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Home My WebLink About209-061MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3C-14B KUPARUK RIV UNIT 3C-14B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3C-14B 50-029-21425-02-00 209-061-0 W SPT 5847 2090610 1500 2960 2960 2960 2960 320 400 400 400 4YRTST P Austin McLeod 8/2/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3C-14B Inspection Date: Tubing OA Packer Depth 690 1790 1720 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250803181314 BBL Pumped:0.7 BBL Returned:0.6 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 99 999 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:11:49 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch ConocoPhillips Alaska, Inc 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 9382 feet N/A feet true vertical 6459 feet N/A feet Effective Depth measured 9380 feet 6335 feet true vertical 6459 feet 5847 feet Perforation depth Measured depth 6789' - 9348'feet True Vertical depth 6272' - 6461'feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 6341' MD 5853' TVD Packers and SSSV (type, measured and true vertical depth) Baker seal assembly 6335' MD / 5847' TVD TRMAXX-5E SCSSV 2027' TVD/ 2026' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date: Contact Name: Jan Byrne Contact Email:Jan.Byrne@conocophillps.com Authorized Title: Well Integrity Specialist Contact Phone: 907-659-7224 321-628 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 116 7 5.5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 209-061 50029214250200' P.O. Box 100360, Anchorage, AK 995103. Address: N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025634 Kuparuk River/ Kuparuk River Oil KRU 3C-14B Plugs Junk measured Length 80 4025 116Conductor Surface Production 16 9.625 measured TVD Liner Liner 4145 2692 635 Casing Structural 3808 6116 3.5 4178 6616 6951 6400 4061 3720 Burst Collapse p k ft t Fra O s 209 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 4:02 pm, Dec 20, 2022 Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I wrote the sundry request Location: Anchorage tower Date: 2022.12.20 10:10:00-09'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne Page 1/10 3C-14 Report Printed: 12/20/2022 Well History API / UWI5002921425 Legal WellName3C-14 Field NameKUPARUK RIVER UNIT Well TypeDevelopment Original KB/RT Elevation (ft)85.00 Well StatusINJ Left START DATE is from Daily Ops and Right Start Date represents the Job Start Start Date Last 24hr Sum Project Ref # Rig Supervisor Job Type Start Date Primary Wellbore Affected 9/11/2022 (SW) 3C-14 STATE WITNESSED SULLY SULLIVAN MITIA PASSED TO 1815 PSI. 10439155 SUMRALL, SHELBY,DHD Field Supervisor ANNCOMM 11/14/2021 3C-14B 9/3/2022 (PRE-SW) MITIA PASSED TO 3000 PSI. 10437436 SUMRALL, SHELBY,DHD Field Supervisor ACQUIRE DATA 9/2/2022 3C-14B 9/2/2022 (MISC) : POT-IC PASSED, BLEED IA & OA TO 0 PSI (COMPLETE), INSTALL IC-EP RE-ENERGIZER JEWELRY (COMPLETE), RE-ENERGIZE IC-PO (COMPLETE), PPPOT-IC PASSED. 10437436 SUMRALL, SHELBY,DHD Field Supervisor ACQUIRE DATA 9/2/2022 3C-14B 8/29/2022 STING INTO LOWER P2P @ 4081' RKB & SET UPPER 2.72" P2P, SPACER PIPE, & ANCHOR LATCH @ 4051' RKB (31' OAL-SN: CPP35323/CPAL35176) RAN 3 1/2" TTS TEST TOOL TO UPPER PACKER @ 4051' RKB & MITT TO 2500 PSI (PASS). MITIA TO 2500 PSI (PASS). JOB COMPLETE 10439155 ZEMBA, EDDIE,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 8/28/2022 RAN 3 1/2" TTS TEST TOOL TO LOWER P2P @ 4084' RKB & CMIT TBG X IA TO 2500 PSI (PASS). IN PROGRESS. 10439155 ZEMBA, EDDIE,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 8/11/2022 SET LOWER QUADCO P2P PACKER W/ MOE @ 4084' RKB (SN: CPP35128). JOB IS READY FOR SL HUNG UP BRIEFLY IN THE SSSV AT 2026'. PRESSURE TO THE SSSV WAS LOW AND SSSV WAS ISOLATED FROM THE PANEL. BROUGHT UP SSSV PRESSURE AND PULLED THROUGH W/O ISSUE. 10439155 CONNELLY, JEFF,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 7/14/2022 DRIFT TBG W/ 2.72"X84" DRIFT TO 6250' RKB, NO ISSUES. READY FOR E-LINE TO SET LOWER PACKER. 10439155 FERGUSON, SID,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 7/12/2022 PUMPED 55 BBLS SEAWATER CONTAINING 23 GALLONS CRW-132 DOWN IA TAKING RETURNS UP TUBING PUMPED 76 BBLS DIESEL DOWN IA UTUBE FOR FREEZE PROTECT JOB COMPLETE 10439155 FERGUSON, SID,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 7/11/2022 PULLED CA2 PLUG @ 6250' RKB. BRUSH AND FLUSHED FOCUSING ON PATCH AREA 3900' RKB TO 4200' RKB. HAVE TO GET EXTRA SURFACE EQUIP RIGGED FOR IA DISPLACEMENT, LRS UP NEXT. 10439155 FERGUSON, SID,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 7/10/2022 PULLED EXTENDED PACKING DMY f/ STA # 2 @ 4066' RKB. PULLED 2.72" AVA CATCHER. ATTEMPT MULTIPLE TIMES TO PULL CA2 PLUG @ 6253' RKB w/o SUCCESS, INJ SCHMOO AT PLUG. JOB IN PROGRESS. 10439155 FERGUSON, SID,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 12/7/2021 LOG READ ACOUSTIC LDL FROM 6,250' MD TO SURFACE, LRS ONLINE AND ABLE TO PUMP AT 0.5 BPM @ 1500 PSI WHILE TAKING RETURNS UP IA. LEAK DETECTED AT 4,068' MD, 2.5' BELOW TOP OF GLM #2. LOG READ CALIPER FROM 6,250' TO SURFACE . *JOB COMPLETE* READY FOR PLAN FORWARD. 10439155 WORTHINGT ON, BRYCE,Wells Supervisor ANNCOMM 11/14/2021 3C-14B 11/15/2021 SET EXTENDED PACKING DV @ 4065' RKB (TBG X IA CONTINUES); CMIT TBG X IA TO 3000 PSI (PASS); DRAW DOWN TBG X IA TO 700 PSI & DRIFT TO ENSURE AVA CATCHER ON TOP OF PLUG @ 6253' RKB. READY FOR PLAN FORWARD. 10439155 ZEMBA, EDDIE,Wells Supervisor ANNCOMM 11/14/2021 3C-14B Submit to: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2090610 Type Inj W Tubing 2740 2740 2740 2740 Type Test P Packer TVD 5847 BBL Pump 0.8 IA 600 1815 1745 1740 Interval O Test psi 1500 BBL Return 0.8 OA 250 390 380 380 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 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA post patch per Sundry # 321-628 Notes: 3C-14B Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3C Pad Sully Sullivan Beck / Borge 09/11/22 Form 10-426 (Revised 01/2017)MIT KRU 3C-14 09-11-22.xlsx Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,747.0 3C-14B 4/29/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set upper section of Patch 3C-14B 8/29/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: ATTEMPT BUT UNABLE TO PASS 6784' RKB (MARKS ON BOTTOM OF TOOLS SUGGEST POSS. METAL OBSTRUCTION 4/29/2016 pproven NOTE: RKBs FROM DIFFERENT RIGS ACCOUNT FOR TBG/CSG TOPS 10/17/2012 osborl NOTE: SIDETRACK B DRILLED 9/9/2009 lmosbor NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 8/22/2008 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 116.0 116.0 62.50 H-40 SURFACE 9 5/8 8.76 35.2 4,060.5 3,720.0 36.00 J-55 PRODUCTION Post S/T 7 6.28 33.0 4,178.0 3,808.3 26.00 J-55 LINER A 5.5" 5 1/2 4.85 3,924.1 6,616.0 6,116.1 15.50 L-80 Hydril 511 WINDOW B 4 3.00 6,825.0 6,830.0 6,307.6 LINER A 3.5" 3 1/2 2.99 6,316.1 6,951.0 6,400.3 9.20 L-80 Hydril 511 SLOTTED LINER B 2 3/8 1.99 6,810.0 9,382.0 4.60 L-79 STL Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 37.7 Set Depth 6,341.0 Set Depth 5,852.8 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.7 37.7 0.00 HANGER 10.850 CIW Gen 4, Type N-FBB, "H" BPV profioe, P/N 156156-01-01-01 2.992 2,026.5 2,026.2 5.09 SAFETY VLV 5.176 3.5" TRMAXX-5E SCSSV w/ 2.812" X Profile Ser.# HZS-028 Camco TRMAX X-5E 2.812 2,543.9 2,521.7 24.41 GAS LIFT 4.725 3-1/2" x 1" Camco GLM, KBG-2-9 w/ DCK-3 Shear Valve, Integral Latch Camco KBG-2-9 2.900 4,065.9 3,724.1 40.77 GAS LIFT 4.725 3-1/2" x 1" Camco GLM, KBG-2-9 w/ DK-A1 Dummy, Integral Latch Camco KBG-2-9 2.900 5,082.3 4,605.8 9.61 GAS LIFT 4.725 3-1/2" x 1" Camco GLM, KBG-2-9 w/ DK-A1 Dummy, Integral Latch Camco KBG-2-9 2.900 5,872.5 5,389.0 6.57 GAS LIFT 4.725 3-1/2" x 1" Camco GLM, KBG-2-9 w/ DK-A1 Dummy, Integral Latch Camco KBG-2-9 2.900 6,172.1 5,686.7 7.56 GAS LIFT 4.725 3-1/2" x 1" Camco GLM, KBG-2-9 w/ DK-A1 Dummy, Integral Latch Camco KBG-2-9 2.900 6,252.3 5,766.0 10.12 NIPPLE 4.520 3-1/2" x 2.750" Camco "D" Nipple (EUE 8rd) 2.750" No-Go Profile Camco "D" 2.750 6,322.7 5,834.9 13.04 LOCATOR 4.400 Baker Locator Coupling (4.40" O.D.) Baker Locator Collar 2.990 6,335.5 5,847.4 13.41 SEAL ASSY 4.125 Baker Bullet Seal Assembly (O.D. 4.125") Baker Bullet Seal Assembl y 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,051.0 3,712.8 40.73 PACKER - PATCH - UPR 2.72" UPPER P2P PACKER (MID ELEMENT @ 4053.95), SPACER PIPE, & ANCHOR LATCH (31' OAL) QUADC O 2.72" P2P CPP3 5323 8/29/2022 1.625 4,054.6 3,715.6 40.74 ANCHOR LATCH ON SPACER PIPE 2 1/6" SPACER PIPE & ANCHOR LATCH ATTACHED TO UPPER P2P QUADC O CPAL 35176 8/29/2022 1.600 4,068.5 3,726.1 40.77 LEAK - GLM LEAK IDENTIED BY EL, 2.5' BELOW TOP OF GLM #2 12/7/2021 2.900 4,081.6 3,736.0 40.80 PACKER - PATCH - LWR 3.5" LOWER P2P PACKER CPP35128, OAL = 4', MOE @ 4084' RKB QUADC O 3.5" PARAG ON II PACKER CPP3 5128 8/11/2022 1.625 6,777.0 6,262.3 29.81 PACKER 35 KB LINER TOP PACKER 9/14/2009 1.860 6,781.0 6,265.8 30.00 PATCH BAKER SPACER PIPE, SEAL ASSY 9/14/2009 1.690 6,825.2 6,303.6 33.05 WHIPSTOCK 2.625" OD BAKER MONOBORE WHIPSTOCK 8.74" OAL, .875" FLUID PASS ID: 7.3.2009 WSR FOR DETAILS 7/3/2009 0.000 7,000.0 6,432.6 51.14 FISH 3 ANCHORS FROM 35 KB PACKER, 2 1/8"x1.33"x1/2" THICK 9/10/2009 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,543.9 2,521.7 24.41 1 GAS LIFT DMY BTM 1 0.0 11/29/2009 0.000 4,065.9 3,724.1 40.77 2 GAS LIFT OPEN 1 7/10/2022 5,082.3 4,605.8 9.61 3 GAS LIFT DMY BTM 1 0.0 11/29/2009 0.000 5,872.5 5,389.0 6.57 4 GAS LIFT DMY BTM 1 0.0 11/29/2009 0.000 3C-14B, 12/20/2022 10:01:24 AM Vertical schematic (actual) SLOTTED LINER B; 6,810.0- 9,382.0 LINER SHOE; 9,380.6-9,382.0 O-RING; 9,348.4-9,349.0 SLOTS; 8,246.0-9,348.0 DEPLOY; 8,245.0-8,245.8 LINER SHOE; 8,243.6-8,245.0 SLOTS; 8,117.0-8,244.0 SLOTS; 6,953.0-7,773.0 FISH; 7,000.0 LINER A 3.5"; 6,316.1-6,951.0 SHOE; 6,950.0-6,951.0 WINDOW B; 6,825.0-6,830.0 WHIPSTOCK; 6,825.2 DEPLOY; 6,820.2-6,826.6 PACKER; 6,810.0-6,820.2 IPERF; 6,789.0-6,803.0 PATCH; 6,781.0 PACKER; 6,777.0 LINER A 5.5"; 3,924.1-6,616.0 LINER FLOAT SHOE; 6,614.4- 6,616.0 LINER COLLAR; 6,529.6- 6,531.2 HANGER; 6,343.7-6,350.6 PACKER; 6,335.3-6,343.7 SEAL ASSY; 6,335.5 LOCATOR; 6,322.7 NIPPLE; 6,252.3 GAS LIFT; 6,172.1 GAS LIFT; 5,872.5 GAS LIFT; 5,082.3 PRODUCTION Post S/T; 33.0- 4,178.0 PACKER - PATCH - LWR; 4,081.5 GAS LIFT; 4,065.9 LEAK - GLM; 4,068.5 ANCHOR LATCH ON SPACER PIPE; 4,054.6 SURFACE; 35.2-4,060.5 FLOAT SHOE; 4,058.7-4,060.5 PACKER - PATCH - UPR; 4,051.0 FLOAT COLLAR; 3,978.7- 3,980.4 HANGER; 3,934.9-3,941.4 PACKER; 3,924.1-3,934.9 GAS LIFT; 2,543.9 SAFETY VLV; 2,026.5 CONDUCTOR; 36.0-116.0 XO TUBING; 42.0 HANGER; 37.7 HANGER; 35.2-39.6 KUP INJ KB-Grd (ft) 37.40 RR Date 10/18/198 5 Other Elev 3C-14B ... TD Act Btm (ftKB) 9,382.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292142502 Wellbore Status INJ Max Angle & MD Incl (°) 100.09 MD (ftKB) 8,579.59 WELLNAME WELLBORE3C-14B Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,172.1 5,686.7 7.56 5 GAS LIFT DMY BTM 1 0.0 11/30/2009 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 3,924.1 3,616.7 41.06 PACKER 5.730 5.5" X 7" LTP "CHP" LINER TOP HANGER, C-2 profile w/ 6.1' ext. Est 5.5" ID (Pkr 4.91" ID) - SEAL IS ONLY BETWEEN PROD CSG & LINER 4.910 6,335.3 5,847.2 13.41 PACKER 3.500 HR ZXP Liner Top Packer Baker Oil Tools 3.000 6,810.0 6,290.7 31.70 PACKER 2.740 BAKER KB PACKER 1.730 6,820.2 6,299.4 32.35 DEPLOY 2.630 DEPLOYMENT SLEEVE 2.250 8,245.0 6,543.9 83.23 DEPLOY 2.630 DEPLOYMENT SLEEVE 2.250 9,348.4 6,461.3 93.93 O-RING 2.375 O-RING SUB 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,789.0 6,803.0 6,272.7 6,284.7 C-1, 3C-14A 3/14/2008 6.0 IPERF SQUEEZED OFF 7/24/2009 6,953.0 7,773.0 6,401.7 6,493.6 UNIT B, A-5, A- 4, A-3, A-2, 3C- 14B 9/6/2009 32.0 SLOTS ALL B SIDETRACK SLOTS - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 8,117.0 8,244.0 6,519.7 6,543.8 A-5, A-4, A-3, 3C -14B 9/6/2009 32.0 SLOTS 8,246.0 9,348.0 6,544.1 6,461.3 A-3, 3C-14B 9/6/2009 32.0 SLOTS 3C-14B, 12/20/2022 10:01:25 AM Vertical schematic (actual) SLOTTED LINER B; 6,810.0- 9,382.0 LINER SHOE; 9,380.6-9,382.0 O-RING; 9,348.4-9,349.0 SLOTS; 8,246.0-9,348.0 DEPLOY; 8,245.0-8,245.8 LINER SHOE; 8,243.6-8,245.0 SLOTS; 8,117.0-8,244.0 SLOTS; 6,953.0-7,773.0 FISH; 7,000.0 LINER A 3.5"; 6,316.1-6,951.0 SHOE; 6,950.0-6,951.0 WINDOW B; 6,825.0-6,830.0 WHIPSTOCK; 6,825.2 DEPLOY; 6,820.2-6,826.6 PACKER; 6,810.0-6,820.2 IPERF; 6,789.0-6,803.0 PATCH; 6,781.0 PACKER; 6,777.0 LINER A 5.5"; 3,924.1-6,616.0 LINER FLOAT SHOE; 6,614.4- 6,616.0 LINER COLLAR; 6,529.6- 6,531.2 HANGER; 6,343.7-6,350.6 PACKER; 6,335.3-6,343.7 SEAL ASSY; 6,335.5 LOCATOR; 6,322.7 NIPPLE; 6,252.3 GAS LIFT; 6,172.1 GAS LIFT; 5,872.5 GAS LIFT; 5,082.3 PRODUCTION Post S/T; 33.0- 4,178.0 PACKER - PATCH - LWR; 4,081.5 GAS LIFT; 4,065.9 LEAK - GLM; 4,068.5 ANCHOR LATCH ON SPACER PIPE; 4,054.6 SURFACE; 35.2-4,060.5 FLOAT SHOE; 4,058.7-4,060.5 PACKER - PATCH - UPR; 4,051.0 FLOAT COLLAR; 3,978.7- 3,980.4 HANGER; 3,934.9-3,941.4 PACKER; 3,924.1-3,934.9 GAS LIFT; 2,543.9 SAFETY VLV; 2,026.5 CONDUCTOR; 36.0-116.0 XO TUBING; 42.0 HANGER; 37.7 HANGER; 35.2-39.6 KUP INJ 3C-14B ... WELLNAME WELLBORE3C-14B MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3C-14B KUPARUK RIV UNIT 3C-14B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2022 3C-14B 50-029-21425-02-00 209-061-0 W SPT 5847 2090610 1500 2740 2740 2740 2740 250 390 380 380 OTHER P Sully Sullivan 9/11/2022 MIT after tubing patch (Sundry 321-628), Baker seal assembly @5847' 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3C-14B Inspection Date: Tubing OA Packer Depth 600 1815 1745 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS220912143326 BBL Pumped:0.8 BBL Returned:0.8 Thursday, September 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 Þ 9 9 MIT after tubing patch James B. Regg Digitally signed by James B. 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Chris D (CED) To: AOGCC Records (CED sponsored) Subject: FW: KRU 3C-14B (PTD# 209-061) Date: Thursday, November 18, 2021 10:48:33 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, November 2, 2021 3:32 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Subject: KRU 3C-14B (PTD# 209-061) Chris— KRU injection well 3C-14B (PTD# 209-061) was reported by operations with TxIA communication while on water injection. The well has been shut-in and freeze -protected. DHD will perform routine diagnostics, including wellhead testing and an MITIA. Based on diagnostics we will formulate a path forward and submit Sundry paperwork as necessary. The well will remain shut-in until the issue can be resolved. Let me know if you have any questions or disagree with the plan. Travis Smith WINS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith(@conocophillips.com MEMORANDUM TO: Jim Regg P.I. Supervisor�i �� FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3C-14B Insp Num: mitBDB210821164947 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3C-14B KUPARUK RIV UNIT 3C-1413 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21425-02-00 Inspector Name: Brian Bixby Permit Number: 209-061-0 Inspection Date: 8/21/2021 Packer Well - 3ca4B - i Type Inj w TVD PTD1 2090610 Type Test) SPT Test psi j BBL Pumped: 1 ,'BBL Returned: Interval avRTST iP/j+ Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5847 Tubing 2910 2910 —' 2910 2910 1500 � IA 830 2000 1920 1910 1 OA 500 610 610 610 P Wednesday, August 25, 2021 Page I of'] 0 �J MEMORANDUM TO: Jim Regg 4� P.I. Supervisor <<t of z �i % FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 10, 2017 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. 3C-14B KUPARUK RIV UNIT 3C-1413 Src: Inspector Reviewed By: P.I. Supry 3 6,IZ- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3C-14B API Well Number 50-029-21425-02-00 Inspector Name: Chuck Scheve Permit Number: 209-061-0 Inspection Date: 8/3/2017 " Insp Num: mitCS170806084624 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well sC-14B Type Inj `��TVD 5847 Tubing 2950 2950 2950 - 2950PTD 2090610 Type Test SPTest psi 1500 IA 650 2000 1890 1890 BBL Pumped: 12 BBL Returned: I " OA 400 520 520 520 . _ — Interval 4YRTST _ P/F P Notes: SCANNED Fc _N Thursday, August 10, 2017 Page 1 of I RECEIVED 2_'0°\- oc 1 Originated: Schlumberger FEB 2 3 2017 PTS - PRINT CENTER 6411 A Street �"1O � �1 Anchorage, AK 99518 v (9117)273-1700 main (907) 273-4760 fax Delivered to: MakanaK Bender Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W Ave. Suite 100 Anchorage, AK 9950I TRANSMITTAL DATE TRANSMITTAL H DATA LOGGED 2 i2Ti201 M K.BENDE WELL NAME 1C-04 API # 50-029-20547-00 ORDERSERVICE # DDTF-00106 FIELD NAME KUPARUK RIVER DESCRIPTION WL DELIVERABLE . • PPROF .• I INAL FIELD j • ,' 16-Feb-17 1 • 1 1 R-21 50-029-22211-00 DDTF-00107 KUPARUK RIVER WL PPROF FINAL FIELD 17-Feb-17 1 1 3C-14B 50-029-21425-02 DDTF-00109 KUPARUK RIVER WL Caliper FINAL FIELD 19-Feb-17 1 1 3C-12 50-029-21354-00 DDTF-00110 KUPARUK RIVER WL [PROF FINAL FIELD 20-Feb-17 1 1 3C-12 50-029-21354-00 DDTF-00111 KUPARUK RIVER WL Caliper FINAL FIELD 21-Feb-17 1 1 3C-05 50-029-21389-00 DDTF-00112 KUPARUK RIVER WL Caliper FINAL FIELD 22-Feb-17 1 1 6 6 Transmittal Receipt Print Name A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Schlumberger. point. AI a s ka PTS P ri ntC e me r(@ s I b. c om SCANNED MAY 19 2017 SLB Auditor - MEMORANDUM l State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 16, 2013 TO: Jim Re P.I. Supervisor 1 `�jrt t �7 SUBJECT: Mechanical Integrity Tests [ CONOCOPHILLIPS ALASKA INC 3C-14B FROM: John Crisp KUPARUK RIV UNIT 3C-14B Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 5� - NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3C-14B API Well Number 50-029-21425-02-00 Inspector Name: John Crisp Permit Number: 209-061-0 Inspection Date: 8/9/2013 Insp Num' mitJCrl308l2101947 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell 3C-14B Type Inj w'TVD 5847 IA 430 1970 - 1880 T lsso TD 2090610 Type Test SPT Test psi 1500 OA 230 380 360— 360 — Interval 4YRTST P/F� P Tubing 2850 285� 50 2850 � Notes: 1.4 bbls pumped for test. SCA►HNED 0 C T 2 8 2014 Friday, August 16, 2013 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 9/21/2010 Permit to Drill 2090610 Well Name/No. KUPARUK RIV UNIT 3C-1413 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21425-02-00 MD 9382 TVD 6459 Completion Date 9/8/2009 Completion Status 1-OIL Current Status 1 WINJ / REQUIRED INFORMATION Mud Log No Samples No Directional Survey - N{ j Y "- % 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 meairrmi Number ,Name 5caie meaia No Start Stop CH Received Comments D C Lis 18951 Induction/Resistivity 6825 9385 Open 11/16/2009 MPR logs in EMF, CGm and PDF og Induction/Resistivity 2 Col 6825 9382 Open 11/16/2009 MD MPR, GR 'Cog Induction/Resistivity 5 Col 6825 9382 Open 11/16/2009 MD MPR, GR Log Induction/Resistivity 5 Col 6825 9382 Open 11/16/2009 TVD MPR, GR D C Lis 18952 t,*fnduction/Resistivity 6825 8084 Open 11/16/2009 P131 MPR logs in EMF, CGm and PDF og Induction/Resistivity 2 Col 6825 8084 Open 11/16/2009 P61 MD MPR, GR Grog Induction/Resistivity 5 Col 6825 8084 Open 11/16/2009 P131 MD MPR, GR o Induction/Resistivity 5 Col 6825 8084 Open 11/16/2009 PB1 TVD MPR, GR 7D C Lis 19314 &,fnduction/Resistivity 6825 8084 Open P61 MPR logs in EMF, CGm and PDF Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments 0 0 DATA SUBMITTAL COMPLIANCE REPORT 9/21 /2010 Permit to Drill 2090610 Well Name/No. KUPARUK RIV UNIT 3C-14B MD 9382 TVD 6459 ADDITIONAL INFORMATION Well Cored? Y Chips Received? X4-N-� Analysis —YC 4� Received? Comments: Compliance Reviewed By: Completion Date 9/8/2009 Operator CONOCOPHILLIPS ALASKA INC Completion Status 1-OIL Current Status 1WINJ Daily History Received? I(Y N Formation Tops N Date: API No. 50-029-21425-02-00 UIC Y ral 0 U vc0 l a se.,-,c� 61, <l//(,/0 Company ConocoPhillips, Alaska, Inc. Well Name 3C-14BPB1 Date 2/4/2010 iAF■r BAKER HUGHES ANTE( Page 1 of 4 i r MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I1Z-7�G DATE: Friday, January 22, 2010 P.I. Supervisor i Z i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA WC 3C-14B FROM: John Crisp KUPARUK RIV UNIT 3C-14B Petroleum Inspector Src: Inspector NON-CONFIDF,IIITI A i . Reviewed By: P.I. Supry Comm Well Name: KUPARUK RIV UNIT 3C-1413 Insp Num: mitJCrl00121084409 Rel Insp Num: API Well Number: 50-029-21425-02-00 Permit Number: 209-061-0 Inspector Name: John Crisp Inspection Date: 1/17/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3C-14B Type Inj. w ' TVD I 5847 IA 1 aoo I z000 �; —+ 1940 1 1930 P.T.D 2090610' TypeTest sPT Test psi 1s00 Qq 140 160 160 160 Interval INITAL P/F P Tubing i 2350 i 2350 2350 2350 Notes: 1.1 bbl pumped for test. 9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. operations Perrormed: Abandon r Repair well r Plug Perforations r Stimulate r Other r Prod to WINJ Alter Casing r Pull Tubing r? Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re-enter Suspended Well r 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r" Stratigraphic r Service r 209-061 3. Address: . API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-21425-02 7. Ptoperty Designation: 8. Well Name and Number: ` ADL 25634, 2567 3C-14B 9. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 9382 feet Plugs (measured) None true vertical 6459 feet Junk (measured) None Effective Depth measured 9380 feet Packer (measured) 3924, 6335 true vertical 6459 feet (true vertucal) 3616, 5847 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116 116 RECEIVED SURFACE 4025 9-5/8" 4061 3720 PRODUCTION 4145 7 4178 3808 BAN 2 1 2010 LINER A5.5" 2692 5-1/2" 6616 6116 LINER A 3.5" 635 3-1/2" 6951 6324 Make VIA & YM {10nYa blllMISiI0 Anchorage Perforation depth: Measured depth: 6789-6803; 6953-7773; 8117-8244; 9246-9348' True Vertical Depth: 6272-+285'; 6402-6494; 6520-6544; 6544-6461' Tubing (size, grade, MD, and TVD) 3.5, L-80, 6336 MD, 5847 TVD Packers & SSSV (type, MD, and TVD) PACKER - 5.5" X 7" LTP "CHP" @ 3924 MD and 361E TVD a,p Pfki Cw�iK` PACKER - HR ZXP Liner Top Packer 6335 MD and 5847 TVD 4+/ SSSV - 3.5" TRMAXX-5E SCSSV w/ 2.812" X Profile Ser.# HZS-028 @ 2026 MD and 2026 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mof Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 627 337 8 887 104 Subsequent to operation 2773 350 1871 13. Attachments . Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service oi Well Status after work: Oil r Gas r WDSPL r! Daily Report of Well Operations X GSTOR r WAG r GASINJ r WINJ 7o SPLUG r 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 309-407 Contact Bob Christensen/Darrell Humphrey Printed Name ob@dD._Qhristgnsen Title Production Engineering Specialist Signature Phone: 659-7535 Date ed '4_�J (9/ Form 10-404 Revised 7/2009 RQ©MS JAN 21 20I C-)� Submit Original Only .r 3C-14B DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/28/09 SET 2.75 CAT STANDING VALVE @ 6252' RKB. PULLED OV @ 6172' RKB. IN PROGRESS. 11/29/09 PULLED GLV'S AND SET DGLV'S @ 2544', 4066', 5082', AND 5872' RKB. LRS ON LOCATION FOR CIRC OUT. 11/30/09 SET DGLV @ 6172' RKB. MITIA IA TO 2500 PSI ( PASSED ). PULLED CAT @ 6252' RKB. JOB COMPLETE. 12/11/09 1 Commenced Water Injection Service KUP a 3C-14B ConocoPhillips Alaska. Inc. W.JICon-3C-14B 1/16710101:18:58 PM Schemelk - Pctuai HANGER. 35 XO TUBING, 42 CONDUCTOR, W-115 SSSV. 2.026 0 GAS LIFT, 2,544 SURFACE, 35-4,061 GAS LIFT, 4,06E PRODUCTION, 331,178 GAS LIFT, 5.082 GAS LIFT, 5,873 GAS LIFT, 6,172 NIPPLE, 6,252 LOCATOR, -- 6,323 SEAL ASSY. 6,336 LINER A 5.5, 3,924-6,611i PACKER. 6.777 PATCH, 6,781 IPERF, 5.739-a.803 WHIPSTOCK, 6,825 WINDOW B. 6,8258,830 LINER A 35', 8.3168,951 FISH. TWO SLOTS, 6.953-7,173 TO (3C-148), 8,084 SLOTS, 8,117-8,244 SLOTS tl 146-9 34B SLOTTED LINER B. 8, 810-9,382 Well Attributes Max Angle & MD TD Well6ore APIIUWI Flald Name Well Status 500292142502 LidRIVER UNIT PROD I"I (') MD (RKB) 100.09 8,579.59 Act Stan (RKB) 9,382.0 Comment H2S (,pm) Date SSSV: TRDP 130 12/312008 Annoation Last WO: End Date KB-Grtl (R) 37.40 Rlg Ralaaae Data 10/18/1985 Annotation Daplh Last Tag: (RKB) End Date Annotation Rev Reason: LINER SET DEPTH UPDATE Last Motl By n1894 Entl Date 1/16/2010 Casing Strings Casing Description CONDUCTOR String 0... 16 String 10 ... 15.062 Top (RKB) Set 36.0 Depth (t... Set 116.0 Depth (TVO) ... String 116.0 W.. i. 62.50 String... H-40 String Top Thrd Casing Descrlptlon SURFACE String 0... 95/8 Stnng ID ... 8.765 Top (RKB) Set 35.2 Depth If... Set 4,060.5 Depth (TVD) ... String 3,720.0 Wit 36.00 String ... J-55 String Top Thrd Casing Description PRODUCTION String 0... 7 String ID ... 6.151 Top (RKB) Set 33.0 Depth (F... Set 4,178.0 Depth (TVD) ... String 3,808.3 Wit 26.00 string ... J-55 String Top Thrd Casing Description LINER A 5.5" String 0... 5 12 String ID ... 4.850 Top (RKB) Set 3,924.1 Depth (f... Set 6,616.0 Depth (TVD) ... String 6,115.9 Wt... 15.50 String ... L-80 String Top Thrd Hydril 511 Liner Details Top (RKB) Top Depth (TVD) (KKB) Top Inc. (') Item Description Comment Noml... ID (In) 3,924.1 3,616.4 40.46 PACKER 5.5" X 7" LTP "CHP" C-2 profile w/ 6.1' ext. Est 5.5" ID (Pkt 4.91" ID) - SEAL IS ONLY BETWEEN PROD CSG & LINER 4.910 3,934.9 3,624.6 40.48 HANGER HMC liner hanger - 5.5" Vam p X p (4.96" Io) 4.960 6,529.6 6,034.2 17.79 COLLAR 5.5 " Weatherford 403 Float Collar 4.850 Casing GascHptlon WINDOW B String 0... 4 string to ... 3.000 Top IRKS) Set 6.825.0 Depth (C.. last 6,830.0 Depth (TVD) ... Slring 6,307.1 Wt... String ... String Top Thrd Casing Descrlptlon LINER A 3.5" Siring D... 3 12 String ID ... 2.992 Top (KKS) Set 6,316.1 Depth (1... S.t 6,951.0 Depth (TVD) ... String 6,400.2 Wt... 9.20 string ... L-80 string Top Thrd Hydril 511 Liner Details Top (RKB) Top Depth (TVD) (RKB) Top Inc, V) It.. Description Comment Nom1... ID (in) 6,316.1 5,828.4 13.01 SBE ZXP Seal Bore Extension 4.130 0,335.3 5.847.2 13.50 PACKER HR ZXP Liner Top Packer 3.000 6,343.7 5,855.4 13.71 HANGER HMC Liner Hanger 2.920 Catalog D..."ption String.. ng 0. String ID ... Top (RKB) Sat Depth it... Set Depth (TVD) ... String Wt... Slring ... String Top Thrd SLOTTED LINER B 2 3/8 1.992 6,810.0 9,382.0 4.60 L-79 Liner Details Top RKB Top Depth (TVD) (KKS) Top Inc. V) Item Descrlptlon Comment Nomi... 10 (in) 6,810.0 6,290.6 30.91 PACKER BAKER KB PACKER 1.730 6,820.2 5,299.4 32.35 DEPLOY DEPLOYMENT SLEEVE 2.250 8,245.0 5.543.9 83.23 DEPLOY DEPLOYMENT SLEEVE 2.250 9.348.4 6,461.3 93.93 O-RING O-RING SUB 1.000 Tubing Strings Tubing Description String 0... String 10 ... Top (RKB) Set Depth If... Set Depth (TVD) ... String W1t String ... Slring Top Thrd TUBING 31/2 2.992 37.7 6,341.0 5,852.8 9.30 L-80 IBTM Cori tion Details Top (RKB) Top D.Pth (TVD) (RKB) Top Ind (') Item Description Comment Noml... to (in) 37.7 37.7 -0.01 HANGER CIW Gen 4, Type N-FBB, "H" BPV profios, P/N 156156-01-01-01 2.992 2,026.5 2,026.2 5.09 SSSV 3.5" TRMAXX-5E SCSSV wl 2.812' X Profile Ser.# HZS-028 2.812 6,252.3 5,766.0 10.04 NIPPLE 3-12" x 2.750" Cameo "D' Nipple (EUE Brd) 2.750' No -Go Profile 2.750 6,322.7 5,834.9 13.18 LOCATOR Baker Locator Coupling (4.40' O.D.) 2.990 6,335.5 5,847.4 13.50 SEAL ASSY Baker Bullet Seal Assembly (O.D. 4.125") 2,990 Other In Hole Wireline retrievable plugs, valves pumps, fish etc. Top (KKB) Top Depth (TVD) (KKB) Top Inc. (') Description Comment Run Date ID (In) 6.777 6,262.3 29.65 PACKER 35 KB LINER TOP PACKER 9/142009 1.860 6,781 6,265.8 29.90 PATCH BAKER SPACER PIPE, SEAL ASSY 9/142009 1.690 6,825 6,303.0 33.29 WHIPSTOCK 2.625- OD BAKER MONOBORE WHIPSTOCK 8.74" OAL, 7132009 .875" FLUID PASS ID: 7.3.2009 WSR FOR DETAILS 0.000 7,000 6,432.6 51.14 FISH 3 ANCHORS FROM 35 KB PACKER, 2 1/8"x1.33'x12" 9/102009 THICK 0.000 Perforations & Slots Top (RKS) at. (RKS) Top (TVD) 1 (RKB) Elm (TVD) (RKB) Z.- Data Shot Gans (sh... Type Comment 6,789 6,8031 6,271.8 6.284.5 C-1, 3C-14A 3/142008 6.0 IPERF SQUEEZED OFF 7242009 6,953 7,773 6,401.6 6,493.E 9162009 32.0 SLOTS ALL 0.125'x2.5" adjacent 18 B SIDETRACK SLOTS - @ 4 circumferential rows, 3" centers staggered deg, 3' non -slotted ends 8,117 8,244 8,519.6 6,543.8 9/62009 32.0 SLOTS 8,246 9,34E 6,544,0 6,461.3 9/62009 32.0 SLOTS Notes: General & Safety End Data A, Iltl.n W22200B NOTE: VIEW SCHEMATIC w/Alaska SchematiC9.0 9/92009 NOTE: SIDETRACK B DRILLED Mandrel Details Stn Top Depth (TVD) Top (KKS) (KKB) Top Ind (") Make Model OD (in) Sary Vat- Type Latch Type Port at- TRID (in) Run (P61) Run Data Co.... 1 2,543.9 2,521.0 23.11 Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11292009 2 4,065.9 3.724.1 40.77 Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11292009 3 5,082.3 4,605.8 9.61 Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11292009 4 5,872.5 5,389.0 6.57 Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11292009 5 6,172.1 5,686.7 7.5E Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11/302009 # Page 1 of 3 P-1-6 --&,I-0(f Regg, James B (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com] �� r'►+(I n Sent: Monday, January 11, 2010 11:34 AM To: NSK Problem Well Supv; Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MIT Report 3C-14B All- the schematic has been scheduled for updating and as soon as it's complete we will resubmit this sundry Thanks for catching this error. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) From: NSK Problem Well Supv Sent: Monday, January 11, 2010 9:53 AM To: NSK Prod Engr Specialist Subject: FW: MIT Report 3C-1413 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, January 11, 2010 9:50 AM To: NSK Problem Well Supv Cc: Brooks, Phoebe L (DOA) Subject: RE: MIT Report 3C-14B kINTi� CPAI will need to resubmit the 10-404 for the work completed under sundry 309-407 with correct well schematic and correct Packer TVD. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (DOA) Sent: Monday, January 11, 2010 7:31 AM To: Regg, James B (DOA) Subject: FW: MIT Report 3C-14B Phoebe Brooks f 1/11/2010 0 Page 2 of 3 Statistical Technician II Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax:907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Sunday, January 10, 2010 10:25 AM To: Brooks, Phoebe L (DOA) Subject: RE: MIT Report 3C-146 I found an error on the completion schematic that showed the Baker HR ZXP Liner Top Packer at 6235' MD (5749' TVD) instead of 6335' MD (5847' TVD) corresponding to the the adjacent hardware and the 3-1/2" liner detail. I have corrected the schematic to be consistent with the 5847' TVD on the MIT form. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Friday, January 08, 2010 8:43 AM To: NSK Problem Well Supv Subject: FW: MIT Report 3C-1413 Martin, I had a chance to review this report and noticed that the PKTVD of 5847 does not match up with the PKTVD we have in our system of 5749 (based upon sundry 309-407); can you please clarify? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax:907-276-7542 From: Brooks, Phoebe L (DOA) Sent: Thursday, January 07, 2010 2:50 PM To: 'NSK Problem Well Supv' Subject: RE: MIT Report 3C-14B You are correct, thank you Martin. Phoebe Brooks 1/11/2010 0 0 Page 3 of 3 Statistical Technician II Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax:907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Thursday, January 07, 2010 2:47 PM To: Brooks, Phoebe L (DOA) Subject: RE: MIT Report 3C-14B Attached is the requested report. I think you may be referring to 3C-14B considering the well name, records, and PTD#. The well is on our schedule to have a witnessed test in the near future. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Thursday, January 07, 2010 12:52 PM To: NSK Problem Well Supv Subject: MIT Report 2C-14B Brent, We were looking at a sundry for well 2C-1413 (PTD #2090610) that mentioned a pre injection MIT completed on 11/30/09 which we don't seem to have a copy of; can you please send this report? Thank you, Phoebe Phoebe Brooks Statistical Technician 11 Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax:907-276-7542 1/11/2010 Mot Page 1 of 2 Regg, James B (DOA) From: Brooks, Phoebe L (DOA) )� e 1 Sent: Thursday, January 07, 2010 2:59 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA) Subject: FW: MIT Report 3C--14B Attachments: MIT KRU 3C-14B 11-30-09.xls Attached is the MIT report Steve McMains asked about. Phoebe Brooks Statistical Technician I1 Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax:907-276-7542 From: NSK Problem Well Supv[ma i[to:n1617@conocophillips. com] Sent: Thursday, January 07, 2010 2:47 PM To: Brooks, Phoebe L (DOA) Subject: RE: MIT Report 3C-14B Attached is the requested report. I think you may be referring to 3C-146 considering the well name, records, and PTD#. The well is on our schedule to have a witnessed test in the near future. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Thursday, January 07, 2010 12:52 PM To: NSK Problem Well Supv Subject: MIT Report 2C-1413 Brent, We were looking at a sundry for well 2C-14B (PTD #2090610) that mentioned a pre injection MIT completed on 11/30/09 which we don't seem to have a copy of; can you please send this report? Thank you, Phoebe � ail 1/8/2010 0o 0 0 Page 2 of 2 Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax:907-276-7542 1/8/2010 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.Fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov Email to:guy.schwartz@alaska.gov OPERATOR: ConocoPhillips Alaska Inc.��° i� FIELD / UNIT / PAD: Kuparuk / KRU / 3C DATE: 11 /30/09 OPERATOR REP: Zemba - HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 3C-146 Type Inj. W TVD 1 5,847 Tubing 8501 9001 900 900 Interval O P.T.D. 2090610 f T pe test I P Test psi 1 1500 Casing 500 2,500 2,500 P/F P Notes: Post Injector Conversion Non -Witnessed MITIA OA 801 801 80---80-F— Welli I Type Inj. I I TVD I Tubing I Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F I Notes: OA EEJ I Weill Type Inj. TVD Tubing Interval P.T.D. Type test Test psi I Casing I P/F Notes: OA Well I Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing I P/F Notes: 0AJ TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 3C-146 11-30-09 (2).xls i STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r r, " �p�p�� 18IS8 01s o�to Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension , WINJSI_ Change Approved Program r Operat. Shutdown r Perforate ❑ Re-enter Suspended Well r 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: ConocoPhillips Alaska, Inc. Development -1 Exploratory r Stratigraphic r Service r{ 209-061 3. Address: API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21425-02 7. Property Designation: . Well Name and Number: ADL 25634, 2567 3C-14B 9. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 9382 feet Plugs (measured) None true vertical 6459 feet Junk (measured) None Effective Depth measured 6459 feet Packer (measured) 6335.51, 6777 true vertical 9380 feet (true vertucal) 5847.39, 6262.31 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16" 116 116 0 0 SURFACE 4025 9-5/8" 4061 3720 0 0 PRODUCTION 4145 7" 4178 3808 0 0 LINER A 5.5" 2692 5-1/2" 6616 6116 0 0 LINER A3.5" 635 3-1/2" 6851 6325 0 0 Perforation depth: Measured depth: 6789-6803; 6953-7773'; 8117-8244'; 8246-9348' V (— True Vertical Depth: 6272-6285; 6402-6494'; 6520-6544'; 6544-6461' ale L Tubing (size, grade, MD, and TVD) 3.5, L-80, 6341 MD, 5847.39 TVD Packers & SSSV (type, MD, and TVD) PACKER - 5.5" X 7" LTP "CHP", MD= 3924 = 3616 Tvf' P1QcKE� PACKER - HR ZXP LINER TOP PKR, D= 6235 TVD= 5749 SSSV - TRMAXX-5E @ 2026.47 MD and 2026.19 TVD 11. Stimulation or cement squeeze summary: w r ° "1 P'`' Intervals treated (measured): Treatment descriptions including volumes used and final pressure: / L/ 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 627 337 8 887 104 Subsequent to operation 2773 350 1871 13. Attachments . Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development ❑ Service ry Well Status after work: Oil r Gas r WDSPIL Daily Report of Well Operations X rGSTOR r WAG ❑ GASINJ r VVINJ Lv7o SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 309-407 Contact Bob Christensen/Darrell Humphrey Printed Name obey D. Chri nsen Title Production Engineering Specialist Signature Phone: 659-7535 Date ®� Form 10-404 Revised 7/2009 RBDMS JAN " s � /. 7. /o Submit Original Only 3C-14B DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/28/09 SET 2.75 CAT STANDING VALVE @ 6252' RKB. PULLED OV @ 6172' RKB. IN PROGRESS. 11/29/09 PULLED GLV'S AND SET DGLV'S @ 2544', 4066', 5082', AND 5872' RKB. LRS ON LOCATION FOR CIRC OUT. 11/30/09 SET DGLV @ 6172' RKB. MITIA IA TO 2500 PSI ( PASSED ). PULLED CAT @ 6252' RKB. JOB COMPLETE. 12/11/09 1 Commenced Water Injection Service KUP • 3C-14B ConocoPhillips 1 Alaska. 4K;. Wall Conf,-3C-14B 12n 20097:50:4 matic- 1 HANGER, 38 XO TUBING, 42 CONDUCTOR, 36-116 SSSV, 2,026 GAS LIFT, 2,544 SURFACE, 35-4.061 GAS LIFT, 4.066 PRODUCTION, 334.178 GAS LIFT, 6082 GAS LIFT, 5,873 GAS LIFT, 6,172 NIPPLE, 6,252 - j- LOCATOR, 6,323 SEAL ASSY, 6,33E LINER A 5.5', 3, 924-6.616 PACKER, 8,777 PATCH, 6,781 IPERF, 6,789-6,803 WHIPSTOCK, 6,825 WINDOWS, 6.82M 830 LINER A 3.5', 621641,B5i FISH, 1.000 SLOTS, 6.9537,773 To(3C-14B), 8,084 SLOTS, 8,117-8,244 SLOTS, 6-9,348 8,21SLOTS. O SLOTTED LINER B, 6,810-9,382 wVecoreAAHPuubwl�s Max A Mo rc& MD Fleltl Name Weli Statue 500292142502 KUPARUK RIVER UNIT PROD 100.09 8,579.59 ATcD tm (RKe) 9,382.0 Comment HIS Ippm) SSSV: TRDP 130 Dab 12/31/2008 Annotation Last WO: End Deb K81iM IR) 37.40 Rig Release Data 10/1&1985 Annotation Last Tag: Depth (ftKB) End Dab AnnoteIII- Laet Rev Reason: GLV C/O, PULL PLUG Mod ... Imosbor End Date 12/1/2009 Casing Strings Casing Description CONDUCTOR String 0... 16 String ID ... 15.062 Top (RKB) Set 36.0 Depth if... 116.0 Set Depth (TVD) ... 116.0 String Wt... String 62.50 H-40 ... String Top Thrd '.sing Description SURFACE String 0... 95(8 String ID ... 8.765 Top (RKS) Set 35.2 Depth (f... 4,060.5 Set Depth (TVD) ... 3,720.0 String Wt... String 36.00 J-55 ... String Top Thrd Casing Description PRODUCTION String 0... 7 String ID ... 6.151 Top [NKB) Set 33.0 Depth (f... 4,178.0 Set Depth (TVD) ... 3,808.3 String Wit String 26.00 J55 ... String Top Thrd Casing Description LINERA5.5" String 0... 51/2 String 10 ... 4.850 Top (RKB) Set 3,924.1 Depth It- 6,616.0 Set Depth (TVD) ... 6,115.9 String Wt String... 15.50 L-80 String Top Thri Hydnl 511 Liner Details Top (ttKB) Top Depth (TVD) (RKB) Top Inc1 (1 Item Description Comment Noml... ID (In) 3,924.1 3,616.4 40.46 PACKER 5.5" X 7" LTP "CHP" C-2 profile w/ 6.1' ext. Est 5.5" ID (Pkr 4.91" ID) - SEAL IS ONLY BETWEEN PROD CSG & LINER 4.910 3,934.9 3,624.6 40.48 HANGER HMC liner Ranger- 5.5" Vam p X p (4.96" ID) 4.960 6.529.6 6,034.2 17.79 COLLAR 5.5" Weatherford 403 Float Collar 4.850 Casing Description WINDOW B String 0... 4 String ID .,. 3.000 Top (Itlt13 Set 6,825.)0 Depth If... Set 6,8:0 Depth (TVD) ... 6,307.1 String Wi... String - String Top Thrd Casing Description LINERA3.5" String 0... 3112 String w ... 2.992 Top (nKB) Set 6,216.1 Depth if... Set 6851.0 Depth (TVD) ... 6,324.8 String Wt... String 9.20 L-80 ... String Top Thrd Hydd1511 Liner Details To (Po(B) Top Depth (TVD) (RKB) Top Incl V) Item Description Comment Noml... ID (in) 6,216.1 5,730.1 8.37 SBE ZXP Seal Bore Extension 4.130 6,235.3 5,749.2 9.25 PACKER HR ZXP Liner Top Packer 3.000 6,243.7 5,757.5 9.64 HANGER HMC Liner Hanger 2.920 6,754.0 6,242.3 28.74 COLLAR Baker 3-1/2 Type I Landing Collar 2.880 Casing Description String 0... Siring ID _. Top 1Po(B) Set Depth 1f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SLOTTED LINER B 2 3/8 1.992 6,810.0 9,382.0 4.60 L-79 Liner Details Top (RKB) Top Depth (TVD) (RKB) Top Incl (") Item Description Comment Nom1... ID (In) 6,810.0 6,290.6 30.91 PACKER BAKER KB PACKER 1.730 6,820.2 6,299.4 32.35 DEPLOY DEPLOYMENT SLEEVE 2,250 8,245.0 6,543.9 83.23 DEPLOY DEPLOYMENT SLEEVE 2.250 9,348.4 6,461.3 93.93 O-RING O-RING SUB 1.000 Tubing Strings Tubing Descripton String 0... String ID ... Top (ftKB) Set Depth if... Set Depth (TVD)... String Wt String ... String Top Thrtl TUBING 31/2 2.992 37.7 6,341.0 5,852.8 9.30 L-80 IBTM Completion Details Top (RKB) Top Depth (TVD) (RI(B) Top Incl (") Item Description Comment Noml... ID (In) 37.7 37.7 -0.01 HANGER CIW Gen 4, Type N-FBB, "H" BPV profice, PIN 156156-01-01-01 2.992 2,026.5 2,026.2 5.09 SSSV 3.5" TRMA)OXSE SCSSV W/ 2.812" X Profile Ser.# HZS-028 2.812 6,252.3 5,766.0 10.04 NIPPLE 3-1/2" x 2.750"Camco "D" Nipple (EUE 8rd) 2.750" No -Go Profile 2.750 6,322.7 5,834.9 13.18 LOCATOR Baker Locator Coupling (4.40" O.D.) 2.990 6,335.5 5,847.4 13.50 SEAL ASSY I Baker Bullet Seal Assembly (O.D. 4.125") 2.990 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc. Top (RKB) Top Depth (TVD) (B) Top Incl (") Description Comment Run Dab ID (In) 6,777 6,262.31 29.65 PACKER 35 KB LINER TOP PACKER 9/14/2009 1.860 6,781 6,265.8 29.90 PATCH BAKER SPACER PIPE, SEAL ASSY 9/14/2009 1.690 6,825 6,303.0 33.29 WHIPSTOCK 2.625" OD BAKER MONOBORE WHIPSTOCK 8.74" OAL, .875" FLUID PASS ID: 7.3.2009 WSR FOR DETAILS 7/3/2009 0.000 TON 6,432.6 51.14 FISH 3 ANCHORS FROM 35 KB PACKER, 2 1/8"x1.33"x1/2" THICK 9/10/2009 0.000 Perforations & Slots Top(i Btm(RKe) Top (TVD) (RKB) Btm (TVD) (RKB) Zone Data Shot Dane (ah-, Tye Comment 6,789 6,803 6,271.8 6,284.5 C-1, 3C-14A 3(14/2008 6.0 IPERF SQUEEZED OFF 7/24/2009 6,953 7,773 6,401.6 6,493.6 9/6/2009 32.0 SLOTS ALL B SIDETRACK SLOTS - 0.125')Q.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' ran -slotted ends 8,117 8,244 6,519.E 6,543.8 1 9/6/2009 32.0 SLOTS 8,2461 9,3481 6,544.01 6,461.3 9/6/2009 1 32.0 SLOTS Mandrel Details Stn Top (TVD) Top(RKB) (RKB) Depth Top I -I (") Make Model OD (In) Be- Val- Type latch Type Port Size (in) TRO Run (psi) Run Dab Com... 1 2,543.9 2,521.0 23.11 Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11/29/2009 2 4,065.9 3,724.1 40.77 Carrico KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11/29/2009 3 5,082.3 4,605.8 9.61 Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11/29/2009 4 5,872.5 5.389.0 6.57 Camco KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11/29/2009 5 6,172.1 5.686.7 7.5E Cameo KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 11/30/2009 KUP 3C-14B ConocoPhillips 37.40 1 10/18/1985 HANGER, 38 (O TUBING, 42 CONDUCTOR, 36-116 SSSV, 2.028 GAS LIFT, 2,544 SURFACE, 35-4.061 GAS LIFT, PRODUCTION, 33-4,178 GAS LIFT, 5.052 GAS LIFT, 5,873 GAS LIFT, NIPPLE. 6. 252 LOCATOR, 6,323 SEAL ASSY, 6,3M LINER A55', 3 924-6 616 PACKER,5777 PATCH, 6,781 IPERF, 5.789-8.803 WHIPSTOCK, 6,825 WINDOWS INDOWB 6,625-6,830 LINER A35', 6, 2150,851 FISH, 7,000 SLOTS, S.953.7,773 TO(3C-14S). 8,084 SLOTS, 6117A,244 SLOTS, a.248$34S SLOTTED LINER B. 6,8109,382 SEAN PARNELL, GOVERNOR ��+ 3 AIIASSA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 a FAX (907) 276-7542 Mr. Darrell R. Humphrey Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Of Re: Kuparuk River Field, Kuparuk River Pool, 3C-14B Sundry Number: 309-407 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 11� Daniel T. Seamount, Jr. Chair DATED this l d day of December, 2009 Encl. FENCED I STATE OFALASKA DEC Q 8 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALAIaska Ail & G&3 Cons. Commission 20 AAC 25.280 . Anchorage 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other Q Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program ❑ Pull Tubing ❑ Perforate New Pool ElRe-enter Plod to Inj Suspended Well El f 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development Q Stratigraphic ❑ Exploratory ❑ Service ❑ 209-061 ' 3. Address: 6. API Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-21425-02 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number ownership or landownership changes: Spacing Exception Required? Yes No ❑✓ 3C-14B 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25634/ 2567 RKB 88' Kuparuk River Field / Kuparuk River Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft) Effective Depth MD (it): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9382' 6459' - 9380' 6459' None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 116, 116' SURFACE 4023 9-5/8" 4061' 3720' PRODUCTION 4145' 7" 4178' 3808' LINER A 5.5" 2692 5-1/2" 6616' 6116' LINER A 3.5" 635' 3.5" 6851' 6324' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6789'-6803,6953'-7773',8117'-8244',8 6272'-6284',6402'-6494',6520'-6543',6544'-6461' 3.5 L-80 6341' Packers and SSSV Type: Packers and SSSV MD (ft) 5.5" x 7" LTP CHP, HR ZXP, BAKER KB 3924', 6235', 6810' TRMAXX-5E SCSSV 2026' 13. Attachments: Description Summary of Proposal ✓❑ 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December 1, 2009 Oil El WAG ❑ Gas ❑ GINJ ❑ Plugged ❑ Abandoned El WINJ ❑✓ WDSPL ❑ 17. Verbal Approval: Date: Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: B. Christensen/ D. Humphrey Printed Name Darrell R. Hum re Title: Production Engineering Specialist Signature Phone: 659-7535 Date Co mission Use Only Sundry Numb r. Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other. wi � h e SS cX M I T l A a- P4, r s 4'C.6 i li z e �(t Subsequent Form Required: / a Y 0 A-1 APPROVED BY / 0/o 21/ Approved by: COMMISSIONER THE COMMISSION Date: i ORIGINAL �gbns Bali l�hi Form 10-403 Revised 06/2006 Submit in Duplicate i 3C-14B DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. Kuparuk Well 3C-14B (PTD 209-061) Sundry Notice 10-403 Request November 24 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to change the service of 3C-14B from production to water injection. History (if needed): 3C-14B was a injection well, then switched to production for a short period of time and now we would like to switch it back to injection service. Proposed Plan: The proposed plan includes: Make surface piping modifications for injection service (complete) Pull live gas lift valves and run dummy gas lift valves MITIA to 2500 psi Place on injection A_N& KUP Affil, 3C-14B ConocoPhillips Well AttributesMax Angle & MD TD Alaska Inc Walloons API/UWI FleldName WeII3faNs 500292142502 KUPARUK RIVER UNIT PRODUCING Incln MO INKS) 100.09 8,579.59 Act dim (RKB) 9,382.0 Comment M23 (ppm) Defa Annotation End Dab KB-Grtl (R) Rig Release Date SSSV': TRDP 130 12/31/2008 Last WO: 37.40 10/18/1985 Wall Confi - S:S/:3i AM I Annotaticm Depth Last l-ag: (ftKB) Entl Dale Annotallon Rev Reason: GLV C/O, PULL( SV Laat MoO ... Imosbor Entl Date 10/2/2009 Casino Strings Casing Oeacription String 0... String ID ... Top (ftKS) Set Depth If... Set Depth (TVD) ... Siring Wt... String ... String Top Third CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H-40 Casing Description String 0... String ID ... Top (RKB) Set Depth if... Set Depth (TVD) �� Strong Wt... String... String Top Third HANGER, 38 SURFACE 9 5/8 8.765 35.2 4,060.5 3,720.0 36.00 J-55 Casing Description String 0... String ID ... Top (RK8) Set Depth if... Set Depth (TVD) ... String Wt.. String ... String Top Third PRODUCTION 7 6.151 33.0 4,178.0 3,808.3 26.00 J-55 xO TUBING, 42 Casing Description String 0... Slring ID ... Top (RKB) Set Depth If... Set Depth (TVD) _. String Wt.. String ... Strong Top Thrtl CONDUCTOR, LINERA5.5" 51/2 4.850 3,924.1 6,616.0 6,115.9 15.50 L-80 Hyddl 511 Liner Details w18 Top Depth SSSV, 2,028 (TVD) Top Incl Top (RKB) (RKB) (") It.. Description Comment ID (In) 3,924.1 3,616.4 40.4E PACKER 5.5" X 7" LTP "CHP" C-2 profile w/ 6.1' ext. Est 5.5" ID (Pitt 4.91" ID) - 4.915 GAS LIFT, 2.544 SEAL IS ONLY BETWEEN PROD CSG & LINER 3,934.9 3,624.6 40.48 HANGER HMC liner hanger - 5.5" Vent p X p (4.96" ID) 4.960 6,529.6 6,034.2 17.79 COLLAR 5.5 " Weatherford 403 Float Collar 4.850 Casing Description String 0... 10 ... Top (RKB) Set Depth If... Set Depth (TVD) ... String Wt... Strong ... Top Thrtl WINDOW 8 4 lathing 3.000 6,825.0 6.830.0 6,307.1 lathing Casing Description String 0... Strong ID ... Top (RKB) Set Depth If... Set Depth (TVD) ... String Wt.. String ... String Top ThM SURFACE, LINER A 3.5" 3 1/2 2.992 6,216.1 6,851.0 6,324.8 9.20 L-80 Hydril 511 Liner Details 35.4,0611 Top Depth GAS LIFT, 4,06E (TVD) Top Incl Top (RKB) (RKB) (") Item Description Comment ID (in) 6,216.1 5,730.1 8.37 SBE ZXP Seal Bore Extension 4.130 PRODUCTION, 33-4,178 6,235.3 5,749.2 9.25 PACKER HR ZXP Loner Top Packer 3.6W GAS LIFT, 5,OB2 6,243.7 5,757.5 9.64 HANGER HMC Liner Hanger 2.920 6,754.0 6,242.3 28.74 COLLAR Baker 3-1/2 Type I Landing Collar 2.880 GAS LIFT, 5,873 Caaing DescripBon String 0... Strong ID ... Top (RKB) Set Depth If... Set Depth (TVD) ... String Wt... String ... Strong Top ThM SLOTTED LINER 8 2 3/8 1.992 6,810.0 9,382.0 4.60 L-79 Liner Details GAS LIFT, 8,172 Top Depth (TVD) Top lna Top (RKB) (RKB) (") Item Description Comment ID (In) 6,810.0 6,290.6 30.91 PACKER BAKER KB PACKER 1.730 6,820.2 6,299.4 32.35 DEPLOY DEPLOYMENT SLEEVE 2.250 8,245.0 6,543.9 83.23 DEPLOY DEPLOYMENT SLEEVE 2.250 9,348.4 6,461.3 93.93 O-RING O-RING SUB 1.000 NIPPLE, 6,252 t TubingStrings Tubing Description String 0... String ID ... Top (RK8) Set Depth If... Set Depth (TVD) ... String Wt... String ... String Top Thrtl LocATOR, TUBING 3112 2.992 37.7 6,341.0 5,852.8 9.30 L-80 IBTM Completion Details 6,323 Top Depth SEAL A55Y, 6,336 (TVD) Top Incl I Top 1fB(8) (RKB) (") Item Description Comment 10 (in) 37.7 37.7 -0.01 HANGER CIW Gen 4, Type N-FBB, "W BPV profice, P/N 156156-01-01-01 2.992 2,026.5 2,026.2 5.09 SSSV 3.5" TRMAXX-5E SCSSV W/ 2.812" X Profile Ser.# HZS-028 2.812 6.252.3 5,766.0 10.04 NIPPLE 3.1/2" x 2.750" Cameo "D" Nipple (EUE 8rd) 2.750" No -Go Profile 2.750 6,322.7 5.834.9 13.18 LOCATOR Baker Locator Coupling (4.40" O.D.) 2.990 LINER ,615 3,9248,8[B 6,335.5 5,847.4 13.50 SEAL ASSY Baker Bullet Seal Assembly (O.D. 4.125") 2.990 Other In Hole Wireline retrlevable plugs, valves pumps, fish etc. Top Depth (TVD) Top Inc. PACKER, 6,777 Top(ftKB) IRKS) P) Description Comment Run Dale to (in) 6,777 6,262.3 29.65 PACKER 35 KB LINER TOP PACKER 9/14/2009 1.860 6,781 6,265.8 29.90 PATCH BAKER SPACER PIPE, SEAL ASSY 9/14/2009 1.690 PATCH, 6,761 IPERF, 6,825 6,303.0 33.29 WHIPSTOCK 2.625' OD BAKER MONOBORE WHIPSTOCK 8.74" OAL, 7/3/2009 .875" FLUID PASS ID: 7.3.2009 WSR FOR DETAILS 0.000 6, 789-5,803 7,000 6,432.E 51.14 FISH 3 ANCHORS FROM 35 KB PACKER, 2 1/8"x1.33"x1/2" 9f10/2009 0.000 THICK Perforations & Slots Shot WHIPSTOCK 6825 WINDOW B, Top (RKB) Btm (RKB) Top (TVD) I�BI Bt(f (TVD) l�Bl Zone Data Dens I.h... Type Comment 6,789 6,8031 6,271.8 6,284.5 C-1, 3C-14A 3114/2008 6.0 IPERF SQUEEZED OFF 7/24/2009 6,925 6,83 6,953 7,773 6,401.6 6,493.6 9/6/2009 32.0 SLOTS ALL B SIDETRACK SLOTS - 0.125' x2.5" @ 4 circumferential LINER A35', 6.2e51 adjacent rows, 3" centers staggered 18 deg, Trion -slotted ends FISH. 8,244 6,519.E 6,543.8 9/6/2009 32.0 SLOTS TWO8,117 SLOTS, 8,246 9,348 6,544.01 6,461.3 9/6/2009 32.0 SLOTS 8,953-7,773 Mandrel Details To(3C-14B), Top Depth Top Port 8, D84 (TVD) Incl OD Val- Latch SILO TRO Run SLOTS, Sin Top IRKB) (RKS) (1 Make Model (In) Sery Type Type (In) (Pei) Run Date Com- 1 2,543.9 2.521.0 23.11 Cameo KBG-2-9 1 GAS LIFT GLV BTM 0.15E 1,352.0 9/26/2009 8,T17-8,244 2 4,065.9 3,724.1 40.77 Cameo KBG-2-9 1 GAS LIFT GLV BTM 0.15E 1,341.0 9/25/2009 3 5,082.3 4,605.8 9.61 Cameo KBG-2-9 1 GAS LIFT GLV BTM 0.188 1,368.0 9/25/2009 4 5,872.5 5,389.0 6.57 Cameo KBG-2-9 1 GAS LIFT GLV BTM 0.188 1,355.0 9/2&11 SLOTS, 8,24fi-9,348 5 6,172.1 5.686.7 7.56 Cameo KBG-2-9 1 GAS LIFT OV BTM 0.2501 0.0 9/24/2009 SLOTTED LINER B, 6. B10-9.382 ?7 Cie 1xrCW1 ICAL INTEGRITY REPORT — o "'Z 6 FIELD FUD Lt . OPER. "MLL DAT l; TD s (; Y 3M.. G S Z Tn. ; PBTD : ? M TVD S Casing: Shoe: MD TVD ; DV: TGD Shoe: HD TVD; TO : _ ubi.^.g . Packer TVD; Set at :ale S;ze and Perfs to . ? Cr�.P.,NLCAL iNTEGRTTY - ?ART 11 Annulus tress Test: ; 15 min ; 3 0 min ,•,,,_ • �s Cot®BntS : 7 _ D 1 n HECHA.NIC?.L 'INTEGRITY - PART # 2 � n Cement Volumes:-Amt. Liaear 3 sg_ - DV - Cmt Vol to cove: Derfs d .7S— 0S�ZS 0; 11 Theoretical TOC Cement Bond Log (Yes r No)�t In AOGCC File,„-� CBL :valuation, zone above perfs T Production Log: Typei Evaluation CONCLUSIONS: _ram, mart #2: 0 02232 04:45 05:00 0.25 0 0 COMPZI CASINI SFTY P I PJSM - with GBR and Baker on running 3-1/2" 05:00 06:00 1.00 0 400 COMPZI CAST RUNL P TIH with 3-1/2" liner. Check float equipment. Monitor displacement via trip tank. 06:00 06:15 0.25 400 599 COMPZP CASIN RUNL P TIH with 3-1/2" liner 06:15 06:45 0.50 599 640 COMPZI, CASIN RUNL P Pick uo ZXP liner top packer and HMC liner hanger 06:45 07:15 0.50 640 640 COMPZP CASIN RURD P Rig down GBR equipment, change out elevators slips and clear rig floor 07:15 07:45 0.50 640 640 COMPZ CASIN RURD P Rig up 2-7/8" handling equipment 07:45 08:15 0.50 640 640 COMPZ CASIN RURD P Rig up line to fill liner from mud manifold 08:15 09:00 0.75 640 640 COMPZ CASIN RUNL P Mix and pour PAL mix into liner sleeve and let setup. Service top drive. 09:00 09:45 0.75 640 735 COMPZP CASIW RUNL P Trip in hole with 3-1/2" liner and one stand of drill pipe. Check floats. Pump 1 bpm -110 psi, 2 bpm -180 psi, 3 bpm - 310 psi, 4 b - 470 psi 09:45 12:00 2.25 735 2,537 COMPZ CASIN RUNL P Trip in hole with 3-112" liner on 2-78" drill pipe. Filled pipe at 1589' MD, pumping 2 bpm, 290 PSI 12:00 18:00 6.00 2,537 5,857 COMPZ CASIN RUNL P Trip in hole with 3-12" liner on 2-7/8" drill pipe. Filled pipe at 3485' MD, pumping 2 bpm, 720 psi, 4433' MD, pumping 2bpm, 960 psi, 5383' MD, pumping 2 bpm, 810 psi 18:00 18:45 0.75 5,857 6,613 COMPZ CASIN RUNL P Trip in hole with 3-1/2" finer on 2-7/8" drill pi . 18:45 22:30 3.75 6,613 6,613 COMPZP CASIN CHIC P Circulate surface to surface at 5-12" shoe. Stage pumps to 1.5 bpm, 1210 psi. 22:30 23:00 0.50 6,613 6,951 COMPZ CASIW RUNL P Trip in hole with 3-12" liner on 2-7/8" drill pipe. Tagged bottom on depth. Monitor well via trip tank 23:00 00:00 1.00 6,951 6,951 COMPZ CASIN RUNL P Pick up and make up cement head and lines 02242008 00:00 04:45 4.75 6,951 6,951 COMPZ CEME CIRC P Circulate and recpirocate pipe 16. Stage pumps from .5 bpm to 2 bpm. Pump full surface to surface volume. PU wt 135k, SO wt 125k. Pumping .5 bpm, 860 psi 1 bpm, 1110 psi 1.5 bpm, 1340 psi 2 bpm 1570 psi 04:45 05:00 0.25 6,951 6,951 COMPZ CEME SFTY P PJSM with Schlumberger and Baker, cementing 3-12" liner 06:30 1.50 6,951 6,310 COMPZJ CEMEP OTHR P Pump cement job. Flood lines with 5 bbls water and pressure test to 4500 psi. Pump 9.9 bbls of 8.41 ppg CW100, 18.5 bbls 14.85 ppg Mud and 10.75 bbls cf1& pW cis G off. Stage raft buoi .5 bpm, 1400 psi during CW100 to 2 bpm, 1500 psi by the end of the cement. Pushed drill pipe wiper plug out with 5 bbls of water and chased it with 25.9 bbls of 14.2 ppg mud. Plug bumped at 29.9 bbls of displacement. Pressured up to 3100, bleed off and check floa s, floals hokft W. Ptdr dogs out of tie back skein. Set down 45K to set packer twice. Observed screws sheared when drill pipe was rotated. Top of liner Q 6316 MD Doyon 15 RKB. Did not see drill pipe wiper plug latch into liner wiper plug. Cement was displaced by Dowell cementing unit Cement in place at 06:25. 06:30 07:30 1.00 6,310 6,310 COMPZ CEME CIRC P Close annular preventor, pump down kill line and reverse out cement using rig pumps. Pump 80 bbls at 126 gpm, 1800 psi. 07:30 08:30 1.00 6,310 6,310 COMPZ CEME CIRC P Open annular preventor, dose kill line and circulate surface to surface volume at 120 gpm, 2050 psi. 08:30 10:00 1.50 6,310 6,310 COMPZ1 CEME RURD P Rig down cement head and lines, lay down cement head. 10:00 10:30 0.50 6,310 6,186 COMPZP CEMEN TRIP P Trip out of hole. PU wt 135k, SO wt 125k. Monitor well via trip tank. 10:30 11:00 0.50 6,186 6,186 COMPZP CEMEIS CIRC P Pump dry job 11:00 21:15 10.25 6,186 0 COMPZ CEMEIN TRIP P Trip out of hole laying down 2-7/8" drill pipe. onitoring well via trip tank. 21:15 21:45 0.50 0 0 COMPZ CEMEJ PULD P Lay down Baker liner running tool 21:45 22:45 1.00 0 0 COMPZP CEMU RURD P Shut blind rams and rig down 2-7/8" handling tools. Clear rig floor. 22:45 23:00 0.25 0 0 COMPZ CEMEh RURD P Rig up to lay down 4" drill pipe from derrick. Put mouse hole in rotary table 23:00 00:00 1.00 0 0 COMPZ CEMU PULD P Lay down 4" drill pipe from derrick 02/25/2 00:00 01:45 1.75 0 0 COMPZ CEMEh PULD P Lay down 4" drill pipe from derrick 01:45 02:15 0.50 0 0 COMP CEMEh PULD P Pull mouse hole from rotary table, drain stack and pull wear bushing. 02:15 02:45 0.50 0 0 COMPZ CEMEh PULD P Clean geo-span and lower down beaver slide. 02:45 03:45 1.00 0 0 COMPZP RPCON RURD P Rig up GBR to run in hole with3-1/2" M 02/25/2008 03:45 047OW02. FM 0 COMPZ RPCO SFTY P PJSM - running tubing with Baker and GBR. 04:00 06 427 COMPZI Run in hole with 3-1/2" production tubing from derrick. Monitoring .displacement via tip tank 06:00 10:30 4.50 427 4,310 COMPZF RPCOR RCST P I Continue running tubing from derrick. PU wt 100k, SO wt 100k. 10:30 11:30 1.00 4,310 4,317 COMPZI RPCON RURD P Rig up sheave in derrick to run SSSV control line. Connect control lice to SSSV and test line to 5000 psi for 10 minutes. 11:30 16:00 4.50 4,317 6,233 COMPZI RPCOJ RCST P Continue running tubing from derrick. PU wt 228k SO wt 215k. 16:00 18:00 2.00 6,233 6,233 COMPZI RPCOI RCST P Run in hole to locate seals for space out Lay down 3 joints and pick up 3 pups for space out 10.07' 9.81', 7.83' 18:00 18:15 0.25 6,233 6,233 COMPZ RPCON PULD P Make up landing joint to hanger 18:15 18:30 0.25 6,233 6,250 COMPZt RPCOA PULD P Connect SSSV control line to hanger 18:30 19:15 0.75 6,250 6,296 COMPZP RPCOK DHEQ P Pressure test packer to psi - held pressure. 19:15 19:45 0.50 6,296 6,296 COMPZf RPCOK RURD P Rig up for displacing well to seawater. 19:45 21:15 1.50 6,296 6,296 COMPZP RPCOK CIRC P Displace well to seawater, pumped 270 bbls. Mix and pump 25 bbls corrosion inhibitor mixed with seawater. Chased Cl pill with 55 bbls of seawater 21:15 21:30 0.25 6,296 6,296 COMPZP RPCOh OTHR P Blow down kill line. 21:30 22:30 1.00 6,296 6,333 COMPZP RPCOK RCST P Land hanger and run in lock down screws. Rig up to test 22:30 00:00 1.50 COMPZ RPCOK RCST P Test tubing to 25W psi for 15 minutes and 7" x 3-1C2" a Ior288f,Bf W for, 30 minutes. Shear dump valve. Pressure up tubing and annulus and ciose SSSV. Bleed off tubing and monitor tubing for returns - no returns. Pressure up tubing and open SSSV. All tests charted. 02/26/2008 00:00 01:00 1.00 0 0 COMPZI RPCOK RURD P Rig down test equipment and blow down lines 01:00 01:30 0.50 0 0 COMPZ RPCOK RURD P Break out circulating head, pull landing joint and rig down control line sheave. 01:30 02:00 0.50 0 0 COMPZt RPCOI RURD P Set back pressure valve and cut control line 02:00 05:00 3.00 0 0 COMPZP RPCOh RURD P Rig down flow line, pull bell nipple and nipple down BOP. Pull and lay down mouse hole. Bleed koome 05:00 06:00 1.00 0 0 COMPZP RPCOJ NUND P I P/U Tree and Orient per DSO 06:00 06:30 0.50 0 0 COMPZI RPCOI RURD P R/U to Test Tree & Pack Off PIN'u k, �„ 0 ConocoPhillin%A" December 7, 2009 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7`" Ave. Ste. 100 Anchorage, AK 99501 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit, NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax:659-7314 RECEIVED Alaska Gil & Gas Cons. Commission Anchorage Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 3C-1413 from Pre -produced Oil Production service to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3C-1413 (PTD 209-061). Note: This application is a replacement for the lost 10-403 dated 11/25/09. ✓ If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659-7535. Sincerely, Robert D. Christensen Attachments 9 C� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ECEI YE111—_. D/nChcorallule 00 Alaska Oil . Corr: 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ ❑ Other Q Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ /Elon Time❑ pROD to WINJ Change approvedprogram 9 pP Pull Tubing ❑ Perforate New Pool ❑ Conversion Re-enter Suspe❑ 2. Operator Name: 4. Current Well Class: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development❑ Stratigraphic ❑ Exploratory ❑ Service ❑ 209-061 ' 3. Address: 6. API Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-2142 0 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well NamA and Number: ownership or landownership changes: Spacing Exception Required? Yes No F±1 3/4� 9. Property Designation: 10. KB Elevation (ft): 11. eld/P s) ADL 25634 RKB 88' K aruk Ri Fie Ku ru iv Pool - 12. PRESENT WELL CO DITIONJAJ M NMY Total depth MD (ft): Total Depth TVD (ft) Effective Depth MD (ft): Effective Depth TVD ): lugs ( a ): k (measured): 9382' • 6459' 9380' 6459' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16 6' SURFACE 4023' 9-5/8" ki 2 ' PRODUCTION 4112' 7" 41 5 37 ' LINER 2692' 5-1/2" 6IiX16' 6116' LINER 635' 3-1/2" 685 ' 6325' Slotted Liner 2572' 2- 9382' 6459' Perforation Depth MD (ft): Pe ration Dep TVD : )'; Tubing Size: Tubing Grade: Tubing MD (ft): 6953-7773'; 8117-8244'; 8246-9348' 64 2-6493'; 65 O-6 5 4-6461' 3.5 L-80 6341' Packers and SSSV Type: Packers and SSSV MD (ft) 5.5" x 7" LTP CHIP, HR ZXP, BAKER KB 3924', 6235', 6810' TRMAXX-5E SCSSV 2026' 13. Attachments: Description Summary of Proposal ❑✓ 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑✓ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December 1, 2 9 Oil ❑ WAG ❑ Gas ❑ GINJ ❑ Plugged ❑ Abandoned El WINJ WDSPL ❑ 17. Verbal Approval: Date: Commission Representative: 18. 1 hereby certify that the foregoing is true and correct the best of my knowledge. Contact: B. Christensen/ D. Humphrey Printed Name R D. h ' tensen Title: Production Engineering Specialist Signature Phone:669-7535 Date �a Commission Use Only Sundry Number: Conditions of approval: Notify Commission that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Subsequent Form Required: l �/ O APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL 1,,-12- � Form 10-403 Revised 06/2006 Submit in Duplicate i 0 3C-14B DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3C-146 from Oil Production service to Water Injection service. Well 3C-14B was completed as a CTD Kuparuk Oil Pool A sand, single, pre - produced sidetrack injector on September 10, 2009. Oil production rates and bottom hole pressures have have declined and warrant returning this well to its original intended service at this time. Conversion of well 3C-14B to water injection service will provide pressure support to offset producers 1 Q-15 & 3C-15. The 16" Conductor was cemented with 188 sx CS II. The 9-5/8" Surface casing (4061' and / 3720' tvd) was cemented with 940 sx PF'E', 380 sx PF'C', and 125 sx PF'C'. The 7" Production casing (4150' and / 3787' tvd) was cemented with 550 sx Class'G" & 200 sx PF'C'. An MIT -IA was last performed on 11/30/09; MITIA 2500 psi, 30 minutes, Passed The injection tubing/casing annulus is isolated via 5-1/2" x 7" LTP "CHP" Packer located @ 3924' and / 3616' tvd. The Top of the Kuparuk B sand was found at 6825' and / 6303' tvd. The Top of the Kuparuk A sand was found at 6896' and / 6424' tvd. 3C-14B Final CTD Sidetrack Completion 16" 62.5# H-40 shoe @ 116' MD 9-5/8" 36# J-55 shoe @ 4061' MD 7" 26# J-55 Top of Window @ 4150' MD 5.5" 15.5# L-80 @ 6616' MD C-sand perfs 6789' - 6803' MD cement squeeze KOP @ 6825.20' MD 3-1/2" Monobore Whipstock 6842' ELM PBTD 6853' Landing Collar 6886' Float Collar 3-1/2" 9.2# L-80 shoe @ 6950' MD SSSV @ 2026' MD ; 2026' MD (Tubing Tally) ID = 2.812" 3-1/2" 9.3# L-80 IBTM Tubing 6316' MD surface 3 1/2" 9.2# L-80 Hydril 511 Tubing 6351' MD 5-1/2" Liner Top Packer @ 3924' MD 5-1/2" Liner Hanger @ 3935' MD 3-1/2" Carrico KBG gas lift mandrels @ 2544' MD RKB 4066' MD RKB 5082' MD RKB 5873' MD RKB 6172' MD RKB 3-1/2" Carrico DS landing nipple @ 6252' MD RKB (2.75" min ID) 6246' MD ELM Locator Coupling @ 6322' MD RKB (6316' ELM) ID = 2.99" Baker 3 1/2" ZXP Extension @ 6323' ELM ID = 4.13" Baker 3-1/2" ZXP liner top packer @ 6335' ELM ID = 3.00" Baker 3-1/2" liner hanger @ 6344' ELM ID = 2.93" 3-1/2" Tubing Collars @ 6793' & 6824' Ran 3-1/2" Stop Collars in the middle of each joints f/ #1 - #10 Ran 3-1/2" x 4-1/2" Straight Blade Centralizers floating between stops: covering f/ 6950' to 6590' MD F .- Top of KB Straddle - 6777' RKB Top of KB Liner Top Packer - 6809.98' Top of 2-3/8" Liner - 6826.63' 6824' Collar 3C-14B PB1: 7,010' - 8,084' MD aluminum billet at 7,010' MD 3C-14B: 6,830' - 9382' MD solid 2-3/8" 6826.63 - 6953.11 slotted 2-3/8" 6953.11-7773.29 solid 2-318" 7773.29 - 8117.50 slotted 2.318" 8117.50-9348.36 2-3/8" liner segment at 8244.96' MD ID = 1.00" • James Ohlinger 3C-14B CTD Planning workbook.xis 9/15/2009 /L-4 KUP • 3C-14B ConocoPhillips Well Attributes I Max Angle & MD TD r11.t n..f 111, Wellbore API/UWI Fieltl Name Well Status 500292142502 KUPARUK RIVER UNIT PROD loan (1) MU(RKB) 100.09 8,579.59 Act Stm(RKB) 9,382.0 Comment HIS (ppm) Date Annotation End Data K"rtl (R) Rig Release Date .. SSSV: TRDP 130 12/312008 Last WO: 37.40 10118/1985 Well Confi , - 3C-140 /2/12009 7.50.11 AM Schemata- Nal An notation Last Tag: Depth (ftKB) I End Data Annotation Rev Reason: GLV C/O, PULL PLUG Laat Mod ... Imosbor End Date 1P/1/2009 Casing Strings Casing Description String 0... Siring ID ... Top (ftKB) Set Depth if... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H-00 Casing Description String 0... String ID ... Top (fli Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top ThirdHANGER, 38 SURFACE 9 5/8 8.765 35.2 4,060.5 3.720.0 36.00 J-55 Casing Description String 0... String ID ... Top (fIKS) Set Depth If... Set Depth (TVD) ... String Wt... String ... String Top Third PRODUCTION 7 6.151 33.0 4,178.0 3,808.3 26.00 J-55 XO TUBING, 42 Casing Description String 0... String ID ... Top (ftKB) Set Depth If... Set Depth (TVD) ... String Wt... String ... String Top ThirdCONDUCTOR, LINER A 5.5" 5 112 4.850 3,924.1 6,616.0 6,115.9 15.50 L-80 Hydril 511 Liner Details 36-115 Top Depth (TVD) Top Incl Noml... SSSV, 2,026 Top (ftKB) (RKB) (0) Item Description Comment ID (in) GAS LIFT, 2• 3,924.1 3,616.4 40.46 PACKER 5.5" X 7' LTP "CHP" C-2 profile w/ 6.1' ext. Est 5.5" ID (Pkr 4.91" ID) - SEAL IS ONLY BETWEEN PROD CSG 8 LINER 4.910 3,934.9 3,624.6 40.48 HANGER HMC liner hanger- 5.5" Vam p X p (4.96" ID) 4.960 6,529.6 6,034.2 17.79 COLLAR 5.5" Weatherford 403 Float Collar 4.850 Casing Dsscrlptlon 34ing 0... String ID ... Top (RKB) Set Depth if... ast Depth (TVD) ... String Wt... String ... String Top Thrd WINDOW B 4 3.000 6,825.0 6,830.0 8,307.1 Cuing Deacriptlon String 0... String to... Top (ftKB) Set Depth if... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, LINER A3.5" 31/2 2.992 6,216.1 6,851.0 6,324.8 9.20 L-80 Hydril 511 35-4,061 Liner Details GAS LIFT, Top Depth 4,066 (TVD) Top Ind Nonni Top (aKa) IRKS) (') Item Description Comment ID (In) 6,216.1 5,730.11 8.37 SSE ZXP Seal Bore Extension 4.130 PRODUCTION, 33-4,178 6,235.3 5,749.2 9.25 PACKER HR ZXP Liner Top Packer 3.000 GAS LIFT, 5,082 6,243.7 5,757.5 9.64 HANGER HMC Liner Hanger 2.920 6,754.0 6,242.3 28.74 COLLAR Baker 3-1/2 Type 1 Landing Collar 2.8W GAS LIFT, 5,573 Casing Do crlption String D... String ID ... Top (Po(B) Set Depth (f... Set Depth (TVO) ... String Wt... Suing ... String Top Thrd SLOTTED LINER B 2 318 1.992 6,810.0 9,382.0 4.60 L-79 Liner Details GAS LIFT, 8,172 Top Depth (TVD) Top Inol Noml... Top (RKB) (RKB) (") Item Description Comment to (in) 6,810.0 6,290.6 30.91 PACKER BAKER KB PACKER 1.730 6.820.2 6,299.4 32.35 DEPLOY DEPLOYMENT SLEEVE 2.250 8,245.0 6,543.9 83.23 DEPLOY DEPLOYMENT SLEEVE 2.250 9,348.4 6,461.3 93.93 O-RING O-RING SUB 1.000 NIPPLE, 6,252 t Tubing Strings Tubing Deacriptlon String 0... String ID ... Top (ftKS) Set Depth (f... Depth IT VD) ... String WI... String ... String Top Thrd LOCATOR, last TUBING 31/2 2.992 37.7 6,341.0 5,852.8 9.30 L-80 IBTM Com letion Details 6, 323 Top Depth SEAL ASSY, 6,336 (TVD) Top Incl Noml... Top (ftlt8) (RKB) I') Item Description Comment 10 (In) 37.7 37.7 -0.01 HANGER CIW Gen 4, Type N-FBB, "H" BPV prohoe, P/N 156156-01-01-01 2.992 2,026.5 2,026.2 5.09 SSSV 3.5" TRMAXX-SE SCSSV w/ 2.812" X Profile Ser.# HZS-028 2.812 6,252.3 5,766.0 10.04 NIPPLE 3-1/2" x 2.750" Camco "D" Nipple (EUE 8rd) 2.750" NoGo Profile 2.750 6,322.7 5,834.9 13.18 LOCATOR Baker Locator Coupling (4.40" O.D.) 2.990 LINER A55". 3.9za-6.616 6,335.5 5,847.4 13.50 SEAL ASSY Baker Bullet Seal Assembly (D.D. 4.125") 2.990 Other In Hole Wireline retrievable plugs, valves pumps, fish etc. Top Depth (TVD) Top Incl PACKER. 6,777 Top IftKB) (RKB) (1 Deacriptlon Comment Run Data ID (in) 6,777 6,262.3 29.65 PACKER 35 KB LINER TOP PACKER 9/14/2009 1.860 6,781 6,265.8 29.90 PATCH BAKER SPACER PIPE, SEAL ASSY 9/14/2009 1.690 PATCH, 6,781 6,825 6,303.0 33.29 WHIPSTOCK 2.625" OD BAKER MONOBORE WHIPSTOCK 8.74" OAL, 7/312009 0.000 PERF, .875" FLUID PASS ID: 7.3.2009 WSR FOR DETAILS 6,789-6,503 7,000 6,432.E 51.14 FISH 3 ANCHORS FROM 35 KB PACKER, 2 1/8"x1.33'k1I2" 9/102009 0.000 THICK Perforations & Slots Shot WHIPSTOCK, WINDOW B, Top(ftKB) Btm(Po(B) Top(TVO) I (RKB) Stm(TVD) (ftKS) Zone Date Dens (sh Type Comment 6,789 6,8031 6,271.8 6,284.5 Gt, 3C-14A 3114/2008 6.0 IPERF SQUEEZED OFF 7/242009 6,825-6,53o 6.953 7,773 6,401.6 6,493.6 9/6/2009 32.0 SLOTS ALL B SIDETRACK SLOTS - 0.125"):25' @ 4 Circumferential LINER A3.5', 621sa 551 adjacent rows, 3" centers staggered 18 deg, 3'non-slotted ends 8,117 8,244 6.519.6 6,543.8 9/62009 32.0 SLOTS FISH, 7,000 SLOTS, 8,24E 9,348 6,544.0 6,461.3 9/6/2009 1 32.0 SLOTS 8,953-7,773 Mandrel Details TD (3C-14B), 8,084 Top (TVD) Depth Top IndqKBG-2-91 Valve Latch Port Sita TRO Run SLOTS, 9,117-8,244 Sin Top(MKB) (RKB) (1 Make Sery Type Type (in) (psi) Run Date Com... 1 2,543.9 2,521.0 23.11 Camco GAS LIFT DMY BTM 0.000 0.0 11/292009 2 4,065.9 3,724.1 40.77 Camco GAS LIFT DMY BTM 0.000 0.0 11/29/2009 3 5,082.3 4,605.8 9.61 Camco GAS LIFT DMY BTM 0.000 0.0 11292009 4 5,872.5 5,389.0 6.57 Camco GAS LIFT DMY BTM 0.000 0.0 11/2911 SLOTS. 5 6,17P,1 5,688.7 7.58Camoo GAS LIFT DMY BTM 0.000 0.011/302009 8,246-9,348 SLOT ED LINER a382 6,810-9, ConocoPhillips ••• Well ConRa�-3C-14612M ItYM �. HANGER, 35 XO TUBING, 42 CONDUCTOR, 36-116 SSSV, 2,026 GAS LIFT, 2.544 SURFACE, 35 4,081 GAS LIFT, 4,066 PRODUCTION, 33-4.178 GAS LIFT, S,OB2 GAS LIFT, 5,873 GAS LIFT, 6,172 NIPPLE, 6,252 LOCATOR, 6.323 SEAL ASSY, 6.336 LINER A55', 3,9245616 'ACKER, 6,777 PATCH, 6,781 IPERF, 8,7898,803 WHIPSTOCK, 6,825 WINDOW B, 6,825 SAM LINER A 3.5'. 6,2168851 FISH, 7.000 SLOTS, S.953.7.773 TO (3C-148), 8.054 SLOTS, 8.1178,244 SL0T8, 8,248-9,318 SLOTTED LINER B, Q810-9,382 KUP i 3C-14B 37.40 10 ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS 0 0 ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS '06 9 ,0(' % I� 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil o Gas Plugged ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: 1b. Well Class: Development ❑✓ v Exploratory ❑ Service ❑ Stratigraphic Test❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: September 8, 2009� 12. Permit to Drill Number: 209-061 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 26, 2009 r 13. API Number: 50-029-21425-02 4a. Location of Well (Governmental Section): Surface: 1251' FNL, 1229' FEL, Sec. 14, T12N, R9E, UM Top of Productive Horizon: 2558' FSL, 51' FWL, Sec. 13, T12N, R9E, UM Total Depth: 344' FSL, 23' FEL, Sec. 14, T12N, R9E, UM 7. Date TO Reached: September 4, 2009 14. Well Name and Number: 3C-14B 8. KB (ft above MSL): 88' RK Ground (ft MSL): 47.6' AMSL,i 15. Field/Pool(s): Kuparuk River Field Kupuruk River Oil Pool 9. Plug Back Depth (MD + TVD): 9380' MD / 6459' TVD 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528346 y- 5995180 Zone-4 TPI: x- 529632 y- 5993714 Zone-4 Total Depth: x- 529569 - 5991500 Zone-4 10. Total Depth (MO TVD): ✓ 9382' MD / 6459' TVD 16. Property Designation: ADL 25634 f 11. SSSV Depth (MD + TVD): SSSV @ 2027' MD / 2026' TVD 17. Land Use Permit: 2567 18. Directional Survey: Yes ❑✓ 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): approx. 1700' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 6825' GR/Res lva 22. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 62.5# H-40 38' 116' 38' 116' 24" 188 sx CS II 9.625" 36# J-55 38' 4061' 38' 3720' 12.25" 940 sx PF'E', 380 sx PF'C', 125 sx PF'C' 7" 26# J-55 38' 4150' 38' 3787' 8.5" 550 sx Class G, 200 sx PF'C' 2.375" 4.6# 1 L-80 j 6810' 1 9382' 6291' 6459' 1 3" Islotted liner 23. Open to production or injection? Yes ❑ No ❑ If Yes, list each Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): solid from 6826'-6953' MD 6303' - 6402' TVD slotted liner from 6953'-7773' MD 6402'-6493' TVD solid from 7773'-8117' MD 6493' - 6520' TVD slotted liner from 8117'-8244' MD 6520'-6543' TVD solid from 8244'-8246' MD 6543'-6544' TVD slotted liner from 8246'-9348' MD 6544'-6461' TVD 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET 3.5" 6341' 3924', 6810' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production September 22, 2009 Method of Operation (Flowing, gas lift, etc.) pre -produced injector Date of Test 9/26/2009 Hours Tested 11 hours Production for Test Period --> OIL-BBL 620 GAS-MCF 734 WATER-BBL 0 CHOKE SIZE 124% GAS -OIL RATIO 1329 Flow Tubing press. 126 psi Casing Pressure 918 Calculated 24-Hour Rate -> OIL-BBL 1214 GAS-MCF 1614 WATER-BBL 0 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No ❑✓ 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. RECEIVED NONE , OCT U g 2009 Y Alaska Oil & G83 Cons Commission Anchnreae Form 10-407 Revised 2/2007 .. L�,ti (;Is;),Ong CONTINUED ON REVERSE SIDE Ah As I 28. GEOLOGIC MARKERS (List all formations and markers ncountered): NW 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface ground surface Permafrost - Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. A3 7021' 6445' A2 7240' 6484' invert point 8310' 6548' A3 8171' 6532' 3C-14BPB1 top 7010' 6439' TD 8084' 6501' N/A Formation at total depth: Kuparuk A3 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger �102 Printed J es Ohlin er Title: CT Drilling Engineer Signature'11Phone 2 ��02 Date \� 1 l IZ��C\ \or 7 �Wv%) Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: 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 3C-14B 16" 62.5# H-40 shoe @ 116' MD Final CTD Sidetrack Completion 9-5/8" 36# J-55 shoe @ 4061' MD 7" 26# J-55 Top of Window @ 4150' MD :Zo7iF-l��l C-sand perfs 6789' - 6803' MD cement squeeze KOP @ 6825.20' MD 3-1/2" Monobore Whipstock 6842' ELM PBTD 6853' Landing Collar 6886' Float Collar 3-1/2" 9.2# L-80 shoe @ 6950' MD SSSV @ 2026' MD : 2026' MD (Tubing Tally) ID = 2.812" 3-1/2" 9.3# L-80 IBTM Tubing 6316' MD surface 3 1/2" 9.2# L-80 Hydril 511 Tubing 6351' MD 5-1/2" Liner Top Packer @ 3924' MD 5-1/2" Liner Hanger @ 3935' MD' 3-1/2" Camco KBG gas lift mandrels @ 2544' MD RKB 4066' MD RKB 5082' MD RKB 5873' MD RKB 6172' MD RKB 3-1/2" Camco DS landing nipple @ 6252' MD RKB (2.75" min ID) 6246' MD ELM Locator Coupling @ 6322' MD RKB (6316' ELM) ID = 2.99" Baker 3 112" ZXP Extension @ 6323' ELM ID = 4.13" Baker 3-1/2" ZXP liner top packer @ 6335' ELM ID = 3.00" Baker 3-1/2" liner hanger @ 6344' ELM ID = 2.93" 3-1/2" Tubing Collars @ 6793' & 6824' Ran 3-1/2" Stop Collars in the middle of each joints f/ #1 - #10 Ran 3-1/2" x 4-1/2" Straight Blade Centralizers floating between stops: coverinq f/ 6950' to 6590' MD Top of KB Straddle - 6777' RKB Top of KB Liner Top Packer - 6809.98, Top of 2-3/8" Liner - 6826.63' 6824' Collar 3C-14B PB1: 7,010' - 8,084' MD aluminum billet at 7,010' MD 3C-14B: 6,830' - 9382' MD solid 2-3/8" 6826.63 - 6953.11 slotted 2-3/8" 6953.11-7773.29 solid 2-3/8" 7773.29 - 8117.50 slotted 2-3/8" 8117.50-9348.36 ID = 1.00" 09 James Ohlinger 3C-14B CTD Planning workbook.xls 9/15/2009 Conouphillips ,. ,ENe11,C _ a 3C-14B, 9/14 HANGER, 38 - CONDUCTOR, 36-116 SSSV, 2,026 GAS LIFT, 2,544 SURFACE, 354,061 GAS LIFT, 4,066 PRODUCTION, 334.178 GAS LIFT, 5,082 GAS LIFT, 5.873 GAS LIFT, 6,172 NIPPLE, 6,252 -�- LOCATOR,-- 6,323 SEAL ASSY, _--. 6,336 LINER A 5S', 3'924-6.616 LINER A 3.5', 6,216-6,851 SLOTS, 6,953-7,773 4B), TD (3aLom 8 I� SLOTS, 8,117-8,244 SLOTS, Zw 1 8,246-9,348 _LL) SLOTTED LINER B, —� 6,810.9,382 KUP 3C-14B Well Attributes Max & MD I TD W 11,b e APVUWI Field Name Well Status Ind (°) 71e (ftKB) !Act Bim (ftKB) 500292142502 KUPARUK RIVER UNIT PRODUCING 9,382.0 Pf Comment H2S (ppm) Date KB-Grd (ft) Rig R I age Del SSSV IRDP 130 (Date 12/31/2008 (Annotation Last WO' (End 3740 10/18/1985 Annotation Depth (n K8) End Date Annotation Last Mod By End Data Last Tag: 1Rev Reason NEW SIDETRACK'B' Imosbor 9/10/2009 Casino Strings Casing Description String 0... Stir g ID -. Top (ftKB) Set Depth (f... Set Depth (ND) Str g Wt. (String String Top Third CONDUCTOR 16 15 062 36.0 116.0 62.50 H40 Casing Description String O... String lD... Top (ftKB) Set Depth (t... Set Depth(NDI ... String yrt... String... String Top Thrd SURFACE 95/8 8.765 35.2 4,060-5 36.00 J-55 __-__-- CasingDescnption String O... String ID... —�.__ lop 01KB) Set Depth if... ,_.,,.._......__.__ Set Depth(TVD)... String Wl... _ String... Sting Tap Thrd PRODUCTION 7 6.151 33.0 41,17&0 26.00 J-55 Casing Description String 0... String ID ... Top (ftKB) Set Depth (i.-. Set Depth (ND) String Wt. String ... String Top Thrd LINER A 5.5" Liner Details Top Depth (ND) Topg1(ftKS) 5 1/2 4.850 3,924.1 6,616.0 15.50 L-80 Hydril 511 Top Incl (°) Item Description Comment ID h 3,924.1 PACKER 5.5" X 7" LTP "CHP" C-2 profile w/ 6-1' exi Est 5.5" ID (Pkr 4.91" ID) 4.910 3,934.9 HANGER HMC liner harger - 5.5"Vamp X p (4.96" ID) 4.960 6,529-6 COLLAR--- - 5-5"Weatherford 403Float Col lar - 4.850 Cuing Description String 0... String ID gringTop Thrd (ftKB)Depth (E.. Set Dapth (ND) ... String MTL10]: 3.00 6,825.0 6,830Cuig JT*p Dascdption String O._ String ID ..Top (ftKB) Set Depth (f... Sat Depth (ND) String apThNLINER A3.5" 31/2 2.992 6,216.1 6,851.0 9.2Hytlri1511 Liner Details Top Depth (ND) Top Incl Top (PoCB (ftB) C) Item Description _ Comment _. ID (in) 6,216.1 SBE ZXP Seal Bore Extension 4.13( 6,235.3 PACKER HR ZXP Liner Top Packer 3.00( 6,243 7 HANGER HMC Liner Harper 2.92( 6,754.0 COLLAR Baker 3-1/2 Type I Landing Collar 2.88( �-_. _ — Caeing De ription String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... Sni g Wt. Siritg Top Thrd SLOTTED LINER B 2 3/8 1.992 1 _ 6,810.0 _L 9,392,0 -..I _ 4.60...- l L 79 Liner Details Top Depth (ND) Top Incl TIREp(B (ftKB) (°) Item D rpton' „Comment IDS 6,810.0 PACKER (BAKER KB PACKER 1.73( 6,820.2 DEPLOY DEPLOYMENT SLEEVE 2-25( 8,245.0 DEPLOY DEPLOYMENT SLEEVE 2.25( 9,3484 O-RING OARING SUB _ _ _ 1.00( Tubing Strings n �� Tubing Description (String O._ (String ID ... Top (ftKB) Set Depth (f... Sat Depth (ND) String Wt Strng . String Top Third TUBING 312 2992 I 377 63410 930-". L80 1-_ IBTM CompletionDetails _ Top Depth (TVD) Top Inc' To KB (ftKB) (°) Item Description — __.. CommeM ID (in) 37-7 HANGER CIW Gen 4, Type N-FBB, "H" BPV profioe, P/N 156156-01-01-01 2.99, ---- - --. ___----_ __�__ - 2,026.5 ISSSV 3.5" TRMAXX-SE SCSSV wl 2.812" X Profile Ser.!! HZS-028 6,252.3 IPPLE 3-1/2"x2.750"Camco"D" Nipple (EUE 8rd) 2.750" No-GoProfile 2.75( 6,322.7 LOCATOR Baker Locator Coupling (4.40" O.D.) 2.99( 6,335-5 ��",N EBak AL ASSY er Bullet Seal Assembly (O.D. 4.125") 2-99( Other In Hole (Wireline retrievable Si plugs, valves, purril b, etc.)_ Top Depth (TVD) Top Incl _ToP (NCB (ftKB) r) _ Description Run Date ID in 6,825 WHIPSTOCK 2-625" OD -BAKER MONOBORE WHIPSTOCK 8.74" OAL, 7/3/2009 0.00( .875" FLUID PASS ID: 7.3-2009 WSR FOR DETAILS Perforations & Slots Shot ' Top (ND) etm (ND) Dens Top (ftKB) Bfm (ftKB) (NCB) (ftKB) Zone Dale (sh-. Type Comment 6,7891 6,803 C-1, 3C-14A 3114'20011 6-0 IPERF SQUEEZED OFF 7124/2009 Jj,jT 9/62009 32.0 SLOTS ALL B SIDETRACK SLOTS - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends Notes General & Safety Entl Date Annotation 3/22/2008 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 )/9/2009-NOTE SIDETRACK B DRILLED Mandrel Details Top Depth Top Port (ND) Ind OD Valve Lath Size TRO Run >tn To ftKB (ftKB) (°) M ke ._kbdN (in) Sere Type Type (in) (Ps), Run Date Con 1 2,543.9 2,521.0 23-11 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0 0 7/22/2009 2 4,065.9 3,724 1 40 77 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 7/22/2009 3 5,082.3 4,605 7 8 661Camco 1KBG-2-9 1 GAS LIFT DMY INT 0 000 _ 0.0 7122/2009 4 5,872 5 5,389.0 6 58 Camco KBG-2 9 - 1 GAS LIFT DMY INT 0.000 0.0 7/22/2009 5 6,172.1 5.686.7 7-96�Cameo IKBG-2-9 1 GASLIFT DMY INT 0-000 0.07R32009 r1 ConocoPhillips Time Log &Summary Wellview Web Reporting r1 e Y o ri Well Name: 3C-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/25/2009 12:00:00 AM Rig Release: Time Loge Date From To Dur S. Dep1h E. DWth Phase Code Subcode T Comment, 8/24/2009 24 hr Summary Move rigfrom 1 Q ad to 3C ad P P 12:00 00:00 12.00 0 1 0 MIRU MOVE MOB P Move rig from 1Q pad to 3C pad. 8/25/2009 Perform BOP test ( waived by Jeff Jones). Slack MNGT 26 ft cut off. 00:00 03:30 3.50 0 MIRU WHDBO BOPE P Rig Accept, Nipple up BOP, RU for BOP test 03:30 06:30 3.00 MIRU WHDBO BOPE P Master valve will not hold test pressure, shut in surface safety valve, still not holding. Shut in both swab valves and test pressure held. Called out grease crew to service valves. "° This three hours will not be a part of the 06:30 12:00 5.50 MIRU WHDBO BOPE P Continue with testing, Hyd. leak on "B1" choke side HCR. Continue testing choke while making repairs 12:00 19:00 7.00 MIRU WHDBO BOPE T Completed BOP tests (over 10 hour time frame). Break down as follows NAD BOP time (10 hrs) CPAI - Wellhead valves - +2 hrs, NAD NPT - 6 hrs. total 18 hours BOP test time. 19:00 23:00 4.00 MIRU WHDBO SLPC P Perfrom slack management, fluid transfer, and complete post rig move - pre -spud operations. Charged Kummi bottles, inspected & tested fluid lines and cut off a total of 26 ft. 23:00 00:00 1.00 MIRU WHDBOSLPC P Re -head CT. 8/26/2009 P/U BHA # 1 milling (2.74") total lenght 83.41'. RIH & Tie @ 6771' (-4') correction. Started losing weight @ 6827', begin Milling window with flo-pro pumping 1.5 bpm, WOB 1 k @ 1 FPH. Current TOW - 6827.2, BOW - 6832.4. Milling ahead to 6842.5'. Only 1 stall for entire window. 00:00 03:00 3.00 0 0 MIRU WHDBO SLPC P Make up CT connector, Pressure and pull test. Good. Clean Gripper blocks and change out pack -off. Inspect Injector & chains. 03:00 03:30 0.50 0 0 MIRU WHDBO SFTY P Safety meeting for BHA handling and review. Flo -check on well. Zero pressure for 30 minutes. 03:30 04:00 0.50 0 0 MIRU WHDBO PRTS P Pressure test both PDL to 3500 psi. 04:00 05:00 1.00 0 0 PROD1 WHPST PULD P P/U BHA # 1 BHA 2.74" Mill (2.73" No-go) & String mill( 2.72") no-go, Baker Xtreme 2.13", X-over, 1 joint CS Hydril & 2-3/8 Coiltrak. Flo -check on well. Zero pressure for 30 minutes. Page 1 of 18 • Time' Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:00 07:15 2.25 0 6,586 PROD1 WHPST TRIP P RIH flushing well with sea water. 100bbrls away of SW. Swap hole over to Flo Pro. pumping through EDC 1.6 BPM 07:15 07:30 0.25 6,580 6,800 PROD1 WHPST DLOG P Tie in Depth, correct 4. 6771' Tie in depth with Gamma. No correction. Offline with pumps. Close EDC. RIH to Mill. 07:30 08:00 0.50 6,800 6,826 PROD1 WHPST TRIP P Flo -Pro around. Take returns back inside. Dry tag PUH start pumping recording up weights and off bottom pressures. 25.51K up weight, 11 K RIH weight. 3900psi CTP, 1.5 BPM. Mill down minimal motor work and DHWOB. Possible cement. 08:00 08:30 0.50 6,826 6,827 PROD1 WHPST MILL P Start taking weight on DHWOB sensor at 6827.2'. Milling .4 FPH with 150-200psi differential, 1-1.5K DHWOB. 08:30 11:30 3.00 6,827 6,828 PROD1 WHPST MILL P Stall, Offline with pumps. PUH 27K up weight. RIH 11:30 12:30 1.00 6,828 6,829 PROW WHPST MILL P Continue milling .4 FPH, 11K CTW, 1.5K DHWOB, 4000psi CTP. Metal found on ditch magnets. PUH swap pumps. Blew swab seal on pump. Online, RIH continue milling 12:30 15:00 2.50 6,829 6,829 PROW WHPST MILL P Continue milling .8 FPM, 11 K CTW, 1.9 DHWOB, 4050psi CTP. Good amount of metal in returns 15:00 17:30 2.50 6,829 6,830 PROD1 WHPST MILL P Continue milling 1 FPH, 1.2K DHWOB, 4010 psi CTP. 17:30 21:00 3.50 6,830 6,835 PROD1 WHPST MILL P Continue milling ahead slowly, 1fh no stalls since 18:00. Bit out casing @ 6832.5'. B/U sample @ 6833. show heavier sand concentration in returns. Continue drilling ahead slowly. Increase to 2 f h. 21:00 00:00 3.00 6,835 6,843 PROW WHPST MILL P 3.5 FPH, Circ pressure 3850, WOB .8, 1.5 BPM, ECD 11.8, continue milling/reaming down to 6842.5'. 1 for 1 returns during entire operation. 8/27/2009 P/U BHA #2, RIH and start drilling build section from 6842'. Drill down to 7055.13, Decision made to POOH and increase motor bend. Tie in whipstock de th - TOW - 6825.2 BOW - 6830.2. 00:00 01:30 1.50 6,843 6,843 PROD1 WHPST MILL P Drilled down to 6842.5' @ 3.3 fph. Back ream @ 1 fpm, pumping 1.5 bpm, 3850 psi, 1for1 returns, pass through 3 times and looked clean while pumping. No overpulls from 6842.5 to 6825'. Samples indicate sand with very little metal shavings. 01:30 02:00 0.50 6,843 6,843 PROD1 WHPST MILL P Shut down pumps and dry tag bottom. Trap 250 psi @ surface. make two passes from 6800 - 6842.5'. No weight bobbles. Page 2of18 ll Time Logs Date From To Dur S. De th E. De th Phase ' Code Subcode T Comment 02:00 05:00 3.00 6,843 0 PROD1 WHPST TRIP P POOH pumping 1.5 BPM following the MCS. Slow down through restictions @ 6252'. Tie in @ 6580' with + 1 ft correction. Inspect chains closer to surface, some links need to be repaired at surface. 05:00 06:30 1.50 0 0 PROD1 WHPST PULD P UndeDlov BHA # 1. 06:30 08:30 2.00 0 0 PROW DRILL SVRG P Service Injector Head. Blow back and clean Micro Motion, Inline HP filters 08:30 09:00 0.50 0 0 PROW DRILL SFTY P Hold Pre -Spud Meeting 3C14. 09:00 09:15 0.25 0 0 PROW DRILL SFTY P Hold PJSM for Deploying drilling BHA 09:15 10:45 1.50 0 0 PROD1 DRILL PULD P Deploy BHA #2 10:45 11:45 1.00 0 6,575 PROD1 DRILL TRIP P RIH 11:45 12:00 0.25 6,575 6,845 PROD1 DRILL DLOG P Tie in depth, No correction, RIH throu h window 12:00 12:06 0.10 6,845 6,810 PROW DRILL CIRC P Tag 6845', PUH into casing. Swap hole over to Flow-Vis. 12:06 12:42 0.60 6,810 6,842 PROD1 DRILL TRIP P Offline with Pumps. Close EDC. Record up weights, 23K. RIH to drill. 12:42 12:57 0.25 6,845 6,855 PROD1 DRILL DRLG P On bottom Drilling, 1.4 BPM at 3000psi CTP, 2.6K DHWOB. Stall PUH 25K, Drill Ahead 5-10FPH 12:57 15:57 3.00 6,855 6,915 PROD1 DRILL DRLG P Drilling Ahead, 1.4 BPM at 3080psi CTP, 1K DHWOB, 30 FPM. 15:57 18:57 3.00 6,915 6,975 PROD1 DRILL DRLG P Stall, PU trap psi. RIH, Drill Ahead. 18:57 20:15 1.30 6,975 7,005 PROD1 DRILL DRLG P Continue drilling ahead, 1.5 BPM, circ press. 3250, WHP-180, BHP-3800, ECD-11.60, ROP 12.70, WOB 1.3, CT weight 10,500. 20:15 21:45 1.50 7,005 7,005 PROW DRILL WPRT P Wiper trip up to tie in depth @ 6580. P/U weight 28,500#. No depth correction, check RA tag depth. Correct depth of whipstock ( -2 feet). TOW - 6825.2, RA tag 6830.5, BOW - 6830.2. RIH 21:45 22:45 1.00 7,005 7,055 PROD1 DRILL DRLG P Back on bottom drilling. 1.5 bpm, circ. 3250, WHP 185, BHP - 3800„ ECD 11.6, ROP 20 - 60 fph. Continue drilling ahead, B/U samples A3 show from 7020'. Discuss with town, pull a wiper while talking. 22:45 23:45 1.00 7,055 7,055 PROD1 DRILL WPRT P Wiper trip while town discussion. Decision made to POOH. 23:45 00:00 0.25 7,055 5,000 PROD1 DRILL TRIP P POOH to swap BHA to 1.4 AKO 8/28/2009 RIH with 1.4 AKO BHA #3. Start drilling from 7055'. Slow ROP most of the day, drilled into clay formation 7394'. Formation indicated Lower A2, start to turn u 7452' to 94 degrees. 00:00 02:00 2.00 5,000 0 PROW DRILL TRIP P POOH to switch motor AKO from 1.1 to 1.4. 02:00 04:00 2.00 0 0 PROW DRILL PULD P Undeploy/Deploy - Change AKO to 1.4 - bit looks good. Re -run entire BHA. 04:00 07:00 3.00 0 6,575 PROD1 DRILL TRIP P RIH Page 3of18 r] Time Logs Date From To Dur S. De th E. Decith Phase` Code Subcode T - ,Comment 07:00 07:15 0.25 6,575 7,055 PROW DRILL DLOG P Tie in Depth with Gamma, No Correction. RIH to Drill 07:15 09:00 1.75 7,055 7,149 PROD1 DRILL DRLG P Perform Weight check 27K. Drill Ahead 60 FPH, 1.6K DHWOB, 1.4 BPM, 3100psi CTP, 10K CTW, 170 si WHP, 09:00 09:15 0.25 7,149 7,205 PROD1 DRILL DRLG P Weight check 27500 CTW, Drill ahead 1.3K DHWOB, 50 FPH, 1.5 BPM, 3150 si CTP, 11 K CTW 09:15 10:09 0.90 7,205 6,850 PROD1 DRILL TRIP P Wiper Trip to 6850'. 29K up weight. 10:09 10:48 0.65 7,205 7,257 PROD1 DRILL DRLG P Drill Ahead 1.4K DHWOB, 83 FPH, 1.5 BPM 3200 si CTP. 10:48 12:48 2.00 7,257 7,355 PROD1 DRILL DRLG P Drilling Ahead 60 FPH, 2K DHWOB, 1.5 BPM, 3250 si CTP. 12:48 14:03 1.25 7,355 6,850 PROD1 DRILL TRIP P Wiper trip to 6850'. 29K. 14:03 14:48 0.75 7,355 7,390 PROD1 DRILL DRLG P On bottom drilling 2K DHWOB, 100 FPH, 1.5 BPM, 3350psi CTP, 195psi WHP, 3900 BHP. 14:48 16:18 1.50 7,390 7,410 PROD1 DRILL DRLG P Slow drilling 3K DHWOB, 10FPH, 1.5 BPM, 3400 si CTP 16:18 16:33 0.25 7,410 7,415 PROD1 DRILL DRLG P PUH BHA length, 30K, RIH to drill. ROP Increased. 50 FPH. Clay in returns, possible bit balling. Mix 50 bbrls 1 % Drill Zone. For sweeps. 16:33 18:00 1.46 7,415 7,430 PROD1 DRILL DRLG P ROP dropped off 10 FPH. PUH BHA length to wipe BHA. 30K RIH to drill. Continue drilling ahead with 50 bbl ill. 18:00 19:30 1.50 7,430 7,460 PROD1 DRILL DRLG P ROP ranging from 8 - 40 fph, Discussion of drilling into clay indicates we need to turn up sharply. Geo's feel we are in lower A2 formation. Turning up from 87 to 94 degrees @ 7450' 19:30 20:54 1.40 7,460 7,485 PROD1 DRILL DRLG P Quick wiper 100' to ensure good hole cleaning., P/U weight 28500#, 1.5 bpm, Circ 3300, BHP 3900, ECD 11.80, ROP 30 fph, WHP 180 psi. Continue drilling ahead. 20:54 22:12 1.30 7,485 7,500 PROD1 DRILL DRLG P Another quick 100 ft wiper, slight weight gain to 29000#, Back on bottom drilling, pump second 10 bbl pill. ROP still slow, no improvements 10 fph. 94 degree @ bit, 5000# surface Ct weight, WOB 2.0, 1.5 BPM, Circ 3400, BHP 3900, ECD 11.80. Slow ROP 6 fph. 22:12 23:36 1.40 6,830 7,500 PROD1 DRILL WPRT P Wiper trip to window, include tie in. CT weight 29,000#, 1.5 bpm, 3450 psi, WHP 185, ECD 11.80, BHP 3950, no losses or gains. Choke seems to be plugging off, swap and flush choke at surface while performing wiper. Page 4 of 18 L 0 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:36 23:59 0.39 7,500 7,511 PROD1 DRILL DRLG P Back on bottom drilling. Better ROP 15 fph, BHP 3900, ECD 11.80, 1.6 BPM, 3600 psi, CT weight 7000#, WOB 1.4. Bit inclination 94 degree. 8/29/2009 Drilling ahead from 7511'. Swapped to new mud system @ 7000' and began pumping 10 bbl visc. pills every 50' to clean up shales. Large shale chunks in returns throughout the day, cleared up after 20:00 hrs. Slight over ulI detected 7500' durin wipers. 00:00 02:00 2.00 7,511 7,542 PROD1 DRILL DRLG P Drilling Ahead. ROP 12 fph, 95 degree inclination, ECD 11.80, BHP 3940, 1.6 BPM @ 3700psi, CT weight 6800#, WOB 2.8. No losses or gains in last two hours. Returns indicate still in upper Al Lower A2 formation. 02:00 02:18 0.30 7,542 7,542 PROW DRILL WPRT P Wiper up 100' Slower ROP's. CT weight 28,500#. 02:18 03:48 1.50 7,542 7,587 PROD1 DRILL DRLG P Back on bottom drilling. ROP picked up once on bottom to 60 fph. 1.6 BPM, 3600 psi, BHP 3930, ECD 11.80, CT weight 7000#, WOB 1.2. 03:48 04:12 0.40 7,587 7,587 PROD1 DRILL DRLG P Quick 100 ft wiper. ECD & BHP slightly dropped. 11.70 & BHP 3800 psi. 04:12 05:12 1.00 7,587 7,604 PROD1 DRILL DRLG P Back on bottom drilling. 1.6 bpm, 3650 psi, BHP 3900, ECD 11.75, ROP 15 fph, WOB 2.3, CT weight 5500#. Begin steering up from 94 to 95+ degrees. Formation indicating still in upper Al, Lower A2 formations. 05:12 05:48 0.60 7,604 7,650 PROD1 DRILL DRLG P Drilling in better formation. ROP 60 fph, CT weight 8000#, WOB 1.45, BHP 3900, ECD 11.8, WHP 190. 05:48 07:09 1.35 7,650 6,850 PROD1 DRILL TRIP P Wiper trip, CT weight 29,000# off bottom. Set up for mud swap at the end of Wiper trip. RIH to drill 07:09 09:30 2.35 7,650 7,714 PROD1 DRILL DRLG P On bottom drilling 50 FPH, 1.7K DHWOB, 1.5 BPM, 3300psi CTP, 9000lbs CTW. New mud around. Bypassing Micro Motion to rebuild "MPD Choke B" 09:30 09:42 0.20 7,714 7,610 PROD1 DRILL TRIP P PUH 28K, BHA Wiper. RIH to drill 09:42 10:42 1.00 7,714 7,760 PROD1 DRILL DRLG P Drill Ahead 15 FPH, 2K DHWOB, 1.5 BPM 3300psi CTP. 180 WHP, 3900 BHP 10:42 11:42 1.00 7,760 7,785 PROD1 DRILL DRLG P Drilling Ahead 25 FPH, 2K DHWOB, 1.5 BPM 3200psi CTP, 180psi WHP, 3900psi BHP. 11:42 12:42 1.00 7,785 7,805 PROD1 DRILL DRLG P Drilling Ahead 70 FPH, 2K DHWOB, 1.5 BPM 3280psi CTP, 175psi WHP, 3950 si BHP. 12:42 14:27 1.75 7,805 6,850 PROD1 DRILL TRIP P Wiper Trip back to 6850'. pick up 30K. 7508' 5K over pull, RIH 100'. PUH, No over pull seen on second attempt. Continue wiper trip. Page 5 of 18 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:27 15:42 1.25 7,866 7,866 PROW DRILL DRLG P On bottom drilling, 30 FPM 1.7 BPM. 1.5 BPM 3300psi CTP. 160psi WHP, 3900psi BHP. Bypassed Micro Motion to blow back. Found shale in MM and across shaker. Dime to Quarter size. Possible shale laying in low TVD area of lateral, 7508' overpull area. Mix 50bbrl high vis fluid for pills. WHP and out flow rate stabilized. Shale cuttings building up in MM. 15:42 16:09 0.45 7,866 7,881 PROD1 DRILL DRLG P Pump 10bbrl pill high vis pill. 16:09 17:39 1.50 7,881 6,850 PROD1 DRILL TRIP P High Vis pill at bit, Wiper trip chasing high vis pill. MM and MP choke plugging up causing irratic WHP and return rate. Large amounts of shale in returns with High Vis pill. Bypass MM to blow back MP choke. Tie in to RA tag. Correct +3.5'. RIH to drill 17:39 19:39 2.00 7,881 7,937 PROD1 DRILL DRLG P Back on Bottom drilling. ROP 30 FPH, 1.5 bpm @ 3300 psi, WHP - 190, BHP 3950, ECD 11.80, WOB 1.5, CT surface weight - 6200#. Pumping 10 bbl high vis pill every 50 ft drilled. 19:39 21:15 1.60 7,937 7,980 PROD1 DRILL DRLG P Quick 100 ft wiper to check for weight and cuttings. CT weight 29, 500#. Continue drilling ahead. Visc. pill @ surface, smaller shale particles, plugging off MM. ROP 40 FPH. 21:15 23:03 1.80 7,980 7,980 PROW DRILL WPRT P Pump 10 bbl sweep, Once at bit start Wiper trip to Window. CT weight 30,000#. Slight over pull of 5K @ 7580. Choke plugging off during top of wiper. Swap chokes and clean the system. No big shale chunks found, smaller packed off cuttings. 23:03 00:00 0.95 7,980 8,020 PROD1 DRILL DRLG P Back on bottom drilling. ROP 60 fph, 1.5 BPM, 3300 psi, WHP 180, BHP 3950, ECD 11.80, WOB 1.65, CT weight 3500.. Pumping 10 bbl sweeps every 50 ft. 8/30/2009 Drilled ahead to 8084'. During Wiper had numerous over -pulls due to shale formation. POOH, P/U anchored billet. RIH set billet top @ 7010' - 70 Left. Difficult time disconnecting - 60,000# overpull. P/U BHA # 5 RIH and tagged GIL 0 2540'. POOH to change BHA - 15 K Downwei ht on BHA . 00:00 01:00 1.00 8,020 8,056 PROD1 DRILL DRLG P Drilling ahead. Formation samples show we crossed the fault @ 8035'. ROP 60 FPH, 1.5 BPM, 3400 psi, BHP 3950, ECD 11.85, WOB 1.8, CT weight 5000#. Pumping 10 bbls sweeps every 50 ft. 01:00 01:30 0.50 8,056 8,084 PROD1 DRILL DRLG P Turning down 160 right. continue drilling ahead. Possible A-5 formation. Page 6 of 18 • Time Logs Date From To Dur S. De th E. De th Phase Code - Subcode T ` Comment 01:30 03:12 1.70 8,084 6,754 PROM DRILL WPRT X Wiper trip to window. P/U weight 29,500 - 31000. Sweep out the nozzle.. Weight gain to 37,000# @ 7996'. RIH, Slow POOH, weight gain 7915', thick shale return @ surface. Numerous overpulls in the 7550 - 7350 area. Pull past window, looked clean. Stop pumping & open EDC 03:12 05:12 2.00 6,754 0 PROD1 DRILL TRIP X POOH @ 60 fpm, pumping 1.8 BPM to clean the tubing while POOH for Anchored Billet run to sidetrack lateral. Large chunks across the shakers from 1500' to surface. tag at surface, RIH 500' to ensure the surface is flushed. 05:12 06:00 0.80 0 0 PROD1 DRILL CIRC X Flush Chokes and fluid lines at surface. 06:00 06:15 0.25 0 0 PROD1 DRILL SFTY X Crew Change, PJSM for Undeploy 06:15 07:15 1.00 0 0 PROD1 DRILL PULD X Undeploy BHA #3. Lay Down 07:15 10:15 3.00 0 0 PROD1 DRILL SVRG P Service Injector Head, CT Reel. Clean gripper blocks on Injector head. Hammer up 1502 iron inside reel. Disassemble MP Choke "B" and replace stem seal and clean. 10:15 10:30 0.25 0 0 PROD1 DRILL SFTY X Hold PJSM, deploying BHA #4 10:30 11:00 0.50 0 0 PROD1 STK PULD X PU open hole anchor with aluminum billet. MU Coil Track BHA to billet and PDL to well head. 11:00 12:00 1.00 0 0 PROM STK TRIP X Deploy BHA #4 12:00 14:00 2.00 0 0 PROD1 STK TRIP X RIH, bypassing MM, continue servicing 14:00 14:09 0.15 6,580 6,596 PROD1 STK DLOG X Tie in depth with gamma, Correction +2' 14:09 14:18 0.15 6,596 6,789 PROM STK WPST X RIH to set Billet. Perform weight check at 6789'. 30K up, 11 K , IH. Offline with pumps, bleed CT and close EDC. 14:18 14:27 0.15 6,789 7,035 PROM STK WPST X Orient TF 70L and lock in TF. RIH through window past setting depth. PUH to 7021'. Page 7 of 18 b�� Time Logs Date From ' To Dur S. De th E. De thPhase Code Subcode T Comment 14:27 15:06 0.65 7,035 7,021 PROW STK WPST XT PUH to 7021'placing top of billet at 7010'. TF at 70L. Shut pump in on CT. Online with pumps minimum rate to set billet. Start.5 BPM slowly increasing rate to 2.46 BPM at 4650psi CTP with -8K DHWOB, indication of shearing. Set down 4K DHWOB. Confirmed Billet is set. PUH 38K up weight cannot release off. STOP. RIH to neutral weight. Online with pumps .75 BPM 2100 psi CTP, PUH 35K, -9K DHWOB cannot release. Increase pump psi. 2.14 BPM 4500psi CTP at surface and down hole and -12K DHWOB. Cannot shear off of Billet. RIH to neutral weight, continue to pump .5 BPM. Rethink next step. 15:06 15:21 0.25 7,021 7,021 PROD1 STK WPST XT Online with pumps 4000psi CTP at 1.8 BPM, PUH to max 18K DHWOB. 48K CTW. Cannot release off of billet. RIH to neutral weight. Drop pump rate to .9 BPM. Mix up a high vis 100K LSRV pill to pump down hole to try and release. 15:21 16:03 0.70 7,021 6,800 PROD1 STK WPST XT Offline with pumps. 700psi CTP. PUH to 60K to try and release off of billet. POP free at 60K CTW. POOH. through window. Open EDC above window. 16:03 18:33 2.50 6,800 0 PROD1 STK TRIP X POOH 18:33 19:03 0.50 0 0 PROD1 STK SFTY X Pre-jop safety meeting, flush Choke B & fix electronic problems. 19:03 21:03 2.00 0 0 PROD1 STK PULD X Undeploy BHA. Setting Stinger in tact but the O-rings in the EDC are damaged. Make BHA adjustments as per town conversations 21:03 22:33 1.50 0 0 PROD1 STK PULD X P/U BHA #5 Bi-center & 2.2 AKO, total len ht of BHA 62.41 22:33 23:33 1.00 0 2,540 PROD1 STK TRIP XT RIH, Set down weight hard @ 2540 ft. ( - 15K down on BHA - 21,000 on CT weight) Well schematics show GLM. Pressures look good, good communication with BHA. RIH 5' and weight was good. 23:33 00:00 0.45 2,540 1,000 PROD1 STK TRIP XT POOH to inspect BHA & Bit. MAx. stack out weight for BHA is 6000. 8/31 /2009 Deploy BHA #6 with 2.2 AKO. RIH & KO billet @ 7010', only 1 stall recorded near bottom of KO point.(looked good). rill build section, pump problems for 2 hours, continue drilling down to 7136'. POOH to swap BHA's. 00:00 00:30 0.50 1,000 0 PROD1 STK TRIP XT POOH to swap out BHA # 5. 00:30 01:00 0.50 0 0 PROW STK SFTY X Have a discussion of past 24 hours of near misses and what the crews should do to go in the right direction. Pre- Undeploy TBT. Page 8 of 18 0 • Time Logs Date- From To Dur S. De th E. De th Phase Code Subcode T ' Comment 01:00 02:30 1.50 0 0 PROD1 STK PULD X Begin undeploying BHA #5. Bit has a very small nick missing on the side of the bit. No damage to cutters or bottom of the bit. Swap out BHA. 02:30 04:00 1.50 0 0 PROD1 STK PULD X Deploy BHA # 6. with 2.2 AKO. Well is not taking any rate while de to in /unde to in . 04:00 05:45 1.75 0 6,850 PROD1 STK TRIP X Start to RIH. Slowdown near 2200 - 2500 ft. Lightly tagged up again @ 12540 ft. P/U and orient motor. Ran through smoothly. 05:45 05:57 0.20 6,575 6,590 PROD1 STK DLOG X Tie in depth with Gamma. Correction -1.5'. RIH 05:57 06:12 0.25 6,590 6,820 PROD1 STK TRIP X Record PU weights before window. 29K up, 11K RIH, RIH through window. Did not see any DHWOB with 2.2 AKO. Close EDC 06:12 06:27 0.25 6,820 7,010 PROD1 STK TRIP X Dry Tag top of billet, PUH 10', 30K CTW. Online with pumps 1.5 BPM 3100psi CTP. Hold 180psi WHP 3750psi BHP. 06:27 07:27 1.00 7,009 7,010 PROD1 STK KOST X Start time drilling 7009.35'. 180psi WHP, 3750 BHP, 1 FPH 07:27 08:27 1.00 7,010 7,011 PROD1 STK KOST X Continue drilling 1 FPH, 1.5 BPM at 3162psi CTP, 180psi WHP, 3750psi BHP. 08:27 09:12 0.75 7,011 7,012 PROW STK KOST X Increase ROP 2 FPH, 1.5 BPM at 3177psi CTP, 180psi WHP, 3750psi BHP. 09:12 11:27 2.25 7,012 7,033 PROD1 STK KOST X Increase ROP to 4-5 FPH. 1.5 BPM at 3200psi CTP, 180psi WHP, 3750psi BHP. 11:27 12:57 1.50 7,033 7,045 PROD1 STK KOST X Stall PUH 28K, RIH continue drilling 12:57 18:27 5.50 7,045 7,118 PROD1 DRILL DRLG X Drill ahead 18:27 18:57 0.50 7,118 7,125 PROD1 DRILL DRLG X Getting slow ROP, P/U to bottom of billet. CT weight 28,000K off bottom. Back on bottom drilling. Back on bottom drilling. ROP 60 fpm, circ press 3300, BHP 3800, WOB 1.3, ECD 11.6 18:57 19:27 0.50 7,125 6,750 PROD1 DRILL WPRT XT Pump went down, Motor problems. Shut in choke. Having problems switching to pumps. Pull CT all the way out the window until pumps are operational. 19:27 20:57 1.50 6,750 7,125 PROD1 DRILL EQRP XT Op en EDC - start pumping with a limp pump a full B/U. Watch returns in case the well came in while the pumps were down. Stop and fix pump to finish build section. 20:57 21:57 1.00 7,125 7,136 PROD1 DRILL DRLG X Back on bottom drilling. ROP 50 fph, 1.5 bpm @ 3400 psi, WHP 170 psi, BHP 3860, ECD 11.65 WOB 1.8, CT weight 7800#. TD build section POOH slowly to billet. Back ream Billet section 25 left then 15 left, to ensure billet is clean. Page 9 of 18 0 • Time Logs Date From To Dur S. De th E. De th`Phase Code Subcode T ` Comment 21:57 00:00 2.05 7,136 0 PROD1 DRILL TRIP X POOH to swap BHA's. Stop above window & open EDC. 9/01 /2009 Deploy BHA #7, 1.2 AKO, Bi-Center and Resistivity. Tie in for -3.5' correction. MAD Pass Build section. Drill Ahead per plan 00:00 00:30 0.50 0 0 PROD1 DRILL SFTY X Hold pre-undeploy safety meeting. Discuss how we will be breaking down BHA - different than normal operation. 00:30 01:12 0.70 0 0 PROD1 DRILL PULD X Undeploy BHA # 6. 01:12 02:00 0.80 0 0 PROD1 DRILL PULD X Change out BHA compenents at surface. Bit guaged to 1:1. 02:00 03:00 1.00 0 0 PROW DRILL PULD X Deploy BHA # 7. 03:00 04:45 1.75 0 6,580 PROW DRILL TRIP X RIH, slowing down at SSSV and GLM 04:45 04:54 0.15 6,580 6,800 PROD1 DRILL DLOG X Tie in depth with gamma, -3.5' correction, continue RIH 04:54 05:24 0.50 6,800 7,136 PROD1 DRILL TRIP X Stop CT, Offline with pumps, Close EDC. RIH through window Odeg TF. Slide through w/o any DHWOB. 05:24 06:54 1.50 7,136 7,295 PROW DRILL DRLG X Tag 6' high. 7130'. Drill Ahead 90 FPH, 2.7K DHWOB, 1.4 BPM with 3470psi CTP. 3200psi off bottom CTP. Holding 180psi on WHP, 3900 si BHP, 11.7 ECD. 06:54 07:54 1.00 7,295 7,295 PROD1 DRILL TRIP X Wiper Trip to 6850', 28K pick. Decrease pump rate to minimum rate pulling throw h billet 7020-7000'. 07:54 09:24 1.50 7,295 7,410 PROW DRILL DRLG X Drill Ahead 80-100 FPH, 1.5-2K DHWOB, 1.44 BPM with 3150psi off bottom psi, 3500psi on bottom. 180psi WHP, 3900psi BHP, 11.8 ECD. 09:24 10:24 1.00 7,410 7,445 PROW DRILL DRLG X Drilling Ahead 80-100 FPM, 2K DHWOB, 1.44 BPM, with 3500psi CTP, 160psi WHP, 3950psi BHP, 11.8 ECD. A-2 formation. 10:24 11:24 1.00 7,445 7,445 PROD1 DRILL WPRT X Wiper trip to window. CT P/U weight 29, 000#. 11:24 13:18 1.90 7,445 7,595 PROW DRILL DRLG X Back on bottom drilling. 1.5 bpm 3300 psi, BHP 3900, ECD 11.80, WOB 1.5, CT weight 7000#, ROP 70 FPH. A-2 sands. 13:18 14:18 1.00 7,595 7,595 PROW DRILL WPRT X Wiper trip, P/U weight 29,000#. Tie in - zero correction. 14:18 15:18 1.00 7,595 7,650 PROW DRILL DRLG X Back on bottom drilling - 1.6 BPM, 3500 psi, BHP 3950, ECD 12.0, WOB 1.5, CT weight 6000#. ROP 70 FPM. (increase pump rate from 1.45 to 1.57) to see if it helps the oil content in teh mud. Current mud system has 1000' drilled so far. 15:18 15:48 0.50 7,650 7,650 PROD1 DRILL WPRT X Quick wiper trip while MWD reset computers. CT weight 28,000# 15:48 16:48 1.00 7,650 71745 PROD1 DRILL DRLG X Back on bottom drilling. 1.56 bpm, 3500 psi, ECD 11.90, WOB 1.4, ROP 110 f h. Page 10 of 18 C� • Time Logs , Date From To `- Dur S. De th E. De th Phase Code Subcode T Comment 16:48 18:03 1.25 7,745 7,745 PROW DRILL WPRT X Wiper to window, 29K PUW 1.55 BPM 3500 18:03 20:03 2.00 7,745 7,895 PROD1 DRILL DRLG X 7445' Drill Ahead 1.52 BPM @ 3500 PSI FS 5.4K RIW 20:03 21:33 1.50 7,895 7,895 PROD1 DRILL WPRT X 7895 Wipe to Window, Saw shales on shakers, Geo's say we past fault 1. No overpulls or setdowns on trip. Plan is to stick to plan #9 21:33 00:00 2.45 7,895 8,036 PROD1 DRILL DRLG X 7895', Drill ahead 1.5 BPM @ 3500 PSI, ECD 12.1 4100lbs W 1.3 Ibs WOB 9/02/2009 Swapped out Mud System, Continue drilling with BHA#7 from 8036 to 8655. On drilling plan #9 towards tanned TD of 9255 00:00 00:15 0.25 8,036 8,045 PROD1 DRILL DRLG X Drilling Ahead @ 8036 Midnight depth 00:15 01:15 1.00 8,045 6,855 PROW DRILL WPRT X Wiper trip to window, 1.55 @ 3625 FS 29K PUW 10k RIW 01:15 01:30 0.25 6,855 6,871 PROD1 DRILL DLOG X Tie into RA tag. +8 foot correction, RBIH 01:30 02:30 1.00 6,871 8,052 PROD1 DRILL WPRT X I Continue wiper trip to bottom 02:30 02:45 0.25 8,052 8,084 PROD1 DRILL DRLG X 8052 Drill Ahead. 1.57 BPM @ 3860 FS 3K RIW BHP=4077 12.2 ECD 02:45 04:45 2.00 8,084 8,195 PROD1 DRILL DRLG P 8052 Drill Ahead. 1.57 BPM @ 3860 FS 3K RIW BHP=4077 12.2 ECD At 8084 back on planned time Drill solids at .85, LSRV 36K 04:45 06:45 2.00 8,195 8,195 PROD1 DRILL WPRT P Wiper trip. 06:45 07:45 1.00 8,195 8,210 PROD1 DRILL DRLG P Back on bottom drilling. 1.5 BPM, 3800 PSI, BHP, 4100, ECD 12.17, WHP 150, WOB 2.66, CT WEIGHT 2100, ROP 20 FPH ( POSSIBLE ANCHERITE). Begin mud swap. 07:45 10:15 2.50 8,210 8,303 PROD1 DRILL DRLG P New mud going down the CT. Continue drilling ahead, Slow ROP - ancherite. Drilled through the ancherite @ 8224'. Total of 14 ft. Continue drilling ahead, turn the bit to hold 90 degrees. 10:15 13:45 3.50 8,303 6,850 PROD1 DRILL WPRT P Wiper trip - CT weight 29,500, 1.5 BPM 3300psi, BHP 3900, ECD 11.80, WHP 160 psi. Light traces of shale in returns to surface. 13:45 15:15 1.50 8,303 8,303 PROD1 DRILL DRLG P No problem seen through window, rih wt=9300#. Back on bottom drilling. 1.5 BPM, 3600 PSI, BHP, 3960, ECD 12.10, WHP 290, WOB 1.32, CT WEIGHT 9000, ROP 80 FPH. Continue to Drill Ahead. Page 11 of 18 n L J TimeLogs Date From To Dur S. De th E. De th Phase Code - Subcode T Comment 15:15 16:51 1.60 8,303 8,415 PROD1 DRILL DRLG P Turn bit inclination to 95 degree then 100 degree @ 8344' to start chasing the fault. All drilling parameters still the same. Light trace of oil stringers in the returns. ROP - 10 FPH @ 8415'. 16:51 17:21 0.50 8,415 8,420 PROD1 DRILL DRLG P ROP - 10 fph, 100 degree inclination, 1.5 BPM, 3500 PSI, BHP-4100, ECD12.1, WOB 2.3, CT WEIGHT 8300'. 17:21 17:36 0.25 8,420 8,450 PROD1 DRILL DRLG P ROP UP TO 90 fph @ 8420', 95 deg inclination, 1.5 BPM, 3600 PSI, BHP-4080, ECD 12.2, WOB 1.5. 17:36 18:21 0.75 8,450 8,500 PROD1 DRILL DRLG P PERFORM 100' SHORT TRIP PICK-UP @ 8450', UP WT=28K, 1.5 BPM, 3450 PSI, BHP-4100.CLEAN PICK-UP.CONTINUE W/ DRILLING OPERATION DOWN TO 8500' BEFORE STARTING THE NEXT WPRT. 18:21 21:03 2.70 8,505 8,507 PROD1 DRILL WPRT P Wiper trip. CT WT 28K 1.5 BPM, 3600psi, bhp=4115, ECD 12.30, WHP=275PSI, Clean up wt. ROP was 113' FPH. Performed Tie In +1.5 feet Tight spot @ 7125 coming up, Set down 7955, Adjusted TF and went right through 21:03 22:03 1.00 8,507 8,602 PROW DRILL DRLG P 8507' Drill ahead. 1.51 BPM @ 3300, BHP=4050, ECD=12.3Dropped WHP to 160 from 250. ROP 55 FPM at 50R TF Near Bit 95.6 WOB 1600 5K RIW 22:03 23:33 1.50 8,602 8,620 PROD1 DRILL DRLG P 8603, Drilling ahead, Hit Anchorite, ROP 5 to 7 FPH 23:33 00:00 0.45 8,620 8,655 PROD1 DRILL DRLG P Drilled to 8655 at midnight PUW 25K 1.49 BPM @ 3360 BHP=4060 Wiper to window 9/03/2009 Spent much of day in Anchorite, 258' last 24 Hours. Broke out @8819. Added lubes to system to achieve 2% concentration of 776 and Lo-Tork 00:00 02:30 2.50 8,655 6,830 PROD1 DRILL WPRT P On wiper trip from 8655 to window, 1.5 BPM @3250 FS OverPull @ 7139, Setdowns @ 7939 and 8415 02:30 06:30 4.00 8,655 8,719 PROD1 DRILL DRLG P 8655 Drill Ahead, 1.53 @ 3480 FS, 90L TF 4480 RIW, BHP=4060, ECD=12.1 Hold 98 degrees Inc. Back in Anchorite very low ROP's 06:30 09:30 3.00 8,719 8,619 PROD1 DRILL WPRT P 8719', 1.55 @ 3575psi, BHP=4065, ECD=12.2, 94 degrees inc. Still in Anchorite low ROP's @ 5.3. Puh 100' for short trip. Up wt=28k-30k, wh =240 si. 09:30 09:45 0.25 8,719 8,735 PROD1 DRILL DRLG P 8719' continue to drill ahead, 1.54 @ 3560psi, BHP=4072, ECD=12.2 / ROP's 6.8, WOB 2.75. Page 12 of 18 0 Time Logs Date From To = Dur S. De th E. De thPhase Code Subcode T Comment 09:45 13:00 3.25 8,735 8,635 PROW DRILL WPRT P 8735', puh 100' short trip (100') Still slow ROP's @ 4.3.WOB 2.74, ECD=12.2. 1.55 @ 3550psi. 4060psi BHP. UP WT=29 13:00 13:15 0.25 8,735 8,735 PROW DRILL DRLG P Back down 8735' rih wt= 4700, continue W/ drilling operation @ 1.5 bpm, 3580psi, ECD's 12.2 / WOP= 2.3 / ROP=5.3 FPH 13:15 14:39 1.40 8,735 8,780 PROD1 DRILL DRLG P Drilling break @ 8740' RIH WT=5k / WOP 1.65 / ROP 88, ECD's 12.2. BHP=4066. 14:39 17:39 3.00 8,780 6,850 PROD1 DRILL WPRT P SLow ROP again.. Pull a wiper to window to check on hole condition (drilling for 12 hours without a short trip). P/U weight 30,000#. Two small overpulls 80' off bottom to 35,000. More overpulls @ 7140'. Worked BHA & pipe through a couple fo times at build section. Pull up to window then RIH and wipe from 7146.0 to window again 17:39 20:39 3.00 8,780 8,780 PROD1 DRILL DRLG P Back on bottom drilling 20:39 22:24 1.75 8,780 8,819 PROD1 DRILL DRLG P Still slow drilling, Plan is to drop angle out of Anchorite 1.52 BPM @ 3450 FS BHP=4097 ECD=12.3 WHP=240 22:24 00:00 1.60 8,819 8,828 PROD1 DRILL DRLG P 8819 - ROP to 20 FPH, 8828 - 60FPH Out of Anchorite 1.55 BPM @ 3450 FS 5200LBs RIW 1.41K WOB BHP 4071 WHP=200 ECD 12.2 8,828 8,913 PROD1 DRILL DRLG P Depth @ Midnight, ROP=60 FPH 1.55 BPM @ 3450 FS 90R TF 9/04/2009 TD well @ 9382 Corrected, Lay in Beaded liner running pill, POOH, trap pressure and Shut In SSSV, Monitor well, Pull BHA #7, Prepfor runnino liner 00:00 00:15 0.25 8,913 5 PROW DRILL DRLG P 8913' Drill Ahead 00:15 02:15 2.00 8,935 6,850 PROD1 DRILL WPRT P 8935 Wiper Trip to Window and Tie In PUW 30k, 1.55 BPM @ 3500 Tight spot and overpulls at 7140 to 7110 02:15 02:30 0.25 6,850 6,888 PROD1 DRILL DLOG P Perform Gamma Ray Tie, +4 02:30 04:15 1.75 6,888 8,937 PROD1 DRILL WPRT P RIH, RIW=10100lbs Work tight area from 7110 to 7140, still a little tight at 7114, Continue in hole. 04:15 05:15 1.00 8,937 9,085 PROD1 DRILL DRLG P 8937' Drill Ahead with 80 to 90R TF 1.50 BPM @ 3500 PSI FS BHP=4100 ECD=12.2 ROP 100 FPM 05:15 09:15 4.00 9,085 6,850 PROD1 DRILL WPRT P Wiper trip to window. having problems getting to TD due to weight slacking off at surface @ 8900'. Page 13 of 18 C� Time Logs Date From To -' Dur S. De th E. De th Phase Code -- Subcode T Comment 09:15 09:45 0.50 9,085 9,235 PROD1 DRILL DRLG P Back on bottom drilling - 1.5 bpm, 3400 psi, WHP 180, BHP 4000, ECD 12.2, WOB 1.0, CT weight - 5000#. 09:45 12:15 2.50 9,235 9,115 PROM DRILL WPRT P 9,230 Short Trip (150').PUW 28k, 1.52 BPM @ 3530. 12:15 12:45 0.50 9,235 9,270 PROD1 DRILL DRLG P Back on bottom drilling ahead-1.5 bpm, 3480 psi, WHP 180, BHP=4080, ECD 75, WOB 1.1, CT wt-1400# 12:45 16:30 3.75 9,270 6,850 PROM DRILL WPRT X Wiper to window. P/U weight off bottom 28,000#. 1.5 bpm, 3400 psi, WHP 150, BHP 4080, ECD 12.2. Seen small overpull @ 7,111.Rih to bottom / RIH wt= 9800# 16:30 20:30 4.00 9,270 9,374 PROD1 DRILL DRLG X Back on bottom drilling @ 1.5 bpm, 3675 psi, ECD=12.3 / BHP=4080 / WOB-1.2, CT WT= -1100# 20:30 23:00 2.50 9,374 6,850 PROD1 DRILL WPRT X. Call TD, Pull up hole to Tie In, 7115 overpull 1.5 BPM @ 3620, BHP=4010 23:00 23:15 0.25 6,850 6,867 PROD1 DRILL DLOG P Tie into RA marker, + 12.5', will inspect counters at surface 23:15 00:00 0.75 8,781 8,781 PROD1 DRILL WPRT P RIH to Tag bottom and confirm TD Midni ht Depth 8781 Tripping in 9/05/2009 MU & Run lower section of liner@ 9382' / top of lower section @ 8245'. MU upper section of liner. Tie in to formation @ 6580 for a +4' correction, Set liner 8243, TOL=6818.3 00:00 00:15 0.25 8,781 9,382 PROM DRILL WPRT P RIH to Tag TD 00:15 03:00 2.75 9,382 1,800 PROM DRILL TRIP P Tag TD @ 9382 Corrected, POOH laying in 28 BBI liner running pill With 2LBS/BBL Alpine Beads Paint EOP Flag @ 8100 & 5500 EOP flags 03:00 03:30 0.50 1,800 1,800 PROM DRILL TRIP P PJSM W DSO, Trap 780 PSI, S/D Pump, Dump SSSV at Rig Floor, Monitor well for returns 03:30 04:00 0.50 1,800 0 PROD1 DRILL TRIP P SSSV Holding, Continue out of well fill across the to 04:00 04:15 0.25 0 0 PROM DRILL SFTY P Tag Up and monitor well, PJSM pull BHA #7 04:15 05:15 1.00 0 0 PROM DRILL PULD P Unstab injector from well, break off coil, Flush and Blow down BHA, Lay down BHA #7 05:15 06:15 1.00 0 0 COMPZ CASING PULD P Prep for liner running 06:15 07:15 1.00 0 0 COMPZ CASING SFTY P Pre- job meeting on liner assembly, valve checklist, safety joint inspection. Flo -check for SSSV. 07:15 07:45 0.50 0 0 COMPZ CASING PUTB P P/U first joint. Top drive - High speed not activated. Troubleshoot. Install Safety valve while working on Top drive. 07:45 10:45 3.00 0 1,182 COMPZ CASING RUNL P Start running liner. Safety joint drill performed. 1 solid & 35 slotted P/U & Coiltrack assembly Page 14 of 18 I i' Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:45 11:45 1.00 1,182 1,182 COMPZ CASING SVRG P Stab on Injector head, secure well at surface. Need to perfrom maintanance on CT reel. Locked out equipment 11:45 13:45 2.00 1,182 6,380 COMPZ CASING RUNL P Open EDC, pressure up on well and open SSSV.(DSO). RIH with liner. Slow CT speed while RIH to try and log as per MWD - Not successful 6310'. Stop pumping - Stop CT @ 6400' Close EDC. 13:45 15:45 2.00 6,380 9,380 COMPZ CASING RUNL P RIH with pumps off holding 450 psi on WHP = 3900 BHP @ 6900' ECD 12.3. CTES depth zero correction at flag. Slid through the window & billet @ 30 fpm. CT weight 12,000#. Tag on bottom Liner landed.' 15:45 15:57 0.20 9,381 9,381 COMPZ CASING RUNL P WOB 7K, CT weight @ surface -10,000# P/U weight 31,000. RIH and same spot. 15:57 17:27 1.50 9,381 6,805 COMPZ CASING RUNL —tag P Start pumping beads and release from liner. P/U weigth 25K. POOH to tie in @ 6805'. + 4ft correction. 17:27 18:15 0.80 6,805 1,795 COMPZ CASING RUNL P POOH 18:15 18:45 0.50 1,795 0 COMPZ CASING RUNL P Stop above SSSV, Trap 780 PSI, Shut SSSV monitor well, SSSV holding, Continue to surface filling across top. Monitor well 18:45 19:00 0.25 0 0 COMPZ CASING SFTY P On Surface, Monitor well, PJSM to lay down BHI Tools, discuss safety oint drill. 19:00 19:45 0.75 0 0 COMPZ CASING PULD P Lay down BHA #8 19:45 20:00 0.25 0 0 COMPZ CASING SFTY P PJSM to pick up and lay down liner 20:00 21:30 1.50 0 0 COMPZ CASING RGRP T Troubleshoot draw works for speed control, crown and floor saver. Call out electrician for diagnosis 21:30 00:00 2.50 0 0 COMPZ CASING PULD P Perform safety joint drill - Pick up upper section of liner 9/06/2009 POOH after setting upper liner section.MU and Run & set Lower KB Packer, @ 6809' (TOP). Found some feces of skate bearing in injector sump. Start demob of injector to repair 00:00 00:30 0.50 0 0 COMPZ CASING PULD P I Done making up upper liner section, 00:30 01:00 0.50 0 6,833 COMPZ CASING RUNL P PJSM,Surface test on MWD tools, open EDC, open sssv.Rih with liner pumping @ 1.50 bpm / 3400. WHP= 720 01:00 03:00 2.00 6,833 7,954 COMPZ CASING RUNL P Tie into Red EOP flag @ 5355 (+1469.64=6824.5 Bit) Current BHI Counter is 6832.5 for an -8 Foot correction, CTES Counter 5353.5 Trip in 03:00 03:30 0.50 7,954 8,244 COMPZ CASING RUNL P Tie into cased hole 7954 to 8002 Bit for a +4' Correction, RIH 8150 PUW=28K Page 15 of 18 n L Time Logs Date From To + Dur S. De th E. De th Phase Code Subcode T ' Comment 03:30 03:45 0.25 8,243 8,243 COMPZ CASING RUNL P Tag @ 8244, 9k down weight, P/U 20', re tag, Trap 780 PSI WHP, Shut EDC, Pump on to 4K Release off liner, 21k PUW Bottom of liner @ 8243 TOL @ 6818.3 03:45 06:45 3.00 8,243 0 COMPZ CASING RUNL P POOH following pressure schedule, Close SSSV. 06:45 09:45 3.00 0 0 COMPZ RPEQPI PULD P lay down BHA #10 , Make up and P/U BHA # 11 with bottom section of KB liner top. (total length of BHA 71.72') P/U new EDC with 5/8" ball on seat. 09:45 13:15 3.50 0 6,825 COMPZ RPEQPITRIP P RIH slowy - 50 fpm, circ..5 bpm, WHP 600 psi. Log from 6570-6595' ( -2 ft) correction. Begin CCL log from 6650' RIH. Weight check 21,000#. 13:15 14:15 1.00 6,825 6,825 COMPZ RPEQPI PACK P Stung into seal assembly. Stop Pumping, P/U weight 23,000#Slack off. P/U and orientate to double check. Tagged in the same spot. P/U string weight 21 K. 14:15 14:39 0.40 6,825 6,825 COMPZ RPEQPI PRTS P Close ECD - pressure up on CT slowly to 1700 psi. Packer set. Stop pumping. close choke and pressure up on backside to 1000 psi. Very slight leak off to 950 psi. Hold for 10 min. Start circulating down CT - Shear released @ 3500 psi. Packer -mid-element (6816') & deployment sleeve 6809'. 14:39 17:09 2.50 6,825 0 COMPZ RPEQPITRIP P POOH 17:09 19:00 1.85 0 0 COMPZ RPEQPITRIP P Tag up and close sssv, Monitor for 15 mins. Show small psi @ surface. Function sssv. Monitor for 15 mins.Psi good @ surface.PJSM/Pick up BOT tools. 19:00 20:00 1.00 0 0 COMPZ RPEQPI PULD P Rig back injection and remove setting tools to prep for 2nd packer assembly. Inspect injector. 20:00 21:45 1.75 0 COMPZ RPEQPI RGRP T Found bearing parts in injector sump. Call out mechanic to trouble shoot injector. 21:45 22:45 1.00 0 0 COMPZ RPEQPI RGRP T Found broken section chain bearing. Decision was made to replace chain bearing. 22:45 23:00 0.25 0 0 COMPZ RPEQPI SFTY T PJSM with all personal. Review procedure for removing coil and proper steps on removing coil from injector. 23:00 00:00 1.00 0 0 COMPZ RPEQPI RGRP T Cut off connector and 10' of coiled tubing. Remove coil from injector, remove CTES counter from Horse Head 9/07/2009 Repair injector skate bearings, Replace injector chains 00:00 01:00 1.00 0 0 COMPZ RPEQPI RGRP T Remove CT From injector. Page 16 of 18 • 0 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 06:00 5.00 0 0 COMPZ RPEQPI RGRP T Removing skates from injector. Remove pack off assembly. Remove gripper blocks from chains. 06:00 08:00 2.00 0 0 COMPZ RPEQPI RGRP T Safety meeting on plan formward. Set up to remove chains from injector, install new set of chains while rolling old ones out. 08:00 13:00 5.00 0 0 COMPZ RPEQPI RGRP T Remove skates. 4 skate bearing damaged on the front side of injector (towards the reel). Install all new skate bearings. 13:00 17:00 4.00 0 0 COMPZ RPEQPI RGRP T Switch to generator power, while still working on Injector issues. Moving power lines & cables. Pulling fluid off rig. 17:00 22:00 5.00 0 0 COMPZ RPEQPI RGRP T Injector Skate repairs complete, new chains installed, Gooseneck alignment and stuffing box alignment checked. Rig floor cleaned up. PJSM to re-intall coil into injector 22:00 00:00 2.00 0 0 COMPZ RPEQPI RGRP T Pull test Coil Connector to 35K / BHI begin to head u 9/08/2009 Install Coil Connector and Rehead BHI UQC, RIH with Liner top packer. Pre set packer @ 9063, POOH with no packer. Fish packer, et hung up in upper GLM. F/P and R/D 00:00 00:15 0.25 0 0 COMPZ RPEQPI RGRP T Continue to Head up BHI Upper connect 00:15 00:30 0.25 0 0 COMPZ RPEQPI RGRP —quick T Fliud Pack and pressure test Coil Connector 00:30 01:00 0.50 0 91 COMPZ RPEQPI PULD P PJSM, Open up well, P/U KB straddle Packer and coil track BHA #11, Surface test tool 01:00 01:45 0.75 91 1,800 COMPZ RPEQPITRIP P RIH, EDC Open 01:45 02:15 0.50 1,800 6,093 COMPZ RPEQPITRIP P 1800', Pressure well up to 780 PSI, Pump open SSSV w/ 4350 PSI, Valve is open, Continue in hole 02:15 03:45 1.50 6,093 6,061 COMPZ RPEQPITRIP P Set Down @ 6093 BHI, CTES 5994", -8k Surface weight, No Differential across EDC, Nothing in this area to set down in. RIW 10k. P/U to 38k PUH, looks clean, Attempt to RIH and set down @ 20 FPM @ 4K, P/U to 35K and Start out of well, Overpull @ 6061 Stop and RIH, Stack out. Pull to neutral weight 03:45 04:15 0.50 6,061 6,061 COMPZ RPEQPITRIP T Cannot move Packer from 6062. Get to neutral weight, close EDC and line up to pump off packer, Baker has no other options 04:15 06:45 2.50 6,061 0 COMPZ RPEQPITRIP T Shear off, POOH 06:45 08:45 2.00 0 0 COMPZ RPEQPI PULD T CT @ surface. Close SSSV & monitor well for 15 min. safety meeting for Pulling BHA. Pull BHA - indicator at BOT setting tool had a clean disconnect. Page 17 of 18 r-1 L J r--1 Time Logs Date` from 08:45 To 09:45 Du r 1.00 S. De th 0 E. De th 0 Phase COMPZ Code RPEQPI Subcode FISH T T Comment P/U 2-1/8" Up/down jars with GIEDC circ sub, and coiltrack with new 09:45 11:45 2.00 0 5,900 COMPZ RPEQPI FISH T EDC. Total len ht 41.83'. Open RIH, increase WHP to 700 psi, open SSSV. Taking returns to tiger tank, pumping SSW down CT string. Weight check @ 5900' SSW in the coil and out BHA. P/U weight 20,000#. 11:45 12.45 1.00 5,900 6,028 COMPZ RPEQPI FISH T Stop pumping. RIH slowly tag top of fish @ 6028'. 5K weight on bit. P/U 32K at surface, jars fired. Fish is dragging. Stop RIH, reset jars. continue process. So far 22 hits, P/U weight 35 - 38K, 12K on BHA. Feel hits to surface. Pull weight and hold for 10 min. Packer element is holding us. 12:45 16:15 3.50 6,028 2,521 COMPZ RPEQPI FISH T Popped free on 26th hit. POOH slowly until GLM, pulled heavy again. POOH all the way to top GLM. Could not beat it up through. Discuss disconnecting and POOH with town. (fishing next @ 2521' 16:15 17:30 1.25 2,521 0 COMPZ RPEQPI DISP T Hook up diesel and pump 30 bbls for freeze protect from 2400' to surface. 17:30 19:00 1.50 0 0 COMPZ RPEQPI OWFF T At surface, Shut SSSV, getting gas back to surface, Bleed off then Monitor, After third bleed off rig up to pressure unde to 19:00 20:30 1.50 0 0 COMPZ RPEQPI PULD P PJSM, Pressure Uundeploy BHA and fishing tools Lay down all tools 20:30 22:00 1.50 0 0 DEMOB WHDBO NUND P PJSM, P/U FMC Lubricator, Set BPV in han er 22:00 00:00 2.00 0 DEMOB WHDBO DMOB P PJSM, Liner up Big compressor and start to blow down coil 9/09/2009 00:00 01:00 1.00 0 0 DEMOB WHDBO DMOB P Continue putting 350 PSI Rig air to coil. Evacuated 20 BBLs out of coil before fluid and air stalled. Bleed off at compressor end 01:00 02.30 1.50 0 0 DEMOB WHDBO DMOB P Flushing stack and surface lines with seawater and then blowing down rig 02:30 03:30 1.00 0 0 DEMOB WHDBO NUND P Remove Riser from BOP's, hook up blocks to BOP's. Start nipple down, Lift BOPE from tree. Install Tree to Flan 03:30 04:00 0.50 0 DEMOB MOVE DMOB P 04:06 RIG RELEASE Page 18 of 18 • 3C-14B Pre and Post Rig Events DATE SUMMARY 10 6/18/09 DRIFT TBG W/ 20' X 2.73" SOLID DRIFT, NO RESRICTIONS. TAG @ 6800' SLM. EST 24' OF RATHOLE. APPROX. 15' HIGHER THAN TARGET DEPTH FOR WHIPSTOCK. IN PROGRESS. 6/19/09 BAILED SAND FROM 6803' SLM TO 6822' SLM (-6849' RKB). DRIFT TBG W/ 21' OF 2.73" SOLID DRIFT (DUMMY WHIPSTOCK) TO 6823' SLM (-6850' RKB), NO RESTRICTIONS. JOB COMPLETE. 6/22/09 MEASURED SBHP OF 2258# @ 6795' RKB AND GRADIENT OF 2216# @ 6682' RKB. JOB COMPLETE 7/3/09 SET 3.5" BAKER MONOBORE RETRIEVABLE WHIPSTOCK AT 6828' CORRELATED TO PDC AND PERFORATION RECORD. 2 PIP TAGS INSTALLED IN WHIPSTOCK AT 6833.35'. WHIPSTOCK IS ORIENTED 6 DEG RIGHT OF HIGH SIDE. WEIGHT WAS SLACKED OFF ON WHIPSTOCK TO CONFIRM SET. 7/21/09 PT/DDT- MV/SV- PASSED, DDT-SSV/SSSV -PASSED (PRE-CTD) 7/21/09 TAGGED WHIPSTOCK @ EST. 6828' RKB. SET 2.75" CA-2 PLUG @ 6252' RKB WITH CATCHER @ SAME. PULLED GLV @ 5872' RKB. IN PROGRESS. 7/22/09 PULLED GLVs @ 6172', 5058', 4065' & 2543' RKB. SET DVs @ 5872', 5082', 4065' & 2543' RKB. CIRCULATED 140 BBL DSL, TAKING RETURNS TO PROD. IN PROGRESS. 7/23/09 CIRCULATE 50 BBL DSL TO PROD. SET DV @ 6172' RKB. MIT IA 2500 PSI, PASSED. PULLED CATCHER & CA-2 PLUG @ 6252' RKB. READY FOR CTU. 7/24/09 PERFORMED CEMENT SQUEEZE ON C-SAND PERFS. ESTIMATE APPROXIMATELY 8-BBL BEHIND PIPE BASED ON LOSSES OBSERVED DURING HESITATION SQUEEZE. LEFT WELL SHUT-IN AND FREEZE PROTECTED WITH 1200-PSI AT SURFACE. 7/29/09 TAG TOP OF WHIPSTOCK @ 6800' SLM. MIT TBG TO #1000. MIT PASS. JOB COMPLETE 9/10/09 FISHED 35.89' KB PKR/STINGER ASS'Y @ 2499' SLM (MISSING ALL THREE ANCHORS - - 2 1/8" LONG X 1.33" WIDE X 1/2" THICK). MADE MAGNET RUN TO TOP OF DEPLOYMENT SLV @ 6809' RKB, NO RECOVERY. TAGGED TOP OF DEPLOYMENT SLV W/ 2.67 CENT AND 4.6' PRONG TO CONFIRM CLEAR OF ANY ANCHORS, NO RECOVERY, ANCHORS WILL FALL THRU MIN ID OF 1.73" IN LOWER PKR. IN PROGRESS. 9/11/09 DRIFTED TBG. W/ 2.74" DUMMY PATCH (26' OAL) DOWN TO TOP OF DEPLOYEMENT SLEEVE @ 6809' RKB, SLIGHT BOBBLE @ 5873' RKB (STA#4) WORKED AREA UNTIL SMOOTH. READY FOR PATCH. 9/14/09 SET HALF PATCH ASS'Y (BAKER 35 "KB" PKR, SPACER PIPE & SEAL ASS'Y. OAL=35.89', MIN ID=1.73" W/ DRIFT OF 1.69"). SEALS STABBED IN LOWER BAKER 35 "KB" PKR @ 6810' RKB. TOP 35 "KB" PKR @ 6777' RKB. TESTED TOP KB PKR TO 2500 PSI, GOOD. COMPLETE. 9/16/09 MEASURED BHP @ EST. 7093' RKB: 3572 PSI. NOTE: PULLED 3 HEAVY BINDS (1000 Ibs) WHILE PULLING OUT OF LINER. COMPLETE. C6nocoPhillips laska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-14B 500292142502 Baker Hughes INTEQ Definitive Survey Report 09 September, 2009 • t CcirtocoPh llips Alaska Corhpany:. Conoco Phil Iips(Alaska) Inc. Pro-oct: iKuparuk River Unit Site: Kuparuk 3C Pad N,61 '3C-14 J�/etlbore; 3C-14 Desian: 3C-14 ConocoPhillips Definitive Survey Report 3C-14 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14A (D15) @ 88.45ft (Doyon 15) True Animum Curvature .DM Alaska Prod v16 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 ... Wetly 3,C-14 Well Position +N/S 0.00 ft Northing: 5,995,180.01 ft Latitude: 70° 23' 52.506 N +E/-W 0.00 ft Easting: 528,345.63ft Longitude: 149' 46' 9.594 W Position Uncertainty 0.00 it Wellhead Elevation: ft Ground Level: 47.60 ft Audit Notes: Version: 1.0 Phase: ACTUAL 40.85 Tie On Depth: 7,000.37 0.00 91912009 9:30:38AM Page 2 COMPASS 2003.16 Build 69 LA ConocoRhillips rf ConocoPhillip5 ; Definitive Survey Report f0jams Alaska ^,ornpany: ConocoPhillips(Alaska) Inc. Local Ca -ordinate Reference: " 3C-14 'roject: Kuparuk River Unit TVD Reference: 3C-14A (D15) @ 88.45ft (Doyon 15) Site: Kuparuk 3C Pad MO Reference: 3C-14A (D15) @ 88.45ft (Doyon 15) Mell: 3C-14 North Reference: True Nellbore: 3C-14 Survey Calculation Method: Minimum Curvature 3e wn: 3C-14 Database: EDM Alaska Prod v16 103.45 4,103.45 3C-14 (3C-14) GCT-MS Schlumberger GCT multishot 1/12/2001 4,162.85 6,598.93 3C-14A MWD+SAG+IIFR+CA+MS Doyo MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/26/2008 2/5/2008 6,641.41 6,819.99 3C-14A MWD+SAG+IIFR+CA+MS Doyo MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/18/2008 2/22/2008 6,825.00 7,000.37 3C-14BPB1 (3C-14BPB1) MWD MWD - Standard 8/28/2009 8/29/2009 7,011,00 9,345.30 3C-146 (3C-14B) MWD MWD - Standard 8/31/2009 9/4/2009 ur+ey Map Map .. vertical MD lnc" +�zi " )fV TVDSS +N!-S +J-t/ Northing Lasting; DLS apctlor+urvy S FctrlNatne Atnnfztatic+n. " MY 00 40.85 0.00 0.00 40.85 47.60 0,00 0.00 5.995,180.01 528,345.63 0.00 0.00 UNDEFINED 103.45 0.20 225.45 103.45 15.00 -0.08 -0.08 5,995,179.93 528,345.55 0.32 0.05 GCT-MS (1) 203.45 0.18 232.55 203.45 115.00 -0.29 -0.33 5,995,179.71 528,345.30 0.03 0.18 GCT-MS (1) 303.45 0.22 219.62 303.45 215.00 -0.54 -0.57 5,995,179.47 528,345.06 0.06 0.33 GCT-MS (1) 403.45 0.32 207.59 403.45 315.00 -0.93 -0.83 5,995,179.07 528,344.81 0.11 0.63 GCT-MS (1) 503.45 0.42 170.06 503.45 415.00 -1.54 -0.89 5,995,178.46 528,344.74 0.26 1.19 GCT-MS (1) 603.45 0.08 159.73 603.44 514.99 -1.97 -0.80 5,995,178.04 528,344.83 0.34 1.62 GCT-MS(1) 703.45 0.17 168.38 703.44 614.99 -2.18 -0.75 5,995,177.83 528,344.89 0.09 1.84 GCT-MS (1) 803.45 0.52 162.85 803.44 714.99 -2.76 -0.59 5,995,177.25 528,345.05 0.35 2.44 GCT-MS (1) 903.45 0.63 161.31 903.44 814.99 -3.71 -0.28 5,995,176.30 528,345.37 0.11 3.44 GCT-MS (1) 1,003.45 0.73 157.71 1,003.43 914.98 -4.82 0.14 5,995,175.19 528,345.79 0.11 4.63 GCT-MS (1) 1,103.45 0.67 151.13 1,103.42 1,014.97 -5.92 0.66 5,995,174.09 528,346.32 0.10 5.84 GCT-MS (1) 1,203.45 0.67 143.22 1,203.42 1,114.97 -6.90 1.30 5,995,173.11 528,346.95 0.09 6.96 GCT-MS (1) 1,303.45 0.67 142.19 1,303.41 1,214.96 -7.83 2.01 5,995,172.18 528,347.66 0.01 8.07 GCT-MS (1) 1,403.45 0.70 145.57 1,403.40 1,314.95 -8.80 2.71 5,995,171.22 528,348.37 0.05 9.21 GCT-MS (1) 1,503.45 0.77 157.52 1,503.39 1,414.94 -9.93 3.31 5,995,170.10 528,348.98 0.17 10.46 GCT-MS (1) 1,603.45 0.82 162.25 1,603.38 1,514.93 -11.23 3.79 5,995,168.80 528,349.46 0.08 11.85 GCT-MS (1) 1,703.45 0.55 152,74 1,703.38 1,614.93 -12.34 4.23 5,995,167.69 528,349.90 0.29 13.04 GCT-MS (1) 1,803.45 0.28 142.04 1,803.37 1,714.92 -12.95 4.60 5,995,167.07 528,350.27 0.28 13.74 GCT-MS (1) 9/9/2009 9:30:38AM Page 3 COMPASS 2003.16 Build 69 0 CJ +won co'Phrlllips Aaska nc. Kuparuk River Unit Kuparuk 3C Pad 3C-14 3C-14 3C-14 ConocoPhillips Definitive Survey Report -14 14A (D15) @ 88.45ft (Doyon 15) 14A (D15) @ 88.45ft (Doyon 15) imum Curvature 0 Alaska Prod v16 1,903A5 0.73 133.96 1,903.37 1,814.92 -13.59 5.20 5,995,166.44 528,350.88 0.45 14.53 GCT-MS (1) 2,003.45 4.15 138.73 2,003.26 1,914.81 -16.75 8.05 5,995,163.29 528,353.74 3.42 18.43 GCT-MS (1) 2,103.45 8.25 137.86 2,102.66 2,014.21 -24.80 15.25 5,995,155.27 528,360.98 4.10 28.32 GCT-MS (1) 2,203.45 12.47 135.55 2,201.01 2,112.56 -37.83 27.63 5,995,142.29 528,373.40 4.24 44.56 GCT-MS (1) 2,303.45 16.53 135.90 2,297.80 2,209.35 -55.76 45.10 5,995,124.43 528,390.94 4.06 67.04 GCT-MS (1) 2,403.45 20.97 138.94 2,392.47 2,304.02 -79.48 66.77 5,995,100.79 528,412.69 4.54 96.34 GCT-MS (1) 2,503.45 24.07 139.06 2,484.84 2,396.39 -108.38 91.89 5,995,071.99 528,437.92 3.10 131.64 GCT-MS (1) 2,603.45 24.90 137.93 2,575.84 2,487.39 -139.42 119.36 5,995,041.06 528,465.50 0.95 169.69 GCT-MS (1) 2,703.45 27.90 136.58 2,665.40 2,576.95 -172.05 149.55 5,995,008.55 528,495.82 3.06 210.11 GCT-MS (1) 2,803.45 30.62 142.11 2,752.65 2,664.20 -209.15 181.29 5,994,971.57 528,527.69 3.83 255.26 GCT-MS (1) 2,903.45 33.78 147.02 2,837.28 2,748.83 -252.59 212.07 5,994,928,25 528,558.64 4.10 306.13 GCT-MS (1) 3,003.45 35.83 149.05 2,919.39 2,830.94 -301.02 242.26 5,994,879.94 528,589.01 2.35 361.56 GCT-MS (1) 3,103.45 37.12 143.57 2,999.82 2,911.37 -350.41 275.24 5,994,830.68 528,622.17 3.50 418.78 GCT-MS(1) 3,203.45 39.17 137.40 3,078.49 2,990.04 -397.96 314.56 5,994,783.28 528,661.66 4.33 476.21 GCT-MS (1) 3,303.45 40.80 133.41 3,155.12 3,066.67 -443.67 359.68 5,994,737.75 528,706.95 3.04 533.72 GCT-MS (1) 3,403.45 42.38 134.68 3,229.91 3,141.46 -489.82 407.38 5,994,691.78 528,754.82 1.79 592.44 GCT-MS (1) 3,503.45 42.40 135.55 3,303.77 3,215.32 -537.59 454.96 5,994,644.20 528,802.58 0.59 652.66 GCT-MS (1) 3,603.45 42.32 135.65 3,377.66 3,289.21 -585.73 502.10 5,994,596.25 528,849.90 0.10 713.11 GCT-MS (1) 3,703.45 42.08 135.69 3,451.74 3,363.29 -633.78 549.04 5,994,548.38 528,897.01 0.24 773.40 GCT-MS (1) 3,803.45 41.67 135.73 3,526.20 3,437.75 -681.56 595.65 5,994,500.78 528,943.80 0.41 833.33 GCT-MS (1) 3,903.45 41.17 135.65 3,601.19 3,512.74 -728.90 641.86 5,994,453.62 528,990.19 0.50 892.72 GCT-MS (1) 4,003.45 40.63 135.73 3,676.77 3,588.32 -775.75 687.60 5,994,406.95 529,036.10 0.54 951.50 GCT-MS (1) 4,103.45 40.85 136.04 3,752.54 3,664.09 -822.61 733.03 5,994,360.27 529,081.70 0.30 1,010.19 GCT-MS (1) 4,162.85 42.04 137.02 3,797.07 3,708.62 -851.14 760.07 5,994,331.84 529,108.85 2.28 1,045.74 MWD+IFR-AK-CAZ-SC (2) 4,187.52 42.59 137.05 3,815.31 3,726.86 -863.29 771.39 5,994,319.73 529,120.21 2.23 1,060.81 MWD+IFR-AK-CAZ-SC (2) 4,281.75 38.59 137.17 3,886.85 3,798.40 -908.20 813.11 5,994,274.99 529,162.10 4.25 1,116.49 MWD+IFR-AK-CAZ-SC (2) 4,376.23 35.89 137.31 3,962.06 3,873.61 -950.18 851.93 5,994,233.17 529,201.07 2.86 1,168.48 MWD+IFR-AK-CAZ-SC (2) 4,470.55 33.32 137.49 4,039.69 3,951.24 -989.60 888.18 5,994,193.88 529,237.47 2.73 1,217.24 MWD+IFR-AK-CAZ-SC (2) 4,563.82 29.92 136.84 4,119.10 4,030.65 -1,025.46 921.41 5,994,158.15 529,270.84 3.66 1,261.68 MWD+IFR-AK-CAZ-SC (2) 4,658.66 26.47 136.29 4,202.67 4,114.22 -1,058.00 952.21 5,994,125.73 529,301.75 3.65 1,302.20 MWD+IFR-AK-CAZ-SC (2) 4,753.50 22.26 136.02 4,289.05 4,200.60 -1,086.22 979.30 5,994,097.62 529,328.95 4.44 1,337.46 MWD+IFR-AK-CAZ-SC (2) 91912009 9:30:38AM Page 4 COMPASS 2003.16 Build 69 9 • �►-' ConocoPhillips r + onocoPhill`t 5 Definitive Survey Report r._w Alaska tiv'Ct _ ConocoPhillips(Alaska) Inc. Local Co=ordinate Reference: 3C-14 Kuparuk River Unit TVb Inference: 3C-14A (D15) @ 88.45ft (Doyon 15) Kuparuk 3C Pad MD Reference; 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14 North Reference: True 3C-14 Survey Calculation Method: Minimum Curvature 3C-14 Database: EDM Alaska Prod v16 4,847.62 17.66 133.12 4,377.49 4,289.04 -1,108.82 1,002.11 5,994,075.11 529,351.84 5.00 1,366.05 MWD+IFR-AK-CAZ-SC (2) 4,941.99 13.65 128.03 4,468.35 4,379.90 -1,125.47 1,021.34 5,994,058.53 529,371.13 4.49 1,387.87 MWD+IFR-AK-CAZ-SC (2) 5,038.08 10.78 121.35 4,562.26 4,473.81 -1,137.14 1,037.95 5,994,046.93 529,387.78 3.32 1,404.13 MWD+IFR-AK-CAZ-SC (2) 5,132.08 8.30 110.12 4,654.96 4,566.51 -1,144.04 1,051.83 5,994,040.08 529,401.69 3.29 1,415.02 MWD+IFR-AK-CAZ-SC (2) 5,226.24 7.61 102.99 4,748.21 4,659.76 -1,147.78 1,064.29 5,994,036.38 529,414.16 1.28 1,422.46 MWD+IFR-AK-CAZ-SC (2) 5,321.01 7.45 103.73 4,842.16 4,753.71 -1,150.65 1,076.37 5,994,033.56 529,426.25 0.20 1,428.95 MWD+IFR-AK-CAZ-SC (2) 5,415.34 7.24 103.69 4,935.72 4,847.27 -1,153.51 1,088.09 5,994,030.75 529,437.98 0.22 1,435.32 MWD+IFR-AK-CAZ-SC (2) 5,510.71 7.86 102.70 5,030.26 4,941.81 -1,156.37 1,100.29 5,994,027.94 529,450.19 0.66 1,441.84 MWD+IFR-AK-CAZ-SC (2) 5,603.96 7.59 103.03 5,122.67 5,034.22 -1,159.16 1,112.51 5,994,025.19 529,462.42 0.29 1,448.31 MWD+IFR-AK-CAZ-SC (2) 5,698.85 8.05 102.75 5,216.67 5,128.22 -1,162.04 1,125.09 5,994,022.36 529,475.01 0.49 1,454.97 MWD+IFR-AK-CAZ-SC (2) 5,793.46 6.95 104.52 5,310.47 5,222.02 -1,164.93 1,137.10 5,994,019.51 529,487.02 1.19 1,461.46 MWD+IFR-AK-CAZ-SC(2) 5,889,02 6.49 103,70 5,405.38 5,316,93 -1,167,66 1,147.94 5,994,016,82 529,497.88 0,49 1,467,44 MWD+IFR-AK-CAZ-SC (2) 5,980.48 5.98 104.30 5,496.30 5,407.85 -1,170.06 1,157.58 5,994,014.46 529,507.52 0.56 1,472.72 MWD+IFR-AK-CAZ-SC (2) 6,074.54 5.91 104.15 5,589.85 5,501.40 -1,172.46 1,167.02 5,994,012.10 529,516.97 0.08 1,477.94 MWD+IFR-AK-CAZ-SC (2) 6,169.93 7.50 114.33 5,684.59 5,596.14 -1,176.22 1,177.46 5,994,008.38 529,527.42 2.07 1,484.78 MWD+IFR-AK-CAZ-SC (2) 6,215.67 8.69 115.32 5,729.87 5,641.42 -1,178.93 1,183.30 5,994,005.69 529,533.28 2.62 1,489.17 MWD+IFR-AK-CAZ-SC (2) 6,264.64 10.60 115.56 5,778.15 5,689.70 -1,182.46 1,190.71 5,994,002.19 529,540.70 3.90 1,494.83 MWD+IFR-AK-CAZ-SC (2) 6,309.05 12.64 115.67 5,821,64 5,733.19 -1,186.32 1,198.78 5,993,998.36 529,548.78 4.59 1,501.02 MWD+IFR-AK-CAZ-SC(2) 6,358.75 14.09 123.62 5,870.00 5,781.55 -1,192.03 1,208.72 5,993,992.69 529,558.74 4.70 1,509.54 MWD+IFR-AK-CAZ-SC (2) 6,405.14 15.26 132.07 5,914.88 5,826.43 -1,199.25 1,217.95 5,993,985.51 529,568.00 5.25 1,519.28 MWD+IFR-AK-CAZ-SC (2) 6,450.85 16.12 137.83 5,958.89 5,870.44 -1,207.98 1,226.68 5,993,976.81 529,576.76 3.89 1,530.30 MWD+IFR-AK-CAZ-SC (2) 6,502.92 17.28 142.21 6,008.77 5,920.32 -1,219.45 1,236.27 5,993,965.37 529,586.39 3.29 1,544.19 MWD+IFR-AK-CAZ-SC (2) 6,545.83 18.06 144.97 6,049.65 5,961.20 -1,229.94 1,243.99 5,993,954.92 529,594.15 2.67 1,556.56 MWD+IFR-AK-CAZ-SC (2) 6,598.93 18.96 150.09 6,100.01 6,011.56 -1,244.15 1,253.02 5,993,940.74 529,603.23 3.50 1,572.88 MWD+IFR-AK-CAZ-SC (2) 6,641.41 20.66 155.15 6,139.98 6,051.53 -1,256.94 1,259.61 5,993,927.98 529,609.87 5.68 1,587.09 MWD+IFR-AK-CAZ-SC (3) 6,668.31 22.67 158.27 6,164.98 6,076.53 -1,266.06 1,263.53 5,993,918.87 529,613.82 8.61 1,596.97 MWD+IFR-AK-CAZ-SC (3) 6,699.07 24.42 160.64 6,193.17 6,104.72 -1,277.57 1,267.83 5,993,907.39 529,618.17 6.47 1,609.25 MWD+IFR-AK-CAZ-SC (3) 6,727.16 26.84 164.37 6,218.50 6,130.05 -1,289.16 1,271.46 5,993,895.81 529,621.85 10.35 1,621.39 MWD+IFR-AK-CAZ-SC (3) 6,758.95 28.97 171.59 6,246.60 6,158.15 -1,303.69 1,274.52 5,993,881.29 529,624.96 12.55 1,636.16 MWD+IFR-AK-CAZ-SC (3) 6,787.82 30.32 175.72 6,271.69 6,183.24 -1,317.87 1,276.09 5,993,867.12 529,626.58 8.48 1,650.12 MWD+IFR-AK-CAZ-SC (3) 6,819.99 32.32 180.52 6,299.18 6,210.73 -1,334.58 1,276.62 5,993,850.42 529,627.17 9.94 1,666.15 MWD+IFR-AK-CAZ-SC (3) 9/9/2009 9:30:38AM Page 5 COMPASS 2003.16 Build 69 r L_J i ConocoPhrillips Alaska C. Kuparuk River Unit Kuparuk 3C Pad 3C-14 3C-14 3C-14 ConocoPhittips Definitive Survey Report •14 14A (D15) @ 88.45ft (Doyon 15) 14A (D15) @ 88.45ft (Doyon 15) iimum Curvature M Alaska Prod v16 6,825.00 33.03 181.57 6,303.40 6,214.95 -1,337.28 1,276.57 5,993,847.71 529,627.13 18.13 1,668.71 MWD (4) 6,860.25 36.88 180.28 6,332.28 6,243.83 -1,357.47 1,276.25 5,993,827.53 529,626.89 11.12 1,687.79 MWD (4) 6,891.34 40.07 179.32 6,356.62 6,268.17 -1,376.81 1,276.33 5,993,808.19 529,627.04 10.44 1,706.19 MWD (4) 6,920.49 42.64 178.53 6,378.50 6,290.05 -1,396.06 1,276.69 5,993,788.94 529,627.48 9.00 1,724.60 MWD (4) 6,950.24 45.95 177.81 6,399.79 6,311.34 -1,416.82 1,277.36 5,993,768.18 529,628.22 11.25 1,744.53 MWD (4) 6,967.19 48.18 177.44 6,411.33 6,322.88 -1,429.22 1,277.87 5,993,755.78 529,628.79 13.25 1,756.47 MWD (4) 7,000.37 51.17 178.08 6,432.80 6,344.35 -1,454.50 1,278.86 5,993,730.52 529,629.87 9.13 1,780.79 MWD (4) 7,011.00 52.39 178.33 6,439.38 6,350.93 -1,462.84 1,279.12 5,993,722.17 529,630.16 11.62 1,788.81 MWD (5) 7,037.71 56.69 163.03 6,454.93 6,366.48 -1,484.19 1,282.70 5,993,700.84 529,633.82 49.29 1,810.20 MWD (5) 7,066.24 66.42 162.33 6,468.50 6,380.05 -1,508.10 1,290.17 5,993,676.96 529,641.38 34.17 1,835.26 MWD (5) 7,096.73 75.48 161.50 6,478.45 6,390.00 -1,535.47 1,299.11 5,993,649.63 529,650.42 29.83 1,864,05 MWD (5) 7,130,62 89,11 161.60 6,482,98 6,394.53 -1,567,25 1,309.71 5,993,617,89 529,661.15 40,22 1,897.55 MWD (5) 7,160.51 89.45 168.36 6,483.36 6,394.91 -1,596.10 1,317.45 5,993,589.07 529,669.00 22.64 1,927.37 MWD (5) 7,190.63 89.60 174.52 6,483.61 6,395.16 -1,625.87 1,321.94 5,993,559.32 529,673.59 20.46 1,957.06 MWD (5) 7,220.65 89.05 180.30 6,483.96 6,395.51 -1,655.85 1,323.29 5,993,529.36 529,675.06 19.34 1,985.96 MWD (5) 7,250.48 88.77 186.40 6,484.53 6,396.08 -1,685.61 1,321.55 5,993,499.59 529,673.43 20.47 2,013.69 MWD (5) 7,280.49 88.46 192.20 6,485.25 6,396.80 -1,715.20 1,316.70 5,993,469.98 529,668.70 19.35 2,040.30 MWD (5) 7,310.38 88.96 197.76 6,485.93 6,397.48 -1,744.06 1,308.98 5,993,441.10 529,661.09 18.67 2,065.31 MWD (5) 7,340.44 89.85 203.63 6,486.24 6,397.79 -1,772.16 1,298.36 5,993,412.96 529,650.58 19.75 2,088.70 MWD (5) 7,370.36 90.03 209.29 6,486.27 6,397.82 -1,798.94 1,285.04 5,993,386.14 529,637.35 18.93 2,109.98 MWD (5) 7,400.41 89.91 214.96 6,486.29 6,397.84 -1,824.38 1,269.06 5,993,360.64 529,621.48 18.87 2,129.17 MWD (5) 7,430.27 90.49 221.54 6,486.18 6,397.73 -1,847.81 1,250.59 5,993,337.14 529,603.09 22.12 2,145.68 MWD (5) 7,460.52 89.63 227,13 6,486.15 6,397.70 -1,869.44 1,229.46 5,993,315.43 529,582.05 18.70 2,159.63 MWD (5) 7,490.44 90.06 233.12 6,486.23 6,397.78 -1,888.61 1,206.51 5,993,296.17 529,559.17 20.07 2,170.69 MWD (5) 7,520.39 87.88 227.85 6,486.77 6,398.32 -1,907.66 1,183.41 5,993,277.04 529,536.15 19.04 2,181.59 MWD (5) 7,550.57 86.99 222.03 6,488.12 6,399.67 -1,928.99 1,162.13 5,993,255.63 529,514.95 19.49 2,195.22 MWD (5) 7,580.45 87.21 215.89 6,489.63 6,401.18 -1,952.18 1,143.37 5,993,232.37 529,496.28 20.54 2,211.40 MWD (5) 7,612.85 87.70 209.82 6,491.07 6,402.62 -1,979.36 1,125.82 5,993,205.13 529,478.84 18.78 2,231.75 MWD (5) 7,640.09 88.77 204.73 6,491.91 6,403.46 -2,003.55 1,113.35 5,993,180.89 529,466.46 19.09 2,250.85 MWD (5) 7,670.16 89.17 199.17 6,492.46 6,404.01 -2,031.43 1,102.11 5,993,152.98 529,455.33 18.53 2,273.83 MWD (5) 7,700.18 89.42 193.02 6,492.83 6,404.38 -2,060.26 1,093.80 5,993,124.12 529,447.12 20.50 2,298.62 MWD (5) 9/9/2009 9:30:38AM Page 6 TIP 3C-14BPB1 KOP COMPASS 2003,16 Build 69 0 ✓ ConocoPhillips i'I onocoPh hips Definitive Survey Report k Alaska :ompany, ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 3C-14 �rojcct; Kuparuk River Unit `?VD Reference:. 3C-14A (D15) @ 88.45ft (Doyon 15) 3itea Kuparuk 3C Pad Mp, Reference: 3C-14A (D15) @ 88.45ft (Doyon 15) Nell- 3C-14 North Reference: True Nell re: 3C-14 Survey Calculation Method: ' Minimum Curvature )esian: 3C-14 Database: ' EDM Alaska Prod v16 7,730.31 89.63 186.66 6,493.08 6,404.63 -2,089.93 1,088.65 5,993,094.43 529,442.09 21.12 2,325.21 MWD (5) 7,760.28 89.08 180.71 6,493.41 6,404.96 -2,119.82 1,086.72 5,993,064.54 529,440.28 19.94 2,353.01 MWD (5) 7,790.01 89.42 174.61 6,493.80 6,405.35 -2,149.51 1,087.94 5,993,034.86 529,441.60 20.55 2,381.60 MWD (5) 7,826.42 89.69 167.34 6,494.09 6,405.64 -2,185.44 1,093.64 5,992,998.95 529,447.45 19.98 2,417.52 MWD (5) 7,859.91 90.00 160.02 6,494.18 6,405.73 -2,217.56 1,103.05 5,992,966.87 529,456.97 21.88 2,450.97 MWD (5) 7,890.10 88.99 154.28 6,494.44 6,405.99 -2,245.37 1,114.77 5,992,939.11 529,468.79 19.30 2,481.04 MWD (5) 7,920.09 89.54 155.32 6,494.83 6,406.38 -2,272.50 1,127.53 5,992,912.03 529,481.66 3.92 2,510.80 MWD (5) 7,950.15 90.09 160.61 6,494.92 6,406.47 -2,300.35 1,138.81 5,992,884.22 529,493.04 17.69 2,540.79 MWD (5) 7,980.00 87.02 165.13 6,495.68 6,407.23 -2,328.86 1,147.60 5,992,855.75 529,501.93 18.30 2,570.61 MWD (5) 8,010.99 84.22 168.81 6,498.04 6,409.59 -2,358.96 1,154.56 5,992,825.68 529,509.01 14.89 2,601.38 MWD (5) 8,040.02 80.87 173.57 6,501.81 6,413.36 -2,387.39 1,158.97 5,992,797.27 529,513.53 1994. 2.629.77 MWD (5) 8,069,62 77.25 178.49 6,507,43 6,418.98 -2,416,36 1,160,99 5,992,768,30 529,515.66 20.39 2,657,93 MWD (5) 8,100.18 73.82 184.28 6,515.07 6,426.62 -2,445.93 1,160.29 5,992,738.74 529,515.07 21.50 2,685.80 MWD (5) 8,130.31 75.13 189.39 6,523.14 6,434.69 -2,474.74 1,156.83 5,992,709.92 529,511.72 16.91 2,712.10 MWD (5) 8,157.44 77.31 190.72 6,529.60 6,441.15 -2,500.68 1,152.23 5,992,683.96 529,507.22 9.34 2,735.31 MWD (5) 8,190.04 80.03 184.86 6,536.01 6,447.56 -2,532.34 1,147.91 5,992,652.30 529,503.02 19.50 2,764.03 MWD (5) 8,220.13 81.93 180.16 6,540.73 6,452.28 -2,562.02 1,146.61 5,992,622.61 529,501.83 16.67 2,791.83 MWD (5) 8,250.31 83.51 175.81 6,544.56 6,456.11 -2,591.93 1,147.66 5,992,592.71 529,503.00 15.23 2,820.58 MWD (5) 8,280.11 87.27 170.98 6,546.95 6,458.50 -2,621.42 1,151.08 5,992,563.24 529,506.53 20.50 2,849.66 MWD (5) 8,310.02 90.03 166.79 6,547.66 6,459.21 -2,650.75 1,156.84 5,992,533.93 529,512.40 16.77 2,879.33 MWD (5) 8,340.02 93.56 163.07 6,546.72 6,458,27 -2,679.69 1,164.64 5,992,505.02 529,520.31 17.09 2,909.26 MWD (5) 8,370.08 97.14 158.88 6,543.92 6,455.47 -2,707.98 1,174.39 5,992,476.77 529,530.16 18.29 2,939.17 MWD (5) 8,400.00 99.44 162.03 6,539.60 6,451.15 -2,735.87 1,184.29 5,992,448.92 529,540.17 12.95 2,968.77 MWD (5) 8,430.16 98.47 165.71 6,534.90 6,446.45 -2,764.49 1,192.57 5,992,420.34 529,548.55 12.47 2,998.53 MWD (5) 8,460.35 95.38 169.60 6,531.26 6,442.81 -2,793.76 1,198.97 5,992,391.10 529,555.07 16.38 3,028.34 MWD (5) 8,490.22 95.35 175.83 6,528.47 6,440.02 -2,823.24 1,202.74 5,992,361.63 529,558.95 20.77 3,057.53 MWD (5) 8,520.21 97.98 180.26 6,524.99 6,436.54 -2,853.00 1,203.76 5,992,331.88 529,560.08 17.09 3,086.12 MWD (5) 8,550.05 99.68 184.76 6,520.40 6,431.95 -2,882.45 1,202.47 5,992,302.43 529,558.90 15.95 3,113.70 MWD (5) 8,579.59 100.09 185.89 6,515.33 6,426.88 -2,911.42 1,199.77 5,992,273.45 529,556.31 4.02 3,140.39 MWD (5) 8,610.13 99.84 178.45 6,510.04 6,421.59 -2,941.46 1,198.63 5,992,243.41 529,555.29 24.01 3,168.57 MWD (5) 8,640.75 99.50 172.85 6,504.89 6,416.44 -2,971.54 1,200.92 5,992,213.34 529,557.69 18.06 3,197.87 MWD (5) 9/9/2009 9:30:38AM Page 7 COMPASS 2003.16 Build 69 • �-' ConocoPhillips C?CCQai1 Iiti "M -- Definitive Survey Report Alaska tw'FEQ ConocoPhillips(Alaska) Inc. L©Cat Gay -ordinate Reference: 3C-14 Kuparuk River Unit TVD Reference: 3C-14A (D15) @ 88.45ft (Doyon 15) Kuparuk 3C Pad MO, Referenee, 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14 North Reference: True 3C-14 Survey Calculation Method: Minimum Curvature 3C-14 Database, EDM Alaska Prod v16 . lay, �F5 � % y 8,670.10 97.91 168.13 6,500.45 6,412.00 -3,000.15 1,205.71 5,992,184.75 529,62.59 16.79 3,22226.54 MWD (5) 8,700.08 94.42 166.44 6,497.23 6,408.78 -3,029.22 1,212.27 5,992,155.71 529,569.26 12.92 3,256.21 MWD (5) 8,730.56 89.82 165.35 6,496.10 6,407.65 -3,058.75 1,219.70 5,992,126.21 529,576.80 15.51 3,286.58 MWD (5) 8,760.62 90.58 162.05 6,496.00 6,407.55 -3,087.60 1,228.13 5,992,097.40 529,585.34 11.27 3,316.62 MWD (5) 8,790.45 92.03 157.99 6,495.32 6,406.87 -3,115.62 1,238.32 5,992,069.42 529,595.63 14.45 3,346.42 MWD (5) 8,820.57 89.20 156.77 6,494.99 6,406.54 -3,143.42 1,249.90 5,992,041.67 529,607.32 10.23 3,376.45 MWD (5) 8,850.48 90.86 161.91 6,494.98 6,406.53 -3,171.39 1,260.45 5,992,013.73 529,617,97 18.06 3,406.32 MWD (5) 8,880.61 92.27 167.58 6,494.15 6,405.70 -3,200.44 1,268.37 5,991,984.72 529,626.00 19.38 3,436.38 MWD (5) 8,920.63 92.98 174.79 6,492.32 6,403.87 -3,239.92 1,274.50 5,991,945.27 529,632.28 18.08 3,475.80 MWD (5) 8,950.65 94.09 179.94 6,490.47 6,402.02 -3,269.84 1,275.87 5,991,915.36 529,633.77 17.52 3,504.66 MWD (5) 8,980.48 94.03 186.18 6,488.35 6,399.90 -3,299.53 1,274.29 5,991,885.66 529,632.29 20.87 3,532.38 MWD (5) 9,010,84 94,73 191.52 6,486.03 6,397,58 -3,329.43 1,269,63 5,991,855.74 529,627.75 17.69 3,559.34 MWD (5) 9,040.93 94.36 198.65 6,483.65 6,395.20 -3,358.38 1,261.83 5,991,826.77 529,620.06 23.65 3,584,40 MWD (5) 9,070.40 94.02 204.65 6,481.49 6,393.04 -3,385.68 1,250.99 5,991,799.43 529,609.33 20.34 3,606.97 MWD (5) 9,100.28 95.54 209.41 6,479.00 6,390.55 -3,412.20 1,237.46 5,991,772.87 529,595.90 16.67 3,627.94 MWD (5) 9,130.31 95.13 203.45 6,476.20 6,387.75 -3,438.96 1,224.16 5,991,746.06 529,582.70 19.81 3,649.22 MWD (5) 9,160.38 95.53 198.73 6,473.41 6,384.96 -3,466.89 1,213.39 5,991,718.09 529,572.04 15.69 3,672.40 MWD (5) 9,190.59 94.18 194.34 6,470.85 6,382.40 -3,495.74 1,204.83 5,991,689.21 529,563.59 15.15 3,697.14 MWD (5) 9,220.31 93.59 190.19 6,468.84 6,380.39 -3,524.70 1,198.53 5,991,660.22 529,557.40 14.07 3,722.70 MWD (5) 9,250.46 92.67 184.06 6,467.19 6,378.74 -3,554.56 1,194.80 5,991,630.36 529,553.78 20.53 3,749.90 MWD (5) 9,280.46 93.13 178.07 6,465.67 6,377.22 -3,584.51 1,194.24 5,991,600.41 529,553.34 20.00 3,778.18 MWD (5) 9,310.65 93.87 172.65 6,463.83 6,375.38 -3,614.53 1,196.68 5,991,570.40 529,555.89 18.09 3,807.46 MWD (5) 9,345.30 93.93 168.72 6,461.47 6,373.02 -3,648.64 1,202.27 5,991,536.32 529,561.61 11.32 3,841.61 MWD (5) 9,382.00 93.93 168.72 6,458.95 6,370.50 -3,684.54 1,209.43 5,991,500.45 529,568.91 0.00 3,877.96 PROJECTED to TD 91912009 9:30:38AM Page 8 COMPASS 2003,16 Build 69 C6nocoPhunps�, ConocoPhill ips(Alaska) Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-14BPB1 500292142570 Baker Hughes INTEQ Definitive Survey Report 09 September, 2009 NOFAI MGM BAKER LM +mac noc Phillips Alaska Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site; Kuparuk 3C Pad Nall: 3C-14 dlteiEt�ore: 3C-14 Destan:_ _ _ :3C-14 Map System: US State Plane 1927 (Exact solution) Audit Notes: Version: 1.0 Phase: ACTUAL 40.85 ConocoPhitlips Definitive Survey Report System Datum: Easting: Wellhead Elevation: -14A (D15) @ 88.45ft (Doyon 15) -14A (D15) @ 88.45ft (Doyon 15) rue inimum Curvature DM Alaska Prod v16 Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,995,180.01 ft 528,345.63ft ft Tie On Depth: 6,819.99 0.00 103.45 4,103.45 3C-14 (3C-14) GCT-MS Schlumberger GCT multishot 4,162.85 6,598.93 3C-14A MWD+SAG+IIFR+CA+MS Doyo MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,641.41 6,819.99 3C-14A MWD+SAG+IIFR+CA+MS Doyo MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,825.00 8,045.34 3C-14BPB1 (3C-14BPB1) MWD MWD - Standard Latitude: Longitude: Ground Level: IAG Hoom t v r• 4` 70' 23' 52.506 N 149° 46' 9.594 W 47.60 ft 1 /26/2008 2/5/2008 2/18/2008 2/22/2008 8/28/2009 8/29/2009 9/9/2009 9:32:34AM Page 2 COMPASS 2003,16 Build 69 61 01 r.^ ConocoPhillips " C+QriocoPhillip►s Definitive Survey Report s Alaska Kuparuk River Unit Kuparuk 3C Pad 3C-14 3C-14 3C-14 3C-14 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14A (D15) @ 88.45ft (Doyon 15) imum Curvature 0 Alaska Prod 06 40.85 0.00 0.00 40.85 -47.60 0.00 0.00 5,995,180.01 528,345.63 0.00 0.00 UNDEFINED 103.45 0.20 225.45 103.45 15.00 -0.08 -0.08 5,995,179.93 528,345.55 0.32 0.04 GCT-MS (1) 203.45 0.18 232.55 203.45 115.00 -0.29 -0.33 5,995,179.71 528,345.30 0.03 0.13 GCT-MS (1) 303.45 0.22 219.62 303.45 215.00 -0.54 -0.57 5,995,179.47 528,345.06 0.06 0.26 GCT-MS (1) 403.45 0.32 207.59 403.45 315.00 -0.93 -0.83 5,995,179.07 528,344.81 0.11 0.51 GCT-MS (1) 503.45 0.42 170.06 503.45 415.00 -1.54 -0.89 5,995,178.46 528,344.74 0.26 1.04 GCT-MS (1) 603.45 0.08 159.73 603.44 514.99 -1.97 -0.80 5,995,178.04 528,344.83 0.34 1.47 GCT-MS (1) 703.45 0.17 168.38 703.44 614.99 -2.18 -0.75 5,995,177.83 528,344.89 0.09 1.68 GCT-MS (1) 803.45 0.52 162.85 803.44 714.99 -2.76 -0.59 5,995,177.25 528,345.05 0.35 2.28 GCT-MS (1) 903.45 0.63 161.31 903.44 814.99 -3.71 -0.28 5,995,176.30 528,345.37 0.11 3.27 GCT-MS (1) 1,003.45 0.73 157.71 1,003.43 914.98 -4.82 0.14 5,995,175.19 528,345.79 0.11 4A6 GCT-MS (1) 1,103,45 0,67 151,13 1,103,42 1,014,97 -5,92 0.66 5,995,174.09 528,346.32 0.10 5.68 GCT-MS(1) 1,203.45 0.67 143.22 1,203.42 1,114.97 -6.90 1.30 5,995,173.11 528,346.95 0.09 6.83 GCT-MS (1) 1,303.45 0.67 142.19 1,303.41 1,214.96 -7.83 2.01 5,995,172.18 528,347.66 0.01 7.97 GCT-MS (1) 1,403.45 0.70 145.57 1,403.40 1,314.95 -8.80 2.71 5,995,171.22 528,348.37 0.05 9.14 GCT-MS (1) 1,503.45 0.77 157.52 1,503.39 1,414.94 -9.93 3.31 5,995,170.10 528,348.98 0.17 10.41 GCT-MS (1) 1,603.45 0.82 162.25 1,603.38 1,514.93 -11.23 3.79 5,995,168.80 528,349.46 0.08 11.79 GCT-MS (1) 1,703.45 0.55 152.74 1,703.38 1,614.93 -12.34 4.23 5,995,167.69 528,349.90 0.29 12.98 GCT-MS (1) 1,803.45 0.28 142.04 1,803.37 1,714.92 -12.95 4.60 5,995,167.07 528,350.27 0.28 13.70 GCT-MS (1) • 1,903.45 0.73 133.96 1,903.37 1,814.92 -13.59 5.20 5,995,166.44 528,350.88 0.45 14.53 GCT-MS (1) 2,003.45 4.15 138.73 2,003.26 1,914.81 -16.75 8.05 5,995,163.29 528,353.74 3.42 18.58 GCT-MS (1) 2,103.45 8.25 137.86 2,102.66 2,014.21 -24.80 15.25 5,995,155.27 528,360.98 4.10 28.87 GCT-MS (1) 2,203.45 12.47 135.55 2,201.01 2,112.56 -37.83 27.63 5,995,142.29 528,373.40 4.24 45.83 GCT-MS (1) 2,303.45 16.53 135.90 2,297.80 2,209.35 -55.76 45.10 5,995,124.43 528,390.94 4.06 69.35 GCT-MS (1) 2,403.45 20.97 138.94 2,392.47 2,304.02 -79.48 66.77 5,995,100.79 528,412.69 4.54 99.87 GCT-MS (1) 2,503.45 24.07 139.06 2,484.84 2,396.39 -108.38 91.89 5,995,071.99 528,437.92 3.10 136.53 GCT-MS (1) 2,603.45 24.90 137.93 2,575.84 2,487.39 -139.42 119.36 5,995,041.06 528,465.50 0.95 176.09 GCT-MS (1) 2,703.45 27.90 136.58 2,665.40 2,576.95 -172.05 149.55 5,995,008.55 528,495.82 3.06 218.23 GCT-MS (1) 2,803.45 30.62 142.11 2,752.65 2,664.20 -209.15 181.29 5,994,971.57 528,527.69 3.83 265.09 GCT-MS (1) 2,903.45 33.78 147.02 2,837.28 2,748.83 -252.59 212.07 5,994,928.25 528,558.64 4.10 317.33 GCT-MS (1) 9/9/2009 9:32:34AM Page 3 COMPASS 2003.16 Build 69 VII C660cbPhillips C. Kuparuk River Unit Kuparuk 3C Pad 3C-14 3C-14 3C-14 3,003.45 35.83 149.05 2,919.39 2,830.94 3,103.45 37.12 143.57 2,999.82 2,911.37 3,203.45 39.17 137.40 3,078.49 2,990.04 3,303.45 40.80 133.41 3,155.12 3,066.67 3,403.45 42.38 134.68 3,229.91 3,141.46 3,503.45 42.40 135.55 3,303.77 3,215.32 3,603.45 42.32 135.65 3,377.66 3,289.21 3,703.45 42.08 135.69 3,451.74 3,363.29 3,803.45 41.67 135.73 3,526.20 3,437.75 3,903.45 41.17 135.65 3,601.19 3,512.74 4,003.45 40.63 135.73 3,676.77 3,588.32 4,103,45 40,85 136,04 3,752,54 3,664,09 4,162.85 42.04 137.02 3,797.07 3,708.62 4,187.52 42.59 137.05 3,815.31 3,726.86 4,281.75 38.59 137.17 3,886.85 3,798.40 4,376.23 35.89 137.31 3,962.06 3,873.61 4,470.55 33.32 137.49 4,039.69 3,951.24 4,563.82 29.92 136.84 4,119.10 4,030.65 4,658.66 26,47 136.29 4,202.67 4,114.22 4,753.50 22.26 136.02 4,289.05 4,200.60 4,847.62 17.66 133.12 4,377.49 4,289.04 4,941.99 13.65 128.03 4,468.35 4,379.90 5,038.08 10.78 121.35 4,562.26 4,473,81 F' 5,132.08 8.30 110.12 4,654.96 4,566.51 5,226.24 7.61 102.99 4,748.21 4,659.76 5,321.01 7.45 103.73 4,842.16 4,753.71 5,415.34 7.24 103.69 4,935.72 4,847.27 5,510.71 7.86 102.70 5,030.26 4,941.81 5,603.96 7.59 103.03 5,122.67 5,034.22 5,698.85 8.05 102.75 5,216.67 5,128.22 5,793.46 6.95 104.52 5,310.47 5,222.02 9/9/2009 9:32:34AM Conocoftillips Definitive Survey Report 3C-14 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14A (D15) @ 88,45ft (Doyon 15) iimum Curvature M Alaska Prod v16 -301.02 242.26 5,994,879.94 528,589.01 2.35 373.88 GCT-MS (1) -350.41 275.24 5,994,830.68 528,622.17 3.50 432.45 GCT-MS (1) -397.96 314.56 5,994,783.28 528,661.66 4.33 491.94 GCT-MS (1) -443.67 359.68 5,994,737.75 528.706.95 3.04 552.13 GCT-MS (1) -489.82 407.38 5,994,691.78 528,754.82 1.79 613.78 GCT-MS (1) -537.59 454.96 5,994,644.20 528,802.58 0.59 676.85 GCT-MS (1) -585.73 502.10 5,994,596.25 528,849.90 0.10 740.08 GCT-MS (1) -633.78 549.04 5,994,548.38 528,897.01 0.24 803.15 GCT-MS (1) -681.56 595.65 5,994,500.78 528,943.80 0.41 865.84 GCT-MS (1) -728.90 641.86 5,994,453.62 528,990.19 0.50 927.97 GCT-MS (1) -775.75 687.60 5,994,406.95 529,036.10 0.54 989.45 GCT-MS (1) -822.61 733.03 5,994,360,27 529,081.70 0.30 1,050,81 GCT-MS (1) -851.14 760.07 5,994,331.84 529,108.85 2.28 1,087.93 MWD+IFR-AK-CAZ-SC (2) -863.29 771.39 5,994,319.73 529,120.21 2.23 1,103.65 MWD+IFR-AK-CAZ-SC (2) -908.20 813.11 5,994,274.99 529,162.10 4.25 1,161.72 MWD+IFR-AK-CAZ-SC (2) -950.18 851.93 5.994,233.17 529,201.07 2.86 1,215.91 MWD+IFR-AK-CAZ-SC (2) -989.60 888.18 5,994,193.88 529,237.47 2.73 1,266.74 MWD+IFR-AK-CAZ-SC (2) -1,025.46 921.41 5,994,158.15 529,270.84 3.66 1,313.07 MWD+IFR-AK-CAZ-SC (2) -1,058.00 952.21 5,994,125.73 529,301.75 3.65 1,355.38 MWD+IFR-AK-CAZ-SC (2) -1,086.22 979.30 5,994,097.62 529,328.95 4.44 1,392.22 MWD+IFR-AK-CAZ-SC (2) -1,108.82 1,002.11 5,994,075.11 529,351.84 5.00 1,422.18 MWD+IFR-AK-CAZ-SC (2) -1,125.47 1,021.34 5,994,058.53 529,371.13 4.49 1,445.25 MWD+IFR-AK-CAZ-SC (2) -1,137.14 1,037.95 5,994,046.93 529,387.78 3.32 1,462.70 MWD+IFR-AK-CAZ-SC (2) -1,144.04 1,051.83 5,994,040.08 529,401.69 3.29 1,474.69 MWD+IFR-AK-CAZ-SC (2) -1,147.78 1,064.29 5,994,036.38 529,414.16 1.28 1,483.21 MWD+IFR-AK-CAZ-SC (2) -1,150.65 1,076.37 5,994,033.56 529,426.25 0.20 1,490.78 MWD+IFR-AK-CAZ-SC (2) -1,153.51 1,088.09 5,994,030.75 529,437.98 0.22 1,498.19 MWD+IFR-AK-CAZ-SC (2) -1,156.37 1,100.29 5,994,027.94 529,450.19 0.66 1,505.80 MWD+IFR-AK-CAZ-SC (2) -1,159.16 1,112.51 5,994,025.19 529,462.42 0.29 1,513.35 MWD+IFR-AK-CAZ-SC (2) -1,162.04 1,125.09 5,994,022.36 529,475.01 0.49 1,521.14 MWD+IFR-AK-CAZ-SC (2) -1,164.93 1,137.10 5,994,019.51 529,487.02 1.19 1,528.70 MWD+IFR-AK-CAZ-SC (2) Page 4 fAl t�•rrc COMPASS 2003.16 Build 69 Ci • C+ noc Ph illiprs Alaska C. Kuparuk River Unit Kuparuk 3C Pad 3C-14 3C-14 3C-14 ConocoPhillips Definitive Survey Report 3C-14 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14A (D15) @ 88.45ft (Doyon 15) timum Curvature M Alaska Prod v16 5,889.02 6.49 103.70 5,405.38 5,316.93 -1,167.66 1,147.94 5,994,016.82 529,497.88 0.49 1,535.64 MWD+IFR-AK-CAZ-SC (2) 5,980.48 5.98 104.30 5,496.30 5,407.85 -1,170.06 1,157.58 5,994,014.46 529,507,52 0.56 1,541.78 MWD+IFR-AK-CAZ-SC (2) 6,074.54 5.91 104.15 5,589.85 5,501.40 -1,172A6 1,167.02 5,994,012.10 529,516.97 0.08 1,547.83 MWD+IFR-AK-CAZ-SC (2) 6,169.93 7.50 114.33 5,684.59 5,596.14 -1,176.22 1,177.46 5,994,008.38 529,527.42 2.07 1,555.55 MWD+IFR-AK-CAZ-SC (2) 6,215.67 8.69 115.32 5,729.87 5,641.42 -1,178.93 1,183.30 5,994,005.69 529,533.28 2.62 1,560.41 MWD+IFR-AK-CAZ-SC (2) 6,264.64 10.60 115.56 5,778.15 5,689.70 -1,182.46 1,190.71 5,994,002.19 529,540.70 3.90 1,566.66 MWD+IFR-AK-CAZ-SC (2) 6,309.05 12.64 115.67 5,821.64 5,733.19 -1,186.32 1,198.78 5,993,998.36 529,548.78 4.59 1,573.50 MWD+IFR-AK-CAZ-SC (2) 6,358.75 14.09 123.62 5,870.00 5,781.55 -1,192.03 1,208.72 5,993,992.69 529,558.74 4.70 1,582.78 MWD+IFR-AK-CAZ-SC (2) 6,405.14 15.26 132.07 5,914.88 5,826.43 -1,199.25 1,217.95 5,993,985.51 529,568.00 5.25 1,593.15 MWD+IFR-AK-CAZ-SC (2) 6,450.85 16.12 137.83 5,958.89 5,870.44 -1,207.98 1,226.68 5,993,976.81 529,576.76 3.89 1,604.69 MWD+IFR-AK-CAZ-SC (2) 6,502.92 17.28 142.21 6,008.77 5,920.32 -1,219.45 1,236.27 5,993,965.37 529,586.39 3.29 1,619.09 MWD+IFR-AK-CAZ-SC (2) 6,545.83 18.06 144,97 6,049,65 5,961,20 -1,229.94 1,243,99 5,993,954.92 529,594.15 2,67 1,631.81 MWD+IFR-AK-CAZ-SC (2) 6,598.93 18.96 150.09 6,100.01 6,011.56 -1,244.15 1,253.02 5,993,940.74 529,603.23 3.50 1,648.48 MWD+IFR-AK-CAZ-SC(2) 6,641.41 20.66 155.15 6,139.98 6,051.53 -1,256.94 1,259.61 5,993,927.98 529,609.87 5.68 1,662.85 MWD+IFR-AK-CAZ-SC (3) 6,668.31 22.67 158.27 6,164.98 6,076.53 -1,266.06 1,263.53 5,993,918.87 529,613.82 8.61 1,672.77 MWD+IFR-AK-CAZ-SC (3) 6,699.07 24.42 160.64 6,193.17 6,104.72 -1,277.57 1,267.83 5,993,907.39 529,618.17 6.47 1,685.03 MWD+IFR-AK-CAZ-SC (3) 6,727.16 26.84 164.37 6,218.50 6,130.05 -1,289.16 1,271.46 5,993,895.81 529,621.85 10.35 1,697.09 MWD+IFR-AK-CAZ-SC (3) 6,758.95 28.97 171.59 6,246.60 6,158.15 -1,303.69 1,274.52 5,993,881.29 529,624.96 12.55 1,711.60 MWD+IFR-AK-CAZ-SC(3) 6,787.82 30.32 175.72 6,271.69 6,183.24 -1,317.87 1,276.09 5,993,867.12 529,626.58 8.48 1,725.18 MWD+IFR-AK-CAZ-SC (3) 6,819.99 32.32 180.52 6,299.18 6,210.73 -1,334.58 1,276.62 5,993,850.42 529,627.17 9.94 1,740.63 MWD+IFR-AK-CAZ-SC (3) 6,825.00 33.03 181.57 6,303.40 6,214.95 -1,337.28 1,276.57 5,993,847.71 529,627.13 18.13 1,743.08 MWD (4) 6,860.25 36.88 180.28 6,332.28 6,243.83 -1,357.47 1,276.25 5,993,827.53 529,626.89 11.12 1,761.36 MWD (4) 6,891.34 40.07 179.32 6,356.62 6,268.17 -1,376.81 1,276.33 5,993,808.19 529,627.04 10.44 1,779.03 MWD (4) 6,920.49 42.64 178.53 6,378.50 6,290.05 -1,396.06 1,276.69 5,993,788.94 529,627.48 9.00 1,796.74 MWD (4) 6,950.24 45.95 177.81 6,399.79 6,311.34 -1,416.82 1,277.36 5,993,768.18 529,628.22 11.25 1,815.95 MWD (4) 6,967.19 48.18 177.44 6,411.33 6,322.88 -1,429.22 1,277.87 5,993,755.78 529,628.79 13.25 1,827.47 MWD (4) 7,000.37 51.17 178.08 6,432.80 6,344.35 -1,454.50 1,278.86 5,993,730.52 529,629.87 9.13 1,850.93 MWD (4) 7,031.08 54.66 178.78 6,451.32 6,362.87 -1,478.98 1,279.53 5,993,706.04 529,630.63 11.51 1,873.54 MWD (4) 7,064.55 59.61 179.06 6,469.47 6,381.02 -1,507.08 1,280.05 5,993,677.94 529,631.26 14.81 1,899.38 MWD (4) 7,092.84 64.78 179.57 6,482.67 6,394.22 -1,532.09 1,280.35 5,993,652.93 529,631.65 18.34 1,922.32 MWD (4) 7,125.23 70.70 181.39 6,494.93 6,406.48 -1,562.05 1,280.09 5,993,622.98 529,631.51 19.00 1,949.54 MWD (4) 91912009 9:32:34AM Page 5 TIP 3C-14A KOP Interpolated AZI Interpolated AZI Interpolated AZI Interpolated AZI COMPASS 2003.16 Build 69 �i • V-' ConocoPhillips rai CowcoPhillip►s' , Definitive Survey Report Nwom Alaska Nf 5 Kuparuk River Unit Kuparuk 3C Pad 3C-14 3C-14 3C-14 3C-14 lC-14A (D15) @ 88.45ft (Doyon 15) 3C-14A (D15) @ 88.45ft (Doyon 15) ium Curvature Alaska Prod v16 7,157.18 76.37 184.77 6,503.99 6,415.54 -1,592.63 1,278.43 5,993,592.39 529,629.96 20.44 1,976.75 MWD (4) 7,189.00 81.87 188.38 6,509.99 6,421.54 -1,623.66 1,274.85 5,993,561.36 529,626.50 20.56 2,003.58 MWD (4) 7,224.73 87.64 192.68 6,513.26 6,424.81 -1,658.61 1,268.34 5,993,526.38 529,620.13 20.11 2,032.79 MWD (4) 7,256.61 88.19 199.46 6,514.42 6,425.97 -1,689.21 1,259.53 5,993,495.76 529,611.43 21.32 2,057.09 MWD (4) 7,284.88 88.89 205.33 6,515.14 6,426.69 -1,715.33 1,248.77 5,993,469.60 529,600.77 20.90 2,076.50 MWD (4) 7,315.46 89.51 214.35 6,515.57 6,427.12 -1,741.82 1,233.57 5,993,443.05 529,585.67 29.56 2,094.43 MWD (4) 7,347.98 87.33 216.09 6,516.46 6,428.01 -1,768.38 1,214.82 5,993,416.43 529,567.03 8.58 2,110.97 MWD (4) 7,377.83 86.50 209.55 6,518.07 6,429.62 -1,793.41 1,198.67 5,993,391.33 529,550.98 22.05 2,127.18 MWD (4) 7,409.59 86.96 213.91 6,519.89 6,431.44 -1,820.37 1,182.00 5,993,364.31 529,534.41 13.78 2,144.94 MWD (4) 7,440.72 88.19 219.60 6,521.20 6,432.75 -1,845.28 1,163.40 5,993,339.34 529,515.90 18.68 2,160,03 MWD (4) 7,470.62 92.89 222.83 6,520.92 6,432.47 -1,867.76 1,143.71 5,993,316.78 529,496.30 19.07 2,172.47 MWD (4) 7,500,26 94,33 217.66 6,519,05 6,430.60 -1,890,33 1,124,60 5,993,294.14 529,477,28 18,07 2,185,22 MWD (4) 7,530.97 94.83 210.36 6,516.60 6,428.15 -1,915.69 1,107.49 5,993,268.72 529,460.27 23.75 2,201.33 MWD (4) 7,561.03 94.64 204.04 6,514.12 6,425.67 -1,942.32 1,093.80 5,993,242.04 529,446.68 20.96 2,220.01 MWD (4) 7,591.24 94.42 197.52 6,511.73 6,423.28 -1,970.46 1,083.13 5,993,213.86 529,436.11 21.53 2,241.30 MWD (4) 7,620.89 94.79 190.98 6,509.34 6,420.89 -1,999.09 1,075.85 5,993,185.21 529,428.95 22.02 2,264.44 MWD (4) 7,656.49 94.98 183.02 6,506.31 6,417.86 -2,034.27 1,071.53 5,993,150.02 529,424.76 22.28 2,294.75 MWD (4) 7,686.77 93.72 177.50 6,504.01 6,415.56 -2,064.45 1,071.40 5,993,119.84 529,424.74 18.65 2,322.22 MWD (4) 7,715.67 92.55 171.15 6,502.43 6,413.98 -2,093.15 1,074.25 5,993,091.16 529,427.71 22.31 2,349.57 MWD (4) 7,760.50 93.16 161.11 6,500.19 6,411.74 -2,136.56 1,084.97 5,993,047.79 529,438.59 22.41 2,393.56 MWD (4) 7,787.83 91.20 155.57 6,499.15 6,410.70 -2,161.93 1,095.05 5,993,022.46 529,448.76 21.49 2,420.83 MWD (4) 7,820.01 91.23 156.47 6,498.47 6,410.02 -2,191.33 1,108.12 5,992,993.12 529,461.94 2.80 2,453.00 MWD (4) 7,861.51 91.35 164.31 6,497.53 6,409.08 -2,230.38 1,122.04 5,992,954.12 529,476.00 18.89 2,494.33 MWD (4) 7,895.26 89.91 170.62 6,497.16 6,408.71 -2,263.31 1,129.36 5,992,921.23 529,483.45 19.18 2,527.36 MWD (4) 7,925.19 88.80 176.18 6,497.50 6,409.05 -2,293.02 1,132.79 5,992,891.52 529,487.00 18.94 2,555.88 MWD (4) 7,955.39 88.43 182.51 6,498.23 6,409.78 -2,323.20 1,133.14 5,992,861.36 529,487.46 20.99 2,583.54 MWD (4) 7,985.45 89.02 189.12 6,498.90 6,410.45 -2,353.08 1,130.10 5,992,831.47 529,484.53 22.07 2,609.55 MWD (4) 8,015.31 88.96 196.09 6,499.42 6,410.97 -2,382.20 1,123.59 5,992,802.33 529,478.13 23.34 2,633.44 MWD (4) 8,045.34 88.10 201.67 6,500.19 6,411.74 -2,410.59 1,113.88 5,992,773.90 529,468.53 18.79 2,655.35 MWD (4) 8,084.00 88.10 201.67 6,501.48 6,413.03 -2,446.50 1,099.61 5,992,737.94 529,454.40 0.00 2,682.26 PROJECTED to TD 9/9/2009 9:32:34AM Page 6 COMPASS 2003.16 Build 69 3C-14B Plugback Page 1 of Maunder, Thomas E (DOA) From: Long, Jill W[Jill.W.Long@conocophiIlips.com] Sent: Monday, August 31, 2009 9:30 AM To: Maunder, Thomas E (DOA) Cc: Ohlinger, James J; Gantt, Lamar L Subject: RE: 3C-14B Plugback Hi Tom, aoco _©AO Here are the answers to your questions: - TD of the lost section was 8084' MD - The new KOP is 7010' MD - The TD of the OHST is still the same as the original plan, 9260' MD Let me know what else you need. Thanks, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-240-6574 Fax: 918-662-6330 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 31, 2009 8:10 AM To: Long, Jill W Cc: Ohlinger, James J; Gantt, Lamar L Subject: RE: 3C-14B Plugback Morning Jill, Could you provide some of the depths regarding the OHST? What was the TD of the lost section and the new KOP? Thanks, Tom Maunder, PE AOGCC Fro—nti*. L-ea ill W[mailto:Jill.W.Long@conocophillips.com] Sent: Saturday, 2009 10:23 PM To: Maunder, Thomas E (DOA Cc: Ohlinger, James J; Gantt, Lamar L Subject: 3C-14B Plugback Tom, 8/31/2009 3C-14B Plugback • Page 1 of 1 Maunder, Thomas E (DOA) From: Long, Jill W[Jill.W.Long@conocophillips.com] Sent: Saturday, August 29, 2009 10:23 PM To: Maunder, Thomas E (DOA) Cc: Ohlinger, James J; Gantt, Lamar L Subject: 3C-1413 Plugback a'00"_ O c c Tom, This email is being sent to you as notification of a plugback in well 3C-1413 (permit #209-061). Due to concerns with hole stability, we have decided to plugback the current lateral and perform an openhole sidetrack. If you have questions or require further information please give me a call. Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-240-6574 Fax: 918-662-6330 8/31 /2009 11 %J ��M" E A4^ter ALASSA OIL AND GAS CONSERVATION COMMISSION Mr. James Ohlinger Coiled Tubing Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-14B ConocoPhillips Alaska, Inc. Permit No: 209-061 Surface Location: 1251' FNL, 1229' FEL, Sec. 14, T12N, R9E, UM Bottomhole Location: 402' FSL, 1' FWL, Sec. 13, T12N, R9E, UM Dear Mr. Ohlinger: Enclosed is the approved application for permit to drill the above referenced service 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 (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this -� day of July, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. r L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED PERMIT TO DRILL,1 20 AAC 25.005 rin a r% -_ r+ -_- f%. 1a. Type of Work: El ❑ Re-drillStratigraphic Re-entry ❑ 1b. Current Well Class: Exploratory Development Oil ❑ Test ElService ❑✓ Development Gas ❑ Multiple Zone❑ Single Zone ❑ 1c. Speer i we I is prop f . a. klu#1111114blull Coalbed Methane [AnchOJ ydrates ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ✓ Blanket Single Well Bond No. 59-52-180 • 11. Well Name and Number: 3C-14�� 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9260' • TVD: 6390' 12. Field/Pool(s): Kuparuk River Field Kupuruk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 1251' FNL, 1229' FEL Sec. 14, T12N, R9E, UM • Top of Productive Horizon: 2517' FSL, 17' FWL, Sec. 13, T12N, R9E, UM Total Depth: 402' FSL, 1' FWL Sec. 13, T12N, R9E, UM • 7. Property Designation: ADL 25634 8. Land Use Permit: 2567 13. Approximate Spud Date: 8/1/2009 9. Acres in Property: 2560 14. Distance to Nearest Property: 16500' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 528346 • y- 5995180 • Zone- 4 10. KB Elevation above MSL: 88 feet KB Elevation above GL: . etjAsame 15. Distance to Nearest Well Ooen Pool: 10-21 , 1700"'�Y"�� / I 16. Deviated wells: Kickoff depth: 6828 • ft. Maximum Hole Angle: 98° deg 17. Maximum Anticipated Pressures n pgfg see 7 AAC 25.035) Downhole: 3643 psig Surface: 3017 psig 18. Casing Program Size Specifications Setting Depth Quantity of Cement c. f. or sacks Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST-L 2943' 1 6822' 6210' 9260' 6390' slotted / solid liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 6953' Total Depth TVD (ft): 6403' Plugs (measured) Effective Depth MD (ft): 6854' Effective Depth TVD (ft): 6327' Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 188 sx CS II 116' 116' Surface 4025' 9-5/8" 940 sx PF'E', 505 sx PF'C' 4061' 3720' Intermediate 4062, 7" 550 sx Cl G, 200 sx PF'C' 4150' 3787' Liner 2692' 5.5" 153 sx CI G, 57 sx CI G w/GasBLOK 6616' 6116' Liner 635' 3.5" 51 sx Class G 6951' 6401' Perforation Depth MD (ft): 6789'-6803' Perforation Depth TVD (ft): 6273'-6285' 20. Attachments: Filing Fee ❑ BOP Sketch ✓ Drilling Program ✓ Time v. Depth Plot Shallow Hazard Analysis Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 Printed Name __jarnesgo-Wigger Title Coiled Tubing Engineer Signature �� • PhoneDate P�JG (o/ Commission Use Only Permit to Drill Number: API Number: 50- VZJ� ©v Permit Appro I Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ne, gas hydrates, or gas contained in shales: `N_ 7 sSQ0 Q�4 G,4 `� �5� Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [� Other: a S ` _ _QFS meassuurres: Yes [.� No ❑ Directional svy req'd: Yes [✓� No ❑ APPROVED BY THE COMMISSION 7/7/7 DATE: COMMISSIONER .09 r 01 Form 10-401 (Revised 1/2009) U l t t ,`r'A L Submit in Dupligate � �� OU 3C-14 L al - Coiled TAg Drilling C. l /� �lot q-A 3C- 1 Drilling Permit Engineer: James Ohlinger CT Drilling Engineer (907)265-1102 The anticipated spud date for Nabors CDR-2AC to drill a CTD A -sand horizontal lateral injector from well 3C-14A is August 2009. Summary of Operations: Well 3C-14A is currently a producer completed in the C-sand with 3-1/2" liner and tubing. 3C-14AL1 will be a single lateral to provide injection support to the North and South side of a major east/west fault for 1Q-15A and 3C-16. 3C-14AL1 will target the A2/A3-sand in the existing northern fault block and the A3-sand on the southern side of an estimated 100' thrown DTS fault with a single lateral. The sidetrack will utilize a through -tubing whipstock for exiting the 3-1/2" liner after the C-sand perforated interval is cement squeezed. Once the well is complete and pre -produced to clean it up, it will be converted to an injector to support the IQ-15A and 3C-16 producers. ' The 3C-14AL1 lateral will exit the 31/2" liner at 6828' MD in the B5-interval from a 31/2" monobore whipstock. The lateral will have 2,432' of openhole drilled and TD at 9,260' MD: The hole will be completed with a 2%" slotted liner to the top of the A -sand and solid liner covering the B-interval up to the liner top located inside the existing 31/2" liner 6822' MD. The 2-3/8" liner top will be tied into a r - straddle-packer completion that will cover the previous cemented C-sand perforated interval. -k lJt�/fart CTD Drill and Complete 3C-14A program: August 2009 Pre -Rig Work 1. SCMT Cement Bond Log 2. Test packoffs — T & IC, MIT-OA 3. TIFL, Positive pressure and drawdown tests on MV and SV. Drawdown test on SCSSV 4. Slickline tag fill/bottom, drift w/ dummy whipstock, obtain SBHP 5. E-Line to set a BOT 31/2" Mono -bore whipstock at 6828' MD j 6. Cement squeeze on existing C-sand perfs, clean out cement to TTWS / 7. Load tbg & IA, DGLV's. MIT -IA 8. Prep site for Nabors CDR2-AC Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3C-14AL1 Lateral a. Mill 2.74" window with 0° HS orientation at 6,828' MD b. Drill 2.70" x 3" bi-center lateral to the south at a TD of 9,260' MD c. Run the 2%" slotted liner from TD through the A -sand connected to solid liner through the B-interval into the existing 31/2" liner, utilize the SSSV to run liner and eliminate killing the well with KWF Page 1 of 3 6/2/2009 OU 3C-14AL1 Lateral — Coiled TAg Drilling d. The liner top will be completed with a KB Straddle Packer Assembly across the existing C- sand perfs. 3. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC Post -Rig Work 1. Obtain static BHP 2. Install GLV design 3. Pre -produce well for cleanup 4. Convert well to injection Mud Program • Will use chloride -based Biozan brine (8.5 ppg) for milling operations, and chloride -based Flo -Pro mud (-10.0 ppg) for drilling operations. There is a SSSV installed in 3C-14A so we should not have to kill the well to deploy the 2%" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class H drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. - Casing Program: - • 3C-14ALL 2%", 4.7#, L-80, ST-L slotted & solid liner from 9260' MD to—6822.' MD Existing Casing/Liner Information Surface: 0-4031' MD: 9%", J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi Intermediate: 0-4150' MD (top of window): 7", J-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Intermediate: 3924'-6616' MD: 51/z", L-80, 15.5 ppf Burst 7000 psi; Collapse 6280 psi Tubing: 0'-6316' MD: 31/2", L-80, 9.3 ppf Burst 10,160 psi; Collapse 10,530 psi Liner: 6341'-6950' MD: 31/z", L-80, 9.2 ppf Burst 10,160 psi; Collapse 10,530 psi Well Control: • Two well bore volumes (— 160 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum .potential surface .pressure is 3017 psi assuming a gas gradient to surface and maximum potential formation pressure (i.e. based on highest bottom hole pressure measurement in the vicinity, which is 3643 psi at the producer 1Q-15 in July 2008). • The annular preventer will be tested to 250 psi and 2500 psi. Page 2 of 3 ORIGI NAL 6/2/2009 OU 3C-14AL1 Lateral — Coiled TuGg Drilling Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 3C-14AL1 TD: 16,500' to property line,--1700' from well 1Q-21 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure 3C-16 is the closest offset well producing the A -sand interval and has a static BHP survey of 1605 psi at 6241' TVDss, or 4.9 ppg EMW. The most recent static BHP survey in well 3C-14A was taken August 2008 which measured the C-sand reservoir pressure of 3641 psi at 6796'MD, 6191' TVDss, which corresponds to 11.3 ppg EMW. Expect to encounter similar to slightly increasing pressure as the laterals are drilled towards the producing well 1Q-15, although higher pressures could be encountered with unexpected fault crossings. Hazards • Lost circulation is not expected to be particularly troublesome. Expect to encounter similar to slightly increasing pressure as the laterals are drilled away from the mother well. • Well 3C-14A has 130 ppm H2S as measured on 4/27/08. The maximum H2S level on the 3C pad is 160 ppm measured on 1/22/08 at 3C-08. 3C-08 is 670' to the left of 3C-14. All H2S monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by. using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 3C-14 does have a SSSV, so the well will not have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 1600 psi at 6218' TVDss, with a 4.95 ppg EMW on the North side of the primary fault. On the north side, 3C-16 has a static BHP survey of 1605 psi at 6241' TVDss, or 4.9 ppg EMW. On the south side, drilling towards 1Q-15 with a pressure up to 3643 psi at 6265' TVDss or 11.2 EMW. • Expected annular friction losses while circulating: 615 psi (assuming friction of 90 psi/1000 ft due to the 31/2" tubing) • Planned mud density: 10.0 ppg equates to 3233 psi hydrostatic bottom hole pressure at 6218' TVDss. • While circulating 10.0 ppg mud, bottom hole circulating pressure is estimated to be 3848 psi or 11.9 ppg . EMW without holding any additional surface pressure. This will sufficiently overbalance formation pressure in 3C-14AL1. If increased formation pressure is encountered while drilling the lateral, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, it is anticipated that —600 psi of surface pressure shall have to be applied to maintain the same pressure as during drilling. Page 3 of 3 17�1 I G I N A L 6/2/2009 - CoIM Tubing Drilling 6/3/2009 ConocoPhillips '/,-Mile Sundry — Cement Evaluation for Injection Permit Assessment of Cement and Wells With -in One -Quarter Mile for Application to Convert to Water Injection i y_� Well: 3C-1� Rig: Nabors CDR-2AC Well 3C-14A is currently a producer completed in the C-sand with 3-1/2" liner and tubing. The CTD sidetrack will be renamed 3C-14ALL It will target the A2/A3-sand in the existing northern fault block and the A3-sand on the southern side of an estimated 100' thrown DTS fault with a single lateral. The sidetrack will utilize a through -tubing whipstock for exiting the 3-1/2" liner, after the C-sand perforated interval; 6789' - 6803' MD (6272 - 6285' TVD) is targeted with a 12 ppg cement squeeze. The completion will consist of a 2%" slotted liner and tied into a straddle - packer completion that will cover the previously cemented C-sand perforated interval. The 3-1/2" liner in 3C-14A was run on 2/23/08 with Stop Collars in the middle of each joint for the first 10 joints. Then ran 3-1/2" x 4-1/2" Straight Blade Centralizers floating between the stops: covering from 6950' to 6590' MD, and circulating and reciprocating the pipe 15'. When pumping the cement job, they flooded the lines with 5 bbls water and pressure tested to 4500 psi. Then they pumped 9.9 bbls of 8.41 ppg CW 100, 18.5 bbls 14.85 ppg Mud Push, and setting the 3-1/2" liner in place with 10.75 bbls of 15.8 ppg class G cement. Compared to a gauge open hole volume of 7.32 bbls. The SCMT log ran on 9/22/08 in the 3-1/2" liner shows excellent cement coverage for converting 3C-14 into an injector. Cement is more than adequately present from the C-sand perforated I interval 6803' MD/6285' TVD to 6650' MD/6148' TVD, and with the top of cement at the seal ' assembly (6335' MD/5847' TVD) within the 5-1/2" 15.5# L-80 casing. 3C-17 3C-17 is a new well completed as a Producer in the Kuparuk A -sand, and at 6,885' MD/6075' TVD is 611 ft away from the proposed 3C-14B at 6,828' MD/6306' TVD. The Kuparuk A3 sand has been hydraulically fractured through the perforations from 7420' to 7440' MD (6532'- 6550' TVD) in the 3-1/2" (9.2# L-80) liner. The 3-1/2" liner covers from 7,077' MD to 7,65l' MD; (6236' — 6655' TVDss). The cement bond log that was ran on 8/25/08 shows adequate cement above and below the perforations in the A3 interval. There is additional isolation with cement above the B Shale. 3C-15 The original well has been plugged. In 3C-15 at 7245' MD/6245' TVD it is 1348' away in the Kuparuk A -sand interval from 3C-14B at 8050' MD/6577' TVD. This well was sidetracked 08/01/08 and renamed 3C-15A. On 4/27/08 an HES 2 7/8" FastDrill Cement Retainer with the mid -element set at 7155' MD. A Coil Unit then pumped a total of 61 bbls of cement, with 35 bbls below the cement retainer, and James Ohlinger 1/4-Mile Sundry — Cement Evaluation Page 1 of 2 t � 4 �. CoW Tubing Drilling 5/18/2009 ConocoPhillips i/,_Mile Sundry — Cement Evaluation for In'ection Permit 30 bbls into the C Sand. Cement was tagged at 7091' MD. After failing the initial MITIA a GLM was repaired and passed on 5/4/08. 3C-15A exited above the "K-l" CIBP that was set in the 7" (26# J-55) at 3017' MD through the 7" and 9 5/8" casing departing in a northwest direction away from 3C-14B. The 5-1/2" liner in 3C-15A was down squeezed from the top with 48 bbls of 15.8 ppg cement along with the 3-1/2" Liner. James Ohlinger 1/4-Mile Sundry — Cement v ion Page 2 of 2 3C-14 1 Proposed CTD Sidetrack 16" 62.5# H-40 shoe @ 116' MD 9-5/8" 36# J-55 shoe @ 4061' MD 7" 26# J-55 Top of Window @ 4150' MD 5.5" 15.5# L-80 e 6616' MD C-sand perfs 6789' - 6803' MD cement squeeze KOP @ 6828' MD 3" Monobore Whipstock 3-1/2" 9.2# L-80 shoe @ 6950' MD SSSV @ 2026' MD 2026' MD (Tubing Tally) ID = 2.812" 3-1/2" 9.3# L-80 IBTM Tubing 6316' MD surface 3 1/2" 9.2# L-80 Hydril 511 Tubing 6351' MD 5-1/2" Liner Top Packer @ 3924' MD 5-1/2" Liner Hanger @ 3935' MD 3-1/2" Camco KBG gas lift mandrels @ 2544' MD RKB 4066' MD RKB 5082' MD RKB 5873' MD RKB 6172' MD RKB 3-1/2" Camco IDS landing nipple @ 6252' MD RKB (2.75" min ID) 6246' MD ELM Locator Coupling @ 6322' MD RKB (6316' ELM) ID = 2.99" Baker 3 1/2" ZXP Extension @ 6323' ELM ID = 4.13" Baker 3-1/2" ZXP liner top packer @ 6335' ELM ID = 3.00" Baker 3-1/2" liner hanger @ 6344' ELM ID = 2.93" 12" Tubing Collars @ 6793' & 6824' 3-1/2" Stop Collars in the middle of each joints f/ #1 - #10 3-1/2" x 4-1/2" Straight Blade Centralizers floating between stops: rina f/ 6950' to 6590' MD 6824' Collar 2 3/8" Solid Liner through the 11 2 3/8" Slotted Liner: TD - 9260' MD 6842' ELM PBTD 6853' Landing Collar 6886' Float Collar_- 0 James Ohlinger 3C-14AL1 CTD Planning workbook.xls 6/2/2009 CD 1 3C-14A 16" 62.5# H-40 Ishoe @ 116' MD I Exisitinq Schematic 9-5/8" 36# J @ 4061' MD IC -sand pe cement sq 3 SSSV @ 2020' MD 2026' MD (Tubing Tally) 1/2" 9.3# L-80 IBTM Tubing 6316' MD surface 1/2" 9.2# L-80 Hydril 511 Tubing 6351' MD /2" Liner Top Packer @ 3924' MD /2" Liner Hanger @ 3935' MD /2" Camco KBG gas lift mandrels @ 2538' MD 4060' MD 5076' MD 5867' MD 6166' MD /2" Camco IDS landing nipple @ 6246' MD (2.75" min ID) )r Coupling @ 6316' MD ID = 2.99" 3 112" ZXP Extension @ 6316' MD ID = 4.13" 3-1 /2" ZXP liner top packer @ 6335' MD ID = 3.00" 3-1/2" liner hanger @ 6344' MD ID = 2.93" 1/2" Tubing Collars @ 6793' & 6824' 3-1/2" Stop Collars in the middle of each joints f/ #1 - #10 3-1 /2" x 4-1 /2" Straight Blade Centralizers floating between stops. ring f/ 6950' to 6590' MD 9 I* James Ohlinger 3C-14AL1 CTD Planning workbook.xls 5/18/2009 `r Conoa3�hillips 0 KUP Alaska, Inc Well Cori : • 3C-14A 6222008 2:38:29 PM Schem2 -AcIN - --- --`------�-- --- HANGER. 38 XO TUBING, 42 Conductor, - 0-116 SSSV, 2,026 :. GAS LIFT, C_ 2,5" Surface, 0-4,061 GAS LIFT, G 4,066 Production, ___ 04.ISo GAS LIFT, C-- 5,082 GAS LIFT. 5,a73 GAS LIFT, [.. 6, 172 NIPPLE, 6,252---- ---- '�-r LOCATOR, 6, 323 SEAL ASSY, 6,336 512" Liner, 3.924-6 616 IPERF, 6,78MB03 3-12° Liner, o(3C-1451 TD (3C 6M), 6,853 0 3C-14A Well At API / UWI Field Name Well Status Maximum Inclination (°) Total Depth (ftKB) 5002921425 KUPARUK RIVER UNIT INJ 42.59 8,450.0 Comment SSSV: TRDP H2S (ppm) Date 130 7/1/2008 Annatrtion Last W0: End Date KB -Ground Distance (ft) 37.40 Rig Release Date 2/262008 Annotation Depth Last Tag: (ftKB) End 6,816.0 8/21/2008 Date Annotation Rev Reason: GLV C/O, TAG End Data 8/22/2008 Casing Strings Casing Description Conductor OD (in) 16 ID (in) Top 15.062 (ftKB) Set 0.0 Depth (ft... Set 116.0 Depth (TVD) (ft... 116.0 Wt (lbs/... 62.50 Grade H-40 Top Connection Casing Description Surface OD (In) 95/8 ID (In) Top 8.765 (ftKB) Set 0.0 Depth (I Set 4'061.0 Depth (TVD) (it.. 3,720.4 Wt (lbal... 36.00 Grade J-55 Top Connection Casing Description Production OD (in) 7 ID (In) Top 6.151 (ftKB) Set 0.0 Depth (I Set 4.150.0 Depth (TVD) (It... 3,787.5 Wt (lbsl... 26.00 Grade J-55 Top Connection Casing Description 5 1/2" Liner OD (In) 5 1/2 ID (In) Top 4.850 (ftKB) Set 3,924.1 Depth (i Set 6,616.0 Depth (TVD) (ft... 6,115.9 Wt (lba/... 15.50 Grade L-80 Top Conrlectlon Hydril 511 Liner Details Top(ftKB)l Item Description Comment ID (In) 3,924.11 PACKER 5.5" X 7" LTP "CHIP" C-2 profile w/ 6.1' ext. Est 5.5" ID (Pkr 4.91" ID) 4.910 3,934.9 HANGER HMC liner hanger - 5.5" Vam p X p (4.96" ID) 4.960 6,529.6 COLLAR 5.5" Weatherford 403 Float Collar 4.850 Casing Description OD (In) ID (in) Top (ftKB) Set Depth (R.. Set Depth (TVD) (it Wt (Ibsl... Grade Top Connection 3-1/2" Liner 3 1/2 2.992 6,316.1 6,951.0 6,401.2 9.20 L-80 Hydril 511 Liner Details Top (ftKB) Item Description Comment to (in) 6,316.1 SBE ZXP Seal Bore Extension 4.130 6,335.3 PACKER HR ZXP Liner Top Packer 3.000 6,343.7 HANGER HMC Liner Hanger 2.926 6,854.0 COLLAR Baker 3-1/2 Type I Landing Collar 2.886 6,886.4 COLLAR 3-1/2" Weatherford Float Collar 2.880 Tubing Strings Tubing Description OD (in) ID (In) Top (tt... Set Depth (ftK... Set Depth (TVD) (ftKB) Wt (Ibslft) Grade Top Connection TUBING 31/2 2.992 37.7 6,341.0 5,852.8 9.30 L-80 IBTM Com letion Details Top (ftKB) Item Description Comment ID (in) 37.7 HANGER CIW Gen 4, Type N-FB8, "H" BPV profioe, P/N 156156-01-01-01 2.992 2,026.5 SSSV 3.5" TRMAXX-5E SCSSV w/ 2.812" X Profile Ser.# HZS-028 2.812 6,252.3 NIPPLE 3-1/2' x 2.750" Camco "D" Nipple (ELIE 8rd) 2.750" No -Go Profile 2.750 6,322.7 LOCATOR Baker Locator Coupling (4.4(Y" O.D.) 2.990 6,335.5 SEAL ASSY Baker Bullet Seal Assembly (O.D. 4.1&') 2.990 Perforations Top Sir. (ftKB) (ftKB) Top (TVD) (ftKB) Elm (TV (ftKB) Type Zone Shot Dens (aho.. Date Comment 6,789.0 6,803.0 6,272.1 6,284.5 IPERF C-1, 3C-14A 1 6.0 3/14/2008 2.5" PJ 2506, 60 Deg Phase Notes: General & Safety End Date Annotation 8/22/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9,0 Mandrel Details Sin Top (ftKB) Set Depth (TVD) (ftKB) Make Model DD (in) Valve Type Latch Type Port Size (in) TRO Run (pat) Run Date Comment 1 2,543.9 5,852.8 Cameo KBG-2-9 1 GLV INT 1/8 1,338.0 W2008 2 4,065.9 5,852.8 Cameo KBG-2-9 1 GLV INT 0.156 1,350.0 3/5/2008 3 5,082.3 5,852.8 Cameo KBG-2-9 1 GLV INT 0.156 1,331.0 3/5/2008 4 5,872.5 5,852.8 Cameo KBG-2-9 1 GLV INT 0.156 1,312.0 3/5/2008 5 6,172.1 5,852.8 Cameo KBG-2-9 1 1 OV INT 1 3/16 0.0 8/21/2008 ORIGINAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-14 Plan 5, 3C-14AL1 Plan: Plan 5 Standard Planning Report 20 May, 2009 FOR11 BAKER HUGMS IN EQ ✓ ConocoPhillips ISM ConocoPhillips Planning Report RM16 Alaska INTEQ 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 gKuparuk 3C Pad Site Position: Northing: 5,995,835.14ft Latitude: 70* 23'58.955 N From: Map Easting: 528,205.68ft Longitude: 149' 46' 13.622 W Position Uncertainty: 0.0 ft Slot Radius: Grid Convergence: 0.22 Well Position +Nl-S 0.0 ft Northing: 5,995,180.01 ft r Latitude: 70* 23'52.506 N +E/-W 0.0 ft Easting: 528,345.63 ft Longitude: 149* 46'9.594 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 47.6ft Plan 5, 3C-14ALI Model Name Sample Date Declination now, """Non User Defined 8/17/20C9 22.12 80.87 57,689 Audit Notes: Version: 512012009 10:43:56PM Page 2 COMPASS 2003.16 Build 42F i 0 ✓ ConocoPhillips nag ConocoPhillips Planning Report Alaska INTEQ 6,820.0 32.32 180.52 6,210.7 -1,334.6 1,276.6 0.00 0.00 0.00 0.00 6,828.0 33.14 181.72 6,217.5 -1,338.9 1,276.5 13.05 10.24 14.98 38.86 6,848.0 34.71 180.14 6,234.1 -1,350.1 1,276.4 9.00 7.85 -7.90 330.00 6,908.0 42.71 173.52 6,280.9 -1,387.4 1,278.6 15.00 13.34 -11.04 330.00 6,938.0 47.21 173.52 6,302.1 -1,408.5 1,281.0 15.00 15.00 0.00 0.00 7,064.0 63.61 185.03 6,373.5 -1,511.6 1,281.3 15.00 13.02 9.14 33.50 7,232.9 86.00 197.41 6,417.7 -1,669.9 1,248.9 15.00 13.26 7.33 30.00 7,265.3 85.93 192.54 6,420.0 -1,701.1 1,240.6 15.00 -0.22 -15.04 269.00 7,414.3 86.44 214.94 6,430.0 -1,836.3 1,181.1 15.00 0.34 15.03 89.46 7,742.8 86.16 165.55 6,452.6 -2,148.9 1,124.6 15.00 -0.08 -15.03 268.00 7,872.8 87.85 181.08 6,459.4 -2,277.5 1,139.6 12.00 1.30 11.95 84.24 7,986.8 74.17 181.08 6,477.2 -2,389.8 1,137.5 12.00 -12.00 0.00 180.00 8,136.8 89.89 172.20 6,498.0 -2,537.5 1,146.4 12.00 10.48 -5.93 330.00 8,221.8 89.89 162.00 6,498.1 -2,620.2 1,165.3 12.00 0.00 -12.00 270.00 8,321.8 98.37 170.51 6,490.9 -2,716.9 1,189.0 12.00 8.48 8.52 44.80 8,514.5 96.29 193.74 6,466.0 -2,906.5 1,181.9 12.00 -1.08 12.05 93.60 8,849.5 95.44 153.32 6,430.3 -3,230.7 1,218.8 12.00 -0.25 -12.06 271.00 9,260.0 95.14 202.81 6,389.9 -3,626.4 1,232.1 12.00 -0.07 12.05 87.90 512012009 10:43:56PM Page 3 COMPASS 2003.16 Build 42F • 0 ✓ ConocoPhillips In;:llill! ConocoPhillips Planning Report Alaska INTEQ 100.0 0.19 225.45 11.5 -0.1 -0.1 0.1 0.00 0.00 5,995,179.94 528,345.56 200.0 0.18 232.28 111.5 -0.3 -0.3 0.3 0.02 114.13 5,995,179.72 528,345.31 300.0 0.22 219.98 211.5 -0.5 -0.6 0.5 0.06 -54.80 5,995,179.48 528,345.07 400.0 0.32 207.88 311.5 -0.9 -0.8 0.9 0.11 -36.14 5,995,179.09 528,344.82 500.0 0.41 170.99 411.5 -1.5 -0.9 1.5 0.25 -86.55 5,995,178.49 528,344.74 600.0 0.09 161.36 511.5 -2.0 -0.8 2.0 0.32 -177.29 5,995,178.04 528,344.83 700.0 0.17 168.24 611.5 -2.2 -0.8 2.2 0.08 15.09 5,995,177.84 528,344.89 800.0 0.51 162.91 711.5 -2.7 -0.6 2.7 0.34 -7.92 5,995,177.28 528,345.04 900.0 0.63 161.35 811.5 -3.7 -0.3 3.7 0.12 -8.21 5,995,176.33 528,345.35 1,000.0 0.73 157.82 911.5 -4.8 0.1 4.8 0.11 -24.37 5,995,175.23 528,345.77 1,100.0 0.67 151.38 1,011.5 -5.9 0.6 5.9 0.10 -127.97 5,995,174.12 528,346.30 1,200.0 0.67 143.49 1,111.5 -6.9 1.3 6.8 0.09 -95.26 5,995,173.14 528,346.93 1,300.0 0.67 142.23 1,211.5 -7.8 2.0 7.8 0.01 -89.83 5,995,172.22 528,347.64 1,400.0 0.70 145.46 1,311.5 -8.8 2.7 8.7 0.05 54.79 5,995,171.26 528,348.35 1,500.0 0.77 157.15 1,411.5 -9.9 3.3 9.8 0.16 71.42 5,995,170.14 528,348.96 1,600.0 0.82 162.10 1,511.5 -11.2 3.8 11.1 0.09 55.76 5,995,168.84 528,349.44 1,700.0 0.56 153.22 1,611.5 -12.3 4.2 12.2 0.28 -162.03 5,995,167.72 528,349.89 1,800.0 0.29 142.74 1,711.5 -12.9 4.6 12.9 0.28 -169.17 5,995,167.09 528,350.26 1,900.0 0.71 134.07 1,811.5 -13.6 5.2 13.5 0.43 -14.47 5,995,166.47 528,350.85 2,000.0 4.03 138.70 1,911.4 -16.6 7.9 16.4 3.32 5.63 5,995,163.47 528,353.58 2,100.0 8.11 137.88 2,010.8 -24.4 14.9 24.2 4.08 -1.64 5,995,155.64 528,360.65 2,200.0 12.32 135.60 2,109.2 -37.3 27.1 36.8 4.23 -6.58 5,995,142.82 528,372.88 2,300.0 16.39 135.89 2,206.0 -55.1 44.4 54.3 4.07 1.14 5,995,125.13 528,390.25 2,400.0 20.82 138.86 2,300.8 -78.6 66.0 77.4 4.52 13.48 5,995,101.71 528,411.88 2,500.0 23.96 139.06 2,393.2 -107.3 91.0 105.7 3.15 1.48 5,995,073.04 528,437.00 2,600.0 24.87 137.97 2,484.3 -138.3 118.4 136.3 1.01 -26.85 5,995,042.13 528,464.53 2,700.0 27.80 136.62 2,573.9 -170.9 148.4 168.3 2.99 -12.14 5,995,009.72 528,494.71 2,800.0 30.52 141.93 2,661.2 -207.8 180.2 204.6 3.76 45.86 5,994,972.95 528,526.60 2,900.0 33.67 146.86 2,746.0 -251.0 211.0 247.3 4.09 41.90 5,994,929.85 528,557.59 3,000.0 35.76 148.98 2,828.1 -299.3 241.2 295.0 2.41 30.87 5,994,881.67 528,587.96 3,100.0 37.07 143.75 2,908.6 -348.7 274.0 343.9 3.37 -69.20 5,994,832.35 528,620.93 3,200.0 39.09 137.60 2,987.4 -396.4 313.1 390.8 4.30 -64.38 5,994,784.88 528,660.19 3,300.0 40.74 133.54 3,064.1 -442.1 358.0 435.8 3.08 -59.26 5,994,739.30 528,705.31 3,400.0 42.33 134.64 3,138.9 -488.2 405.7 481.0 1.74 25.03 5,994,693.41 528,753.17 3,500.0 42.40 135.52 3,212.8 -535.9 453.3 527.9 0.60 83.24 5,994,645.86 528,800.94 3,600.0 42.32 135.65 3,286.7 -584.1 500.5 575.2 0.11 131.92 5,994,597.90 528,848.27 3,700.0 42.09 135.69 3,360.7 -632.1 547.4 622.5 0.24 173.14 5,994,550.03 528,895.39 3,800.0 41.68 135.73 3,435.2 -679.9 594.0 669.4 0.41 176.23 5,994,502A2 528,942A9 3,900.0 41.19 135.65 3,510.1 -727.3 640.3 716.0 0.50 -174.26 5,994,455.24 528,988.59 4,000.0 40.65 135.73 3,585.7 -774.1 686.0 762.1 0.54 174.86 5,994,408.55 529,034.52 4,064.5 40.76 135.92 3,634.6 -804.3 715.3 791.7 0.26 47.42 5,994,378.51 529,063.94 4,100.0 40.84 136.03 3,661.5 -821.0 731.5 808.1 0.30 42.58 5,994,361.89 529,080.13 4,150.0 41.78 136.81 3,699.1 -844.9 754.2 831.6 2.14 29.10 5,994,338.09 529,102.96 7" TOW 4,200.0 42.06 137.06 3,736.1 -869.4 777.1 855.8 0.65 31.36 5,994,313.60 529,125.96 4,300.0 38.07 137.20 3,812.7 -916.5 820.8 902.0 3.99 178.84 5,994,266.71 529,169.82 4,400.0 35.24 137.35 3,892.9 -960.3 861.3 945.2 2.83 178.16 5,994,223.04 529,210.48 4,500.0 32.25 137.30 3,976.0 -1,001.3 899.0 985.5 3.00 -179.44 5,994,182.19 529,248.31 4,600.0 28.60 136.64 4,062.2 -1,038.3 933.5 1,021.9 3.66 -175.09 5,994,145.32 529,283.00 4,700.0 24.63 136.18 4,151.5 -1,070.9 964.5 1,053.9 3.97 -177.22 5,994,112.90 529,314.13 4,800.0 19.98 134.75 4,244.0 -1,098.2 991.1 1,080.7 4.68 -173.98 5,994,085.73 529,340.75 4,900.0 15.42 130.61 4,339.3 -1.118.8 1,013.2 1,100.9 4.73 -166.56 5,994,065.19 529,362.96 512012009 10:43:56PM Page 4 COMPASS 2003.16 Build 42F r] r.' ConocoPhillips ConocoPhillips Planning Report Alaska INTEQ 5,000.0 11.90 124.38 4,436.5 -1,133.1 1,031.7 1,114.9 3.81 -160.31 5,994,050.98 529,381.49 5,100.0 9.10 114.63 4,534.8 -1,142.2 1,047.4 1,123.7 3.30 -152.27 5,994,041.91 529,397.20 5,200.0 7.79 105.10 4,633.8 -1,146.9 1,060.9 1,128.2 1.92 -137.87 5,994,037.22 529,410.75 5,300.0 7.49 103.56 4,732.9 -1,150.0 1,073.7 1,131.1 0.37 -146.88 5,994,034.19 529,423.60 5,400.0 7.27 103.70 4,832.1 -1,153.1 1,086.2 1,133.9 0.21 175.43 5,994,031.20 529,436.09 5,500.0 7.79 102.80 4,931.2 -1,156.0 1,098.9 1,136.7 0.53 -13.23 5,994,028.25 529,448.76 5,600.0 7.60 103.02 5,030.3 -1,159.0 1,112.0 1,139.5 0.19 171.55 5,994,025.31 529,461.91 5,700.0 8.04 102.77 5,129.4 -1,162.1 1,125.3 1,142.3 0.44 -4.54 5,994,022.33 529,475.17 5,800.0 6.92 104.47 5,228.5 -1,165.1 1,137.9 1,145.1 1.14 169.66 5,994,019.32 529,487.79 5,900.0 6.43 103.77 5,327.8 -1,168.0 1,149.1 1,147.7 0.50 -170.91 5,994,016.54 529,499.08 6,000.0 5.97 104.27 5,427.3 -1,170.6 1,159.5 1,150.1 0.47 173.58 5,994,013.97 529,509.49 6,100.0 6.31 107.36 5,526.7 -1,173.2 1,169.6 1,152.6 0.48 45.12 5,994,011.37 529,519.58 6,200.0 8.28 115.01 5,625.9 -1,177.9 1,181.2 1,157.2 2.19 30.10 5,994,006.67 529,531.18 6,300.0 12.22 115.65 5,724.4 -1,185.5 1,197.0 1,164.4 3.94 1.96 5,993,999.19 529,547.02 6,400.0 15.12 131.20 5,821.5 -1,198.4 1,216.9 1,176.9 4.65 59.53 5,993,986.40 529,566.99 6,500.0 17.21 141.98 5,917.5 -1,218.8 1,235.7 1,197.0 3.65 60.32 5,993,966.06 529,585.86 6,600.0 %00 150.23 6,012.6 -1,244.5 1,253.2 1,222.4 3.12 59.07 5,993,940.44 529,603.41 6,616.0 19.63 152.22 6,027.7 -1,249.1 1,255.7 1,227.0 5.68 47.52 5,993,935.81 529,605.97 5,1/2" 6,700.0 24.50 160.77 6,105.6 -1,277.9 1,268.0 1,255.6 6.93 37.41 5,993,907.02 529,618.30 6,800.0 31.06 177.60 6,193.7 -1,324.1 1,276.5 1,301.6 10.17 57.79 5,993,860.91 529,626.97 6,820.0 32.32 180.52 6,210.7 -1,334.6 1,276.6 1,312.1 9.94 51.74 5,993,850.42 529,627.17 TIP 6,828.0 33.14 181.72 6,217.5 -1,338.9 1,276.5 1,316.4 13.05 38.86 5,993,846.09 529,627.10 KOP 6,848.0 34.71 180.14 6,234.1 -1,350.1 1,276.4 1,327.6 9.00 -30.00 5,993,834.93 529,626.97 End of 9 deg/100' DLS 6,900.0 41.62 174.28 6,274.9 -1,382.1 1,278.0 1,359.6 15.00 -30.00 5,993,802.90 529,628.78 6,908.0 42.71 173.52 6,280.9 -1,387.4 1,278.6 1,364.9 15.00 -25.38 5,993,797.56 529,629.37 4' 6,938.0 47.21 173.52 6,302.1 -1,408.5 1,281.0 1,385.9 15.00 0.00 5,993,776.52 529,631.84 5 6,950.0 48.72 174.84 6,310.1 -1,417.4 1,281.9 1,394.8 15.00 33.50 5,993,767.66 529,632.78 3 1/2" 7,000.0 55.15 179.76 6,340.9 -1,456.6 1,283.7 1,434.0 15.00 32.61 5,993,728.38 529,634.71 7,064.0 63.61 185.03 6,373.5 -1,511.6 1,281.3 1,489.0 15.00 29.58 5,993,673.44 529,632.51 6 7,100.0 68.32 187.93 6,388.2 -1,544.2 1,277.6 1,521.7 15.00 30.00 5,993,640.77 529,628.91 7,200.0 81.60 195.18 6,414.1 -1,638.5 1,258.1 1,616.3 15.00 28.82 5,993,546.42 529,609.79 7,232.9 86.00 197.41 6,417.7 -1,669.9 1,248.9 1,647.9 15.00 26.92 5,993,515.01 529,600.74 7 7,265.3 85.93 192.54 6,420.0 -1,701.1 1,240.6 1,679.2 15.00 -91.00 5,993,483.77 529,592.51 8 7,300.0 86.00 197.76 6,422.4 -1,734.5 1,231.5 1,712.8 15.00 89.46 5,993,450.33 529,583.59 7,400.0 86.37 212.79 6,429.1 -1,824.5 1,189.0 1,803.5 15.00 89.09 5,993,360.22 529,541.45 7,414.3 86.44 214.94 6,430.0 -1,836.3 1,181.1 1,815.5 15.00 88.09 5,993,348.34 529,533.55 9 7,500.0 86.09 202.06 6,435.6 -1,911.3 1,140.4 1,891.1 15.00 -92.00 5,993,273.20 529,493.12 7,600.0 85.92 187.02 6,442.6 -2,007.6 1,115.4 1,987.9 15.00 -91.16 5,993,176.83 529,468.51 7,700.0 86.03 171.99 6,449.7 -2,107.1 1,116.2 2,087.3 15.00 -90.10 5,993,077.38 529,469.74 7,742.8 86.16 165.55 6,452.6 -2,148.9 1,124.6 2,129.0 15.00 -89.04 5,993,035.56 529,478.21 End of 15 deg/100' DlS 512012009 10:43:56PM Page 5 COMPASS 2003.16 Build 42F ,'IIAL 0 'v ConocoPhillips idat ConocoPhillips Planning Report W Alaska 1NTEQ 7,800.0 86.88 172.39 6,456.1 -2,205.0 7,872.8 87.85 181.08 6,459.4 -2,277.5 11" 7,900.0 84.59 181.08 6,461.2 -2,304.6 7,986.8 74.17 181.08 6,477.2 -2,389.8 12 8,000.0 75.54 180.27 6,480.6 -2,402.5 8,100.0 86.02 174.32 6,496.7 -2,500.9 8,136.8 89.89 172.20 6,498.0 -2,537.5 13 8,200.0 89.89 164.61 6,498.1 -2,599.3 8,221.8 89.89 162.00 6,498.1 -2,620.2 14 8,300.0 96.53 168.64 6,493.7 8,321.8 98.37 170.51 6,490.9 15 8,400.0 97.68 179.96 6,480.0 8,500.0 96.49 192.00 6,467.6 8,514.5 96.29 193.74 6,466.0 16 8,600.0 96.37 183.41 6,456.5 8,700.0 96.20 171.34 6,445.6 8,800.0 95.76 159.28 6,435.1 8,849.5 95.44 153.32 6,430.3 17 8,900.0 95.64 159.41 6,425.4 9,000.0 95.83 171.47 6,415.4 9,100.0 95.76 183.53 6,405.2 9,200.0 95.44 195.58 6,395.4 9,260.0 95.14 202.81 6,389.9 TD - 2 3/8" 1,135.5 2,184.8 1,139.6 2,257.2 1,139.1 2,284.4 1,137.5 2,369.6 1,137.3 2,382.3 1,142.0 2,480.6 1,146.4 2,517.1 1,159.1 2,578.7 1,165.3 2,599.5 -2,695.6 1,185.1 2,674.6 -2,716.9 1,189.0 2,695.7 -2,794.0 1,195.4 2,772.7 -2,892.5 1,185.1 2,871.4 -2,906.5 1,181.9 2,885.5 -2,990.4 1,169.2 2,969.6 -3,089.6 1,173.8 3,068.6 -3,185.6 1,199.0 3,164.2 -3,230.7 1,218.8 3,208.9 -3,276.7 1,238.9 3,254.6 -3,372.8 1,263.9 3,350.2 -3,472.0 1,268.2 3,449.4 -3,570.0 1,251.7 3,547.6 -3,626.4 1,232.1 3,604.3 12.00 84.24 5,992,979.60 529,489.34 12.00 83.82 5,992,907.09 529,493.74 12.00 -180.00 5,992,879.96 529,493.33 12.00 -180.00 5,992,794.78 529,492.04 12.00 -30.00 5,992,782.04 529,491.94 12.00 -29.79 5,992,683.66 529,497.04 12.00 -28.83 5,992,647.17 529,501.50 12.00 -90.00 5,992,585.35 529,514.42 12.00 -89.99 5,992,564.50 529,520.76 12.00 44.80 5,992,489.15 529,540.83 12.00 45.17 5,992,467.91 529,544.82 12.00 93.60 5,992,390.86 529,551.53 12.00 94.92 5,992,292.33 529,541.58 12.00 96.41 5,992,278.27 529,538.42 12.00 -89.00 5,992,194.32 529,526.09 12.00 -90.14 5,992,095.24 529,531.01 12.00 -91.47 5,991,999.32 529,556.55 12.00 -92.73 5,991,954.31 529,576.50 12.00 87.90 5,991,908.36 529,596.82 12.00 88.49 5,991,812.35 529,622.15 12.00 89.70 5,991,713.17 529,626.86 12.00 90.92 5,991,615.16 529,610.74 12.00 92.10 5,991,558.71 529,591.33 5/20/2'009 10:43:56PM Page 6 COMPASS 2003.16 Build 42F ORIGINAL • 0 ✓ ConocoPhillips IN -to COnocoP fillips Planning Report Alaska INTEQ 3C-14AL1 1:6.5 (copy) 0.00 0.00 6,390.0 -3,625.7 1,232.2 - plan hits target - Point 3C-14AL1 t3.5 (copy) 0.00 0.00 6,460.0 -2,281.3 1,139.3 - plan hits target - Point 3C-14AL1 Polygon (a 0.00 0.00 0.0 -1,014.4 1,212.1 - plan misses by 1580.6ft at 100.Oft MD (11.5 TVD, -0.1 N, -0.1 E) - Polygon Point 1 0.0 -1,014.4 1,212.1 Point 0.0 -1,197.1 1,393.4 Point 0.0 -1,413.2 1,415.6 Point 0.0 -2,381.1 1,355.0 Point 5 0.0 -2,847.2 1,376.3 Point 0.0 -3,807.4 1,383.7 Point 7 0.0 -3,828.3 1,087.6 Point 8 0.0 -2,265.5 934.4 Point 9 0.0 -1,399.8 1,028.6 Point 10 0.0 -1,217.5 960.3 Point 11 0.0 -1,014.4 1,212.1 3C-1,4AL1 1:1.5 (copy) 0.00 0.00 6,375.0 -1,511.6 1,247.2 plan misses by 33.9ft at 7068.1ft MD (6375.4 TVD,-1515.3 N, 1280.9 E) Point 3C-1.4AL1 1:2.5 (copy) 0.00 0.00 6,430.0 -1,836.4 1,181.0 - plan hits target - Point 3C-14AL1 1:5.5 (copy) 0.00 0.00 6,466.0 -2,906.5 1,181.9 - plan hits target - Point 3C-14AL1 t4.5 (copy) 0.00 0.00 6,498.0 -2,588.4 1,176.1 - plan misses by 19.3ft at 8192.7ft MD (6498.1 TVD, -2592.3 N, 1157.2 E) - Point 3C-14AL1 fault 1 (cop 0.00 0.00 0.0 -2,359.5 1,203.0 - plan misses by 2648.5ft at 100.Oft MD (11.5 TVD, -0.1 N, -0.1 E) - Polygon Point 1 0.0 -2,359.5 1,203.0 Point 0.0 -2,318.2 1,126.1 Point 3 0.0 -2,320.7 990.1 Point 0.0 -2,318.2 1,126.1 5,991,559.34 529,591.41 70° 23' 16.847 N 149° 45' 33.518 W 5,992,903.32 529,493.42 70° 23' 30.070 N 149° 45' 36.232 W 5,994,170.29 529,561.44 70° 23' 42.529 N 149° 45' 34.093 W 5,994,170.29 529,561.44 5,993,988.30 529,743.46 5,993,772.31 529, 766.47 5,992,804.30 529,709.51 5,992,338.30 529,732.54 5,991,378.30 529,743.59 5,991,356.29 529,447.59 5,992,918.28 529,288.51 5,993,784.29 529,379.47 5,993,966.28 529,310.45 5,994,170.29 529,561.44 5,993,673.30 529,598.44 70° 23' 37.639 N 149° 45' 33.067 W 5,993,348.31 529,533.43 70° 23' 34.445 N 149° 45' 35.009 W 5,992,278.32 529,538.42 70° 23' 23.921 N 149° 45' 34.987 W 5,992,596.32 529,531.42 70° 23' 27.049 N 149° 45' 35.155 W 5,992,825.32 529,557.43 70° 23' 29.300 N 149° 45' 34.367 W 5,992,825.32 529,557.43 5, 992, 866.31 529,480.43 5,992,863.30 529,344.42 5,992,866.31 529,480.43 4,064.5 3,634.6 9 5/8" 9-5/8 12-1/4 4,150.0 3,699.1 7" TOW 7 8-1/2 6,616.0 6,027.7 51/2" 5-1/2 7 6,950.0 6,310.1 31/2" 3-1/2 4-1/8 9,260.0 6,389.9 2 3/8" 2-3/8 3 5/20/2009 10:43:56PM Page 7 COMPASS 2003.16 Build 42F ORIGINAL 0 ✓ ConocoPhillips KA-1 ConocoPhillips Planning Report Alaska INTEQ TIP KOP End of 9 deg/100' DLS 4 5 6 7 8 9 End of 15 deg/100' DLS 11 12 13 14 15 16 17 TD 512012009 10:43:56PM Page 8 COMPASS 2003.16 Build 42F ConocoPhiiiips Project: Kuparuk River Unit Site: Kuparuk3CPad Aaeee him Nwn Nazis MagrreueFleld WELLBORE DETAILS: Plan 5, 3C-14AL1 REFERENCE INFORMATION 500292142560 Coordinate(N/9Reference: Well 3C•14,True North Well: 3C44 strength: e7eas.0an Vertical (TVD) Reference: Mean Sea Level Wellbore: Plan 5, 3C-14AL1 Dip Mg19: 80.87 Parent Wellbore: 3C-14A Section (VS) Reference: Slot-(O.00N, 0,00E) Plan: Plan 5 (3C-14/Plan 5, 3C-14AL1) Date: en7120o Mode; USER DEFINE Tie MD: 6819.99 .Measured Depth Reference: 3C-W(D15)@88A5ft o 15) on Calculation Method: Minimum Curvature WELL DETAILS: X-14 Ground Level: 47.60 +N/S +E/-W Northing Eaedng Latiftude Longitude, Slot 0.00 0.00 5995180.01 528345.63 70. 23' 52.506 N 149' 46' 9.594 W SECTION DETAILS ANNOTATIONS Sec MD Inc Azi ssTVD +NIS +EI-W DLeg TFace VSec Target Annotation 1 6819.99 32.32 180.52 6210.73 -1334.58 1276.62 0.00 0.00 1312.09 TIP 2 6828.00 33.14 181.72 6217.47 -1338.90 1276.53 13.05 38.86 1316.42 KOP 3 6848.00 34.71 180.14 6234.06 -1350.06 1276.35 9.00 330.00 1327.58 End of 9 deg/100' DLS 4 6908.00 42.71 173.52 6280.86 -1387.44 1278A1 15.00 330.00 1364.92 4 5 6938.00 47.21 173.52 6302.09 -1408.50 1281.01 15.00 0.00 1385.93 5 6 7064.00 63.61 185.03 6373.53 -1511.59 1281.28 15.00 33.50 1489.00 6 0 0 7 7232.90 86.00 197.41 6417.68 -1669.92 1248.91 15.00 30.00 1647.87 7 8 7265.30 85.93 192.54 6419.96 -1701.13 1240.56 15.00 269.00 1679.22 8 9 7414.30 86.44 214.94 6430.00 -1836.34 1181.08 15.00 89.46 1815.45 9 + .� 10 7742.80 86.16 165.55 6452.59 -2148.94 1124.55 15.00 268.00 2128.99 End of 15 deg1100' DLS 11 7872.80 87.85 181.08 6459.42 -2277A8 1139.60 12.00 84.24 2257.25 11 y 12 7986.80 74.17 181.08 6477.19 -2389.79 1137.47 12.00 180.00 2369.58 12 C 13 8136.80 89.89 172.20 6497.97 -2537A6 1146.36 12.00 330.00 2517.07 13 ^ ••� 14 8221.80 89.89 162.00 6498.13 -2620.20 1165.32 12.00 270.00 2599.47 14 x r 15 8321.80 98.37 170.51 6490.92 -2716.90 1189.02 12.00 44.80 2695.73 15 . 16 8514.50 96.29 193.74 6465.99 -2906.53 1181.90 12.00 93.60 2885.46 16 „..,., 17 8849.50 95.44 153.32 6430.27 -3230.66 1218.75 12.00 271.00 3208.90 17 rn e iD 18 9260.00 95.14 202.81 6389.90 -3626.36 1232.08 12.00 87.90 3604.31 TD H VA Irkr FRIGMS I NTEQ .l000 TIP -1200 KOP i End ol 9 deg/ OODI S .140 5 1600 7 d 800 9 2000 -220 2400 1 Endo 15 de 100' L 260 3 14 15 2800 16 3000 3 -14/3 14 -- 3200 3400 3600 4 3800 1000 ..,West( -)/East(+) (200 Win) • Vertical Section at 181.00' (65 Win) Cf nocidi I ps Project: Kuparuk River Unit Site: Kuparuk 3C Pad MIa"e ^� a �12. Megneee Fla. WELLBORE DETAILS: Plan 5, 3C-14AL1 REFERENCE INFORMATION 500292142560 Co-ordimte(NIE) Reference: Well 3C-14, True North Well: 3C-14 Strength: STB89.Oen erca() Reference: 3C-14A (D75) @ 88A50 (Doon 15y VolTVD ) Welibore: Plan 5,3C•14AL1 Dip Angle: 80.e7' Dete: 0/17n009 Parent Welibore: 3C-14A Section (VS) Reference: Slot -(O.00N, 0.00E) Measured Depth Reference: 3C-14A(D15) @ 88A5ft (Doyon 15) Plan: Plan 5 3C441P1an 5, 3C-14AL1 ( ) Model: USER DEFINED Tie on MD: 6819.99 CalwMm Method: Minimum Curvature rigs �i. uomm INTEQ zoo d—} ! } .i..l.. 4 (i. 1. { [�.1.I` .:. +i' t.+11 ._.., 'T�t! t. -t i' -i• .�b fa.� { ^(�i-i { t _ +j ! } +, 1 ! a 1 f..l.. -t+. Y -20 7 ( # " I+ } { -- { } +a 1 t - 4 la "-: ...,_. -:,- . „ : - _ ..-_ r - .t,. -+.._1_:. ki { -400 i i { I t '.1 + 1 h ..t.t. €.+ _`-4` _ _ 3'-� } t-}-i-�- .. -•-J-- 1 (-` -T--, -+-1 LI j-+ F �; - t # f -=.. 1 4 } 1 r- .t ii -600 i I ♦ i !- i'-I '.:' i : I 1� .. .� t -k -( ..�{ + } t {- k # ' { i + i -RDD loco -1200I # I_ }•. .{. 1 { 4.-.+- f 1 l y� I T #- }- 1-- A� 1». . F-^ -r- -1400 600 1}�r : - t 4 t : _r;� '� 7�rt ., j -1800 + ,.� -j � f+. I } -� -., f -2000 w -220 -.. t - �i t _ fit' Y, i I f ! }t _ _ -240 a t {{. } 1JJm ,.. I'1.- t i 1 "- , -2800 L.. - �- z. .� 1 } T , _ ! ... -300 J�+ {}.. 1-_4 `i`T.,4__.. i 1 ?-+ F +- i 14 1•'t +- -+ } + 1 t 1 x _ -320 :=.� :. -{• �'.4 �) , 41 _ +�1- 1 - �-t - 1 I ,_ 1 ? - {....i t - t i..� , _� t , + i -�- i� f {'c't' y' l f i +' i ! ( T i' i { i 7 �. ... r 1- i 1. r y� + i�i �t °+� n�� ` � -1 '-�- f �- �;� I i.,. r ; � ._'fit' #� � , t � 1 . { 1• '- 1- r r� -; : r - f. { 36�:.':° _ rrfJY +Yll�'_j1; - Ott L iy# t} #J 4{ -! i f _ + i 3 �- .J {i t: -3800 -4000 Its 1� a F # a�. ? r {�-� }?1 -+7� l- ..�I .r r - Y _} #' i : i _ r { d- .:{- -4400� + -4600 ! �r y "`.1 _ rt 1 t-F+- i f i f i +r #�1- ' x r7I-_ i. �- t k 1; -4800 7 I -r {r- -,-- -�-+ t 3. -'t tr+ .� . I I-_- i -h + l- �-t- I i, +. - } 'Fi r r + L - _ 4 }+- 1,'" _ r�-�-# -q+, r-'-4"jj' t'-{' -r .i.4 i 1-2 -500 r �-+ y+ F +•t Y -+ -; y- -4 1 }' t �S R i 1• l r L t i�l j.+-i + . # 4 _i„( {.i.N .L -i. 4- N. 1 i -5200 + i r _ -•. j � - _ f - * f- 14' V-}r.i +r + ,-+. 'r. F ) U (_{. ..- t.t . _{_ + ..,.tt i -lYW -11UV -1VVV -OVV -UVV - VV -LUV V LW YVV UVV ouu 1UVV 1LW 14VV A— 1oVV LVW LLVV WVV LOVV LOW JVUV JLW JYVV JVVV JOVV 1— 1— 'wVV YWV 1— JWU JLW J— JVW ..OW vUVU 3C-14A (015) @ 88A5ft (Doyon 15) West( -)/East(+) (200 Win) Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Pump into U above BH/ Kill KRU 3C-14B —Area of Review Y ti 025634 02 m; - .nu a'E-Ub Gn0 1 no -pL soon anna 3dnn ° ME o9 EON CG)__ ,_- \\doaancogcfps0l\HOME\OGC\sfdavies\DailyDocument Record\2009\090609 MAP _2090610_KRU-3C-14B AOR.ppt SFD 6/9/2009 • • C� J TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# 2�2_ C�6 J Development &Z Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: �_ ,lC/0-64— POOL: y C�� le f 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 through target zones. Non -Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1 /11 /2008 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 3C-14B Program SER Well bore seg ❑ PTD#: 2090610 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / 1-OIL GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 1 Permitfee-attached --------------------------------------------- -NA --------------------------------------------------------------------------- 2 -Lease numtw appropriateL ----------------------------------------- Yes-------Re-dril[WllJieentirelywlthinAOL 025634-------------------------------------------- 3 Unique well name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - - - As planned, this wellbore_vdll_be are -drill, NOT a lateral -as -stated in -the permitapplication --- - - - - - - - - - - - - - - - 4 Well Jwatedinadefinedpool ---------------------------------------- Yes ------- KUPARUKRIVE R,KUPARUKRYOIL--490100, governed byCommotion QrderNo,4320-_-_--__------_ 5 Well Jocated proper distance frcm drilling unit -boundary _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - - _ Conservation Qrder_Ko, 432C contairtsno spacing restrictions with respect to ddlUng unit boundaries, - _ _ - _ - _ _ _ _ 6 Well Jocated proper distance frQm otbdr Wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - - - Conservation OrderNo, 432C has no interwell-spacing restrictions. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage available Jn_drilling unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Conservation QrderNo:432C has nointenyell spacing restrictions. Wellbore will be_more than 5017 from_ _ _ _ _ _ - _ _ 8 If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ art extemall -property line where ownership or landownership chsoges-_ - _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ _ _ _ _ - _ _ _ - _ _ 9 -Operator Qnlyoffectedparty----------------------------------------- Yoe ----------------------------•---------------------------------------------- 10 Operator hasopprQpriatebondin_fQrm-------------------------------•--Yoe ---- - - - --- --------------------------------------------------------------- 11 Permit -can beissued.without oQnservationorder---------------•-------------Yss--------------------------------------------------------------------------- Appr Date 12 Permitconbe_issuedwithout administratixe -approval ---------------------------- Yes --------- _------------------------------------------------------------ ----- 13 -Can permkbeapproved -before 15-day_waft--------------------------------Yes----------------------------- ------------------------------------•-------- SFD 6/9/2009 14 Well located within area and strata auftrized_by JNection -Order # (put IO# In -comments) .(For sery Yes _ _ _ _ _ _ - Area Injection Order No. 2B _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells within 114 mile areaof review Identified- (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ - _ Affected wellbores are: 3C-14,-3Q-15,1Q-1'z,1 R-151.1, 1 0-1&1-01, Well_Kr 3_passes thrLLAOR, butis shallower_ - 16 -Pre-produced-Injector: _ duration of pre -production less than 3-months (For. service well_only)_ - - _ _ No _ - _ _ _ _ _ _ Pro -produced for cleanup only- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 Nonconven.-gas conforms toAS31,Q5.030(j.1_.A).O.2.A-D)--------------- ------ ---NA----------------- -•--------------------------------------- - - - - - - - - - - 18 Qoncluotorstring provided ------------------------------------------- NA--------CQrductgr set Jn3C-14_0e5-199)-------- -------------•-------------------------- Engineering 19 Surfacecasingprotectsail known US4Ws------------------------ --------- NA--------Allaquifers.exempted,400FR147.102(bO) ---------------------------- -------------- 20 CMT_voladequatetocirWateonconduotor_& surf csg-------------------------- NA--------SurfaCerasing set in 30-14.----------•-------------------------------------•--- 21 CMT-voladequateto_tieinlongstringtosurfosg------------------------------NA ---- -- -- ProdupWrijoaWng_set_in30-14------------------ ------.------_-.----------._----- 22 CMT-wilt cover all known productive bQrizQns-------------------------------- Ko-------_$Qlid/slotted liner oompletlon_planned,----------------------------------------- ----- 23 Casing designs_ adequate for C. T, B.4 permafrost- - - - - - - - - - - - - - - - - - - - - - - - - - - - -NA- - - - - - - - QdglnalweJI metdesign specifications. _ NA for slotted liner- _ _ - _ _ _ _ - _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Rig equipped with steel -pits. -No-reserve pit planned. All waste to approved disposal wells)-- - - - - - - - - - - - - - 25 Jfa_re-drill. has -a10-403for_abandonmentbeen approved------------------------ Yes-------309-190------------.--.--.-------------------------------.-----------_ 26 Adequate weltbore separation_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ - Proximity analy_slsperformed, Nearest segmeotJs P&A protim 900714A and paths diyerge - - . - - _ _ _ _ _ _ _ _ _ - 27 Jf_diverterrequired, _does_Itmeetregulations --------------------------------- NA ----_---SOP StacXwJll.alreadylr.inplace. -_------------------------------------- _-_------ Appr Date 28 Drilling fluid-program_schematic & equip -list -adequate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _ Maximum expected formation pressure 11.31=MY1t. _Managed pressure_driUing will be -used with 10.0 ppg fluid -and _ _ - TEM 7/7/2009 29 -BOPEs, do they meet regulation _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ ECD Qrappiied pressure._ 2 wellbQre volumes of-KWE will be available infield._ _ _ _ _ _ - _ _ _ _ _ - _ _ - _ _ _ _ AT— 30 31 BOPEpress rating -appropriate;_ test to_(put prig in comments) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Choke manifold-compllesWAPI RP-53(May 64)--------------------- -------Yes------------------------------------------------ _ _ _ Yes _ _ _ _ _ _ _ MASP calculated at_3017_psi 350Q psi. SOP testplanned._ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 WorkwtUoccur-w"QutoperatiQn_shutdQwn-------------------------------- Yoe --------------------------------------------------------------------------- 33 Js_ presence of H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ H2$ is present at 3C pad, Mud sbouldpreclude Ham -rig.- Rig has siomors_and alarms- _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ 34 MechanicalcQn-dition-of wells withinAQRyerifiied(Forseryloewollonly) -------- _-------- Yoe ______-No issues wfth.wellsinAOR-------------------------------------- .______-______ 35 Permit can t;ieL issued w/o hydrogen sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - - -N.o _ - - - - - - - Existing wellbore, 3C-14A, measured I ppnl H2Sjn AprO, 20Q8- - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 36 Data presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Static-BHP_survey_in 30-14A in Aug 2006 measured 1 t.3 ppg_EMW,'_willlie-drilled using t0,0_ppg mud and. - _ _ - - - Appr Date 37 Seismicarxnlysisofshallowgo%zones----------------------------------- NA--------managed_pressuredrilling techniques ---------------------------------------- ------- SFD6/9/2009 38 -Seabed cQndltiQn-survey-(if off -shore) ------------------------------------ A--------------------------------------------------------------------- ------- 39 Contaetnamelphone_forweekly-prWressrepQrtsjexploratoryonly]--------------------N-A---------------------------------------------------------------------------- Geologic Date: Engineering Date Public Date As planned, this weilbore will be a re -drill, NOT a lateral as stated in the permit application. Commissioner: C�� ioneCommissioner i' 7-71�i W