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Home My WebLink About212-165STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Kayla Junke of 10:10 am, Mar 13, 2023 1. Operations Susp Well Insp ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Operations shutdown ❑ Performed: Install Whipstock ❑ Perforate ❑ Other Stimulate ❑ After Casing ❑ Change Approved Program ❑ Mod Artificial Lift ❑ Perforate New Pool ❑ Repair Well ❑� Coiled Tubing Ops ❑ Other: Replace Tubing ❑� 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 212-166-0 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-029-23479-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025519 KRU 3K-106 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. FieldlPocl(s): NIA Kuparuk River Field/ West Bak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12700' feet Plugs measured None feet true vertical 3599' feet Junk measured None feet Effective Depth measured 12700' feet Packer measured 4992', 5126' feet true vertical 3599' feet true vertical 3401', 3432' feet Casing Length Size MD TVD Burst Collapse Conductor 79' 20" 108, 108, Surface 2338' 13-3/8" 2369' 2250' Intermediate 5650' 9-5/8" 5682' 3511' Production Liner 7507' 4-1/2" 1263T 3596' Perforation depth Measured depth: Alternating Slotted Liner: 5825-12568' True Vertical depth: Alternating Slotted Liner: 3520-3593' Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4975' MD 3397' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer 4992' MD 3401' TVD Packer: MLZXP Liner Top Packer 5126' MD 3432' TVD SSSV: None N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: WA 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-BbI Casing Pressure Tubing Pressure Prior to well operation:1 Well Remains Shut -In - - - Subsequent to operation: - - - - - 13b. Pools active after work: West Sak Oil Pool 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Z Exploratory ❑ Development Q Service ❑ Stmligraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LV Gas Li WDSPL Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: MCws ou croi RM Di E"a "een. o� 323-016 Elliott Tuttle°'"'"°°°'°`°"-"°m"°bee- Authorized Name and °" ,-nI;� nocoph1"Pemm a°°:°": °°°Am"a tm°eaan,em Digital Signature with Date: Dade:°2oz3.o>.,o,a:adz. o"oo Contact Name: Elliott Tuttle `,mit Contact Email: elliott.tullleidconocoohillios.com Authorized Title: Senior RWO/CTD Engineer Contact Phone: (907) 263-4742 Sr Pet Eng: Sr Pet Geo: I I Sr Res Eng: 4/23 RBDMS JSB 031423 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Operations Summary (with Timelog Depths) 3K-105 9.6 RIG RELEASE DATE 2/9/2023 Co..;phiOips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time ErM Time our (hr) Phase Activity Cotle Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 2/4/2023 2/4/2023 6.00 MIRU, MOVE MOB P Bridal up. Lay over derrick. B/D pits. 12:00 18:00 RID interconnect. 2/4/2023 2/4/2023 1.00 MIRU, MOVE MOB P Load shop and office. 18:00 19:00 2/4/2023 2/4/2023 2.00 MIRU, MOVE MOB P Pull mats from under pits. Pull pits 19:00 21:00 away form sub. Turnaround and stage on pad. Hook up jeep to pits. 2/4/2023 2/4/2023 1.00 MIRU, MOVE MOB P Pull sub off of well and stage on pad. 21:00 22:00 2/4/2023 2/5/2023 2.00 MIRU, MOVE MOB P Move pits, office and shop. Clean up 22:00 00:00 around well 30-15. 2/5/2023 2/5/2023 5.00 MIRU, MOVE MOB P Set office and shop. Stage pits on pad. 00:00 05:00 Move sub T/ 3K. 2/5/2023 2/5/2023 2.50 MIRU, MOVE RURD P Prep location, Build dance floor. Spot 05:00 07:30 sub base on well. 2/5/2023 2/5/2023 4.00 MIRU, MOVE RURD P Bridal up. Raise Derrick and safe out. 07:30 11:30 Make up Kelly. Raise cattle shoot. 2/5/2023 2/5/2023 3.00 MIRU, MOVE RURD P Relief Sow on location. Spot pits 11:30 14:30 2/5/2023 2/5/2023 1.50 MIRU, MOVE RURD P Complete rig up check list. Bring on 9.5 14:30 16:00 PPG brine into pits Interconnect hook up complete On High Line 14:45 Hang bridal line. 2/5/2023 2/5/2023 2.00 MIRU, WELCTL RURD P Rig Accept 16:00 Continue rigging up 16:00 18:00 cellar R/U Circulating equipment in cellar 2/5/2023 2/5/2023 1.25 MIRU, WELCTL PRTS P Pump 10 Bbls 9.5 PPG brine out T/ tiger 18:00 19:15 tank to warm up lines. PT tiger tank line T/ 2500 PSI. Identified union without gasket in it. Installed gasket PT tiger tank line T/ 2500 PSI - Good test. B/D Tiger tank line. 2/5/2023 2/5/2023 0.50 MIRU, WELCTL SFTY P PJSM w/ rig crew and MI on well kill. 19:15 19:45 2/5/2023 2/5/2023 2.00 MIRU, WELCTL CIRC P Pump 50 bbi 9.5 PPG Deep clean pill @ 19:45 21:45 3 bpm, follow by 9.5 PPG @ 5 bpm down the tubing taking returns from the IA, ICP=150, FCP=400. 525 bbls away shut down pump, blow down choke & kill tank line and secure choke house, 2/5/2023 2/5/2023 0.50 MIRU, WELCTL OWFF P Open up IA and TBG and monitor well 21:45 22:15 1for flow, NO FLOW 2/5/2023 2/5/2023 0.25 MIRU, WELCTL MPSP P MU and set BPV, 22:15 22:30 2/5/2023 2/5/2023 0.25 MIRU, WELCTL PRTS P PT BPV from below 1,000 psi for 10 Min 22:30 22:45 - Good test 2/5/2023 2/5/2023 0.25 MIRU, WHDBOP RURD P B/D, RID Circ manifold 22:45 23:00 2/5/2023 2/5/2023 0.50 MIRU, WHDBOP SVRG P Service rig 23:00 23:30 2/5/2023 2/6/2023 0.50 MIRU, WHDBOP NUND P Bleed off hanger void. Begin N/D tree. 23:30 00:00 2/6/2023 2/6/2023 1.00 MIRU, WHDBOP NUND P Terminate gauge above adaptor. Nipple 00:00 01:00 down tree. Install tree test dart. Inspect hanger neck threads. Plug gauge wire. 2/6/2023 2/6/2023 1.50 MIRU, WHDBOP NUND P N/U BOP 01:00 02:30 2/6/2023 2/6/2023 7.50 MIRU, WHDBOP SVRG P Performing between well maintenance. 02:30 10:00 Page 114 Report Printed: 2/27/2023 Operations Summary (with Timelog Depths) 3K-105 9.6 RIG RELEASE DATE 2/9/2023 Co..;p illips Rig: NABORS 7ES Job: RECOMPLETION Time Log Statl Time End Time Dur (m) Phase Activity Cod. Time P-T-X Operation Stan Depth htKB) End Depth (ftKB) 2/6/2023 2/6/2023 0.50 MIRU, WHDBOP SVRG P Service rig. Steam top drive. 10:00 10:30 2/6/2023 2/6/2023 1.50 MIRU, WHDBOP RURD P Rig up to test BOP PU test joint. MU 10:30 12:00 FOSV to test joint. RU to test BOP. 2/6/2023 2/6/2023 7.75 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 12:00 19:45 250/2500 PSI for 5 Min each, Tested annular, UVBR's, w/41/2"test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1550 PSI, 200 PSI attained =16 sec, full recovery attained = 126 sec. UVBR's= 5 sec, Annular- 28 sec. Simulated blinds= 5 sec. LVBR's= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1930 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook. 2/6/2023 2/6/2023 0.25 MIRU, WHDBOP BOPE T Hyd IBOP failed initial test. Replaced 19:45 20:00 Hyd IBOP. Passed retest. 2/6/2023 2/6/2023 0.50 MIRU, WHDBOP RURD P B/D, R/D testing equipment. 20:00 20:30 2/6/2023 2/6/2023 0.50 MIRU, WHDBOP MPSP P Pull tree test dart & BPV. 20:30 21:00 2/6/2023 2/6/2023 0.50 COMPZN, RPCOMP PULD P M/U landing joint T/ hanger. M/U TD. 21:00 21:30 Set down 10 block weight. 2/6/2023 2/6/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. TD, blocks, draw works. 21:30 22:00 2/6/2023 2/6/2023 1.00 COMPZN, RPCOMP RURD P BOLDS. BO orienting pin. 22:00 23:00 2/6/2023 2/6/2023 0.50 COMPZN, RPCOMP PULL P Pull hanger T/ RF F/ 4973' T/ 4943'.. 4,973.0 4,943.0 23:00 23:30 Hanger free @ 180K. P/U saw seal drag of 85K. PUW=80k. 2/6/2023 2/7/2023 0.50 COMPZN, RPCOMP CIRC P Begin circ @j 5 BPM, 120 PSI. 4,943.0 4,913.0 23:30 00:00 Clean up hanger. Terminate gauge wire and connect to spooling unit. 2/7/2023 2/7/2023 0.75 COMPZN, RPCOMP CIRC P Complete circ STS Q 5 BPM, 120 PSI. 4,913.0 4,913.0 00:00 00:45 2/7/2023 2/7/2023 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow 4,913.0 4,913.0 00:45 01:00 2/7/2023 2/7/2023 0.75 COMPZN, RPCOMP PULD P UD hanger and landing joint. 4,913.0 4,913.0 01:00 01:45 2/7/2023 2/7/2023 3.25 COMPZN, RPCOMP PULL P UD 4 1/2" IBT completion string, 4,913.0 2,700.0 01:45 05:00 spooling up control line and removing cannon clamps F/ 4913' T/ 2700', PUW=80K. 2/7/2023 2/7/2023 5.00 COMPZN, RPCOMP PULL P UD 4 1/2" IBT completion string, 2,700.0 0.0 05:00 10:00 spooling up control line and removing cannon clamps F/ 2700' T/ seal Assy., PUW=78K. Recovered 167 total cannon clamps. 2/7/2023 2/7/2023 1.00 COMPZN, RPCOMP CLEN P Clean & Clear Rig floor. 0.0 0.0 10:00 11:00 Page 214 Report Printed: 2/27/2023 Operations Summary (with Timelog Depths) 3K-105 9.6 RIG RELEASE DATE 2/9/2023 cr.. ;aharps Rig: NABORS 7ES Job: RECOMPLETION Time Log Shmt Time Ertl Time Dur (hr) Phase Activity Cotle Time P-T-X Operation Stan Depth rtKB) End Depth (ftKB) 2/7/2023 2/7/2023 0.50 COMPZN, RPCOMP SVRG P Rig Service. 0.0 11:00 11:30 2/7/2023 2/7/2023 1.25 COMPZN, RPCOMP RURD P Unload Cannon Clamps, Tongs, 0.0 0.0 11:30 12:45 Elevators and Tee Line Spooler. 2/7/2023 2/7/2023 1.50 COMPZN, RPCOMP RURD P Load New Tee Line and Spooler to Rig 0.0 0.0 12:45 14:15 floor. Load GBR Tongs and Equipment. Hang Tee Line Sheave. 2/7/2023 2/7/2023 0.25 COMPZN, RPCOMP SFTY P PJSM with all HES and rig crew. Verify 0.0 0.0 14:15 14:30 Completion Running Order. 2/7/2023 2/7/2023 7.50 COMPZN, RPCOMP PUTB P PU/MU Seal Assembly with Locator and 0.0 4,932.0 14:30 22:00 Pup Joint. PU Gauge Mandrel and Splice TEC Wire to Mandrel and Test Same to 71K for 15 min.. Install LaSalle Clamps and torque each bolt to 25 ft/lbs. Continue in hole with 4-1/2" Completion Per Tally T/ 4932, PUW=73K, SOW=60K. 2/7/2023 2/7/2023 0.50 COMPZN, RPCOMP PUTB P M/U TD. Circ 2 BPM, 80 PSI. RIH PSI 4,932.0 4,980.4 22:00 22:30 increase T/ 500 PSI @ 4961.5', Turn off pump. P/U pressure released @ 4961'. Cont RIH fully located w/ 10K down 4980.37', 7ES RKB. (23.98') 2/7/2023 2/7/2023 1.00 COMPZN, RPCOMP HOSO P L/D joints #119,118 & 117 T/4889'. M/U 4,980.4 4,924.7 22:30 23:30 space out pups 5.78', 9.72", 9.73' & 2.11' XO pup 4 1/2" IBT Box x 4 1/2" Hyd 563 Pin. T/ 2/7/2023 2/8/2023 0.50 COMPZN, RPCOMP SVRG P Service rig. Service 2" HP 1502 swing. 4,924.7 4,924.7 23:30 00:00 2/8/2023 2/8/2023 1.00 COMPZN, RPCOMP PULD P P/U landing joint. R/U circ equipment. 4,924.7 4,946.0 00:00 01:00 P/U hanger. M/U landing joint to hanger. M/U hanger to string. RIH T/ 4946' 2/8/2023 2/8/2023 0.50 COMPZN, RPCOMP SVRG P Service rig 4,946.0 4,946.0 01:00 01:30 2/8/2023 2/8/2023 1.50 COMPZN, RPCOMP CRIH P Cite 340 Bbls 9.5 PPG Cl NaBr @ 4 4,946.0 4,946.0 01:30 03:00 BPM, 160 PSI. Chased w/ 10 Bbls 9.5 PPG NaBr. Terminate gauge wire through hanger. Check gauge readings - 1690 PSI, 60' F. 2/8/2023 2/8/2023 0.50 COMPZN, RPCOMP RCST P RIH F/ 4946' T/ 4974.55' ORKB. Land 4,946.0 4,974.6 03:00 03:30 hanger. Total of 118 LaSalle Cross Collar Clamps, 1 Cannon mid joint clamp w/ 1 pin run. RILDS. Check gauge readings - 1690 PSI, 60' F. 2/8/2023 2/8/2023 0.50 COMPZN, RPCOMP PRTS P PT upper and lower hanger seals T/ 4,974.6 4,974.6 03:30 04:00 5000 PSI for 15 Min each - Good test. 2/8/2023 2/8/2023 2.00 COMPZN, RPCOMP PRTS P PT tubing T/ 3000 PSI for 30 Min. Bleed 4,974.6 4,974.6 04:00 06:00 tubing T/ 1500 PSI. PT IA T/ 2500 PSI for 30 Min. Dump tubing pressure, shear out SOV. Establish circ rate down IA @ 2 BPM, 600 psi. 2/8/2023 2/8/2023 1.00 COMPZN, RPCOMP RURD P RD Circulating equipment. Backout 0.0 0.0 06:00 07:00 Landing Joint 2/8/2023 2/8/2023 1.00 COMPZN, WHDBOP MPSP P Install BPV and Test same to 1000 psi. 0.0 0.0 07:00 08:00 2/8/2023 2/8/2023 2.00 COMPZN, WHDBOP NUND P ND BOPE 0.0 0.0 08:00 10:00 I 2/8/2023 2/8/2023 2.00 COMPZN, WHDBOP NUND P Clean well head and prep Tee wire for 0.0 10:00 12:( I installation, Page 314 Report Printed: 2/27/2023 Operations Summary (with Timelog Depths) 9.6 3K-105 RIG RELEASE DATE 2/9/2023 Co..;p illips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time E M Time Dur (m) Phase Activity Code Time P-T-X Operation Stan Depth rtKB) End Depth (ftKB) 2/8/2023 2/8/2023 5.50 COMPZN,WHDBOP NUND T Install tree test dart. N/U adaptor spool 0.0 0.0 12:00 17:30 and tree. DSO verify alignment. Termination of TEC Wire through Wellhead & Hanger. Lost communication w/ gauge. N/D adaptor spool & tree. Identify pinched Tec wire above hanger. Trimmed wire. Feed control line through adaptor. Install tree test dart. N/U adaptor spool and tree. Check gauge - 1734 PSI, 65' 2/8/2023 2/8/2023 0.50 COMPZN, WHDBOP NUND P N/U adaptor spool and tree. 0.0 0.0 17:30 18:00 Check gauge - 1734 PSI, 65' 2/8/2023 2/8/2023 0.50 COMPZN, WHDBOP SVRG P Service rig. 0.0 18:00 18:30 2/8/2023 2/8/2023 0.50 COMPZN, WHDBOP PRTS P PT Hanger void to 5k for 15 min. 0.0 0.0 18:30 19:00 Check gauge - 1734 PSI, 65' 2/8/2023 2/8/2023 0.25 COMPZN, WHDBOP RURD P RID test pump equipment to tree. 0.0 0.0 19:00 19:15 2/8/2023 2/8/2023 0.25 COMPZN, WHDBOP PRTS P PT tree T/ 5000 PSI for 5 Min. 0.0 0.0 19:15 19:30 Check gauge - 1734 PSI, 65' 2/8/2023 2/8/2023 0.25 COMPZN, WHDBOP MPSP P Pull tree test dart & BPV. 0.0 0.0 19:30 19:45 R/U LRS. 2/8/2023 2/8/2023 0.25 COMPZN, WHDBOP SFTY P PJSM w/ LRS and rig crew on PT and 0.0 0.0 19:45 20:00 freeze protect. 2/8/2023 2/8/2023 0.25 COMPZN, WHDBOP PRTS P LRS PT tiger tank line T/ 2500 PSI. 0.0 0.0 20:00 20:15 2/8/2023 2/8/2023 2.75 COMPZN, WHDBOP FRZP P LRS pump 144 Bbls diesel down IA 0.0 0.0 20:15 23:00 taking returns to tiger tank. ICP=m, FCP=x . U-tube well. Blow down steam and water to pits. Unhook interconnect. Bridal up. 2/8/2023 2/9/2023 1.00 DEMOB, MOVE DMOB P B/D, R/D circulating equipment. Secure 0.0 0.0 23:00 00:00 1 I tree. I Lay over derrick. Page 414 Report Printed: 2/27/2023 3K-105 RWO Summary of Operations DTTMSTARTJOBTYP SUMMARYOPS 1/23/2023 ACQUIRE DATA (PRE-RWO) CMIT T X IA TO 2500 PSI PASSED, CDDT T X IA TO 0 PSI IN PROGRESS. 1/24/2023 ACQUIRE DATA (PRE-RWO) CDDT T X IA 0 PSI (PASSED). 2/4/2023 RECOMPLETION Bridal up. Lay over derrick. Load shop and office. Pull pits away from sub. Pull sub off of well and stage on pad. Move shop office and pits. Clean up around well 30- 15. 2/5/2023 RECOMPLETION Set office and shop. Stage pits on pad. Move sub to 3K. Hang tree, stage wellhead equipment in cellar. Spot sub over 2K-105. Spot pits to sub. Spot auxiliary equipment. Cuttings tank, tiger tank, choke and tiger tank hard line. Hook up electrical and plumbing in interconnect. Turn on steam and air to pits. Berm in rig. Raise derrick. Bridal down. Complete acceptance checklist. Get measurements for riser height from tubing spool height. Take on 9.5 PPG NaCl into pits. Rig up circ manifold in cellar. Pressure test circ manifold & tiger tank T/ 2500 PSI. Kill well Pump 50 Bbls Duo-Vis deep clean pill followed by 475 Bbls 9.5 PPG NaCl, 30 min no flow check. Install BPV. Pressure test BPV from below. Bleed off hanger void. Begin nippling down tree. 2/6/2023 RECOMPLETION Terminate gauge above adaptor. Nipple down tree. Install tree test dart. Inspect hanger neck threads. Plug gauge wire. Nipple up BOP. Perform between wells maintenance. Fill BOPE with fresh water and test to sundry 250/2500 PSI. Pull tree test dart and BPV. Make up 4'/2" 4.909" MCA landing joint. Set 10 block weight down on hanger. BOLDS. Unseat hanger and pull hanger to rig floor. Circulating surface to surface. Terminate gauge wire and connect to SLB spooling unit. 2/7/2023 RECOMPLETION Cont circulate surface to surface. Lay down landing joint and hanger. Lay down 4 /" IBT SC completion string, removing cannon clamps F/ 4913" T/ Surface. Change out spooling units. Rig up GBR. Run 4 1/2" Hyd 563 completion installing cannon clamps on each connection. Make up top drive wash seals into SBE. PSI increase T/ 500 PSI @ 4961.5', Turn off pump. pick up pressure released @ 4961'. Run in hole and fully located w/ 1 OK down @ 4980.37', 7ES RKB. Lay down 3 joints. Make up space out pups and XO pup T/ 4924' 2/8/2023 RECOMPLETION Make up hanger and landing joint. Run in hole T/ 4946'. Pump 340 Bbls 9.5 PPG Cl NaBr. Terminate gage control line through hanger. Land hanger with bottom of seals @ 4974.55' ORKB. RILDS. Pressure test upper and lower hanger seals T/ 5000 PSI for 15 Min each. Pressure test tubing T/ 3000 PSI for 30 Min. Pressure test IA T/ 2500 PSI for 30 Min. Shear out SOV. Establish circulating pressure. Install HP BPV. Pressure test BPV from below T/ 1000 PSI for 10 Min. Nipple down BOP. Install tree test dart. Nipple up adaptor spool and tree spool. Terminate gauge wire through adaptor. Crushed Tec wire. Nipple down adaptor an tree. Trim Tec wire. Nipple up and re -terminate gauge wire - Good communication with gauge. Rig up circ manifold. Pressure test tree T/ 5000 PSI. LRS Pressure test tiger tank line to 2500 PSI. LRS pump 144 Bbls freeze protect. Bridal up. U-tube well. Secure tree and cellar. Demob. Lay over derrick. 2/14/2023 ACQUIRE DATA REPLACED ST #2 @4760'RKB W/1" OV(1/4"PORT)BK LATCH,REPLACED ST#1 @2777'RKB W/1"GLV(3/16"PORT,1458TRO),PULLED BAIT SUB/EQ PRONG @5044'RKB,ATTEMPTED TO PULL 3.79"DB PLUG BODY IN PROGRESS 2/15/2023 ACQUIRE DATA ATTEMPT TO PULL BAITED PRS(OAL40") & 3.79"DB PLUG BODY @ 4975'RKB IN PROGRESS 2/16/2023 ACQUIRE DATA RETIEVED 1"GLV FROM BAIT SUB @5047'RKB, PULLED BAITED PRS & 3.79"DB PLUG BODY @5047'RKB IN PROGRESS 2/17/2023 ACQUIRE DATA SET 1"GLV(3/16"PORT,1458TRO)W/BK LATCH ST#1@2777'RKB,PULLED 3.79"CATCHER @5047'RKB JOB COMPLETE KUP PROD WELLNANIE 3K-105 WELLBORE 3K-105 WELLS + II�IIIIVP CONDUCTOR: psu,o sLors:Be26oe.4o4.p-_ E d _ SLOTS: 66N.O6,646.0 SLOTS: B, P40.6].520.0 f t = SLOTS: 8, 411.08.112.0 I = SLOTS: 8.2a3.610.3W.0-- � � = sLors, +n4sao-+t44ao sLors, n.au.o-n.]oa.o- SLOTS, N ZCTSOLIZ58i BSANO LINER: 5,1 xf.6 12.Kd.O Well Attributes I Max Angle&MD TO I'l Name Wellborn APWWI WellnoI. .'am.Id(°) NE WET AK500292347900PR D 00.11 M0 mKBI ],952 not Rolm NIKB) 2 12,]00.0 Cammeni ju'61ppm) Gate . Mml n Last WO: Entl pNe KBGNIflI RR Oaie longer 21212(U3 Ekv... test Amwmalion De,do hi WNlbore I End Date Lart MOd By Last Tag: 3K-1o5 condijw Last Rev Reason Annotation WelINrt Ena Dale Last Motl By Rev Reason: Change out GLV's 31-lum 1111all.zi jM1aniall Notes: General & Safety Annotation Ena Date Lum Moa Br NOTE. MULTI -LATERAL WELL 3K-105, 3K-1051_1 211212013 asb0d General Notes: Last 3 entries rem Bare L,aNMm By Junction box for down bole gauge, off of well head outlet needs to be secured 2/8I2023 nsklwocm Casing Strings CapBea On(I. ID lint TOPNRKB) Set Depth set NRKB) RVOI Deem NIKB) WLLen gnMl O ,aae TMeaa oPT CONDUCTOR 20 19.12 29.0 108.0 108.0 94.00 X-65 WELDED SURFACE 13 SAS 12.41 31.0 2,369.1 2,250.4 68.00 L40 BTC INTERMEDIATE 95/8 8.83 31.4 5,681.7 3,511.4 40.00 L-Bo BTC LINER DNERTER ABSY 8.51 ].]3 5,066.9 5,164.2 3,441.3 2.97 LINER LEM 4112 3.94 4,948.8 5,039.3 3,423.9 30.89 4.5 BSAND LINER 4112 3.48 5,125.8 12,633.0 3,595.7 11.60 L480 BID Tubing Strings: string max indicates LONGEST segment of string Top IftNB) sn Bep[n... srt Bnpm._ s[rmq Ma... Tubing Description WIgWX) araee Top Connection IDfin) 22.6 4,9]4.6 3,397.3 41/2 Tubing -Completion Upper 12.60 L-80 HYD563 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top(..) Top Ono" IXK9) Topind r) kem Des OD Nominal (in) Core Meke Model Nominal Is lint 22.6 22.6 0.00 Hanger 13.000 Vault 13318"x4112"w14.909"MCA Veto top Connection Tubing Hanger M6-222 3.900 503.4 502.5 9.57 Nipple -X 5.030 4.5"x 3.813"X44ipple TIES XNipple 3.813 2,777.0 2.612.7 31.10 Mandrel - GAS LIFT 6.393 4112"x 1-KBMG, GLM SUB KBMG 3.865 4,760.0 3.355.0 79.88 Mandrel -GAS LIFT 6.393 4112"x 1-KBMG, GLM SUB KBMG 3.865 4,828.8 3.367.3 78.80 Sleeve -Sliding 5.490 412"x 3.813"NEXA-2 Sliding SUB Sleeve, Closed Position, 4140, WD 563 CMU Sliding Sleeve 3.813 4,893.5 3,380.4 78.17 Sensor- Suction Gauge 5.993 4.5° Solid Gauge Mandrel, HYD563 SUB Box. Box Gauge bough) 3.865 4,953.2 3,392.7 T'.79 Locator 5.210 Baker19247, GBH-22, Locator Baker 192-47, GBH-22 Seal Assembl Y 3.980 4,954.1 3,392.9 A]] Seal Assembly 4.730 Baker 19247, GBH-2 Seal Baker Assembly(3.98'From Fully LOcaled) 119247, GBHF2 Seal Assembl Y 1 3.870 Mandrel Inserts : excludes pulled inserts Top Puke) Top nVO) (NINE) an Top on Inol l°) No h Sery a.k. Type LNCM1 Type OD (in) TRO Run (psi) Run Oate Cam Make Moda Pal Elie gn) 2,]]].0 Z. 31.10 GASLIFT GLV BK 1 1,458.0 211 TI2023 SLB KBMG 0.188 A,]60.0 AJCd.0 1RdA I 2 GAS LIFT 11V BEK 1 1 O.o 2I1412023 ISLB KBMG p.250 Liner Details: Excludes Liner, Pup, Joints, rasing, float, sub, shoe... Tap least Top Royal) WB) Topind (°) M. Dea OD Nominal (in) Co. Make Model Nominal l0 lira) 4,948.8 3,391.8 ]].88 SLEEVE 7.000 ]" wl HRD£ Liner Setting SleeveHR 8.31 7.50" ID ext. 6' BUT 6.220 4,958.7 3,393.9 77.68 SBR 6.270 Seal Bore 4314" 6.27 BOT 4.750 4,991.6 3,401.1 ]].00 PACKER 8,420 BAKER PREMIER PACKER 8A2 3.880 5,047.4 3,414.1 76.38 NIPPLE 5.250 CAMCO LANDING DB NIPPLE 5.25 SUB 3.750 5,062.7 3,417.7 76.52 COLLET 7.330 RAM Module Hanger LEM Completion 7.33 ( Collet to tap Of LEM ) BOT 3.960 5,064.8 3,418.2 76.54 COLLET 7.330 RAM Module Hanger LEM Completion 7.33 ( Collet to re-enby) BOT 3.960 5,087.6 3,423.5 76.55 WLEG 5.020 BAKER GUIDE WIRELINE RE-ENTRY 5D2 BUT 3.730 5,066.9 3.418] 76.55 R T2 8.510 SEAL above BORE DNERTERr-IengN 8.51 collet profile it RAM Hanger BOT ]J30 5,069.9 3,419.3 76.58 R TI 8.510 SEAL below BORE DIVERTER, lengm 8.51 callel profile BOT 7.730 5,115.4 3,430.0 76.39 5.250 CAMCO NIPPLE DBS 3.563"NO GO 5.25 3.563 5,134.7 3,434.5 76.49 6.520 MLHR PRODUCTION ANCHOR 7.39 ROT 3.910 5,138.9 3,435.5 76.55 6.520 MLHR PRODUCTION ANCHOR Z39 BOT 3.910 5,125.8 3,432A ]639 dANCHOR 8.420 MLZXP TOP w/HR PROFILE LINER Baker PACKER MLZXP 6.100 5,1518 3,438.9 T6.]3 6.280 4.]50" SEAL BORE Baker SBE190-4T 4.T50 5,720.8 3,513.9 86.05 cker 6.380 FREECAP SWELL PACKER TAM Freecapl FSC 4.000 5,]98.5 "R.9 86.4] 5.500 TRACERO CARTIDGE OILANATER TRACER 5112"x4112" 4.500 6,455.2 3,523.0 89.28cker 6.380 FREECAP SWELL PACKER TAM Freecapl FSC 4.000 KUP PROD WELLNAME 3K-105 WELLBORE 3K-105 GxxxoPhillips Alaska, Inc. Tomgnps Annmaron End Sea act WO. MU rRR LATERALS, 3MW =0c3 E:a3:22 PM Liner Details: Excludes Liner, Pup, Joints, Casi In v.mm..n maana.uao GG Top IT) Topintl Nominal Nominal ID Hangq Me— TopIMB)151.5 1,525 1, ft.. OR Des P, Com Make Made! I4, 6,85].5 3,525.9 89.9 SENSOR 5.500 CARTIDGE TRACERO O 1/2"x4112"TRACER 4.500 CARTIDGE 5112"x4112" 7,576.5 3,537.0 91.66 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecapl 3A76 FSC CONDUCTOR: pArAa60 CARTIDGE 5112"x4112" 8,306.7 3,4]].8 91.01 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecapl 3AT6 mppb-x; sm.a FSC 8,385.0 3,478.0 88.53 SENSOR 5.500 TRACERO OILINlATER TRACER 4.500 SMREAce. m.Daam.1 9,162.0 3,498.6 86.70 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecapl 3A76 Mandrel -GAS LlR. 2.777.0 FSC 9,240.1 3,504.3 85.00 SENSOR 5.500 TRACERO OILIWATER TRACER 4.500 Mandel -GAG LIFT: 4.791 CARTIDGE 5112"x4112" 10,350.5 3,529.0 88.13 Swell Packer 6.380 FREECAP SWELL PACKER TAM Freecapl 3.476 Sbwe-SIIdIna, 4,a ek FSC 10,428.2 3,531.9 87.46 SENSOR 5.500 TRACERO OILANATER TRACER 4.500 CARTIDGE 512"x4112" 11,496.5 3,568.9 90.99 Swell Packer 6.330 FREECAP SWELL PACKER TAM Freecapl 3.476 FSC 11,573.9 3,567.4 91.25 SENSOR 5,500 TRACERO OILANATER TRACER 4.500 CARTIDGE 5112"x4112" Perforations & Slots BXm Top IND) arm MID) Dan. Top IXMB) arm IMB) (MB) (XXB) Orland Zone D. Io11oltlX) Tyq Com 5,825.0 6d1[A.0 3,520.5 3,522.4 WS B, 3K-105 W012013 32.0 SLOTS SLOTTED LINER 6,521.0 6,646.0 3,523.9 3,525.8 WS B, 3K-105 1202013 32.0 SLOTS 6,944.0 7,524.0 3,530.6 3,538.4 WS B, 3K-105 1202013 32.0 SLOTS LINER LEM, a D46BS.aR9.a Dsu,D LINER: 5.062.3 8,411.0 9,112.0 3,478.9 3,496.2 WS B, 3K-105 12W2013 32.0 SLOTS 12AEEE 9,266.0 10,300.0 3,506.5 3,527.4 WS 3, 3K-105 W012013 32.0 SLOTS 10,454.0 11,445.0 3,533.1 3,569.5 WS B, 3K-105 11202013 32.0 SLOTS 11,084.0 11,705.0 3,554.4 3,564ES WS B, 3K-105 218I2013 32.0 SLOTS 12,070.0 12,568.0 3,584.E 3,592.9 WS B, 3K-105 VIII2013 32.0 SLOTS LINER ENERTERA66Y; BWBas.164.2 INTERMEDIATE; 31,N,631] SLOTS. I SLOTS, 6 En.M,616.0� SLOTS: S, a40.0.T.aM.O= SLOTS:8,411.D8.112.0= - SWTS;%AdA10.3WA— SLOTa; 10.45A0.11.40.50�� SLOTS I 11.064.0-11.70 SLOTS; 1z010 M 4582.0— .AM. L::,R 5,1 x.6 1zea3.a KUP PROD WELLNAME 3K-105 WELLBORE 3K-105L1 amocOPlllllp5 Alaska, Inc. Well Attributes I Max Angler MD TD FIeM Name NE WET AK WNIbore APWVA Wellhore erelue Id(°) 2 2 4) PR D MD(BKBI 9.16 8?30.68 MBrm (BKB) 12,)14.0 Comment Nudap,Z1212013 In,H2a 1ppm) Oah Mdmamwn Entl aide KBGN Ng RR Dare OIM1er Eke.. Annotation WeIINrt 1 End Dare Lail Mond By Rev Reason: CHANGE OV, SET RECONFIG POGLM 31-105L1 9Ig1201H radial General Notes: last 3 entries corn Doe Loot Moo By Junction box for down hole gauge, off of well head outlet needs to be secured 2nn,ree3 nNowmam Casing Strings C¢g Do OD lint ID (in) Top 1fiKBI set Deem dNKBI set Deem (WD)dNKBI whten ghm) Deal TooThread D-SAND LINER 4112 3.96 5,062.3 12,655.5 3, 554.1 11.60 LAO IT Liner Details: Excludes Liner, Pup, Joints, casing, Float, sub, shoe... Tap IflKBI -P(TMa) reaus, Top inch (1 Kem De¢ or Nominal (in) Com Make Modal Nominal lD (in) 5,099.1 3,424.8 78.80 %O BUSHING 6.820 LINER CROSSOVER BUSHING 3.870 5,194.4 3,440.7 82.09 Swell Packer 6.380 TAM FreeCap IFSC SWELL PACKER 3.476 5,2723 3,449.0 95.96 SENSOR 5.500 TRACERO OILJWATER TRACER CARTRIDGE 4.000 6,007.1 3,460.9 87.52 Swell Packer 6.380 TAM FreeCap IFSC SWELL PACKER 3.476 6,579.9 3,479A 9289 Swell Packer 6.380 TAM FreeCap IFSC SWELL PACKER 3.476 6,)92) 3,469.6 91.52 SENSOR 5.500 TRACERO OILANATER TRACER CARTRIDGE 4.000 7,860.6 3,493.0 8844 Swell Packer 6.380 TAM FreeCap IFSG SWELL PACKER 3.476 9,4121 3,442.2 94.15 Swell Packer 6.380 TAM FreeCap IFSC SWELL PACKER 3.476 8,498.5 3,438.4 90.95 SENSOR 5.500 TRACERO OILANATER TRACER CARTRIDGE 4.000 9,3223 3,455.0 88.42 Swell Packer 6.380 TAM FreeCap IFSC SWELL PACKER 3.476 9,572.9 3,448.4 92.94 SENSOR 5.500 TRACERO OILWATER TRACER CARTRIDGE 4.000 10,))2.8 3,476.1 88.49 Swell Packer 6.380 TAM FreeCap IFSC SWELL PACKER 3.476 11,058.4 3,491.9 85.83 SENSOR 5.500 TRACERO 0 LAVATER TRACER CARTRIDGE 4.000 11,963.9 3,537.4 86.09 Swell Packer 6.380 TAMFreeCap IFSCSWELL PACKER 3.476 12,043.9 3,541.0 I 88.53 SENSOR 5.500 TRACERO OIUWA I ER TRACER CARTRIDGE d.000 Perforations S Slots To, NusI) No (real mP nMD) free) Ban cool (BKB) Linked Zone Dale Shot Dens (¢.) Type C- 5,298.0 5,956.0 3,450.4 3,459.3 XIMM13 32.0 SLOTS SLOTTED LINER 6074.0 6,529.0 3,464.5 3,481.5 066f013 32.0 SLOTS 6,819.0 7,850.0 3,469.2 3,492.7 2/612013 32.0 SLOTS 7,528.0 9,270.0 3,438.1 3,453.7 06I2013 32.0 SLOTS 9,603.0 10,722.0 3,446.8 3,474.4 2161P013 32.0 SLOTS 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Monday, March 6, 2023 11:46 AM To:Morales, Tony Cc:Regg, James B (OGC) Subject:RE: 7ES KRU 3K-105 BOPE Test 2/6/2023 Attachments:Nabors 7ES 02-06-23 Revised.xlsx Tony, Attached is a revised report for Nabors 7ES 02‐06‐23, changing the Upper Kelly test result to “FP” (fail/pass) and the FSV Misc field to “NA”. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Morales, Tony <Tony.Morales@nabors.com> Sent: Tuesday, February 7, 2023 8:54 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: NSK RWO CM <nskrwo.cm@conocophillips.com>; Hobbs, Greg S <greg.s.hobbs@conocophillips.com>; Henson, James <Jim.Henson@nabors.com>; Cozby, Kelly <Kelly.Cozby@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com> Subject: 7ES KRU 3K‐105 BOPE Test 2/6/2023 Tony Morales 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670‐6132 Mobil 805 797‐6720 tony.morales@nabors.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 3K-105PTD 2121650 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:2/6/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2121650 Sundry #323-015 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1340 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 FP Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1575 P Check Valve 0 NA 200 psi Attained (sec)16 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)126 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@1930 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 28 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:8.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/5/23 1:27 AM Waived By Test Start Date/Time:2/6/2023 12:00 (date)(time)Witness Test Finish Date/Time:2/6/2023 20:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors All Tests with 3 1/2" Test joint. All alarms tested , Upper IBOP failed changed out and passed Tony Morales / Johnny Medina ConocoPhillips Mark Adams / Kevin Barr KRU 3K-105 Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0206_BOP_Nabors7ES_KRU_3K-105           J. Regg; 6/2/2023 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' RBDMS JSB 012523 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 ... TD Act Btm (ftKB) 12,714.0 Well Attributes Wellbore API/UWI 500292347960 Field Name NE WEST SAK Wellbore Status PROD Max Angle & MD Incl (°) 99.16 MD (ftKB) 8,230.68 WELL LOG TRANSMITTAL #905950712 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3K-105 Run Date: 9/5/2019 212165 31360 October 17, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.- Fanny f: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3K-105 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23479-00 RECEIVED OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: L&l Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAY 0 9 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operra', apl� Performed: Suspend E] Perforate E] Other Stimulate E] Alter Casing E]Change A Pg2v1��,p� Plug for Redrill ❑ ertorate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE Trtmt ❑� 2. Operator Name: ConocoPhilllps Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development 0 Strafigraphic❑ Exploratory ❑ Service ❑ 212-165 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23479-00 7. Property Designation (Lease Number): 8. Well Name and Number ADL 25519 KRU 3K-105 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,700 feet Plugs measured None feet true vertical 3,599 feet Junk measured None feet Effective Depth measured 12,700 feet Packer measured 4,992 feet true vertical 3,599 feet true vertical 3,401 fast Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 20 108' MD 108' TVD SURFACE 2,338 feet 13 3/8 " 2,369' MD 2250' TVD INTERMEDIATE 5,650 feet 95/8" 5,682' MD 3511' TVD LINER 7,507 feet 4 1/2 " 12,633' MD 3596' TVD Perforation depth: Measured depth: 5825-12568 feet True Vertical depth: 3520-3593 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L80 4,973' MD 3,397' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -BAKER PREMIER PACKER 4,992' MD 3,401' TVD SSSV - NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: Shut -In 14. Attachments (requi.d per 20 AAC 25.070, 25.o71, 825.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-497 Contact Name: John Peirce Authorized Name: John Pierce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer Authorizetl Signature: - L� Contact Phone: (907)265-6471 Date: Form 10-40 Revised 4/201 {ATL 5_12111 / � 04 !_ R�DaAC� MAY 10 2019 Submit Original Only 3K-105 OFFSET PRODUCER FOR 3K -103L1 RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 4/14/19 MISC. PUMPED 6644# OF RPPG MIXED IN 350 CAPACISUSTAITY BBLS 2% KCL AS PER DESIGN, GAIN OF 850 PSI WHP, WELL IS FREEZE PROTECTED. NIPPLE. M.7 EAS (NS Hanger LOCPTOP: EE9LASel. BXOE; Can Con I In MKB) i TOP( O)(.K.) 1 111.1 r) i Item.- i Com i I.nl i Oea 1� IIPOGLM B.BAND LIMEN; NISE B +zeaaD— MA Eiry➢ v2• Com KUP PROD WELLNAME 3K-105 WELLBORE 3K-105 �fL Conoco�Phlliip$ Well Attr butes Max Angle & MD TD AIBSka,inc FIeN Name Wells. APIM WNlboreSWui n[I°I MB �KKBi Act Blm ptNB� NE WEST SAK 5002923W9p0 PROD 001') ),95292 12 )p0.0 ... Comment pgSV'NIPPIF X35 WSW OWOtS 45 tnWfIe.nun I Er. W@ KBGMipt pq peleau Bale an�nme NIPPLE. M.7 EAS (NS Hanger LOCPTOP: EE9LASel. BXOE; Can Con I In MKB) i TOP( O)(.K.) 1 111.1 r) i Item.- i Com i I.nl i Oea 1� IIPOGLM B.BAND LIMEN; NISE B +zeaaD— MA Eiry➢ v2• Com KUP PROD WELLNAME 3K-105 WELLBORE 3K-105 ConocoPhillips IIPNGER:.. Top ma) IRKS) I ('1 1 0- n2 2124S 24.6 2,4] .3 27.58 UPRS PIPE 6 X0'5 UPR SPACER PIPE +ECENTRIC XO'S 9I9201F 2,631] 2,485.6 27.66 POGLM - B MANDR W/ AMCRT, 9191201E BK LATCH, TRO=1494 PSI CO DUGTORa, 410eo 2,638.0 2.491.1 27.74 LWR SPACER LWR SPACER PIPE + ECENTRIC XO'S 919201E NIPPIE, 5WT PIPE 8 XO'S SURFACE: 31 n.3we MCH -UPR Prc WI po . ..12 S1%. 2,644.0 24964 2).1 PAT 7HLWR PACKER(ME) WEATHERFORD WIDEPAK LE(SwACP45024) 9/912018 UPR SPACER FLE 3 Xtl3: S .e Perforations S Slots OAs uFT, z.w0.3 pUGLM:zw1.1 UMt SPACERPIPE6X0'.. PRTCN-IN/R M.R(.E) ?sago Top1111(B) BOn 1N{BI Dens Top DV01 Btm INC) Cana (M(B) MM) -.Sed Ie Uw Ia1gKm Typ Com 5, 5.0 6,404.0 3,520.5 3,522.4 WS B,3K-1 5 1I2W2013 32.0 SL T SLOTTED LINEA CAsuFT, ssua 6,521.0 6,648. 3.523.9 3758 WS B, 3K-1 5 1/202013 32.0 SLOT 6,944.0 ],5240 3,530.6 3,5384 WS B, 3K-1 120201 32.0 SL TS WB LIFT. 4.77I5 LOCATOR, SEALASSY, SHOE; BSAHO LINER: S.t.,& 1?w30� PTD 212-165— Loepp, Victoria T (DOA) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Tuesday, January 8, 2019 3:01 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 3K-103L1(PTD 208-116, Sundry 318-496); KRU 3K-105(PTD 212-165, Sundry 318-497) D MBE RPPG Treatment - Proposed Procedure Changes Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for your reply. I'll proceed as you have requested. I'm not sure when we'll pump the job, but hopefully soon if it warms up a bit on the Slope. Pumping conditions are challenging now due to very cold weather, so we may wait for a break to more favorable weather to reduce some operational risk. Regards, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, January 8, 2019 1:49 PM To: Peirce, John W <John.W.Peirce @conocophillips.com> Subject: [EXTERNAL]KRU 3K-103L1(PTD 208-116, Sundry 318-496); KRU 3K-105(PTD 212-165, Sundry 318-497) D MBE RPPG Treatment -Proposed Procedure Changes John, The proposed procedural changes are approved. Please include this email approval of the changes with the original approved sundries. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loeoo(rDalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska.aov Proposed 3K -103L1 to 3K-105 RPPG Treatment of D MBE 3K-103 Injector has a dual lateral completion design with a dual string Packer, and dual 3-1/2", 9.3#, L-80 tubing strings. 3K-1031-1 is a West Sak D Sand lateral. 3K-103 is a West Sak B Sand lateral. Initial evidence of a possible D MBE from 31K-1031-1 to offset 3K-105 producer arose in Summer 2018 when 3K-105 watercut went from 40% to 85% in a 3 -month period. 31K-1031-1 has 13 inflow control devices (ICD screens). A 9/28 - 9/29/18 IPROF in 3K -103L1 found that the fourth screen down the lateral at 6482 - 6513' RKB took the bulk of total injection in the lateral. Nine other screens below 6513' RKB did not appear to be receiving any significant injection with 1000 BWD entering the lateral during the IPROF. SI warm back passes indicate a D MBE exists at 6300' via the ICD at 6482 - 6513' RKB. We propose sealing the MBE with RPPG: Procedure using 2" OD Coil Tubing: 1. RIH & set a retrievable inflatable Bridge Plug in blank liner at 6613' RKB (target) then POOH. 2. RIH & set retrievable inflatable Treating Packer in blank liner at -6563' RKB (target), then PU CT to 2500 psi to verify good set integrity of IBP at 6613' RKB before RPPG treatment. POOH with retrievable Inflatable Treating Packer. 3. RIH with Perf Gun and then shoot 'big hole' perfs in 3.5" Blank Liner at 6300 - 6305' RKB at 6 spf, 60 deg ph, over D MBE to enable RPPG slurry flow through 3.5" liner. POOH with gun. Verify ASF. Pump 55 bbls Diesel FP down Tubing to ensure Diesel is in well above to at least above 6200' RKB before setting Treating Packer in next work step. 4. SI offset 3K-105 producer 12 to 24 hrs before pumping in 3K -103L1. RIH & set retrievable inflatable Treating Packer in blank liner at 6200' RKB (target) to set Packer 100' above perfs. Pump 100 bbls 2% KCL Brine Pre -Flush at 1 - 2 bpm down CT to verify good injection exists to MBE at -6300' RKB, and to ensure all hydrocarbon contaminants to RPPG are displaced from CT to MBE. When CT is full of Brine, do SRIT at 1, 1.5, 2 bpm down CT. Record CT treating psi at each rate. Pick a constant rate to pump job, and then begin mixing & pumping RPPG Slurry on -the -fly from the Mixing Van down CT as follows: a) RPPG Slurry at steady 0.75 ppg concentration (target) in 2% KCL Brine at steady established rate between 1 to 2 bpm. Continue until CT treating pressure rises, then determine when to call Flush depending on the rate of CT pressure rise observed, then call Flush pumping b) 0.5 bbl 2% KCL Brine Spacer at same steady rate, followed by SD to drop disconnect ball, then c) Resume pumping another 2.5 bbls 2% KCL Brine Spacer at same steady rate to keep Diesel contamination from contacting RPPG tail, followed by d) CT volume of Diesel to displace 2% KCL Brine Spacer to the Treating Packer. When ball lands on seat, disconnect CT from Packer leaving last barrel of RPPG slightly underdisplaced to MBE and check valve on top of treating packer to prevent any up flow (crossflow) through the Packer. Continue pumping the last few bbls of Diesel until CT Diesel FP is completed, then e) SD pumping. RD CTU & Mix Van. MOL. Wait --48 hrs for RPPG to fully cure in the MBE. 5. RIH & pull retrievable inflatable Treating Packer from blank liner at 6200' RKB. 6. RIH with down jet nozzle to perform RPPG cleanout with Diesel to the IBP at -6600' RKB. 7. RIH & pull IBP from blank liner at -6600' RKB. Return 3K-1031-1 to injection. 3Wp 1/10/2019 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, January 8, 2019 5:01 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: KRU 2N-309 (PTD# 199-021) Report of Failed MITIA Attachments: 2N-309 90 day TIO trend 1.8.19JPG; MIT KRU 2N-309 01-08-19.xlsx Chris, KRU TARN WAG Injector (PTD# 199-021) was reported on October 27, 2018 for suspect IA pressure increase. Diagnostics located a tubing leak at —7013' and a tubing patch repair was approved per sundry # 318-528. The tubing patch was installed and successfully passed a diagnostic MITIA on December 27, 2018. The TIO trends appeared stable and did not indicate communication. Today the State Witnessed MITIA Failed. The well is being shut in and freeze protected as soon as possible. Diagnostics utilizing DHD and Slickline will attempt to locate and repair the communication. Proper paperwork will be submitted once a plan forward has been developed. A 90 day TIO trend and 10-426 are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Gores Cohfl ips Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEngi nee@ bp.com > Sent: Tuesday, January 8, 2019 2:35 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Boman, Wade; Glasheen, Brian P; Igbokwe, Chidiebere Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector B-34 (PTD# 1930370) surface repairs complete and ready to be POI, will need 4 year AOGCC MIT -IA All, Injector B-34 (PTD #1930370) was made Not Operable for tracking purposes after it lapsed on its 4 -year AOGCC MIT -IA. The surface repairs are complete and the well is now ready for Injection. Once the well is on stable injection an AOGCC MIT -IA will be performed. The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Tuesday; December 25, 2018 3:23 PM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WelipadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad AB <AKOPSWeliPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWeliPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEt)CTL <AKOPSPCCEOCTL@bp.com>; Boman, Wade <Wade.Boman@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Ch idiebere. Igbokwe@bp.com>; 'chris.wa I lace@alaska.gov' <chris:wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp:com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCPeojectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity<AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWeIIOpk mpRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Ccrey. M unk@bp.com>; Obrigewitch, Beau Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 9, 2019 4:18 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Nottingham, Derek; Ohms, Danielle H; Rupert, C. Ryan; Stechauner, Bernhard; Summers, Matthew; Worthington, Jessica Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey, Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector 16-14B (PTD #2060030) being prepared for Rig Sidetrack All, Injector 16-14B (PTD #2060030) is currently being prepped for a future Rig Sidetrack. Prior to de -completing the well, a tubing punch and jet cut will be performed. The compromised primary barrier means the well will now be classified as NOT OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 K2ik IT -►i0 ('m Z)GC*zo Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Saturday, January 5, 2019 2:15 PM To: Regg, James B (DOA) ' iq Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK Optimization Engr; Autry, Sydney; Braun, Michael (Alaska) Subject: LPP/SSV Returned to Service on well 1J-170 Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 1/5/2019, after the well was shut-in to troubleshoot an offset producer. The LPP had been defeated on 10/4/2018 after the well was returned to service to evaluate whether or not a matrix breakthrough remediation treatment was successful. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate L Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ -1-,./hr-i......9Patch 0 2.Operator ConocoPhillips Alaska, Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 0 Exploratory ❑ 212-165-0 f 3.Address: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic❑ Service❑ 6.API Number: • 50-029-23479-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 o KRU 3K-105 + 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/West Sak Oil Pool • 11.Present Well Condition Summary: Total Depth measured 12700 . feet Plugs measured NA ReE.0I true vertical 3599 • feet Junk measured NA feet Nov 1 0 2015 Effective Depth measured NA feet Packer measured 4992 feet �/" true vertical NA feet true vertical 3401 feet, O �„i Casing Length Size MD TVD Burst Collapse Conductor 79' 20 108' 108' NA NA Surface 2338' 15 2369' 2250' 5020 2260 Intermediate 5650' 9.625 5682' 3511' 5750 3090 Liner 7507 4.5 12633 3596' 8430 7500 Perforation depth Measured depth 5825'-12568' feet t, True Vertical depth 3521'-3593' feet0.0 '' 0 lLt Tubing(size,grade,measured and true vertical depth) 4.5 L80 4974' 3397' Packers and SSSV(type,measured and true vertical depth) Baker Premier Packer 4992' 3401' No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact Jan/Dusty Email N1617@Conocophillips.com Printed Name Jan Byrne Title Problem Wells Supervisor Signature c........4......— ✓ v^ Phone 659-7126 Date 11/7/2015 2/2-7C /2 Form 10-404 Revised 5/2015 A t 2 C RBDNISIOPV 13 2015 Submit Original Only S ri EC E1VED NOV 102015 ConocoPhillips CC Alaska .OG. P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 7th, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3K-105 (PTD 212-165-0) for tubing patch repair. Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659- 7224 if you have any questions. Sincerely, Jan B, e Problem Wells Supervisor Attachments S • 3K-105 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 3K-105 was discovered to have a tubing leak subsequent replacing the wellhead tree. A LDL located the leak at 2636'. A SMR-1B mandrel was set at 2625'-2642' to patch over the leak and maintain gas lift abilitiy. The following is the work performed to locate the leak, patch the tubing, and tests performed to prove integrity of the tubing. 08/23/15 PERFORM LEAK DETECT LOG W/ LRS PUMPING DOWN TUBING AT 0.5 BPM AND 600 PSI, UP IA TO ADJACENT FLOWLINE. LEAK FOUND AT 2636' IN GLM POCKET. RUN BACK IN HOLE AND LOG 24 ARM CALIPER SURVEY FROM TAG AT 5038' TO SURFACE. LOG CORRELATED TO TUBING DETAIL RECORD DATED 09 FEB 2013. JOB COMPLETE. 09/18/15 PULLED BAIT SUB AND P-PRONG @ 5,006' SLM PULLED 4-1/2" SLIP-STOP @ 5,024' SLM PULLED STA.# 1 BK-DMY(ext. pckg) @ 2,630' RKB PULLED DB PLUG @ 5,047' RKB BRUSH AND FLUSH TBG FROM 2,550' SLM TO 2,650' SLM -IN PROGRESS 09/20/15 DRIFT 15'x 3.8" DUMMY TO 2,800' SLM ATTEMPT TO SET WFT 4-1/2"WIDEPAK PACKER, PACKER FAILED TO RELEASE, DISCONNECT FROM TS @ DCR ATTEMPT TO PULL DIGITAL TOOLSTRING AND SETTING TOOL @ 2,595' SLM 10/16/15 SET WFT WIDEPAK LE PACKER W/238 SMR-1B MANDREL AND LATCH ASSEMBLY IN LOWER PACKER MID ELEMENT @ 2,625' RKB SET ER TEST TOOL IN UPPER PACKER @ 2,600' SLM LRS PERFORMED PASSING MIT-T TO 2,500 PSI PULLED ER TEST TOOL @ 2,600' SLM MIT-T 2nd attempt INITIAL T/I/0=2,300/0/180 STARTING T/I/0=2,500/0/180 1ST 15 MINS. TBG LOST 50 PSI. T/1/0=2,450/0/180 2ND 15 MIN. TBG LOST 25 PSI. T/I/0=2,425/0/180 11/06/15 (AC EVAL) : TIFL (PASSED). Initial T/I/O =211/785/157. IA FL @ 4772' (station#3, OV). SI wellhead @ WV&double block AL in manifold building and shut AL gate valve. Stacked WHP's to 775/720/94 in 45 min. IA FL @ same location. Bled AL line to 140 psi in 5 min. Double block AL line in back of wellhouse. Bled IA from 720 psi to 450 psi in 1 hour. T/I/O = 775/450/vac. IA FL @ same location. AL line @ 145 psi. Continued bleeding IA from 450 psi to 270 psi in 1 hour(2 hours total). T/I/O = 790/270/vac. IA FL @ same location. AL line @ 150 psi. Monitor for 1 hour. 15 min T/I/O = 790/270/vac. 30 min T/I/O = 790/270/vac. IA FL @ same location. 45 min T/I/O = 790/270/1. 60 min T/I/O = 790/270/11. IA FL @ same location. AL line @ 153 psi. (Passed). Final T/I/O = 790/270/11. , KUP PROD • 3K-105 ConocoPhillips 6 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(f0KB) crmoetdat, 500292347900 NE WEST SAK PROD 100.11 7,952.92 12,700.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MULTIPLE LATERALS-3K-105,10/29/2015 7:44:50 AM SSSV:NIPPLE 95 1/18/2015 Last WO: 2/12/2013 • Verbal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;226-. SI8_E4_r-<? Last Tag' Rev Reason:PATCH pproven 10/29/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 29.0 108.0 108.0 94.00 X-65 WELDED CONDUCTOR;29.0-108.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)...Wt/Len g...Grade Top Thread SURFACE 133/8 12.415 31.0 2,369.1 2,250.4 68.00 L-80 BTC NIPPLE;599.7 ..'-" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 31.4 5,681.7 3,511.4 40.00 L-80 BTC i Casing Description OD(in) ID(in) Top(ft613) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE;31.0-2,369.1 LINER DIVERTER ASSY 8.51 7.730 5,066.9 5.164.2 3,441.3 2.97 Liner Details GAS LIFT;2,630.3 Sentinel ID PATCH;2,642.0it Top(066) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) s 5,066.9 3,418.7 76.55 DIVERTER T2 SEAL BORE DIVERTERr-length above collet profile 7.730 GAS LIFT;3,545.8 f/RAM Hanger 5,069.9 3,419.3 76.58 DIVERTER T1 SEAL BORE DIVERTER,-Length below collet profile 7.730 GAS LIFT;4,7715 5,115.4 3,430.0 76.39 NIPPLE CAMCO DB-6 3.563"NO GO NIPPLE 3.563 SLEEVE;4,856.2 5,134.7 3,434.5 76.49 ANCHOR MLHR PRODUCTION ANCHOR 3.910 5,138.9 3,435.5 76.55 ANCHOR MLHR PRODUCTION ANCHOR 3.910 GAUGE;4,903.9 5,161.0 3,440.6 76.82 SEAL ASSY BAKER 4.5"SEAL ASSEMBLY 3.870 IMF Mk Casing Description OD(in) ID(in) "Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER LEM 41/2 3.9401 4,948.8 5,089.3 3,423.9 30.89 4.5 LOCATOR;4,9519 Liner Details g. I SEAL ASSY;4,952.6 �- Nominal ID SHOE;4,973.0 - Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) si 4,948.8 3,391.8 77.88 SLEEVE 7"HRD-E Liner Setting SleeveHR w/7.50"ID ext.6' 6.220 • 4,958.7 3,393.9 77.68 SBR 'Seal Bore 4 3/4" 4.750 I.II 4,991.6 3,401.1 77.00 PACKER BAKER PREMIER PACKER 3.880 5,047.4 3,414.1 76.38 NIPPLE CAMCO LANDING DB NIPPLE 3.750 5,062.7 3,417.7 76.52 COLLET RAM Hanger LEM Completion Module(Collet to top 3.960 IL Of LEM) LINER LEM;4,948.8-5,069.3 5,064.8 3,418.2 76.54 COLLET RAM Hanger LEM Completion Module(Collet to re- 3.960 D-SAND LINER;5,062.3- entry) t2,055.5 5,087.6 3,423.5 76.55 WLEG BAKER WIRELINE RE-ENTRY GUIDE 3.730 litCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -- B-SAND LINER 41/2 3.476 5,125.8 12,633.0 3,595.7 11.60 L-80 BTC Nominal ID Liner Details _t.it.i-:6:a q,-e;, Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) �'- 5,125.8 3,432.4 76.39 PACKER MLZXPw/HR PROFILE LINER TOP PACKER 6.100 LINER DIVERTER ASSY; - 5,153.8 3,438.9 76.73 SBR 4.750"SEAL BORE 4.750 5,066.9-5,184.2 la5,720.8 3,513.9 86.05 Swell Packer FREECAP SWELL PACKER 4.000 5,798.5 3,518.9 86.47 SENSOR TRACERO OIL/WATER TRACER CARTIDGE 5 1/2" 4.500 € x 4 1/2" INTERMEDIATE;31.4-5,681.7 6,455.2 3,523.0 89.28 Swell Packer FREECAP SWELL PACKER 4.000 - 6,657.5 3,525.9 89.57 SENSOR TRACERO OIL/WATER TRACER CARTIDGE 5 1/2" 4.500 U x 4 1/2" 7,576.5 3,537.0 91.66 Swell Packer FREECAP SWELL PACKER 3.476 8,306.7 3,477.8 91.01 Swell Packer FREECAP SWELL PACKER 3.476 SLOTS;5,825.0-6,404.0 _ _ 8,385.0 3,478.0 88.53 SENSOR TRACERO OIL/WATER TRACER CARTIDGE 5 1/2" 4.500 x41/2" 9,162.0 3,498.6 86.70 Swell Packer FREECAP SWELL PACKER 3.476 SLOTS;6,521.0-6,646.0 _ 9,240.1 3,504.3 85.00 SENSOR TRACERO OIL/WATER TRACER CARTIDGE 5 1/2" 4.500 X 4 1/2" 10,350.5 3,529.0 88.13 Swell Packer FREECAP SWELL PACKER 3.476 10,428.2 3,531.9 87.46 SENSOR TRACERO OILNVATER TRACER CARTIDGE 51/2" 4.500 SLOTS;6,944.0-7,524.0 - - X 4 1/2" - 11,496.5 3,568.9 90.99 Swell Packer FREECAP SWELL PACKER 3.476 11,573.9 3,567.4 91.25 SENSOR TRACERO OILNVATER TRACER CARTIDGE 51/2" 4.500 x 4 1/2" Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.980 22.6 4,973.5 3,391.1 12.60 L80 IBTM SLOTS;9.4150-6.112.0 - - Completion Details _ _ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.6 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 3.833 599.7 597.3 10.25 NIPPLE CAMCO DB-6 NIPPLE w/3.875"NO GO PROFILE 3.875 4,856.2 3,372.8 78.39 SLEEVE BAKER CMU SLIDING SLEEVE W/3.812"PROFILE 3.810 SLOTS;9,266.0-10,300.0 4,903.4 3,382.4 78.16 GAUGE SLB guage carrier,IBTM,Pin X Pin(4903') 3.870 4,951.9 3,392.4 77.82 LOCATOR BAKER LOCATOR SUB 3.870 4,952.6 3,392.5 77.80 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.870' 4,973.0 3,396.9 77.38 SHOE MULE SHOE 3.870 SLOTS;10,454.0-11,415.0 _ Perforations&Slots SLOTS;11,084.0-11,705.0 Shot - Dens Top(ND) Btm(TOD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 5,825.0 6,404.0 3,520.5 3,522.4•WS B,3K-105 1/20/2013 32.0 SLOTS SLOTTED LINER 6,521.0 6,646.0 3,523.9 3,525.8 WS B,3K-105 1/20/2013 32.0 SLOTS k SLOTS;12,070.0-12,568.0 6 • -SANG LI9NER; ,125.8- II- 12,633.01 KUP PROD • 3K-105 ConocoPhillips Alaska,Inc. conocoPHatpc MULTIPLE LATERALS-3K-105,10/292015 7:44:54 AM Vertical schematic(actual) -- - - HANGER,22 6— Perforations&Slots Shot Dens CONDUCTOR 29.0-108.0 4Tap(TVD) Blm(TVD) (shots/f Top(flKB) Btm(ftKB) OMB) (flKB) Zone Date t) Type Com NIPPLE;599.7 — 6,944.0 7524.0 3,530.6 3538.4 WS B,3K-105 1/20/2013 32.0 SLOTS 8,411.0 9,112.0 3,478.9 3,496.2 WS 6,3K-105 1/20/2013 32.0 SLOTS SURFACE;31.0-2,369.1 GAS UFT Z630 9,266.0 10,300.0 3506.5 3527.4 WS 6,3K-105 1/20/2013 32.0 SLOTS PATCH;2,642.0 ..� 10,454.0 11,445.0 3,533.1 3,569.5 WS B,3K-105 1/20/2013 32.0 SLOTS GAS LIFT;3,545.8 11,084.0 11,705.0 3,554.4 3,564.5 WS B,3K-105 2/6/2013 32.0 SLOTS GAS LIFT;4,771.5 12,070.0 12,568.0 3,584.6 3,592.9 WS B,3K-105 2/6/2013 32.0 SLOTS SLEEVE;4,856.2 Mandrel Inserts St GAUGE,4,903.4 __ all on Top(TVD) Valve Latch Port Size TRO Run N Top(flKB) (flKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corer 2 3,545.8 3,111.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/2112015 9:00 LOCATOR;4,9519 -�� 3 4,771.5 3,357.0 CAMCO KBMG 1 GAS LIFT OV �BK-5 0.313 0.0 8/18/2015 11:30 SEAL ASSY,4,952.6 Notes:General&Safety SHOE;4,973.0 ' - End Date Annotation 2/12/2013 NOTE:MULTI-LATERAL WELL 3K-105,3K-105L1 LINER LEM;4,948.8-5,089.3 :'1 D-SAND LINER;5,082.3- 'k 12,655.5 111 111 Ti�FF LINER DIVERTER ASSY; c � 5,086.9-5,164.2 INTERMEDIATE;31.4-5,881.7 SLOTS;5,825.0-6,404.0 SLOTS;6,521.0-6,6446.0 _ SLOTS;6,944.0-7,524.0 SLOTS;8,411.0-9,112.0 SLOTS;9,266.0-10,300.0 SLOTS;10,454.0-11,445.0, ,— SLOTS, 0,454.0-11,445.0 SLOTS;11,084.0-11,705.0 SLOTS;12,070.0-12,568.0 B-SAND LINER;5,125.8- 12,633.1 2x2.— Go5 • -x S 5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 15, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 0/'3/2o15 M.K.BENDER Anchorage, Alaska 99501 OCT 0 8 Z015 RE: Multi Finger Caliper(MFC) & Leak Detect Log (LDL): 3K-105 Run Date: 8/23/20151A C 1 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3K-105 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23479-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 %PAKp Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed"1o4 '`4/`E:itea Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. La - 1 23" Well Histo File Identifier Organizing (done) Two-sided ❑ Rescan Needed ;SCAN: OVERSIZED: NOTES: for Items: ‘097/1 ps: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: dEP Date: a 31 / /sl Mr Project Proofing BY: a, Date: I c 3 ii I /s/ vYiP Scanning Preparation x 30 = INS- 0 + =TOTAL PAGES �O ID (Count does not include cover sheet) BY: Caria Date: `� 3 /s/ J I Production Scanning Stage 1 Page Count from Scanned File: ' 57 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: a, Date: 1 CT 3 I { L6 /s/ vvi p Stage I If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES • TOTAL PAGES: P Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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H o O co a 9 a11 w a.D U W 0Z U 0 q Z o Q N J/� o I 0. 1 ° E � o a Ij O r. E U � o a 0 d 0 J E v Mu Q M C a U a fA M •, 5 • o N > I I I CO cc N a o ° i hi. Q Y o _ V Q Z EE z \ d I ` rn U) C) - l In up p m CI; 9 N 3 N d d a' 6• o^ o 'vi u m to u E Z. 8 E co) E 1 E a 2 U I U ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 19, 2014 Commissioner Cathy Foerster Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped April 29, 2004, May 26, 2013 &August 1, 2013. The corrosion inhibitor/sealant was pumped April 5, 2014, April 6, 2014 & April 13, 2014. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, 74-"e'//: G MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 4/19/2014 1A, 1D, IL, 2G,3H,3J&3K PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1A-24 50029229840000 2001810 6" NA 48" NA 23 4/5/2014 1D-103 50029230860000 2020960 21' 3.0 37" 8/1/2013 20.37 4/13/2014 1L-29 50029221570000 1910510 SF NA 8" NA 2.1 4/5/2014 2G-07 50029211240000 1840850 SF NA 29" NA 3.4 4/13/2014 3H-24 50103202350000 1960150 25' 3.00 17" 4/29/2004 2.97 4/6/2014 3J-17 50029227000000 1961460 SF 1.00 20" 5/26/2013 9.4 4/6/2014 3K-105 50029234790000 2121650 34" NA 34" NA 13.6 4/6/2014 Schwartz, Guy L (DOA) From: Myers, Monty M <Monty.M.Myers@conocophillips.com> Sent: Friday, August 23, 2013 9:08 AM To: Schwartz, Guy L(DOA) Subject: 3K-105 Information Attachments: Doyon 141 3K-105 Surface.pdf; Doyon141 3K-105 Intermediate.pdf; 3K-105 Surf Rpt WV.pdf Guy, Attached are the cement reports for both the surface and the intermediate on 3K-105.The intermediate report does notate that we lost returns during cement displacement,and also notates where we regained returns shortly thereafter (strokes are associated). For the surface cement job, we pumped an 11.09 lb/gal lead Arctic LiteCRETE slurry with a yield of 1.90 ft3/sk, and a 12 lb/gal tail LiteCRETE slurry with a yield of 1.63 ft3/sk. For the intermediate cement job,we pumped a 12.5 lb/gal lead LiteCRETE slurry with a yield of 1.56 ft3/sk,and a 15.8 lb/gal tail slurry with a yield of 1.16 ft3/sk. There is no mention on the Schlumberger cement report as to how many bbls of cement were returned to surface,so I included the cement report from Wellview that states we returned 320 bbls of cmt to surface. Please let me know if you have any questions or need any more information. 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SOT-:I£ �N alol 3gS14a1 �N- IIaM 4 li Well lob Wart Customer lob Number 3k-105 jib kapurak Dec/28/2012 Conoco BVCN-00060 Data Thee Treating Rory Ruta Marry IA Message 24-hr Pressure Rate Wags Density PreeMrre deck PSI PIN Volume 1a/0 PSI SBL 12/28/2012 13:35:27 69 0.0 19.9 0.00 -1250 12/28/2012 13:38:47 9 0.0 19.9 0.00 -1250 Post LJob Summary Average Pump Rates,bbl/min Volume of Fluid Injected,bbl Slurry 52 Mud Maximum Rate Ted Slurry Mud Spacer N2 4.0 6.4 653.3 0.0 0.0 Treating Pressure Summary,psi Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 3692 0 332 bbl Ib/gal Avg.52 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? 0 Volume bbl % 0.0 bbl 0.0 bbl degF Washed Tlru Pers ❑ To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost 0 fob Completed 11 Undy Byerly - - Page 6 of 6 'Z2�� 212�� -2...\-2_- k�,Ca O S? RECEIVED MAR 1 2 2013 WELL LOG TRANSMITTAL l 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"TVD 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.Bryant(ahalliburton.com Benjamin.Schulze@halliburton.com r Date: A 3 l \3 Signed: glaidc,<.--- 2) 62e.e .efr I STATE OF ALASKA MAR 0 8 2013 ALASK ,OIL AND GAS CONSERVATION COMMIS.,ION QQ WELL COMPLETION OR RECOMPLETION REPORT ANDE?&CC la.Well Status: Oil O Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb Well Class: 20AAC 25.105 20AAC 25.110 Development a Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions. Service ❑ StratigraphicTest❑ 2 Operator Name5.Date Comp.,Susp, 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband: February 12,2013• 212-165/ 1 3.Address. 6.Date Spudded 13 API Number: P.O.Box 100360,Anchorage,AK 99510-0360 December 25,2012• 50-029-23479-00 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 17,2013• • 3K-105,3K-105PB1,3K-105PB2 Top of Productive Horizon. 8. KB(ft above MSL): 61'RKB• 15 Field/Pool(s): 776'FSL,2802'FEL,Sec.35,T13N, R9E, UM GL(ft above MSL): 33'AMSL. Kuparuk River Field • Total Depth 9 Plug Back Depth(MD+TVD)• 95'FSL,574 FEL,Sec.36,T13N, R9E, UM 12633'MD/3596'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 12700'MD/3599'TVD• ADL 25519 • TPI: x-531469 y- 6007779 Zone-4 11 SSSV Depth(MD+ND): 17.Land Use Permit Total Depth: x-538978 y- 6007133 Zone-4 nipple @ 600'MD/597'ND 2555 18.Directional Survey: Yes ❑✓ 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'ND 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 not applicable 23. CASING,LINER AND CEMENTING RECORD 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 5126' 12633' 3432' 3596' 6.75" slotted liner 24 Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5" 4974' 4992'MD/3401'ND,5126'MD/3432'ND slots from 5825'-6404'MD 3520'-3522'ND slots from 6521'-6646'MD 3524'-3526'ND 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC. slots from 6944'-7524'MD 3531'-3541'ND -J.1 k Was hydraulic fracturing used during completion? Yes Li No Q slots from 8411'-9112'MD 3479'-3496'ND - a DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED slots from 9266-10300'MD 3506'-3529'ND % 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 Li No 2 . Sidewall Cores Acquired? Yes Li No Q ' 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 8 7.013,4 -11 Form 10-407 Revised 10/2012 -?/1•I (/r•� CONTINUED ON REVERSE 4 •/O./ Submit original only w .'6`1f G 29 GEOLOGIC MARKERS(List all formations and mar icountered). 30. FORMATION TESTS NAME MD TVD Well tested? Ei res Q✓ No , If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 2369' 2250' needed,and submit detailed test information per 20 AAC 25.071. West Sak Sand 5032' 3410' West Sak B Top 5530' 3500' West Sak B Bottom 11766' 3566' 3K-105PB1 N/A total depth 11139' 3557' 3K-105PB2 total depth 11364' 3567' Formation at total depth: Kuparuk B - 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 /�/�3 Email Printed Name G.Alvord `•` Title: Alaska Drilling Manager Signature / r y-04-- Phone 265-6120 Date 3(7(2....o'Z. 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-105 ConocoPhillips 0-4' ' ell Attributes lax Angle&MD TD Alaska,111.;. Wellbore API/UWI Field Name Well Status in (C) MD(ftKB) Act Btm(ftKB) 500292347900 NE WEST SAK EXPEND 1100.11 7,952.92 12,700.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Confq:MULTIPLE LATERALS-3K-105,2,22,201312:17.02 PM SSSV:NIPPLE Last W0: 2/12/2013 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,23 d,, Last Tag: Rev Reason:NEW WELL osborl 2/20/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 20 19.124 29.0 108.0 108.0 94.00 X-65 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd SURFACE 133/8 12.415 31.0 2,369.1 _ 2,250.4 68.00 L-80 BTC CONDUCTOR, MIN Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 29-106 INTERMEDIATE 95/8 8.835 31.4 ' 5,681.7 3,510.9 40.00 L-80 ETC NIPPLE.600 1."F Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd SUnFACE, LINER DIVERTER 8.51 7.730 5,066.9 5,164.2 3,441.3 2.97 31-2,360C ASSY GAS z e 0 Liner Details GAS LIFT, Top Depth 3' I- (ND) Top Incl Nomi... GAS4 7 Top(ftKB) (ftKB) F) Item Description Comment ID(in) SLEEVE,4,8565,066.9 3,418.6 76.55 DIVERTER T2 SEAL BORE DIVERTERr-length above collet profile f/RAM Hanger 7.730 1 GAUGE,4,903 _ LOCATOR. 5,069.9 3,419.3 76.58 DIVERTER Ti SEAL BORE DIVERTER,-Length below collet profile 7.730 4,952 SEAL ASSY, . 5,115.4 3,429.9 76.26 NIPPLE CAMCO DB-6 3.563"NO GO NIPPLE 3.563 4,953 SHOE.4.9731 5,134.7 3,434.2 76.25 ANCHOR MLHR PRODUCTION ANCHOR 3.910 LINER LEM, 4,949-5,089 I n •I 5,138.9 3,435.3 76.34 ANCHOR MLHR PRODUCTION ANCHOR 3.910 LINER DIVERTER , 'I-- 5,161.0 3,440.5 76.77 SEAL ASSY BAKER 4.5"SEAL ASSEMBLY 3.870 ASSY, 5.067-5,164 1" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd NTERMEDIATE 31-5,682 LINER LEM 4 1/2 3.940 4,948.8 5,089.3 3,423.5 30.89 4.5 SLOTS, 5,825-6,404 Liner Details SLOTS, Top Depth 6,5216.846 (ND) Top Incl Nomi... 8,944-7..524 Top(ftKB) (ftKB) (°) kern Description Comment ID(in) SLOTS, 1 4,948.8 3,391.8 77.88 SLEEVE 7"HRD-E Liner Setting SleeveHR w/7.50'ID ext.6' 6.220 8,4119,112 SLOTS, 4,958.7 3,393.9 77.68 SBR Seal Bore 43/4" 4.750 9,266-10.300 _ SLOTS, . 4,991.6 3,400.6 75.90 PACKER BAKER PREMIER PACKER 3.880 10,454-11.445 SLOTS 5,047.4 3,414.0 76.38 NIPPLE CAMCO LANDING DB NIPPLE 3.750 11,084.11,705 SLOTS, 5,062.7 3,417.6 76.52 COLLET RAM Hanger LEM Completion Module(Collet to top Of LEM) 3.960 12,070-12,565 B-SANI 1 t 5,064.8 3,418.1 76.54 COLLET RAM Hanger LEM Completion Module(Collet to re-entry) 3.960 512612,633 i 5,087.6 3,423.1 75.92 WLEG BAKER WIRELINE RE-ENTRY GUIDE 3.730 D-SAND LINER, ;, ° Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd 5,062-12,655Lfiiiiiiiiiii• B-SAND LINER 41/2 3.476 5,125.8 12,633.0 11.60 L-80 BTC Immo Liner Details lirk Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) F) nem Description Comment ID(in) 1 ' 5,125.8 3,432.0 76.08 PACKER MLZXP w/HR PROFILE LINER TOP PACKER 6.100 it 5,153.8 3,438.9 76.63 SBR 4.750"SEAL BORE 4.750 5,720.8 3,513.9 8622 Swell Packer FREECAP SWELL PACKER 4.000 III 5,798.5 3,518.8 86.47 SENSOR TRACERO OIL/WATER TRACER CARTIDGE 51/2'x412" 4.500 6,455.2 3,523.0 89.32 Swell Packer FREECAP SWELL PACKER 4.000 6,657.5 3,525.9 89.74 SENSOR TRACERO OIL/WATER TRACER CARTIDGE 51/2'x412" ' 4.500 • I A 7,576.5 3,537.4 92.40 Swell Packer FREECAP SWELL PACKER 3.476 8,306.7 3,477.9 91.26 Swell Packer FREECAP SWELL PACKER 3.476 1111. 8,385.0 3,477.5 87.22 SENSOR TRACERO OILNVATERTRACER CARTIDGE 51/2'x412" 4.500 9,162.0 3,489.6 79.82 Swell Packer FREECAP SWELL PACKER 3.476 rz 9,240.1 3,504.1 84.28 SENSOR TRACERO OILJINATER TRACER CARTIDGE 51/2'x41/2" 4.500 i 10,350.5 3,529.5 88.19 Swell Packer FREECAP SWELL PACKER 3.476 I ;:--"./ 10,428.2 3,532.2 86.73 SENSOR TRACERD OIL/WATER TRACER CARTIDGE 512"x41/2' 4.500 11,496.5 3,569.4 91.10 Swell Packer FREECAP SWELL PACKER 3.476 C 1 i m 11,573.9 3,567.9 91.26 SENSOR TRACERO OILNVATER TRACER CARTIDGE 51/2"x41/2" 4.500 s- Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 41/2 3.980 22.6 4,973.5 3,397.0 12.60 L80 IBTM Completion Details Top Depth _ (ND) Top Incl Nomi... III Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 22.6 22.6 0.41 HANGER VETCO GRAY TUBING HANGER 3.833 ,1 599.7 597.3 1025 NIPPLE CAMCO DB-6 NIPPLE w/3.875"NO GO PROFILE 3.875 L-1 611111...- 4,856.2 3,372.7 78.23 SLEEVE BAKER CMU SLIDING SLEEVE W/3.812"PROFILE _ - 3.810 III 1 ■ 4,903.4 3,382.8 78.82 GAUGE SLB guage carrier,IBTM,Pin X Pin(4903') 3.870 4,951.9 3,392.4 77.82 LOCATOR BAKER LOCATOR SUB 3.870 3.870 3.870 4,952.6 3,392.6 77.80 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 4,973.0 3,396.9 77.38 SHOE MULE SHOE Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh-._ Type Comment IIII5,825.0 6,404.0 3,520.4 3,522.3 WS B,3K-105 1/20/2013 32.0 SLOTS SLOTTED LINER 6,521.0 6,646.0 3,523.9 3,525.8 WS B,3K-105 1202013 32.0'SLOTS 6,944.0 7,524.0 3,530.5 3,540.8 WS B,3K-105 1/20/2013 32.0 SLOTS 8,411.0 9,112.0 3,478.8 3,496.4 WS B,3K-105 1/20/2013 32.0 SLOTS 14 9,266.0 10,300.0 3,506.3 3,528.5 WS B,3K-105 1/20/2013 32.0 SLOTS Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) 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 2 3,545.8 3,111.1 67.16 CAMCO KBMG 1 GAS LIFT SOV DCK2 0.000 2,500.0 2/11/2013 TD(3K-105), I1 3 4,771.5 3,357.0 79.92 CAMCO KBMG 1-GAS LIFT DMY BK-5 0.000' 0.0 2/6/2013 12.700 ' KUP 3K-105 ConocoPhillips 0.; Alaska.Inc. CongaP illips KB-Grd(R) Rig Release Date "' 2/12/2013 Well Confp:MULTIPLE LATERALS-3K-105,2/22/201312:17 02 PM — I Actual -ASS/ HANGER,23 7 Perforations&Slots Shot Top(TVD) Elbe(TVD) Dens Top(kK8)Btm MKS) (R103) MEI) Zone Date 0h-- Type Comment 10,454.0 11,445.0 3,533.7 3,570.2 WS B,3K-105 1/20/2013 32.0 SLOTS CONDUCTOR, 11 084.0 11,705.0 3,555.0 3,565. WS B,3K-105 2/62013 32.0 SLOTS 29-108 NIPPLE.600 4 12,070.0 12,568.0 3,585.8 3,594.4 WS B,3K-105 2/6/2013 32.0 SLOTS SURFACE, Notes:General&Safety 31-2.369 End Date Annotation GAS LIFT, 2,830 2/12/2013 NOTE:MULTI-LATERAL WELL 3K-105,3K-105L1 GAS LIFT. 3,546 GAS LIFT, 4,772 SLEEVE,4,858.856 GAUGE.T.O -.. LOCATOR. 4,952 SEAL ASSY, 4,953 SHOE,4,973 LINER LEM. 4,949-5.089 --4• •I LINER DIVERTER , ASSY,' 5,067-5,164' {®I NTE RUED TATE, 315,682 SLOTS, 5,8255,404 SLOTS, ri 6,5215,846 SLOTS, 6,9447,524 SLOTS, 8,411-9,112LOTS, 4 SLOTS, 9,268-10,300 SLOTS, 10,45411,445 SLOTS, 1 I 11,08411,705 1 '®' SLOTS. 12.070-12,568 B-SAND I LINER, 5,126-12,633 I D-SAND 5,062-12.655 LINER.R. .. . i. II . E I : I I —I i 11 TD(3K-105). 1 I 12,700 ConocoPhillips Time Log & Summary We/lv,ew 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 U 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 U 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. Depth E. Death 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 t/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 I, 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'U 103' 08:15 11:00 2.75 103 243 SURFA( DRILL DDRL P Drill f/103't/243',gyro every connection.TVD-245,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'U 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'U 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/0=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 U 2141'TVD=2041' 00:00 06:00 6.00 915 1,213 SURFA( DRILL DRLG P Cont.drilling f/915't/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'U 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'U 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'U 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'U 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/0=81K, POOH f/2190'U 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. 0745 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 1815 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 U 2332',M/U landing jt. land on hanger,Circ&cond. mud staging pumps U 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 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 U RIH U 1674' 00:15 01:00 0.75 1,674 1,674 SURFA( CASING CIRC P CBU stage pumps U 210 gpm,300 psi 01:00 03:30 2.50 1,674 2,332 SURFA( CASING RNCS P Continue U run csaing f/1674'U 2332' 03:30 03:45 0.25 2,332 2,369 SURFA( CASING RNCS P M/U landing joint,wash casing U bottom @ 2369' 03:45 07:30 3.75 2,369 2,369 SURFA( CASING CIRC P Circ.and condition mud Staging pumps U 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. Depth 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 V 3500 psi, 15 bbls of CW100, mix& pump 50 bbls 10.5ppg mud push, drop bottom plug,437 bbls of 11.09 lead cmt, 103 bbls of 12ppg tail cmt, drop top plug,20 bbls of H2O,chase plug w/318 bbls of mud, Bump plugs w/3184 stks, FCP @ 42 gpm 350 psi,pressure up V 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"Diver-ter 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 V 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 V 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'RURD P 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-TRIPP TIH with hwt and P/U singles from shed to 1503'MD, P/U=95K,S/O= 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-TRIPP Continue singling in the hole w/ drilling BHA f/1503'U 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 U 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 ppg EMW 08:30 09:15 0.75 2,334 2,400 INTRM1 DRILL CIRC P P/U stand RIH U 2400'Displace drill out mud w/9.4ppg LSND mud. 09:15 12:00 2.75 2,400 2,520 INTRM1 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,S/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 INTRM1 DRILL DRLG P Directional Drill 12-1/4"Hole from 2520'-2891'MD,TVD-2706'MD, Pumps @ 700 gpm, PSi-1650, WOB-3K, P/U wt= 135K, S/0 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. Death 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,TVD-2971'MD, Pumps @ 700 gpm, PSi-1650, WOB-5K, P/U wt=140K,S/0 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'(TVD=3390') 00:00 06:00 6.00 3,261 3,631 INTRM1 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 INTRM1 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,S/O 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,S/O 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, (TVD 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. Depth 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,TVD-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,S/O 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', L/D 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 INTRM1 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 INTRMI CASING CIRC P CBU with 750 gpm 1900 psi,while working pipe and rotary. 18:00 18:15 0.25 2,335 2,335 INTRMI 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 PP9) 02:15 02:45 0.50 5,687 5,687 INTRM1 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 INTRMI 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 INTRM1 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 INTRM1 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 INTRM1 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 01/03/2013 From 24hrSummaTory Dur S. Depth E. Depth Phase Code Subcode T Comment 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/1 bpm 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,S/O= 111K,Calc=38.52 _ bbls,Act=33.6 bbls. 18:00 20:00 2.00 5,687 5,687 INTRM1 CEMEN"CIRC P L/D 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 INTRM1 CEMEN"CIRC P Break circulation @ 5 bpm 250 psi, while recip.string 30', P/U=185K, ,S/0=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 INTRM1 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. 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. Death 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 INTRMI 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 13-3/8'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 INTRMI 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 INTRM1 CEMEN'TRIP P 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 INTRM1 CEMEN'CIRC P 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 TVD 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 INTRM1 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 INTRM1 CEMEN-CIRCP 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 INTRM1 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. UD 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 Time Logs Date From To Dur S. Death E. Death 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=3527',ART=2.26,ADT=2.26, Jar hrs=2.26, Bit hrs=2.26, P/U= 115K,S/O=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.Death E. Death 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/0=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,5/0=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.ND=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 1DDRL 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/0=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. Death 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,SIO=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,SIO=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,SIO=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/O=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.TVD=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 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, SIO=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. Death 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,S/O=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/0=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 U 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 U 7074'.CBU and POOH on elevators UD BHA. Rig up and start testing BOPE U 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' MD U 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. 0930 11:45 2.25 7,074 7,074 PROD1 DRILL CIRC T Attempted to get MWD detection, no success.Circulate hole clean @ 6 bpm=2500 psi, 50 rpm,Tq=4K, P/U= 105K,S/0=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. 01/12/2013 Complete BOP test t/250/3500 psi,Jeff Jones of AOGCC waived witness of test. Make up BHA#5 and RIH t/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 U 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 U 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,5/0=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'MDU 10826' MD. Pump @ 2.5 bpm=700 psi, Rot @ 20 rpm w/6K Tq. P/U=112K, 5/0=80K, Rot=94K. Slow pump rate U 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'MDU 10823' MD. Pump @ 1 bpm=275 psi, Rot 20 rpm w/6 K Tq. P/U=112K,S/0= 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 U 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'U 11194'.Time drilled f/11194'U 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'U 10427', UD 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'U 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/11103 U 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'U 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/0=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't/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 t/ 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'U 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 CASING SVRG 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 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&R/U 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 U 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 U 3600 psi release running tool, bleed off tool verify tool is released, Pressure test Ann.U 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 t/MOBM @ 210 gpm 300 psi,Obtain SPR's 18:00 1815 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 U 4903'Madd Pass f/4903'U 4983',Orient whip stock,set anchor,shear whipstock,Mill window,TOW @ 5074'BOW @ 5091'amd 20'new hole to 5111'.CBU and perform FIT U 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, S/O=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. UD, P/U Scraper/Magnet BHA RIH t/5111', POOH, UD 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 L/D BHA. 16:00 17:00 1.00 0 0 PROD2 DRILL PULD P L/D 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 t/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& manIBOP,TIW&Dart4"&5",4" Demco, HCR&man choke&kill,w/ 4"4.5"&5"test jts U 250 low 3500 high,test ann.t/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 t/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,PUW-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'V 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'V 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'V 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'V 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'V 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 V 6314'trough and side track well,drill t/6482'high dog leg observed, POOH V 6205'trough and side track well @ 6220'Drill ahead V 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 t/6290'cut trough t/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 V 6314' time drill f/6314'V 6338'kicked off. 10:00 12:00 2.00 6,338 6,482 PROD2 DRILL DDRL T Drill f/6338't/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't/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 V ream out dogleg to high. Discuss w/town geology. 14:30 15:00 0.50 6,586 6,205 PROD2 DRILL TRIP T POOH t/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'U 6232', 3473'-ND,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'U 6385'ND-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'U 7326',Change out leaky swivel packing. 00:00 06:00 6.00 6,385 6,485 PROD2 DRILL DDRL T Drill f/6385'U 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'ND-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'ND,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'U 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'U 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 U 7342'Observe dogleg, P/U U 7250'trough U 7280 side track&time drill t/7295'Drill ahead U 7780' CBU, OWFF, BROOH U 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'U 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 U 7250'start troughing U 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'U 7342'ADT-.85, PUW-110,SOW-71, ROTWT-90 Page 25 of 41 Time Logs Date From To Dur S. Death 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'TVD, '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'U 7780'3475'TVD, 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't/4" X-Over. 21:45 2245 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 w/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'U8246'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'TVD-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'TVD-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. Death E. Death Phase Code Subcode T Comment 06:00 12:00 6.00 9,361 9,775 PROD2 DRILL DDRL P Drill f/9361'U 9775'ND-3438', ADT-3.43,Jar hrs-186.66, BIT HRS-68.49, PUW-121,SOW-60, ROTWT-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'ND-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'ND-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'ND-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'U 11,960'ND-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,ND=3555',CBU X 3,Monitor well and back ream to 4"dp, L/D 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'U 12,145'TVD-3539', ART-3.19,Jar hrs-209.30, BIT HRS-91.13, PUW-170,SOW-42, ROTWT-92,TQ-8K,TQ 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. Death Phase Code Subcode T Comment 06:00 12:00 6.00 12,145 12,475 PROD2 DRILL DDRL P Drill f/12,145't/12,475'TVD-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't/12,714 TVD-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,S/0=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,5/0= 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/O=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/0 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 RPEQPI SVRG 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,S/O= 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 RPEQPITRIP P POOH F/4,618'to HWdp,Monitor well(Static)POOH and L/D BHA. (Got back 22 lbs of metal debris on magnet) 18:30 19:15 0.75 0 0 COMPZ RPEQP1PULD 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,S/O=85K, Rot=90K,40 RPM.wash and ream to 4,798' 02/04/2013 Wash&ream to 5094',CBU, POOH and L/D clean out BHA,M/U whipstock retrieval tool and RIH, Pull whipstock,CBU thru choke,Monitor well, POOH L/D 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 RPEQP1TRIP 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 RPEQP1 TRIP P Rack back 4 stds of HWdp, L/D clean out BHA. 05:00 05:45 0.75 0 0 COMPZ RPEQP1 PULD 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 RPEQP1 TRIP 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. Death Phase Code Subcode T Comment 07:45 08:45 1.00 5,079 5,060 COMPZ RPEQP1 CIRC 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 RPEQP1 CIRC 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 RPEQP1OWFF 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 RPEQP1 TRIP 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 RPEQP1 PULD P Break&UD whip stock assembly. 19:15 20:00 0.75 0 0 COMPZ RPEQP1 PULD 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 RPEQP1 BOPE 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, CIO 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. Depth Phase Code Subcode T Comment 02/05/2013 24 hr Summary Continue testing BOP'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 RPEQP1 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 RPEQP1BOPE 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 RPEQP1BOPE P Rig down test equipment and blow down Top drive, and lines. 10:00 10:30 0.50 0 0 COMPZ RPEQP1 RURD P Pull tools to rig floor,and rig up tubing runinng equipment. 10:30 11.00 0.50 0 0 COMPZ RPEQP1SFTY 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 RPEQP1PULD 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 RPEQPI PULD 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 RPEQPI PULD 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 RPEQPI TRIP 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 RPEQP1OTHR 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 2200 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 RPEQPI CIRC 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 RPEQP1 TRIP 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 RPEQPITRIP 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 0830 1.00 549 0 COMPZ RPEQP1 PULD P Stand back HWDP, lay down MWD tools and SBD running tool. 08:30 08:45 0.25 0 0 COMPZ RPEQP1 OTHR P Clean and clear rig floor. 08:45 09:15 0.50 0 0 COMPZ RPEQP1SVRG 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. LID 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 t/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/O=85K without liner. P/U=146K,S/O=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 RPEQP1 CIRC 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 RPEQP1OWFF P Monitor well,slight flow then became static. 05:30 06:45 1.25 5,090 4,040 COMPZ RPEQPI TRIP 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 RPEQPITRIP 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 RPEQP1OWFF P Monitor well,static. 09:00 10:00 1.00 475 0 COMPZ RPEQP1PULD P Stand back HWDP and lay down running tool as per Baker rep. 10:00 11:00 1.00 0 0 COMPZ RPEQP1OTHR P Clean and clear rig floor. 11:00 12:45 1.75 0 0 COMPZ RPEQP1RURD P Rig up to run LEM,M/U MWD and stage in pipe shed. 12:45 16.00 3.25 0 0 COMPZ RPEQP1PULD 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 RPEQP1PULD 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 RPEQP1 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 RPEQPI 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 RPEQPI OTHR P Picked up 23', observed 15K overpull when cup pulled through packer.Set slips and L/D 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 RPEQP1 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"DR 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 RPEQP1 OPNW P Monitor well,slight flow becoming static. 00:30 04:30 4.00 4,970 462 COMPZ RPEQP1 TRIP 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 RPEQP1 OTHR 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 RPEQP1 PULD P Lay down 4"drill pipe from derrick vai mouse hole. 14:30 15:30 1.00 0 0 COMPZ RPEQP1 PULD P Change out handling tools and lay down 2 stands of drill collars. 15:30 16:00 0.50 0 0 COMPZ RPEQP1 PULD 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/O=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.Death 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 U 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 0/0 DCK valve on GLM#2(2500 casing U 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 TWC and test tree U 5000 PSI. Page 39 of 41 Time Logs Date From To Dur S. Death 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,5/0=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 UD 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 WHDBOTHGR 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/0=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 R/D 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., 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 U 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 DCIV 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 L F g amu n E I LI ConocoPhillips (Alaska) Inc NAD27 a, Kuparuk River Unit Kuparuk 3K Pad 3K-105 API:500292347900 - PTD:212-165 Sperry Drilling Services Definitive Survey Report , .; 19 February, 2013 211111 HAILLIIBURTDN 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-105 Survey Calculation Method: Minimum Curvature Design: 3K-105 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-105 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1 (nT) BGG M2011 1/20/2013 20.17 81.03 57,633 Design 3K-105 iuei«wmiimai,;,, -a, ,mom«: samME iiiiiiiimmiiIIIIMIiumiami IIIIIIMMIi I,.. iHuuuHmn0umr11111N ,,ixri ..4441 I, ,i Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,107.20 Vertical Section: Depth From(ND) +Ni-5 +El-W 1,4,1111111111'' Direction (ft) (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-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 5,648.49 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 5,648.49 10,363.30 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 10,380.00 11,107.20 3K-105(3K-105PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/10/2013 11,194.00 12,624.62 3K-105(3K-105) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/16/2013 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) (°/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 10:44:12AM 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-105 Survey Calculation Method: Minimum Curvature Design: 3K-105 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) (°) (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-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-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 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-CAZSC(2) 2,19478 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-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 10:44:12AM 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 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-105 Survey Calculation Method: Minimum Curvature Design: 3K-105 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi ND TVDSS +N1-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (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-CAZSC(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 M1ND+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-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-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 MVVD+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 1,866.92 MWD+IFR-AK-CAZ-SC(3) 2/19/2013 10:44:12AM 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-105 Survey Calculation Method: Minimum Curvature Design: 3K-105 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) (°/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) 5,074.62 76.62 95.63 3,420.44 3,359.79 -153.75 2,113.44 6,007,783.77 531,419.22 1.11 2,113.44 MWD+IFR-AK-CAZSC(3) 5,122.76 76.35 96.25 3,431.69 3,371.04 -158.59 2,160.00 6,007,779.11 531,465.79 1.37 2,160.00 MWD+IFR-AK-CAZSC(3) 5,167.05 76.89 96.40 3,441.94 3,381.29 -163.34 2,202.82 6,007,774.53 531,508.63 1.26 2,202.82 MWD+IFR-AK-CAZ-SC(3) 5,214.17 77.82 96.78 3,452.26 3,391.61 -168.62 2,248.49 6,007,769.43 531,554.32 2.12 2,248.49 MWD+IFR-AK-CAZ-SC(3) 5,260.97 79.10 96.53 3,461.62 3,400.97 -173.93 2,294.04 6,007,764.30 531,599.88 2.78 2,294.04 MWD+IFR-AK-CAZ-SC(3) 5,308.89 80.16 95.58 3,470.24 3,409.59 -178.90 2,340.91 6,007,759.51 531,646.76 2.95 2,340.91 MWD+IFR-AK-CAZSC(3) 5,353.59 80.46 95.85 3,477.77 3,417.12 -183.29 2,384.75 6,007,755.30 531,690.62 0.90 2,384.75 MWD+IFR-AK-CAZSC(3) 5,401.02 81.53 95.81 3,485.19 3,424.54 -188.05 2,431.36 6,007,750.72 531,737.24 2.26 2,431.36 MWD+IFR-AK-CAZSC(3) 5,446.31 83.30 94.39 3,491.17 3,430.52 -192.04 2,476.07 6,007,746.91 531,781.96 4.99 2,476.07 MWD+IFR-AK-CAZ-SC(3) 5,493.44 83.70 92.85 3,496.51 3,435.86 -194.99 2,522.80 6,007,744.14 531,828.70 3.36 2,522.80 MWD+IFR-AK-CAZSC(3) 5,538.58 84.33 92.11 3,501.21 3,440.56 -196.94 2,567.65 6,007,742.37 531,873.55 2.15 2,567.65 MWD+IFR-AK-CAZ-SC(3) 5,586.65 84.97 91.96 3,505.69 3,445.04 -198.64 2,615.48 6,007,740.86 531,921.39 1.37 2,615.48 MWD+IFR-AK-CAZ-SC(3) 5,631,32 86.96 92,03 3,508.84 3,448.19 -200.19 2,660.01 6,007,739.48 531,965.92 4.46 2,660.01 MWD+IFR-AK-CAZ-SC(3) 5,648.49 87.38 91.39 3,509.68 3,449.03 -200.70 2,677.16 6,007,739.04 531,983.06 4.45 2,677.16 MWD+IFR-AK-CAZ-SC(3) 5,719.50 86.04 92.71 3,513.76 3,453.11 -203.23 2,748.00 6,007,736.78 532,053.90 2.65 2,748.00 MWD+IFR-AK-CAZ-SC(4) 5,758.62 86.34 93.44 3,516.36 3,455.71 -205.33 2,786.98 6,007,734.84 532,092.89 2.01 2,786.98 MWD+IFR-AK-CAZ-SC(4) 5,857.28 86.65 92.81 3,522.39 3,461.74 -210.70 2,885.31 6,007,729.86 532,191.22 0.71 2,885.31 MWD+IFR-AK-CAZ-SC(4) 5,948.98 89.86 93.56 3,525.18 3,464.53 -215.79 2,976.81 6,007,725.13 532,282.74 3.59 2,976.81 MWD+IFR-AK-CAZ-SC(4) 6,041.40 90.67 90.72 3,524.76 3,464.11 -219.24 3,069.15 6,007,722.04 532,375.09 3.20 3,069.15 MWD+IFR-AK-CAZ-SC(4) 6,133.99 90.54 89.28 3,523.78 3,463.13 -219.24 3,161.74 6,007,722.40 532,467.66 1.56 3,161.74 MWD+IFR-AK-CAZ-SC(4) 6,226.87 91.41 88.75 3,522.20 3,461.55 -217.65 3,254.39 6,007,724.36 532,560.29 1.10 3,254.39 MWD+IFR-AK-CAZ-SC(4) 6,319.76 89.43 86.94 3,521.52 3,460.87 -214.15 3,347.40 6,007,728.23 532,653.28 2.88 3,347.40 MWD+IFR-AK-CAZ-SC(4) 6,412.07 89.37 87.74 3,522.49 3,461.84 -209.86 3,439.60 6,007,732.87 532,745.46 0.87 3,439.60 MWD+IFR-AK-CAZ-SC(4) 6,501.13 89.19 88.50 3,523.60 3,462.95 -206.94 3,528.61 6,007,736.14 532,834.45 0.88 3,528.61 MWD+IFR-AK-CAZSC(4) 6,592.12 88.94 88.69 3,525.09 3,464.44 -204.71 3,619.56 6,007,738.73 532,925.38 0.35 3,619.56 MWD+IFR-AK-CAZSC(4) 6,687.04 89.86 88.29 3,526.08 3,465.43 -202.21 3,714.44 6,007,741.60 533,020.24 1.06 3,714.44 M1ND+IFR-AK-CAZSC(4) 6,781.55 90.23 88.04 3,526.01 3,465.36 -199.18 3,808.90 6,007,745.00 533,114.68 0.47 3,808.90 MWD+IFR-AK-CAZSC(4) 6,872.10 87.70 87.54 3,527.64 3,466.99 -195.69 3,899.36 6,007,748.85 533,205.11 2.85 3,899.36 MWD+IFR-AK-CAZ-SC(4) 6,961.29 87.58 87.27 3,531.32 3,470.67 -191.66 3,988.38 6,007,753.23 533,294.11 0.33 3,988.38 MWD+IFR-AK-CAZ-SC(4) 7,055.88 88.26 88.12 3,534.75 3,474.10 -187.86 4,082.83 6,007,757.40 533,388.54 1.15 4,082.83 MWD+IFR-AK-CAZ-SC(4) 7,149.78 88.57 89.69 3,537.35 3,476.70 -186.06 4,176.68 6,007,759.56 533,482.36 1.70 4,176.68 MWD+IFR-AK-CAZ-SC(4) 7,241.12 88.75 89.01 3,539.48 3,478.83 -185.03 4,267.99 6,007,760.96 533,573.66 0.77 4,267.99 MWD+IFR-AK-CAZ-SC(4) 2/19/2013 10:44:12AM 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(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-105 Survey Calculation Method: Minimum Curvature Design: 3K-105 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) (0/100') (ft) Survey Tool Name 7,332.71 89.93 90.36 3,540.54 3,479.89 -184.52 4,359.57 6,007,761.82 533,665.23 1.96 4,359.57 MWD+IFR-AK-CAZ-SC(4) 7,429.77 90.60 89.18 3,540.09 3,479.44 -184.13 4,456.62 6,007,762.59 533,762.27 1.40 4,456.62 MWD+IFR-AK-CAZ-SC(4) 7,519.86 91.41 89.36 3,538.51 3,477.86 -182.99 4,546.69 6,007,764.09 533,852.32 0.92 4,546.69 MWD+IFR-AK-CAZ-SC(4) 7,617.77 91.84 88.62 3,535.73 3,475.08 -181.26 4,644.54 6,007,766.20 533,950.16 0.87 4,644.54 MWD+IFR-AK-CAZ-SC(4) 7,676.84 91.04 87.99 3,534.25 3,473.60 -179.51 4,703.57 6,007,768.18 534,009.17 1.72 4,703.57 MWD+IFR-AK-CAZ-SC(4) 7,770.49 94.81 89.01 3,529.47 3,468.82 -177.06 4,797.05 6,007,771.00 534,102.63 4.17 4,797.05 MWD+IFR-AK-CAZ-SC(4) 7,859.27 98.29 90.49 3,519.34 3,458.69 -176.68 4,885.23 6,007,771.73 534,190.80 4.26 4,885.23 MWD+IFR-AK-CAZ-SC(4) 7,952.92 100.11 92.06 3,504.37 3,443.72 -178.73 4,977.65 6,007,770.04 534,283.22 2.55 4,977.65 MWD+IFR-AK-CAZ-SC(4) 8,045.31 95.81 91.78 3,491.58 3,430.93 -181.79 5,069.07 6,007,767.34 534,374.65 4.66 5,069.07 MWD+IFR-AK-CAZSC(4) 8,136.28 92.83 92.63 3,484.73 3,424.08 -185.28 5,159.71 6,007,764.20 534,465.28 3.41 5,159.71 MWD+IFR-AK-CAZSC(4) 8,229.31 92.65 93.69 3,480.28 3,419.63 -190.41 5,252.49 6,007,759.45 534,558.07 1.15 5,252.49 MWD+IFR-AK-CAZ-SC(4) 8,325.41 90.61 95.23 3,477.55 3,416.90 -197.88 5,348.25 6,007,752.35 534,653.86 2.66 5,348.25 MWD+IFR-AK-CAZ-SC(4) 8,415.87 87.46 95.17 3,479.07 3,418.42 -206.07 5,438.31 6,007,744.51 534,743.94 3.48 5,438.31 MWD+IFR-AK-CAZ-SC(4) 8,512.84 88.20 96.80 3,482.74 3,422.09 -216.18 5,534.68 6,007,734.79 534,840.34 1.84 5,534.68 MWD+IFR-AK-CAZ-SC(4) 8,604.94 88.94 98.85 3,485.04 3,424.39 -228.71 5,625.89 6,007,722.61 534,931.59 2.37 5,625.89 MWD+IFR-AK-CAZSC(4) 8,696.33 88.94 101.69 3,486.73 3,426.08 -245.00 5,715.79 6,007,706.68 535,021.54 3.11 5,715.79 MWD+IFR-AK-CAZSC(4) 8,785.72 88.75 101.08 3,488.53 3,427.88 -262.64 5,803.40 6,007,689.38 535,109.22 0.71 5,803.40 MWD+IFR-AK-CAZSC(4) 8,876.95 88.69 100.57 3,490.57 3,429.92 -279.77 5,892.99 6,007,672.61 535,198.86 0.56 5,892.99 MWD+IFR-AK-CAZSC(4) 8,973.22 89.00 100.69 3,492.51 3,431.86 -297.53 5,987.59 6,007,655.23 535,293.52 0.35 5,987.59 M1ND+IFR-AK-CAZ-SC(4) 9,065.89 88.44 100.71 3,494.58 3,433.93 -314.73 6,078.62 6,007,638.38 535,384.61 0.60 6,078.62 MWD+IFR-AK-CAZ-SC(4) 9,155.76 86.84 98.32 3,498.28 3,437.63 -329.57 6,167.17 6,007,623.89 535,473.21 3.20 6,167.17 MWD+IFR-AK-CAZ-SC(4) 9,249.21 84.80 96.78 3,505.10 3,444.45 -341.82 6,259.56 6,007,612.01 535,585.63 2.73 6,259.56 M1ND+IFR-AK-CAZ-SC(4) 9,339.96 89.98 99.32 3,509.23 3,448.58 -354.51 6,349.28 6,007,599.67 535,655.39 6.36 6,349.28 MWD+IFR-AK-CAZ-SC(4) 9,396.34 91.28 99.92 3,508.61 3,447.96 -363.93 6,404.86 6,007,590.47 535,711.01 2.54 6,404.86 MWD+IFR-AK-CAZ-SC(4) 9,436.07 90.67 98.78 3,507.93 3,447.28 -370.39 6,444.06 6,007,584.17 535,750.23 3.25 6,444.06 MWD+IFR-AK-CAZ-SC(4) 9,527.07 90.23 97.02 3,507.22 3,446.57 -382.89 6,534.19 6,007,572.02 535,840.39 1.99 6,534.19 MWD+IFR-AK-CAZ-SC(4) 9,619.45 88.01 93.93 3,508.64 3,447.99 -391.71 6,626.12 6,007,563.57 535,932.35 4.12 6,626.12 MWD+IFR-AK-CAZ-SC(4) 9,710.30 88.26 94.40 3,511.59 3,450.94 -398.30 6,716.68 6,007,557.33 536,022.93 0.59 6,716.68 MWD+IFR-AK-CAZ-SC(4) 9,805.07 88.20 95.69 3,514.52 3,453.87 -406.63 6,811.04 6,007,549.37 536,117.31 1.36 6,811.04 MWD+IFR-AK-CAZ-SC(4) 9,900.53 88.32 95.98 3,517.42 3,456.77 -416.33 6,905.96 6,007,540.04 536,212.26 0.33 6,905.96 MWD+IFR-AK-CAZSC(4) 9,992.12 88.38 96.16 3,520.06 3,459.41 -426.01 6,997.00 6,007,530.72 536,303.32 0.21 6,997.00 MWD+IFR-AK-CAZSC(4) 10,083.92 89.06 96.16 3,522.11 3,461.46 -435.86 7,088.24 6,007,521.23 536,394.60 0.74 7,088.24 MWD+IFR-AK-CAZSC(4) 10,177.17 88.44 98.12 3,524.14 3,463.49 -447.45 7,180.74 6,007,510.01 536,487.13 2.20 7,180.74 MWD+IFR-AK-CAZSC(4) 10,271.33 88.51 100.52 3,526.65 3,466.00 -462.69 7,273.62 6,007,495.13 536,580.06 2.55 7,273.62 MWD+IFR-AK-CAZ-SC(4) 10,363.30 88.07 98.68 3,529.39 3,468.74 -478.02 7,364.26 6,007,480.16 536,670.75 2.06 7,364.26 MWD+IFR-AK-CAZ-SC(4) 10,380.00 87.91 98.90 3,529.98 3,469.33 -480.57 7,380.75 6,007,477.68 536,687.25 1.63 7,380.75 MWD+IFR-AK-CAZ-SC(5) 10,455.35 87.21 99.91 3,533.18 3,472.53 -492.87 7,455.02 6,007,465.67 536,761.56 1.63 7,455.02 MWD+IFR-AK-CAZ-SC(5) 10,548.87 88.87 101.61 3,536.38 3,475.73 -510.32 7,546.84 6,007,448.58 536,853.43 2.54 7,546.84 MWD+IFR-AK-CAZ-SC(5) 10,639.41 89.00 101.94 3,538.07 3,477.42 -528.79 7,635.45 6,007,430.46 536,942.12 0.39 7,635.45 MWD+IFR-AK-CAZ-SC(5) 10,733.52 88.26 101.79 3,540.32 3,479.67 -548.14 7,727.53 6,007,411.48 537,034.26 0.80 7,727.53 MWD+IFR-AK-CAZ-SC(5) 2/19/2013 10:44:12AM 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 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-105 Survey Calculation Method: Minimum Curvature Design: 3K-105 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) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°l100) (ft) Survey Tool Name 10,826.90 88.01 99.90 3,543.36 3,482.71 -565.70 7,819.19 6,007,394.28 537,125.97 2.04 7,819.19 MWD+IFR-AK-CAZ-SC(5) 10,917.64 87.76 97.24 3,546.71 3,486.06 -579.21 7,908.84 6,007,381.12 537,215.67 2.94 7,908.84 MWD+IFR-AK-CAZ-SC(5) 11,014.10 87.09 97.35 3,551.04 3,490.39 -591.44 8,004.43 6,007,369.26 537,311.29 0.70 8,004.43 MWD+IFR-AK-CAZ-SC(5) 11,107.20 87.52 97.95 3,555.42 3,494.77 -603.82 8,096.59 6,007,357.25 537,403.50 0.79 8,096.59 MWD+IFR-AK-CAZ-SC(5) 11,194.00 86.86 97.99 3,559.67 3,499.02 -615.84 8,182.45 6,007,345.56 537,489.40 0.76 8,182.45 MWD+IFR-AK-CAZ-SC(6) 11,211.99 86.72 98.38 3,560.68 3,500.03 -618.40 8,200.23 6,007,343.08 537,507.18 2.30 8,200.23 MWD+IFR-AK-CAZ-SC(6) 11,304.88 86.34 101.95 3,566.30 3,505.65 -634.76 8,291.48 6,007,327.08 537,598.49 3.86 8,291.48 MWD+IFR-AK-CAZ-SC(6) 11,397.37 89.68 101.92 3,569.51 3,508.86 -653.87 8,381.90 6,007,308.32 537,688.98 3.61 8,381.90 MWD+IFR-AK-CAZ-SC(6) 11,490.45 90.97 99.58 3,568.99 3,508.34 -671.23 8,473.34 6,007,291.32 537,780.47 2.87 8,473.34 MWD+IFR-AK-CAZ-SC(6) 11,583.15 91.28 97.19 3,567.17 3,506.52 -684.75 8,565.02 6,007,278,17 537,872.20 2.60 8,565.02 MWD+IFR-AK-CAZ-SC(6) 11,677.00 91.47 96.81 3,564.91 3,504.26 -696.18 8,658.15 6,007,267.10 537,965.36 0.45 8,658.15 MWD+IFR-AK-CAZ-SC(6) 11,770.27 86.90 96.59 3,566.24 3,505.59 -707.06 8,750.75 6,007,256.59 538,057.99 4.91 8,750.75 MWD+IFR-AK-CAZ-SC(6) 11,861.11 85.79 96.20 3,572.03 3,511.38 -717.16 8,840.84 6,007,246.85 538,148.11 1.29 8,840.84 MWD+IFR-AK-CAZ-SC(6) 11,954.71 85.66 96.92 3,579.01 3,518.36 -727.82 8,933.56 6,007,236.55 538,240.87 0.78 8,933.56 MWD+IFR-AK-CAZ-SC(6) 12,046.44 88.26 98.38 3,583.87 3,523.22 -740.02 9,024.34 6,007,224.71 538,331.68 3.25 9,024.34 MWD+IFR-AK-CAZ-SC(6) 12,138.67 89.00 97.84 3,586.08 3,525.43 -753.02 9,115.62 6,007,212.07 538,423.01 0.99 9,115.62 MWD+IFR-AK-CAZ-SC(6) 12,232.56 88.57 96.48 3,588.07 3,527.42 -764.72 9,208.75 6,007,200.73 538,516.18 1.52 9,208.75 MWD+IFR-AK-CAZ-SC(6) 12,325.05 89.49 95.75 3,589.63 3,528.98 -774.57 9,300.70 6,007,191.24 538,608.15 1.27 9,300.70 MWD+IFR-AK-CAZ-SC(6) 12,417.97 91.34 97.23 3,588.96 3,528.31 -785.08 9,393.02 6,007,181.11 538,700.50 2.55 9,393.02 MWD+IFR-AK-CAZ-SC(6) 12,509.43 87.09 99.00 3,590.21 3,529.56 -797.98 9,483.53 6,007,168.56 538,791.05 5.03 9,483.53 MWD+IFR-AK-CAZ-SC(6) 12,602.38 87.95 100.60 3,594.24 3,533.59 -813.79 9,575.03 6,007,153.11 538,882.61 1.95 9,575.03 MWD+IFR-AK-CAZ-SC(6) 12,624.62 87.02 101.97 3,595.21 3,534.56 -818.13 9,596,82 6,007,148.85 538,904.41 7.44 9,596.82 MWD+IFR-AK-CAZ-SC(6) 12,700.00 87.02 101.97 3,599.13 3,538.48 -833.75 9,670.46 6,007,133.53 538,978.11 0.00 9,670.46 PROJECTED to TD 2/19/2013 10:44:12AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc NAD27 Kuparuk River Unit Kuparuk 3K Pad 3K-105PB1 API 500292347970 - PTD 212-165 riSperry Drilling 3er~vices Definitive Survey Report 19 February, 2013 I 11 I'r >iE HALLIRUR' Sperry Drilling Services �4t 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-105PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105PB1 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 +NI-S 0.00 ft Northing: 6,007,929.20 ft Latitude: 70°25'57.87 N +EI-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-105PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2011 1/20/2013 20.17 81.03 57,633 Design 3K-105PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.35 Vertical Section: Depth From(ND) +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 11,064.10 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 2,333.08 5,648.49 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 5,648.49 11,064.10 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (0I100') (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) 2119/2013 10:51:37AM 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-105PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (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-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-CAZSC(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-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-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 -65.57 6,008,421.19 529,237.90 3.47 -65.57 MVVD+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-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-CAZSC(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-CAZSC(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) 2,665.68 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) 2/19/2013 10:51:37AM 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-105PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105PB1 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) (°/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 35.81 113.38 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-CAZSC(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) 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 10:51:37AM 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-105PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105PB1 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) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (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) 5,074.62 76.62 95.63 3,420.44 3,359.79 -153.75 2,113.44 6,007,783.77 531,419.22 1.11 2113.44 MWD+IFR-AK-CAZ-SC(3) 5,122.76 76.35 96.25 3,431.69 3,371.04 -158.59 2,160.00 6,007,779.11 531,465.79 1.37 2,160.00 MWD+IFR-AK-CAZ-SC(3) 5,167.05 76.89 96.40 3,441.94 3,381.29 -163.34 2,202.82 6,007,774.53 531,508.63 1.26 2,202.82 MWD+IFR-AK-CAZ-SC(3) 5,214.17 77.82 96.78 3,452.26 3,391.61 -168.62 2,248.49 6,007,769.43 531,554.32 2.12 2,248.49 MWD+IFR-AK-CAZ-SC(3) 5,260.97 79.10 96.53 3,461.62 3,400.97 -173.93 2,294.04 6,007,764.30 531,599.88 2.78 2,294.04 MWD+IFR-AK-CAZ-SC(3) 5,308.89 80.16 95.58 3,470.24 3,409.59 -178.90 2,340.91 6,007,759.51 531,646.76 2.95 2,340.91 MWD+IFR-AK-CAZ-SC(3) 5,353.59 80.46 95.85 3,477.77 3,417.12 -183.29 2,384.75 6,007,755.30 531,690.62 0.90 2,384.75 MWD+IFR-AK-CAZSC(3) 5,401.02 81.53 95.81 3,485.19 3,424.54 -188.05 2,431.36 6,007,750.72 531,737.24 2.26 2,431.36 MWD+IFR-AK-CAZSC(3) 5,446.31 83.30 94.39 3,491.17 3,430.52 -192.04 2,476.07 6,007,746.91 531,781.96 4.99 2,476.07 MWD+IFR-AK-CAZSC(3) 5,493.44 83.70 92.85 3,496.51 3,435.86 -194.99 2,522.80 6,007,744.14 531,828.70 3.36 2,522.80 MWD+IFR-AK-CAZSC(3) 5,538.58 84.33 92.11 3,501.21 3,440.56 -196.94 2,567.65 6,007,742.37 531,873.55 2.15 2,567.65 MWD+IFR-AK-CAZSC(3) 5,586.65 84.97 91.96 3,505.69 3,445.04 -198.64 2,615.48 6,007,740.86 531,921.39 1.37 2,615.48 MWD+IFR-AK-CAZ-SC(3) 5,631.32 86.96 92.03 3,508.84 3,448.19 -200.19 2,660.01 6,007,739.48 531,965.92 4.46 2,660.01 MWD+IFR-AK-CAZ-SC(3) 5,648.49 87.38 91.39 3,509.68 3,449.03 -200.70 2,677.16 6,007,739.04 531,983.06 4.45 2,677.16 MWD+IFR-AK-CAZ-SC(3) 5,719.50 86.04 92.71 3,513.76 3,453.11 -203.23 2,748.00 6,007,736.78 532,053.90 2.65 2,748.00 MWD+IFR-AK-CAZ-SC(4) 5,758.62 86.34 93.44 3,516.36 3,455.71 -205.33 2,786.98 6,007,734.84 532,092.89 2.01 2,786.98 MWD+IFR-AK-CAZ-SC(4) 5,857.28 86.65 92.81 3,522.39 3,461.74 -210.70 2,885.31 6,007,729.86 532,191.22 0.71 2,885.31 MWD+IFR-AK-CAZ-SC(4) 5,948.98 89.86 93.56 3,525.18 3,464.53 -215.79 2,976.81 6,007,725.13 532,282.74 3.59 2,976.81 MWD+IFR-AK-CAZ-SC(4) 6,041.40 90.67 90.72 3,524.76 3,464.11 -219.24 3,069.15 6,007,722.04 532,375.09 3.20 3,069.15 MWD+IFR-AK-CAZ-SC(4) 6,133.99 90.54 89.28 3,523.78 3,463.13 -219.24 3,161.74 6,007,722.40 532,467.66 1.56 3,161.74 MWD+IFR-AK-CAZ-SC(4) 6,226.67 91.41 88.75 3,522.20 3,461.55 -217.65 3,254.39 6,007,724.36 532,560.29 1.10 3,254.39 MWD+IFR-AK-CAZ-SC(4) 6,319.76 89.43 86.94 3,521.52 3,460.87 -214.15 3,347.40 6,007,728.23 532,653.28 2.88 3,347.40 MWD+IFR-AK-CAZ-SC(4) 6,412.07 89.37 87.74 3,522.49 3,461.84 -209.86 3,439.60 6,007,732.87 532,745.46 0.87 3,439.60 MWD+IFR-AK-CAZ-SC(4) 6,501.13 89.19 88.50 3,523.60 3,462.95 -206.94 3,528.61 6,007,736.14 532,834.45 0.88 3,528.61 MWD+IFR-AK-CAZ-SC(4) 6,592.12 88.94 88.69 3,525.09 3,464.44 -204.71 3,619.56 6,007,738.73 532,925.38 0.35 3,619.56 MWD+IFR-AK-CAZ-SC(4) 6,687.04 89.86 88.29 3,526.08 3,465.43 -202.21 3,714.44 6,007,741.60 533,020.24 1.06 3,714.44 MWD+IFR-AK-CAZSC(4) 6,781.55 90.23 88.04 3,526.01 3,465.36 -199.18 3,808.90 6,007,745.00 533,114.68 0.47 3,808.90 MWD+IFR-AK-CAZSC(4) 6,872.10 87.70 87.54 3,527.64 3,466.99 -195.69 3,899.36 6,007,748.85 533,205.11 2.85 3,899.36 MWD+IFR-AK-CAZSC(4) 6,961.29 87.58 87.27 3,531.32 3,470.67 -191.66 3,988.38 6,007,753.23 533,294.11 0.33 3,988.38 MWD+IFR-AK-CAZSC(4) 7,055.88 88.26 88.12 3,534.75 3,474.10 -187.86 4,082.83 6,007,757.40 533,388.54 1.15 4,082.83 MWD+IFR-AK-CAZ-SC(4) 7,149.78 88.57 89.69 3,537.35 3,476.70 -186.06 4,176.68 6,007,759.56 533,482.36 1.70 4,176.68 MWD+IFR-AK-CAZ-SC(4) 7,241.12 88.75 89.01 3,539.48 3,478.83 -185.03 4,267.99 6,007,760.96 533,573.66 0.77 4,267.99 MWD+IFR-AK-CAZ-SC(4) 7,332.71 89.93 90.36 3,540.54 3,479.89 -184.52 4,359.57 6,007,761.82 533,665.23 1.96 4,359.57 MWD+IFR-AK-CAZ-SC(4) 2/19/2013 10:51:37AM 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 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-105PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,429.77 90.60 89.18 3,540.09 3,479.44 -184.13 4,456.62 6,007,762.59 533,762.27 1.40 4,456.62 MWD+IFR-AK-CAZ-SC(4) 7,519.86 91.41 89.36 3,538.51 3,477.86 -182.99 4,546.69 6,007,764.09 533,852.32 0.92 4,546.69 MWD+IFR-AK-CAZ-SC(4) 7,617.77 91.84 88.62 3,535.73 3,475.08 -181.26 4,644.54 6,007,766.20 533,950.16 0.87 4,644.54 MWD+IFR-AK-CAZSC(4) 7,676.84 91.04 87.99 3,534.25 3,473.60 -179.51 4,703.57 6,007,768.18 534,009.17 1.72 4,703.57 MWD+IFR-AK-CAZ-SC(4) 7,770.49 94.81 89.01 3,529.47 3,468.82 -177.06 4,797.05 6,007,771.00 534,102.63 4.17 4,797.05 MWD+IFR-AK-CAZ-SC(4) 7,859.27 98.29 90.49 3,519.34 3,458.69 -176.68 4,885.23 6,007,771.73 534,190.80 4.26 4,885.23 MWD+IFR-AK-CAZ-SC(4) 7,952.92 100.11 92.06 3,504.37 3,443.72 -178.73 4,977.65 6,007,770.04 534,283.22 2.55 4,977.65 MWD+IFR-AK-CAZ-SC(4) 8,045.31 95.81 91.78 3,491.58 3,430.93 -181.79 5,069.07 6,007,767.34 534,374.65 4.66 5,069.07 MWD+IFR-AK-CAZ-SC(4) 8,136.28 92.83 92.63 3,484.73 3,424.08 -185.28 5,159.71 6,007,764.20 534,465.28 3.41 5,159.71 MWD+IFR-AK-CAZ-SC(4) 8,229.31 92.65 93.69 3,480.28 3,419.63 -190.41 5,252.49 6,007,759.45 534,558.07 1.15 5,252.49 MWD+IFR-AK-CAZ-SC(4) 8,325.41 90.61 95.23 3,477.55 3,416.90 -197.88 5,348.25 6,007,752.35 534,653.86 2.66 5,348.25 MWD+IFR-AK-CAZ-SC(4) 8,415.87 87.46 95.17 3,479.07 3,418.42 -206.07 5,438.31 6,007,744.51 534,743.94 3.48 5,438.31 MWD+IFR-AK-CAZ-SC(4) 8,512.84 88.20 96.80 3,482.74 3,422.09 -216.18 5,534.68 6,007,734.79 534,840.34 1.84 5,534.68 MWD+IFR-AK-CAZ-SC(4) 8,604.94 88.94 98.85 3,485.04 3,424.39 -228.71 5,625.89 6,007,722.61 534,931.59 2.37 5,625.89 MWD+IFR-AK-CAZ-SC(4) 8,696.33 88.94 101.69 3,486.73 3,426.08 -245.00 5,715.79 6,007,706.68 535,021.54 3.11 5,715.79 MWD+IFR-AK-CAZ-SC(4) 8,785.72 88.75 101.08 3,488.53 3,427.88 -262.64 5,803.40 6,007,689.38 535,109.22 0.71 5,803.40 MWD+IFR-AK-CAZ-SC(4) 8,876.95 88.69 100.57 3,490.57 3,429.92 -279.77 5,892.99 6,007,672.61 535,198.86 0.56 5,892.99 M1ND+IFR-AK-CAZ-SC(4) 8,973.22 89.00 100.69 3,492.51 3,431.86 -297.53 5,987.59 6,007,655.23 535,293.52 0.35 5,987.59 MWD+IFR-AK-CAZ-SC(4) 9,065.89 88.44 100.71 3,494.58 3,433.93 -314.73 6,078.62 6,007,638.38 535,384.61 0.60 6,078.62 MWD+IFR-AK-CAZ-SC(4) 9,155.76 86.84 98.32 3,498.28 3,437.63 -329.57 6,167.17 6,007,623.89 535,473.21 3.20 6,167.17 MWD+IFR-AK-CAZ-SC(4) 9,249.21 84.80 96.78 3,505.10 3,444.45 -341.82 6,259.56 6,007,612.01 535,565.63 2.73 6,259.56 MWD+IFR-AK-CAZ-SC(4) 9,339.96 89.98 99.32 3,509.23 3,448.58 -354.51 6,349.28 6,007,599.67 535,655.39 6.36 6,349.28 MWD+IFR-AK-CAZ-SC(4) 9,396.34 91.28 99.92 3,508.61 3,447.96 -363.93 6,404.86 6,007,590.47 535,711.01 2.54 6,404.86 MWD+IFR-AK-CAZSC(4) 9,436.07 90.67 98.78 3,507.93 3,447.28 -370.39 6,444.06 6,007,584.17 535,750.23 3.25 6,444.06 MWD+IFR-AK-CAZSC(4) 9,527.07 90.23 97.02 3,507.22 3,446.57 -382.89 6,534.19 6,007,572.02 535,840.39 1.99 6,534.19 MWD+IFR-AK-CAZSC(4) 9,619.45 88.01 93.93 3,508.64 3,447.99 -391.71 6,626.12 6,007,563.57 535,932.35 4.12 6,626.12 MWD+IFR-AK-CAZ-SC(4) 9,710.30 88.26 94.40 3,511.59 3,450.94 -398.30 6,716.68 6,007,557.33 536,022.93 0.59 6,716.68 MWD+IFR-AK-CAZ-SC(4) 9,805.07 88.20 95.69 3,514.52 3,453.87 -406.63 6,811.04 6,007,549.37 536,117.31 1.36 6,811.04 MWD+IFR-AK-CAZ-SC(4) 9,900.53 88.32 95.98 3,517.42 3,456.77 -416.33 6,905.96 6,007,540.04 536,212.26 0.33 6,905.96 MWD+IFR-AK-CAZ-SC(4) 9,992.12 88.38 96.16 3,520.06 3,459.41 -426.01 6,997.00 6,007,530.72 536,303.32 0.21 6,997.00 MWD+IFR-AK-CAZ-SC(4) 10,083.92 89.06 96.16 3,522.11 3,461.46 -435.86 7,088.24 6,007,521.23 536,394.60 0.74 7,088.24 MWD+IFR-AK-CAZ-SC(4) 10,177.17 88.44 98.12 3,524.14 3,463.49 -447.45 7,180.74 6,007,510.01 536,487.13 2.20 7,180.74 MWD+IFR-AK-CAZ-SC(4) 10,271.33 88.51 100.52 3,526.65 3,466.00 -462.69 7,273.62 6,007,495.13 536,580.06 2.55 7,273.62 MWD+IFR-AK-CAZ-SC(4) 10,363.30 88.07 98.68 3,529.39 3,468.74 -478.02 7,364.26 6,007,480.16 536,670.75 2.06 7,364.26 MWD+IFR-AK-CAZ-SC(4) 10,454.29 89.80 98.38 3,531.08 3,470.43 -491.51 7,454.22 6,007,467.02 536,760.76 1.93 7,454.22 MWD+IFR-AK-CAZ-SC(4) 10,550.58 90.97 99.02 3,530.44 3,469.79 -506.08 7,549.40 6,007,452.83 536,855.98 1.38 7,549.40 MWD+IFR-AK-CAZ-SC(4) 10,642.98 91.28 98.45 3,528.62 3,467.97 -520.11 7,640.71 6,007,439.16 536,947.34 0.70 7,640.71 MWD+IFR-AK-CAZ-SC(4) 10,736.18 90.73 97.89 3,526.99 3,466.34 -533.35 7,732.95 6,007,426.29 537,039.62 0.84 7,732.95 MWD+IFR-AK-CAZ-SC(4) 10,827.67 88.38 97.95 3,527.70 3,467.05 -545.95 7,823.56 6,007,414.04 537,130.27 2.57 7,823.56 MWD+IFR-AK-CAZ-SC(4) 10,921.78 86.16 97.38 3,532.18 3,471.53 -558.49 7,916.71 6,007,401.87 537,223.46 2.44 7,916.71 MWD+IFR-AK-CAZ-SC(4) 2/19/2013 10:51:37AM 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-105PB1 Survey Calculation Method: Minimum Curvature Design: 3K-105PB1 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi WD TVDSS +NI-S +E/-W Northing Fasting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 11,013.89 83.49 97.40 3,540.49 3,479.84 -570.29 8,007.68 6,007,390.43 537,314.46 2.90 8,007.68 MWD+IFR-AK-CAZ-SC(4) 11,064.10 82.00 96.73 3,546.83 3,486.18 -576.42 8,057.11 6,007,384.50 537,363.91 3.25 8,057.11 MWD+IFR-AK-CAZ-SC(4) 11,139.00 82.00 96.73 3,557.25 3,496.60 -585.11 8,130.77 6,007,376.09 537,437.60 0.00 8,130.77 PROJECTED to TD 2/19/2013 10:51:37AM Page 7 COMPASS 2003.16 Build 69 ti "I C t 'all.. =.1 '.E t ! F ',4 [ ill IIt I ConocoPhillips (Alaska) Inc NAD27 Kuparuk River Unit 14 Kuparuk 3K Pad 3K-105PB2 r'i ; API: 500292347971 - PTD:212-165 E Sperry rfflnq . ervee Definitive Survey Report 19 February, 2013 0 II 311 d d€ 1 H2 „2„. tar .k m h, ° I € h�I f1 IF 701 2 le At i'.' 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-105PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105PB2 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 iu,wi,8N SII'tINIM,IIIA NN,V,11114,2411, e.. Well Position +N/-S 0.00 ft Northing: 6,007,929.20 ft Latitude: 70°25'57.87 N +EI-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-105PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (') (nT) BGGM2011 1/20/2013 20.17 81.03 57,633 Design 3K-105PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,363.30 Vertical Section: Depth From(ND) +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 5,648.49 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 5,648.49 10,363.30 3K-105(3K-105PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2012 10,380.00 11,199.15 3K-105(3K-105PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 01/10/2013 Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/10(Y) (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 10:52:28AM 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-105PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105PB2 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Nor-thing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/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-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 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-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-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-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-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 MVVD+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-CAZSC(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-CAZSC(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 10:52:28AM 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-105PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105PB2 Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Nor-thing Fasting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (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 37.89 113.84 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-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 10:52:28AM 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-105PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105PB2 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) (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) 5,074.62 76.62 95.63 3,420.44 3,359.79 -153.75 2,113.44 6,007,783.77 531,419.22 1.11 2,113.44 MWD+IFR-AK-CAZ-SC(3) 5,122.76 76.35 96.25 3,431.69 3,371.04 -158.59 2,160.00 6,007,779.11 531,465.79 1.37 2,160.00 MWD+IFR-AK-CAZ-SC(3) 5,167.05 76.89 96.40 3,441.94 3,381.29 -163.34 2,202.82 6,007,774.53 531,508.63 1.26 2,202.82 MWD+IFR-AK-CAZ-SC(3) 5,214.17 77.82 96.78 3,452.26 3,391.61 -168.62 2,248.49 6,007,769.43 531,554.32 2.12 2,248.49 MWD+IFR-AK-CAZSC(3) 5,260.97 79.10 96.53 3,461.62 3,400.97 -173.93 2,294.04 6,007,764.30 531,599.88 2.78 2,294.04 MWD+IFR-AK-CAZ-SC(3) 5,308.89 80.16 95.58 3,470.24 3,409.59 -178.90 2,340.91 6,007,759.51 531,646.76 2.95 2,340.91 MWD+IFR-AK-CAZ-SC(3) 5,353.59 80.46 95.85 3,477.77 3,417.12 -183.29 2,384.75 6,007,755.30 531,690.62 0.90 2,384.75 MWD+IFR-AK-CAZ-SC(3) 5,401.02 81.53 95.81 3,485.19 3,424.54 -188.05 2,431.36 6,007,750.72 531,737.24 2.26 2,431.36 MWD+IFR-AK-CAZ-SC(3) 5,446.31 83.30 94.39 3,491.17 3,430.52 -192.04 2,476.07 6,007,746.91 531,781.96 4.99 2,476.07 MWD+IFR-AK-CAZ-SC(3) 5,493.44 83.70 92.85 3,496.51 3,435.86 -194.99 2,522.80 6,007,744.14 531,828.70 3.36 2,522.80 MWD+IFR-AK-CAZ-SC(3) 5,538.58 84.33 92.11 3,501.21 3,440.56 -196.94 2,567.65 6,007,742.37 531,873.55 2.15 2,567.65 MWD+IFR-AK-CAZ-SC(3) 5,586.65 84.97 91.96 3,505.69 3,445.04 -198.64 2,615.48 6,007,740.86 531,921.39 1.37 2,615.48 MWD+IFR-AK-CAZ-SC(3) 5,631.32 86.96 92.03 3,508.84 3,448.19 -200.19 2,660.01 6,007,739.48 531,965.92 4.46 2,660.01 MWD+IFR-AK-CAZ-SC(3) 5,648.49 87.38 91.39 3,509.68 3,449.03 -200.70 2,677.16 6,007,739.04 531,983.06 4.45 2,677.16 MWD+IFR-AK-CAZ-SC(3) 5,719.50 86.04 92.71 3,513.76 3,453.11 -203.23 2,748.00 6,007,736.78 532,053.90 2.65 2,748.00 MWD+IFR-AK-CAZ-SC(4) 5,758.62 86.34 93.44 3,516.36 3,455.71 -205.33 2,786.98 6,007,734.84 532,092.89 2.01 2,786.98 MWD+IFR-AK-CAZ-SC(4) 5,857.28 86.65 92.81 3,522.39 3,461.74 -210.70 2,885.31 6,007,729.86 532,191.22 0.71 2,885.31 MWD+IFR-AK-CAZ-SC(4) 5,948.98 89.86 93.56 3,525.18 3,464.53 -215.79 2,976.81 6,007,725.13 532,282.74 3.59 2,976.81 MWD+IFR-AK-CAZ-SC(4) 6,041.40 90.67 90.72 3,524.76 3,464.11 -219.24 3,069.15 6,007,722.04 532,375.09 3.20 3,069.15 MWD+IFR-AK-CAZ-SC(4) 6,133.99 90.54 89.28 3,523.78 3,463.13 -219.24 3,161.74 6,007,722.40 532,467.66 1.56 3,161.74 MWD+IFR-AK-CAZ-SC(4) 6,226.67 91.41 88.75 3,522.20 3,461.55 -217.65 3,254.39 6,007,724.36 532,560.29 1.10 3,254.39 M1ND+IFR-AK-CAZSC(4) 6,319.76 89.43 86.94 3,521.52 3,460.87 -214.15 3,347.40 6,007,728.23 532,653.28 2.88 3,347.40 MWD+IFR-AK-CAZSC(4) 6,412.07 89.37 87.74 3,522.49 3,461.84 -209.86 3,439.60 6,007,732.87 532,745.46 0.87 3,439.60 MWD+IFR-AK-CAZ-SC(4) 6,501.13 89.19 88.50 3,523.60 3,462.95 -206.94 3,528.61 6,007,736.14 532,834.45 0.88 3,528.61 MWD+IFR-AK-CAZ-SC(4) 6,592.12 88.94 88.69 3,525.09 3,464.44 -204.71 3,619.56 6,007,738.73 532,925.38 0.35 3,619.56 MWD+IFR-AK-CAZ-SC(4) 6,687.04 89.86 88.29 3,526.08 3,465.43 -202.21 3,714.44 6,007,741.60 533,020.24 1.06 3,714.44 MWD+IFR-AK-CAZ-SC(4) 6,781.55 90.23 88.04 3,526.01 3,465.36 -199.18 3,808.90 6,007,745.00 533,114.68 0.47 3,808.90 MWD+IFR-AK-CAZ-SC(4) 6,872.10 87.70 87.54 3,527.64 3,466.99 -195.69 3,899.36 6,007,748.85 533,205.11 2.85 3,899.36 MWD+IFR-AK-CAZ-SC(4) 6,961.29 87.58 87.27 3,531.32 3,470.67 -191.66 3,988.38 6,007,753.23 533,294.11 0.33 3,988.38 MWD+IFR-AK-CAZ-SC(4) 7,055.88 88.26 88.12 3,534.75 3,474.10 -187.86 4,082.83 6,007,757.40 533,388.54 1.15 4,082.83 MWD+IFR-AK-CAZSC(4) 7,149.78 88.57 89.69 3,537.35 3,476.70 -186.06 4,176.68 6,007,759.56 533,482.36 1.70 4,176.68 MWD+IFR-AK-CAZSC(4) 7,241.12 88.75 89.01 3,539.48 3,478.83 -185.03 4,267.99 6,007,760.96 533,573.66 0.77 4,267.99 MWD+IFR-AK-CAZ-SC(4) 2/19/2013 10:52:28AM 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(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-105PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105PB2 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) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,332.71 89.93 90.36 3,540.54 3,479.89 -184.52 4,359.57 6,007,761.82 533,665.23 1.96 4,359.57 MWD+IFR-AK-CAZ-SC(4) 7,429.77 90.60 89.18 3,540.09 3,479.44 -184.13 4,456.62 6,007,762.59 533,762.27 1.40 4,456.62 MWD+IFR-AK-CAZ-SC(4) 7,519.86 91.41 89.36 3,538.51 3,477.86 -182.99 4,546.69 6,007,764.09 533,852.32 0.92 4,546.69 MWD+IFR-AK-CAZ-SC(4) 7,617.77 91.84 88.62 3,535.73 3,475.08 -181.26 4,644.54 6,007,766.20 533,950.16 0.87 4,644.54 MWD+IFR-AK-CAZ-SC(4) 7,676.84 91.04 87.99 3,534.25 3,473.60 -179.51 4,703.57 6,007,768.18 534,009.17 1.72 4,703.57 MWD+IFR-AK-CAZ-SC(4) 7,770.49 94.81 89.01 3,529.47 3,468.82 -177.06 4,797.05 6,007,771.00 534,102.63 4.17 4,797.05 MWD+IFR-AK-CAZ-SC(4) 7,859.27 98.29 90.49 3,519.34 3,458.69 -176.68 4,885.23 6,007,771.73 534,190.80 4.26 4,885.23 MWD+IFR-AK-CAZ-SC(4) 7,952.92 100.11 92.06 3,504.37 3,443.72 -178.73 4,977.65 6,007,770.04 534,283.22 2.55 4,977.65 MWD+IFR-AK-CAZSC(4) 8,045.31 95.81 91.78 3,491.58 3,430.93 -181.79 5,069.07 6,007,767.34 534,374.65 4.66 5,069.07 MWD+IFR-AK-CAZ-SC(4) 8,136.28 92.83 92.63 3,484.73 3,424.08 -185.28 5,159.71 6,007,764.20 534,465.28 3.41 5,159.71 MWD+IFR-AK-CAZ-SC(4) 8,229.31 92.65 93.69 3,480.28 3,419.63 -190.41 5,252.49 6,007,759.45 534,558.07 1.15 5,252.49 MWD+IFR-AK-CAZ-SC(4) 8,325.41 90.61 95.23 3,477.55 3,416.90 -197.88 5,348.25 6,007,752.35 534,653.86 2.66 5,348.25 MWD+IFR-AK-CAZ-SC(4) 8,415.87 87.46 95.17 3,479.07 3,418.42 -206.07 5,438.31 6,007,744.51 534,743.94 3.48 5,438.31 MWD+IFR-AK-CAZ-SC(4) 8,512.84 88.20 96.80 3,482.74 3,422.09 -216.18 5,534.68 6,007,734.79 534,840.34 1.84 5,534.68 MWD+IFR-AK-CAZ-SC(4) 8,604.94 88.94 98.85 3,485.04 3,424.39 -228.71 5,625.89 6,007,722.61 534,931.59 2.37 5,625.89 MWD+IFR-AK-CAZ-SC(4) 8,696.33 88.94 101.69 3,486.73 3,426.08 -245.00 5,715.79 6,007,706.68 535,021.54 3.11 5,715.79 MWD+IFR-AK-CAZ-SC(4) 8,785.72 88.75 101.08 3,488.53 3,427.88 -262.64 5,803.40 6,007,689.38 535,109.22 0.71 5,803.40 MWD+IFR-AK-CAZ-SC(4) 8,876.95 88.69 100.57 3,490.57 3,429.92 -279.77 5,892.99 6,007,672.61 535,198.86 0.56 5,892.99 MWD+IFR-AK-CAZ-SC(4) 8,973.22 89.00 100.69 3,492.51 3,431.86 -297.53 5,987.59 6,007,655.23 535,293.52 0.35 5,987.59 MWD+IFR-AK-CAZ-SC(4) 9,065.89 88.44 100.71 3,494.58 3,433.93 -314.73 6,078.62 6,007,638.38 535,384.61 0.60 6,078.62 MWD+IFR-AK-CAZ-SC(4) 9,155.76 86.84 98.32 3,498.28 3,437.63 -329.57 6,167.17 6,007,623.89 535,473.21 3.20 6,167.17 MWD+IFR-AK-CAZ-SC(4) 9,249.21 84.80 96.78 3,505.10 3,444.45 -341.82 6,259.56 6,007,612.01 535,565.63 2.73 6,259.56 MWD+IFR-AK-CAZ-SC(4) 9,339.96 89.98 99.32 3,509.23 3,448.58 -354.51 6,349.28 6,007,599.67 535,655.39 6.36 6,349.28 MWD+IFR-AK-CAZ-SC(4) 9,396.34 91.28 99.92 3,508.61 3,447.96 -363.93 6,404.86 6,007,590.47 535,711.01 2.54 6,404.86 MWD+IFR-AK-CAZ-SC(4) 9,436.07 90.67 98.78 3,507.93 3,447.28 -370.39 6,444.06 6,007,584.17 535,750.23 3.25 6,444.06 MWD+IFR-AK-CAZ-SC(4) 9,527.07 90.23 97.02 3,507.22 3,446.57 -382.89 6,534.19 6,007,572.02 535,840.39 1.99 6,534.19 MWD+IFR-AK-CAZ-SC(4) 9,619.45 88.01 93.93 3,508.64 3,447.99 -391.71 6,626.12 6,007,563.57 535,932.35 4.12 6,626.12 MWD+IFR-AK-CAZ-SC(4) 9,710.30 88.26 94.40 3,511.59 3,450.94 -398.30 6,716.68 6,007,557.33 536,022.93 0.59 6,716.68 MWD+IFR-AK-CAZ-SC(4) 9,805.07 88.20 95.69 3,514.52 3,453.87 -406.63 6,811.04 6,007,549.37 536,117.31 1.36 6,811.04 MWD+IFR-AK-CAZ-SC(4) 9,900.53 88.32 95.98 3,517.42 3,456.77 -416.33 6,905.96 6,007,540.04 536,212.26 0.33 6,905.96 MWD+IFR-AK-CAZ-SC(4)• 9,992.12 88.38 96.16 3,520.06 3,459.41 -426.01 6,997.00 6,007,530.72 536,303.32 0.21 6,997.00 MWD+IFR-AK-CAZ-SC(4) 10,083.92 89.06 96.16 3,522.11 3,461.46 -435.86 7,088.24 6,007,521.23 536,394.60 0.74 7,088.24 MWD+IFR-AK-CAZ-SC(4) 10,177.17 88.44 98.12 3,524.14 3,463.49 -447.45 7,180.74 6,007,510.01 536,487.13 2.20 7,180.74 MWD+IFR-AK-CAZSC(4) 10,271.33 88.51 100.52 3,526.65 3,466.00 -462.69 7,273.62 6,007,495.13 536,580.06 2.55 7,273.62 MWD+IFR-AK-CAZSC(4) 10,363.30 88.07 98.68 3,529.39 3,468.74 -478.02 7,364.26 6,007,480.16 536,670.75 2.06 7,364.26 MWD+IFR-AK-CAZSC(4) 10,380.00 87.91 98.90 3,529.98 3,469.33 -480.57 7,380.75 6,007,477.68 536,687.25 1.63 7,380.75 MWD+IFR-AK-CAZ-SC(5) 10,455.35 87.21 99.91 3,533.18 3,472.53 -492.87 7,455.02 6,007,465.67 536,761.56 1.63 7,455.02 MWD+IFR-AK-CAZSC(5) 10,548.87 88.87 101.61 3,536.38 3,475.73 -510.32 7,546.84 6,007,448.58 536,853.43 2.54 7,546.84 MWD+IFR-AK-CAZSC(5) 10,639.41 89.00 101.94 3,538.07 3,477.42 -528.79 7,635.45 6,007,430.46 536,942.12 0.39 7,635.45 MWD+IFR-AK-CAZSC(5) 10,733.52 88.26 101.79 3,540.32 3,479.67 -548.14 7,727.53 6,007,411.48 537,034.26 0.80 7,727.53 MWD+IFR-AK-CAZ-SC(5) 2/19/2013 10:52:28AM 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-105PB2 Survey Calculation Method: Minimum Curvature Design: 3K-105PB2 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) (°1100') (ft) Survey Tool Name 10,826.90 88.01 99.90 3,543.36 3,482.71 -565.70 7,819.19 6,007,394.28 537,125.97 2.04 7,819.19 MWD+IFR AK CAZ SC(5) 10,917.64 87.76 97.24 3,546.71 3,486.06 -579.21 7,908.84 6,007,381.12 537,215.67 2.94 7,908.84 MWD+IFR-AK-CAZ-SC(5) 11,014.10 87.09 97.35 3,551.04 3,490.39 -591.44 8,004.43 6,007,369.26 537,311.29 0.70 8,004.43 MWD+IFR-AK-CAZ-SC(5) 11,107.20 87.52 97.95 3,555.42 3,494.77 -603.82 8,096.59 6,007,357.25 537,403.50 0.79 8,096.59 MWD+IFR-AK-CAZ-SC(5) 11,199.15 87.33 98.00 3,559.55 3,498.90 -616.57 8,187.56 6,007,344.86 537,494.51 0.21 8,187.56 MWD+IFR-AK-CAZ-SC(5) 11,364.00 87.33 98.00 3,567.23 3,506.58 -639.49 8,350.63 6,007,322.59 537,657.65 0.00 8,350.63 PROJECTED to TD 2/19/2013 10:52:28AM Page 7 COMPASS 2003.16 Build 69 oF Fit \%1 // s THE STATE Alaska Oil and Gas 14 °fALAS� Conservation Commission * GOVERNOR SEAN PARNELL 333 West Seventh Avenue OD Anchorage, Alaska 99501-3572 ALAS 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-105 ConocoPhillips Alaska, Inc. Permit No: 212-165 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 drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, r� Pt9h- Cathy . Foerster Chair DATED this /c--141•--ay 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 ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 2 2012 PERMIT TO DRILL AOGCC 20 AAC 25.005 �i 'l t.4: la.Type of Work: lb Proposed Well Class: Development-Oil EService-Winj III Single Zone ❑I lc.Specify if well is proposed for: Drill 0 Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG 111 Service-Disp E] Geothermal ❑ Shale Gas ❑ •2.Operator Name: 5. Bond: ❑✓ Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 3K-105 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12687' . TVD: 3622' 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: ,-;-6.,,c; 14.Distance to 7•-;31.�vcZv� ? Nearest Property: > i;1�.� 89'FSL,568'FEL,Sec.36,T13N, R9E,UM 489-" , r(_i;•l L ��,�n,1 / 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 62 feet 15.Distance to Nearest,Well Open Surface:x- 529306 . y- 6007929 • Zone- 4 GL Elevation above MSL. - 34 feet to Same pool:�)K.6Jt» ��•i ` 16.Deviated wells: Kickoff depth. 700 ' ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 100' deg Downhole: 1800 psig ,--r-- 7 Surface: 1195 psig • 18.Casing Procram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks - Hole Casing Weight Grade Coupling Length MD ND MD ND (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 DeepCRETE 6.75" 4.5" 11.6# L-80 Hydril 521 7072' 5614' 3554' 12687' 3622' slotted liner - B.(,cam..," 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(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 Q Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21 Verbal Approval. Commission Representative: Date 3 22 I hereby certify that the foregoing is true and correct. Contact Monty Myers @ 265-6318 Email Monty.M.Mvers( conocophillips.com Printed Name G. AlvordTitle Alaska Drilling Manager //// Signature f "`�� 4- __ I`Phone:265-6120 Date `1201 z Commission Use Only Permit to Drill API Number: Permit Approval 1_ 1See cover letter Number: --,- /2--/LS50-Z)2.6)_7 3�7C 60Date: I 11 (Z for other requirements Conditions of approval: If box is checked,w II may not be used to explore for,test,or produce coalbed thane,gas hydrates,or gas contained in shales: liti Other: s' 35a) /s- est Samples req'd: Yes No Mud log req'd: Yes❑ No I e.5 o 3 c �r•1 TS r H2S measures: Yes No Directional svy req'd: Yes I No❑ Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No 0 PP by: ;:7 `� ��"'/T APPROVED BY THE •— (• - ;v Approved `•eQ-loissI Rn cpr nifsi 1 Date: �/— lS r� Form 10-401(Revis d 10/2012) This permit is valid fo 24 nlel�th 14 tut dtte of,a(•proval(20 AAC 25.005(g)) '- 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 • P tion for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 Permit It - West Sak Well #3K-105 Application for Permit to Drill Document MaxWell M O x i M i z e Well Vc Iue Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 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 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11.Seabed Condition Analysis..... 6 Requirements of 20 AAC 25.005(c)(11) 6 3K-105 PERMIT.doc n 9 �q Page 1 of 8 n «. x' Printed:29-Oct-12 t) ..� IC � < < tip.. Al on for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Cement Loads and CemCADE Summary 8 Attachment 4 Well Schematic 8 1. Well Name Requirements of 20 AAC 25.005(f) 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. 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, RKB: 3622' Total Vertical Depth, SS: 3560' 3K-105 PERMIT.doc Page 2 of 8 Printed:29-Oct-12 F ition for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent weilbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 3K-105 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(ROPE)as required by 20 AAC 25.035,20 AAC 25.036, or 20 AAC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 3K-105. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 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). 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: Foo�O s c `1.SS- MPSP SMPSP = (3,628 ft TVD)(0.44 - 0.11 psi/ft) e s621 tvu /'r} = 1,195 psi - (8)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 Drilling Hazards Summary. 4. 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(1); 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. /J w Fl r/4or- l . 3K-105 PERMIT.doc �/ r Page 3 of 8 Printed:29-Oct-12 AI ion for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 5. 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 Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 x 34 40 94 K55 Welded 80 28/ 28 108/ 108 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 13-3/8 16 68 L-80 BTC 2447 28/ 28 2475/2356 1438 sx ASLite Lead, 376 sx DeepCRETE Tail Cement Top planned @ 9-5/8 12-1/4 40 L-80 BTCM 5787 28/ 28 5815/3554 2375ND/22671VD Cemented w/487 sx 12.5 ppg DeepCRETE and 406 sx 15.8 ppg DeepCRETE tail. 4-1/2 6 3/4" B Sand 11.6 L-80 Hydril 521 7072 5614/ 3554 12687 / 3622 Slotted—no cement slotted Lateral(3K-105) x BTCM 4-1/2 6 3/4"D Sand 11.6 L-80 Hydril 521 7650 5028/ 3426 12678/ 3568 Slotted—no cement slotted Lateral(3K-105 X BTCM 6. 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); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 3K-105. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 3K-105 PERMIT.doc '° n � . Page 4 of 8 1—; ti ;{ TM Printed:29-Oct-12 ,. 6 A ion for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 7. 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 muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 13-3/8"Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.7 9.4 - 9.4 9.4 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (cP) Plastic Viscostiy 30 55 15 20 (lb/100 sf) pH 9.0 10.0 9.0 10.0 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program (LSND) Lateral Mud Program (Ml VersaPro Mineral Oil Base) B & D sand laterals 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.6—9.8 Density(ppg) 9.4 - 9.6 Plastic Viscostiy Funnel Viscosity (lb/100 s f) 15-25 (seconds) 45 - 60 Yield Point 15-20 Plastic Viscostiy 12 18 (cP) (lb/100 sf) Yield Point 18-24 HTHP Fluid loss (cP) (m1/30 min @ <4.0 API Filtrate 200psi 8 150° (cc/30 min)) 4 - 6 Oil/Water Ratio 80/20 Chlorides (mg/I) <500Electrical 650 - 900 pH 9.0— 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 8. 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(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 3K-105 PERMIT.doc Page 5 of 8 p t ti , ! `A� Printed:29-Oct-12 A, ion for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 9. 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. 10.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 seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11.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. 12.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 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 34"insulated conductor to +/- 80' RKB. Install landing ring on conductor. //ier 2' - 2. Move in / rig up Doyon Rig 141. Install 21-1/4"Annular with 16"di rertIr line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 2475' MD/ 2356'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's as described above in Section 3 above and test to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4"bit and 8"drilling assembly, with MWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to leak off, recording results. 1.0i1'h,;., /(.I. fn 8. Directionally drill to 9-5/8"casing point at 581 ' MD/ 3554'TVD. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. ' co, 10. Run 9-5/8", 40# L80, BTC Mod casing to surface. (top or f cement to be 2375' MD/ 2267'TVD which corrresponds to 580'above the Ugnu C formation, and 100'overlap in the surface casing.) 11. Circulate out excess cement thru DV cementing tool placed at 2375'. 12. Install wellhead x 9-5/8" packoff and test to 3500 psi. 13. Flush 13-3/8"x 9-5/8"annulus with water, followed by diesel. PV 3K-105 PERMIT.doc L'S Page 6 of 8 Printed:29-Oct-12 P tion for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 14. PU 6-3/4" PDC Bit and 4-1/2"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. R_e-test casing if cement is tagged more than 100 feet above the float collar. 15. Drill out cement and 20'of new hole. Displace hole to lateral drilling OBM mud. Perform formation integrity test to leak off, recording results. Fir r+4.w. I L? iPy 16. Directionally drill 6-3/4" hole to West Sak B Sand TD at +/- 12687 MD/ 3622'TVD as per directional plan. 17. POOH to 9-5/8"shoe. TIH to bottom &displace to solids-free oil based mud. Pump out of Hole. 18. PU and run 4-1/2"slotted liner. 19. Land liner, set liner hanger @ +/- 5080'MD/3437'TVD. POOH. Note: Remaining operations are covered under the 3K-105L1 Application for Permit to Drill, and are provided here for information only. 20. Run and set Baker Gen2 WindowMaster whipstock system, at window point of +/- 5028' MD/ 3426'TVD, the top of the D sand. i. 21. Mill 8-1/2"window. POOH. 22. Pick up 6-3/4"drilling assembly with MWD and LWD logging tools. RIH. 23. Drill to TD of West Sak D Sand) teral at -F/- 12679 MD/ 3568'TVD, as per directional plan. 24. POOH, back reaming out of lateral to window. TIH to bottom &displace to solids-free oil based mud. Pump out of hole. 25. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 26. RIH and set Baker Seal Bore diverter 27. PU and run 4-1/2"slotted liner with Baker Oil Tools RAM Hangar system. 28. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH 29. 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 requil'ad. 30. PU Gas Lift completion as required and RIH to depth. Land tubing. Set BPV 31. Nipple down BOPS nipple up tree and test. Pull BPV. 32. 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). 33. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) 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: (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 3K-105 PERMIT.doc Page 7 of 8 Printed:29-Oct-12 P ion for Permit to Drill,Well 3K-105 Revision No.0 Saved:29-Oct-12 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. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 3K-105 PERMIT.doc Page 8 of 8 Printed:29-Oct-12 , - 1 -- , . I . ConocoPhillips (Alaska) Inc. -Kup2 ,.! Kuparuk River Unit Kuparuk 3K Pad / , .. . Plan 3K-105 (E15) .,,-• A, =.4 3K-105 -Z- 3,,, :',;73: 1 ti, Plan: 3K-105 (wp12) 1 c ,.- ':.: Z. ,.- , 4 .=„:„, , ..,.;. : Standard Proposal Report , 04 October, 2012 t - ;-' -4- '',33:'''' '?I'' 'll• .'-: 1 . . . .„ .. .•...• . HALLIBURTON ,.• :•',E Sperry Drilling Services 0r, 1 C 1 " 17'':' L , II I II Ivi I I W II d - o 0 Ili ' C -a II I o IIIN •. _—o ,� 0soAM II I 2 I . t1 a c — itg.— N N O O o Y YY N0000� I I I 'F' I 11'I I O j - p A i- 80ma 2comCO o in�av II 1 I �11 - a _ o ',6'' m3 > > m •-•- I I I M I `ZIIY d _ R. s +� '6 co gi 0-=aarn� d 0 0 ° oaeay I I ate) I mll M = O c$ -J u I-mYcOD»Z�� a'-'7,a II I I IPI 1 i- a 0 34 r zUvq II I I 1I'I ' ' a 3 _o W �acna�mworp oa),- a) ,OO II I W II - p Q �O)mo?a,r-oo000Ohr ��'� II I LL L19Zil11 '_ o -- V tl. 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M m _ in 0 II I`, t0001> III Na) - a)' I I 1 \ II I Q _oo i 3 I I 1 \ co I I III 2 O I , co I I I `, M 00S 1 1 III,- - Cl) ) II 1 \ .96s1I III M 'i I I I \\ I 00 I I III - 0 � II I , i 0 1 1 1 III _a) , II I 01 X 1 1 Kw _ 00 oII 10 .Y), 1 1 1 NCO - o 53 O oII I o I 1 1 m co.. 2 �1' .I-II IN • I I� I � yti o 0 _ I I cI y ��, - IIyI �i I 1 Q+I 3�. aNi III 0 CS m�� 'II'3 - o a 'll 11 —O q II I CO o)I h IIIII -- I-- IICO I Y 1n 1 Z 91P , M \II' I, I 1 1 1 1 fiV _ o Yi , I , I I , I I I I I I I I 1 I I I I I , I I I I I I I I I III s I I I I I'lI I I`, I I I A ISI I I I I I 1 I 1 I I I I I I I I I I I I I .� 0 0 O 0 0 o 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 N 0 0 0 ,.Fn '4 R�! �`+"; N 0 M '07 a) N 1 ' `I ( ' t NO(9,I*P 1JeA 8�1 Halliburton -Sperry 1-1A,LLIBURT01 - 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)(copy)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)(copy)@ 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-105 Design: 3K-105(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 +E/-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 • Wellbore 3K-105 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) bggm2007 10/16/2007 17.98 79.80 57,264 Design 3K-105(wp12) Audit Notes: Version: 17 Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) L 28.00 0.00 0.00 90.00 10/4/2012 3:32:02PM Page 2 COMPASS 2003.16 Build 69 W a N CI n C N C°D yC 000 •- �j QW (�CD00 _ O _, E C p 2 LLoOiNN _� U M n O v N U I^tD� 0 \ `��-� N O O O.p .NOOm - /O A N N QC Y to MM N��N .{-I-]1 \ t,1 M N U 2$a2 - o V • -83 n av N g Ern 2 2 - o C Q ME,'1 '.r f in - 0 OU• 0 < Ill F 'UU❑ �.- 066 _ F rn W L''f.'v M _. _ • A r o $1 O W88e ngk . -—o Q O LL p AIn N __--_ o Z Z N W e„+, 066 - P N , W t•,MMV Q ,,,.C.N A _^o-. 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N 0S4F — M - LLJ _ 0 rn Ud rn OO -o 3 Z - Y _ ` 0001 n W cu�v.) _ F 0 —o zo h 0 ,n W - ,n N SCZ J -- N - N M WI C ,- - r�, yg CO F Z " El) - I 1 - 2 _o 7 - m ' 1 1 1 1 1 1 o 11 I I I I I I I I I I I o I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I 0 I I I I I I I I I I I I I 1 0 I I I 1 0 l I l I - 0 O O 0 0 0 0 0 0 0 0 0 J o 0 0 0 0 0 0 0 0 0 0 0 0 0 o O V M N N ,�. O- V, V, O V', N N O O Q atm, ( 1 zow )4 o Iv , , , t : j . L. Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-105(E15) Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: 62.3'(34.3+28)(copy)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)(copy)@ 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-105 Design: 3K-105(wp12) Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (°) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 -34.30 0.00 0.00 0.00 0.00 0.00 0.00 260.00 0.00 0.00 260.00 197.70 0.00 0.00 0.00 0.00 0.00 0.00 703.99 13.32 308.00 700.00 637.70 31.63 -40.48 3.00 3.00 0.00 308.00 853.99 13.32 308.00 845.96 783.67 52.91 -67.72 0.00 0.00 0.00 0.00 1,464.95 25.01 354.19 1,425.00 1,362.70 226.22 -136.84 3.00 1.91 7.56 76.00 1,664.95 25.01 354.19 1,606.24 1,543.94 310.35 -145.41 0.00 0.00 0.00 0.00 2,464.95 27.61 82.44 2,347.74 2,285.44 509.61 26.92 4.50 0.32 11.03 128.00 2,714.95 29.64 105.67 2,567.86 2,505.56 500.50 144.25 4.50 0.81 9.29 90.00 3,164.95 49.45 112.44 2,913.27 2,850.97 404.17 412.22 4.50 4.40 1.50 15.00 3,748.60 78.57 110.14 3,166.32 3,104.02 216.98 896.24 5.00 4.99 -0.39 -4.63 4,673.66 78.57 110.14 3,349.69 3,287.39 -95.17 1,747.52 0.00 0.00 0.00 0.00 4,928.56 77.00 98.51 3,403.80 3,341.50 -156.76 1,988.42 4.50 -0.61 -4.56 -99.06 5,028.56 77.00 98.51 3,426.30 3,364.00 -171.18 2,084.79 0.00 0.00 0.00 0.00 5,167.96 79.97 92.07 3,454.15 3,391.85 -183.73 2,220.71 5.00 2.13 -4.62 -65.46 5,641.04 79.97 92.07 3,536.55 3,474.25 -200.59 2,686.25 0.00 0.00 0.00 0.00 5,814.84 88.25 89.42 3,554.37 3,492.07 -202.81 2,858.96 5.00 4.76 -1.53 -17.84 6,139.84 88.25 89.42 3,564.30 3,502.00 -199.52 3,183.79 0.00 0.00 0.00 0.00 6,170.13 89.19 88.65 3,564.98 3,502.68 -199.01 3,214.07 4.00 3.10 -2.53 -39.30 6,475.04 89.19 88.65 3,569.30 3,507.00 -191.84 3,518.86 0.00 0.00 0.00 0.00 6,499.75 89.86 89.38 3,569.51 3,507.21 -191.42 3,543.57 4.00 2.71 2.95 47.42 7,616.28 89.86 89.38 3,572.30 3,510.00 -179.34 4,660.03 0.00 0.00 0.00 0.00 7,857.24 100.29 92.36 3,551.02 3,488.72 -182.94 4,899.66 4.50 4.33 1.24 15.78 7,979.09 100.29 92.36 3,529.26 3,466.96 -187.87 5,019.45 0.00 0.00 0.00 0.00 8,258.06 88.51 96.73 3,507.90 3,445.60 -209.96 5,296.16 4.50 -4.22 1.57 159.49 9,158.06 88.51 96.73 3,531.30 3,469.00 -315.39 6,189.66 0.00 0.00 0.00 0.00 9,223.09 88.04 99.29 3,533.26 3,470.96 -324.45 6,254.02 4.00 -0.72 3.94 100.47 9,516.57 88.04 99.29 3,543.30 3,481.00 -371.80 6,543.47 0.00 0.00 0.00 0.00 9,552.89 88.47 98.29 3,544.41 3,482.11 -377.34 6,579.35 3.00 1.18 -2.76 -66.75 11,683.01 88.47 98.29 3,601.30 3,539.00 -684.28 8,686.47 0.00 0.00 0.00 0.00 11,722.65 89.51 98.87 3,602.00 3,539.70 -690.19 8,725.67 3.00 2.62 1.46 29.19 11,990.51 89.51 98.87 3,604.30 3,542.00 -731.49 8,990.32 0.00 0.00 0.00 0.00 12,024.34 88.49 98.90 3,604.89 3,542.59 -736.71 9,023.73 3.00 -3.00 0.11 177.95 12,686.79 88.49 98.90 3,622.30 3,560.00 -839.21 9,677.97 0.00 0.00 0.00 0.00 10/4/2012 3:32:02PM Page 3 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLI B U RTCh .• 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)(copy)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)(copy)@ 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-105 Design: 3K-105(wp12) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -34.30 1 28.00 0.00 0.00 28.00 -34.30 0.00 0.00 6,007,929.00 529,305.43 0.00 0.00 SHL:935'FSL,315'FWL-Sec35-T13N-R09E 260.00 0.00 0.00 260.00 197.70 0.00 0.00 6,007,929.00 529,305.43 0.00 0.00 703.99 13.32 ' 308.00 700.00 637.70 31.63 -40.48 6,007,960.47 529,264.83 3.00 -40.48 853.99 13.32 308.00 845.96 783.67 52.91 -67.72 6,007,981.63 529,237.51 0.00 -67.72 1,464.95 25.01 354.19 1,425.00 1,362.70 226.22 -136.84 6,008,154.66 529,167.71 3.00 -136.84 1,610.94 25.01 354.19 1,557.30 1,495.00 287.63 -143.09 6,008,216.04 529,161.22 0.00 -143.09 T3 1,664.95 25.01 354.19 1,606.24 1,543.94 310.35 -145.41 6,008,238.75 529,158.82 0.00 -145.41 1,684.83 24.47 355.89 1,624.30 1,562.00 318.64 -146.13 6,008,247.03 529,158.07 4.50 -146.13 Base Pfrost 1,855.84 20.78 13.56 1,782.30 1,720.00 383.56 -141.55 6,008,311.97 529,162.39 4.50 -141.55 K15 2,464.95 27.61 82.44 2,347.74 2,285.44 509.61 26.92 6,008,438.66 529,330.35 4.50 26.92 2,474.61 27.61 83.38 2,356.30 2,294.00 510.16 31.36 6,008,439.23 529,334.79 4.50 31.36 Surface Casing @ 2475'MD,2356'TVD:1445'FSL,347'FWL-Sec35-T13N-R09E-13 3/8"Surface Casing 2,490.41 27.63 84.91 2,370.30 2,308.00 510.91 38.65 6,008,440.00 529,342.07 4.50 38.65 Surface Csg I 2,714.95 29.64 105.67 2,567.86 2,505.56 500.50 144.25 6,008,430.01 529,447.69 4.50 144.25 2,954.76 40.16 109.98 2,764.30 2,702.00 457.93 274.40 6,008,387.96 529,578.01 4.50 274.40 Ugnu C 3,164.95 49.45 112.44 2,913.27 2,850.97 404.17 412.22 6,008,334.75 529,716.02 4.50 412.22 3,320.88 57.23 111.69 3,006.30 2,944.00 357.25 528.07 6,008,288.29 529,832.04 5.00 528.07 Ugnu B 3,539.00 68.11 110.84 3,106.30 3,044.00 287.14 708.39 6,008,218.89 530,012.62 5.00 708.39 Ugnu A 3,748.60 78.57 110.14 3,166.32 3,104.02 216.98 896.24 6,008,149.48 530,200.73 5.00 896.24 4,036.06 78.57 110.14 3,223.30 3,161.00 119.98 1,160.77 6,008,053.53 530,465.60 0.00 1,160.77 N Sand 4,673.66 78.57 110.14 3,349.69 3,287.39 -95.17 1,747.52 6,007,840.70 531,053.13 0.00 1,747.52 4,928.56 77.00 98.51 3,403.80 3,341.50 -156.76 1,988.42 6,007,780.07 531,294.26 4.50 1,988.42 5,028.56 77.00 98.51 3,426.30 3,364.00 -171.18 2,084.79 6,007,766.03 531,390.67 0.00 2,084.79 3K-105 D-sand Top(wp12) 5,046.60 77.38 97.67 3,430.30 3,368.00 -173.65 2,102.20 6,007,763.62 531,408.09 5.00 2,102.20 Top West Sak D @ 5047'MD,3430'TVD:761'FSL,2417'FWL-Sec35-T13N-R09E-West Sak D 5,167.96 79.97 92.07 3,454.15 3,391.85 -183.73 2,220.71 6,007,754.01 531,526.62 5.00 2,220.71 5,346.79 79.97 92.07 3,485.30 3,423.00 -190.10 2,396.69 6,007,748.33 531,702.61 0.00 2,396.69 West Sak C 5,641.04 79.97 92.07 3,536.55 3,474.25 -200.59 2,686.25 6,007,738.99 531,992.18 0.00 2,686.25 5,735.11 84.45 90.63 3,549.30 3,487.00 -202.78 2,779.41 6,007,737.16 532,085.34 5.00 2,779.41 West Sak B 5,814.84 88.25 89.42 3,554.37 3,492.07 -202.81 2,858.96 6,007,737.44 532,164.88 5.00 2,858.96 Intermediate Casing @ 5815'MD,3554'TVD:732'FSL,2107'FEL-Sec35-T13N-R09E-9 5/8"Intermediate Casing 6,139.84 88.25 89.42 3,564.30 3,502.00 -199.52 3,183.79 6,007,742.01 532,489.67 0.00 3,183.79 3K-105 CP2(wp10) I 6,170.13 89.19 88.65 3,564.98 3,502.68 -199.01 3,214.07 6,007,742.64 532,519.94 4.00 3,214.07 10/4/2012 3:32:02PM Page 4 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTOft Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-105(E15) Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: 62.3'(34.3+28)(copy)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)(copy)@ 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-105 Design: 3K-105(wp12) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,507.00 6,475.04 89.19 88.65 3,569.30 3,507.00 -191.84 3,518.86 6,007,751.00 532,824.67 0.00 3,518.86 3K-105 CP3(wp10) 6,499.75 89.86 89.38 3,569.51 3,507.21 -191.42 3,543.57 6,007,751.52 532,849.37 4.00 3,543.57 7,616.28 89.86 89.38 3,572.30 3,510.00 -179.34 4,660.03 6,007,767.98 533,965.67 0.00 4,660.03 3K-105 CP4(wp10) 7,857.24 100.29 92.36 3,551.02 3,488.72 -182.94 4,899.66 6,007,765.33 534,205.29 4.50 4,899.66 7,979.09 100.29 92.36 3,529.26 3,466.96 -187.87 5,019.45 6,007,760.86 534,325.08 0.00 5,019.45 8,258.06 88.51 96.73 3,507.90 3,445.60 -209.96 5,296.16 6,007,739.87 534,601.85 4.50 5,296.16 9,158.06 88.51 96.73 3,531.30 3,469.00 -315.39 6,189.66 6,007,637.95 535,495.67 0.00 6,189.66 3K-105 CP6(wp10) 9,223.09 88.04 99.29 3,533.26 3,470.96 -324.45 6,254.02 6,007,629.15 535,560.06 4.00 6,254.02 9,516.57 88.04 99.29 3,543.30 3,481.00 -371.80 6,543.47 6,007,582.95 535,849.67 0.00 6,543.47 1 3K-105 CP7(wp10) 9,552.89 88.47 98.29 3,544.41 3,482.11 -377.34 6,579.35 6,007,577.54 535,885.56 3.00 6,579.35 11,683.01 88.47 98.29 3,601.30 3,539.00 -684.28 8,686.47 6,007,278.91 537,993.66 0.00 8,686.47 3K-105 CP8(wp10) ' 11,722.65 89.51 98.87 3,602.00 3,539.70 -690.19 8,725.67 6,007,273.16 538,032.88 3.00 8,725.67 11,990.51 89.51 98.87 3,604.30 3,542.00 -731.49 8,990.32 6,007,232.91 538,297.66 0.00 8,990.32 I 3K-105 CP9(wp10) 12,024.34 88.49 98.90 3,604.89 3,542.59 -736.71 9,023.73 6,007,227.82 538,331.09 3.00 9,023.73 12,686.78 88.49 98.90 3,622.30 3,560.00 -839.21 9,677.96 6,007,127.90 538,985.66 0.00 9,677.96 TD @ 12687'MD,3622'TVD:89'FSL,568'FEL-Sec36-T13N-R09E • • 12,686.79 88.49 98.90 3,622.30 , 3,560.00 -839.21 9,677.97 6,007,127.90 538,985.66 0.00 9,677.97 3K-105 Toe(wp10) 10/4/2012 3:32:02PMPage 5 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTOi.. 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)(copy)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)(copy)@ 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-105 I Design: 3K-105(wp12) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 3K-105 CP9(wp10) 1.48 97.59 3,604.30 -731.49 8,990.32 6,007,232.91 538,297.66 -plan hits target center -Polygon Point 1 3,604.30 -731.49 8,990.32 6,007,232.91 538,297.66 Point 2 3,622.27 -839.14 9,677.84 6,007,127.96 538,985.53 3K-105 Toe(wp10) 0.00 0.00 3,622.30 -839.21 9,677.97 6,007,127.90 538,985.66 -plan hits target center -Point 3K-105 CP2(wp10) 0.85 97.46 3,564.30 -199.52 3,183.79 6,007,742.01 532,489.67 -plan hits target center -Polygon Point 1 3,564.30 -199.52 3,183.79 6,007,742.01 532,489.67 Point 2 3,569.26 -192.19 3,521.73 6,007,750.66 532,827.54 3K-105 CP4(wp10) -8.53 97.59 3,572.30 -179.34 4,660.03 6,007,767.98 533,965.67 -plan hits target center -Polygon Point 1 3,572.30 -179.34 4,660.03 6,007,767.98 533,965.67 Point 2 3,504.46 -188.47 5,115.10 6,007,760.65 534,420.72 3K-105 CP7(wp10) 1.53 97.59 3,543.30 -371.80 6,543.47 6,007,582.95 535,849.67 -plan hits target center -Polygon Point 1 3,543.30 -371.80 6,543.47 6,007,582.95 535,849.67 Point 2 3,601.13 -684.07 8,686.04 6,007,279.12 537,993.23 3K-105 CP6(wp10) 1.92 97.59 3,531.30 -315.39 6,189.66 6,007,637.95 535,495.67 -plan hits target center -Polygon Point 1 3,531.30 -315.39 6,189.66 6,007,637.95 535,495.67 Point 2 3,543.30 -371.75 6,543.33 6,007,583.00 535,849.52 3K-105 CP5(wp10) 1.49 97.59 3,503.30 -189.16 5,120.04 6,007,759.97 534,425.67 -plan misses target center by 12.30ft at 8081.37ft MD(3514.80 TVD,-193.48 N,5120.51 E) -Polygon Point 1 3,503.30 -189.16 5,120.04 6,007,759.97 534,425.67 1 Point2 3,531.31 -315.29 6,189.46 6,007,638.05 535,495.47 3K-105 CP3(wp10) 0.15 97.58 3,569.30 -191.84 3,518.86 6,007,751.00 532,824.67 -plan hits target center -Polygon Point 1 3,569.30 -191.84 3,518.86 6,007,751.00 532,824.67 Point 2 3,572.26 -179.34 4,660.61 6,007,767.99 533,966.25 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 CP1 (wp10) 1.75 90.23 3,538.30 -208.16 2,331.67 6,007,730.02 531,637.67 -plan misses target center by 66.59ft at 5292.68ft MD(3475.88 TVD,-188.17 N,2343.44 E) -Polygon Point 1 3,538.30 -208.16 2,331.67 6,007,730.02 531,637.67 Point 2 3,564.32 -199.46 3,183.40 6,007,742.07 532,489.27 3K-105 CP8(wp10) 0.56 97.59 3,601.30 -684.28 8,686.47 6,007,278.91 537,993.66 -plan hits target center -Polygon Point 1 3,601.30 -684.28 8,686.47 6,007,278.91 537,993.66 Point 2 3,604.30 -731.47 8,990.35 6,007,232.92 538,297.69 10/4/2012 3:32:02PM Page 6 COMPASS 2003.16 Build 69 Halliburton -Sperry 1-1ALLIBURTClivi 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)(copy)@ 62.30ft(62.3'(34.3+28)) Project: Kuparuk River Unit MD Reference: 62.3'(34.3+28)(copy)@ 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-105 Design: 3K-105(wp12) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ('') (") 12,686.79 3,622.30 4 1/2"Production Liner 4-1/2 6-3/4 2,474.61 2,356.30 13 3/8"Surface Casing 13-3/8 16 5,814.84 3,554.37 9 5/8"Intermediate Casing 9-5/8 12-1/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (") 1,610.94 1,557.30 T3 0.00 4,036.06 3,223.30 N Sand 0.00 1,855.84 1,782.30 K15 0.00 2,954.76 2,764.30 Ugnu C 0.00 2,490.41 2,370.30 Surface Csg 0.00 1,684.83 1,624.30 Base Pfrost 0.00 5,346.79 3,485.30 West Sak C 0.00 5,046.60 3,430.30 West Sak D 0.00 3,539.00 3,106.30 Ugnu A 0.00 5,735.11 3,549.30 West Sak B 0.00 3,320.88 3,006.30 Ugnu B 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 28.00 28.00 0.00 0.00 SHL:935'FSL,315'FWL-Sec35-T13N-R09E 2,474.61 2,356.30 510.16 31.36 Surface Casing @ 2475'MD,2356'TVD:1445'FSL,347'FWL-Sec35-T13N-R09E 5,046.60 3,430.30 -173.65 2,102.20 Top West Sak D @ 5047'MD,3430'TVD:761'FSL,2417'FWL-Sec35-T13N-R09E 5,814.84 3,554.37 -202.81 2,858.96 Intermediate Casing @ 5815'MD,3554'TVD:732'FSL,2107'FEL-Sec35-T13N-R0! 12,686 78 3,622.30 -83921 9,677.96 TD @ 12687'MD,3622'ND:89'FSL,568'FEL-Sec36-T13N-R09E 10/4/2012 3:32:02PM Page 7 COMPASS 2003.16 Build 69 . t 1 . i o I f I I 0000ood0 � d Co ^ w W d d H o % m c _ m < W ` ' C C m m N cn c co• 12 0 a m c rt r� m ED 0 0 W" 5. g 3 0 Fo' ' 0 m In r, z o . 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IIIIIIIIIIIIIIIIIIIIII1111IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII J 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 o o 0 0 0 0 QM N N N N M M V V U = (u!j 0050 (+)4]JoN/(-)q nog N L c LID 0 C = ,1.011111111111111 V LID • O O M E0 to J 4.11 0 i^", +�++ O w > > > Y > > > > M W W _ N M m '8 v Y M M N N O M L �y� W Y Y Y Y Y Y Y co __�_ W J M M M w M M M M t _ _ I, r CZ `4'. N CO h a M M 0) N N O M Q. i = © Y Y Y s- Y Y Y 3 C ."11 �� co M M Y co co co co 0 , 1 N M h CD I� MM c N N O C') 5 or co co co d M co co co co Cti yCD J r C o C Cu U 7 V Ir o It ' a •, (V CV 1— N r Q 1 I J1; N O 1r N N , P p 00 Ln M 3 ti Ii O 1' y 0 c.)1 d ii I: = Y co • Y� re M I •1c Y Y Y7 ` =M C r 3 3 d M / YY Mamoro �/ yan N HI a o o _ u 0 ,/ Lf) 2 '� a • 4.— J `n h = U °' 4. 1 3K-105 tilling Hazards Siinmary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate • Control drill, Reduced pump rates, Reduced drilling • fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Gas Hydrates Low i Control drill, reduced pump rates,reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates,mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low ' Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning aided by circulation sub and cuttings bed impellers, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out or backreaming _ 3K-105 Drilling Hazards Summa,y.doc 10/29/20121:44:52 PM Schlumberger Cem CAD E*well cementing recommendation for 13 3/8" Surface Operator : CPAI Well : 3K-105 Country : USA Field : Kuparuk State : Alaska Prepared for : Monty Myers Location : Kuparuk Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 10-26-2012 Business Phone : (907)659-2434 FAX No. Prepared by : Jenna Houston Phone : (907)223-8916 E-Mail Address : jhouston2@slb.com 04„ URTE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment experience.and good oilfield practices. This information is presided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals.recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. r Mark of Schlumberger Page 1 3k-105 Cement v1.cfw;10-26-2012; LoadCase Surface w/15.8;Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2474.0 ft BHST : 69 degF ft (x 1000)psi 0 1 2 . . . . . . . Frac ---I . . . — Pore • • • • • • •• •'• • 1 • 'Sandstone• • • _ • -1 k 4",'ell Lithologv Formation Press Page 2 3k-105 Cement v1.cfw;10-26-201Y222;r6{yLoadCase Surface w[15.8 Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surfacew/15.8 Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 110.0 20 106.5 19.000 Landing Collar MD : 2394.0 ft Casing/liner Shoe MD : 2474.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2474.0 13 3/8 40.0 68.0 12.415 L-80 2040 4310 IFJ Mean OH Diameter : 16.000 in Mean Annular Excess : 201.4% Mean OH Equivalent Diameter: 20.281 in Total OH Volume : 944.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1900.0 16.000 250.0 21.184 2474.0 16.000 50.0 17.163 Page 3 3k-105 Cement v1.cfw;10-26-2012; LoadCase Surface w/15.8;Version wcs-cem472_05 :e",, K t, p Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Max. Deviation Angle : 28 deg Max. DLS : 4.814 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 0.0 0.000 28.0 28.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 260.0 260.0 0.0 0.0 0.000 300.0 300.0 1.2 308.0 3.000 400.0 399.9 4.2 308.0 3.000 500.0 499.4 7.2 308.0 3.000 600.0 598.2 10.2 308.0 3.000 704.0 700.0 13.3 308.0 3.000 800.0 793.4 13.3 308.0 0.000 854.0 846.0 13.3 308.0 0.000 900.0 890.7 13.7 313.7 3.003 1000.0 987.6 15.0 324.7 2.997 1100.0 1083.8 16.7 333.7 3.001 1200.0 1179.0 18.7 341.0 2.997 1300.0 1273.1 21.0 346.9 3.006 1400.0 1365.7 23.4 351.6 2.995 1464.9 1424.9 25.0 354.2 2.998 1500.0 1456.7 25.0 354.2 0.000 1600.0 1547.3 25.0 354.2 0.000 1610.9 1557.2 25.0 354.2 0.000 1664.9 1606.2 25.0 354.2 0.000 1684.8 1624.2 24.5 355.9 -4.493 1700.0 1638.1 24.1 357.2 -4.509 1800.0 1730.2 21.8 7.2 -4.499 1855.8 1782.2 20.8 13.6 -4.500 1900.0 1823.6 20.2 19.0 -4.502 2000.0 1917.6 19.5 32.1 -4.496 2100.0 2011.8 19.8 45.5 4.501 2200.0 2105.6 21.0 58.0 4.499 2300.0 2198.3 23.0 68.7 4.504 2400.0 2289.4 25.6 77.6 4.494 2464.9 2347.4 27.6 82.4 4.510 2474.0 2355.4 27.6 83.4 4.814 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 2474.0 12.50 8.00 Sandstone Page 4 3k-105 Cement vl.cfw;10-26-2012; LoadCase Surface w/15.8;Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Geothermal Temperature Profile ___ MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1800.0 1730.2 32 0.7 2474.0 2355.4 69 2.1 Page 5 3k-105 Cement v1.ctw;;10-(r {pL26-2012; loadCase Surface w/15.0;Version wcs-cem472_05 �[ Rte..' f r A /...e Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2454.0 ft Casing Shoe :2474.0 ft NB of Cent. Used :61 NB of Floating Cent. :61 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 2474.0 61 1/1 1501813-13 3/8-8-POSITIVE 0.0 1914.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) 1501813-13 3/8-8- 13 3/8 15.252 15.252 Yes Houma N.A. N.A. N.A. POSITIVE 0.• ft 0 2[l 40 60 80 100 �..t Ce-t = 0 C• p_ c Pipe Standoff Page 6 3k-105 Cement v1.cfw;10-26-2012; LoadCasee-Surface w/15.8;Version wcs-cem472_05 � ��' . Client : CPAI Well : 3K-105 Schbiergcr String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 lb/gal Rheo.Model : BINGHAM Pv : 12.000 cP At temp. :80 degF Ty :20.00 Ibf/100ft2 Gel Strength :21.00 Ibf/100ft2 MUD Mud Type :WBM Job volume : 358.4 bbl Water Type : Fresh MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :3.51E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.406 Ty : 16.351bf/100ft2 Gel Strength :29.67 Ibf/100ft2 Job volume : 50.0 bbl ALC Surface Lead DESIGN Fluid No:3 Density : 11.09 lb/gal Rheo. Model : BINGHAM Pv : 174.489 cP At temp. :65 degF Ty :32.60 Ibf/100ft2 Gel Strength :23.04 Ibf/100ft2 DESIGN BLEND SLURRY Name :ALC(0.80) Mix Fluid :6.400 gal/sk Job volume :487.2 bbl Dry Density :96.52 lb/ft3 Yield : 1.90 ft3/sk Quantity : 1438.03 sk Sack Weight : 100 lb Solid Fraction :55.0% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :6.204 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.750%BWOB Dispersant D044 10.000%BWOW Salt Page 7 3k-105 Cement v1 cfw,10-26-2012, LoadCase Surface w/15 8,Version wcs-cem472_05 t . Client : CPAI Well : 3K-105 SchlcmIcrgcr String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Surface Tail DESIGN Fluid No:4 Density : 15.80 lb/gal Rheo. Model : BINGHAM Pv :93.197 cP At temp. :71 degF Ty : 13.30 Ibf/100ft2 Gel Strength : 16.33 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid :5.100 gal/sk Job volume :78.0 bbl Dry Density : 199.77 lb/ft3 Yield : 1 1 .ft3/sk Quantity : 376.37 sk Sack Weight :94 lb Solid Fraction :41.4% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.100 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 0.300%BWOC Dispersant D167 0.350%BWOC Fluid loss S002 0.400%BWOC Accelerator CW100 DESIGN Fluid No:6 Density : 8.33 lb/gal Rheo.Model : NEWTONIAN At temp. : (degF) Viscosity :5.000 cP Gel Strength : (Ibf/100ft2) Job volume :20.0 bbl Page 8 3k-105 Cement v1 cfw,10-26-2012, LoadCase Surface w/158,Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumberger String : 13 3/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Section 4: fluid sequence Original fluid Mud 9.50 lb/gal Pv: 12.000 cP Ty:20.00 Ibf/100ft2 Displacement Volume 358.4 bbl Total Volume 993.7 bbl TOC 0.O ft Fluid Sequence Name Volume Ann.Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) CW100 20.0 0.0 8.33 viscosity:5.000 cP MUDPUSH II 50.0 0.0 10.50 k:3.51 E-2 Ibf.sAn/ft2 n:0.406 Ty:16.35 Ibf/100ft2 ALC Surface Lead 487.2 1894.0 0.0 11.09 Pv:174.489 cP Ty:32.60 Ibf/100ft2 Surface Tail 78.0 580.0 1894.0 15.80 Pv:93.197 cP Ty:13.30 Ibf/100ft2 Mud 358.4 0.0 9.50 Pv:12.000 cP Ty:20.00 Ibf/100ft2 Static Security Checks: Frac 8 psi at 110.0 ft Pore 18 psi at 110.0 ft Collapse 1657 psi at 2394.0 ft Burst 4310 psi at 0.0 ft Csg.Pump out 47 ton Check Valve Diff Press 302 psi Page 9 3k-105 Cement v1 cfw,10-26-2012, LoadCase Surface w/15 8,Version wcs-cem472_05 t r'- 1 ( ! Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Section 5: pumping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) CW100 6.0 20.0 3.3 20.0 80 MUDPUSH II 6.0 50.0 8.3 50.0 80 Shark Tooth 1 6.0 487.2 81.2 487.2 80 Surface Lead Field Blend Red Wolf 2 5.0 78.0 15.6 78.0 80 Surface Tail Field Blend Mud 8.0 348.4 43.6 348.4 80 Mud 2.0 10.0 5.0 358.4 80 Total 02:37 993.7 bbl hr:mn Dynamic Security Checks: Frac 1 psi at 2474.0 ft Pore 4 psi at 110.0 ft Collapse 1657 psi at 2394.0 ft Burst 3954 psi at 0.0 ft _ Page 10 3k-105 Cement vl.cfw,10-26-2012, LoadCase Surface w/15 8;Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumberger String : 13 3/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 ft (x 1000)psi 0 1 2 oO 1 HydrostaticCalc.Ceml-P -Mn.Hydrostatic -Calc.Furry Press. Max.Dynarric ^ -- - -Mn.Dynarric p, -Frac -Fore N o0 2 N li o o_ o N 0 0 100 200 Time(min) o - Depth= 2474 ft o i -Annular Velocity o ` o- C N .- .0T o C C o Q O O co O 0 100 200 Fluid Sequence Dynamic Well Security Time(min) o Depth= 2474 ft Ili -Frac ^N-. -Fore 0 -Hydrostatic •,.........Dvnanic z---...(Ni w a.O 0 25 50 75 100 125 150 175 Time(min) c Fluids at 2474 ft o —Acquired 0 Out -Acquired Q h I .S Ill -Q Out .. - E t` -Qin C) N 0 ,3 LY L° o N 0 25 50 75 100 125 150 175 Time(min) Page 11 3k-105 Cement vl.cfw;10-26-2012; LoadCase Surface w/15.0;Version wcscem472_05 ORIGINAL Client : CPAI Well : 3K-105 Schlumberger String : 13 3/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Section 6: WELLCLEAN II Simulator ft % % 0 25 50 75 100 0 25 50 75 100 o - I_ ; ir —Std Betw.Cent Mud Contarrination -Cement Coverage' -Uncontarrinated Slurry 7 ---- T O O_ O �_ . . .. 1 O _.,_ i 1N O O 0 M- Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall b 1 i 1 0-1 r -0 0-1 -0 506- i _509 500- lr -500 15 cI II laoo- ->Iaoa E lana- l -1ix* t _ t t - _' I I ' - t a 1590- -1500 g a 1500- -1 r. IT 1500 g 20042000 2000- -2404 2540 -2500 25001 -2500 L o 'D s a a # '4:' a A 'o a Z Mud 0 High Low Red Wolf 2 Surface Tail Field Blend I I Medium None I I Shark Tooth 1 Surface Lead Field Blend (—I MUDPUSH II - CW100 Page 12 3k-105 Cement vt.cfw;10-26-2012; LoadCase Surface w/15.8;Version wcs-cem472_05 0 0,,, M Client : CPAI Well : 3K-105 Schlumrgcr String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Surface w/15.8 Tolerances - Spacer Max Rate is 6 BPM - Cement rate 4-6 BPM (remain within +/-0.2ppg Density Range,to be checked periodically with a mud balance) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - Max displacement Rate is 8 BPM, must slow to 2 BPM as indicated - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be conditioned prior to cementing - Maintain returns during cement job if possible Contingencies In the event that a problem occurs during mixing, pumping, or displacement, contingency plans should be systematically followed. If a shutdown occurs during the job, make note in the CemCAT report of when the stoppage occurred and how much time is available to remedy an issue before the thickening time becomes a problem. 1) If losses are encountered prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Slow rate until full circulation is regained c) Determine max rate with full circulation and pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at minimum rate b) Attempt to remedy issue in less than 30 mins c) If issue with mixing system—switch to back-up mixing system d) If issue with triplex pump—continue with secondary triplex on unit 3) Mud Pump failure during displacement a) Discuss rig up in the event of cement unit displacement in PJSM b) Attempt to continue displacement with secondary rig pump c) Attempt to remedy issue (downtime <10 mins) d) Note displacement volume pumped by mud pumps: verify with well site leader e) Subtract pumped volume from total volume, which will be the volume pumped by the cement unit f) Rig up hoses to get mud to Cement Unit and begin displacement with cement unit (verify volume with well site leader) 4) Data Acquisition System Failure a) Continue pumping b) The final volume will be based on the physical count of the mix water Page 13 3k-105 Cement v1 cfw,10-26-2012, LoadCase Surface w/15 0:Version wcs-cem472_05 f7 I CemCAD E*well cementing recommendation for 9 5/8" Intermediate Operator : CPAI Well : 3K-105 Country : USA Field : Kuparuk State : Alaska Prepared for : Monty Myers Location : Kuparuk Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 10-26-2012 Business Phone : (907)659-2434 FAX No. Prepared by : Jenna Houston Phone : (907)223-8916 E-Mail Address : jhouston2©slb.com C) 940ATE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others.limitations.computer models.measurements,assumptions and inferences Nat are not infallible. Calculations are estimates based an provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GWEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTNENESS OF MATERIAL,PRODUCTS OR SUPPLIES.RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to he interred and no intellectual property rights are granted hereby. * Mark of Schlumberger Page 1 3k-105 Cement vi.cfw;10-26-2012; LoadCase Intermediate la);Version wcs-cem472_05 n I (,J I t''‘.! 11-• tt aim Client : CPAI Well : 3K-105 S hlcmherger String : 13 3/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 5815.0 ft BHST : 95 degF Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2474.0 13 3/8 68.0 12.415 Landing Collar MD : 5735.0 ft Casing/liner Shoe MD : 5815.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 5815.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 IFJ Page 2 3k-105 Cement v1.cfw;10-26-2012; LoadCase Intermediate(a);Version wcs-cem472_05 V t rpt' Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Mean OH Diameter : 12.250 in Mean Annular Excess : 40.0% Mean OH Equivalent Diameter: 13.154 in Total OH Volume : 561.6 bbl (including excess) Max. Deviation Angle : 88 deg Max. DLS : 5.012 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 0.0 0.000 28.0 28.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 260.0 260.0 0.0 0.0 0.000 300.0 300.0 1.2 308.0 3.000 400.0 399.9 4.2 308.0 3.000 500.0 499.4 7.2 308.0 3.000 600.0 598.2 10.2 308.0 3.000 704.0 700.0 13.3 308.0 3.000 800.0 793.4 13.3 308.0 0.000 854.0 846.0 13.3 308.0 0.000 900.0 890.7 13.7 313.7 3.003 1000.0 987.6 15.0 324.7 2.997 1100.0 1083.8 16.7 333.7 3.001 1200.0 1179.0 18.7 341.0 2.997 1300.0 1273.1 21.0 346.9 3.006 1400.0 1365.7 23.4 351.6 2.995 1464.9 1424.9 25.0 354.2 2.998 1500.0 1456.7 25.0 354.2 0.000 1600.0 1547.3 25.0 354.2 0.000 1610.9 1557.2 25.0 354.2 0.000 1664.9 1606.2 25.0 354.2 0.000 1684.8 1624.2 24.5 355.9 -4.493 1700.0 1638.1 24.1 357.2 -4.509 1800.0 1730.2 21.8 7.2 -4.499 1855.8 1782.2 20.8 13.6 -4.500 1900.0 1823.6 20.2 19.0 -4.502 2000.0 1917.6 19.5 32.1 -4.496 2100.0 2011.8 19.8 45.5 4.501 2200.0 2105.6 21.0 58.0 4.499 2300.0 2198.3 23.0 68.7 4.504 2400.0 2289.4 25.6 77.6 4.494 2464.9 2347.4 27.6 82.4 4.510 2474.6 2356.0 27.6 83.4 4.510 2490.4 2370.0 27.6 84.9 4.491 2500.0 2378.5 27.6 85.8 4.504 2600.0 2466.8 28.2 95.4 4.501 2700.0 2554.4 29.4 104.4 4.499 2714.9 2567.5 29.6 105.7 4.491 2800.0 2640.0 33.3 107.5 4.500 2900.0 2721.3 37.7 109.2 4.501 2954.8 2763.9 40.2 110.0 4.514 3000.0 2798.0 42.2 110.6 4.484 3100.0 2869.4 46.6 111.8 4.506 3164.9 2912.9 49.5 112.4 4.487 3200.0 2935.2 51.2 112.3 5.008 3300.0 2994.4 56.2 111.8 5.005 Page 3 3k-105 Cement v1 cfw;10-26-2012; LoadCase Intermediate la);Version wcs-cem472_05 r) fl..) 1 H I A 1 Client : CPAI Well : 3K-105 Schi mbergcr String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 3320.9 3005.9 57.2 111.7 4.996 3400.0 3046.4 61.2 111.4 4.992 3500.0 3090.7 66.2 111.0 5.002 3539.0 3105.9 68.1 110.8 5.012 3600.0 3127.1 71.2 110.6 4.994 3700.0 3155.3 76.1 110.3 5.000 3748.6 3165.9 78.6 110.1 5.011 3800.0 3176.1 78.6 110.1 0.000 3900.0 3195.9 78.6 110.1 0.000 4000.0 3215.7 78.6 110.1 0.000 4036.0 3222.9 78.6 110.1 0.000 4100.0 3235.6 78.6 110.1 0.000 4200.0 3255.4 78.6 110.1 0.000 4300.0 3275.2 78.6 110.1 0.000 4400.0 3295.0 78.6 110.1 0.000 4500.0 3314.8 78.6 110.1 0.000 4600.0 3334.6 78.6 110.1 0.000 4673.7 3349.2 78.6 110.1 0.000 4700.0 3354.5 78.4 108.9 -4.494 4800.0 3375.2 77.7 104.4 -4.499 4900.0 3396.9 77.2 99.8 -4.498 4928.5 3403.3 77.0 98.5 -4.516 5000.0 3419.4 77.0 98.5 0.000 5028.5 3425.8 77.0 98.5 0.000 5046.5 3429.8 77.4 97.7 5.005 5100.0 3441.0 78.5 95.2 4.994 5168.0 3453.7 80.0 92.1 4.997 5200.0 3459.3 80.0 92.1 0.000 5292.6 3475.4 80.0 92.1 0.000 5300.0 3476.7 80.0 92.1 0.000 5346.7 3484.8 80.0 92.1 0.000 5400.0 3494.1 80.0 92.1 0.000 5500.0 3511.5 80.0 92.1 0.000 5600.0 3528.9 80.0 92.1 0.000 5641.0 3536.1 80.0 92.1 0.000 5700.0 3544.9 82.8 91.2 5.002 5735.0 3548.8 84.4 90.6 5.006 5800.0 3553.3 87.6 89.6 5.004 5815.0 3553.9 88.3 89.4 4.891 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (Ib/gal) 5815.0 12.50 8.00 Sandstone Page 4 3k-105 Cement vi.cfw;10-26-2012; LeadCase Intermediate(a);Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumhergcr String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1800.0 1730.2 32 0.7 2474.0 2355.4 69 2.1 5815.0 3553.9 95 2.1 Page 5 3k-105 Cement v1.cfw;10-25-2012; oadCase Intermediate(a);Version wcs-cern472_05 Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :5795.0 ft Casing Shoe :5815.0 ft NB of Cent. Used :83 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 2495.0 0 0/0 0.0 2512.5 5815.0 83 1/1 1233695-9 5/8-8-36E(1/8") 21.2 2515.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 1233695-9 5/8-8-36E 9 5/8 13.626 10.374 No Houma 12.250 137.13 968.93 (1/8") 0/0 ft -, 0 2n 0 60 80 100 Betamen Cant. I I + -I At Cc-a. o ' 0 o—krI ' G- C tri _ ,. ... . C, O Pipe Standoff C Page 6 3k-105 Cement vi.cfw;10-26ORIG1NA -212; Load Intermediate(a);Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Section 3: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : BINGHAM P„ : 12.000 cP At temp. : 80 degF Ty :20.00 Ibf/100ft2 Gel Strength :21.00 lbf/100ft2 MUD Mud Type :WBM Water Type : Fresh MUDPUSH II DESIGN Fluid No:2 : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :3.51E-2 lbf.s^n/ft2 At temp. : 65 degF n :0.406 Ty : 16.35 lbf/100ft2 Gel Strength :29.67 Ibf/100ft2 Job volume :40.0 bbl Tail Slurry DESIGN 1 Fluid No:4 15.80 lb/gal Rheo. Model : BINGHAM Py :93.197 cP At temp. : 71 degF Ty : 13.30 Ibf/100ft2 Gel Strength : 16.33 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.100 gal/sk Job volume : 84.2 bbl Dry Density : 199.77 lb/ft3 Yield : 1.16 ft3/sk Quantity :405.86 sk Sack Weight : 94 lb Solid Fraction :41.4% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :5.100 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 0.300%BWOC Dispersant D167 0.350%BWOC Fluid loss S002 0.400%BWOC Accelerator Page 7 3k-t05 Cement v1.cfw;10-26-2012; LoadCase Intermediate(a);Version wcs-cem472_05 Client : CPAI Well : 3K-105 $chi hanger String : 133/8 District : Prudhoe Bay (l�l� {till U Country : USA Loadcase : Intermediate(a) Lead Slurry DESIGN Fluid No: 6 Density : 12.50 Ib/gal Rheo. Model : HERSCHEL_B. k : 9.51E-2Ibf.s^n/ft2 At temp. :80 degF n : 0.344 Ty : 6.76 lbf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 7.568 gal/sk Job volume : 194.7 bbl Dry Density : 199.77 lb/ft3 Yield :2.24 ft3/sk Quantity :487.79 sk Sack Weight : 94 lb Solid Fraction -- 54.9% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :7.468 gal/sk Additives Code Conc. Function D046 0.600%BWOC ANTIFOAM D167 0.200%BWOC fluid loss D185 0.060 gal/sk blend dispers. LT D186 0.040 gal/sk blend Accelerator CW100 DESIGN Fluid No: 7 Density 8.33 lb/gal Rheo. Model : NEWTONIAN At temp. : (degF) Viscosity : 5.000 cP Gel Strength : (Ibf/100ft2) Job volume Page 8 3k-105 Cement vi.ctw;10-26-2012; LoadCase Intermediate lal;Version wcs-cem472_05 ti 1 0 t � t Client : CPAI Well : 3K-105 Schlumberger String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Section 4: fluid sequence Original fluid Mud 9.50 lb/gal Pv: 12.000 cP Ty:20.00 Ibf/100ft2 Displacement Volume 434.9 bbl Total Volume 773.7 bbl TOC 2275.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) CW100 20.0 334.8 1270.6 8.33 viscosity:5.000 cP MUDPUSH II 40.0 669.6 1605.4 10.50 k:3.51E-2 lbf.s^n/ft2 n:0.406 Ty:16.35lbf/100ft2 3K-103 9.625in Pilot 194.7 2540.0 2275.0 12.50 k:9.51 E-2 Ibf.s^n/ft2 n:0.344 Ty:6.76 Ibf/100ft2 Red Wolf 2 Surface 84.2 1000.0 4815.0 15.80 Pv:93.197 cP Ty:13.30 Ibf/100ft2 Tail Field Blend Mud 434.9 0.0 9.50 Pv:12.000 cP Ty:20.00 Ibf/100ft2 Static Security Checks: Frac 295 psi at 5815.0 ft Pore 225 psi at 2474.0 ft Collapse 2379 psi at 5735.0 ft Burst 4901 psi at 1605.4 ft Csg.Pump out 52 ton Check Valve Diff Press 257 psi Page 9 3k-105 Cement v1 cfw;10-26-2012; loadCase Intermediate(a);Version wcs-cem472_05 I' Client : CPAI Well : 3K-105 3cMiller String : 133/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Section 5: pumping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) CW100 6.0 20.0 3.3 20.0 80 MUDPUSH II 6.0 40.0 6.7 40.0 80 Lead Slurry 6.0 194.7 32.5 194.7 80 Tail Slurry 5.0 84.2 16.8 84.2 80 Mud 6.0 420.0 70.0 420.0 80 Mud 3.0 14.9 5.0 434.9 80 Total 02:14 773.7 bbl hr:mn Dynamic Security Checks: Frac 99 psi at 5815.0 ft Pore 166 psi at 2474.0 ft Collapse 2218 psi at 747.9 ft Burst 4419 psi at 0.0 ft Temperature Results BHCT 88 degF Simulated Max HCT 80 degF Simulated BHCT 79 degF Max HCT Depth 4509.6 ft CT at TOC 79 degF Max HCT Time 02:14:14 hr:mn:sc Static temperatures: At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 1 59 degF Bottom Hole , (degF) (degF) 95 degF Page 10 3k-105 Cement v1.cfw;10-26-2012; LoadCase Intermediate(a);Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumberger String : 13 3/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) ft (x 1000)psi 0 2.5 Q– F-- i o Hydrostatic 0 —Calc.Ceml-P 1 —Mn.Hydrostatic —Calc.Furrp Reiss. - - Max.Dynanic - Mn.Dynamic p-O- - Frac _.__. Pore N a 0 L. l N f O 0 50 100 150 Time min k:' ( ) I �i o Depth= 5815 ft d_ 0 in I .0 O >L C O Q O u7LO 0 50 100 150 Fluid Sequence Dynamic Well Security Time(min) o Depth= 5815 ft -Ir Frac `— Fore CD —Hydrostatic Ii r). ..Dynamic I 2— to 1 2 0 a C� c a 0 25 50 75 100 125 150 Time(min) Fluids s at 5815 ft m Acquired Q O —Acquired Q In •E c0 ' Q Out i L 1. ifi rY o� 0 25 50 75 100 125 150 Time(min) Page 11 3k-105 Cement vi.cfw;10-25-2012; LoadCase Intermediate la);Version wcs-cem472_05 Client : CPAI Well : 3K-105 Schlumherger String : 13 3/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate la) Section 6: WELLCLEAN II Simulator ft % % o 0 25 50 75 100 0 25 50 75 100 Std Betw.Cent. —Mud Contamination —Cement Coverage —Uncontaminated Slurry O i ci — N O Oo_ o O p O In N-- Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall i. a 1 a 1 0 0 a a 1040-: 1040 1 000 1000 I 2000- -2000 2000 2000 Z.- z S 3000- -3000 S S 300x- 3006 5 AGOG— -,000 ,006- �~ ,boa soaa sada 5006- 1i LI saoa IIIL —I f- 6aoa -5000 6046-1 6000 r v ; r . 3 r a o a 50 a a Z S ® Mud I I High MIll Low Red Wolf 2 Surface Tail Field Blend 1i Medium 1 I None I i 3K-103 9.625in Pilot (—I MUDPUSH II MI CW100 Page 12 3k-105 Cement vi.cfw;10-26-2012; LoadCase Intermediate(a); n s-cem472_05 ORIGINAL Client : CPAI Well : 3K-105 Schlumberger String : 13 3/8 District : Prudhoe Bay Country : USA Loadcase : Intermediate(a) Tolerances - Spacer Max Rate is 6 BPM - Cement rate 4-5 BPM (remain within +/-0.2ppg Density Range, to be checked periodically with a mud balance) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - Max displacement Rate is 6 BPM, must slow to 3 BPM as indicated - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be conditioned prior to cementing - Maintain returns during cement job if possible Contingencies In the event that a problem occurs during mixing, pumping, or displacement, contingency plans should be systematically followed. If a shutdown occurs during the job, make note in the CemCAT report of when the stoppage occurred and how much time is available to remedy an issue before the thickening time becomes a problem. 1) If losses are encountered prior to cementing a) Utilize CemNET(1-2 Ib/bbl; 2 lb MAX) b) Slow rate until full circulation is regained c) Determine max rate with full circulation and pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at minimum rate b) Attempt to remedy issue in less than 30 mins c) If issue with mixing system—switch to back-up mixing system d) If issue with triplex pump—continue with secondary triplex on unit 3) Mud Pump failure during displacement a) Discuss rig up in the event of cement unit displacement in PJSM b) Attempt to continue displacement with secondary rig pump c) Attempt to remedy issue (downtime <10 mins) d) Note displacement volume pumped by mud pumps: verify with well site leader e) Subtract pumped volume from total volume, which will be the volume pumped by the cement unit f) Rig up hoses to get mud to Cement Unit and begin displacement with cement unit (verify volume with well site leader) 4) Data Acquisition System Failure a) Continue pumping b) The final volume will be based on the physical count of the mix water Page 13 3k-105 Cement vi.cfw;10-26-2012; LoadCase Intermediate lal;Version wcs-cem472_05 - f • 1 A 1111 IIII „„ „„ 1111 1111 (IIII 'Z' 1111 1111 iF �m>Q � PU IIII CO b, 1111 11111E (D •N \ N e �2¢ VIII N F Q 0 v 11111 11111 VIII 2 C 2 o` m 11111 11111 N 111111 To 2 (0 m 1111111 17-' 11111 �' N O J ti (IIII E" (IIII w11111 CO -1 Q C CO A o 11111 11111 CO 17: 11111C a VIII ` J m Y o v Il IIII LL N U > d U N v III I y � o m m a �, 11111 u11 c ,e ?? i o —, 0- Emil [int d -0 J L O N C U C-.:'' I I I I I I I UM 0 1111 rn � co N k VIII c VII I N pL N W a VIII U 111 111 1 1N > c C c. /n > o /n J J Dmil Occ ccc7 VIII " imIIIId — .5 rt CLOdQ1:CdCC III I VIII 1111 a .- N M v to Ci OD 11111 7 I111H um U unlVo n n n a a a n m 11111 m 11111 F- 1` H 1. i- H H nut IIII i 11111 int Cl 11111 1111 o o lull T 11111 11111 to S 11111 --1 1 111 1 m I11111 8 ::: r a Inn1 _ VIII '11111 11111 N 11111 11111 II v1111 > , E ,n v 11111 TO 11111 liii E 11111 c T '- 5 1111 .0 1111 0 • 1111 C 'I I I Cl III I III IIII pII IIII ON d v 4 ;a m� siiii m owl u n 'Hui h p n s $ a 3---i 1 ° m At "'So �' i i K a Qo ,g0 i 1 o of N I • �` N of vii 3 F • I c!i cv N O 141 • o t a $ a b i c ❑ a ELI 6.0 0a 0 C7 U i 1 0. '`� / c0 N o Q OP%.0 '0 if\`Y Q S N @l 0F" q llO N vi ON V T T a. a tp Ii! q>E' es Q co N. o O ♦+ M d , _n .a, o as a a 3Q o of- ' Q E" �e O e 'o�.rn + N k O N 0 . Bo n a X F c:, F� l� 3 N V N 1V lh In y aN, y V UN y-- COnoco 11illiS West Sak Producer Well 3K-105 3K-IOS Plan Schematic WP-12.vsd Draft Schematic 10/29/2012 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 Davies, Stephen F (DOA) From: Myers, Monty M [Monty.M.Myers@conocophillips.com] Sent: Thursday, November 08, 2012 2:08 PM To: Davies, Stephen F (DOA) Subject: RE: KRU 3K-105 Permit to Drill Application Question yes there has been. 3K-102 had 155 ppm measured on December 15 2011 I'm not sure of any other but I can try to track it down if needed. Thanks! Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell From: Davies, Stephen F (DOA) [ma ilto:steve.davies@alaska.gov] Sent: Thursday, November 08, 2012 11:44 AM To: Myers, Monty M Subject: [EXTERNAL]KRU 3K-105 Permit to Drill Application Question Monty, I'm a geologist with the AOGCC, and I'm reviewing the permit to drill application for 3K-105. Has any H2S been measured in any of the West Sak wells on 3K-Pad? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME l 1 1/( -16K- /Os PTD# t/Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: POOL: 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___ (If last two digits in Permit No. ,API No. 50- API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 L C. N " ; : ; ; ; h 3 0 , , �, , g ' , ' . • Q a• ` o U C co 0 w (/) v, , , , , ; Z' ; E E' CD E OC' A' CO, CO N 0 0' o' C. oi' to r. ' ' a a o o. 0' 3. moo' m d ,�. - r, v) up a)' a), c. 3' a' ' bo' M' ' 3. �' c o E0.. 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