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Home My WebLink About212-166New Plugback Esets 7/3/2024 Well Name API Number PTD Number ESet Number Date 1D-141A PB1 50-029-22967-73-00 208-016 T39107 7-16-2008 1D-141APB2 50-029-22967-74-00 208-016 T39108 7-16-2008 1D-141APB3 50-029-22967-75-00 208-016 T39109 7-16-2008 2K-08APB2 50-103-20111-71-00 211-049 T39110 6-13-2011 2K-08APB3 50-103-20111-71-00 211-049 T39111 6-13-2011 2K-08B PB1 50-103-20111-73-00 211-152 T39112 2-15-2012 2K-08B PB2 50-103-20111-74-00 211-152 T39113 2-15-2012 2K-08B PB3 50-103-20111-75-00 211-152 T39114 2-15-2012 3K-105L1 PB1 50-029-23479-72-00 212-166 T39115 3-12-2013 3K-105L1 PB2 50-029-23479-73-00 212-166 T39116 3-12-2013 3K-105L1 PB3 50-029-23479-74-00 212-166 T39117 3-12-2013 SP22-FN01 PB3 50-629-23478-72-00 212-162 T39118 3-20-2013 V-214 PB2 50-029-23275-71-00 205-134 T39119 1-29-2007 V-214 PB3 50-029-23275-72-00 205-134 T39120 1-29-2007 V-214 PB4 50-029-23275-73-00 205-134 T39121 1-29-2007 3K-105L1 PB1 50-029-23479-72-00 212-166 T39115 3-12-2013 3K-105L1 PB2 50-029-23479-73-00 212-166 T39116 3-12-2013 3K-105L1 PB3 50-029-23479-74-00 212-166 T39117 3-12-2013 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12700'None Casing Collapse Conductor Surface Intermediate B-Sand Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742 Senior CTD/RWO Engineer Tubing Grade: Tubing MD (ft): 2614' MD and 2470' TVD 2640' MD and 2493' TVD 4992' MD and 3401' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 4973' MD 1/22/2023 Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker Premier Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025519 212-165 P.O. Box 100360, Anchorage, AK 99510 50-029-23479-00-00 ConocoPhillips Alaska, Inc. KRU 3K-105 West Sak Oil PoolWest Sak Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 3599' 12700' 3599' 1340 None MD 108' 2250' 3511' 108' 2369' 5682' 20" 13-3/8" 79' 2338' Perforation Depth MD (ft): 9-5/8"5650' Alternating Slotted Liner: 5825-12568 4-1/2" Alternating Slotted Liner: 3520-3593' 12633' 7507' 4-1/2" 3596' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 8:05 am, Jan 13, 2023 323-015 Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips, Inc", CN=Elliott Tuttle, E=elliott.tuttle@conocophillips.com Reason: I am the author of this documentLocation: Date: 2023.01.13 07:19:03-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle DSR-1/17/23SFD 1/13/2023 BOP test pressure to 2500 psig Annular test pressure to 2500 psig 10-404 X X VTL 1/23/2023GCW 01/23/23 JLC 1/23/2023 1/23/23Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.01.23 14:55:06 -09'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 12, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3K- 105 (PTD# 212-165). Well 3K-105 was drilled and completed in February of 2013 by rig Doyon 141 as a dual lateral West Sak producer. The well has a Lateral Entry Module (LEM) landed in the hook hanger of the L1 Lateral liner to allow access to both the mainbore and L1 lateral. Recent diagnostics have found that the LEM is damaged not allowing drift into the L1. The upper most GLM at 2630' RKB developd a leak in 2015. Since then, a POGLM (Patch over gas lift mandrel) has been set and retrieved many times since the first install due to the need for retreival to perform FCO's in the laterals. If you have any questions or require any further information, please contact me at 907-252-3347. The plan is to perform a tubing swap to repair the leak at 2630' RKB. The Damged LEM will not be addressed with this RWO. 3K-105 RWO Procedure West Sak Producer P&R Tubing PTD #212-165 Page 1 of 2 Remaining Pre-Rig Work 1. Clear ice plug with CT Intervention 2. Fish/ Retrieve POGLM (failed) set over 2630’ RKB GLM 3. Set plug in DB Nipple @ 5047’ RKB 4. Open Sliding sleeve @ 4856’ RKB 5. CMIT-IA to 2500 psig, pump freeze protect 6. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3K-105. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. 4. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 5. Pull BPV, MU landing joint and BOLDS. 6. Pull 4-1/2” tubing down to Seal Assembly landed in a Sealbore at 4959’ RKB. a. Spool TEC wire, account for and discard clamps Install in 4-½” Tubing with new gauge 7. MU 4 ½” completion with New Seal Assembly/ Locator, Gauge Carrier/ Gauge, 4 ½” Sliding Sleeve, 2 Each GLM’s, 3.875” Tubing Nipple, Tubing Hanger 8. Once on depth, pick up and space out tubing hanger, terminate TEC wire, circulate CI, land tubing hanger and seal assembly 9. Pressure test tubing to 3000 psi for 5 minutes. 10. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests, then shear out SOV with pressure differential. 12. Install BPV. 13. ND BOPE. NU tree. 14. Pull BPV, freeze protect well, and set BPV if necessary. 15. RDMO. Post-Rig Work 16. Install GLD 17. Return to GL & production 3K-105 RWO Procedure West Sak Producer P&R Tubing PTD #212-165 Page 2 of 2 General Well info: Wellhead type/pressure rating: Vetco Gray (Vault PC) 5K rated Production Engineer: Brian Lewis Reservoir Development Engineer: Kaylie Plunkett Estimated Start Date: 1/22/2023 Workover Engineer: Elliott Tuttle (Elliott.tuttle@conocophillips.com/ 907-252-3347) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 4-1/2” completion down to the seal assembly, replace with like completion with new GLM depths. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: Leak found @ 2630’ successfully patched 8/23/2015 CMIT-TxIA Passed 6/19/22 Gas MIT-OA Passed 12/16/2022 IC POT &PPPOT PASSED – 11/19/2022 TBG POT &PPPOT PASSED – 11/19/2022 MPSP: 1340 psi using 0.1 psi/ft gradient Static BHP: 1655 psi / 3382.4’ TVD measured on 12/15/22 3K-105 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108' 108' 20" 19.124" 94# X-65 Welded Welded Surface 2369.1' 2250.4' 13 3/8" 12.415" 68# L-80 BTC BTC Intermediate 5681.7' 3716.8' 9 5/8" 8.835" 40# L-80 BTC-M BTC-M B Liner (Main)11792' 3661' 5 1/2" 4.95" 15.5# L-80 IBT-M IBT-M D Liner (L1 Lat)12015.3' 3588.9' 4 1/2" 4.00" 11.6# L-80 IBT-M IBT-M Tubing 7979.8' 3647' 4 1/2" 3.958" 12.6# L-80 IBT-M IBT-M Surface Casing Conductor Perfs 4-1/2" DB-6 Landing Nipple @ XXX' RKB (3.875" ID) 4-1/2" x 1" Camco KBMG GLM @ XXXX' RKB 4-1/2" Sliding Sleeve @ XXXX' RKB (3.812" ID) 4-1/2" Gauge Carrier, SLB Gauge @ XXXX' RKB 4-1/2" Locator/ Seal Assembly @ XXXX' RKB 7" HRD-E Liner Setting Sleeve w/ 7.5" ID extension, 6' lng 4 3/4" ID Seal Bore 20' Lng @ 4958.7' 4-1/2" x 9 5/9" Premier Packer @ 4991.6' RKB 4-1/2" DB Nipple @ 5047.4' RKB (3.75" ID) 9 5/8" x 4 1/2" RAM LEM @ 5062.7' RKB (Damaged) See RAM Hanger detail in D Sand Lateral 9 5/8" x 4 1/2" RAM SBD @ 5066.9' RKB 4 1/2" DB-6 Nipple @ 5115.4' RKB (3.563" ID) MLHR Production Anchor @ 5134.7' RKB Latched into:Mainbore Liner Modified by EDT 12/12/2022 B Sand Lateral (Mainbore): RAM Hanger @ 5062.3' RKB 4 1/2" 11.6lb/ft Slotted liner with Swell Packers and Tracer Subs LEM Damaged Intermediate Casing D Sand Lateral (L1 Liner): 7" x 9 5/8" ML-ZXP w/ HR Profile Liner Top Packer @ 5125.8' RKB 4 3/4" ID Seal Bore 20' Lng @ 5153.8' 4 1/2" 11.6lb/ft Slotted liner with Swell Packers and Tracer Subs RAM Hanger RAM SBD Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:3K-105 condijw Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper P2P Poglm Patch 3K-105 11/19/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL 3K-105, 3K-105L12/12/2013 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2019.12 29.0 108.0 108.094.00 X-65 WELDED SURFACE 13 3/8 12.41 31.0 2,369.1 2,250.4 68.00 L-80 BTC INTERMEDIATE 9 5/88.8331.45,681.7 3,511.4 40.00 L-80 BTC LINER DIVERTER ASSY 8.51 7.73 5,066.9 5,164.2 3,441.3 2.97 LINER LEM 4 1/23.944,948.8 5,089.33,423.930.89 4.5 B-SAND LINER 4 1/23.48 5,125.812,633.03,595.7 11.60 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.6 Set Depth … 4,973.5 Set Depth… 3,397.1 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L80 Top Connection IBTM ID (in) 3.98 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) 22.6 22.60.00 HANGER 13.375 VETCO GRAY TUBING HANGER 3.833 599.7 597.3 10.25 NIPPLE 5.650 CAMCO DB-6 NIPPLE w/3.875 "NO GO PROFILE SLB 3.875 2,630.3 2,484.3 27.64 GAS LIFT 6.437 Camco GLM, KBMG, 4-1/2" X 1" w/ Dummy (BK-5 Latch) (2648') CAMCO KBMG3.860 3,545.8 3,111.9 66.95 GAS LIFT 6.437 Camco GLM, KBMG, 4-1/2" X 1" w/ DCK-2 shear valve 2500 psi(3532') CAMCO KBMG3.860 4,771.5 3,357.0 79.92 GAS LIFT 6.437 Camco GLM, KBMG, 4-1/2" X 1" w/ Dummy (BK-5 Latch) (4771') CAMCO KBMG3.860 4,856.2 3,372.8 78.39 SLEEVE CMU 5.500 BAKER CMU SLIDING SLEEVE W/3.812" PROFILE (OPEN 6/17/2022) BAKER CMU CMU Sleeve (CLOSE D 6/28/202 2) 3.810 4,903.4 3,382.4 78.16 GAUGE5.390 SLB guage carrier, IBTM, Pin X Pin (4903') SLB GAUGE 3.870 4,951.93,392.4 77.82 LOCATOR5.210 BAKER LOCATOR SUB 3.870 4,952.6 3,392.5 77.80 SEAL ASSY 4.730 BAKER GBH-22 SEAL ASSEMBLY 3.870 4,973.0 3,396.9 77.38 SHOE 4.650 MULE SHOE 3.870 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) 2,614.02,469.927.56 PACKER - PATCH - LWR 3.75" UPPER P2P, SPACER PIPE/POGLM, & ANCHOR LATCH (27.2' OAL / 20' FROM TOP OF POGLM TO BTM LATCH GLV) MID ELEMENT @ 2617.0' TTS P2P CPP4 5040 11/19/2022 0.000 2,618.8 2,474.1 27.53 ANCHOR LATCH ON SPACER PIPE SPACER PIPE, POGLM (BTM LATCH RECEPTACLE), & ANCHOR LATCH CONNECTED TO UPPER PACKER TTS POGLM CPAL 45009 11/19/2022 0.000 2,640.02,492.927.76 PACKER - PATCH - LWR 3.75" LWR PIIP PATCH PACKER MID-ELEMENT AT 2643' RKB, OAL 4.89' TTS PIIP CPP4 5039 11/17/2022 2.000 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) 2,630.32,484.327.64 1 GAS LIFT OPEN BK 1 9/18/20155:30 3,545.83,111.966.95 2 GAS LIFT DMY BK 1 0.011/14/2022 9:00 0.000 4,771.5 3,357.0 79.92 3 GAS LIFT OV BK-5 1 0.011/15/2022 11:30 0.313 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) 4,948.83,391.8 77.88 SLEEVE 7.000 7'' HRD-E Liner Setting SleeveHR w/ 7.50'' ID ext. 6' 8.31 BOT 6.220 4,958.7 3,393.9 77.68 SBR 6.270 Seal Bore 4 3/4'' 6.27 BOT 4.750 4,991.6 3,401.1 77.00 PACKER 8.420 BAKER PREMIER PACKER 8.42 3.880 5,047.4 3,414.1 76.38 NIPPLE 5.250 CAMCO LANDING DB NIPPLE 5.25 SLB 3.750 5,062.7 3,417.7 76.52 COLLET 7.330 RAM Hanger LEM Completion Module ( Collet to top Of LEM ) 7.33 BOT 3.960 5,064.8 3,418.2 76.54 COLLET 7.330 RAM Hanger LEM Completion Module ( Collet to re-entry) 7.33 BOT 3.960 5,087.6 3,423.5 76.55 WLEG 5.020 BAKER WIRELINE RE-ENTRY GUIDE 5.02BOT 3.730 5,066.93,418.7 76.55 DIVERTER T28.510 SEAL BORE DIVERTERr-- length above collet profile f/ RAM Hanger 8.51 BOT7.730 5,069.93,419.3 76.58 DIVERTER T18.510 SEAL BORE DIVERTER, --Length below collet profile 8.51 BOT7.730 MULTIPLE LATERALS, 3K-105, 11/21/2022 7:59:55 AM Vertical schematic (actual) B-SAND LINER; 5,125.8- 12,633.0 SLOTS; 12,070.0-12,568.0 SLOTS; 11,084.0-11,705.0 SLOTS; 10,454.0-11,445.0 SLOTS; 9,266.0-10,300.0 SLOTS; 8,411.0-9,112.0 SLOTS; 6,944.0-7,524.0 SLOTS; 6,521.0-6,646.0 SLOTS; 5,825.0-6,404.0 INTERMEDIATE; 31.4-5,681.7 LINER DIVERTER ASSY; 5,066.9-5,164.2 D-SAND LINER; 5,062.3- 12,655.5 LINER LEM; 4,948.8-5,089.3 SHOE; 4,973.0 SEAL ASSY; 4,952.6 LOCATOR; 4,951.9 GAUGE; 4,903.4 SLEEVE CMU; 4,856.2 GAS LIFT; 4,771.5 GAS LIFT; 3,545.8 PACKER - PATCH - LWR; 2,640.0 GAS LIFT; 2,630.3 ANCHOR LATCH ON SPACER PIPE; 2,618.8 PACKER - PATCH - LWR; 2,614.0 SURFACE; 31.0-2,369.1 NIPPLE; 599.7 CONDUCTOR; 29.0-108.0 HANGER; 22.6 KUP PROD KB-Grd (ft)RR Date 2/12/2013 Other Elev… 3K-105 ... TD Act Btm (ftKB) 12,700.0 Well Attributes Field Name NE WEST SAK Wellbore API/UWI 500292347900 Wellbore Status PROD Max Angle & MD Incl (°) 100.11 MD (ftKB) 7,952.92 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 95 Date 1/18/2015 Comment SSSV: NIPPLE 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) 5,115.4 3,430.0 76.39 NIPPLE 5.250 CAMCO DB-6 3.563" NO GO NIPPLE 5.25 3.563 5,134.7 3,434.5 76.49 ANCHOR 6.520 MLHR PRODUCTION ANCHOR 7.39 BOT 3.910 5,138.9 3,435.5 76.55 ANCHOR 6.520 MLHR PRODUCTION ANCHOR 7.39 BOT 3.910 5,125.8 3,432.4 76.39 PACKER 8.420 MLZXP w/HR PROFILE LINER TOP PACKER BakerMLZXP 6.100 5,153.83,438.9 76.73SBR 6.280 4.750'' SEAL BORE Baker SBE 190-47 4.750 5,720.83,513.986.05 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecap I FSC 4.000 5,798.5 3,518.986.47 SENSOR5.500TRACERO OIL/WATER TRACER CARTIDGE 5 1/2'' x 4 1/2'' 4.500 6,455.2 3,523.0 89.28 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecap I FSC 4.000 6,657.5 3,525.9 89.57 SENSOR 5.500 TRACERO OIL/WATER TRACER CARTIDGE 5 1/2'' x 4 1/2'' 4.500 7,576.5 3,537.0 91.66 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecap I FSC 3.476 8,306.7 3,477.8 91.01 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecap I FSC 3.476 8,385.03,478.088.53SENSOR5.500TRACERO OIL/WATER TRACER CARTIDGE 5 1/2'' x 4 1/2'' 4.500 9,162.0 3,498.6 86.70 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecap I FSC 3.476 9,240.1 3,504.3 85.00 SENSOR 5.500 TRACERO OIL/WATER TRACER CARTIDGE 5 1/2'' x 4 1/2'' 4.500 10,350.5 3,529.088.13 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecap I FSC 3.476 10,428.23,531.987.46SENSOR5.500TRACERO OIL/WATER TRACER CARTIDGE 5 1/2'' x 4 1/2'' 4.500 11,496.5 3,568.9 90.99 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecap I FSC 3.476 11,573.9 3,567.4 91.25 SENSOR 5.500 TRACERO OIL/WATER TRACER CARTIDGE 5 1/2'' x 4 1/2'' 4.500 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,825.06,404.03,520.5 3,522.4 WS B, 3K-105 1/20/2013 32.0SLOTSSLOTTED LINER 6,521.06,646.03,523.93,525.8 WS B, 3K-105 1/20/2013 32.0SLOTS 6,944.0 7,524.0 3,530.6 3,538.4 WS B, 3K-105 1/20/2013 32.0 SLOTS 8,411.0 9,112.0 3,478.9 3,496.2 WS B, 3K-105 1/20/2013 32.0 SLOTS 9,266.0 10,300.0 3,506.5 3,527.4 WS B, 3K-105 1/20/2013 32.0 SLOTS 10,454.0 11,445.0 3,533.1 3,569.5 WS B, 3K-105 1/20/2013 32.0 SLOTS 11,084.011,705.03,554.4 3,564.5 WS B, 3K-105 2/6/2013 32.0SLOTS 12,070.012,568.03,584.63,592.9 WS B, 3K-105 2/6/2013 32.0SLOTS MULTIPLE LATERALS, 3K-105, 11/21/2022 7:59:59 AM Vertical schematic (actual) B-SAND LINER; 5,125.8- 12,633.0 SLOTS; 12,070.0-12,568.0 SLOTS; 11,084.0-11,705.0 SLOTS; 10,454.0-11,445.0 SLOTS; 9,266.0-10,300.0 SLOTS; 8,411.0-9,112.0 SLOTS; 6,944.0-7,524.0 SLOTS; 6,521.0-6,646.0 SLOTS; 5,825.0-6,404.0 INTERMEDIATE; 31.4-5,681.7 LINER DIVERTER ASSY; 5,066.9-5,164.2 D-SAND LINER; 5,062.3- 12,655.5 LINER LEM; 4,948.8-5,089.3 SHOE; 4,973.0 SEAL ASSY; 4,952.6 LOCATOR; 4,951.9 GAUGE; 4,903.4 SLEEVE CMU; 4,856.2 GAS LIFT; 4,771.5 GAS LIFT; 3,545.8 PACKER - PATCH - LWR; 2,640.0 GAS LIFT; 2,630.3 ANCHOR LATCH ON SPACER PIPE; 2,618.8 PACKER - PATCH - LWR; 2,614.0 SURFACE; 31.0-2,369.1 NIPPLE; 599.7 CONDUCTOR; 29.0-108.0 HANGER; 22.6 KUP PROD 3K-105 ... WELLNAME WELLBORE Annotation Last WO: End Date Casing Strings Casing Description D-SAND LINER OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 5,062.3 Set Depth (ftKB) 12,655.5 Set Depth (TVD) … 3,554.1 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,062.3 3,417.3 77.55 HANGER (above Collet) RAM HANGER (above LEM Profile to Top of RAM Hanger 6.750 5,064.8 3,417.8 77.65 HANGER HANGER (above Collet into LEM Profiler) 6.750 5,069.9 3,418.9 77.85 RAM HANGER RAM LINER HANGER 6.630 5,099.1 3,424.8 78.80 XO BUSHING LINER CROSSOVER BUSHING 3.870 5,194.4 3,440.7 82.09 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 5,272.3 3,449.0 85.96 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 6,007.1 3,460.9 87.52 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 6,579.9 3,479.9 92.89 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 6,792.7 3,469.6 91.52 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 7,860.6 3,493.0 88.44 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 8,412.1 3,442.2 94.15 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 8,498.5 3,438.4 90.95 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 9,322.3 3,455.0 88.42 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 9,572.9 3,448.4 92.94 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 10,772.8 3,476.1 88.49 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 11,058.4 3,491.9 85.83 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 11,963.9 3,537.4 86.09 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 12,043.9 3,541.0 88.53 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 5,298.0 5,956.0 3,450.4 3,459.3 2/6/2013 32.0 SLOTS SLOTTED LINER 6,074.0 6,529.0 3,464.5 3,481.5 2/6/2013 32.0 SLOTS 6,819.0 7,850.0 3,469.2 3,492.7 2/6/2013 32.0 SLOTS 8,528.0 9,270.0 3,438.1 3,453.7 2/6/2013 32.0 SLOTS 9,603.0 10,722.0 3,446.8 3,474.4 2/6/2013 32.0 SLOTS Notes: General & Safety End Date Annotation 10/25/2015 NOTE: MULTI-LATERAL WELL 3K-105, 3K-105L1 Comment SSSV: NIPPLEMULTIPLE LATERALS - 3K-105L1, 2/8/2016 11:07:30 AM Vertical schematic (actual) D-SAND LINER; 5,062.3- 12,655.5 SLOTS; 9,603.0-10,722.0 SLOTS; 8,528.0-9,270.0 SLOTS; 6,819.0-7,850.0 SLOTS; 6,074.0-6,529.0 SLOTS; 5,298.0-5,956.0 INTERMEDIATE; 31.4-5,681.7 LINER DIVERTER ASSY; 5,066.9-5,164.2 LINER LEM; 4,948.8-5,089.3 SHOE; 4,973.0 SEAL ASSY; 4,952.6 LOCATOR; 4,951.9 GAUGE; 4,903.4 SLEEVE; 4,856.2 GAS LIFT; 4,771.5 GAS LIFT; 3,545.8 PATCH; 2,642.0 PATCH; 2,625.0 GAS LIFT; 2,630.3 SURFACE; 31.0-2,369.1 NIPPLE; 599.7 CONDUCTOR; 29.0-108.0 HANGER; 22.6 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: SET POGLM's Last Mod By pproven End Date 12/6/2015 KUP PROD KB-Grd (ft) Rig Release Date 2/12/2013 Annotation Last WO: End Date 3K-105L1 H2S (ppm) 95 Date 1/18/2015 ... 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O 0 U E, O W o . I O N a E li I Z c vU OU ai o E JY O }c E °)mnQ M j Q a , E 1o T- w O W N c `I 2 = N y V M re i- a0+ c E W �� re N I C O ~ 7 1 Cl) Q• 76 CO c •d o 0 NIN Q 0. c 41 = O .;1 • m c •- a < a •° m O z E d D D E 1LikZ1 f4 M N d �p O O VIII C ® I N N -AIM O M Q Cr) CO1 E 0 } 'rl N `_ c 1J (Ocp w W IPup } E W € a 0 m I- N N d W t V) d 'a y d' O C ` 2 y > E E Z c H Y w m re .` 'in c O a F m 0 O 4) c m 0 N Z F- C C Z C fC O tll o O y Q o o Q o O :� c U U o a� - 2 I J T) N .° c m U n o a a m o E a 2 m ¢ O v m a 2 Uw I ? 0 a 0 rI O 0 c o 0 0 2s� 2\2k� Z�2 lG CE r I mAR ] 2 2013 WELL LOG TRANSMITTAL AOGCC To: State of Alaska 8 March 2013 Alaska Oil and Gas Conservation Commission Attn.: Makana Bender 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 3K-105+PB1+PB2+L1+L1PB1+L1PB2+L1PB3 AK-MW-9902398 3K-105+PB1+PB2+L1+L1PB1+L1PB2+L1PB3 (50-103-20604-00: -70: -71: -60: -72:-73:-74) 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log for each wellbore 2" x 5"ND TRIPLE COMBO Logs: 1 Color Log for each wellbore Digital Log Images, LAS Data, & DLIS Data w/verification listing 1 CD ROM PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryantfthalliburton.coni Benjamin.Schulze@ihalliburton.com Date: (3 (‘Z Signed: STATE OF ALASKA MAR 0 8 2013 ALASK,-,OIL AND GAS CONSERVATION COMMI:-,ION WELL COMPLETION OR RECOMPLETION REPORT AND 6PCC la.Well Status: Oil ❑ , Gas ❑ SPLUG ❑ Plugged ❑ Abandoned Li Suspended ❑ 1b Well Class 20AAC 25.105 20AAC 25.110 Development a , Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions Service ❑ StratigraphicTest❑ 2 Operator Name. 5 Date Comp,Susp, 12 Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband. February 12,2013 212-166/, 3 Address 6 Date Spudded 13 API Number P.O. Box 100360,Anchorage,AK 99510-0360 December 25,2012 50-029-23479-60 • 4a Location of Well(Governmental Section): 7 Date TD Reached: 14 Well Name and Number: Surface: 935'FSL,315'FWL,Sec. 35,T13N, R9E,UM January 31,2013 i3K-105L1 3K-105L1PB1,3K-305L1PB2,3K-105L1PB3 Top of Productive Horizon 8 KB(ft above MSL): 61'RKB 15 Field/Pool(s) 781'FSL,2416'FWL,Sec.35,T13N,R9E, UM GL(ft above MSL): 33'AMSL Kuparuk River Field , Total Depth: 9.Plug Back Depth(MD+TVD): 100'FSL,588'FEL,Sec.36,T13N, R9E, UM 12656'MD/3554'TVD West Sak Oil Pool , 4b.Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD): 16.Property Designation: Surface: x-529305 y- 6007929 Zone-4 12714'MD/3556'TVD ADL 25519 - TPI: x-531407 y- 6007784 Zone-4 11.SSSV Depth(MD+ND) 17 Land Use Permit Total Depth: x-538966 y- 6007139 Zone-4 nipple @ 600'MD/597'TVD 2555 18 Directional Survey Yes Q • No❑ 19 Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 2369'MD/2250'TVD 21 Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071) 22 Re-drill/Lateral Top Window MD/TVD GR/Res 7280'MD/3477'TVD 23 CASING,LINER AND CEMENTING RECORD I SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20"x 34" 94# X-65 29' 108' 29' 108' 40" 93 sx AS 1,255 sx AS 1 13.375" 68# L-80 31' 2369' 31' 2250' 16" 1303 sx AS Lite,354 sx LiteCRETE 9.625" 40# L-80 31' 5682' 31' 3511' 12.25" 616 sx DeepCRETE,332 sx DeepCRETE 4.5" 11.6# L-80 5062' 12656' 3417' 3554' 6.75" slotted liner ,/ 24.Open to production or injection? Yes Li No O If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number). SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5" 4974' 4992'MD/3401'ND,5126'MD/3432'ND slots from 5298'-5956'MD 3397'-3457'TVD slots from 6074'-6529 MD 3464'-3481 TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC :i.:. i:ns76 , slots from 6819'-7850'MD 3468'-3492'TVD - ,•I Was hydraulic fracturing used during completion? Yes❑ No❑ slots from 8528'-9270'MD 3438'-3453'TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED slots from 9603'-10722'MD 3446'-3474'TVD ' .AV•' .'' 1 na 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes Li 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. NONE RBDMS MAR 0 81013 . 18/), Form 10-407 Revised 10/2012 'I& 4/A.41(7 CONTINUED ON REVERSE Submit original only 29 GEOLOGIC MARKERS(List at formations and marl countered) 30. FORMATION TESTS NAME MD TVD Well tested? 111 cs O✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 2369' 2250' needed,and submit detailed test information per 20 AAC 25 071. Top West Sak D 5032' 3410' Bottom West Sak D 10991' 3487' 3K-105L1 PB1 total depth 6534' 3458' 3K-105L1 PB2 N/A total depth 6586' 3457' 3K-105L1PB3 total depth 7342' 3478' Formation at total depth: Kuparuk D 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Monty Myers @ 265-6318 MI' Email Printed Name nG.Alvord Title Alaska Drilling Manager Signature /_ I. ,t;c/� Phone 265-6120 Date 3(Z(Z--°13 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation' Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29. Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP 3K-105L1 ConocoPhillips 0/1s ell Attributes ax Angle&MD TD Alaska Inc, Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(RKB) CancoNdpp500292347960 NE WEST SAK EXPEND 9916 8,230.68 12,714.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date –SSSV:NIPPLE Last WO: 2/12/2013 Well Conrg'MULTIPLE LATERALS-3K-105L1,222/2013 12'.15'16 PM Schamatlo-Adual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:NEW WELL osborl 2/20/2013 HANGER,23 ER �—' Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd PD-SAND LINER 41/2 3.958 5,062.3 12,655.5 11.60 L-80 BTC Liner_Details 1141 t ♦ Top Depth (ND) Top Incl Nomi... CONDUCTOR, 29-108 11111Top(RKB) (RKB) (°) Item Description Comment ID(in) 5,062.3 3,368.0 84.83 HANGER RAM HANGER(above LEM Profile to Top of RAM Hanger 6.750 NIPPLE,600 (above Collet) 5,064.8 3,368.3 84.83 HANGER HANGER(above Collet into LEM Profiler) 6.750 5,069.9 3,369.0 84.84 RAM HANGER RAM LINER HANGER 6.630 S31-23389 .. 5,099.1 3,372.8 84.90 XO BUSHING LINER CROSSOVER BUSHING 3.870 GAS LIFT, 5,194.4 3,384.6 85.09 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 2,630 aaaM. 5,272.3 3,393.8 85.25 SENSOR TRACEROOILNVATER TRACER CARTRIDGE 4.000 GAS LIFT, _ f 6,007.1 3,4602 86.71 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 3,548 6,579.9 3,479.8 92.89 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 GAS LIFT, 6,792.7 3,465.8 86.94 SENSOR TRACERO OILNVATER TRACER CARTRIDGE 4.000 4,772 7,860.6 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 SLEEVE,4,656— 4• •I 8,412.1 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 8,498.5 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 GAUGE.4,903 '.;=.1.1.1. 9,322.3 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 9,572.9 SENSOR TRACERO OILANATER TRACER CARTRIDGE 4.000 10,772.8 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 LOCATOR, 11,058.4 SENSOR TRACERO OILANATER TRACER CARTRIDGE 4.000 4,952 SEAL ASSY, 11,963.9 Swell Packer TAM FreeCap IFSC SWELL PACKER 3.476 4'953 SHOE,4,973 12,043.9 SENSOR TRACERO OIL/WATER TRACER CARTRIDGE 4.000 Perforations&Slots -_---Shot Top(ND) Btm(TVD) Dens Top(RKB)Btm IRKS) (RKB) (RKB) Zone Date (eh... Type Comment 5,298.0 5,956.0 3,396.8 3,456.8 2/6/2013 32.0 SLOTS SLOTTED LINER LINER LEM, 4,99495,089 I 6,074.0 6,529.0 3,464.3 3,481.3 2/6/2013 32.0 SLOTS LINER DIVERTER 6,819.0 7,850.0 3,467.5 2/6/2013 32.0 SLOTS 5,067.5.t64 8,528.0 9,270.0 2/6/2013 32.0 SLOTS SLOTS, S.298-5,0569,603.0 10,722.0 2/6/2013 32.0 SLOTS NTERMEDIATE, 315.682 la IF ,1 ,t Notes:General&Safety End Date Annotation . 2/12/2013 NOTE:MULTI-LATERAL WELL 3K-105,3K-105L1 J sLo7s, – 6.074-6,529 -- 6 819-]83 850 .2 0 i I®1 1 SLOTST ri 6.528-9,2]0 - I Mandrel Details SLOTS. - - Top Depth Top Port 9.50310.]22 '- S (TVD) Incl OD Valve Latch Sloe TRO Run N...Top(RKB) (RKB) (°) Make Model 1161 Sera Type TyPe PN (Pel) Run Date Corn... 1 2,630.3 2,484.3 27.64 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/6/2013 III 2 3,545.8 3,111.1 67.16 CAMCO KBMG 1 GAS LIFT SOV DCK2 0.000 2,500.0 2/112013 3 4,771.5 3,357.0 79.92 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/6/2013 . I a C9 D-SAND I I LINER, 5.082-12.855 TD(3K-105L1), 12,714 ConocoPhiIIips Time Log & Summary Welrview Web Reporting Report Well Name: 3K-105 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 12/24/2012 12:00:00 AM Rig Release: 2/12/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/22/2012 24 hr Summary, Blow down water&steam,disconnect electrical lines,split complexes,Move t/3K-105 15:00 17:30 2.50 0 0 MIRU MOVE DMOB P Blow down water,steam& disconnect electrical lines. 17:30 18:30 1.00 0 0 MIRU MOVE DMOB P Pull pipe sheds and rockwawsher out of way. 18:30 20:00 1.50 0 0 MIRU MOVE DMOB P Break complexes apart. 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Move Complexes t/3K PAD,simops prep sub for move. 12/23/2012 Finish moving complexes to 3K, return&pull sub off of well,Move sub base&pipe sheds to 3K pad,spot over well,set mats for complexes and spot complexes, Phase 3 weather conditions--trucks on hold. 00:00 01:15 1.25 0 0 MIRU MOVE MOB P Finish moving complexes t/3K pad &return. 01:15 02:30 1.25 0 0 MIRU MOVE MOB P Move sub off of well. 02:30 06:30 4.00 0 0 MIRU MOVE MOB P Move sub&pipe sheds t/3K pad. 06:30 08:30 2.00 0 0 MIRU MOVE MOB P Spot sub over well. 08:30 11:00 2.50 0 0 MIRU MOVE MOB P Set mats, unload pipe sheds,spot pipe sheds. 11:00 12:00 1.00 0 0 MIRU MOVE MOB P Set mats for complexes. 12:00 15:00 3.00 0 0 MIRU MOVE MOB P Spot complexes. 15:00 16:30 1.50 0 0 MIRU MOVE MOB P move pipe sheds closer together spot rock washer. 16:30 18:15 1.75 0 0 MIRU MOVE MOB P Level sub&pit room, Plug in electrical lines. 18:15 20:15 2.00 0 0 MIRU MOVE MOB P Hook steam,glycol,water,fuel&air lines up. 20:15 00:00 3.75 0 0 MIRU MOVE MOB P Level pipe sheds and hook up skate. Rig accepted @ 00:00 hrs on 12/24. 12/24/2012 Phase 3 weather conditions,restricted work, Phase conditions reduced, Load shed, P/U subs, P/U 5"DP rack back in derrick, Function Test Diverter, Load pipe shed w/hwdp&directional tools, off load spud mud to pits, P/U 5"HWDP stand back in derrick. Install riser. 00:00 12:00 12.00 0 0 SURFA( DRILL OTHR T (Rig Accepted @ 0000)Phase 3 Weather conditions,Restricted work status. 12:00 15:30 3.50 0 0 SURFA( DRILL RURD P Weather down graded still waiting on roads to be cleared,load pipe shed w/sperry tools. 15:30 18:00 2.50 0 0 SURFA( DRILL PULD P P/U 5"DP&stand back in derrick. 18:00 19:00 1.00 0 0 SURFA( DRILL RURD P P/U lifting subs&riser f/beaver slide 19:00 19:15 0.25 0 0 SURFA( DRILL BOPE P Function test Diverter, no leak functioned properly. Page 1 of 41 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 19:15 21:30 2.25 0 0 SURFA( DRILL RURD P Load&mix spud mud, P/U BHA components. 21:30 23:00 1.50 0 0 SURFA( DRILL PULD P P/U 5"HWDP stand back in derrick. 23:00 00:00 1.00 0 0 SURFA( DRILL RURD P P/U&install riser. 12/25/2012 Flood stack,test surface equip.P/U Clean out BHA,Clean out V 243'POOH,M/U Drilling BHA, Drill f/243't/ 915'MD,TVD=906',Gyro every connection. 00:00 01:00 1.00 0 0 SURFA( DRILL RURD P Continue install riser 01:00 02:00 1.00 0 0 SURFA( DRILL PULD P P/U&Stand back,change out slips dies. 02:00 02:15 0.25 0 0 SURFA( DRILL SFTY P Diverter drill rig evacuation,After action reveiw w/crew. 02:15 03:15 1.00 0 0 SURFA( DRILL PRTS P Flood stack test mud pumps t/3000 psi. 03:15 06:30 3.25 0 0 SURFA( DRILL PULD P M/U drill out BHA,orient motor ubho &Dm Collar. 06:30 07:30 1.00 0 0 SURFA( DRILL RURD P R/U gyro data hang sheave in derrick. 07:30 08:15 0.75 91 103 SURFA( DRILL DDRL P Drill ice plug f/91'V 103' 08:15 11:00 2.75 103 243 SURFA( DRILL DDRL P Drill f/103't/243',gyro every connection.TVD-243',ART=.7, AST=.98, ADT=1.68, Bit hrs.= 1.68 11:00 12:00 1.00 243 59 SURFA( DRILL TRIP P POOH t/59' 12:00 12:30 0.50 59 59 SURFA( DRILL PULD P M/U flex collars&surface jars. 12:30 18:00 5.50 59 611 SURFA( DRILL DDRL P Drill f/243't/611'Gyro every connection,TVD-608' ART= 1.04 AST=1.19, ADT=2.23, Jar hrs= 2.23, Bit hrs=3.91 18:00 00:00 6.00 611 915 SURFA( DRILL DDRL P Drill f/611't/915'MD,TVD 906', ART= 1.43,AST=1.42,ADT=2.23, Jar hrs=6.76, Bit hrs=6.76,P/U=73 K,S/O=71 K, ROT=65 K,Tq on=3 K,Off=1.5 K,WOB=15/20 K, RPM=40,GPM=510 12/26/2012 Drilling Ahead f/915'V 2141'TVD=2041' 00:00 06:00 6.00 915 1,213 SURFA( DRILL DRLG P Cont.drilling f/915'V 1213' ,TVD-1192',ART-2.02,AST-1.46, ADT-3.48, Bit&Jar hrs-10.24 06:00 12:00 6.00 1,213 1,479 SURFA( DRILL DRLG P Drilling f/1213't/1479',TVD-1447', ART-1.02,AST-2.11,ADT-3.13, Bit& Jar hrs-13.37 12:00 18:00 6.00 1,479 1,817 SURFA( DRILL DRLG P Drilling f/1479'V 1817',TVD-1751', ART-1.52,AST-1.76,ADT-3.28, Bit &Jar hrs-16.65 18:00 00:00 6.00 1,817 2,141 SURFA( DRILL DRLG P Drilling f/1817't/2141',TVD-2041', ART-.71,AST-1.49,ADT-2.20, Bit& Jar hrs-18.85 12/27/2012 Drilled to TD @ 2380'MD, (TVD=2260'), CBU X 2,Short trip back to hwtdp on elevators W/O/issues, RIH, CBU X 2 and POOH,stood back hwt&DCs, L/D MWD and motor, Bit. Clear and clean rig floor, make dummy run with hanger,rig up and run casing to 1519'MD,(Encountered tight spot @ 1000'MD worked through 3 times while pumping) Page 2 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 03:00 3.00 2,141 2,380 SURFA( DRILL DRLG P Drilling f/2141't/2380',TVD-2260', TD @ 2380'MD, ART-1.06, AST-1.11,ADT-2.17, Bit&Jar hrs- 21.02. 03:00 05:00 2.00 2,380 2,190 SURFA( CASING CIRC P Attain survey,CBU x 2 @ 570 gpm, 40 RPM, 1750 psi,Tq=5/10 K, Rack back stand on every BU 05:00 06:30 1.50 2,190 614 SURFA( CASING TRIP P Monitor well, P/U=105K,S/O=81 K, POOH f/2190't/614'on elevators with no issues.Calc= 13.2 bbls, Act=16.7 bbls. 06:30 07:45 1.25 614 2,375 SURFA( CASING TRIP P Monitor well, RIH taking 10-15 K Wt @ 1620'MD, 1980 MD,2100-200' MD,clean up after wipe.Calc=40.8 bbls,Act=40.9 bbls. 07:45 10:00 2.25 2,375 2,097 SURFA( CASING CIRC P P/U single and wash down to 2380' MD with no fill,circ with 570 gpm, RPM=40,Tq=4-7K, Rack back stand on every Bottoms up. 10:00 12:00 2.00 2,097 614 SURFA( CASING TRIP P Monitor well, POOH f/2097't/614' MD, P/U=105K,S/O=80K,Monitor well @ hwtdp.Calc=13.2 bbls,Act= 19.1 bbls. 12:00 13:45 1.75 614 0 SURFA( CASING TRIP P PJSM, POOH and stand back hwtdp &DCs,lay down BHA as per Halliburton DD. 13:45 14:45 1.00 0 0 SURFA( CASING PULD P Clear and clean rig floor of tools. 14:45 15:45 1.00 0 0 SURFA(CASING OTHR P Drain stack and make dummy run with hanger as per-Vetco Rep. 15:45 18:00 2.25 0 0 SURFA( CASING RNCS P P/U tools from beaver slide&R/U to run 13-3/8"casing. 18:00 18:15 0.25 0 0 SURFA( CASING SFTY P PJSM on running Surface Casing with crew. 18:15 00:00 5.75 0 1,519 SURFA( CASING RNCS P RIH with L-80 68#13-3/8"casing to 1519'MD.Tight spot at 1000'MD worked through 3 times pumping @ 3 bpm,225 psi. Calc=35.42 bbls, Act=30.1 bbls. 12/28/2012 Run casing t/2332',M/U landing jt.land on hanger, Circ&cond.mud staging pumps t/210 gpm 300 psi, R/U cmt head,cement csing as per detail,CIP 1325 hrs,ck floats good, R/D cmt equip. N/D riser&diverter, N/U J wellhead and test to 5000 psi for 10 min. (Good) 00:00 00:15 0.25 1,519 1,674 SURFA( CASING RNCS P Continue t/RIH t/1674' 00:15 01:00 0.75 1,674 1,674 SURFA(CASING CIRC P CBU stage pumps t/210 gpm,300 psi 01:00 03:30 2.50 1,674 2,332 SURFA( CASING RNCS P Continue t/run csaing f/1674't/ 2332' 03:30 03:45 0.25 2,332 2,369 SURFA( CASING RNCS P M/U landing joint,wash casing t/ bottom @ 2369' 03:45 07:30 3.75 2,369 2,369 SURFA( CASING CIRC P Circ. and condition mud Staging pumps t/210 gpm FCP-250 psi 07:30 08:00 0.50 2,369 2,369 SURFA( CASING RURD P R/D Franks fill up tool/R/U Cement head 08:00 09:00 1.00 2,369 2,369 SURFA( CEMEN"CIRC P Circ&condition mud 252 gpm 300 psi,Simops PJSM on cementing surface casing. Page 3 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:00 14:15 5.25 2,369 0 SURFA(CEMEN"CMNT P Pump 5 bbls CW 100,test lines t/ S 3500 psi, 15 bbls of CW100,mix& pump 50 bbls 10.5ppg mud push, Cwt drop bottom plug, of 11.09 lead cmt, 103 bbls of 12ppg tail cmt, drop to-lb—plug,20 bbls of H2O,chase plug w/318 bbls of mud, Bump plugs w/3184 stks, FCP @ 42 gpm 350 psi,pressure up t/850 psi hold f/5 min bleed off ck floats good.CIP 1325 14:15 15:00 0.75 0 0 SURFA( CEMEN"OTHR P Clean&drain riser,clean&clear rig floor. 15:00 15:30 0.50 0 0 SURFA( CEMEN"RURD P Blow down&Rig down cement equip. Pull landing joint. Rinse out and function bag. 15:30 15:45 0.25 0 0 SURFA( CEMEN"SFTY P Pre Job Safety Meeting 15:45 17:30 1.75 0 0 SURFA(CEMEN"RURD P Continue UD casing equip.bails& elevalors. R/U drilling bails& elevators. 17:30 21:45 4.25 0 0 SURFA( CEMEN"NUND P PJSM,N/D 20"Diverter system and stage outside of sub. 21:45 00:00 2.25 0 0 SURFA(CEMEN"NUND P Nipple up Vetco Gray well head and test to 5000 psi for 10 min.(Good test) 12/29/2012 N/U BOPE, R/U&test BOPE 250/3500 psi, Bag 2500 psi,Moblize Halliburton tools to rig floor, R/U and P/U 20 stands of 5"dp and rack back in derrick,Clear rig floor, M/U drilling BHA, load MWD,shallow test MWD, Load sources,TIH&P/U singles to 1503'MD 00:00 03:15 3.25 0 0 SURFA(CEMEN"NUND P N/U stack&riser, install secondary IA valve, blank of remaining ann. 03:15 04:30 1.25 0 0 SURFA( CEMEN"RURD P R/U t/test bops,fill stack and choke manifold with water. 04:30 10:00 5.50 0 0 SURFA( CEMEN"BOPE P Test BOP'S test choke valves 1-14, HCR&man choke&kill,4"demco, �� auto&man IBOP, Upper lower& blind rams,Annular,TIW&Dart t/ 250 low 3500 high,ACC.test, witness waived by Chuck Scheeve w/ AOGCC 10:00 10:45 0.75 0 0 SURFA( CEMEN-OTHR P R/D test equipment,set 12 7/16 ID wear ring,blow down lines. 10:45 14:30 3.75 0 1,850 SURFA(CEMEN-RURDP UD rig tong heads, P/U BHA components to rig floor, RIH hole with singles to 1850'from shed. 14:30 15:15 0.75 1,850 0 SURFA( CEMEN"PULD P POOH&stand back 5"DP in derrick 20 stands. Calc=15 bbls,Act=14.8 bbls. 15:15 15:45 0.50 0 0 SURFA(CEMEN"OTHR P Clear and clean rig floor. 15:45 18:00 2.25 0 0 SURFA( CEMEN"PULD P PJSM,M/U BHA assembly. 18:00 19:15 1.25 0 0 SURFA( CEMEN"OTHR P Up load MWD data. 19:15 20:00 0.75 0 0 SURFA( CEMEN"CIRC P Pulse test MWD w/480 gpm 100 psi,600 gpm 1500 psi,good blow down top drive. 20:00 20:45 0.75 0 0 SURFA( CEMEN"SFTY P H2S drill, Evacuate rig, helded ARR. Page 4 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:30 0.75 0 0 SURFA(CEMEN'OTHR P PJSM,on loading nuclear sources. Rack back stand and load sources. 21:30 00:00 2.50 0 1,503 SURFA(CEMEN"TRIP P TIH with hwt and P/U singles from shed to 1503'MD, P/U=95K, 8/0= 80K,Calc=24.22 bbls,Act=24.96 bbls. 12/30/2012 Test casing and lower well head flange to 2500 psi F/30 min and chart(Good), Drill shoe track and 20'new hole to 2400'MD,CBU,and perform FIT, EMW=13.5 ppg,Swap over to 9.4 ppg LSND mud system and Directional Drill 12-1/4 hole F/2380'-T/3261'MD,(TVD=2971') 00:00 00:30 0.50 1,503 1,964 SURFA( CEMEN'TRIP P Continue singling in the hole w/ drilling BHA f/1503't/1964' 00:30 00:45 0.25 1,964 1,964 SURFA(CEMEN'SFTY P Pre Job Safety Meeting on slipping& cutting drill line. 00:45 02:00 1.25 1,964 1,964 SURFA(CEMEN"SLPC P Slip&Cut drilling line 78'service top drive. 02:00 03:00 1.00 1,964 2,241 SURFA(CEMEN-WASH P Wash in the hole f/1964' U 2241'@ 294 gpm 600 psi 03:00 04:00 1.00 2,241 2,241 SURFA(CEMEN"PRTS P R/U&test casing U 2500 psi 30 min. on chart, R/D test equipment. 04:00 04:15 0.25 2,241 2,271 SURFA(CEMEN"WASH P Wash in the hole t/2271'tag top of float colar. 04:15 06:30 2.25 2,271 2,380 SURFA(CEMEN"DRLG P Drill float collar,shoe track&float shoe&rat hole @ 550 gpm 1571 psi 40 rpm,8K tq 06:30 07:00 0.50 2,380 2,400 SURFA(CEMEN"DRLG P Drill 20'of new hole f/2380'U 2400' w/550 gpm, 1350 psi,40 rpm, 7k ' tq 07:00 07:30 0.50 2,400 2,400 SURFA( CEMEN"CIRC P CBU condition mud f/FIT test,550 gpm 40 rpm 6.5k tq • 07:30 08:30 1.00 2,400 2,334 SURFA(CEMEN'FIT P Stand back stand, R/U&perform FIT U 13.5 p EMW 08:30 09:15 0.75 2,334 2,400 INTRM1 DRILL CIRC P stand RIH U 2400'Displace drill out mud w/9.4ppg LSND mud. 09:15 12:00 2.75 2,400 2,520 INTRMI DRILL DRLG P Directional Drill 12-1/4"Hole from 2400'-2520'MD,TVD-2393'MD, Pumps @ 600 gpm, PSi-1150, WOB-5K, P/U wt=127K,8/O wt= 90K, Rot wt=106K,Tq on=10K,Tq off=7K, RPM=40,Jar hrs=22.02, Bit hrs=1.0,AST=.61 hrs,ART= .39 hrs, Flow=72%, ECD=N/A 12:00 18:00 6.00 2,520 2,891 INTRMI DRILL DRLG P Directional Drill 12-1/4"Hole from 2520'-2891'MD,ND-2706'MD, Pumps @ 700 gpm, PSi-1650, WOB-3K, P/U wt=135K,S/O wt= 92K, Rot wt=110K,Tq on=9K,Tq off=7K, RPM=80,Jar hrs=24.76, Bit hrs=3.74,AST=1.99 hrs,ART= ..75 hrs,ADT=2.74 hrs, Flow=72%, ECD=N/A Page 5 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 2,891 3,261 INTRM1'DRILL DRLG P Directional Drill 12-1/4"Hole from 2891'-3261'MD,ND-2971'MD, Pumps @ 700 gpm, PSi-1650, WOB-5K, P/U wt=140K,S/O wt= 95K, Rot wt=115K,Tq on=10K,Tq off=8K, RPM=80,Jar hrs=27.47, Bit hrs=6.45,AST=1.94 hrs,ART= .77 hrs,ADT=2.71 hrs, Flow=78%, ECD=N/A, Pumped sweep @ 3258' MD, about 20%increase in cuttings. 12/31/2012 Directional Drill 12-1/4"hole F/3261'T/4929'(ND=3390') 00:00 06:00 6.00 3,261 3,631 INTRMI DRILL DDRL P Directional Drill 12-1/4"Hole from 3261'-3631'MD,TVD-3142'MD, Pumps @ 700 gpm, PSi-1870, WOB-5K, P/U wt=144K,S/O wt= 90K, Rot wt=105K,Tq on=10K,Tq off=9K, RPM=80,Jar hrs=29.91, Bit hrs=8.89,AST=1.8 hrs,ART= .64 hrs,ADT=2.44 hrs, Flow=77%, ECD=N/A, 06:00 12:00 6.00 3,631 3,961 INTRMI DRILL DDRL P Directional Drill 12-1/4"Hole from 3631'-3961'MD,TVD-3203'MD, Pumps @ 700 gpm, PSi-1940, WOB-5K, P/U wt=137K,5/0 wt= 86K, Rot wt=101K,Tq on=10K,Tq off=8K, RPM=80,Jar hrs=32.33, Bit hrs=11.31,AST=1.39 hrs,ART= 1.03 hrs,ADT=2.42 hrs, Flow= 78%, ECD=N/A, 12:00 18:00 6.00 3,961 4,500 INTRM1 DRILL DDRL P Directional Drill 12-1/4"Hole from 3661'-4500'MD,TVD-3306'MD, Pumps @ 750 gpm, PSi-2150, WOB-5K, P/U wt=125K,S/0 wt= 85K, Rot wt=100K,Tq on=10K,Tq off=8K, RPM=80,Jar hrs=35.66, Bit hrs=14.64,AST=1.39 hrs,ART= 1.03 hrs,ADT=2.42 hrs, Flow= 78%, ECD=10.19, 18:00 00:00 6.00 4,500 4,929 INTRM1 DRILL DDRL P Directional Drill 12-1/4"Hole from 4500'-4929'MD,TVD-3390'MD, Pumps @ 750 gpm, PSi-2250, WOB-7K, P/U wt=125K,5/0 wt= 86K, Rot wt=102K,Tq on=9K,Tq off=8K, RPM=80,Jar hrs=38.80, Bit hrs=17.78,AST=.86 hrs,ART= 2.28 hrs,ADT=3.14 hrs, Flow= 78%, ECD=10.22. Pumped sweep @ 4650'and saw no increase in cuttings. 01/01/2013 Directional Drilling 12-1/4"hole to TD @ 5687'MD,(ND 3511')CBU x 4, POOH saw overpull starting at 3050' work pipe and clear ball before the shoe,CBU @ 13-3/8"shoe, RIH,Wash to btm, had clay balls back to surface, half way into btms up, Break down clay balls and clear flowline,Circ and balance well fluid, had 10.4 ppg coming back. Page 6 of 41 Time Logs Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 00:00 06:00 6.00 4,929 5,300 INTRM1 DRILL DDRL P Directional Drill 12-1/4"Hole from 4929'-5300'MD,ND-3469'MD, Pumps @ 750 gpm, PSi-2200, WOB-5K, P/U wt=127K,S/O wt= 87K, Rot wt=105K,Tq on=8.5K,Tq off=7.5K, RPM=80,Jar hrs=42.5, Bit hrs=21.48,AST=1.29hrs,ART= 2.41 hrs,ADT=3.7 hrs, Flow=78%, ECD=10.13. 06.00 12:00 6.00 5,300 5,687 INTRM1 DRILL DDRL P Directional Drill 12-1/4"Hole from 5300'-5687'MD,TD called by Geologist,ND-3511'MD, Pumps @ 750 gpm, PSi-2250,WOB-5K, P/U wt=119K,SIO wt=89K, Rot wt=103K,Tq on=7K,Tq off=5K, RPM=80,Jar hrs=44.41, Bit hrs= 23.39,AST=1.18 hrs,ART=.73 hrs, ADT= 1.91 hrs, Flow=78%, ECD= 10.13. 12:00 12:45 0.75 5,687 5,687 INTRM1 CASING CIRC P CBU x 2, Rotate and reciprocate pipe @ 40 RPM 750 gpm,2250 psi 12:45 13:00 0.25 5,687 5,687 INTRM1 CASING CIRC P Obtain SPRs @ 5687'MD ND 3511' with 9.7 ppg MW. 13:00 13:30 0.50 5,687 5,580 INTRM1 CASING TRIP P Pump out F/5687'T/5580', UD single and rack back stand. 13:30 14:30 1.00 5,580 5,458 INTRM1 CASING CIRC P CBU x 2 Work pipe with same parameters,SIMOPs bring geo-span to rig floor. Rack back stand T/5485' MD 14:30 15:00 0.50 5,458 5,458 INTRMI CASING OWFF P Monitor well,Static 15:00 17:30 2.50 5,458 2,335 INTRM1 CASING TRIP P POOH F/5458'T/2335', BHA started balling up @ 3050'overpull up to 25K over, Reciprocate string several times to clear ball on every stand to shoe. 17:30 18:00 0.50 2,335 2,335 INTRM1 CASING CIRC P CBU with 750 gpm 1900 psi,while working pipe and rotary. 18:00 18:15 0.25 2,335 2,335 INTRM1 CASING OWFF P Monitor well,Static 18:15 20:30 2.25 2,335 5,673 INTRM1 CASING TRIP P RIH F/2335'T/5673'MD.Calc=27 bbls,Act=25.45 bbls. 20:30 22:15 1.75 5,673 5,687 INTRM1 CASING REAM P P/U single and wash down to TD, 5687'MD,40 RPM,400 gpm, 875 psi,work rate up slowly to 600 gpm 1850 psi,Mud ring developed at surface with half bottoms up,Break down clay balls and clear flowline. increase rate back up to 750 gpm 2650 psi,MWT coming back 10.4 ppg and ECD= 10.75. 22:15 00:00 1.75 5,687 5,687 INTRM1 CASING CIRC P Continue circulate and balance well with same parameters.Mud wt coming back 10.0 ppg.Continue to circulate and work on reducing mud wt. Page 7 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/02/2013 24 hr Summary Continue circ&cond.working on reducing mud wt.to 10.0 ppg, POOH to shoe on elevators,CBU,Slip and cut drlg line, POOH, unload nukes and data from MWD, UD BHA, Pull wear bushing,C/O top rams to 9-5/8", R/U and tried to test,Test joint had cracked welds,weld up same three times,tested good, R/D and R/U casing tools, PJSM, run 9-5/8"casing 00:00 02:15 2.25 5,687 5,687 INTRM1 CASING CIRC P Continue circulating to get mud wt down, 176 spm,2500 psi,50 RPM,7 K Tq,flow=78%while working drill string.(Mud wt F/10.4ppg T/10.0 ppg) 02:15 02:45 0.50 5,687 5,687 INTRMI CASING CIRC P Obtain SPRs, Blow down Top Drive, Monitor well.Good 02:45 05:15 2.50 5,687 2,429 INTRM1 CASING TRIP P PJSM, POOH F/5687'T/2429'on elevators,Clac=26.52 bbls,Act= 30.43 bbls, 05:15 06:00 0.75 2,429 2,429 INTRMI CASING CIRC P Circulate @ shoe, 138 spm 1250 psi, with 40 RPM 06:00 06:15 0.25 2,429 2,429 INTRM1 CASING SFTY P PJSM on cutting drilling line. 06:15 07:15 1.00 2,429 2,429 INTRM1 CASING SLPC P Slip and cut 104'drilling line,service Top Drive. 07:15 08:15 1.00 2,429 662 INTRM1 CASING TRIP P Continue POOH F/2429'T/662'MD, Calc= 10.14 bbls,Act= 12.07 bbls. 08:15 09:30 1.25 662 114 INTRM1 CASING PULD P Monitor well, Rack back hwdp, UD two joints hwdp and jars, UDtools to MWD.Calc=13.2 bbls.Act=17 bbls. 09:30 09:45 0.25 114 114 INTRM1 CASING SFTY P PJSM,on removing nukes sources. 09:45 11:15 1.50 114 114 INTRMI CASING PULD P PJSM,UD nukes and down load MWD. 11:15 12:00 0.75 114 61 INTRM1 CASING PULD P UD remaining BHA to 61' 12:00 13:00 1.00 61 0 INTRM1 CASING PULD P Continue UD BHA and bit. 13:00 13:30 0.50 0 0 INTRM1 CASING OTHR P Clear and Clean rig floor. 13:30 14:00 0.50 0 0 INTRM1 CASING OTHR P Pull wear ring. 14:00 16:00 2.00 0 0 INTRM1 CASING OTHR P C/O upper rams to 9-5/8". 16:00 16:30 0.50 0 0 INTRM1 CASING BOPE P R/U test equipment. 16:30 17:45 1.25 0 0 INTRM1 CASING BOPE T Made several attemps to test 9-5/8" rams,pulled test joint and found cracks between 9-5/8"X 5',send to welding shop. 17:45 21:00 3.25 0 0 INTRM1 CASING OTHR T Weld test joint, reinstall in stack, made several more attempts with no success,pulled and observed failed welds,send back to shop and reweld and reinstall again. 21:00 21:45 0.75 0 0 INTRMI CASING BOPE P Test upper ram's to 250 low/3500 high and annular to 2500 psi 21:45 22:00 0.25 0 0 INTRM1 CASING BOPE P R/D test equipment. 22:00 23:00 1.00 0 0 INTRMI CASING RNCS P Finish R/U to run casing. 23:00 23:30 0.50 0 0 INTRM1 CASING SFTY P PJSM,on running 9-5/8"casing. 23:30 00:00 0.50 0 0 INTRM1 CASING RNCS P Fill stack and P/U first joint of 9-5/8" casing&shoe. Page 8 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/03/2013 24 hr summary Run 9-5/8"40#L-80 breaking circulation every 10 joints, CBU @ shoe,cont. RIH with casing to 5687'MD tagged bottom and circ&cond mud for cement job.Mud wt=9.7 ppg, break out Franks fill up tool, Blow down, R/U cement head and break circ. 00:00 00:15 0.25 0 0 INTRM1 CASING SFTY P PJSM with new crew on running casing. 00:15 08:00 7.75 0 2,385 INTRM1 CASING RNCS P RIH with 9-5/8 40#L-80 casingm as per detail, breaking circulationn every 10 jts, @ 1 bpm.to 2385'MD, P/U= 117K,S/O=100K,Calc=34.65 bbls, Act=30.80 bbls. 08:00 10:00 2.00 2,385 2,385 INTRM1 CASING CIRC P CBU staging pumps up F/lbpm T/4 bpm 250 psi. 10:00 12:00 2.00 2,385 3,067 INTRM1 CASING RNCS P Continue running 9-5/8"casing F/ 2385'T/3067'MD,breaking circulation every 10 joints, P/U= 146K, S/O=111K,Calc=10.27 bbls, Act=8.7 bbls.(Total tour loss=18 bbls.) 12:00 18:00 6.00 3,067 5,687 INTRM1 CASING RNCS P Continue running 9-5/8"casing F/ 3067'T/5687'MD,Tagged bottom, breaking circulation every 10 joints, P/U=146K,SIO=111K,Calc=38.52 bbls,Act=33.6 bbls. 18:00 20:00 2.00 5,687 5,687 INTRM1 CEMEN-CIRC P UD joint after tagging bottom @ 5687'MD,CBU @ 2bpm and step rate up to 6 bpm with 500 psi and work string. 20:00 22:30 2.50 5,687 5,687 INTRM1 CEMEN"CIRC P Swap to pit#6,circ and cond.mud to 9.6 ppg in/out,at 5 bpm with 450 psiand 350 FCP. 22:30 23:15 0.75 5,687 5,687 INTRM1 CEMEN"OTHR P R/D Franks fil up tool, Blow down Top Drive and R/U cement head. 23:15 00:00 0.75 5,687 5,687 INTRMI CEMEN-CIRC P Break circulation @ 5 bpm 250 psi, while recip.string 30',P/U=185K, S/O=120K. 01/04/2013 Circ&cond for cement, Held PJSM,cement as per program,displace with rig and bumped plug on calculated stks,CIP @ 03:29 hrs,check floats, R/U cement head and lines, Break stack and set slips, Install pack-off and test same,R/U and flush&freeze protect 13-3/8"x 9-5/8"OA, R/U and test BOP doors& annular w/4"&5"test jt.Set wear bushing,M/U clean out BHA&RIH to 5579'CBU,set stand back. 00:00 00:15 0.25 5,681 5,681 INTRMI CEMEN-CIRC P Continue circ and cond mud @ 5 bpm 250 psi 00:15 00:30 0.25 5,681 5,681 INTRM1 CEMEN'SFTY P PJSM with all involved with cement job. 41 00:30 02:00 1.50 5,681 5,681 INTRM1 CEMEN'CMNT P Pump 5 bbls water,pressure test �/ lines to 4000 psi,Pumped 15 bbls of CW-100,40 bbls of mud push II,drop btm plug and 173.35 bbls of lead 12.5 ppg.69.14 bbls of tail 15.8 ppg, , drop top plug with 10 bbls water. 02:00 03:30 1.50 5,681 5,681 INTRM1 CEMEN"CMNT P swap over to rig and dispalce @ 5 bpm 150 psi, FCP @ 5 bpm 650 psi, slow pumps to 3 bpm at 3850 stks, with 550 psi, Bumped plug with 4090 stks, pressured up to 1050 psiand held for 5 min.CIP @ 03:29 hrs,set shoe @ 5681'MD Page 9 of 41 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:30 05:15 1.75 0 0 INTRM1 CEMEN"CMNT P Check floats(Good)R/D cement line and blow down, R/D cement head and x-over,drain stack and vac out landing joint. 05:15 05:30 0.25 0 0 INTRM1 CEMEN'SFTY P PJSM,on breaking stack and lifting to set emergency slips. 05:30 06:30 1.00 0 0 INTRM1 CEMEN NUND P Break stack and lift same. 06:30 12:00 5.50 0 0 INTRM1 CEMEN'OTHR P Set emergency slips in tension w/ 92K,Cut casing joint and lay down (Cut jt=31.09,)dress off stump, P/U joint and make up to top drive and set packoffwith 15K, RILDS 12:00 13:00 1.00 0 0 INTRM1 CEMEN'NUND P PJSM, Nipple back up stack, Rig up lines for 13-318'x 9-5/8"flush& freeze protection. 13:00 13:45 0.75 0 0 INTRM1 CEMEN"OTHR P Test Pack-off to 2400 psi for 10 min (Good) 13:45 15:15 1.50 0 0 INTRM1 CEMEN"OTHR P Pump and break down formation with water 1 bpm @ 1000 psi,increase rate to 1.5 bpm pressure increase to 1100 psi and stabilized @ 800 psi, pumped 20 bbls and increased rate to 3 bpm with 900 psi&stabilized @ 800 psii, FlushedOA with 155 bbls water,shut in with 575 psi,SIMOPS change top rams to VBR 3.5 x 6. 15:15 16:30 1.25 0 0 INTRM1 CEMEN"OTHR P PJSM with Little Red, PT lines to 2000 psi,freeze protect with 120 bbl of diesel ICP=550 psi, FCP 1100 psi,SIMOPS R/U test joint 4"and test equipment. 16:30 17:30 1.00 0 0 INTRM1 CEMEN"BOPE P Test BOP with 4"test joint, ram's and annular, Lower 2-7/8"x 5"VBR, upper 3.5"x 6"VBR to 250/3500 psi&annular to 250/2500 psi for 5 min each. 17:30 18:15 0.75 0 0 INTRM1 CEMEN"BOPE P Test BOP with 5"test joint,ram's and annular, Lower 2-7/8"x 5"VBR, upper 3.5"x 6"VBR to 250/3500 psi&annular to 250/2500 psi for 5 min each. Record all tests on chart. 18:15 18:45 0.50 0 0 INTRM1 CEMEN"BOPE P Pull test plug, R/D test equipment and set wear bushing. 18:45 22:30 3.75 0 5,500 INTRMI CEMEN-TRIPP PJSM,M/U bit bit sub&hwdp and RIH to 5500'MD,Calcu=47.93 bbls, Act=48.05 bbls. 22:30 23:15 0.75 5,500 5,579 INTRMI CEMEN-CIRCP Kelly up, P/U=120K,S/O=80K, wash down to 5579'7 bpm 600 psi, P/U and circ 14 bpm 600 gpm, 1800 psi, Rot wt=94K TQ=5.5K 23:15 23:30 0.25 5,579 5,579 INTRM1 CEMEN'CIRC P Obtain SPRs @ 5579'3511 ND 9.7 ppg Mud wt. 23:30 00:00 0.50 5,579 5,500 INTRM1 CEMEN TRIP P Rack back stand of 5"to 5500'MD and blow down top drive. Page 10 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 01/05/2013 24 hr summary Test 9-5/8"casing to 3000 psi(Good), Drill float equipment plus 20'new hole to 5707'MD,CBU, Perform FIT, EMW=12.8 ppg,displace well to OBM,Monitor well, POOH installing super sliders, P/U 60 joint of 4"dp and rack back in derrick,M/U 6-3/4"drilling BHA and up load data to MWD tools. 00:00 00:15 0.25 5,500 5,500 INTRM1 CEMEN-PRTS P PJSM,&R/U to test 9-5/8:casing. 00:15 01:15 1.00 5,500 5,500 INTRM1 CEMEN"PRTS P Pressure test 9-5/8"casing to 3000 psi and chart same. Good. R/D test equipmen&blow down lines. 01:15 01:30 0.25 5,500 5,594 INTRM1 CEMEN"COCF P Tagged up at 5582'M D,wash& ream from 5582'to 5594'with 650 gpm,2250 psi,60-100 rpm,Tq= 8-10K, 01:30 03:45 2.25 5,594 5,687 INTRMI CEMEN"DRLG P Drill float equipment out F/5594'T/ 5687'MD @ 100 rpm,Tq=7-11K, 650 gpm with 2250 psi. 03:45 04:00 0.25 5,687 5,707 INTRM1 CEMEN"DRLG P Drill 20'new hole F/5687'T/5707' MD @ 100 rpm,Tq=10K,650 gpm with 2250 psi. 04:00 04:45 0.75 5,707 5,592 INTRMI CEMEN-CIRC P CBU and set back stand, R/U for FIT. 04:45 05:15 0.50 5,592 5,592 INTRM1 CEMEN'FIT P Perform FIT pressure up to 630 psi, EMW=12.8 PPG, R/D test equipment and blow down. 05:15 06:30 1.25 5,592 5,592 INTRM1 DRILL CIRC P Pick up stand back to 5707'MD and displace well to 9.6 ppg,VersaPro OBM.Set back stand. 06:30 07:00 0.50 5,592 5,592 INTRM1 DRILL OWFF P Monitor well and clean under shakers and trough,Static. 07:00 07:15 0.25 5,592 5,592 INTRM1 DRILL CIRC P Obtain SPRs and blow down top drive. 07:15 07:30 0.25 5,592 5,592 INTRM1 DRILL SFTY P PJSM,on installing super sliders. 07:30 12:00 4.50 5,592 3,183 INTRMI DRILL TRIP P POOH F/5592'T/3183'MD, installing super slider on every joint, Calc=19.5 bbls,Act=23.46 bbls. 12:00 15:45 3.75 3,183 0 INTRM1 DRILL TRIP P Continue POOH install supper sliders on every joint F/3183'except for the last 14 stands did not have any more. LID jars and rack back hwdp.Calc=29.2 bbls,Act=34.0 bbls. 15:45 17:00 1.25 0 0 INTRM1 DRILL OTHR P Clear rig floor and change over to 4" handling equipment. 17:00 18:45 1.75 0 0 INTRM1 DRILL PULD P PJSM, M/U mule shoe and single in 60 jts of 4"dp for pipe management. 18:45 19:30 0.75 0 0 INTRM1 DRILL TRIP P POOH and rack back in Derrick. 19:30 20:30 1.00 0 0 INTRM1 DRILL PULD P Clear rig floor and bring up Sperry subs for next BHA run. 20:30 23:15 2.75 0 97 PROD1 DRILL PULD P PJSM,M/U 6-3/4"Geo Pilot BHA#4 to 97'MD. 23:15 00:00 0.75 97 97 PROD1 DRILL PULD P Up load data to MWD tool. 01/06/2013 Finish P/U BHA(Flex DCs, hwdp&Jars)Pulse test MWD good,Single in the hole W/4"dp to 5707'MD, Perform base line ECD=10.05 pp , Directional Drill F/5707'MD T/6673'MD,TVD=3526' 00:00 01:00 1.00 97 373 PROD1 DRILL PULD P P/U 3 jts Flex DCs,4 jts of hwdp and jars. Page 11 of 41 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:45 0.75 373 373 PROD1 DRILL CIRC P Pulse test MWD @ 300 gpm, 1800 psi,Good. 01:45 06:00 4.25 373 5,469 PROD1 DRILL TRIP P Single in hole with 4"XT-39 dp F/ 373'T/5469'MD filling every 20 stands. 06:00 06:15 0.25 5,469 5,469 PROD1 DRILL OTHR P C/O handling tools F/4"T/5". 06:15 06:30 0.25 5,469 5,680 PROD1 DRILL TRIP P RIH F/5469'T/5680'MD,with 5"dp from derrick. Calc=35.47 bbls,Act= 36.06 bbls. 06:30 07:15 0.75 5,680 5,707 PROD1 DRILL CIRC P Establish ECD base line(10.05 ppg) RIH to 5707'MD Obtain SPRs. 07:15 12:00 4.75 5,707 5,951 PROD1 DRILL DDRL P Directional Drill F/5707'T/5951'MD, TVD=352T,ART=2.26,ADT=2.26, Jar hrs=2.26, Bit hrs=2.26, P/U= 115K,S/0=63K, Rot=83K,Tq on= 5K,Off=5K, ECD=10.03,WOB= 4-5K, RPM= 100,GPM=250, PSI= 2250. 12:00 18:00 6.00 5,951 6,253 PROD1 DRILL DDRL P Directional Drill F/5951'T/6253'MD, TVD=3524',ART=3.34,ADT=3.34, Jar hrs=5.60, Bit hrs=5.60,P/U= 117K,S/O=64K, Rot=84K,Tq on= 5K,Off=4K, ECD=10.15,WOB= 4-5K, RPM= 125,GPM=250, PSI= 2300. 18:00 00:00 6.00 6,253 6,673 PROD1 DRILL DDRL P Directional Drill F/6253'T/6673'MD, TVD=3526',ART=3.39,ADT=3.39, Jar hrs=8.99, Bit hrs=8.99,P/U= 110K,S/O=70K, Rot=85K,Tq on= 4K,Off=3K, ECD=10.26,WOB= 4-5K, RPM=125,GPM=275, PSI= 2350. 01/07/2013 Directional Drilling F/7284'T/7693'TVD=3533',CBU,flowcheck, BROOH to 5655'MD,CBU @ shoe,Slip and cut drlg line,C/O handling equipment to 4", RIH with 17 stands of 4"dp and M/U circ subs, Instal XO, M/U MI circ sub to 5"dp Ream to bottom no fill, Directional Drill F/7693'T/7885'TVD=3515' 00:00 06:00 6.00 6,673 7,284 PROD1 DRILL DDRL P Directional Drill F/6373'T/7284'MD, TVD=3540',ART=4.21,ADT=4.21, Jar hrs=13.20, Bit hrs=13.20, P/U= 121K,S/O=62K, Rot=88K,Tq on= 4K,Off=4K, ECD=10.35,WOB= 2-4K, RPM=120,GPM=275, PSI= 2350,psi 2375. 06:00 10:30 4.50 7,284 7,693 PROD1 DRILL DDRL P Directional Drill F/7284'T/7693'MD, TVD=3533',ART=3.51,ADT=3.51, Jar hrs=16.71, Bit hrs=16.71, P/U= 117K,S/O=67K, Rot=88K,Tq on= 4.5K,Off=4K, ECD=10.42,WOB= 4-6K, RPM=120,GPM=275, PSI= 2400. 10:30 10:45 0.25 7,693 7,693 PROD1 DRILL CIRC P Obtain SPRs 10:45 12:00 1.25 7,693 7,693 PROD1 DRILL CIRC P CBU @ 275 gpm, 120 RPM 12:00 12:15 0.25 7,693 7,693 PROD1 DRILL OWFF P Monitor well(Static) Page 12 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 15:00 2.75 7,693 5,655 PROD1 DRILL REAM P BROOH F/7693'T/5750"with 220 gpm, 1550 psi,and pumped out to 5655'MD up into the shoe. 15:00 16:15 1.25 5,655 5,565 PROD1 DRILL CIRC P CBU @ 250 gpm, 1850 psi, Rot& Recip.90'standwith 50 rpm,F/5655' T/5565'MD. Calc=17.25 bbls, Act= 25.55 bbls. 16:15 16:45 0.50 5,565 5,565 PROD1 DRILL SFTY P Blow down, Monitor well, PJSM on slip&cut drlg line. 16:45 18:15 1.50 5,565 5,565 PROD1 DRILL SLPC P Slip and cut 91'drlg line and service Top Drive. 18:15 18:30 0.25 5,565 5,466 PROD1 DRILL OWFF P Rack back stand of 5"to 5466',M/U floor valve for 4"dp and C/O/handling eqiupment to 4". 18:30 20:30 2.00 5,466 7,661 PROD1 DRILL TRIP P RIH with 17 stands of 4"dp,Test RFID circ sub,M/U and continue RIH with 3 more stands of 4"dp,XO,abd stand of 5"dp,M/U MI circ sub& RIH to 7661'MD.Calc=11.55 bbl, Act=11.97 bbls. 20:30 21:00 0.50 7,661 7,693 PROD1 DRILL REAM P M/U TD and wash&ream to 7693' MD,with 270 gpm,2450 psi,did not see any fill. P/U=122K,S/O=50K, 21:00 00:00 3.00 7,693 7,885 PROD1 DRILL DDRL P Directional Drill F/7693'T/7885'MD, TVD=3515',ART=1.52,ADT=1.52, Jar hrs=18.23, Bit hrs=18.23,P/U= 127K, S/0=50K, Rot=80K,Tq on= 5K,Off=4K, ECD= 10.40,WOB= 4-6K, RPM=120,GPM=275, PSI= 2475. 01/08/2013 Continue Directional drilling from 7885'MD to 9192'MD.TVD=3498'.ADT today=13.37 HRS.Total Bit& Jar Hrs=31.88. ECD-10.66 PPG EMW 00:00 06:00 6.00 7,885 8,216 PROD1 DRILL DDRL P Directional Drill F/7885'T/8216'MD, TVD=3481',ART=3.51,ADT=3.51, Jar hrs=21.74, Bit hrs=21.74,P/U= 120K,S/0=56K, Rot=82K,Tq on= 5K,Off=5K, ECD= 10.55,WOB= 5-7K, RPM= 120,GPM=270, PSI= 2450. Note:Work on and troubleshoot MWD computer issues. 06:00 12:00 6.00 8,216 8,354 PROD1 DRILL DDRL P Directional Drill F/8216'T/8354'MD, TVD=3474',ART=2.78,ADT=2.78, Jar hrs=24.80, Bit hrs=24.80,P/U= 120K,S/O=56K, Rot=82K,Tq on= 5K,Off=5K, ECD= 10.55,WOB= 10-15K, RPM= 120,GPM=270, PSI=2510.Crew Change 12:00 18:00 6.00 8,354 8,866 PROD1 DRILL DDRL P Directional Drill F/8354'T/8866'MD, TVD=3489',ART=3.99,ADT=3.99, Jar hrs=28.79, Bit hrs=28.79, P/U= 130K,S/O=55K, Rot=85K,Tq on= 6K,Off=6K, ECD=10.61,WOB=3. -5K, RPM= 120,GPM=270,PSI= 2500. Page 13 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 8,866 9,192 PROD1 DRILL DDRL P Directional Drill F/8866'T/9192'MD, TVD=3498', ART=3.09,ADT=3.09, Jar hrs=31.88, Bit hrs=31.88,P/U= 135K,S/O=56K, Rot=86K,Tq on= 6K, Off=6K, ECD= 10.66,WOB=3. -5K, RPM=120,GPM=270, PSI= 2500.Obtained SPR's.Crew Change 01/09/2013 Continue Directional drilling from 9192'MD to 10811'MD.TVD=3527'.ADT today=14.76 HRS.Total Bit& Jar Hrs=46.64. ECD-10.82 PPG EMW 00:00 06:00 6.00 9,192 9,421 PROD1 DRILL DDRL P Directional Drill F/9192'T/9421'MD, TVD=3526',ART=3.89,ADT=3.89, Jar hrs=35.77, Bit hrs=35.77, P/U= 133K,S/O=57K, Rot=91K,Tq on= 6K,Off=6K, ECD=10.72,WOB= 10-12K, RPM=120,GPM=270, PSI=2525. 06:00 12:00 6.00 9,421 9,931 PROD1 DRILL DDRL P Directional Drill F/9421'T/9931'MD, TVD=3518',ART=3.85,ADT=3.85, Jar hrs=39.62, Bit hrs=39.62, P/U= 135K, S/0=57K, Rot=92K,Tq on= 6.5K,Off=7K, ECD=10.94,WOB= 3-5K, RPM=120,GPM=270, PSI= 2650.Obtained SPR's.Crew Change 12:00 18:00 6.00 9,931 10,347 PROD1 DRILL DDRL P Directional Drill F/9931'T/10347' MD,TVD=3530',ART=3.54,ADT= 3.54,Jar hrs=43.16, Bit hrs=43.16, P/U=145K,S/0=50K, Rot=87K,Tq on=7K,Off=7K, ECD=10.96, WOB=3-10K, RPM=120,GPM= 270, PSI=2625. 18:00 00:00 6.00 10,347 10,811 PROD1 DRILL DDRL P Directional Drill F/10347'T/10811' MD,TVD=3527',ART=3.48,ADT= 3.48,Jar hrs=46.64, Bit hrs=46.64, P/U=148K,SIO=45K, Rot=92K,Tq on=7K,Off=6.5K, ECD=11.01, WOB=7-9K, RPM=120,GPM= 270, PSI=2650.Obtained SPR's. Crew Change 01/10/2013 Continue directional drilling B lateral from 10811'-11139'MD.ND=3529'.Observed Fault crossing with throw allowing us to drill out of the top of the reservoir.Pull back and trough hole form 10370'-10380'MD. Kick off at 10380'MD, and continue directional drill B lateral to 11364 MD.TVD=3567.Observed-350 psi pressure and MWD stopped working.Trouble shoot MWD, no success. Circ hole clean to POOH. 00:00 04:00 4.00 10,811 r 11,139 PROD1 DRILL DDRL P Directional Drill F/10811'T/11139' MD,TVD=3529',ART=2.43,ADT= 2.43,Jar hrs=49.07, Bit hrs=49.07, P/U=175K,S/0=45K, Rot=93K,Tq on=7.5K,Off=6.5K, ECD=11.15, WOB=8-10K, RPM=135,GPM= 270, PSI=2650.Observed fault crossing with the throw severe enough to allow us to drill out of top of the reservoir. Decision to pull back for sidetrack. 04:00 05:00 1.00 11,139 10,350 PROD1 DRILL REAM T BROOH from 11139'-10350'MD. Pump rates at 50 RPM's-200 GPM's-1500 PSI. Page 14 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 10,350 10,380 PROD1 DRILL REAM T Trough hole from 10370'-10380'MD. 05:45 12:00 6.25 10,380 10,625 PROD1 DRILL DDRL T Directional Drill F/10380'T/10625' MD,TVD=3543',ART=4.35,ADT= 4.35,Jar hrs=53.42, Bit hrs=53.42, P/U= 140K,5/0=55K, Rot=94K,Tq on=7K,Off=7K, ECD=10.79, WOB=3-5K, RPM=120,GPM= 270, PSI=2550.Obtained SPR's. Crew Change 12:00 18:30 6.50 10,625 11,139 PROD1 DRILL DDRL T Directional Drill F/10625'T/11139' MD,TVD=3560',ART=3.41,ADT= 3.41,Jar hrs=56.83, Bit hrs=56.83, P/U=150K,S/O=50K, Rot=91K,Tq on=7.5K,Off=7K, ECD=10.95, WOB=8-10K, RPM=120,GPM= 268, PSI=2600.Obtained SPR's. 18:30 23:00 4.50 11,139 11,364 PROD1 DRILL DDRL P Directional Drill f/11139'MD t/ 11364'MD,TVD 3567'.ADT=3.06, Jar hrs=59.89, Bit hrs=59.89,P/U= 150K,S/O=55K, ROT=90K,Tq on= 7.5L,Tq off=7.5K, ECD= 10.91, Flow out=50%,WOB=10-12K, RPM=120,GPM=270, Pump pressure=2575 PSI 23:00 00:00 1.00 11,364 11,364 PROD1 DRILL CIRC T Observed pump pressure increase f/ 2650 psi to 2950 psi,MWD tool failed also.Work string with pumps on/off,string free with same flow percent. Bleed off pressure and attempt to clear blockage, increased pump rate to 300 gpm=3400 psi several times to unplug, no success. 01/11/2013 Pump HiVis sweep and circulate hole clean. Back ream out of the hole t/7074'.CBU and POOH on elevators. UD BHA. Rig up and start testing BOPE t/250/3500 psi.Jeff Jones of the AOGCC waived witness of the test. 00:00 00:15 0.25 11,364 11,364 PROD1 DRILL CIRC T PJSM,continue attempt T/unplug string(no success). Decision made to pump sweep and POOH. 00:15 00:30 0.25 11,364 11,364 PROD1 DRILL TRIP T Obtain SPR, rack back two stands. 00:30 03:30 3.00 11,364 11,182 PROD1 DRILL CIRC T Pump hi-vis sweep and circulate until hole clean. No increase in cutting observed at shakers when the sweep returned. 03:30 03:45 0.25 11,182 11,182 PROD1 DRILL OWFF T Monitor well,static. 03:45 09:15 5.50 11,182 7,074 PROD1 DRILL REAM T Backream out of the hole f/11182' MDU 7074'MD @ 250 gpm=2650 psi,50 rpms,Tq=7K,50%flow. Lay down Well Commander, lost all pump pressure after Well Commander was laid down. Lay down Weatherfrod Circ sub(observed Weatherford sub open)Actual displacement=48.46 bbls, Calculated displacement=31.98 bbls. Page 15 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:30 0.25 7,074 7,074 PROD1 DRILL RURD T Change over to 4"handling tools and OWFF. 09:30 11:45 2.25 7,074 7,074 PROD1 DRILL CRC T Attempted to get MWD detection, no success.Circulate hole clean @ 6 bpm=2500 psi,50 rpm,Tq=4K, P/U=105K,S/O=62K. 11:45 12:00 0.25 7,074 7,074 PROD1 DRILL OWFF T Blow down top drive and OWFF. 12:00 16:30 4.50 7,074 373 PROD1 DRILL TRIP T POOH on elevators f/7074'MD t/ 373'MD.Actual displacement= 65.54 bbls, Calculated displacement=43.25 bbls 16:30 16:45 0.25 373 373 PROD1 DRILL OWFF T Monitor well,static. 16:45 18:00 1.25 373 90 PROD1 DRILL PULD T L/D BHA,stand back HWDP,jars and flex collars. 18:00 19:15 1.25 90 90 PROD1 DRILL PULD T Plug in and download MWD tools. 19:15 20:30 1.25 90 0 PROD1 DRILL PULD T Cont.to lay down BHA.The popit on the MWD pulser was stuck in the open position. 20:30 21:00 0.50 0 0 PROD1 DRILL OTHR T Clean and clear rig floor. 21:00 21:30 0.50 0 0 PROD1 WHDBO RURD P Drain stack and pull wear bushing. 21:30 22:30 1.00 0 0 PROD1 WHDBO SEQP P Set test plug and rig up to test BOPE. 22:30 22:45 0.25 0 0 PROD1 WHDBO SFTY P Hold PJSM,fill out hazard cards on testing BOPE. Install high pressure testing signage. Discuss working around high pressure lines. 22:45 00:00 1.25 0 0 PROD1 WHDBO BOPE P Test BOPE w/5"test joint to 250/3500 PSI.Test#1:Top pipe rams,CV 1,12,13,14 and manual kill. Test#2: Upper IBOP,HCR kill CV 9 and 11. Test#3: Lower IBOP,CV 5,8,and 10. Jeff Jones of the AGOCC waived witness of test. 31/12/2013 Complete BOP test t/250/3500 psi,Jeff Jones of AOGCC waived witness of test.Make up BHA#5 and RIH U 5750'MD.CBU @ casing shoe. RIH t/7071'MD and M/U Well Commander Circ sub.Cont RIH t/9483' MD, ran out of down weight. Rotate in the hole pumping @ 100 gpm w/30 rpms.Weather became Phase III, pump @ 100 gpm w/30 rpms.Wait on weather. Page 16 of 41 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 06:15 6.25 0 0 PROD1 DRILL BOPE P PJSM held prior to testing BOPE. BOPE tested T/250/3500 PSI.4"and 5"dart valve,C.V.#4,#6,and#7. 4" and 5"floor valve,C.V.#2. HCR choke,4"kill line demco. Manual choke valve, HCR kill. Blind rams. Test annular preventer W/4", 4.5" and 5"test joints T/250/2500 PSI. Test top pipe rams W/4",4.5"and 5"test joints T/250/3500 PSI. Test lower pipe rams W/4",4.5"and 5" test joints T/250/3500 PSI. Accumulator test=system pressure =3000 PSI,pressure after closed= 1800 PSI,200 PSi attained=32 sec. Full pressure attained= 191 sec. 5 bottle average=2050 PSI. Jeff Jones of AOGCC waived witness. 06:15 07:30 1.25 0 0 PROD1 DRILL BOPE P R/D test equipment, break 4"and 5" floor valves apart. Drain stack,blow down top drive, kill line, choke line and choke manifold. 07:30 08:00 0.50 0 0 PROD1 DRILL OTHR P Install 9"wear bushing. 08:00 08:30 0.50 0 0 PROD1 DRILL SVRG P Service rig. 08:30 08:45 0.25 0 0 PROD1 DRILL SFTY T Hold PJSM on making up BHA#5. 08:45 11:00 2.25 0 0 PROD1 DRILL PULD T Pick up and make up BHA#5 as per Halliburton rep. 11:00 12:00 1.00 0 0 PROD1 DRILL PULD T Upload MWD tool as per Halliburton rep. 12:00 12:30 0.50 0 0 PROD1 DRILL PULD T PJSM,Cont. P/U BHA. 12:30 13:15 0.75 0 370 PROD1 DRILL CIRC T Pick up Jars and one stand of HWDP.Shallow hole test and break in seals on Geo-Pilot. Pump @ 6 bpm=1250 psi, ROT 5 rpm and stage up to 40 rpm.,good test. 13:15 16:30 3.25 370 5,655 PROD1 DRILL TRIP T Trip in the hole f/370'MD t/5655' MD. 16:30 17:30 1.00 5,655 5,750 PROD1 DRILL CIRC T Wash down f/5655't/5750'.CBU @ shoe to clean up casing, pump @ 250 gpm= 1900 psi., ROT 30 rpm. Increase pump rate t/270 gpm=2200 psi, ROT 60 rpm w/Geo-Pilot in open hole. 17:30 18:30 1.00 5,750 7,071 PROD1 DRILL TRIP T Cont tripping in the hole t/7072'MD. 18:30 19:00 0.50 7,071 7,071 PROD1 DRILL PULD T Pick up single and make up MI-SWACO Well Commander. 19:00 21:00 2.00 7,071 9,483 PROD1 DRILL TRIP T Cont tripping in the hole f/7171't/ 9483'. Unable to trip in further on elevators due to running out of down weight. 21:00 00:00 3.00 9,483 10,826 PROD1 DRILL TRIP T Wash and ream in the hole. Pump @ 100 gpm-600 psi, rotate @ 30 rpms, Tq=5-6K. P/U= 112K,S/0=80K Page 17 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/13/2013 24 hr Summary Waiting on Phase III weather.Train crews on NPRA training,polar bear and cultural awareness. 00:00 00:30 0.50 10,826 10,826 PROD1 DRILL SFTY T PJSM on Phase III weather.Talk about not working alone,do not work on any major projects.Walk to/from camp in groups. 00:30 12:00 11.50 10,826 10,826 PROD1 DRILL OTHR T Work pipe f/10734'MD t/10826' MD. Pump @ 2.5 bpm=700 psi, Rot @ 20 rpm w/6K Tq. P/U=112K, SIO=80K, Rot=94K.Slow pump rate t/1 bpm=275 psi @ 4 am. 12:00 12:30 0.50 10,826 10,826 PROD1 DRILL SFTY T PJSM on Phase III weather.Talk about not working alone,do not work on any major projects.Walk to/from camp in groups. 12:30 00:00 11.50 10,826 10,826 PROD1 DRILL OTHR T Work pipe f/10734'MD t/10823' MD. Pump @ 1 bpm=275 psi, Rot 20 rpm w/6 K Tq. P/U=112K,S/O= 80K, Rot=95K. Train crews on NPRA training, polar bear and cultural awareness. 01/14/2013 Waiting on Phase III weather. Pumping @ 3.8 bpm laying down 1 joint every bottoms up. 00:00 00:00 24.00 10,826 10,641 PROD1 DRILL OTHR T Phase III weather.Work pipe f/ 10826'MD t/10641'MD. Pump @ 160 gpm=1100 psi, Rot 20 rpm=6K Tq. P/U=106K,S/O=76K. Lay down 1 single every bottoms up.Start adding base fluid into mud @ 17:00 hrs. 01/15/2013 Continue to wait on weather and for support crews to clear roads. Roads down graded to Phase II @ 17:00 hrs.Troughted f/11160't/11194'.Time drilled f/11194't/11223'. Drilling ahead @ 11270'MD.Seapage losses of—5 bph. 00:00 08:15 8.25 10,641 10,427 PROD1 DRILL OTHR T Phase III weather conditions, Continue to work pipe f/10641't/ 10427', L/D 1 jt every BU, 160 gpm 1100 psi 20 rpm 6K tq. 08:15 09:15 1.00 10,427 11,193 PROD1 DRILL OTHR T RIH f/10427't/11196'Circ&recip.f/ 11010't/11193'150 gpm 1100 psi 20 rpm 6k tq. 09:15 12:00 2.75 11,193 11,193 PROD1 DRILL OTHR T Work pipe f/11103't/11193' 160 gpm 1100 psi 20 rpm 6-7K tq. Lost 12 bbls from 0:00 to 12:00 12:00 17:00 5.00 11,193 11,193 PROD1 DRILL OTHR T Phase III road conditions,work pipe f/11103t/11193'160 gpm 1100 psi, 20 rpm 6-7k tq. 17:00 17:45 0.75 11,193 11,194 PROD1 DRILL DDRL T Troughing f/11160't/11194'250gpm 2300 psi 60 rpm 6k tq. 17:45 21:30 3.75 11,194 11,204 PROD1 DRILL DDRL T Time drill f/11194't/11024',pump @ 250 gpm=2300 psi,60 rpms w/6K tq. 21:30 22:00 0.50 11,204 11,217 PROD1 DRILL DDRL T Drilled f/11204'U 11217'. Lost ledge and fell back into out hole. Page 18 of 41 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 11,217 11,223 PROD1 DRILL DDRL T Time drill f/11216't/11223'. Pump @ 250 gpm=2300 psi, 100 rpms w/ 6-7K tq. P/U= 106K,S/O=76K, Rot 96K.ADT=2.73,Jar hrs=62.62, Bit hrs=2.73. Lost 29.5 bbls from 12:00 to 24:00, 41.5 bbls lost in 24 hours. 01/16/2013 Directional drilled f/11223'to 12216'TVD-3587',footage drilled-993'.ADT=13.56 hrs 00:00 07:30 7.50 11,223 11,364 PROD1 DRILL DDRL T Drill f/11223't/11364'TVD-3568' ART-4.99 ADT-4.99 Jar hrs-68.57, Bit hrs-8.68 P/U=138K S/0=58K ROT=91K, 120 RPM Tq 7.5 K ECD- 10.88 WOB 5-10K 250 GPM. 07:30 12:00 4.50 11,364 11,507 PROD1 DRILL DDRL P Drill f/11364't/11507'TVD-3565' ADT-2.60 HRS Jar hrs-70.30 Bit hrs-10.41 P/U=91K S/O=55K ROT=9K Tq=8 K ECD-11.1 WOB- 7-10K 270 GPM. 12:00 18:00 6.00 11,507 12,029 PROD1 DRILL DDRL P Drill f/11507't/12029'TVD-3587' ADT-3.90 Jar hrs-74.20 Bit hrs-14.31 P/U=155K S/0=54K ROT=91K Tq=8K ECD-11.4 270 GPM.Obtain SPR 18:00 00:00 6.00 12,029 12,216 PROD1 DRILL DDRL P Drill f/12029'to 12216'.TVD-3583', ADT-2.94 Jar hrs-77.14 Bit hrs- 17.25, P/U= 147K,S/O=59K, ROT=92K. Tq=7.5K ECD-11.28, Flow=54%WOB 5-15K,270 GPM. Increase lubes in Versa Pro MOBM to 1% 01/17/2013 Directional Drilled f/12216'to TD @ 12700' TVD-3599'.CBU x 3 @ 270 gpm 80 rpm. BROOH f/12700'to 7120',pump @ 270 gpm=2650 psi w/80 rpms.C/O handling equipment. Lost 24 bbls of MOBM last 24 hrs. 00:00 11:00 11.00 12,216 12,700 PROD1 DRILL DDRL P Drill f/12216't/12700'3599'TVD ADT-7.59 TOTAL JAR HRS 84.73 BIT HRS 24.84 PUW-150 SOW-60 ROT WT-95 TQ 8K ECD-11.30 WOB 3-5K 120 RPM 270 GPM 11:00 15:15 4.25 12,700 12,700 COMPZ CASING CIRC P CBU X 3 @ 270 gpm 2600 psi 120 RPM 8K tq 15:15 23:30 8.25 12,700 7,120 COMPZ CASING REAM P BROOH f/12700'to 7120' 270 gpm 2650 psi 80 RPM 23:30 00:00 0.50 7,120 7,120 COMPZ CASING PULD P Lay down Well Commander and 1 joint of 5"drill pipe.Change out to 4" handling equipment.Actual displacement=57.09 bbls, Calculated displacement=48.35 bbls 01/18/2013 POOH f/7120'U 5657', CBU x 3 @ 5657'slip&cut drill line, P/U well commander RIH U 12700',CBU x 3, drop ball open well commander circ.casing clean 200%increase in cuttings @ bottoms up,displace well U EMS 6800 9.8 ppg,OWFF static.Attempt to POOH on elevators,swabbing. POOH w/pump @ 2 bpm no rotary. 00:00 00:15 0.25 7,120 7,120 PROD1 CASING OWFF P Observe well for flow static,change over handling equip. 00:15 01:30 1.25 7,120 5,657 PROD1 CASING TRIP P Pooh w/4"on elevators,t/5657 01:30 04:15 2.75 5,657 5,657 PROD1 CASING CIRC P CBU x 3 @ 270 GPM 2100 psi,40 RPM 3k tq,reciprocate pipe. Page 19 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 5,657 5,657 PROD1 CASING SFTY P Pre Job Safety Meeting on slip&cut drill line. 04:30 06:00 1.50 5,657 5,657 PROD1 CASING SLPC P Slip&cut drill line 97',service top drive&drawworks 06:00 06:15 0.25 5,657 5,657 PROD1 CASING SFTY P Pre Job Safety Meeting on P/U well commander&TIH 06:15 12:00 5.75 5,657 12,700 PROD1 CASING TRIP P RIH f/5657't/12700'filling pipe every 20 stands.Tight spot @ 11705'work through spot without pumps. 12:00 16:45 4.75 12,700 12,700 PROD1 CASING CIRC P CBU x 3 @ 270 gpm 2560 psi&80 RPM reciprocate pipe. 16:45 17:00 0.25 12,700 12,700 COMPZ CASING SFTY P Pre Job Safety Meeting on displacing well to SFMOBM. 17:00 18:00 1.00 12,700 12,700 COMPZ CASING CIRC P Continue to circ.empty pits prep for displacement. 18:00 21:00 3.00 12,700 12,700 COMPZ CASING DISP P Displace 9.6 ppg MOBM out of hole w/9.8 ppg SFMOBM(EMS 6800) as per plan,drop ball&open well commander finish displacement, drop ball&close well commander. Pump @ 270 gpm=2600 psi stage pump rate down to 190 gpm=2000 psi as ECD dictated. Pumped @ 500 gpm=950 psi with Well Commander open. 21:00 21:30 0.50 12,700 12,700 COMPZ CASING OWFF P Establish slow pump rates, blow down TD, Flow check well static. 21:30 22:00 0.50 12,700 12,650 COMPZ CASINGSVRG P Service rig. 22:00 23:15 1.25 12,650 12,650 COMPZ CASING CIRC P Establish circulation,pump @ 2 bpm=750 psi w/30 rpms. Prep mud pits to POOH and move Vac trucks around. 23:15 00:00 0.75 12,650 12,650 COMPZ CASING OWFF P Blow down top drive and monitor well,static. 01/19/2013 Drop 2.25 rabbit,OWFF, POOH f/12650'to 9800'w/pumps @ 84 gpm ,no rotary.Cont. POOH on elevators to 5657',OWFF @ shoe,pump slug, Download&UD BHA,Clear floor R/U&Run 4.5 liner as per completion. 00:00 00:15 0.25 12,650 12,650 COMPZ CASING OTHR P Drop 2.25 OD rabbit, monitor well static,SPR's 00:15 08:30 8.25 12,650 7,120 COMPZ CASING TRIP P POOH f/12650't/7120'w/pumps @ 84 gpm 700 psi. 08:30 09:00 0.50 7,120 7,120 COMPZ CASING PULD P UD commander sub and ball catcher 09:00 10:00 1.00 7,120 5,657 COMPZ CASING TRIP P Continue POOH f/7120't/5657 10:00 11:15 1.25 5,657 5,657 COMPZ CASING OWFF P Monitor well for flow static, pump slug, BD top drive 11:15 13:15 2.00 5,657 373 COMPZ CASING TRIP P POOH f/5657't/373'Actual displacement=119 bbls,Calculated displacement=95 bbls. 13:15 13:30 0.25 373 373 COMPZ CASING OWFF P Observe well for flow static 13:30 16:30 3.00 373 0 COMPZ CASING PULD P Stand back&UD BHA, Download MWD,break bit, UD BHA. Page 20 of 41 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 21:00 4.50 0 0 COMPZ CASING RURD P Clean&clear rig floor P/U tools and equipment f/liner run,M/U slim hole MWD&Rill to run 4.5 liner completion. 21:00 21:15 0.25 0 0 COMPZ CASING SFTY P Pre Job Safety Meeting on running 4.5 liner. 21:15 21:30 0.25 0 0 COMPZ CASING SFTY P Hold safety stand down on pressure washer leg laceration. Discuss what factors may have caused this incident and how we as a rig team mitigate these issues.Go over CPAI pressure washer policy. 21:30 00:00 2.50 0 1,764 COMPZ CASING PUTB P Run 4-1/2"11.6 ppf L-80 liner as per detail to 1764'. 01/20/2013 RIH w/4.5 liner t/12700'tag TD P/U orient hanger,drop ball release f/liner shoe @ 12633'liner top @ 5125', Disp.well t/9.6 ppg MOBM, POOH w/liner running tool on 5"DP. UD running tool and MWD. R/U to run Whipstock. 00:00 06:30 6.50 1,764 7,456 COMPZ CASING PUTB P Continue RIH w/4.5 slotted liner t/ 7456' 06:30 09:00 2.50 7,456 7,456 COMPZ CASING PUTB P M/U liner hanger&slim hole MWD& seal bore,C/O Elevators 09:00 09:45 0.75 7,456 7,600 COMPZ CASING OTHR P RIH t/7600',shallow pulse test MWD,Obtain T&D Values 20 rpm 2800 TQ 09:45 14:45 5.00 7,600 12,700 COMPZ CASING RUNL P RIH w/liner on 5"DP F/7600 U 12700'Tag BTM.Actual displacement=78.1 bbls,Calculated displacement=77.7 bbls P/U=145K, S/O=60K 14:45 16:30 1.75 12,700 5,025 COMPZ CASING PACK P P/U UD 2 jts DP M/U TD 126 gpm orient lug t/17°L, Drop ball pressure up on liner hanger,slack off engage dogs,pressure up t/3600 psi release running tool,bleed off tool verify tool is released, Pressure test Ann.t/ 2500 psi f/10 min.good test. Liner shoe @ 12633'.After releasing P/U= 110K,S/O=85K 16:30 16:45 0.25 5,025 5,025 COMPZ CASING SFTY P Pre Job Safety Meeting on displacing well to MOBM 16:45 18:00 1.25 5,025 5,025 COMPZ CASING CIRC P Displace well U MOBM @ 210 gpm 300 psi,Obtain SPR's 18:00 18:15 0.25 5,025 5,025 COMPZ WHPST OTHR P Blow down TD, OWFF well static. 18:15 21:15 3.00 5,025 104 COMPZ WHPST TRIP P POOH w/liner running tool on 5"DP f/5025'U 104'.Actual displacement= 48.11 bbls,Calculated displacement=42.92 bbls 21:15 23:00 1.75 104 0 COMPZ WHPST PULD P UD BHA. Pick up power tongs and UD MWD tools. 23:00 23:30 0.50 0 0 COMPZ WHPST OTHR P Clean and clear rig floor. 23:30 00:00 0.50 0 COMPZ WHPST PULD P UD tools from rig floor. 01/21/2013 M/U Whip stock&anchor, RIH t/4903'Madd Pass f/4903't/4983',Orient whip stock,set anchor,shear whipstock,Mill window,TOW @ 5074'BOW @ 5091'amd 20'new hole to 5111'.CBU and perform FIT t/12.6 ppg EWM. Page 21 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 COMPZ WHPST OTHR P Clean&clear rig floor P/U BHA components f/next run. 02:00 07:45 5.75 0 270 COMPZ WHPST PULD P P/U&M/U Whipstock&milling assembly,Orient latch&MWD. 07:45 08:15 0.50 270 270 COMPZ WHPST CIRC P SHT MWD @ 414 gpm 800 psi 08:15 12:30 4.25 270 4,903 COMPZ WHPST TRIP P RIH w/whipstock&mill t/4903' 12:30 13:30 1.00 4,903 4,983 COMPZ WHPST OTHR P Madd pass f/4903't/4983'@ 130 FPH 400 gpm 1300 psi. P/U=115K, 5/0=85 13:30 14:45 1.25 4,983 5,139 COMPZ WHPST WPST P Orient whipstock while RIH,Orient t/ 15°L and land MLZXP anchor. P/U 15K over to verify anchor is latched. Shear out anchor,Apply 35K down weight to shear window mill. 14:45 15:00 0.25 5,139 5,074 COMPZ WHPST WPST P Obtain drilling perimeter 80 RPM 4k tq,pump @ 450 gpm=1600 psi. Install ditch magnets and close master valves on stack.Obtain SPR's 15:00 22:00 7.00 5,074 5,111 PROD2 WHPST WPST P Mill window f/5074'TOW to BOW @ 5091'and 20'of new hole to 5111'@ 450 gpm= 1600 psi,WOB=6-10K. Pumped super sweep @ 5085', observed 100%increase in mill cuttings with sweep. Pumped a 2nd super sweep @ 5095',observed a 75%increase in mill cuttings with sweep. 22:00 22:30 0.50 5,111 5,111 PROD2 WHPST OTHR P Work mill through window several times,good window no drag or overpull observed. P/U=111K,S/O= 84K 22:30 23:00 0.50 5,111 5,074 PROD2 WHPST CIRC P Circulate hole clean @ TOW 5074' for FIT. 23:00 23:15 0.25 5,074 5,074 PROD2 WHPST OTHR P Stand back one stand and blow down top drive for FIT. 23:15 00:00 0.75 5,074 5,074 PROD2 DRILL FIT P Rig up and perform FIT t/12.6 ppg EWM.Record test on chart recorder. 01/22/2013 POOH w/Milling Assy. L/D, P/U Scraper/Magnet BHA RIH t/5111', POOH, LID BHA, Drain&Flush stack, Change out lower IBOP valve and saver sub, R/U to Test BOP's. 00:00 00:30 0.50 5,074 5,074 PROD2 DRILL PULD P Obtain SPR's, Blow down lines, R/D test equipment, P/U handling tools f/ beaver slide 00:30 03:30 3.00 5,074 638 PROD2 DRILL TRIP P POOH w/milling Assy.F/5074't/ 638' 03:30 06:00 2.50 638 0 PROD2 DRILL PULD P Stand back&lay down BHA,Clean &Clear rig floor. 06:00 07:00 1.00 0 0 PROD2 DRILL OTHR P R/U&flush stack @ 600 gpm 150 PSI, R/D blow down lines. 07:00 08:30 1.50 0 113 PROD2 DRILL PULD P M/U scraper&magnet BHA t/113' 08:30 12:00 3.50 113 5,020 PROD2 DRILL TRIP P RIH w/Scraper BHA t/5020' 12:00 12:15 0.25 5,020 5,111 PROD2 DRILL WASH P Wash&ream f/5020 t/5111'@ 425 gpm 1550 psi slide through window, no drag. Page 22 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 13:15 1.00 5,111 5,071 PROD2 DRILL CIRC P Pump Hi-Vis sweep. 13:15 13:30 0.25 5,071 4,971 PROD2 DRILL OWFF P Monitor well and Blow down top drive. 13:30 15:00 1.50 4,971 665 PROD2 DRILL TRIP P PJSM,POOH from 4971'MD to BHA 15:00 16:00 1.00 665 0 PROD2 DRILL PULD P Rack back hwdp, DCs and UD BHA. 16:00 17:00 1.00 0 0 PROD2 DRILL PULD P UD and clean magnets,(Total of 160 #s of metal back) 17:00 18:00 1.00 0 0 PROD2 DRILL OTHR P Function test Rams and rerun magnets in stack. 18:00 18:15 0.25 0 0 PROD2 DRILL PULD P Clear and clean rig floor. 18:15 18:45 0.50 0 0 PROD2 DRILL OTHR P PJSM, Flush stack out with 750 gpm. 18:45 19:00 0.25 0 0 PROD2 DRILL OTHR P Lay down joint of dp and blow down Top Drive. 19:00 19:15 0.25 0 0 PROD2 DRILL SFTY P PJSM on changing out lower IBOP valve&saver sub. 19:15 22:00 2.75 0 0 PROD2 DRILL RGRP P Change out IBOP valve and saver sub. 22:00 22:45 0.75 0 0 PROD2 DRILL BOPE P PJSM, Pull wear ring and set test plug. 22:45 00:00 1.25 0 0 PROD2 DRILL BOPE P R/U to test BOPs, Fill stack with water. 01/23/2013 Test BOP's w/4"4.5"5"test jts t/250 low 3500 high, M/U Drilling BHA, RIH V 5093'Slip&Cut drill line, Drill Ahead f/5111't/5140' 00:00 06:45 6.75 0 0 PROD2 DRILL BOPE P Test BOP's,Choke valves 1-14, Upper lower&blind rams,Auto& man IBOP,TIW&Dart 4"&5",4" Demco, HCR&man choke&kill,w/ 4"4.5"&5"test jts V 250 low 3500 high,test ann.V 250 low 2500 high, Acc.test,Witness waived by Lou Grimaldi of AOGCC 06:45 08:00 1.25 0 0 PROD2 DRILL RURD P R/D test equipment, Blow down lines,set 9"ID wear ring. 08:00 09:00 1.00 0 0 PROD2 DRILL PULD P P/U BHA components V rig floor 09:00 13:15 4.25 0 373 PROD2 DRILL PULD P P/U Drilling BHA as per Sperry, Upload MWD,SHT w/275 gpm 1400 psi, Break in seals on Geo pilot 13:15 16:00 2.75 373 5,093 PROD2 DRILL TRIP P RIH w/drilling BHA f/373 t/5093' Filling pipe every 20 stands. 16:00 16:30 0.50 5,093 5,093 PROD2 DRILL OTHR P Blow Down top drive, inspect drilling line. 16:30 16:45 0.25 5,093 5,093 PROD2 DRILL SFTY P Pre Job Safety Meeting on slipping& cutting drill line. 16:45 18:00 1.25 5,093 5,093 PROD2 DRILL SLPC P Slip&cut drill line 85' 18:00 18:45 0.75 5,093 5,093 PROD2 DRILL SVRG P Service rig and TD 18:45 00:00 5.25 5,093 5,140 PROD2 DRILL DDRL P Drill New hole f/5111't/5140' TVD-3438',ADT-1.89,JAR HRS-120.06, BIT HRS-1.89,PU W-93,SOW-75,ROT WT-91,TQ ON 3-4K, ECD-9.79,WOB-5-15K,250 GPM 1900PSI Page 23 of 41 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01/24/2013 24 hr Summary Drill f/5140't/6534'Observe Micro dogleg on ABI consult town decsion made to side track@ 6314' 00:00 06:00 6.00 5,140 5,463 PROD2 DRILL DDRL P Drill New hole f/5140't/5463 TVD-3451',ADT-4.84,JAR HRS-124.90, BIT HRS-4.84, PUW-95,SOW-71, ROT WT-82,TQ ON 3K, ECD-9.87,WOB-5-10K,264 GPM 1975 PSI. 06:00 12:00 6.00 5,463 5,742 PROD2 DRILL DDRL P Drill New hole f/5463't/5742' TVD-3454',ADT-2.66,JAR HRS-127.56, BIT HRS-9.39, PUW-95,SOW-71, ROT WT-82,TQ ON 3K, ECD-9.97,WOB-5-10K,264 GPM 2035 PSI. 12:00 18:00 6.00 5,742 6,287 PROD2 DRILL DDRL P Drilling New Hole f/5742't/6287' TVD-3476',ADT-4.13,JAR HRS-131.69 BIT HRS-13.52, PUW-100, SOW-71, ROT WT-84, TQ ON 3.5K,OFF 3K,ECD-10.21, WOB 4-10K, 120 RPM,264 GPM 18:00 23:15 5.25 6,287 6,534 PROD2 DRILL DDRL P Drilling New Hole f/6287't/6534' ND-3453',ADT-3.34,JAR HRS-135.03, BIT HRS-16.86, PUW-101,SOW-85, ROT WT-84,TQ ON-4-5K OFF-3K, ECD-10.19, WOB-6-10K, 120 RPM,264 GPM 2100PSI 23:15 00:00 0.75 6,534 6,534 PROD2 DRILL OTHR P Stand Bye wait on geologist and DD Micro dogleg observed on ABI, Discus options with town. 01/25/2013 Pull up U 6314'trough and side track well,drill t/6482'high dog leg observed, POOH t/6205'trough and side track well @ 6220'Drill ahead U 6385' 00:00 00:30 0.50 6,534 6,534 PROD2 DRILL CIRC T Circ.&reciprocate pipe,geology& direction pick a side track depth. 00:30 01:45 1.25 6,534 6,314 PROD2 DRILL REAM T BROOH U 6290'cut trough U 6314' 100 rpm 250 gpm 01:45 10:00 8.25 6,314 6,338 PROD2 DRILL DDRL T Sidetrack f/6314't/6337'slipped into old hole,pick back up U 6314' time drill f/6314'U 6338'kicked off. 10:00 12:00 2.00 6,338 6,482 PROD2 DRILL DDRL T Drill f/6338'U 6482' TVD-3462',PUW-105,SOW-73, ROT WT-86,TQ ON-4 OFF-3.5, WOB-5-10K,ADT-1.39, ECD-10.08 JAR HRS-141.42 12:00 12:45 0.75 6,482 6,534 PROD2 DRILL DDRL T Drill f/6482'U 6534'ND-3460' ADT-.16,PUW-106, SOW-74, ROT WT-88,TQ-4,WOB-5-10K, 12:45 14:30 1.75 6,534 6,586 PROD2 DRILL DDRL P Drill f/6534'U 6586'TVD-3461'ADT- .76 Observe dogleg attepmt t/ream out dogleg to high. Discuss w/town geology. 14:30 15:00 0.50 6,586 6,205 PROD2 DRILL TRIP T POOH U 6205'for side track due to high dogleg. 15:00 16:00 1.00 6,205 6,220 PROD2 DRILL DDRL T Trough f/6205'U 6220'265 gpm 2000 psi 120 rpm Page 24 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:30 2.50 6,220 6,232 PROD2 DRILL DDRL T Time Drill side track f/6220't/6232', 3473'-TVD,265 gpm,2000 psi, 120 rpm,TQ-4k 18:30 00:00 5.50 6,232 6,385 PROD2 DRILL DDRL T Drill f/6232't/6385'TVD-3580', ADT-6.84, BIT HRS-31.22,JARS HRS-148.26, PUW-105,SOW-74, ROT WT-85,TQ-4K, ECD-9.83, WOB-10K, 120 RPM,268 GPM, 2075 PSI 01/26/2013 Drill f/6385't/7326',Change out leaky swivel packing. 00:00 06:00 6.00 6,385 6,485 PROD2 DRILL DDRL T Drill f/6385't/6485'TVD-3591', ADT-2.71,JAR HRS-151,56 BIT HRS-33.39, PUW-105, SOW-74, ROT WT-85,TQ-4, ECD-10.01,WOB 5-10K, RPM 80-120,264 GPM 06:00 09:00 3.00 6,485 6,586 PROD2 DRILL DDRL T Drill F/6485'T/6586'TVD-3479', ADT-1.90,JAR HRS-154.51, BIT HRS-36.34, PUW-105,SOW,74, ROT WT-86,TQ-4, ECD-10.18, WOB 5-15, 100 RPM,220 GPM 09:00 12:00 3.00 6,586 6,668 PROD2 DRILL DDRL P Drill f/6586't/6668'3479'TVD,ADT- 1.05,JAR HRS-, BIT HRS-, PUW-105,SOW-74, ROT WT-87, TQ-4, ECD-10.05,WOB 5-10, 100 RPM,220 GPM 12:00 18:00 6.00 6,668 7,079 PROD2 DRILL DDRL P Drill f/6668't/7079'3472',ADT-4.28, JAR HRS-158.79 BIT HRS-40.62, PUW-110,SOW-72, ROT WT-90, TQ-4, ECD-10.25,WOB-5,60 RPM, 230 GPM 1650 PSI 18:00 23:15 5.25 7,079 7,326 PROD2 DRILL DDRL P Drill f/7079't/7326'TVD-3477', ADT-1.89,JAR HRS-160.68, BIT HRS-42.51,PUW-110,SOW-73, ROT WT-90,TQ-4, ECD-10.37, WOB 2-4K, RPM-100,250 GPM, 2000 PSI 23:15 00:00 0.75 7,326 7,326 PROD2 DRILL RGRP P Change out swivel packing. 01/27/2013 Drill t/7342'Observe dogleg, P/U t/7250'trough t/7280 side track&time drill t/7295'Drill ahead U 7780' CBU,OWFF, BROOH t/shoe,CBU RIH w/remaining 4"dp U 5186' 00:00 00:30 0.50 7,326 7,342 PROD2 DRILL DDRL P Drill f/7326't/7342'TVD-3475', ADT-.37, PUW-110,SOW-73, ROTWT-90,TQ-4K, ECD-10.37,JAR HRS-161.05, BIT HRS-42.88. Observe Dog leg stop drilling. 00:30 01:00 0.50 7,342 7,242 PROD2 DRILL DDRL T Circ&reciprocte pipe wait on DD& Geologist to pick sidetrack depth. 01:00 03:00 2.00 7,242 7,250 PROD2 DRILL DDRL T Pull up t/7250'start troughing t/ 7280',220 gpm 80 rpm,tq-4k 03:00 05:30 2.50 7,250 7,295 PROD2 DRILL DDRL T Side track&time drill f/7280'U 7295'220 gpm 80 rpm 05:30 06:30 1.00 7,295 7,342 PROD2 DRILL DDRL T Drill f/7295't/7342'ADT-.85, PUW-110,SOW-71, ROTWT-90 Page 25 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 12:00 5.50 7,342 7,502 PROD2 DRILL DDRL P Drill f/7342'U 7502'3478'ND, PUW-110,SOW-71, ROTWT-91, WOB 5-10, ECD-10.13,JAR HRS- 167.40, BIT HRS-49.23 12:00 16:00 4.00 7,502 7,780 PROD2 DRILL DDRL P Drill f/7502't/7780'3475'ND, ADT-1.93,JAR HRS-169.33, BIT HRS-51.16, PUW-118,SOW-72, ROTWT-90,TQ-5K, ECD-10.32, WOB-12,50 RPM 225 GPM 1950 PSI 16:00 16:45 0.75 7,780 7,780 PROD2 DRILL CIRC P Circ sweep around,slight increase on sweep to surface.Mointor well static. 16:45 21:45 5.00 7,780 5,070 PROD2 DRILL REAM P BROOH U casing shoe @ 5074'U 4" X-Over. 21:45 22:45 1.00 5,070 5,070 PROD2 DRILL CIRC P CBU @ 264 gpm 1960 psi 20 rpm, blow down TD observe well for flow 22:45 00:00 1.25 5,070 5,186 PROD2 DRILL TRIP P RIH w/first stand of drill pipe observe 3-4k drag through window,work through tight spot @ 5136'10k drag U 5186' 01/28/2013 Continue RIH U 6485'work through tight spot WI pumps&rotation,continue RIH U 7780'Drill New Hole U 8953' 00:00 02:15 2.25 5,186 7,741 PROD2 DRILL TRIP P Continue trip in the hole U 6485'take wt.work pipe,M/U TD establish circ. pump up survey,Wash through tight spot 60 rpm 220 gpm,continue RIH U 7741'no othe hole issues. 02:15 03:15 1.00 7,741 7,780 PROD2 DRILL WASH P M/U well commander and first stand of DP,Wash U 7780',60 rpm 225 gpm 1550 psi 03:15 12:00 8.75 7,780 8,246 PROD2 DRILL DDRL P Drill f/7780't/8246'TVD-3456', ADT-3.72,JAR HRS-164.77, BIT HRS-54.88, PUW-106,SOW-60, ROT WT-83,TQ-5K, ECD-10.28, WOB 5-15, RPM-80,225 GPM 12:00 18:00 6.00 8,246 8,583 PROD2 DRILL DDRL P Drill f/8246'U 8583'ND-3438' ADT-3.54,JAR HR-176.59,BIT HRS-58.42, PUW-115,SOW-60, ROT WT-88,TQ-5K, ECD-10.54, WOB-15K, 120 RPM,270 GPM, 2550 PSI 18:00 00:00 6.00 8,583 8,953 PROD2 DRILL DDRL P Drill f/8583't/8953'TVD-3447', ADT-3.15,JAR HRS-179.74, BIT HRS-61.57, PUW-114,SOW-64, ROTWT-85,TQ-5K, ECD-10.66, WOB-7-8K, 120 RPM 269 GPM 2575 PSI 01/29/2013 Directional Drilling as per-Geologist F/8,953'T/10,529'TVD=3467' 00:00 06:00 6.00 8,953 9,361 PROD2 DRILL DDRL P Drill f/8553'U 9361'ND-3457', ADT-3.49,Jar hrs-183.23, BIT HRS-65.06, PUW-114,SOW-65, ROTWT-87,TQ-5K, ECD-10.73, WOB-5-10K, 120 RPM 269 GPM 2550 PSI Page 26 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 9,361 9,775 PROD2 DRILL DDRL P Drill f/9361't/9775'TVD-3438', ADT-3.43,Jar hrs-186.66, BIT HRS-68.49,PUW-121,SOW-60, ROTVVT-90,TQ-5K, ECD-10.88, WOB-5-10K, 120 RPM 270 GPM 2575 PSI 12:00 18:00 6.00 9,775 10,198 PROD2 DRILL DDRL P Drill f/9775't/10,198'TVD-3461', ADT-3.74,Jar hrs-190.40, BIT HRS-72.23, PUW-132,SOW-60, ROTWT-85,TQ-6K, ECD-10.80, WOB-9K, 120 RPM 260 GPM 2475 PSI 18:00 00:00 6.00 10,198 10,529 PROD2 DRILL DDRL P Drill f/10,198't/10,529'TVD-3467', ADT-2.55,Jar hrs-192.95, BIT HRS-74.78, PUW-130,SOW-62, ROTWT-91,TQ-6K,TQ off-5K, ECD-10.94,WOB-7K, 120 RPM 256 GPM 2425 PSI 01/30/2013 Directional Drilling as per-Geologist F/10,529'T/11,960'TVD=3535' 00:00 06:00 6.00 10,529 11,016 PROD2 DRILL DDRL P Drill f/10,529't/11,016'TVD-3491', ADT-3.55,Jar hrs-196.50, BIT HRS-78.33, PUW-153,SOW-45, ROTWT-91,TQ-6.5K,TQ off-6K, ECD-10.95,WOB-5-10K, 120 RPM 260 GPM 2550 PSI 06:00 12:00 6.00 11,016 11,429 PROD2 DRILL DDRL P Drill f/11,016't/11,429'TVD-3409', ADT-3.05,Jar hrs-199.55, BIT HRS-81.38, PUW-153,SOW-45, ROTWT-90,TQ-6.5K,TQ off-6K, ECD-11.15,WOB-5-12K, 120 RPM 260 GPM 2575 PSI,(Total loss= 23,2 bbls) 12:00 18:00 6.00 11,429 11,754 PROD2 DRILL DDRL P Drill f/11,429't/11,754'TVD-3519', ADT-2.86,Jar hrs-202.41, BIT HRS-84.24, PUW-150,SOW-52, ROTWT-94,TQ-7K,TQ off-6.5K, ECD-11.17,WOB-5-12K, 120 RPM 260 GPM 2625 PSI, 18:00 00:00 6.00 11,754 11,960 PROD2 DRILL DDRL P Drill f/11,754't/11,960'TVD-3535', ADT-3.70,Jar hrs-206.11, BIT HRS-87.94, PUW-165,SOW-52, ROTWT-90,TQ-7K,TQ off-6.5K, ECD-11.08,WOB-5-10K, 120 RPM 260 GPM 2550 PSI,(Total loss= 51.0 bbls) 01/31/2013 Directional drill F/11,960'T/12,714'MD and TD,TVD=3555',CBU X 3,Monitor well and back ream to 4"dp, UD circ sub and change over saver sub to 4"continue back reaming to the window with 4"dp. 00:00 06:00 6.00 11,960 12,145 PROD2 DRILL DDRL P Drill f/11,960'V 12,145'TVD-3539', ART-3.19,Jar hrs-209.30, BIT HRS-91.13, PUW 170,SOW-42, ROTWT-92,TQ-8K,TO off-7K, ECD-11.08,WOB-5-15K, 120 RPM 260 GPM 2500 PSI Page 27 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 12,145 12,475 PROD2 DRILL DDRL P Drill f/12,145'U 12,475'ND-3549', ART-3.41,Jar hrs-212.71, BIT HRS-94.54, PUW-160,SOW-50, ROTWT-90,TQ-8K,TQ off-7K, ECD-11.13,WOB-5-10K, 120 RPM 260 GPM 2600 PSI(Total losses= 32 bbls) 12:00 15:30 3.50 12,475 12,714 PROD2 DRILL DDRL P Drill f/12,475'U 12,714 ND-3555', ART-2.39,Jar hrs-215.10, BIT HRS-96.93, PUW-160,SOW-48, ROTWT-91,TQ-7.5K,TQ off-7K, ECD-11.15,WOB-12-15K, 120 RPM 260 GPM 2425 PSI 15:30 17:00 1.50 12,714 12,714 COMPZ DRILL CIRC P TD well @ 12,714'MD,CBU with 250 gpm 2450 psi, Rotate&reciprocate 50'with 120 RPM. 17:00 17:30 0.50 12,714 12,660 COMPZ DRILL CIRC P Obtain SPR's @ 12,714',TVD=3555' with 9.6 ppg, P/U=156K,S/0=50K, Rot=92K,back ream stand out to 12,660' 17:30 20:30 3.00 12,660 12,475 COMPZ DRILL CIRC P CBU X 2 with same parameters and rack back one stand every BU to 12,475 20:30 21:00 0.50 12,475 12,475 COMPZ DRILL OWFF P Monitor well(static) 21:00 00:00 3.00 12,475 10,624 COMPZ DRILL REAM P Backream F/12,475'T/10,624'with 120 RPM,250 gpm,at 40 FPM, P/U=142K,SIO=57K, Rot=91K, TQ=7K.Calc=15 bbls,Act=19.5 bbls.(Total losses=31.32 bbls) 02/01/2013 Finish changing saver sub to XT-39, BROOH with 4'dp to bottom of window at 5374'and pull up into window, no issues, RIH to 5373'and CBU X 3,Monitor well and pull up to 4997',Slip&cut drilling line,Change saver sub back to 4-1/2 IF and RIH to 7074'MD. 00:00 03:45 3.75 10,624 7,745 COMPZ DRILL REAM P PJSM,Continue to BROOH F/ 10,624'T/7,745',260 gpm,2300 psi, 120 RPM,Tq=5K, P/U=105K,S/0= 60K. 03:45 04:00 0.25 7,745 7,745 COMPZ DRILL OWFF P Monitor well(Static) 04:00 07:30 3.50 7,745 7,745 COMPZ DRILL OTHR P PJSM, C/O saver sub,Grabber,jaws and bell guide, Monitor wwell via trip tank. 07:30 12:00 4.50 7,745 5,090 COMPZ DRILL REAM P Continue BROOH w/260 gpm,2200 psi, 120 RPM, F/7,745'T/5,373', Pull BHA through window with out rotation to 5090'Fill for trip=Calc= 36.9 bbls,Act=58.83 bbls. 12:00 12:15 0.25 5,090 5,070 COMPZ DRILL REAM P Continue to pull bit through window F/5,090'T/5,070',saw no drag P/U= 95K,S/0=70K 12:15 12:30 0.25 5,070 5,374 COMPZ DRILL TRIP P TIH F/5,070'T/5,374'Clear BHA from window 12:30 15:15 2.75 5,374 5,374 COMPZ DRILL CIRC P Break circ with 260 gpm, 1825 psi, P/U=95K,Rot=80K, S/0=67K, Pump 17 bbl 10.2 ppg Hi-Vis sweep, CBU X 3,saw 10%increase in cuttings. Rotate and reciprocate drill pipe Page 28 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 15:45 0.50 5,374 4,997 COMPZ DRILL OWFF P Monitor well(Static)pull one stand F/5,373'T/5,280'Observed fuid drop pull out to 4,997'MD, P/U=90K, S/O=71K. 15:45 16:15 0.50 4,997 4,997 COMPZ DRILL SLPC P Blow down Top Drive, Instal TIW& hange blocks 16:15 17:30 1.25 4,997 4,997 COMPZ DRILL SLPC P PJSM,Slip and cut 85'of drilling line. 17:30 17:45 0.25 4,997 4,997 COMPZ DRILL SVRG P Service Top Drive and Drawworks. 17:45 21:00 3.25 4,997 4,997 COMPZ DRILL OTHR P PJSM, Install TIW valve and C/O saversub F/XT-39 T/4-1/2 IF. 21:00 21:30 0.50 4,997 4,997 COMPZ DRILL OTHR P After action review, PJSM. 21:30 00:00 2.50 4,997 7,074 COMPZ DRILL TRIP P RIH F/4,997'T/7,074'fill every 20 stands&obtain S/O wts every 2 stands. Fill on trip in=Calc=11.88 bbls,Act=5.95 bbls 02/02/2013 Finish RIH to 12,714'MD with no issues,CBU,Open circ sub,CBU X 2,close circ sub&CBU, Displace to EMS 6800, POOH, L/D circ sub,C/O to 4"handling equip. POOH to 6505'Tight spot,drop down 2 stands and Circ 1000 stks and pull back up, not cuttings bed but concretion, ream out, Hung up for few minutes, P/U 10'5"pup,x-over and work free. 00:00 04:15 4.25 7,074 12,663 COMPZ DRILL TRIP P PSJM,RIH F/7,074'T/12,663'MD, Filling every 20 stds.Calc=45.66 bbls,Act=43.26 bbls. 04:15 04:30 0.25 12,663 12,714 COMPZ DRILL REAM P Wash&ream F/12,663'T/12,714' MD @ 250 gpm 2550 psi, 100 RPM, Tq=7K, P/U=100K, S/O=85K. 04:30 06:45 2.25 12,714 12,714 COMPZ DRILL CIRC P CBU @ 250 gpm,2550 psi, 100 RPM,Tq=7K, ECD= 11.35,till hole cleaned up. 06:45 07:00 0.25 12,714 12,714 COMPZ DRILL CIRC P Drop ball to open Well Commander, Pressured up to 1500,2000,and 2750 PSI and opened. 07:00 07:30 0.50 12,714 12,714 COMPZ DRILL CIRC P Circulate through Well Commander sub @ 4961'MD with 500 gpm,825 psi, 100 RPM,Tq=7 K. 07:30 08:30 1.00 12,714 12,663 COMPZ DRILL CIRC P Pull F/12,714'T/12,663'MD, CBU X 2 through well commander sub with same parameters. 08:30 08:45 0.25 12,663 12,663 COMPZ DRILL CIRC P Drop ball to close well commander sub, Pressured up to 1500,2000 and closed with 2800 psi. 08:45 09:00 0.25 12,663 12,714 COMPZ DRILL TRIP P RIH F/12663'T/12,714'MD. 09:00 11:15 2.25 12,714 12,714 COMPZ DRILL CIRC P CBU @ 250 gpm,2500 psi, 100 RPM,Tq=7 K, 11:15 12:00 0.75 12,714 12,714 COMPZ DRILL CIRC P PJSM, Displace well over to 9.8 ppg SFOBM as per well plan. 12:00 15:00 3.00 12,714 12,714 COMPZ DRILL CIRC P Continue displacing well over to SFOBM with 246 gpm,2100 psi, following schedule with EMS 6880 @ 2000'from surface,drop ball,ball on seat pressure up to 3800 psi,bleed off and pressure up in 500 psi increments to 4000 psi and open circ sub, Rot&Recip.string with 500 gpm,80 RPM with displacement. Page 29 of 41 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:00 15:30 0.50 12,714 12,660 COMPZ DRILL OWFF P Monitor well(Static)Observed fuild dropping in stack, Blow down and left circ sub in open position due to prior high pressure to open. 15:30 19:30 4.00 12,660 7,750 COMPZ DRILL TRIP P POOH with drilling assembly F/12, 660'T/7,750'MD 19:30 20:30 1.00 7,750 7,733 COMPZ DRILL PULD P UD Well Commander Sub&C/O handling equipment to 4",Monitor well(Static) 20:30 21:30 1.00 7,733 6,505 COMPZ DRILL TRIP P Continue POOH F/7,733'T/6505' MD,saw overpull of 30 K, P/U= 105K,S/O=60K,Cal 6.48 bbls, Act= 10.15 bbls. 21:30 22:15 0.75 6,505 6,695 COMPZ DRILL CIRC P RIH to 6695'and Make up Top Drive &brk circ.to check for cuttings bed, pumped 1000 stks and rotate and work pipe with 250 gpm,2150 psi, Rot=80K. 22:15 00:00 1.75 6,695 6,410 COMPZ DRILL TRIP P POOH F/6,695'T/6,505'pulled tight again at 6505', not a cuttings bed but concretion @ 6490'Kelly up and ream through tight spot 250 gpm, 2150 psi, 100 RPM, saw erratic torque 5-10K to 6,410'MD,shut down pumping and work stand up, had 40K over pull and no down wt, Hung up at 6410'and attempt to work tight spot no success, Rack back stand and kelly up to stump with 10'5"pup and x-over to 4"dp and worked free. 02/03/2013 Ream out tight spots, POOH with no other issues, UD BHA,M/U&RIH with whipstock retrieving tool,tagged up @ 4,675'packing off,POOH to make clean out run,P/U clean out BHA&RIH to 4,613',Wash and ream to 4,798'MD 00:00 01:15 1.25 6,410 6,410 COMPZ DRILL CIRC P PJSM, Break circ. @ 250 gpm,2100 psi,50 RPM,Tq=5K,work tight spots F/6410'T/6370'MD,CBU no cuttings observed over shakers. 01:15 02:30 1.25 6,410 4,995 COMPZ DRILL TRIP P POOH F/6,410'T/4,995'MD with no issues. 02:30 02:45 0.25 4,995 4,995 COMPZ DRILL OWFF P Monitor well(Static) 02:45 04:45 2.00 4,995 374 COMPZ DRILL TRIP P POOH F/4,995'T/374'MD Calc= 40.03 bbls,Act=51.45 bbls, 04:45 05:45 1.00 374 280 COMPZ DRILL PULD P Rack back 2 stds.of HW, UD 3 jts. Flex DCs. 05:45 06:45 1.00 280 280 COMPZ DRILL PULD P Down load MWD data 06:45 08:00 1.25 280 0 COMPZ DRILL PULD P UD BHA#10 08:00 08:15 0.25 0 0 COMPZ DRILL PULD P Clear and clean rig floor of BHA tools 08:15 08:45 0.50 0 0 COMPZ RPEQP1SVRG P Service rig 08:45 10:00 1.25 0 0 COMPZ RPEQP1PULD P PJSM,and M/U Baker whipstock retieving tool 10:00 10:15 0.25 0 451 COMPZ RPEQP1TRIP P RIH with 4 stds. HWdp from derrick Page 30 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 12:00 1.75 451 3,693 COMPZ RPEQP1TRIP P RIH with 5"dp F/451'T/3,693'MD, Calc=36.03 bbls,Act=41.65 bbls. Total losses= 13 bbls. 12:00 12:15 0.25 3,693 4,710 COMPZ RPEQP1TRIP P PJSM,continue RIH F/3,693'T/ 4,710'Taking inproper displacement, Circ port plugged, P/U=105K,SIO= 78K,Calc=7.5 bbls,Act=16.1 bbls. 12:15 13:45 1.50 4,710 4,710 COMPZ RPEQP1CIRC P Break Circ,saw pressure increase to 1500 psi,work std.&clear plug,circ 2 bpm 350 psi,work string with 25 RPM,slowly increase rate to 7.8 bpm with 1550 psi,work through cutting bed @ 4,675'saw 5K Tq and packing off,CBU. 13:45 14:15 0.50 4,710 4,618 COMPZ RPEQP1TRIP P Pull one std.to 4,618'and observe fluid drop in well, Blow down and monitor well(Static)Hold PJSM on POOH, P/U=110K,S/O=85K. 14:15 18:30 4.25 4,618 0 COMPZ RPEQP1TRIP P POOH F/4,618'to HWdp,Monitor well(Static)POOH and UD BHA. (Got back 22 lbs of metal debris on magnet) 18:30 19:15 0.75 0 0 COMPZ RPEQPI PULD P Clear and clean rig floor, P/U BOT subs for next run 19:15 22:30 3.25 0 4,613 COMPZ RPEQP1TRIP P PJSM,M/U Baker clean out BHA and RIH to 4,613' Calc=42.48 bbls, Act=42.1 bbls. 22:30 00:00 1.50 4,613 4,798 COMPZ RPEQP1CIRC P Break circ 8 bpm with 800 psi, P/U= 110K, SIO=85K, Rot=90K,40 RPM.wash and ream to 4,798' 02/04/2013 Wash&ream to 5094',CBU, POOH and UD clean out BHA,M/U whipstock retrieval tool and RIH, Pull whipstock,CBU thru choke, Monitor well, POOH UD whipstock BHA, R/U and test BOPE. (Lower IBOP valve and#5 choke valve failed) Witness of BOP test By AOGCC rep Jeff Jones. 00:00 01:15 1.25 4,798 5,104 COMPZ RPEQP1 REAM P PJSM,Wash and ream F/4,798'T/ 5094'MD, Shut down rotation& pump down to 5,104'MD,@ 8 BPM, 850 psi,40 RPM,Tq=4K. 01:15 02:00 0.75 5,104 4,950 COMPZ RPEQP1CIRC P CBU and work pipe F/4,986'T/ 4,950'MD @ 12 bpm, 1350 psi,40 RPM,Tq=4K,(No cutting observed @ BU) 02:00 02:15 0.25 4,950 4,950 COMPZ RPEQP1OWFF P Monitor well(Static) 02:15 04:15 2.00 4,950 445 COMPZ RPEQPI TRIP P POOH F/4,986'T/445'MD,Calc= 47.73 bbls,Act=54.95 bbls. 04:15 05:00 0.75 445 0 COMPZ RPEQP1TRIP P Rack back 4 stds of HWdp, UD clean out BHA. 05:00 05:45 0.75 0 0 COMPZ RPEQP1PULD P Clear and clean rig floor. 05:45 06:30 0.75 0 427 COMPZ RPEQP1 PULD P PJSM on whipstock retrieval tool and M/U BHA 06:30 07:45 1.25 427 5,079 COMPZ RPEQP1TRIP P RIH with retrieval tool F/427'T/ 5,079'MD, P/U=110K,S/O=85K, Calc=47.73 bbls,Act=49.0 bbls, Page 31 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:45 1.00 5,079 5,060 COMPZ RPEQP1CIRC P Brk Circ @ 2 bpm,300 psi,Shut down,could not latch up,turn pipe 1/4 turn right and work torque,still could not latch up,turn another 1/4 turn and work torque,Observed overpull, P/U to 175K and let jars bleed off, P/U to 175 slack off to 100K P/U to 175K and 200K no change,cock jars and P/U to 175K, observed jar fire and P/U to 200K no change,Cock jars and P/U to 175K jars fired,observed wt.drop off to 110K,Observed 15K overpull, whipstock free, P/U F/5,079'T/ 5,060'MD 08:45 10:30 1.75 5,060 5,060 COMPZ RPEQP1CIRC P Shut well in and circ through an open choke to make sure there was no trapped gas under the whipstock, CBU @ 3 bpm 530 psi. 10:30 11:00 0.50 5,060 5,060 COMPZ RPEQP1 OWFF P Monitor well, had slight flow. 11:00 11:30 0.50 5,060 5,060 COMPZ RPEQP1 TRIP P Rack back one stand and blow down Top Drive and choke 11:30 12:00 0.50 5,060 5,060 COMPZ RPEQP1OWFF P Decision made to monitor well, No flow,slight perking. 12:00 12:15 0.25 5,060 5,058 COMPZ RPEQP1TRIP P Pull up stand to 5058'and observe fluid dropping. 12:15 17:30 5.25 5,058 0 COMPZ RPEQP1TRIP P PJSM, POOH F/5,058'to the HWdp and drop 1.91"drift and monitor well, (Static)Continue POOH and UD retrieval BHA. 17:30 18:15 0.75 0 0 COMPZ RPEQP1 PULD P P/U on whipstock assembly inspect and scribe offset of mill walk to MLXZ anchor lug for the seal bore diverter. 18:15 18:30 0.25 0 0 COMPZ RPEQP1OWFF P Monitor well(Static)Close binds. 18:30 19:15 0.75 0 0 COMPZ RPEQP1PULD P Break&UD whip stock assembly. • 19:15 20:00 0.75 0 0 COMPZ RPEQP1PULD P Clear and clean floor, UDUD Baker subs and tools. 20:00 20:30 0.50 0 0 COMPZ RPEQP1OWFF P open Blinds and monitor well, (Static)Drain stack&pull wear ring. 20:30 21:15 0.75 0 0 COMPZ RPEQP1 BOPE P Install test plug with 5"test joint and rig up test equipment. 21:15 22:00 0.75 0 0 COMPZ RPEQP1BOPE P Test BOPE with 5"test joint to 250 low/3500 high and record on chart, Test witnessed by Jeff Jones, Test#1, Upper 3.5"x 6"VBR, Manual Kill valves&choke valves 1, 12, 13&14. Test#2, Upper IBOP valve,HCRkill &Choke valves 8&11. 22:00 23:00 1.00 0 0 COMPZ RPEQP1 BOPE P Chart recorded fail,C/O recorders and purge sensor 23:00 00:00 1.00 0 0 COMPZ RPEQP1 BOPE P Continue with test, had IBOP valve and Choke valve#5 failed. Page 32 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02/05/2013 24 hr Summary Continue testing GOP's. Observed Lower IBOP valve failed test. Changed out valve and retested. Performed Koomey test,observing initial 200 PSI obtained in 38 sec,and full 3000 PSI obtaines in 185 seconds.5 Nitrogen bottles with an avg PSI of 2000.Witness of test by AOGCC rep Jeff Jones. Held PJSM,and make up Seal Bore Diverter assembly.Orient and scribe to 13.2 deg offset for window.Make up MWD assembly and verify offset correction to 66.3 Deg.Trip in hole at 90 ft/min as per BOT rep.Set SBD anchor @ 18°L and release.OWFF,slight flow.CBU and condition mud. 00:00 05:15 5.25 0 0 COMPZ RPEQPI BOPE P Crew Change, Held PJSM.Continue testing BOP's.test Choke manifold and valves.Test all rig floor dafety valves and Dart valve.Test kill and choke manuals and HCR's,to 250 /3500 PSI including BOP stack rams and Annular to 250/2500 PSI, with 4 1/2"and 5"test joints.Test all H2S and LEL gas alarms. Performed Koomey test observing initial 200 PSI increase in 38 seconds,and full 3000 PSI obtained in 185 seconds. Observed 5 bottle nitrogen pressure averaged at 2000 PSI.Witness of test by AOGCC rep Jeff Jones. Observed lower IBOP valve failed during test. Record all tests on chart. 05:15 06:15 1.00 0 0 COMPZ RPEQPI BOPE P Rig down test equipment. Blow down choke manifold,choke and kill lines, and top drive. Install wear bushing. RILDS. 06:15 06:30 0.25 0 0 COMPZ RPEQP1SFTY P Held PJSM.Discuss safety and hazard recognition issues. Discuss procedure to rig up and change out lower IBOP valve. 06:30 08:45 2.25 0 0 COMPZ RPEQPI RGRP P Pull valve to floor. Remove old lower IBOP valve. Install new valve. 08:45 09:30 0.75 0 0 COMPZ RPEQP1 BOPE P Rig up test equipment,and test lower IBOP valve to 250/3500 PSI. Good test. Record test on chart. 09:30 10:00 0.50 0 0 COMPZ RPEQPI BOPE P Rig down test equipment and blow down Top drive, and lines. 10:00 10:30 0.50 0 0 COMPZ RPEQPI RURD P Pull tools to rig floor,and rig up tubing runinng equipment. 10:30 11:00 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew, BOT reps, MWD rep, and Mu engineer.Discuss safety and hazard recognition issues. Discuss procedure to make up Seal Bore Diverter assembly. 11:00 13:00 2.00 0 0 COMPZ RPEQPI PULD P Make up Baker Seal assembly and MLHR production Anchor assembly and Baker-Loc connections. Continue make up Seal Bore Diverter assembly with 3.563"DB-6 Nipple spaced out.Make up Running tools. Orient and scribe SBD anchor assembly to verify offset at 13.2 degrees.Work assembly in-out of hole and repeat calculation to verify offset correction. Page 33 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:30 1.50 0 0 COMPZ RPEQP1PULD P Make up Sperry Sun MWD assembly with Float sub.Orient SBD assembly to MWD verifying offset correction at 66.3 Degrees. Repeat. Pump down assembly to 300 GPM's -930 PSI verifying MWD.Continue pump to 330-400 GPM to verify SBD collet release of SBD.at 1500 PSI. Pick up to verify release with pumps on,good test. Re-engage collet assembly as per BOT rep. Verify engaged with straight pick up. 14:30 15:00 0.50 0 538 COMPZ RPEQP1PULD P Continue make up remaing BHA assembly of 4 stands of HWDP and bumper sub.Total BHA=538.16'. 15:00 19:45 4.75 538 5,164 COMPZ RPEQP1TRIP P Trip in hole with SBD assembly at 90 ft/min as per BOT rep.Observed proper displacement. 19:45 21:30 1.75 5,164 5,165 COMPZ RPEQP1 OTHR P Attempt to gain detection from MWD tools @ 225 gpm=1150 psi, increase pump rate to 270 gpm= 1350 psi,no detection.Shut down pump and RIH to 5090'P/U= 110K, S/O=85K. Bleed off pulsation dampener to 500 PSI,pump @ 290 gpm=1475 psi.Good detection, orient 45°L and slack off observed 10K drag upon entering liner top. SBD anchor lug on depth @ 5165'. P/U 75K to verify latch up. 21:30 22:00 0.50 5,165 5,165 COMPZ RPEQP1COND P Fill pit with mud and treat aired up mud. 22:00 22:30 0.50 5,165 4,900 COMPZ RPEQP1CIRC P Bring pump rate to 350 gpm=1700 psi,verify SBD set @ 18°L.Increase pump rate to 475 gpm=3000 psi and release running tool.Stand back one stand. 22:30 23:15 0.75 4,900 4,900 COMPZ RPEQP1OWFF P Blow down top drive and monitor well. Slight flow,air breaking out of the mud and surface. 23:15 00:00 0.75 4,900 4,900 COMPZ RPEQP1CIRC P Circulate and condition mud @ 7 bpm=1300 psi. 02/06/2013 Continue circulate bottoms up.Monitor well-static. POOH and lay down running tools for SBD assembly. Rig up and RIH w/4-1/2"slotted/blank liner to 7590'MD. Make up RAM and run 4-1/2"liner on drill pipe 11495'MD. 00:00 00:15 0.25 4,900 5,089 COMPZ RPEQP1CIRC P PJSM,Cont to circulate and condition mud @ 7 bpm=1300 psi. 00:15 02:30 2.25 5,089 5,089 COMPZ RPEQP1OWFF P Monitor well,slight flow from what appeared to be air breaking out of the mud.Wait until static. Blow down top drive. Page 34 of 41 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02:30 06:45 4.25 5,089 1,754 COMPZ RPEQPITRIP P POOH f/5089'to 4070'pumping @ 2 bpm=450 psi.Attempt to pull on elevators,swabbing.Cont to POOH w/pump @ 2 bpm=400 psi to 1754'. Actual displacement=32.9 bbls, Calculated displacement=28.08 bbls. 06:45 07:15 0.50 1,754 549 COMPZ RPEQP1TRIP P POOH on elevators to 549'.Actual displacement=20.65 bbls, Calculated displacement=18.08 bbls. 07:15 07:30 0.25 549 549 COMPZ RPEQP1OWFF P Monitor well,static. 07:30 08:30 1.00 549 0 COMPZ RPEQPI PULD P Stand back HWDP, lay down MWD tools and SBD running tool. 08:30 08:45 0.25 0 0 COMPZ RPEQPI OTHR P Clean and clear rig floor. 08:45 09:15 0.50 0 0 COMPZ RPEQPISVRG P Service rig. 09:15 10:30 1.25 0 0 COMPZ CASING RURD P Rig up to run 4-1/2"liner. Pick up tools and make up safety valve. 10:30 10:45 0.25 0 0 COMPZ CASING SFTY P Hold PJSM on running 4-1/2"liner. Discuss power tong safety and other hazards while picking up liner from the pipe skate. 10:45 21:00 10.25 0 7,590 COMPZ CASING PUTB P Pick up 4-1/2"11.6#L-80 liner and M/U RAM hanger as per detail to 7590'.Actual displacement=29.7 bbls,Calculated displacement= 29.92 bbls. 21:00 00:00 3.00 7,590 11,495 COMPZ CASING RUNL P Run 4-1/2"liner on 5"drill pipe f/ 7590'to 11495'. P/U=135K,S/O= 40K.Actual displacement=31.85 bbls,Calculated displacement= 32.93 bbls. 02/07/2013 Cont to run 4-1/2"liner on drill pipe to 12655.46'.Latched in RAM hanger and released from liner. Liner shoe @ 12656',top of RAM @ 5062'.CBU and POOH with running tool. UD running tool and make up LEM and packer assy. RIH w/LEM and packer, place tool face @ 90°R and latch LEM,tool face came around to 6° R. Release and test IA V 3000 psi.CBU and POOH w/running tool. 00:00 02:00 2.00 11,495 12,610 COMPZ CASING RUNL P Cont. running 4-1/2"liner on drill pipe to 12610'.Actual displacement= 12.25 bbls,Calculated displacement=11.7 bbls. 02:00 03:30 1.50 12,610 12,656 COMPZ CASING OTHR P Establish circulation @ 4 bpm=910 psi. P/U=105k,S/0=85K without liner. P/U= 146K,S/0=60K. Run in and latch RAM hanger,pull 10K overpull to ensure RAM is latched. Drop ball and release from liner. Blow ball seat @ 4300 psi. Pick up 74' and slack off to tag mother bore @ 5090'. Pull inner string out of liner as per Baker rep. 03:30 04:30 1.00 12,656 5,090 COMPZ RPEQPICIRC P Circulate and condition mud,pump surface to surface @ 6 bpm=725 psi. Pump heated SF MOBM around to increase temp to 62°. Page 35 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:30 1.00 5,090 5,090 COMPZ RPEQPI OWFF P Monitor well,slight flow then became static. 05:30 06:45 1.25 5,090 4,040 COMPZ RPEQP1TRIP P POOH w/pump @ 2 bpm=275 psi f/ 5090'to 4040'.Actual displacement= 9.1 bbls,Calculated displacement= 7.8 bbls. 06:45 08:45 2.00 4,040 475 COMPZ RPEQPI TRIP P POOH on elevators f/4040'to 475'. Actual displacement=45.5 bbls, Calculated displacement=38.03 bbls. 08:45 09:00 0.25 475 475 COMPZ RPEQP1 OWFF P Monitor well,static. 09:00 10:00 1.00 475 0 COMPZ RPEQPI PULD P Stand back HWDP and lay down running tool as per Baker rep. 10:00 11:00 1.00 0 0 COMPZ RPEQPI OTHR P Clean and clear rig floor. 11:00 12:45 1.75 0 0 COMPZ RPEQPI RURD P Rig up to run LEM,M/U MWD and stage in pipe shed. 12:45 16:00 3.25 0 0 COMPZ RPEQP1 PULD P PJSM,Make up LEM and packer assy as per Baker rep. M/U and orient MWD with cup assy to LEM. 16:00 17:00 1.00 0 245 COMPZ RPEQPI PULD P Make up bumper sub and 1 stand of HWDP and RIH to 245'.Shallow hole test MWD tools @ 115 gpm=650 psi,good. 17:00 19:45 2.75 245 4,973 COMPZ RPEQPI TRIP P Run LEM/Packer assy in the hole to 4973'.Actual displacement=43.39 bbls,Calculated displacement= 44.07 bbls. 19:45 20:45 1.00 4,973 5,089 COMPZ RPEQPI PACK P Establish circulation, P/U=110K, S/O=84K. Pump @ 115 gpm=1025 psi. Place tools face @ 90°R,slack off and latch LEM in.Observed tool face change to 6°R when LEM latched up. Pull 5K over to ensure LEM in place.Slack off to neutral weight and drop ball to set packer. Set down 10K on guide. 20:45 22:00 1.25 5,089 5,089 COMPZ RPEQP1 PACK P Establish circulation @ 3 bpm=1200 psi, reduce rate to 2 bpm=750 psi, once ball on seat increase pressure to 4000 psi and set packer @ 4991'. Held pressure for 2 min.and bled off to 500 psi.Closed upper rams and pressured up IA to 3000 psi. Held test for 15 min and recorded on chart,good test. 22:00 22:15 0.25 5,089 4,970 COMPZ RPEQP1OTHR P Picked up 23',observed 15K overpull when cup pulled through packer.Set slips and LID single. Blow down top drive. 22:15 23:00 0.75 4,970 4,970 COMPZ RPEQP1CIRC P Circulate and condition mud. Pump heated SF MOBM @ 7 bpm=750 psi.Circualted until returns reached 72° 23:00 00:00 1.00 4,970 4,970 COMPZ RPEQPI OWFF P Blow down and monitor well,slight flow then became static. Page 36 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/08/2013 24 hr Summary POOH f/4894'to surface,removing Super Sliders from 5"DP. UD MWD and running tool.Slip and cut drilling line. UD 4"drill pipe from derrick,43 stands. Pull wear bushing and flush stack. R/U to run 4-1/2"completion. RIH w/4-1/2"12.6#L-80 completion to 1429'. 00:00 00:30 0.50 4,970 4,970 COMPZ RPEQPI OPNW P Monitor well,slight flow becoming static. 00:30 04:30 4.00 4,970 462 COMPZ RPEQP1TRIP P POOH f/4894'to 462'.Actual displacement=51.1 bbls,Calculated displacement=44.46 bbls. Removed all Super Sliders from the 5"drill pipe on the trip out. 04:30 06:30 2.00 462 0 COMPZ RPEQP1 PULD P Stand back HWDP and lay down MWD and LEM running tool as per Baker rep. 06:30 07:15 0.75 0 0 COMPZ RPEQP1OTHR P Clean and clear rig floor. 07:15 07:30 0.25 0 0 COMPZ RIGMNT SFTY P Hold PJSM on slip and cut drilling line. Discussed using proper PPE while working around drilling line and using proper hand/body placement. 07:30 08:30 1.00 0 0 COMPZ RIGMNT SLPC P Slip and cut drilling line, 11 wraps. 08:30 09:00 0.50 0 0 COMPZ RPEQP1 RURD P Rig up to lay down 4"drill pipe out of the derrick. 09:00 14:30 5.50 0 0 COMPZ RPEQPI PULD P Lay down 4"drill pipe from derrick vai mouse hole. 14:30 15:30 1.00 0 0 COMPZ RPEQP1PULD P Change out handling tools and lay down 2 stands of drill collars. 15:30 16:00 0.50 0 0 COMPZ RPEQP1PULD P Lay down mouse hole and tools down slide. 16:00 16:15 0.25 0 0 COMPZ WHDBO OTHR P Pull wear bushing. 16:15 17:00 0.75 0 0 COMPZ WHDBO OTHR P Rig up and wash stack with stack washer, blow down top drive. 17:00 18:00 1.00 0 0 COMPZ RPCOM PULD P Lay down Geo-span and Sperry tools. 18:00 19:45 1.75 0 0 COMPZ RPCOM RURD P PJSM,pick up handling tools, 191 cannon clamps,4 offset clamps, spooler unit and spooler tools. 19:45 00:00 4.25 0 1,429 COMPZ RPCOM PUTB P Run 4-1/2"12.6#L-80 upper completion as per detail to 1429'MD. 02/09/2013 Continue make up and run 4 1/2"Completion tubing with I wire and SLB Gauge,attaching a total of 165 Cannon Clamps and 2 Offset clamps.Observed proper displacement.Space out tubing to locate 5'off of Seal bore crossover,and install space out pups.Make up Vetco hanger and landing joint. RU&displace well with 9.8 PPG Brine at 4 BPM-170 PSI. Land tbg hanger, RILDS.Test hanger seals to 5000 PSI and annulus to 1000 psi,shear SOV.OWFF and set 2-way check. N/D BOPE and N/U Tree. 00:00 07:30 7.50 1,429 4,955 COMPZ RPCOM PUTB P Cont running 4-1/2"upper completion as per detail f/1429'to 4955',testing SLB Tec wire every 25 joints. Ran 165 cannon clamps and 2 offset clamps.Actual displacement=22.94 bbls,Calculated displacement=23.4 bbls. Page 37 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 4,955 4,955 COMPZ RPCOM CIRC P Establish circulation,pump @ 1 bpm=250 psi.Observed a increase in pressure as seals entered seal bore.Shut down pumps and run in and fully locate @ 4978',set down 10K. 08:00 09:00 1.00 4,955 4,955 COMPZ RPCOM HOSO P Space out,5'from fully located and make up tubing hanger. 09:00 10:45 1.75 4,955 4,955 COMPZ RPCOM RURD P Rig up to displace well to 9.8 ppg brine. 10:45 11:00 0.25 4,955 4,955 COMPZ RPCOM SFTY P Hold PJSM on displacing well. Dicussed checking all 0-rings in hoses,filling out permits and hazards working around CRW-132 inhibiter. 11:00 11:15 0.25 4,955 4,955 COMPZ RPCOM CIRC P Establish circulation and check from leaks,good. 11:15 15:30 4.25 4,955 4,955 COMPZ RPCOM DISP P Displace well to 9.8 ppg NaCI/KCL as follows, pumped 15 bbls mineral oil,40 bbls HiVis 9.8 ppg brine,40 bbls HiVis brine w/10% DEEPKLEEN,670 bbls of neat 9.8 ppg brine(2 hole volumes)and 290 bbls of 9.8 ppg Inhibited brine. 15:30 15:45 0.25 4,955 4,974 COMPZ RPCOM THGR P Land tubing hanger 5'off fully located position w/mule shoe @ 4973.53'. P/U=75K,S/0=63K. 15:45 17:15 1.50 4,974 4,974 COMPZ RPCOM THGR P Run in locks downs. 17:15 19:15 2.00 4,974 4,974 COMPZ RPCOM THGR P Test upper and lower hanger seals to 5000 psi for 15min.,recored on chart.Good test. 19:15 19:30 0.25 0 0 COMPZ RPCOM PRTS P Test annulus to 1000 psi for 10 min. to confirm seals are stabbed in seal bore. Ramped up pressure to 3000 psi to shear SOV,confirmed valve sheared by returns up the tubing. Charted. 19:30 20:00 0.50 0 0 COMPZ RPCOM OTHR P Lay down landing joint. 20:00 20:30 0.50 0 0 COMPZ WHDBO OWFF P Monitor well,static. 20:30 20:45 0.25 0 0 COMPZ WHDBO SEQP P Set 2-way check.Verify barriers in place before nipple down,9.8 ppg brine in tubbing,9.8 ppg brine IA, 2-way chack installed in hanger and hanger seals tested to 5000 psi. 20:45 21:15 0.50 0 0 COMPZ WHDBO OTHR P Blow down lines and clean out BOP stack. 21:15 22:30 1.25 0 0 COMPZ WHDBO NUND P PJSM, Nipple down BOPs and rack back. 22:30 00:00 1.50 0 0 COMPZ WHDBO NUND P Prep tree for installation and terminate Tec wire. 02/10/2013 Cont N/U Tree and terminated tec wire.Attempted to pressure test void multiple times,no success.After exhausting all options the tree was nippled down,a small scratch was noticed on bonnet. UD 5"drill pipe while waiting on another bonnet. N/U another(used)bonnet and attempt to test, leaked. Decision made to N/U BOPs and C/O tubing hanger. N/U BOP's.Body test stack and choke line to 250/3500 psi. R/U to pull hanger. Page 38 of 41 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 0 0 COMPZ WHDBO NUND P PJSM,Terminate Tec wire and install SSV valves on wellhead as per Vetco/DSO. 02:15 06:45 4.50 0 0 COMPZ WHDBO PRTS T Attempt to pressure test tree,could not pressure up. Pulled tree cap and observed hyd oil leaking up into tree. Talked to Vetco town support,Vetco town rep informed Vetco service tech to tighten up bolts on tree, no success.Attempted to pressure up inside the tree to see if the neck would hold that way.The void was drained and the cap removed,as diesel was put in the tree it leaked out the void. Decision made to nipple down tree.Wait on new bonnet. 06:45 07:15 0.50 0 0 COMPZ MOVE RURD P Rig up to lay down 5"drill pipe. 07:15 07:30 0.25 0 0 COMPZ MOVE SFTY P Hold PJSM on laying down 5"drill pipe. Fill out HRC and HRW. 07:30 13:15 5.75 0 0 COMPZ MOVE PULD P Lay down 5"drill pipe out of the derrick using mouse hole. 13:15 14:15 1.00 0 0 COMPZ WHDBO NUND T PJSM, Bring new(used)bonnet into the cellar. Inspect and prep for installation. 14:15 15:45 1.50 0 0 COMPZ WHDBO NUND T Splice Tec wire as per SLB rep., SIMOPS lay down 5"drill pipe and scrub drip pan for welder. 15:45 18:15 2.50 0 0 COMPZ WHDBO NUND T PJSM, nipple up bonnet as per Vetco rep.Attempt to test void, held pressure until 4200 psi then all the pressure bled off.Would not hold any pressure after. Decision made to nipple up BOPs and pull hanger to replace it.All indications point to the hanger neck as the problem. 18:15 19:00 0.75 0 0 COMPZ WHDBO NUND T PJSM, nipple down bonnet and disconnect Tec wire. 19:00 20:15 1.25 0 0 COMPZ WHDBO NUND T PJSM, Nipple up BOP's. 20:15 21:30 1.25 0 0 COMPZ WHDBO BOPE T PJSM,rig up to test BOPs. Body test BOP stack and choke line t/ 250/3500 PSI for 5 min.Confirmed body test was acceptable with AOGCC,spoke to AOGCC rep Chuck Scheve on the telephone. 21:30 22:00 0.50 0 0 COMPZ WHDBO SFTY T Hold PJSM and P/U tubing tools from slide. 22:00 23:00 1.00 0 0 COMPZ WHDBO RURD T Rig up 4-/12"tubing tools and power tongs. 23:00 00:00 1.00 0 0 COMPZ WHDBO OTHR T Wait on 150 bbls of 9.8 ppg brine to show up on location before pulling hanger to floor.Clean up cellar and put away tools. 02/11/2013 BOLDs and pull hanger to rig floor.M/U new tubing hanger. R/U and RIH w/HES slickline and C/O DCK valve on GLM#2(2500 casing t/tubing)R/D slickline. Land 4-1/2"tubing and test seals to 1000 PSI f/10min.Test hanger seals U 5000 PSI.Set TWC. N/D BOPE and N/U bonnet,test void to 5000 PSI,good. N/U tree and attempt to test tree,leaking by TWC.C/O TWO and test tree U 5000 PSI. Page 39 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 COMPZ WHDBO OWFF T PJSM,service top drive,clean drip pan and pits while waiting on 9.8 ppg brine.OWFF through annulus,static. 01:30 01:45 0.25 0 0 COMPZ WHDBO SEQP T Pull TWC as per Vetco rep.Verified no pressure under valve by a open annulus valve and unseating the popit on TCW. 01:45 03:15 1.50 0 0 COMPZ WHDBO THGR T BOLDs and pull hanger to floor. P/U=75K,S/O=63K,hanger pulled free @ 105K. 03:15 05:30 2.25 0 4,950 COMPZ WHDBO THGR T Pick up new hanger and prep. Pick up landing joint ad drop 3.875"drift needed for slickline tools. Drift would not pass through landing joint due to build up of rust in the joint.Decision made to L/D hanger and slickline through the 4-1/2"tubing stump. 05:30 07:00 1.50 4,950 4,950 COMPZ WHDBO RURD T Spot Halliburton slickline trucks and rig up HES slickline tools. 07:00 07:15 0.25 4,950 4,950 COMPZ WHDBO SFTY T Hold PJSM with Halliburton and rig crews. 07:15 12:00 4.75 4,950 4,950 COMPZ WHDBO SLKL T Slickline, make 4 runs.Set catcher, Pull sheared out DCK @ 3546'. Install new 2500 PSI casing to tubing DCK in GLM#2 @ 3546'.and retreive catcher. 12:00 12:30 0.50 4,950 4,950 COMPZ WHDBO RURD T PJSM, Rig down HES slickline as per HES rep. 12:30 13:00 0.50 4,950 4,950 COMPZ WHDBO THGR T M/U new Vetco tubing hanger. 13:00 13:45 0.75 4,950 4,950 COMPZ WHDBO THGR T Splice SLB Tec wire and terminate Tec wire. 13:45 14:45 1.00 4,950 0 COMPZ WHDBOTHGR T Land Hanger and RILD's. P/U=75K, S/O=63K. 14:45 16:00 1.25 0 0 COMPZ WHDBO THGR T Test lower and upper hanger seals to 5000 PSI for 15 min.on chart,good test. 16:00 16:15 0.25 0 0 COMPZ WHDBO PRTS T Pressure test IA to 1000 psi for 10min.on chart,good test. 16:15 16:45 0.50 0 0 COMPZ WHDBO OWFF T RID landing joint. Monitor well for 30 min.,staitc. 16:45 17:00 0.25 0 0 COMPZ WHDBO SEQP T Set 2-way check.Verify barriers in place before nipple down,9.8 ppg brine in tubbing, 9.8 ppg brine IA, 2-way chack installed in hanger and hanger seals tested to 5000 psi. 17:00 17:45 0.75 0 0 COMPZ WHDBO NUND T PJSM, Nipple down BOP stack and prep hanger neck for bonnet. 17:45 19:00 1.25 0 0 COMPZ WHDBO NUND T Nipple up bonnet on wellhead as per Vetco rep. 19:00 19:15 0.25 0 0 COMPZ WHDBO PRTS P Test void to 5000 PSI for 10 min., ---COMPZ good test. 19:15 20:00 0.75 0 0 COMPZ WHDBO NUND P Terminate SLB Tec wire and test. 20:00 20:45 0.75 0 0 COMPZ WHDBO NUND P Nipple up tree as per Vetco rep. 20:45 21:15 0.50 0 0 COMPZ WHDBO PRTS P Attempt to pressure test tree t/5000 PSI. Pressure leaking off,no visible signs of leaks.TWC leaking. Page 40 of 41 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 21:15 23:00 1.75 0 0 COMPZ WHDBO RURD T Vetco rep had to go to the valve shop to get another TWC.SIMOPS, R/U to shear DCK/freeze protect well and clean casing tools and remove from rig floor. 23:00 00:00 1.00 0 0 COMPZ WHDBO SEQP T Pull TWC and install new TWC. 02/12/2013 Tested tree to 5000 PSI. Pull TWC and pump 150 bbls of freeze protect w/Little Red. U-Tube diesel and set BPV. R/D and secure well. Rig down,release rig @ 12:00 hours 00:00 01:00 1.00 0 0 COMPZ WHDBO PRTS P PJSM,pressure test tree to 5000 PSI f/10 min.on chart,good test. 01:00 01:15 0.25 0 0 COMPZ WHDBO SEQP P Pull TWC as per Vetco rep. 01:15 01:30 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on freeze protect well. Discuss safe muster areas with LRS, fill out permits and HRC's. 01:30 02:00 0.50 0 0 COMPZ WHDBO RURD P Rig up Little Red to freeze protect well. 02:00 02:15 0.25 0 0 COMPZ WHDBO PRTS P Pressure test lines to 3500 PSI, good. 02:15 03:30 1.25 0 0 COMPZ WHDBO FRZP P Ramp up t/2500 PSI to shear SOV, valved sheared @ 2550 psi. Pump 150 bbls of diesel @ 2 BPM,top of freeze protect @ 2110'. 03:30 05:00 1.50 0 0 COMPZ WHDBO FRZP P Rig down Little Red and U-tube well. 05:00 05:30 0.50 0 0 COMPZ WHDBO RURD P Shut in well. Rig down lines and blow down. 05:30 07:00 1.50 0 0 COMPZ WHDBO OTHR P Set BPV with lubricator as per Vetco. 07:00 07:30 0.50 0 0 COMPZ WHDBO RURD P Rig down lubricator.Secure well. Tubing pressure=0 psi, Annulus pressure=65 psi. 07:30 12:00 4.50 0 0 DEMOB MOVE RURD P Cont cleaning MOBM in pits,rock washer and rig floor. Blow down service lines and rig down to move to 1R-07. Release rig @ 12:00 Page 41 of 41 ConocoPhillips (Alaska) Inc NAD27 Kuparuk River Unit Kuparuk 3K Pad 3K-105L1 API:500292347960 - PTD:212-166 1111 " 1 Sperry Drilling ervices Definitive Survey Report 19 February, 2013 Ph I HALU1 P U RTS Sperry Drilling Services ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit ND Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 Database: EDM 2003.16 Single User Db Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3K-105 Well Position +N/-S 0.00 ft Northing: 6,007,929.20 ft Latitude: 70°25'57.87 N +E/-W 0.00 ft Easting: 529,305.40 ft Longitude: 149°45 40.01 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.30 ft Wellbore 3K-105L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) O (nT) BGGM2011 1/20/2013 20.17 81.03 57,633 Design 3K-105L1 immmum imiiii,,,,,,mmmmmmmaiiimeimmmiimuutiw,imuniiiiii•iiir,,,.,uiuiuniuuuumummuuaur..,_, Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,242.26 Vertical Section: Depth From(ND) ( a' Il �.w II +E/-W Direction l gai (ft) jjl��4i`^ Iw 6 1,e�h �< ciao„r l��, ':"I"! (') 27.35 0.00 0.00 90.00 Survey Program Date 2/15/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 77.00 1,003.00 3K-105(3K-105PB1) GYD-GC-SS Gyrodata gyro single shots 12/25/2012 1,088.07 2,332.08 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 2,333.08 5,028.47 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 5,074.00 6,129.90 3K-105LIPB1(3K-105L1PB1) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 01/21/2013 6,220.00 7,242.26 3K-105L1 PBS(3K-105L1PB3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/25/2013 7,280.00 12,638.32 3K-105L1(3K-105L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/28/2013 Survey Map Map Vertical MD Inc Azi ND TVDSS 4-NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.35 0.00 0.00 27.35 -33.30 0.00 0.00 6,007,929.20 529,305.40 0.00 0.00 UNDEFINED 77.00 0.48 77.44 77.00 16.35 0.05 0.20 6,007,929.25 529,305.60 0.97 0.20 GYD-GC-SS(1) 169.00 0.59 27.28 169.00 108.35 0.55 0.80 6,007,929.75 529,306.19 0.50 0.80 GYD-GC-SS(1) 200.00 0.79 23.15 199.99 139.34 0.89 0.95 6,007,930.09 529,306.35 0.66 0.95 GYD-GC-SS(1) 263.00 0.84 1.44 262.99 202.34 1.75 1.14 6,007,930.95 529,306.53 0.49 1.14 GYD-GC-SS(1) 355.00 1.71 317.84 354.97 294.32 3.44 0.23 6,007,932.64 529,305.62 1.35 0.23 GYD-GC-SS(1) 401.00 4.10 305.91 400.90 340.25 4.91 -1.56 6,007,934.11 529,303.82 5.33 -1.56 GYD-GC-SS(1) 447.00 7.20 300.72 446.67 386.02 7.35 -5.37 6,007,936.53 529,300.00 6.82 -5.37 GYD-GC-SS(1) 493.00 9.53 299.99 492.18 431.53 10.73 -11.15 6,007,939.88 529,294.21 5.07 -11.15 GYD-GC-SS(1) 539.00 9.69 299.10 537.54 476.89 14.51 -17.83 6,007,943.64 529,287.51 0.47 -17.83 GYD-GC-SS(1) 2/19/2013 10:45:36AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 632.00 10.55 304.26 629.09 568.44 23.11 -31.71 6,007,952.19 529,273.61 1.34 -31.71 GYD-GC-SS(1) 725.00 11.40 307.91 720.39 659.74 33.55 -45.99 6,007,962.57 529,259.28 1.18 -45.99 GYD-GC-SS(1) 818.00 11.59 312.49 811.53 750.88 45.51 -60.14 6,007,974.47 529,245.09 1.00 -60.14 GYD-GC-SS(1) 911.00 13.64 318.18 902.28 841.63 60.00 -74.34 6,007,988.90 529,230.83 2.58 -74.34 GYD-GC-SS(1) 1,003.00 16.78 327.72 991.06 930.41 79.32 -88.67 6,008,008.16 529,216.43 4.35 -88.67 GYD-GC-SS(1) 1,088.07 15.32 325.90 1,072.81 1,012.16 99.01 -101.53 6,008,027.80 529,203.49 1.82 -101.53 MWD+IFR-AK-CAZ-SC(2) 1,127.95 16.20 328.51 1,111.19 1,050.54 108.11 -107.39 6,008,036.88 529,197.60 2.83 -107.39 MWD+IFR-AK-CAZ-SC(2) 1,221.38 14.95 330.70 1,201.19 1,140.54 129.74 -120.10 6,008,058.45 529,184.81 1.48 -120.10 MWD+IFR-AK-CAZSC(2) 1,313.71 18.19 339.79 1,289.69 1,229.04 153.66 -130.91 6,008,082.33 529,173.90 4.48 -130.91 MWD+IFR-AK-CAZ-SC(2) 1,347.58 20.14 343.21 1,321.68 1,261.03 164.20 -134.42 6,008,092.86 529,170.35 6.64 -134.42 MWD+IFR-AK-CAZ-SC(2) 1,377.82 19.65 343.07 1,350.12 1,289.47 174.05 -137.40 6,008,102.69 529,167.33 1.63 -137.40 MWD+IFR-AK-CAZ-SC(2) 1,406.44 18.90 344.95 1,377.13 1,316.48 183.13 -140.01 6,008,111.76 529,164.69 3.40 -140.01 MWD+IFR-AK-CAZSC(2) 1,438.76 19.82 346.59 1,407.63 1,346.98 193.52 -142.64 6,008,122.13 529,162.02 3.31 -142.64 MWD+IFR-AK-CAZSC(2) 1,470.35 21.47 349.96 1,437.19 1,376.54 204.42 -144.89 6,008,133.03 529,159.73 6.43 -144.89 MWD+IFR-AK-CAZSC(2) 1,500.11 22.47 351.78 1,464.79 1,404.14 215.41 -146.65 6,008,144.01 529,157.92 4.06 -146.65 M1ND+IFR-AK-CAZ-SC(2) 1,532.75 23.94 354.73 1,494.79 1,434.14 228.18 -148.15 6,008,156.77 529,156.37 5.74 -148.15 MWD+IFR-AK-CAZ-SC(2) 1,563.13 25.06 355.99 1,522.43 1,461.78 240.74 -149.17 6,008,169.32 529,155.30 4.07 -149.17 MWD+IFR-AK-CAZ-SC(2) 1,593.70 25.07 356.15 1,550.12 1,489.47 253.66 -150.05 6,008,182.24 529,154.37 0.22 -150.05 MWD+IFR-AK-CAZ-SC(2) 1,635.67 24.21 357.97 1,588.27 1,527.62 271.13 -150.96 6,008,199.71 529,153.40 2.73 -150.96 MWD+IFR-AK-CAZ-SC(2) 1,684.66 25.03 0.96 1,632.81 1,572.16 291.53 -151.14 6,008,220.11 529,153.13 3.04 -151.14 MWD+IFR-AK-CAZSC(2) 1,728.85 26.01 3.40 1,672.69 1,612.04 310.55 -150.41 6,008,239.13 529,153.79 3.25 -150.41 MWD+IFR-AK-CAZ-SC(2) 1,777.86 26.71 6.71 1,716.60 1,655.95 332.22 -148.48 6,008,260.80 529,155.63 3.32 -148.48 MWD+IFR-AK-CAZ-SC(2) 1,825.53 26.87 11.84 1,759.16 1,698.51 353.41 -145.02 6,008,282.00 529,159.01 4.86 -145.02 MWD+IFR-AK-CAZ-SC(2) 1,870.48 27.34 17.21 1,799.18 1,738.53 373.21 -139.88 6,008,301.82 529,164.07 5.54 -139.88 MWD+IFR-AK-CAZ-SC(2) 1,915.17 28.01 21.57 1,838.76 1,778.11 392.77 -132.99 6,008,321.41 529,170.89 4.77 -132.99 MWD+IFR-AK-CAZ-SC(2) 1,962.97 27.67 25.52 1,881.03 1,820.38 413.23 -124.08 6,008,341.90 529,179.71 3.92 -124.08 MWD+IFR-AK-CAZ-SC(2) 2,009.47 26.46 28.88 1,922.44 1,861.79 432.05 -114.42 6,008,360.75 529,189.29 4.19 -114.42 MWD+IFR-AK-CAZ-SC(2) 2,056.28 25.81 34.48 1,964.47 1,903.82 449.58 -103.61 6,008,378.33 529,200.03 5.45 -103.61 MWD+IFR-AK-CAZ-SC(2) 2,101.78 24.27 39.24 2,005.70 1,945.05 464.99 -92.09 6,008,393.78 529,211.49 5.57 -92.09 MWD+IFR-AK-CAZ-SC(2) 2,147.42 24.42 44.55 2,047.29 1,986.64 478.98 -79.54 6,008,407.82 529,223.99 4.81 -79.54 MWD+IFR-AK-CAZ-SC(2) 2,194.78 23.70 48.18 2,090.53 2,029.88 492.30 -65.57 6,008,421.19 529,237.90 3.47 -65.57 MWD+IFR-AK-CAZSC(2) 2,240.00 23.41 53.80 2,131.99 2,071.34 503.67 -51.55 6,008,432.62 529,251.88 5.01 -51.55 MWD+IFR-AK-CAZSC(2) 2,287.66 23.01 61.83 2,175.81 2,115.16 513.66 -35.69 6,008,442.67 529,267.69 6.69 -35.69 MWD+IFR-AK-CAZSC(2) 2,333.08 23.90 66.93 2,217.48 2,156.83 521.46 -19.40 6,008,450.53 529,283.95 4.88 -19.40 MWD+IFR-AK-CAZ-SC(3) 2,387.65 24.31 70.83 2,267.29 2,206.64 529.48 1.38 6,008,458.63 529,304.70 3.01 1.38 MWD+IFR-AK-CAZ-SC(3) 2,437.33 25.10 75.02 2,312.43 2,251.78 535.56 21.22 6,008,464.79 529,324.51 3.87 21.22 MWD+IFR-AK-CAZ-SC(3) 2,479.65 26.14 80.26 2,350.59 2,289.94 539.46 39.08 6,008,468.76 529,342.36 5.89 39.08 MWD+IFR-AK-CAZ-SC(3) 2,524.98 27.52 85.29 2,391.05 2,330.40 542.01 59.36 6,008,471.39 529,362.63 5.86 59.36 MWD+IFR-AK-CAZ-SC(3) 2,573.03 27.87 89.03 2,433.59 2,372.94 543.11 81.66 6,008,472.58 529,384.92 3.69 81.66 MWD+IFR-AK-CAZSC(3) 2,619.93 27.52 93.60 2,475.13 2,414.48 542.62 103.44 6,008,472.17 529,406.69 4.59 103.44 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:45:36AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 2,665.68 28.07 99.63 2,515.60 2,454.95 540.15 124.60 6,008,469.78 529,427.87 6.26 124.60 MWD+IFR-AK-CAZ-SC(3) 2,712.74 28.97 103.31 2,556.96 2,496.31 535.68 146.61 6,008,465.40 529,449.89 4.19 146.81 MWD+IFR-AK-CAZ-SC(3) 2,758.64 30.01 106.76 2,596.91 2,536.26 529.81 168.42 6,008,459.61 529,471.72 4.34 168.42 MWD+IFR-AK-CAZ-SC(3) 2,803.41 32.67 110.90 2,635.15 2,574.50 522.27 190.44 6,008,452.16 529,493.76 7.64 190.44 MWD+IFR-AK-CAZ-SC(3) 2,850.11 35.38 113.24 2,673.85 2,613.20 512.43 214.64 6,008,442.42 529,518.00 6.44 214.64 MWD+IFR-AK-CAZ-SC(3) 2,895.36 35.81 113.38 2,710.65 2,650.00 502.01 238.83 6,008,432.09 529,542.23 0.97 238.83 MWD+IFR-AK-CAZ-SC(3) 2,941.81 37.89 113.64 2,747.82 2,687.17 490.90 264.37 6,008,421.08 529,567.81 4.49 264.37 MWD+IFR-AK-CAZ-SC(3) 2,989.56 39.89 114.58 2,784.98 2,724.33 478.65 291.73 6,008,408.94 529,595.22 4.37 291.73 MWD+IFR-AK-CAZ-SC(3) 3,035.74 42.01 116.01 2,819.86 2,759.21 465.71 319.09 6,008,396.11 529,622.62 5.02 319.09 MWD+IFR-AK-CAZ-SC(3) 3,082.63 44.43 117.28 2,854.03 2,793.38 451.30 347.78 6,008,381.82 529,651.37 5.48 347.78 MWD+IFR-AK-CAZ-SC(3) 3,127.76 46.91 116.60 2,885.56 2,824.91 436.68 376.56 6,008,367.31 529,680.20 5.60 376.56 MWD+IFR-AK-CAZ-SC(3) 3,174.72 49.00 116.04 2,917.01 2,856.36 421.22 407.82 6,008,351.98 529,711.52 4.54 407.82 MWD+IFR-AK-CAZ-SC(3) 3,223.90 51.75 116.29 2,948.37 2,887.72 404.52 441.81 6,008,335.41 529,745.57 5.61 441.81 MWD+IFR-AK-CAZ-SC(3) 3,269.18 54.81 115.83 2,975.44 2,914.79 388.58 474.41 6,008,319.60 529,778.24 6.81 474.41 MWD+IFR-AK-CAZ-SC(3) 3,314.13 58.00 115.82 3,000.31 2,939.66 372.27 508.11 6,008,303.43 529,811.99 7.10 508.11 MWD+IFR-AK-CAZ-SC(3) 3,360.92 59.18 115.01 3,024.70 2,964.05 355.14 544.18 6,008,286.43 529,848.13 2.92 544.18 MWD+IFR-AK-CAZ-SC(3) 3,406.23 59.11 114.62 3,047.93 2,987.28 338.81 579.48 6,008,270.25 529,883.49 0.75 579.48 MWD+IFR-AK-CAZ-SC(3) 3,452.48 60.91 114.90 3,071.05 3,010.40 322.03 615.86 6,008,253.62 529,919.93 3.93 615.86 MWD+IFR-AK-CAZ-SC(3) 3,498.42 64.06 114.79 3,092.27 3,031.62 304.92 652.83 6,008,236.65 529,956.96 6.86 652.83 MWD+IFR-AK-CAZ-SC(3) 3,545.13 66.91 114.55 3,111.65 3,051.00 287.18 691.44 6,008,219.07 529,995.64 6.12 691.44 MWD+IFR-AK-CAZ-SC(3) 3,592.72 69.61 115.64 3,129.28 3,068.63 268.43 731.47 6,008,200.48 530,035.74 6.06 731.47 MWD+IFR-AK-CAZ-SC(3) 3,638.45 72.00 114.63 3,144.31 3,083.66 250.09 770.57 6,008,182.29 530,074.90 5.63 770.57 MWD+IFR-AK-CAZSC(3) 3,685.67 74.61 115.18 3,157.88 3,097.23 231.04 811.58 6,008,163.41 530,115.99 5.64 811.58 MWD+IFR-AK-CAZSC(3) 3,729.51 78.02 116.62 3,168.25 3,107.60 212.44 849.89 6,008,144.95 530,154.37 8.41 849.89 MWD+IFR-AK-CAZSC(3) 3,777.86 80.43 115.74 3,177.28 3,116.63 191.49 892.51 6,008,124.17 530,197.07 5.30 892.51 MWD+IFR-AK-CAZ-SC(3) 3,824.74 81.42 115.56 3,184.68 3,124.03 171.45 934.25 6,008,104.30 530,238.87 2.15 934.25 MWD+IFR-AK-CAZ-SC(3) 3,870.07 82.71 112.73 3,190.94 3,130.29 153.09 975.21 6,008,086.10 530,279.90 6.81 975.21 MWD+IFR-AK-CAZ-SC(3) 3,917.96 81.73 110.38 3,197.42 3,136.77 135.65 1,019.34 6,008,068.84 530,324.09 5.27 1,019.34 MWD+IFR-AK-CAZ-SC(3) 3,961.92 80.86 108.84 3,204.08 3,143.43 121.07 1,060.27 6,008,054.42 530,365.08 3.99 1,060.27 MWD+IFR-AK-CAZ-SC(3) 4,008.60 79.75 107.13 3,211.94 3,151.29 106.86 1,104.03 6,008,040.39 530,408.89 4.32 1,104.03 MWD+IFR-AK-CAZ-SC(3) 4,055.79 79.39 107.74 3,220.48 3,159.83 92.96 1,148.31 6,008,026.66 530,453.22 1.48 1,148.31 MWD+IFR-AK-CAZ-SC(3) 4,102.79 78.75 107.42 3,229.39 3,168.74 79.02 1,192.30 6,008,012.89 530,497.26 1.52 1,192.30 MWD+IFR-AK-CAZ-SC(3) 4,148.74 78.07 107.36 3,238.62 3,177.97 65.57 1,235.25 6,007,999.61 530,540.27 1.49 1,235.25 MWD+IFR-AK-CAZ-SC(3) 4,241.40 76.59 107.33 3,258.95 3,198.30 38.62 1,321.54 6,007,973.00 530,626.65 1.60 1,321.54 MWD+IFR-AK-CAZ-SC(3) 4,289.60 77.29 108.06 3,269.84 3,209.19 24.34 1,366.28 6,007,958.91 530,671.43 2.07 1,366.28 MWD+IFR-AK-CAZ-SC(3) 4,333.51 78.98 108.17 3,278.87 3,218.22 10.98 1,407.12 6,007,945.71 530,712.32 3.86 1,407.12 MWD+IFR-AK-CAZ-SC(3) 4,381.30 79.68 107.73 3,287.71 3,227.06 -3.49 1,451.79 6,007,931.41 530,757.05 1.72 1,451.79 MWD+IFR-AK-CAZ-SC(3) 4,422.48 80.65 108.26 3,294.75 3,234.10 -16.03 1,490.38 6,007,919.03 530,795.69 2.68 1,490.38 MWD+IFR-AK-CAZ-SC(3) 4,518.60 78.95 108.13 3,311.77 3,251.12 -43.99 1,580.75 6,007,891.42 530,886.15 2.81 1,580.75 MWD+IFR-AK-CAZ-SC(3) 4,609.99 79.97 106.75 3,328.49 3,267.84 -69.42 1,666.92 6,007,866.33 530,972.41 1.30 1,666.92 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:45:36AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) ' Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) 11 Well: 3K-105 North Reference: True Wellbore: 3K-105L1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,701.74 79.72 104.61 3,344.67 3,284.02 -93.83 1,753.86 6,007,842.27 531,059.45 2.31 1,753.86 MWD+IFR-AK-CAZ-SC(3) 1 4,748.12 79.83 103.91 3,352.90 3,292.25 -105.07 1,798.10 6,007,831.20 531,103.72 1.50 1,798.10 MWD+IFR-AK-CAZ-SC(3) 4,794.29 80.01 102.66 3,360.98 3,300.33 -115.52 1,842.34 6,007,820.93 531,148.00 2.69 1,842.34 MWD+IFR-AK-CAZ-SC(3) 4,836.85 78.52 99.63 3,368.91 3,308.26 -123.60 1,883.36 6,007,813.01 531,189.05 7.82 1,883.36 MWD+IFR-AK-CAZSC(3) 4,889.05 78.18 98.33 3,379.45 3,318.80 -131.58 1,933.86 6,007,805.23 531,239.57 2.52 1,933.86 MWD+IFR-AK-CAZSC(3) 4,938.27 78.10 97.96 3,389.57 3,328.92 -138.41 1,981.54 6,007,798.59 531,287.27 0.75 1,981.54 MWD+IFR-AK-CAZSC(3) 4,980.41 77.23 97.23 3,398.57 3,337.92 -143.85 2,022.35 6,007,793.31 531,328.10 2.67 2,022.35 MWD+IFR-AK-CAZSC(3) 5,028.47 76.22 95.96 3,409.61 3,348.96 -149.22 2,068.81 6,007,788.12 531,374.58 3.32 2,068.81 MWD+IFR-AK-CAZSC(3) 5,074.00 78.01 97.04 3,419.76 3,359.11 -154.25 2,112.91 6,007,783.27 531,418.69 4.56 2,112.91 MWD+IFR-AK-CAZ-SC(4) 5,145.15 80.26 98.70 3,433.17 3,372.52 -163.82 2,182.12 6,007,773.97 531,487.93 3.91 2,182.12 MWD+IFR-AK-CAZ-SC(4) 5,203.98 82.44 100.05 3,442.02 3,381.37 -173.29 2,239.49 6,007,764.72 531,545.34 4.34 2,239.49 MWD+IFR-AK-CAZ-SC(4) 5,266.77 85.61 101.48 3,448.55 3,387.90 -184.96 2,300.83 6,007,753.30 531,606.72 5.53 2,300.83 MWD+IFR-AK-CAZ-SC(4) 5,325.50 89.32 102.17 3,451.15 3,390.50 -196.98 2,358.25 6,007,741.51 531,664.17 6.43 2,358.25 MWD+IFR-AK-CAZ-SC(4) 5,359.63 88.02 101.99 3,451.94 3,391.29 -204.12 2,391.62 6,007,734.50 531,697.56 3.85 2,391.62 MWD+IFR-AK-CAZ-SC(4) 5,388.59 88.89 101.44 3,452.72 3,392.07 -210.00 2,419.96 6,007,728.73 531,725.93 3.55 2,419.96 MWD+IFR-AK-CAZ-SC(4) 5,423.96 90.28 102.26 3,452.98 3,392.33 -217.26 2,454.58 6,007,721.61 531,760.57 4.56 2,454.58 MWD+IFR-AK-CAZ-SC(4) 5,481.83 91.17 100.17 3,452.25 3,391.60 -228.51 2,511.33 6,007,710.58 531,817.36 3.93 2,511.33 MWD+IFR-AK-CAZ-SC(4) 5,574.70 90.04 95.80 3,451.27 3,390.62 -241.41 2,603.27 6,007,698.04 531,909.34 4.86 2,603.27 MWD+IFR-AK-CAZ-SC(4) 5,667.06 88.19 90.25 3,452.69 3,392.04 -246.28 2,695.45 6,007,693.53 532,001.53 6.33 2,695.45 MWD+IFR-AK-CAZ-SC(4) 5,713.57 88.31 87.86 3,454.11 3,393.46 -245.52 2,741.93 6,007,694.48 532,048.00 5.14 2,741.93 MWD+IFR-AK-CAZ-SC(4) 5,759.03 88.68 87.72 3,455.31 3,394.66 -243.76 2,787.34 6,007,696.41 532,093.40 0.87 2,787.34 MWD+IFR-AK-CAZ-SC(4) 5,851.41 88.68 86.39 3,457.44 3,396.79 -239.02 2,879.57 6,007,701.52 532,185.61 1.44 2,879.57 MWD+IFR-AK-CAZ-SC(4) 5,944.38 89.24 86.78 3,459.12 3,398.47 -233.48 2,972.36 6,007,707.42 532,278.36 0.73 2,972.36 MWD+IFR-AK-CAZ-SC(4) 6,037.23 86.70 88.57 3,462.41 3,401.76 -229.72 3,065.07 6,007,711.55 532,371.04 3.35 3,065.07 MWD+IFR-AK-CAZ-SC(4) 6,129.90 86.83 88.59 3,467.64 3,406.99 -227.42 3,157.56 6,007,714.20 532,463.52 0.14 3,157.56 MWD+IFR-AK-CAZ-SC(4) 6,220.00 87.13 87.68 3,472.39 3,411.74 -224.50 3,247.49 6,007,717.49 532,553.42 1.06 3,247.49 MWD+IFR-AK-CAZ-SC(5) 6,315.54 87.32 83.71 3,477.02 3,416.37 -217.33 3,342.63 6,007,725.02 532,848.52 4.16 3,342.63 MWD+IFR-AK-CAZ-SC(5) 6,408.04 88.56 81.47 3,480.34 3,419.69 -205.41 3,434.29 6,007,737.30 532,740.13 2.77 3,434.29 MWD+IFR-AK-CAZ-SC(5) 6,501.66 89.79 79.02 3,481.69 3,421.04 -189.55 3,526.53 6,007,753.52 532,832.30 2.93 3,526.53 MWD+IFR-AK-CAZ-SC(5) 6,593.61 93.44 78.75 3,479.10 3,418.45 -171.84 3,616.71 6,007,771.59 532,922.40 3.98 3,616.71 MWD+IFR-AK-CAZ-SC(5) 6,686.23 92.82 81.55 3,474.04 3,413.39 -156.02 3,707.82 6,007,787.76 533,013.44 3.09 3,707.82 MWD+IFR-AK-CAZ-SC(5) 6,778.97 92.14 82.75 3,470.03 3,409.38 -143.36 3,799.60 6,007,800.78 533,105.16 1.49 3,799.60 MWD+IFR-AK-CAZSC(5) 6,871.53 87.94 82.37 3,469.96 3,409.31 -131.38 3,891.36 6,007,813.12 533,196.86 4.56 3,891.36 MWD+IFR-AK-CAZSC(5) 6,964.03 89.11 81.71 3,472.34 3,411.69 -118.58 3,982.94 6,007,826.28 533,288.38 1.45 3,982.94 MWD+IFR-AK-CAZSC(5) 7,056.96 88.87 85.86 3,473.98 3,413.33 -108.52 4,075.29 6,007,836.70 533,380.68 4.47 4,075.29 MWD+IFR-AK-CAZ-SC(5) 7,149.78 89.55 93.33 3,475.26 3,414.61 -107.86 4,168.03 6,007,837.72 533,473.41 8.08 4,168.03 MWD+IFR-AK-CAZ-SC(5) 7,198.42 89.61 93.18 3,475.62 3,414.97 -110.63 4,216.59 6,007,835.15 533,521.97 0.33 4,216.59 MWD+IFR-AK-CAZ-SC(5) 7,242.26 89.18 92.44 3,476.08 3,415.43 -112.77 4,260.37 6,007,833.17 533,565.76 1.95 4,260.37 MWD+IFR-AK-CAZ-SC(5) 7,280.00 88.46 92.29 3,476.86 3,416.21 -114.33 4,298.07 6,007,831.76 533,603.46 1.95 4,298.07 MWD+IFR-AK-CAZSC(6) 7,370.78 88.68 95.88 3,479.13 3,418.48 -120.80 4,388.58 6,007,825.66 533,693.99 3.96 4,388.58 MWD+IFR-AK-CAZSC(6) 2/19/2013 10:45:36AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105©60.65ft(0141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (011001 (ft) Survey Tool Name 7,427.12 90.04 96.08 3,479.76 3,419 11 -126.66 4,444.61 6,007,820.01 533,750.03 2.44 4,444.61 MVVD+IFR-AK-CAZ-SC(6) 7,519.42 88.31 92.72 3,481.09 3,420.44 -133.74 4,536.61 6,007,813.29 533,842.05 4.09 4,536.61 MWD+IFR-AK-CAZ-SC(6) 7,567.39 88.12 90.65 3,482.58 3,421.93 -135.15 4,584.53 6,007,812.07 533,889.97 4.33 4,584.53 MWD+IFR-AK-CAZ-SC(6) 7,612.36 87.26 87.75 3,484.39 3,423.74 -134.53 4,629.46 6,007,812.87 533,934.89 6.72 4,629.46 MWD+IFR-AK-CAZ-SC(6) 7,656.89 90.53 87.05 3,485.25 3,424.60 -132.51 4,673.93 6,007,815.07 533,979.35 7.51 4,673.93 MWD+IFR-AK-CAZ-SC(6) 7,705.57 88.99 85.18 3,485.46 3,424.81 -129.21 4,722.49 6,007,818.56 534,027.89 4.98 4,722.49 MWD+IFR-AK-CAZ-SC(6) 7,766.29 85.78 85.95 3,488.23 3,427.58 -124.52 4,782.96 6,007,823.48 534,088.34 5.44 4,782.96 MWD+IFR-AK-CAZ-SC(6) 7,859.58 88.37 86.56 3,492.99 3,432.34 -118.43 4,875.92 6,007,829.93 534,181.26 2.85 4,875.92 MWD+IFR-AK-CAZ-SC(6) 7,909.60 91.58 87.68 3,493.01 3,432.36 -115.92 4,925.87 6,007,832.64 534,231.20 6.80 4,925.87 MWD+IFR-AK-CAZ-SC(6) 7,953.12 90.60 85.78 3,492.18 3,431.53 -113.44 4,969.31 6,007,835.29 534,274.62 4.91 4,969.31 MWD+IFR-AK-CAZ-SC(6) 8,002.90 93.62 86.27 3,490.35 3,429.70 -109.99 5,018.93 6,007,838.94 534,324.22 6.15 5,018.93 MWD+IFR-AK-CAZSC(6) 8,045.06 95.11 87.36 3,487.14 3,426.49 -107.66 5,060.90 6,007,841.44 534,366.18 4.37 5,060.90 MWD+IFR-AK-CAZSC(6) 8,137.96 98.53 87.97 3,476.11 3,415.46 -103.90 5,153.05 6,007,845.56 534,458.31 3.74 5,153.05 MWD+IFR-AK-CAZSC(6) 8,230.68 99.16 91.50 3,461.85 3,401.20 -103.47 5,244.65 6,007,846.34 534,549.90 3.82 5,244.65 MWD+IFR-AK-CAZSC(6) 8,323.26 95.42 93.15 3,450.10 3,389.45 -107.20 5,336.39 6,007,842.97 534,641.64 4.41 5,336.39 MWD+IFR-AK-CAZSC(6) 8,369.37 95.36 97.61 3,445.77 3,385.12 -111.50 5,382.08 6,007,838.85 534,687.34 9.63 5,382.08 MWD+IFR-AK-CAZSC(6) 8,415.43 94.06 98.48 3,441.98 3,381.33 -117.93 5,427.53 6,007,832.61 534,732.81 3.39 5,427.53 MWD+IFR-AK-CAZSC(6) 8,507.84 90.60 98.96 3,438.23 3,377.58 -131.92 5,518.78 6,007,818.97 534,824.11 3.78 5,518.78 MWD+IFR-AK-CAZ-SC(6) 8,600.29 89.12 98.50 3,438.45 3,377.80 -145.96 5,610.16 6,007,805.30 534,915.53 1.68 5,610.16 MWD+IFR-AK-CAZ-SC(6) 8,693.16 88.56 100.65 3,440.33 3,379.68 -161.40 5,701.71 6,007,790.22 535,007.14 2.39 5,701.71 MWD+IFR-AK-CAZ-SC(6) 8,785.95 88.00 100.36 3,443.12 3,382.47 -178.31 5,792.90 6,007,773.67 535,098.39 0.68 5,792.90 MWD+IFR-AK-CAZ-SC(6) 8,878.81 88.00 103.39 3,448.36 3,385.71 -197.40 5,883.71 6,007,754.93 535,189.26 3.26 5,883.71 MWD+IFR-AK-CAZ-SC(6) 8,971.93 88.13 104.35 3,449.51 3,388.86 -219.71 5,974.06 6,007,732.98 535,279.69 1.04 5,974.06 MWD+IFR-AK-CAZ-SC(6) 9,064.55 88.93 104.57 3,451.88 3,391.23 -242.83 6,063.72 6,007,710.21 535,369.42 0.90 6,063.72 MWD+IFR-AK-CAZ-SC(6) 9,156.90 90.29 105.09 3,452.51 3,391.86 -266.47 6,152.99 6,007,686.93 535,458.78 1.58 6,152.99 MWD+IFR-AK-CAZ-SC(6) 9,248.99 88.81 104.43 3,453.23 3,392.58 -289.93 6,242.03 6,007,663.82 535,547.91 1.76 6,242.03 MWD+IFR-AK-CAZ-SC(6) 9,342.43 88.31 103.52 3,455.58 3,394.93 -312.49 6,332.68 6,007,641.62 535,638.63 1.11 6,332.68 M1ND+IFR-AK-CAZSC(6) 9,435.44 92.32 103.29 3,455.07 3,394.42 -334.05 6,423.13 6,007,620.42 535,729.16 4.32 6,423.13 MWD+IFR-AK-CAZSC(6) 9,527.14 93.06 102.70 3,450.77 3,390.12 -354.64 6,512.39 6,007,600.18 535,818.48 1.03 6,512.39 MWD+IFR-AK-CAZSC(6) 9,619.31 92.82 100.34 3,446.04 3,385.39 -373.03 6,602.57 6,007,582.15 535,908.73 2.57 6,602.57 MWD+IFR-AK-CAZSC(6) 9,713.12 89.79 99.05 3,443.90 3,383.25 -388.82 6,695.01 6,007,566.72 536,001.22 3.51 6,695.01 MWD+IFR-AK-CAZ-SC(6) 9,805.96 88.31 98.20 3,445.44 3,384.79 -402.74 6,786.78 6,007,553.17 536,093.04 1.84 6,786.78 MWD+IFR-AK-CAZ-SC(6) 9,898.40 88.56 99.29 3,447.97 3,387.32 -416.79 6,878.11 6,007,539.48 536,184.41 1.21 6,878.11 MWD+IFR-AK-CAZ-SC(6) 9,990.81 88.19 102.12 3,450.59 3,389.94 -433.94 6,968.87 6,007,522.68 536,275.23 3.09 6,968.87 MWD+IFR-AK-CAZ-SC(6) 10,083.31 87.08 102.46 3,454.40 3,393.75 -453.61 7,059.17 6,007,503.36 536,365.60 1.25 7,059.17 MWD+IFR-AK-CAZ-SC(6) 10,176.24 88.19 103.02 3,458.24 3,397.59 -474.09 7,149.73 6,007,483.25 536,456.23 1.34 7,149.73 MWD+IFR-AK-CAZSC(6) 10,268.78 89.05 103.56 3,460.47 3,399.82 -495.36 7,239.77 6,007,462.33 536,546.34 1.10 7,239.77 MWD+IFR-AK-CAZSC(6) 10,361.30 89.05 103.20 3,462.00 3,401.35 -516.76 7,329.76 6,007,441.28 536,636.41 0.39 7,329.76 MWD+IFR-AK-CAZSC(6) 10,454.22 87.88 99.47 3,464.49 3,403.84 -535.02 7,420.82 6,007,423.39 536,727.53 4.21 7,420.82 MWD+IFR-AK-CAZ-SC(6) 10,546.97 88.13 98.86 3,467.72 3,407.07 -549.78 7,512.33 6,007,408.99 536,819.09 0.71 7,512.33 MWD+IFR-AK-CAZ-SC(6) 2/19/2013 10:45:36AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,639.40 87.63 98.51 3,471.14 3,410.49 -563.73 7,603.64 6,007,395.40 536,910.44 0.66 7,603.64 MWD+IFR-AK-CAZ-SC(6) 10,731.05 87.88 98.13 3,474.73 3,414.08 -576.98 7,694.25 6,007,382.51 537,001.10 0.50 7,694.25 MWD+IFR-AK-CAZ-SC(6) 10,824.71 89.24 99.33 3,477.08 3,416.43 -591.19 7,786.79 6,007,368.66 537,093.68 1.94 7,786.79 MWD+IFR-AK-CAZ-SC(6) 10,916.72 85.78 97.84 3,481.08 3,420.43 -604.91 7,877.67 6,007,355.30 537,184.61 4.09 7,877.67 MWD+IFR-AK-CAZ-SC(6) 11,009.67 85.41 97.19 3,488.22 3,427.57 -617.03 7,969.55 6,007,343.54 537,276.52 0.80 7,969.55 MWD+IFR-AK-CAZ-SC(6) 11,102.92 86.21 98.18 3,495.03 3,434.38 -629.47 8,061.71 6,007,331.47 537,368.72 1.36 8,061.71 MWD+IFR-AK-CAZ-SC(6) 11,195.78 87.08 98.14 3,500.47 3,439.82 -642.63 8,153.47 6,007,318.67 537,460.53 0.94 8,153.47 MWD+IFR-AK-CAZ-SC(6) 11,286.90 87.51 98.55 3,504.77 3,444.12 -655.84 8,243.53 6,007,305.81 537,550.62 0.65 8,243.53 MWD+IFR-AK-CAZ-SC(6) 11,380.69 88.50 98.99 3,508.03 3,447.38 -670.13 8,336.16 6,007,291.89 537,643.31 1.15 8,336.16 MWD+IFR-AK-CAZ-SC(6) 11,473.41 88.31 98.49 3,510.61 3,449.96 -684.21 8,427.77 6,007,278.17 537,734.96 0.58 8,427.77 MWD+IFR-AK-CAZ-SC(6) 11,565.66 89.05 98.04 3,512.74 3,452.09 -697.47 8,519.04 6,007,265.27 537,826.27 0.94 8,519.04 MWD+IFR-AK-CAZ-SC(6) 11,658.81 87.88 95.54 3,515.23 3,454.58 -708.48 8,611.49 6,007,254.62 537,918.76 2.96 8,611.49 MWD+IFR-AK-CAZ-SC(6) 11,751.21 85.28 94.95 3,520.75 3,460.10 -716.91 8,703.33 6,007,246.56 538,010.62 2.89 8,703.33 MWD+IFR-AK-CAZ-SC(6) 11,843.79 85.77 95.81 3,527.97 3,467.32 -725.56 8,795.22 6,007,238.26 538,102.53 1.07 8,795.22 MWD+IFR-AK-CAZ-SC(6) 11,936.22 85.10 96.14 3,535.33 3,474.68 -735.16 8,886.86 6,007,229.03 538,194.20 0.81 8,886.86 MWD+IFR-AK-CAZ-SC(6) 12,029.57 88.43 98.76 3,540.59 3,479.94 -747.24 8,979.25 6,007,217.31 538,286.63 4.54 8,979.25 MWD+IFR-AK-CAZ-SC(6) 12,123.38 89.05 97.28 3,542.66 3,482.01 -760.32 9,072.12 6,007,204.59 538,379.54 1.71 9,072.12 MWD+IFR-AK-CAZ-SC(6) 12,216.22 90.35 96.54 3,543.14 3,482.49 -771.49 9,164.28 6,007,193.79 538,471.73 1.61 9,164.28 MWD+IFR-AK-CAZ-SC(6) 12,307.38 89.05 96.46 3,543.62 3,482.97 -781.81 9,254.85 6,007,183.83 538,562.33 1.43 9,254.85 MWD+IFR-AK-CAZ-SC(6) 12,400.71 86.77 95.64 3,547.02 3,486.37 -791.64 9,347.59 6,007,174.36 538,655.10 2.60 9,347.59 MWD+IFR-AK-CAZ-SC(6) 12,493.16 88.37 96.77 3,550.94 3,490.29 -801.63 9,439.41 6,007,164.74 538,746.96 2.12 9,439.41 MWD+IFR-AK-CAZSC(6) 12,585.79 89.48 98.22 3,552.68 3,492.03 -813.71 9,531.23 6,007,153.02 538,838.81 1.97 9,531.23 MWD+IFR-AK-CAZ-SC(6) 12,638.32 88.44 96.29 3,553.64 3,492.99 -820.34 9,583.33 6,007,146.59 538,890.93 4.17 9,583.33 MWD+IFR-AK-CAZSC(6) 12,714.00 88.44 96.29 3,555.70 3,495.05 -828.63 9,658.53 6,007,138.60 538,966.15 0.00 9,658.53 PROJECTED to TD 2/19/2013 10:45:36AM Page 7 COMPASS 2003.16 Build 69 r ConocoPhillips (Alaska) Inc NAD27 Kuparuk River Unit Kuparuk 3K Pad 3K-105L1 PB1 API:500292347972 - PTD:212-166 Sn+ rry Drilling Services Definitive Survey Report 19 February, 2013 11 Sperry Drilling Services ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1PB1 Database: EDM 2003.16 Single User Db Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3K-105 Well Position +N/-S 0.00 ft Northing: 6,007,929.20 ft Latitude: 70°25'57.87 N +E/-W 0.00 ft Easting: 529,305.40 ft Longitude: 149°45'40.01 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.30 ft Wellbore 3K-105L1PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2011 1/20/2013 20.17 81.03 57,633 Design 3K-105L1PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 5,028.47 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 27.35 0.00 0.00 90.00 Survey Program Date 2/15/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 77.00 1,003.00 3K-105(3K-105PB1) GYD-GC-SS Gyrodata gyro single shots 12/25/2012 1,088.07 2,332.08 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 2,333.08 5,028.47 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 5,074.00 6,458.07 3K-105L1PB1(3K-105L1PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/21/2013 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°l (1 (ft) (ft) (ft) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 27.35 0.00 0.00 27.35 -33.30 0.00 0.00 6,007,929.20 529,305.40 0.00 0.00 UNDEFINED 77.00 0.48 77.44 77.00 16.35 0.05 0.20 6,007,929.25 529,305.60 0.97 0.20 GYD-GC-SS(1) 169.00 0.59 27.28 169.00 108.35 0.55 0.80 6,007,929.75 529,306.19 0.50 0.80 GYD-GC-SS(1) 200.00 0.79 23.15 199.99 139.34 0.89 0.95 6,007,930.09 529,306.35 0.66 0.95 GYD-GC-SS(1) 263.00 0.84 1.44 262.99 202.34 1.75 1.14 6,007,930.95 529,306.53 0.49 1.14 GYD-GC-SS(1) 355.00 1.71 317.84 354.97 294.32 3.44 0.23 6,007,932.64 529,305.62 1.35 0.23 GYD-GC-SS(1) 401.00 4.10 305.91 400.90 340.25 4.91 -1.56 6,007,934.11 529,303.82 5.33 -1.56 GYD-GC-SS(1) 447.00 7.20 300.72 446.67 386.02 7.35 -5.37 6,007,936.53 529,300.00 6.82 -5.37 GYD-GC-SS(1) 493.00 9.53 299.99 492.18 431.53 10.73 -11.15 6,007,939.88 529,294.21 5.07 -11.15 GYD-GC-SS(1) 539.00 9.69 299.10 537.54 476.89 14.51 -17.83 6,007,943.64 529,287.51 0.47 -17.83 GYD-GC-SS(1) 632.00 10.55 304.26 629.09 568.44 23.11 -31.71 6,007,952.19 529,273.61 1.34 -31.71 GYD-GC-SS(1) 2/19/2013 10:46:49AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1001 (ft) Survey Tool Name 725.00 11.40 307.91 720.39 659.74 33.55 -45.99 6,007,962.57 529,259.28 1.18 -45.99 GYD-GC-SS(1) 818.00 11.59 312.49 811.53 750.88 45.51 -60.14 6,007,974.47 529,245.09 1.00 -60.14 GYD-GC-SS(1) 911.00 13.64 318.18 902.28 841.63 60.00 -74.34 6,007,988.90 529,230.83 2.58 -74.34 GYD-GC-SS(1) 1,003.00 16.78 327.72 991.06 930.41 79.32 -88.67 6,008,008.16 529,216.43 4.35 -88.67 GYD-GC-SS(1) 1,088.07 15.32 325.90 1,072.81 1,012.16 99.01 -101.53 6,008,027.80 529,203.49 1.82 -101.53 MWD+IFR-AK-CAZ-SC(2) 1,127.95 16.20 328.51 1,111.19 1,050.54 108.11 -107.39 6,008,036.88 529,197.60 2.83 -107.39 MWD+IFR-AK-CAZ-SC(2) 1,221.38 14.95 330.70 1,201.19 1,140.54 129.74 -120.10 6,008,058.45 529,184.81 1.48 -120.10 MWD+IFR-AK-CAZ-SC(2) 1,313.71 18.19 339.79 1,289.69 1,229.04 153.66 -130.91 6,008,082.33 529,173.90 4.48 -130.91 MWD+IFR-AK-CAZ-SC(2) 1,347.58 20.14' 343.21 1,321.68 1,261.03 164.20 -134.42 6,008,092.86 529,170.35 6.64 -134.42 MWD+IFR-AK-CAZ-SC(2) 1,377.82 19.65 343.07 1,350.12 1,289.47 174.05 -137.40 6,008,102.69 529,167.33 1.63 -137.40 MWD+IFR-AK-CAZ-SC(2) 1,406.44 18.90 344.95 1,377.13 1,316.48 183.13 -140.01 6,008,111.76 529,164.69 3.40 -140.01 MWD+IFR-AK-CAZ-SC(2) 1,438.76 19.82 346.59 1,407.63 1,346.98 193.52 -142.64 6,008,122.13 529,162.02 3.31 -142.64 MWD+IFR-AK-CAZ-SC(2) 1,470.35 21.47 349.96 1,437.19 1,376.54 204.42 -144.89 6,008,133.03 529,159.73 6.43 -144.89 MWD+IFR-AK-CAZ-SC(2) 1,500.11 22.47 351.78 1,464.79 1,404.14 215.41 -146.65 6,008,144.01 529,157.92 4.06 -146.65 MWD+IFR-AK-CAZ-SC(2) 1,532.75 23.94 354.73 1,494.79 1,434.14 228.18 -148.15 6,008,156.77 529,156.37 5.74 -148.15 MWD+IFR-AK-CAZ-SC(2) 1,563.13 25.06 355.99 1,522.43 1,461.78 240.74 -149.17 6,008,169.32 529,155.30 4.07 -149.17 MWD+IFR-AK-CAZSC(2) 1,593.70 25.07 356.15 1,550.12 1,489.47 253.66 -150.05 6,008,182.24 529,154.37 0.22 -150.05 MWD+IFR-AK-CAZSC(2) 1,635.67 24.21 357.97 1,588.27 1,527.62 271.13 -150.96 6,008,199.71 529,153.40 2.73 -150.96 MWD+IFR-AK-CAZSC(2) 1,684.66 25.03 0.96 1,632.81 1,572.16 291.53 -151.14 6,008,220.11 529,153.13 3.04 -151.14 MWD+IFR-AK-CAZSC(2) 1,728.85 26.01 3.40 1,672.69 1,612.04 310.55 -150.41 6,008,239.13 529,153.79 3.25 -150.41 MWD+IFR-AK-CAZ-SC(2) 1,777.86 26.71 6.71 1,716.60 1,655.95 332.22 -148.48 6,008,260.80 529,155.63 3.32 -148.48 MWD+IFR-AK-CAZ-SC(2) 1,825.53 26.87 11.84 1,759.16 1,698.51 353.41 -145.02 6,008,282.00 529,159.01 4.86 -145.02 MWD+IFR-AK-CAZ-SC(2) 1,870.48 27.34 17.21 1,799.18 1,738.53 373.21 -139.88 6,008,301.82 529,164.07 5.54 -139.88 M1ND+IFR-AK-CAZ-SC(2) 1,915.17 28.01 21.57 1,838.76 1,778.11 392.77 -132.99 6,008,321.41 529,170.89 4.77 -132.99 M1ND+IFR-AK-CAZ-SC(2) 1,962.97 27.67 25.52 1,881.03 1,820.38 413.23 -124.08 6,008,341.90 529,179.71 3.92 -124.08 MWD+IFR-AK-CAZ-SC(2) 2,009.47 26.46 28.88 1,922.44 1,861.79 432.05 -114.42 6,008,360.75 529,189.29 4.19 -114.42 MWD+IFR-AK-CAZ-SC(2) 2,056.28 25.81 34.48 1,964.47 1,903.82 449.58 -103.61 6,008,378.33 529,200.03 5.45 -103.61 MWD+IFR-AK-CAZSC(2) 2,101.78 24.27 39.24 2,005.70 1,945.05 464.99 -92.09 6,008,393.78 529,211.49 5.57 -92.09 MWD+IFR-AK-CAZSC(2) 2,147.42 24.42 44.55 2,047.29 1,986.64 478.98 -79.54 6,008,407.82 529,223.99 4.81 -79.54 MWD+IFR-AK-CAZSC(2) 2,194.78 23.70 48.18 2,090.53 2,029.88 492.30 -65.57 6,008,421.19 529,237.90 3.47 -65.57 MWD+IFR-AK-CAZ-SC(2) 2,240.00 23.41 53.80 2,131.99 2,071.34 503.67 -51.55 6,008,432.62 529,251.88 5.01 -51.55 MWD+IFR-AK-CAZ-SC(2) 2,287.66 23.01 61.83 2,175.81 2,115.16 513.66 -35.69 6,008,442.67 529,267.69 6.69 -35.69 MWD+IFR-AK-CAZ-SC(2) 2,333.08 23.90 66.93 2,217.48 2,156.83 521.46 -19.40 6,008,450.53 529,283.95 4.88 -19.40 MWD+IFR-AK-CAZ-SC(3) 2,387.65 24.31 70.83 2,267.29 2,206.64 529.48 1.38 6,008,458.63 529,304.70 3.01 1.38 MWD+IFR-AK-CAZ-SC(3) 2,437.33 25.10 75.02 2,312.43 2,251.78 535.56 21.22 6,008,464.79 529,324.51 3.87 21.22 MWD+IFR-AK-CAZ-SC(3) 2,479.65 26.14 80.26 2,350.59 2,289.94 539.46 39.08 6,008,468.76 529,342.36 5.89 39.08 MWD+IFR-AK-CAZ-SC(3) 2,524.98 27.52 85.29 2,391.05 2,330.40 542.01 59.36 6,008,471.39 529,362.63 5.86 59.36 MWD+IFR-AK-CAZ-SC(3) 2,573.03 27.87 89.03 2,433.59 2,372.94 543.11 81.66 6,008,472.58 529,384.92 3.69 81.66 MWD+IFR-AK-CAZ-SC(3) 2,619.93 27.52 93.60 2,475.13 2,414.48 542.62 103.44 6,008,472.17 529,406.69 4.59 103.44 MWD+IFR-AK-CAZ-SC(3) 2,665.88 28.07 99.63 2,515.60 2,454.95 540.15 124.60 6,008,469.78 529,427.87 6.26 124.60 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:46:49AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) b Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 2,712.74 28.97 103.31 2,556.96 2,496.31 535.68 146.61 6,008,465.40 529,449.89 4.19 146.61 MWD+IFR-AK-CAZ-SC(3) 2,758.64 30.01 106.76 2,596.91 2,536.26 529.81 168.42 6,008,459.61 529,471.72 4.34 168.42 MWD+IFR-AK-CAZ-SC(3) 2,803.41 32.67 110.90 2,635.15 2,574.50 522.27 190.44 6,008,452.16 529,493.76 7.64 190.44 MWD+IFR-AK-CAZ-SC(3) 2,850.11 35.38 113.24 2,673.85 2,613.20 512.43 214.64 6,008,442.42 529,518.00 6.44 214.64 MWD+IFR-AK-CAZ-SC(3) 2,895.36 35.81 11338 2,710.65 2,650.00 502.01 238.83 6,008,432.09 529,542.23 0.97 238.83 MWD+IFR-AK-CAZ-SC(3) 2,941.81 37.89 113.64 2,747.82 2,687.17 490.90 264.37 6,008,421.08 529,567.81 4.49 264.37 MWD+IFR-AK-CAZ-SC(3) 2,989.56 39.89 114.58 2,784.98 2,724.33 478.65 291.73 6,008,408.94 529,595.22 4.37 291.73 MWD+IFR-AK-CAZ-SC(3) 3,035.74 42.01 116.01 2,819.86 2,759.21 465.71 319.09 6,008,396.11 529,622.62 5.02 319.09 MWD+IFR-AK-CAZ-SC(3) 3,082.63 44.43 117.28 2,854.03 2,793.38 451.30 347.78 6,008,381.82 529,651.37 5.48 347.78 MWD+IFR-AK-CAZ-SC(3) 3,127.76 46.91 116.60 2,885.56 2,824.91 436.68 376.56 6,008,367.31 529,680.20 5.60 376.56 MWD+IFR-AK-CAZ-SC(3) 3,174.72 49.00 116.04 2,917.01 2,856.36 421.22 407.82 6,008,351.98 529,711.52 4.54 407.82 MWD+IFR-AK-CAZ-SC(3) 3,223.90 51.75 116.29 2,948.37 2,887.72 404.52 441.81 6,008,335.41 529,745.57 5.61 441.81 MWD+IFR-AK-CAZ-SC(3) 3,269.18 54.81 115.83 2,975.44 2,914.79 388.58 474.41 6,008,319.60 529,778.24 6.81 474.41 MWD+IFR-AK-CAZ-SC(3) 3,314.13 58.00 115.82 3,000.31 2,939.66 372.27 508.11 6,008,303.43 529,811.99 7.10 508.11 MWD+IFR-AK-CAZ-SC(3) 3,360.92 59.18 115.01 3,024.70 2,964.05 355.14 544.18 6,008,286.43 529,848.13 2.92 544.18 MWD+IFR-AK-CAZ-SC(3) 3,406.23 59.11 114.62 3,047.93 2,987.28 338.81 579.48 6,008,270.25 529,883.49 0.75 579.48 MWD+IFR-AK-CAZ-SC(3) 3,452.48 60.91 114.90 3,071.05 3,010.40 322.03 615.86 6,008,253.62 529,919.93 3.93 615.86 MWD+IFR-AK-CAZ-SC(3) 3,498.42 64.06 114.79 3,092.27 3,031.62 304.92 652.83 6,008,236.65 529,956.96 6.86 652.83 MWD+IFR-AK-CAZ-SC(3) 3,545.13 66.91 114.55 3,111.65 3,051.00 287.18 691.44 6,008,219.07 529,995.64 6.12 691.44 MWD+IFR-AK-CAZ-SC(3) 3,592.72 69.61 115.64 3,129.28 3,068.63 268.43 731.47 6,008,200.48 530,035.74 6.06 731.47 MWD+IFR-AK-CAZ-SC(3) 3,638.45 72.00 114.63 3,144.31 3,083.66 250.09 770.57 6,008,182.29 530,074.90 5.63 770.57 MWD+IFR-AK-CAZ-SC(3) 3,685.67 74.61 115.18 3,157.88 3,097.23 231.04 811.58 6,008,163.41 530,115.99 5.64 811.58 MWD+IFR-AK-CAZ-SC(3) 3,729.51 78.02 116.62 3,168.25 3,107.60 212.44 849.89 6,008,144.95 530,154.37 8.41 849.89 MWD+IFR-AK CAZ SC(3) 3,777.86 80.43 115.74 3,177.28 3,116.63 191.49 892.51 6,008,124.17 530,197.07 5.30 892.51 MWD+IFR-AK-CAZ-SC(3) 3,824.74 81.42 115.56 3,184.68 3,124.03 171.45 934.25 6,008,104.30 530,238.87 2.15 934.25 MWD+IFR-AK-CAZ-SC(3) 3,870.07 82.71 112.73 3,190.94 3,130.29 153.09 975.21 6,008,086.10 530,279.90 6.81 975.21 MWD+IFR-AK-CAZ-SC(3) 3,917.96 81.73 110.38 3,197.42 3,136.77 135.65 1,019.34 6,008,068.84 530,324.09 5.27 1,019.34 MWD+IFR-AK-CAZ-SC(3) 3,961.92 80.86 108.84 3,204.08 3,143.43 121.07 1,060.27 6,008,054.42 530,365.08 3.99 1,060.27 MWD+IFR-AK-CAZ-SC(3) 4,008.60 79.75 107.13 3,211.94 3,151.29 106.86 1,104.03 6,008,040.39 530,408.89 4.32 1,104.03 MWD+IFR-AK-CAZ-SC(3) 4,055.79 79.39 107.74 3,220.48 3,159.83 92.96 1,148.31 6,008,026.66 530,453.22 1.48 1,148.31 MWD+IFR-AK-CAZ-SC(3) 4,102.79 78.75 107.42 3,229.39 3,168.74 79.02 1,192.30 6,008,012.89 530,497.26 1.52 1,192.30 MWD+IFR-AK-CAZSC(3) 4,148.74 78.07 107.36 3,238.62 3,177.97 65.57 1,235.25 6,007,999.61 530,540.27 1.49 1,235.25 MWD+IFR-AK-CAZSC(3) 4,241.40 76.59 107.33 3,258.95 3,198.30 38.62 1,321.54 6,007,973.00 530,626.65 1.60 1,321.54 MWD+IFR-AK-CAZSC(3) 4,289.60 77.29 108.06 3,269.84 3,209.19 24.34 1,366.28 6,007,958.91 530,671.43 2.07 1,366.28 MWD+IFR-AK-CAZSC(3) 4,333,51 78.98 108.17 3,278.87 3,218.22 10.98 1,407.12 6,007,945.71 530,712.32 3.86 1,407.12 MWD+IFR-AK-CAZ-SC(3) 4,381.30 79.68 107.73 3,287.71 3,227.06 -3.49 1,451.79 6,007,931.41 530,757.05 1.72 1,451.79 MWD+IFR-AK-CAZ-SC(3) 4,422.48 80.65 108.26 3,294.75 3,234.10 -16.03 1,490.38 6,007,919.03 530,795.69 2.68 1,490.38 MWD+IFR-AK-CAZ-SC(3) 4,518.60 78.95 106.13 3,311.77 3,251.12 -43.99 1,580.75 6,007,891.42 530,886.15 2.81 1,580.75 MWD+IFR-AK-CAZ-SC(3) 4,609.99 79.97 106.75 3,328.49 3,267.84 -69.42 1,666.92 6,007,866.33 530,972.41 1.30 1,666.92 MWD+IFR-AK-CAZ-SC(3) 4,701.74 79.72 104.61 3,344.67 3,284.02 -93.83 1,753.86 6,007,842.27 531,059.45 2.31 1,753.86 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:46:49AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,748.12 79.83 103.91 3,352.90 3,292.25 -105.07 1,798.10 6,007,831.20 531,103.72 1.50 1,798.10 MWD+IFR-AK-CAZ-SC(3) 4,794.29 80.01 102.66 3,360.98 3,300.33 -115.52 1,842.34 6,007,820.93 531,148.00 2.69 1,842.34 MWD+IFR-AK-CAZ-SC(3) 4,836.85 78.52 99.63 3,368.91 3,308.26 -123.60 1,883.36 6,007,813.01 531,189.05 7.82 1,883.36 MWD+IFR-AK-CAZ-SC(3) 4,889.05 78.18 98.33 3,379.45 3,318.80 -131.58 1,933.86 6,007,805.23 531,239.57 2.52 1,933.86 MWD+IFR-AK-CAZ-SC(3) 4,938.27 78.10 97.96 3,389.57 3,328.92 -138.41 1,981.54 6,007,798.59 531,287.27 0.75 1,981.54 MWD+IFR-AK-CAZ-SC(3) 4,980.41 77.23 97.23 3,398.57 3,337.92 -143.85 2,022.35 6,007,793.31 531,328.10 2.67 2,022.35 MWD+IFR-AK-CAZ-SC(3) 5,028.47 76.22 95.96 3,409.61 3,348.96 -149.22 2,068.81 6,007,788.12 531,374.58 3.32 2,068.81 MWD+IFR-AK-CAZ-SC(3) 5,074.00 78.01 97.04 3,419.76 3,359.11 -154.25 2,112.91 6,007,783.27 531,418.69 4.56 2,112.91 MWD+IFR-AK-CAZ-SC(4) 5,145.15 80.26 98.70 3,433.17 3,372.52 -163.82 2,182.12 6,007,773.97 531,487.93 3.91 2,182.12 MWD+IFR-AK-CAZ-SC(4) 5,203.98 82.44 100.05 3,442.02 3,381.37 -173.29 2,239.49 6,007,764.72 531,545.34 4.34 2,239.49 MWD+IFR-AK-CAZ-SC(4) 5,266.77 85.61 101.48 3,448.55 3,387.90 -184.96 2,300.83 6,007,753.30 531,606.72 5.53 2,300.83 MWD+IFR-AK-CAZ-SC(4) 5,325.50 89.32 102.17 3,451.15 3,390.50 -196.98 2,358.25 6,007,741.51 531,664.17 6.43 2,358.25 MWD+IFR-AK-CAZ-SC(4) 5,359.63 88.02 101.99 3,451.94 3,391.29 -204.12 2,391.62 6,007,734.50 531,697.56 3.85 2,391.62 MWD+IFR-AK-CAZ-SC(4) 5,388.59 88.89 101.44 3,452.72 3,392.07 -210.00 2,419.96 6,007,728.73 531,725.93 3.55 2,419.96 MWD+IFR-AK-CAZ-SC(4) 5,423.96 90.28 102.26 3,452.98 3,392.33 -217.26 2,454.58 6,007,721.61 531,760.57 4.56 2,454.58 MWD+IFR-AK-CAZ-SC(4) 5,481.83 91.17 100.17 3,45225 3,391.60 -228.51 2,511.33 6,007,710.58 531,817.36 3.93 2,511.33 MWD+IFR-AK-CAZ-SC(4) 5,574.70 90.04 95.80 3,451.27 3,390.62 -241.41 2,603.27 6,007,698.04 531,909.34 4.86 2,603.27 MWD+IFR-AK-CAZ-SC(4) 5,667.06 88.19 90.25 3,452.69 3,392.04 -246.28 2,695.45 6,007,693.53 532,001.53 6.33 2,695.45 MWD+IFR-AK-CAZ-SC(4) 5,713.57 88.31 87.86 3,454.11 3,393.46 -245.52 2,741.93 6,007,694.48 532,048.00 5.14 2,741.93 MWD+IFR-AK-CAZ-SC(4) 5,759.03 88.68 87.72 3,455.31 3,394.66 -243.76 2,787.34 6,007,696.41 532,093.40 0.87 2,787.34 MWD+IFR-AK-CAZ-SC(4) 5,851.41 88.68 86.39 3,457.44 3,396.79 -239.02 2,879.57 6,007,701.52 532,185.61 1.44 2,879.57 MWD+IFR-AK-CAZ-SC(4) 5,944.38 8924 86.78 3,459.12 3,398.47 -233.48 2,972.36 6,007,707.42 532,278.36 0.73 2,972.36 MWD+IFR-AK-CAZ-SC(4) 6,037.23 86.70 88.57 3,462.41 3,401.76 -229.72 3,065.07 6,007,711.55 532,371.04 3.35 3,065.07 MWD+IFR-AK-CAZ-SC(4) 6,129.90 86.83 88.59 3,467.64 3,406.99 -227.42 3,157.56 6,007,714.20 532,463.52 0.14 3,157.56 MWD+IFR-AK-CAZ-SC(4) 6,222.47 88.99 88.02 3,471.02 3,410.37 -224.69 3,250.02 6,007,717.30 532,555.96 2.41 3,250.02 MWD+IFR-AK-CAZ-SC(4) 6,314.91 92.14 88.64 3,470.11 3,409.46 -221.99 3,342.41 6,007,720.36 532,648.32 3.47 3,342.41 MWD+IFR-AK-CAZ-SC(4) 6,407.54 94.12 88.89 3,465.05 3,404.40 -220.00 3,434.87 6,007,722.72 532,740.77 2.15 3,434.87 MWD+IFR-AK-CAZ-SC(4) 6,458.07 93.07 88.46 3,461.88 3,401.23 -218.83 3,485.29 6,007,724.08 532,791.18 2.24 3,48529 MWD+IFR-AK-CAZ-SC(4) 6,534.00 93.07 88.46 3,457.81 3,397.16 -216.80 3,561.08 6,007,726.42 532,866.95 0.00 3,561.08 PROJECTED to TD 2/19/2013 10:46:49AM Page 5 COMPASS 2003.16 Build 69 a l ir ConocoPhillips (Alaska) Inc NAD27 Kuparuk River Unit Kuparuk 3K Pad 3K-105L1 PB2 API:500292347973 - PTD:212-166 e, 'v 4 i Br* err l �illinci ervice Definitive Survey Report 19 February, 2013 F 't � II sy °lr r 1 w ill cal 11111111111111R/MMIIIMMIONF9 will '1911111111111111111F -1111, MU Sperry Drilling Services ConocoPhillips(Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 PB2 Database: EDM 2003.16 Single User Db Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3K-105 Well Position +N/-S 0.00 ft Northing: 6,007,929.20 ft Latitude: 70°25'57.87 N +El-W 0.00 ft Easting: 529,305.40 ft Longitude: 149°45'40.01 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.30 ft Wellbore 3K-105L1PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength I°) (°) (nT) BGG M2011 1/26/2013 20.16 81.03 57,633 Design 3K-105L1PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,222.47 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 27.35 0.00 0.00 90.00 Survey Program Date 2/15/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 77.00 1,003.00 3K-105(3K-105PB1) GYD-GC-SS Gyrodata gyro single shots 12/25/2012 1,088.07 2,332.08 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 2,333.08 5,028.47 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 5,074.00 6,222.47 3K-105L1PB1(3K-105L1PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/21/2013 6,314.00 6,499.61 3K-105 PB2(3K-105L1PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/28/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (`) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.35 0.00 0.00 27.35 -33.30 0.00 0.00 6,007,929.20 529,305.40 0.00 0.00 UNDEFINED 77.00 0.48 77.44 77.00 16.35 0.05 0.20 6,007,929.25 529,305.60 0.97 0.20 GYD-GC-SS(1) 169.00 0.59 27.28 169.00 108.35 0.55 0.80 6,007,929.75 529,306.19 0.50 0.80 GYD-GC-SS(1) 200.00 0.79 23.15 199.99 139.34 0.89 0.95 6,007,930.09 529,306.35 0.66 0.95 GYD-GC-SS(1) 263.00 0.84 1.44 262.99 202.34 1.75 1.14 6,007,930.95 529,306.53 0.49 1.14 GYD-GC-SS(1) 355.00 1.71 317.84 354.97 294.32 3.44 0.23 6,007,932.64 529,305.62 1.35 0.23 GYD-GC-SS(1) 401.00 4.10 305.91 400.90 340.25 4.91 -1.56 6,007,934.11 529,303.82 5.33 -1.56 GYD-GC-SS(1) 447.00 7.20 300.72 446.67 386.02 7.35 -5.37 6,007,936.53 529,300.00 6.82 -5.37 GYD-GC-SS(1) 493.00 9.53 299.99 492.18 431.53 10.73 -11.15 6,007,939.88 529,294.21 5.07 -11.15 GYD-GC-SS(1) 539.00 9.69 299.10 537.54 476.89 14.51 -17.83 6,007,943.64 529,287.51 0.47 -17.83 GYD-GC-SS(1) 2/19/2013 10:47:39AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit ND Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 PB2 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (`) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 632.00 10.55 304.26 629.09 568.44 23.11 -31.71 6,007,952.19 529,273.61 1.34 -31.71 GYD-GC-SS(1) 725.00 11.40 307.91 720.39 659.74 33.55 -45.99 6,007,962.57 529,259.28 1.18 -45.99 GYD-GC-SS(1) 818.00 11.59 312.49 811.53 750.88 45.51 -60.14 6,007,974.47 529,245.09 1.00 -60.14 GYD-GC-SS(1) 911.00 13.64 318.18 902.28 841.63 60.00 -74.34 6,007,988.90 529,230.83 2.58 -74.34 GYD-GC-SS(1) 1,003.00 16.78 327.72 991.06 930.41 79.32 -88.67 6,008,008.16 529,216.43 4.35 -88.67 GYD-GC-SS(1) 1,088.07 15.32 325.90 1,072.81 1,012.16 99.01 -101.53 6,008,027.80 529,203.49 1.82 -101.53 MWD+IFR-AK-CAZ-SC(2) 1,127.95 16.20 328.51 1,111.19 1,050.54 108.11 -107.39 6,008,036.88 529,197.60 2.83 -107.39 MWD+IFR-AK-CAZ-SC(2) 1,221.38 14.95 330.70 1,201.19 1,140.54 129.74 -120.10 6,008,058.45 529,184.81 1.48 -120.10 MWD+IFR-AK-CAZSC(2) 1,313.71 18.19 339.79 1,289.69 1,229.04 153.66 -130.91 6,008,082.33 529,173.90 4.48 -130.91 MWD+IFR-AK-CAZ-SC(2) 1,347.58 20.14 343.21 1,321.68 1,261.03 164.20 -134.42 6,008,092.86 529,170.35 6.64 -134.42 MWD+IFR-AK-CAZSC(2) 1,377.82 19.65 343.07 1,350.12 1,289.47 174.05 -137.40 6,008,102.69 529,167.33 1.63 -137.40 MWD+IFR-AK-CAZ-SC(2) 1,406.44 18.90 344.95 1,377.13 1,316.48 183.13 -140.01 6,008,111.76 529,164.69 3.40 -140.01 MWD+IFR-AK-CAZ-SC(2) 1,438.76 19.82 346.59 1,407.63 1,346.98 193.52 -142.64 6,008,122.13 529,162.02 3.31 -142.64 MWD+IFR-AK-CAZ-SC(2) 1,470.35 21.47 349.96 1,437.19 1,376.54 204.42 -144.89 6,008,133.03 529,159.73 6.43 -144.89 M1ND+IFR-AK-CAZSC(2) 1,500.11 22.47 351.78 1,464.79 1,404.14 215.41 -146.65 6,008,144.01 529,157.92 4.06 -146.65 MWD+IFR-AK-CAZSC(2) 1,532.75 23.94 354.73 1,494.79 1,434.14 228.18 -148.15 6,008,156.77 529,156.37 5.74 -148.15 MWD+IFR-AK-CAZSC(2) 1,563.13 25.06 355.99 1,522.43 1,461.78 240.74 -149.17 6,008,169.32 529,155.30 4.07 -149.17 MWD+IFR-AK-CAZSC(2) 1,593.70 25.07 356.15 1,550.12 1,489.47 253.66 -150.05 6,008,182.24 529,154.37 0.22 -150.05 MWD+IFR-AK-CAZ-SC(2) 1,635.67 24.21 357.97 1,588.27 1,527.62 271.13 -150.96 6,008,199.71 529,153.40 2.73 -150.96 MWD+IFR-AK-CAZ-SC(2) 1,684.66 25.03 0.96 1,632.81 1,572.16 291.53 -151.14 6,008,220.11 529,153.13 3.04 -151.14 MWD+IFR-AK-CAZ-SC(2) 1,728.85 26.01 3.40 1,672.69 1,612.04 310.55 -150.41 6,008,239.13 529,153.79 3.25 -150.41 MWD+IFR-AK-CAZ-SC(2) 1,777.86 26.71 6.71 1,716.60 1,655.95 332.22 -148.48 6,008,260.80 529,155.63 3.32 -148.48 MWD+IFR-AK-CAZ-SC(2) j 1,825.53 26.87 11.84 1,759.16 1,698.51 353.41 -145.02 6,008,282.00 529,159.01 4.86 -145.02 MWD+IFR-AK-CAZ-SC(2) 1,870.48 27.34 17.21 1,799.18 1,738.53 373.21 -139.88 6,008,301.82 529,164.07 5.54 -139.88 MWD+IFR-AK-CAZ-SC(2) 1,915.17 28.01 21.57 1,838.76 1,778.11 392.77 -132.99 6,008,321.41 529,170.89 4.77 -132.99 MWD+IFR-AK-CAZ-SC(2) 1,962.97 27.67 25.52 1,881.03 1,820.38 413.23 -124.08 6,008,341.90 529,179.71 3.92 -124.08 MWD+IFR-AK-CAZ-SC(2) 2,009.47 26.46 28.88 1,922.44 1,861.79 432.05 -114.42 6,008,360.75 529,189.29 4.19 -114.42 MWD+IFR-AK-CAZ-SC(2) 2,056.28 25.81 34.48 1,964.47 1,903.82 449.58 -103.61 6,008,378.33 529,200.03 5.45 -103.61 MWD+IFR-AK-CAZ-SC(2) 2,101.78 24.27 39.24 2,005.70 1,945.05 464.99 -92.09 6,008,393.78 529,211.49 5.57 -92.09 M1ND+IFR-AK-CAZ-SC(2) 2,147.42 24.42 44.55 2,047.29 1,986.64 478.98 -79.54 6,008,407.82 529,223.99 4.81 -79.54 MWD+IFR-AK-CAZSC(2) 2,194.78 23.70 48.18 2,090.53 2,029.88 492.30 -65.57 6,008,421.19 529,237.90 3.47 -65.57 MWD+IFR-AK-CAZSC(2) 2,240.00 23.41 53.80 2,131.99 2,071.34 503.67 -51.55 6,008,432.62 529,251.88 5.01 -51.55 MWD+IFR-AK-CAZSC(2) 2,287.66 23.01 61.83 2,175.81 2,115.16 513.66 -35.69 6,008,442.67 529,267.69 6.69 -35.69 MWD+IFR-AK-CAZSC(2) 2,333.08 23.90 66.93 2,217.48 2,156.83 521.46 -19.40 6,008,450.53 529,283.95 4.88 -19.40 MWD+IFR-AK-CAZSC(3) 2,387.65 24.31 70.83 2,267.29 2,206.64 529.48 1.38 6,008,458.63 529,304.70 3.01 1.38 MWD+IFR-AK-CAZ-SC(3) 2,437.33 25.10 75.02 2,312.43 2,251.78 535.56 21.22 6,008,464.79 529,324.51 3.87 21.22 MWD+IFR-AK-CAZ-SC(3) 2,479.65 26.14 80.26 2,350.59 2,289.94 539.46 39.08 6,008,468.76 529,342.36 5.89 39.08 MWD+IFR-AK-CAZ-SC(3) 2,524.98 27.52 85.29 2,391.05 2,330.40 542.01 59.36 6,008,471.39 529,362.63 5.86 59.36 MWD+IFR-AK-CAZ-SC(3) 2,573.03 27.87 89.03 2,433.59 2,372.94 543.11 81.66 6,008,472.58 529,384.92 3.69 81.66 MWD+IFR-AK-CAZSC(3) 2,619.93 27.52 93.60 2,475.13 2,414.48 542.62 103.44 6,008,472.17 529,406.69 4.59 103.44 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:47:39AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105LIPB2 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 2,665.68 28.07 99.63 2,515.60 2,454.95 540.15 124.60 6,008,469.78 529,427.87 6.26 124.60 MWD+IFR-AK-CAZ-SC(3) 2,712.74 28.97 103.31 2,556.96 2,496.31 535.68 146.61 6,008,465.40 529,449.89 4.19 146.61 MWD+IFR-AK-CAZ-SC(3) 2,758.64 30.01 106.76 2,596.91 2,536.26 529.81 168.42 6,008,459.61 529,471.72 4.34 168.42 MWD+IFR-AK-CAZ-SC(3) 2,803.41 32.67 110.90 2,635.15 2,574.50 522.27 190.44 6,008,452.16 529,493.76 7.64 190.44 MWD+IFR-AK-CAZ-SC(3) 2,850.11 35.38 113.24 2,673.85 2,613.20 512.43 214.64 6,008,442.42 529,518.00 6.44 214.64 MWD+IFR-AK-CAZ-SC(3) 2,895.36 35.81 113.38 2,710.65 2,650.00 502.01 238.83 6,008,432.09 529,542.23 0.97 238.83 MWD+IFR-AK-CAZ-SC(3) 2,941.81 37.89 113.64 2,747.82 2,687.17 490.90 264.37 6,008,421.08 529,567.81 4.49 264.37 MWD+IFR-AK-CAZ-SC(3) 2,989.56 39.89 114.58 2,784.98 2,724.33 478.65 291.73 6,008,408.94 529,595.22 4.37 291.73 MWD+IFR-AK-CAZ-SC(3) 3,035.74 42.01 116.01 2,819.86 2,759.21 465.71 319.09 6,008,396.11 529,622.62 5.02 319.09 MWD+IFR-AK-CAZ-SC(3) 3,082.63 44.43 117.28 2,854.03 2,793.38 451.30 347.78 6,008,381.82 529,651.37 5.48 347.78 MWD+IFR-AK-CAZ-SC(3) 3,127.76 46.91 116.60 2,885.56 2,824.91 436.68 376.56 6,008,367.31 529,680.20 5.60 376.56 MWD+IFR-AK-CAZ-SC(3) 3,174.72 49.00 116.04 2,917.01 2,856.36 421.22 407.82 6,008,351.98 529,711.52 4.54 407.82 MWD+IFR-AK-CAZ-SC(3) 3,223.90 51.75 116.29 2,948.37 2,887.72 404.52 441.81 6,008,335.41 529,745.57 5.61 441.81 MWD+IFR-AK-CAZ-SC(3) 3,269.18 54.81 115.83 2,975.44 2,914.79 388.58 474.41 6,008,319.60 529,778.24 6.81 474.41 MWD+IFR-AK-CAZ-SC(3) 3,314.13 58.00 115.82 3,000.31 2,939.66 372.27 508.11 6,008,303.43 529,811.99 7.10 508.11 MWD+IFR-AK-CAZ-SC(3) 3,360.92 59.18 115.01 3,024.70 2,964.05 355.14 544.18 6,008,286.43 529,848.13 2.92 544.18 MWD+IFR-AK-CAZ-SC(3) 3,406.23 59.11 114.62 3,047.93 2,987.28 338.81 579.48 6,008,270.25 529,883.49 0.75 579.48 MWD+IFR-AK-CAZ-SC(3) 3,452.48 60.91 114.90 3,071.05 3,010.40 322.03 615.86 6,008,253.62 529,919.93 3.93 615.86 MWD+IFR-AK-CAZ-SC(3) 3,498.42 64.06 114.79 3,092.27 3,031.62 304.92 652.83 6,008,236.65 529,956.96 6.86 652.83 MWD+IFR-AK-CAZ-SC(3) 3,545.13 66.91 114.55 3,111.65 3,051.00 287.18 691.44 6,008,219.07 529,995.64 6.12 691.44 MWD+IFR-AK-CAZSC(3) 3,592.72 69.61 115.64 3,129.28 3,068.63 268.43 731.47 6,008,200.48 530,035.74 6.06 731.47 MWD+IFR-AK-CAZSC(3) 3,638.45 72.00 114.63 3,144.31 3,083.66 250.09 770.57 6,008,182.29 530,074.90 5.63 770.57 MWD+IFR-AK-CAZSC(3) 3,685.67 74.61 115.18 3,157.88 3,097.23 231.04 811.58 6,008,163.41 530,115.99 5.64 811.58 MWD+IFR-AK-CAZSC(3) 3,729.51 78.02 116.62 3,168.25 3,107.60 212.44 849.89 6,008,144.95 530,154.37 8.41 849.89 MWD+IFR-AK-CAZSC(3) 3,777.86 80.43 115.74 3,177.28 3,116.63 191.49 892.51 6,008,124.17 530,197.07 5.30 892.51 MWD+IFR-AK-CAZSC(3) 3,824.74 81.42 115.56 3,184.68 3,124.03 171.45 934.25 6,008,104.30 530,238.87 2.15 934.25 MWD+IFR-AK-CAZ-SC(3) 3,870.07 82.71 112.73 3,190.94 3,130.29 153.09 975.21 6,008,086.10 530,279.90 6.81 975.21 MWD+IFR-AK-CAZ-SC(3) 3,917.96 81.73 110.38 3,197.42 3,136.77 135.65 1,019.34 6,008,068.84 530,324.09 5.27 1,019.34 MWD+IFR-AK-CAZSC(3) 3,961.92 80.86 108.84 3,204.08 3,143.43 121.07 1,060.27 6,008,054.42 530,365.08 3.99 1,060.27 MWD+IFR-AK-CAZSC(3) 4,008.60 79.75 107.13 3,211.94 3,151.29 106.86 1,104.03 6,008,040.39 530,408.89 4.32 1,104.03 MWD+IFR-AK-CAZ-SC(3) 4,055.79 79.39 107.74 3,220.48 3,159.83 92.96 1,148.31 6,008,026.66 530,453.22 1.48 1,148.31 MWD+IFR-AK-CAZ-SC(3) 4,102.79 78.75 107.42 3,229.39 3,168.74 79.02 1,192.30 6,008,012.89 530,497.26 1.52 1,192.30 MWD+IFR-AK-CAZ-SC(3) 4,148.74 78.07 107.36 3,238.62 3,177.97 65.57 1,235.25 6,007,999.61 530,540.27 1.49 1,235.25 MWD+IFR-AK-CAZ-SC(3) 4,241.40 76.59 107.33 3,258.95 3,198.30 38.62 1,321.54 6,007,973.00 530,626.65 1.60 1,321.54 MWD+IFR-AK-CAZ-SC(3) 4,289.60 77.29 108.06 3,269.84 3,209.19 24.34 1,366.28 6,007,958.91 530,671.43 2.07 1,366.28 MWD+IFR-AK-CAZ-SC(3) 4,333.51 78.98 108.17 3,278.87 3,218.22 10.98 1,407.12 6,007,945.71 530,712.32 3.86 1,407.12 MWD+IFR-AK-CAZ-SC(3) 4,381.30 79.68 107.73 3,287.71 3,227.06 -3.49 1,451.79 6,007,931.41 530,757.05 1.72 1,451.79 MWD+IFR-AK-CAZ-SC(3) 4,422.48 80.65 108.26 3,294.75 3,234.10 -16.03 1,490.38 6,007,919.03 530,795.69 2.68 1,490.38 MWD+IFR-AK-CAZ-SC(3) 4,518.60 78.95 106.13 3,311.77 3,251.12 -43.99 1,580.75 6,007,891.42 530,886.15 2.81 1,580.75 MWD+IFR-AK-CAZ-SC(3) 4,609.99 79.97 106.75 3,328.49 3,267.84 -69.42 1,666.92 6,007,866.33 530,972.41 1.30 1,666.92 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:47:39AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105©60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105L1PB2 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 4,701.74 79.72 104.61 3,344.67 3,284.02 -93.83 1,753.86 6,007,842.27 531,059.45 2.31 1,753.86 MWD+IFR-AK-CAZ-SC(3) 4,748.12 79.83 103.91 3,352.90 3,292.25 -105.07 1,798.10 6,007,831.20 531,103.72 1.50 1,798.10 MWD+IFR-AK-CAZ-SC(3) 4,794.29 80.01 102.66 3,360.98 3,300.33 -115.52 1,842.34 6,007,820.93 531,148.00 2.69 1,842.34 MWD+IFR-AK-CAZ-SC(3) 4,836.85 78.52 99.83 3,368.91 3,308.26 -123.60 1,883.36 6,007,813.01 531,189.05 7.82 1,883.36 MWD+IFR-AK-CAZ-SC(3) 4,889.05 78.18 98.33 3,379.45 3,318.80 -131.58 1,933.86 6,007,805.23 531,239.57 2.52 1,933.86 MWD+IFR-AK-CAZ-SC(3) 4,938.27 78.10 97.96 3,389.57 3,328.92 -138.41 1,981.54 6,007,798.59 531,287.27 0.75 1,981.54 MWD+IFR-AK-CAZ-SC(3) 4,980.41 77.23 97.23 3,398.57 3,337.92 -143.85 2,022.35 6,007,793.31 531,328.10 2.67 2,022.35 MWD+IFR-AK-CAZ-SC(3) 5,028.47 76.22 95.96 3,409.61 3,348.96 -149.22 2,068.81 6,007,788.12 531,374.58 3.32 2,068.81 MWD+IFR-AK-CAZSC(3) 5,074.00 78.01 97.04 3,419.76 3,359.11 -154.25 2,112.91 6,007,783.27 531,418.69 4.56 2,112.91 MWD+IFR-AK-CAZ-SC(4) 5,145.15 80.26 98.70 3,433.17 3,372.52 -163.82 2,182.12 6,007,773.97 531,487.93 3.91 2,182.12 MWD+IFR-AK-CAZ-SC(4) 5,203.98 82.44 100.05 3,442.02 3,381.37 -173.29 2,239.49 6,007,764.72 531,545.34 4.34 2,239.49 MWD+IFR-AK-CAZ-SC(4) 5,266.77 85.61 101.48 3,448.55 3,387.90 -184.96 2,300.83 6,007,753.30 531,606.72 5.53 2,300.83 MWD+IFR-AK-CAZ-SC(4) 5,325.50 89.32 102.17 3,451.15 3,390.50 -196.98 2,358.25 6,007,741.51 531,664.17 6.43 2,358.25 MWD+IFR-AK-CAZSC(4) 5,359.63 88.02 101.99 3,451.94 3,391.29 -204.12 2,391.62 6,007,734.50 531,697.56 3.85 2,391.62 M1ND+IFR-AK-CAZSC(4) 5,388.59 88.89 101.44 3,452.72 3,392.07 -210.00 2,419.96 6,007,728.73 531,725.93 3.55 2,419.96 MWD+IFR-AK-CAZSC(4) 5,423.96 90.28 102.26 3,452.98 3,392.33 -217.26 2,454.58 6,007,721.61 531,760.57 4.56 2,454.58 MWD+IFR-AK-CAZ-SC(4) 5,481.83 91.17 100.17 3,452.25 3,391.60 -228.51 2,511.33 6,007,710.58 531,817.36 3.93 2,511.33 MWD+IFR-AK-CAZ-SC(4) 5,574.70 90.04 95.80 3,451.27 3,390.62 -241.41 2,603.27 6,007,698.04 531,909.34 4.86 2,603.27 MWD+IFR-AK-CAZ-SC(4) 5,667.06 88.19 90.25 3,452.69 3,392.04 -246.28 2,695.45 6,007,693.53 532,001.53 6.33 2,695.45 MWD+IFR-AK-CAZ-SC(4) 5,713.57 88.31 87.86 3,454.11 3,393.46 -245.52 2,741.93 6,007,694.48 532,048.00 5.14 2,741.93 MWD+IFR-AK-CAZ-SC(4) 5,759.03 88.68 87.72 3,455.31 3,394.66 -243.76 2,787.34 6,007,696.41 532,093.40 0.87 2,787.34 MWD+IFR-AK-CAZ-SC(4) 5,851.41 88.68 86.39 3,457.44 3,396.79 -239.02 2,879.57 6,007,701.52 532,185.61 1.44 2,879.57 MWD+IFR-AK-CAZ-SC(4) 5,944.38 89.24 86.78 3,459.12 3,398.47 -233.48 2,972.36 6,007,707.42 532,278.36 0.73 2,972.36 MWD+IFR-AK-CAZ-SC(4) 6,037.23 86.70 88.57 3,462.41 3,401.76 -229.72 3,065.07 6,007,711.55 532,371.04 3.35 3,065.07 MWD+IFR-AK-CAZ-SC(4) 6,129.90 86.83 88.59 3,467.64 3,406.99 -227.42 3,157.56 6,007,714.20 532,463.52 0.14 3,157.56 MWD+IFR-AK-CAZ-SC(4) 6,222.47 88.99 88.02 3,471.02 3,410.37 -224.69 3,250.02 6,007,717.30 532,555.96 2.41 3,250.02 MWD+IFR-AK-CAZ-SC(4) 6,314.00 91.52 88.00 3,470.61 3,409.96 -221.51 3,341.49 6,007,720.84 532,647.40 2.76 3,341.49 MWD+IFR-AK-CAZ-SC(5) 6,408.44 92.82 87.48 3,467.03 3,406.38 -217.79 3,435.79 6,007,724.93 532,741.67 1.48 3,435.79 MWD+IFR-AK-CAZ-SC(5) 6,499.61 93.50 86.62 3,462.01 3,401.36 -213.10 3,526.70 6,007,729.97 532,832.56 1.20 3,526.70 MWD+IFR-AK-CAZ-SC(5) 6,586.00 93.50 86.62 3,456.73 3,396.08 -208.02 3,612.77 6,007,735.39 532,918.61 0.00 3,612.77 PROJECTED to TD 2/19/2013 10:47:39AM Page 5 COMPASS 2003.16 Build 69 L , E ConocoPhillips (Alaska) Inc NAD27 Kuparuk River Unit Kuparuk 3K Pad bi 3K-105L1 PB3 API:500292347974 - PTD:212-166 in Sperry Drilling Services Definitive Survey Report 19 February, 2013 IP i =r t, ;a P E q HALLIE URT®N Sperry Drilling Services ConocoPhillips(Alaska) Inc. Definitive Survey Report Company:, ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 PB3 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 PB3 Database: EDM 2003.16 Single User Db Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3K-105 Well Position +N/-S 0.00 ft Northing: 6,007,929.20 ft Latitude: 70°25'57.87 N +E/-W 0.00 ft Easting: 529,305.40 ft Longitude: 149°45'40.01 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.30ft Wellbore 3K-105L1PB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 1/20/2013 20.17 81.03 57,633 Design 3K-105L1PB3 .AMIIIk 1.001M IIi;uNL!1NIM@NIpP%''XdkS{N IBMI TIliIIOkHiiN186Ni PM'' I1MigiR lI kI NUN Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,129.90 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ff) (ft) (ft) r) 27.35 0.00 0.00 90.00 Survey Program Date 2/15/2013 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 77.00 1,003.00 3K-105(3K-105P81) GYD-GC-SS Gyrodata gyro single shots 12/25/2012 1,088.07 2,332.08 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 2,333.08 5,028.47 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 5,074.00 6,129.90 3K-105L1PB1(3K-105L1PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/21/2013 6,220.00 7,242.26 3K-105L1 PB3(3K-105L1 PB3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/25/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.35 0.00 0.00 27.35 -33.30 0.00 0.00 6,007,929.20 529,305.40 0.00 0.00 UNDEFINED 77.00 0.48 77.44 77.00 16.35 0.05 0.20 6,007,929.25 529,305.60 0.97 0.20 GYD-GC-SS(1) 169.00 0.59 27.28 169.00 108.35 0.55 0.80 6,007,929.75 529,306.19 0.50 0.80 GYD-GC-SS(1) 200.00 0.79 23.15 199.99 139.34 0.89 0.95 6,007,930.09 529,306.35 0.66 0.95 GYD-GC-SS(1) 263.00 0.84 1.44 262.99 202.34 1.75 1.14 6,007,930.95 529,306.53 0.49 1.14 GYD-GC-SS(1) 355.00 1.71 317.84 354.97 294.32 3.44 0.23 6,007,932.64 529,305.62 1.35 0.23 GYD-GC-SS(1) 401.00 4.10 305.91 400.90 340.25 4.91 -1.56 6,007,934.11 529,303.82 5.33 -1.56 GYD-GC-SS(1) 447.00 7.20 300.72 446.67 386.02 7.35 -5.37 6,007,936.53 529,300.00 6.82 -5.37 GYD-GC-SS(1) 493.00 9.53 299.99 492.18 431.53 10.73 -11.15 6,007,939.88 529,294.21 5.07 -11.15 GYD-GC-SS(1) 539.00 9.69 299.10 537.54 476.89 14.51 -17.83 6,007,943.64 529,287.51 0.47 -17.83 GYD-GC-SS(1) 2/19/2013 10:48:27AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1 PB3 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 PB3 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 632.00 10.55 304.26 629.09 568.44 23.11 -31.71 6,007,952.19 529,273.61 1.34 -31.71 GYD-GC-SS(1) 725.00 11.40 307.91 720.39 659.74 33.55 -45.99 6,007,962.57 529,259.28 1.18 -45.99 GYD-GC-SS(1) 818.00 11.59 312.49 811.53 750.88 45.51 -60.14 6,007,974.47 529,245.09 1.00 -60.14 GYD-GC-SS(1) 911.00 13.64 318.18 902.28 841.63 60.00 -74.34 6,007,988.90 529,230.83 2.58 -74.34 GYD-GC-SS(1) 1,003.00 16.78 327.72 991.06 930.41 79.32 -88.67 6,008,008.16 529,216.43 4.35 -88.67 GYD-GC-SS(1) 1,088.07 15.32 325.90 1,072.81 1,012.16 99.01 -101.53 6,008,027.80 529,203.49 1.82 -101.53 MWD+IFR-AK-CAZ-SC(2) 1,127.95 16.20 328.51 1,111.19 1,050.54 108.11 -107.39 6,008,036.88 529,197.60 2.83 -107.39 MWD+IFR-AK-CAZ-SC(2) 1,221.38 14.95 330.70 1,201.19 1,140.54 129.74 -120.10 6,008,058.45 529,184.81 1.48 -120.10 MWD+IFR-AK-CAZ-SC(2) 1,313.71 18.19 339.79 1,289.69 1,229.04 153.66 -130.91 6,008,082.33 529,173.90 4.48 -130.91 MWD+IFR-AK-CAZ-SC(2) 1,347.58 20.14 343.21 1,321.68 1,261.03 164.20 -134.42 6,008,092.86 529,170.35 6.64 -134.42 MWD+IFR-AK-CAZ-SC(2) 1,377.82 19.65 343.07 1,350.12 1,289.47 174.05 -137.40 6,008,102.69 529,167.33 1.63 -137.40 MWD+IFR-AK-CAZ-SC(2) 1,406.44 18.90 344.95 1,377.13 1,316.48 183.13 -140.01 6,008,111.76 529,164.69 3.40 -140.01 MWD+IFR-AK-CAZ-SC(2) 1,438.76 19.82 346.59 1,407.63 1,346.98 193.52 -142.64 6,008,122.13 529,162.02 3.31 -142.64 MWD+IFR-AK-CAZ-SC(2) 1,470.35 21.47 349.96 1,437.19 1,376.54 204.42 -144.89 6,008,133.03 529,159.73 6.43 -144.89 MWD+IFR-AK-CAZ-SC(2) 1,500.11 22.47 351.78 1,464.79 1,404.14 215.41 -146.65 6,008,144.01 529,157.92 4.06 -146.65 MWD+IFR-AK-CAZ-SC(2) 1,532.75 23.94 354.73 1,494.79 1,434.14 228.18 -148.15 6,008,156.77 529,156.37 5.74 -148.15 MWD+IFR-AK-CAZ-SC(2) 1,563.13 25.06 355.99 1,522.43 1,461.78 240.74 -149.17 6,008,169.32 529,155.30 4.07 -149.17 MWD+IFR-AK-CAZ-SC(2) 1,593.70 25.07 356.15 1,550.12 1,489.47 253.66 -150.05 6,008,182.24 529,154.37 0.22 -150.05 MWD+IFR-AK-CAZ-SC(2) 1,635.67 24.21 357.97 1,588.27 1,527.62 271.13 -150.96 6,008,199.71 529,153.40 2.73 -150.96 MWD+IFR-AK-CAZ-SC(2) 1,684.66 25.03 0.96 1,632.81 1,572.16 291.53 -151.14 6,008,220.11 529,153.13 3.04 -151.14 MWD+IFR-AK-CAZ-SC(2) 1,728.85 26.01 3.40 1,672.69 1,612.04 310.55 -150.41 6,008,239.13 529,153.79 3.25 -150.41 MWD+IFR-AK-CAZ-SC(2) 1,777.86 26.71 6.71 1,716.60 1,655.95 332.22 -148.48 6,008,260.80 529,155.63 3.32 -148.48 MWD+IFR-AK-CAZ-SC(2) 1,825.53 26.87 11.84 1,759.16 1,698.51 353.41 -145.02 6,008,282.00 529,159.01 4.86 -145.02 MWD+IFR-AK-CAZ-SC(2) 1,870.48 27.34 17.21 1,799.18 1,738.53 373.21 -139.88 6,008,301.82 529,164.07 5.54 -139.88 MWD+IFR-AK-CAZ-SC(2) 1,915.17 28.01 21.57 1,838.76 1,778.11 392.77 -132.99 6,008,321.41 529,170.89 4.77 -132.99 MWD+IFR-AK-CAZ-SC(2) 1,962.97 27.67 25.52 1,881.03 1,820.38 413.23 -124.08 6,008,341.90 529,179.71 3.92 -124.08 MWD+IFR-AK-CAZ-SC(2) 2,009.47 26.46 28.88 1,922.44 1,861.79 432.05 -114.42 6,008,360.75 529,189.29 4.19 -114.42 MWD+IFR-AK-CAZ-SC(2) 2,056.28 25.81 34.48 1,964.47 1,903.82 449.58 -103.61 6,008,378.33 529,200.03 5.45 -103.61 MWD+IFR-AK-CAZ-SC(2) 2,101.78 24.27 39.24 2,005.70 1,945.05 464.99 -92.09 6,008,393.78 529,211.49 5.57 -92.09 MWD+IFR-AK-CAZ-SC(2) 2,147.42 24.42 44.55 2,047.29 1,986.64 478.98 -79.54 6,008,407.82 529,223.99 4.81 -79.54 MWD+IFR-AK-CAZ-SC(2) 2,194.78 23.70 48.18 2,090.53 2,029.88 492.30 -6557 6,008,421.19 529,237.90 3.47 -65.57 MWD+IFR-AK-CAZ-SC(2) 2,240.00 23.41 53.80 2,131.99 2,071.34 503.67 -51.55 6,008,432.62 529,251.88 5.01 -51.55 MWD+IFR-AK-CAZ-SC(2) 2,287.66 23.01 61.83 2,175.81 2,115.16 513.66 -35.69 6,008,442.67 529,267.69 6.69 -35.69 MWD+IFR-AK-CAZ-SC(2) 2,333.08 23.90 66.93 2,217.48 2,156.83 521.46 -19.40 6,008,450.53 529,283.95 4.88 -19.40 MWD+IFR-AK-CAZ-SC(3) 2,387.65 24.31 70.83 2,267.29 2,206.64 529.48 1.38 6,008,458.63 529,304.70 3.01 1.38 MWD+IFR-AK-CAZ-SC(3) 2,437.33 25.10 75.02 2,312.43 2,251.78 535.56 21.22 6,008,464.79 529,324.51 3.87 21.22 MWD+IFR-AK-CAZ-SC(3) 2,479.65 26.14 80.26 2,350.59 2,289.94 539.46 39.08 6,008,468.76 529,342.36 5.89 39.08 MWD+IFR-AK-CAZ-SC(3) 2,524.98 27.52 85.29 2,391.05 2,330.40 542.01 59.36 6,008,471.39 529,362.63 5.86 59.36 MWD+IFR-AK-CAZ-SC(3) 2,573.03 27.87 89.03 2,433.59 2,372.94 543.11 81.66 6,008,472.58 529,384.92 3.69 81.66 MWD+IFR-AK-CAZ-SC(3) 2,619.93 27.52 93.60 2,475.13 2,414.48 542.62 103.44 6,008,472.17 529,406.69 4.59 103.44 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:48:27AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit TVD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB3 Survey Calculation Method: Minimum Curvature Design: 3K-105L1 PB3 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 2,665.68 28.07 99.63 2,515.60 2,454.95 540.15 124.60 6,008,469.78 529,427.87 6.26 124.60 MWD+IFR-AK-CAZ-SC(3) 2,712.74 28.97 103.31 2,556.96 2,496.31 535.68 146.61 6,008,465.40 529,449.89 4.19 146.61 MWD+IFR-AK-CAZ-SC(3) 2,758.64 30.01 106,76 2,596.91 2,536.26 529.81 168.42 6,008,459.61 529,471.72 4.34 168.42 MWD+IFR-AK-CAZ-SC(3) 2,803.41 32.67 110.90 2,635.15 2,574.50 522.27 190.44 6,008,452,16 529,493.76 7.64 190.44 MWD+IFR-AK-CAZ-SC(3) 2,850.11 35.38 113.24 2,673.85 2,613.20 512.43 214.64 6,008,442.42 529,518.00 6.44 214.64 MWD+IFR-AK-CAZ-SC(3) 2,895.36 35.81 113.38 2,710.65 2,650.00 502.01 238.83 6,008,432.09 529,542.23 0.97 238.83 MWD+IFR-AK-CAZ-SC(3) 2,941.81 37.89 113.64 2,747.82 2,687.17 490.90 264.37 6,008,421.08 529,567.81 4.49 264.37 MWD+IFR-AK-CAZ-SC(3) 2,989.56 39.89 114.58 2,784.98 2,724.33 478.65 291.73 6,008,408.94 529,595.22 4.37 291.73 MWD+IFR-AK-CAZ-SC(3) 3,035.74 42.01 116.01 2,819.86 2,759.21 465.71 319.09 6,008,396.11 529,622.62 5.02 319.09 MWD+IFR-AK-CAZ-SC(3) 3,082.63 44.43 117.28 2,854.03 2,793.38 451.30 347.78 6,008,381.82 529,651.37 5.48 347.78 MWD+IFR-AK-CAZ-SC(3) 3,127.76 46.91 116.60 2,885.56 2,824.91 436.68 376.56 6,008,367.31 529,680.20 5.60 376.56 MWD+IFR-AK-CAZ-SC(3) 3,174.72 49.00 116.04 2,917.01 2,856.36 421.22 407.82 6,008,351.98 529,711.52 4.54 407.82 MWD+IFR-AK-CAZ-SC(3) 3,223.90 51.75 116.29 2,948.37 2,887.72 404.52 441.81 6,008,335.41 529,745.57 5.61 441.81 MWD+IFR-AK-CAZ-SC(3) 3,269.18 54.81 115.83 2,975.44 2,914.79 388.58 474.41 6,008,319.60 529,778.24 6.81 474.41 MWD+IFR-AK-CAZ-SC(3) 3,314.13 58.00 115.82 3,000.31 2,939.66 372.27 508.11 6,008,303.43 529,811.99 7.10 508.11 MWD+IFR-AK-CAZ-SC(3) 3,360.92 59.18 115.01 3,024.70 2,964.05 355.14 544.18 6,008,286.43 529,848.13 2.92 544.18 MWD+IFR-AK-CAZ-SC(3) 3,406.23 59.11 114.62 3,047.93 2,987.28 338.81 579.48 6,008,270.25 529,883.49 0.75 579.48 MWD+IFR-AK-CAZ-SC(3) 3,452.48 60.91 114.90 3,071.05 3,010.40 322.03 615.86 6,008,253.62 529,919.93 3.93 615.86 MWD+IFR-AK-CAZSC(3) 3,498.42 64.06 114.79 3,092.27 3,031.62 304.92 652.83 6,008,236.65 529,956.96 6.86 652.83 MWD+IFR-AK-CAZ-SC(3) 3,545.13 66.91 114.55 3,111.65 3,051.00 287.18 691.44 6,008,219.07 529,995.64 6.12 691.44 MWD+IFR-AK-CAZ-SC(3) 3,592.72 69.61 115.64 3,129.28 3,068.63 268.43 731.47 6,008,200.48 530,035.74 6.06 731.47 MWD+IFR-AK-CAZ-SC(3) 3,638.45 72.00 114.63 3,144.31 3,083.66 250.09 770.57 6,008,182.29 530,074.90 5.63 770.57 MWD+IFR-AK-CAZ-SC(3) 3,685.67 74.61 115.18 3,157.88 3,097.23 231.04 811.58 6,008,163.41 530,115.99 5.64 811.58 MWD+IFR-AK-CAZ-SC(3) 3,729.51 78.02 116.62 3,168.25 3,107.60 212.44 849.89 6,008,144.95 530,154.37 8.41 849.89 MWD+IFR-AK-CAZ-SC(3) 3,777.86 80.43 115.74 3,177.28 3,116.63 191.49 892.51 6,008,124.17 530,197.07 5.30 892.51 MWD+IFR-AK-CAZ-SC(3) 3,824.74 81.42 115.56 3,184.68 3,124.03 171.45 934.25 6,008,104.30 530,238.87 2.15 934.25 MWD+IFR-AK-CAZ-SC(3) 3,870.07 82.71 112.73 3,190.94 3,130.29 153.09 975.21 6,008,086.10 530,279.90 6.81 975.21 MWD+IFR-AK-CAZ-SC(3) 3,917.96 81.73 110.38 3,197.42 3,136.77 135.65 1,019.34 6,008,068.84 530,324.09 5.27 1,019.34 MWD+IFR-AK-CAZ-SC(3) 3,961.92 80.86 108.84 3,204.08 3,143.43 121.07 1,060.27 6,008,054.42 530,365.08 3.99 1,060.27 MWD+IFR-AK-CAZ-SC(3) 4,008.60 79.75 107.13 3,211.94 3,151.29 106.86 1,104.03 6,008,040.39 530,408.89 4.32 1,104.03 MWD+IFR-AK-CAZ-SC(3) 4,055.79 79.39 107.74 3,220.48 3,159.83 92.96 1,148.31 6,008,026.66 530,453.22 1.48 1,148.31 MWD+IFR-AK-CAZ-SC(3) 4,102.79 78.75 107.42 3,229.39 3,168.74 79.02 1,192.30 6,008,012.89 530,497.26 1.52 1,192.30 MWD+IFR-AK-CAZ-SC(3) 4,148.74 78.07 107.36 3,238.62 3,177.97 65.57 1,235.25 6,007,999.61 530,540.27 1.49 1,235.25 MWD+IFR-AK-CAZSC(3) 4,241.40 76.59 107.33 3,258.95 3,198.30 38.62 1,321.54 6,007,973.00 530,626.65 1.60 1,321.54 MWD+IFR-AK-CAZSC(3) 4,289.60 77.29 108.06 3,269.84 3,209.19 24.34 1,366.28 6,007,958.91 530,671.43 2.07 1,366.28 MWD+IFR-AK-CAZSC(3) 4,333.51 78.98 108.17 3,278.87 3,218.22 10.98 1,407.12 6,007,945.71 530,712.32 3.86 1,407.12 MWD+IFR-AK-CAZSC(3) 4,381.30 79.68 107.73 3,287.71 3,227.06 -3.49 1,451.79 6,007,931.41 530,757.05 1.72 1,451.79 MWD+IFR-AK-CAZSC(3) 4,422.48 80.65 108.26 3,294.75 3,234.10 -16.03 1,490.38 6,007,919.03 530,795.69 2.68 1,490.38 MWD+IFR-AK-CAZ-SC(3) 4,518.60 78.95 106.13 3,311.77 3,251.12 -43.99 1,580.75 6,007,891.42 530,886.15 2.81 1,580.75 MWD+IFR-AK-CAZ-SC(3) 4,609.99 79.97 106.75 3,328.49 3,267.84 -69.42 1,666.92 6,007,866.33 530,972.41 1.30 1,666.92 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:48:27AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc NAD27 Local Co-ordinate Reference: Well 3K-105 Project: Kuparuk River Unit ND Reference: 3K-105©60.65ft(D141(33.3+27.35)) Site: Kuparuk 3K Pad MD Reference: 3K-105 @ 60.65ft(D141(33.3+27.35)) Well: 3K-105 North Reference: True Wellbore: 3K-105L1PB3 Survey Calculation Method: Minimum Curvature Design: 3K-105L1PB3 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD WDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 4,701.74 79.72 104.61 3,344.67 3,284.02 -93.83 1,753.86 6,007,842.27 531,059.45 2.31 1,753.86 MWD+IFR-AK-CAZ-SC(3) 4,748.12 79.83 103.91 3,352.90 3,292.25 -105.07 1,798.10 6,007,831.20 531,103.72 1.50 1,798.10 MWD+IFR-AK-CAZ-SC(3) 4,794.29 80.01 102.66 3,360.98 3,300.33 -115.52 1,842.34 6,007,820.93 531,148.00 2.69 1,842.34 MWD+IFR-AK-CAZ-SC(3) 4,836.85 78.52 99.63 3,368.91 3,308.26 -123.60 1,883.36 6,007,813.01 531,189.05 7.82 1,883.36 MWD+IFR-AK-CAZ-SC(3) 4,889.05 78.18 98.33 3,379.45 3,318.80 -131.58 1,933.86 6,007,805.23 531,239.57 2.52 1,933.86 MWD+IFR-AK-CAZ-SC(3) 4,938.27 78.10 97.96 3,389.57 3,328.92 -138.41 1,981.54 6,007,798.59 531,287.27 0.75 1,981.54 MWD+IFR-AK-CAZ-SC(3) 4,980.41 77.23 97.23 3,398.57 3,337.92 -143.85 2,022.35 6,007,793.31 531,328.10 2.67 2,022.35 MWD+IFR-AK-CAZ-SC(3) 5,028.47 76.22 95.96 3,409.61 3,348.96 -149.22 2,068.81 6,007,788.12 531,374.58 3.32 2,068.81 MWD+IFR-AK-CAZ-SC(3) 5,074.00 78.01 97.04 3,419.76 3,359.11 -154.25 2,112.91 6,007,783.27 531,418.69 4.56 2,112.91 M1ND+IFR-AK-CAZ-SC(4) 5,145.15 80.26 98.70 3,433.17 3,372.52 -163.82 2,182.12 6,007,773.97 531,487.93 3.91 2,182.12 MWD+IFR-AK-CAZ-SC(4) 5,203.98 82.44 100.05 3,442.02 3,381.37 -173.29 2,239.49 6,007,764.72 531,545.34 4.34 2,239.49 MWD+IFR-AK-CAZ-SC(4) 5,266.77 85.61 101.48 3,448.55 3,387.90 -184.96 2,300.83 6,007,753.30 531,606.72 5.53 2,300.83 MWD+IFR-AK-CAZ-SC(4) 5,325.50 89.32 102.17 3,451.15 3,390.50 -196.98 2,358.25 6,007,741.51 531,664.17 6.43 2,358.25 MWD+IFR-AK-CAZ-SC(4) 5,359.63 88.02 101.99 3,451.94 3,391.29 -204.12 2,391.62 6,007,734.50 531,697.56 3.85 2,391.62 MWD+IFR-AK-CAZSC(4) 5,388.59 88.89 101.44 3,452.72 3,392.07 -210.00 2,419.96 6,007,728.73 531,725.93 3.55 2,419.96 MWD+IFR-AK-CAZSC(4) 5,423.96 90.28 102.26 3,452.98 3,392.33 -217.26 2,454.58 6,007,721.61 531,760.57 4.56 2,454.58 MWD+IFR-AK-CAZ-SC(4) 5,481.83 91.17 100.17 3,452.25 3,391.60 -228.51 2,511.33 6,007,710.58 531,817.36 3.93 2,511.33 M1ND+IFR-AK-CAZ-SC(4) 5,574.70 90.04 95.80 3,451.27 3,390.62 -241.41 2,603.27 6,007,698.04 531,909.34 4.86 2,603.27 MWD+IFR-AK-CAZ-SC(4) 5,667.06 88.19 90.25 3,452.69 3,392.04 -246.28 2,695.45 6,007,693.53 532,001.53 6.33 2,695.45 MWD+IFR-AK-CAZ-SC(4) 5,713.57 88.31 87.86 3,454.11 3,393.46 -245.52 2,741.93 6,007,694.48 532,048.00 5.14 2,741.93 MWD+IFR-AK-CAZ-SC(4) 5,759.03 88.68 87.72 3,455.31 3,394.66 -243.76 2,787.34 6,007,696.41 532,093.40 0.87 2,787.34 MWD+IFR-AK-CAZ-SC(4) 5,851.41 88.68 86.39 3,457.44 3,396.79 -239.02 2,879.57 6,007,701.52 532,185.61 1.44 2,879.57 MWD+IFR-AK-CAZ-SC(4) 5,944.38 89.24 86.78 3,459.12 3,398.47 -233.48 2,972.36 6,007,707.42 532,278.36 0.73 2,972.36 MWD+IFR-AK-CAZ-SC(4) 6,037.23 86.70 88.57 3,462.41 3,401.76 -229.72 3,065.07 6,007,711.55 532,371.04 3.35 3,065.07 MWD+IFR-AK-CAZ-SC(4) 6,129.90 86.83 88.59 3,467.64 3,406.99 -227.42 3,157.56 6,007,714.20 532,463.52 0.14 3,157.56 MWD+IFR-AK-CAZ-SC(4) 6,220.00 87.13 87.68 3,472.39 3,411.74 -224.50 3,247.49 6,007,717.49 532,553.42 1.06 3,247.49 MWD+IFR-AK-CAZ-SC(5) 6,315.54 87.32 83.71 3,477.02 3,416.37 -217.33 3,342.63 6,007,725.02 532,648.52 4.16 3,342.63 M1ND+IFR-AK-CAZ-SC(5) 6,408.04 88.56 81.47 3,480.34 3,419.69 -205.41 3,434.29 6,007,737.30 532,740.13 2.77 3,434.29 MWD+IFR-AK-CAZSC(5) 6,501.66 89.79 79.02 3,481.69 3,421.04 -189.55 3,526.53 6,007,753.52 532,832.30 2.93 3,526.53 MWD+IFR-AK-CAZSC(5) 6,593.61 93.44 78.75 3,479.10 3,418.45 -171.84 3,616.71 6,007,771.59 532,922.40 3.98 3,616.71 MWD+IFR-AK-CAZSC(5) 6,686.23 92.82 81.55 3,474.04 3,413.39 -156.02 3,707.82 6,007,787.76 533,013.44 3.09 3,707.82 MWD+IFR-AK-CAZ-SC(5) 6,778.97 92.14 82.75 3,470.03 3,409.38 -143.36 3,799.60 6,007,800.78 533,105.16 1.49 3,799.60 MWD+IFR-AK-CAZSC(5) 6,871.53 87.94 82.37 3,469.96 3,409.31 -131.38 3,891.36 6,007,813.12 533,196.86 4.56 3,891.36 MWD+IFR-AK-CAZ-SC(5) 6,964.03 89.11 81.71 3,472.34 3,411.69 -118.58 3,982.94 6,007,826.28 533,288.38 1.45 3,982.94 MWD+IFR-AK-CAZ-SC(5) 7,056.96 88.87 85.86 3,473.98 3,413.33 -108.52 4,075.29 6,007,836.70 533,380.68 4.47 4,075.29 MWD+IFR-AK-CAZ-SC(5) 7,149.78 89.55 93.33 3,475.26 3,414.61 -107.86 4,168.03 6,007,837.72 533,473.41 8.08 4,168.03 MWD+IFR-AK-CAZ-SC(5) 7,198.42 89.61 93.18 3,475.62 3,414.97 -110.63 4,216.59 6,007,835.15 533,521.97 0.33 4,216.59 MWD+IFR-AK-CAZSC(5) 7,242.26 89.18 92.44 3,476.08 3,415.43 -112.77 4,260.37 6,007,833.17 533,565.76 1.95 4,260.37 MWD+IFR-AK-CAZSC(5) 7,342.00 89.18 92.44 3,477.51 3,416.86 -117.02 4,360.01 6,007,829.32 533,665.41 0.00 4,360.01 PROJECTED to TD 2/19/2013 10:48:27AM Page 5 COMPASS 2003.16 Build 69 6w\\\\�/7,4. THE STATE Alaska Oil and Gas M �f�p �p l - _= ALAS Conservation Conservation Commission ^� GOVERNOR SEAN PARNELL 333 West Seventh Avenue OAN ^fib Anchorage, Alaska 99501-3572 11LA5 Main: 907.279.1433 Fax: 907.276.7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 3K-105L1 ConocoPhillips Alaska, Inc. Permit No: 212-166 Surface Location: 935' FSL, 315' FWL, SEC. 35, T13N, R9E, UM Bottomhole Location: 89' FSL, 568' FEL, SEC. 36, T13N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3K-105, Permit No 212- 165, API 50-029-23479-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, a/e4 Cathy P/Foerster Chair DATED this l s day of November, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA NOV 0 2 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL J -iP AOGCC 20 AAC 25.005 / i(• la.Type of Work: lb Proposed Well Class: Development-Oil Q Service-Winj [11 Single Zone [3 lc.Specify if well is proposed for: Drill ❑ Lateral ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name: 5. Bond. U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. • Bond No. 59-52-180 3K-105L1 • 3.Address: 6 Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12679' TVD: 3568' • Kuparuk River Field • 4a. Location of Well(Governmental Section) 7.Property Designation(Lease Number): Surface:935'FSL,315'FWL,Sec.35,T13N,R9E,UM , ADL 25519 • West Sak Oil Pool , . Top of Productive Horizon 8.Land Use Permit 13.Approximate Spud Date: 761'FSL,2417'FWL,Sec.35,T13N,R9E,UM 2555 12/15/2012 Total Depth: 9.Acres in Property. ?ic IIIA 2 LL-- 14.Distance to Pk li )� 89'FSL,568'FEL,Sec.36,T13N,R9E,UM 489 :(5,-.v Nearest Property: >1 mile ^'ac;�� p�- 7tc 1<i2tti, A.4(c4,' 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL. 62 feet 15.Distance to Neare W II Open, l 3K'/gyp 4 GL Elevation above MSL: 34 feet Surface:x- 529306 y- 6007929 Zone- 4 to Same Pool: 3�6-5647' M 16.Deviated wells: Kickoff depth 5028 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) u/4.2., Maximum Hole Angle: 98° deg Downhole: 1800 psig Surface: 1195 psig 18 Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade _ Coupling - Length MD TVD MD TVD (including stage data) 40" 20 x34" 94# K-55 Welded 80' 28' 28' 108' 108' 200 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 2447' 28' 28' 2475' 2356' 1438 sx ASLite,376 sx DeepCRETE 12.25" 9.625" 40# L-80 BTCM 5787' 28' 28' 5815' 3554' 487 sx DeepCRETE,406 sx DeepCR TE 6.75" 4.5" 11.6# L-80 Hydril 521 7650' 5028' 3426' - 12679' 3568' slotted liner - D (a_er_ Wf scoa( A.,4-,4-, 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft). Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments. Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25 050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: 3 22. I hereby certify that the foregoing is true and correct. Contact Monty Myers @ 265-6318 Email Monty.M.MyersaconocoDhillios.com Printed Name G. Alvord Title Alaska Drilling Manager Signature / j(-04tPhone:265-6120 Date /41(2.0(2_, • Commission Use Only Permit to Drill I API Number: I Permit Approval See cover letter Number: I( 4 l 6 JII 50- O (-,2 3-i 7'i -(DO (' Date. k\1‘ I for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed7hane,gas hydrates,or gas contained in shales: Other: 4 3 S-044 pct.: ^ BDP e S ti— Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No Je ie- LScr� l0 S` An n wt!-•-t- s t- H2S measures: Yes IZI No ❑ Directional svy req'd: Yes[ No❑ Spacing exception req'd: Yes ❑ No aInclination-only svy req'd: Yes❑ No d b APPROVED BY THE �— Approved by: /% r''—COMMISSIONER , COMMItsicN Date/7— / 5 Form 10-401(Revi-ed 10/2012) This permit is valid for 24 months from the data of approval(20 AAC 25.005(9)) 7,Q,` //1 ,Q,` ll•�'/L i2 ,Jf ' ?I�° (`l�� s ConocoPhilhi s p Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Myers Phone (907) 265-6318 November 9, 2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 3K-105, 3K-105 Ll Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore producer well, a horizontal well in the West Sak"B"and"D"sands. The main bore of the well will be designated 3K-105, and the lateral bore of the well will be designated 3K-105 L1. The expected spud date for 3K-105 is, December 15th 2012. The West Sak in the 3K area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 3K-105 well will be drilled down structure to the east with planned lateral lengths of approximately 7500'. Both laterals will cross a major, down-to-the-west fault with anticipated throw between 60 and 70 feet. D Sand pay is divided into two 10-15'intervals separated by about 10'of poorer quality sandy siltstone. This will require undulating the borehole in the D lateral between the upper and lower intervals to insure adequate contact with both sands. The B Sand lateral targets the upper 10 to 15 feet of the B Sand interval. There are no known H2S issues associated with the drilling of these wells or is it anticipated to see any pressures higher than 9.8 ppg equivalent during the drilling of these wells. A FIT test to a minimum of 11.6 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 11.8 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 3K-105. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 2500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production laterals of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sincerely, M. Myers Kuparuk Drilling Engineer Appli for Permit to Drill,Well 3K-105 L1 Revision No.0 Saved:29-Oct-12 Permit It - West Sak Well #3K-105 L1 Application for Permit to Drill Document MaxWell M Q x i th i z p Well Value Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(t) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 3 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) 4 Lateral Mud Program (Ml VersaPro Mineral Oil Base) 4 9. Abnormally Pressured Formation Information 4 Requirements of 20 AAC 25.005 (c)(9) 4 10.Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 11.Seabed Condition Analysis 5 Requirements of 20 AAC 25.005(c)(11) 5 12.Evidence of Bonding 5 Requirements of 20 AAC 25.005(c)(12) 5 3K-105 L1 PERMIT.doc Page 1 of 6 Printed:29-Oct-12 App i for Permit to Drill,Well 3K-105 L1 Revision No.(; Saved:29-Oct-12 13.Proposed Drilling Program 5 Requirements of 20 AAC 25.005(c)(13) 5 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 6 Requirements of 20 AAC 25.005(c)(14) 6 15.Attachments 6 Attachment 1 Directional Plan 6 Attachment 2 Drilling Hazards Summary 6 Attachment 3 Well Schematic 6 1. Well Name Requirements of 20 AAC 25.005(t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6).For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 3K-105 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 935' FSL, 315' FWL, Section 35, T13N, RO9E ASP Zone 4 NAD 27 Coordinates RKB Elevation 62.3'AMSL Northings 6,007,929' Eastings: 529,306' Pad Elevation 34.3'AMSL Location at Top of Productive Interval 761' FSL, 2417' FWL, Section 35, T13N, RO9E (West Sak"D"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 5028' Northings: 6,007,763' Eastings:531,408' Total Vertical Depth, RKB: 3426' Total Vertical Depth, SS:: 2085' Location at Total Depth 89' FSL, 568' FEL, Section 36,T13N, RO9E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12687' Northings: 6,007,128' Eastings: 538,986' Total Vertical Depth, PKB: 3622' Total Vertical Depth, SS: 3560' and (D)other information required by 20 AAC 25.050(6); 3K-105 L1 PERMIT.doc Page 2 of 6 Printed:29-Oct-12 • Appli for Permit to Drill,Well 3K-105 L1 Revision No.0 • Saved:30-Oct-12 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent we//bores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 3K-105 L1 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(DOPE)as required by 20 AAC 25.035,20 AAC 25.036, or 20 MC 25.037,as applicable; An API 13-5/8"x 5,000 psi BOP stack will be utilized to drill and complete well 3K-105 L1. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 3K area are 0.44 psi/ft, or 8.4 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the deepest planned vertical depth of the West Sak"B"sand formation is 1,197 psi, calculated thusly: MPSP = (3,628 ft TVD)(0.44 - 0.11 psi/ft) = 1,195 psi (B)data on potential gas zones; !/ The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 3K-105 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(f); The parent wellbore, 3K-105, will be completed with a 9-5/8" intermediate casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. No formation integrity test will be performed in the drilling of the 3K-105 L1. 3K-105 L1 PERMIT.doc Page 3 of 6 Printed:30-Oct-12 Appr i for Permit to Drill,Well 3K-105 L1 Revision No.0, Saved:30-Oct-12 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD(in) (in) t(Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 4-1/2 6-3/4"D Sand 11.6 L-80 Hydril 7650 5028/ 3426 12678/ 3568 Slotted-no cement Slotted Lateral(3K-105 Ll) 521 X BTCM 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on 3K-105 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (Ml VersaPro, Mineral Oil Base) Value Density(ppg) 9.6—9.8 Plastic Viscostiy 15-25 (lb/100 sf) Yield Point 15-20 (cP) HTHP Fluid loss(ml/30 <4.0 min @ 200psi& 150° Oil/Water Ratio 80/20 Electrical Stability 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(1); 3K-105 L1 PERMIT.doc Page 4 of 6 Printed:30-Oct-12 Applit for Permit to Drill,Well 3K-105 L1 Revision No.0 Saved:29-Oct-12 Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis- of nalysisof seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 3K-105 Application for Permit to Drill. 1. Run and set Baker Gen2 WindowMaster whipstock system, at window point of +/- 5028' MD/ 3426'TVD, the top of the D sand. 2. Mill 8-1/2"window. POOH. 3. Pick up 6-3/4"drilling assembly with MWD and LWD logging tools. RIH. 4. Drill to TD of West Sak D Sand lateral at +/- 12679 MD/ 3568'TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom &displace to solids-free oil based mud. Pump out of hole. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. • 7. RIH and set Baker Seal Bore diverter X—C) / j ash ''- / .. — 8. PU and run 4-1/2"slotted liner with Baker Oil Tools RAM Hangar system. 9. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH 10. Make up junction isolation / re-entry (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly (Torquemaster packer) and release from assembly. Pull out of hole laying down drillpipe as required. T "X"(e 11. PU Gas Lift completion as required and RIH to depth. Land tubing. Set BPV l 12. Nipple down BOPE, nipple up tree and test. Pull BPV. , Z J „ �,�� 3K-105 L1 PERMIT.doc Page 5 of 6 Printed:29-Oct-12 App i for Permit to Drill,Well 3K-105 L1 • Revision No.0, Saved:29-Oct-12 13. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 14. Set BPV and move rig off. 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 3K Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 3K Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 3K-105 L1 PERMIT.doc Page 6 of 6 t '`, i ` Printed:29-Oct-12 A 9 p g ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad Plan 3K-105 (E15) 3K-105L1 Plan: 3K-105L1 (wp12) Standard Proposal Report 04 October, 2012 HALLIBURTON Sperry Drilling Services II I 'II - N c>3 I I I d'I I - o Q 2 0 .-- 75.,r I I I rn bl I N - O = a y. 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(- a - v -‘0) 3 n \ ` ` c o Ua a \ - 0 In _o 3 ogre d a - 8 - x MI N _ O a —o o Z Y c - -. 000,-. en W _ U n N O °SG w W O. ^ Z J u, 3 - 0 0 c - J .1 M 0 -o u _ y`= d M - ti -o Vt 0 _ o —o W ' I , I I I I I I I I I I I I I I I I I I I M i l l i „ I p „ I , I I I I I I I I I I I I I , , , I , , j „ , , V I I I l I I I l I I I l I I J 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O0 0 0 0 0 0 0 0 J o en M N N N O '/t '.1 O v, o N o M o Qi ar OW OSZI)(+)quo1LI/(")illnog Y Halliburton -Sperry HALLIBURTOw Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-105(E15) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-105(E15) Survey Calculation Method: Minimum Curvature Wellbore: 3K-105L1 Design: 3K-105L1 (wp12) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3K Pad Site Position: Northing: 6,008,428.74 ft Latitude: 70°26'2.780 N From: Map Easting: 529,306.18ft Longitude: 149°45'39.930 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.23 ° Well Plan 3K-105(E15) Well Position +N/-S 0.00 ft Northing: 6,007,929.00 ft Latitude: 70°25'57.865 N +El-W 0.00 ft Easting: 529,305.43 ft Longitude: 149°45'40.009 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft I Wellbore 3K-105L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) 1 bggm2007 10/16/2007 17.98 79.80 57,264 Design 3K-105L1(wp12) Audit Notes: Version: 8 Phase: PLAN Tie On Depth: 5,028.47 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 90.00 J 10/4/2012 3:30:49PM Page 2 COMPASS 2003.16 Build 69 Halliburton -Sperry I-IALLIBURTI , Standard Propose! Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-105(E15) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-105(E15) Survey Calculation Method: Minimum Curvature Wellbore: 3K-105L1 Design: 3K-105L1 (wp12) -plan misses target center by 14.21ft at 5280.87ft MD(3460.33 TVD,-196.49 N,2333.18 E) -Polygon Point 1 3,468.30 -208.16 2,331.67 6,007,730.02 531,637.67 Point 2 3,495.22 -199.46 3,183.55 6,007,742.07 532,489.43 5,028.49 3,426.28 9 5/8"TOW 9-5/8 13-1/2 2,474.61 2,356.30 13 3/8"Surface Casing 13-3/8 16 12,678.83 3,568.30 4 1/2"Production Liner 4-1/2 6-3/4 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (ft) (ft) (ft) (ft) Comment 5,028.47 3,426.28 -171.17 2,084.70 TOW @ 5028'MD,3426'TVD:764'FSL,2399'FWL-Sec35-T13N-R09E 12,678.83 3,568.30 -839.21 9,677.97 TD @ 12679'MD,3568'TVD:89'FSL,568'FEL-Sec36-T13N-R09E 10/4/2012 3:30:49PM Page 6 COMPASS 2003.16 Build 69 Halliburton -Sperry I--IALLIBURTOR Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-105(E15) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-105(E15) Survey Calculation Method: Minimum Curvature Wellbore: 3K-105L1 Design: 3K-105L1 (wp12) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape C) C) (ft) (ft) (ft) (ft) (ft) 3K-105 L1 Heel(wp12) 2.52 98.51 3,458.30 -171.18 2,084.79 6,007,766.03 531,390.67 -plan misses target center by 31.24ft at 5035.17ft MD(3427.74 TVD,-172.12 N,2091.17 E) -Polygon Point 1 3,458.30 -171.18 2,084.79 6,007,766.03 531,390.67 Point 2 3,469.28 -208.10 2,331.59 6,007,730.08 531,637.59 3K-105 L1 CP9(wp12) 1.48 96.42 3,550.30 -731.49 8,990.32 6,007,232.91 538,297.66 -plan hits target center -Polygon Point 1 3,550.30 -731.49 8,990.32 6,007,232.91 538,297.66 Point 2 3,568.27 -839.19 9,678.19 6,007,127.92 538,985.88 3K-105 L1 CP7(wp12) 1.63 96.32 3,466.30 -371.80 6,543.47 6,007,582.95 535,849.67 -plan misses target center by 1.47ft at 9507.73ft MD(3467.74 TVD,-371.50 N,6543.51 E) -Polygon Point 1 3,466.30 -371.80 6,543.47 6,007,582.95 535,849.67 Point 2 3,527.87 -684.06 8,685.80 6,007,279.13 537,992.99 3K-105 L1 CP2(wp12) 1.20 88.68 3,495.30 -199.52 3,183.79 6,007,742.01 532,489.67 -plan hits target center -Polygon Point 1 3,495.30 -199.52 3,183.79 6,007,742.01 532,489.67 Point 2 3,502.32 -191.82 3,518.79 6,007,751.02 532,824.60 3K-105 L1 CP4(wp12) -8.41 96.73 3,490.30 -179.34 4,660.03 6,007,767.98 533,965.67 -plan hits target center -Polygon Point 1 3,490.30 -179.34 4,660.03 6,007,767.98 533,965.67 Point 2 3,423.32 -188.55 5,115.15 6,007,760.57 534,420.77 3K-105 L1 CP5(wp12) 1.65 97.32 3,442.30 -189.16 5,120.04 6,007,759.97 534,425.67 -plan misses target center by 5.65ft at 8072.27ft MD(3447.32 TVD,-191.74 N,5120.17 E) -Polygon Point 1 3,442.30 -189.16 5,120.04 6,007,759.97 534,425.67 Point2 3,473.34 -315.38 6,190.13 6,007,637.97 535,496.14 3K-105 L1 CP6(wp12) 2.06 98.09 3,473.30 -315.39 6,189.66 6,007,637.95 535,495.67 -plan hits target center -Polygon Point 1 3,473.30 -315.39 6,189.66 6,007,637.95 535,495.67 Point 2 3,486.18 -371.74 6,543.29 6,007,583.00 535,849.48 3K-105 L1 CP3(wp12) 0.40 89.37 3,482.30 -191.84 3,518.86 6,007,751.00 532,824.67 -plan misses target center by 2.83ft at 6468.19ft MD(3485.04 TVD,-192.54 N,3518.99 E) -Polygon Point 1 3,482.30 -191.84 3,518.86 6,007,751.00 532,824.67 Point 2 3,490.27 -179.26 4,660.34 6,007,768.06 533,965.98 3K-105 L1 Toe(wp12) 0.00 0.00 3,568.30 -839.21 9,677.97 6,007,127.90 538,985.66 -plan hits target center -Point 3K-105 L1 CP8(wp12) 0.37 89.63 3,528.30 -684.28 8,686.47 6,007,278.91 537,993.66 -plan hits target center -Polygon Point 1 3,528.30 -684.28 8,686.47 6,007,278.91 537,993.66 Point 2 3,530.26 -731.49 8,990.52 6,007,232.90 538,297.86 3K-105 D-sand Top(wp12) 0.00 0.26 3,426.30 -171.18 2,084.79 6,007,766.03 531,390.67 -plan hits target center -Point 3K-105 L1 CP1 w.12) 1.81 89.42 3,468.30 -208.16 2,331.67 6,007,730.02 531,637.67 10/4/2012 3:30:49PM Page 5 • COMPASS 2003.16 Build 69 Halliburton -Sperry . P-IALLIBURTOle Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-105(E15) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-105(E15) Survey Calculation Method: Minimum Curvature Wellbore: 3K-105L1 Design: 3K-105L1 (wp12) Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) • 5,028.47 77.00 98.51 3,426.28 3,363.98 -171.17 2,084.70 0.00 0.00 0.00 0.00 5,044.97 79.16 97.92 3,429.69 3,367.39 -173.47 2,100.68 13.56 13.10 -3.57 -15.00 5,074.97 79.16 97.92 3,435.33 3,373.03 -177.53 2,129.86 0.00 0.00 0.00 0.00 5,215.59 85.03 94.00 3,454.67 3,392.37 -191.95 2,268.31 5.00 4.17 -2.79 -33.80 5,371.47 85.03 94.00 3,468.19 3,405.89 -202.79 2,423.22 0.00 0.00 0.00 0.00 1 5,482.69 88.19 89.42 3,474.77 3,412.47 -206.10 2,534.15 5.00 2.85 -4.12 -55.47 6,132.69 88.19 89.42 3,495.30 3,433.00 -199.52 3,183.79 0.00 0.00 0.00 0.00 6,240.33 92.43 88.69 3,494.71 3,432.41 -197.74 3,291.39 4.00 3.94 -0.68 -9.76 6,486.53 92.43 88.69 3,484.26 3,421.96 -192.12 3,537.31 0.00 0.00 0.00 0.00 6,559.37 89.60 89.37 3,482.97 3,420.67 -190.89 3,610.12 4.00 -3.89 0.93 166.50 7,609.37 89.60 89.37 3,490.30 3,428.00 -179.34 4,660.03 0.00 0.00 0.00 0.00 7,837.46 98.44 91.63 3,474.32 3,412.02 -181.30 4,887.31 4.00 3.88 0.99 14.22 7,916.80 98.44 91.63 3,462.67 3,400.37 -183.53 4,965.76 0.00 0.00 0.00 0.00 8,199.35 88.35 96.73 3,445.95 3,383.65 -204.11 5,246.59 4.00 -3.57 1.81 153.02 9,149.35 88.35 96.73 3,473.30 3,411.00 -315.39 6,189.66 0.00 0.00 0.00 0.00 9,248.54 91.30 99.38 3,473.60 3,411.30 -329.29 6,287.86 4.00 2.98 2.67 41.89 9,495.77 91.30 99.38 3,467.97 3,405.67 -369.57 6,531.72 0.00 0.00 0.00 0.00 9,574.26 88.36 98.29 3,468.20 3,405.90 -381.62 6,609.27 4.00 -3.75 -1.39 -159.71 11,674.26 88.36 98.29 3,528.30 3,466.00 -684.28 8,686.47 0.00 0.00 0.00 0.00 11,749.37 85.42 98.91 3,532.37 3,470.07 -695.50 8,760.61 4.00 -3.91 0.83 168.03 11,931.36 85.42 98.91 3,546.90 3,484.60 -723.61 8,939.84 0.00 0.00 0.00 0.00 12,008.83 88.52 98.90 3,551.00 3,488.70 -735.59 9,016.26 4.00 4.00 -0.02 -0.28 12,678.83 88.52 98.90 3,568.30 3,506.00 -839.21 9,677.97 0.00 0.00 0.00 0.00 10/4/2012 3.30:49PM Page 3 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLI B U RTO Standard Proposa)Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-105(E15) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)@ 62.30ft(62.3'(34.3+28)) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-105(E15) Survey Calculation Method: Minimum Curvature Wellbore: 3K-105L1 Design: 3K-105L1 (wp12) r Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,363.98 5,028.47 77.00 98.51 3,426.28 3,363.98 -171.17 2,084.70 6,007,766.04 531,390.58 0.00 2,084.70 TOW @ 5028'MD,3426'TVD:764'FSL,2399'FWL-Sec35-T13N-R09E 5,028.49 77.00 98.51 3,426.28 3,363.98 -171.17 2,084.72 6,007,766.04 531,390.60 0.00 2,084.72 9 5/8"TOW 5,044.97 79.16 97.92 3,429.69 3,367.39 -173.47 2,100.68 6,007,763.80 531,406.57 13.58 2,100.68 5,074.97 79.16 97.92 3,435.33 3,373.03 -177.53 2,129.86 6,007,759.85 531,435.76 0.00 2,129.86 5,215.59 85.03 94.00 3,454.67 3,392.37 -191.95 2,268.31 6,007,745.98 531,574.25 5.00 2,268.31 5,371.47 85.03 94.00 3,468.19 3,405.89 -202.79 2,423.22 6,007,735.75 531,729.19 0.00 2,423.22 5,482.69 88.19 89.42 3,474.77 3,412.47 -206.10 2,534.15 6,007,732.88 531,840.12 5.00 2,534.15 6,132.69 88.19 89.42 3,495.30 3,433.00 -199.52 3,183.79 6,007,742.01 532,489.67 0.00 3,183.79 3K-105 L1 CP2(wp12) 6,240.33 92.43 88.69 3,494.71 3,432.41 -197.74 3,291.39 6,007,744.21 532,597.24 4.00 3,291.39 6,486.53 92.43 88.69 3,484.26 3,421.96 -192.12 3,537.31 6,007,750.79 532,843.11 0.00 3,537.31 6,559.37 89.60 89.37 3,482.97 3,420.67 -190.89 3,610.12 6,007,752.31 532,915.91 4.00 3,610.12 7,609.37 89.60 89.37 3,490.30 3,428.00 -179.34 4,660.03 6,007,767.98 533,965.67 0.00 4,660.03 3K-105 L1 CP4(wp12) 7,837.46 98.44 91.63 3,474.32 3,412.02 -181.30 4,887.31 6,007,766.92 534,192.93 4.00 4,887.31 4,965.76 6,007,765.00 534 271.38 0.00 4 965.76 7,916.80 98.44 91.63 3,462.67 3,400.37 183 53 , 8,199.35 88.35 96.73 3,445.95 3,383.65 -204.11 5,246.59 6,007,745.52 534,552.27 4.00 5,246.59 9,149.35 88.35 96.73 3,473.30 3,411.00 -315.39 6,189.66 6,007,637.95 535,495.67 0.00 6,189.66 3K-105 L1 CP6(wp12) 9,248.54 91.30 99.38 3,473.60 3,411.30 -329.29 6,287.86 6,007,624.44 535,593.91 4.00 6,287.86 9,495.77 91.30 99.38 3,467.97 3,405.67 -369.57 6,531.72 6,007,585.13 535,837.90 0.00 6,531.72 9,574.26 88.36 98.29 3,468.20 3,405.90 -381.62 6,609.27 6,007,573.38 535,915.49 4.00 6,609.27 11,674.26 88.36 98.29 3,528.30 3,466.00 -684.28 8,686.47 6,007,278.91 537,993.66 0.00 8,686.47 3K-105 L1 CP8(wp12) 11,749.37 85.42 98.91 3,532.37 3,470.07 -695.50 8,760.61 6,007,267.99 538,067.84 4.00 8,760.61 11,931.36 85.42 98.91 3,546.90 3,484.60 -723.61 8,939.84 6,007,240.58 538,247.16 0.00 8,939.84 12,008.83 88.52 98.90 3,551.00 3,488.70 -735.59 9,016.26 6,007,228.91 538,323.61 4.00 9,016.26 12,678.83 88.52 98.90 3,568.30 3,506.00 -839.21 9,677.97 6,007,127.90 538,985.66 0.00 9,677.97 TD @ 12679'MD,3568'TVD:89'FSL,568'FEL-Sec36-T13N-R09E-41/2"Production Liner-3K-105 L1 Toe(wp12) 10/4/2012 3:30:49PM Page 4 COMPASS 2003.16 Build 69 Z in m 0 .L H w E w, 3 M oJ J C. 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J: fl3 iii \ a'- mS \ . • el 2 va. 2 M cUT• 3\ .4 8N I SW 43 II' N ill U7 y rn6 Q C Qun dm9Nh ^ p � y Ml2o CI N in .ri en nh 7 --(N� 1J O p M V r.A U NY.'Cwnw_ ''I I West Sak Producer Well 3K-105 �(,� 3K-105 Plan Schematic WP-12.1rd -.Draft Schematic 10/29/2012 Li Page 1 of 2 Schwartz, Guy L (DOA) From: Myers, Monty M [Monty.M.Myers©conocophillips.com] Sent: Friday, November 09, 2012 3:30 PM To: Schwartz, Guy L (DOA) Subject: RE: 3K-105 (PTD 212-165) Attachments: 3K-105 permit Cover Letter.pdf Great questions Guy! I will do my best to answer these 1) Min FIT at the surface casing shoe to be 11 6 ppg equivalent(2 ppg higher than expected MW equivalent at Intermediate TD) Min FIT at the intermediate casing shoe to be 11.8 ppg equivalent (2 ppg higher than expected MW at B sand TD) 2) For the DV tool placed inside the surface casing shoe, my thought was to meet regulations to have 500 foot of cement above the upper most hydrocarbon producing zone In our case the Ugnu C is the upper most zone that we will see below the surface shoe The distance between the top of the Ugnu C and the surface shoe is only 480'. I though about asking for a waiver to put the DV tool below the shoe, but it would be just as easy to tie it back in to the surface shoe and still be able to circulate freeze protect in thru the tool. 3) This well is only targeting the B and D west sak sands in 2 separate laterals. 4) Cover letter attached. Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, November 09, 2012 1:31 PM To: Myers, Monty M Cc: Davies, Stephen F(DOA) Subject: [EXTERNAL]3K-105 (PTD 212-165) Monty, Quick questions on 3K-105 grassroots West Sak well. 1) Please supply the Min LOT/FIT values at the surface shoe and intermediate casing respectively. 2) I am not sure what you are doing at the surface casing shoe with the DV. Are you planning on leaving cement in the 100' overlap or not(2375-2475' md)? Please clarify steps 11-13. 3) Is this going to be a B and D multilateral only ? 11/9/2012 Page 2 of 2 4)A cover letter with a summary and job scope is needed also. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 11/9/2012 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME KRcL PTD# 2 ) 2 / (A., 7( Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ,k , tPOOL: G� �� S-1I< C. I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well AIAL 3A- (If last two digits in Permit No. Ji 2 j S ,API No. 50-CAc% - 2•34/ ? - cc . 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(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well • SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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