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206-151
TEOF ALASKA OS WSAK 1J-180L1 AAKA OIL AND GAS CONSERVATION COMIGN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 1 Plug Perforations I.... Fracture Stimulate F Pull Tubing FOperations Shutdown Performed: Suspend I" Perforate IT Other Stimulate I i.f Alter Casing IT Change Approved Program IT Plug for Redrill Perforate New Pool . Repair Well V.. I .... Re-enter Susp Well IT FT 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory f.... 206-151 3.Address: 6.API Number: Stratigraphic Service F P. O. Box 100360,Anchorage,Alaska 99510 50-029-23329-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25663,385172 KRU 1J-180L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17779 feet Plugs(measured) None true vertical 3252 feet Junk(measured) None Effective Depth measured 17749 feet Packer(measured) 0 true vertical 3252 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120 120 0 0 SURFACE 3963 13.375 4001 2226 0 0 INTERMEDIATE 10804 9.625 10843 3377 0 0 D-SAND LINER 7496 4.5 17750 3252 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: slots from 10324-117710 ;,;.., ~ True Vertical Depth: 3320-3252 i..��A DEC 0 1 2015 Tubing(size,grade,MD,and TVD) Tubing in main wellbore SCANNEDAPP ( R 701 6 AoGcn Packers&SSSV(type,MD,and TVD) ZXP Liner Top Packer 9989=MD, 3290=TVD, HRD ZXP Liner Top Packer 10168=MD, 3314=TVD SSSV: Nipple Camco DB 6 514=MD, TVD=512 12.Stimulation or cement squeeze summary: Intervals treated(measured): none 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 Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory P Development I....... Service I: Stratigraphic Copies of Logs and Surveys Run IT 16.Well Status after work: Oil P Gas — WDSPL P Printed and Electronic Fracture Stimulation Data € GSTOR I....... WINJ I✓ WAG I— GINJ P SUSP I— 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: 315-621 Contact Danny Kane@265-6048 Email Danny.Kane(a conocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer SignaturePhone:265-6048 Date 0f—PEG—Z S vn 51ig-0RBDMS�L. U2 2015 4,,,/74Form 10-404 Revised 5/2014,,,/74Submit Original Only , , KUP � � 1J-1801_1 ConocoPhi lips Well Attribut Max Angle D TD Alaska.IncWellbore API/UWI Field Name Wellbore Status ncl I°) MD(ftKB) Act Btm(ftKB) r Conocophdh9s`''- 500292332960 WEST SAK INJ 0.00 17,779.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Laterals-13-180L1,1211/2015 11:27.06 AM SSSV:NIPPLE Last WO: 43.51 2/27/2007 Vertical schematic laotuah..... 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,36.0 1yt Last Tag: Rev Reason:WORKOVER,GLV CIO,removed lehallf 11/13/2015 - ISO Sleeve Casing Strings .......................nu.u....,uA4At4 wui Casing Description OD(in) ID(In) Top(kKB( Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread D-SAND LINER Liner Details 41/2 3476 10254.7 17,750.3 3,252.2 11.60 L80 BTC - I 31.3 CONDUCTOR, .7 Nominal ID NIPPLE;522 Top(ftKB) Top(TVD)(ftKB) Top Indy) Item Des Com (in) 10,254.7 3,317.8 87.35 SLEEVE 5 1/2"Baker"HR"Liner Setting Sleeve(6.41"0.0.x 5.750 GAS LIFT;2,309.4 5.75"I.D.) 10,319.5 3,319.7 89.08 XO Reducing 5 1/2"Hydril 521 Pin X 4 1/2"BTC Pin X/O(3.96" 3.960 tI.D.) SURFACE;37.7-4,000.6 17,712.0 3,252.3 90.35 XO 3-1/2",9.3 ppf,L-80,IBT Box X EUE 8rd Pin X/O 2.992 SLEEVE;9,943.2 - 9110 PUP LOCATOR;9,991 4— JCC Perforations&Slots SEAL ASSY;9,992.4 - Shot Dens Top(TVD) Btm(TVD) (shots) Top(ftKB) Dtm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com D LINER HH;10,048.5-10,312.5 10,324.0 10,578.0 3,319.7 3,319.2 WS D,1J- 2/17/2007 32.0 SLOTS ALL PERFS IN D LINER LEM,9,988.9-10,212.1 INTERMEDIATE;40.6-10,844.5 180L1 WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers j staggered 18 deg,3'non — — -slotted ends SLOTS;10,324.0-10,578.0 _ 10,871.0 11,370.0 3,329.1 3,321.9 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 11,669.0 1 12,183.0 3,318.9 3,306.8 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 SLOTS;10,871.0-11,370.0—._, 12,476.0 12,989.0 3,300.8 3,292.0 WS D,1J- 2/17/2007 32.0 SLOTS 1801_1 13,287.0 13,795.0 3,286.7 3,277.5 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 14,047.0. 14,599.0 3,276.6 3,265.3 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 SLOTS;11,669.0-12,183.0 _ 14,848.0 15,405.0 3,259.3 3,262.5 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 15,661.0 16,173.0 3,264.0 3,264.8 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 16,472.0 16,986.0 3,262.0 3,258.3 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 17,282.0 17,710.0 3,255.2 3,252.3 WS D,1J- 2/17/2007 32.0 SLOTS SLOTS;12,476.0-12,999.0 180L1 Notes:General&Safety End Date Annotation 3/2/2007 NOTE:MULTI-LATERAL WELL-1J-180(B-SAND),1J-180L1(D-SAND) SLOTS;13,287.0-13,785.0 SLOTS;14,047.014,599.0 SLOTS;14,848.0-15,405.0 SLOTS;15,681.018,173.0 SLOTS;16,472.S-16,988.0�_. SLOTS;17,2822.0-17,710.0 DSAND LINER;10,254.7- 17,750.3. • • DelHint Daily Operations Summary (with Depth Cost MW) 1J-180 Conocc. hiHips Rig: NABORS 9ES Job: RECOMPLETION Dens Last Depth Progress Mud Field Est Mud Start Date End Date Last 24hr Sum End Depth(ftKB) (ft) Daily Cost Total(Cost) Cum Cost(Cost) (Cost) Cum Mud Cost(Cost) (lblgal) 10/19/2015 10/20/2015 Pull Pit module away 0.0 442,424.84 442,424.84 from sub and transport to 1J pad. Lay derrick over and prep sub in preparation for Pad to Pad move. Road rig off 1D pad onto spine for 1/10th of a mile then right hand turn onto 1J Access road. Travel down 1J access towards 1J Pad. 10/20/2015 10/21/2015 Continue to move rig 0.0 233,049.94 675,474.78 58,031.78 58,031.78 9.90 to location,Spot, MIRU and Berm up. Accept rig Nabors 9ES at 15:00 hrs. Kill well, 10/21/2015 10/22/2015 Continue to kill well 0.0 132,913.61 808,388.39 28,320.56 86,352.34 9.90 and monitor for flow. Shoot fluid level-1st shot=50-ft,2nd Shot=60-ft. Set BPV. ND Tree. 10/22/2015 10/23/2015 ND SSV and install 0.0 127,668.72 936,057.11 29,744.17 116,096.51 9.90 1502 integral on Production wing valve. NU BOP and Test,24 hr Notice was given @ 07:09 hrs on 10-19-15 and Witnessed by Lou Grimaldi. Pull blanking plug and BPV. Pull seals from SBR @ 10,012-ft. POOH to 8,945-ft and PU storm packer and set at 118-ft. Test to 500 psi for barrier test. 10/23/2015 10/24/2015 Pull mouse hole, 0.0 99,785.71 1,035,842.82 2,078.31 118,174.82 9.84 Riser and ND BOP. ND and Pull Well head and swap out do to bad lock down pins. NU and Shell test break. Recover storm packer and continue to POOH from 8,945-ft to 4,081-ft 64K Up wt, 53K Dn wt. Page 1/2 Report Printed: 11/30/2015 • • r Driller Daily Operations Summary (with Depth Cost MW) 0 s;l �il &Wells 1J-180 Conoccehitlips Rig: NABORS 9ES Job: RECOMPLETION Dens Last Depth Progress Mud Field Est Mud Start Date End Date Last 24hr Sum End Depth(ftKB) (ft) Daily Cost Total(Cost) Cum Cost(Cost) (Cost) Cum Mud Cost(Cost) (Ib/gal) 10/24/2015 10/25/2015 Contninue to POOH 0.0 98,908.36 1,134,751.18 2,078.31 120,253.13 9.80 laying down 4-1/2 De completion from 4,081-ft to seal assembly. Load pipe shed with remaining 124 jts and Completion components. RIH as per Run order to 4,334-ft 65K Up wt, 54K Dn wt and AVE MU torque=3,800 ft/lbs 10/25/2015 10/26/2015 Continue to RIH as 0.0 125,951.55 1,260,702.73 7,117.02 127,370.15 9.90 per Run order from 4,334-ft 65K Up wt, 54K Dn wt and AVE MU torque=3,800 ft/lbs. to 10,014-ft and locate SBE and No-Go. Space out, MU TBG hanger and load IA with CI 9.9 ppg Brine to 10,014- ft. Land hanger, RILDS and PT IA to 2,500 psi for 30 minutes. Bleed off and ramp up to 3,500 psi and shear out SOV @ 2,297-ft±. Conduct BWM. 10/26/2015 10/26/2015 ND BOPE and NU 0.0 135,928.08 1,396,630.81 251.52 127,621.67 9.90 Tree. FP to 2,300-ft ± RDMO. Release Nabors 9ES @ 12:00 hrs on 10-26-15 Page 2/2 Report Printed: 11/30/2015 • • Operations Summary (with Timelog Depths) &Wells 1J-180 Conocohitllps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/19/2015 10/19/2015 10.00 MIRU MOVE RURD P Bridle up and lower bridle lines. Tie 10:00 20:00 back service loop in derrick. Remove pins from blocks and pin bridle lines to blocks.Raise blocks with bridle lines. Remove torque tube pins,lower upper and lower cattle chute. Inspect derrick. Remove A leg pins and lower mast. Secure lines in derrick for transport. PJSM with Peak driver and pusher. Pull pits away from Sub. Install jeep and transport pits to 1J Pad and stage. Pull rig off of well 1 D- 123. Clean and clear area in preparation of environmental handover. 10/19/2015 10/20/2015 4.00 MIRU MOVE MOB P Road rig off 1D pad onto spine for 20:00 00:00 1/10th of a mile then right hand turn onto 1J Access road. Travel down 1J access towards 1J Pad. 10/20/2015 10/20/2015 1.00 MIRU MOVE MOB P Road rig down 1J access to 1J Pad. 00:00 01:00 10/20/2015 10/20/2015 0.50 MIRU MOVE MOB P Set mats around cellar and lay out 30 01:00 01:30 x 30 pit liner. 10/20/2015 10/20/2015 2.50 MIRU MOVE MOB P Pull rig over well,sit down. 01:30 04:00 Sim ops-Set kill tanks 10/20/2015 10/20/2015 1.50 MIRU MOVE MOB P PJSM with Truck driver,Spot pit 04:00 05:30 module. Sim ops-Continue to set kill tanks 10/20/2015 10/20/2015 2.50 MIRU MOVE RURD P Berm up,raise derrick and set cattle 05:30 08:00 chute. Set choke house and lay kill lines from well to kill tank. Set and berm LEPD Fuel tank. Load pits with 9.9 ppg 3%KCL/NaCI brine w/.06% by volume safe lube. PT kill lines to 250/3,500 psi. 10/20/2015 10/20/2015 9.00 MIRU MOVE RURD P Raise derrick and set cattle chute. 08:00 17:00 Dr-1g toolhouse Sim ops-Set choke house and lay kill lines from well to kill tank. RU inter-connect Set and berm LEPD Fuel tank. Load pits with 9.9 ppg 3%KCL/NaCI brine w/.06%by volume safe lube. 10/20/2015 10/20/2015 0.50 MIRU MOVE SFTY P Accept Nabors 9ES @ 15:00 hrs and 17:00 17:30 hold Pre spud with Night crew for 1J- 180, 10/20/2015 10/20/2015 2.25 MIRU WELCTL MPSP P Open well,PU, RU and PT lubricator 17:30 19:45 to 1,000 psi. Pull BPV with lubricator. RD Lubricator. Obtain pressures- SITP= 400,SICP=380,SIOCP= 10/20/2015 10/20/2015 1.25 MIRU WELCTL RURD P RU and PT kill lines to 250/3,500 psi. 19:45 21:00 10/20/2015 10/21/2015 3.00 MIRU WELCTL KLWL P PJSM,Bleed TBG Psi from 400 psi to 21:00 00:00 260 psi through choke house to kill tank#1. 101 bbls of diesel total- SIP's=260 psi 10/21/2015 10/21/2015 1.25 MIRU WELCTL OWFF P Shut well in and monitor pressures. 0.0 0.0 00:00 01:15 Disconnect lines. SITP=260 psi. SICP=260 psi Page 1/7 Report Printed: 3/15/2016 • • Drilling Operations Summary (with Timelog Depths) &Wens 1J-180 Cortoa:1 hitlips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKB) 10/21/2015 10/21/2015 0.25 MIRU WELCTL SFTY P Pre-job meeting with crew and truck 0.0 0.0 01:15 01:30 drivers 10/21/2015 10/21/2015 0.25 MIRU WELCTL SEQP P Pressure test lines and surface 0.0 0.0 01:30 01:45 equipmet to 3500 psi. Blow down lines 10/21/2015 10/21/2015 3.25 MIRU WELCTL KLWL P Reverse circulate to kill well. Pump 0.0 0.0 01:45 05:00 down IA taking returns to tiger tanks. Initial volume in tank= 101 bbl. Initial rate 5 bpm @ 780 psi. Final rate 4 bpm @ 171 gpm. Final fluid weight= 9.7+ppg. Pumped a total of 1004 bbl. Final tank volume=702 bbl. SIDP= 38 psi,SICP=65 psi 10/21/2015 10/21/2015 0.25 MIRU WELCTL RURD P Blow down lines 0.0 0.0 05:00 05:15 10/21/2015 10/21/2015 1.25 MIRU WELCTL OWFF P Monitor well while waiting for brine. 0.0 0.0 05:15 06:30 SICP=65 psi, SITP=38 psi 10/21/2015 10/21/2015 0.50 MIRU WELCTL OWFF P Open IA to Tiger Tank while taking 0.0 0.0 06:30 07:00 straps and pressure readings every 5 mionute4s. SWI. SITP=2;SICP= 110;SIOCP=8. Recovered 32 bbls of 9.9 ppg brine while bleeding off pressure for 30 minutes. 10/21/2015 10/21/2015 ' 8.00 MIRU WELCTL WAIT T Monitor well pressures while waiting 0.0 0.0 07:00 15:00 for KWF to arrive from Dead horse. Starting SIPs= 10 PSI TBG, 130 PSI IA and 8 PSI OA. Ending SIP's=24 PSI TBG, 150 PSI IA and 16 PSI OA. after 8 hrs. Sim-ops- Continue to load,drift to 3.90"and rack and tally 4-1/2, 12.6#, L -80 IBTM R2 Tubing in the pipe shed. 10/21/2015 10/21/2015 1.50 MIRU WELCTL KLWL T PJSM,RU to take returns to the kill 0.0 0.0 15:00 16:30 tank. PT lines at 250/3,500 psi- good test. Pumped 150 bbls at 4 bpm at 260 psi ICP and 310 FCP. Recovered 109 bbls at the kill tank. 10/21/2015 10/21/2015 0.50 MIRU WELCTL RURD T RU to take returns from the tree to the 0.0 0.0 16:30 17:00 mud pits. Fill up pits in preparation for circulating. Monitor well. IA psi=0 and tbg psi=0. 10/21/2015 10/21/2015 4.00 MIRU WELCTL KLWL T PJSM,circulate 903 bbls of 9.9 ppg 0.0 0.0 17:00 21:00 Brine @ 4 bpm @ 280 psi w/65 BPH Fluid losses. 10/21/2015 10/21/2015 0.50 MIRU WELCTL OWFF T Monitor well for flow- well on vac. 0.0 0.0 21:00 21:30 Call out DHD for FL shot. 10/21/2015 10/21/2015 0.50 MIRU WELCTL KLWL T Shoot fluid level-1st shot 21:30 hrs= 0.0 0.0 21:30 22:00 50-ft,2nd shot @ 22:00 hrs=60-ft. 10/21/2015 10/21/2015 1.25 MIRU WELCTL RURD P PJSM,RD circulating equipment in the 0.0 0.0 22:00 23:15 cellar. 10/21/2015 10/21/2015 0.25 MIRU WHDBOP MPSP P Dry rod in BPV 0.0 0.0 23:15 23:30 10/21/2015 10/22/2015 0.50 MIRU WHDBOP NUND P PJSM, ND Tree 0.0 0.0 23:30 00:00 10/22/2015 10/22/2015 2.50 MIRU WHDBOP NUND P PJSM, Remove Surface safety valve 0.0 0.0 00:00 02:30 from production wing and install 1502 Integral adapter. ND tree,pull tree with traveling blocks. Remove the tree and hang back. Page 2/7 Report Printed: 3/15/2016 • S Operations Summary (with Timelog Depths) &Welts 1J-180 Conocc>Phitlips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 0.50 MIRU WHDBOP OTHR P Inspect lock downs for failure during 0.0 0.0 02:30 03:00 function testing Pre-rig. Install Blanking plug and gather measurements for clearance during ram closure. 10/22/2015 10/22/2015 2.50 MIRU WHDBOP NUND P NU 13-5/8 5M BOPE onto 13-5/8 5M 0.0 0.0 03:00 05:30 well head flange. 10/22/2015 10/22/2015 0.50 MIRU WHDBOP RURD P PJSM, RU testing equipment. PU test 0.0 0.0 05:30 06:00 joint, MU 4"Dart valve and 4:HT FOSV, MU X-O's on 4-1/2 EUE 8rd FOSV, line up on choke,post signs and fill BOP stack- look for leaks- Good Purge manifold and hoses. it Page 3/7 Report Printed: 3/15/2016 • S Drilling Operations Summary (with Timelog Depths) &Wells 1J-180 ocoPhi[iips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 8.75 MIRU WHDBOP BOPE P Conduct Initial BOP test @ 250/ 0.0 0.0 06:00 14:45 3,500 psi with 4"and 4-1/2 test joints. 24 hr notice was given @ 7:09 hrs on 10-19-15. Test was witnessed by Lou Grimaldi. Test#1 Blinds,choke valves 1,2,3,16 and Demco kill,Upper IBOP,Mud manifold Test#2 Choke Valves 4,5,6. HCR Kill,Lower IBOP Test#3 Choke Valves 7,8,9. Manual Kill,4- 1/2 TIW Test#4 Manual and Hydraulic Choke, HCR Kill. Test#5 Choke Valves 10&11 Test#6 Choke Valves 12,13,14. Install 4"test joint and close LPR's. Test#7 Choke Valves 15. Annular,dart and HCR Kill. Test to 3,500 psi in order to make valves used in test count. Test#8 TIW,Top Rams and HCR Choke. Test#9 Manual Choke Test#10 TIW Valve, Install 4-1/2"test joint and close LPR's. Koomey test Koomey Pressure=2,975 psi. After Function=1,600 psi. 200 psi gain=31 seconds Full pressure=154 seconds 6 Bottles @ 2,054 psi Test#11 LPR's TIW,HCR Choke and Kill and change test hose to Choke Test#12 Annular,TIW,Outer test spool and HCR Kill. Test#13 UPR's TIW and Inner test spool and HCR Kill. Blow down all test equipment and pull blanking plug 10/22/2015 10/22/2015 0.25 MIRU WHDBOP MPSP P Dry rod out BPV-Well on a vacuum 0.0 0.0 14:45 15:00 10/22/2015 10/22/2015 1.50 COMPZN RPCOMP RURD P PJSM, RU Weatherford Running 0.0 0.0 15:00 16:30 services tongs and equipment. 10/22/2015 10/22/2015 1.00 COMPZN RPCOMP PULL P PU,MU and un land TBG hanger at 0.0 0.0 16:30 17:30 196K Page 4/7 Report Printed: 3/15/2016 • • Dai lliit g Operations Summary (with Timelog Depths) &Wells 1J-180 Conoco 'hill ps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 3.00 COMPZN RPCOMP PULL P Pull hanger to rig floor and break out, 10,014.0 8,945.0 17:30 20:30 crimped pup jt under hanger-prep for shipping. Continue to POOH with 4- 1/2, 12.6#, IBTM Tubing from 10,014- ft to 8,945-ft 96K Up wt,53K Dn wt. 10/22/2015 10/22/2015 2.50 COMPZN RPCOMP MPSP X PU, MU and RIH 118-ft w/9-5/8 40# 8,945.0 9,063.0 20:30 23:00 Baker Storm packer and set with TBG tail @ 9,063-ft. Release from storm packer and POOH w/setting tool.84 Up wt,56K Dn wt. 10/22/2015 10/23/2015 1.00 COMPZN RPCOMP MPSP X Pjsm, PT against storm packer to 500 118.0 118.0 23:00 00:00 psi for 15 minutes-Good Test. 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP OWFF X Monitor well for flow-No flow 118.0 118.0 00:00 00:30 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP OWFF X Drain stack thru the IA valve,and blow 118.0 118.0 00:30 01:00 down lines. Open OA to cuttings box- bleed 16 psi 10/23/2015 10/23/2015 2.00 COMPZN RPCOMP NUND X ND BOPE and rack back 118.0 118.0 01:00 03:00 10/23/2015 10/23/2015 2.50 COMPZN RPCOMP NUND X ND Vetco Gray West Sak MB 222A 03:00 05:30 Big Bore Injector well head. Remove Horizontal 4-1/16 5M Production and IA valves.Prep wellhead -remove studs while bleeding OA to cuttings box. 10/23/2015 10/23/2015 0.25 COMPZN RPCOMP SFTY X PJSM with all on removal and 05:30 05:45 replacement of well head with assistance of Boom truck,Loader with stinger and Bridge crane in cellar. 10/23/2015 10/23/2015 1.75 COMPZN RPCOMP NUND X Prep area for well head recovery and 05:45 07:30 pull well head off starting head. Load Replacement head in cellar with loader assistance. 10/23/2015 10/23/2015 1.75 COMPZN RPCOMP NUND X Install and NU Replacement well head 07:30 09:15 and side port valves. PT Starting head pack off @ 2,400 psi for 10 minutes. 10/23/2015 10/23/2015 2.75 COMPZN RPCOMP NUND X NU BOPE. Install riser,mouse hole 09:15 12:00 and turn buckles.Set test plug and fill stack. 10/23/2015 10/23/2015 1.50 COMPZN RPCOMP BOPE X Shell test BOP flange/Well head 12:00 13:30 break @ 250/3,500 psi. Passed. RD Bop test equipment and clean and clear floor of testing equipment. 10/23/2015 10/23/2015 2.00 COMPZN RPCOMP MPSP X PU 3 jts of DP and retrieving tool. 13:30 15:30 RIH, locate and engage Storm packer. Check for pressure below packer- None. Release storm packer and POOH. Lay Down the same. 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP RURD X Change over elevators and floor 15:30 16:00 equipment for POOH and laying 4-1/2 IBTM tubing. Page 5/7 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) { &wells 1J-180 Con000Phillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/23/2015 10/24/2015 8.00 COMPZN RPCOMP PULL P Continue to POOH,laying down 4-1/2 8,945.0 4,081.0 16:00 00:00 12.6#,L-80 IBT-M Tubing from 8,945- ft 88K Up wt,55K Dn wt. to 4,081-ft 64K Up wt,53K Dn wt. Found hole in jt 157 @ 4,882-ft and jt# 178 had corroded threads 10/24/2015 10/24/2015 7.50 COMPZN RPCOMP PULL P Continue to POOH,laying down 4-1/2 4,081.0 0.0 00:00 07:30 12.6#,L-80 IBT-M Tubing from 4,882- ft 64K Up wt,53K Dn wt. to seal assembly 10/24/2015 10/24/2015 0.50 COMPZN RPCOMP SVRG P Service draw works and equipment 0.0 0.0 07:30 08:00 10/24/2015 10/24/2015 8.00 COMPZN RPCOMP OTHR P Load,drift,rack and Tally 124 joints of 0.0 0.0 08:00 16:00 4-1/2, 12.6#,L-80 IBTM R2 Tubing for Total of 350 joints. Load completion equipment and double measurements and placement. 10/24/2015 10/24/2015 0.50 COMPZN RPCOMP SFTY P Held PJSM with all involved in the 0.0 0.0 16:00 16:30 running of the 4-1/2 recompletion string to 10,014-ft. 10/24/2015 10/25/2015 7.50 COMPZN RPCOMP PUTB P PU,MU and RIH w/4-1/2 Completion 0.0 4,334.0 16:30 00:00 string as per run order to 4,334-ft 65K Up wt,54K Dn wt.and AVE MU torque=3,800 ft/lbs 10/25/2015 10/25/2015 9.25 COMPZN RPCOMP PUTB P Continue to PU,MU and RIH w/4-1/2 4,334.0 10,010.0 00:00 09:15 Completion string as per run order from 4,334-ft 65K Up wt,54K Dn wt. and AVE MU torque=3,800 ft/lbs to 10,014-ft and No-Go.Space out 4-ft afetr break over, mark pipe and lay down 3 joints add 2 pups= 15.52-ft (9.85+5.67)and 346 joints @ 28.48- ft long average. 10/25/2015 10/25/2015 6.25 COMPZN RPCOMP CRIH P With mule shoe @ 9,985-ft. Pumped 9,985.0 9,985.0 09:15 15:30 562 bbls of CI 9.9 ppg 3%KCL/NaCI @ 3 bpm @ 290 psi. Blow down lines and drain BOPE stack 10/25/2015 10/25/2015 1.00 COMPZN RPCOMP THGR P Land TBG hanger and RILDS. 9,985.0 10,010.0 15:30 16:30 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP THGR P Test upper and lower hanger seals @ 0.0 0.0 16:30 17:00 250/5,000 psi as per Vetco Gray. 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP RURD P RD cement hose,head pin,and 0.0 0.0 17:00 17:30 landing joint. 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP SFTY P PJSM with all involved for PT IA @ 0.0 0.0 17:30 18:00 2,500 psi shearing of the SOV. 10/25/2015 10/25/2015 1.50 COMPZN RPCOMP PRTS P Purge lines,fill hole and PT lines to 0.0 0.0 18:00 19:30 2,500 psi and chart for 30 minutes. Bleed IA and TBG to 0 psi. Pressure IA to 3,900 psi to shear SOV-No shear. Bleed pressure off,pressure back up and seen shear @ 3,650 psi. Reverse circulate @ 2 bpm @ 400 psi thru valve. Switch over and circulate @ 2 bpm @ 170 psi to verify shear out. 10/25/2015 10/25/2015 0.25 COMPZN RPCOMP OWFF P Monitor well for flow for 15 minutes. 0.0 0.0 19:30 19:45 No flow. 10/25/2015 10/25/2015 0.25 COMPZN WHDBOP MPSP P Install 3"BPV as per Vetco Gray 0.0 0.0 19:45 20:00 Page 6/7 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) &Weft 1J-180 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/25/2015 10/25/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 20:00 21:00 Pull riser and BWM on Annular preventer with 4"test joint. Function annular-annular element in good condition with no defects. Observed, no key seating noted at this time. 10/25/2015 10/25/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 21:00 22:00 Break bolts,open upper ram doors. Inspect 2-7/8 x 5"VBR rams. Close doors and install studs 10/25/2015 10/25/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 22:00 23:00 Break bolts,open upper ram doors. Inspect Blind rams. Close doors and install studs 10/25/2015 10/26/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 23:00 00:00 Break bolts,open lower ram doors. Inspect 2-7/8 x 5"VBR rams. Close doors and install studs 10/26/2015 10/26/2015 1.50 COMPZN WHDBOP NUND P Pull riser,disconnect turn buckles,pull 0.0 0.0 00:00 01:30 mouse hole. ND and set 13-5/8 5M BOP Stack. 10/26/2015 10/26/2015 1.50 COMPZN WHDBOP NUND P PU and land 13-5/8 5M Adapter and 0.0 0.0 01:30 03:00 Vetco Gray Horizontal Tree. NU same. 10/26/2015 10/26/2015 1.00 COMPZN WHDBOP MPSP P Pull BPV and Install TWC for testing of 0.0 0.0 03:00 04:00 the tree flanges. 10/26/2015 10/26/2015 2.00 COMPZN WHDBOP PRTS P Pressure test tree flanges-Good test. 0.0 0.0 04:00 06:00 Test hanger adapter seals @ 250/ 5,000 psi-All good tests. 10/26/2015 10/26/2015 0.50 COMPZN WHDBOP MPSP P Pull TWC with dry rod 0.0 0.0 06:00 06:30 10/26/2015 10/26/2015 3.75 COMPZN WHDBOP FRZP P RU Little Red Services, PT Lines at 0.0 0.0 06:30 10:15 2,000 psi. Pump 120 bbls into the!A attempting to take returns from the tubing. Recovered 77 bbls. Shut in tubing and bullhead 55 bbls due to volume to circ point and difference between 6.5 ppg diesel and 9.9 ppg Brine. Close well in. RD LRS. RU to Allow the TBG to swap with the IA. Allow 15 minutes for well swap. Ending pressure was= 100 psi 10/26/2015 10/26/2015 1.00 COMPZN WHDBOP MPSP P PU lubricator and lubricate in the BPV 0.0 0.0 10:15 11:15 10/26/2015 10/26/2015 0.75 DEMOB MOVE RURD P RD berming around LEPD tank,tail 0.0 0.0 11:15 12:00 roll out LEPD tank.Clean and dress the tree. SIP's=TBG-100 psi, IA- 100 psi and OA-0 psi. Finish removing berming from around the rig. Pull off well. Release Nabors 9ES @ 12:00 hrs on 10-26-15 Page 7/7 Report Printed: 3/15/2016 tioF THE STATE Alaska Oil and Gas 4° s of Conservation CommissionLAsKAL 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALA6�� �� Fax: 907.276.7542 op O Q -�`� www.aogcc.alaska.gov Danny Kane Sr. Wells Engineer 6;1 Jr' 1 ConocoPhillips Alaska, Inc. I I P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-180L1 Sundry Number: 315-621 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this 9y of October,2015 Encl. JG RBDMS OCT - 9 2015 • STATE OF ALASKA III AKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon P Pug Perforations 1 Fracture Stimulate I Pull Tubing )✓ Operations Shutdown "" Suspend P Perforate 1.— Other Stimulate r Alter Casing P Change Approved Program r Rug for Redrill I— Perforate New Pool P Repair Well I ' Re-enter Susp Well P Other: (- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory (- Development (— 206-151 • 3.Address: 6.API Number: Stratigraphic )` Service ri P. O. Box 100360,Anchorage,Alaska 99510 50-029-23329-60 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes P No IV ✓ KRU 1J-180L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25663,385172 • Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 17779 • 3252 • 17749' . 3252' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120' 120' SURFACE 3963 13.375 4001' 2226' INTERMEDIATE 10804 9.625 10843' 3377' D-SAND LINER 7496 4.5 17750' 3252' v:. i t L z.0 is: t-r5 1011I15 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slots from 10324-17710 , 3320-3252 tubing in main wellbore Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=9989 TVD=3290 ' PACKER-HRD ZXP LINER TOP PACKER MD=10168 TVD=3314 NIPPLE-4.5"Camco DB-6 Nipple w/3.875"No-Go Profile MD=514 TVD=512 12.Attachments: Description Surrtrttary of Proposal ., 13. Well Class after proposed work: Detailed Operations Program BOP Sketch p Exploratory P Stratigraphic p. Development }Service l 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/19/2015 OIL r WINJ J- WDSPL P. Suspended 1-- 16.Verbal Approval: Date: GAS r WAG l--4 GSTOR P SPLUG 1- Commission Commission Representative: GINJ p Op Shutdown P Abandoned I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email: Danny.KaneOconocophillips.com Printed Name Danny Kane Title: Sr. Wells Engineer Signature Phone:265-6048 Date QRZ.—oc_T'—ZifpS Commission Use Only Sundry Number:Nu Conditions of approval: Notify Commission so that a representative may witness 71 E-( o 2-\ Plug Integrity 1 BOP Test ( Mechanical Integrity Test Location w Clearance r Other 56P ft5t �,�vo r5� �'A4ps- l� ,s � \ /45-4 p } ) y¢nr) 1a C- re -r�i-r.' > /1v ZSoaPS� __l wiz' � v z55.rd AA r,T-1 4 e- L i✓rd�.F1—e✓ S it d i k r ciz� Spacing Exception Required? Yes ❑ No Ir Subsequent Form Required: /0 -4O4 Approved by: � .. COMMISSIONER APPROVED BY THE COMMISSION Appre I IvAo12 months from; date of approval. val. Date:kQ "/5 Submit Form and d Form 10-403 Revised 5/2015 ' k-,/,q/ RBDIII sac s inLI.,,liotc)L • • • RECEIVED ConocoPhillips OCT 0 2 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 2,2015 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby sub ' • pplication for Sundry Approval to workover West Sak Injector KRU 1J-180/ 1J-180 Ll (PTD#206-150 06-151). KRU 1J-180/1J-180 L1 was spur ded in January 2007 and completed as a dual-lateral West Sak B-&D-sand injector. However, after receiving permission from the AOGCC to gas-lift the well through an open sliding sleeve,the well was initially pre-produced for a few months before finally coming online as a water injector in June 2007. In 2009,the well failed an MIT-IA and was shut-in. After performing diagnostic work,the sliding sleeve in the 4-%2" upper completion was cycled open and after being closed,the well passed a MIT-IA. The well was then brought back on water injection service. In 2014, after a few months where the IA was tracking higher than the tubing pressure while on water injection, operations attempted to pressure up on the IA to create a positive IA to tubing differential pressure but was unable to build pressure within the IA. The well was shut-in at that time and after performing additional diagnostic work, multiple tubing leaks were identified in the 4-'/2"upper completion at 5,062',5,148',&5,300'MD. The proposed rig work-over of 1J-180/ 1J-180 L1 will consist of pulling the entire existing 4-Y2"upper completion to the seal assembly and replacing with a new 4-'/2"upper completion to bring the well back on water-alternating-gas injection. This Sundry is intended to document the proposed rig workover on KRU 1J-180/ 1J-180 L1 where the intent is to pull tubing and to request approval to workover this well. If you have any questions or require any further information, please call me at 265-6048 or email me at danny.kane(uiconocophillips.com. Sincerely, Danny Kane Senior Wells Engineer CPAI Drilling and Wells KUP INJ • 1J-180L1 • ' Conocof fillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl 0) MD(ftKB) Act Btm(ftKB) cr.444a7Ohilhm 500292332960 WEST SAK INJ 0.00 17,779.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date Mwnple Laterals-tJ-180L1,6/24/20158:04:02 PM SSSV:NIPPLE Last WO: 43.51 2/27/2007 Vertical schematic(actual) Annotation •Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'. Rev Reason:SET ISO SLEEVE lehallf 6/24/2015 HANGER 360 (I 9110 . Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB( Set Depth(ND)... WELen(I...Grade Top Thread D-SAND LINER 4 1/2 3.476 10,254.7 17,750.3 3,252.2 11.60 L80 BTC .h-h/CONDUCTOR;400-120.0• 111 • Liner Details Nominal ID NIPPLE;513.6 - -- Top(ftKB) -Top(ND)(ftKB) Top Incl 0) Item Des Com (in) GAS LIFT;2,260.6 10,254.7 3,317.8 87.35 SLEEVE 5 1/2"Baker"HR"Liner Setting Sleeve(6.41"O.D.x 5.750 5.75"I.D.) 10,319.5 3,319.7 89.08 XO Reducing 5 1/2"Hydril 521 Pin X 4 1/2"BTC Pin X/O(3.96" 3.960 SURFACE;37.7-4,000.6 I.D.) SLEEVE-C;9.948.2 17,712.0 3,252.3 90.35 XO 3-1/2",9.3 ppf,L-80,IBT Box X EUE 8rd Pin X/O 2.992 PUP LOCATOR;9,995.8 i= Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY;9,996.4 aa Top(ND) Top Incl = Top(ftKB) (ftKB) I') Des Com Run Date ID(in) 10,106.1 3,304.7 84.11 SLEEVE ISO SLEEVE SET IN NIPPLE 6/21/2015 2.125 D LINER HH;10.048.5-10.312.5 INTERMEDIATE;40.6-10,844.5 II IF Perforations&Slots D LINER LEM';9.988.9-10.212.1 Shot Dens Top(ND) Btm(TVD) (shcts/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,324.0 10,578.0 3,319.7 3,319.2 WSD,1J- 2/17/2007 32.0 SLOTS ALL PERFS IN 180L1 WELLBORE:Alternating solid/slotted pipe- SLOTS;10,324.0-10,578.0 — 0.125"x2.5"@ 4 — — circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends SLOTS;10,871.0-11,370.0 — — 10,871.0 11,370.0 3,329.1 3,321.9 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 11,669.0 12,183.0 3,318.9 3,306.8 WSD,1J- 2/17/2007 32.0 SLOTS _ _ 180L1 12,476.0 12,989.0 3,300.8 3,292.0 WSD,1J- 2/17/2007 32.0 SLOTS — — 180L1 SLOTS;11.669.0-12.183.0-2— — 13,287.0 13,795.0 3,286.7 3,277.5 WSD,1J- 2/17/2007 32.0 SLOTS 180L1 — — 14,047.0 14,599.0 3,276.6 3,265.3 WS D,1J- 2/17/2007 32.0 SLOTS _ _ 180L1 14,848.0"' 15,405.0 3,259.3 3,262.5 WSD,1J- 2/17/2007 32.0 SLOTS 180L1 15,661.0 16,173.0 3,264.0 3,264.8 WSD,1J- 2/17/2007 32.0 SLOTS SLOTS;12,476.0-12,989.0 — 180L1 16,472.0 16,986.0 3,262.0 3,258.3 WSD,1J- 2/17/2007 32.0 SLOTS 180L1 17,282.0 17,710.0 3,255.2 3,252.3 WS D,1J- 2/17/2007 32.0 SLOTS 180L1 — — Notes:General&Safety SLOTS;13,287.0-13.795.0 " End Dale Annotation 3/2/2007 NOTE:MULTI-LATERAL WELL-1J-180(B-SAND),1J-180L1(D-SAND) SLOTS;14.047.0-14,599.0— SLOTS; 4.047014,599.0SLOTS;14,848.0-15,405.0 SLOTS;15,661.016,173.0 SLOTS;16,472.0-16,986.0 — — SLOTS:17,282.017,710 0 DSAND LINER;10,254.7- 17.750.31 • • KRU 1J-180 (& 1J-180 L1)—Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-150 (& 206-151) Current Status: KRU 1J-180(& 1J-180 L1),a West Sak B-&D-sand dual-lateral injector,is currently shut-in after failing multiple MIT-IAs as a result of a tubing leaks identified at 5,062',5,148' &5,300'MD. Please see below for the well integrity history of 1J-180,including the aforementioned failure which required the well to be shut-in: o 2007–The KRU 1J-180& 1J-180 L1 dual lateral injector was drilled and completed. o 2009–Failed a MIT-IA(24-May-2009). • Shifted the Baker CMD sliding sleeve at 9,948'MD open&close. Re-tested&passed a MIT-IA. o 2015–Operations noticed that the IA would not hold pressure. • With the IA tracking above the tubing pressure for a few months,operations attempted to reestablish a positive IA differential pressure over the tubing but were unable to after establish a positive differential when the IA failed to build pressure. Failed tubing integrity was suspected with the IA test pressure leaking through the tubing and into the reservoir. • The tubing&IC Pack-Offs were pressure-tested successfully. Failed tubing integrity confirmed. • The Baker CMD sliding sleeve was opened&closed twice,each time with a follow-up failed MIT-IA. Tubing leak suspected. • Leak Detect Log(22-Jun-2015)confirmed loss of tubing integrity through multiple tubing leaks. • Leaks identified at 5,062',5,148,&5,300'MD. • CMIT-TxIA passed—confirmed production casing integrity. Scope of Work: Pull the 4-1/2"upper completion&run new 4-1/2"upper completion. General Well Info: Well Type: Injector MPSP: 1,454 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. ✓ Reservoir Pressure/TVD: West Sak B/D–1,788 psi/3,323' TVD(10.6 ppg EMW) Wellhead Type/Pressure Rating: Vetco Gray Horizontal(5M Tubing&Casing Heads) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-IA Failed 20-Apr-2015 Last Passed 15-May-2014 CMIT-TxIA Passed 30-Sep-2015 Production Casing Integrity Confirmed MIT-OA–Open Shoe Earliest Estimated Start Date: 19-Oct-2015 Production Engineer: Michael Sullivan Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com Summary of Proposed RWO Procedure: Proposed Pre-Rig Work: 1. RU Coiled Tubing. a. Set an Isolation Sleeve across the D-Sand LEM to isolate the D-Sand lateral. b. Set a 3.562"DB Plug within the DB Nipple at 10,102'MD to isolate from the B-Sand lateral. c. Perform a CMIT-TxIA to confirm that the Isolation Sleeve&DB plug are set&holding pressure. d. Open the Baker CMD sliding sleeve at 9,948'MD. e. RD Coiled Tubing. 2. Set the BPV. • • KRU 1J-180 (& 1J-180 L1) —Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-150 (& 206-151) Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull the BPV. Circulate seawater around through the open Baker CMD sliding sleeve at 9,948' MD. Obtain SITP & SICP; if pressure is still observed at surface, calculate the required KWF and circulate around as necessary. Verify the well is static. 3. Set the BPV,ND the tree,set the blanking plug,NU BOPE,&test BOPE to 250/3000 psi low/high. 4. Pull the blanking plug&BPV,screw in the landing joint,BOLDS,&unseat the tubing hanger. 5. P/U on the tubing&pull the tubing hanger to the rig floor. Verify that the well is static&TOH laying down the existing 4-1/2"upper completion(entire upper completion to the base of the locating seal assembly). 6. M/U&TIH with the new 4-1/2"upper completion as per design to just above the casing sealbore receptacle. 7. Engage the seal assembly until fully-located into the casing sealbore receptacle. P/U from fully-located,space- out 7',&mark the pipe at surface. 8. Space-out the completion with tubing pups and M/U the tubing hanger, 9. Swap the well over to corrosion-inhibited seawater across the upper completion. 10. Land the tubing hanger&RILDS. 11. Pressure-test tubing&IA. BJ.d the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV(IA to tubing shear). ✓ 12. Back-out the landing joint&install the BPV. 13. ND BOPE,NU the tree,install the tree test plug,&pressure test the tree to 250/5,000 psi. Pull tree test plug. 14. Freeze protect the well through the SOV in GLM#1. 15. Set the BPV. 16. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull the BPV. 2. RU Coiled Tubing: a. Remove the SOV from GLM#1 &replace with a DV. b. Pull the Isolation Sleeve from across the D-Sand LEM c. Pull the 3.562"DB Plug set within the DB Nipple at 10,102'MD. d. RD Coiled Tubing. 3. Reset well house(s)&re-attach flow line(s). 4. Turn the well over to operations. • • Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Thursday, October 08, 2015 11:30 AM To: Loepp, Victoria T (DOA) Subject: KRU 1J-180& 1J-180 Ll - PTD 206-150 206-151 10-403 Sundry Request Amendment Victoria, While putting together the Sundry Request for KRU 1J-184–very similar to the submitted Sundry Request for KRU 11- 180—that I wrote down the wrong BOPE high test pressure. For the KRU 1J-180&KRU 1J-180 L1 Sundry Requests,the planned BOPE test pressure will be 250/3500 psi in order to bring this dual lateral injector back online for MWAG service. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ ~ L Well History File Identifier Organizing (aone> ~o-sided III II'lll II III II III ^ Rescan Needed III IIIII II II III III RE AN DIGI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ~ Maps: ^ Greyscale Items: ~ ^ Other, No~fype: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ) ~~ /s/ Project Proofing II I Il Il 11 l i 111 I I III BY: Maria Date: ~ ~ ~~~9 /s/ Scanning Preparation ~ x 30 = ~ + ~ ~ =TOTAL PAGES~~ (Count does not include cover sheet) BY: Maria Date: ~ ~' ~! %C~ /s/ / i~ ~ IIIIIIIIIIIIIIIIIII Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Sc_anni'ng Preparation: ~ YES NO BY: Maria Date: ~~~ J Q C~ lsl Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII ReScanned BY: Maria Date: /s/ Comments about this file: o , ~~~kea ii~uiimuiiiuii P 10/6/2005 well History File Cover Page.doc -g,. ~ . ~~ ` ~v~ ~ +.~ ~' ~~ ~ MICROFILMED .6/3012010 DO .NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Ternporary Internet Files\OLK9\Microfilm_Marker.doc ~ M DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061510 Well Name/No. KUPARUK RIV U WSAK 1J-180L1 Operator CONOCOPHILLIPS ALASKA INC MD 17779 TVD 3252 REQUIRED INFORMATION API No. 50-029-23329-60-00 Completion Date 2/2/2007 Completion Status 1-OIL Current Status 1WINJ ~ Samples No Directional Survey Yes Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/RES, DENS/NEU, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey ~ED D Asc Directional Survey tJ~D C Lis 15111/Induction/Resistivity ~pt 15111 LIS Verification ~D C Lis 15111 ~nduction/Resistivity ~lMpt 15111 LIS Verification Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 15729 17779 Open 4/13/2007 9991 16246 Open 4/13!2007 PB 1 3951 17779 Open 5/8/2007 LIS Veri, GR, FET, ROP 3951 17779 Open 5/8/2007 LIS Veri, GR, FET, ROP 3951 16246 Open 5/8/2007 P61 LIS Veri, GR, ROP, FET 3951 16246 Open 5/8/2007 P61 LIS Veri, GR, ROP, FET Sample Interval Set Start Stop Sent Received Number Comments ~, ADDITIONAL INFORMATION Well Cored? Y N Chips Received? ~AL_ Analysis ~rt~v Received? Comments: Compliance Reviewed By: _. _.__ __ Daily History Received? ~ N Formation Tops Date: -__-_~.~-1~ WELL L®G TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-180+L1+L1PB1 November 14, 2008 AK-MW-4794615 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-180+L1+L1PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-23329-00,60,71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-23329-00 Digital Log Images 50-029-23329-00,60,71 Ll AND L1PB1 HAS NO TVD. 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan. Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3536 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~o Signed: Vs-~~b~-rs r t~-3t~ ~( Li l / VIJ • l4V iVKlV I{ VAi to i ~~.+~ ~vu' a.. ar. ~ a.. a.. ~ ... ~... .. Maunder, Thomas E (DOA) __ From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (bOA) Cc: CPFl DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, iJ-127, 1J-164, 1J-180 Torn ;Jim, The LPP/SSV's on all of the West Salc DS1 E and DS1 J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I wasn't sure if yo!~ wanted the permit to drill number for the mainbore only or the laterals as well so f included both. WELL ID Permit to Drill No. 1 E-112 7_04-091 (MAlNBORE), 204-092 (L1 ), 204-093 (L2) 1J-102 206-110 (MAINBORE), 206-111 (L1), 206-112 (L2) 1J-105 207-027 (MAINBORE), 207-028 (L1}, 207-029 (L2) 1J-'i27 206-047 (MAINBORE), 206-048 (L1), 206-049 (L2} 1J-160 207-015 (MAiNBORE), 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAINBORE), 205-145 (L1 ), 205-146 (L2) -~ 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/?_007). Let me know if you have any questions. Regards, Hai Hunt Hai Haant /Pete Nezaticky /Eric Hollar NSK West Sal< Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com ~~~ RECEIVED ~ ~ ~°~~~ JUN 1 9 7.007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska O1I & GaS COn$. CttmrniS$la REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate. ^ Other ^ Pre-Prod to Inj Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well. ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-151 1 3. Address: Strati ra hic g p ^ Service ^~ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23329-60 7. KB Elevation (ft): 9. Well Name and Number. RKB 121' 1J-180L1 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field /West Sak Oil Poop 11. Present Well Condition Summary: Total Depth measured 17779' feet true vertical 3252' feet Plugs (measured) Effective Depth measured 17749' feet Junk (measured) true vertical 3252' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE. 3879' 13-3/8" 4000' 2227. INTERMEDIATE 10723' 9-5/8" 10844' 3378' WINDOW L1 1' 7-5/8" 10051' 3298' LINER D-SAND. 7496' 4-1/2" 17750' 3252' Perforation depth: .Measured depth: 10325' - 17711' true vertical depth: 3320' - 3252' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10013' MD. Packers &SSSV (type & measured depth) D-SAND ZXP LINER TOP PACKER PKR = 9989' SSSV= NIP SSSV= 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data. Oil-Bbl Gas-Mcf Water-Bbl. Casin Pressure Tubin Pressure Prior to well operation- 774. 1642 24 1189 303 Subsequent to operation 2942 1213. 262 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service. ^~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 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: / ~ ~/~ ~ ~ Q'L contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature one 659-7535 Date /~j / ~~ ~• ~' 7 Form 10-404 Revised 04/2004 ~ R ~ G ~ N ~ !~ '~ Submit Original Onl ~~~T 1J-180L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/09/07 Commenced Water Injection wE>.><, Loc "rr~alys~~>o<T~rAL To: State oFAlaslca Api-~l 24, ?Q07 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~ Avenue, Suite 100 Anchorage, Alaska. RE: MVl%D Formation Evaluation Logs IJ-180_L1_Ll PBI, AK-MW-4794615 1 LDWG formatted CD Rom with veri£cation listing. API#: 50-029-23329-00, 60, 71 PLEASE ACI{~'VOWT,EDGE RECEIPT BY SIGNING AND RETURNING A COPY OF TTIE "TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Ancharag; ~l~ska,~9~ ~I:& Date:. Signed: fix'-~i `. A 'e q ~„ ~e^~. ~, 1 7v:~K;.°s'^f ~U~- l5b # !5 Il0 2 a~ - 1 S( ~ r5 /I/ SARAH PAUN, GOVERNOR ~7~A OII/ ~ ~~ 333 W. 7th AVENUE, SUITE 100 C011TSERQ~7.`I011T C011II~IISSIOI~T ~ ANCHORAGE, ALASKA 99501-35 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen 39 Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-180L1 Sundry Number: 307-125 Dear Mr. Christensen Enclosed is the approved- Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of April, 2007 Encl. Sincerely, RECEIV ~/~ f T Gib' q.,-~,,-o~ ED STATE OF ALASKA ~t (~ ALASKA OIL AND GAS CONSERVATION COMMISSION APR- , ~"'07 .APPLICATION FOR. SUNpRY APPROVAL Alaska Oil & Gas Cons.. Commission 20 AAC 25.280 aflChnr~nn T. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate , ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram 9 PP P 9 ^ Pull Tubing ^ Perforate New Pool ^ Oil to Winj Re-enter Suspended Well ^ Conversion 2. Operator Name: 4. Current Well Class: 5. Permitto Drill Number:. - ConocoPhillips Alaska, Inc. Development Q - 'Exploratory. ^ 206-151 3. Address: ` Stratigraphic ^ Service. ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23329-60 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and_ Number. where ownership or landownership chang es: Spacing Exception Required? YeS ^ NO ^~ 1J-180L1 .•-: 9. Property Designation: _ 38SL'72 ~ 4O ~-" Z5~3 r r 10. KB Elevation (ft): 11..Field/Pool(s): • ' j Kupa Unit . uk Rive '(. / 7RKB 121' Ku aruk River Field /West Sak Oil Pool f p 12. PRESENT WELL CONDITION SUMMARY . Total depth MD (ft) Total Depth TVD (ft)[. Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured); Junk (measured}: - 17779' 3252' 17749': 3252' Casing Length Size MD TVD Burst Collapse. CONDUCTOR 120,.., 20" 120' - 120 , , ,: .` SURFACE 3879' 13-3/8" 4000' 2227 INTERMEDIATE 10723' 9-5/8" 10844' ~ ~ 3378 WINDOW L1 1,_ 7-5/8" 10051':. - `_.. 3298 LINER D-SAND 7496` 4-1/2", 17750' 2832 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing-Size: Tubing grade: ' Tubing MD (ft): 10325' -17711' 3320"- 3252' 4-1 f2" .; i.-80 _ ~ 00 ~ 3' Packers and SSSV Type: Packers and SSSV MD (ft) , . ' D-SAND ZXP LINER TOP PACKER PKR = 9989' ~ ' SSSV= NIP SSSV= 514' ~ .: 13. Attachments:.Description Summary of Proposal ~ 14. Well Class after proposed work: betailed Operations Program ^ BOP Sketch ^ Exploratory ^ - Development ^ ` Service Q' ~ 15. Estimated Date for ` 16. Well Status after proposed work: ' Commencing Operations: April 30, 2007 Oil ^ Gas ^ Plugged. ^ Abandoned- ^ 17. Verbal Approval: Date: WAG ^ ~ ~ GINJ ^ 1NINJ ~ '~ WDSPL ^ Commission Representative: • 18. I hereby certify that the foregoing is true and correct to the best of my knowledge.., Contact: ~ ' _ Bob Christensen /Bob Buchholz' '' Printed Nam i eft hriste 2n Title: ~ Producfion Engineering Technician" Signature ~ _ Phone 659-7535. Date ~~ f~ Commission-Use Onl _ . ' Sundry Number. Conditions of approval: Notify Commission so that a representative may witness - Plug Integrity. ^ BOPTest [~ Mechanical Integrity Test Location Clearance ^ Other: ~ a~l~ ~ °~ Sao .Subsequent Form. Required: l APPROVED BY Approved by: C MISSIONER THE COMMISSION Date: ~~/~O ~Q~ Form 10-403 Revised 06/2006 ~a S bmit i Du licate f ,~i`~ ~. ~'v .07 -- - ''~ ~ 1J-180L1 ' '`` ~ DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Multi-lateral We11 1J-180L1. This wel(was pre-produced in order to recover Oil based drilling fluids prior to putting the well on injection. Welt 1J-180L1 will provide pressure support for the West Sak D sands. The 13-3/8" Surface casing (4001' and / 2227 tvd) was cemented with 680 sx AS Lite followed by 335 sx DeepCrete. The 9-5/8" Intermediate casing (10844' and / 3378' tvd) was cemented with 835 sx DeepCrete. The injection tubing/casing annulus is isolated via 7" x 9-5/8" ~JCP Liner Top Packer with 190- 47 Gasing Sealbore Receptacle Located @ 9989' and / 3290' tvd. The top of West Sak. D sand was found at 10074' and / 3298' tvd. • • °~ KRU 1J-180L1 ~+~t~c~~~~l~~~ ~~a~ka, ~~~'a 77~ ~.{ = ~ ~""..l`f ~ 1, c~ l . ~! ~ L',1 ~ 1 :. ~~ 7 „= (V~ 7 .~'~.J ~ L ~asi~g ~J~~ Shoe_ ~~r ~~~ ~~~~-'~~~ D~I. ~~ ?~ =`v~i -=_~°_ - ~ :hoe. ~ _ .~ , .'C; '--~ _'i~ :owe S«e and Pe=~s to ®S ~:`_ ~" ~r?~i =C~_. ~NTEGRI'Z~~ - Pp.RT #? nr:uius ?ress Test: _? 15 min ~0 min Cc~,ents . '~'CI~FNIC~_L INTEGRIT 7 - PART # 2 ~ ~ 3~ bh~~ Cement Volumes : Amt. Liner ~~ CsQ 4s~3Js~ ; DV ~.~ C,mt -sol to cover oers ~l~'1~~t~~ 30~,`~rj ~ ~~~~ ~- ~1 _ :eoretical TOC ~ ~~~a`~~ ~~~5 ~o~~ ~~ `pC Cement Bond Log (Yes or Nc) ~~~ In AOGCC File ~~S CBL Bvzl.uation, Done above perYs -~- c3.~c~c3~-~e rc~~~o~~ ?roduction Log: Twe valuation CONCLJS~ONS: ?art ? 1 ~A ,---_ ~,~vtu STATE OF ALASKA ~ ;~_~;~ p 4 ZOO7 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT-~ s• Commission 1a. Well Status: Oil O Gas Plugged Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_ 1b. Welt Class: Development O Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., P' or Aband.: February 27, 2007 12. Permit to Drill Number: 206-151 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~eab /bi1.m January 7, 2007 ~•9r• 13. API Number: 7 50-029-23329-60 4a. Location of Well (Governmental Section): Surface: y80i~FSL, 2443 L, Sec. 35, T11N, R10E, UM 'F E 7. Date TD Reached: February 16, 2007 14. Well Name and Number: 1J-180L1 , / " At Top Productive ~s~ ,,~ 7'07 Horizon: 1264' FNL, 132' FEL, Sec. 10, T10N, R10E, UM 8. KB Elevation (ft): 40.7' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1588' FSL, 359' FEL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17749' MD / 3252' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558770 y- 5945420 Zone- 4 10. Total Depth (MD + TVD): 17779' MD / 3252' TVD ~ 16. Property Designation: ~ • ADL 25663, 385172 TPI: x- 555873 y- 5937247 Zone- 4 Total Depth: x- 555714 .y - 5929538 + Zone- 4 11. Depth where SSSV set: nipple @ 514' 17. Land Use Permit: ALK 2177, 472, 2181 18. Directional Survey: Yes 0 No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1697' MD 21. Logs Run: ~"' /~~Q$~j rljfj~ 3 7y'D GR/Res, Dens/Neu, USIT ~ y~~7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE TIN AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN G RECORD PULLED 20" 78.6# H-40 Surf. 121' Surf. 121' 42" 355 sx AS 1 13.375" 68# L-80 Surf. 4001' Surf. 2226' 16" 680 sx ASLite, 335 sx DeepCRETE 9-5/8" 40# L-80 Surf. 10843' Surf. 3377' 12.25" 835 sx DeepCRETE 4.5" 11.6# L-80 10254' 17750' 3318' 3252' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore slotted liner from: 17750'-17710', 17282'-16986', 16471'-16172', 15660'-15405' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14849'-14598', 14047'-13795', 13287'-12989', 12476'-12183' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11669'-11370', 10871'-10577', 10324'-10254' MD n/a 26. PRODUCTION TEST Date First Production March 25, 2007 Method of Operation (Flowing, gas lift, etc.) pre-produced injector - flowback to facility Date of Test 3/25/2007 Hours Tested not available Production for Test Period --> OIL-BBL 2300 GAS-MCF 2600 WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". - - '"""""""""' i ~~~ii~ t . NONE - ~ ~1e~;'~'~u ~ .Y Form 10-407 Revised 12/2003 ORIGINAL CON ~iERpP~ ~ ~I I.OQI ~ ~~6~' ~~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-180L1 West Sak D 10047' 3298' Base West Sak D ~ 17779' 3252' 1 J-180L1 P61 r TD 16246' 3256' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Narva Randv Thomas Title: Greater Kuoaruk Area Drillino Team Leader 3 l jo ~~ ~ ~ Signature : ne `~ 5 ~ .~ > ~, Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Time Logs __ Date From To bur S De th E De th i'hase Code Subcode T COM 02/08/2007 11:15 11:30 0.25 17,834 17,830 COMPZ CASINC RUNL P Tag bottom @ 17834' while rotating in hole. Pull up & position string at setting depth as per detail with Shoe 17830' MD. 11:30 12:00 0.50 17,830 10,164 COMPZ CASIN CIRC P Break circulation, drop 1 3/4" ball down drill string, pump ball down allowing to seat. Pressure to 4000 PSI to set liner hanger & packer as per BOT rep. Note: Top of B lateral liner - 10164' MD 12:00 13:00 1.00 10,164 10,164 COMPZ CASINC OTHR P Rig up and pressure down annulus to test packer to 1000 PSI - 10 minutes. Good test. Release from Liner hanger as per BOT rep. Attempt to slack off to verify top of Iliner, no slack off wei ht. 13:00 14:00 1.00 10,164 10,164 COMPZ CASINC CIRC P Circulate bottoms up @ 10 BPM - 1030 PSI. Observe no fluid loss. 14:00 18:00 4.00 10,164 2,378 COMPZ CASINC RUNL P POOH from 10164' - 2378'. Observe hole taking proper fill. Obtain SLM on TOH. Crew Chan e 18:00 20:00 2.00 2,378 0 COMPZ CASIN RUNL P Continue POOH from 2378' -surface. Observe correct hole fill. 20:00 21:00 1.00 0 0 COMPZ CASIN RURD P Breakout, inspect and lay down runnin & settin tools. All tools OK. 21:00 21:30 0.50 0 0 COMPZ STK OTHR P Clean & clear floor area. Held PJSM with crew. Discuss saftey issues and procedure for picking up 42 joints of 5" HWDP and racking back in derrick for whi stock run. 21:30 23:00 1.50 0 1,300 COMPZ STK PULD P Run in hole with 42 joints of 5" HWDP. 23:00 00:00 1.00 1,300 0 COMPZ STK PULD P POOH, rack back 5" HWDP - 14 stands. Obtain SLM on TOH. 02/09/2007 00:00 01:00 1.00 0 0 COMPZ STK OTHR P Clean & clear rig floor area of OBM. Pull 20 LoTads to rig floor. Strap & caliper same. Pull whipstock tools to ri floor. 01:00 02:00 1.00 0 0 COMPZ STK OTHR P PJSM with Crew, Sperry Sun reps, and BOT rep. Discuss saftey issues and procedure for making up 9 5/8" whipstock assembly with MWD assembly. Continue pulling Lo tads to rig floor and rigging up to make up BHA. 02:00 03:15 1.25 0 0 COMPZ STK OTHR T Pick up 1 stand of 5" HWDP. joint came in contact with Top Drive when lowering. Lay down joint, inspect Top Drive assembl .Service To Drive 03:15 06:00 2.75 0 202 PROD2 STK PULD P Make up 9 5/8" whipstock assembly with space out pipe as per BOT rep. Make up MWD assembly. Crew Chan e 06:00 06:30 0.50 202 202 PROD2 STK PULD P Continue make up MWD assembly. Orient MWD with high side face of whi stock slide. ~ ~~ ~ ~'~ex`s ?~ ofi ~~ l J Time Logs __J, Date______ From To Dur ___S. Depth__E, De~th_ Phase _ Code Subcode T _COM __ _ 02/09!2007 06:30 07:15 0.75 202 202 PROD2 STK OTHR P Plug in and upload MWD assembly. 07:15 07:30 0.25 202 301 PROD2 STK TRIP P RIH with whipstock assembly from 202' - 301'. Perform shallow pulse test on MWD tools. Good test. 07:30 10:30 3.00 301 2,181 PROD2 STK TRIP P Trip in hole with whipstock assembly from 301' - 2181'. Install Lo-Tads on drill pipe, 1 per stand. Observe correct dis lacement. 10:30 12:00 1.50 2,181 2,181 PROD2 STK PULD P Pull 30 more Lotads to rig floor. Drift , stra & record serial numbers. 12:00 16:45 4.75 2,181 5,149 PROD2 STK TRIP P Continue trip in hole from 2181' - 5149'. Install Lotads on drill string, 1 per stand. Total of 50 LoTads installed. Fill drill string every 25 stands. Observe ro er dis lacement. 16:45 17:00 0.25 5,149 5,149 PROD2 STK PULD P Clean & clear rig floor area. lay down all thread protectors, and install lift subs on racks. 17:00 18:00 1.00 5,149 6,575 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 5149' - 6575'. Crew Chan e 18:00 20:30 2.50 6,575 8,100 PROD2 STK TRIP P Continue trip in hole from 6575' - 8100'. 20:30 21:00 0.50 8,100 8,100 PROD2 WELCT SFTY P Held BOP drill. Held safety standown meeting with rig crew, TP's and CPAI reps. Discuss safety issues and incident on ri . 21:00 21:45 0.75 8,100 9,300 PROD2 STK TRIP P Continue trip in hole from 8100' - 9300'. 21:45 22:00 0.25 9,300 9,400 PROD2 STK OTHR P Perform MAD PASS from 9300' - 9400' DPM. pumps @ 600 GPM's - 3050 PSI. 22:00 23:00 1.00 9,400 10,100 PROD2 STK TRIP P Continue trip in hole from 9400' - 10100'. 23:00 00:00 1.00 10,100 10,050 PROD2 STK CIRC P Make Top Drive connection. Pump @ 615 GPM's - 3100 PSI to orient whipstock face at 17 Deg left of high side. UP WT = 235K, SO WT = 100K. Slack off tag top of B lat liner @ 10168' (3' low- Make change on Liner Detail Tally). Set down 25K to set Bottom trip anchor. Pull 10K over to verify set. Slack off 40k to shear bolt. Pull to neutral position. Attempt to rotate free with 12K plus torque. Stop rotation. Window To = 10050' MD. 02/10/2007 00:00 01:00 1.00 10,050 10,050 PROD2 STK CIRC P Displace well from SF MOBM to OBM 615 GPM's - 3050 PSI. 01:00 06:00 5.00 10,050 10,067 PROD2 STK MILL P Mill 8 1/2" window from 10050' - 10067' in 4.58 HRS. Crew Chan e 06:00 07:30 1.50 10,067 10,097 PROD2 STK MILL P Continue mill open hole from 10067' - 10097' in 1.33 HRS. GAuged hole to 10087' as per DD. Top of window @ 10050'. Bottom of window 10067'. ® ~~ ,__~.~ w 0~~~ ~- ~~ f'as~~ 2~ cif ~~ ~ ~i • Time Logs Date From To ur _ D S Depth E. Depth Phase Code Subcode T __ COP~1 ____ 02!10/2007 . 07:30 09:15 _ _ __ 1.75 _ 10,097 10,097 PROD2 STK CIRC P _ Pump 30 BBLS Hi Visc weighted sweep, while working drill string to ensure clean wiindow area. Work window without rotation or pump. Looked ood. 09:15 09:30 0.25 10,097 10,097 PROD2 STK OWFF P Monitor well -static. 09:30 10:00 0.50 10,097 10,097 PROD2 STK CIRC P Pump dry job, blow down Top drive & lines. 10:00 11:15 1.25 10,097 8,737 PROD2 STK TRIP P POOH, breakout & lay down first 18 'oints of 5" HWDP. 11:15 12:00 0.75 8,737 6,172 PROD2 STK TRIP P Continue POOH from 8737' - 6172'. Observed ro er hole fill. 12:00 17:00 5.00 6,172 84 PROD2 STK TRIP P POOH from 6172' - 84'. Observed proper hole fill. Reposition top super slider on each stand to enable racking back in fingers. SIMOPS: Test choke manifold on TOH for week) BOP Test. 17:00 17:30 0.50 84 0 PROD2 STK PULD P Breakout & lay down BHA. 17:30 18:00 0.50 0 0 PROD2 STK PULD P Plug in and download MWD. Breakout & lay down MWD assembly. Crew chan e 18:00 18:30 0.50 0 0 PROD2 STK PULD P Continue breakout & lay down MWD assembl . 18:30 19:15 0.75 0 0 PROD2 STK PULD P Breakout & lay down mills. Gauge Upper mill to full gauge of 8 1/2". Clean & clear ri floor area. 19:15 21:00 1.75 0 0 PROD2 WELCT OTHR P Pick up 1 stand of DP and stack washer assembly. Flush stack, lay down washer. Rack back stands and ick u test 'oint. 21:00 22:45 1.75 0 0 PROD2 WELCT OTHR P BOLDS & pull wear bushing. Install test plug. Rig up BOP test equipment. Fill BOP stack & choke manifold with water. 22:45 23:00 0.25 0 0 PROD2 WELCT SFTY P Held PJSM with crew. Discuss safety issues and hazard recognition. Discuss BOP testin rocedure. 23:00 00:00 1.00 0 0 PROD2 WELCT BOPE P Test BOP's. AOGCC rep Chuck Sheve on location to witness test. 02/11/2007 00:00 02:45 2.75 0 0 PROD2 WELC BOPE P Continue test BOP's with AOGCC rep Chuck Sheve witnessing test. test with 4", 4 1/2" & 5" test joints. Perform Accumulator test with 200 PSI increase in 36 sec, and full 3000 PSI in 3 min, 11 sec. 02:45 03:45 1.00 0 0 PROD2 WELCT OTHR P Rig down all BOP testing equipment. Pull test plug & install wear bushing. RILDS. 03:45 04:00 0.25 0 0 PROD2 DRILL SFTY P Held PJSM with crew. Discuss saftey issues, hazard recognitions and procedure for making up 6 3/4" drilling BHA. 04:00 06:00 2.00 0 0 PROD2 DRILL PULD P Make up 6 3/4" Drilling BHA as per DD & MWD re s. Crew Chan e ~.~._~e_ l J • Time Logs __ _ Date From To Dur S. Depth E De th Phase Code Subcode T COM 02/11!2007 06:00 06:30 0.50 0 0 PROD2 DRILL OTHR P Plug in and Upload MWD assembly. Observed bad connection. 06:30 07:15 0.75 0 0 PRODZ DRILL OTHR P Upload MWD assembly. 07:15 08:00 0.75 0 362 PROD2 DRILL PULD P Continue make up remaining BHA. 08:00 08:30 0.50 362 453 PROD2 DRILL TRIP P Trip in hole 1 stand and perform shallow pulse test. Check Geo pilot sendin commands. All ood. 08:30 09:15 0.75 453 1,100 PROD2 DRILL PULD P Pick up 21 joints of 4"drill pipe from i e shed. 09:15 12:00 2.75 1,100 6,200 PROD2 DRILL TRIP P Continue trip in hole with 4" DP from derrick to 6200'. 12:00 14:45 2.75 6,200 10,046 PROD2 DRILL TRIP P Trip in hole from 6200' - 10046'. Top of window. Observed proper dis lacement. 14:45 16:00 1.25 10,046 10,046 PROD2 RIGMN' SVRG P Held PJSM. Discuss Hazards & safety issues. Slip & cut drilling line, adjust brakes on draw works & ins ect linka e. 16:00 18:00 2.00 10,046 10,046 PROD2 RIGMN SVRG P Change out top Drive saver sub. Service To Drive. Crew Chan e 18:00 00:00 6.00 10,046 10,575 PROD2 DRILL DDRL P Observe no issues going through window area. Directional drill in the D lateral from 10097' - 10575'. ADT = 3.11 HRS. ECD - 9.70 PPG 02/12/2007 00:00 06:00 6.00 10,575 11,232 PROD2 DRILL DDRL P Directional drill in the D lateral from 10575' - 11232'. ADT = 3.58 HRS. ECD - 10.1 PPG Crew Chan e 06:00 12:00 6.00 11,232 12,102 PROD2 DRILL DDRL P Directional drill in the D lateral from 11232' - 12102'. ADT = 4.04 HRS. ECD - 10.2 PPG 12:00 18:00 6.00 12,102 13,014 PROD2 DRILL DDRL P Directional drill in the D lateral from 12102' - 13014'. ADT = 3.79 HRS. ECD - 10.32 PPG Crew chan e 18:00 21:00 3.00 13,014 13,298 PROD2 DRILL DDRL P Directional drill in the D lateral from 13014' - 13298'. ADT = 1.26 HRS. ECD - 10.16 PPG. Observed geo pilot failure. Attempt to trouble shoot. Unsuccessful. 21:00 23:30 2.50 13,298 12,719 PROD2 DRILL REAM T Pump 30 BBL Hi Visc sweep while BROOH @ 10 ft./min until sweep returned. Observed no signifcant increase in cutting upon sweep returnin 23:30 00:00 0.50 12,719 12,125 PROD2 DRILL TRIP T POOH on elevators from 12719' - 12125'. Observe clean ho-e and no swabbin issues. Mix D ~ob. 02/13/2007 00:00 00:15 0.25 12,125 12,125 PROD2 DRILL CIRC T Pump 25 BBI Dry Job. Blow down Top Drive & lines. Monitor well -static. 00:15 07:00 6.75 12,125 360 PROD2 DRILL TRIP T POOH on elevators from 12125' - 2423'. No issues with BHA going through window area. Observed proper hole fill. Open hole looked good with no overpull or swab issues. Layed down Centurian circ valve to pipe shed. _ _ _. _ ..~ -_s® _me ~ _~~ _ ac~~~i s'~ ~f ~~~ r J Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T _ COM 02/13/2007 07:00 07:45 0.75 360 91 PROD2 DRILL TRIP T Work BHA # 8. 07:45 08:30 0.75 91 91 PROD2 DRILL OTHR T Break Hycatog 6-3/4" bit (ser#117781), then download MWD, clean ri floor, inspect bit. 08:30 09:00 0.50 91 0 PROD2 DRILL PULD T Break and laydown Sperry Sun eoPilot TL-019, PU eoPilot TL 033. 09:00 09:15 0.25 0 91 PROD2 DRILL TRIP T Make up Sperry Sun geoPilot (ser # TL033). Make up same Hycalog 6-3/4" bit ser # 117781 . 09:15 10:00 0.75 91 91 PROD2 DRILL OTHR T Sperry Sun upload MWD. 10:00 10:30 0.50 91 912 PROD2 DRILL TRIP T Work BHA #9. Run in hole 6 stands of 4" drill i e. 10:30 11:00 0.50 912 912 PROD2 DRILL OTHR T Shallow test MWD. 11:00 11:30 0.50 912 912 PROD2 RIGMN SVRG T Wrap service loop on top drive. 11:30 15:00 3.50 912 8,052 PROD2 DRILL TRIP T Run in hole with 4"drill pipe. fill every 25 stands. Record PU and SO wei hts. 15:00 15:30 0.50 8,052 8,052 PROD2 DRILL PULD T Install 4" XT 39 x 4-1/2" IF crossover, Pickup Centurian circulating valve up from i e shed and make u . 15:30 16:30 1.00 8,052 9,848 PROD2 DRILL TRIP T Continue run in hole with BHA #9 on 5" drill pipe. Fill pipe every 25 stands. Record PU and SO wei hts. 16:30 17:00 0.50 9,848 9,848 PROD2 RIGMN SVRG T Service rig while filling pipe. Downlink eo ilot, ok. 17:00 18:30 1.50 9,848 11,828 PROD2 DRILL TRIP T Continue run in hole with BHA #9 on 5" drill pipe. Fill pipe every 25 stands. Record PU and SO wei hts. 18:30 21:00 2.50 11,828 13,298 PROD2 DRILL REAM T Ream to bottom because of no down weight. Rotating 60-80 rpm with torque 10k ft lbs. Rot wt 135k. 21:00 00:00 3.00 13,298 13,678 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 77.65. Max as 140 units. 02/14/2007 00:00 06:00 6.00 13,678 14,246 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 81.53. Max gas 100 units. Pumped a 25 bbl sweep 10.5 ppg, 170 vis sweep while drilling @ 14339'. Sli ht increase in cuttin s. 06:00 12:00 6.00 14,246 14,756 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 85.15. Max as 72 units. 12:00 18:00 6.00 14,756 15,388 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 88.68. Max gas 72 units. Pumped a 25 bbl 10.4 ppg, 150 vis sweep white drilling @ 15410'. Slight increase in cuttin s. 18:00 21:45 3.75 15,388 15,800 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 91.91. Max as 107 units. 21:45 23:45 2.00 15,800 15,928 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 91.91. Max gas 107 units. Pumped a 35 bbl 10.4ppg 150 vis swee while drillin 15928'. ~a~~ 1; ref ~ C~ Time Logs -- - Date From To ____Dur __S. Depth E. De th Pha~E _ Code __ Subcode T COM __ _ _ 02/14/2007 23:45 00:00 0.25 15,958 15,928 PROD2 DRILL REAM NP Start backreaming 3'/min, rotating 120rpm w/ 13k ft/Ib torque, pumping 340 gpm w/ 3400 psi, to clean up hole. Max ECD's 11.06 02/15/2007 00:00 02:00 2.00 15,928 15,765 PROD2 DRILL REAM NP Backreaming 3'/min to clean up hole. Circulated sweep out of hole. Circulated total of 1050 bbls. Surface to surface = 927 bbls. Max ECD's 11.06 ppg. Final ECD's = 10.68 ppg. Calculated clean hole 10.14 02:00 02:15 0.25 15,765 15,958 PROD2 DRILL REAM NP Ream two stands back to bottom. 02:15 02:30 0.25 15,958 15,958 PROD2 DRILL CIRC NP Take Slow pump rates. Cleaned suction on # 1 mud pump. Grease swival ackin . 02:30 06:45 4.25 15,958 16,236 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 94.01. Max as 59 units. 06:45 07:30 0.75 16,246 15,760 PROD2 DRILL TRIP T POOH to sidetrack @ 15800'. Out of top of "D" sands @ approx 15950'. 07:30 08:00 0.50 15,760 15,800 PROD2 DRILL REAM T Open hole sidetrack "D" lateral. Sidetracked 15800'. 08:00 12:15 4.25 15,800 16,246 PROD2 DRILL DDRL T Directional drill "D" lateral. Jar hrs 96.95. Total bit hrs 36.87. Max gas 92 units. 12:15 18:00 5.75 16,246 16,812 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 99.88. Total bit hrs 39.80. Max gas 110 units. 18:00 00:00 6.00 16,812 17,384 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 102.91. Total bit hrs 42.83. Max gas 110 units. 02/16/2007 00:00 05:00 5.00 17,384 17,779 PROD2 DRILL DDRL P Directional drill "D" lateral. Jar hrs 105.46. Total bit hrs 45.38, this run . Max gas 138 units. Pumped a 35 bbl hi vis (215) weighted sweep (10.4 ppg) while drilli~n 17752'. 05:00 05:45 0.75 17,779 17,779 PROD2 DRILL CIRC P Circulate till sweep inside of casing while backreaming. Rotating 120 rpm w/ 15k ft Ibs torque. Pumping 340 gpm w/ 3800 psi. ECD's 11.56-11.59 ppg. Clean hole calculated ECD's 10.65 . Surve TD. 05:45 07:00 1.25 17,779 17,667 PROD2 DRILL CIRC P Continue circulating while backreaming @ 3'/min pulling speed. Rotate 120 rpm w! 15k ft Ib torque. Pumping 340 gpm w/ 3800 psi until) sweep back to surface. ECD's down to 11.4 07:00 08:30 1.50 17,667 17,590 PROD2 DRILL CIRC P Continue circulating while backreaming @ 6'/min pulling speed. Rotate 120 rpm w/ 15k ft Ib torque. Pumping 350 gpm w/ 3850 psi While circulating 1 more bottom's up. Final ECD's 11.27 ~ e ~_-- , ~~ ~~ ®._~ _ _ n 1 i~~c;~~ ;3~J o~ • r~ f, Time Logs Date From To Dur S. Depth_ _E Depth Phase Code Subcode T COM __ 02!16/2007 08:30 12:00 3.50 17,590 15,107 PROD2 DRILL REAM P Backream out of hole every other stand. Pulling speed 45' per min, or as hole conditions would allow. Rotate 140 rpm w/14-15k ft Ib torque. Pumping 350 gpm w/ 3750- 3300 psi. ECD's @ 1545 hrs = 9.74 ppg @ 11895'. 12:00 18:00 6.00 15,107 10,244 PROD2 DRILL REAM P Continue to backream out of hole every other stand. Pulling speed 45' per min, or as hole conditions would allow. Rotate 140 rpm w/13-14k ft Ib torque. Pumping 350 gpm w/ 3300-3050 si. 18:00 18:45 0.75 10,244 10,048 PROD2 DRILL REAM P Continue to backream out of hole every other stand. Pulling speed 45' per min, or as hole conditions would allow. Rotate 140 rpm w/13-14k ft Ib torque. Pumping 350 gpm w/ 3300-3050 psi. ECD's 9.4 ppg @ 10048'. 18:45 20:30 1.75 10,048 10,048 PROD2 DRILL CIRC P Circulate and reciprocate pipe 60' while pumping a 35 bbl weighted (10.4 ppg) hi vis (214) sweep. Pump @ 350 gpm w/ 2950 psi, rotate 120 rpm w/ 6k ft Ib torque. Pump total of 850 bbls. Final ECD's = 9.45 20:30 20:45 0.25 10,048 10,048 PROD2 DRILL OWFF P Monitor well, static. Blow down top drive. 20:45 21:00 0.25 10,048 10,048 PROD2 RIGMN SFTY P Pre job safety meeting on slipping and cuttin 1-3/8" drillin line. 21:00 22:30 1.50 10,048 10,048 PROD2 RIGMN SVRG P Slip and cut 86' of 1-3/8"drilling line. Monitor well on tri tank. 22:30 23:00 0.50 10,048 10,048 PROD2 RIGMN SVRG P Service top drive. Check brakes on d rawworks. 23:00 00:00 1.00 10,048 11,828 PROD2 DRILL TRIP P Trip in hole. Fill pipe every 25 stands. Record PU and SO weights every 10 stands. 02/17/2007 00:00 02:00 2.00 11,828 12,800 PROD2 DRILL TRIP P Trip in hole. Fill pipe every 25 stands. Record PU and SO weights every 10 stands. 02:00 09:00 7.00 12,800 17,779 PROD2 DRILL REAM P Ream in hole because of no down weight. Pumping 150 gpm w/ 950-1000 psi. Rotating 70-90 rpm w/ 10-12k ft Ib. 09:00 10:30 1.50 17,779 17,779 PROD2 DRILL CIRC P Pump a 35 bbl weighted fti vis (10.4 ppg/210 vis) sweep to clean hole prior to displacing to SFOBM. With sweep above circ sub @ 9728', but not yet out of hole, shut down. 10:30 11:00 0.50 17,779 17,779 PROD2 DRILL OTHR P Drop a 2-1/8" steel ba-I to open the Centurian Circulation valve. Circ down @ 3 bpm w/ 1010 psi. Rotate string 70 rpm. Ball on seat @ 885 strokes. Pressure to 1500 psi, hold a minute, while increasing pressure to 2000 psi, valve shifted to open position @ 1850 si. ~~ ~m® ~~.._ ~ _ ~~. ~,~~~ 3t eat T l I l J Time Logs _ -- Date From To Dur Depth S E, Depth Phase Cody Subcode T - - COM 02/17/2007 - 11:00 __ - - 12:00 _ - 1.00 _ 17,779 17,779 _ ___ PROD2 DRILL CIRC P __ - - With valve open @ 9728', finish circulating sweep out of hole. Pumping 650 gpm w/ 2370 psi, then 750 gpm w/ 2710 psi, then 850 gpm w/ 3340 psi, then 875 gpm w/ 3400 psi. Rotating 120 rpm w/ 12-13k ft Ib for ue. 12:00 13:00 1.00 17,779 17,779 PROD2 DRILL OTHR P Drop a 2-1 /8" steel ball to close the Centurian Circulation valve. Circ down @ 3 bpm w/ 1010 psi. Rotate string 70 rpm. Ball on seat @ 880 strokes. Pressure to 1500 psi, hold a minute, continue to pressure to 2000 psi, then 2500 psi and @ 2940 psi the valve shifted closed. Pumped @ 350 gpm to confirm valve was closed by ressure/rate. 13:00 15:15 2.25 17,779 17,779 PROD2 DRILL CIRC P Displace well from 8.5 ppg OBM to 8.4 ppg SFOBM. Pumping 350 w/ 3950 psi. Rotate 130 rpm w/ 12-13 ft Ib for ue. 15:15 16:00 0.75 17,779 17,779 PROD2 DRILL OTHR P Drop a 2-1 /8" steel ball to open the Centurian Circulation valve. Circ down @ 3 bpm w/ 547 psi. Rotate string 70 r m. 16:00 16:30 0.50 17,779 17,410 PROD2 DRILL TRIP P Pull out of hole on elevators. Using trip tank to monitor hole fill. 16:30 17:45 1.25 17,410 15,830 PROD2 DRILL TRIP P Blow down top drive. Continue to pull out of hole on elevators. Monitor hole fill using trip tank. Quetionable proper hole fill. 17:45 18:15 0.50 15,830 15,830 PRODZ DRILL OTHR P Drop a 2-1/8" steel ball to close the Centurian Circulation valve, to be able to pump out of the hole due to questionable hole fill. Circ down @ 3 bpm w/ 180 psi. Rotate string 70 rpm. After valve closed, pumped @ 300 gpm to confirm valve was closed by pressure of 3750 psi. Downlink GEO PILOT to confirm Zero deflection. 18:15 00:00 5.75 15,830 8,052 PROD2 DRILL TRIP P Pull out of hole on elevators. Using trip tank to monitor hole fill. 8,052 PROD2 DRILL Note: Total of (4) 2-1 /8" balls were used to open and close Centurian Circ Sub ser No. SPS 6245. Balls were removed from ball catcher ser No. SPS 4986 when ulled out of hole. 02/18/2007 00:00 00:45 0.75 8,052 8,030 PROD2 DRILL PULD P Break and lay down Centurian Circulation Sub. Note: Total of (4) 2-1/8" balls were used to open and close Centurian Circ Sub ser No. SPS 6245. Balls were removed from ball catcher ser No. SPS 4986 when ulled out of hole. 00:45 04:45 4.00 8,032 362 PROD2 DRILL TRIP P Pull out of hole on elevators. Using trip tank to monitor hole fill. Record PU and SO wt's eve 10 stands. j t'~c~t~ ,'~~ t~~~ ~~ • • Time Logs Date From To ' Dur S. De th E Depth_Phase Code S~rbcode T COM _ 02!18/2007 04:45 05:00 0.25 362 362 PROD2 DRILL OTHR P Rig up skate on rig floor to lay down BHA #9. Clear and clean ri floor. 05:00 05:15 0.25 362 362 PROD2 DRILL SFTY P Pre job safety meeting on laying down BHA. 05:15 06:15 1.00 362 89 PROD2 DRILL PULD P Lay down BHA #9. 06:15 07:00 0.75 89 89 PROD2 DRILL OTHR P Download Sperry Sun MWD tools. 07:00 08:30 1.50 89 0 PROD2 DRILL PULD P Finish laying down BHA #9. Break and rade bit. 08:30 09:15 0.75 0 0 PROD2 DRILL OTHR P Clear and clean rig floor after wet trip SFOBM . 09:15 09:30 0.25 0 0 COMPZ CASIN( SFTY P PJSM on rigging up casing tools to run "D" lateral liner. 09:30 10:00 0.50 0 0 COMPZ CASIN( RURD P Rig up to run "D" lat Plop and drop 4-1/2" slots and blanks 10:00 10:15 0.25 0 0 COMPZ CASIN( SFTY P Pre job safety meeting on running liner. 10:15 15:30 5.25 0 7,500 COMPZ CASIN PUTB P PU/MU/RIH w/ 4-1/2" 11.6 ppf L-80 BTC slots and blank "Plop and drop" liner for the "D" lateral. MU baker setting sleeve. Record PU and SO wt's. PU wt 112k, SO wt 88k. 15:30 16:30 1.00 7,500 8,283 COMPZ CASINC RUNL P Change out slips and elevators, install crossover to dp, run 3 stands of 4"drill pipe, change elevators and slips, install crossover and make up one stand of 5" dp. Record PU, SO and rotating weight. PU 125k, SO 90k, Rot @ 30 rpm w/ 4500 ft Ib torque and Rot wt 110k. 16:30 18:45 2.25 8,283 12,300 COMPZ CASINC RUNL P Continue running 4-1 /2" 11.6 ppf slots and blank liner in the hole on 5"drill pipe. Record PU and so wt's every 5 stands. Make top drive connection every 10 stands to record PU,SO and Rot wt and Rot tro ue. 18:45 00:00 5.25 12,300 16,100 COMPZ CASINC RUNL P Continue running liner on 5"drill pipe. Ran out of down weight @ 12,300'. Start rotating liner in the hole. Recording PU and So weights every 5 stands. Rotatin 60' er min 30 r m 02/19/2007 00:00 06:00 6.00 16,100 17,750 COMPZ CASIN RUNL P Continue rotating "D" lateral liner in the hole. Recording PU and SO weights every 5 stands. Rotating 30 to zero rpm, torque 16k- as much as 20k ft Ibs by time we got to setting depth. On bottom: PU wt 300k, SO wt none, Rotating wt 155k w/ 30 rpm & 20k ft Ibs of torque, Rotating while working down 115k. Note: Rotating @ max torque, speed of travel de endent on hole conditions. ®m ~~~ ~_ z ~s;~ ~3 ~f • Time Logs _ _ Date -_._-_ From To Dur S. De th E. De th Phase _ Code Subcode T _COM 02/19/2007 06:00 06:45 0.75 17,750 17,750 COMPZ CASINC OTHR P Drop 29/32" ball, circ ball down w/ liner on depth. Shoe @ 1775.32'. Pump 4 bpm w/ 500 psi for 1000 strokes, slow pumps to 3 bpm w/ 370 si until ball on seat 1900 strokes . 06:45 07:00 0.25 17,750 10,255 COMPZ CASINC OTHR P With ball on seat, pressure to 2500 psi, slack off 20k on HR setting tool. Bleed off pressure. PU, not released, Set down again, pressure back up to 2500 psi, bleed off pressure. PU and indicated release w/ PU wt of 240-245k. Lost liner weight. Top of liner 10254.73' 07:00 07:30 0.50 10,255 10,247 COMPZ CASINC OTHR P PU 5'. Pressure up to 4300 psi w/ rig pumps to blow ball seat. Did not shear. Bleed and try again, no good. Lay down single. Rig up test pump and blow ball seat w/ 4400 si. 07:30 07:45 0.25 10,056 10,056 COMPZ DRILL TRIP P Pull two stands plus 36' to circ and wash slot area on the whi stock. 07:45 09:30 1.75 10,247 10,056 COMPZ DRILL CIRC P Circ @ 630 gpm w/ 2700 psi. Hole appeared to be taking some fluid, slowed pumps to 500 gpm w/ 1600 psi., increased rate to 540 gpm w/ 1940 psi. Circ two bottoms up. Note: Hole a eared to be dirt . 09:30 16:45 7.25 10,056 300 COMPZ DRILL TRIP P Monitor well. Pull out of hole with liner running tools. Record PU and SO weight's. Nore: @ 9970': PU wt 245k, SO wt 85k. 16:45 17:30 0.75 300 0 COMPZ DRILL PULD P Change elevators to 4", stand back 3 stands of 4" DP, Lay down Baker liner runnin tools. 17:30 18:15 0.75 0 0 COMPZ FISH PULD P Change elevators to 5". Clear and clean rig floor. PU to the rig floor Baker fishing jars, bumper sub and retrieval hook for the whi stock. 18:15 19:15 1.00 0 62 COMPZ FISH PULD P MU Baker fishing tools to pull Whi stock. 19:15 00:00 4.75 62 9,092 COMPZ FISH TRIP P Trip in hole w/ hook to retrieve Whipstock for the "D" lateral. Record PU and SO wt's every 10 stands. Fill ie 02/20/2007 00:00 01:15 1.25 9,092 10,056 COMPZ FISH TRIP P Continue trip in hole w/ hook to retrieve Whipstock for the "D" lateral. Record PU and SO wt's every 10 stands. Fill i e. 01:15 02:45 1.50 10,056 10,056 COMPZ FISH CIRC P Circulate and wash slot while circulate two bottm's up to clean up Solids Free Oil Base Mud. Initial PU wt 230-240k, SO wt 90-95k. Final PU wt 225-230k. Hole took approx 19 bbls while circulating. Note: Friction factors seem to be hi h. • I Time Logs - - ~' Date From To Dur - S. De th -- E. Depth - - Phase - Code _--- Subcode T _ --__ __ COM 02/20/2007 02:45 03:45. 1.00 10,056 10,056 COMPZ FISH FISH P Engage whipstock slot w/ retieval tool. Initially jar @ 280k, pull to 310K, increase in stages to jarring @ 310k, pulling to finally pulled free @ 335k after numerous attem ts. 03:45 04:30 0.75 10,056 10,017 COMPZ FISH CIRC P Pull stand # 104 out of hole. Circulate @ 550 gpm w/ 2400 psi f/ 350 bbls, slow rate to 500 gpm w/ 2000 psi. Circulate one bottom's up. Hole took 18 bbfs while circulatin . 04:30 12:00 7.50 10,017 182 COMPZ FISH TRIP P POOH w/ Whipstock f/ "D" lateral. Record PU wt's eve 10 stands. 12:00 14:15 2.25 182 0 COMPZ FISH PULD P Break and lay down fishing assembly. La dwon whistock assembl . 14:15 16:00 1.75 0 0 COMPZ FISH PULD P Clear and clean rig fllor. Lay down tools from ri floor. 16:00 16:15 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on picking up and making up Baker PZ hook hanger assembl for the "D" lateral. 16:15 19:45 3.50 0 272 COMPZ RPCOh RCST P PU/MU Baker PZ hook hanger assembly for the "D" lateral. MU inner string 3 -1/8" super slim MWD tools. MU PZ hook hanger and orient to MWD. 19:45 20:30 0.75 272 272 COMPZ RPCOh RURD P Rig down GBR casing tools and Baker Oil tools equipemt. Clear rig floor of tools. 20:30 20:45 0.25 272 371 COMPZ RPCOb TRIP P RIH w/ Baker 9-5/8" x 5-1/2" PZ hook Hanger crossed over to 4-1/2" 11.6 ppf L-80 BTC on 5"drill i e. 20:45 22:15 1.50 371 371 COMPZ RPCOh OTHR P Shallow test super slim MWD. Pumping 90 gpm w/ 310 psi, 100 gpm w/ 350 psi, 110 gpm w/ 420 psi, 120 gpm w/ 500 psi, 135 gpm w/ 580 psi and 145 gpm w/ 610 psi. No success-- noise? 22:15 23:00 0.75 371 1,262 COMPZ RPCO TRIP P Btow down top drive. Trip in the hole to t at a dee er de th. 23:00 23:45 0.75 1,262 12,625 COMPZ RPCO OTHR T Shallow test Super slim MWD. Pumping 115 gpm w/ 440 psi, 140 gpm w/ 660 psi, 155 gpm w/ 770 psi. Still no ood detection. 23:45 00:00 0.25 12,625 968 COMPZ RPCOh TRIP T POOH to change out Sperry Sun MWD. 02/21/2007 00:00 00:45 0.75 968 272 COMPZ RPCO TRIP T POOH to change out Sperry Sun MWD. 00:45 01:15 0.50 272 272 COMPZ RPCOh RURD T RU GBR casing tools and Baker Oil tools small ton s 01:15 01:30 0.25 272 272 COMPZ RPCOh SFTY T PJSM on breaking PZ hook hanger and changing out Sperry Sun MWD in the inner strip . 01:30 03:15 1.75 272 272 COMPZ RPCOh OTHR T Break out Hook Hanger, Break Sperry Sun super slim 3-1/8" MWD and lay down. ~ ~ ~ m e 3 ~~~ s~cX LTgb J~:3 [}f r~ • Time Logs Date From To Dur S Depth E Depth Phase _Code Subcoc~e T COM 02/21/2007 03:15 04:15 1.00 272 272 COMPZ RPCOh OTHR T PU and Make up another Sperry Sun 3-1/8" super slim MWD tool. (Tool brou ht over from Do on Ri 141 . 04:15 04:45 0.50 272 272 COMPZ RPCOh RURD T Rig down GBR tools and baker tools. Clean and clear ri floor. 04:45 05:00 0.25 272 667 COMPZ RPCOb TRIP T Trip in the hole w/ 5"drill pipe and Hook han er assembl . 05:00 07:00 2.00 667 667 COMPZ RPCOIL OTHR T Shallow pulse test Sperry Sun super slim MWD. Pumping 75 gpm w/ 250 psi, 85 gpm w/ 300 psi, 95 gpm w/ 350 psi, 110 gpm w/ 370 psi. Still no detection. 07:00 07:45 0.75 667 272 COMPZ RPCOh TRIP T Blow down top drive. Pull hook hanger assembl out of the hole. 07:45 08:00 0.25 272 272 COMPZ RPCOh OTHR T Pulse test MWD tool w/ tool at the surface. Pumping 120 gpm. No test. Discovered fluid leaking past the upper cup of inner string. Cup is in the 4' 4-1/2" 12.6 ppg L-80 pup below the hook han er. 08:00 09:30 1.50 272 272 COMPZ RIGMN SVRG T Service rig and top drive. Change out filter in the drawworks while waiting on parts from Baker Oil Tools. (Will try to rebuild cu on location. 09:30 11:00 1.50 272 272 COMPZ RPCOh OTHR T Break hook hanger @ the crossover below hook hanger. Visual inspection of the 4.15" OD cup appeared OK. Changed the cup. Check MWD for debris, OK. Make up the cup and MWD. 11:00 11:15 0.25 272 272 COMPZ RPCOh RCST T Make up the hook hanger assembly w/inner string to the rest of the assembl . 11:15 11:30 0.25 272 272 COMPZ RPCOti OTHR T Pulse test Sperry Sun MWD. Good test (Detection) while pumping 100 m w/ 390 si. 11:30 12:00 0.50 272 272 COMPZ RPCO OTHR T Change out the elevators to 5" While cleaning and clearing tools from the rig floor. 12:00 12:30 0.50 272 1,262 COMPZ RPCOh TRIP T Run Hook hanger assembly in the hole on 5"drill pipe. Running speed 120'/min. Record PU and SO wt's eve 5 stands. 12:30 13:15 0.75 1,262 2,255 COMPZ RPCOI~ TRIP P Continue to RIH w/ Hook hanger assembly on 5" drill pipe. Record PU and SO wt's eve 5 stands. 13:15 13:30 0.25 2,255 2,255 COMPZ RPCO11 CIRC P Fill pipe. Check detection of Sperry Sun 3-1/8" super slim MWD tool. Pumping @ 100 gpm w/ 440 psi. Good test. Blow down to drive. 13:30 15:00 1.50 2,255 5,223 COMPZ RPCO11 TRIP P Continue to RIH w/ Hook hanger assembly on 5" drill pipe. Record PU and SO wt's eve 5 stands. 15:00 15:30 0.50 5,223 5,223 COMPZ RPCOh CIRC P Fill pipe. Check detection of Sperry Sun 3-1/8" super slim MWD tool. Pumping @ 100 gpm w/ 500 psi. Good test. Blow down to drive. ____._~ ,~e.® e _. ®®® ~_ 1 ~'~c~~ 3~ of ~~ Time Logs __-- _ _ _ ---- - ,_Date__ From To - -- - Dur ___ - - S,_De th E Depth Phase Code Subcode T COM_ _- - - - -_ 02/22/2007 01:15 02:00 0.75 10,313 10,313 COMPZ RPCOPo CIRC P Inflate 4-1/2" ECP. Pressure to 1500 psi, then to 2200 psi, 2400 psi, 2600 psi, then @ 2800 psi valve opened to fill ESP. The difference of strokes @ 1500 psi to 2800 psi = 9 strokes (.9 bbls= 38 gals to fil-, hole size 9".). Once filled, pressure decreased to 1150 psi and held. Bleed off pressure. Repressure to 1000. Bleed off ressure. 02:00 02:45 0.75 10,313 10,030 COMPZ RPCOh TRIP P Pickup and lay down single on top of stand 104. POOH 3 stands of 5" HWDP. PU wt 225k to 240k. 02:45 04:45 2.00 10,030 10,030 COMPZ RPCOh CIRC P Finish circulating a bottom's up. Figured that 1400 strokes were pumped while orienting and circulating prior to dropping ball, 1490 strokes were pumped while pumping ball down to seat, finish by circulating another 300 lus bbls. 04:45 05:00 0.25 10,030 10,030 COMPZ RPCOh OWFF P Monitor well. Slight returns @ flowline. Possible mud out of balance. 05:00 05:30 0.50 10,030 10,030 COMPZ RPCOh CIRC P Continue circuating @ 115 gpm w/ 250 si. 05:30 05:45 0.25 10,030 10,030 COMPZ RPCOh OWFF P Monitor well. Static. 05:45 09:15 3.50 10,030 8,355 COMPZ RPCOM1 TRIP P Pump out of hole due to hole appearing to be swabbing. Pulling out w/ Baker H.H. running tools and inner string.Pumping 20 spm w/ 210 psi. Monitoring hole fill via the active mud s stem Pit #5 . 09:15 16:00 6.75 8,355 260 COMPZ RPCOh TRIP P Blow down top drive. Continue pulling out on elevators, using trip tank to monitor displacement. Inspect super sliders and Lo-Tads. Record PU and SO wt eve 5 stands. 16:00 17:30 1.50 260 0 COMPZ RPCOh PULD P Change elevators to 3-1/2". Lay down baker runnin tool and inner strin . 17:30 19:00 1.50 0 0 COMPZ DRILL OTHR P Clean and clear rig floor. Bring 4" XT39 thread rotectors to the floor. 19:00 19:30 0.50 0 0 COMPZ DRILL RURD P Rig up to laydown 4" XT39 drill pipe from derrick via mousehole. in the rota table. 19:30 00:00 4.50 0 0 COMPZ DRILL PULD P Laydown 41 stands of 4"drill pipe from derrick. There are a total of 82 stands to be la ed down. 02/23/2007 00:00 03:00 3.00 0 0 COMPZ DRILL PULD P Laydown last 41 stands of 4" drill pipe from derrick. There was a total of 82 stands la ed down. 03:00 03:30 0.50 0 0 COMPZ DRILL OTHR P Remove mousehole from rotary table, Chan a elevators and clean ri floor. 03:30 04:00 0.50 0 0 COMPZ RPCOh SFTY P PJSM on running PZ LEM for "D" lateral hook han er. 04:00 04:15 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meeting for PU/MU LEM w! Baker Oil tool, GBR and S er Sun. . r ~ ~m~ _® ®~~_n F~~~ :3,~~ tsf n Time Logs Date From To Dur S. Depth E_ Depth Phase Code Subcode__T COM __ 02/23/2007 04:15 07:00 2.75 0 230 COMPZ RPCO PULD P PU/MU 4-1/2" PZ LEM assembly f/ "D" lateral. MU Sperry Sun 3-1/8" Super Slim MWD, orient w/ Baker LEM (High side oriented to the center of the window of the LEM). MU Baker 9-5/8" x 7" ZXP liner top aaker. 07:00 07:45 0.75 230 230 COMPZ RPCOti OTHR P Mix and install Pal mix in the liner top packer. 07:45 08:00 0.25 230 230 COMPZ RPCOh OTHR P Shallow test Sperry Sun Super slim MWD. Pumping 20 spm (85 gpm) w/ 340 psi. Pumping 24 spm (100 gpm) w/ 400 psi. Pumping 26 spm (110 m w/ 460 m. 08:00 09:30 1.50 230 2,213 COMPZ RPCOb TRIP P RIH w! 4-1/2" PZ LEM for the "D" lateral, on 5" drill pipe from the derrick. Record PU and SO wt's. 09:30 09:45 0.25 2,213 2,213 COMPZ RPCOh CIRC P Fill pipe. Check Sperry MWD, OK. 09:45 10:15 0.50 2,213 2,213 COMPZ RPCOh SFTY P Blow down top drive. Conduct a full H2S drill. Alarms on rig went off. All OK. Electrician checking out false alarm. 10:15 11:30 1.25 2,213 4,193 COMPZ RPCOh TRIP P RIH w/ the 4-1/2" PZ LEM assembly for the "D" lateral, on 5"drill pipe from the derrick. Record PU and SO wt's. 11:30 11:45 0.25 4,193 4,193 COMPZ RPCOM1 CIRC P Fill pipe. Check Sperry MWD, OK. Blow down to drive. 11:45 12:45 1.00 4,193 6,132 COMPZ RPCOh TRIP P RIH w/ the 4-1/2" PZ LEM for the "D" lateral, on 5" drill pipe from the derrick. Record PU and SO wt's. 12:45 13:00 0.25 6,132 6,132 COMPZ RPCOti CIRC P Fill pipe. Check Sperry MWD, OK. Blow down top drive. Pumping 24 spm 100 m w/ 540 si. 13:00 14:45 1.75 6,132 8,887 COMPZ RPCOh TRIP P Blow down top drive. RIH w/ LEM for the "D" lateral, on 5"drill pipe from the derrick. Record PU and SO wei ht's. 14:45 15:30 0.75 8,887 8,887 COMPZ RPCOh OTHR P Fill pipe. Check Sperry MWD, OK. Blow down top drive. Pumping 24 spm (100 gpm) w/ 600 psi. Max gas observed was 23 units. Not: Had trouble um in out tri tank. 15:30 16:30 1.00 8,887 9,992 COMPZ RPCOh TRIP P RIH w/ LEM for the "D" lateral, on 5" drill pipe from the derrick. Record PU and SO wei ht's. 16:30 17:45 1.25 9,992 10,007 COMPZ RPCOh SRVY P Fill pipe, establish circulation @ 100 gpm w/ 650 psi. With seals above Hook Hanger, orient LEM from initial of 118 right to 46 left. Work torque down to MWD. PU wt without circ 235k, SO wt 102K. While circulating: PU wt 245k, SO wt 100k. 17:45 18:00 0.25 10,007 10,082 COMPZ RPCOh TRIP P While circualting, run in hole past the top of the Hook Hanger (top @ 10048.5' 18:00 18:15 0.25 10,082 10,174 COMPZ RPCOh TRIP P RIH w/ stand # 103 on elevators. PU wt 245k, SO wt 105-108k. ~a~e 3~ ~t ~ l J i Time Los ~ 9-- -- _ _ _ -- _ _ ; Date From To Dur S. De th E. De t_h _P Phase_ - Code_ _Subcode T_ COM __ --- 02/23/2007 18:15 19:30 1.25 10,174 10,211 COMPZ RPCO6 TRIP P Make a top drive connection on stand # 104. Pumping 24 spm (100 gpm) w/ 630 psi, 25 spm (105 spm) w/ 680 psi. While circulating: PU wt 245k, SO wt 100-105k. MWD showing 43 to 40 left. Slack off and mule shoe went into "B" lateral CSR @ 25' in, seals went in @ 27' in, Weight indicator indicating seals in receptacle w/down wt 98-100k. PU wt 250k. Slacked off to 33' in, PU wt while pumping is 250k, SO wt 100k, MWD indicating 43 left. Appeared to tag @ 35.3' in (on depth) 36' in with 20k set down). MWD moved to 23 left. 19:30 20:00 0.50 10,211 10,212 COMPZ RPCOh OTHR P PU and set down twice with snap in and out. MWD changed f/ 17 left to 6 right. PU became 265k when snapping out (15k over pull). Pumping 25 spm w/ 680 psi. Good indication of LEM in osition. 20:00 21:15 1.25 10,212 10,212 COMPZ RPCOh OTHR P Snap out and PU to break connection and drop the 1-3/4" ball to set the ZXP @ 9988.87'and release from the LEM assembly. Slack back off to 36 1/2' in on stand 104 w/MWD reading 6 Right. Pumping ball down @ 110 gpm w/ 700 psi for 1200 strokes, slow pumps to 15 spm w/ 480 psi. Ball on seat 1490 strokes. 21:15 21:30 0.25 10,212 10,212 COMPZ RPCOh PACK P Pumping to set ZXP, neutralize pusher tool and release LEM. Stage pressure up to 1000 psi then 500 psi increments to 4000 si. 21:30 22:00 0.50 10,212 10,212 COMPZ RPCOh DHEQ P With ZXP packer set @ 9988.87', test 9-5/8" x 5" dp annulus to 2500 psi. Use upper pipe rams, pumping through the kill line. Hold the test f/ 5 min after pumps were shut in.. Good test. Chart test. 22:00 22:15 0.25 10,212 10,207 COMPZ RPCOti OTHR P PU above top of ZXP with the dog sub, Slack off and tag top on depth with the do sub. OK. 22:15 22:45 0.50 10,207 10,174 COMPZ RPCOti TRIP P Continue to POOH and break off stand # 104. Blow down to drvie. 22:45 23:00 0.25 10,174 10,082 COMPZ RPCOh TRIP P Pull stand 103 out of the hole w/ running tools for the 4-1/2" PZ LEM assembl . 23:00 00:00 1.00 10,082 10,082 COMPZ RIGMN SVRG P Slip and cut 146' of 1-3/8"drilling line. Ad~ust brakes. Ins ect crown-o-matic. 02/24/2007 00:00 01:45 1.75 10,082 10,082 COMPZ RIGMN SVRG P Continue to slip and cut 146' of 1-3/8" drilling line. Adjust brakes. Inspect crown-o-matic. service automatic driller. 01:45 04:15 2.50 10,082 8,505 COMPZ RPCOh TRIP P Pump out of hole. Pumping 120 gpm w/ 240 psi. Pulling speed 45'/min. Monitor well on it #5 active. m~~~~ _v ~ ~'~a~ ~C~ ref ~5 { ..-J Time Logs ~ --- - - -- Date From To__ Dur___ S_Depth E. De th Phase Code_ 8ubcode T COM _-- ----- 02/24/2007 04:15 05:00 0.75 8,505 8,125 COMPZ RPCO TRIP P POOH on elevators. Monitor well on tri tank. Incorrect hole fill. 05:00 05:45 0.75 8,125 7,557 COMPZ RPCOh TRIP P Pump out of hole. Pumping 120 gpm w/ 200 psi. Pulling speed 45'-60'/min. Monitor well on it # 5 active. 05:45 06:45 1.00 7,557 7,081 COMPZ RPCOh TRIP P POOH on elevators. Monitor well"on tri tank. Incorrect hole fill. 06:45 09:30 2.75 7,081 5,560 COMPZ RPCOti TRIP P Pump out of hole. Pumping 120 gpm w/ 200 psi. Pulling speed 90'-120'/min. Monitor well on it # 5 active. 09:30 10:00 0.50 5,560 5,560 COMPZ RPCOh TRIP P Monitor well on trip tank. Clean and clear ri floor. 10:00 10:30 0.50 5,560 5,180 COMPZ RPCOh TRIP P POOH on elevators. Monitor well on tri tank. Hole fill OK. 10:30 12:15 1.75 5,180 4,191 COMPZ RPCOti TRIP P POOH on elevators. Monitor well on trip tank. Remove Lo Tads from 10 stands of 5" dp. Stand stands back in derrick. 12:15 12:45 0.50 4,191 4,191 COMPZ RPCOh CIRC P Rig up to lay down 5" drill pipe to pipe shed. Remove 10 LoTads from rig floor. Drop the Haggard (Mud Dog) ID drill i e wi er inside the 5" drill i e. 12:45 13:00 0.25 4,191 4,191 COMPZ RPCOh SFTY P Pre job safety meeting on laying down 5"drill i e to the i e shed. 13:00 15:00 2.00 4,191 3,203 COMPZ RPCOi1 TRIP P Continue to POOH on elevators, lay down 5"drill pipe. Monitor well on trip tank. Remove Lo Tads and Super sliders from the 5" d . 15:00 15:30 0.50 3,203 3,203 COMPZ RPCOh PULD P Remove Lo-tads from rig floor. 15:30 16:45 1.25 3,203 2,213 COMPZ RPCOti TRIP P Continue to POOH on elevators, lay down 5"drill pipe. Monitor well on trip tank. Remove Lo Tads and Super sliders from the 5" d . 16:45 17:30 0.75 2,213 2,213 COMPZ RPCOh PULD P Remove Lo- tads from rig floor. 17:30 18:00 0.50 2,213 1,718 COMPZ RPCOh TRIP P Continue to POOH on elevators, lay down 5"drill pipe. Monitor well on trip tank. Remove Lo Tads and Super sliders from the 5" dp. Calculated displacement to this depth = 86.77 bbls, actual dis lacement 91.5 bbls. 18:00 18:30 0.50 1,718 1,222 COMPZ RPCOh TRIP P Continue to POOH on elevators, lay down 5"drill pipe. Monitor well on trip tank. Remove Lo Tads and Super sliders from the 5" d . 18:30 19:15 0.75 1,222 12,222 COMPZ RPCOti PULD P Remove 5"drill pipe from pipe shed. Clear rig floor of super sliders and LoTads. 19:15 21:15 2.00 1,222 0 COMPZ RPCOh TRIP P Continue to POOH on elevators, lay down 5" drill pipe. Monitor welt on trip tank. Remove Lo Tads and Super sliders from the 5" dp. Calculated displacement for the whole trip is 95.09 bbls, actual fill 102.5 bbls = 7.41 over calculated. ~~~ ~~.~ F'~~~ ~; ~ z~# ~ Time Logs Date From To Dur S. De th E. De th Phase Code_ Subcode T COM _ _ __ __ _ ~ 02/24!2007 21:15 22:15 1.00 0 0 COMPZ RPCO PULD P Remove 5" drill pipe from pipe shed. Clear rig floor of super sliders and LoTads. 22:15 22:45 0.50 0 0 COMPZ RPCOh RURD P Rig up to break and lay down LEM runnin tools and inner strin . 22:45 23:45 1.00 0 0 COMPZ RPCOh PULD P Break and lay down Baker LEM running tools and Sperry Sun Super slim 3-1/8" MWD. 23:45 00:00 0.25 0 0 COMPZ RPCOh RURD P Rig down tools to break and handle LEM. 02/25/2007 00:00 00:45 0.75 0 0 COMPZ RPCOh PULD P Lay down tools for LEM. 00:45 01:15 0.50 0 0 COMPZ RPCOh OTHR P Drain stack, Pull wear bushing. 01:15 02:15 1.00 0 0 COMPZ RPCOh RURD P Rig up to run 4-1 /2" 12.6 ppf L-80 IBT-m com letion. 02:15 02:30 0.25 0 0 COMPZ RPCO SFTY P Pre job safety meeting to run 4-1 /2" 12.6 f L-80 IBT-m com letion. 02:30 06:45 4.25 0 4,661 COMPZ RPCOh RCST P PU/MU/RIH w/ 4-1/2" 12.6 ppf L-80 IBT-m completion. 149 joints in the hole. Record PU and SO wt's every 15 joints. Monitor displacement on trip tank. 06:45 07:30 0.75 4,661 4,661 COMPZ RPCOh RCST P Clear rig floor. Service pipe skate. 07:30 12:00 4.50 4,661 9,599 COMPZ RPCOti RCST P Continue PU/MU/RIH w/ 4-1/2" 12.6 ppf L-80 IBT-m completion. Record PU and SO wt's every 15 jts. Ran out of down weight w/ 6' in on jt # 310. Pull jt # 310 out of the hole. Monitor hole dis lacement on tri tank. 12:00 12:45 0.75 9,590 9,590 COMPZ RPCOh RURD T Rig up to circulate through 2" circulating hose. Jt # 309 in the hole. Ran out of down weight 6' in on jt # 310'. 12:45 15:00 2.25 9,590 9,575 COMPZ RPCOh CIRC T Circulate w/ 8.5 solids free oil base mud to try and gain down weight/ clean hole. Stage pumps up to 14 bpm w/ 1990 psi. No mud losses. PU wt 135k, no down (Blocks/TD 70k) 30 spm 250 psi, 40 spm w/ 310 psi, 50 spm w/ 380 psi, 60 spm w/ 450 psi, 70 spm w/ 580 psi, 80 spm w/ 780 psi, 90 spm w/ 990 psi, 100 spm w/ 1160 psi, 110 spm w/ 1340 psi, 122 spm w/ 1570 psi, 140 spm w/ 1990 si. 146 s m 2060 si. 15:00 17:00 2.00 9,575 9,965 COMPZ RPCOh RCST T Working completion string in the hole. Jt # 321 in the hole. 17:00 17:15 0.25 9,965 9,965 COMPZ RPCO RURD T Rig up to circulate on jt # 322 with jt # 321 in the hole. 17:15 18:45 1.50 9,965 9,965 COMPZ RPCOti CIRC T Circulate @ 9965' w/ 140 spm (598 gpm) w/ 2010 psi. Attempt to work pie down. No success. No fluid losses. 18:45 19:30 0.75 9,965 9,965 COMPZ RPCOh OTHR T Rig down circ line. Break off crossover on tubing. Change elevators to 5". Lay down 't # 322. __ a , .~~ ®~ __________ s~.~..~_ ~~~~ ~~ ~t~ J C Time Logs -- ___ Da_t_e_____ From To Dur S. De th E Depth Phase Code Subcode T COM _--- 02/25/2007 19:30 19:45 0.25 9,965 9,965 COMPZ RPCOh RCST T Latch a stand of 5" HWDP, MU crossover f/ 4-1/2" IF to 4" XT39, crossover f/ 4" XT39 to 4-1 /2" IBT. Attempt to work down. No go. Screw into tubin strin . 19:45 20:15 0.50 9,965 9,965 COMPZ RPCOh SFTY T Pre job safety meeting on displacement f/ 8.5 ppg SFOBM to 8.6 MOBM. 20:15 21:30 1.25 9,965 9,965 COMPZ RPCOh CIRC T Displace to 8.6 ppg MOBM. Circulate @ 140 spm (14 bpm) w/ 1650 psi. PU wt 140k. No down weight. Slow down to 425 gpm w/ 930 psi after 3450 strokes. After circualting 6000 strokes, gained some down wt. Slacked off w/ 85K down wt to 13' in on stand. Tagging up pretty solid. (Top of ZXP packer, although 10' high). PU wt 148k, SO wt 85-90k w/ um son. 21:30 22:15 0.75 9,965 10,018 COMPZ RPCOM1 RCST T Worked pipe (PU wt 140k, SO wt 80K-70K) and finally got by the top of the ZXP. Continued down and saw seals take weight when going into the CSR w/ 35.8' in (again 10' high). Located with 52' in on stand. Mule shoe depth of 10017.84'. Repeat indications with pumps off. All tags appear that tubing tally is 10' shallow of LEM tally, but tag increments, are ri ht. 22:15 23:30 1.25 10,018 10,014 COMPZ RPCO HOSO P PU, break off stand of 5", Change elevators, Blow down top drive. Lay down tubing joints 321 and 320. PU tubing jt # 336(original tally), then a 5.83' pup, then jt # 337(original tally), MU Vetco Gray hanger and landing joint. Land tubing string @ 2330 hrs, s aced out 4' above full located. 23:30 00:00 0.50 10,014 10,014 COMPZ WELCT OTHR P RILDS on tubing hanger. Test upper body seals on hanger to 5000 psi f/ 10 min. Test lower body seals to 5000 psi f/ 10 min. Good test. 02/26/2007 00:00 00:30 0.50 10,014 0 COMPZ WELCT OTHR P Pull and lay down landing joint. PU "T" bar and install BPV. 00:30 01:15 0.75 0 0 COMPZ RPCOh RURD P Rig down equipment to run com letion. Clear and clean ri floor. 01:15 01:45 0.50 0 0 COMPZ RPCO PULD P Rig up to laydown 5"drill pipe from the derrick. via mousehole in rota table. 01:45 02:00 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meting on laying down drill i e. 02:00 11:00 9.00 0 0 COMPZ RPCOh PULD P Lay down 5"drill pipe f/ derrick, in mousehole. Blow down Sperry SunGeo Pilot skid. Hang cement line backu in derrick. Cleanin its. 11:00 15:00 4.00 0 0 COMPZ RPCOti NUND P Nipple down BOPE. Preparing mud um s f/ ri move. Cleanin its. 15:00 16:30 1.50 0 0 COMPZ RPCOh NUND P NU Vetco gray 4-1/8" 5m tree. Cleanin its. ~.._~ ~ ~ ®~ ~~~e Zvi ~f ~ ~~ Time Logs Date From To Dur 5. De th E. De th Phase Code Subcode T COM _ 02/26/2007 16:30 17:30 1.00 0 0 COMPZ RPCO _ DHEQ P __ Set TWC. Pressure test neck seal void to 5000 psi. Test tree to 250 psi f/ 10 min. OK. Test tree to 5000 psi f/ 10 min. OK. Bleed off pressure. Cleaning its. 17:30 18:00 0.50 0 0 COMPZ RPCOb RURD P Pull TWC with Vetco Gray, RU to freeze protect/ displace 8.6 ppg MOBM from well. 18:00 20:45 2.75 0 0 COMPZ RPCOh RURD P RU to freeze protect/ displace 8.6 ppg MOBM from well. Cleanin its. 20:45 21:15 0.50 0 0 COMPZ RPCOti SFTY P PJSM with all involved parties on dis lacement of well to diesel. 21:15 00:00 2.75 0 0 COMPZ RPCO FRZP P Little Red pressure test lines to 2500 psi. Start pumping @ 2 bpm w/ 375 psi., 7 bbls to fill lines to mud pits. Increase rate to 4 bpm w/ 600 psi. Total of 536 bbls um ed midni ht. 02/27/2007 00:00 03:00 3.00 0 0 COMPZ RPCOh FRZP P Little Red pumping down tubing with diesel @ 4 bpm w/ 620-530 psi., while holding 140 to 340 psi back pressure through choke. Little Red bbl counter 871 bbls total, although only 830 bbls were brou ht to work with. 03:00 03:30 0.50 0 0 COMPZ RPCOh FRZP P Blow down all lines. Blow down choke manifold & lines. Rig down Little Red Services. 03:30 04:45 1.25 0 0 COMPZ RPCO OTHR P Rig up Vetco Gray lubricator. Install BPV as per Vetco rep. Rig down Lubricator. Shut in pressures =Tubing = 400 PSI, Upper annulus = 350 PSI, Lower annulus = 155 PSI. 04:45 06:00 1.25 0 0 COMPZ RPCOh OTHR P Secure tree & valves. Clean out cellar box & wipe off tree. Clean around cellar box. Clean pits, and clean out OBM from rig floor drip pans & floor area. Crew Chan e 06:00 10:00 4.00 0 0 COMPZ MOVE DMOB P Continue cleaning drip pans. Install strong backs in pipe shed. continue cleaning pits. Blow down all centrifugal um s, mud um s & lines. 10:00 11:15 1.25 0 0 COMPZ MOVE DMOB P Change out saver sub. Continue cleaning drip pans & pits. Prep mud pumps for rig move. Rig off of Hi Line ower 1100 HRS. 11:15 12:00 0.75 0 0 COMPZ MOVE DMOB P Pull new flush mounted casing slips to rig floor. Obtain measurements for installation. Continue cleaning pits & rockwasher. 12:00 14:00 2.00 0 0 COMPZ MOVE DMOB P Continue cleaning pits. Modify drip pan area with welder for installation of flush mounted slips & removal of surface stack riser. Rig down flowline, choke line, and mud lines. n ~~ Time Logs Date From To__ ___Dur ___ S Depth E _Depth Phase Code Subcode T___ COM - - _ _ 02/27/2007 14:00 18:00 4.00 0 0 COMPZ MOVE DMOB P Continue modify drip pan under rig floor for installation of flush mounted slips. Modify rotary table. Continue rig down and blow down all mud lines, and cement lines. Dress shakers for next well. Inspect & replace carrier bearin son au er. Crew than e 18:00 00:00 6.00 0 0 COMPZ MOVE DMOB P Weather in Phase II. Continue prep rig for move. Clean out drip pans, and wash OBM from windwalls. Continue blow down all mud lines, drain all pumps. Inspect & clean out all suction screens & sumps. Check all air pressures in tires. Check moving system. Rig released form 1J-180 2400 HRS. Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 3!22/2007 Time: 14:46:52 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1 J-180, True North Site: Kuparuk 1J Pad Vertical (f VD) Re ference: 1J-180L1: 121.4 WeII: 1 J-180 Section (VS) Reference: WeII (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-180L1 Survey Calculation Method: Minimum Curvat ure Db: Oracle Field: Kuparuk River Unit -- _ North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-180 Slot Name: 1 Well Position: +N/-S -499.40 ft Northing: 5945420.12 ft ' Latitude: 70 15 41.346 N i +E/-W -23.60 ft Fasti ng : 558770.25 ft ' Longitude: 149 31 29.693 W ~ Position Uncertainty: 0.00 ft Wellpath: 1J-180L1 Drilled From: 1J-180L1P61 ~ j 500292332960 Tie-on Depth: 15729.98 ft Current Datum: 1 J-180L1: Height 12 1.40 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 1/3/2007 Declination: 23.67 deg Field Strength: 57616 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction i ft ft ft deg I 40.40 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 3/22/2007 Validated: No Version: 2 Actuaffl From To Survey L ft -- Toolcode Tool Name - ~ 80.00 470.00 1J-180PB1 Gyros (80.00-470.00) CB-GYRO-SS Camera based gyro single shot ~ ', 516.32 2772.58 1J-180PB1 (516.32-2867.70) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC I 2790.00 9991.73 1J-180 (2790.00-17795.20) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10050.00 15729.98 1J-180L1P61 (1005 0.00-16202.62 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 15800.00 17739.62 1J-180L1 (15800.00 -17739.62) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Y1D lncl Azim TVD Sys "1'VD N/S EIW b1apN MapE Tool ft deg deg ft ft ft ft ft ft -____ __ 40.40 0.00 0.00 40.40 --- _ -81.00 _ 0.00 0.00 _ ___ _ 5945420.12 558770.25 __ __ 7 TIE LINE 80.00 0.25 204.54 80.00 -41.40 -0.08 -0.04 5945420.04 558770.21 CB-GYRO-SS 120.00 0.31 93.19 120.00 -1.40 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS 195.00 0.31 275.44 195.00 73.60 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS 273.00 1.70 207.09 272.99 151.59 -1.17 -0.70 5945418.95 558769.56 CB-GYRO-SS 370.00 4.93 214.60 369.81 248.41 -5.88 -3.72 5945414.21 558766.57 CB-GYRO-SS ~ 470.00 8.58 215.07 469.10 347.70 -15.52 -10.45 5945404.52 558759.92 CB-GYRO-SS ~'i 516.32 10.63 215.05 514.77 393.37 -21.85 -14.89 5945398.16 558755.53 MWD+IFR-AK-CAZ-SC 585.68 13.33 214.06 582.61 461.21 -33.71 -23.04 5945386.23 558747.47 MWD+IFR-AK-CAZ-SC 681.16 17.45 210.75 674.65 553.25 -55.15 -36.53 5945364.70 558734.15 MWD+IFR-AK-CAZ-SC ~ 775.68 20.50 207.94 764.03 642.63 -81.95 -51.54 5945337.77 558719.36 MWD+IFR-AK-CAZ-SC 872.00 23.89 207.47 853.20 731.80 -114.17 -68.44 5945305.43 558702.71 MWD+IFR-AK-CAZ-SC 964.80 27.53 210.33 936.80 815.40 -149.37 -87.95 5945270.09 558683.48 MWD+IFR-AK-CAZ-SC 1060.69 31.40 211.51 1020.27 898.87 -189.81 -112.21 5945229.46 558659.54 MWD+IFR-AK-CAZ-SC 1156.07 33.60 212.52 1100.71 979.31 -233.25 -139.38 5945185.81 558632.71 MWD+IFR-AK-CAZ-SC 1249.41 36.08 211.06 1177.31 1055.91 -278.58 -167.45 5945140.27 558604.99 MWD+IFR-AK-CAZ-SC 1345.29 36.19 210.02 1254.75 1133.35 -327.27 -196.18 5945091.36 558576.65 MWD+IFR-AK-CAZ-SC 1440.67 37.63 209.99 1331.01 1209.61 -376.87 -224.82 5945041.54 558548.39 MWD+IFR-AK-CAZ-SC 1536.41 39.59 209.64 1405.82 1284.42 -428.71 -254.52 5944989.48 558519.10 MWD+IFR-AK-CAZ-SC ~ 1631.01 42.74 208.47 1477.03 1355.63 -483.14 -284.74 5944934.82 558489.31 MWD+IFR-AK-CAZ-SC I~ 1725.56 43.94 205.13 1545.80 1424.40 -541.06 -313.97 5944876.68 558460.54 MWD+IFR-AK-CAZ-SC I 1821.24 46.86 205.17 1612.98 1491.58 -602.72 -342.92 5944814.80 558432.07 MWD+IFR-AK-CAZ-SC ' 1915.82 51.32 206.09 1674.90 1553.50 -667.14 -373.85 5944750.15 558401.65 MWD+IFR-AK-CAZ-SC ~ '~ 2010.35 51.48 206.20 1733.87 1612.47 -733.45 -406.40 5944683.59 558369.62 MWD+IFR-AK-CAZ-SC 2106.00 56.34 203.99 1790.21 1668.81 -803.44 -439.13 5944613.35 558337.44 MWD+IFR-AK-CAZ-SC ', 2200.83 59.85 203.96 1840.32 1718.92 -876.99 -471.84 5944539.56 558305.32 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 3!22/2007 Time: 14:46:52 Page: Field: Kuparuk River Unit ~o-ordinate(NF,) Reference: WeII: 1 J-18Q. True North Site: Kuparuk 1J Pad Vertical (TVD) Rcfere~ree: 1J-180L1: 121.4 Well: 1J-180 Section(VS)Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-180L1 SurveyCalculation Method: Minimum Curvature Db: OraCie Survey MD Inc! Azim TVD Svs T~"D N/S EI1'1' AIapN >V1apE "fool ft deg deg ft ft ft ft ft ft 2295.95 63.63 203.71 1885.35 1763.95 -953.61 -505.69 5944462.68 558272.07 MWD+IFR-AK-CAZ-SC ~ 2391.44 68.25 203.43 1924.27 1802.87 -1033.51 -540.54 5944382.52 558237.85 MWD+IFR-AK-CAZ-SC 2486.93 72.33 203.18 1956.46 1835.06 -1116.06 -576.09 5944299.71 558202.94 MWD+IFR-AK-CAZ-SC 2582.57 76.51 202.25 1982.15 1860.75 -1201.02 -611.65 5944214.48 558168.05 MWD+IFR-AK-CAZ-SC 2675.82 77.78 199.58 2002.90 1881.50 -1285.94 -644.10 5944129.32 558136.27 MWD+IFR-AK-CAZ-SC 2772.58 79.53 197.43 2021.93 1900.53 -1375.89 -674.20 5944039.14 558106.87 MWD+IFR-AK-CAZ-SC ' 2790.00 80.44 197.37 2024.96 1903.56 -1392.26 -679.33 5944022.73 558101.87 MWD+IFR-AK-CAZ-SC 2864.94 79.21 197.21 2038.20 1916.80 -1462.69 -701.25 5943952.14 558080.50 MWD+IFR-AK-CAZ-SC 2959.69 80.46 197.21 2054.92 1933.52 -1551.77 -728.85 5943862.85 558053.61 MWD+IFR-AK-CAZ-SC 3056.41 80.12 198.03 2071.23 1949.83 -1642.63 -757.70 5943771.78 558025.46 MWD+IFR-AK-CAZ-SC 3150.25 80.58 197.20 2086.96 1965.56 -1730.81 -785.70 5943683.40 557998.16 MWD+IFR-AK-CAZ-SC 3244.96 78.36 197.90 2104.27 1982.87 -1819.58 -813.77 5943594.42 557970.78 MWD+IFR-AK-CAZ-SC 3341.20 80.54 197.42 2121.89 2000.49 -1909.73 -842.47 5943504.05 557942.79 MWD+IFR-AK-CAZ-SC 3436.13 80.03 196.90 2137.91 2016.51 -1999.14 -870.08 5943414.45 557915.88 MWD+IFR-AK-CAZ-SC 3531.52 79.12 198.29 2155.17 2033.77 -2088.56 -898.43 5943324.81 557888.23 MWD IFR-AK-CAZ-SC 3625.00 81.41 198.40 2170.98 2049.58 -2176.00 -927.43 5943237.15 557859.92 MWD+IFR-AK-CAZ-SC 3719.78 80.65 198.59 2185.76 2064.36 -2264.79 -957.13 5943148.15 557830.92 MWD+IFR-AK-CAZ-SC 3815.77 80.33 198.62 2201.61 2080.21 -2354.51 -987.33 5943058.20 557801.42 MWD+IFR-AK-CAZ-SC 3910.90 82.27 199.47 2216.00 2094.60 -2443.40 -1018.02 5942969.09 557771.43 MWD+IFR-AK-CAZ-SC 3968.17 83.70 199.59 2223.00 2101.60 -2496.96 -1037.02 5942915.38 557752.85 MWD+IFR-AK-CAZ-SC 4026.70 83.32 199.21 2229.61 2108.21 -2551.82 -1056.34 5942860.38 557733.96 MWD+IFR-AK-CAZ-SC 4121.44 80.34 198.42 2243.08 2121.68 -2640.57 -1086.58 5942771.40 557704.41 MWD+IFR-AK-CAZ-SC 4215.52 78.26 198.74 2260.54 2139.14 -2728.19 -1116.03 5942683.56 557675.65 MWD+IFR-AK-CAZ-SC 4311.51 78.90 199.68 2279.55 2158.15 -2817.04 -1146.99 5942594.48 557645.39 MWD+IFR-AK-CAZ-SC 4405.70 79.98 200.54 2296.81 2175.41 -2903.99 -1178.83 5942507.30 557614.23 MWD+IFR-AK-CAZ-SC 4500.70 78.33 201.08 2314.68 2193.28 -2991.20 -1211.97 5942419.84 557581.77 MWD+IFR-AK-CAZ-SC 4595.30 79.08 200.19 2333.21 2211.81 -3078.02 -1244.66 5942332.78 557549.76 MWD+IFR-AK-CAZ-SC 4690.23 78.47 200.08 2351.69 2230.29 -3165.44 -1276.72 5942245.12 557518.40 MWD+IFR-AK-CAZ-SC 4785.43 77.84 201.41 2371.23 2249.83 -3252.57 -1309.72 5942157.74 557486.08 MWD+IFR-AK-CAZ-SC i 4883.48 79.16 201.97 2390.78 2269.38 -3341.85 -1345.23 5942068.20 557451.27 MWD+IFR-AK-CAZ-SC 4983.15 80.26 201.16 2408.59 2287.19 -3433.05 -1381.27 5941976.73 557415.94 MWD+IFR-AK-CAZ-SC 5079.43 79.96 200.85 2425.12 2303.72 -3521.59 -1415.27 5941887.93 557382.64 MWD+IFR-AK-CAZ-SC ~I 5174.94 79.72 199.15 2441.97 2320.57 -3609.93 -1447.42 5941799.35 557351.18 MWD+IFR-AK-CAZ-SC ~~ 5268.30 80.20 197.99 2458.25 2336.85 -3697.08 -1476.70 5941711.99 557322.59 MWD+IFR-AK-CAZ-SC 5356.51 81.90 196.57 2471.97 2350.57 -3780.27 -1502.58 5941628.60 557297.36 MWD+IFR-AK-CAZ-SC 5451.25 80.85 195.38 2486.18 2364.78 -3870.32 -1528.36 5941538.36 557272.29 MWD+IFR-AK-CAZ-SC 5546.69 81.97 196.31 2500.44 2379.04 -3961.10 -1554.12 5941447.39 557247.24 MWD+IFR-AK-CAZ-SC 5640.42 82.66 196.96 2512.97 2391.57 -4050.10 -1580.72 5941358.19 557221.34 MWD+IFR-AK-CAZ-SC 5735.62 79.48 198.15 2527.75 2406.35 -4139.76 -1609.07 5941268.33 557193.69 MWD+IFR-AK-CAZ-SC li 5830.71 78.71 199.37 2545.74 2424.34 -4228.17 -1639.10 5941179.70 557164.35 MWD+IFR-AK-CAZ-SC 5926.82 80.22 200.87 2563.31 2441.91 -4316.88 -1671.60 5941090.74 557132.55 MWD+IFR-AK-CAZ-SC 6019.81 77.14 200.71 2581.56 2460.16 -4402.12 -1703.97 5941005.26 557100.85 MWD+IFR-AK-CAZ-SC 6118.91 78.19 200.34 2602.73 2481.33 -4492.78 -1737.91 5940914.34 557067.62 MWD+IFR-AK-CAZ-SC 6213.05 80.66 199.26 2620.01 2498.61 -4579.85 -1769.25 5940827.05 557036.97 MWD+IFR-AK-CAZ-SC 6308.88 76.93 199.73 2638.62 2517.22 -4668.45 -1800.61 5940738.21 557006.30 MWD+IFR-AK-CAZ-SC 6404.03 79.51 199.07 2658.05 2536.65 -4756.30 -1831.55 5940650.13 556976.05 MWD+IFR-AK-CAZ-SC 6499.17 79.20 199.93 2675.62 2554.22 -4844.43 -1862.76 5940561.76 556945.53 MWD+IFR-AK-CAZ-SC 6594.06 81.53 199.62 2691.50 2570.10 -4932.46 -1894.41 5940473.50 556914.58 MWD+IFR-AK-CAZ-SC 6689.72 82.97 197.25 2704.40 2583.00 -5022.38 -1924.37 5940383.36 556885.31 MWD+IFR-AK-CAZ-SC 6783.16 82.16 195.42 2716.50 2595.10 -5111.29 -1950.43 5940294.26 556859.95 MWD+IFR-AK-CAZ-SC 6879.42 80.60 195.62 2730.92 2609.52 -5202.99 -1975.90 5940202.37 556835.21 MWD+IFR-AK-CAZ-SC 6974.71 79.65 195.84 2747.27 2625.87 -5293.35 -2001.35 5940111.82 556810.46 MWD+IFR-AK-CAZ-SC 7069.27 80.22 196.54 2763.79 2642.39 -5382.76 -2027.31 5940022.22 556785.21 MWD+IFR-AK-CAZ-SC I • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Dxte: 3/22/2007 Time: 14:46:52 Page: 3 Field: KuparukRlver Unit Co-ordinate(NE)Refe~rence: Well: 1J-180, True North Site: Kupa~ uk 1 J Pad Vertical (TVD) Reterence: "'1 J-180L1: 121.4 Nell: 1 J-180 Section (VS) Reference: WeH (O.OON,O.OOE,180 OOAzi) V~'ellpaih: 1 J-18GL1 Survey Calculation Dleihod: Minimum Curvature Ub: Oracle Survey MD Incl azim TVD SysTVD N/S E/~V ~1ap\ MapE 'Tool ft deg deg ft ft ft ft ft ft 7164.01 78.70 196.70 2781.12 2659.72 -5472.01 -2053.95 5939932.78 556759.27 MWD+IFR-AK-CAZ-SC i 7259.22 81.71 197.49 2797.32 2675.92 -5561.67 -2081.53 5939842.91 556732.39 MWD+IFR-AK-CAZ-SC 7353.88 81.14 197.53 2811.43 2690.03 -5650.94 -2109.69 5939753.43 556704.93 MWD+IFR-AK-CAZ-SC 7447.35 81.97 198.10 2825.16 2703.76 -5738.96 -2137.98 5939665.20 556677.33 MWD+IFR-AK-CAZ-SC 7542.43 80.33 197.62 2839.79 2718.39 -5828.38 -2166.79 5939575.57 556649.22 MWD+IFR-AK-CAZ-SC 7637.54 79.78 197.62 2856.21 2734.81 -5917.66 -2195.15 5939486.08 556621.56 MWD+IFR-AK-CAZ-SC 7732.51 80.02 197.62 2872.87 2751.47 -6006.77 -2223.45 5939396.76 556593.96 MWD+IFR-AK-CAZ-SC 7827,90 78.16 197.33 2890.92 2769.52 -6096.11 -2251.57 5939307.21 556566.53 MWD+IFR-AK-CAZ-SC 7923.25 78.66 196.36 2910.08 2788.68 -6185.51 -2278.64 5939217.61 556540.17 MWD+IFR-AK-CAZ-SC 8018.36 78.51 197.52 2928.90 2807.50 -6274.69 -2305.80 5939128.23 556513.71 MWD+IFR-AK-CAZ-SC 8113.72 79.40 198.56 2947.17 2825.77 -6363.68 -2334.79 5939039.02 556485.42 MWD+IFR-AK-CAZ-SC I, 8208.78 80.66 198.96 2963.63 2842.23 -6452.33 -2364.90 5938950.15 556456.00 MWD+IFR-AK-CAZ-SC 8301.64 81.46 199.56 2978.06 2856.66 -6538.92 -2395.16 5938863.33 556426.43 MWD+IFR-AK-CAZ-SC 8398.12 81.10 200.50 2992.68 2871.28 -6628.52 -2427.82 5938773.49 556394.47 MWD+IFR-AK-CAZ-SC 8491.81 79.59 200.91 3008.40 2887.00 -6714.92 -2460.47 5938686.85 556362.49 MWD+IFR-AK-CAZ-SC 8588.99 79.42 201.18 3026.10 2904.70 -6804.10 -2494.79 5938597.42 556328.88 MWD+IFR-AK-CAZ-SC 8682.68 79.71 201.17 3043.07 2921.67 -6890.02 -2528.07 5938511.25 556296.27 MWD+IFR-AK-CAZ-SC 8776.52 80.10 201.56 3059.52 2938.12 -6976.05 -2561.73 5938424.96 556263.29 MWD+IFR-AK-CAZ-SC 8874,12 79.33 201.13 3076.94 2955.54 -7065.50 -2596.68 5938335.25 556229.04 MWD+IFR-AK-CAZ-SC 8941.46 78.33 201.56 3089.99 2968.59 -7127.03 -2620.73 5938273.54 556205.47 MWD+IFR-AK-CAZ-SC ~ 9040.32 76.67 202.18 3111.38 2989.98 -7216.60 -2656.68 5938183.70 556170.23 MWD+IFR-AK-CAZ-SC 9135.52 72.02 202.95 3137.07 3015.67 -7301.23 -2691.84 5938098.81 556135.73 MWD+IFR-AK-CAZ-SC 9229.84 73.64 203.11 3164.91 3043.51 -7384.16 -2727.09 5938015.62 556101.13 MWD+IFR-AK-CAZ-SC 9326.06 76.87 201.55 3189.40 3068.00 -7470.22 -2762.43 5937929.29 556066.47 MWD+IFR-AK-CAZ-SC 9419.65 77.18 201.55 3210.41 3089.01 -7555.04 -2795.93 5937844.21 556033.63 MWD+IFR-AK-CAZ-SC 9514.40 79.05 202.71 3229.92 3108.52 -7640.93 -2830.86 5937758.07 555999.38 MWD+IFR-AK-CAZ-SC 9608.12 82.04 200.40 3245.32 3123.92 -7726.89 -2864.81 5937671.85 555966.11 MWD+IFR-AK-CAZ-SC 9706.28 82.09 197.39 3258.87 3137.47 -7818.87 -2896.29 5937579.64 555935.35 MWD+IFR-AK-CAZ-SC 9801.91 83.93 193.96 3270.52 3149.12 -7910.24 -2921.92 5937488.08 555910.43 MWD+IFR-AK-CAZ-SC 9896.65 84.59 190.13 3279.99 3158.59 -8002.41 -2941.59 5937395.77 555891.49 MWD+IFR-AK-CAZ-SC 9991.73 82.60 186.83 3290.60 3169.20 -8095.84 -2955.52 5937302.24 555878.28 MWD+IFR-AK-CAZ-SC 110050.00 82.49 184.99 3298.16 i 3176.76 -8153.31 -2961.47 5937244.73 555872.78 MWD+IFR-AK-CAZ-SC ~ 10104.42 84.13 184.49 3304.50 3183.10 -8207.17 -2965.94 5937190.84 555868.74 MWD+IFR-AK-CAZ-SC ~I 10156.50 83.57 184.01 3310.08 3188.68 -8258.81 -2969.78 5937139.18 555865.30 MWD+IFR-AK-CAZ-SC 10251.03 87.23 183.15 3317.66 3196.26 -8352.84 -2975.66 5937045.12 555860.16 MWD+IFR-AK-CAZ-SC 10304.35 89.02 182.67 3319.41 3198.01 -8406.06 -2978.36 5936991.88 555857.87 MWD+IFR-AK-CAZ-SC 10401.01 89.39 181.79 3320.75 3199.35 -8502.63 -2982.12 5936895.29 555854.86 MWD+IFR-AK-CAZ-SC 10500.51 91.99 180.89 3319.55 3198.15 -8602.09 -2984.45 5936795.83 555853.31 MWD+IFR-AK-CAZ-SC 10600.44 87.60 175.94 3319.91 3198.51 -8701.93 -2981.69 5936696.03 555856.85 MWD+IFR-AK-CAZ-SC 10697.12 90.07 176.61 3321.87 3200.47 -8798.37 -2975.41 5936599.64 555863.88 MWD+IFR-AK-CAZ-SC 10796.88 86.05 176.24 3325.25 3203.85 -8897.86 -2969.19 5936500.21 555870.87 MWD+IFR-AK-CAZ-SC 10896.32 88.72 179.37 3329.79 3208.39 -8997.10 -2965.39 5936401.01 555875.45 MWD+IFR-AK-CAZ-SC 10996.78 92.05 182.99 3329.11 3207.71 -9097.51 -2967.46 5936300.60 555874.16 MWD+IFR-AK-CAZ-SC 11094.99 91.00 183.33 3326.50 3205.10 -9195.53 -2972.87 5936202.55 555869.52 MWD+IFR-AK-CAZ-SC 11192.61 93.79 183.53 3322.42 3201.02 -9292.88 -2978.71 5936105.17 555864.44 MWD+IFR-AK-CAZ-SC 11292.44 88.28 182.49 3320.62 3199.22 -9392.52 -2983.94 5936005.50 555859.98 MWD+IFR-AK-CAZ-SC 11392.26 90.20 183.19 3321.94 3200.54 -9492.20 -2988.89 5935905.79 555855.82 MWD+IFR-AK-CAZ-SC 11491.92 90.81 184.39 3321.06 3199.66 -9591.64 -2995.48 5935806.32 555850.01 MWD+IFR-AK-CAZ-SC 11589.69 91.55 183.54 3319.05 3197.65 -9689.15 -3002.24 5935708.76 555844.01 MWD+IFR-AK-CAZ-SC 11689.55 87.91 179.88 3319.52 3198.12 -9788.93 -3005.21 5935608.97 555841.81 MWD+IFR-AK-CAZ-SC 11788.42 91.31 181.20 3320.19 3198.79 -9887.78 -3006.15 5935510.13 555841.65 MWD+IFR-AK-CAZ-SC I~ 11887.23 91.49 182.69 3317.78 3196.38 -9986.50 -3009.50 5935411.40 555839.07 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ __ (tympany: ConocoPhillips Alaska Inca Date: 3!22!2007 Time: 14:46:52 Pasc: -4 fielJ: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-180, True North tiilc: Kuparuk 1J Pad Vertica.I(TVD)Retcrcnce: 1J-180L1: 121:4-, ~~ell: 1J-180 Section(VS)Reference: Well (O.OON,O.OOE,180.OOAzi) ~~ cllpath: 1 J-180L1 Sun~ey Calculation Method: Minimum Curvature nh: Oracle Survey - __ NID Iucl 2~zim TVD Sys T~-D N/S E/W ~1ap~ MapE Tool ft deg deg ft ft ft ft ft ft 11986.17 92.67 181.22 3314.19 3192.79 -10085.31 -3012.87 5935312.57 555836.46 MWD+IFR-AK-CAZ-SC 12085.13 93.35 179.67 3308.99 3187.59 -10184.13 -3013.64 5935213.76 555836.47 MWD+IFR-AK-CAZ-SC 12184.11 89.14 179.87 3306.84 3185.44 -10283.07 -3013.24 5935114.84 555837.64 MWD+IFR-AK-CAZ-SC 12282.08 92.36 177.75 3305.56 3184.16 -10380.99 -3011.21 5935016.95 555840.43 MWD+IFR-AK-CAZ-SC 12381.18 91.68 175.99 3302.07 3180.67 -10479.87 -3005.80 5934918.12 555846.61 MWD+IFR-AK-CAZ-SC 12480.03 89.82 176.82 3300.77 3179.37 -10578.52 -2999.60 5934819.53 555853.58 MWD+IFR-AK-CAZ-SC 12579.19 90.63 178.83 3300.38 3178.98 -10677.60 -2995.84 5934720.49 555858.11 MWD+IFR-AK-CAZ-SC 12678.44 91.24 180.77 3298.76 3177.36 -10776.83 -2995.50 5934621.28 555859.24 MWD+IFR-AK-CAZ-SC 12777.77 91.31 181.86 3296.55 3175.15 -10876.11 -2997.77 5934522.00 555857.73 MWD+IFR-AK-CAZ-SC I 12877.53 91.25 183.39 3294.32 3172.92 -10975.73 -3002.34 5934422.35 555853.94 MWD+IFR-AK-CAZ-SC 12974.65 91.18 186.94 3292.26 3170.86 -11072.42 -3011.08 5934325.60 555845.96 MWD+IFR-AK-CAZ-SC 13070.43 91.68 188.34 3289.87 3168.47 -11167.32 -3023.81 5934230.62 555833.97 MWD+IFR-AK-CAZ-SC 13164.70 90.44 189.07 3288.13 3166.73 -11260.48 -3038.08 5934137.35 555820.43 MWD+IFR-AK-CAZ-SC 13259.95 90.81 189.54 3287.09 3165.69 -11354.48 -3053.48 5934043.25 555805.77 MWD+IFR-AK-CAZ-SC i 13352.81 91.06 188.54 3285.57 3164.17 -11446.17 -3068.06 5933951.46 555791.90 MWD+IFR-AK-CAZ-SC 13437.80 91.43 189.84 3283.73 3162.33 -11530.05 -3081.63 5933867.48 555778.99 MWD+IFR-AK-CAZ-SC 13545.13 91.31 188.83 3281.16 3159.76 -11635.92 -3099.04 5933761.48 555762.41 MWD+IFR-AK-CAZ-SC 13640.05 90.94 186.20 3279.30 3157.90 -11730.00 -3111.45 5933667.32 555750.73 MWD+IFR-AK-CAZ-SC 13733.74 90.50 185.75 3278.12 3156.72 -11823.17 -3121.20 5933574.08 555741.71 MWD+IFR-AK-CAZ-SC 13829.78 90.63 184.62 3277.17 3155.77 -11918.81 -3129.88 5933478.39 555733.78 MWD+IFR-AK-CAZ-SC 13924.19 90.01 184.99 3276.65 3155.25 -12012.89 -3137.79 5933384.26 555726.61 MWD+IFR-AK-CAZ-SC 14019.90 89.95 184.34 3276.68 3155.28 -12108.28 -3145.57 5933288.82 555719.57 MWD+IFR-AK-CAZ-SC 14115.37 90.87 185.44 3276.00 3154.60 -12203.40 -3153.71 5933193.65 555712.17 MWD+IFR-AK-CAZ-SC 14210.70 90.44 184.68 3274.91 3153.51 -12298.35 -3162.12 5933098.65 555704.51 MWD+IFR-AK-CAZ-SC 14302.79 90.57 183.42 3274.09 3152.69 -12390.21 -3168.62 5933006.75 555698.72 MWD+IFR-AK-CAZ-SC 14400.20 91.12 182.22 3272.66 3151.26 -12487.49 -3173.41 5932909.45 555694.69 MWD+IFR-AK-CAZ-SC 14493.71 93.17 180.51 3269.16 3147.76 -12580.90 -3175.64 5932816.03 555693.19 MWD+IFR-AK-CAZ-SC 14589.80 91.24 177.40 3265.46 3144.06 -12676.88 -3173.89 5932720.07 555695.69 MWD+IFR-AK-CAZ-SC 14685.99 92.05 174.76 3262.70 3141.30 -12772.80 -3167.31 5932624.22 555703.01 MWD+IFR-AK-CAZ-SC 14780.82 91.31 173.77 3259.92 3138.52 -12867.11 -3157.84 5932529.99 555713.22 MWD+IFR-AK-CAZ-SC 14875.50 89.14 173.45 3259.55 3138.15 -12961.20 -3147.31 5932436.00 555724.49 MWD+IFR-AK-CAZ-SC 14970.35 89.76 175.73 3260.46 3139.06 -13055.61 -3138.36 5932341.67 555734.17 MWD+IFR-AK-CAZ-SC 15065.99 87.97 177.67 3262.35 3140.95 -13151.07 -3132.86 5932246.27 555740.42 MWD+IFR-AK-CAZ-SC 1516021 91.00 179.02 3263.20 3141.80 -13245.23 -3130.14 5932152.14 555743.87 MWD+IFR-AK-CAZ-SC 15255.57 90.07 177.71 3262.31 3140.91 -13340.55 -3127.42 5932056.86 555747.34 MWD+IFR-AK-CAZ-SC 15350.46 89.76 176.57 3262.45 3141.05 -13435.32 -3122.68 5931962.14 555752.81 MWD+IFR-AK-CAZ-SC 15445.11 90.51 178.42 3262.23 3140.83 -13529.87 -3118.55 5931867.63 555757.68 MWD+IFR-AK-CAZ-SC 15540.68 89.45 175.74 3262.26 3140.86 -13625.31 -3113.68 5931772.24 555763.30 MWD+IFR-AK-CAZ-SC 15634.59 88.90 177.56 3263.61 3142.21 -13719.04 -3108.19 5931678.56 555769.51 MWD+IFR-AK-CAZ-SC 15729.98 91.49 181.47 3263.29 3141.89 -13814.40 -3107.39 5931583.22 555771.06 MWD+IFR-AK-CAZ-SC 15800.00 92.35 181.00 3260.94 3139.54 -13884.36 -3108.89 5931513.25 555770.10 MWD+IFR-AK-CAZ-SC 15825.14 91.18 180.47 3260.17 3138.77 -13909.49 -3109.22 5931488.13 555769.98 MWD+IFR-AK-CAZ-SC 15920.48 87.17 181.23 3261.54 3140.14 -14004.79 -3110.63 5931392.83 555769.31 MWD+IFR-AK-CAZ-SC 16012.08 89.33 181.52 3264.34 3142.94 -14096.31 -3112.83 5931301.30 555767.82 MWD+IFR-AK-CAZ-SC 16107.52 89.95 183.95 3264.94 3143.54 -14191.64 -3117.38 5931205.95 555764.02 MWD+IFR-AK-CAZ-SC i 16202.63 90.44 184.84 3264.61 3143.21 -14286.46 -3124.67 5931111.08 555757.47 MWD+IFR-AK-CAZ-SC 16293.40 90.63 184.78 3263.76 3142.36 -14376.91 -3132.28 5931020.58 555750.56 MWD+IFR-AK-CAZ-SC 16393.69 90.69 185.05 3262.61 3141.21 -14476.83 -3140.87 5930920.62 555742.75 MWD+IFR-AK-CAZ-SC 16488,35 90.13 183.80 3261.93 3140.53 -14571.20 -3148.17 5930826.20 555736.19 MWD+IFR-AK-CAZ-SC 16584.46 90.57 184.36 3261.35 3139.95 -14667.06 -3155.01 5930730.29 555730.10 MWD+IFR-AK-CAZ-SC 16679.28 90.13 184.01 3260.77 3139.37 -14761.63 -3161.93 5930635.68 555723.92 MWD+IFR-AK-CAZ-SC 16774.98 90.44 185.46 3260.29 3138.89 -14857.00 -3169.83 5930540.27 555716.76 MWD+IFR-AK-CAZ-SC 16869.39 90.50 187.87 3259.52 3138.12 -14950.76 -3180.79 5930446.43 555706.54 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inca Date: 3/22/2007 Time: -14:46.52 Page: 5 Field: KuparukRiver Unit Co-ordiuate(NE)Refereoce: Well: 1J-180,Tru e North Site: Kuparuk 1J Pad Verti cal ('I'VD) Re ference: 1J-180L1: 121.4 WrIL• 1J -180 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAzi)' Weltpath:_ 1J -180L1 __ Survey Calculation blcthod: Minimum Curvat ____ ure Ilh: Oracle Su n~ey b~ID Incl Azim TVD Sys TVD ;~~/S E/bV !Napi~ MapE Tool ft deg deg ft ft ft ft ft ft ~~ 16965.23 90.69 187.41 3258.52 3137.12 -15045.74 -3193.53 5930351.36 555694.54 MWD+IFR-AK-CAZ-SC 17060.46 90.63 185.04 3257.42 3136.02 -15140.40 -3203.85 5930256.63 555684.96 MWD+IFR-AK-CAZ-SC 17155.60 90.57 181.14 3256.43 3135.03 -15235.38 -3208.98 5930161.63 555680.57 MWD+IFR-AK-CAZ-SC 17250.58 90.57 177.32 3255.48 3134.08 -15330.33 -3207.70 5930066.70 555682.59 MWD+IFR-AK-CAZ-SC j 17345.79 90.13 175.02 3254.90 3133.50 -15425.31 -3201.35 5929971.77 555689.69 MWD+IFR-AK-CAZ-SC '~i 17440.57 90.26 176.65 3254.58 3133.18 -15519.84 -3194.46 5929877.31 555697.31 MWD+IFR-AK-CAZ-SC 17536.52 90.57 176.89 3253.88 3132.48 -15615.64 -3189.06 5929781.57 555703.46 MWD+IFR-AK-CAZ-SC 17630.59 90.57 178.20 3252.95 3131.55 -15709.61 -3185.03 5929687.64 555708.22 MWD+IFR-AK-CAZ-SC 17724.83 90.32 178.22 3252.21 3130.81 -15803.80 -3182.08 5929593.48 555711.90 MWD+IFR-AK-CAZ-SC 17739.62 89.88 178.23 3252.19 3130.79 -15818.59 -3181.62 5929578.71 555712.48 MWD+IFR-AK-CAZ-SC i ,17779.08 89.88 178.23 3252.27 - 3130.87 -15858.03 -3180.41 5929539.28 555714.00 PROJECTED to TD ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. __ Date: 3!22/2007 Time: 14:30:17 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeIL 1J-180, Tr ue Nofth Sitc: Kuparuk 1J Pad Vertical (TVD) Re ference:. 1J-180L1PB1 121.4 Wcll: 1J-180 Section(VS)Refer ence: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-180L1PB1 Survey Calculatio n'Method: Minimum Curvature nh: Oracle -- Field: Kuparuk River Unit North Slope Alaska ~ United States j Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea level Geomagnetic Model: bggm2006 Well: 1 J-180 Slot Name: Well Position: +N/-S -499.40 ft North ing: 594542 0.12 ft Latitude: 70 15 41.346 N +E/-W -23.60 ft Easting : 558770.25 ft Longitude: 149 31 29.693 W Position Uncertainty: 0.00 ft ~Ilpath: 1J-180L1P61 Drilled From: 1J-180 i 500292332971 Tie-on Depth: 9991.73 ft Current Datum: 1 J-180L1 P61 Height 12 1.40 ft Above System Datum: Mean Sea Level ~, Magnetic Data: 1/3/2007 Declination: 23.67 deg Field Strength: 57616 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.40 0.00 0.00 180.00 Survey Program for Definitive Wellpath _ Date: 3/22/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ~ ft ft ~ 80.00 470.00 1J-180P61 Gyros (80.00-470.00) CB-GYRO-SS Camera based gyro single shot 516.32 2772.58 1J-180P61 (516.32- 2867.70) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2790.00 9991.73 1J-180 (2790.00-17795.20) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 10050.00 16202.62 1J-180L1PB1 (10050.00-16202.62 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey - __ - _ MD Inc! Azim TVD Sys TVD N/S E/W MapN DfapE Tool ft dzg deg ft ft ft ft ft ft 40.40 0.00 0.00 40.40 -81.00 0.00 0.00 5945420.12 558770.25 TIE LINE 80.00 0.25 204.54 80.00 -41.40 -0.08 -0.04 5945420.04 558770.21 CB-GYRO-SS 120.00 0.31 93.19 120.00 -1.40 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS 195.00 0.31 275.44 195.00 73.60 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS 273.00 1.70 207.09 272.99 151.59 -1.17 -0.70 5945418.95 558769.56 CB-GYRO-SS 370.00 4.93 214.60 369.81 248.41 -5.88 -3.72 5945414.21 558766.57 CB-GYRO-SS ~ 470.00 8.58 215.07 469.10 347.70 -15.52 -10.45 5945404.52 558759.92 CB-GYRO-SS 516.32 10.63 215.05 514.77 393.37 -21.85 -14.89 5945398.16 558755.53 MWD+IFR-AK-CAZ-SC 585.68 13.33 214.06 582.61 461.21 -33.71 -23.04 5945386.23 558747.47 MWD+IFR-AK-CAZ-SC 681.16 17.45 210.75 674.65 553.25 -55.15 -36.53 5945364.70 558734.15 MWD+IFR-AK-CAZ-SC 775.68 20.50 207.94 764.03 642.63 -81.95 -51.54 5945337.77 558719.36 MWD+IFR-AK-CAZ-SC 872.00 23.89 207.47 853.20 731.80 -114.17 -68.44 5945305.43 558702.71 MWD+IFR-AK-CAZ-SC 964.80 27.53 210.33 936.80 815.40 -149.37 -87.95 5945270.09 558683.48 MWD+IFR-AK-CAZ-SC I 1060.69 31.40 211.51 1020.27 898.87 -189.81 -112.21 5945229.46 558659.54 MWD+IFR-AK-CAZ-SC ~ I 1156.07 33.60 212.52 1100.71 979.31 -233.25 -139.38 5945185.81 558632.71 MWD+IFR-AK-CAZ-SC 1249.41 36.08 211.06 1177.31 1055.91 -278.58 -167.45 5945140.27 558604.99 MWD+-FR-AK-CAZ-SC 1345.29 36.19 210.02 1254.75 1133.35 -327.27 -196.18 5945091.36 558576.65 MWD+IFR-AK-CAZ-SC 1440.67 37.63 209.99 1331.01 1209.61 -376.87 -224.82 5945041.54 558548.39 MWD+IFR-AK-CAZ-SC ~ 1536.41 39.59 209.64 1405.82 1284.42 -428.71 -254.52 5944989.48 558519.10 MWD+IFR-AK-CAZ-SC 1631.01 42.74 208.47 1477.03 1355.63 -483.14 -284.74 5944934.82 558489.31 MWD+IFR-AK-CAZ-SC 1725.56 43,94 205.13 1545.80 1424.40 -541.06 -313.97 5944876.68 558460.54 MWD+IFR-AK-CAZ-SC 1821.24 46.86 205.17 1612.98 1491.58 -602.72 -342.92 5944814.80 558432.07 MWD+IFR-AK-CAZ-SC 1915.82 51.32 206.09 1674.90 1553.50 -667.14 -373.85 5944750.15 558401.65 MWD+IFR-AK-CAZ-SC 2010.35 51.48 206.20 1733.87 1612.47 -733.45 -406.40 5944683.59 558369.62 MWD+IFR-AK-CAZ-SC 2106.00 56.34 203.99 1790.21 I 1668.81 -803.44 -439.13 5944613.35 558337.44 MWD+IFR-AK-CAZ-SC 2200.83 59.85 203.96 1840.32 1718.92 -876.99 -471.84 5944539.56 558305.32 MWD+IFR-AK-CAZ-SC 2295.95 63.63 203.71 1885.35 1763.95 -953.61 -505.69 5944462.68 558272.07 MWD+IFR-AK-CAZ-SC ~, Halliburton Company Survey Report _. __ ___ __ Company: ConocoPhillips Alaska Inc. Date: 3/22/2007 Teme: 14:30:17 - Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-180, TrueNorth Site: KuparuklJPad Vertical(TVD}Reference: 1J-180L1PB1121.4 Well: 1J-180 Section (~'S)Iteference: WeII (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-180L1PB1 Survey Calculation Method: Minimum Curvature Db: Oracle ____ __ Survcv -_- -- YID Incl lzim TVD SysTVD N/S E/W Maps 1IapE Tool ft deg deg ft ft ft ft ft ft 2391.44 68.25 203.43 1924.27 1802.87 -1033.51 -540.54 5944382.52 558237.85 MWD+IFR-AK-CAZ-SC ~, 2486.93 72.33 203.18 1956.46 1835.06 -1116.06 -576.09 5944299.71 558202.94 MWD+IFR-AK-CAZ-SC 2582.57 76.51 202.25 1982.15 1860.75 -1201.02 -611.65 5944214.48 558168.05 MWD+IFR-AK-CAZ-SC 2675.82 77.78 199.58 2002.90 1881.50 -1285.94 -644.10 5944129.32 558136.27 MWD+IFR-AK-CAZ-SC 2772.58 79.53 197.43 2021.93 1900.53 -1375.89 -674.20 5944039.14 558106.87 MWD+IFR-AK-CAZ-SC 2790.00 80.44 197.37 2024.96 1903.56 -1392.26 -679.33 5944022.73 558101.87 MWD+IFR-AK-CAZ-SC 2864.94 79.21 197.21 2038.20 1916.80 -1462.69 -701.25 5943952.14 558080.50 MWD+IFR-AK-CAZ-SC 2959.69 80.46 197.21 2054.92 1933.52 -1551.77 -728.85 5943862.85 558053.61 MWD+IFR-AK-CAZ-SC ~I 3056.41 80.12 198.03 2071.23 1949.83 -1642.63 -757.70 5943771.78 558025.46 MWD+IFR-AK-CAZ-SC I 3150.25 80.58 197.20 2086.96 1965.56 -1730.81 -785.70 5943683.40 557998.16 MWD+IFR-AK-CAZ-SC I 3244.96 78.36 197.90 2104.27 1982.87 -1819.58 -813.77 5943594.42 557970.78 MWD+IFR-AK-CAZ-SC 3341.20 80.54 197.42 2121.89 2000.49 -1909.73 -842.47 5943504.05 557942.79 MWD+IFR-AK-CAZ-SC 3436.13 80.03 196.90 2137.91 2016.51 -1999.14 -870.08 5943414.45 557915.88 MWD+IFR-AK-CAZ-SC 3531.52 79.12 198.29 2155.17 2033.77 -2088.56 -898.43 5943324.81 557888.23 MWD+IFR-AK-CAZ-SC 3625.00 81.41 198.40 2170.98 2049.58 -2176.00 -927.43 5943237.15 557859.92 MWD+IFR-AK-CAZ-SC 3719.78 80.65 198.59 2185.76 2064.36 -2264.79 -957.13 5943148.15 557830.92 MWD+IFR-AK-CAZ-SC 3815.77 80.33 198.62 2201.61 2080.21 -2354.51 -987.33 5943058.20 557801.42 MWD+IFR-AK-CAZ-SC 3910.90 82.27 199.47 2216.00 2094.60 -2443.40 -1018.02 5942969.09 557771.43 MWD+IFR-AK-CAZ-SC ~~ 3968.17 83.70 199.59 2223.00 2101.60 -2496.96 -1037.02 5942915.38 557752.85 MWD+IFR-AK-CAZ-SC 4026.70 83.32 199.21 2229.61 2108.21 -2551.82 -1056.34 5942860.38 557733.96 MWD+IFR-AK-CAZ-SC 4121.44 80.34 198.42 2243.08 2121.68 -2640.57 -1086.58 5942771.40 557704.41 MWD+IFR-AK-CAZ-SC 4215.52 78.26 198.74 2260.54 2139.14 -2728.19 -1116.03 5942683.56 557675.65 MWD+IFR-AK-CAZ-SC 4311.51 78.90 199.68 2279.55 2158.15 -2817.04 -1146.99 5942594.48 557645.39 MWD+IFR-AK-CAZ-SC 4405.70 79.98 200.54 2296.81 2175.41 -2903.99 -1178.83 5942507.30 557614.23 MWD+IFR-AK-CAZ-SC ~ 4500.70 78.33 201.08 2314.68 2193.28 -2991.20 -1211.97 5942419.84 557581.77 MWD+IFR-AK-CAZ-SC 4595.30 79.08 200.19 2333.21 2211.81 -3078.02 -1244.66 5942332.78 557549.76 MWD+IFR-AK-CAZ-SC 4690.23 78.47 200.08 2351.69 2230.29 -3165.44 -1276.72 5942245.12 557518.40 MWD+IFR-AK-CAZ-SC 4785.43 77.84 201.41 2371.23 2249.83 -3252.57 -1309.72 5942157.74 557486.08 MWD+IFR-AK-CAZ-SC 4883.48 79.16 201.97 2390.78 2269.38 -3341.85 -1345.23 5942068.20 557451.27 MWD+IFR-AK-CAZ-SC 4983.15 80.26 201.16 2408.59 2287.19 -3433.05 -1381.27 5941976.73 557415.94 MWD+IFR-AK-CAZ-SC ~~ 5079.43 79.96 200.85 2425.12 2303.72 -3521.59 -1415.27 5941887.93 557382.64 MWD+IFR-AK-CAZ-SC 5174.94 79.72 199.15 2441.97 2320.57 -3609.93 -1447.42 5941799.35 557351.18 MWD+IFR-AK-CAZ-SC 5268.30 80.20 197.99 2458.25 2336.85 -3697.08 -1476.70 5941711.99 557322.59 MWD+IFR-AK-CAZ-SC 5356.51 81.90 196.57 2471.97 2350.57 -3780.27 -1502.58 5941628.60 557297.36 MWD+IFR-AK-CAZ-SC i 5451.25 80.85 195.38 2486.18 2364.78 -3870.32 -1528.36 5941538.36. 557272.29 MWD+IFR-AK-CAZ-SC 5546.69 81.97 196.31 2500.44 2379.04 -3961.10 -1554.12 5941447.39 557247.24 MWD+IFR-AK-CAZ-SC 5640.42 82.66 196.96 2512.97 2391.57 -4050.10 -1580.72 5941358.19 557221.34 MWD+IFR-AK-CAZ-SC i 5735.62 79.48 198.15 2527.75 2406.35 -4139.76 -1609.07 5941268.33 557193.69 MWD+IFR-AK-CAZ-SC 5830.71 78.71 199.37 2545.74 2424.34 -4228.17 -1639.10 5941179.70 557164.35 MWD+IFR-AK-CAZ-SC 5926.82 80.22 200.87 2563.31 2441.91 -4316.88 -1671.60 5941090.74 557132.55 MWD+IFR-AK-CAZ-SC 6019.81 77.14 200.71 2581.56 2460.16 -4402.12 -1703.97 5941005.26 557100.85 MWD+IFR-AK-CAZ-SC 6118.91 78.19 200.34 2602.73 2481.33 -4492.78 -1737.91 5940914.34 557067.62 MWD+IFR-AK-CAZ-SC 6213.05 80.66 199.26 2620.01 2498.61 -4579.85 -1769.25 5940827.05 557036.97 MWD+IFR-AK-CAZ-SC I 6308.88 76.93 199.73 2638.62 2517.22 -4668.45 -1800.61 5940738.21 557006.30 MWD+IFR-AK-CAZ-SC j 6404.03 79.51 199.07 2658.05 2536.65 -4756.30 -1831.55 5940650.13 556976.05 MWD+IFR-AK-CAZ-SC 6499.17 79.20 199.93 2675.62 2554.22 -4844.43 -1862.76 5940561.76 556945.53 MWD+IFR-AK-CAZ-SC 6594.06 81.53 199.62 2691.50 2570.10 -4932.46 -1894.41 5940473.50 556914.58 MWD+IFR-AK-CAZ-SC I 6689.72 82.97 197.25 2704.40 2583.00 -5022.38 -1924.37 5940383.36 556885.31 MWD+IFR-AK-CAZ-SC ~ 67$3.16 82.16 195.42 2716.50 2595.10 -5111.29 -1950.43 5940294.26 556859.95 MWD+IFR-AK-CAZ-SC 6879.42 80.60 195.62 2730.92 2609.52 -5202.99 -1975.90 5940202.37 556835.21 MWD+IFR-AK-CAZ-SC 6974.71 79.65 195.84 2747.27 2625.87 -5293.35 -2001.35 5940111.82 556810.46 MWD+IFR-AK-CAZ-SC 7069.27 80.22 196.54 2763.79 2642.39 -5382.76 -2027.31 5940022.22 556785.21 MWD+IFR-AK-CAZ-SC I 7164.01 78.70 196.70 2781.12 2659.72 -5472.01 -2053.95 5939932.78 556759.27 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 3/22/2007 Time: 14:30:17 Page: ; Field: Ke~paruk River Unit Co-ordinate(iVE)Reference: Well: 1J-180, True North Site: Kuparuk 1J Pad Vertical {TVD)Rcfcrence: 1J-t80L1PBi 121.4 ~i'ell: 1J-180 Section (VS)Keferenee: Well (O.OON,O.OOE,~30 OOAzi) Wellpath: 4J-18011 P61 Survey CaleulationAlethod: Minimum Curvature 1)h: Oracle Su i~ ev MD Incl Azim TVD tivs TVD \7S E/W MapN 1V1apE Tool '~ ft deg deg ft ft ft ft ft ft I 7259.22 81.71 197.49 2797.32 2675.92 -5561.67 -2081.53 5939842.91 556732.39 MWD+IFR-AK-CAZ-SC 7353.88 81.14 197.53 2811.43 2690.03 -5650.94 -2109.69 5939753.43 556704.93 MWD+IFR-AK-CAZ-SC ~, 7447.35 81.97 198.10 2825.16 2703.76 -5738.96 -2137.98 5939665.20 556677.33 MWD+IFR-AK-CAZ-SC 7542.43 80.33 197.62 2839.79 2718.39 -5828.38 -2166.79 5939575.57 556649.22 MWD+IFR-AK-CAZ-SC 7637.54 79.78 197.62 2856.21 2734.81 -5917.66 -2195.15 5939486.08 556621.56 MWD+IFR-AK-CAZ-SC i 7732.51 80.02 197.62 2872.87 2751.47 -6006.77 -2223.45 5939396.76 556593.96 MWD+IFR-AK-CAZ-SC 7827.90 78.16 197.33 2890.92 2769.52 -6096.11 -2251.57 5939307.21 556566.53 MWD+IFR-AK-CAZ-SC 7923.25 78.66 196.36 2910.08 2788.68 -6185.51 -2278.64 5939217.61 556540.17 MWD+IFR-AK-CAZ-SC 8018.36 78.51 197.52 2928.90 2807.50 -6274.69 -2305.80 5939128.23 556513.71 MWD+IFR-AK-CAZ-SC 8113.72 79.40 198.56 2947.17 2825.77 -6363.68 -2334.79 5939039.02 556485.42 MWD+IFR-AK-CAZ-SC 8208.78 80.66 198.96 2963.63 2842.23 -6452.33 -2364.90 5938950.15 556456.00 MWD+IFR-AK-CAZ-SC 8301.64 81.46 199.56 2978.06 2856.66 -6538.92 -2395.16 5938863.33 556426.43 MWD+IFR-AK-CAZ-SC 8398.12 81.10 200.50 2992.68 2871.28 -6628.52 -2427.82 5938773.49 556394.47 MWD+IFR-AK-CAZ-SC 8491.81 79.59 200.91 3008.40 2887.00 -6714.92 -2460.47 5938686.85 556362.49 MWD+IFR-AK-CAZ-SC 8588.99 79.42 201.18 3026.10 2904.70 -6804.10 -2494.79 5938597.42 556328.88 MWD+IFR-AK-CAZ-SC 8682.68 79.71 201.17 3043.07 2921.67 -6890.02 -2528.07 5938511.25 556296.27 MWD+IFR-AK-CAZ-SC 8776.52 80.10 201.56 3059.52 2938.12 -6976.05 -2561.73 5938424.96 556263.29 MWD+IFR-AK-CAZ-SC 8874.12 79.33 201.13 3076.94 2955.54 -7065.50 -2596.68 5938335.25 556229.04 MWD+IFR-AK-CAZ-SC 8941.46 78.33 201.56 3089.99 2968.59 -7127.03 -2620.73 5938273.54 556205.47 MWD+IFR-AK-CAZ-SC 9040.32 76.67 202.18 3111.38 2989.98 -7216.60 -2656.68 5938183.70 556170.23 MWD+IFR-AK-CAZ-SC 9135.52 72.02 202.95 3137.07 3015.67 -7301.23 -2691.84 5938098.81 556135.73 MWD+IFR-AK-CAZ-SC ~ 9229.84 73.64 203.11 3164.91 3043.51 -7384.16 -2727.09 5938015.62 556101.13 MWD+IFR-AK-CAZ-SC 9326.06 76.87 201.55 3189.40 3068.00 -7470.22 -2762.43 5937929.29 556066.47 MWD+IFR-AK-CAZ-SC 9419.65 77.18 201.55 3210.41 3089.01 -7555.04 -2795.93 5937844.21 556033.63 MWD+IFR-AK-CAZ-SC 9514.40 79.05 202.71 3229.92 3108.52 -7640.93 -2830.86 5937758.07 555999.38 MWD+IFR-AK-CAZ-SC 9608.12 82.04 200.40 3245.32 3123.92 -7726.89 -2864.81 5937671.85 555966.11 MWD+IFR-AK-CAZ-SC 9706.28 82.09 197.39 3258.87 3137.47 -7818.87 -2896.29 5937579.64 555935.35 MWD+IFR-AK-CAZ-SC 9801.91 83.93 193.96 3270.52 3149.12 -7910.24 -2921.92 5937488.08 555910.43 MWD+IFR-AK-CAZ-SC 9896.65 84.59 190.13 3279.99 3158.59 -8002.41 -2941.59 5937395.77 555891.49 MWD+IFR-AK-CAZ-SC ' 9991.73 82.60 186.83 3290.60 3169.20 -8095.84 -2955.52 5937302.24 555878.28 MWD+IFR-AK-CAZ-SC 10050.00 82.49 184.99 3298.16 3176.76 -8153.31 -2961.47 5937244.73 555872.78 MWD+IFR-AK-CAZ-SC ~' 10104.42 84.13 184.49 3304.50 3183.10 -8207.17 -2965.94 5937190.84 555868.74 MWD+IFR-AK-CAZ-SC ~ !, 10156.50 83.57 184.01 3310.08 3188.68 -8258.81 -2969.78 5937139.18 555865.30 MWD+IFR-AK-CAZ-SC 10251.03 87.23 183.15 3317.66 3196.26 -8352.84 -2975.66 5937045.12 555860.16 MWD+IFR-AK-CAZ-SC 10304.35 89.02 182.67 3319.41 3198.01 -8406.06 -2978.36 5936991.88 555857.87 MWD+IFR-AK-CAZ-SC 10401.01 89.39 181.79 3320.75 3199.35 -8502.63 -2982.12 5936895.29 555854.86 MWD+IFR-AK-CAZ-SC 10500.51 91.99 180.89 3319.55 3198.15 -8602.09 -2984.45 5936795.83 555853.31 MWD+IFR-AK-CAZ-SC 10600.44 87.60 175.94 3319.91 3198.51 -8701.93 -2981.69 5936696.03 555856.85 MWD+IFR-AK-CAZ-SC 10697.12 90.07 176.61 3321.87 3200.47 -8798.37 -2975.41 5936599.64 555863.88 MWD+IFR-AK-CAZ-SC 10796.88 86.05 176.24 3325.25 3203.85 -8897.86 -2969.19 5936500.21 555870.87 MWD+IFR-AK-CAZ-SC 10896.32 88.72 179.37 3329.79 3208.39 -8997.10 -2965.39 5936401.01 555875.45 MWD+IFR-AK-CAZ-SC 10996.78 92.05 182.99 3329.11 3207.71 -9097.51 -2967.46 5936300.60 555874.16 MWD+IFR-AK-CAZ-SC 11094.99 91.00 183.33 3326.50 3205.10 -9195.53 -2972.87 5936202.55 555869.52 MWD+IFR-AK-CAZ-SC ~ 11192.61 93.79 183.53 3322.42 3201.02 -9292.88 -2978.71 5936105.17 555864.44 MWD+IFR-AK-CAZ-SC 11292.44 88.28 182.49 3320.62 3199.22 -9392.52 -2983.94 5936005.50 555859.98 MWD+IFR-AK-CAZ-SC 11392.26 90.20 183.19 3321.94 3200.54 -9492.20 -2988.89 5935905.79 555855.82 MWD+IFR-AK-CAZ-SC 11491.92 90.81 184.39 3321.06 3199.66 -9591.64 -2995.48 5935806.32 555850.01 MWD+IFR-AK-CAZ-SC 11589.69 91.55 183.54 3319.05 3197.65 -9689.15 -3002.24 5935708.76 555844.01 MWD+IFR-AK-CAZ-SC 11689.55 87.91 179.88 3319.52 3198.12 -9788.93 -3005.21 5935608.97 555841.81 MWD+IFR-AK-CAZ-SC 11788.42 91.31 181.20 3320.19 3198.79 -9887.78 -3006.15 5935510.13 555841.65 MWD+IFR-AK-CAZ-SC 11887.23 91.49 182.69 3317.78 3196.38 -9986.50 -3009.50 5935411.40 555839.07 MWD+IFR-AK-CAZ-SC 11986.17 92.67 181.22 3314.19 3192.79 -10085.31 -3012.87 5935312.57 555836.46 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ____ Company: ConocoPhillips Alaska Inc. llate: 3122/2007 "Time: 14:30:17 Pa~c: 4 Field: Kuparuk River Unit Co-ordinate(NEpReference: Wetl: 1J-180, True North Site: Kuparuk 1J Pad Vertical (TVD)Reference: 1 J-180t_1 P81 121.4 1Vett: 1J-180 Section (VS)Reference: Well {O.OON,O.OOE,180.OOAzi) Welip:~th: 1J-180L1PB1 SurveyCalcula[ion 4cthod: Minimum Curvature Db: Oracle Su~rocv v1D [ncl Azim TVD Sys TVD N/S E/~V MapN MapE Tool ft deg deg ft ft ft ft ft ft 12085.13 93.35 179.67 3308.99 3187.59 -10184.13 -3013.64 5935213.76 555836.47 MWD+IFR-AK-CAZ-SC 12184.11 89.14 179.87 3306.84 3185.44 -10283.07 -3013.24 5935114.84 555837.64 MWD+IFR-AK-CAZ-SC i 12282.08 92.36 177.75 3305.56 3184.16 -10380.99 -3011.21 5935016.95 555840.43 MWD+IFR-AK-CAZ-SC 12381.18 91.68 175.99 3302.07 3180.67 -10479.87 -3005.80 5934918.12 555846.61 MWD+IFR-AK-CAZ-SC I, ~ + 12480.03 89.82 176.82 3300.77 3179.37 -10578.52 -2999.60 5934819.53 555853.58 MWD IFR-AK-CAZ-SC 12579.19 90.63 178.83 3300.38 3178.98 -10677.60 -2995.84 5934720.49 555858.11 MWD+IFR-AK-CAZ-SC 12678.44 91.24 180.77 3298.76 3177.36 -10776.83 -2995.50 5934621.28 555859.24 MWD+IFR-AK-CAZ-SC 12777.77 91.31 181.86 3296.55 3175.15 -10876.11 -2997.77 5934522.00 555857.73 MWD+IFR-AK-CAZ-SC 12877.53 91.25 183.39 3294.32 3172.92 -10975.73 -3002.34 5934422.35 555853.94 MWD+IFR-AK-CAZ-SC 12974.65 91.18 186.94 3292.26 3170.86 -11072.42 -3011.08 5934325.60 555845.96 MWD+IFR-AK-CAZ-SC 13070.43 91.68 188.34 3289.87 3168.47 -11167.32 -3023.81 5934230.62 555833.97 MWD+IFR-AK-CAZ-SC ~ 13164.70 90.44 189.07 3288.13 3166.73 -11260.48 -3038.08 5934137.35 555820.43 MWD+IFR-AK-CAZ-SC 13259.95 90.81 189.54 3287.09 3165.69 -11354.48 -3053.48 5934043.25 555805.77 MWD+IFR-AK-CAZ-SC I i ~ 13352.81 91.06 188.54 3285.57 3164.17 -11446.17 -3068.06 5933951.46 555791.90 MWD+IFR-AK-CAZ-SC 13437.80 91.43 189.84 3283.73 3162.33 -11530.05 -3081.63 5933867.48 555778.99 MWD+IFR-AK-CAZ-SC 13545.13 91.31 188.83 3281.16 3159.76 -11635.92 -3099.04 5933761.48 555762.41 MWD+IFR-AK-CAZ-SC 13640.05 90.94 186.20 3279.30 3157.90 -11730.00 -3111.45 5933667.32 555750.73 MWD+IFR-AK-CAZ-SC 13733.74 90.50 185.75 3278.12 3156.72 -11823.17 -3121.20 5933574.08 555741.71 MWD+IFR-AK-CAZ-SC 13829.78 90.63 184.62 3277.17 3155.77 -11918.81 -3129.88 5933478.39 555733.78 MWD+IFR-AK-CAZ-SC 13924.19 90.01 184.99 3276.65 3155.25 -12012.89 -3137.79 5933384.26 555726.61 MWD+IFR-AK-CAZ-SC 14019.90 89.95 184.34 3276.68 3155.28 -12108.28 -3145.57 5933288.82 555719.57 MWD+IFR-AK-CAZ-SC 14115.37 90.87 185.44 3276.00 3154.60 -12203.40 -3153.71 5933193.65 555712.17 MWD+IFR-AK-CAZ-SC 14210.70 90.44 184.68 3274.91 3153.51 -12298.35 -3162.12 5933098.65 555704.51 MWD+IFR-AK-CAZ-SC I 14302.79 90.57 183.42 3274.09 3152.69 -12390.21 -3168.62 5933006.75 555698.72 MWD+IFR-AK-CAZ-SC 14400.20 91.12 182.22 3272.66 3151.26 -12487.49 -3173.41 5932909.45 555694.69 MWD+IFR-AK-CAZ-SC 14493.71 93.17 180.51 3269.16 3147.76 -12580.90 -3175.64 5932816.03 555693.19 MWD+IFR-AK-CAZ-SC 14589.80 91.24 177.40 3265.46 3144.06 -12676.88 -3173.89 5932720.07 555695.69 MWD+IFR-AK-CAZ-SC 14685.99 92.05 174.76 3262.70 3141.30 -12772.80 -3167.31 5932624.22 555703.01 MWD+IFR-AK-CAZ-SC 14780.82 91.31 173.77 3259.92 3138.52 -12867.11 -3157.84 5932529.99 555713.22 MWD+IFR-AK-CAZ-SC 14875.50 89.14 173.45 3259.55 3138.15 -12961.20 -3147.31 5932436.00 555724.49 MWD+IFR-AK-CAZ-SC 14970.35 89.76 175.73 3260.46 3139.06 -13055.61 -3138.36 5932341.67 555734.17 MWD+IFR-AK-CAZ-SC 15065.99 87.97 177.67 3262.35 3140.95 -13151.07 -3132.86 5932246.27 555740.42. MWD+IFR-AK-CAZ-SC 15160.21 91.00 179.02 3263.20 3141.80 -13245.23 -3130.14 5932152.14 555743.87 MWD+IFR-AK-CAZ-SC ~~ 15255.57 90.07 177.71 3262.31 3140.91 -13340.55 -3127.42 5932056.86 555747.34 MWD+IFR-AK-CAZ-SC ! 15350.46 89.76 176.57 3262.45 3141.05 -13435.32 -3122.68 5931962.14 555752.81 MWD+IFR-AK-CAZ-SC 15445.11 90.51 178.42 3262.23 3140.83 -13529.87 -3118.55 5931867.63 555757.68 MWD+IFR-AK-CAZ-SC 15540.68 89.45 175.74 3262.26 3140.86 -13625.31 -3113.68 5931772.24 555763.30 MWD+IFR-AK-CAZ-SC ~ i 15634.59 88.90 177.56 3263.61 3142.21 -13719.04 -3108.19 5931678.56 555769.51 MWD+IFR-AK-CAZ-SC i 15729.98 91.49 181.47 3263.29 3141.89 -13814.40 -3107.39 5931583.22 555771.06 MWD+IFR-AK-CAZ-SC 15825.78 92.67 180.83 3259.81 3138.41 -13910.12 -3109.31 5931487.50 555769.89 MWD+IFR-AK-CAZ-SC 15920.26 92.85 175.84 3255.26 3133.86 -14004.42 -3106.57 5931393.23 555773.37 MWD+IFR-AK-CAZ-SC 16013.29 89.02 171.95 3253.74 3132.34 -14096.87 -3096.68 5931300.87 555783.98 MWD+IFR-AK-CAZ-SC 16109.79 88.47 170.89 3255.85 3134.45 -14192.27 -3082.28 5931205.60 555799.11 MWD+IFR-AK-CAZ-SC 16202.62 90.45 172.52 3256.73 3135.33 -14284.11 -3068.89 5931113.86 555813.22 MWD+IFR-AK-CAZ-SC i 16246.00 90.45 172.52 3256.39 3134.99 -14327.12 -3063.24 5931070.90 555819.20 PROJECTED to TD Description of Casing Well : 1J-1 ConacoPhil~Ep~ Slotted and Blank Liner. Date: .211 Alaska, ~n~., Supervisors; Mike Thornton ;Granvil/e Rizek Rig: Doyon 15 ~:;e4:. DEPTH Jt Number Num of Jts COMPLETE ~' OF EQUIPMENT RUN LENGTH TOPS ~~ ~ Plop & Drop 10248.70 "B" Lateral ZXP @ 10168.58' / XO @ 10219.99' 10248.70 Note: "D" lateral window top @ 10050'/ Btm @ 10067' 10248,70 TOL 18T out in open hole @ 10,254' 10248.70 10248.70 10248.70 5" DP to Surface =_> 10248.70 Liner Runnin .Tool 5" goes not sta in hole 6.03 10248.70 5 1/2" Baker "HR" Liner Setting Sleeve (6.41" O.D. x 5.75" I.D.) 15.16 10254.73 5 1/2", 15.5 ppf, L-80, Hydril 521 Pup joint 7.34 10269:89 51/2", 15.5 ppf, L-80, Hydril 521 42.27 10277.23 5.1/2" Hydril 521 Pin X 4 1/2" BTC Pin X/O (3.96" LD.) 1.40 10319.50 4-1/2", 11.6 ppf, L-80, BTC PUP Jt. 3.80 10320.90 Jts 173 to 17 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 86.40 10324.70 Jts 172 to 17 1 Jts 4-1/2", 11.6 ppf, L-80, BTC$lank Casing 42.72 10411.10 Jts 171 to 171 1 Jts 4-1/2",11.6 ppf, L-80, BTC ~#ottect Casing 42.47 10453.82 Jts 17o to 17 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 41.13 10496.29 Jts 169 to 16 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.52 10537.42 Jts 162 to 16 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 293.07 10577.94 Jts 160 to 161 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 86.52 10871.01. Jts 159 to 15 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 39.48 10957.53 Jts 158 to 15 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 39.87 10997.01 Jts 157 to 15 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.95 1103ti.88 Jts 156.to 15 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 39.53 11079.83 Jts 155 to 15 1 Jts 4-1/2",.11.6 ppf, L-80, BTC Blank Casing 42.53 11119.36 Jts 154 to 15 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.85 11161.89 Jts 153 to 15 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.67 11204.74 Jts 152 to 15 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.31 11247.41 Jts 151 to 151 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 41.70 11289.72 Jts 15o to 15 1 Jts 4-1/2",11.6 -ppf, L-80, BTC Slotted Casing 38..82 . 11331.42 Jts 143 to 14 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 298.81 11370.24 Jts 141 to 14 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 86.42 11669.05 Jts 14o to 14 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.34 11755.47 Jts 139 to 13 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.50 11798.81 Jts 138 to 13 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.14 11842.31 Jts 137 to 13 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.38 -11885.45 Jts 136 to 13 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.93 11928.83 Jts 135 to 13 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.37 11971.76 4-1/2" :Ran total of 108 Jts Blank= 4,575.76' and 66 Jts Slotted= 2,810.17'. Up Wt 300K Slots are w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, Dn VVt OK 3" Centers Staggered 18 deg., 3 ft. non-slotted ends. Block IIVt 70K Used Run-N-Seal thread compound on alf connections. Rot VVt 155K Drifted 4-1/2" to 3.885 w/ teflon rabbit. 80 L1 7107 Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH Jts 134 to 13 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.68 12015.13 Jts 133 to 13 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.42 12057.81 Jts 132 to 13 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.65 12100.23 Jts 131 to 131 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.49 12142.88 Jts 124 to 13 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 293.00 12183.37 Jts 122 to 12 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Easing 85.71 12476.37 Jts 121 to 121 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.7$ 12562.08 Jts 120 to 12 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.49 12604.86 Jts 119 to 11 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.70 .12648.35 Jts 11s to 11 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.ss .12691.05 Jts 117 to 11 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing. 42.94 12732.93 Jts 116 to 11 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.39 12775.$7 Jts 115 to 11 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.35 12819.26 Jts 114 to 11 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.79 12862.61 Jts 113 to 11 1 Jts 4-1/2", 11..6 ppf, L-80, BTC Blank Casing 42.68 12903.40 Jts 112 to 11 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.38 12946.08 Jts 105 to 111 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 297.57 12989.46 Jts 103 to 10 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 86.84 13287.03 Jts 102 to 10 1 Jts 4-1/2", 1.1:6 ppf, L-80, BTC Blank Casing 39.75 13373.87 Jts 101 #0 101 1 ~Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 42.84 1:3413.62 Jts 1ooto 10 1 Jt? 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.21 ' 13456.46 Jts 99 to 99 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.86 13499.67 Jts 98 to 98 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 41.95 . 13542.53 Jts 97 to 97 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.62 13584.48 Jts 96 to 96 1 Jts 4-1/2' ; 11.6 ppf, L-80, BTC Blank Casing 42.73 13628.10 Jts 95 to 95 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 42.84 13670.83 Jts 94 to 94 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 38:66 13713.67 Jts 93 to 93 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.29 13752.33 Jts s7 to 92 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 251.47 13795.62 Jts 86 to s6 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.35 14047.09 Jts 85 to 85 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.70 14090.44 Jts 84 to s4 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.63 . 14133.14 Jts s3 to 83 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.88 14176.77 Jts s2 to 82 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.62 .14219.65 Jts s1 to 81 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.40 14263.27 Jts 8o to 80 1 Jts 4-1/2",11.6 ppf, L-80, BTG Slotted Casing 42:84 14306.67 Jts 79 to 79 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.81 14349.51 Jts 78 to 7s 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 36.95 14392.32 Remarks: TOPS • • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 77 to 77 1 Jts 4-1l2°', 11.6 ppf, L-80, BTC Blank Casing 39.so :14429.27 Jts 76 to 76 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.32 14469.07 Jts 75 to 75 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.88 14512.39 Jts 74 to 74 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.52 ,14555.08 Jts 68 to 73 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 250.37 .14598.60 Jts 67 to 67 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.05 14848.97 Jts 66 to 66 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.08 14892.02 Jts 65 to 65 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.91 14935.10 Jts 64 to 64 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.41 14978.01 Jts 63 to 63 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.14 15021.42 Jts 62 to 62 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 39.77 15064.56 Jts 61 to 61 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.17 15104:33 Jts 6o to 60 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.93. 15146,50 Jts 59 to 59 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 42.68 .15189.43 Jts 58 to 58 1 Jts 4-1/2".,11.6 ppf, L-80, BTC Blank Casing 42.91 15232.11 Jts 57 to 57 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.27 15275.02 Jts 56 to 56 1 Jts 4-1/2", 11..6 ppf, L-80, BTC Blank Casing 43.30 . 15318.29 Jts 55 to 55 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.40 15361.59 Jts 49 to 54 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 255.85 15404.99 Jts 47 to 48 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 86.22 15660.84 Jts 46 to 46 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.08 15747.06 Jts 45 to 45 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.43 15790.14 Jts 44 to 44 1 Jts' 4-1/2", 11.6 ppf, L$0, BTC Blank Casing 42.60 15831.57 Jts 43 to 43 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.30 .15874.17 Jts 42 to 42 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.02 . 15917.47 Jts 41 to 41 1 Jts 4-1/2",1.1.6 ppf, L-80, BTC Slotted Casing 43.04 15960.49 Jts 4o to 40 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.95 16003.53 Jts 39 to 39 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.03 16046.48 Jts 38 to 38 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.68 16089.51 Jts 37 to 37 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.48 16132.19 Jts 30 to 36 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 299.08 16172.67 Jts 28 to 29 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing s4.13 16471.75 Jts 27 to 27 1 Jts 4-1/2",11.6 ppf, L-80, BTC Blank Casing 42.69 16555.88 Jts 26 to 26 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.29 16598.57 Jts 25 to 25 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.93 16641.86 Jts 24 to 24 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.05 16684.79 Jts 23 to 23 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.85 16727.84 Jts 22 to 22 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.32 ..16770.69 Remarks: • • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT. RUN Page 4 LENGTH TOPS Jts 21 to 21 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.52 16814.01 Jts 20 to 20 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.11 16856.53 Jts 19 to 19 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.40 16899.64 Jts 18 to 18 1 Jts 4-1/2",11.6 ppf, L-80, BTG Slotted Casing 42.89 16943.04 Jts 11 to 17 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing. 286.52 16985.93 Jts 9 to 10 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 86.74 17282.45 Jts s to 8 1 Jts 4-1%2", 11.6 p.pf, L-80, BTC Blank Casing 43.51 17369.19 Jts 7 to 7 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.57 17412.70 Jts 6 to 6 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.so 17455.27 Jts 5 to 5 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.40 17498.07 Jts 4 to 4 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.53 17538.47 Jts 3 to 3 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.26 17582.00 Jts 2 to 2 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.11 .17625.26 Jts 1 to 1 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.26 17668.37 Cross over 4-1/2" BTC Box X 3-1 /2" IBT Pin 1.41 17710.63 3-1/2", 9.3 ppf, L-80, IBT Box X EUE 8rd Pin X/O PUP 6.35 17712.04 3-1/2", 9.3 ppf, L-80, EUE 8rd Blank Casing 31.33 17718.39 3-1/2", EUE 8rd Baker Float Shoe .60 -1"749.7 ~. 17750.32 177.32 17750.32 17750.32 TD 6 3/4" hole @ 17,779' MD / 3,252' TVD 17750.32 4-1/2" Shoe @ 17,750' MD / 3,252' TVD (Rathole 28') 17750.32 17750.32 17750.32 Total Parts used; 17750.32 174- 4-1/2"x 6.13" HydroFORM (#80549) Centralizers. 17750.32 17750.32 Run 1 HydroFORM every jt. Floating on each joint 17750.32 f/ Jt #1 thru Jt #174 17750.32 17750.32 Run torque rings from joint #90 thru #174 17750.32 Total of 85-4-1/2" torque rings. 17750.32 17750.32 17750.32 17750.32 17750.32 Remarks: 04-Apr-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-180L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 15,729.98' MD Window /Kickoff Survey 15,800.00' MD (if applicable) Projected Survey: 17,779.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) `~ 04-Apr-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-180 L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,991.73' MD Window /Kickoff Survey 10,050.00' MD (if applicable) Projected Survey: 16,246.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Signed Please call me at 273-3534 if you have any. questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~'`" 151 Re: 1 J-180 (PTD 2061510) Request to pre-produce with TxIA comm. Subject: Re: 1J-180 (PTD 2061510) Request to pre-produce with TxIA comm. From: Thomas Maunder <tom_mauz~der~cv,`admin.state.ak.us> Date: Fri, 23 Mar 2007 09:29:27 -0800 To: NSK Problem `~~"cll Supv <n16i7(~.conocophillips.com~~ CC: ,i~uu~~s Rc~~~~` jim_rc~~~~~r~adr»ii~.siatc.al;.us I need to provide an edit of my earlier message. Sorry for missing a word or two. Tom NSK Problem Well Supv wrote, On 3/23/2007 9:21 AM: Tom, Thanks for the quick response. ll~arie From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us} Sent: Friday, March 23, 2007 9:05 AM - To: NSK Problem Well Supv Cc: James Regg Subject: Ike: I,J-180 (PTD'2061510) Request to pre-produce with TxIA comm. _ Mariey The sliding sleeve is located proximate to the packer and for gas to enter the tubing by default little '', to no liquid will be in the annulus. It is acceptable to produce the well. So far as T' x IA communication is concerned in this and similar cases, it is a fact of lifting the vve11. It is a much '' different situation where{~el~iej-communication between the IA and T has been realized by compromising some part of the completion equipment. '' Call or message with any questions. ', Tom Maunder, PE AOGCC NSK Problem We11 Supv wrote, On 3/23/2007 8:59 AM: Tom, New West Sak injector 1J-180 (PTD 2061510) is being prep'd fora 30 day pre-production period. The completion has a packer with a sliding sleeve (CMD) and one GLM above the packer. To lift the well as deep as possible, a gaslift valve will be installed in the GLM and the sliding sleeve will be opened as the bottom lifting point. With the sliding sleeve open, there will be TxIA communication. The annulus (IA) will not be isolated from produced fluids per 20 AAC 25.200 (d) while on pre-production; however, gas lift will be injected down the IA, minimizing or preventing produced fluids from entering the IA. Permission is requested to pre-produce 1 J-180 with the sliding sleeve above the packer during the pre-production period. The pre-production is scheduled to start tomorrow, Sat 3/24. Please let me know if there are any questions. I of 2 ~ ~ 3/23/2007 9:29 AM RE: Corrected PERMIT IT's for IJ-180 » • Subject:RE: Corrected PERMIT IT's forlJ-180 From: "Greener, Mike R." <Mike.R.Greenera,conocophillips.com> Date: F7-i; 27 Oct 2006 OS:~6:~5 -0~(~i7 To: `I~homas Maunder ~~_-tom maunder(-radmin.state.ak.ii5. The bond log would be run after we get the liner in the ground on the first lateral to give the cement an appropriate time to cure due to the low temperature of the formations. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, October 27, 2006 7:34 AM To: Greener, Mike R. Subject: Re: Corrected PERMIT ITs for 1]-180 Mike, What you sent takes care of the hardware of the completion. I don't see where you plan to run a bond log. I also had one other thought concerning the BOP description. I seem to remember that in one of the "versions" out there that there was a description of the ram configuration with DP on top and casing on bottom. If you have that description, it would be appropriate to include it. Thanks for your attention to these requests. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 10/27/2006 6:57 AM: My :fault on the permits. I should have caught that. Thanks for the phone call. I have attached. the carrected versions. «1J-180 PERMIT IT.doc» «1J-180 L1 PERMIT IT.doc» \ c M1ike Greener ~~ ~S °~',~~~cs.~-`~io~ ~~ ~.C.~~c@~ ~~~,~ GAS ~ e~a~C~~C.~'`° I~STP~ «Greener, Mike R..vcf» ~~~ ~~` ` ~-- "~~~ ~ '! Content-Description: 13-5 BOP 3K diagram.pdf `13-5 BOP 3K diagram.pdf 'i Content-Type: application/octet-stream '' Content-Encoding: base64 ~~,~~ ~J~<C,~ 1 of 1 10/27/2006 8:53 AM r~ FRANK H. MURKOWSKI, GOVERNOR Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-7433 FAX .(907)276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-180L 1 ConocoPhillips Alaska, Inc. Permit No: 206-151 Surface Location: 1508' FSL, 2443' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1588' FSL, 184' FEL, SEC. 15, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-180, Permit No 206-150, API 50-029-23329-00. Injection should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commissi petroleum field inspector at (907) 659-3607 (pager). ~. DATED this30 day of October, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~}/ ` ~ STATE OF ALASKA ~ ~"i ~ O/ ~® ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~~ ~ 1 7 2006 20 AAC 25.005 C.~1nS• Ct?f11mIS'i011 1 a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service Q • Development Gas ^ Multiple Zone^ Single Zone ~ 1 ~ e is pr os~r: f Coalbed Metha~~ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 1J-180L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17862'• TVD: 3246' ~ 12, FieldlPool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1508' FSL, 2443' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ,~j I?Z ADL 2 , 25663,~~72 ~• ~° ~? West Sak Oil Pool Top of Productive Horizon: 1421' FNL, 201' FEL, Sec. 10, T10N, R10E, UM 8. Land Use Permit: ALK 2177, 472, 2181 13. Approximate Spud Date: 12/27/2006 Total Depth: 1588' FSL, 184' FEL, Sec. 15, T10N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: < 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558770 y- 5945420 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1J-156L2 , 364' @ 125E 16. Deviated wells: Kickoff depth: 10318 • ft. Maximum Hole Angle: 93.6° deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.oa5) Downhole: 1451 psig, Surface: 1096 psig ~ 18. Casing Program ti S if Setting Depth Quantity of Cement Size ons pec ica Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 80' 80' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3878' 28' 28' 3878' 2142' 730 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10784' 28' 28' 10784' 3412' 700 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTCM 7544' 10318' 3345' 17862' ~ 3246' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): c5~~~ ~~"`'~- 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ( l Phone 2,bs 6Z? 3o Date to ~C61o6 Pre h n All k Commission Use Only Permit to Drill Number: ~~~0"~S/ API Number: 50-~Z9~~?jG.w/'~ Permit Approval Date: /d 30 See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ,~®~pSi ~ Samples req'd: Yes ^ No ~ Mu g r q'd: Yes ^ No Other: \ ~ T F~ measu/res: Yes [] No [~ Dir a svy q'd: Yes ~ No ^ U ~ ~-L J--cC~~-C~ C~ O~t~S`r.t~-p,CCS~r~\ ~G ~~~~ PROVED BY THE COMMISSION DATE: ~~ ~' Q~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ 1 ~ ~ (-y ~ ~ ©~V ~/ ~ Submit in Du/pl~icate ter V ~ 1 ~iC~ t~'/~G Ot Appli~ for Permit to Drill, Well 1 J-180 L1 Revision No.O Saved: 16-Oct-06 Permit It -West Sak Well #1J-180L1 Application for Permit to Drill Document M p x i m i z~ VJef l Vv1u B Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ ............................................................................................................. 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 2S.OOS(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 2S.050(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.OOS(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)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 3 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.OOS(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 2S.OOS(c)(8) ......................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ............................................................................... 4 9. Abnormally Pressured Formation Information ........................................................... 4 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 4 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 12. Evidence of Bonding ................................................................................................... 5 NOT DONE 1J-180 L1 PERMIT IT Page 1 of 6 Printed: 16-Oct-O6 ORIGINAL Appli~ for Permit to Drill, Well 1J-180 L1 Revision No.O Saved. 16-Oct-06 Requirements of 20 AAC 25.005 (c)(12) ....................... .............. 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 6 Requirements of 20 AAC 25.005 (c)(14) .......................................:.................................:............................ 6 15. Attachments ............................................................................................................... 6 Attachment 2 Directional Plan (6 pages) .................................................................................................... 6 Attachment 3 Drilling Hazards Summary (1 page) ...................................................................................... 6 Attachment 4 Well Schematic (1 page) ....................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be ident~ed by a tmique ~aame designated by the operator mid a unique API number assigned by the commission under 20 AAC 25.040(b). For a well x~ith multiple well branches, each branch must similarly be ident~ed by a unique name and API number by adding a suffix to the name designated for the x ell by the operator and to the number assigned to the i+~eil by the commission. The well for which this Application is submitted will be designated as 1J-180 L1. 2. Location Summary Requirements of 20 AAC 25.005(c) (2) An application for a Permit to Drili must be accomprnaied by each of the folloining items, except for an item already on file ~~~ith the commission and ident~ed in the application: (2) a plat ident~ing the property and the properg~'s oia~ners and shooing (A)che coordinates of the proposed location of tlae i+~ell at the surface, at the top of eac1~ objective formation, and at totat depth, referenced to governmental section lines. (B) the coordinates of the proposed Location of the i~~elt 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 hell at the top of each objective formation and at total depth; Location at Surface 1,508' FSL, 2443' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5,945,420 Eastings: 558,770 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 1,421' FNL, 201' FEL, Section 10, T10N, R10E Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10,317 Northings: 5,937,079 Eastings: 555,806 Total Vertical Depth, RKB: 3,346 Total Vertical Depth, SS: 3,224 Location at Total De th 1,588' FSL, 184' FEL, Section 15, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 17, 862 Northings: 5,929,540 Eastings: 555,889 Total Vertical De th, RKB: 3,246 - Total Vertical Depth, SS: 3,125 and (D) other information required by 20 AAC 25.0~0(b); Requirements of 20 AAC 25.050(b) If a i+~ell 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 ivellbores tivithin 200 feet of any portion of the proposed i+~ell; NOT DONE 1J-180 L1 PERMIT IT Page 2 of 6 Printed: 16-Oct-O6 ORIGINAL • Please see Attachment 1: Directional Plan Appli~ for Permit to Drill, Well 1J-180 L1 Revision No.O Saved: 16-Oct-06 and (2) for all wells ia~ithin 200 feet of the proposed ia~ellbore (A) list the names of the operators of those wells, to the extervt that those names are known or discoverable in public records, and shrnv 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 folloi~-ing 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 (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 2.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-180 L1. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the follrnving items, exceptfor an item ab^eady on file with the commission and identified in the application: (4) information on drilling ha=aids, inch4ding (A) lire 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 pressure in the West Sak sands in the 1J-180 L1 is 0.45 psi/ft, or 8.6 ppg EMW (equivalent - mud weight). The maximum potential surface pressure (MPSP) is 1,096 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 3,224'. The MPSP is: MPSP = (3,224 ft)(0.45 - 0.11 psi/ft) =1,096 psi , (B) data on potential gas pones; The well bore is not expected to penetrate any gas zones. And (C) data concerningpotential causes of hole problems such as abnorrnally geo ~r•essured strata, lost circulation pones, and pones that have a propensity for d~erential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill mast be accompanied by each of the following items, except for an item already on file 1a~ith the commission and ident~~ed in the application: (.i) a description of the procedure for conducting formation integrity tests, as required under 20 A~1C 25.0300; No formation integrity test will be performed in the drilling of 1J-180 L1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application far a Permit to Drill must be accompm~ied by each of the following items, except for an item already on file 4vith the commission and identified in the application: (6) a complete proposed casing arad cementing program as required by 20 A.1C 25.030, and a description of airy slotted liner, pre perforated liner, or screen to be installed; NOT DONE 1J-180 L1 PERMIT IT Page 3 of 6 Printed: 16-Oct-06 ~~~~~ Application for Permit to Drill, Well 1J-180 L1 Revision No.O Saved: 16-Oct-06 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" 40" 62 5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf . ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,878 28' / 28' 3,878' / 2,142' 730 sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 6,877' 9-5/8" 12-1/4" 40 L-80 BTCM 10,784 28' / 28' 10,784' / 3,412' MD / 2,591' TVD. Cemented w/ 700 sx DeepCRETE 4-1/2 6-3/4" B Sand Lateral 11.6 L- BTCM 543 7 10,418' / 3,362' 17,961' / 3,315' Slotted-no cem s tted , ~=~----~ - _ , _ _ __ 4- 12" 6-3/4" D Sand Lateral 11.6 L-80 BTCM 544 7 10,318' / 3,345' 17,862' / 3,246' Slotted- no cement slotted (1J-180 Ll) , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the follox~ing ite»ts, exceptfor an item already on file x~ith the commission and identified in the application: (7) a diao 'am and description of the diverter system as required by 20 AAC 25.035, unless this requirement is ia~aived by the commission under 20 AAC 25.035(h)(2); No diverter system will be used during operations on 1J-180 L1 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ident~ed in the application: (8) a drilling fluid progran¢, including a diagram and description of the drillingfluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Density ( ~ 9.0 Plastic Viscostiy (lb/100 s,~ 15-25 Yield Point (cP) 18-28 HTHP Fluid loss (ml/30 min 200psi & 1 SO° <4.0 Oil /Water Ratio 80:20 Electrical Stability >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the follrna ing items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or sb~atigraphic test hell, a tabulation setting out the depths of predicted abnormally geo yressured strata as required by 20 AAC 2~. 0330; 1J-180 L1 PERMIT IT ^ ~ ~ ~ ` , ~ Page4of6 11~,`,t' ~\`~~ Printed:16-Oct-06 Appli~ for Permit to Drill, Well 1 J-180 L1 Revision No.O Saved: 16-Oct-06 Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) ~n application for a Permit to Drill must be accompanied by each of the folloia~ing items, except for an item already on file with the commission and identified in the application: (10J for an exploratory or stratigraphic test weD, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded sb~ucture, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been nzet; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-180 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 10,318' MD /~4' TVD, the top of the r "D" sand. 33`~i ~ io -~?.o(. 2. Mi118-1/2" window. POOH. 3. Pick up 4-3/4" drilling assembly with LWD and MWD apd PWD. RIH. z.NG ~D io.i?• e~ 4. Drill to TD of "D" sand lateral at 17,862' MD /~5' T D, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 11. POOH, laying down drill pipe as required. 12. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPS, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and move rig off. NOT DONE 1J-180 Li PERMIT IT Page 5 of 6 Printed: 16-Oct-06 ORIGINAL Appli~ for Permit to Drill, Well 1 J-180 L1 Revision No.O Save 6-Oct-06 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. 19. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disp al Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill nsustc be accompanied by each of the follo~+ n ~ m exceptfor an item already on file with the commissio~a and identified in the application: (14) a general description of how the operator plans to dispose of drilling a .tongs and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for ma annular disposgj.cy~erati n in e t+~ell.; 11 be p Y operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Attachment 3 Well Schematic NOT DONE 1J-180 L1 PERMIT IT Page 6 of 6 Printed: 16-Oct-06 Waste fluids generated during the drilling process will bed sed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fl Class II disposal well. All cuttings generated wi disposed of either down a permitted annulus on uled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for inje down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous s nces) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Al ConocoPhilli s Alaska ma in the future r~~ t thorization for the use of this well for annular disposal 16. Rig up wire line unit. Pull BPV. App~n for Permit to Drill, Well 1J-180 L1 Revision No.O Saved: 27-Oct-06 17. Set gas lift valves in mandrels. Operate well on gas lift until well cleanup is finished. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. 19. Place well on injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) lIY rfjlr 1TL`FTEPYJY jOY tZ ~Frxfdlt TO ~tYtt mLdSlC Cxe (ZCCY)772~Jrlrxtf,'tt t)}~ t:fxCh oftT. f: fEJt:Cr ~Sdrx~ Tt6tDLS, B.CL t.~%t tOY ftrt 1LLtPI tLlrPdxdj-' t~tF fll£'. N'tlli the t".'1Jn2Tt2TSSZf31t CLnd €Ftl7titjl{=11Pf t11C: fIp]J1tC`Qx"It3ix: rt•l) cz rererrt dcst;rzpt;r~T€ c; l€©w zlae ©~xcrntr.Jr ptarxs to drsj~t~se o) drillzn~ mud crrad cuttings rrnc.; c€ strrtem.€nt ~~iar~cahc:x the r~pnrtzt~r trxterxds to request arrlhcJrt.~t€ti~n urxdt:r 2d ~t~4~ 25.t?r4f f1Jr crn anrxxrtax~ dzsp~sat oirex•rzfrcJn irx the Fti•e11.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-180 L1 PERMIT IT.doc Page 6 of 6 Printed: 27-Oct-06 • Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular ~ To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/" to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ~ To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" ~ To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly V ~~~ DO On 13-5 BOP 3K diagram.vsd ~~~~~~~~~ ~ `~ ~~ y 7'4''rWest Sak 3 ksi Sheet 1 of 1 BOP Configuration prepared by Steve~112004 hoc}Si~.:~ ' • Conoco hillips Alaska Plan: 1J-180 L1 (wp08) Sperry Drilling Services Proposal Report -Geographic 11 October, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-180 Plan 1J-180 L1 Local Coordinate Origin: Centered on Well Plan 1J-180 Viewing Datum: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet Sperry Drilling Services ~. ~ k ~~~~~ Project: Kuparuk River Uni ~ CASING DETAILS Site: Kuparuk 1J Pad Well: Plan 1J-180 No TVD MD Name Size Wellbore: Plan 1J-180 L1 ~DO° 3 1 2142.00 3878.25 13 3/8" 13-3/8 " Plan: 1J-180 L1 (wp08) 00 2 TOW 9-5/8 3345.17 10318.41 9 5/8 3 3246.00 17861.90 41/2" 4-1/2 -7000 190° L1: 9 5/8" TOW @ 10317' MD 3345' TVD: 1421' FNL, 201' FEL - Sec10-T10N-R1 -aooo ___--- - )~980° ----"- -9000 1J-180 L1 wp08 (West Turn Point) 1J-180 L1 wp08 T2 (Exit Upper) 1-11 1J-180 L1 wp08 T3 (Exit Lower) -- 179° 180° 180° 1J-180 L1 wp08 T3.1 o '--- 1J-180 L1 wp08 T4 (Exit Upper) - - - 180° z r 0 Z 180° r 0 1J-180 L1 wp08 T5 (Exit Lower) - - - 180° 1J-180 L1 wp08 T6 - - - 180° 1J-180 L1wp08Toe- -. ~______________ 4 1/2" ~, L1: BHL @ 17862' MD, 3246' TVD: 1588' FSL, 184' FEL - Sec15-T10N-R1 1J-180 L1 (wp08) ~-1 COtIOCOP~II~~t~?S Akr.:ka -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 West(-)/East(+) (1500 ft/in) T M 4zunulh5 to True I!or~h Magnetic Norlh: 24.09° Magnetic Field Strength: 57563.7nT Dip Angle: 80.77° Date: 5/17/2006 Model: BGGM2005 Orifih+g antl Formation Evsiwtlon 2000 3000 ORIGINAL Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-180 Wellbore: Plan 1J-180 L1 Plan: 1J-180 L1 (wp08) a 1 1 L1: 9 5/8" TOW ~ 10317' MD 3345' TVD: 1421' FNL, 201' FEL - Sec10-T10N-R10E - - - - - - - - - - - - - - - - - - - - - - - - - - CASING DETAILS No TVD MD Name Size 1 3345.17 10318.41 9 518" TOW 9-518 2 3246.00 17861.90 41/2" 4-112 FORMATION TOP DETAILS No. TVDPath TVDSS MDPath Formation 1 1546.00 1425 1696.94 Base Perm 2 1645.00 1524 1849.26 K15 3 1948.00 1827 2849.70 T3 4 2142.00 2021 3878.25 T3 +550 5 2802.00 2681 7377.43 Ugnu C 6 2991.00 2870 8379.70 Ugnu B 7 3066.00 2945 8779.33 Ugnu A 8 3212.00 3091 9570.02 K13 9 3337.00 321610271.42 WSAK D 10 3345.00 322410317.41 WSAK C 11 NaN WSAK B 2000 L1: BHL ~ 17862' MD, 3246' TVD: 1588' FSL, 184' FEL - Sec15-T10N-R10E ® 2500 000 -__------a---_ ~~/----------------------------------------- ---`~• " ~/ / 0 -- ar _ ._ _ _ 0 41/2 Q _ _ - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - ° _ o oo o i ~ , ~ _~_~ _ 1J-180 L1 (wp08 ~ ___________ ~ X1 1J-180 (wp08 w i > '~ i I c c I c I ~ 5110 I 1 m f e r c `~ to 00 ~ °o i I o I °o i m l O ` I \ U ~ I N I lh~S.4h 1. ~ 1 0 ~` ~ ~ ~ ~ I ~ I 1 I 1 1 ~ 1 I ! ~ I 1 1 I 11 1 1 \ ~DDO 1 1 11 11 \~ I I I ~ I 1 I I I 1 1 ~ 1J-180 L1 wp08 T2 (Exit Upper) , 1J-1B0 L11wp08 T3. 111 1J-180 L1 wp08 T5 (Exit Lower) II 1J-180 L1 wpo8 To I I 1 1 I I 1J-180 L1 wp08 7 tt L 08 T3 E 1 4500 ( x wp ower) 1J-180 L1 wp08 T4 (Exit Upper 1J-180 L1 wp08 (West Tum Polnt 1J-180 L ConocoPhiliips Alaska 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 1 VeRical SecUOn at 180.00° (1000 tUin) Drllliny end Form~don @voluAClon 14000 14500 15000 15500 16000 16500 ConacaPhillips p1~3$~ Database: _EDM_2003.11_b48 Halliburton Energy Services ~ Planning Report -Geographic Drilling and Formation Evaluetlon Local Co-ordinate Reference: Well Plan 1 J-180 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (4U+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True ~ Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 L1 De~ sign: 1J-180 L1 (wp08) 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) Map Zone: Alaska Zone 04 - Using geodetic scale factor Well Plan 1J-180 Well Position +N/-S 0.00 ft Northing: 5,945,419.90 ft Latitude: 70° 15' 41.344" N +E/-W 0.00 ft Easting: 558,770.00 ft Longitude: 149° 31' 29.701" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft ~ Wellbore Plan 1J-180 L1 Maynetics Model Name Sample Date Declination Dip Angle Field Strength bggm2005 5/17/2006 24.09 80.77 57,564 Design 1J-180 L1 (wp08) Audit Notes: Version: 20 Phase: PLAN Tie On Depth: 10,317.41 Vertical Section: Depth From (TVD) +N!-S +E!-W Direction (ft) (ft) (ft) ('') 0.00 0.00 0.00 180.00 10/16/2006 2:46:46PM Page 2 of 8 COMPASS 2003.11 Build 50 ~~i~.Ji~l-tL • 1/ Coruxo~tillips Alaska Halliburton Energy Services Planning Report -Geographic • 1..~.~ ~r Oriliing and FormaGirn~ ~vai~:a, Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True i Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 L1 Design: 1J 180 L1 (wp08) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +El-W Rate Rate Rate TFO (ft) (°} (°} (ft) (ft) (ft) (°/100ft) (°I100ft) (°1100ft) {°) 10,317.41 80.00 178.94 3,345.00 -8,318.31 -3,029.30 0.00 0.00 0.00 0.00 10,333.91 82.24 178.94 3,347.55 -8,334.61 -3,029.00 13.60 13.60 0.00 0.00 10,363.91 82.24 178.94 3,351.59 -8,364.33 -3,028.45 0.00 0.00 0.00 0.00 10,553.03 91.70 178.94 3,361.57 -8,552.94 -3,024.96 5.00 5.00 0.00 0.00 10,639.94 96.04 178.68 3,355.71 -8,639.61 -3,023.16 5.00 4.99 -0.29 -3.36 10,747.46 96.04 178.68 3,344.40 -8,746.51 -3,020.70 0.00 0.00 0.00 0.00 10,841.59 91.34 178.97 3,338.35 -8,840.40 -3,018.78 5.00 -4.99 0.30 176.51 11,991.59 91.34 178.97 3,311.45 -9,989.90 -2,998.12 0.00 0.00 0.00 0.00 12,072.19 91.34 183.00 3,309.57 -10,070.45 -2,999.50 5.00 0.00 5.00 90.00 12,165.07 87.05 181.23 3,310.88 -10,163.23 -3,002.93 5.00 -4.62 -1.91 -157.59 12,218.48 87.05 181.23 3,313.63 -10,216.56 -3,004.07 0.00 0.00 0.00 0.00 12,303.19 91.10 180.00 3,315.00 -10,301.23 -3,004.98 5.00 4.78 -1.45 -16.88 13,553.19 91.10 180.00 3,291.00 -11,551.00 -3,004.98 0.00 0.00 0.00 0.00 13,610.24 93.95 180.00 3,288.49 -11,607.99 -3,004.98 5.00 5.00 0.00 0.00 13,710.25 93.95 180.00 3,281.59 -11,707.76 -3,004.98 0.00 0.00 0.00 0.00 13,776.10 90.66 180.00 3,278.94 -11,773.55 -3,004.98 5.00 -5.00 0.00 180.00 14,726.10 90.66 180.00 3,268.00 -12,723.48 -3,004.98 0.00 0.00 0.00 0.00 14,761.74 89.59 180.00 3,267.92 -12,759.13 -3,004.98 3.00 -3.00 0.00 180.00 15,052.62 89.59 180.00 3,270.00 -13,050.00 -3,004.98 0.00 0.00 0.00 0.00 15,145.38 84.95 180.00 3,274.41 -13,142.62 -3,004.98 5.00 -5.00 0.00 -180.00 15,196.36 84.95 180.00 3,278.90 -13,193.41 -3,004.98 0.00 0.00 0.00 0.00 15,303.10 90.29 180.00 3,283.33 -13,300.02 -3,004.98 5.00 5.00 0.00 0.00 16,553.10 90.29 180.00 3,277.00 -14,550.00 -3,004.98 0.00 0.00 0.00 0.00 16,619.99 93.63 180.00 3,274.71 -14,616.84 -3,004.98 5.00 5.00 0.00 0.00 16,726.81 93.63 180.00 3,267.94 -14,723.45 -3,004.98 0.00 0.00 0.00 0.00 16,774.70 91.24 180.00 3,265.90 -14,771.29 -3,004.98 5.00 -5.00 0.00 180.00 17,324.70 91.24 180.00 3,254.00 -15,321.16 -3,004.98 0.00 0.00 0.00 0.00 17,337.75 90.85 180.00 3,253.76 -15,334.21 -3,004.98 3.00 -3.00 0.00 -180.00 17,861.91 90.85 180.00 3,246.00 -15,858.31 -3,004.98 0.00 0.00 0.00 0.00 10/16/2006 2:46:46PM Page 3 of 8 COMPASS 2003.11 Build 50 CortotoPhillips Alaska Halliburton Energy Services Planning Report -Geographic ~;a.t~t L°rr~ Grilling and FormaE~ Evairtatian Database: _EDM_2003.11_b48 Locat Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True , ~ Well; Plan 1J-180 Survey Calculation Method: Minimum Curvature . I Wellbore: Plan 1J-180 L1 Design: 1J-180 L1 (wp08) Planned Survey 1J-1801_1 (wp08) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E!-W Northing Fasting DLSEV Vert Section (ft) (°) (°) Ift) (ft) (ft) lft) lftl (ft) (°/100ft) (ft) 10,317.41 80.00 178.94 3,345.00. 3,224.00 -8,318.31 -3,029.30 5,937,079.00 555,806.00 0.00 8,318.31 L7: 9 5/8" TOW @ 10317' MD 3345' TVD: 1421' FNL, 2 01' FEL - Sec10-T10N-R10E - WSAK C -1J-180 114 Mile Heel 10,318.41 80.14 178.94 3,345.17 3,224.17 -8,319.30 -3,029.28 5,937,078.02 555,806.03 13.60 8,319.30 9 5/8" TOW 10,333.91 82.24 178.94 3,347.55 3,226.55 -8,334.61 -3,029.00 5,937,062.71 555,806.43 13.60 8,334.61 10,363.91 82.24 178.94 3,351.59 3,230.59 -8,364.33 -3,028.45 5,937,032.99 555,807.21 0.00 8,364.33 10,400.00 84.05 178.94 3,355.90 3,234.90 -8,400.15 -3,027.78 5,936,997.18 555,808.15 4.99 8,400.15 10,500.00 89.05 178.94 3,361.92 3,240.92 -8,499.92 -3,025.94 5,936,897.44 555,810.78 5.00 8,499.92 10,553.03 91.70 178.94 3,361.57 3,240.57 -8,552.94 -3,024.96 5,936,844.44 555,812.17 5.00 8,552.94 10,600.00 94.04 178.80 3,359.22 3,238.22 -8,599.84 -3,024.03 5,936,797.55 555,813.46 5.00 8,599.84 10,639.94 96.04 178.68 3,355.71 3,234.71 -8,639.61 -3,023.16 5,936,757.79 555,814.64 5.01 8,639.61 10,700.00 96.04 178.68 3,349.39 3,228.39 -8,699.32 -3,021.79 5,936,698.10 555,816.48 0.00 8,699.32 10,747.46 96.04 178.68 3,344.40 3,223.40 -8,746.51 -3,020.70 5,936,650.92 555,817.93 0.00 8,746.51 10,800.00 93.42 178.84 3,340.07 3,219.07 -8,798.85 -3,019.58 5,936,598.60 555,819.47 5.00 8,798.85 10,841.59 91.34 178.97 3,338.35 3,217.35 -8,840.40 -3,018.78 5,936,557.06 555,820.59 5.01 8,840.40 10,900.00 91.34 178.97 3,336.98 3,215.98 -8,898.78 -3,017.73 5,936,498.70 555,822.09 0.00 8,898.78 11,000.00 91.34 178.97 3,334.64 3,213.64 -8,998.74 -3,015.94 5,936,398.77 555,824.67 0.00 8,998.74 11,100.00 91.34 178.97 3,332.30 3,211.30 -9,098.69 -3,014.14 5,936,298.84 555,827.25 0.00 9,098.69 11,200.00 91.34 178.97 3,329.96 3,208.96 -9,198.65 -3,012.34 5,936,198.91 555,829.82 0.00 9,198.65 11,300.00 91.34 178.97 3,327.63 3,206.63 -9,298.61 -3,010.55 5,936,098.98 555,832.40 0.00 9,298.61 11,400.00 91.34 178.97 3,325.29 3,204.29 -9,398.56 -3,008.75 5,935,999.05 555,834.98 0.00 9,398.56 11,500.00 91.34 178.97 3,322.95 3,201.95 -9,498.52 -3,006.95 5,935,899.12 555,837.56 0.00 9,498.52 11,600.00 91.34 178.97 3,320.61 3,199.61 -9,598.48 -3,005.15 5,935,799.19 555,840.13 0.00 9,598.48 11,700.00 91.34 178.97 3,318.27 3,197.27 -9,698.43 -3,003.36 5,935,699.26 555,842.71 0.00 9,698.43 11,800.00 91.34 178.97 3,315.93 3,194.93 -9,798.39 -3,001.56 5,935,599.33 555,845.29 0.00 9,798.39 11,900.00 91.34 178.97 3,313.59 3,192.59 -9,898.35 -2,999.76 5,935,499.40 555,847.86 0.00 9,898.35 11,991.59 91.34 178.97 3,311.45 3,190.45 -9,989.90 -2,998.12 5,935,407.87 555,850.22 0.00 9,989.90 1J-180 L1 wp08 (West Tu rn Point) 12,000.00 91.34 179.39 3,311.26 3,190.26 -9,998.30 -2,998.00 5,935,399.47 555,850.41 4.97 9,998.30 12,072.19 91.34 183.00 3,309.57 3,188.57 -10,070.45 -2,999.50 5,935,327.32 555,849.47 5.00 10,070.45 12,100.00 90.06 182.47 3,309.23 3,188.23 -10,098.22 -3,000.83 5,935,299.54 555,848.36 4.99 10,098.22 12,165.07 87.05 181.23 3,310.88 3,189.88 -10,163.23 -3,002.93 5,935,234.52 555,846.76 5.00 10,163.23 12,200.00 87.05 181.23 3,312.67 3,191.67 -10,198.10 -3,003.68 5,935,199.65 555,846.29 0.00 10,198.10 12,218.48 87.05 181.23 3,313.63 3,192.63 -10,216.56 -3,004.07 5,935,181.19 555,846.04 0.00 10,216.56 12,300.00 90.95 180.05 3,315.05 3,194.05 -10,298.04 -3,004.98 5,935,099.71 555,845.77 5.00 10,298.04 12,303.19 91.10 180.00 3,315.00 3,194.00 -10,301.23 -3,004.98 5,935,096.52 555,845.79 5.00 10,301.23 12,400.00 91.10 180.00 3,313.14 3,192.14 -10,398.02 -3,004.98 5,934,999.74 555,846.55 0.00 10,398.02 12,500.00 91.10 180.00 3,311.22 3,190.22 -10,498.00 -3,004.98 5,934,899.78 555,847.33 0.00 10,498.00 12,600.00 91.10 180.00 3,309.30 3,188.30 -10,597.98 -3,004.98 5,934,799.81 555,848.11 0.00 10,597.98 12,700.00 91.10 180.00 3,307.38 3,186.38 -10,697.97 -3,004.98 5,934,699.84 555,848.89 0.00 10,697.97 12,800.00 91.10 180.00 3,305.46 3,184.46 -10,797.95 -3,004.98 5,934,599.87 555,849.67 0.00 10,797.95 12,900.00 91.10 180.00 3,303.54 3,182.54 -10,897.93 -3,004.98 5,934,499.90 555,850.45 0.00 10,897.93 13,000.00 91.10 180.00 3,301.62 3,180.62 -10,997.91 -3,004.98 5,934,399.93 555,851.23 0.00 10,997.91 13,100.00 91.10 180.00 3,299.70 3,178.70 -11,097.89 -3,004.98 5,934,299.96 555,852.01 0.00 11,097.89 13,200.00 91.10 180.00 3,297.78 3,176.78 -11,197.87 -3,004.98 5,934,199.99 555,852.79 0.00 11,197.87 13,300.00 91.10 180.00 3,295.86 3,174.86 -11,297.86 -3,004.98 5,934,100.02 555,853.57 0.00 11,297.86 13,400.00 91.10 180.00 3,293.94 3,172.94 -11,397.84 -3,004.98 5,934,000.05 555,854.35 0.00 11,397.84 10/16/2006 2:46:46PM Page 4 of 8 COMPASS 2003.11 Build 50 ~~.~ r /p1~ Halliburton Energy Services ~~ndiC~l'I II~~I~S Planning Report -Geographic Alaska t~i ~° Oriliing and FormaEfon Evaluation Database: _EDM_2003.11_b48 Locai Go-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) I Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True WeII: Plan 1 J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 L1 Desiym 1J-180 L1 (:vp03) Planned Survey 1J-1EO L1 (wp08) Map Map MD Inclination Azimuth TVD SSTVD +N/S +E/-W Northing Easting DLSEV Vert Section (ffl (°) (°) (ft) (ft] (ft) (ff) (~) (~) (°l100ft1 ('ft) 13,500.00 91.10 180.00 3,292.02 3,171.02 -11,497.82 -3,004.98 5,933,900.09 555,855.13 0.00 11,497.82 13,553.19 91.10 180.00 3,291.00 3,170.00 -11,551.00 -3,004.98 5,933,846.91 555,855.54 0.00 11,551.00 1J-180 L1 wp08 T3 (Exit Lower) 13,600.00 93.44 180.00 3,289.15 3,168.15 -11,597.77 -3,004.98 5,933,800.15 555,855.91 4.99 11,597.77 13,610.24 93.95 180.00 3,288.49 3,167.49 -11,607.99 -3,004.98 5,933,789.93 555,855.99 5.03 11,607.99 13,700.00 93.95 180.00 3,282.30 3,161.30 -11,697.53 -3,004.98 5,933,700.40 555,856.69 0.00 11,697.53 13,710.25 93.95 180.00 3,281.59 3,160.59 -11,707.76 -3,004.98 5,933,690.17 555,856.77 0.00 11,707.76 13,776.10 90.66 180.00 3,278.94 3,157.94 -11,773.55 -3,004.98 5,933,624.39 555,857.28 5.00 11,773.55 13,800.00 90.66 180.00 3,278.67 3,157.67 -11,797.45 -3,004.98 5,933,600.50 555,857.47 0.00 11,797.45 13,900.00 90.66 180.00 3,277.52 3,156.52 -11,897.44 -3,004.98 5,933,500.52 555,858.25 0.00 11,897.44 14,000.00 90.66 180.00 3,276.36 3,155.36 -11,997.43 -3,004.98 5,933,400.54 555,859.03 0.00 11,997.43 14,100.00 90.66 180.00 3,275.21 3,154.21 -12,097.43 -3,004.98 5,933,300.55 555,859.81 0.00 12,097.43 14,200.00 90.66 180.00 3,274.06 3,153.06 -12,197.42 -3,004.98 5,933,200.57 555,860.59 0.00 12,197.42 14,300.00 90.66 180.00 3,272.91 3,151.91 -12,297.41 -3,004.98 5,933,100.59 555,861.37 0.00 12,297.41 14,400.00 90.66 180.00 3,271..76 3,150.76 -12,397.41 -3,004.98 5,933,000.61 555,862.15 0.00 12,397.41 14,500.00 90.66 180.00 3,270.60 3,149.60 -12,497.40 -3,004.98 5,932,900.63 555,862.93 0.00 12,497.40 14,600.00 90.66 180.00 3,269.45 3,148.45 -12,597.39 -3,004.98 5,932,800.65 555,863.71 0.00 12,597.39 14,700.00 90.66 180.00 3,268.30 3,147.30 -12,697.39 -3,004.98 5,932,700.67 555,864.49 0.00 12,697.39 14,726.10 90.66 180.00 3,268.00 3,147.00 -12,723.48 -3,004.98 5,932,674.58 555,864.69 0.00 12,723.48 1J-180 L1 wp08 T3.1 14,761.74 89.59 180.00 3,267.92 3,146.92 -12,759.13 -3,004.98 5,932,638.94 555,864.97 3.00 12,759.13 14,800.00 89.59 180.00 3,268.20 3,147.20 -12,797.38 -3,004.98 5,932,600.69 555,865.27 0.00 12,797.38 14,900.00 89.59 180.00 3,268.91 3,147.91 -12,897.38 -3,004.98 5,932,500.70 555,866.05 0.00 12,897.38 15,000.00 89.59 180.00 3,269.62 3,148.62 -12,997.38 -3,004.98 5,932,400.72 555,866.83 0.00 12,997.38 15,052.62 89.59 180.00 3,270.00 3,149.00 -13,050.00 -3,004.98 5,932,348.10 555,867.24 0.00 13,050.00 1J-180 L1 wp08 T4 (Exit Upper) 15,100.00 87.22 180.00 3,271.32 3,150.32 -13,097.35 -3,004.98 5,932,300.75 555,867.61 4.99 13,097.35 15,145.38 84.95 180.00 3,274.41 3,153.41 -13,142.62 -3,004.98 5,932,255.49 555,867.96 5.01 13,142.62 15,196.36 84.95 180.00 3,278.90 3,157.90 -13,193.41 -3,004.98 5,932,204.71 555,868.36 0.00 13,193.41 15,200.00 85.13 180.00 3,279.21 3,158.21 -13,197.03 -3,004.98 5,932,201.09 555,868.39 4.92 13,197.03 15,300.00 90.14 180.00 3,283.34 3,162.34 -13,296.92 -3,004.98 5,932,101.21 555,869.17 5.00 13,296.92 15,303.10 90.29 180.00 3,283.33 3,162.33 -13,300.02 -3,004.98 5,932,098.12 555,869.19 5.00 13,300.02 15,400.00 90.29 180.00 3,282.84 3,161.84 -13,396.92 -3,004.98 5,932,001.23 555,869.95 0.00 13,396.92 15,500.00 90.29 180.00 3,282.33 3,161.33 -13,496.91 -3,004.98 5,931,901.24 555,870.73 0.00 13,496.91 15,600.00 90.29 180.00 3,281.82 3,160.82 -13,596.91 -3,004.98 5,931,801.26 555,871.51 0.00 13,596.91 15,700.00 90.29 180.00 3,281.32 3,160.32 -13,696.91 -3,004.98 5,931,701.27 555,872.29 0.00 13,696.91 15,800.00 90.29 180.00 3,280.81 3,159.81 -13,796.91 -3,004.98 5,931,601.28 555,873.07 0.00 13,796.91 15,900.00 90.29 180.00 3,280.31 3,159.31 -13,896.91 -3,004.98 5,931,501.30 .555,873.85 0.00 13,896.91 16,000.00 90.29 180.00 3,279.80 3,158.80 -13,996.91 -3,004.98 5,931,401.31 555,874.63 0.00 13,996.91 16,100.00 90.29 180.00 3,279.29 3,158.29 -14,096.91 -3,004.98 5,931,301.33 555,875.41 0.00 14,096.91 16,200.00 90.29 180.00 3,278.79 3,157.79 -14,196.91 -3,004.98 5,931,201.34 555,876.19 0.00 14,196.91 16,300.00 90.29 180.00 3,278.28 3,157.28 -14,296.90 -3,004.98 5,931,101.35 555,876.97 0.00 14,296.90 16,400.00 90.29 180.00 3,277.77 3,156.77 -14,396.90 -3,004.98 5,931,001.37 555,877.75 0.00 14,396.90 16,500.00 90.29 180.00 3,277.27 3,156.27 -14,496.90 -3,004.98 5,930,901.38 555,878.53 0.00 14,496.90 16,553.10 90.29 180.00 3,277.00 3,156.00 -14,550.00 -3,004.98 5,930,848.29 555,878.95 0.00 14,550.00 1J-180 L1 wp08 T5 (Exit Lower) 10/16/2006 2:46:46PM Page 5 of 8 COMPASS 2003.11 Build 50 ~ ~~~ ., ConocoPhillips AIa,Ska Halliburton Energy Services Planning Report -Geographic Drilling and Formation Evaluation rLS Database: _EDM_2003.11_b48 local Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 L1 Design: 1J-180 L1 (wp08) Planned Survey 1J-180 L1 (wp08) Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing {ft) (°) (°) (ff) (ft) (ft) (ft) (ft) 16,600.00 92.63 180.00 3,275.80 3,154.80 -14,596.88 -3,004.98 5,930,801.41 16,619.99 93.63 180.00 3,274.71 3,153.71 -14,616.84 -3,004.98 5,930,781.46 16,700.00 93.63 180.00 3,269.64 3,148.64 -14,696.69 -3,004.98 5,930,701.62 16,726.81 93.63 180.00 3,267.94 3,146.94 -14,723.45 -3,004.98 5,930,674.86 16,774.70 91.24 180.00 3,265.90 3,144.90 -14,771.29 -3,004.98 5,930,627.03 16,800.00 91.24 180.00 3,265.35 3,144.35 -14,796.58 -3,004.98 5,930,601.74 16,900.00 91.24 180.00 3,263.19 3,142.19 -14,896.56 -3,004.98 5,930,501.77 17,000.00 91.24 180.00 3,261.03 3,140.03 -14,996.54 -3,004.98 5,930,401.81 17,100.00 91.24 180.00 3,258.86 3,137.86 -15,096.51 -3,004.98 5,930,301.85 17,200.00 91,24 180.00 3,256.70 3,135.70 -15,196.49 -3,004.98 5,930,201.88 17,300.00 91.24 180.00 3,254.53 3,133.53 -15,296.47 -3,004.98 5,930,101.92 17,324.70 91.24 180.00 3,254.00 3,133.00 -15,321.16 -3,004.98 5,930,077.23 1J-180 L1 wp08 T6 17,337.75 90.85 180.00 3,253.76 3,132.76 -15,334.21 -3,004.98 5,930,064.18 17,400.00 90.85 180.00 3,252.84 3,131.84 -15,396.45 -3,004.98 5,930,001.94 17,500.00 90.85 180.00 3,251.36 3,130.36 -15,496.44 -3,004.98 5,929,901.97 17,600.00 90.85 180.00 3,249.88 3,128.88 -15,596.43 -3,004.98 5,929,801.99 17,700.00 90.85 180.00 3,248.40 3,127.40 -15,696.42 -3,004.98 5,929,702.02 17,800.00 90.85 180.00 3,246.92 3,125.92 -15,796.41 -3,004.98 5,929,602.04 17,861.91 ~ 90.85 180.00 3,246.00 ~ 3,125.00 -15,858.31 -3,004.98 5,929,540.14 L1: BHL @ 17882' MD, 3246' TVD: 1588' FSL, 184' FEL - Sec15-T10N-R10E - 4 1/2" -1J-180 L1 wp08 Toe • Map Fasting lff) 555,879.31 555,879.47 555,880.09 555,880.30 555,880.67 555,880.87 555,881.65 555, 882.43 555,883.21 555,883.99 555,884.77 555, 884.97 DLSEV (°l100ft) 4.99 5.02 0.00 0.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vert Section (ft) 14,596.88 14,616.84 14,696.69 14,723.45 14,771.29 14,796.58 14,896.56 14,996.54 15,096.51 15,196.49 15,296.47 15,321.16 555,885.07 3.00 15,334.21 555,885.55 0.00 15,396.45 555,886.33 0.00 15,496.44 555, 887.11 0.00 15, 596.43 555,887.89 0.00 15,696.42 555,888.67 0.00 15,796.41 555,889.16 0.00 15,858.31 10/16/2006 2:46:46PM Page 6 of 8 COMPASS 2003.11 Build 50 x ~~~„ e ~ ~ ~ ~~ ~ ~~._ Halliburton Energy Services ~~-i ~' ~Ot'10C 0 hill) Planning Report -Geographic Grilling nand Fairrr~etbn Ala$ka Eveluetion Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 1 S (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Site: Kuparuk 1J Pad Narth Reference: True Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 L1 Design: 1J-130 L1 ~wp08) ~~ GealogicTargets Flan 1J-130 L1 TVD Target Name +Nl-S +E/-W Northing Easting (ft) -Shape k ft (ft) (ft) 3,310.00 1J-180 L1 wp08 T2 (Exit Upper) -10,052.00 -3,004.98 5,935,345.72 555,843.85 - Point 3,246.00 1J-180 L1 wp08 Toe -15,858.31 -3,004.98 5,929,540.14 555,889.16 - Point 3,254.00 1J-180 L1 wp08 T6 -15,321.16 -3,004.98 5,930,077.23 555,884.97 - Point 3,311.45 1J-180 L1 wp08 (West Turn Point) -9,989.90 -2,998.12 5,935,407.87 555,850.22 - Point 3,277.00 1J-180 L1 wp08 TS (Exit Lower) -14,550.00 -3,004.98 5,930,848.29 555,878.95 - Point 3,270.00 1J-180 L1 wp08 T4 (Exit Upper) -13,050.00 -3,004.98 5,932,348.10 555,867.24 - Point 3,246.00 1J-180 1/4 Mile Toe -15,858.31 -3,004.98 5,929,540.14 555,889.16 - Circle (radius 1,320.00) 3,291.00 1J-180 L1 wp08 T3 (Exit Lower) -11,551.00 -3,004.98 5,933,846.91 555,855.54 - Point 3,268.00 1J-180 L1 wp08 T3.1 -12,723.48 -3,004.98 5,932,674.58 555,864.69 - Point 3,345.00 1J-180 1/4 Mile Heel -8,318.31 -3,029.30 5,937,079.00 555,806.00 - Circle (radius 1,320.00) Proynosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (~) (ft) (") C'1 3,878.25 2,142.00 13-3/8 16 10,318.41 3,345.17 4-518 12-1/4 17,861.90 3,246.00 4-112 6.3/4 10/16/2006 2:46:46PM Page 7 of 8 ~~ ~~~~ 5 ., COMPASS 2003.11 Build 50 C011000F~I11I~1 5 Halliburton Energy Services ~~ ~' A p Planning Report -Geographic Oriiflng and FormatFon Evaluation . _.... Database: _EDM_2003.11_b48 local Co-ordinate Reference: Well Plan 1J-180 Company; ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk Rlver Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 L1 Design: 1J-180 L1 (wp08) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft} (~) (~) (ft) (ft) (ftl Name 1,696.94 47.14 210.00 1,546.00 -451.08 -260.43 Base Perm 1,849.26 52.97 208.16 1,645.00 -551.99 -316.92 K15 2,849.70 79.13 202.25 1,948.00 -1,414.51 -693.98 T3 3,878.25 79.13 202.25 2,142.00 -2,349.37 -1,076.50 T3+550 7,377.43 79.13 202.25 2,802.00 -5,529.80 -2,377.85 Ugnu C 8,379.70 79.15 198.63 2,991.00 -6,444.76 -2,740.27 Ugnu B 8,779.33 79.22 194.56 3,066.00 -6,820.86 -2,852.34 Ugnu A 9,570.02 79.53 186.52 3,212.00 -7,584.22 -2,994.33 K13 10,271.42 79.97 179.41 3,337.00 -8,273.03 -3,029.95 WSAK D 10,317.41 80.00 178.94 3,345.00 -8,318.31 -3,029.30 WSAK C 3,372.00 WSAK B Plan AilnOtatiOns Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W Comment (ft) (ft} (ft) (ft) 10,317.42 3,345.00 -8,318.32 -3,029.30 L1: 9 5/8" TOW @ 10317' MD 3345' TVD: 1421' FNL, 201' FEL - Sec10-T10N-R10E 17,861.90 3,246.00 -15,858.30 -3,004.98 L1: BHL @ 17862' MD, 3246' TVD: 1588' FSL, 184' FEL - Sec15-T10N-R10E 10/16/2006 2:46:46PM Page 8 of 8 ~~9 ~ t ~~. ~ ~ , COMPASS 2003.11 Build 50 r ConocoPhillips Alaska Plan: 1J-180 L1 (wp08) Sperry Drilling Services Anticoltision Summary 13 October, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 L1 Local Coordinate Origin: Centered on Well Plan 1J-180 Viewing Datum: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~ - ~~~:.- ~... , ., ,.:,:C~ _ ,,.,. .i. .e31F:at-, ~,;,: '~~..:.a ...:_. _ >~. sue,.., . -.~, ~-~ ~; ~ -~ ~ ~ T:~.` `: u i ~,, Sp®rry Drilling Services 1~3~ 4 SURVEY PROGRAM Da[c: 21X16-IU-IITW:W:W Validalcd: Ycs Version: 2U.WU Dcplh Frum Dcplh To Sun-cy/Pl:m Tad 40.1X1 11511.1X1 CB-GYRO-SS 150.1X1 111317.]1 MWDtIFR-AK-CAZSC 10317.]1 17X61.91 IJ-IriU LI (w pOR) MWp+IFR-AK-CA~SC ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 10317.4100017827 To 17861.9111 Maximum Range:1986.19070355859 Reference: Plan: 1J-180 Li (wp08) 0 NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-180 Ground Level: 0.00 +N/-S +E/-W Northing Easing Latittude Longitude 0.00 0.00 5945419.90 558770.00 70°75'4t.344N 149°31'29.701 W COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Slot Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder Nonh Error Surface: Elliptical COnic Warning Method: Rules Basetl 0 90 90 1so Travelling C}lintler Azimuth (TFO+AZ[) ~°~ vs Centre to Centre Separation X75 ft/ink From Colour To MD REFERENCEINFORMATION Co-ordinate (N/E) Reference: Well Plan iJ-180, True Nonh Vertical (ND) Reference: Dayon 15 (40+81) ~ 121.OOR (DOyon 15 (40+81 )) Section (VS) Reference: Slot - (0.00X, O.OOE) Measured Depth Reference: Doyon 15 (40+8t) @ 121.OOR (DOyon 15 (40+81)) Calculation Method: Minimum Curvature 0 1000011500 1200013500 -°~~- 1400015500 16000 10000 1050012000 -~ 1250014000 1450016000 16500 10500 1100012500 1300014500 1500016500 17000 11000 1150013000 1350015000 15500 36 16)]4.]0 91.24 18000 3365.%-16]]1.29 -SO%.98 500 190.00 14]]119 37 17324.]0 9114 180.00 32%.00 -15321.15 -3004.98 0 00 0.00 16321.16 11180 L1 w908 T6 28 1133].75 90.86 190.00 3363.76.15336.21 4004.99 300 19000 16131.21 39 1]961.91 90.86 180.00 ]266.00-1585811 -30%.99 0.00 000 16858.]1 11180 L1 wpOB TOa sscnon oETaLs Sec MD Inc KI TVD HJIS ~FJ-W DLe9 TFatt VSec Targel 1 10311.11 %.00 1]8.% SM5.00 4]16)1 -3029.10 2 10]]].91 82.24 1]8.% JM].55 933061 -3029.00 0.00 1].60 000 9]18.11 000 93M.61 3 10363.91 82.20 118.% 3161.59 -9361.3] 4028A5 4 10651.03 91.]0 1]8.% ]361.5] 41553.% -1020.% O.OD 500 0.00 BJ%.33 0.00 8652.% 5 1%J9.% %.% 17098 ]355.]1 4639.61 -1023.18 6 1014)46 %.b 118.68 JJ4140 -9]4651 .3020.]0 500 0.00 -3.J6 %39.61 00 8]46.61 7 10%1.69 91.31 118.9] 11]8.35 884040 -)018.18 B it%1.59 91.% 1]8.91 1311. S -9989.% 3998.13 6.00 0.00 11651 8840.40 0.00 9989.% 11180 L1 a,P09 (Wear Turn Fdnt) 9 120]2.19 91.]0 181.00 3309.51 -100]OAS -2999.50 f0 12165.0] 9706 18111 3310.88-10153.21 -1002.93 6.00 90.00 10010.46 500 -151.591016].31 1 13218.48 97.06 18111 1113.61 -10216.% -SW4.0) 12 13303.19 91.10 1%.00 JJ1fi.00 -10301.23 -1004.98 1J 1]661.19 91.10 1%.00 329100-11551.00 ]004.98 050 5.00 0.00 0.00 10216.66 -16.88 10101.21 0.00 1155100 111%Lt wp09 TJ IEUt LOwerl 14 1361014 8J.% 180.00 3288.49 -11607.99 ]004.98 16 13]10.M 93.% 18000 3281.59 -11]0].16 -1000.98 600 0.00 0.00 1160].99 0.00 1110].]6 16 13]16.10 %.66 1%00 ]2]8.%-1171655 -3004.98 1] 14]26.10 90.66 19000 ]268.00-1PISx8 -30%.98 6.00 0.00 100.00 11]]3.55 000 13]2JA8 11180 L1 wpO8 71.1 18 1x18114 8959 18000 ]36].93-13]59.13 -30%.98 1915063.62 8959 18000 ]21000-1]050.00 -3004.98 3.00 0.00 18000 12]59.1] 000 1%50.00 11180 L1 wp08 T4IExit WVlrl 20 1514538 %.95 180.00 127461 1314262 -3000.% 500 180.00 13142.52 1St%.I6 %.95 18000 3378.%-13193.41 -3004.98 22 1530].10 %.29 180.00 ]28].3] -1)]00.02 -30%.98 5.00 0.00 11191A1 0.00 1310002 23 16653.10 90.29 180.00 327/.00 -14560.00 -30%.98 26 16619.99 93.6] 180.00 3214.71 -14616.% 3004.98 25 16)2691 9].6] 180.00 326].%-14]3345 3004.98 0.00 5.00 0.00 0.00 14550.00 11180L1 wpO9 T6lEUl LOxer) 0.00 14616.84 0.00 14721.45 180 Travelling Cylinder Azimuth (TFO+AZq ~°J vs Centre td Centre Separation 115 ft/ini Halliburton Company Anticollision Report Company: Conoco Phillips Al aska Inc. Uate: 10/13/2006 Timc: 13:41:29 Page: 1 Field: Kuparuk River Un it Reference Site: Kuparuk 1J Pad Co-ordinate(NF.) Reference. Well: Plan 1J-180, True North Reference ~Vcll: Plan 1J-180 Vertical (1'VD) Reference: Doyon 15 (40+81) 121.0 Reference ~Vellpath: Plan 1J-180 L1 _ Uh: Oracle _._ - GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1 J-180 L1 (wp08) & NOT PLAN NE Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10317.41 to 17861.91 ft Scan Method: Trav Cylinder North Maximum Radius: 1982.19 ft Error Surface: Ellipse + Casing Casing Points - - yfU TVD Diameter Hole Size Name ft ft in in 10317.41 3345.00 9.625 12.250 9 5/8" TOW 17861.91 3246.00 4.500 6.750 41/2" Plan: 1 J-180 L1 (wp08) Date Composed: 10/13/2006 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary <- ----------- ---- -Offset ~>'cllpath --- ------------- -----> Reference Offset _ Ctr-Ctr No-Co Allo~rable Site Nell Wcllpath ATD 11ID Distance Arca Deg°iation V1'arning ft ft ft ft ft Kuparuk 1J Pad 1J-156 1J-156L1 V1 10318.87 12963.00 78.09 31.44 46.64 Pass: Minor 1/200 Kuparuk 1J Pad 1J-156 1J-156L2 V1 Out of range Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 L1 V2 Pla 16024.51 16378.07 1327.84 395.89 931.95 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 V2 Plan: 16024.07 16383.34 1324.87 429.46 895.42 Pass: Major Risk Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 V2 Plan: 1 10325.00 10325.00 0.07 0.00 0.07 Pass: No Errors Kuparuk 1J Pad Rig: 1J-182 Plan: 1J-182 L1 V5 Pla 12015.99 11650.00 1201,43 304.30 897.13 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-182 Plan: 1J-182 V1 Plan: 17779.55 17425.00 1355.45 476.14 879.31 Pass: Major Risk Kuparuk WT Pad WT-04 WT-04 VO Out of range ROGRAA ~~~ , ®~,, wnd Formwtfon CASING DETAILS No TVD MD Name Size 1 2142.00 3878.25 13 3/8" 13-3/8 2 3345.17 10318.41 9 5/8" TOW 9-5/8 3 3246.00 17861.90 41/2" 4-1/2 0 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1 J-180 Wellbore: Plan 1J-180 L1 Plan: 1J-180 L1 (wp08) ConocoPhillips AI<.~ska I ~~~0 2~~~ ..o°° 6~~~ o° ° o0 ~o O _ / 2~~0 ~// zooo _-~~~o 6 pQO g ~ 0 0 / ADO O~ ~ Q ~ O ~` 0 0 O ~~ 6~ O~ N Closest in Pool 1J-180 L1 (wp13) D-Sand "*.~gg.''~/''~~ v°"~,J ~~w~ Closest A roach: Refierence Well : 1J-180 L1 w OS Plan Offset Weil: 1J -152 L2 Coords. - Coords. - ASP ASP 3-D ctr-ct I Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. TVD E(+)/W(-) (180° Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(-) 180°) Comments POOL Min Distance POOL Min Distance (1775.79 ft) in POOL (1775.79 ft) in POOL (10271.42 - 17861.91 (10271.42 - 17861.91 MD) to 1J-152 L2 (5403 MD) to 1J-180 L1 (wp08) 1775.79 10271.42 79.97 179.41 3215.859 5937123 555805.4 8273.167 - 13112 MD) 13112 89.69 182.82 3249.047 5938467 556965.6 6938.37 Plan (5403 - 13112 MD) Closest A roach: Reference Weil : 1J-180 L1 w 08 Pian Offset Well: 1J -156L2 Coords. - Coords. - ASP ASP 3-D ctr-ct I Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + AN - 180°) Comments De th Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance POOL Min Distance (363.52 ft) in POOL (363.52 ft) in POOL (10271.42 - 17861.91 (10271.42 - 17861.91 MD) to 1J-156L2 (5698 MD) to 1J-180 L7 (wp08) 363.52 "" 10271.42 79.97 179.41 3215.859 5937123 555805.4 8273.167 12566 MD) 12566 92.4 185.29 3220.94 5937482 555744.8 7914.315 Plan (5698-12566 MD) Closes t A roach: Reference Well : 1J-180 L1 w 08 Plan Offset Well: 1J -178 L1 w 01 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + AN - 180° Comments De th Incl. An le TRUE Azi. TVD E + AN - 180° Comments POOL Min Distance P in istance (1328.13 ft) in POOL (1328.13 ft) in POOL (10271.42 - 17861.91 (10271.42 - 17861.91 MD) to 1J-178 L1 MD) to 1J-180 L1 (wp08) (wp01) (10200 - Plan (10200 - 16378.07 1328.13 ' 1@; £ 16025 90.29 180 3158.534 5931375 555875.5 14022.05 16378.07 MD) 16378.07 89.97 179.15 3070.063 5931365 554550.4 14020.96 MD) Closes t A roach: Reference Wel l: 1J-180 L1 w 08 Plan Offset Well: 1J -182 L1 w 13 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. TVD E(+)/W(-) (180° Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W - (180° Comments P Min Distance P L Min Distance (1200.98 ft) in POOL (1200.98 ft) in POOL (10271.42 - 17861.91 (10271.42 - 17861.91 MD) to 1J-182 L1 MD) to 1J-180 L1 (wp08) (wp13) (9105.36 - Plan (9105.36 - 1200.98 12000 91.34 179.39 3190.108 5935398 555850.9 9998.443 17744.75 MD) 11625 90.74 179.97 3222.69 5935412 557051.3 9994.087 17744.75 MD) J 1J-180L~Drillin~ Hazards ~mmarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-180L1 Drilling Hazards Summary ~"'~ 10/4/2006 10:37 AM ~- I° z n r /1 Insulated Conductor fYl Casing 20", 94#, k55 x ~~ 34", 0 312" WT (r~i, +/- 80' MD ~e tB ~ ~ ~~ ~~ S C a n ,., va e o ~ o -^ ~ .- y n ri O s~ i^ c W' a ~_~ Wellhead /Tubing Nead /Tree, 13-3/8" x 4-%", 5,000 ksi Tubing String: 4-1/2", 12.6 #, L-80, IBTM (1) 3.875" DB nipple set +/- 500' 13-3/S", G8#, L-80, BTC ~ 3/378' MD / 2,142' TVD ~~ L~ 79 degrees TD IG" hole Top of llgnu C (al 7,377 MD / 2,802' -1'VD -~ (1) Gas Litt Mandrel, CAMCO 4-1/2" x l" Model KBG-2, rt 72 deg.) (l) Sliding Sleeve, with 3.812" nipple, 1 joint above seals) Lateral Entry Module # I (LEM), Baker, with seal bore and Z]CY packer ~. x,xxx' MD, x,xxx' TVD Top of West Sak D (a7 10,31 T MD / 3,345' 'TVD Tubing, 4--'/" IBTM, from LEM to A2 Liner, with seal stem and Top of Wes[ Sak B (a CAMCO 3.562" "DB" nipple. 10,784' 1vID / 3,412' TVD ~ Seal bore and ZXP packer fur B liner rt. 10,418' MD, 3,365' Tb'D 9-5/8", 40#, L-80, BTCM, Csg ~. 10,784' MD / 3,412' TVD n 85 degrees TD 12-1/4" hole (1)GasLiftMandrel, CAnICO4-I/2"x1" ModeIKBG-2,@ 2,200'?VD. 180 LI "D' Sand Window (~ IQ318' Iv1D / 3,345' TVD -__ --_,IJ-180 L 1: 80 degrees 6-3/4" "D" sartdJateral ~~` ~ ~ ~~ V`V ~ ~ TD I7,8G3' MD / 3,256' TVD "D" Liner, 4-1/Y', I L6#, LSO, BTCM Angle 90 degrees ~~- ===_____= ~oc~-~~~========== ___ -__ ---- ® ®---°---- ® da B Sand Liner _"`---- IJ-180-.-_. 6-3/4 B sand lateral TD 17,932' MD / 3,315' TVD Angle 90 degrees • • WELL ~ ~~>~~ ~~~ r~~ _ ~~ ~. i PT~~ 2Uly ' /S / ®evelopment ~ 5en~ice Exploratora~ Stratigraphic Vest Non-Conventional W"ell Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CI{ECK ADD-ONS WHAT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER NIL'LTI LATERAL ~ The permit is fora®new weilbore segment of existing well /~/~K lj'~~d (If fast two digits in API number are ~ Permit w;o. ~~,~ , API No. ~0-~- Z 3 Z9 '_~C~ between 60-69) should continue to be reported as a function of the I original API number stated above. I PILOT HOLE In accordance with 20 ~~C 2~.00~(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number ~~0- - -~ from records. data and logs j acquired for well ~' SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION Z~.O~~. Approval to perforate and produce /inject is contingent 'upon issuance of a conservation order approvin¢ a spacing ;' ;exception. assumes the i i liability of any protest to the spacing exception that may occur. ;DRY DITCH Al[ 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. r !Please note the following special condition of this permit: won-Conventional production or production testing of coal bed methane is not allowed li 'Well ~ for (name of well) until after (Companv Name) has designed and implemented a water well testing program to provide baseEine data ~! ! on water quality and quantity. (Companv Name) must contact the ,~~ ;Commission to obtain advance approval of such water well testing _ proffram. 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Y O; t; O °' a aui ~ ~ ~- f° , ~, ' , ~ , o~ ~ ~ >, c ~ a i o- -~ : ~; ~; cn ~-; ~' ~ a a a; a; O O U ~; Q; a; z` U ~; U; U , U U ¢ ~-; ¢ ~-; o; ~ m m U ~; ~'; ~; a~ a i a i a cn cn D U ~ U , ~ , , , , , ~ , , , , , , , , , , , , , , _ O w _ Q ~ O N M CY ~ (O I~ M O O N M V to (O I~ W p O N M V' ~ CO 1~ W p ~' O ~ N M V ~ CO h OD _ p e- ~ N N N N N N N N N N M M M M M M M M M M U __ _ Imo- U W O ~ O . m r 0 o N 0 m w O o N N m o ~' N E ~ ~ V O a ~ O a w+ W ~ ~ ~_ •L o o O y V C ~ J N N 01 ~, ~ ~ a ~ a w a~ U ~ LL1 ~ a a ¢ cn ~ w a r c ~ a<n ~~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Apr 18 07:57:36 2007 Reel Header Service name ......... ....LISTPE Date ................. ....07/04/18 Origin ............... ....STS Reel Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Reel Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library Tape Header Service name ......... ....LISTPE Date ................. ....07/04/18 Origin ............... ....STS Tape Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Tape Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: W-0004794615 LOGGING ENGINEER: R. WILSON OPERATOR WITNESS: M. THORNTON MWD RUN 8 JOB NUMBER: W-0004794615 LOGGING ENGINEER: R. WILSON OPERATOR WITNESS: M.THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services 1J-180 L1 500292332960 ConocoPhillips Alaska Inc Sperry Drilling Services 18-APR-07 MWD RUN 4 MWD RUN 7 W-0004794615 W-0004794615 B. HENNINGSE R. WILSON M. THORNTON M. THORNTON MWD RUN 9 MWD RUN 10 W-0004794615 W-0004794615 R. WILSON R. WILSON M. THORNTON M. THORNTON 35 11N l0E 1608 2443 121.40 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 4000.0 2ND STRING 6.750 9.625 10050.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE c'~~'t5 ( ~ ~5'IC • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-180 L1PB1 WELLBORE AT 15800'MD/3260'TVD, WITHIN THE MWD RUN 9 INTERVAL. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO MWD DATA WERE ACQUIRED. 5. MWD RUNS 3,4,8-10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 8-10 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4,7-10 REPRESENT WELL 1J-180 L1 WITH API#: 50-029-23329-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17779'MD/3252'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3951.5 17721.5 FET 3990.0 17728.5 RPX 3990.0 17728.5 RPM 3990.0 17728.5 RPD 3990.0 17728.5 RPS 3990.0 17728.5 ROP 4021.5 17779.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH • MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3951.5 8932.0 MWD 4 8932.0 10050.0 MWD 7 10050.5 10097.0 MWD 8 10097.0 13298.0 MWD 9 13298.0 15800.0 MWD 10 15800.5 17779.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3951.5 17779.5 10865.5 27657 3951.5 17779.5 RPD MWD OHMM 0.49 2000 28.6772 27478 3990 17728.5 RPM MWD OHMM 0.1 2000 29.4833 27478 3990 17728.5 RPS MWD OHMM 0.13 2000 30.8631 27478 3990 17728.5 RPX MWD OHMM 3.2 2000 28.735 27478 3990 17728.5 FET MWD HOUR 0.15 98.17 1.5378 27478 3990 17728.5 GR MWD API 22.33 128.39 64.0668 27541 3951.5 17721.5 ROP MWD FT/H 2.27 971.39 187.586 27517 4021.5 17779.5 First Reading For Entire File..........3951.5 Last Reading For Entire File...........17779.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .......... ...STSLIB.002 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/18 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3951.5 8868.0 RPD 3990.0 8860.0 RPM 3990.0 8860.0 RPX 3990.0 8860.0 RPS 3990.0 8860.0 FET 3990.0 8860.0 ROP 4021.5 8932.0 LOG HEADER DATA DATE LOGGED: 18-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8932.0 TOP LOG INTERVAL (FT) 4021.0 BOTTOM LOG INTERVAL (FT) 8932.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.9 MAXIMUM ANGLE: 83.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 4000.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 55.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.020 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .730 104.0 MUD FILTRATE AT MT: .660 72.0 MUD CAKE AT MT: 1.570 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 • Depth Units ..... .......... ... ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3951.5 8932 6441.75 9962 3951.5 8932 RPD MWD030 OHMM 0.49 2000 14.1536 9741 3990 8860 RPM MWD030 OHMM 0.1 42.11 12.6249 9741 3990 8860 RPS MWD030 OHMM 0.13 34.51 11.4632 9741 3990 8860 RPX MWD030 OHMM 3.2 21.91 9.3211 9741 3990 8860 FET MWD030 HOUR 0.26 98.17 1.81382 9741 3990 8860 GR MWD030 API 22.33 128.39 69.1082 9834 3951.5 8868 ROP MWD030 FT/H 10.99 971.39 168.739 9822 4021.5 8932 First Reading For Entire File..........3951.5 Last Reading For Entire File...........8932 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .......... ...STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/18 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8860.5 10050.0 RPX 8860.5 10050.0 RPD 8860.5 10050.0 RPS 8860.5 10050.0 RPM 8860.5 10050.0 GR 8868.5 10050.0 ROP 8932.5 10050.0 LOG HEADER DATA DATE LOGGED: 22-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10050.0 TOP LOG INTERVAL (FT) 8932.0 BOTTOM LOG INTERVAL (FT) 10050.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.0 MAXIMUM ANGLE: 88.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120557 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .1IN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 12.250 4000.0 Fresh Water Gel 9.10 74.0 9.4 1200 4.0 1.200 75.0 .870 106.0 1.100 70.0 .950 76.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8860.5 10050 9455.25 2380 8860.5 10050 RPD MWD040 OHMM 5.53 41.5 11.2524 2380 8860.5 10050 RPM MWD040 OHMM 4.98 47.66 10.8414 2380 8860.5 10050 RPS MWD040 OHMM 4.48 30.79 9.79625 2380 8860.5 10050 RPX MWD040 OHMM 3.93 21.99 7.98919 2380 8860.5 10050 FET MWD040 HOUR 0.31 53.55 4.44182 2380 8860.5 10050 C GR MWD040 API 22.96 114.74 81.2529 2364 ROP MWD040 FT/H 3.58 470.55 108.248 2236 First Reading For Entire File..........8860.5 Last Reading For Entire File...........10050 File Trailer Service name .......... ...STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/18 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 ~~ 8868.5 10050 8932.5 10050 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10050.5 10097.0 LOG HEADER DATA DATE LOGGED: 10-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10097.0 TOP LOG INTERVAL (FT) 10050.0 BOTTOM LOG INTERVAL (FT) 10097.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4000.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S) 47.0 MUD PH: .0 MUD CHLORIDES (PPM): 71000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 105.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 000 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 Name Service Unit Min Max Mean Nsam DEPT FT 10050.5 10097 10073.8 94 ROP MWD070 FT/H 2.27 43.52 18.3155 94 First Reading For Entire File..........10050.5 Last Reading For Entire File...........10097 File Trailer Service name ........... ..STSLIB.004 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/04/18 Maximum Physical Record ..65535 File Type .............. ..LO Next File Name......... ..STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 • 0 First Reading 10050.5 10050.5 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 10050.5 13247.5 RPM 10050.5 13247.5 RPS 10050.5 13247.5 Last Reading 10097 10097 RPD 10050.5 13247.5 FET 10050.5 13247.5 GR 10050.5 13240.5 ROP 10097.5 13298.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 12-FEB-07 Insite 74.11 Memory 13298.0 10097.0 13298.0 82.5 93.8 TOOL NUMBER 232602 228502 6.750 10050.0 • Mineral Oil Base 8.50 77.0 .0 28000 .0 000 .0 000 104.0 000 .0 000 .0 Data Format Specification Record Data Record Type ............. .... .0 Data Specification Block Type .... .0 Logging Direction ............ .... .Down Optical log depth units...... .... .Feet Data Reference Point ......... .... .Undefined Frame Spacing ................ .... .60 .lIN Max frames per record ........ .... .Undefined Absent value ................. .... .-999 Depth Units .................. .... . Datum Specification Block sub -typ e...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWDO80 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWDO80 FT/H 4 1 68 28 8 • • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10050.5 13298 11674.3 6496 10050.5 13298 RPD MWD080 OHMM 1.78 976.56 39.3843 6395 10050.5 13247.5 RPM MWD080 OHMM 7.79 976.52 38.3104 6395 10050.5 13247.5 RPS MWDOSO OHMM 7.57 2000 39.4291 6395 10050.5 13247.5 RPX MWD080 OHMM 4.75 2000 39.4144 6395 10050.5 13247.5 FET MWD080 HOUR 0.15 44.76 1.06971 6395 10050.5 13247.5 GR MWDO80 API 33.84 83.17 61.0278 6381 10050.5 13240.5 ROP MWDO80 FT/H 10.41 536.56 243.294 6402 10097.5 13298 First Reading For Entire File..........10050.5 Last Reading For Entire File...........13298 File Trailer Service name .......... ...STSLIB.005 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/18 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13241.0 15800.0 RPX 13248.0 15800.0 FET 13248.0 15800.0 RPS 13248.0 15800.0 RPM 13248.0 15800.0 RPD 13248.0 15800.0 ROP 13298.5 15800.0 LOG HEADER DATA DATE LOGGED: 15-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15800.0 TOP LOG INTERVAL (FT) 13298.0 BOTTOM LOG INTERVAL (FT) 15800.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 93.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 • • EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 10050.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 60.0 MUD PH: .0 MUD CHLORIDES (PPM): 17000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPE RATURE (DEGF) MUD AT MEASURED TEMPERAT URE (MT) .000 .0 MUD AT MAX CIRCULATING T ERMPERATURE: .000 107.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13241 15800 14520.5 5119 13241 15800 RPD MWD090 OHMM 13.24 2000 47.6737 5105 13248 15800 RPM MWD090 OHMM 13.47 2000 55.3074 5105 13248 15800 RPS MWD090 OHMM 13.17 2000 63.446 5105 13248 15800 RPX MWD090 OHMM 17.24 2000 57.3372 5105 13248 15800 FET MWD090 HOUR 0.17 25.18 1.00589 5105 13248 15800 GR MWD090 API 39.27 87.12 57.2234 5119 13241 15800 ROP MWD090 FT/H 40.08 398.78 188.022 5004 13298.5 15800 First Reading For Entire File..........13241 Last Reading For Entire File...........15800 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 • • Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 15800.5 17728.5 RPD 15800.5 17728.5 RPX 15800.5 17728.5 RPM 15800.5 17728.5 ROP 15800.5 17779.5 GR 15800.5 17721.5 FET 15800.5 17728.5 LOG HEADER DATA DATE LOGGED: 16-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17779.0 TOP LOG INTERVAL (FT) 15800.0 BOTTOM LOG INTERVAL (FT) 17779.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.3 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 10050.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.45 MUD VISCOSITY (S) 64.0 MUD PH: .0 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 107.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type ...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15800.5 17779.5 16790 3959 15800.5 17779.5 RPD MWD100 OHMM 7.09 1553.36 33.2132 3857 15800.5 17728.5 RPM MWD100 OHMM 12.21 299.13 34.7471 3857 15800.5 17728.5 RPS MWD100 OHMM 16.53 356.92 35.5295 3857 15800.5 17728.5 RPX MWD100 OHMM 17.51 231.89 35.003 3857 15800.5 17728.5 FET MWD100 HOUR 0.17 10.9 0.528877 3857 15800.5 17728.5 GR MWD100 API 33.09 79.53 54.7559 3843 15800.5 17721.5 ROP MWD100 FT/H 14.33 347.99 192.535 3959 15800.5 17779.5 First Reading For Entire File..........15800.5 Last Reading For Entire File...........17779.5 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/04/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 ~~,. • i Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File { Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 17 17:32:00 2007 Reel Header Service name ............ .LISTPE Date .................... .07/04/17 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Tape Header Service name ............ .LISTPE Date .................... .07/04/17 Origin .................. .STS Tape Name ............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: W-0004794615 LOGGING ENGINEER: R. WILSON OPERATOR WITNESS: M. THORNTON MWD RUN 8 JOB NUMBER: W-0004794615 LOGGING ENGINEER: R. WILSON OPERATOR WITNESS: M.THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-180 L1 PB1 500292332971 ConocoPhillips Alaska Inc Sperry Drilling Services 17-APR-07 MWD RUN 4 MWD RUN 7 W-0004794615 W-0004794615 B. HENNINGSE R. WILSON M. THORNTON M. THORNTON MWD RUN 9 W-0004794615 R. WILSON M. THORNTON 35 11N l0E 1608 2443 121.40 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 4000.0 2ND STRING 6.750 9.625 10050.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE ~v~-~s~ ~ rs~c~ NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10050' MD/3297'TVD, WITHIN THE RUN 4 INTERVAL OF THE 1J-180 WELLBORE. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 7. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO MWD DATA WERE ACQUIRED. 5. MWD RUNS 3,4,8,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 8,9 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4,7-9 REPRESENT WELL 1J-180 L1PB1 WITH API#: 50-029-23329-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16246'MD/3256'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3951.5 16188.0 RPM 3990.0 16195.5 RPX 3990.0 16195.5 FET 3990.0 16195.5 RPD 3990.0 16195.5 RPS 3990.0 16195.5 ROP 4021.5 16246.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 3951 .5 8932.0 4 8932 .0 10050.0 7 10050 .5 10097.0 8 10097 .0 13298.0 9 13298 .0 16246.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ................ ..0 Data Specification Block Type... ..0 Logging Direction ............... ..Down Optical log depth units......... ..Feet Data Reference Point ............ ..Undefined Frame Spacing ................... ..60 .lIN Max frames per record ........... ..Undefined Absent value .................... ..-999 Depth Units ..................... .. Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3951.5 16246 10098.8 24590 3951.5 16246 RPD MWD OHMM 0.49 2000 27.6631 24412 3990 16195.5 RPM MWD OHMM 0.1 2000 28.3325 24412 3990 16195.5 RPS MWD OHMM 0.13 2000 29.7394 24412 3990 16195.5 RPX MWD OHMM 3.2 2000 27.3686 24412 3990 16195.5 FET MWD HOUR 0.15 98.17 1.68002 24412 3990 16195.5 GR MWD API 22.33 128.39 65.6446 24474 3951.5 16188 ROP MWD FT/H 2.27 971.39 185.487 24450 4021.5 16246 First Reading For Entire File..........3951.5 Last Reading For Entire File...........16246 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 • Maximum Physical Record..65535 File Type ....... .........LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3951.5 8868 .0 RPD 3990.0 8860 .0 FET 3990.0 8860 .0 RPS 3990.0 8860 .0 RPX 3990.0 8860 .0 RPM 3990.0 8860 .0 ROP 4021.5 8932 .0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet 18-JAN-07 Insite 72.13 Memory 8932.0 4021.0 8932.0 76.9 83.3 TOOL NUMBER 126027 77613 12.250 4000.0 Fresh Water Gel 9.10 55.0 9.7 150 5.2 1.020 72.0 .730 104.0 .660 72.0 1.570 72.0 • Data Reference Point ...... .. ......Undefined Frame Spacing .. ........... .. ......60 .lIN Max frames per record ..... .. ......Undefined Absent value ... ........... .. ......-999 Depth Units .... ........... .. ...... Datum Specification Block. sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3951.5 8932 6441.75 9962 3951.5 8932 RPD MWD030 OHMM 0.49 2000 14.1536 9741 3990 8860 RPM MWD030 OHMM 0.1 42.11 12.6249 9741 3990 8860 RPS MWD030 OHMM 0.13 34.51 11.4632 9741 3990 8860 RPX MWD030 OHMM 3.2 21.91 9.3211 9741 3990 8860 FET MWD030 HOUR 0.26 98.17 1.81382 9741 3990 8860 GR MWD030 API 22.33 128.39 69.1082 9834 3951.5 8868 ROP MWD030 FT/H 10.99 971.39 168.739 9822 4021.5 8932 First Reading For Entire File..........3951.5 Last Reading For Entire File...........8932 File Trailer Service name .......... ...STSLIB.002 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/17 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FZLE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8860.5 10050.0 RPD 8860.5 10050.0 RPS 8860.5 10050.0 RPX 8860.5 10050.0 RPM 8860.5 10050.0 GR 8868.5 10050.0 ROP 8932.5 10050.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • 22-JAN-07 Insite 72.13 Memory 10050.0 8932.0 10050.0 72.0 88.2 TOOL NUMBER 120557 67981 12.250 4000.0 Fresh Water Gel 9.10 74.0 9.4 1200 4.0 1.200 75.0 .870 106.0 1.100 70.0 .950 76.0 Data Format Specification Record Data Record Type .............. .. ..0 Data Specification Block Type. .. ..0 Logging Direction ............. .. ..Down Optical log depth units....... .. ..Feet Data Reference Point .......... .. ..Undefined Frame Spacing ................. .. ..60 .lIN Max frames per record ......... .. ..Undefined Absent value .................. .. ..-999 Depth Units ................... .. .. Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 8860.5 10050 9455.25 2380 8860.5 RPD MWD040 OHMM 5.53 41.5 11.2524 2380 8860.5 Last Reading 10050 10050 • • RPM MWD040 OHMM 4.98 47 .66 10.8414 2380 8860.5 10050 RPS MWD040 OHMM 4.48 30. 79 9.79625 2380 8860.5 10050 RPX MWD040 OHMM 3.93 21. 99 7.98919 2380 8860.5 10050 FET MWD040 HOUR 0,31 53. 55 4.44182 2380 8860.5 10050 GR MWD040 API 22.96 114. 74 81.2529 2364 8868.5 10050 ROP MWD040 FT/H 3.58 470. 55 108.248 2236 8932.5 10050 First Reading For Entire File..........8860.5 Last Reading For Entire File...........10050 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10050.5 10097.0 LOG HEADER DATA DATE LOGGED: 10-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10097.0 TOP LOG INTERVAL (FT) 10050.0 BOTTOM LOG INTERVAL (FT) 10097.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 10050.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S): 47.0 MUD PH: .0 MUD CHLORIDES (PPM): 71000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 000 000 000 000 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 Name Service Unit Min Max Mean Nsam DEPT FT 10050.5 10097 10073.8 94 ROP MWD070 FT/H 2.27 43.52 18.3155 94 First Reading For Entire File... .......10050.5 Last Reading For Entire File.... .......10097 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .......... ...STSLIB.005 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/17 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.004 Comment Record FILE HEADER .0 105.0 .0 .0 First Last Reading Reading 10050.5 10097 10050.5 10097 FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY • VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 10050.5 13247.5 FET 10050.5 13247.5 GR 10050.5 13240.5 RPX 10050.5 13247.5 RPD 10050.5 13247.5 RPM 10050.5 13247.5 ROP 10097.5 13298.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 12-FEB-07 Insite 74.11 Memory 13298.0 10097.0 13298.0 82.5 93.8 TOOL NUMBER 232602 228502 6.750 10050.0 Mineral Oil Base 8.50 77.0 .0 28000 .0 .000 .0 .000 104.0 .000 .0 .000 .0 Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .DOwn Optical log depth units.......... .Feet Data Reference Point ............. .Undefined Frame Spacing .................... .60 .lIN Max frames per record ............ .Undefined Absent value .................... ..-999 Depth Units ..................... .. Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 • • FET MWD080 HOUR 4 1 68 20 6 GR MWDO80 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10050.5 13298 11674.3 6496 10050.5 13298 RPD MWD080 OHMM 1.78 976.56 39.3843 6395 10050.5 13247.5 RPM MWD080 OHMM 7.79 976.52 38.3104 6395 10050.5 13247.5 RPS MWD080 OHMM 7.57 2000 39.4291 6395 10050.5 13247.5 RPX MWD080 OHMM 4.75 2000 39.4144 6395 10050.5 13247.5 FET MWDO80 HOUR 0.15 44.76 1.06971 6395 10050.5 13247.5 GR MWD080 API 33.84 83.17 61.0278 6381 10050.5 13240.5 ROP MWDO80 FT/H 10.41 536.56 243.294 6402 10097.5 13298 First Reading For Entire File..... .....10050 .5 Last Reading For Entire File...... .....13298 File Trailer Service name .............STSLIB .005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/ 17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB .006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13241.0 16188.0 RPM 13248.0 16195.5 RPX 13248.0 16195.5 RPS 13248.0 16195.5 RPD 13248.0 16195.5 FET 13248.0 16195.5 ROP 13298.5 16246.0 LOG HEADER DATA DATE LOGGED: 15-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16246.0 TOP LOG INTERVAL (FT) 13298.0 BOTTOM LOG INTERVAL (FT) 16246.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 93.2 • • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 10050.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.45 MUD VISCOSITY (S) 60.0 MUD PH: .0 MUD CHLORIDES (PPM): 17000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefine d Frame Spacing .....................60 .lIN Max frames per record .............Undefine d Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13241 16246 14743.5 6011 13241 16246 RPD MWD090 OHMM 10.49 2000 43.8937 5896 13248 16195.5 RPM MWD090 OHMM 10.16 2000 50.5214 5896 13248 16195.5 RPS MWD090 OHMM 9.47 2000 57.4749 5896 13248 16195.5 RPX MWD090 OHMM 8.73 2000 51.943 5896 13248 16195.5 FET MWD090 HOUR 0.17 25.18 1.00611 5896 13248 16195.5 GR MWD090 API 39.27 87.94 58.605 5895 13241 16188 ROP MWD090 FT/H 22.71 416.25 182.576 5896 13298.5 16246 First Reading For Entire File..........13241 Last Reading For Entire File...........16246 File Trailer .~ Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/17 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/04/17 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
