.00 116.14 1,816.71 1,705.21 -272.26 .632.56 5,959,411.70 561,125.29 4.29 272.26 MWD (2) 2,126.80 51.41 113.67 1,879.08 1,767.58 -303.19 699.26 5,959,381.30 561,192.25 4.04 303.19 MWD (2) 2,223.14 55.85 113.16 1,936.20 1,824.70 -334.00 770.45 5,959,351.07 561,263.66 4.63 334.00 MWD (2) 2,318.81 59.53 111.66 1,987.33 1,875.83 -364.80 845.19 5,959,320.88 561,338.64 4.07 364.80 MWD (2) 2,413.93 60.15 107.25 2,035.13 1,923.63 -392.17 922.71 5,959,294.13 561,416.37 4.06 392.17 MWD (2) 2,509.34 60.67 106.35 2,082.25 1,970.75 -416.15 1,002.14 5,959,270.80 561,495.98 0.98 416.15 MWD (2) 2,605.40 60.88 106.69 2,129.15 2,017.65 -439.99 1,082.51 5,959,247.61 561,576.53 0.38 439.99 MWD (2) 2,700.89 61.36 107.31 2,175.27 2,063.77 -464.44 1,162.47 5,959,223.81 561,656.68 0.76 464.44 MWD (2) 2,796.49 60.58 104.62 2,221.67 2,110.17 -487.43 1,242.82 5,959,201.46 561,737.21 2.59 487.43 MWD (2) 2,892.79 59.47 103.82 2,269.78 2,158.28 -507.93 1,323.68 5,959,181.62 561,818.22 1.36 507.93 MWD (2) 2,989.04 58.76 103.50 2,319.19 2,207.69 -527.43 1,403.95 5,959,162.76 561,896.63 0.79 527.43 MWD (2) 3,084.63 57.96 105.90 2,369.34 2,257.84 -548.08 1,482.66 5,959,142.76 561,977.50 2.30 548.08 MWD (2) 3,180.93 59.65 105.81 2,419.21 2,307.71 -570.58 1,561.90 5,959,120.90 562,056.91 1.76 570.58 MWD (2) 3,277.10 58.12 106.67 2,468.91 2,357.41 -593.74 1,640.90 5,959,098.38 562,136.09 1.85 593.74 MWD (2) 3,373.89 60.56 106.90 2,518.26 2,406.76 -617.92 1,720.57 5,959,074.84 562,215.94 2.52 617.92 MWD (2) 4/4/2008 2:32:39PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: 1D-141A @ 111.SOft (D15 (70.7+40.8)) Stte Kuparuk 1D Pad MD Reference: 1D-141A @ 111.SOft (D15 (70.7+40.8)) Well: 1D-141 North Reference: True Wellbore: 1D-141APB2 Survey Calculation Method: Minimum Curvature Design: 1D-141APB2 Database:.,... EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azl TVD NDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,469.90 59.32 106.84 2,566.35 2,454.85 E42.03 1,800.09 5,959,051.37 Sti2,295.ti4 129 64`LA3 MWD (Z) 3,566.00 59.39 107.38 2,615.34 2,503.84 X66.36 1,879.10 5,959,027.68 562,374.85 0.49 666.36 MWD (2) 3,662.85 59.40 107.48 2,664.65 2,553.15 -691.33 1,958.64 5,959,003.36 562,454.57 0.09 691.33 MWD (2) 3,758.65 60.67 106.53 2,712.49 2,600.99 -715.59 2,038.00 5,958,979.73 562,534.12 1.58 715.59 MWD (2) 3,855.13 61.02 106.30 2,759.50 2,648.00 -739.40 2,118.82 5,958,956.58 562,615.12 0.42 739.40 MWD (2) 3,951.44 60.98 105.98 2,806.19 2,694.69 -762.82 2,199.74 5,958,933.81 562,696.21 0.29 762.82 MWD(2) 4,048.08 61.10 106.62 2,852.98 2,741.48 -786.55 2,280.89 5,958,910.74 562,777.55 0.59 786.55 MWD (2) 4,144.45 59.87 106.08 2,900.46 2,788.96 -810.16 2,361.36 5,958,887.78 562,858.20 1.37 810.16 MWD (2) 4,240.41 59.61 105.60 2,948.82 2,837.32 -832.79 2,441.10 5,958,865.80 562,938.11 0.51 832.79 MWD (2) 4,336.22 60.46 104.93 2,996.67 2,885.17 -854.64 2,521.17 5,958,844.60 563,018.35 1.07 854.64 MWD (2) 4,431.89 58.75 106.66 3,045.08 2,933.58 -877.09 2,600.57 5,958,822.79 563,097.92 2.37 877.09 MWD (2) 4,528.51 58.54 106.72 3,095.35 2,983.85 -900.78 2,679.61 5,958,799.73 563,177.14 0.22 900.78 MWD (2) 4,624.58 58.80 106.32 3,145.30 3,033.80 -924.12 2,756.28 5,958,777.04 563,255.99 0.45 924.12 MWD (2) 4,719.45 58.69 107.40 3,194.53 3,083.03 -947.64 2,835.90 5,958,754.14 563,333.78 0.98 947.64 MWD (2) 4,816.43 59.02 106.89 3,244.69 3,133.19 -972.10 2,915.21 5,958,730.32 563,413.28 0.56 972.10 MWD (2) 4,911.88 58.61 107.64 3,294.11 3,182.61 -996.34 2,993.19 5,958,706.71 563,491.44 0.80 996.34 MWD (2) 5,007.61 59.20 105.81 3,343.55 3,232.05 -1,019.92 3,071.69 5,958,683.76 563,570.12 1.75 1,019.92 MWD (2) 5,105.00 59.33 105.41 3,393.33 3,281.83 -1,042.45 3,152.31 5,958,661.89 563,650.92 0.38 1,042.45 MWD (2) 5,200.38 59.01 105.24 3,442.21 3,330.71 -1,064.09 3,231.30 5,958,640.88 563,730.07 0.37 1,064.09 MWD (2) 5,294.22 58.34 105.58 3,491.00 3,379.50 -1,085.39 3,308.58 5,958,620.21 563,807.51 0.78 1,085.39 MWD (2) 5,390.16 59.75 104.29 3,540.34 3,428.84 -1,106.59 3,388.07 5,958,599.65 563,887.17 1.87 1,106.59 MWD (2) 5,486.19 59.50 104.23 3,588.90 3,477.40 -1,127.00 3,468.37 5,958,579.89 563,967.62 0.27 1,127.00 MWD (2) / 5,502.00 59.83 104.97 3,596.89 > 3,485.39 -1,130.44 3,481.57 5,958,576.56 563,980.85 4.55 1,130.44 MWD+IFR-AK-CAZ-SC (3) 5,531.65 61.28 104.16 3,611.46 3,499.96 -1,136.93 3,506.56 5,958,570.27 564,005.88 5.44 1,136.93 MWD+IFR-AK-CAZ-SC (3) 5,559.63 62.30 103.41 3,624.69 3,513.19 -1,142.80 3,530.51 5,958,564.59 564,029.87 4.34 1,142.80 MWD+IFR-AK-CAZ-SC (3) 5,580.58 62.00 102.86 3,634.48 3,522.98 -1,147.01 3,548.55 5,958,560.53 564,047.95 2.73 1,147.01 MWD+IFR-AK-CAZ-SC (3) 5,610.34 61.80 102.08 3,648.49 3,536.99 -1,152.68 3,574.18 5,958,555.07 564,073.62 2.41 1,152.68 MWD+IFR-AK-CAZ-SC (3) 5,641.78 63.97 101.27 3,662.82 3,551.32 -1,158.34 3,601.58 5,958,549.63 564,101.07 7.27 1,158.34 MWD+IFR-AK-CAZ-SC (3) 5,673.51 65.19 100.47 3,676.44 3,564.94 -1,163.75 3,629.73 5,958,544.45 564,129.25 4.47 1,163.75 MWD+IFR-AK-CAZ-SC (3) 5,701.79 66.41 99.78 3,688.04 3,576.54 -1,168.28 3,655.12 5,958,540.12 564,154.67 4.85 1,168.28 MWD+IFR-AK-CAZ-SC (3) 5,732.13 67.57 102.17 3,699.90 3,588.40 -1,173.60 3,682.53 5,958,535.02 564,182.13 8.20 1,173.60 MWD+IFR-AK-CAZ-SC (3) 5,763.66 69.45 105.19 3,711.45 3,599.95 -1,180.54 3,711.03 5,958,528.31 564,210.68 10.72 1,180.54 MWD+IFR-AK-CAZ-SC (3) 5,793.64 71.63 108.37 3,721.44 3,609.94 -1,188.70 3,738.09 5,958,520.37 564,237.80 12.36 1,188.70 MWD+IFR-AK-CAZ-SC (3) i 5,824.51 72.97 110.11 3,730.82 3,619.32 -1,198.40 3,765.85 5,958,510.90 564,265.63 6.90 1,198.40 MWD+IFR-AK-CAZ-SC (3) 5,856.25 74.23 114.28 3,739.79 3,628.29 -1,209.90 3,794.03 5,958,499.63 564,293.91 13.21 1,209.90 MWD+IFR-AK-CAZ-SC (3) 5,900.33 75.93 117.50 3,751.14 3,639.64 -1,228.50 3,832.34 5,958,481.34 564,332.36 8.04 1,228.50 MWD+IFR-AK-CAZ-SC (3) 5,943.96 78.66 119.22 3,760.74 3,649.24 -1,248.71 3,869.79 5,958,461.42 564,369.97 7.34 1,248.71 MWD+IFR-AK-CAZ-SC (3) 5,987.70 80.79 122.45 3,768.54 3,657.04 -1,270.77 3,906.74 5,958,439.67 564,407.08 8.75 1,270.77 MWD+IFR-AK-CAZ-SC (3) 6,031.75 83.19 123.06 3,774.68 3,663.18 -1,294.37 3,943.42 5,958,416.36 564,443.95 5.62 1,294.37 MWD+IFR-AK-CAZ-SC (3) 6,075.66 85.52 124.63 3,779.00 3,667.50 -1,318.77 3,979.66 5,958,392.26 564,480.39 6.65 1,318.77 MWD+IFR-AK-CAZ-SC (3) 4/4/2008 2:32:39PM Page 4 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) InC. Local Co-ordinate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: 1D-141A @ 111.SOft (D15 (70.7+40.8)) Site: Kuparuk1DPad MD Reference: 1D-141A@111.SOft(D15(70.7+40.8)) Well: 1D-141 North Reference: True Wellbore: 1D-141APB2 Survey Calculation Method: Minimum Curvature Design: 1D-141AP62 Database; EDM Alaska Prod v16 Survey - --- Map Map Vertical MD Inc Axl ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 6,119.69 87.36 126.67 3,781.73 3,670.23 -1,344.45 4,015.'32 5,958,xt>.o6 a4,51b.e:. 5.9U l,:ri4.d5 MWD+IFR-AK-CAZ-SC (3) 6,164.06 92.52 128.40 3,781.78 3,670.28 -1,371.47 4,050.49 5,958,340.14 564,551.63 12.27 1,371.47 MWD+IFR-AK-CAZ-SC (3) 6,208.65 90.76 130.88 3,780.50 3,669.00 -1,399.90 4,084.81 5,958,311.99 564,586.18 6.82 1,399.90 MWD+IFR-AK-CAZ-SC (3) 6,237.92 89.53 133.71 3,780.43 3,668.93 -1,419.59 4,106.46 5,958,292.47 564,607.98 10.54 1,419.59 MWD+IFR-AK-CAZ-SC (3) 6,280.62 89.90 137.63 3,780.64 3,669.14 -1,450.13 4,136.29 5,958,262.18 564,638.06 9.22 1,450.13 MWD+IFR-AK-CAZ-SC (3) 6,323.66 89.15 140.58 3,781.00 3,669.50 -1,482.66 4,164.47 5,958,229.88 564,666.49 7.07 1,482.66 MWD+IFR-AK-CAZ-SC (3) 6,367.63 88.29 143.83 3,781.98 3,670.48 -1,517.39 4,191.40 5,958,195.37 564,693.70 7.64 1,517.39 MWD+IFR-AK-CAZ-SC (3) 6,410.72 90.23 148.38 3,782.54 3,671.04 -1,553.15 4,215.42 5,958,159.81 564,718.00 11.48 1,553.15 MWD+IFR-AK-CAZ-SC (3) 6,453.64 88.92 151.58 3,782.85 3,671.35 -1,590.30 4,236.89 5,956,122.84 564,739.77 8.06 1,590.30 MWD+IFR-AK-CAZ-SC (3) 6,495.66 88.71 154.48 3,783.72 3,672.22 -1,627.74 4,255.94 5,958,085.56 564,759.12 6.92 1,627.74 MWD+IFR-AK-CAZ-SC (3) 6,500.00 88.97 154.87 3,783.81 3,672.31 -1,631.66 4,257.80 5,958,081.65 564,761.01 10.80 1,631.66 MWD+IFR-AK-CAZ-SC (4) 6,544.91 89.38 158.78 3,784.46 3,672.96 -1,672.94 4,275.47 5,958,040.52 564,779.01 8.75 1,672.94 MWD+IFR-AK-CAZ-SC (4) 6,589.73 89.44 162.80 3,784.92 3,673.42 -1,715.25 4,290.21 5,957,998.33 564,794.09 8.97 1,715.25 MWD+IFR-AK-CAZ-SC (4) 6,634.83 88.18 165.82 3,785.86 3,674.36 -1,758.65 4,302.40 5,957,955.03 564,806.63 7.25 1,758.65 MWD+IFR-AK-CAZ-SC (4) 6,678.79 86.23 168.53 3,788.00 3,676.50 -1,801.46 4,312.15 5,957,912.31 564,816.72 7.59 1,801.46 MWD+IFR-AK-CAZ-SC (4) 6,721.82 89.60 167.71 3,789.57 3,678.07 -1,843.53 4,321.00 5,957,870.31 564,825.91 8.06 1,843.53 MWD+IFR-AK-CAZ-SC (4) 6,767.57 92.44 169.64 3,788.75 3,677.25 -1,888.38 4,329.98 5,957,825.55 564,835.25 7.50 1,888.38 MWD+IFR-AK-CAZ-SC (4) 6,800.57 93.49 172.51 3,787.04 3,675.54 -1,920.93 4,335.10 5,957,793.04 564,840.62 9.25 1,920.93 MWD+IFR-AK-CAZ-SC (4) 6,829.61 93.43 175.58 3,785.29 3,673.79 -1,949.76 4,338.10 5,957,764.24 564,843.86 10.55 1,949.76 MWD+IFR-AK-CAZ-SC (4) 6,859.23 93.67 177.04 3,783.46 3,671.96 -1,979.26 4,340.00 5,957,734.76 564,846.00 4.99 1,979.26 MWD+IFR-AK-CAZ-SC (4) 6,895.21 93.92 179.51 3,781.08 3,669.58 -2,015.14 4,341.D9 5,957,698.89 564,847.37 6.89 2,015.14 MWD+IFR-AK-CAZ-SC (4) 6,938.36 92.65 181.85 3,778.60 3,667.10 -2,058.21 4,340.57 5,957,655.82 564,847.20 6.16 2,058.21 MWD+IFR-AK-CAZ-SC (4) 6,983.76 92.65 184.60 3,776.50 3,665.00 -2,103.49 4,338.02 5,957,610.53 564,845.02 6.05 2,103.49 MWD+IFR-AK-CAZ-SC (4) 7,033.00 92.65 184.60 3,774.23 3,662.73 -2,152.52 4,334.08 5,957,561.47 564,841.47 0.00 2,152.52 PROJECTED to TD 4/4/2008 2:32:39PM Page 5 COMPASS 2003.16 Build 42F • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-141 APB3 50-029-22967-02 Definitive Survey Report 04 April, 2008 Sperry 'Drilling Services • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: ',Nell 1D-141 Protect: Kuparuk River Unit TVD Reference: 1D-141A @ 111.50ft (D15 (70.7+40.8)) Site: Kuparuk 1D Pad MD Reference: 1D-141A @ 111.50ft(D15 (70.7+40.8)) Well: 1D-141 North Reference: True Wellbore: 1D-141AP63 Survey Calculation Method: Minimum Curvature Design: 1D-141APB3 Database: EDM Alaska Prod v16 Protect 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 1D-141.... __ _- - Well Position +NI-S 0.00 ft Northing: 5,959,678.83 ft Latitude: 70° 18' 1.455 N +EI-W 0.00 ft Easting: 560,490.62 ft Longitude: 149° 30' 36.290 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70ft Wellbore 1D-141APB3 I Magnetics Model Name Sample Date Declination Dip Angle Field Strength EGGM~00; 3 1 V000o" 17 54 ~ 5.7~ -.. 274 Design _,_._ 1D-141AP63 -- - _..._ _.... __ __..._.. .__ ,- . _..., i Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,119.69 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (tt) (ft) (ft) (') 40.20 0.00 0.00 120 00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description 105.45 646.55 1D-141PB1 gyro (1D-141PB1) CB-GYRO-SS Camera based gyro single shot 681.46 5,486.19 1D-141PB1 (1D-141PB1) MWD MWD-Standard 5,502.00 6,119.69 1D-141APB1 MWD+SAG+CA+IIFR+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,125.00 6,310.62 1D-141AP83 MWD+SAG+CA+IIFR+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Survey Start Date 04/04/2008 04/04/2008 04/04/2008 04/04/2008 Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (`) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 40.80 0.00 0.00 40.80 -70.70 0.00 0.00 5,959,678.83 560,490.62 0.00 0.00 UNDEFINED 105.45 0.10 330.50 105.45 -6.05 0.05 -0.03 5,959,678.88 560,490.59 0.15 -0.05 CB-GYRO-SS (1) 200.45 0.30 315.40 200.45 88.95 0.30 -0.24 5,959,679.13 560,490.37 0.22 -0.30 CB-GYRO-SS (1) 295.45 0.30 25.10 295.45 183.95 0.70 -0.31 5,959,679.53 560,490.30 0.36 -0.70 CB-GYRO-SS (1) 318.45 0.30 303.60 318.45 206.95 0.79 -0.34 5,959,679.62 560,490.28 1.70 -0.79 CB-GYRO-SS (1) 348.45 0.30 303.00 348.45 236.95 0.87 -0.47 5,959,679.70 560,490.14 0.01 -0.87 CB-GYRO-SS (1) 390.45 0.00 0.00 390.45 278.95 0.93 -0.56 5,959,679.76 560,490.05 0.71 -0.93 CB-GYRO-SS (1) 414.45 0.40 346.80 414.45 302.95 1.02 -0.58 5,959,679.84 560,490.03 1.67 -1.02 CB-GYRO-SS (1) 460.45 0.40 31.60 460.45 348.95 1.31 -0.53 5,959,680.13 560,490.08 0.66 -1.31 CB-GYRO-SS (1) 493.45 1.90 38.60 493.44 381.94 1.83 -0.13 5,959,680.66 560,490.47 4.56 -1.83 CB-GYRO-SS (1) 530.45 1.10 32.00 530.43 418.93 2.62 0.44 5,959,681.45 560,491.04 2.21 -2.62 CB-GYRO-SS (1) 4/4/2008 2:34:20PM Page 2 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordlnateReference: Well 1D-141 Pro)ect: Kuparuk River Unit ND Reference: 1D-141A @ 111.508 (D15 (70.7+40.8)) Site Kuparuk 1D Pad MD Reference: 1D-141A @ 111.SOft(D15 (70.7+40.8)) Well: 1D-141 North Reference: True Wellbore: 1D-141AP63 Survey Calculation Method: Minimum Curvature Design: 1D-141AP63 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azl ND NDSS +N!-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 549.45 1.20 35.20 549.42 437.92 2.83 il.o5 5,959,681.77 ex,u,49 L25 u.o3 -2.93 CB-GYRU-SS (1) 587.45 3.10 111.90 587.40 475.90 2.87 1.83 5,959,681.72 560,492.43 8.04 -2.87 CB-GYRO-SS (1) 646.45 6.40 116.60 646.19 534.69 0.81 6.26 5,959,679.69 560,496.87 5.63 -0.81 CB-GYRO-SS (1) 681.46 8.31 120.17 680.91 569.41 -1.34 10.19 5,959,677.57 560,500.82 5.61 1.34 MWD (2) 714.62 8.45 119.15 713.71 602.21 -3.73 14.39 5,959,675.22 560,505.04 0.62 3.73 MWD (2) 748.20 9.27 116.77 746.89 635.39 -6.15 18.96 5,959,672.83 560,509.62 2.67 6.15 MWD (2) 777.47 10.62 117.25 775.72 664.22 -8.45 23.46 5,959,670.57 560,514.15 4.62 8.45 MWD (2) 811.34 11.84 116.08 808.94 697.44 -11.40 29.36 5,959,667.66 560,520.06 3.66 11.40 MWD (2) 843.66 13.99 112.15 840.45 728.95 -14.33 35.95 5,959,664.79 560,526.68 7.18 14.33 MWD (2) 873.61 17.20 110.68 869.29 757.79 -17.26 43.45 5,959,661.92 560,534.21 10.80 17.26 MWD (2) 908.63 20.11 109.71 902.47 790.97 -21.12 53.97 5,959,658.14 560,544.75 8.36 21.12 MWD (2) 940.81 20.54 110.98 932.64 821.14 -25.01 64.45 5,959,654.34 560,555.26 1.91 25.01 MWD (2) 970.89 21.52 110.46 960.72 849.22 -28.83 74.54 5,959,650.60 560,565.38 3.32 28.83 MWD (2) 1,005.44 23.24 111.69 992.67 881.17 -33.56 86.81 5,959,645.97 560,577.69 5.16 33.56 MWD (2) 1,037.35 24.13 112.22 1,021.89 910.39 -38.36 98.70 5,959,641.27 560,589.62 2.87 38.36 MWD (2) 1,067.31 24.70 111.43 1,049.17 937.67 -42.96 110.20 5,959,636.76 560,601.15 2.19 42.96 MWD (2) 1,163.67 26.43 113.69 1,136.09 1,024.59 -58.93 148.58 5,959,621.10 560,639.66 2.06 58.93 MWD (2) 1,259.90 30.34 115.14 1,220.74 1,109.24 -77.87 190.21 5,959,602.50 560,681.43 4.13 77.87 MWD (2) 1,355.72 33.44 116.08 1,302.09 1,190.59 -99.76 235.84 5,959,580.98 560,727.24 3.28 99.76 MWD (2) 1,452.67 33.40 114.53 1,383.01 1,271.51 -122.59 284.11 5,959,558.54 560,775.68 0.88 122.59 MWD (2) 1,549.88 35.63 111.32 1,463.11 1,351.61 -143.99 334.84 5,959,537.55 560,826.58 2.96 143.99 MWD (2) 1,646.69 39.28 112.00 1,539.95 1,428.45 -165.73 389.54 5,959,516.25 560,881.45 3.79 165.73 MWD (2) 1,742.09 42.92 113.31 7,611.83 1,500.33 -189.91 447.40 5,959,492.55 560,939.49 3.92 189.91 MWD(2) 1,838.15 44.12 113.98 1,681.48 1,569.98 -216.44 507.99 5,959,466.50 561,000.28 1.34 216.44 MWD (2) 1,934.22 44.49 113.15 1,750.23 1,638.73 -243.27 569.49 5,959,440.18 561,062.00 0.72 243.27 MWD (2) 2,030.35 48.00 716.14 1,816.71 1,705.21 -272.26 632.56 5,959,411.70 561,125.29 4.29 272.26 MWD (2) 2,126.80 51.41 113.67 1,879.08 1,767.58 303.19 699.28 5,959,381.30 561,192.25 4.04 303.19 MWD (2) 2,223.14 55.85 113.16 1,936.20 1,824.70 -334.00 770.45 5,959,351.07 561,263.66 4.63 334.00 MWD (2) 2,318.81 59.53 111.66 1,987.33 1,875.83 -364.80 845.19 5,959,320.88 561,338.64 4.07 364.80 MWD (2) 2,413.93 60.15 107.25 2,035.13 1,923.63 -392.17 922.71 5,959,294.13 561,416.37 4.06 392.17 MWD (2) 2,509.34 60.67 106.35 2,082.25 1,970.75 -016.15 1,002.14 5,959,270.80 561,495.98 0.98 416.15 MWD (2) 2,605.40 60.88 106.69 2,129.15 2,017.65 -039.99 1,082.51 5,959,247.61 561,576.53 0.38 439.99 MWD (2) 2,700.89 61.36 107.31 2,175.27 2,063.77 -464.44 1,162.47 5,959,223.81 561,656.68 0.76 464.44 MWD(2) 2,796.49 60.58 104.62 2,221.67 2,710.17 -487.43 1,242.82 5,959,201.46 561,737.21 2.59 487.43 MWD (2) 2,892.79 59.47 103.82 2,269.78 2,158.28 -507.93 1,323.68 5,959,181.62 561,818.22 7.36 507.93 MWD (2) 2,989.04 58.76 103.50 2,319.19 2,207.69 -527.43 1,403.95 5,959,162.76 561,898.63 0.79 527.43 MWD (2) 3,084.63 57.96 105.90 2,369.34 2,257.84 -548.08 1,482.66 5,959,142.76 561,977.50 2.30 548.08 MWD (2) 3,180.93 59.65 105.87 2,419.21 2,307.77 -570.58 1,561.90 5,959,120.90 562,056.97 1.76 570.58 MWD (2) 3,277.10 58.12 106.87 2,468.91 2,357.41 -593.74 1,640.90 5,959,098.38 562,136.09 1.85 593.74 MWD (2) 3,373.89 60.56 106.90 2,518.26 2,406.76 -617.92 1,720.57 5,959,074.84 562,215.94 2.52 617.92 MWD (2) 4/4/2008 2:34:20PM Page 3 COMPASS 2003.18 Build 42F Conoco Phillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc . Local Co-ordi nate Reference : Well 1D-141 Project: Kuparuk River Unit ND Referenc e: 1 D-1 41A @ 1 11.SOft (D15 (70.7+40.8)) Site: Kuparuk 1D Pad MD Reference: 1D-1 41A ~ 1 11.SOft (D15 (70.7+40.8)) Well: 1D-1 41 North Referen ce: True Wellbore: 10-1 41AP63 Survey Calcu lation Method: Minimum Curvature Design: 1D-1 41AP63 Database: EDM Alaska Prod v16 Survey -- - Map Map Vertical MD Inc Axi ND NDSS +N/-S +E!-W Northing Easting DLS Section (ft) (°} (`) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name ~,4b9.95 "x9.32 iuu.84 2,566.35 2,454.85 -a42.W 1,800.09 5,959,051 37 562,295.64 1.29 642.03 MWD (2) 3,566.00 59.39 107.38 2,615.34 2,503.84 -666.36 1,879.10 5,959,027.68 562,374.85 0.49 666.36 MWD (2) 3,662.85 59.40 107.48 2,664.65 2,553.15 -691.33 1,958.64 5,959,003.36 562,454.57 0.09 691.33 MWD (2) 3,758.65 60.67 106.53 2,712.49 2,600.99 -715.59 2,038.00 5,958,979.73 562,534.12 1.58 715.59 MWD (2) 3,855.13 61.02 106.30 2,759.50 2,648.00 -739.40 2,118.82 5,958,956.58 562,615.12 0.42 739.40 MWD (2) 3,951.44 60.98 105.98 2,806.19 2,694.69 -762.82 2,199.74 5,958,933.81 562,696.21 0.29 762.82 MWD (2) 4,048.08 61.10 106.62 2,852.98 2,741.48 -786.55 2,280.89 5,958,910.74 562,777.55 0.59 786.55 MWD (2) 4,144.45 59.87 106.08 2;900.46 2,788.96 -810.16 2,361.36 5,958,887.78 562,858.20 1.37 810.16 MWD (2) 4,240.41 59.61 105.60 2,948.82 2,837.32 -832.79 2,441.10 5,958,865.80 562,938.11 0.51 832.79 MWD (2) 4,336.22 60.46 104.93 2,996.67 2,885.17 -854.64 2,521.17 5,958,844.60 563,018.35 1.07 854.64 MWD (2) 4,431.89 58.75 106.66 3,045.08 2,933.58 -877.09 2,600.57 5,958,822.79 563,097.92 2.37 877.09 MWD (2) 4,528.51 58.54 106.72 3,095.35 2,983.85 -900.78 2,679.61 5,958,799.73 563,177.14 0.22 900.78 MWD (2) 4,624.58 58.80 106.32 3,145.30 3,033.80 -924.12 2,758.28 5,958,777.04 563,255.99 0.45 924.12 MWD (2) 4,719.45 58.69 107.40 3,194.53 3,083.03 -947.64 2,835.90 5,958,754.14 563,333.78 0.98 947.64 MWD (2) 4,816.43 59.02 106.89 3,244.69 3,133.19 -972.10 2,915.21 5,958,730.32 563,413.28 0.56 972.10 MWD (2) 4,911.88 58.61 107.64 3,294.11 3,182.61 -996.34 2,993.19 5,958,706.71 563,491.44 0.80 996.34 MWD (2) 5,007.61 59.20 105.81 3,343.55 3,232.05 -1,019.92 3,071.69 5,958,683.76 563,570.12 1.75 1,019.92 MWD (2) 5,105.00 59.33 105.41 3,393.33 3,281.83 -1,042.45 3,152.31 5,958,661.89 563,650.92 0.38 1,042.45 MWD (2) 5,200.38 59.01 105.24 3,442.21 3,330.71 -1,064.09 3,231.30 5,958,640.88 563,730.07 0.37 1,064.09 MWD (2) 5,294.22 I 58.34 105.58 3,491.00 3,379.50 -1,085.39 3,308.58 5,958,620.21 563,807.51 0.78 1,085.39 MWD (2) 5,390.16 59.75 104.29 3,540.34 3,428.84 -1,106.59 3,388.07 5,958,599.65 563,887.17 1.87 1,106.59 MWD (2) ~ 5,486.19 59.50 104.23 3,588.90 3,477.40 -1,127.00 3,468.37 5,958,579.89 563,967.62 0.27 1,127.00 MWD (2) 5,502.00 59.83 104.97 3,596.89 3,485.39 -1,130.44 3,481.57 5,958,576.56 563,980.85 4.55 1,130.44 MWD+IFR-AK-CAZ-SC (3) 5,531.65 61.28 104.16 3,611.46 3,499.96 -1,136.93 3,506.56 5,958,570.27 564,005.88 5.44 1,136.93 MWD+IFR-AK-CAZ-SC (3) 5,559.63 62.30 103.41 3,624.69 3,513.19 -1,142.80 3,530.51 5,958,564.59 564,029.87 4.34 1,142.80 MWD+IFR-AK-CAZ-SC (3) 5,580.58 62.00 102.86 3,634.48 3,522.98 -1,147.01 3,548.55 5,958,560.53 564,047.95 2.73 1,147.01 MWD+IFR-AK-CAZ-SC (3) 5,610.34 61.80 102.08 3,648.49 3,536.99 -1,152.68 3,574.18 5,958,555.07 564,073.62 2.41 1,152.68 MWD+IFR-AK-CAZ-SC (3) 5,641.78 63.97 101.27 3,662.82 3,551.32 -1,158.34 3,601.58 5,958,549.63 564,101.07 7.27 1,158.34 MWD+IFR-AK-CAZ-SC (3) 5,673.51 65.19 100.47 3,676.44 3,564.94 -1,163.75 3,629.73 5,958,544.45 564,129.25 4.47 1,163.75 MWD+IFR-AK-CAZ-SC (3) 5,701.79 66.41 99.78 3,688.04 3,576.54 -1,168.28 3,655.12 5,958,540.12 564,154.67 4.85 1,168.28 MWD+IFR-AK-CAZ-SC (3) 5,732.13 67.57 102.17 3,699.90 3,588.40 -1,173.60 3,682.53 5,958,535.02 564,182.13 8.20 1,173.60 MWD+IFR-AK-CAZ-SC (3) 5,763.66 69.45 105.19 3,711.45 3,599.95 -1,180.54 3,711.03 5,958,528.31 564,210.68 10.72 1,180.54 MWD+IFR-AK-CAZ-SC (3) 5,793.64 71.63 108.37 3,721.44 3,609.94 -1,188.70 3,738.09 5,958,520.37 564,237.80 12.36 1,188.70 MWD+IFR-AK-CAZ-SC (3) 5,824.51 72.97 110.11 3,730.82 3,619.32 -1,198.40 3,765.85 5,958,510.90 564,265.63 6.90 1,198.40 MWD+IFR-AK-CAZ-SC (3) 5,856.25 74.23 114.28 3,739.79 3,628.29 -1,209.90 3,794.03 5,958,499.63 564,293.91 13.21 1,209.90 MWD+IFR-AK-CAZ-SC (3) 5,900.33 75.93 117.50 3,751.14 3,639.64 -1,228.50 3,832.34 5,958,481.34 564,332.36 8.04 1,228.50 MWD+IFR-AK-CAZ-SC (3) 5,943.96 78.66 119.22 3,760.74 3,649.24 -1,248.71 3,869.79 5,958,461.42 564,369.97 7.34 1,248.71 MWD+IFR-AK-CAZ-SC (3) 5,987.70 60.79 122.45 3,768.54 3,657.04 -1,270.77 3,906.74 5,958,439.67 564,407.08 8.75 1,270.77 MWD+IFR-AK-CAZ-SC (3) 6,031.75 83.19 123.06 3,774.68 3,663.18 -1,294.37 3,943.42 5,958,416.36 564,443.95 5.62 1,294.37 MWD+IFR-AK-CAZ-SC (3) 6,075.66 85.52 124.83 3,779.00 3,667.50 -1,318.77 3,979.66 5,958,392.26 564,480.39 6.65 1,318.77 MWD+IFR-AK-CAZ-SC (3) 4/4/2008 2:34:20PM Page 4 COMPASS 2003.16 Build 42F • Conoco Phillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc . Local Co-ordinate Reference: Well 1D-141 Project: Kuparuk River Unit ND Reference: 1D-141A @ 1 11.SOft (D15 (70.7+40.8)) Site: Kuparuk 1D Pad MD Reference: 1D-141A @ 1 11.SOft (D15 (70.7+40.8)) Well: 1D-141 North Reference: True Wellbore: 1D-141AP63 Survey Calculation Method: Minimum Curvature Design: 1D-141AP63 Database; EDM Alaska Prod v16 _ ---- Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) lft) (ft) (ft) (it) (ft) (ft) (`/100') (ft) Survey Tool Name 6,11y.o9 87.3b' 126.67 3,/81.73 3,670.23 -1,,44.45 4,015.32 5,y5tf,`3Bti.Sb 504,510.25 5.50 1,344.45 MvYD+IFk-v,h-GAZ-SG (3) 6,125.00 87.98 126.88 3,781.95 3,670.45 -1,347.62 4,019.57 5,958,363.74 564,520.52 12.33 1,347.62 MWD+IFR-AK-CAZ-SC (4) 6,169.64 87.32 127.19 3,783.78 3,672.28 -1,374.49 4,055.18 5,958,337.16 564,556.34 1.63 1,374.49 MWD+IFR-AK-CAZ-SC (4) 6,199.72 88.92 128.05 3,784.76 3,673.26 -1,392.84 4,078.99 5,958,319.01 564,580.30 6.04 1,392.84 MWD+IFR-AK-CAZ-SC (4) 6,237.30 88.82 131.10 3,785.51 3,674.01 -1,416.77 4,107.95 5,958,295.31 564,609.44 8.12 1,416.77 MWD+IFR-AK-CAZ-SC (4) 6,280.71 89.81 134.64 3,786.02 3,674.52 -1,446.30 4,139.75 5,958,266.04 564,641.48 8.47 1,446.30 MWD+IFR-AK-CAZ-SC (4) 6,310.62 91.83 133.28 3,785.60 3,674.10 -1,467.06 4,161.28 5,958,245.46 564,663.18 8.14 1,467.06 MWD+IFR-AK-CAZ-SC (4) 6,360.00 91.83 133.28 3,784.02 3,672.52 -1,500.89 4,197.21 5,958,211.92 564,699.37 0.00 1,500.89 PROJECTED to TD 4/4/2008 2:34;20PM Page 5 COMPASS 2003.16 Build 42F 1D-141A PBl, PB2 &PB3 ~ • Page 1 of 2 Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.com] Sent: Monday, March 17, 2008 3:01 PM To: Maunder, Thomas E (DOA) ~~(~ Cc: Allsup-Drake, Sharon K ~/ Subject: 1D-141A PB1, PB2 &PB3 Attachments: Sidetracks.ppt; Patrick.J.Reilly@conocophillips.com.vcf Tom, Here are the details of two more sidetracks. I have also corrected the date on PB1. I have attached a schematic with the details. The numbers in front of each text entry reflect the chronological order of the events. The schematic references the tool face being off from the original set. We believe slip stick caused some of the connections to make up down hole and that caused our steering problems. PBl • Well: 1 D-141A • Rig: Doyon 15 • Date: 3/12/08 (NOTE: Date correction -the original notification had the date listed as 3/13/08) • Time: 2100 hrs • Last Casing: D Window 5,502' • MD of abandoned section: 6,474' - 6,680' We exited the top of the formation due to geologic uncertainty. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. PB2 • Well: 1 D-141A • Rig: Doyon 15 • Date: 3/13/08 • Time: 1645 hrs • Last Casing:. D Window 5,502' • MD of abandoned section: 6,125' - 7,033' We were having directional control problems. We are planning to isolate the sidetrack by allowing it to collapse. PB3 3/17/2008 1D-141A PB1, PB2 & PB3 • Well: 1D-141A • Rig: Doyon 15 • Date: 3/15/08 • Time: 1645 hrs • Last Casing: D Window 5,502' • MD of abandoned section: 6,125' - 6,360' Page 2 of 2 After changing tools due to directional control problems, we were attempting to get into the main bore when we unintentionally sidetracked. We are planning to isolate the sidetrack by allowing it to collapse. «Sidetracks.ppt» Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J. Reilly@conocophillips.com «patrick.J.Reilly@conocophillips.com.vcf» 3/17/2008 1 D-141 A Sidetracks 5,5Q2' r n 3 - 6,228', TOOH •Confirm issue is BHA not formation. building angle when pointed down •Tool face off 64 degrees 125' 6, 680' 2 -Steering problems •Formation or BHA? •Close to top of formation •Close to 1 D-32 water injector PB2 = 6,125' - 7,033' 7, 033' C e m e n t 125' ~- F r ~ ' ~ ~ . h', y f,.. a; ~~i„ ., ~ a~ , .. ' 6,421' 1 -Geological ST, exit top of formation PB1 = 6,474' - 6,680' 4 - 6,360', POOH • Tool going left when pointed right. •Tool face off 86 degrees PB3 = 6,125' - 6,360' 5 - 6,125' • Searching for main well bore, kicked off unintentional sidetrack @ 6,125' ~ ,. i/.ream L ~ F ~~ ~ ~ -----~ 4 .. ~ .: _ P `3117,~0s~ _° ~ ~, ~~~ fw 7,241' 6 - 7,241 • TOOH - Motor ~ RSS •Remaining directional work does not require motor •TAD modeling indicates little chance of success with motor - buckling, actual plan higher dog legs than planned •I 1D-141A PB1 ~ ~ Page 1 of 1 2~° ~ z~~~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, March 13, 2008 4:54 PM To: 'Reilly, Patrick J' Subject: RE: 1D-141A PB1 Thanks Pat. I will place a copy of this message in the file. Nothing further is needed. Tom Maunder, PE AOGCC From: Reilly, Patrick J [mailto:Patrick.J.Reilly@conocophillips.com] Sent: Thursday, March 13, 2008 3:57 PM To: Maunder, Thomas E (DOA) Subject: 1D-141A PBl Tom, The details of the sidetrack are as follows: • Well: 1D-141A • Rig: Doyon 15 • Date: 3/13/08 • Time: 2100 hrs • Last Casing: D Window 5,502' • MD of abandoned section: 6,474' - 6,6$0' We exited the top of the formation due to geologic uncertainty. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. If you need any additional information please contact me. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick. J. Reilly@conocophillips.com «Patrick.J.Reilly@conocophillips.com.vch> 3/13/200$ ~~` ~ f~~ °; ~~ 33 s ALASSA OIL A1~TD GAS C011iSER'QATIO)•T CO1rII-IISSIOl~ Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 700 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 G~~I~.-o`er Re: Kuparuk River Field, West Sak Oil Pool ~ ~'Cj ~- `~ r ConocoPhillips Alaska, Inc. Permit No: 208-016 Surface Location: 14' FNL, 596' FEL, SEC. 14, T11N, R10E, UM Bottomhole Location: 294' FSL, 1981, FEL, SEC. 24, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a .Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9659-3607 (pager). DATED this ~ day of February, 2008 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Conoco~hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com January 29, 2008 ~~ Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue ~-~!~ ~ ~ ~~~'~ Suite 100 Anchorage, Alaska 99501 ~IgS~~ ~°~ - 8~ ~c°'"` ~ ~c7ta;~°~sl~n ~nixh~~~~a Re: Application for Permit to Drill, West Sak Producer, iD-141A Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permit to Drill for an onshore producer well, a sidetrack well in the West Sak "D" sands. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005. The expected spud date of iD-141A is February 19, 2008. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, -~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ORIGINAL STATE OF ALASKA ALFA OIL AND GAS CONSERVATION COIV~SION PERMIT TO DRILL ~.~y 20 AAC 25.005 A~__ JAN 3 ~ 20Q8 R'1 f6 YY _ _. M 1 a. Type of Work: Drill ^ Redrill Q Re-entry ^ 1 b. Current Well Class: Exploratory ^ Stratigraphic Test ^ Service ^ Multiple Zone ^ Development Oil • Q Development Gas ^ Single Zone ^ 1 c. Specify if o ` Coalbed Methane ^ AnC~ISE~~~drates ^ Shale Gas ^ 2. Operator Name:. ConocoPhillipsAlaska, Inc. 5. Bond: Blanket Q Single Well ^ Bond No. 59-52-180 11. Well Name and Number: 1D-141A 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9844 ' TvD: 3743' 12. Field/Pool(s): Kuparuk River Field • 4a. Location of Well (Governmental Section): Surface: 14' FSL, 596' FEL, Sec. 14, T11 N, R10E, UM 7. Property Designation: ADL 25650 West Sak Oil Pool , Top of Productive Horizon: 1256' FNL, 1993' FEL, Sec. 24, T11 N, R10E, UM ~ 8. Land Use Permit: ALK 468 13. Approximate Spud Date: Total Depth: 294' FSL, 1981' FEL, Sec. 24, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 1981' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560490 y- 5959678 Zoi 4 10. KB Elevation (Height above GL): • 111' AMSL feet 15. Distance to Nearest Well Within Pool: none 16. Deviated wells: Kickoff depth: 5500' feet Maximum Hole Angle: 91 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1792 Surface: 1377 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) 6.75" 4.5" 11.6# L-80 BTCM 585' 5380' 3534' 5965' 3764' blank 6.75" 4.5" 11.6# L-80 BTCM 3879' 5965' 3764' 9844' 3743' slotted liner , 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): 9550' Total Depth TVD (ft): 3779' Plugs (measured): Effect. Depth MD (ft): 5417' Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD ConductodStructural 80' 16" 110' 110' Surface 472' 10-3/4" 502' S02~ Intermediate 5489' 7-5/8" 5519' 3600 Production 900' 7" 6419' 3829' Liner Perforation Depth MD (ft): 8197'-9510' Perforation Depth TVD (ft): 3794'-3778' 20. Attachments: Filing Fee ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ^ Drilling Program ^ Time v. Depth Plot ^ Shallow Hazard Analysis Seabed Report ^ Drilling Fluid Program Q' 20 AAC 25.050 requirements ^Q 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct. Printed Name RANDY THOMAS Signature ~ \ _ Date Contact Pat Reilly @ 265-6048 Title DRILLING TEAM LEADER Phone 265-6830 Date `~ Z~ ~~Z Commission Use Only Permit to Drill r^~; ~ Number: E'~~-~C.% • ~•' ~~ API Number: ~ 50- ~1 ~- ~ -' Z,~, Permit Appr val ~j 7- (~, Date:o See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce co Ibed methane, gas ydrates, or gas contained in shales: Other: ~ Samples req'd: Yes^ No Mud log req'd: Yes^ No[]• ~ ~~~ ~'~, ~j ~ HZS measures: Yesr~ No [•~ Directional svy req'd: Yes[ No^ ~~,: PPRO ED BY THE COMMISSION DATE: ~~ D ,COMMISSIONER Form 10-401 Revised 12/2005 it i D plicate 0 R 1 GI NA ~~~ .~ z.~.` • Ap~ion for Permit to Drill, Well 1 D-141A Revision No.O Saved: 29-Jan-08 Permit It -West Sak Well #1D-141A "" r.~ ~'t Application for Permit to Drill Document ~ ~ ~~~ ~I p x i rt't i s 1MefI Vviue Table of Contents 1. Well Name .................................................................................................................. 2 q f ~ .......................................................................................................... Re uirements o 20 AAC 25.005 ... 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.050(b) ............................................................................................................. 3 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 4 Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 4 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 5 Requirements of 20 AAC 25.005(c)(8) ......................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) D sand laterals ........................................................ 5 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10 . Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c) (10) ...................................................................................................... 5 11 . Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 12. Evidence of Bonding ................................................................................................... 5 1D-141A PERMIT IT.doc Page 1 of 7 ` Printed:29ti1an-08 ~~~~~~~~ Requirements of 20 AAC 25.005 (c)(12) Appl•n for Permit to Drill, Well 1 D-141A Revision No.O Saved: 29-Jan-08 ........................................................... 5 13. Proposed Drilling Program ......................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 7 15. Attachments ............................................................................................................... 7 Attachment 1 Directional Plan .................................................................................................................. 7 Attachment 2 Drilling Hazards Summary ................................................................................................... 7 Attachment 3 Current Schematic ............................................................................................................... 7 Attachment 4 P&A Schematic (Work to be performed under P&A Sundry) .................................................... 7 Attachment 5 Proposed 1D-141A Well Schematic ....................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 11J Each well must be identified by a unique name desig~aated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be ident~ed by a ainique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1D-141A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the follolving items, except for an item already on file with the commission and tdent~ed in the application: (2) a plat ident~ing the property and the property s oN~ners and shoiwing (A)the coordinates of the proposed location of the swell at the surface, at the top of each objective formation, and at total depth, referenced to governmental section ]roes. (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 tlae top of each objective forrnation and at total depth; Location at Surface 14' FSL, 596' FEL, Section 14, T11N, R10E ' ASP Zone 4 NAD 27 Coordinates RKB Elevation 111' AMSL Northings: 5,959,678 Eastings: 560,490 Pad Elevation 71' AMSL Location at Top of Productive Interval (West 1,256' FNL, 1,993' FEL, Section 24, T11N, R10E Sak "D" Sand Measured De th, RKB: 5,965 ASP zone 4 NAD 27 Coordinates Northin 441 Eastin s: 564 s: 5 958 385 Total Vertical De th, RKB: 3,764 , g , , g Total Vertical De th, SS: 3,653 Location at Total Depth 294' FSL, 1,981' FEL, Section 24, T11N, R10E Measured De th, RKB: 9,844 ASP zone 4 NAD 27 Coordinates Northin 954 712 Eastin s: 5 s: 564 429 Total Vertical De th, RKB: 3,743 , g , g , Total Vertical De th, SS: 3,633 and (D) other information required by 20 AAC 25.0 0(b); } , . .~~` e ~ ~. 1D-141A PERMIT IT.doc Page 2 of 7 Printed: 29-Jan-08 • Ap~ion for Permit to Drill, Well 1 D-141A Revision No.0 Saved: 29-Jan-08 Requirements of 20 AAC 25.050(6) If a smell is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) rnust (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of arty portion of the proposed well; Please see Attachment 1: 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 applicafion by certified mail; or (B) state that the applicant is the on]y affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25. DOS(c)(3) An application.for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the conzniission and ident~ed in the application: (3) a diagram and descripflon of the blowout prevention equipment (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1D-141A. For all operations except the completion tubing run, we plan to have the stack equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 4-1/2" to 7" variable bore rams in the lowermost cavity. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 4-1/2" OD tubular and a 5-1/2" OD tubular. While running the completion tubing, the uppermost ram cavity will have 2-7/8" rams and the configuration of the rest of the stack will remain unchanged. 4. 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, exceptfor an item ab~eady on file with the commission arzd identified in the application: (4J inforn2arion on drilling hazards, including (A) the maximum downhole pressure that nray be encountered. criteria used to determine it, and nurxinrum potential surface pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1D-141A area is 0.476 psi/ft, or 9.2 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,377 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 3,764'. The MPSP is: MPSP = (3,764 ft)(0.476 - 0.11 psi/ft) =1,377 psi (Bj data on potential gas =ones; The well bore is not expected to penetrate any gas zones. grad (C) .data concenring potential causes of hole problems such as abnormally geo pressured strata, lost circulation =ones, acrd pones that have a propensity for differential srick-ing, Please see Attachment 2: 1D-141A Drilling Hazards Summary. OR~GINAt 1D-141A PERMIT IT.doc Page 3 of 7 Printed: 29-Jan-OS Appt~in for Permit to Drill, Well 1 D-141A Revision No.O Saved: 29-Jan-08 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of the follorr~ing items, except for an item already on file with the commission and identified in the application: (S) a description of the procedure for conducting fornurtion integrity tests, as required under 20 AAC 2S. 030(fl; 1D-141A will be completed with 9-5/8" casing landed at the top of the West Sak "B" sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. 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 dze commission and identified in the application: (6) a complete proposed casing mid cementing proge•anz as regzired by 20 AAC 2.030, and a description of any slotted liner, pre perforated liner-. or screen to be installed: Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/t) Grade Connection (ft) t) t) Cement Pro am 16" N/A 151.5 X-65 Welded 110 40' / 40' 150' / 150' ~ PLACE 10-3/4" N/A 40.5 J-55 BTC 462 40' / 40' 502' / 502' IN PLACE 7-5/8 N/A 29.7 L-80 BTCM 5,460' @ 40' / 40' 5,500 / 3,595 IN PLACE -CEMENTED TO Window suxFACE 5-1/2" Inside 7-5/8" Casing " 15.5 L-80 BTCM 5 340' 40' / 40' 534' • .5 380' / 3 N/A ID 6.875 , , , 6-3/4" D Sand Lateral 4-1/2" Section Above D 11.6 L-80 BTCM 585' - 5 380' / 3 534' • ' S 965' / 3 764' Blank to Swell Packer-No blank Sand ~ ~ ~ ~ cement (1D-141A) 4-1 /2" 6-3/4" D Sand Lateral slotted Section in the D Sand 11.6 L-80 BTCM 3,879' ~ 5,965' / 3,764' 9,844' / 3,743' Slotted- no cement (1D-141A 7. 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 follrn+%ing items, except for an item abeady on file with the commission and identfed in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.03, unless this requirement is waived by the commission under 20 AAC 25.035(h) (2); This is a sidetrack. No diverter will be used. 1D-141A PERMIT IT.doc Page 4 of 7 n ~ ~ Printed: 29-Jan-08 4~'J ~ ~, .~ ,_ a x ,~ Ap~ion for Permit to Drill, Well 1 D-141A Revision No.O Saved: 29-Jan-08 8. 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 ident~ed in the application: (8) a drilliizgfluid program, including a diagram and description of the drilliizgfluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) D sand laterals Value Density ( 8.6 - 9.6 Plastic Viscostiy (lb/100 s 15-22 Yield Point (cP) 15-20 HTHP Fluid loss (ml/30 min @ <4.0 200psi & 150° Oil /Water Ratio 80:20 Electrical Stabili 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the follox~ing items, exceptfor an item already on fate with the commission and ideiat~~ed in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpredicted abnormally geo pressured strata as required by 20 AAC 2~. 033(~,~ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompmiied by each of flue following items, except for an item already on file with the commission .and identified in the application: (10) for an exploratory or stratigraphic test weld a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and idenfified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 10 ~.4C 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accomprnued by each of the fo[loi~~ing items, except for an item aleady on ftle with the commission and identified in the application: 1D-141A PERMIT IT.doc Page 5 of 7 z , x Printed: 29-Jan-08 (~ ~ ~~~ ~L ~J App~n for Permit to Drill, Well 1 D-141A Revision No.O Saved: 29-Jan-08 (12) evidence shoiro~ing that the requirements of 20 AAC 25.025 {Bonding}have been rnet; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file lvith the commission and identified in theapplication: The proposed drilling program is listed below. Please refer also to well schematic attachments. P&A WORK (Pre Rig): 1. Install VR plug. 2. Pull OV and leave pocket open. 3. Test well head pack offs and cycle lock down screws. 4. Install BPV P8~A WORK (On Rig): -This work to be performed under the approved P&A sundry. L MIRU Doyon 15. 2. Pull BPV. 3. Circulate hot seawater with 6% KCL to clean the completion string. 4. Displace well to kill weight brine (estimated 9.2 ppg). 5. Set BPV 6. ND tree. 7. NU and test BOPS. 8. POOH with tubing and ESP. 9. RIH with clean out assembly and clean out to the top of the D window. POOH. 10. RIH with a 7-5/8" cement retainer on DP and set at the 7-5/8" x 7" XO. 11. Squeeze cement below the retainer. Plan to squeeze in 50-100 bbl increments. 12. Run in with Baker WindowMaster whipstock system, at window point of 5,500' MD. Do not set whipstock. 13. Test casing to 3000 psi for 30 minutes and record test. 14. Set whipstock at 5,500' MD. A`~ 15. Shear whipstock bolt. '1j~~ `~ 16. Set storm packer. ~~A 17. ND BOPE. 18. Remove wellhead and replace with new wellhead. 19. NU and test BOPE. 20. Prepare to mill the D window in accordance with the 1D-141A permit to drill. . oRi~rrtA~ 1D-141A PERMIT IT.doc Page 6 of 7 Printed: 29-Jan-08 Ap~ion for Permit to Drill, Well 1 D-141A Revision No.O Saved: 29-Jan-08 1 D-141 A Redrill (On Rig): -This work to be performed under the permit to drill. 21. Mi116-3/4" window. POOH. 22. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 23. Drill to TD of "D" sand lateral at 9,844' MD / 3,743' TVD, as per directional plan. 24. Backream to window. RIH and displace to solids free oil based mud. POOH. 25. PU and run 4-1/2" blank liner x 4-1/2" slotted liner. 26. Release hanger running tool, POOH, laying down drill pipe as required. 27. Run 5-1/2" intermediate casing and space out for landing in liner top. 28. Displace the 5-1/2" x 7-5/8" annulus by pumping down the annulus with corrosion inhibited brine followed by diesel such that the diesel cap extends from surface to 1,800' MD. 'Take returns from the 5-1/2" casing. The brine will be weighted such that the column of brine and diesel maintains an overbalance condition in the annulus. 29. Land the 5-1/2" casing. 30. Pick up and run the 2-7/8" gas lift completion as required. Land tubing. Set BPV. 31. Nipple down BOPE, nipple up tree and test. Pull BPV. 32. Freeze protect well with diesel by pumping into 2-7/8" x 5-1/2" annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 33. Set BPV and move rig off. 34. Rig up wire line unit. Pull BPV. 35. Set gas lift valves in mandrels. 36. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) ~fn application for a Pernut to Drill mustc be accompanied by each of the fo1loN~ing items, exceptfor an item alreadv on frle with the commission and identified in dae application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request anthori~ation under 20 AAC 2.080 for an am~utar disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1D Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on ID Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Current Schematic Attachment 4 P&A Schematic (Work to be performed under P&A Sundry) Attachment S Proposed 1D-141A Well Schematic 1D-141A PERMITIT.doc Page 7 of 7 Printed: 29-Jan-08 ORIGINAL 1D-141A~rilling Hazard~5ummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht, Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin Q ~"1~ ~ ~ ~ ~ ~ ~ 1D-141A Drilling Hazards Summary.doc K 1/29/2008 9:43:00 AM >; ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 D Pad 1 D-141 Plan: 1 D-141A Plan: 1 D-141A (wp11) Standard Proposal Report 25 January, 2008 HLLItJRTON Sperry Drilling Servioes ORIGINAL HALLIBURTON •parry OrWr~p •wrviw~ 7so s00 -750 -1000 -1250 -1500 C ~ -zooo °o ~ -2250 -2500 0 -2750 Y -3000 7 O -3250 Project: Kuparuk River Unit wELLDETAns: 1D-141 Site: Kuparuk 1 D Pad croana l~,et 70 7u , Well: 1 D-141 Wellbore: PIan:1D-141A Plan: 1D-141A (wp11) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well 10-141, True Norlh Vertical (TVD) Reference: 1D-141 A-D75 (d7 110.70ft (D15 (70.7+q0)) 0 o Measured Depth Reference: 1D-141 A-D75 ~ 110.70ft (D15 (70.7+40)) ° Calculation Method: Minimum Curvature ° o __ l0 3/4" ~ ^h° CASING DETAILS S N N TVD TVDSS MD Size Name `~ , o° 51 L63 400.93 51 L65 10-3/4 10 3/4" ^ "r ^ 3595.49 3484.79 5500.02 7-5/8 7-5/8" TOW ^i o° 3764.11 3653.41 5965.71 41/2 4 l/2" Blank ~° 0 3743.50 3632.80 9844.49 4-1/2 4 1/2" 4 1/2" Blank 0 0 M o° -• y° n _ - - . ' ~ ^° 4 I/2" Liner 1256' FNL, 1993' FEL - Sec24-TI 1N-Rl OE KOP: l l1T FNL, 2397 FEL- Sec24-Tl1N-R10E 7-5/8" TOW / ~A5 _ ID-141u MB_TopD _ - \6~° 1D-141a MB_TI 175° ID-141a MB_T2 - _ __--1D-14IPBI (89° lD-141a ME3_T3 ---- 187° IU-141a MB_T4 - -~- - 186° -3 X250 -4500 -4750 -5750 -6000 ID-141a MB_TS - -- IU-1 I~,~~~.[[l_lG - -- 185° _ ID-14IL1 ID-141a M8_T7 --- - - I U-141 a MB_Toe - - - ; 3744 Bk1L: 295' FSL, 1981' FEL - Sec24-TI IN-R10E • T M Azimuths to True North 41/2" \~ Magnetic North: 23.13° 1D-I41A (well) Magnetic Field Strength:57624.5snT Dip Angle: 80.82° Date: 1 0/3112 00 7 Model: BGGM2007 -1750 -1500 -1250 -1000 -750 -s00 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 32s0 3500 37s0 4000 4250 4s00 4750 5000 5250 5500 s7s0 6000 6250 6500 6750 7000 7250 7s00 7750 800 West(-)/East(+) (1000 fl/in) ~ ConocoPhillips Alaslta C c ~~ 1 !-IALLI BUR'i'®N Project: Kuparuk River Unit weu~eTnus: ~0-~4~ NonhAmericanDatum1963 AlaskaZonc4 Site: Kuparuk 1D Pad G°wd~,e~: 7o.~e E~psrry Or• Illin~ Sarvloes Well: 1 D-141 Wellbore: Plan: 1 D-141A Design: 1 D-141A (wp11) FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 2167 3572.70 3462.00 5455.01 K 13 3763.70 3653.00 5963.08 W Sak D 3~p0 2333 CASING DETAILS 2500 ~~ TVD TVDSS MD Size Name " 3y S l 1.63 400.93 511.65 10-3/4 10 3/4 3595.49 3484.79 5500.02 7-5/8 7-5/8" TOW 2667 3764.11 3653.41 5965.71 4-1/2 4 1/2" Blank 3743.50 3632.80 9844.49 4-1/2 41/2" ao°° 2833 3000 ~ Ay0 3167 3333 c yp0~ KOP: 1117' F NL, 2397' FEL -Sec24-T11 N-R10E BHL: 295' FSL, 1981' FEL -Sec24-T11N-R10E _ ~ ~ ~ p 4 1/2" Liner: 1256' FNL, 1993' FEL -Sec24-T11N-R10E ~ 3500 , - " ' ~~ .~ -------- --- ~0, , - - ~ ~ ' o o ~ ~ 1D-141A (wp11) 3667 7-5/8" TOW o ° ",~' ~ rn \ ~ L o ;' --- -1---- 3833 W Sak D ~ ~ ~, - - - o - - ~- - ° ~ o - - -------- ° . , ,,. ° A a~ 4 1/2" Blanly ' o ~ o ' ' o ° i i 1 D-141 L1 ~ a ~ ] ~ i i ~ ~ it i i ~ ~ 4 1 /2,. N ' ' ' 1 D-141 P61 ~ ~ ' ~ ; ~~ ~ 4000 1 D-141 a MB_Top D i ~ ~ ~ i ~ ~ ~ ~ H ~ i ~ 1D- 141a MB_T1 1D-141a MB_T2 1D-141a MB_T3 1D-141a MB_T4 1D-141a MB_T`1D-141a MB_T6 1D-141a MB_T7 1D-141a MB_Toe 4167 4333 4500 4667 4833 5000 5167 5333 667 833 1000 1167 1333 1500 1667 1833 2000 2167 2333 2500 2667 2633 3000 3167 3333 3500 3667 3833 4000 4167 4333 4500 4667 4833 5000 5167 5333 ° ~~ Vertical (500 ft/in) Section at 180.00 ConocoPhillips Alaska r 1 J Database: Alaska EDM Prod v16 Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1D-141 Wellbore: PIan:1D-141A Design: 1 D-141A (wp11) Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well 1D-141 TVD Reference: 1D-141A-D15 @ 110.70ft (D15 (70.7+40)) MD Reference: 1 D-141A-D15 @ 110.70ft (D15 (70.7+40)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 System Datum: Mean Sea Level Geo Datum: North American Datum 1927 Using Well Reference Point Map Zone: Alaska Zone 4 • Using geodetic scale factor Site Kuparuk 1D Pad, KRU Site Position: Northing: 5,959,678.83ft Latitude: 70° 18' 0.267 N From: Map Easting: 560,490.62ft Longitude: 149° 30' 30.085 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.46 ° Well 1 D-141 Well Position +N/-S 0.00 ft Northing: 5,959,678.83 ft Latitude: 70° 18' 0.404 N +E/-W 0.00 ft Easting: 560,490.62 ft Longitude: 149° 30' 47.455 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70ft - Wellbore - PIan:1D-141A - ~ Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2007 10/31 /2007 23.13 80.82 57,625 Design 1D-141A (wp11) Audit Notes: Version: 3 Phase: PROTOTYPE Tie On Depth: 5,500.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) {ft) (°) I 40.00 0.00 0.00 180.00 1/257200810:22:37AM ORIGINAL COMPASS 2003.16 Buifd 42F b ~ ~ ~, a Halliburton -Sperry Standard Proposal Report Database: Alaska EDM Prod v16 Local Co-ordinate Reference: Well 1D-141 Company: ConocoPhil lips (Alaska) Inc. -Kup1 ND Reference: 1 D-141A-D15 ~ 110.70ft (D15 (70.7+40)) Project: Kuparuk River Unit MD Refere nce: 1D-141A-D15 @ 110.70ft (D15 (70.7+40)) Site: Kuparuk 1D Pad North Reference: True Well: 1D-141 Survey Calculation Meth od: Minimum Curvature Wellbore: PIan:1D-141A Design: 1 D-141A (wp11) Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (/100ft) (°) 5,500.00 59.80 104.91 3,595.48 3,484.78 -1,130.17 3,480.57 0.00 0.00 0.00 0.00 5,512.00 60.77 103.02 3,601.43 3,490.73 -1,132.68 3,490.68 15.90 8.06 -15.78 -60.00 5,542.00 60.77 103.02 3,616.08 3,505.38 -1,138.58 3,516.19 0.00 0.00 0.00 0.00 5,587.04 61.61 99.02 3,637.80 3,527.10 -1,146.11 3,554.92 8.00 1.86 -8.88 -77.51 5,619.00 61.61 99.02 3,653.00 3,542.30 -1,150.52 3,582.69 0.00 0.00 0.00 0.00 5,960.64 81.00 122.00 3,763.32 3,652.62 -1,265.96 3,880.58 8.50 5.68 6.73 52.61 5,965.64 81.00 122.00 3,764.10 3,653.40 -1,268.57 3,884.77 0.00 0.00 0.00 0.00 6,101.57 87.97 131.27 3,777.19 3,666.49 -1,349.22 3,993.13 8.50 5.13 6.82 53.45 6,121.66 87.97 131.27 3,777.90 3,667.20 -1,362.46 4,008.22 0.00 0.00 0.00 0.00 6,373.21 90.50 152.50 3,781.30 3,670.60 -1,559.21 4,162.56 8.50 1.01 8.44 83.42 6,689.30 90.41 179.37 3,778.74 3,668.04 -1,863.02 4,238.68 8.50 -0.03 8.50 90.08 6,714.54 90.41 179.37 3,778.56 3,667.86 -1,888.25 4,238.96 0.00 0.00 0.00 0.00 6,722.43 90.41 180.00 3,778.50 3,667.80 -1,896.13 4,239.00 8.00 -0.02 8.00 90.16 6,853.39 90.48 189.17 3,777.48 3,666.78 -2,026.54 4,228.54 7.00 0.05 7.00 89.52 7,213.95 90.48 189.17 3,774.45 3,663.75 -2,382.48 4,171.10 0.00 0.00 0.00 0.00 7,237.75 90.71 188.00 3,774.20 3,663.50 -2,406.01 4,167.55 5.00 0.96 -4.91 -78.93 7,362.46 90.66 186.75 3,772.70 3,662.00 -2,529.68 4,151.54 1.00 -0.04 -1.00 -92.09 7,815.40 90.66 186.75 3,767.45 3,656.75 -2,979.45 4,098.28 0.00 0.00 0.00 0.00 7,906.14 91.17 186.00 3,766.00 3,655.30 -3,069.61 4,088.20 1.00 0.56 -0.83 -56.13 7,939.58 91.17 186.33 3,765.32 3,654.62 -3,102.84 4,084.61 1.00 0.00 1.00 90.15 8,803.06 91.17 186.33 3,747.70 3,637.00 -3,960.87 3,989.36 0.00 0.00 0.00 0.00 8,924.93 90.94 185.14 3,745.46 3,634.76 -4,082.11 3,977.18 1.00 -0.19 -0.98 -101.03 9,106.26 90.94 185.14 3,742.50 3,631.80 -4,262.69 3,960.94 0.00 0.00 0.00 0.00 9,228.87 89.76 184.79 3,741.76 3,631.06 -4,384.84 3,950.33 1.00 -0.96 -0.28 -163.64 9,643.90 89.76 184.79 3,743.50 3,632.80 -4,798.41 3,915.66 0.00 0.00 0.00 0.00 9,670.12 90.02 184.74 3,743.55 3,632.85 -4,824.54 3,913.48 1.00 0.98 -0.19 -10.80 9,844.49 90.02 184.74 3,743.50 3,632.80 -4,998.31 3,899.06 0.00 0.00 0.00 0.00 1 ~ ~Q:22.37 ~ pgg~3^ ~ ~, `~ ~ COMPASS 2003.16 Build 42F ~~••--~-~ ,r~1"J ~~~ ~ I ~,~ Operator: ConocoPhillips (Alaska) Inc. -Kupl Surface Location: 5959678.83 N 560490.62 E Well: 1D-141A (wpl l) Grid Coordinate System: North American Datum 1927 ~""~~-LL~ ~r V ~T Field: Kuparuk River Unit Grid Convergence: Alaska Zone 4 Rig: Doyon 141 Vertical Section Plane: 180.00° RKB Height: 110.7 ft i3perry drilling 'Servi~cs®rt Date: 25-Jan-08 Unwrapped Displacement: 7978.87 DDI: 6.679 SVY 1'v7[D Inc Azim. SSTVD TVD N/-S G/-W N Y DLS V.S. Comments # (ft) (Deg) (Deg) (ft) (ft) (1't) (ft) (ft) (ft) °1100ft (ft) 1 40.00 0.00 0.00 -70.70 40.00 0.00 N 0.00E 560490.62E 5959678.83 N 0.00 0.00 2 104.65 0.10 330.50 -6.05 104.65 0.05 N -0.03 560490.59E 5959678.88 N 0.15 -0.05 CB-GYRO-SS (1) 3 199.65 0.30 315.40 88.95 199.65 0.30 N -0.24 560490.37E 5959679.13 N 0.22 -0.30 4 294.65 0.30 25.10 183.95 294.65 0.70 N -0.31 W 560490.30E 5959679.53 N 0.36 -0.70 5 317.65 0.30 303.60 206.95 317.65 0.79 N -0.34 560490.28E 5959679.62 N 1.70 -0.79 6 347.65 0.30 303.0 236.95 347.65 0.87 N -0.47 560490.14E 5959679.70 N 0.01 -0.87 7 389.65 0.00 0.00 278.95 _ 389.65 0.93 N -0.56 ~ 560490.05E 5959679.76 N 0.71 -0.93 8 413.65 0.40 346.80 302.95 413.65 1.02 N -0.581'~ 560490.03E 5959679.84 N 1.67 -1.02 9 459.65 0.40 31.60 348.95 459.65 1.31 N -0.53 W 560490.08E 5959680,13 N 0.66 -1.31 • 10 492.65 1.90 38.60 381.94 492.64 1.83 N -0.13 ~ 560490.47E 5959680.66 N 4.56 -1.83 11 511.65 1.49 30,.10 400.93 511.63 2.28 N 0.21E 560490.81E 5959681.11 N 2.21 -2.28 10 3/4" 12 529.65 1.10 32.00 418.93 529.63 2.62 N 0.44E 560491.04E 5959681.45 N 2.21 -2.62 13 548.65 1.20 35.20 437.92 548.62 2.93 N 0.65E 560491.25E 5959681.77 N 0.63 -2.93 14 586.65 3.10 111.90 475.90 586.60 2.87 N 1.83E 560492.43E 5959681.72 N 8.04 -2.87 15 645.65 6.40 116.60 534.69 645.39 0.81 N 6.26E 560496.87E 5959679.69 N 5.63 -0.81 16 680.66 8.31 120.17 569.41 68Q11 -1.34 S 10.19E 560500.82E 5959677.57 N 5.61 1.34 MWD (2) 17 713.82 8.45 119.15 602.21 712.91 -3.73 S 14.39E 560505.04E 5959675.22 N 0.62 3.73 18 747.40 9.27 116.77 635.39 746.09 -6.15 S 18.96E 560509.62E 5959672.83 N 2.67 6.15 19 776.67 10.62 117.25 664.22 774.92 -8.45 S 23.46E 560514.14E 5959670.57 N 4.62 8.45 20 810.54 11.84 11.6.08 697.44 808.14 -11.40 S 24.36E 560520.06E 5959667.66 N 3.66 11.40 21 842.8b 13.99 ll2.15 728.95 839.65 -14.33 S 35.95E 560526.68E 5954664.78 N 7.18 14.33 22 872.81 17.20 110.68 757.79 ___ 868.49 -17.26 S 43.45E 560534.20E 5959661.92 N 10.80 17.26 23 907.83 20.11 109.''1 790.97 901.67 -21.12 S 53.97E 560544.75E 5959658.14 N 8.36 21.12 24 940.01 20.54 110.~~8 821.14 931.84 -25.01 S 64.45E 560555.26E 5959654.34 N 1.91 25.01 25 970.09 21.52 1 lu.-1 r, 849.22 9~~i.92 -28.83 S 74.54 1 560565.38E 5959650.60 N 3.32 28.83 26 1004.64 23.24 I 1 L6`~ 881.17 991.87 -33.56 S 86.81 L 560577.69E 5959645.96 N 5.16 .13.56 27 1036.55 24.13 I I?._'_ 910.39 1021.04 -38.36 S 98.;0 l~, 560589.61E 5959641.27 N 2.87 __ 38.36 28 1066.51 24.70 1 I I.4 ~ 937.67 1048.37 -42.96 S 110.20 l 560601.15E 5959636.76 N 2.19 4296 29 1162.87 26.43 l 1 ~.~~~~ 1024.59 1135.29 -58.93 S 14858 I: 560639.65E 5959621.09 Ty~ 2.06 58.93 30 1259.] 0 30.34 1 i ~. I + 1109.24 I ' I ~).~~4 -77.87 S I CIO z t F; 560681.43E 595~r602.49 N 4.13 77.8? 31 1354.92 33.44 116.118 1190.59 I ~Ol?9 -99.76 S 2~~.84 I~ 560727.23E '`9'158096 N 3.28 ~1~~.76 32 1451.87 33.40 114.>> 1271.51 1.5'__'1 -122.59 S 284.tL t. 560775.67E ~~139»8.> ~ 0.88 122.9 33 1549.08 35.63 I 11. ~2 1351.61 I~lt~2.31 -143.99 S ~3~.84 E 560826.56E ~959> 7.S 5 ~ 2.96 i~t 3.9~> ~ 34 1645:89 39.28 l I?.On 1428.45 _ I ~~ 9.15 -165.73 S _ 389.4 E 560881.43E __ _ ?9~9~ 16.2 ~ ~' 3.79 _ I6~.7 35 1',4129 42.92 113.31 1500.33 1011.(13 -189.91 S -1-1; -1o F, 560939.47E ~9~9-1~~Z52 1y 3.92 189.~~1 36 183?.,, 44.12 113.98 1569.98 16tii) 08 -216.44 S 507.99 ]: 561000.26E ~~»~~-lay,.-1~ ~ 1.34 216.4-1 Page 1 of 5 +... •-...~ ~y~ J-~' ~~ SV1' P!'iD Inc Azim. S5TVD TVll N/-S E/-W l Y DLS ~'.~. Comments #~ (ft) (Deg) (Deg) ('ft) (ft) (ft) (£t) (ft) (£t) °/100ft (ft4 37 1933.42 44.49 ll3.15 1638.73 4 7~49.~3 -243.27 S 569.49E 561061.97E 5159-4~nJ4 N 0.72 . 2-43.2 38 2029.55 48.00 II6J~4 1705.21 1815.91 -272.26 S 63256E 561125.26E ~~>~~~-}I 1.66 N 4.29 .72.26 39 2126.00 51.41 113.67 1767.58 18'18.28 -303.19 S ~>~~~~'3 [: 561192.22E ~~~~~>>ti1.26 N 4.04 303.19 40 2222.34 55.85 113. I6 1824.70 1935.40 -334.00 S -'0.45 E 561263.63E 5959 ~~ 1.03 N 4.63 334.00 41 2318.01 59.53 111.6E 1875.83 1986.53 -364.80 S 845.19E 561338.60E 5959320.83 N 4.07 364 eU 42 241 ^.13 60.15 107.25 1923.63 2034.33 -392.17 S 922.71E 561416.33E 5959294.08 N 4.06 39''. I 43 2508.54 60.67 106.35 1970.75 2081.45 -416.15 S - 1002.14E 561495.94E --- 5959270.74 ~J 0.98 41 h. 45 44 260.60 60.88 Inr,_69 2017.65 2128.35 -439.99 S 108254E 561576.49E 5959247.55 N 038 -~,~) v~~ 45 27nu 09 6136 107. ~ I 2063.77 2174.47 -464.44 5 1162.47E 561656.63E 5959223.74 N 0.76 464.-t-t 46 2795.69 60.58 I U 1.6_' 2110.17 2220.87 -487.43 S 1242.82 L'' 561737.16E 595920139 N 2.59 487.43 47 2891.99 59.47 l u;.82 2158.28 2268.98 -507.93 S 1323.68E 561818.17E 5959181.54 N 136 507.93 48 ~~+88.24 58.76 103511 2207.69 2318.39 -527.43 S 1403.95E 561898.57E 5959162.68 N 0.79 527--13 49 31183.83 57.96 I n5.9a 2257.84 2368.54 -548.08 S 1482.66E 561977.44E 5959142.67 N 230 548.1)8 50 348~i.i3 59.65 105.81 2307.71 2418.41 -570.58 S 1561.90E 562056.84E ~~>59120.80 N 1.76 57058 51 ~37a.30 58.12 106.5? 2357.41 246~.1 i -593.74 S 1640.90E 562136.02E ~!>59u~~S.28 N 1.85 593.'74 52 3373.09 60.56 106.90 2406.76 2517.-46 -617.92 S 1720.57E 562215.87E ~9~9n7-t.'-4 N 2.52 617.92 53 =i~~9 l0 5932 106.8-t 2454.85 2565 ~~ -642.03 S 1800.09E 562295.57E ~~~?~~u~l?~~ ~,' 1.29 642.03 54 3565.20 59.39 107.38 2503.84 2614.54 -66636 S 187).10 E 562374.77E 595902".~? v 0.49 66636 55 .662.05 59.40 107.48 2553.15 2663.85 -69133 S 1958.6-t E 562454.49E 5~59(u132-t N 0.09 691.3 56 3757.85 60.67 106.53 2600.99 27ll.69 -715.59 S 2038.00E 562534.03E 5958979.61 N 1.58 715.59 57 3854.;3 61.02 106.30 2648.00 2758.70 -739.40 S 2118.82E 562615.03E 59515')5(x.45 N 0.42 739.40 58 3950.64 60.98 105.98 2694.69 2805.39 -762.82 S ------ 2199.74E 562696.12E 5955933.68 N 0.29 762.82 59 4047.28 61.10 106.62 2741.48 2852.1.8 -786.55 S 228u.89 E 562777.45E 5958941~.6n N 0.59 786.55 60 41 t3.65 59.87 106.n8 2788.96 2899.66 -810.16 S 2361.3( E 562858.10E 5955857.C~ t N 137 S I i~.l ~~ 61 -__ 42~9i,1 59.61 105.vi.~ 283732 2948.02 -832.79 S ?111.IU t 562938.00E ~95R~tr,565 ~V 0.51 832.7~~ 62 4335.-I2 60.46 1(lxt.93 2885.17 2995.87 -854.64 S '5_'1.17 ~; 563018.24E 5~~5851-4.=4~ V 1.07 851.~,d 63 4431.n9 58.75 lOr, 66 2933.58 34.1-1.~8 -877.09 S ?60u,5; E 563097.81E S~~Sti~t22.6> ~ 237 S77.u9 64 4527.71 58.54 lUr>.72 2983.85 55)9-4.55 -900.78 S 2679_i~l E 563177.02E ~~~~~799 5' V 0.22 900.7~ 65 4x,3;.73 58.80 1 u6.32 3033.80 ~ 14-I 50 -924.12 S ~ 52, '8 4: 563255.87E ~9~5 7n.S7 N 0.45 924.12 66 4718.65 58.69 If17.4n 3083.03 3193 73 -947.64 S _"5,5 9u L 563333.66E 9~`5?53.97 N 0.98 947.64 67 4815.63 59.02 I u6.89 3133.19 32-43.89 -972.10 S 2915? I E 563413.15E 5958%30.14 N 0.56 972.10 68 4911.08 58.61 l u7.64 3182.61 :+'93.31 -99634 S 2~n>3. L`> E 56349131E 5958706.53 '~~ 0.80 996.34 69 5006.81 59.20 1U5.S1 3232.05 33-4'.75 -1019.92 S 3U71.h9 E 563569.99E 595868358 \ 1.75 1UL~i.92 70 5104.20 5933 105.-11 3281.83 3393.53 -1042.45 S 3152.51E 563650.78E ~9~5661.70 Iv 038 lild2.~45 71 5199.58 59.01 I US _' 4 3330.71 34-41.-41 -1064.09 S 32 ~ I .~ 0 k; 563729.93E 5958640.68 N 037 106-4.09 72 5293.42 5834 105.58 3379.50 349u.3i~ -108539 S ,308.58 I~ 563807.36E 5~>SS63U.no N 0.78 1u85.3~~ 73 589.,1• 59.75 10-4.39 3428.84 3539.5-4 -1106.59 S 388n~1~. 563887.02E 5x>585~>~>.45 N 1.87 1106,59 74 5485.;9 59.50 104? 3 3477.40 3588.10 -1127.00 5 3468.3" E 563967.46E 5958579.68 i~' 0.27 1127.00 Tie-On 55110.00 59.80 104.91 3484.78 3595.45 -1130.17 S 3-450.57E 563979.69E 59585%G.t,l ~ 4.51 1130.17 2 5500.0'_ 59.80 104.91 3484.79 3595.49 -1130.17 S 3-480.5') E 563979.70E - ~958576.r,u \~ 0.00 - I I?0.17 KOP: 1117 FNL, 2397 FEL - Sec24-T11N-R10E - i 3 551 _' 0u 60.77 103.n2 3490.73 3601.43 -1132.68 S 3190.68 E 563989.82E 59585''4.18 N 15.93 113_.68 4 5542.00 60.77 IU3.11? 3505.38 3616.08 -1138.58 S 3516.19 E 56401537E 5958568.48 N 0.00 1138.58 u Page 2 of 5 SVY :YID Inc Azim. SSTVD 'TVll N/-S E/-W 7s Y DLS V.S. Comments # (ft) (lleg) (Deg) (ft) [ft) {ft) (ft) (ft} lft) °/100ft (ft) 5 ??~o.i)0 60.91 102. ~0 3509.28 3619.98 -1140.11 S 3523.01E 564022.20E 5958>67.01 N 8.00 1140.11 6 ~SSZ(>4 61.61 99.u2 3527.10 3637.80 -1146.11 S 3554.92E 564054.15E 5958561.26 '~ 8.00 1146.11 7 5600.00 61.61 99.03 3533.26 3643.9( -1147.90 S 3566.18E 564065.42E 5958559.56. 0.00 11-17.90 8 561 ~~.u0 61.61 99.02 3542.30 3653.00 -1150.52 S - _ 3582.69E 564081.95E -- 5958557.08 N 0.00 -- 1150.52 9 56>o.n0 63.23 101.36 3556.65 3667.35 -1155.38 S 3609.72E 564109.02E 5958552.43 N 8.50 1155.33 10 5^00.00 65.92 10.00 3578.12 3688.82 -1165.69 S 3653.67 E 564153.04E S958S42.47 N 8.50 l It,5.69 11 57511.00 68.69 108.50 3597.42 3708.12 -1179.00 S _ 3697.83E 564197.30E - - -.. 5958529.52 N 8.50 1179.00 12 5800.00 71.53 111.86 3614.43 3725.1.3 -1195.22 S 3741.94E 564241.54E 5958513.65 N 8.50 1195.22 13 5850.00 74.43 1.15.11 3629.07 3739.77 -1214.28 S 3785.78E 564285.52E 5958494.95 N 8.50 1214.28 14 5900.00 77.38 118.26 3641.24 375].94 -1236.06 S 3829.09E 564329.00E 5958473.52 N 8.50 1236.06 15 5950.00 80.36 121.35 3650.89 3761.59 -1260.44 S 3871.65 L 564371.74E 5958449.47 N 8.50 1260.44 16 5960.64 81.00 122.00 3652.62 3763.32 -1265.96 S 3880.58E 564380.72E 5958444.03 N 8.50 1265.9C> 17 5963.08 81.00 122.00 3653.00 3763.70 -1267.24 S _ 3882.63E 564382.78E 5958442.77 N 0.00 1267.24 18 5965.64 81.00 122.00 3653.40 3764.10 -1268.57 S 3884.77E 564384.93E 5958441.45 N 0.00 1268.57 19 5965.71 81.00 122.00 3653.41 3764.11 -1268.61 S 3884.83 1 564384.99E 5958441.41 N 0.00 __1268.61 "I'OP D 4 1/2" Liner: 1256' FNL, 1993' FEL - Sec24-7 20 __ 6000.00 82.75 124.3(1 3658.26 3768.96 -1287.19 S 3913.24 ]: 564413.54E 5958423.06 N 8.52 1287.19 21 6050.00 85.31 127."7 3663.46 3774.16 -1316.46 S 3953.42E 564453.95E 5958394.12 N 8.50 1316.46 22 6101.57 87.97 131_'7 3666.49 3777.1.9 -1349.22 S 3993.13E 564493.91E 5958361.68 N 8.50 1349.22 23 6121.66 87.97 131.27 3667.20 3777.90 -1362.46 S 4008.22E 564509.10E 5958348.56 N 0.00 1362.46 24 6150.00 88.25 133.66 3668.14 3778.84 -1381.58 S 4029.11E 564530.15E 5958329.61 N 8.50 1381.58 25 6200.00 88.74 137.58 3669.45 3780.15 -1417.39 S 4063.96E 564565.28E 5958294.09 N 8.50 1417.39 26 6250.00 89.25 142.10 3670.33 3781.03 -1455.67 S 4096.10E 564597.72E 5958256.07 N 8.50 1455.47 27 6300.00 89.75 146.33 3670.76 3781.46 -1496.22 S 4125.33E 564627.27E 5958215.76 N 8.50 1496.22 28 6350.00 90.26 150.54 3670.76 3781.46 -1538.81 S 4151.50 E 564653.77E 5958173.39 N 8.50 1538.81 29 6372.84 90.50 152.4? 3670.60 3781.30 -1558.88 S _ 3162.40E 564664.83E 5958153.40 N 8.50 1558.88 1D-141a MB_T1 30 6373.21 90.50 152.>0 3670.60 3781.30 -1559.21 S 3162.56E 564665.00E 5958153.08 N 8.50 1559.21 31 6400.00 90.50 154.78 3670.37 378].07 -1583.21 S 4174.46E 564677.08E 5958129.17 N 8.50 _ 1583.21 32 6450.00 90.49 159A3 3669.94 3780.64 -1629.19 S 4194.07E 564697.06E 5958083.36 N 8.50 1629.19 33 6500.00 90.48 163.?8 3669.52 3780.22 -1676.50 S 4210.22E 564713.58E 5958036.19 N 8.50 1676.50 34 6550.00 90.46 167.5: 3669.11 3779.81 -1724.87 S 4222.81E 564726.56E 5957987.92 N 8.50 1724.87 35 6600.00 90.45 I71?8 3668.71 3779.41 -1774.04 S 1?31.79 E 564735.93E 5957938.83 N 8.50 1774.04 36 6650.00 90.43 176.1!3 3668.33 :"'79.03 -1823.75 S 4237.10E 564741.64E 5957889.17 N 8.50 1823.75 37 6689.30 90.41 179. ~ % 3668.04 3778.74 -1863.02 S 4238.68E 564743.53E 5957849.92 N 8.50 1863.02 38 6700.00 90.41 179.37 3667.96 3778.(6 -1873.71 S 4238.80E 564743.73E 5957839.23 N 0.00 1873.71 39 6714.5-I 90.41 I"~~. ~ ~ 3667.86 ~?78.56 -1888.25 S 4238.96E 564744.01E 5957824.70 N 0.00 1888.25 40 6?32.43 90.41 I80.U0 3667.80 37-8.50 -1896.13 S 423~a.00 E 564744.12E 5)57816.81 N 8.00 1896.13 41 ~>?22.79 90.41 I SO.U ~ 3667.80 3778.0 -1896.50 S #_'39.00 E 564744.12E 5957876.45 N 7.00 1896.50 1D-141a MB_T2 42 6750.00 90.43 18 L~) ~ 3667.60 3778.30 -1923.70 S 4238.54E 564743.87E 595778~?5 N 7.00 123.70 43 6800.00 90.45 185.43 3667.21 37;7.91 -1973.59 S 4335.33 L 564741.06E 5957739.34 ~ 7.00 Iv73.59 44 683.39 90.48 189.17 3666.78 3777.48 -2026.54 S 4228.54 [: 564734.70E 5'~5768~>._4 N 7.00 Zli_6.5~1 45 690u.00 90.48 189.17 3666.39 3777.09 -2072.55 S 4^_21..12 1 564727.65E 5'x.576 4i1._'R N 0.00 '_07_'.55 46 70(u).110 90.48 189.17 3665.55 3776.25 -2171.27 S -t20~.19 I~: 564712.51E 595754E-15 1y 0.00 3171.27 11N-R • Page 3 of 5 SVY MD inc Azim. SST~'D TVD N!-S E/-tip' X Y DLS t'.S. Comments # (ft} (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) °1100ft (ft) 47 7100.00 90.48 189.17 3664.71 3775.47 -2269.99 S 4189.26E 564697.37E ~~~7442.(;'` 'v 0.00 226999 48 7200.00 90.48 189.17 3663.86 3774.56 -2368.71 S 4173.32 JL 564682.23E ~~>~? ~-13.7' ~' 0.00 2368.71 49 7213.95 90.48 189.17 3663.75 3774.45 -2382.48 S 417].10 E 564680.11E ~~~~ 7 ~3u.o0 ti 0.00 _' ;8'.48 50 7237.75 90.71 188.00 3663.50 3774?0 -2406.01 S 4167.55E 564676.75E ~'>~?301,.4 N 5.00 2~U6.01 51 7243.12 90.71 18'.95 3663.43 3774.li -2411.33 S 41i~6g0 E 564676.05E 5957301.12 N 1.00 ?-111.,E 1D-141aMB_T3 52 73011.00 90.69 187.38 3662.74 377 3.4-1 -2467.70 S 4159.?2 l: 564668.92E ~~~~"'_-13.7i~ N 1.00 ~'-ti~7.7q 53 %=h2.46 90.66 T8GJ5 3662.00 37-x.70 -2529.68 S -41St ~4 L: 564661.73E Se~7lR2.~~G ~ 1.00 "'5_'9.68 54 74D+1.011 90.66 186.75 3661.57 377'_..'7 -2566.95 S 414",.I? I: 564657.61E ~y~'1-1~.~i~ N 0.00 2566.9 55 7500.011 90.66 186.75 3660.41 377L11 -2666.25 S 41>~.~' L~ 564646.65E 5y57045.98 N 0.00 2666.25 56 7600.00 90.66 186.75 3659.25 3769.~~5 -2765.55 S 41'_.61 L 564635.69E 5956v-1(i.(~I ~ 0.00 2765.55 57 7700.00 90.66 186.75 3658.09 37~~8.7~~ -2864.85 S 41 I I.85 E 564624.72E 5956847?3 1y 0.00 2864.85 58 7800.00 90.66 186.75 3656.93 3767.1?- -2964.15 S 4100.09 1~. 564613.76E 595v747.85 1~ 0.00 2964. I 59 7815.-1(1 90.66 __ _ 186.75 3656.75 3767.45 -2979.45 S 4098.28 I. 564612.07E - 595673?.5~1 1~ 0.00 2>i9.45 60 7>ur,.l4 91.17 186.00 3655.30 3766.011 -3069.61 S 4088.20 L 564602.72E 595h642.31 i~ 1.00 3069.61 61 79(19.'3 91.17 186.03 3655.24 3765.94 -3072.68 S 4087.88E 564602.42E 595hi~39?4 ~ 1.00 3072.68 1D-141aMB T4 62 7>39.58 91.17 186.33 3654.62 3765.>2 -3102.84 S -1nSa.bl I: 564599.39E ~~~~6~~u~1.05 N 1.00 3102.84. 63 8000.00 91.17 186.33 3653.38 3764.u8 -3162.89 S 4077.94 1~: 564593.21E ~~~~~~~-18.97 N 0.00 3162.89 64 8100A0 91.17 186.33 3651.34 376?.i14 -3262.26 S 4066.91 L 564582.97E 5951,a4~i.53 N 0.00 3262.26 65 8200.00 91.17 186.33 3649.30 3760.(111 -3361.62 S 4055.88E 564572.74E 5956350.08 N 0.00 3361.62 66 8300.011 91.17 186.33 3647.26 3757.96 -3460.99 S 4044.85 L 564562.50E 5956250,64 N 0.00 3460.99 67 840n.(in 91.17 18b.33 3645.22 3755.92 -3560.36 S 4033.82 F, 564552.27E 5956151.20 N 0.00 3560.36 68 85uu.uU 91.17 186.33 3643.18 3753.88 -3659.73 S 4022.79 ~ 564542.03E 5956051.76 N 0.00 3659.73 69 8t~0o.uo 91.17 186.33 3641.14 3751.84 -3759.10 S 4011.76E 564531.80E 5955952.32 N 0.00 3759.10 70 8^ou.0u 91.17 151.; ~ 3639.10 3749.80 -3858.47 S 4000.73E 564521.56E __5955852.87 N 0.00 3858.47 71 88U29~ 91.17 _ 186.33 3637.00 3747.70 -3960.77 S :949.37 E 564511.02E 5955^50.5(1 N 0.00 3960.77 1D-141aMB T5 72 8803.06 91.17 186.33 3637.00 3747.78 -3960.87 S 398'3.36 F 564511.01E 5955" 50.39 N 0.00 3961).87 73 8900.0u 90.98 185.38 3635.18 3745.58 -4057.29 S 39-9.47 I: 564501.89E 5955653.91 N 1.00 4u57?9 74 8~~_4.~13 90.94 185.14 3634.76 37~15.a6 -4082.11 S 39;7.18 I~: 564499.80E X955629.08 ~ 1.00 4082.11 75 90u(i.0u 90.94 185.14 3633.54 3744?4 -4156.87 S ;y7ii46 1. 564493.68E ~9~"~~4.27 V 0.00 4156.87 76 9106.16 90.94 185.14 3631.80 3742.811 -4262.59 S ;96(i'~5 1. 564485.02E ~y~--4~4~t.5Q v 0.00 4262.59 1D-141aMB_T6 77 `lluv?r, 90.94 185.1 4 3631.80 3743.59 -4262.69 5 3~~60.94 1~~ 564485.01 E ~~~~~-t~iS.39 ~~ 0.00 4'~>'.~>9 78 '0.00.00 90.04 184.8- 3631.01 3741.71 -4356.07 S 3<i52.77 L 564477.58E ~~»~_~4.!~7 N 1.00 4356.07 79 1)_28.87 89.76 184.'79 3631.06 3741.76 -4384.84 S '~~u.33 I~: 564475.38E ~9~532~~.18 N 1.00 438x.81 80 '>.300.00 89.76 184..79 3631.36 _ 3742.06 -4455.72 S 3~i-11.3! 1= 564470.00E ~~1~~2~5 '? T~ 0.00 ~Id~> 72 81 9400.00 89.76 184.7~> 3631.78 37-4_'.48 -4555.37 S 393~~-(13 l= 564462.44E ~9~~I~i.~4~ ~ 0.00 4~?~.37 82 9500.00 89.76 184.79 3632.20 37~L.~10 -4655.02 S 392?.>8 F 564454.89E 3~)~6(135.8G ~i 0.00 ~i~~3.02 83 9600.00 89.76 154.79 3632.62 3743.32 -4754.67 S 3919 ,2 1~. 564447.33E 5'i~4956 16 v 0.00 4754.67 84 9643.71 89.76 18-1.79 3632.80 3?-13.50 -4798.27 S 3')15.67 I~. 564444.02E 595-191_'.33 N 0.00 4798.27 1D-141aMB T7 85 96~13.91i 89.76 184."9 3632.80 3743.50 -4798.41 S 391 ~ ~~~~ I~; 564444.01E 5~~~-I~~12.3~1 '~ 0.00 ~t7~~8.41 86 9i>?0.12 90.02 _ IS4J-4 3632.85 3743.55 -4824.54 S 3913 1~ E 564442.04E _ 595-1886.25 ~ 1.00 ~48~4.54 87 970u.00 90.02 184.7 I 3632.84 37-1_ .54 -4854.32 S 391 I .li I E 564439.81E 5~~54856.46 !~' 0.00 4854.32 88 ~18nn.U0 90.02 184.'4 3632.81 37-13.51 -4953.98 S 3902 ?4 L: 564432.34 E Se5~1756.75 ~ 0.00 4953.98 I~ L J Page 4 of 5 a..,,,.,,~, ~.: ,~ .~r...o 5~T # i~1D (ff) Inc (Deg) Azim. (llcg) SSTVD (ft) 'TVD (ft) N/-S (tt) El-~~' (fe) h (ft) Y (ftj DLS °/100ft ~'.S. (ft) Comments 89 90 - 9844.3 9844.49 90A2 90.02 184.74 184.74 3632.80 3632.80 3743.50 3743.50 -4998.17 S -4998.31 S 3899.07E 3899.06E 564429A2 E 564429.01E 595~k?13.53 N 59-4? 13.39 N 0.00 0.00 4994.1? -I~I~i~.: l 1D-141aMB_Toe-MWD(3) 4 1/2" Page 5 of 5 i ~~~~ Database: Alaska EDM Prod v16 Local Co-ordinate Reference Company: ConocoPhillips (Alaska) Inc. -Kup1 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1D Pad North Reference: Well: 1 D-141 Survey Calculation Method: Wellbore: Plan:1D-141A Design: 1 D-141A (wp11) - -_ __ Targets li Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S -Shape (°) (°) (ft) (ft) 1 D-141 a MB_T5 0.00 0.00 3,747.70 -3,960.75 - plan hits target - Point 1 D-141 a MB_Toe 0.00 0.00 3,743.50 -4,998.16 - plan hits target - Point 1D-141a MB_T4 0.00 0.00 3,765.70 -3,069.17 - plan misses by 32.68ft at 7909.23ft MD (3765.94 TVD, -3072.68 N, 4087.88 E) - Point 1D-141a MB_T1 0.00 0.00 3,780.70 -1,558.83 - plan hits target - Point 1D-141a MB_Top D 0.00 0.00 3,764.10 -1,268.57 - plan hits target - Point 1 D-141 a MB_T3 0.00 0.00 3,773.70 -2,405.64 - plan misses by 42.48ft at 7242.89ft MD (3774.14 TVD, -2411.10 N, 4166.84 E) - Point 1D-141a MB_T2 0.00 0.00 3,777.70 -1,896.49 - plan hits target - Point 1D-141a MB_T7 0.00 0.00 3,741.60 -4,798.27 - plan misses by 1.90ft at 9643.76ft MD (3743.50 TVD, -4798.27 N, 3915.67 E) - Point 1 D-141 a MB_T6 0.00 0.00 3,741.70 -4,262.57 - plan hits target - Point Casing Points Halliburton -Sperry Standard Proposal Report Well 1 D-141 1 D-141A-D15 @ 110.70ft (D15 (70.7+40)) 1 D-141A-D15 cQ 110.70ft (D15 (70.7+40)) True Minimum Curvature +E/_yp (ft) 3,989.25 3,898.94 4,055.39 4,162.48 3,884.77 4,124.71 4,238.79 3,915.54 3,960.83 Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ('~) ('~) 511.65 511.63 10 3/4" 10-3/4 13-1/2 5,500.02 3,595.49 7-5/8" TOW 7-5/8 9-7/8 5,965.71 3,764.11 4 1/2" Blank 4-1/2 6-3/4 9,844.49 3,743.50 41/2" 4-1/2 6-3/4 Formations Measured Depth (ft) 5,963.08 Vertical Vertical Depth Depth SS-: (ft) ft 3,572.70 3,763.70 Dip Dip Direction Name Lithology (°) (°) K 13 0.00 W Sak D 0.00 1/25J200810:22:37AM Page 5 COMPASS 2003.16 Build 42F a ~ ... ~ .~ Database: Alaska EDM Prod v16 Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1D-141 Wellbore: PIan:1D-141A Design: 1 D-141A (wp11) Plan Annotations Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well 1D-141 TVD Reference: 1D-141A-D15 ~ 110.70ft (D15 (70.7+40)) MD Reference: 1D-141A-D15 @ 110.70ft (D15 (70.7+40)) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Local Coordinates Depth Depth +N/-S +E/_W (ft) (ft) (ft) (ft) Comment 5,500.02 3,595.49 -1,130.17 3,480.59 KOP: 1117' FNL, 2397' FEL -Sec24-T11 N-R10E 5,965.71 3,764.11 -1,268.61 3,884.83 4 1/2" Liner: 1256' FNL, 1993' FEL -Sec24-T11N-R10E 9,844.49 3,743.50 -4,998.32 3,899.06 BHL: 295' FSL, 1981' FEL -Sec24-T11 N-R10E 1/25/2008 10:22:37AM Page 6 ~ COMPASS 2003.16 Build 42F ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1 D-141 Plan: 1D-141A 1D-141A (wp11) Anticollision Summary Report 11 January, 2008 .~" Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1D Pad - 1D-141 - Plan: 1D-141A - 1D-141A (wp11) Datum Height: 1 D-141A-D15 ~ 110.70ft (D15 (70.7+40)) Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ALLIBURTN Sperry Drilling Services n ~U ~.~J ',® G-~ ~~ SURVEY PROGRAM Date:2008-01-1 OT00:00:00 Validated: Yes Version:3 ~Ih From Deplh To Survey/Plan Tool 104.65 645.65 1D-]41 PB1 gyro (]D-141 PB1) CB-GYROSS 680.66 5500.00 ]D-141 PB1 (ID-141P61) MWD 5500.00 9844.05 10.141A (wpl l)(Plan: ID-l4[A) MWD+IFR-AIC-CAZ-SC 10.11 0 0_ 1 D-141 L1 zoo 180 Travelling Cylinder Azimuth (TFO+AZI) [°~ vs Centre to Centre Separation [200 ft/inJ NAD 27 ASP Zone 4 : WELL DETAILS: 1D-141 Greund Lavel: 70.70 +N/-S+E/-W Northing Easling Latittude Longitude Slot 0.00 0.00 6969430.34 1700622.6870° 18' 0.404 N 149° 30' 47.466 W REFERENCE INFORMATION Co-ordinals (N/E) Reference: Well 1D-141, True Nonh Vertical (ND) Reference: 1 D-141 A-D16 ~ 110.70R (D76 (70.7+40)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 1D-141 A-D16 ~ 110.70R (D16 (70.7+40)) Calculation Method: Minimum Curvature ConocoPhillips (Alaska) Ina. -Kup1 Calculation Method: Minimum CurvaWre Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surfaes: Elliptical Conic Warning Method: Rules Based From Colour To MD 0 5250 5250 --- - 5500 5500 6000 6000 7000 7000 8000 8000 9000 9000 10000 I D-32 90 1 U-141 L1 180 Travelling Cylinder Azimuth (TFO+AZI) (°J vs Centre to Centre Separation 150 9/inl ANT-COLLISION SETTINGS Interpolation Melhod: MD, interval: 60.00 Depth Range From: 6600.00 To 9844.64 Centre Distance: 1180.46 Reference: PIan:10.141A (w p11)(10.141/PIan:1D-141A) 0 6 u-f ata~ it lt°zSV~ 16 ]Z3 W J]]lM 2~ °-um ~6n°~son o-uw xe i6t+o~a o-ui.6e_np°a°n n sa,+n eo.r¢ ,6+.>. J~o.w ~.a: J~J~ °ro °m ~6.J, ,o-,n. xe_*mo~n HAtrLIBtJRTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Summary Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1D Pad - 1D-141 - Plan: 1D-141A -1D-141A (wp11) Scan Range: 5,500.00 to 9,844.64 ff. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Se paration is Unl imited Reference Well Comparison Well Proximity Measured Vertical Measured Vertical Between Between Relative Site Name Depth Depth Depth Depth Centres Ellipsoids North Comparison Well Name -Design (ft) (ft) (ft) (ft) (ft) (ff) Bearing Kuparuk 1C Pad 1C-135 1C-135 5,738.80 3,703.81 11,700.00 3,752.65 446.33 191.35 8.15 1C-135 1C-135 (wp02) 5,726.89 3,699.29 11,695.55 3,765.50 435.47 170.47 4.51 Kuparuk 1D Pad Clearance Factor Warning 1.750 Pass -Major Risk 1.643 Pass -Major Risk °'- 'I"'9 1 D-05 1 D-05 5,507.67 3,599.31 5,775.00 4,465.58 1,012.84 859.52 291.81 6.606 Pass -Major Risk ~ .~.~ 1D-11 1D-11 6,389.19 3,781.16 6,150.00 4,053.20 349.24 178.33 296.43 2.043 Pass-Major Risk ,~''~ 1 D-11 1 D-11 L1 6,389.19 3,781.16 6,150.00 4,053.20 349.24 178.33 296.43 2.043 Pass -Major Risk 1 D-11 1 D-11 L2 6,389.19 3,781.16 6,150.00 4,053.20 349.24 178.12 296.43 2.041 Pass -Major Risk ~' 1 D-11 1 D-11 L2P61 6,389.19 3,781.16 6,150.00 4,053.20 349.24 178.33 296.43 2.043 Pass -Major Risk ~ r ~ .~i ~i ~i ~ ~ ~ ~ ~ ~ 1 D-30 1 D-30 7,657.31 3,769.28 6,675.00 4,253.73 566.65 438.04 336.58 4.406 Pass -Major Risk 1 D-30 1 D-30L1 7,657.31 3,769.28 6,675.00 4,253.73 566.65 438.08 336.58 4.407 Pass -Major Risk 1 D-32 1 D-32 7,436.36 3,771.84 6,725.00 3,642.88 144.42 18:42 154.84 1.146 Pass -Major Risk 1 D-32 1 D-32L1 7,436.36 3,771.84 6,725.00 3,642.88 .144.42 18.40 154.94 1.148 Pass -Major Risk 1 D-32 1 D-32L1 PB1 7,436.38 3,771.84 8,725.00 3,642.88 144.42 18.54 154.94 1.147 Pass -Major Risk • 1 1 L_J 11 January, 2008 - 14:03 Page 2 of 6 COMPASS HAL.L.IBURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Summary Report for 1 D-141/1 D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1D Pad - 1D-141 - Plan: 1D-141A - 1D-141A (wp11) Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Se paration is Unlimited Reference Well Comparis on Well Proximity Measured Vertical Measured Vertical Between Between Relative Site Name Depth Depth Depth Depth Centres Ellipsoids North Clearance Comparison Well Name -Design (ft) (ff) (ft) (ft) (ft) (ft) Bearing Factor Warning 1D-34 1D-34 8,982.86 3,744.51 7,200.00 3,516.36 243.36 105.93 161.24 1.771 Pass- Major Risk 1 D-34 1 D-34L1 8,982.16 3,744.52 7,200.00 3,517.10 243.33 106.01 161.40 1.772 Pass -Major Risk 1D-34 1D-34L1PB1 8,982.16 3,744.52 7,200.00 3,517.10 243.33 106.38 161.40 1.777 Pass-Major Risk ~ ., - - - 1 D-41 ~ 1 D-41 .~ 1 D-41 1D-41 Prelim: 1 D-13 Kuparuk 1E Pad Kuparuk 1J Pad 1 D-41 6,382.81 3,781.21 5,850.00 3,160.67 669.13 537.81 131.42 5.095 Pass -Major Risk 1 D-41 PB1 6,382.81 3,781.21 5,850.00 3,160.67 669.13 538.07 131.42 5.106 Pass -Major Risk 1 D-41 (wp05) 6,390.32 3,781.15 5,900.00 3,180.54 671.65 529.83 127.43 4.736 Pass -Major Risk 1D-41PB2 6,382.81 3,781.21 5,850.00 3,160.67 669.13 538.07 131.42 5.106 Pass- Major Risk 1 D-13wp02 7,186.16 3,774.68 6,375.00 3,191.45 598.31 486.67 170.71 5.359 Pass -Major Risk Survev tool program From lff) 104.65 680.66 5,500.00 To (ff) 645.65 5,500.00 9,844.05 1D-141A (wp11) SurveylPlan Survey Tool CB-GYRO-SS MWD MWD+IFR-AK-CAZ-SC • 11 January, 2008 - 14:03 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Summary Report for 1D-141/1D-141A (wp11) Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. /°"°°'~ SSG / ,,,1,..~ 11 January, 2008 - 14:03 Page 4 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Summary Report for 1 D-141/1 D-141A (wp11) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to 1 D-141A-D15 @ 110.70ft (D15 (70.7+40)). Northing and Easting are relative to 1 D-141. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: 0.46 °. Summary is based on Minimum Centre Distance , Ladder Plot C X15 O u7 C O N t6 X10 N i C U O ~ 5 C N U i - - - - - - i i i i - - - -- - - - - - i ~ i i - - - - - - i i i - - - - '- i - I ~ i i i i x:, - ~ i i ~ ~ i ~ i _ i i i i i - i i i i i i i i u i i t 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 ~ t i i i i ~ i i , ~ ~ 0 0 0 0 2000 4000 6000 8000 10000 Measured Depth (2000 ft/in) 1 D-112, 1 D-112, 1 D-112 V 2 1 D-113, 1 D-113, 10.113 V2 1 D-114, 1 D-114, 1 D-114 V2 1 D-115, 1 D-115, 10.115 V 2 1 D-116, 1 D-116, 1 D-116 V 2 1D-117, 1D-117, 10.117 V2 1 D-118, 1 D-118, 1 D-118 V2 1D-118, 10.118, Plan #1 V1 1D-118, Plan: 1D-118A, Plan: 1D-118A V1 1 D-119, 1 D-119, 1 D-119 V2 1D-12, 10.12, 10.12 V9 1 D-120, 10.120, 1 D-120 V2 1D-121, 1D-121, 1D-121 V2 1 D-122, 1 D-122, 1 D-122 V2 1 D-123, 1 D-123, 1 D-123 V2 1 D-124, 1 D-124, 1 D-124 V 2 1 D-125, 10.125, 10.125 V2 1 D-125, 1 D-125A, 10.125A VO 1 D-135, 1 D-135, 10.135 V2 10.14, 1D-14, 10.14 V3 1 D-140, 1 D-140, 1 D-140 V 0 1D-140, 10.140L1, 1D-14 L1 VO 1D-140, 1D-140L1, 1D-140 L1 Wp10 V1 1D-140, 10.140PB1, 10.140 Wp10 V1 1D-140, 10.140PB1, 1D-140P81 V4 1D-141, 1D-141, 10.141 V2 1D-141, 10.141L1P61, 10.141L1PB1 V2 1D-141, 1D-141L1P62, 1D-141L1P62 V2 1D-141, 1D-141PB1, 1D-141PB1 V2 1 D-28, 10.28, 1 D-28 V4 1D-28, 1D-28, Plan 1D-28 L1 (wp08) V5 1D-28, 1D-28L1, 1D-28L1 V8 1D-28, 1D-28L1, Plan 1D-28 (wp07) V5 1f 1l u 11 January, 2008 - 14:03 Page 5 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Summary Report for 1D-141/1D-141A (wp11) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor '''J~ N ~.t~ ~~ Y 1 1 c O m LL c O .~ a fn 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 Measured Depth (2000 ft/in) 1.00 - ~ ~ i ~ 0.00 f - ---- - --- _.._ ._ ~ - ~ ~ _-. --.._: -- ~ ~ ~ ~ ~ ~ I i 9.00 i --- - -- ------ -~- ~ i -- - -- - -- ~ ~ ~ I, 8.00 ~ -- - - - - - I -- - - ~-- -- _ i ,' ,~ ~ i I ~ i 7.00 -- - - - _._:_- --- -- _ - --- ~_ - y i I 6.00 ~ ! ~ ; ~ ~ _ :. ~ i ' ~ ~ 1 ~. ~ 5.00 ~ -- T --_ , ( _ ,T (jj ~ -- z ~ ;~, i ~ ~ , f, I ~ I , ; •j> 4.00 ~ - __ - -- - t -- ~ I'` i _ ~~~ `~ }, ~., l 3.00 ~ - --- - - i --- `' , -~ i ~ i 2.00 ~ -- ~ ~ - -- -- - ~~ _ L_ . % 1.00 _s ' ~~ I 0.00 LEGEND ~- 1D-141, 1D-141L1, 1D-141L1 V2 -~ 1 C-135, 1 C-135, 1 C-135 V2 ;~^ 1C-135,1G135PB1,1C-135(wp02)V1 1D-05, 1D-05, 1D-OS V6 -~ 1D-11, 1D-11, 1D-11 V2 1D-11, 1D-11L1, 1D-11L1 V1 1D-11, 1D-11L2, 1D-11 L2 V5 1D-11, 1D-11L2PB1, 1D-11L2PB1 V1 ~- 1D-141, 1D-141, 1D-141 V2 -~- 1D-141, 1D-141L1PB1, 1D-141L1PB1 V2 1D-141, 1D-141 L1PB2, 1D-141L1PB2 V2 1D-141, 1D-141PB1, 1D-141PB1 V2 1 D-30, 1 D-30, 1 D-30 V6 ~- 1D-30, 1D-30L1, 1D-30L1 V2 r~ 1 D-32, 1 D-32, 1 D-32 V5 1D-32, 1D-32L1, 1D-32L1 V1 - 1D-32, 1D-32L1PB1, 1D-32L1PB1 V1 1 D-34, 1 D-34, 1 D-34 V6 1D-34, 1D-34L1, 1D-34L1 V3 -~}- 1D-34, 1D-34L1PB1, 1D-34L1P81 V4 M 1D-41, 1D~1, 1D~1 V1 -~ 1D~1, 1D~1PB1, 1D~1 (wp05)V1 - 1D~1,1D~1P81,1D~1PB1V4 1D~1, 1D~1P82, 1D~1P82 V1 Prelim: 1D-13, Prelim: 1D-13, 1D-13wp02 V2 • i 11 January, 2008 - 14:03 Page 6 of 6 COMPASS HALLIBURTCIN ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32L1P81 Scan Range: 5,500.00 to 9,844.84 ft. Measured Depth. Scan Radius is 1,180 .46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axisl2 (ft) (ft) Axisl2 (ft) (ft) (ft) Bearing Bearing Factor Warning 5,503.02 3,597.00 60.43 5,425.00 3,256.87 31.67 544.68 304.40 317.10 -106.17 149.40 2.393 Pass -Major Risk 5,518.85 3,604.78 60.52 5,450.00 3,265.41 31.81 556.80 304.35 325.97 -107.25 149.73 2.412 Pass -Major Risk 5,538.10 3,614.18 60.56 5,475.00 3,273.99 31.95 569.13 304.76 335.05 -106.22 150.77 2.431 Pass -Major Risk 5,550.00 3,619.98 60.58 5,500.00 3,282.61 32.08 581.69 304.84 344.62 -106.26 151.41 2.454 Pass -Major Risk 5,566.17 3,627.77 60.61 5,525.00 3,291.24 32.22 594.60 304.38 354.86 -107.38 151.69 2.480 Pass -Major Risk 5,582.82 3,635.68 60.65 5,550.00 3,299.81 32.36 607.92 303.87 365.59 -108.58 151.91 2.509 Pass -Major Risk 5,595.70 3,641.76 60.67 5,575.00 3,308.31 32.50 621.55 304.24 376.41 -107.63 152.86 2.535 Pass -Major Risk 5,614.04 3,650.40 60.71 5,600.00 3,316.73 32.64 635.41 304.63 387.60 -106.74 153.75 2.564 Pass -Major Risk 5,815.18 3,729.68 61.15 5,625.00 3,325.08 32.79 648.46 308.64 395.66 -84.39 162.74 2.565 Pass -Major Risk 6,102.81 3,776.96 61.83 5,650.00 3,333.35 32.93 651.32 293.04 419.00 -50.76 178.51 2.804 Pass -Major Risk "ray 6,167.97 3,779.21 61.98 5,675.00 3,341.55 33.08 651.09 285.78 422.84 -41.10 -176.31 2.853 Pass -Major Risk !~ 6,284.36 3,781.35 62.24 5,700.00 3,349.67 33.22 648.43 264.42 436.96 -20.94 -165.97 3.066 Pass -Major Risk ~+~..~. 393.90 6 3 781.12 62.45 5,725.00 3,357.72 33.36 642.65 238.92 451.72 -1.91 -156.19 3.366 Pass -Major Risk , 6,477.69 , 3,780.40 62.59 5,750.00 3,365.71 33.50 634.49 216.31 460.59 12.74 -148.67 3.649 Pass -Major Risk 3~.u. 6,557.29 3,779.74 62.71 5,775.00 3,373.62 33.64 624.35 193.14 468.62 26.51 -141.66 4.009 Pass -Major Risk * `~'°~ 6,631.15 3,779.17 62.79 5,800.00 3,381.46 33.78 612.39 170.86 474.90 39.16 -135.29 4.454 Pass -Major Risk 6,692.01 3,778.72 62.85 5,825.00 3,389.22 33.92 598.80 153.14 476.20 48.94 -130.43 4.884 Pass -Major Risk rv...b 6,712.59 3,778.57 62.87 5,850.00 3,396.87 34.07 584.71 153.72 461.79 48.79 -130.58 4.757 Pass -Major Risk 3 6,756.34 3,778.25 62.91 5,875.00 3,404.43 34.21 570.27 143.20 456.63 54.65 -127.74 5.018 Pass -Major Risk 6,797.99 3,777.93 62.94 5,900.00 3,411.87 34.35 555.09 134.06 450.45 60.21 -125.10 5.305 Pass -Major Risk 6,836.77 3,777.62 62.96 5,925.00 3,419.15 34.50 539.25 126.18 442.88 65.26 -122.76 5.596 Pass -Major Risk 6,863.29 3,777.39 62.97 5,950.00 3,426.25 34.65 522.93 123.61 429.91 67.07 -122.10 5.621 Pass -Major Risk 6,881.59 3,777.24 62.98 5,975.00 3,433.18 34.79 506.64 123.98 413.54 66.52 -122.65 5.442 Pass -Major Risk 6,899.90 3,777.09 62.99 6,000.00 3,440.03 34.93 490.44 124.32 397.30 65.92 -123.25 5.265 Pass -Major Risk 6,918.25 3,776.93 63.00 6,025.00 3,446.94 35.06 474.30 124.66 381.14 65.29 -123.88 5.091 Pass -Major Risk 6,936.63 3,776.78 63.00 6,050.00 3,453.93 35.19 458.23 125.01 365.07 64.63 -124.54 4.919 Pass -Major Risk 6,955.05 3,776.62 63.01 6,075.00 3,460.98 35.33 442.23 125.35 349.08 63.94 -125.23 4.747 Pass -Major Risk 6,973.49 3,776.47 63.02 6,100.00 3,468.10 35.45 426.29 125.68 333.17 63.20 -125.97 4.578 Pass -Major Risk 6,991.93 3,776.31 63.03 6,125.00 3,475.29. 35.57 410.39 126.02 317.33 62.42 -126.75 4.410 Pass -Major Risk 7,010.37 3,776.16 63.04 6,150.00 3,482.55 35.69 394.56 126.36 301.56 61.59 -127.58 4.243 Pass -Major Risk ~~ 11 January, 2008 - 14:53 Page 2 of 21 COMPASS HALLIBURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32L1PB1 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.48 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 7,028.82 3,776.00 63.05 6,175.00 3,489.86 35.81 378.80 126.71 285.88 60.70 -128.47 4.077 Pass -Major Risk 7,047.33 3,775.85 63.06 6,200.00 3,496.96 35.94 363.28 127.07 270.46 59.70 -129.47 3.914 Pass -Major Risk 7,065.90 3,775.69 63.07 6,225.00 3,503.76 36.08 348.06 127.44 255.39 58.58 -130.59 3.756 Pass -Major Risk 7,084.53 3,775.53 63.07 6,250.00 3,510.29 36.21 333.18 127.81 240.69 57.31 -131.85 3.602 Pass -Major Risk 7,103.18 3,775.38 63.08 6,275.00 3,516.60 36.36 318.60 128.18 226.32 55.90 -133.26 3.453 Pass -Major Risk 7,121.73 3,775.22 63.09 6,300.00 3,523.00 36.50 304.11 128.54 212.05 54.35 -134.82 3.303 Pass -Major Risk 7,140.15 3,775.07 63.10 6,325.00 3,529.51 36.65 289.72 128.91 197.88 52.64 -136.53 3.155 Pass -Major Risk 7,158.46 3,774.91 63.11 6,350.00 3,536.12 36.79 275.48 129.28 183.84 50.75 -138.42 3.006 Pass -Major Risk 7,176.75 3,774.76 63.12 6,375.00 3,542.62 36.94 261.63 129.64 170.15 48.63 -140.54 2.860 Pass -Major Risk ~,~ 7,195.07 3,774.60 63.13 6,400.00 3,548.92 37.09 248.32 130.01 156.92 46.25 -142.92 2.717 Pass -Major Risk 7,213.41 3,774.45 63.14 6,425.00 3,555.03 37.24 235.66 130.38 144.18 43.57 -145.60 2.576 Pass -Major Risk ~ 7,231.12 3,77428 63.15 6,450.00 3,560.97 37.38 223.73 133.71 131.56 38.88 -149.43 2.427 Pass -Major Risk ~, 7,249.45 3,774.05 63.16 6,475.00 3,567.06 37.52 212.41 135.61 119.65 34.83 -153.05 2.290 Pass -Major Risk 773.82 63.17 08 3 7 268 6,500.00 3,573.39 37.66 201.66 136.63 108.10 31.02 -156.67 2.155 Pass -Major Risk , , . 7,286.88 3,773.60 63.18 6,525.00 3,579.94 37.80 191.55 137.66 96.81 26.93 -160.58 2.022 Pass -Major Risk ~~ 7,305.79 3,773.37 63.19 6,550.00 3,586.74 37.93 182.11 138.68 85.65 22.50 -164.81 1.888 Pass -Major Risk 7,324.65 3,773.14 63.20 6,575.00 3,593.87 38.06 173.35 139.70 74.45 17.68 -169.44 1.753 Pass -Major Risk 7 343.46 3,772.92 63.21 6,600.00 3,601.32 38.19 165.41 140.72 63.34 12.44 -174.50 1.621 Pass -Major Risk , 7,362.21 7,380.85 3,772.70 3,772.49 63.22 63.23 6,625.00 6,650.00 3,609.11 3,617.19 38.33 158.46 141.74 38.46 152.70 142.14 52.48 42.15 6.74 179.99 0.98 174.23 1.495 1.381 Pass -Major Risk Pass -Major Risk 7,399.42 3,772.27 63.24 6,675.00 3,625.51 38.59 148.34 142.53 32.77 -5.18 168.07 1.284 Pass -Major Risk 7,417.92 3,772.06 63.25 6,700.00 3,634.07 38.73 145.54 142.95 24.75 -11.64 161.60 1.205 Pass -Major Risk 7,436.36 3,771.84 63.26 6,725.00 3,642.88 38.86 144.42 143.37 18.54 -18.31 154.94 1.147 Pass -Major Risk 7,454.69 3,771.63 63.28 6,750.00 3,651.95 39.00 745.04 143.80 14.46 -25.04 148.21 1.111 Pass -Major Risk 7,472.89 3,771.42 63.29 6,775.00 3,661.30 39.13 147.41 144.22 12.79 -31.69 141.56 1.095 Pass -Major Risk 7,490.97 3,771.21 63.30 6,800.00 3,670.92 39.27 151.51 144.65 13.62 -38.12 135.12 1.099 Pass -Major Risk 7,508.91 3,771.00 63.31 6,825.00 3,680.82 39.41 157.24 145.08 16.91 -44.23 129.02 1.121 Pass -Major Risk 7,526.76 3,770.80 63.32 6,850.00 3,690.93 39.55 164.50 145.51 22.50 -49.91 123.34 1.158 Pass -Major Risk 544.50 7 3,770.59 63.33 6,875.00 3,701.24 39.68 173.14 145.94 30.14 -55.12 118.13 1.211 Pass -Major Risk , 562.13 7 770.39 3 63.34 6,900.00 3,711.76 39.82 182.99 146.38 39.51 -59.86 113.39 1.275 Pass -Major Risk , 7,579.68 , 3,770.18 63.35 6,925.00 3,722.46 39.97 193.91 146.81 50.35 -64.14 109.11 1.351 Pass -Major Risk 11 January, 2008 - 14:53 Page 3 of 21 COMPASS HALLIBURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/10-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32L1PB1 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 7,180 .46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 7,597.19 3,769.98 63.37 6,950.00 3,733.20 40.11 205.79 147.24 62.43 -67.96 105.29 1.436 Pass -Major Risk 7,614.67 3,769.78 63.38 6,975.00 3,743.99 40.25 218.48 147.68 75.51 -71.36 101.88 1.528 Pass -Major Risk 7,632.11 3,769.57 63.39 7,000.00 3,754.81 40.39 231.87 148.11 89.37 -74.39 98.86 1.627 Pass -Major Risk 7,649.58 3,769.37 63.40 7,025.00 3,765.68 40.54 245.78 148.59 103.78 -77.09 96.16 1.731 Pass -Major Risk 7,667.11 3,769.17 63.41 7,050.00 3,776.58 40.68 260.07 149.07 118.57 -79.50 93.74 1.838 Pass -Major Risk 7,684.72 3,768.96 63.42 7,075.00 3,787.51 40.83 274.65 149.54 133.65 -81.67 91.57 1.948 Pass -Major Risk 7,702.40 3,768.76 63.43 7,100.00 3,798.47 40.97 289.47 150.02 148.96 -83.63 89.62 2.060 Pass -Major Risk 7,720.07 3,768.55 63.45 7,125.00 3,809.43 41.12 304.60 150.50 164.54 -85.39 87.85 2.175 Pass -Major Risk 7,737.70 3,768.35 63.46 7,150.00 3,820.37 41.27 320.07 150.97 180.42 -86.98 86.26 2.292 Pass -Major Risk 7,755.28 3,768.15 63.47 7,175.00 3,831.28 41.42 335.84 151.44 196.55 -88.42 84.83 2.411 Pass -Major Risk 7,772.83 3,767.94 63.45 7,200.00 3,842.16 41.57 351.86 151.92 212.89 -89.71 83.53 2.532 Pass -Major Risk 7,790.43 3,767.74 63.49 7,225.00 3,852.96 41.73 368.01 152.39 229.32 -90.89 82.36 2.653 Pass -Major Risk ~,,,,_a! 7,808.12 3,767.53 63.51 7,250.00 3,863.66 41.89 384.25 152.86 245.78 -91.95 81.30 2.775 Pass -Major Risk ~--~p 7,826.40 3,767.32 63.52 7,275.00 3,874.25 42.04 400.54 153.75 261.96 -93.10 80.24 2.890 Pass -Major Risk ...~.~„ 7,845.11 3,767.06 63.53 7,300.00 3,884.74 42.20 416.87 154.93 277.94 -94.29 79.21 3.001 Pass -Major Risk 7,863.88 3,766.77 63.54 7,325.00 3,895.13 42.36 433.27 156.13 293.96 -95.41 78.25 3.110 Pass -Major Risk 7 882.70 3,766.45 63.56 7,350.00 3,905.43 42.52 449.73 157.33 310.02 -96.46 77.35 3.219 Pass -Major Risk , 7,901.57 3,766.09 63.57 7,375.00 3,915.62 42.68 466.26 158.54 326.12 -97.45 76.51 3.327 Pass -Major Risk ~' 7,918.76 a 3,765.74 63.58 7,400.00 3,925.77 42.83 482.82 158.70 343.10 -97.89 75.98 3.456 Pass -Major Risk 7,935.43 3,765.40 63.59 7,425.00 3,935.94 42.98 499.41 158.56 360.35 -98.15 75.56 3.591 Pass -Major Risk 7,953.12 3,765.04 63.61 7,450.00 3,946.14 43.14 516.03 158.91 377.08 -98.63 75.04 3.714 Pass -Major Risk 7,971.18 3,764.67 63.62 7,475.00 3,956.37 43.29 532.63 159.40 393.64 -99.15 74.51 3.832 Pass -Major Risk 7,989.25 3,764.30 63.63 7,500.00 3,966.61 43.44 549.25 159.88 410.20 -99.65 74.01 3.950 Pass -Major Risk 8,007.31 3,763.93 63.64 7,525.00 3,976.86 43.59 565.93 160.37 426.80 -100.12 73.54 4.068 Pass -Major Risk 8,025.35 3,763.56 63.66 7,550.00 3,987.11 43.74 582.65 160.87 443.42 -100.56 73.10 4.185 Pass -Major Risk 8,043.38 3,763.19 63.67 7,575.00 3,997.37 43.89 599.42 161.36 460.07 -100.98 72.68 4.301 Pass -Major Risk 8,061.42 3,762.83 63.68 7,600.00 4,007.60 44.04 616.22 161.84 476.74 -101.38 72.29 4.418 Pass -Major Risk 8,079.47 3,762.46 63.70 7,625.00 4,017.80 44.20 633.05 162.32 493.43 -101.74 71.92 4.534 Pass -Major Risk 8,097.53 3,762.09 63.71 7,650.00 4,027.97 44.35 649.89 162.80 510.12 -102.09 71.57 4.650 Pass -Major Risk 8,115.61 3,761.72 63.72 7,675.00 4,038.10 44.51 666.75 163.32 526.77 -702.42 71.25 4.763 Pass -Major Risk 8,133.70 3,761.35 63.74 7,700.00 4,048.24 44.67 683.60 163.88 543.39 -102.73 70.94 4.876 Pass -Major Risk 11 January, 2008 - 14:53 Page 4 of 21 COMPASS u HAL.LIBURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1 D Pad - 1 D-32 - 1 D-32L1 P81 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180 .46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ff) (ff) Axisl2 (ft) (ff) Axis/2 (ft) (ff) (ft) Bearing Bearing Factor Warning 8,151.82 3,760.98 63.75 7,725.00 4,058.38 44.82 700.45 164.44 560.00 -103.03 70.64 4.987 Pass -Major Risk 8,169.95 3,760.61 63.76 7,750.00 4,068.51 44.98 717.29 165.00 576.59 -103.31 70.35 5.098 Pass -Major Risk 8,188.10 3,760.24 63.78 7,775.00 4,078.65 45.13 734.14 165.55 593.19 -103.58 70.08 5.209 Pass -Major Risk 8,206.24 3,759.87 63.79 7,800.00 4,088.80 45.28 751.01 166.10 609.80 -103.84 69.82 5.319 Pass -Major Risk 8,224.38 3,759.50 63.80 7,825.00 4,098.95 45.42 767.89 166.65 626.42 -104.09 69.57 5.428 Pass -Major Risk 8,242.52 3,759.13 63.82 7,850.00 4,109.11 45.57 784.79 167.20 643.05 -104.33 69.33 5.537 Pass -Major Risk 8,260.61 3,758.76 63.83 7,875.00 4,119.24 45.72 801.76 167.70 659.78 -104.56 69.11 5.647 Pass -Major Risk ~^°~°>I 8,278.63 3,758.39 63.84 7,900.00 4,129.32 45.88 818.84 168.20 676.61 -104.76 68.90 5.757 Pass -Major Risk ~~..~ 8,296.57 3,758.03 63.86 7,925.00 4,139.35 46.03 836.02 168.71 693.53 -104.96 68.71 5.867 Pass -Major Risk e"°""_"1 8,314.45 3,757.66 63.87 7,950.00 4,149.34 46.18 853.31 169.22 710.53 -105.13 68.53 5.976 Pass -Major Risk 8,332.30 3,757.30 63.89 7,975.00 4,159.34 46.34 870.61 169.74 727.54 -105.31 68.36 6.085 Pass -Major Risk a~..~ 8,350.16 3,756.94 63.90 8,000.00 4,169.38 46.49 887.92 170.26 744.54 -105.47 68.19 6.193 Pass -Major Risk 8,368.02 3,756.57 63.91 8,025.00 4,179.43 46.64 905.23 170.78 761.55 -105.63 68.03 6.300 Pass -Major Risk 8,385.88 3,756.21 63.93 8,050.00 4,189.51 46.80 922.54 171.32 778.54 -105.79 67.87 6.406 Pass -Major Risk 8,403.77 3,755.84 63.94 8,075.00 4,199.56 46.96 939.83 171.89 795.47 -105.94 67.72 6.510 Pass -Major Risk 8,421.70 3,755.48 63.95 8,100.00 4,209.56 47.11 957.09 172.45 812.37 -106.09 67.58 6.613 Pass -Major Risk 8,439.67 3,755.11 63.97 8,125.00 4,219.54 47.27 974.32 173.02 829.23 -106.22 67.44 6.716 Pass -Major Risk 8,457.65 3,754.74 63.98 8,150.00 4,229.46 47.43 991.55 173.57 846.11 -106.36 67.31 6.818 Pass -Major Risk 8,475.59 3,754.38 64.00 8,175.00 4,239.34 47.60 1,008.83 174.12 863.03 -106.48 67.19 6.919 Pass -Major Risk 8,493.50 3,754.01 64.01 8,200.00 4,249.15 47.76 1,026.16 174.66 879.99 -106.59 67.08 7.020 Pass -Major Risk 8,511.37 3,753.65 64.03 8,225.00 4,258.91 47.93 1,043.53 175.21 896.99 -106.69 66.98 7.121 Pass -Major Risk 8,529.22 3,753.28 64.04 8,250.00 4,268.67 48.09 1,060.95 175.73 914.05 -106.79 66.88 7.222 Pass -Major Risk 8,547.04 3,752.92 64.05 8,275.00 4,278.48 48.25 1,078.39 176.25 931.13 -106.89 66.78 7.323 Pass-Major Risk 8,564.83 3,752.56 64.07 8,300.00 4,288.32 48.40 1,095.86 176.77 948.25 -106.98 66.68 7.424 Pass -Major Risk 8,582.60 3,752.19 64.08 8,325.00 4,298.21 48.56 1,113.35 177.30 965.37 -107.08 66.59 7.524 Pass-Major Risk 8,600.43 3,751.83 64.10 8,350.00 4,308.15 48.72 1,130.77 177.85 982.40 -107.17 66.49 7.622 Pass -Major Risk 8,618.35 3,751.46 64.11 8,375.00 4,318.14 48.87 1,148.09 178.41 999.34 -107.27 66.39 7.718 Pass-Major Risk 8,636.34 3,751.10 64.13 8,400.00 4,328.19 49.03 1,165.32 178.97 1,016.19 -107.38 66.29 7.814 Pass-Major Risk r~ ~_J 11 January, 2008 - 14:53 Page 5 of 21 COMPASS HAl1_BURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1 D-141/1 D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32L7 Scan Range: 5,500.00 to 9,844.64 ff. Measured Depth. Scan Radius is 1,180 .46 ff . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Referen ce Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ff) (ft) Axisl2 (ft) (ff) Axis/2 (ft) (ff) (ff) Bearing Bearing Factor Warning 5,503.02 3,597.00 60.43 5,425.00 3,256.87 31.67 544.68 304.40 317.10 -106.17 149.40 2.393 Pass -Major Risk 5,518.85 3,604.78 60.52 5,450.00 3,265.41 31.81 556.80 304.48 325.84 -107.25 149.73 2.411 Pass -Major Risk 5,538.10 3,614.18 60.56 5,475.00 3,273.99 31.95 569.13 304.90 334.92 -106.22 150.77 2.430 Pass -Major Risk 5,550.00 3,619.98 60.58 5,500.00 3,282.61 32.08 581.69 304.97 344.49 -106.26 151.41 2.452 Pass -Major Risk 5,566.17 3,627.77 60.61 5,525.00 3,291.24 32.22 594.60 304.51 354.73 -107.38 151.69 2.479 Pass -Major Risk 5,582.82 3,635.68 60.65 5,550.00 3,299.81 32.36 607.92 304.01 365.45 -108.58 151.91 2.507 Pass -Major Risk 5,595.70 3,641.76 60.67 5,575.00 3,308.31 32.50 621.55 304.37 376.28 -107.63 152.86 2.534 Pass -Major Risk 5,614.04 3,650.40 60.71 5,600.00 3,316.73 32.64 635.41 304.76 387.47 -106.74 153.75 2.563 Pass -Major Risk 5,815.18 3,729.68 61.15 5,625.00 3,325.08 32.79 648.46 308.77 395.53 -84.39 162.74 2.564 Pass -Major Risk 6,102.81 3,776.96 61.83 5,650.00 3,333.35 32.93 651.32 293.17 418.87 -50.76 178.51 2.802 Pass -Major Risk 6,167.97 3,779.21 61.98 5,675.00 3,341.55 33.08 651.09 285.91 422.71 -41.10 -176.31 2.851 Pass -Major Risk 6,284.36 3,781.35 62.24 5,700.00 3,349.67 33.22 648.43 264.56 436.83 -20.94 -165.97 3.064 Pass -Major Risk 6,393.90 3,781.12 62.45 5,725.00 3,357.72 33.36 642.65 239.05 451.59 -1.91 -156.19 3.364 Pass -Major Risk ,,:~„-„~„ 6,477.69 3,780.40 62.59 5,750.00 3,365.71 33.50 634.49 216.45 460.46 12.74 -148.67 3.646 Pass -Major Risk 6,557.29 3,779.74 62.71 5,775.00 3,373.62 33.64 624.35 193.27 468.49 26.51 -141.66 4.006 Pass -Major Risk ~..,,,® 6,631.15 3,779.17 62.79 5,800.00 3,381.46 33.78 612.39 170.99 474.77 39.16 -135.29 4.450 Pass -Major Risk 6,692.01 3,778.72 62.85 5,825.00 3,389.22 33.92 598.80 153.27 476.07 48.94 -130.43 4.879 Pass -Major Risk 59 6 712 3 778.57 62.87 5,850.00 3,396.87 34.07 584.71 153.85 461.66 48.79 -130.58 4.752 Pass -Major Risk , . 6,756.34 , 3,778.25 62.91 5,875.00 3,404.43 34.21 570.27 143.33 456.50 54.65 -127.74 5.012 Pass -Major Risk ~"""~ 6,797.99 3,777.93 62.94 5,900.00 3,411.87 34.35 555.09 134.19 450.32 60.21 -125.10 5.298 Pass -Major Risk 6,836.77 3,777.62 62.96 5,925.00 3,419.15 34.50 539.25 126.31 442.75 65.26 -122.76 5.588 Pass -Major Risk 6,863.29 3,777.39 62.97 5,950.00 3,426.25 34.65 522.93 123.74 429.78 67.07 -122.10 5.613 Pass -Major Risk 6,881.59 3,777.24 62.98 5,975.00 3,433.18 34.79 506.64 124.11 413.41 66.52 -122.65 5.434 Pass -Major Risk 6,899.90 3,777.09 62.99 6,000.00 3,440.03 34.93 490.44 124.46 397.16 65.92 -123.25 5.258 Pass -Major Risk 6,918.25 3,776.93 63.00 6,025.00 3,446.94 35.06 474.30 124.80 381.01 65.29 -123.88 5.084 Pass -Major Risk 6,936.63 3,776.78 63.00 6,050.00 3,453.93 35.19 458.23 125.14 364.93 64.63 -124.54 4.912 Pass -Major Risk 6,955.05 3,776.62 63.01 6,075.00 3,460.98 35.33 442.23 125.48 348.95 63.94 -125.23 4.741 Pass -Major Risk 6,973.49 3,776.47 63.02 6,100.00 3,468.10 35.45 426.29 125.82 333.04 63.20 -125.97 4.571 Pass -Major Risk 6,991.93 3,776.31 63.03 6,125.00 3,475:29 35.57 410.39 126.15 317.20 62.42 -126.75 4.403 Pass -Major Risk 7,010.37 3,776.16 63.04 6,150.00 3,482.55 35.69 394.56 126.49 301.43 61.59 -127.58 4.237 Pass -Major Risk 7,028.82 3,776.00 63.05 6,175.00 3,489.86 35.81 378.80 126.84 285.75 60.70 -128.47 4.071 Pass -Major Risk • • 11 January, 2008 - ?4:53 Page 6 of 21 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Anticollision Report for 1D-141/1D-141A (wp11) Kuparuk River Unit Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32L1 Scan Range: 5,500.00 to 9,844.54 ft. Measured Depth. Scan Radius is 1,180.48 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 7,047.33 3,775.85 63.06 6,200.00 3,496.96 35.94 363.28 127.21 270.33 59.70 -129.47 3.908 Pass -Major Risk 7,065.90 3,775.69 63.07 6,225.00 3,503.76 36.08 348.06 127.58 255.26 58.58 -130.59 3.750 Pass -Major Risk 7,084.53 3,775.53 63.07 6,250.00 3,510.29 36.21 333.18 127.94 240.55 57.31 -131.85 3.597 Pass -Major Risk 7,103.18 3,775.38 63.08 6,275.00 3,516.60 36.36 318.60 128.31 226.19 55.90 -133.26 3.448 Pass -Major Risk 7,121.73 3,775.22 63.09 6,300.00 3,523.00 36.50 304.11 128.68 211.92 54.35 -134.82 3.299 Pass -Major Risk 140 15 7 775.07 3 63.10 6,325.00 3,529.51 36.65 289.72 129.04 197.75 52.64 -136.53 3.150 Pass -Major Risk `~ . , 7,158.46 , 3,774.91 63.11 6,350.00 3,536.12 36.79 275.48 129.41 183.71 50.75 -138.42 3.002 Pass -Major Risk 7,176.75 3,774.76 63.12 6,375.00 3,542.62 36.94 261.63 129.78 170.01 48.63 -140.54 2.856 Pass -Major Risk ,~„- 7,195.07 3,774.60 63.13 6,400.00 3,548.92 37.09 248.32 130.14 156.78 46.25 -142.92 2.713 Pass -Major Risk 7,213.41 3,774.45 63.14 6,425.00 3,555.03 37.24 235.66 130.51 144.04 43.57 -145.60 2.572 Pass -Major Risk ...~... 7,231.12 3,774.28 63.15 6,450.00 3,560.97 37.38 223.73 133.84 131.43 38.88 -149.43 2.424 Pass -Major Risk 7,249.45 3,774.05 63.16 6,475.00 3,567.06 37.52 212.41 135.74 119.51 34.83 -153.05 2.287 Pass -Major Risk ` 7,268.08 3,773.82 63.17 6,500.00 3,573.39 37.66 201.66 136.76 107.97 31.02 -156.67 2.152 Pass -Major Risk 'y*~ 7,286.88 3,773.60 63.18 6,525.00 3,579.94 37.80 191.55 137.80 96.67 26.93 -160.58 2.019 Pass -Major Risk 7,305.79 3,773.37 63.19 6,550.00 3,586.74 37.93 182.11 138.81 85.52 22.50 -164.81 1.885 Pass -Major Risk 7,324.65 3,773.14 63.20 6,575.00 3,593.87 38.06 173.35 139.83 74.31 17.68 -169.44 1.750 Pass -Major Risk 343.46 7 3,772.92 63.21 6,600.00 3,601.32 38.19 165.41 140.85 63.21 12.44 -174.50 1.619 Pass -Major Risk , 7,362.21 3,772.70 63.22 6,625.00 3,609.11 38.33 158.46 141.87 52.35 6.74 179.99 1.493 Pass -Major Risk 7,380.85 3,772.49 63.23 6,650.00 3,617.19 38.46 152.70 142.27 42.02 0.98 174.23 1.380 Pass -Major Risk 399.42 7 3,772.27 63.24 6,675.00 3,625.51 38.59 148.34 142.67 32.64 -5.18 168.07 1.282 Pass -Major Risk , 92 7 417 772.06 3 63.25 6,700.00 3,634.07 38.73 145.54 143.08 24.62 -11.64 161.60 1.204 Pass -Major Risk , . 7,436.36 , 3,771.84 63.26 6,725.00 3,642.88 38.86 144.42 143.50 18.40 -18.31 154.94 1.146 Pass -Major Risk 7,454.69 3,771.63 63.28 6,750.00 3,651.95 39.00 145.04 143.93 14.33 -25.04 148.21 1.110 Pass -Major Risk 7,472.89 3,771.42 63.29 6,775.00 3,661.30 39.13 147.41 144.36 12.66 -31.69 141.56 1.094 Pass -Major Risk 490.97 7 3,771.21 63.30 6,800.00 3,670.92 39.27 151.51 144.78 13.49 -38.12 135.12 1.098 Pass -Major Risk , 508.91 7 3,771.00 63.31 6,825.00 3,680.82 39.41 157.24 145.21 16.78 -44.23 129.02 1.119 Pass -Major Risk , 526.76 7 3,770.80 63.32 6,850.00 3,690.93 39.55 164.50 145.64 22.37 -49.91 123.34 1.157 Pass -Major Risk , 544.50 7 3,770.59 63.33 6,875.00 3,701.24 39.68 173.14 146.08 30.00 -55.12 118.13 1.210 Pass -Major Risk , 7,562.13 3,770.39 63.34 6,900.00 3,711.76 39.82 182.99 146.51 39.38 -59.86 113.39 1.274 Pass -Major Risk 579.68 7 3,770.18 63.35 6,925.00 3,722.46 39.97 193.91 146.94 50.22 -64.14 109.11 1.350 Pass -Major Risk , 7,597.19 3,769.98 63.37 6,950.00 3,733.20 40.11 205.79 147.37 62.30 -67.96 105.29 1.434 Pass -Major Risk • • 11 January, 2008 - 14:53 Page 7 of 21 COMPASS ConocoPhillips (Alaska) Inc. -Kup1 HA1_L.IBURTON Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32L7 Scan Range: 5,500.00 to 9,844.64 ff. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ff) (ff) Axis/2 (ft) (ff) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 7,614.67 3,769.78 63.38 6,975.00 3,743.99 40.25 218.48 147.81 75.37 -71.36 101.88 1.527 Pass -Major Risk 7,632.11 3,769.57 63.39 7,000.00 3,754.81 40.39 231.87 148.25 89.24 -74.39 98.86 1.626 Pass -Major Risk 7,649.58 3,769.37 63.40 7,025.00 3,765.68 40.54 245.78 148.72 103.65 -77.09 96.16 1.729 Pass -Major Risk 7,667.11 3,769.17 63.41 7,050.00 3,776.58 40.68 260.07 149.20 118.44 -79.50 93.74 1.836 Pass -Major Risk 7,684.72 3,768.96 63.42 7,075.00 3,787.51 40.83 274.65 149.68 133.52 -81.67 91.57 1.946 Pass -Major Risk 7,702.40 3,768.76 63.43 7,100.00 3,798.47 40.97 289.47 150.16 148.82 -83.63 89.62 2.058 Pass -Major Risk 7,720.07 - 3,768.55 63.45 7,125.00 3,809.43 41.12 304.60 150.63 164.41 -85.39 87.85 2.173 Pass -Major Risk 7,737.70 3,768.35 63.46 7,150.00 3,820.37 41.27 320.07 151.10 180.29 -86.98 86.26 2.290 Pass -Major Risk ~, 7,755.28 3,768.15 63.47 7,175.00 3,831.28 41.42 335.84 151.58 196.42 -88.42 84.83 2.409 Pass -Major Risk 7,772.83 3,767.94 63.48 7,200.00 3,842.1 ti 41.57 351.86 152.05 212.76 -89.71 83.53 2.530 Pass -Major Risk 7,790.43 3,767.74 63.49 7,225.00 3,852.96 41.73 368.01 152.52 229.18 -90.89 82.36 2.651 Pass -Major Risk ~,,,r,,,,~ 7,808.12 3,767.53 63.51 7,250.00 3,863.66 41.89 384.25 152.99 245.64 -91.95 81.30 2.772 Pass -Major Risk 7,826.40 3,767.32 63.52 7,275.00 3,874.25 42.04 400.54 153.88 261.82 -93.10 80.24 2.887 Pass -Major Risk ~~~, 7,845.11 3,767.06 63.53 7,300.00 3,884.74 42.20 416.87 155.07 277.80 -94.29 79.21 2.998 Pass -Major Risk 7,863.88 3,766.77 63.54 7,325.00 3,895.13 42.36 433.27 156.26 293.82 -95.41 78.25 3.107 Pass -Major Risk `''~ 7,882.70 3,766.45 63.56 7,350.00 3,905.43 42.52 449.73 157.46 309.89 -96.46 77.35 3.216 Pass -Major Risk , .®~i° 7,901.57 3,766.09 63.57 7,375.00 3,915.62 42.68 466.26 158.67 325.99 -97.45 76.51 3.324 Pass -Major Risk ~~'°'""°~"' 7,918.76 3,765.74 63.58 7,400.00 3,925.77 42.83 482.82 158.84 342.97 -97.89 75.98 3.452 Pass -Major Risk 7,935.43 3,765.40 63.59 7,425.00 3,935.94 42.98 499.41 158.70 360.21 -98.15 75.56 3.588 Pass -Major Risk 7,953.12 3,765.04 63.61 7,450.00 3,946.14 43.14 516.03 159.04 376.95 -98.63 75.04 3.710 Pass -Major Risk 7,971.18 3,764.67 63.62 7,475.00 3,956.37 43.29 532.63 159.53 393.50 -99.15 74.51 3.828 Pass -Major Risk 7,989.25 3,764.30 63.63 7,500.00 3,966.61 43.44 549.25 160.01 410.07 -99.65 74.01 3.946 Pass -Major Risk 8,007.31 3,763.93 63.64 7,525.00 3,976.86 43.59 565.93 160.50 426.67 -100.12 73.54 4.064 Pass -Major Risk 8,025.35 3,763.56 63.66 7,550.00 3,987.11 43.74 582.65 161.00 443.28 -100.56 73.10 4.181 Pass -Major Risk 8,043.38 3,763.19 63.67 7,575.00 3,997.37 43.89 599.42 161.49 459.93 -100.98 72.68 4.297 Pass -Major Risk 8,061.42 3,762.83 63.68 7,600.00 4,007.60 44.04 616.22 161.97 476.61 -101.38 72.29 4.414 Pass -Major Risk 8,079.47 3,762.46 63.70 7,625.00 4,017.80 44.20 633.05 162.45 493.30 -101.74 71.92 4.530 Pass -Major Risk 8,097.53 3,762.09 63.71 7,650.00 4,027.97 44.35 649.89 162.94 509.98 -102.09 71.57 4.645 Pass -Major Risk 8,115.61 3,761.72 63.72 7,675.00 4,038.10 44.51 666.75 163.45 526.63 -102.42 71.25 4.759 Pass -Major Risk 8,133.70 3,761.35 63.74 7,700.00 4,048.24 44.67 683.60 164.01 543.26 -102.73 70.94 4.871 Pass -Major Risk 8,151.82 3,760.98 63.75 7,725.00 4,058.38 44.82 700.45 164.57 559.87 -103.03 70.64 4.982 Pass -Major Risk • 11 January, 2008 - 14:53 Page 8 of 21 COMPASS HAI..LIBURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1 D-141/1 D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32L1 Scan Range: 5,500.00 to 9,844.54 ff. Measured Depth. Scan Radius is 7,180.45 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ff) Axis/2 (ft) (ft) Axisl2 (ff) (ff) (ft) Bearing Bearing Factor Warning 8,169.95 3,760.61 63.76 7,750.00 4,068.51 44.98 717.29 165.13 576.46 -103.31 70.35 5.093 Pass -Major Risk 8,188.10 3,760.24 63.78 7,775.00 4,078.65 45.13 734.14 165.68 593.06 -103.58 70.08 5.204 Pass -Major Risk 8,206.24 3,759.87 63.79 7,800.00 4,088.80 45.28 751.01 166.23 609.67 -103.84 69.82 5.314 Pass -Major Risk 8,224.38 3,759.50 63.80 7,825.00 4,098.95 45.42 767.89 166.78 626.29 -104.09 69.57 5.423 Pass -Major Risk 8,242.52 3,759.13 63.82 7,850.00 4,109.11 45.57 784.79 167.33 642.92 -104.33 69.33 5.532 Pass -Major Risk 8,260.61 3,758.76 63.83 7,875.00 4,119.24 45.72 801.76 167.83 659.65 -104.56 69.11 5.642 Pass -Major Risk 8,278.63 3,758.39 63.84 7,900.00 4,129.32 45.88 818.84 168.34 676.47 -104.76 68.90 5.752 Pass -Major Risk 8,296.57 3,758.03 63.86 7,925.00 4,139.35 46.03 836.02 168.84 693.40 -104.96 68.71 5.862 Pass -Major Risk ~s^~ 8,314.45 3,757.66 63.87 7,950.00 4,149.34 46.18 853.31 169.35 710.40 -105.13 68.53 5.971 Pass -Major Risk 8,332.30 3,757.30 63.89 7,975.00 4,159.34 46.34 870.61 169.87 727.40 -105.31 68.36 6.079 Pass -Major Risk 350.16 ~$~~~~ 8 3,756.94 63.90 8,000.00 4,169.38 46.49 887.92 170.39 744.41 -105.47 68.19 6.187 Pass -Major Risk , 8,368.02 3,756.57 63.91 8,025.00 4,179.43 46.64 905.23 170.91 761.42 -105.63 68.03 6.295 Pass -Major Risk „»,...~ 88 8 385 756 21 3 63.93 8,050.00 4,189.51 46.80 922.54 171.46 778.40 -105.79 67.87 6.400 Pass -Major Risk , . 8,403.77 . , 3,755.84 63.94 8,075.00 4,199.56 46.96 939.83 172.02 795.34 -105.94 67.72 6.504 Pass -Major Risk 8,421.70 3,755.48 63.95 8,100.00 4,209.56 47.11 957.09 172.58 812.24 -106.09 67.58 6.607 Pass -Major Risk ,~. 8 439 67 755.11 3 63.97 8,125.00 4,219.54 47.27 974.32 173.15 829.10 -106.22 67.44 6.709 Pass -Major Risk , . 8,457.65 , 3,754.74 63.98 8,150.00 4,229.46 47.43 991.55 173.70 845.98 -106.36 67.31 6.811 Pass -Major Risk 8,475.59 3,754.38 64.00 8,175.00 4,239.34 47.60 1,008.83 174.25 862.89 -106.48 67.19 6.913 Pass -Major Risk 8,493.50 3,754.01 64.01 8,200.00 4,249.15 47.76 1,026.16 174.80 879.85 -106.59 67.08 7.014 Pass -Major Risk 8,511.37 3,753.65 64.03 8,225.00 4,258.91 47.93 1,043.53 175.34 896.86 -106.69 66.98 7.114 Pass -Major Risk 8,529.22 3,753.28 64.04 8,250.00 4,268.67 48.09 1,060.95 175.86 913.91 -106.79 66.88 7.216 Pass -Major Risk .8,547.04 3,752.92 64.05 8,275.00 4,278.48 48.25 1,078.39 176.38 931.00 -106.89 66.78 7.317 Pass-Major Risk 8,564.83 3,752.56 64.07 8,300.00 4,288.32 48.40 1,095.86 176.90 948.11 -106.98 66.68 7.417 Pass -Major Risk 8,582.60 3,752.19 64.08 8,325.00 4,298.21 48.56 1,113.35 177.43 965.24 -107.08 66.59 7.517 Pass-Major Risk 8,600.43 3,751.83 64.10 8,350.00 4,308.15 48.72 1,130.77 177.99 982.27 -107.17 66.49 7.615 Pass -Major Risk 8,618.35 3,751.46 64.11 8,375.00 4,318.14 48.87 1,148.09 178.55 999.21 -107.27 66.39 7.711 Pass- Major Risk 8,636.34 3,751.10 64.13 8,400.00 4,328.19 49.03 1,165.32 179.10 1,016.06 -107.38 66.29 7.807 Pass-Major Risk 11 January, 2008 - 14:53 Page 9 of 21 COMPASS HAL1_1Bl.fR'ON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32 Scan Range: 5,500.00 to 9,844.84 ft. Measured Depth. Scan Radius is 1,180 .46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ff) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ff) (ff) Bearing Bearing Factor Warning 5,503.02 3,597.00 60.43 5,425.00 3,256.87 31.44 544.68 303.80 317.57 -106.17 149.40 2.398 Pass -Major Risk 5,518.85 3,604.78 60.52 5,450.00 3,265.41 31.58 556.80 303.75 326.45 -107.25 149.73 2.417 Pass -Major Risk 5,538.10 3,614.18 60.56 5,475.00 3,273.99 31.72 569.13 304.17 335.53 -106.22 150.77 2.436 Pass -Major Risk 5,550.00 3,619.98 60.58 5,500.00 3,282.61 31.86 581.69 304.25 345.11 -106.26 151.41 2.459 Pass -Major Risk 5,566.17 3,627.77 60.61 5,525.00 3,291.24 32.01 594.60 303.79 355.35 -107.38 151.69 2.485 Pass -Major Risk 5,582.82 3,635.68 60.65 5,550.00 3,299.81 32.15 607.92 303.28 366.08 -108.58 151.91 2.514 Pass -Major Risk 5,595.70 3,641.76 60.67 5,575.00 3,308.31 32.29 621.55 303.65 376.91 -107.63 152.86 2.541 Pass -Major Risk 5,614.04 3,650.40 60.71 5,600.00 3,316.73 32.43 635.41 304.05 388.10 -106.74 153.75 2.569 Pass -Major Risk 5,815.18 3,729.68 61.15 5,625.00 3,325.08 32.58 648.46 308.11 396.11 -84.39 162.74 2.570 Pass -Major Risk 6,102.81 3,776.96 61.83 5,650.00 3,333.35 32.73 651.32 292.62 419.32 -50.76 178.51 2.807 Pass -Major Risk 6,167.97 3,779.21 61.98 5,675.00 3,341.55 32.87 651.09 285.41 423.13 -41.10 -176.31 2.856 Pass -Major Risk ,. ,. 6,284.36 3,781.35 62.24 5,700.00 3,349.67 33.02 648.43 264.13 437.18 -20.94 -165.97 3.070 Pass -Major Risk ~ ~;;~~ 6,393.90 3,781.12 62.45 5,725.00 3,357.72 33.16 642.65 238.70 451.88 -1.91 -156.19 3.369 Pass -Major Risk 6,477.69 3,780.40 62.59 5,750.00 3,365.71 33.30 634.49 216.16 460.70 12.74 -148.67 3.651 Pass -Major Risk u ~, 6 557.29 3,779.74 62.71 5,775.00 3,373.62 33.44 624.35 193.05 468.70 26.51 -141.66 4.011 Pass -Major Risk ~ , ~"'"""'"° 6,631.15 3,779.17 62.79 5,800.00 3,381.46 33.58 612.39 170.82 474.94 39.16 -135.29 4.455 Pass -Major Risk ~,:~ 6,692.01 3,778.72 62.85 5,825.00 3,389.22 33.73 598.80 153.12 476.22 48.94 -130.43 4.885 Pass -Major Risk a~'4' 6,712.59 3,778.57 62.87 5,850.00 3,396.87 33.87 584.71 153.70 461.81 48.79 -130.58 4.758 Pass -Major Risk 6,756.34 3,778.25 62.91 5,875.00 3,404.43 34.02 570.27 143.20 456.64 54.65 -127.74 5.019 Pass -Major Risk 6,797.99 3,777.93 62.94 5,900.00 3,411.87 34.16 555.09 134.07 450.45 60.21 -125.10 5.305 Pass -Major Risk 6,836.77 3,777.62 62.96 5,925.00 3,419.15 34.31 539.25 126.20 442.88 65.26 -122.76 5.595 Pass -Major Risk 6,863.29 3,777.39 62.97 5,950.00 3,426.25 34.46 522.93 123.64 429.90 67.07 -122.10 5.621 Pass -Major Risk 6,881.59 3,777.24 62.98 5,975.00 3,433.18 34.61 506.64 124.01 413.53 66.52 -122.65 5.441 Pass -Major Risk 6,899.90 3,777.09 62.99 6,000.00 3,440.03 34.75 490.44 124.36 397.28 65.92 -123.25 5.265 Pass -Major Risk 6,918.25 3,776.93 63.00 6,025.00 3,446.94 34.88 474.30 124.71 381.12 65.29 -123.88 5.090 Pass -Major Risk 6,936.63 3,776.78 63.00 6,050.00 3,453.93 35.02 458.23 125.06 365.04 64.63 -124.54 4.917 Pass -Major Risk 6,955.05 3,776.62 63.01 6,075.00 3,460.98 35.15 442.23 125.41 349.04 63.94 -125.23 4.746 Pass -Major Risk 6,973.49 3,776.47 63.02 6,100.00 3,468.10 35.28 426.29 125.75 333.13 63.20 -125.97 4.576 Pass -Major Risk 6,991.93 3,776.31 63.03 6,125.00 3,475.29 35.40 410.39 126.09 317.28 62.42 -126.75 4.408 Pass -Major Risk 7,010.37 3,776.16 63.04 6,150.00 3,482.55 35.52 394.56 126.44 301.51 61.59 -127.58 4.240 Pass -Major Risk 7,028.82 3,776.00 63.05 6,175.00 3,489.86 35.65 378.80 126.80 285.83 60.70 -128.47 4.074 Pass -Major Risk i 11 January, 2008 - 14:53 Page 10 of 21 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Report for 1 D-141/1 D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axisl2 (ft) (ft) (ft) Bearing Bearing Factor Warning 7,047.33 3,775.85 63.06 6,200.00 3,496.96 35.79 363.28 127.17 270.41 59.70 -129.47 3.911 Pass -Major Risk 7,065.90 3,775.69 63.07 6,225.00 3,503.76 35.92 348.06 127.54 255.33 58.58 -130.59 3.753 Pass -Major Risk 7,084.53 3,775.53 63.07 6,250.00 3,510.29 36.06 333.18 127.92 240.63 57.31 -131.85 3.600 Pass -Major Risk 7,103.18 3,775.38 63.08 6,275.00 3,516.60 36.21 318.60 128.29 22626 55.90 -133.26 3.450 Pass -Major Risk ~ 7,121.73 3,775.22 63.09 6,300.00 3,523.00 36.35 304.11 128.66 211.99 54.35 -134.82 3.301 Pass -Major Risk , ? 7,140.15 3,775.07 63.10 6,325.00 3,529.51 36.50 289.72 129.04 197.82 52.64 -136.53 3.153 Pass -Major Risk ~ ~ 7,158.46 3,774.91 63.11 6,350.00 3,536.12 36.65 275.48 129.41 183.78 50.75 -138.42 3.004 Pass -Major Risk _ ~~ 176.75 7 3,774.76 63.12 6,375.00 3,542.62 36.80 261.63 129.79 170.09 48.63 -140.54 2.858 Pass -Major Risk , 7,195.07 3,774.60 63.13 6,400.00 3,548.92 36.95 248.32 130.16 156.86 46.25 -142.92 2.715 Pass -Major Risk ~~.. . 7,213.41 3,774.45 63.14 6,425.00 3,555.03 37.11 235.66 130.54 144.13 43.57 -145.60 2.575 Pass -Major Risk ~.' 7,231.12 3,774.28 63.15 6,450.00 3,560.97 37.25 223.73 133.89 131.53 38.88 -149.43 2.426 Pass -Major Risk > 7,249.45 3,774.05 63.16 6,475.00 3,567.06 37.40 212.41 135.80 119.62 34.83 -153.05 2.289 Pass -Major Risk 7,268.08 3,773.82 63.17 6,500.00 3,573.39 37.54 201.66 136.83 108.08 31.02 -156.67 2.155 Pass -Major Risk 7,286.88 3,773.60 63.18 6,525.00 3,579.94 37.68 191.55 137.86 96.80 26.93 -160.58 2.022 Pass -Major Risk 7,305.79 3,773.37 63.19 6,550.00 3,586.74 37.82 182.11 138.89 85.65 22.50 -164.81 1.888 Pass -Major Risk 7,324.65 3,773.14 63.20 6,575.00 3,593.87 37.95 173.35 139.91 74.45 17.68 -169.44 1.753 Pass -Major Risk 7,343.46 3,772.92 63.21 6,600.00 3,601.32 38.08 165.41 140.94 63.34 12.44 -174.50 1.621 Pass -Major Risk 7,362.21 3,772.70 63.22 6,625.00 3,609.11 38.22 158.46 141.97 52.47 6.74 179.99 1.495 Pass -Major Risk 7,380.85 3,772.49 63.23 6,650.00 3,617.19 38.36 152.70 142.38 42.12 0.98 174.23 1.381 Pass -Major Risk 7,399.42 3,772.27 63.24 6,675.00 3,625.51 38.49 148.34 142.79 32.72 -5.18 168.07 1.283 Pass -Major Risk 7,417.92 3,772.06 63.25 6,700.00 3,634.07 38.63 145.54 143.21 24.67 -11.64 161.60 1.204 Pass -Major Risk 7,436.36 3,771.84 63.26 6,725.00 3,642.88 38.77 144.42 143.64 18.42 -18.31 154.94 1.146 Pass -Major Risk 7,454.69 3,771.63 63.28 6,750.00 3,651.95 38.91 145.04 144.08 14.31 -25.04 148.21 1.109 Pass -Major Risk 7,472.89 3,771.42 63.29 6,775.00 3,661.30 39.05 147.41 144.51 12.60 -31.69 141.56 1.093 Pass -Major Risk 7,490.97 3,771.21 63.30 6,800.00 3,670.92 39.19 151.51 144.94 13.40 -38.12 135.12 1.097 Pass -Major Risk 7,508.91 3,771.00 63.31 6,825.00 3,680.82 39.33 157.24 145.38 16.65 -44.23 129.02 1.118 Pass -Major Risk 7,526.76 3,770.80 63.32 6,850.00 3,690.93 39.47 164.50 145.82 22.21 -49.91 123.34 1.156 Pass -Major Risk 7,544.50 3,770.59 63.33 6,875.00 3,701.24 39.61 173.14 146.26 29.82 -55.12 118.13 1.208 Pass -Major Risk 7,562.13 3,770.39 63.34 6,900.00 3,711.76 39.76 182.99 146.70 39.18 -59.86 113.39 1.272 Pass -Major Risk 7,579.68 3,770.18 63.35 6,925.00 3,722.46 39.90 193.91 147.14 50.00 -64.14 109.11 1.347 Pass -Major Risk 7,597.19 3,769.98 63.37 6,950.00 3,733.20 40.05 205.79 147.58 62.07 -67.96 105.29 1.432 Pass -Major Risk • 11 January, 2008 - 14:53 Page 11 of 21 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALL ~ V RT~N Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-32 - 1D-32 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Referen ce Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) AxisR (ft) (ft) (ft) Bearing Bearing Factor Warning 7,614.67 3,769.78 63.38 6,975.00 3,743.99 40.19 218.48 148.02 75.13 -71.36 101.88 1.524 Pass -Major Risk 7,632.11 3,769.57 63.39 7,000.00 3,754.81 40.34 231.87 148.47 88.98 -74.39 98.86 1.623 Pass -Major Risk 7,649.58 3,769.37 63.40 7,025.00 3,765.68 40.49 245.78 148.95 103.38 -77.09 96.16 1.726 Pass -Major Risk 7,667.11 3,769.17 63.41 7,050.00 3,776.58 40.63 260.07 149.43 118.16 -79.50 93.74 1.833 Pass -Major Risk 7,684.72 3,768.96 63.42 7,075.00 3,787.51 40.78 274.65 149.91 133.24 -81.67 91.57 1.942 Pass -Major Risk 7,702.40 3,768.76 63.43 7,100.00 3,798.47 40.93 289.47 150.39 148.54 -83.63 89.62 2.054 Pass -Major Risk 7,720.07 3,768.55 63.45 7,125.00 3,809.43 41.08 304.60 150.87 164.12 -85.39 87.85 2.168 Pass -Major Risk 7,737.70 3,768.35 63.46 7,150.00 3,820.37 41.23 320.07 151.35 180.00 -86.98 86.26 2.285 Pass -Major Risk 7,755.28 3,768.15 63.47 7,175.00 3,831.28 41.39 335.84 151.83 196.12 -88.42 84.83 2.404 Pass -Major Risk 7,772.83 3,767.94 63.48 7,200.00 3,842.16 41.54 351.86 152.31 212.45 -89.71 83.53 2.524 Pass -Major Risk 7,790.43 3,767.74 63.49 7,225.00 3,852.96 41.70 368.01 152.79 228.87 -90.89 82.36 2.645 Pass -Major Risk 7,808.12 3,767.53 63.51 7,250.00 3,863.66 41.86 384.25 153.27 245.33 -91.95 81.30 2.766 Pass -Major Risk "°'~y ~ ~ 7,826.40 3,767.32 63.52 7,275.00 3,874.25 42.02 400.54 154.17 261.50 -93.10 80.24 2.881 Pass -Major Risk ~ +~•• 7,845.11 3,767.06 63.53 7,300.00 3,884.74 42.18 416.87 155.36 277.48 -94.29 79.21 2.991 Pass -Major Risk ' 7,863.88 3,766.77 63.54 7,325.00 3,895.13 42.34 433.27 156.56 293.50 -95.41 78.25 3.100 Pass -Major Risk ~..rt ~,m:,-,~„ 7,882.70 3,766.45 63.56 7,350.00 3,905.43 42.50 449.73 157.77 309.56 -96.46 77.35 3.208 Pass -Major Risk '= 7,901.57 3,766.09 63.57 7,375.00 3,915.62 42.67 466.26 158.98 325.65 -97.45 76.51 3.316 Pass -Major Risk .'e""`~ 7,918.76 3,765.74 63.58 7,400.00 3,925.77 42.82 482.82 159.15 342.62 -97.89 75.98 3.444 Pass -Major Risk 7,935.43 3,765.40 63.59 7,425.00 3,935.94 42.98 499.41 159.02 359.87 -98.15 75.56 3.579 Pass -Major Risk ~~'~" 7,953.12 3,765.04 63.61 7,450.00 3,946.14 43.13 516.03 159.37 376.60 -98.63 75.04 3.701 Pass -Major Risk 7,971.18 3,764.67 63.62 7,475.00 3,956.37 43.29 532.63 159.86 393.15 -99.15 74.51 3.819 Pass -Major Risk 7,989.25 3,764.30 63.63 7,500.00 3,966.61 43.44 549.25 160.35 409.71 -99.65 74.01 3.936 Pass -Major Risk 8,007.31 3,763.93 63.64 7,525.00 3,976.86 43.59 565.93 160.85 426.30 -100.12 73.54 4.053 Pass -Major Risk 8,025.35 3,763.56 63.66 7,550.00 3,987.11 43.75 582.65 161.35 442.92 -100.56 73.10 4.170 Pass -Major Risk 8,043.38 3,763.19 63.67 7,575.00 3,997.37 43.90 599.42 161.85 459.56 -100.98 72.68 4.286 Pass -Major Risk 8,061.42 3,762.83 63.68 7,600.00 4,007.60 44.06 616.22 162.34 476.23 -101.38 72.29 4.402 Pass -Major Risk 8,079.47 3,762.46 63.70 7,625.00 4,017.80 44.22 633.05 162.83 492.91 -101.74 71.92 4.517 Pass -Major Risk 8,097.53 3,762.09 63.71 7,650.00 4,027.97 44.38 649.89 163.33 509.59 -102.09 71.57 4.632 Pass -Major Risk 8,115.61 3,761.72 63.72 7,675.00 4,038.10 44.54 666.75 163.88 526.24 -102.42 71.25 4.745 Pass -Major Risk 8,133.70 3,761.35 63.74 7,700.00 4,048.24 44.70 683.60 164.44 542.86 -102.73 70.94 4.857 Pass -Major Risk 8,151.82 3,760.98 63.75 7,725.00 4,058.38 44.86 700.45 165.01 559.46 -103.03 70.64 4.968 Pass -Major Risk 11 January, 2008 - 19:53 Page 12 of 21 COMPASS u u HAL.LlBURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 7D Pad - 1D-32 - 1D-32 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Referen ce Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axisl2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 8,169.95 3,760.61 63.76 7,750.00 4,068.51 45.01 717.29 165.57 576.06 -103.31 70.35 5.079 Pass -Major Risk 8,188.10 3,760.24 63.78 7,775.00 4,078.65 45.17 734.14 166.12 592.65 -103.58 70.08 5.189 Pass -Major Risk 8,206.24 3,759.87 63.79 7,800.00 4,088.80 45.32 751.01 166.68 609.26 -103.84 69.82 5.298 Pass -Major Risk 8,224.38 3,759.50 63.80 7,825.00 4,098.95 45.47 767.89 167.23 625.88 -104.09 69.57 5.407 Pass -Major Risk 8,242.52 3,759.13 63.82 7,850.00 4,109.11 45.62 784.79 167.78 642.50 -104.33 69.33 5.515 Pass -Major Risk 8,260.61 3,758.76 63.83 7,875.00 4,119.24 45.77 801.76 168.30 659.22 -104.56 69.11 5.625 Pass -Major Risk 8,278.63 3,758.39 63.84 7,900.00 4,129.32 45.93 818.84 168.81 676.04 -104.76 68.90 5.734 Pass -Major Risk 8,296.57 3,758.03 63.86 7,925.00 4,139.35 46.09 836.02 169.32 692.96 -104.96 68.71 5.844 Pass -Major Risk 8,314.45 3,757.66 63.87 7,950.00 4,149.34 46.24 853.31 169.84 709.95 -105.13 68.53 5.952 Pass -Major Risk 8,332.30 3,757.30 63.89 7,975.00 4,159.34 46.40 870.61 170.37 726.95 -105.31 68.36 6.060 Pass -Major Risk ~~. 8,350.16 3,756.94 63.90 8,000.00 4,169.38 46.56 887.92 170.90 743.95 -105.47 68.19 6.167 Pass -Major Risk 8,368.02 3,756.57 63.91 8,025.00 4,179.43 46.72 905.23 171.43 760.96 -105.63 68.03 6.274 Pass -Major Risk 385.88 8 3 756.21 63.93 8,050.00 4,189.51 46.88 922.54 171.98 777.93 -105.79 67.87 6.380 Pass -Major Risk , ~ ~: 8,403.77 , 3,755.84 63.94 8,075.00 4,199.56 47.04 939.83 172.55 794.86 -105.94 67.72 6.483 Pass -Major Risk 8,421.70 3,755.48 63.95 8,100.00 4,209.56 47.19 957.09 173.11 811.76 -106.09 67.58 6.586 Pass -Major Risk ~ 439.67 ~ 8 3,755.11 63.97 8,125.00 4,219.54 47.35 974.32 173.68 828.62 -106.22 67.44 6.687 Pass -Major Risk , 8,457.65 3,754.74 63.98 8,150.00 4,229.46 47.52 991.55 174.24 845.49 -106.36 67.31 6.789 Pass -Major Risk 8,475.59 3,754.38 64.00 8,175.00 4,239.34 47.69 1,008.83 174.80 862.41 -106.48 67.19 6.890 Pass -Major Risk 8,493.50 3,754.01 64.01 8,200.00 4,249.15 47.86 1,026.16 175.35 879.36 -106.59 67.08 6.990 Pass -Major Risk 8,511.37 3,753.65 64.03 8,225.00 4,258.91 48.02 1,043.53 175.91 896.36 -106.69 66.98 7.090 Pass -Major Risk 8,529.22 3,753.28 64.04 8,250.00 4,268.67 48.19 1,060.95 176.43 913.41 -106.79 66.88 7.191 Pass -Major Risk 8,547.04 3,752.92 64.05 8,275.00 4,278.48 48.35 1,078.39 176.96 930.49 -106.89 66.78 7.291 Pass -Major Risk 8,564.83 3,752.56 64.07 8,300.00 4,288.32 48.51 1,095.86 177.49 947.59 -106.98 66.68 7.391 Pass -Major Risk 8,582.60 3,752.19 64.08 8,325.00 4,298.21 48.67 1,113.35 178.03 964.71 -107.08 66.59 7.490 Pass -Major Risk 8,600.43 3,751.83 64.10 8,350.00 4,308.15 48.83 1,130.77 178.59 981.74 -107.17 66.49 7.588 Pass -Major Risk 8,618.35 3,751.46 64.11 8,375.00 4,318.14 48.99 1,148.09 179.15 998.68 -107.27 66.39 7.684 Pass -Major Risk 8,636.34 3,751.10 64.13 8,400.00 4,328.19 49.14 1,165.32 179.72 1,015.52 -107.38 66.29 7.779 Pass-Major Risk • 11 January, 2008 - 14:53 Page 13 of 21 COMPASS ConocoPhillips (Alaska) lnc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Report for 1 D-141/1 D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-141 - 1D-141 L1 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Measured Vertical Ellipse Depth Depth Major (ft) (ft) Axis/2 .~~ ii ® ~' ~~' ~' 'I ~~ ~ ®' -~~ ' ~•-~ ~ . `~-~ ®' ', ' ~ ®' ' . Y 1 ~' ~~ ®' . ~. ~ 6,078.45 3,775.89 12.95 6,104.38 3,777.02 13.25 6,130.34 3,778.00 13.53 6,158.66 3,778.94 13.83 6,187.63 3,779.75 14.13 6,217.23 3,780.42 14.42 6,247.23 3,780.94 14.71 6,277.79 3,781.29 14.99 6,308.79 3,781.48 15.27 Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor blaming ..~~ ~~ .. ~~ . ~i ~ ~~ ~~ ® ~ ® ~ ~' 6,050.00 3,744.36 24.53 97.11 101.90 0.01 -23.85 -153.44 1.000 Pass -Major Risk 6,075.00 3,747.91 25.03 104.03 103.94 4.40 -19.33 -150.06 1.044 Pass -Major Risk 6,100.00 3,750.95 25.52 111.92 105.82 10.04 -14.88 -146.92 1.099 Pass -Major Risk 6,125.00 3,753.83 25.99 119.94 107.06 16.58 -8.56 -142.96 1.160 Pass -Major Risk 6,150.00 3,756.46 26.45 127.52 108.11 22.99 -2.40 -139.27 1.220 Pass -Major Risk 6,175.00 3,758.75 26.90 134.61 108.93 29.21 3.61 -135.76 1.277 Pass -Major Risk 6,200.00 3,760.86 27.34 141.73 109.51 35.71 9.57 -132.32 1.337 Pass -Major Risk 6,225.00 3,762.87 27.77 148.41 109.85 42.05 15.56 -128.91 1.395 Pass -Major Risk 6,250.00 3,764.87 28.19 154.90 109.93 48.46 21.60 -125.48 1.455 Pass -Major Risk • 11 January, 2008 - 14:53 Page 14 of 21 COMPASS HAI.,LIBURTON ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design:KuparuklDPad- 1D-141- 1D-141L1 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ff) Axisl2 (ft) (ff) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor blaming 6,340.25 3,781.49 15.54 6,275.00 3,766.72 28.59 161.19 109.73 54.95 27.66 -122.08 1.517 Pass -Major Risk 6,372.22 3,781.31 15.81 6,300.00 3,768.15 28.98 167.17 109.24 61.43 33.69 -118.76 1.581 Pass -Major Risk 6,404.71 3,781.02 16.07 6,325.00 3,768.96 29.36 172.92 108.44 68.00 39.60 -115.60 1.648 Pass -Major Risk 6,437.69 3,780.74 16.31 6,350.00 3,769.09 29.73 178.41 107.31 74.63 45.36 -112.64 1.719 Pass -Major Risk 6,471.21 3,780.46 16.55 6,375.00 3,769.29 30.09 183.22 105.76 80.98 51.23 -109.62 1.792 Pass -Major Risk 6,505.25 3,780.17 16.79 6,400.00 3,770.12 30.45 187.02 103.86 86.67 57.37 -106.38 1.864 Pass -Major Risk 539.69 6 3,779.89 17.01 6,425.00 3,771.24 30.76 189.73 101.48 91.73 63.65 -103.02 1.936 Pass -Major Risk , 6,574.44 3,779.61 17.22 6,450.00 3,772.19 31.06 191.29 98.73 96.01 69.92 -99.70 2.008 Pass -Major Risk 6,609.35 3,779.33 17.43 6,475.00 3,772.63 31.37 192.06 95.62 99.85 76.07 -96.53 2.083 Pass -Major Risk ~ 6,644.32 3,779.07 17.62 6,500.00 3,772.52 31.66 192.70 92.15 103.91 82.06 -93.51 2.170 Pass -Major Risk 6,679.34 3,778.81 17.80 6,525.00 3,772.36 31.93 193.61 88.31 108.59 88.04 -90.51 2.277 Pass -Major Risk ,~...F 6,707.07 3,778.61 17.93 6,550.00 3,772.39 32.17 195.20 88.35 110.14 89.75 -89.62 2.295 Pass -Major Risk ,, 6,737.85 3,778.39 18.07 6,575.00 3,772.33 32.40 197.98 86.52 114.72 93.24 -87.86 2.378 Pass -Major Risk 6,770.61 3,778.14 18.22 6,600.00 3,771.49 32.61 201.25 83.35 121.08 97.64 -85.75 2.510 Pass -Major Risk 6,803.49 3,777.88 18.36 6,625.00 3,770.53 32.80 204.87 79.89 128.08 102.03 -83.66 2.668 Pass -Major Risk 6,836.61 3,777.62 18.49 6,650.00 3,769.79 32.98 208.26 76.08 135.19 106.53 -81.49 2.850 Pass -Major Risk 6,865.68 3,777.37 18.60 6,675.00 3,769.08 33.16 210.94 74.76 139.16 108.70 -80.46 2.939 Pass -Major Risk 890.49 6 3,777.16 18.69 6,700.00 3,767.64 33.34 213.74 76.16 140.61 108.37 -80.80 2.923 Pass -Major Risk , 6,915.32 3,776.96 18.79 6,725.00 3,766.22 33.52 216.40 77.53 141.94 108.05 -81.12 2.906 Pass -Major Risk 6,940.18 3,776.75 18.88 6,750.00 3,764.93 33.71 218.76 78.87 143.00 107.77 -81.40 2.888 Pass -Major Risk 965.06 6 3,776.54 18.97 6,775.00 3,763.73 33.91 220.98 80.24 143.90 107.52 -81.65 2.867 Pass -Major Risk , 6,989.94 3,776.33 19.07 6,800.00 3,762.65 34.10 223.37 81.62 144.95 107.30 -81.87 2.848 Pass -Major Risk 7,014.83 3,776.12 19.16 6,825.00 3,761.99 34.30 225.60 83.01 145.84 107.20 -81.97 2.828 Pass -Major Risk 7,039.74 3,775.91 19.26 6,850.00 3,761.44 34.50 227.68 84.38 146.58 107.12 -82.04 2.807 Pass -Major Risk 7,064.67 3,775.70 19.36 6,875.00 3,760.89 34.71 229.61 85.75 147.18 107.05 -82.12 2.785 Pass -Major Risk 7,089.59 3,775.49 19.45 6,900.00 3,760.32 34.92 231.54 87.12 147.77 106.97 -82.20 2.764 Pass -Major Risk 7,114.47 3,775.28 19.55 6,925.00 3,759.72 35.12 233.91 88.52 148.77 106.89 -82.28 2.747 Pass -Major Risk 7,139.26 3,775.07 19.65 6,950.00 3,759.02 35.32 237.11 89.94 150.59 106.79 -82.38 2.741 Pass -Major Risk 7,163.98 3,774.87 19.75 6,975.00 3,758.00 35.52 240.77 91.35 152.88 106.62 -82.55 2.739 Pass -Major Risk 7,188.63 3,774.66 19.85 7,000.00 3,756.75 35.70 244.86 92.74 155.61 106.40 -82.77 2.744 Pass -Major Risk 7,213.16 3,774.45 19.95 7,025.00 3,755.47 35.88 249.58 94.13 158.98 106.19 -82.97 2.755 Pass -Major Risk 11 January, 2008 - 14:53 Page 15 of 21 COMPASS J HALLIBURTCtN ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-141 - 1D-141L1 Scan Range: 5,500.00 to 9,844.84 ft. Measured Depth. Scan Radius is 1,180 .46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor blaming 7,233.32 3,774.25 20.03 7,050.00 3,754.25 36.06 255.12 97.94 160.82 104.08 -84.12 2.705 Pass -Major Risk 7,255.83 3,773.97 20.12 7,075.00 3,753.12 36.23 261.21 100.19 164.71 103.17 -84.64 2.707 Pass -Major Risk 7,278.99 3,773.69 20.21 7,100.00 3,751.92 36.41 267.35 102.00 169.08 102.57 -85.01 2.721 Pass -Major Risk 7,302.15 3,773.41 20.30 7,125.00 3,750.73 36.58 273.36 103.80 173.33 101.98 -85.38 2.733 Pass -Major Risk 7,325.34 3,773.14 20.40 7,150.00 3,749.95 36.76 279.20 105.62 177.38 101.46 -85.66 2.742 Pass -Major Risk 7,348.48 3,772.86 20.49 7,175.00 3,749.35 36.95 285.15 107.46 181.52 101.00 -85.90 2.752 Pass -Major Risk 7,372.06 3,772.59 20.59 7,200.00 3,748.53 37.14 291.19 109.09 185.96 100.67 -86.08 2.767 Pass -Major Risk 7,396.34 3,772.31 20.69 7,225.00 3,747.72 37.33 297.11 110.39 190.61 100.63 -86.13 2.790 Pass -Major Risk 7,420.71 3,772.03 20.80 7,250.00 3,747.46 37.52 302.66 111.74 194.82 100.68 -86.07 2.806 Pass -Major Risk 7,445.28 3,771.74 20.91 7,275.00 3,747.17 37.73 307.31 113.11 198.12 100.72 -86.03 2.814 Pass -Major Risk ,~~ 7,469.87 3,771.46 21.02 7,300.00 3,746.72 37.94 311.78 114.48 201.24 100.73 -86.02 2.821 Pass -Major Risk ~`° 7,494.53 3,771.17 21.13 7,325.00 3,746.18 38.16 315.92 115.86 204.03 100.72 -86.03 2.824 Pass -Major Risk <. 7,519.27 3,770.88 21.24 7,350.00 3,745.59 38.39 319.52 117.26 206.27 100.70 -86.05 2.821 Pass -Major Risk """°°" 7,544.01 3,770.60 21.36 7,375.00 3,744.90 38.62 323.10 118.66 208.48 100.66 -86.09 2.819 Pass -Major Risk ~=~ 7,568.76 3,770.31 21.47 7,400.00 3,744.10 38.85 326.60 120.06 210.62 100.60 -86.15 2.816 Pass -Major Risk - ~ 7,593.53 3,770.02 21.58 7,425.00 3,743.13 39.08 329.95 121.44 212.63 100.51 -86.24 2.812 Pass -Major Risk '~ 7,618.35 3,769.73 21.69 7,450.00 3,742.03 39.31 332.88 122.84 214.21 100.40 -86.36 2.805 Pass -Major Risk 643.25 .< ~~ 7 3 769.45 21.81 7,475.00 3,741.05 39.56 335.00 124.26 214.96 100.30 -86.45 2.791 Pass -Major Risk ~ :,r_ , `~~,, , 7,668.21 3,769.16 21.92 7,500.00 3,740.74 39.82 336.30 125.69 214.87 100.31 -86.45 2.770 Pass -Major Risk ~~~~~~ 7,693.27 3,768.87 22.04 7,525.08 3,740.67 40.08 337.26 127.14 214.42 100.35 -86.40 2.746 Pass -Major Risk 7,718.19 3,768.58 22.15 7,550.00 3,740.49 40.35 337.72 128.58 213.48 100.38 -86.38 2.718 Pass -Major Risk 7,743.19 3,768.29 22.27 7,575.00 3,740.11 40.62 337.57 130.04 211.93 100.36 -86.39 2.687 Pass -Major Risk 7,768.18 3,768.00 22.38 7,600.00 3,739.74 40.90 337.30 131.50 210.25 100.35 -86.41 2.655 Pass -Major Risk 7,793.18 3,767.71 22.50 7,625.00 3,739.32 41.17 337.59 132.96 209.13 100.32 -86.43 2.628 Pass -Major Risk 7,818.04 3,767.42 22.61 7,650.00 3,738.84 41.45 337.46 134.48 207.54 100.24 -86.49 2.597 Pass -Major Risk 7,841.91 3,767.11 22.72 7,675.00 3,738.31 41.73 336.65 136.43 204.87 99.80 -86.73 2.555 Pass -Major Risk 7,865.77 3,766.74 22.83 7,700.00 3,737.79 42.02 335.54 138.38 201.91 99.37 -86.97 2.511 Pass -Major Risk 7,889.60 3,766.32 22.93 7,725.00 3,737.63 42.31 333.89 140.34 198.38 99.00 -87.13 2.464 Pass -Major Risk 7,914.26 3,765.83 23.05 7,750.00 3,737.56 42.61 332.02 141.92 194.99 98.95 -87.13 2.423 Pass -Major Risk 7,940.63 3,765.29 23.16 7,775.00 3,737.41 42.91 330.17 142.71 192.39 99.50 -86.83 2.396 Pass -Major Risk 7,965.56 3,764.78 23.28 7,800.00 3,737.11 43.21 328.27 144.17 189.09 99.52 -86.81 2.359 Pass -Major Risk 11 January, 2008 - 14:53 Page 16 of 21 COMPASS ConocoPhillips (Alaska) lnc. -Kupl Kuparuk River Unit HALLIBURTON Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad- 1D- 141- 1D-141 L1 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 990.45 3,764.27 7 23.39 7,825.00 3,736.82 43.51 325.89 145.63 185.31 99.54 -86.80 2.318 Pass -Major Risk , 8,015.30 3,763.77 23.51 7,850.00 3,737.20 43.81 323.30 147.10 181.28 99.67 -86.67 2.276 Pass -Major Risk 8,040.12 3,763.26 23.62 7,875.00 3,737.84 44.12 320.48 148.60 177.00 99.85 -86.49 2.234 Pass -Major Risk 8,064.94 3,762.75 23.74 7,900.00 3,738.33 44.42 317.59 150.10 172.64 100.00 -86.33 2.191 Pass -Major Risk 089.78 3,762.25 8 23.86 7,925.00 3,738.45 44.73 314.88 151.59 168.48 100.09 -86.24 2.151 Pass -Major Risk , 8,114.65 3,761.74 23.97 7,950.00 3,738.36 45.03 312.31 153.09 164.47 100.15 -86.19 2.112 Pass -Major Risk 8,139.54 3,761.23 24.09 7,975.00 3,738.14 45.34 310.01 154.59 160.72 100.18 -86.15 2.077 Pass -Major Risk 164.43 3,760.72 ~i 8 24.21 8,000.00 3,737.88 45.64 307.68 156.09 156.95 100.21 -86.12 2.041 Pass -Major Risk . , ~" ~ 8,189.31 3,760.22 ' 24.33 8,025.00 3,737.57 45.94 305.20 157.59 153.04 100.23 -86.11 2.006 Pass -Major Risk 8,214.18 3,759.71 " 24.44 8,050.00 3,737.12 46.25 302.67 159.09 149.07 100.22 -86.12 1.970 Pass -Major Risk 8,239.02 3,759.20 24.56 8,075.00 3,736.60 46.55 299.79 160.59 144.75 100.19 -86.14 1.934 Pass -Major Risk - 8,263.86 3,758.70 24.68 8,100.00 3,735.91 46.86 297.05 162.09 140.58 100.13 -86.20 1.898 Pass -Major Risk 8,288.73 3,758.19 24.80 8,125.00 3,735.01 47.17 294.52 163.60 136.62 100.04 -86.30 1.865 Pass -Major Risk 8,313.60 3,757.68 24.91 8,150.00 3,734.04 47.48 292.01 165.12 132.68 99.92 -86.41 1.833 Pass -Major Risk 338.45 3,757.17 8 25.03 8,175.00 3,733.23 47.78 289.37 166.63 128.60 99.84 -86.50 1.800 Pass -Major Risk , 8,363.30 3,756.67 25.15 8,200.00 3,732.82 48.09 286.67 168.13 124.46 99.83 -86.50 1.767 Pass -Major Risk 8,388.12 3,756.16 25.27 8,225.00 3,732.55 48.39 283.67 169.62 120.04 99.85 -86.49 1.734 Pass -Major Risk 412.91 3,755.65 8 25.39 8,250.00 3,732.15 48.70 280.40 171.12 115.34 99.84 -86.50 1.699 Pass -Major Risk , 437.69 3,755.15 8 25.51 8,275.00 3,731.56 49.01 277.13 172.61 110.65 99.78 -86.55 1.665 Pass -Major Risk , 462.49 3,754.64 8 25.62 8,300.00 3,731.10 49.31 273.94 174.09 106.05 99.76 -86.57 1.632 Pass -Major Risk , 487.28 3,754.14 8 25.74 8,325.00 3,730.66 49.62 270.76 175.56 101.46 99.74 -86.59 1.599 Pass -Major Risk , 8,512.14 3,753.63 25.86 8,350.00 3,730.29 49.92 268.11 177.05 97.40 99.74 -86.59 1.571 Pass -Major Risk 8,537.08 3,753.12 25.98 8,375.00 3,730.04 50.21 266.43 178.53 94.28 99.78 -86.56 1.548 Pass -Major Risk 562.05 3,752.61 8 26.10 8,400.00 3,729.78 50.50 265.22 180.02 91.63 99.82 -86.52 1.528 Pass -Major Risk , 752.10 03 3 587 8 26.22 8,425.00 3,729.43 50.80 264.13 181.52 89.09 99.84 -86.49 1.509 Pass -Major Risk , . , 751 59 01 3 8 612 34 26 450.00 8 3,728.98 51.09 263.07 183.03 86.58 99.84 -86.49 1.491 Pass -Major Risk . , , . 8,636.99 3,751.08 . 26.46 , 8,475.00 3,728.55 51.38 262.10 184.51 84.18 99.85 -86.48 1.473 Pass -Major Risk 661.98 3,750.57 8 26.58 8,500.00 3,728.34 51.66 261.34 185.98 81.99 99.91 -86.43 1.457 Pass -Major Risk , 686.96 3,750.06 8 26.70 8,525.00 3,728.13 51.95 260.53 187.46 79.75 99.96 -86.37 1.441 Pass -Major Risk , 749 56 85 3 711 8 26 82 8,549.91 3,727.79 52.24 259.49 188.94 77.28 99.99 -86.34 1.424 Pass -Major Risk . , . , 8,736.91 3,749.04 . 26.94 8,575.00 3,727.41 52.53 258.34 190.43 74.69 100.01 -86.33 1.407 Pass -Major Risk 11 January, 2008 - 14:53 Page 17 of 21 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Report for 1D-141/10-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-141 - 1D-141 L7 Scan Range: 5,500.00 to 9,844.64 ft. Measured Depth. Scan Radius is 1,180.46 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Measured Vertical Ellipse Depth Depth Major (ft) (ft) Axis/2 8,761.89 3,748.53 27.06 8,786.86 3,748.03 27.18 8,811.44 3,747.52 27.30 8,835.36 3,747.05 27.40 8,859.29 3,746.60 27.50 8,883.23 3,746.17 27.61 8,907.18 3,745.75 27.71 8,931.41 3,745.35 27.81 8,956.41 3,744.94 27.92 8,981.40 3,744.54 28.03 '. 9,006.39 3,744.13 28.14 9,031.37 3,743.72 28.26 ,,,,~~ 9,056.36 3,743.31 28.39 9,081.35 3,742.90 28.51 -~ 9,105.99 3,742.50 28.63 ~ 9,130.96 3,742.14 28.73 9,155.60 3,741.90 28.84 9,180.25 3,741.75 28.94 ~~° 9,204.91 3,741.70 29.04 9,229.58 3,741.76 29.12 9,254.57 3,741.87 29.22 9,279.54 3,741.97 29.33 9,304.50 3,742.08 29.43 9,329.46 3,742.18 29.56 9,354.43 3,742.29 29.68 9,379.40 3,742.39 29.80 9,404.37 3,742.49 29.92 9,429.34 3,742.60 30.04 9,454.31 3,742.70 30.17 9,479.28 3,742.81 30.29 9,504.24 3,742.91 30.41 Uncertainty Data for Offset Well Measured Vertical Ellipse Depth Depth Major (ft) (ft) Axis/2 8,600.00 3,727.18 52.81 8,625.00 3,727.35 53.10 8,650.00 3,727.59 53.39 8,675.00 3,727.65 53.68 8,700.00 3,727.50 53.98 8,725.00 3,727.25 54.28 8,750.00 3,726.89 54.57 8,775.00 3,726.38 54.87 8,800.00 3,725.68 55.17 8,825.00 3,724.82 55.46 8,850.00 3,723.85 55.76 8,875.00 3,722.82 56.05 8,900.00 3,722.11 56.34 8,925.00 3,721.94 56.63 8,950.00 3,722.29 56.92 8,975.00 3,722.93 57.21 9,000.00 3,723.66 57.50 9,025.00 3,724.32 57.79 9,050.00 3,724.85 58.09 9,075.00 3,725.31 58.39 9,100.00 3,725.68 58.68 9,125.00 3,726.39 58.98 9,150.00 3,727.39 59.28 9,175.00 3,728.44 59.58 9,200.00 3,729.38 59.88 9,225.00 3,730.23 60.18 9,250.00 3,731.01 60.48 9,275.00 3,731.72 60.78 9,300.00 3,732.29 61.09 9,325.00 3,732.74 61.39 9,350.00 3,733.13 61.70 Between Centres (ft) 257.26 No-Go Area (ft) 191.90 256.25 193.37 255.10 195.06 253.95 197.13 252.91 199.20 251.99 201.27 251.17 203.32 250.53 205.16 249.96 206.61 249.43 208.05 249.00 209.51 248.50 211.02 247.90 212.51 247.23 213.98 246.54 215.45 245.83 217.01 245.26 218.56 244.71 220.13 244.09 221.68 243.40 223.14 242.56 224.54 eparation (Ref. > Comp.) Between Relative Ellipsoids North (ft) Bearing 72.19 100.06 69.72 100.20 66.91 100.19 63.74 99.83 60.68 99.42 57.75 98.98 54.94 98.52 52.52 98.14 50.58 98.07 48.68 97.96 46.87 97.83 44.94 42.92 40.82 38.69 36.41 34.29 32.19 30.04 27.92 25.74 241.58 225.92 240.50 227.32 239.41 228.82 238.32 230.33 237.31 231.84 236.40 233.35 235.46 234.86 234.26 236.37 232.99 237.89 231.69 239.40 23.41 20.98 18.43 15.88 13.41 11.04 8.64 5.98 3.25 0.49 Relative Highside Bearing -86.27 -86.13 -86.06 -86.19 -86.36 -86.56 -86.79 -87.00 -87.07 -87.17 -87.31 97.68 -87.46 97.60 -87.53 97.65 -87.48 97.82 -87.32 97.91 -87.16 97.99 -87.01 98.04 -86.89 98.03 -86.83 97.98 -86.81 98.04 -86.75 98.18 98.39 98.61 98.80 98.98 99.14 99.29 99.40 99.48 99.55 -86.61 -86.41 -86.19 -85.99 -85.81 -85.65 -85.51 -85.39 -85.31 -85.24 Clearance Factor 1.390 1.374 1.356 1.335 1.316 1.297 1.280 1.265 1.254 1.243 1.232 1.221 1.209 1.198 1.186 1.174 1.163 1.151 1.140 1.130 1.119 1.107 1.096 1.083 1.071 1.060 1.049 1.038 1.026 1.014 1.002 Warning Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk IL J 11 January, 2008 - 14:53 Page 18 of 21 COMPASS ConocoPhillips (Alaska) Inc. -Kupl HALLIBURTON Kuparuk River Unit Anticollision Report for 1D-141/1D-141A (wp11) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 1D Pad - 1D-141 - 1D-141 L1 Scan Range: 5,500.00 to 9,844.84 ft. Measured Depth. Scan Radius is 1,180.48 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Measured Vertical Ellipse Depth Depth Major (ft) (ft) Axis/2 ®' Uncertainty Data for Offset Well Measured Depth (ft) • ~~ • .~~ ~i • ~~ ...~ ~~ ~~ Vertical Depth (ft) ~_ ~_ •:i ~~ Survey tool program Separation (Ref. > Comp.) Ellipse Between No-Go Between Relative Major Centres Area Ellipsoids North Axis/2 (ft) (ft) (ft) Bearing ~~ ®' ®'~' ~' ' ' ' I ®'' ~ ~' ~' From To (ft) (ft) 104.65 645.65 680.66 5,500.00 5,500.00 9,844.05 1D-141A (wp11) Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. SurveylPlan Relative Highside Clearance Bearing Factor Warning ~ .., Survey Tool CB-GYRO-SS MWD MWD+IFR-AK-CAZ-SC C~ • 11 January, 2008 - 14.53 Page 19 of 21 COMPASS • 1 D-141 P8A Sundry Schematic Current Condition ~ _ 1 D-141 & (L1) Producer ConocoPhillips Current Condition 10.75" J-55 casing @ 502' MD / 502' ND 75/8"x7"XO@ +/- 5,519' MD Top of D Liner Obstructing Main Bore Access \ Top of Cement = 5900' MD (Designed top, not tagged) Top of D window @ +/- 5,580' MD, Blank Liner 4.5" X 7 5/8" Liner Top +/- 6,196' MD ECP @ +/-6,139' MD „~i: ~ W West Sak D Sand 4.5" 12.6# Blank Liner x 4" 9.5# ScreenLiner @ +/- 9,460' MD 6" Hole Screen Liner ECP @ +/- 8,089' MD W West Sak B Sand 4.5" 12.6# Blank Liner x 4" 9.5# ScreenLiner Screen Liner Blank Liner tom of Cement = 6200' MD I Sidetrack milled during workover attempt TD=6235' MD 6" Hole 7" L-80 BTC-M casing @ 6419' MD / 3829' TVD PJR 1/16/08 1 D-141 P&A Sundry Schematic Post P&A 1 D-141 & L1 P~ducer ( ) Post P&A ~ConocoPhilfi s 10.75" J-55 casing @ 502' MD / 502' ND Sidetrack KOP TOW @ +/- 5,500' MD, +/-3,595 ND 7 5/8" x 7" XO @ +/- 5,519' MD K-13 Shale 5,445' • MD / 3,563' ND (14JUN07 Directional) 4.5" 12.6# Blank Liner x 4" 9.5# ScreenLiner To of D window p @ ECP @ @ +/- 9,460' MD +/- 5,580' MD, +i-s,1ss~ MD 6" Hole CEMENT Blank Liner W West Sak D Sand Screen Liner Top of Cement = 5900' MD CEMENT (Designed top, not tagged) ~ 4.5" X 7 5/8" Liner Top ' ECP @ ~ 5# S enLiner k Li 4" 9 " 12 6# Bl J +/- 6,196 MD +i- a,oss MD cre ner x . . an 4.5 ,`Q~' @ +/- 9,548' MD ~~ CEMENT ~ ~ ~ V Blank Liner W West Sak B Sand Screen Liner Bottom of Cement CEMENT = szoo' MD 6" Hole 7" L-80 BTC-M casing @ 6419' Sidetrack milled during MD / 3829' ND workover attempt TD=6235' MD A °'~ - PJR 1/16/08 1D-141A Proposed Schematic 1D-141A Sidetrack~oducer Proposed D Sand Liner Completion ~ConocoPhillips 10.75" J-55 casing @ 502' MD / 502' . TVD 7 5/8" x 5 %" Annulus Diesel Freeze Protect to -1,800' MD ~ 7 5/8" x 5 %" Annulus Corrosion Inhibited Brine (Naar) From -1,800' MD to Liner Top. 2.312 DS Nipple - 500' 2 7/8" # Gas Lift Tubing PressurelTemp Gauge o 2.25 D Nipple Above Seal Handling Pup U 5 $/:' OD Tie Back Seals 7 5/8"x5--'/2" ZXP(HR) Liner Top Packer w/ 5.5" 15.5# Intermediate Flexlock hanger +/- 5,380' MD / 3,534' TVD Liner Top +/- 5,380' 20' 4.00" ID Sealbore w/ MD / 3,534' TVD production seals K-13 Shale 5,478' MD(from original drill geologist pits) 3,563' TVD ~21' Sidetrack KOP TOW @ +/- 5,500' MD, +/-3,595 TVD ~20' needed for bridge plug and slide 75/8"x7"XO@ +/- 5,519' MD z, ~~ \~e Top D Sand @ +/- 5,965' MD, +/- 3.764' TVD 6'/:' Hole Z cW G W U West Sak D Original B & D Laterals P&A'd I Slotted Liner - Swell Packer 4 '/s" 11.6# L-80 BTC Slotted Liner @ +/- 9,844' MD, +/- 3,743' TVD ~ ~ TRANSMITTAL LETTER CHECK~LjIST WELL NAME ~~~~ ,~ ~ ~ 7 hCc~ rt t ~ PTD# ~~~ ` ~~ ~: Development Service Exploratory Strati raphic Test g Non-Conventional Well 1 . FIELD: ~LuDac-J~L~?.jE.~ POOL: ~~~ JG~~ i Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comnanv Name) must contact the Commission to obtain advance approval of such water we!! testing ro ram. Rev: 1/11/2008 WELE_ PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL - 49015D _ _ .Well Name: KUPARUK RIV U WSAK 1D-141A ......Program DEV ___-_ ____ Well bore seg ^ PTD#:2080160 Company CONOCOPHILLIPS ALASKA INC _ _______ Initial Class/Type __ DEV / PEND GeoArea 890__ Unit 11160 On/Off Shore On_ Annular Disposal [] Administration 1 Permit fee attached NA 2 Lease number appropriat_e_ Y_es Entire wellbore will lie within ADL 25650 j3 Uniquewell_nameandnumber________________________ ____________ Yes_ _-__Re-drill_____._ -------------------------------------------------------- 4 Well located in_a_define_d_pool_ Y_es Kuparuk River, West_Sak Oil Pool - 490150,_ governed by_CO 406B. 5 Well located proper distance from drilling unitboundary_ Yes - CO406B, Rule 3: no restrictions as to well spacing except that no_pay shall be opened in a well closer- - _ 6 Well located proper distance from other wells. Yes than 500 feet loan external_property line where ownersh_ip_ or landownership changes. 7 Sufficient acreage,ayailable in_drilling unit. - Yes . - Well is more than. 500 feet from an external ro-ert line. _ P P y 8 If_deviated, is_wellbore platincluded .... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - . - - .. - _ _ _ _ _ _ _ _ _ _ _ I 9 Operator only affected porky _ _ _ _ _ _ YeS _ _ 10 Operator has_appropriatebondinforce____________________ ___._____Yes_ ____ 11 Permit-can be issued without conservation order. _ - . _ _ Yes Appr Date 12 Permit. can be issued without administrative-approval Yes . - - - - . . SFD 2/1/2008 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized bylnjection Order# (put 1O# i n-comments)_(For_ NA- - - _ . - - - - - - - - - ; I 15 All wellswithin 114_mile_area_o_f review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ - - -- 16 Pre-produced injector; duration.of pre-production Less than 3 months. (Forservice well only) NA_ - - - - --- - ------ - 1 - 17 - Nonconven, gas conforms to AS31,Q5,030(j.1_.A) O 2 A-D) -- --- ----- N_A_ ----- _-- Engineering ! 18 Condu_ctorstringprovided_ _ _ _ _ _ _ _ N_A_ _ --- - - -- -- _ _ _ _ Conductorset_in1D-141-(200-112)._ _ _ 19 Surface casing protects all known USDWs - NA- - All aquifers exempted,-40 CFR 147.102 (b)(3)._ - 20 CMT_vol, adequate to circulate_on conductor ~ surf_csg . - . _ NA_ Surface casing set in 1_D-141. 21 _C_MT_v_ol ad_eguate_to tie-in-long string to surf csg_ NA_ Prooduction_ casing set in_1 D-1.41, 22 CMT_will coyer-all known_productive horizons. - No_ Slotted-liner completion planned, _ 23 Casing des~ns adequate for C, T, B &,permaf[ost_ - - - - - NA_ - Original well_met design specifcations. NA far slatted liner.. 24 Adequate tan_kage_or reserve pit Y_es Rig equipped with steel pits. No reserve pit planned.- All waste_to approved disposal well(s). 1 25 If a.re-drill, hasa 1.0-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ 308-019 (1D-141) and 308-118.(1D-141_L1). _ _ _ _ _ _ _ j I 26 Adequate.wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ __ _ _ _ Yes . - - Proximity analysis performed. Traveling cylinder path calculated, Well segment planned ~250'_laterally_from_ _ _ _ ~~ 27 If.diverter required, does it meet regulations N_A_ BOP stack_will already_be_in place.. _ original penetration. Appr Date 28 Drilling fluid- program schematic-& equipJistadequate_ Yes Maximum expected formation pressure 9.2_ EMW, MW planned up to 9.8 ppg. TEM 2/412008 29 _B_OPEs,_do they meet regulation Yes _ _ _ 30 BOPE press rating appropriate; test ko.(put prig in comments)- Yes MASP calculated at 1377 psi. 3K stack arrangement and BOP_tes_t planned, I 31 Choke manifold complies w1APk RP 53 (May 84)- _ Yes _ _ _ _ _ - _ _ - ! 32 Work will occur without operation shutdown. Yes ! 33 Is presence of H2S gas probable- - - No_ - - - ..Low (< 5ppm)_H2S_reported in WS on_ 1_D. .Mud should preclude H2S on rig.. Rig has sensors and alarms. x, 34 Mechanical_condition of wells within AOR verified (For service well only) _ NA_ Geology 'I 35 Permit can be issued w!o hydrogen sulfide measures .. Yes --- Nearby_wells typically measure. <5 ppm-H2S_in West Sak reservoirs.- . 36 _D_ata_presented on potential overpressure zones- Yes .. . - -Expected reservoir_pressure is 9,2-ppg EMW; will be drilled with mud weights up to 9,6_ppg. Appr Date X 37 Seismic_analysis ofshallow gas-zones NA_ SFD 2/112008 ' 38 Seabed condition survey (if off-shore) NA 39 Contact namelphone for weekly. progress reports [exploratory only] NA- _ _ Geologic Commissioner: Engineering Public Date: Commissioner Date C m sinner Date Predecessor wellbores 1 D-141 & 1 D-141 L1 had solids roduction roblems. The ESP was ulled and an attem t was made P P P P Z r~~ ~~~ to gas lift the well, but without success. Last recorded production from 1D-141 was November 2004. 1 D-141 and 1 D-141 L1 will be plugged and abandoned. The 1 D141A retlrill will parallel the abandoned wellbores at a lateral distance of about 25D'. '" d~ SFD 2/1108 Well I-iistory File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. 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 efi(ori has been made to chronologically organize this category of information. 1d-141apbl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Thu Jun 19 13:25:48 2008 Reel Header Service name .............LISTPE Date . ...................08/06/19 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/06/19 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW-000547770 B. HENNINGSE M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Library. Library 1D-141APB1 500292296773 ConocoPhillips Sperry Sun 15-MAY-08 14 11N l0E 14 596 .00 111.50 70.70 Page 1 • scientific Technical services scientific Technical services Alaska Inc. a r 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1d-141apbl.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5502.0 LDWG RECREATED 19-JUN-2008 TO CORRECT API NUMBER. THIS DATA SUPERSEDE ALL PREVIOUSLY ISSUED DATA. 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 1D-141PB1 WELLBORE. THE TOP OF THE WINDOW WAS AT 5502' MD, 3596' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW - NO DATA PRESENTED. 6. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-2 REPRESENT 1D-141APB1 WITH API#: API# 50-029-22967-73. THIS WELL REACHED A TOTAL DEPTH OF 6,680MD / 3,775'TVO. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SEEP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. Page 2 1d-141apbl.tapx File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 5472.0 5498.0 5498.0 5498.0 5498.0 5498.0 5502.5 STOP DEPTH 6614.5 6622.0 6622.0 6622.0 6622.0 6622.0 6680.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 5472.0 6680.0 S REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service Order units size Nsam DEPT FT 4 1 RPD MWD OHMM 4 1 RPM MWD OHMM 4 1 RPS MWD OHMM 4 1 RPX MWD OHMM 4 1 FET MWD HR 4 1 GR MWD API 4 1 ROP MWD FPH 4 1 Rep Code offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Page 3 • 1d-141apbl.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6680 6076 2417 5472 6680 RPD ' MWD OHMM 0.28 1664.11 23.1888 2249 5498 6622 RPM MWD OHMM 2.52 1133.76 19.3368 2249 5498 6622 RPS MWD OHMM 2.91 1695.24 19.8032 2249 5498 6622 RPX MWD OHMM 3.27 1698.45 19.931 2249 5498 6622 FET MWD HR 0.48 72.48 3.95694 2249 5498 6622 GR MWD API 36.06 128.27 81.3615 2286 5472 6614.5 ROP MWD FPH 0.25 386.15 156.832 2356 5502.5 6680 First Reading For Entire File..........5472 Last Reading For Entire File...........6680 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP LOG HEADER DATA DATE LOGGED: SOFTWARE header data for each bit run in separate files. 2 .5000 START DEPTH 5472.0 5498.0 5498.0 5498.0 5498.0 5498.0 5502.5 STOP DEPTH 6614.5 6622.0 6622.0 6622.0 6622.0 6622.0 6680.0 12-MAR-08 Page 4 • • 1d-141apbl.tapx SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.0 MAXIMUM ANGLE: 90.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EwR4 EwR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 71.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. Down optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units. .. .. ..... Datum specification Block sub-type ...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 Page 5 .0 .0 .0 .0 ~ ~ 1d-141apbl.tapx FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6680 6076 2417 5472 6680 RPD MWD020 OHMM 0.28 1664.11 23.1888 2249 5498 6622 RPM MWD020 OHMM 2.52 1133.76 19.3368 2249 5498 6622 RPS MWD020 OHMM 2.91 1695.24 19.8032 2249 5498 6622 RPX MWD020 OHMM 3.27 1698.45 19.931 2249 5498 6622 FET MWD020 HR 0.48 72.48 3.95694 2249 5498 6622 GR MWD020 API 36.06 128.27 81.3615 2286 5472 6614.5 ROP MWD020 FPH 0.25 386.15 156.832 2356 5502.5 6680 First Reading For Entire File..........5472 Last Reading For Entire File...........6680 File Trailer service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name. ..........LISTPE Date. ...................08/06/19 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/06/19 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN COmments .................STS LIS Physical EOF Physical EOF writing Library. scientific Technical services writing Library. Page 6 scientific Technical services ~ ~ 1d-141apbl.tapx End Of LIS File Page 7 • 1d-141apb2.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 19 13:28:01 2008 Reel Header Service name .............LISTPE Date . ...................08/06/19 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/06/19 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS WELL NAME: 1D-141APB2 API NUMBER: 500292296774 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 29-MAY-08 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: MW-000547770 Mw-000547770 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 14 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 14 FEL: 596 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 111.50 GROUND LEVEL: 70.70 WELL CASING RECORD Page 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1d-141apb2.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5502.0 CJ LDWG RECREATED 19-JUN-2008 TO CORRECT API NUMBER. THIS DATA SUPERSEDS ALL PREVIOUSLY ISSUED DATA. 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A OPENHOLE SIDETRACK EXITING 1D-141APB1 AT 6500' MD, 3784' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW - NO DATA PRESENTED. 6. MWD RUN 2-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-3 REPRESENT 1D-141APB2 WITH API#: API# 50-029-22967-74. THIS WELL REACHED A TOTAL DEPTH OF 7033' MD / 3774' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. Page 2 1d-141apb2.tapx File Header Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped DEPTH INCREMENT: .5000 FILE SUMMARY curves; all bit runs merged. PBU TOOL CODE START DEPTH STOP DEPTH GR 5472.0 6968.0 RPD 5498.0 6975.5 FET 5498.0 6975.5 RP5 5498.0 6975.5 RPM 5498.0 6975.5 RPx 5498.0 6975.5 ROP 5502.5 7033.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 5472.0 6499.5 3 6500.0 7033.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ... ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 Page 3 1d-141apb2.tapx ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 7033 6252.5 3123 5472 7033 RPD MWD OHMM 0.28 1664.11 31.9777 2956 5498 6975.5 RPM MWD OHMM 2.52 1133.76 28.2962 2956 5498 6975.5 RPS MWD OHMM 2.91 1695.24 28.9551 2956 5498 6975.5 RPX MWD OHMM 3.27 2000 30.8156 2956 5498 6975.5 FET MWD HR 0.26 72.48 3.8312 2956 5498 6975.5 GR MWD API 36.06 128.27 77.6877 2993 5472 6968 ROP MWD FPH 0.25 582.14 154.477 3062 5502.5 7033 First Reading For Entire File..........5472 Last Reading For Entire File...........7033 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5472.0 6499.5 FET 5498.0 6499.5 RPX 5498.0 6499.5 RPS 5498.0 6499.5 RPM 5498.0 6499.5 RPD 5498.0 6499.5 ROP 5502.5 6499.5 LOG HEADER DATA DATE LOGGED: Page 4 12-MAR-08 1d- 141apb2.tapx SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.0 MAXIMUM ANGLE: 90.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE DGR EWR4 BOREHOLE AND CASING OPEN HOLE BIT SI; DRILLER'S CASING TOOL TYPE TOOL NUMBER Dual Gamma Ray 184054 EwR Phase-4 223565 DATA ?E (IN): 6.750 DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 71.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units ............ ... ..... Datum specification Block sub-type ...0 Name service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MwD020 oHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 Page 5 .0 .0 .0 .0 1d-141apb2.tapx RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6499.5 5985.75 2056 5472 6499.5 RPD MWD020 OHMM 0.28 1664.11 22.9973 2004 5498 6499.5 RPM MWD020 OHMM 2.52 1133.76 19.0117 2004 5498 6499.5 RPS MWD020 OHMM 2.91 1695.24 19.5553 2004 5498 6499.5 RPX MWD020 OHMM 3.27 1698.45 19.7295 2004 5498 6499.5 FET MWD020 HR 0.48 72.48 4.33426 2004 5498 6499.5 GR MWD020 API 36.06 128.27 81.9258 2056 5472 6499.5 ROP MWD020 FPH 0.25 386.15 151.657 1995 5502.5 6499.5 First Reading For Entire File..........5472 Last Reading For Entire File...........6499.5 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 6500.0 6975.5 RPD 6500.0 6975.5 GR 6500.0 6968.0 RPM 6500.0 6975.5 FET 6500.0 6975.5 RPS 6500.0 6975.5 RPD 6500.0 7033.0 Page 6 1d-141apb2.tapx LOG HEADER DATA DATE LOGGED: 13-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 93.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER's CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 71.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 .0 .0 .0 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 7 1d-141apb2.tapx RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MwD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6500 7033 6766.5 1067 6500 7033 RPD MWD030 OHMM 24.71 87.32 50.882 952 6500 6975.5 RPM MWD030 OHMM 22.73 86.61 47.8404 952 6500 6975.5 RPS MWD030 OHMM 19.67 110.27 48.7421 952 6500 6975.5 RPX MWD030 OHMM 21.1 2000 54.1524 952 6500 6975.5 FET MWD030 HR 0.26 6.84 2.77225 952 6500 6975.5 GR MWD030 API 45.2 89.83 68.3885 937 6500 6968 ROP MWD030 FPH 2.27 582.14 159.749 1067 6500 7033 First Reading For Entire File..........6500 Last Reading For Entire File...........7033 File Trailer service name... .......STSLI6.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLI6.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/19 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/19 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF scientific Technical services Scientific Technical services Page 8 Physical EOF End Of LIS File 1d-141apb2.tapx Page 9 • 1d-141apb3.tapx Sperry-Sun Drillin Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 19 13:26:33 2008 Reel Header Service name .............LISTPE Date. ... ..............08/06/19 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/06/19 origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000547770 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical services scientific Technical services 1D-141AP63 500292296775 ConocoPhillips Alaska Inc. Sperry Sun 29-MAY-08 MWD RUN 4 MWD RUN 5 MW-000547770 Mw-000547770 B. HENNINGSE R. WILSON M. THORNTON M. THORNTON 14 11N l0E 14 596 .00 111.50 70.70 Page 1 ~~~r-OICo `f l(o~ r a 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1d-141apb3.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5502.0 LDWG RECREATED 19-JUN-2008 TO CORRECT API NUMBER. THIS DATA SUPERSEDE ALL PREVIOUSLY ISSUED DATA. 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A OPENHOLE SIDETRACK EXITING 1D-141A PB1 AT 6125' MD, 3782' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW - NO DATA PRESENTED. 6. MWD RUN 2,4,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-2, 4-5 REPRESENT 1D-141APB3 WITH API#:50-029-22967-75. THIS WELL REACHED A TOTAL DEPTH OF 6360' MD / 3782' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SEEP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. Page 2 • 1d-141apb3.tapx File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sT5LI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 5472.0 5498.0 5498.0 5498.0 5498.0 5498.0 5502.5 STOP DEPTH 6295.0 6302.0 6302.0 6302.0 6302.0 6302.0 6360.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 5472.0 4 6125.5 5 6229.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6125.0 6228.5 6360.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ................ ..... Datum specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 RPD MWD OHMM 4 1 RPM MWD OHMM 4 1 RPS MWD OHMM 4 1 RPX MWD OHMM 4 1 FET MWD HR 4 1 Rep Code offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 Page 3 • 1d-141apb3.tapx GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6360 5916 1777 5472 6360 RPD MWD OHMM 0.28 1664.11 27.7821 1609 5498 6302 RPM MWD OHMM 2.52 1133.76 24.5292 1609 5498 6302 RPS MWD OHMM 2.91 1695.24 26.2004 1609 5498 6302 RPX MWD OHMM 3.27 1698.45 27.3899 1609 5498 6302 FET MWD HR 0.49 72.48 7.02122 1609 5498 6302 GR MwD API 36.06 128.27 82.9803 1647 5472 6295 ROP MWD FPH 0.25 504.59 140.494 1716 5502.5 6360 First Reading For Entire File..........5472 Last Reading For Entire File...........6360 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5472.0 6125.0 FET 5498.0 6125.0 RPx 5498.0 6125.0 RPS 5498.0 6125.0 RPM 5498.0 6125.0 RPD 5498.0 6125.0 ROP 5502.5 6125.0 LOG HEADER DATA Page 4 1d-141apb3.tapx DATE LOGGED: 12-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.0 MAXIMUM ANGLE: 90.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 71.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 LOg~ing Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... ............ Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 Page 5 .0 .0 .0 .0 • 1d-141apb3.tapx RPS MwD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6125 5798.5 1307 5472 6125 RPD MWD020 OHMM 0.28 1664.11 19.1719 1255 5498 6125 RPM MwD020 OHMM 2.52 1133.76 14.6989 1255 5498 6125 RPS MWD020 OHMM 2.91 1695.24 15.5923 1255 5498 6125 RPX MWD020 OHMM 3.27 1698.45 15.9623 1255 5498 6125 FET MwD020 HR 0.49 72.48 6.34116 1255 5498 6125 GR MWD020 API 36.06 128.27 87.9422 1307 5472 6125 ROP MWD020 FPH 0.25 322.82 135.388 1246 5502.5 6125 First Reading For Entire File..........5472 Last Reading For Entire File...........6125 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Ty e ................L0 Next Fie Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6125.5 6169.5 RPS 6125.5 6169.5 GR 6125.5 6162.5 RPx 6125.5 6169.5 RPM 6125.5 6169.5 RPD 6125.5 6169.5 ROP 6125.5 6228.5 Page 6 • 1d-141apb3.tapx LOG HEADER DATA DATE LOGGED: 14-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.3 MAXIMUM ANGLE: 87.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EwR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 55.0 MUD PH: .0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ......... Datum specification Block sub-type...0 .0 .0 .0 .0 Name service order units size Nsam Rep code offset channel Page 7 • 1d-141apb3.tapx DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 1Z 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6125.5 6228.5 6177 207 6125.5 6228.5 RPD MWD040 OHMM 49.72 59.53 55.6053 89 6125.5 6169.5 RPM MWD040 OHMM 46.38 59.23 54.3585 89 6125.5 6169.5 RPS MWD040 OHMM 43 65.35 55.5196 89 6125.5 6169.5 RPX MWD040 OHMM 40.04 69.25 55.7207 89 6125.5 6169.5 FET MWD040 HR 2.14 34.59 4.22 89 6125.5 6169.5 GR MWD040 API 58.77 73.51 66.624 75 6125.5 6162.5 ROP MWD040 FPH 2.93 504.59 112.389 207 6125.5 6228.5 First Reading For Entire File..........6125.5 Last Reading For Entire File...........6228.5 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6163.0 RPM 6170.0 RPx 6170.0 RPD 6170.0 STOP DEPTH 6295.0 6302.0 6302.0 6302.0 Page 8 ~-- i 1d-141apb3.tapx FET 6170.0 6302.0 RPS 6170.0 6302.0 ROP 6229.0 6360.0 LOG HEADER DATA DATE LOGGED: 15-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.9 MAXIMUM ANGLE: 91.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 57.0 MUD PH: .O MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ....................... Page 9 .0 .0 .0 .0 1d-141apb3.tapx Datum Specificat ion Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MwD050 HR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MwD050 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 6163 6360 6261.5 395 6163 6360 RPD MWD050 OHMM 53.74 70.19 59.2143 265 6170 6302 RPM. MWD050 OHMM 56.66 78.14 61.0658 265 6170 6302 RPS MWD050 OHMM 60.39 102.93 66.5711 265 6170 6302 RPX MWD050 OHMM 62.48 125.86 71.9947 265 6170 6302 FET MwD050 HR 0.8 24.25 11.128 265 6170 6302 GR MwD050 API 45.9 79.4 63.1366 265 6163 6295 ROP MWD050 FPH 18.34 463.98 186.803 263 6229 6360 First Reading For Entire File..........6163 Last Reading For Entire File...........6360 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI6.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/19 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/19 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services scientific Technical services Page 10 1d-141apb3.tapx Physical EOF Physical EOF End Of LIS File Page 11 • 1d-141a.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 30 16:35:14 2008 Reel Header Service name .............LISTPE Date . ...................08/05/30 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LISTPE Date .....................08/05/30 Origin ...................STS Tape Name...... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000547770 LOGGING ENGINEER: 6. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1D-141A 500292296701 ConocoPhillips Alaska Inc. Sperry Sun 30-MAY-08 MWD RUN 6 MWD RUN 7 Mw-000547770 MW-000547770 R. WILSON R. WILSON M. THORNTON M. THORNTON 14 11N l0E 14 596 111.50 70.70 Page 1 ~o~fr.-6/~ ~ ~v~--l 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • 1d-141a.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5502.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A OPENHOLE SIDETRACK EXITING 1D-141A PB1 AT 6125' MD, 3782' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW - NO DATA PRESENTED. 6. MWD RUN 2,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). 7. MWD RUN 7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), GEO-PILOT ROTARY STEERABLE SYSTEM (GP) AND PRESSURE WHILE DRILLING (PWD). 8. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA. ARE CONSIDERED PDC. 9. MWD RUNS 1-2, 6-7 REPRESENT 1D-141A WITH API#:50-029-22967-01. THIS WELL REACHED A TOTAL DEPTH OF 9925' MD / 3751' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A Page 2 • 1d-141a.txt WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5472.0 9868.5 FET 5498.0 9875.5 RPD 5498.0 9875.5 RPS 5498.0 9875.5 RPM 5498.0 9875.5 RPX 5498.0 9875.5 OP 5502.5 9925.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 5472.0 6125.0 6 6125.5 7240.0 7 7184.0 9925.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel Page 3 • • 1d-141a.txt DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 9925 7698.5 8907 5472 9925 RPD MWD OHMM 0.28 1664.11 45.0949 8756 5498 9875.5 RPM MWD OHMM 2.52 1133.76 42.8717 8756 5498 9875.5 RPS MWD OHMM 2.91 1695.24 44.0475 8756 5498 9875.5 RPX MWD OHMM 3.27 2000 48.0236 8756 5498 9875.5 FET MWD HR 0.17 76.11 2.39598 8756 5498 9875.5 GR MWD API 36.06 128.27 67.9454 8794 5472 9868.5 ROP MWD FPH 0.02 1125.99 200.82 8846 5502.5 9925 First Reading For Entire File..........5472 Last Reading For Entire File...........9925 File Trailer service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 gate of Generation.......08/05/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5472.0 FET 5498.0 RPx 5498.0 RPS 5498.0 STOP DEPTH 6125.0 6125.0 6125.0 6125.0 Page 4 1d-141a.txt RPM 5498.0 6125.0 RPD 5498.0 6125.0 RoP 5502.5 6125.0 LOG HEADER DATA DATE LOGGED: 12-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.0 MAXIMUM ANGLE: 90.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 71.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ....................... Page 5 .0 .0 .0 .0 • 1d-141a.txt Datum Specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6125 5798.5 1307 5472 6125 RPD MWD020 OHMM 0.28 1664.11 19.1719 1255 5498 6125 RPM MWD020 OHMM 2.52 1133.76 14.6989 1255 5498 6125 RPS MWD020 OHMM 2.91 1695.24 15.5923 1255 5498 6125 RPX MWD020 OHMM 3.27 1698.45 15.959 1255 5498 6125 FET MWD020 HR 0.49 72.48 6.34116 1255 5498 6125 GR MWD020 API 36.06 128.27 87.9422 1307 5472 6125 ROP MWD020 FPH 0.25 322.82 135.616 1246 5502.5 6125 First Reading For Entire File..........5472 Last Reading For Entire File...........6125 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6125.5 7190.5 Page 6 • 1d-141a.txt RPS 6125.5 7190.5 GR 6125.5 7183.5 RPX 6125.5 7190.5 RPM 6125.5 7190.5 RPD 6125.5 7190.5 OP 6125.5 7240.0 $ LOG HEADER DATA DATE LOGGED: 16-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.4 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 76.0 MUD PH: .O MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing .....................60 .lIN Page 7 .0 .0 .0 .0 • 1d-141a.txt Max frames per record .............undefined Absent value ... ...................-999 Depth Units. .. .. ..... Datum specifica tion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6125.5 7240 6682.75 2230 6125.5 7240 RPD MWD060 OHMM 17.91 68.59 45.2084 2131 6125.5 7190.5 RPM MWD060 OHMM 15.99 67.3 41.8556 2131 6125.5 7190.5 RPS MWD060 OHMM 15.65 74.85 41.6483 2131 6125.5 7190.5 RPX MWD060 OHMM 9.02 78.83 41.0523 2131 6125.5 7190.5 FET MWD060 HR 0.33 76.11 2.38434 2131 6125.5 7190.5 GR MWD060 API 42.59 91.66 64.8722 2117 6125.5 7183.5 ROP MWD060 FPH 7.02 1125.99 180.873 2230 6125.5 7240 First Reading For Entire File..........6125.5 Last Reading For Entire File...........7240 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........5T5LIB.004 Physical EOF File Header Service name... .......STSLI6.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: header data for each bit run in separate files. 7 5000 Page 8 • 1d-141a.txt FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7184.0 9868.5 RPM 7191.0 9875.5 RPX 7191.0 9875.5 RPD 7191.0 9875.5 FET 7191.0 9875.5 RPS 7191.0 9875.5 ROP 7240.5 9925.0 LOG HEADER DATA DATE LOGGED: 20-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 92.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 091360 EwR4 EWR Phase-4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 72.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ......... .0 Data Specification Block Type.... .0 Logging Direction ................ .DOwn Page 9 .0 .0 .0 .0 • 1d-141a.txt Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MwD070 OHMM 4 1 68 16 5 FET MwD070 HR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MwD070 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7184 9925 8554.5 5483 7184 9925 RPD MWD070 OHMM 16.21 1307.18 51.1082 5370 7191 9875.5 RPM MWD070 OHMM 18.59 96.91 49.859 5370 7191 9875.5 RPS MWD070 OHMM 19.04 162.43 51.6496 5370 7191 9875.5 RPX MWD070 OHMM 20.34 2000 58.2837 5370 7191 9875.5 FET MWD070 HR 0.17 24.42 1.47859 5370 7191 9875.5 GR MWD070 API 40.57 91.05 64.29 5370 7184 9868.5 ROP MWD070 FPH 0.02 549.58 224.233 5370 7240.5 9925 First Reading For Entire File..........7184 Last Reading For Entire File...........9925 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/05/30 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date . ...................08/05/30 Origin ...................STS scientific Technical services Page 10 1d-141a.txt Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN comments .................sTS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 11 • 1d-141apbl.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 15 15:28:07 2008 Reel Header Service name .............LISTPE Date . ...................08/05/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/05/15 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: n scientific Technical services scientific Technical services 1D-141APB1 500292296770 ConocoPhillips Alaska Inc. Sperry Sun 15-MAY-08 MWD RUN 2 MW-000547770 B. HENNINGSE M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 14 11N l0E 14 596 .00 111.50 70.70 Page 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1d-141apbl.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5502.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 1D-141PB1 WELLBORE. THE TOP OF THE WINDOW WAS AT 5502' MD, 3596' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW - NO DATA PRESENTED. 6. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-2 REPRESENT 1D-141APB1 WITH API#: API# 50-029-22967-70. THIS WELL REACHED A TOTAL DEPTH OF 6,680MD / 3,775'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service sub Level~Name... Page 2 • version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5Li6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped DEPTH INCREMENT: .5000 FILE SUMMARY curves; all bit runs merged. PBU TOOL CODE START DEPTH STOP DEPTH GR 5472.0 6614.5 RPD 5498.0 6622.0 .RPM 5498.0 6622.0 RPS 5498.0 6622.0 RPX 5498.0 6622.0 FET 5498.0 6622.0 ROP 5502.5 6680.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL .CODE BIT RUN NO MERGE TOP MERGE BASE $wD 2 5472.0 6680.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 1d-141apbl.txt First Last Page 3 1d-141apbl.txt Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6680 6076 2417 5472 6680 RPD MWD OHMM 0.28 1664.11 23.1888 2249 5498 6622 RPM MWD OHMM 2.52 1133.76 19.3368 2249 5498 6622 RPS MWD OHMM 2.91 1695.24 19.8032 2249 5498 6622 RPX MWD OHMM 3.27 1698.45 19.931 2249 5498 6622 FET MWD HR 0.48 72.48 3.95694 2249 5498 6622 GR MWD API 36.06 128.27 81.3615 2286 5472 6614.5 ROP MWD FPH 0.25 386.15 156.832 2356 5502.5 6680 First Reading For Entire File..........5472 Last Reading For Entire File...........6680 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5472.0 6614.5 RPD 5498.0 6622.0 RPM 5498.0 6622.0 RPS 5498.0 6622.0 RPx 5498.0 6622.0 FET 5498.0 6622.0 ROP 5502.5 6680.0 LOG HEADER DATA DATE LOGGED: 12-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): Page 4 • 1d-141apbl.txt TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR Dual Gamma Ray EWR4 EWR Phase-4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 61.0 90.2 TOOL NUMBER 184054 223565 6.750 5502.0 VersaPro 9.30 71.0 .0 26000 5.1 .000 .0 .000 .0 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPx MWD020 oHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 Page 5 • 1d-141apbl.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6680 6076 2417 5472 6680 RPD MWD020 OHMM 0.28 1664.11 23.1888 2249 5498 6622 RPM MWD020 OHMM 2.52 1133.76 19.3368 2249 5498 6622 RPS MWD020 OHMM 2.91 1695.24 19.8032 2249 5498 6622 RPX MWD020 OHMM 3.27 1698.45 19.931 2249 5498 6622 FET MWD020 HR 0.48 72.48 3.95694 2249 5498 6622 GR MWD020 API 36.06 128.27 81.3615 2286 5472 6614.5 ROP MWD020 FPH 0.25 386.15 156.832 2356 5502.5 6680 First Reading For Entire File..........5472 Last Reading For Entire File...........6680 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/05/15 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/05/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File scientific Technical services Library. Scientific Technical Services Page 6 1d-141apb2.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 29 10:03:22 2008 Reel Header Service name .............LISTPE Date . ...................08/05/29 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/05/29 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing n scientific Technical services Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS WELL NAME: 1D-141AP62 API NUMBER: 500292296771 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 29-MAY-08 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: MW-000547770 MW-000547770 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 14 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 14 FEL: 596 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 111.50 GROUND LEVEL: 70.70 WELL CASING RECORD Page 1 ~ ohs - o i ~ / ~ ~~3 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1d-141apb2.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5502.0 • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A OPENHOLE SIDETRACK EXITING 1D-141APB1 AT 6500' MD, 3784' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW - NO DATA PRESENTED. 6. MWD RUN 2-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-3 REPRESENT 1D-141APB2 WITH API#: API# 50-029-22967-71. THIS WELL REACHED A TOTAL DEPTH OF 7033' MD / 3774' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service Sub Level Name... Page 2 • 1d-141apb2.tapx version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD FET RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 5472.0 5498.0 5498.0 5498.0 5498.0 5498.0 5502.5 STOP DEPTH 6968.0 6975.5 6975.5 6975.5 6975.5 6975.5 7033.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 5472.0 6499.5 3 6500.0 7033.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order DEPT RPD MWD RPM MWD RPS MWD RPX MWD FET MWD GR MWD ROP MWD units size Nsam Rep Code offset FT 4 1 68 0 OHMM 4 1 68 4 OHMM 4 1 68 8 OHMM 4 1 68 12 OHMM 4 1 68 16 HR 4 1 68 20 API 4 1 68 24 FPH 4 1 68 28 Page 3 channel 1 2 3 5 6 8 1d-141apb2.tapx First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 7033 6252.5 3123 5472 7033 RPD MWD OHMM 0.28 1664.11 31.9777 2956 5498 6975.5 RPM MWD OHMM 2.52 1133.76 28.2962 2956 5498 6975.5 RPS MWD OHMM 2.91 1695.24 28.9551 2956 5498 6975.5 RPx MwD OHMM 3.27 2000 30.8156 2956 5498 6975.5 FET MWD HR 0.26 72.48 3.8312 2956 5498 6975.5 GR MWD API 36.06 128.27 77.6877 2993 5472 6968 ROP MWD FPH 0.25 582.14 154.477 3062 5502.5 7033 First Reading For Entire File..........5472 Last Reading For Entire File...........7033 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5472.0 6499.5 FET 5498.0 6499.5 RPx 5498.0 6499.5 RPS 5498.0 6499.5 RPM 5498.0 6499.5 RPD 5498.0 6499.5 OP 5502.5 6499.5 $ LOG HEADER DATA DATE LOGGED: 12-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 4 • 1d-141apb2.tapx TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.0 MAXIMUM ANGLE: 90,2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 71.0 MUD PH: ,0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL .MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 Page 5 .0 .0 .0 .0 • 1d-141apb2.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6499.5 5985.75 2056 5472 6499.5 RPD MWD020 OHMM 0.28 1664.11 22.9973 2004 5498 6499.5 RPM MWD020 OHMM 2.52 1133.76 19.0117 2004 5498 6499.5 RPS MWD020 OHMM 2.91 1695.24 19.5553 2004 5498 6499.5 RPX MWD020 OHMM 3.27 1698.45 19.7295 2004 5498 6499.5 FET MWD020 HR 0.48 72.48 4.33426 2004 5498 6499.5 GR MWD020 API 36.06 128.27 81.9258 2056 5472 6499.5 ROP MWD020 FPH 0.25 386.15 151.657 1995 5502.5 6499.5 First Reading For Entire File..........5472 Last Reading For Entire File...........6499.5 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 6500.0 6975.5 RPD 6500.0 6975.5 GR 6500.0 6968.0 RPM 6500.0 6975.5 FET 6500.0 6975.5 RPS 6500.0 6975.5 RPD 6500.0 7033.0 LOG HEADER DATA DATE LOGGED: 13-MAR-08 SOFTWARE Page 6 • SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 1d-141apb2.tapx Insite 74.11 Memory 86.2 93.9 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EWR4 EWR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 71.0 MUD PH: ,0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 Page 7 .0 .0 .0 .0 i i 1d-141apb2.tapx FET MWD030 HR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MwD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6500 7033 6766.5 1067 6500 7033 RPD MWD030 OHMM 24.71 87.32 50.882 952 6500 6975.5 RPM MwD030 OHMM 22.73 86.61 47.8404 952 6500 6975.5 RPS MWD030 OHMM 19.67 110.27 48.7421 952 6500 6975.5 RPX MWD030 OHMM 21.1 2000 54.1524 952 6500 6975.5 FET MWD030 HR 0.26 6.84 2.77225 952 6500 6975.5 GR MWD030 API 45.2 89.83 68.3885 937 6500 6968 ROP MWD030 FPH 2.27 582.14 159.749 1067 6500 7033 First Reading For Entire File..........6500 Last Reading For Entire File...........7033 File Trailer Service name... .......STSL2B.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File TyC~e ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/05/29 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. scient ific Technical services Reel Trailer Service name .............LISTPE Date .....................08/05/29 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LI5 writing Library. scient ific Technical services Physical EOF Physical EOF Page 8 End Of LIS File 1d-141apb2.tapx Page 9 • r 1d-141apb3.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 29 16:07:52 2008 Reel Header Service name .............LISTPE Date . ...................08/05/29 Ori in ...................STs Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................08/05/29 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000547770 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services scientific Technical services 1D-141AP63 500292296772 ConocoPhillips Alaska Inc. Sperry Sun 29-MAY-08 MWD RUN 4 MWD RUN 5 MW-000547770 MW-000547770 B. HENNINGSE R. WILSON M. THORNTON M. THORNTON 14 11N l0E 14 596 .00 111.50 70.70 Page 1 ~bfs~il~ I ~ ~l ~( • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1d-141apb3.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5502.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A OPENHOLE SIDETRACK EXITING 1D-141A PB1 AT 6125' MD, 3782' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW - NO DATA PRESENTED. 6. MWD RUN 2,4,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-.MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-2, 4-5 REPRESENT 1D-141APB3 WITH API#:50-029-22967-72. THIS WELL REACHED A TOTAL DEPTH OF 6360' MD / 3782' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... Page 2 1d-141apb3.txt version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.000 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 5472.0 5498.0 5498.0 5498.0 5498.0 5498.0 5502.5 STOP DEPTH 6295.0 6302.0 6302.0 6302.0 6302.0 6302.0 6360.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 5472.0 4 6125.5 5 6229.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6125.0 6228.5 6360.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 Page 3 • 1d-141apb3.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6360 5916 1777 5472 6360 RPD MWD OHMM 0.28 1664.11 27.7821 1609 5498 6302 RPM MWD OHMM 2.52 1133.76 24.5292 1609 5498 6302 RPS MWD OHMM 2.91 1695.24 26.2004 1609 5498 6302 RPX MWD OHMM 3.27 1698.45 27.3899 1609 5498 6302 FET MWD HR 0.49 72.48 7.02122 1609 5498 6302 GR MWD API 36.06 128.27 82.9803 1647 5472 6295 ROP MWD FPH 0.25 504.59 140.494 1716 5502.5 6360 First Reading For Entire File..........5472 Last Reading For Entire File...........6360 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.002 Physical EoF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5472.0 6125.0 FET 5498.0 6125.0 RPx 5498.0 6125.0 RPS 5498.0 6125.0 RPM 5498.0 6125.0 RPD 5498.0 6125.0 ROP 5502.5 6125.0 LOG HEADER DATA DATE LOGGED: 12-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 Page 4 • 1d-141apb3.txt DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR Dual Gamma Ray EWR4 EWR Phase-4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Po~nt ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 61.0 90.2 TOOL NUMBER 184054 223565 6.750 5502.0 VersaPro 9.30 71.0 .0 26000 5.1 .000 .0 .000 .0 .000 .0 .000 .0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 Page 5 i ~ 1d-141apb3.txt ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5472 6125 5798.5 1307 5472 6125 RPD MWD020 OHMM 0.28 1664.11 19.1719 1255 5498 6125 RPM MWD020 OHMM 2.52 1133.76 14.6989 1255 5498 6125 RPS MWD020 OHMM 2.91 1695.24 15.5923 1255 5498 6125 RPX MWD020 OHMM 3.27 1698.45 15.9623 1255 5498 6125 FET MwD020 HR 0.49 72.48 6.34116 1255 5498 6125 GR MWD020 API 36.06 128.27 87.9422 1307 5472 6125 ROP MWD020 FPH 0.25 322.82 135.388 1246 5502.5 6125 First Reading For Entire File..........5472 Last Reading For Entire File...........6125 File Trailer Service name... .......STSL2B.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6125.5 6169.5 RPS 6125.5 6169.5 GR 6125.5 6162.5 RPx 6125.5 6169.5 RPM 6125.5 6169.5 RPD 6125.5 6169.5 ROP 6125.5 6228.5 LOG HEADER DATA DATE LOGGED: 14-MAR-08 Page 6 • SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 1d-141apb3.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR Dual Gamma Ray EWR4 EWR Phase-4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ... ..... Datum specification Block sub-type...0 Insite 74.11 Memory 85.3 87.4 TOOL NUMBER 184054 223565 6.750 5502.0 VersaPro 9.00 55.0 .0 23000 5.1 .000 .0 .000 .0 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 Page 7 i ~ 1d-141apb3.txt RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6125.5 6228.5 6177 207 6125.5 6228.5 RPD MwD040 OHMM 49.72 59.53 55.6053 89 6125.5 6169.5 RPM MWD040 OHMM 46.38 59.23 54.3585 89 6125.5 6169.5 RPS MWD040 OHMM 43 65.35 55.5196 89 6125.5 6169.5 RPX MWD040 OHMM 40.04 69.25 55.7207 89 6125.5 6169.5 FET MWD040 HR 2.14 34.59 4.22 89 6125.5 6169.5 GR MWD040 API 58.77 73.51 66.624 75 6125.5 6162.5 ROP MWD040 FPH 2.93 504.59 112.389 207 6125.5 6228.5 First Reading For Entire File..........6125.5 Last Reading For Entire File...........6228.5 File Trailer Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6163.0 6295.0 RPM 6170.0 6302.0 RPx 6170.0 6302.0 RPD 6170.0 6302.0 FET 6170.0 6302.0 RPS 6170.0 6302.0 RoP 6229.0 6360.0 Page 8 1d-141apb3.txt LOG HEADER DATA DATE LOGGED: 15-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.9 MAXIMUM ANGLE: 91.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 184054 EwR4 EwR Phase-4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5502.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 57.0 MUD PH: .O MUD CHLORIDES (PPM): 24000 FLUID LO55 (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 .0 .0 .0 .0 Name Service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 9 :7 1d-141apb3.txt RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6163 6360 6261.5 395 6163 6360 RPD MwD050 OHMM 53.74 70.19 59.2143 265 6170 6302 RPM MwD050 OHMM 56.66 78.14 61.0658 265 6170 6302 RPS MWD050 OHMM 60.39 102.93 66.5711 265 6170 6302 RPX MWD050 OHMM 62.48 125.86 71.9947 265 6170 6302 FET MWD050 HR 0.8 24.25 11.128 265 6170 6302 GR MWD050 API 45.9 79.4 63.1366 265 6163 6295 ROP MWD050 FPH 18.34 463.98 186.803 263 6229 6360 First Reading For Entire File..........6163 Last Reading For Entire File...........6360 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer service name .............LISTPE Date . ...................08/05/29 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date . ...................08/05/29 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical services scientific Technical services Page 10 • 1d-141apb3.txt Physical EOF End Of LIS File Page 11
