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Home My WebLink About200-090 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13692'feet None feet true vertical 5145' feet 13413'feet Effective Depth measured 13285'feet None feet true vertical 5043' feet None feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 12760' 4897' Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Tarn Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-185 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 2600 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: None SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742Staff RWO/CTD Engineer 13260'-13275' 5037'-5040' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 1050 Size 118' 0 00 280 2401600 0 measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-090 50-103-20342-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380054 Kuparuk River Field/ Tarn Oil Pool KRU 2N-316 Plugs Junk measured Length Production 13654' Casing 5143'13686' 3459' 118'Conductor Surface 16" 7-5/8" 79' 3498' 2303' Burst Collapse Fra O s 6. A PG , C Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:40 am, Jul 05, 2023 Digitally signed by Elliott Tuttle DN: OU=CTD/ RWO Senior Engineer, O= Conoco Phillips, CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2023.07.03 10:28:55-08'00' Foxit PDF Editor Version: 12.1.2 Elliott Tuttle Page 1/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/2/2023 18:00 6/3/2023 00:00 6.00 MIRU, MOVE MOB P Pulled sub off of well and staged on pad. Cleaned up around well. Begin moving @ 20:30 Hrs F/ 1D-145 T/ 2N- 316. 6/3/2023 00:00 6/3/2023 05:00 5.00 MIRU, MOVE MOB P Continue moving rig T/ 2N. Stop at 2C- Pad Entrance for Field Crew Change Out. 6/3/2023 05:00 6/3/2023 07:00 2.00 MIRU, MOVE WAIT P Allow for Buses to transport field personal for morning change out. 6/3/2023 07:00 6/3/2023 11:30 4.50 MIRU, MOVE MOB P Continue moving rig from 2C-Pad to 2N -Pad 6/3/2023 11:30 6/3/2023 12:00 0.50 MIRU, MOVE SVRG P Stop Rig at four corners to inspect tires and moving system. 6/3/2023 12:00 6/3/2023 15:00 3.00 MIRU, MOVE MOB P Continue moving rig from 4 Corners to 2N-Pad 6/3/2023 15:00 6/3/2023 15:30 0.50 MIRU, MOVE SVRG P Stopr rig at 3M to inspect tires and moving system. 6/3/2023 15:30 6/3/2023 18:00 2.50 MIRU, MOVE MOB P Continue moveing from 2M to 2N-Pad 6/3/2023 18:00 6/3/2023 18:30 0.50 MIRU, MOVE MOB P Stopr rig in road after Miluviach River. Crew change out, inspect tires and moving system. 6/3/2023 18:30 6/4/2023 00:00 5.50 MIRU, MOVE MOB P Continue moving to 2N Pad. 6/4/2023 00:00 6/4/2023 06:00 6.00 MIRU, MOVE MOB P Stop and allow fueler to service 2N & 2P -pad. Check and Tighten wheel bolts on hub. Continue to move to 2N-Pad. 6/4/2023 06:00 6/4/2023 08:00 2.00 MIRU, MOVE MOB P Install rig mats and herculite. Hang tree in cellar. Stage Hanger and TBG spool behind well. Spot sub over well. 6/4/2023 08:00 6/4/2023 11:00 3.00 MIRU, MOVE WAIT P Unable to spot Sub over well due to Well house didn't get removed. Wasn't requested during the PSFR report. Call for more rig mats to double mat the footprint for Rig. 6/4/2023 11:00 6/4/2023 13:00 2.00 MIRU, MOVE MOB P Unload and spot Rig Mats. Spot Sub over well. MIRU support equipment. 6/4/2023 13:00 6/4/2023 16:00 3.00 MIRU, MOVE MOB P Safe out rig. Stairs and landings. Berm up cellar. Set mud shack, set cutting box, set Tiger tank rig up hardline. RU Iron Manifold in cellar 6/4/2023 16:00 6/4/2023 19:15 3.25 MIRU, WELCTL COND P Accept Rig. Take on Fluid to the Pits. Build 100 bbl Deep Clean Pill before circulating well over to 8.5 PPG seawater. 6/4/2023 19:15 6/4/2023 20:00 0.75 MIRU, WELCTL PRTS P PT squeeze manifold and tiger tank lines T/ 2500 PSI. 6/4/2023 20:00 6/4/2023 20:30 0.50 MIRU, WELCTL SFTY P PJSM w/ rig crew on bleeding gas and killing well with seawater. 6/4/2023 20:30 6/4/2023 21:00 0.50 MIRU, WELCTL KLWL P Initial PSI TBG=90, IA=260. Bleed free gas off of TBG & IA, went to fluid quickly. 6/4/2023 21:00 6/4/2023 23:00 2.00 MIRU, WELCTL KLWL P Pump 100 Bbls deep clean pill followed by seawater down TBG taking returns through IA to tiger tank and open top tank @ 4 BPM, 2400 PSI. Pumped total of 460, total returned 460 Bbls. Clean seawater returns to surface. 6/4/2023 23:00 6/4/2023 23:15 0.25 MIRU, WELCTL OWFF P OWFF, no flow from tubing, slight flow coming from IA. 6/4/2023 23:15 6/4/2023 23:30 0.25 MIRU, WELCTL KLWL P Pump additional 50 Bbls seawater down tubing taking reruns up IA @ 4 BPM, 2400 PSI. Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Page 2/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/4/2023 23:30 6/5/2023 00:00 0.50 MIRU, WELCTL OWFF P 30 Min no flow check - good. 6/5/2023 00:00 6/5/2023 00:30 0.50 MIRU, WELCTL MPSP P Set HP BPV. 6/5/2023 00:30 6/5/2023 01:00 0.50 MIRU, WELCTL PRTS P PT BPV T/ 1000 PSI for 10 Min from below. 6/5/2023 01:00 6/5/2023 01:30 0.50 MIRU, WHDBOP RURD P B/D, R/D circulating equipment. 6/5/2023 01:30 6/5/2023 03:30 2.00 MIRU, WHDBOP NUND P N/D tree. Inspect hanger neck threads - good. Install tree test plug. Function LDS. 6/5/2023 03:30 6/5/2023 09:45 6.25 MIRU, WHDBOP NUND P N/U BOP and Test manifold.Hook up choke and kill hoses, turn buckles, center stack, Install air boot, install riser and power Accumulator system. 6/5/2023 09:45 6/5/2023 10:00 0.25 MIRU, WHDBOP SFTY P PJSM for Testing Operation. 6/5/2023 10:00 6/5/2023 11:00 1.00 MIRU, WHDBOP RURD P R/U testing equipment and 2 7/8" Pac HT floor valves. Fluid pack stack 6/5/2023 11:00 6/5/2023 18:00 7.00 MIRU, WHDBOP BOPE P Shell test BOPE. Found leak on grey lock connection. Remove grey lock connection and inspect same. Failed re- test twice. Inspect same again. Finally got a shell test. Continue will Initial BOP Test. Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 2 7/8" Pac HT FOSV and IBOP. Test 3 ½ & 4 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Witness waived by AOGCC rep Kam StJohn. 6/5/2023 18:00 6/5/2023 22:30 4.50 MIRU, WHDBOP RGRP T Swapped to hi-line power. Lost SCR's on rig. Electrician trouble shooting issue. Changed out power suply to PLC. Continue processing 2 7/8" Pac HT work string. 6/5/2023 22:30 6/6/2023 00:00 1.50 MIRU, WHDBOP BOPE P Continue initial BOPE test. Tested BOPE at 250/5000 PSI for 5 Min each. Tested annular w/ 2 7/8"test joints. Test 3 ½ EUE FOSV. Test manual choke valve. Witness waived by AOGCC rep Kam StJohn. 6/6/2023 00:00 6/6/2023 01:30 1.50 MIRU, WHDBOP BOPE P Continue initial BOPE test. Tested BOPE at 250/5000 PSI for 5 Min each. Tested UVBR's, w/ 2 7/8"test joints. Tested and UVBRs w/ 3 ½ Test joint. Test HCR choke valve. Witness waived by AOGCC rep Kam StJohn. Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Page 3/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/6/2023 01:30 6/6/2023 05:00 3.50 MIRU, WHDBOP BOPE T Perform accumulator test. Initial pressure=3000 PSI, after closure=1625 PSI, 200 PSI attained =21 sec, full recovery attained =130 sec. UVBR's= 4 sec, LVBRs= 4 sec. Annular= 16 sec. Simulated blinds= 4 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Kam StJohn. Cellar H2S monitor failed inital test. Replacing sensor. Good Test on New sensor alarm for H2S monitor in Cellar. 6/6/2023 05:00 6/6/2023 06:00 1.00 COMPZN, RPCOMP MPSP P RU T-Bar, check for pressure under BPV, Pull Test dart and BPV. 6/6/2023 06:00 6/6/2023 07:15 1.25 COMPZN, RPCOMP PULD P M/U Landing Joint to hanger and Hanger to top drive.Stack 10K down weight. BOLDS. Unseat Hanger @ 85K, Pulled 170K to release cut, Pulling weight 120K. 6/6/2023 07:15 6/6/2023 07:45 0.50 COMPZN, RPCOMP OWFF P Top off well bore with 7 Bbls of seawater. OWFF. Well Static. 6/6/2023 07:45 6/6/2023 08:15 0.50 COMPZN, RPCOMP PULD P Pull Hanger to Rig floor and L/D Same. 12,640.0 12,636.0 6/6/2023 08:15 6/6/2023 15:00 6.75 COMPZN, RPCOMP PULL P Continue OOH laying down 3.5" Completion from cut section @ 12,640'. First 42 Joints of TBG had 2 Centralizers Per Joint for a total of 84 Centralizers. 12,636.0 9,092.0 6/6/2023 15:00 6/6/2023 15:15 0.25 COMPZN, RPCOMP SFTY P Kick while tripping drill with day crew. Meet up and discuss corrective actions. 9,092.0 9,092.0 6/6/2023 15:15 6/6/2023 17:30 2.25 COMPZN, RPCOMP PULL P Continue TOOH laying down 3.5" completions. 9,092.0 7,545.0 6/6/2023 17:30 6/6/2023 18:00 0.50 COMPZN, RPCOMP SVRG P Service TD, Blocks, Eckels, and DW. 7,545.0 7,545.0 6/6/2023 18:00 6/6/2023 18:15 0.25 COMPZN, RPCOMP SFTY P PJSM w/ night crew for pulling completion. 7,545.0 7,545.0 6/6/2023 18:15 6/6/2023 22:30 4.25 COMPZN, RPCOMP PULL P Continue TOOH laying down 3.5" completions. 7,545.0 3,627.0 6/6/2023 22:30 6/6/2023 22:45 0.25 COMPZN, RPCOMP SFTY P Kick while tripping drill with night crew. 1:30 response time. 3,627.0 3,627.0 6/6/2023 22:45 6/7/2023 00:00 1.25 COMPZN, RPCOMP PULL P Continue OOH laying down 3.5" Completion from 3,627' to midnight depth of 2,578'. 3,627.0 2,578.0 6/7/2023 00:00 6/7/2023 01:15 1.25 COMPZN, RPCOMP PULL P Cont. to POOH laying down 3 1/2" completions. PUW = 57K. Pulled GLM #3. Documented corrosion and heavy pitting at GLM and collars. 2,578.0 2,071.0 6/7/2023 01:15 6/7/2023 01:30 0.25 COMPZN, RPCOMP CIRC P Circulate BU at 2,071'. 2,071.0 2,071.0 6/7/2023 01:30 6/7/2023 05:30 4.00 COMPZN, RPCOMP PULL P L/D 3.5" completions from 2,071' to surface. 406 full joints and 13.2' of Joint #407. 17.3' of Joint #407 remaining. 2,071.0 0.0 6/7/2023 05:30 6/7/2023 06:00 0.50 COMPZN, RPCOMP CLEN P Clear rig floor and pipe shed. Set tubing hanger and pup joint on pallet for restock. 0.0 0.0 6/7/2023 06:00 6/7/2023 07:30 1.50 COMPZN, RPCOMP RURD P R/D tubing handling equipment. R/U handling equipment for 2 7/8" DP. Install Wear Ring. Load Yellow Jacket BHA #1 (overshot) into pipe shed. 0.0 0.0 6/7/2023 07:30 6/7/2023 08:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ Yellow Jacket and rig crew on M/U BHA #1 (overshot). 0.0 0.0 6/7/2023 08:00 6/7/2023 10:15 2.25 COMPZN, RPCOMP BHAH P MU Fishing BHA #1. OAL: 220.81' 0.0 220.8 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Page 4/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/7/2023 10:15 6/7/2023 16:30 6.25 COMPZN, RPCOMP TRIP P TIH w/ BHA #1 on 2-7/8" HT PAC Drillpipe. 220.8 3,250.0 6/7/2023 16:30 6/7/2023 17:00 0.50 COMPZN, RPCOMP SVRG P Rig Services. Ram Cylinder broke on the back of the Eckels. RU Hand tongs until GBR can get here with the power tongs. 3,250.0 3,250.0 6/7/2023 17:00 6/7/2023 20:00 3.00 COMPZN, RPCOMP TRIP P Continue TIH w/BHA #1 making up work string with hand tongs. 3,250.0 4,638.0 6/7/2023 20:00 6/7/2023 21:00 1.00 COMPZN, RPCOMP SFTY P GBR arrived on location. PJSM on loading power tongs into pipe shed on elevator. 4,638.0 4,638.0 6/7/2023 21:00 6/7/2023 22:00 1.00 COMPZN, RPCOMP RURD P Load power tongs and equipment into pipe shed. Setup GBR equipment on rig floor, tie into hydraulics, and function test. 4,638.0 4,638.0 6/7/2023 22:00 6/8/2023 00:00 2.00 COMPZN, RPCOMP TRIP P Continue TIH w/ BHA #1 (overshot) using power tong to midnight depth of 6,210' 4,638.0 6,210.0 6/8/2023 00:00 6/8/2023 07:30 7.50 COMPZN, RPCOMP TRIP P Cont. TIH with BHA #1 (overshot) to 12,000'. 6,210.0 12,000.0 6/8/2023 07:30 6/8/2023 11:30 4.00 COMPZN, RPCOMP SLPC P Slip & Cut Drilling Line. Circulate @ 1 bpm, 370 psi while cutting drill line. Recalibrate and Check Crown Saver. 12,000.0 12,000.0 6/8/2023 11:30 6/8/2023 12:45 1.25 COMPZN, RPCOMP TRIP P Cont. TIH with BHA #1 to 12,600'. Get Parameters. Up Wt 175K, Dn Wt 55K @ 35 SPM, 1360 psi, 5 RPM, 5.5K Torque. 12,000.0 12,600.0 6/8/2023 12:45 6/8/2023 15:30 2.75 COMPZN, RPCOMP FISH P Tagged and engaged top of TBG stub at 12,641' RKB. Set down 15K and PUH to 185K. Start working fish Up/DN. Continue working fish while increasing pick up weight each 5 cycle. 185K 5 Cycles 195K 5 Cycles 200K 5 Cycles 210K 5 Cycles 215K 5 Cycles 220K 5 Cycles 225K 5 Cycles 12,641.0 12,641.0 6/8/2023 15:30 6/8/2023 16:30 1.00 COMPZN, RPCOMP CIRC P Mix 2% Safe-Lube Pill and circulated same to bottom of BHA at 2 BPM, 1600 PSI. Let Safe-Lube soak for 15 mins. 12,641.0 12,641.0 6/8/2023 16:30 6/8/2023 17:15 0.75 COMPZN, RPCOMP FISH P Continue fishing Ops on Tubing stub. No Luck Rotating with top drive, stalled at 6K. Repeat cycles again. 185K 5 Cycles 195K 5 Cycles 200K 5 Cycles 210K 5 Cycles 215K 5 Cycles 220K 5 Cycles 225K 5 Cycles 12,641.0 12,641.0 6/8/2023 17:15 6/8/2023 17:45 0.50 COMPZN, RPCOMP FISH P Attempt to rotate seal assembly w/ top drive before TOOH for new BHA with functional jars. At 5.8K ft-lbs saw rotation of 10 RPM. 12,641.0 12,641.0 6/8/2023 17:45 6/8/2023 18:15 0.50 COMPZN, RPCOMP FISH P PU to continue working fish to see if rotation freed up seals. PUW = 170K. Saw weight bobbles indicating grapple pulled off fish. Likely spun at the grapple and not at the seals. 12,641.0 12,589.0 6/8/2023 18:15 6/8/2023 19:30 1.25 COMPZN, RPCOMP RURD P Load new Nordic power tongs in pipe shed and move to rig floor. Function test. R/D GBR power tongs. 12,589.0 12,589.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Page 5/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/8/2023 19:30 6/9/2023 00:00 4.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #1 (overshot) to midnight depth of 9,310'. Started pulling wet. Called out new jars, grapple, and OS extension for BHA #2. 12,589.0 9,310.0 6/9/2023 00:00 6/9/2023 00:30 0.50 COMPZN, RPCOMP CIRC P Cont. TOOH w/ BHA #1 (overshot). Started pulling wet @ 9,310'. M/U head pin to pump to confirm circ path and clear potential debris from workstring. Pressured up to 2,400 psi after 0.5 bbls. Check valves at surface. Reattempt. Same result. 9,310.0 9,310.0 6/9/2023 00:30 6/9/2023 01:00 0.50 COMPZN, RPCOMP RURD P Skid GBR power tongs from rig floor to pipe shed. Unload GBR power tongs and release equipment. 9,310.0 9,310.0 6/9/2023 01:00 6/9/2023 03:00 2.00 COMPZN, RPCOMP TRIP P Perform 10 min. NFT. Cont. TOOH w/ BHA #1 (overshot) pulling wet. PUW = 124K. At 8,847' pulled dry. L/D Joint #276 (Stand #92) to inspect for blockage/debris. Found pipe scale blockage. Cleared and re-drifted. Cont. TOOH pulling dry. 9,310.0 8,898.0 6/9/2023 03:00 6/9/2023 08:00 5.00 COMPZN, RPCOMP TRIP P Continue OOH f/8898' to 220'. OWFF. 8,898.0 220.0 6/9/2023 08:00 6/9/2023 09:30 1.50 COMPZN, RPCOMP BHAH P PJSM. L/D Accelerator and Drill Collars. PUH to Overshot and Inspect same. 220.0 0.0 6/9/2023 09:30 6/9/2023 10:00 0.50 COMPZN, RPCOMP CLEN P Clean Rig Floor. 0.0 0.0 6/9/2023 10:00 6/9/2023 12:00 2.00 COMPZN, RPCOMP WAIT P Allow Totalview to do their 3D Scan of the Rig Floor. 0.0 0.0 6/9/2023 12:00 6/9/2023 13:00 1.00 COMPZN, RPCOMP BHAH P Crew Change out. Make up new Grapple and Jars with drill collars. 0.0 224.2 6/9/2023 13:00 6/9/2023 18:00 5.00 COMPZN, RPCOMP TRIP P TIH w/ BHA #2 on 2-7/8" HT PAC Drillpipe to 7,500'. PUW = 91K SOW = 51K. 224.2 7,668.0 6/9/2023 18:00 6/9/2023 22:45 4.75 COMPZN, RPCOMP TRIP P Cont. TIH w/ BHA #2 on 2 7/8" DP to 12,600'. OWFF for 10 min. Circulate BU. Obtain Parameters. Up Wt 158K, Dn Wt 62K. Pump rate 3 BPM at 2,900 psi. Unable to rotate Topdrive. Begin to T/S while pumping BU. 7,668.0 12,609.0 6/9/2023 22:45 6/9/2023 23:45 1.00 COMPZN, RPCOMP RGRP T T/S Topdrive. Unable to rotate. Nordic Electrician on site. Repair complete. Found and replaced a bad relay. 12,609.0 12,609.0 6/9/2023 23:45 6/10/2023 00:00 0.25 COMPZN, RPCOMP FISH P Reestabilish parameters. Free Torque = 5K @ 10 RPM. SOW = 75K. Tag top of Tbg stub at 12,642'. Rotate to swallow stub. PUW = 140K. No latch. 12,609.0 12,642.0 6/10/2023 00:00 6/10/2023 04:00 4.00 COMPZN, RPCOMP FISH P Re-tag tubing stub @ 12,642'. Rotate @ 10 RPM to swallow. Weight came back. Swalled fish down to no-go of 12,645'. Set 15K down. PU to confirm engaged. PUW = 175K (15K over). Jars fired. Continue to jar on fish increasing PUW from 175K to 200K. Hit 50 jar licks. Straight pulled to 220K and weight fell off to 130K indicating seals pulled free. PUH 20'. Crew C/O. SOW = 65K. PUW = 130K. See bumper sub open. 12,642.0 12,645.0 6/10/2023 04:00 6/10/2023 13:15 9.25 COMPZN, RPCOMP TRIP P TOOH w/ BHA #2. 12,624.0 224.0 6/10/2023 13:15 6/10/2023 13:30 0.25 COMPZN, RPCOMP SFTY P PJSM on laying down Drill collars and fishing BHA. 224.0 224.0 6/10/2023 13:30 6/10/2023 14:00 0.50 COMPZN, RPCOMP BHAH P L/D Drill Collars and Fishing BHA #2 224.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Page 6/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/10/2023 14:00 6/10/2023 14:30 0.50 COMPZN, RPCOMP RURD P C/O Handling Equipment from 2-7/8" to 3-1/2" 0.0 0.0 6/10/2023 14:30 6/10/2023 15:30 1.00 COMPZN, RPCOMP PULD P L/D Lower 3-1/2" Completion with cut TBG Joint. 0.0 0.0 6/10/2023 15:30 6/10/2023 16:00 0.50 COMPZN, RPCOMP SVRG P Service TD, Traveling Blocks and Crown. 0.0 0.0 6/10/2023 16:00 6/10/2023 16:15 0.25 COMPZN, RPCOMP SFTY P PJSM for making up BHA. 0.0 0.0 6/10/2023 16:15 6/10/2023 18:00 1.75 COMPZN, RPCOMP BHAH P Make up 5-1/2" CSG Scraper BHA #3 with 3-1/2" EUE Mule Shoe Pup Joint. OAL=241.87' 0.0 241.9 6/10/2023 18:00 6/11/2023 00:00 6.00 COMPZN, RPCOMP TRIP P TIH w/ BHA #3 (5 1/2" casing scraper) on 2 7/8" Work String to midnight depth of 9,385'. 241.9 9,385.0 6/11/2023 00:00 6/11/2023 02:00 2.00 COMPZN, RPCOMP TRIP P Cont. TIH w/ BHA #3 to 12,650'. 9,385.0 12,650.0 6/11/2023 02:00 6/11/2023 03:45 1.75 COMPZN, RPCOMP WASH P Obtain parameters. PUW = 135K, SOW = 62K , Pump Pressure @ 3 BPM = 2,982 psi, Rotating slowly. Wash down into PBR. No-go @ 12,722' 7ES RKB (12,743' CRKB). 19' of 3 1/2" stinger below No-Go. Set 5K down. PUH 20' to reconfirm tag. Reduce pump rate to 1 BPM @ 481 psi. No-go at 12,743' CRKB. Pressure spiked to 1,500 psi. No-go tagged at same. Confirmed 4.4" coupling is at 4" PBR top. PUH 20'. 12,650.0 12,741.0 6/11/2023 03:45 6/11/2023 06:00 2.25 COMPZN, RPCOMP CIRC P Mark pipe for 15' reciprocation interval across PBR. Bring pumps online at 3 BPM (2,957 psi). Reciprocate stinger inside PBR from 12,743' - 12,762' CRKB. Pump 35 bbl Hi-Vis sweep. Chase with 263 bbls Seawater (STS) to carry debris from wellbore. Blow down Drive Drive. 12,741.0 12,726.0 6/11/2023 06:00 6/11/2023 14:45 8.75 COMPZN, RPCOMP PULD P TOOH w/ BHA #3 laying down 2-7/8" DP. Up Wt 150K. 12,726.0 3,785.0 6/11/2023 14:45 6/11/2023 15:30 0.75 COMPZN, RPCOMP SVRG P Remove linkage on chain for pipe skate. 3,785.0 3,785.0 6/11/2023 15:30 6/11/2023 19:00 3.50 COMPZN, RPCOMP PULD P Continue TOOH w/ BHA #3 laying down 2-7/8" DP. 3,785.0 241.9 6/11/2023 19:00 6/11/2023 20:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA #3 (5-1/2" CSG Scraper with 3- 1/2" Mule Shoe Stinger). 241.9 0.0 6/11/2023 20:30 6/11/2023 22:30 2.00 COMPZN, RPCOMP RURD P Clear and clean rig floor. RD 2 7/8" pipe handling equipment. RU 3 1/2" handling equipment. Pull Wear Ring. Load 3 1/2" completion jewelry into pipe shed. Vac out cuttings tank and rig sump. Verify jewelry lengths, running order, and tubing count. Prep rig floor for slip and cut ops. 0.0 0.0 6/11/2023 22:30 6/12/2023 00:00 1.50 COMPZN, RPCOMP SLPC P Slip and cut 66' of drill line. 0.0 0.0 6/12/2023 00:00 6/12/2023 03:00 3.00 COMPZN, RPCOMP SLPC P Slip and cut 66' drill line. Monitor well on choke manifold. Check and Recalibrate Crownmatic. Blowdown choke manifold. 0.0 0.0 6/12/2023 03:00 6/12/2023 03:15 0.25 COMPZN, RPCOMP SFTY P Spill Drill. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Page 7/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2023 03:15 6/12/2023 14:30 11.25 COMPZN, RPCOMP RCST P Prep rig floor and pipe shed to run completions. Check and Recalibrate Crownmatic. Start RIH w/ 3 1/2" EUE 8RD completions. Had to C/O Collar on Joint 175 and replace joint 176 (29.90') with Joint C (31.08'). 0.0 5,520.0 6/12/2023 14:30 6/13/2023 00:00 9.50 COMPZN, RPCOMP RCST P Continue in hole with 3-1/2" Completion to midnight depth of 12,350'. 5,520.0 12,350.0 6/13/2023 00:00 6/13/2023 02:00 2.00 COMPZN, RPCOMP RCST P Continue in hole with 3-1/2" Completion. Kelly up and wash seals into PBR @ 1 BPM 154 psi. Saw pressure bump to 250 psi @ 12,744' ORKB when seals entered PBR. Offline w/ pumps. Open Bleeder. No-Go on top of PBR @ 12,744' ORKB (Btm of Seals @ 12,759' ORKB). 5,520.0 12,738.0 6/13/2023 02:00 6/13/2023 03:15 1.25 COMPZN, RPCOMP PULD P P/U 2' to 12,757' ORKB. Mark Pipe. Pull partial Joint #405 (17.55'). Pull full Joint #403 (30.79'). Total Pulled = 48.34'. Total required for Nordic 3 RKB, Hanger, Hanger Pup = 30.32'. Pup Joints required = 18'. Break out full Joint #402, M/U 10.19' and 8.16' space out pups, M/U full joint #402, hanger, landing joint. 12,738.0 12,704.0 6/13/2023 03:15 6/13/2023 04:30 1.25 COMPZN, RPCOMP CRIH P Circ. 130 BBLS of CI Seawater. Chase with 110 BBLS Seawater to displace to backside. Taking returns to Kill Tank to re-calibrate level sensor. Blown down lines. OWFF. Drain Stack. Open IA valve. 12,704.0 12,704.0 6/13/2023 04:30 6/13/2023 05:30 1.00 COMPZN, RPCOMP HOSO P Land hanger. Bottom of Seals @ 12,757' ORKB. (2' space out). RILDS. 12,704.0 12,736.0 6/13/2023 05:30 6/13/2023 08:00 2.50 COMPZN, RPCOMP RURD P Crew Change out. PJSM. RU pressure testing manifolds and hoses on rig floor and in cellar. 12,736.0 12,736.0 6/13/2023 08:00 6/13/2023 10:15 2.25 COMPZN, RPCOMP PRTS P PT Tubing to 3,000 psi. Pass. Bleed Tubing down to 1,500 psi. PT IA to 2,500 psi. Pass. Dump Tubing Pressure. Shear SOV. 12,736.0 12,736.0 6/13/2023 10:15 6/13/2023 11:15 1.00 COMPZN, RPCOMP RURD P R/D Pressure Testing equipment. Perform 30 min NFT. Back out landing joint. 0.0 0.0 6/13/2023 11:15 6/13/2023 11:45 0.50 COMPZN, RPCOMP MPSP P Set HP BPV 0.0 0.0 6/13/2023 11:45 6/13/2023 12:00 0.25 COMPZN, RPCOMP PRTS P PT BPV T/ 1000 PSI for 10 Min from below - Pass 0.0 0.0 6/13/2023 12:00 6/13/2023 12:30 0.50 COMPZN, WHDBOP RURD P R/D testing equipment. 0.0 0.0 6/13/2023 12:30 6/13/2023 12:45 0.25 COMPZN, WHDBOP SFTY P PJSM on N/D BOP and N/U tree 0.0 0.0 6/13/2023 12:45 6/13/2023 15:30 2.75 COMPZN, WHDBOP NUND P N/D BOP 0.0 0.0 6/13/2023 15:30 6/13/2023 19:00 3.50 COMPZN, WHDBOP NUND P Install tree test dart. Un hang tree. Consult with DSO Rich Clemons on tree orientation. N/U adaptor spool and tree. 0.0 0.0 6/13/2023 19:00 6/13/2023 21:30 2.50 COMPZN, WHDBOP PRTS P PT hanger void. Good. R/U LRS. PT tree to 250psi/5,000 psi. Found leaking 1502 rubber on low. Replaced. Re-test. Suck Back LRS hose. 0.0 0.0 6/13/2023 21:30 6/13/2023 22:00 0.50 COMPZN, WHDBOP MPSP P Pull test dart and BPV. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Page 8/8 2N-316 Report Printed: 6/20/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/13/2023 22:00 6/14/2023 00:00 2.00 COMPZN, WHDBOP FRZP P RU cellar circ manifold and hoses. LRS pump 42 bbls diesel down IA taking returns from Tubing. U-Tube. Gather final pressures. T/I/O = 0 / 0 / 150 psi. RD LRS. DTH on location to RD hardline and haul tanks/equipment to 2L. 0.0 0.0 6/14/2023 00:00 6/14/2023 03:00 3.00 DEMOB, MOVE DMOB P Secure rig for move. Clean and clear cellar and around the rig. Pull sub off of well and stage on pad. Load out misc equipment T/ 2L. Release rig @ 03:00. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 6/14/2023 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 10' of Rathole) 13,285.0 2N-316 8/19/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tubing 2N-316 4/9/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: UNABLE TO PASS 8153'' WLM DURING STATIC 6/3/2003 triplwj NOTE: TAGGED OBSTRUCTION @ 7110'' WLM 6/2/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 118.0 118.0 62.58 H-40 WELDED SURFACE 7 5/8 6.87 39.0 3,497.9 2,302.7 29.70 L-80 BTC-MOD PRODUCTION 5.5"x3.5" @ 12743' 5 1/2 4.95 31.5 13,686.0 5,143.2 15.50 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 29.9 Set Depth 12,759.7 Set Depth 4,897.4 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.9 29.9 0.00 Hanger 10.880 FMC, Gen V, 11" Tubing Hanger FMC Gen V 3.060 523.2 522.5 8.04 Nipple - X 3.759 3.5" x 2.813" X-Nipple Halliburt on X 2.813 2,074.4 1,805.2 56.60 Mandrel GAS LIFT 4.520 3.5" x 1" KBG-2-9, GLM SLB KBG-2-9 2.818 12,577.0 4,839.5 72.17 Sleeve - Sliding 4.500 Baker CMU Sliding Sleeve w/2.813" Profile. Sleeve is Closed Baker CMU 2.820 12,632.4 4,857.1 70.99 Mandrel GAS LIFT 4.710 3.5" x 1" KBG-2-9, GLM SLB KBG-2-9 2.818 12,723.1 4,886.1 71.99 Nipple - D 4.520 3.5" x 2.75" D-Nipple SLB D 2.750 12,744.6 4,892.7 71.91 Seal Assembly 4.000 Tri-Point 4" Seal Assembly w/Locator (2' From Fully Located) Tri-Point Seal Assembl y 2.984 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 12,768.9 4,900.3 71.84 CATCHER Set catcher on EVO plug (106" OAL) 3/25/2023 0.000 12,777.9 4,903.1 72.22 PLUG HES EVO-TRIEVE RBP, MOE = 12,780' RKB, OAL = 69.13", 1-1/4" GS PULLING TOOL HES BRDGPL G,EVO,3 1/2,9.2 MAT NUM: 10190 8464 3/23/2023 0.000 13,413.0 5,075.5 75.45 FISH PANEX GAUGES, ETC. OAL 35.5' TAGGED w/COIL 9/9/2000 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,074.4 1,805.2 56.60 1 SOV BTM 1 6/13/2023 SOV is shear ed out SLB KBG-29 12,632.4 4,857.1 70.99 2 DMY BTM 1 6/13/2023 SLB KBG-2-9 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,260.0 13,275.0 5,036.5 5,040.1 S-3, 2N-316 9/7/2000 4.0 IPERF 2.5" HSD BH CHARGES Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 13,260.0 13,275.0 1 FRAC 9/9/2000 0.0 0.00 0.00 2N-316, 6/20/2023 1:22:27 PM Vertical schematic (actual) Casing 4; 12,743.0-13,686.0 PRODUCTION 5.5"x3.5" @ 12743'; 31.5-13,686.0 FISH; 13,413.0 IPERF; 13,260.0-13,275.0 FRAC; 13,260.0 PLUG; 12,777.9 CATCHER; 12,768.9 Nipple - D; 12,723.1 Mandrel GAS LIFT; 12,632.4 Sleeve - Sliding; 12,576.9 SURFACE; 39.0-3,497.9 Mandrel GAS LIFT; 2,074.4 Nipple - X; 523.2 CONDUCTOR; 39.0-118.0 Hanger; 29.9 KUP PROD KB-Grd (ft) 39.68 RR Date 8/1/2000 Other Elev 2N-316 ... TD Act Btm (ftKB) 13,692.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032034200 Wellbore Status PROD Max Angle & MD Incl (°) 79.52 MD (ftKB) 8,133.81 WELLNAME WELLBORE2N-316 Annotation Last WO: End Date 6/13/2023 H2S (ppm) DateComment SSSV: NIPPLE DSR-3/28/23 X MDG 4/7/2023 X 10-404 BOP test to 2500 psig Annular preventer to 2500 psig VTL 4/13/23GCW 04/13/23JLC 4/13/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.13 15:05:29 -08'00'04/13/2023 RBDMS JSB 041423 x 30 min C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-09-25_22504_2N-316_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22504 KRU 2N-316 50-103-20342-00 LeakPoint Survey 25-Sep-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 200-090 T37132 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.12 08:58:00 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-09-02_21096_KRU_2N-316_CaliperSurvey_LogData_Transmiittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21096 KRU 2N-316 50-103-20342-00 Caliper Survey w/ Log Data 02-Sep-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:200-090 T36985 Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.07 15:54:45 -08'00' • ConocoPhillips Alaska OCT 23 2L,) P.O.BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 September 28, 2015 V e�A`( 1 SCO00 ..... ocio Commissioner Cathy Foerster !. 3 / Alaska Oil& Gas Commission ��f 333 West 7t'Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N 316 50103203420000 2000900 13" N/A 13" N/A 5.95 9/25/2015 2N-333 50103205250000 2060250 19" N/A 19" N/A 5.1 9/25/2015 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 STATE OF ALASKA • RPCFIVED ANOKA OIL AND GAS CONSERVATION COMMISSION O 14 r 0 1 2015 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r RugPerforations r Pull Tubing r r y6$ ow n r r Fracture Stimulate ,��/ ,��..��ii Performed: Suspend r Perforate r Other Stimulate r v t Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re enter Susp Well Other:Gond Ext Fl 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 200-090 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20342-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL380054 KRU 2N-316 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 13692 feet Plugs(measured) None true vertical 5145 feet Junk(measured) 13413 Effective Depth measured 13413 feet Packer(measured) 12744 true vertical 5076 feet (true vertical) 4893 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 118 118 1640 630 SURFACE 3459 7.625 3498 2303 6890 4790 PRODUCTION 13655 10 13686 5143 7000 4990 Perforation depth: Measured depth: 13260-13275 True Vertical Depth: 5037-5040 S tiE 1 DEC: 1 1 2015 Tubing(size,grade,MD,and ND) 3.5, L-80, 12743 MD,4892 TVD Packers&SSSV(type,MD,and ND) PACKER=BAKER 80-40 CASING SEAL ASSEMBLY @ 12744 MD and 4893 TVD SSSV=CAMCO DS NIPPLE @ 516 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-152 Contact MJ Loveland/Martin Walters Email N1878(a�ConocoPhillips.com Printed Name Martin Walters Title WI Project Supervisor Signature //,//a�v�� Phone:659-7043 Date 9/27/15 /01/ //5-- V2 4 /40- > RBDMS Yi Ut;I 0 1 1015 Form 10-404 Revised 5/2015 Submit Original Only y s III • 2N-316 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/23/15 Welder fit&welded a 13-3/8"x 16"x 3/8"62#conductor extension to top of existing conductor. 09/25/15 Pump 5.95 gals of sealant into conductor. • . 2N-316 DESCRIPTION OF WORK COMPLETED SUMMARY Tk, (,<OF \��I�j 4, THE STATE Alaska Oil and Gas _ �M ofALAsKA Conservation Commission 2 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS*P' Fax: 907.276.7542 SCAMS ;`H ¢r www.aogcc.alaska.gov Martin Walters Well Integrity Project 10k1 ' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-316 Sundry Number: 315-152 Dear Mr. Walters: 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, f2 Cathy P. oerster Chair DATED this Z7 day of March, 2015 Encl. RECEIVED STATE OF ALASKA AL..,KA OIL AND GAS CONSERVATION COM, SION MAR 19 2015 APPLICATION FOR SUNDRY APPROVALS 07.5 3�Iz '(LS • 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell, Change Approved Program r r Suspend r Rug Perforations Perforate r Pull Tubing Time Extension r Operational Shutdown r Re-enter Susp Well r- Stimulate r Alter casing r Other: Cond Extension P. 2.Operator Name: 4.Current Well Class 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development 17, 200-090 ' 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20342-00 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No � 1 K(tU 2N-316 • 9 Property Designation(Lease Number): 10.Field/Pool(s): ADL380054 • Kuparuk River Field/Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft). Effective Depth D(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): /1�5 13692 . 5145 • /3413 jo?(, qik3 /3,V13 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 118' 118' 1640 630 SURFACE 3459 7.625 3498' 2303' 6890 4790 PRODUCTION 13655 5.5 13686' 5143' 7000 4990 Perforation Depth MD(ft). Perforation Depth TVD(ft) Tubing Size: Tubing Grade: Tubing MD(ft): 13260'-13275' ' 5037'-5040' 3 5 L-80 12743 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER= BAKER LOCATOR MD= 12743 TVD=4892 SSSV=CAMCO DS NIPPLE MD=516 TVD=515 12 Attachments: Description Summary of Proposal 17 13. Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 17 • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2015 Oil 17. Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878@cop.com Printed Name Martin Walters Title: Well Integrity Project Supervisor Signature /A/7 Wil.�/liline Phone:659-7043 Date:03-14-15 Commission Use Only Sundry Number. Conditions of approval: Notify Commission so that a representative may witness j t, S-- 152. Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r un 0 N Other: r-a Spacing Exception Required? Yes 0 No Subsequent Form Required: /G_ 4 a !.f Q y APPROVED BY (f� Approved by:ae, ,2yC application is v c r��1� ' Oflths from �5ir� ��iNioval. Dater -2-7 �� Form 10-403(ReYsed 10/2012) % RECEIVED Nov • • MAR 192015 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 14, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-316, PTD 200-090 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhiilips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 2N-316 (PTD 200-090) SUNDRY NOTICE 10-403 APPROVAL REQUEST March 14, 2015 This application for Sundry approval for Kuparuk well 2N-316 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 15". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor `, KUP • 2N-316 Conocoph fillips -'&wens Well Attributes Max Angle&MD TD • AlaskaInc. Wellbore API/UWI Field Name Well Status Incl I') MD(RKB) Act Btm(MB) i.r.n Wlu11ip. 501032034200 TARN PARTICIPATING AREA PROD I 79.52 8,133.81 13,692.0 • Comment H2S(ppm) Date Annotation End Date JKB-Grd(ft) Rig Release Date ••• Well con6a:•2Na1s.7/25/2012 tzas 41 PM -SSSV:NIPPLE 30 1/14/2010 Last WO: 39.68 8/1/2000 Schematic-Actual Annotation Depth(ftKB) End Date Annotation (Last Mod...End Date Last Tag:SLM I 13,238.0 10/16/2010 Rev Reason:Wellbore dates/CSG tops osborl 7/25/2012 Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...'String String' Top Thrd HANGER,30 ' ' CONDUCTOR 16 15.062 39.0 118.0 118.0 62.58 H-40 WELDED ill:.:OMR , Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String WE..String String Top Thrd SURFACE 75/8 6.875 39.0 3,497.9 2,505.0 29.70 L-80 BTC-MOD •: Casing Description Shing 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt,..String-.-String Top Thrd PRODUCTION 512 4.950 31.5 13,686.0 15.50 L-80 BTC-MOD 5.5"x3.5"@ 12743' Tubing Strings Tubingng Descri Description iontp String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd 111 TUBING I 31/2 2.992 29.9 12,759.7 9.30 L-80 EUE8RDMOD CompletionI 'Top Depth CONDUCTOR, (TVD) Top Incl Nomi... 39-718 Top(RKB) (RKB) C) Item Description Comment ID(In) 29.9 29.9 -0.14 HANGER FMC GEN IV TUBING HANGER 3.500 NIPPLE,516 515.8 515.3 7.67 NIPPLE CAMCO DS NIPPLE 2.875 Ike 12,621.4 SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 2.813 12,736.1 NIPPLE CAMCO D NIPPLE NO GO 2.750 12,743.2 LOCATOR BAKER LOCATOR 2.985 2.985 12,744.0 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc, Top Depth (ND) Top Incl MB TOp(RKB) (RKB) (") Description Comment Run Date ID(in) al13,413.0 FISH PANEX GAUGES,ETC.OAL 35.5'TAGGED w/COIL 9/9/2000 0.000 GAS LIFT 3.440 I Shot Top(TVD) Btm(TVD) Dens Top(RKB)B1m(RKB) (RKB) (11KB) Zone Date (oh,, Type Comment 13,260.0 13,275.0 S-3,2N-316 9/7/2000 4.0(PERF 2.5"HSD BH CHARGES Stimulations&Treatments ... SURFACE I Bottom I 39-3 49e Min Top Max Min Top Depth Depth I Depth Depth (TVD) (TVD) (RKB) (RKB) (RKB) ( B) Type Date Comment 13,260.0, 13,275.0 FRAC 9/9/2000 Frac;placed 214 Mlbs prop in formation. GAS UFT. ►otes: 7237 End Date Annotation - 62/2003 NOTE:TAGGED OBSTRUCTION @ 7110"WLM 6/3/2003 NOTE:UNABLE TO PASS 8153"WLM DURING STATIC g11/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 IN GAS LIFT, 10,408 It SLEEVE-C. 12.621 t I GAS LIFT, 12,662 illii I NIPPLE.12.736 M I LOCATOR, IL U 1TOR. is SEAL ASSY. - 12,744 Ani I I: Mandrel Details 'Top Depth Top ' Port' (PERF, (TVD) Incl OD Valve Latch Size TRO Run 13.260-13275N Stn Top(RKB) ( ) l") Make Model (in) Seri TYPe Type (in) (6/9 Run Date Com... FRAC.13.280 ' 1 3,440.3 2,481.7 59.87 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.0 8/6/2000 2 7,236.5 3,951.4 75.76 CAMCO KBG29 1 GAS LIFT'DMY INT 0.000 0.0 10232002 3 10,408.4 CAMCO KBG29 1 GAS LIFT OV BTM 0.313 0.05212009 FISH,13,413- 4 12,661.8 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.08/62000 PRODUCTION 5.5"x3.5" 12743, 31-13,686 Casing 5, 12743-13888 4 , TD,13,892 Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Wednesday, March 25, 2015 9:55 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2N-316: Sundry Application There is a fish at 13,413 MD (5,076 TVD) so that would be the effective depth. fit) . o9, ' Martin From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, March 19, 2015 10:37 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]KRU 2N-316: Sundry Application Good morning Martin, What is the current effective depth, both in MD and TVD, for KRU 2N-316? This information was missing on the Form 10-403, Box 11. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, March 19, 2015 10:37 AM To: NSK Well Integrity Proj (N1878@conocophillips.com) Subject: KRU 2N-316: Sundry Application O/ 0i �O Good morning Martin, What is the current effective depth, both in MD and TVD, for KRU 2N-316? This information was missing on the Form 10-403, Box 11. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • )Pir' . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 30,2011 R ' R .. E r Commissioner Dan Seamount " L, 4 8 9 °�. A a Pit rittA C hh;E;USSWOf Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 ; i misag0 Anchorage, AK 99501 0,00_09%0 Commissioner Dan Seamount: a.N - 3 !b Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 6130111 _ 2F,2M,2N,2T,2X,2Z,3B,30 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft _ gal 2F -19 50029227280000 1962010 8" I N/A 23" N/A 13 6/25/2011 • 2M -09A 50103201770100 1960900 SF N/A 18" N/A 3.5 6/26/2011 2M -14 50103201730000 1920630 SF N/A 19" _ N/A 3.5 6/26/2011 2M -17 50103201500000 1910180 SF N/A 19" _ N/A 3.5 6/26/2011 2M -26 50103201720000 1920550 SF N/A 21" _ N/A _ 3.5 6/26/2011 2N -316 50103203420000 2000900 SF N/A 18" N/A 4 6/27/2011 2N -318A 50103203430100 2090220 10" N/A 27" _ N/A 7 6/27/2011 2T -40 50103205280000 2060400 2' N/A 2' N/A - 6 6/26/2011 2T -202 50103202540000 1980370 6" N/A 20" _ N/A _ 9 6/26/2011 2X -07 50029209910000 1831130 SF N/A 21" N/A _ - 2 6/25/2011 2X -08 50029209920000 1831140 SF N/A 21" _ N/A _ 2.5 6/25/2011 2Z -02 50029209600000 1 830800 18" N/A 18" N/A 2.6 6/24/2011 3B -01 50029213180000 1 850560 SF 1.50 17" _ 5/23/2011 _ 6 6/22/2011 30-12 50029218040000 1880410 SF N/A 22" _ N/A 1.7 6/22/2011 2N-316 (PTD 200-090) Report o ailed TIFL Page 1 of 1 ~ ~ Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, May 11, 2009 12:24 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: NSK Problem Well Supv Subject: 2N-316 (PTD 200-090) Report of failed TIFL Attachments: 2N-316 schematic.pdf; 2N-316 90 day TIO plot.jpg I~~~yl ~I~I~~ Tom, / Kuparuk gas ~lift~ed r_oducer 2N-316 (PTD 200-090) failed a diagnostic TIFL on 05/10/09. The TIO prior to the test was 200/800/25- 0. A~aking GLV is suspected. Slickline will troubleshoot the GLV's and. repair if possibie. Attached is a schematic and a 90 day TIO plot. / Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 . .= .. . " ^L .. lV V ~ ~~ ~ ~;~~~~ ~~~~ ~ ~ ~'~ «2N-316 schematic.pdf» «2N-316 90 day TIO plot.jpg» ~ 8/7/2009 KRU 2N-316 PTD 200-090 5/ 11 /2009 TIO Pressures T/UO Plot - 2N-316 1000 800 600 N a 400 200 . .. . . .. .... . . .. . .. .. ..... .. .. . .. . . . .. . . . . . . . . ... . . . .. . . .. .. . ... .. J.J . . r. ~. . . . ~. ~. ~. . . ~. ~.. . . ,. !. . . . ~. ~...~. ~. ~. . . . i. ~ .. . . ~. ~ . . . . ~. ~ .. .. ~.1... . '~ 1~ ............~.1 .................................................`~.~rr.~.....V......~ ............................................................... 0 ~ ~, ~, ,~, ,~, 11-Feb-09 24-Feb-09 09-Mar-09 22-Mar-09 04-Apr-09 Date 17-Apr-09 30-Apr-09 200 ~ 150 a E a~ 100 ~ Y O ~ v 50 0 ~ ~"~ ' ~ 7~ ~/ti ~7 ~~ KUP ~ ~~.~~i~~t~ _ . "~ `.+~:C ~ _ ,~ _ I 9 '~; 3 ~~ 2N 316 ~ i (IWt~ n . ' ._~ ~. 1~r . R Well Stahs Inclination (°) Wellbore API/UWI Field Name MD (ttK8) 7Mal Depth (ftK8) ?~~~ ~ An~• 501032034200 TARN PARTICIPATING AREA PROD 53.63 1,951.44 13,692.0 CommeM HYS (ppm) Date Annotatian End Data KB<ird (R) Rig Release Data we~icc .-zrr.st - .. SSSV: NIPPLE 50 1/t/2008 Last WO: 39.68 8/1/2000 e~~. q~a =~~ ~ AnnMation Depth (ftKB) End Dete AnnWaNon End Date Last Tag: 13,262.0 5/192008 Rev Reason: TAG FISH @ 13413' 8/12/2008 ITi~'-'~ _ii i e - ,~" - ~~~'7r ~ s`'~" ~al ~, i,bb ._ ~ u~,~f , " : , -~ ~ ~ .. , ..k _ ~ . . - - _ li ~ `-.i(d~:: , ' < < Set Depth Set DepM (ND) Wt ~ . .. . . ... ... . Casing Deseription OD (in) ID (In) Top (ftKB) (ftKB) (flKB~ (Ibs/R~ Qrada TopThread ~ ~ :-..~,. ~~~ CONDUCTOR 16 15.062 0.0 116.0 118.0 62.58 H-40 WELDED SURFACE 7 5/8 6.500 0.0 3,498.0 29.70 L-80 BTCM coNOUCroa, iie PRODUCTION 51/2 4.950 0.0 12,743.0 15.50 L-80 LTCM LINER 31/2 2.992 12,743.0 13,886.0 9.30 L-80 EUE SRD f ~ ~ ~ ~ ~;~ ' ~' _ ~' ~t , ~ ~, ~ __ i, .- :& ~ - = _ - ~ Set Depth Tubing Deacri tion OD ~in ID (In) 7op (PoCB) (RKe) Set Depth ND ftKB) Wt (Ibs/R) 6rade To Threatl NIPPLE, 516 TUBING 3 1/2 2.992 0.0 12,760.0 9.30 L-80 EUE SRD ~t . '' ~'1~t1$ /~ I~: #~P.. ` ~#~~illl ~r e~} ~~ - i~ u ~" _~__~ ~ ~ at.,._ ~~ y ° 4e~ ~ a ~~ 4' 7op ~ftKB) Descrlpti on CommeM Run Date ID (in) 576.0 NIPPLE CAMCO' DS' NIPPLE 8/62000 2.875 3,440.0 GAS LIFT CAMCO/KBG29/1/DMYlINT/// Comment: STA 1 8/6/2000 2.900 7,236.0 GAS LIFT CAMCO/KBG29/1/DMV/INT//! Comment: STA 2 10/23/2002 2.900 10 408 0 GAS LIFT CAMCO/KBG29/1/OV/INTf 313lI Comment: STA 3 10/22/2002 2.900 cns uFi. . , . 3,490 12,621.0 SLEEVE-C BAKER CMU SLIDING SLEEVE - dosed 8/6/2000 2.813 12,662.0 GAS LIFT CAMCOIKBG29/1/DMV/INT//I Comment: STA 4 8/6/2000 2.900 72,736.0 NIPPLE CAMCO D NIPPLE $/6/2000 2.750 SURFACE, - 12,760.0 WLEG BAKER WIRELWE GUIDE S/6f2000 2.992 s,ase 13,413.0 FISH PANEX GAUGES, ETC. OAL 35.5' TAGGED w/COIL 9/92000 0.000 _ . k r ,~°~1 ' &w~~n;j ,~.,; ~y ~,~ - ~~ J," r ~. ~ ,. ` h ' ~ - P8 41"~ , ~ i . , t i'- _ ~S}11 , ~ - - ~~t s. _ ,i_. u n.,~, ki ~i ~:_ Shot Top (ND) Bfm ~'VD) Dens 7op (ftKB) Btm (ftKB) (RKB) (RKB) Type Zone (~hOt~•~ Date Comment GAS LIFT, _ 'I3,ZBO.O 13,275.0 IPERF 4.0 9/7/2000 2.5" HSD BH CHARGES 7,236 _ ~' W ~~H~' ~.. p m ! K ~ ~~~~i~ ...-J i~ ~'-" *-~W '''- t 1= -"~'~i t-~~~ F"~i `_" - Min 7op Maz Btm Depth Depth (ftKB) (RKB) Date Type Comment = 13,260.0 13,275.0 9/9/2000 FRAC Frac; placed 214 Mlbs prop in formation. GASLIFT. _ ~'$:4 ~ '~ 0~~ ~ ~~I ~f ' i.y~fr`~+ '' J~~ I~~~ti ~y4n ~ ~ II~V ~F _ 10,408 End Da ; .. ta r .~ , :... AnnMetion 9/92000 NOTE: MAX ANGLE SHOULD BE 79.52 deg @ 8133' ~ ( ~ SLEEVE-C, 12.621 ..:~,.''.",i; GAS LIFf, 12,6fi2 NIPPLE,12,736 PRODUCTION, 12.743 WLEG, 12,760 IPERF, '~,. 13.2fi0.13.275 'I FRAC, 13,2W , FISF1, 13,413 LINER, 73,686 T0, 13,692 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill 2000900 MD 13692 TVD DATA SUBMITTAL COMPLIANCE REPORT 9/912002 Well Name/No. KUPARUK RIV U TARN 2N-316 Operator PHILLIPS ALASKA INC. 5145 Completion Dat 9/7/2000 Completion Statu 1-OIL Current Status APl No. 50-103-20342-00-00 1-OIL UlC N REQUIRED INFORMATION Mud Log N.._9o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Name Scale Media Interval Run No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments D e'~ L L L 9904 LIS Verification SRVY RPT Survey Report MD ROP/GPJRES' TVD GFURES MD GPJDEN/NEU TVD GPJDEN/NEU 2/5 2/5 2/5 2/5 3447 13638 FINAL FINAL 0 13692 FINAL 3447 13692 FINAL 2289 5144 FI NAL 3447 13692 FINAL 2289 5144 Case 2/22/2001 09904 3447-13638 2/23/2001 9904 LIS Verification Digital Data 2/23/2001 LIS Verification Paper Copy OH 8/23/2000 SPERRY 0-13692. 1/9/2001 Surface to TD Paper Report CH 3/7/2001 3447-13692 BL, Sepia CH 3/7/2001 2289-5144 BL, Sepia CH 3/7/2001 3447-13692 BL, Sepia CH 3/7/2001 2289-5144 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~) Chips Received? Analysis Daily History Received? Formation Tops (~/N Comments: Permit to Drill 2000900 MD 13692 TVD DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. KUPARUK RIV U TARN 2N-316 Operator PHILLIPS ALASKA INC. 5145 Completion Dat 9/7/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20342-00-00 UIC N Compliance Reviewed By: Date: ~qnnutar ~tsposat aurtng me m~ra t. 'uar~er oj zoo~ : h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 20Ol July 2001 1C-127j 1C-117, lC-111, 1C-123 CD2'42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept200I 1C-123, 1C-119, 1C-102 ,, CD2-39 279 100 0 379 0 379 Sept 2001 .Sept 2001 Freeze protect volume from CD2-39 ,, z CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli Cor which Disposal Authorization Expired during the third quarter 2001: ............................... d ............. ~r ............... ~-- - t v · Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CDI-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 F~eeze protect 2N-332 only 2N-347 31540 100 .0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, ID-40, 1D-141, ~ 1D-36 1D-30 31622 100 0 31722 'Open, Freeze Protected Sept 2000 Oct 2006 1D-36, 1 D-34 2N-318 ' 17498 100 0 1'7598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N,316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 200i}.. Freeze protect 2N-316 · 2N-332' was permitted for annular dispoSal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2001 RE: MWD Formation Evaluation Logs 2N-316, AK-MM-00089 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 -oqo 2N-316: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20342-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20342-00 2" x 5" MD Neutron & Density Logs: 50-103-20342-00 2" x 5" TVD Neutron & Density Logs: 50-103-20342-00 1 Blueline ~ 1 Folded Sepia 1 Blueline e- l Folded Sepia/ 1 Blueline ~' 1 Folded Sepia" 1 Blueline ~' 1 Folded Sepia,-- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. February 01, 2001 Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-316, AK-MM-00089 1 LDWG formatted Disc with verification listing. API#: 50-103-20342-00 PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date' Signe~~~ ' ~ 20-Nov-O0 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-316 Dear Lori Taylor: · c/Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 13,692.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: .,~ v~; .c0~ ,, Please find reposed below the volumes injected into su~ace casing oy p~ucuon casing anuli during the third queer of 2000, as well as tot~ volumes injected into ~nuli for which injection authorization expired during the third queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(~) h(3) Total for Previous New WelI Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 '385 33990- 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907, 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 'L~' o'qO' PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Annular Injection during the third quarter of 2000: h(1) h(~) h(3) Totaifor Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 ~ CD1-03 33505 100 0 33605 385 33990 ? 1D-14 33916 100 0 34016 1487.5 35503.6 ~ CD1-25 24860 100 0 24960 8627'. 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 j~ oo -IO~ Ms. Wendy Mahan AOCJCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protect~'d CD 1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC.' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel ! Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files STATE OF ALASKA ALAS , OILAND GAS CONSERVATION COMMI ~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ['~ Gas D Suspended [~] Abandoned D Service D 2. Name of Operator 7. Permit Number Inc. ~ 200-090 / Phillips Alaska, 3. Address ~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~.~ 50-103-20342-00 4. Location of well at surface ~.~'~--"~ ~i 9. Unit or Lease Name 44' FNL, 690' FEL, Sec. 3, T9N, R7E, UM (ASP: 460903, 5911964) i ?'i'.T'7~i:~i;i?i''!,., .. Kuparuk River Unit At Top Producing Interval ~ !; ~.': '~ 10. Well Number 2166' FSL, 98' FWL, Sec. 33, T10N, RTE, UM (ASP: 451139, 5914229) i ._~_'_~_'_.4:;:;l~__; 2N-316 At Total Depth *, V; ~-!i~"::,'; 3[ ..........~--~ i 11. Field and Pool 2364' FNL, 1293' FWL, Sec. 28, T10N, R7E, UM (ASP: 452355, 592025 ~:- ~.~_ Kuparuk River Field 5. Elevation in teet (indicate KB, DF, etc.) J6. Lease Designation and Sedal No. Tarn Pool RKB 35 leerJ ADL 380054 / 375074, ALK 4602 12. Date Spudded 13. Date T.D. Reached 14. Date C_omp.,.Su_sp. Or Aband. J15. Water Depth, if offshore 16. No. of Completions July 7, 2000 August 1,2000 ~0'~,,Z~'~' J N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 13692' MD /5145' TVD 13558' MD /5112' TVD YES r~ No EClI N/A feet MD 1249' 22. Type Electdc or Other Logs Run GR/Res/Den/Neu, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 118' 24" 9 cu yds High Early 7.625" 29.7# L-80 Surface 3498' 9.875" ~35o sx AS III Lite, 250 sx Class G 5,5" X 15.5# L-80 Surface 12743' 7.5" 260 sx Class G & 540 sx Class G 3.5" 9.3# L-80 12743' 13686' 7.5" (included above) 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 12760' 12743' (CSR) 13260'-13275' MD 5037'-5040' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13260'- 13275' Pump 214,392#s behind pipe t IL ll IP, L Date First Productio~ Method of Operation (Flowing, gas litt, etc.) September 24, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 9/24/2000 7.0 Test Pedod > 1368 1034 0 100I 1116 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press 432 psi 1182 24-Hour Rate > 4792 3621 0 not available 28. CORE DATA ..... Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.~'~[~t~r=~"~' ./A OCT Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS ( 30. ~ FORMATION TESTS ,,,= NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3.1 12884' 4935' T-2 13346' 5058' Annulus left open - freeze protected with diesel. 31. LiST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I he, reby certily that the following is tree and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 Signed .j {~I,~'~ I ~'~"'t~ Title D rillin.qEn,qineerin,qSupervisor Date ~ CI~ ~ James Trantham INSTRUCTIONS Prepared by Sharon AIIsup-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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28.' If no cores taken, indicate "none". Form 10-407 Date: 09/20/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-316 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:07/08/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20342-00 07/06/00 (D1) TD/TVD: 118/118 SUPV:R.W. SPRINGER 07/07/00 (D2) TD/TVD: 118/118 SUPV:R.W. SPRINGER 07/08/00 (D3) TD/TVD: 1555/118 SUPV:R.W. SPRINGER 07/09/00 (D4) TD/TVD: 2437/118 SUPV:R.W. SPRINGER 07/10/00 (D5) TD/TVD: 2437/118 SUPV:R.W. SPRINGER 07/11/00 (D6) TD/TVD: 3510/118 SUPV:R.W. SPRINGER MW: 9.8 VISC: 90 PV/YP: 24/33 ( 118) DRILLING 9-7/8" SURFACE APIWL: 7.6 Rig released from 2N-332, move to 2N-316. NU diverter and function test diverter. Accept on 7/6/00 @ 1800 hrs. MW: 9.8 VISC: 80 PV/YP: 17/30 0) DIRECTIONALLY DRILLING @ 914' APIWL: 10.0 Drilled ice and formation from 40' to 383' Trouble making surveys. Drilled from 383' to 464'. Circ and condition hole, pump weighted hi-vis sweep. Run gyro survey. Drilled from 464'-625' MW: 10.2 VISC: 70 PV/YP: 26/36 (1437) DRILLING @ 1863' APIWL: 7.5 Drilled from 625' to 1079'. Pump sweep, rotate and reciprocate, pump pill. POH. RIH, ream 15' to bottom. Drilled from 1079' to 1555' Minimal gas through hydrates. MW: 10.2 VISC: 65 PV/YP: 24/24 ( 882) DRILLING @ 2692' APIWL: 5.0 Drilled from 1555' to 2121'. Pump sweeps. POH, tight from 1980'-1076'. RIH. Ream 10' to bottom. Circ high vis sweep. Drilled from 2121' to 2437' MW: 10.2 VISC: 65 PV/YP: 25/40 0) RIH F/WIPER TRIP TO SURFACE. APIWL: 5.0 Drilled from 2437' to 2531'. Pump weighted sweep. Drilled from 2531' to 3510'. Broaching outside subbase noticed. Circ bottoms up, pump low & high vis sweeps and circ. POH. MW: 10.2 VISC: 44 PV/YP: 17/11 (1073) NIPPLING DOWN DIVERTER APIWL: 5.0 Finish short trip from 2964'-1069'. RIH slowly, no returns, surging pipe. POH slow. RIH. Monitor well.'Fluid dropped 5' in riser w/pumps off. Broaching outside of sub-base halted , . ~ ~ lQ,, when mud allowed to drop 5 inside riser PJSM casing. Date: 09/20/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/12/00 (D7) TD/TVD: 3510/118 SUPV:R.W. SPRINGER MW: 9.6 VISC: 45 PV/YP: 12/11 0) TESTING BOPE APIWL: 5.2 Circ and condition hole for cementing. PJSM. Pump cement. Bumped plug, floats held. Cement to surface. Some broaching into lead cement pumping. NU BOPs. 07/13/00 (D8) TD/TVD: 3510/118 SUPV:R.W. SPRINGER MW: 9.6 VISC: 42 PV/YP: 12/12 0) DRILLING @ 3547' APIWL: 5.0 Finish nippling up BOPs and test to 250/3500 psi. PJSM. RIH, tag cement @ 3343'. Drill cement from 3343'-3409' 07/14/00 (D9) TD/TVD: 4237/118 SUPV:R.W. SPRINGER MW: 9.6 VISC: 42 PV/YP: 15/13 (727) DRILLING @ 4341' APIWL: 4.6 Drilled cement and float equipment from 3409' to 3510' Drilled 20' new hole to 3530'. Change over hole to new LSND mud. Perform leak off test to 15.7 ppg EMW. Drilled from 3530'-4237' 07/15/00 (D10) TD/TVD: 4995/118 SUPV:R.W. SPRINGER MW: 9.6 VISC: 45 PV/YP: 13/12 (758) DRILLING @ 5075' APIWL: 4.0 Drilled from 4237' to 4269'. Pump sweep out of hole. Repair bearing in oil pump on rotary table. Drilled from 4269' to 4995' 07/16/00 (Dll) TD/TVD: 5722/118 SUPV:R.W. SPRINGER MW: 9.6 VISC: 46 PV/YP: 15/17 ( 727) DRILLING @ 5905' APIWL: 0.8 Drilled from 4995' to 5027'. Circulate sweep, clean hole, monitor well. POH to 3490', no drag, monitor well. RIH. Wash and ream 30' to bttm, no fill. Drill from 5027' to 5722'. 07/17/00 (D12) TD/TVD: 6069/118 SUPV:R.W. SPRINGER MW: 9.6 VISC: 43 PV/YP: 13/14 ( 347) DRILLING @ 6165' APIWL: 3.6 Drilled from 5722'-6069'. Pump low vis sweep & circulate hole clean. Test BOPE ato 250/2500. PJSM. 07/18/00 (D13) MW: 9.6 VISC: 43 PV/YP: 12/14 APIWL: 3.8 TD/TVD: 6754/3192 ( 685) DIR DRLG @ 6960' (RIG ON RIG GENERATORS LAST 24 HRS) SUPV:DEARL W. GLADDEN TIH to 6019'. Wash and ream from 6019' to 6069'. Dir drilling from 6069' to 6754' 07/19/00 (D14) MW: 9.6 VISC: 43 PV/YP: 12/15 TD/TVD: 7363/3360 ( 609) TOH FOR BIT SUPV:DEARL W. GLADDEN Dir drilling from 6754' to 7363' APIWL: 3.8 Date: 09/20/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 07/20/00 (D15) MW: 9.6 VISC: 44 PV/YP: 12/13 APIWL: 3.6 TD/TVD: 7640/3446 (277) DIR DRLG @ 7877' SUPV:DEARL W. GLADDEN Pump sweep, circ hole clean. Monitor well. TOH. PJSM. TIH. Wash and ream from 7316' to 7363' Dir drilling from 7363' to 7640' 07/21/00 (D16) MW: 9.6 VISC: 47 PV/YP: 13/15 APIWL: 3.6 TD/TVD: 8621/3709 ( 981) DIR DRLG @ 8927' SUPV:DEARL W. GLADDEN Dir drilling 7640' to 8400'. Finish pumping sweep to surface. Dir drilling from 8400' to 8621' 07/22/00 (D17) MW: 9.6 VISC: 46 PV/YP: 13/14 APIWL: 3.8 TD/TVD: 9505/3965 (884) DIR DRLG @ 9760' (RIG ON RIG GENERATORS 24 HRS) SUPV:DEARL W. GLADDEN Dir drilling 8621' to 9221' Pump sweep, circ hole clean, monitor well. Wiper trip to 7325', no excess drag, no tight hole. CBU, circ hole clean after short trip to reduce ECDs. Dir drilling 9221' to 9505' 07/23/00 (D18) MW: 9.6 VISC: 46 PV/YP: 13/14 TD/TVD:10610/4276 (1105) TOH TO TEST BOPS SUPV:DEARL W. GLADDEN Dir drilling from 9505' to 10610' APIWL: 3.6 07/24/00 (D19) MW: 9.6 VISC: 44 PV/YP: 13/10 APIWL: 3.6 TD/TVD:10610/4276 ( 0) TIH ( RIG ON RIG GENERATORS 24 HRS) SUPV:DEARL W. GLADDEN Circ hole clean for short trip. Wiper trip to 9149'. CBU. Monitor well, pump dry job. PJSM. Test BOPs, 250/2500 psi. PJSM. RIH. 07/25/00 (D20) MW: 9.6 VISC: 46 PV/YP: 14/15 APIWL: 3.4 TD/TVD:ll149/4425 ( 539) DIR DRLG @ 11383' (RIG ON RIG GENERATORS 24 HRS) SUPV:DEARL W. GLADDEN Continue TIH to shoe (3494'). Test upper & lower kelly valves 250/3500 psi. Continue TIH to 10538'. Wash and ream from 10538' to 10610'. CBU & clean hole, rotate and recip pipe at all times. Dir drilling 10610' to 11149' 07/26/00 (D21) MW: 9.6 VISC: 45 PV/YP: 12/13 APIWL: 3.4 TD/TVD:l1849/4641 (700) DIR DRLG @ 12,038' (RIG ON RIG GENERATORS 24 HRS) SUPV:DEARL W. GLADDEN Dir drilling from 11149' to 11849' Date: 09/20/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 07/27/00 (D22) MW: 9.7 VISC: 46 PV/YP: 14/16 TD/TVD:12631/4857 (782) WIPER TRIP 15 STDS SUPV:DEARL W. GLADDEN Dir drilling from 11849' to 12631' APIWL: 3.2 07/28/00 (D23) MW: 9.6 VISC: 46 PV/YP: 15/13 APIWL: 3.2 TD/TVD:12688/4877 ( 57) TIH SUPV:DEARL W. GLADDEN Dir drilling from 12631' to 12682'. CBU f/wiper trip, having trouble sliding. Wiper trip 15 stds, no excess drag, no problems tripping. CBU - circ and clean ST hole, Pump nut plus sweep. Dir drilling 12682' to 12688'. MWD failed, attempt to re-gain signal, no signal. Monitor well, pump dry job. TOH. PJSM. 07/29/00 (D24) MW: 9.6 VISC: 45 PV/YP: 11/16 APIWL: 3.8 TD/TVD:12886/4931 ( 198) TOH - SUSPECT MOTOR FAILURE - NO DFFERENTIAL PRESSURE SUPV:DEARL W. GLADDEN PJSM. TIH. Circ and clean hole. wash & ream 12639' to 12688'. Dir drilling 12688' to 12886'. Lost differential pressure on motor, will not drilling. Pump nut plug sweep. Check for bit ball. No results. No drilling. 07/30/00 (D25) MW: 9.6 VISC: 45 PV/YP: 11/16 APIWL: 3.8 TD/TVD:12886/4931 ( 0) CBU ( RIG ON RIG GENERATORS LAST 24 HRS) SUPV:DEARL W. GLADDEN TOH 10 stds wet, monitor well, static. TOH. PJSM. Test BOPs 300/3500 psi. 07/31/00 (D26) MW: 9.6 VISC: 46 PV/YP: 13/17 APIWL: 3.3 TD/TVD:13505/5098 ( 619) WIPER TRIP 15 STDS SUPV:DEARL W. GLADDEN Wash & ream 12851' to 12886'. CBU. Dir drilling 6.75" hole from 12886' to 13505' 08/01/00 (D27) MW: 9.6 VISC: 46 PV/YP: 13/17 TD/TVD:13692/5144 ( 187) CHANGE PIPE RAMS, RIG UP TO RUN CASING. SUPV:R.'W. SPRINGER APIWL: 3.3 Drilled from 13505'-13692'. Circ hi-vis sweep while rotating and reciprocating pipe. Monitor well, short trip to 12220', no hole problems. Circulate hi-vis sweep to surface and spot lube pill on bottom. Monitor well, POH for casing, 7 tight spots. Wipe all tight spots out. Circ bttms up. Pump dry job. Hole well control drill. POH. Date: 09/20/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 08/02/00 (D28) TD/TVD:13692/5144 ( SUPV:R.W. SPRINGER MW: 9.6 VISC: 40 PV/YP: 11/10 0) RUNNING 5-1/2" PRODUCTION CASING APIWL: 3.5 POH, tight @ 4065' PJSM. R/U 3.5" casing equipment. PJSM. Run 3.5" tail pipe. R/U 5.5" casing equipment. Run 5.5" casing. Circ bottoms up @ shoe. Run 5.5" casing to 6036' Circ, lost returns, condition mud, cut mud weight to 9.7 ppg. Partial returns circ bttms up. Continue running 5.5" casing to 7734' 08/03/00 (D29) TD/TVD:13692/5144 ( SUPV:R.W. SPRINGER MW: 9.7 VISC: 43 PV/YP: 13/10 0) RIGGING UP DOWELL APIWL: 3.9 Run casing. Circ bottoms up @ 7734', full returns, well flowing after bottoms up, diminishing with time, monitoring well. Flow back 7 bbl before quitting. Run casing to 9440' Circulate bottoms up. Continue running casing, work and circ down thru tight spot from 9480'-9620'. Continue running casing to 12918'. Circ bttms up, partial returns, lost 131 bbl mud. Observe well, well flowing, diminishing flow. Total 111 bbl mud flowed back. 08/04/00 (D30) TD/TVD:13692/5144 ( SUPV:R.W. SPRINGER MW: 8.6 VISC: 0 PV/YP: 0/ 0 0) RUNNING 3-1/2" COMPLETION APIWL: 0.0 Finish running 5.5" casing. Circulate and condition hole for cementing. PJSM. Pump cement. Bumped plug and floats held. Set packoff and test. Rig up to run 3.5" completion. PJSM. Run 3.5" completion. 08/05/00 (D31) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:13692/5144 ( 0) LAYING DOWN DRILLPIPE FROM DERRICK SUPV:R.W. SPRINGER Continue running 3.5" completion. Space out tubing. Pump diesel down tubing. Freeze protect tubing. PJSM. 08/06/00 (D32) TD/TVD:13692/5144 ( SUPV:R.W. SPRINGER MW: 0.0 VISC: 0 PV/YP: 0/ 0 0)RIG RELEASED, MOVED TO 2N-318 APIWL: 0.0 PJSM. ND nipple & BOPs, N/U tree and test to 3500 psi. Perform LOT and freeze protect. Released rig @ 1900 hrs 8/6/00. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-316(W4-6)) WELL 2N-316 DATE 09/07/00 JOB SCOPE PERFORATIONS-E-LINE(260) DALLY WORK COIL TUBING PERFORATING DAY OPERATION COMPLETE I SUCCESSFUL 2 YES I YES InifialTbgPress IFinalTbgPress IlnitiallnnerAnn 0 PSI 0 PSI 380 PSI DAILY SUMMARY KEY PERSON DS-ROWELL Final Inner Ann I I 380 PSI JOB NUMBER 0902000848.2 UNIT NUMBER UNIT #2 SUPERVISOR FERGUSON Initial Outer Ann I Final Outer Ann 125 PSII 125 PSI RU DOWELL COIL #2. RIH WITH SCHLUMBERGER MEMORY GR/CCL. FLAG PIPE AT 13300' AND LOG FROM 13300' TO 12800' AT 30 FPM. POOH. RU 15' X 2 1/2" 4 SPF, BH CHARGES AND RIH. PERFORATE 13260'-13275' CORRECTED TO SPERRY-SUN MWD. PRESSURE FIRING HEAD USED. POOH ALL SHOTS FIRED.[Perf] TIME LOG ENTRY 00:00 07:00 RU DOWELL COIL UNIT AND HOLD SAFETY MEETING 07:50 MAKE UP WEATHERFORD CT CONNECTOR AND PULL TEST 08:05 PT COIL CONNECTOR TO 3800 PSI 08:30 MAKE UP SCHLUMBERGER LOGGING TOOLS 09:15 RU MORE LUBRICATOR FOR TOOL STRING. AND PT TO 3800 PSI 10:30 START RIH WITH LOGGING TOOLS 11:55 WT CHK AT 9100.2' IS 14000#S 12:40 RIH TO 13450' (21,000#'S PU WT) PU TO 13300' AND FLAG PIPE. PU LOGGING AT 30 FPM 12:47 13:00 LOG TO 12800' AT 30 FPM AND POOH REPLACING VOIDAGE WITH DIESEL 15:00 OUT OF HOLE WITH LOGGING TOOL, SHIFT LOG +10' DEEP TO SPERRY-SUN MWD, FOR CORRECTION. CORRECTED EOT TO FLAG DEPTH OF 13,300' IS 13298.3' 15:30 PRE-PERF SAFETY MEETING, WILL NEED MAN LIFT TO MAKE UP GUN. CALL FOR LIFT. 16:30 OBTAIN DOG COLLAR FROM RIG TO MAKE UP GUNS WHILE WAITING ON MAN LIFT. 16:50 PT LINES TO 3500 PSI 17:05 START IN HOLE WITH PERF GUNS 17:50 6500#S AT 5000' FOR WT CHK 19:00 19:05 ON DEPTH AT 13300', CORRECT TO 13310.5'(12.15' EOT TO TOP SHOT) PU WT 18500#S AT 13315' 19:10 PU TO 13260' TO PERFORATE 13260' TO 13275'. DROP 5/8" BALL 19:25 DISPLACING BALL AT 1.5 BPM, CLOSE CHK TO BRING WHP UP TO 1000 PSI TIME 19:43 19:45 21:30 21:45 23:15 LOG ENTRY BALL ON SEAT,PRESSURE UP TO 3600 PSI AND GUN FIRED WHILE HOLDING 1000 PSI ON WH WITH CHK. START POOH OUT OF HOLE ALL SHOTS FIRED RDMO PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-316(W4-6)) WELL 2N-316 DATE 09/09/0O DAY 1 JOB SCOPE DRILLING SUPPORT-CAPITAL DAILY WORK FRAC TREATMENT OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 0 PSII 0 PSI KEY PERSON DS-GALLEGOS Final Inner Ann I 0 PSI I JOB NUMBER 0908001452.3 UNIT NUMBER SUPERVISOR FERGUSON Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI DALLY SUMMARY RU DOWELL PUMP EQUIP. PUMP BREAKDOWN AND SCOUR STAGES AT MAX RATE OF 35 BPM AND 8000 PSI. PERFORM DATAFRAC AND HOLD PAD AT DESIGN VOLUME OF 600 BBLS. GO LONG ON 4 PPA AND ADD 8 PPA STAGE. PLACE 214,392#'S BEHIND PIPE WITH 8 PPA ON FORMATION(110% OF DESIGN). LEFT 886 #'S IN PIPE. [Frac-Refrac] TIME LOG ENTRY 07:45 ARRIVE LOCATION. DOWELL RU PUMP EQUIPMENT 09:45 SAFETY MEETING 10:30 PT LINES TO 10000 PSI 10:45 START BREAKDOWN STAGE OF 30# X/L GEL. 180 BBLS OF 30# X/L. ISIP= 870 PSI, FG=0.62 PSI/FT. XS FRICTION AT 35 BPM =2167 PSI 11:30 SD AFTER PUMPING SCOUR STAGES AT 20 BPM. ISIP=856 PSI, FG=0.62 PSI FT. XS FRICTION AT 20 BPM=854 PSI 12:00 START 300 BBL DATAFRAC AT 20 BPM. 13:30 DATAFRAC RESULTS 25% EFF, ISIP=1000 PSI, TC=6.5 MIN, PC=930 PSI. RERUN STIMPLAN AND HOLD PAD AT 600 BBLS FOR FRAC .' 13:35 START FRAC AT 20 BPM WITH 600 BBL PAD 14:35 ELECT TO EXTEND 4 PPA FLAT STAGE BY 100 BBLS TO BUILD NET PRESSURE. 15:00 ELECT TO GO TO 8 PPA ON FINAL 100 BBLS OF SLURRY 15:05 ELECT TO GO LONG 20 BBLS ON 8 PPA 15:10 GO TO FUSH AT END OF LONG 8 PPA STAGE 15:20 FLUSH JOB WITH 113 BBLS WITH FINAL 20 BBLS DIESEL FOR FREEZE PROTECT. FINAL RATE AT 5 BPM 15:25 PLACE 214392#'S BEHIND PIPE WITH MAX CONC OF 8 PPA ON FORMATION. LEFT 886#'S IN PIPE. 16:30 RDMO PHILLIPS Alaska, inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 October 2, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 2N-316 (200-090) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 2N-316. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. .Sincerely, ;.-- - James Trantham Drilling Engineering Supervisor PAI Drilling JT/skad Kuparuk River Unit Phillips Alaska Kuparuk 2N 2N-316 Job No. AKMMO0089, Surveyed: 28 July, 2000 SURVEY REPORT 20 November, 2000 Your Reft API501032034200 Surface Coordinates: 5911963.70 N, 460903.15 E (70° 10' 13.5305" N, 209° 41' 07.2379" E) Kelly Bushing: i53.30ft above Mean Sea Level olRi 1,-I.I N I~. A Hallll)urton company Survey Ref: svy9340 '-~o:~ ~o.~.~ o~o~o~o ~ooo, o~ c~o~oo 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ mmmmm mmmmm mmmmm ~ooo 888~ ~~ ..... mmmmm mmmmm ~00 00000 ~0~ ~00 Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: APi$01032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. 973.80 21,190 314.950 1004.33 22.020 314.530 1037.35 22.630 314.590 1065.86 23.730 316.310 1097.58 25.220 317.22o Sub-Sea Depth (ft) 801.34 829.73 860.27 886.48 915.35 Vertical Depth (ft) 954.64 983.03 1013.57 1039.78 1068.65 1128.98 25.830 316.360 943.68 1096.98 1153.30 25.630 317.290 965,59 1118.89 1185.36 25.620 317.090 994.50 1147.80 1217.10 27.410 317.120 1022.90 1176.20 1248.73 29.020 317,370 1050.77 1204.07 1280.58 29.220 317.680 1078.60 1231.90 1312.37 29.910 316.840 1106.25 1259.55 1344.28 29.950 317.140 1133.90 1287.20 1374.48 31.520 316.800 1159.86 1313.16 1406.32 33.200 316.590 1186.75 1340.05 1438.00 33.310 316,830 1213.24 1366.54 1467.79 34.690 316.440 1237.94 1391.24 1500.39 36.640 316.290 1264.42 1417.72 1532.41 36.870 315.950 1290.08 1443.38 1567.01 38.390 316.900 1317.48 1470.78 1599.12 40.160 315.010 1342.34 1495.64 1627.93 40.380 315.030 1364.32 1517.62 1660.18 41.760 313.900 1388.63 1541.93 1691.80 44.130 313.930 1411.78 1565.08 1723.04 46.260 314.120 1433.79 1587.09 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 97.96 N 97.69W 5912062.16 N 460805,97 E 105.87 N 105.68W 5912070.12 N 460798.02E 114.67 N 114.61W 5912078.96 N 460789.13 E 122.67 N 122.48W 5912087.00 N 460781.30 E 132.25 N 131.48W 5912096.63N 460772.35 E 142.11N 140.75W 5912106.53N 460763,14 E 149.81N 147.97W 5912114.27N 460755.96 E 159.98 N 157.39W 5912124.49 N 460746.59 E 170.36 N 167.04W 5912134,92 N 460737.00E 181.34 N 177.19W 5912145.95 N 460726.90 E 192.77 N 187,65W 5912157.44N 460716.49 E 204.29 N 198.30W 5912169.01 N 460705.91 E 215.93 N 209.16W 5912180.71 N 460695.11E 227.22 N 219.69W 5912192.05 N 460684.63 E 239.62 N 231.38W 5912204,51 N 460673.01 E 252.26 N 243.29W 5912217.21 N 460661.16 E 264.37 N 254.73W 5912229.38 N 460649.79E 278.13 N 267,85W 5912243.21N 460636.74 E 291.94 N 281.13W 5912257.08 N 460623.53 E 307.24 N 295.69W 5912272.47 N 460609.05E 321.85 N 309.82W 5912287.14 N 460594.99 E 335.02 N 322.99W 5912300.38 N 460581.90E 349.86 N 338.11W 5912315.30 N 460566.85 E 364.80 N 353.63W 5912330.32 N 460551.41 E 380.20 N 369.56W 5912345.81N 460535.56 E Dogleg Rate (°llOOft) 0.62 2.77 1.85 4.53 4.85 2.27 1.85 0.27 5.64 5.10 0.79 2'53 0.49 5,23 5.29 0.54 4.69 5.99 0.96 4.70 6.65 0.76 4.86 7.50 6.83 Vertical Section 138.31 149.55 162.09 173.31 186.43 199.94 21o.48 224.32 238.47 253.39 268.86 284.51 300.41 315.82 332.84 35o. 19 366.82 385.81 404.96 426,06 446.37 464.98 486.17 5o7.71 529.87 Phillips Alaska Kuparuk 2N Comment Continued... 20 November, 2000 - 17:05 - 3 - DrillQueet 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: AP!501032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1761.76 46.460 313.970 1460.51 1613.81 1792.69 48.530 312.700 1481.41 1634.71 1824.34 50.250 314.620 1502.01 1655.31 1855.81 50.530 313.240 1522.08 1675.38 1887.82 51.900 314.660 1542.13 1695.43 1919.57 52.020 315.300 1561.69 1714.99 1951.45 53.640 316.110 1580.95 1734.25 1983.20 53.780 316.490 1599.74 1753.04 2013.46 54.800 316.830 1617.41 1770.71 2045.38 55.300 315.890 1635.69 1788.99 2069.46 56.500 316.970 1649.19 1802.49 2100.97 57.170 315.420 1666.43 1819.73 2132.89 57.970 317.360 1683.55 1836.85 2164.34 57.410 316.300 1700.36 1853.66 2196.10 57.460 316.480 1717.46 1870.76 2227.88 58.760 315.700 1734.24 1887.54 2260.08 58.970 315.500 1750.89 1904.19 2291.75 60.210 314.820 1766.92 1920.22 2322.24 62.170 315.410 1781.62 1934.92 2353.38 62.770 314.920 1796.01 1949.31 2385.27 63.990 314.400 1810.30 1963.60 2416.81 64.370 315.020 1824.04 1977.34 2448.59 65.420 313.140 1837.52 1990.82 2480.18 66.950 313.370 1850.28 2003.58 2512.23 67.320 312.950 1862.73 2016.03 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 399.68 N 389.70W 5912365.39 N 460515.52 E 415.33 N 406.29W 5912381.12 N 460499.01 E 431.92 N 423.67W 5912397.80 N 460481.72E 448.74 N 441.13W 5912414.71 N 460464.35 E 466.05 N 459.09W 5912432.12 N 460446.48 E 483.73 N 476.78W 5912449.89 N 460428.88 E 501.91N 494.51W 5912468.16 N 460411.24E 520.41N 512.19W 5912486.75 N 460393.65 E 538.28 N 529.06W 5912504.71 N 460376.88 E 557.22 N 547.11W 5912523.74 N 460358.92 E 571.67 N 560.85W 5912538.26 N 460345.26 E 590.70 N 579.11W 5912557.38N 460327.10 E 610.21N 597.69W 5912576.99 N 460308.62 E 629.59 N 615.88W 5912596.47 N 460290.53E 648.97 N 634.34W 5912615.94 N 460272.17 E 668.41N 653.05W 5912635.48 N 460253.56 E 688.10 N 672.34W 5912655.27 N 460234.38 E 707.47 N 691.60W 5912674.73N 460215.22 E 726.40 N 710.45W 5912693.76 N 460196.46 E 745.98 N 729.92W 5912713.44 N 460177.10 E 766.02 N 750.20W 5912733.58 N 460156.92E 785.99 N 770.37W 5912753.66 N 460136.85 E 806.01N 791.05W 5912773.78 N 460116.28 E 825.81N 812.09W 5912793.70 N 460095.33 E 846.01N 833.64W 5912814.01N 460073.90 E Dogleg Rate (°/lOOft) 0.59 7.35 7.12 3.49 5.50 1.63 5.47 1.06 3.49 2.88 6.21 4.63 5.71 3.36 0.50 4.59 O.84 4.33 6.65 2.38 4.09 2.14 6.29 4.89 1.67 Vertical Section 557.89 580.69 604.72 628.96 653.91 678.91 7o4,30 729.86 754.40 780.54 800.46 826.81 853.72 880.26 907.00 933.96 961.5o 988.81 1015.52 1043.12 lO71.63 110O.Ol 1128.79 1157.69 1187.22 Phillips Alaska Kuparuk 2N Comment AK-6 BP_IFR-AK Continued... 20 November, 2000 - 17:05 - 4 - DrillQueet 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: API501032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (ft) 2544.03 68.910 312.850 1874.58 2027.88 2574.71 69.180 317.090 1885.56 2038.86 2613.61 70.490 309.330 1898.99 2052.29 2644.82 70.310 311.120 1909.46 2062.76 2676.68 71.680 309.130 1919.83 2073.13 2708.13 71.510 309.330 1929.76 2083.06 2740.01 71.220 308.780 1939.95 2093.25 2771.71 72.790 309.850 1949.74 2103.04 2803.79 72.580 310.550 1959.29 2112.59 2835.35 72.430 311.300 1968.78 2122.08 2867.00 72.360 311.200 1978.35 2131.65 2898.79 73.510 312.900 1987.68 2140.98 2930.52 73.490 310.400 1996.69 2149.99 2961.81 74.800 312.050 2005.24 2158.54 2992.91 75.000 315.630 2013.35 2166.65 3024.60 74.620 310.440 2021.65 2174.95 3087.49 74.280 309.680 2038.51 2191.81 3119.55 74.080 312.070 2047.26 2200.56 3151.02 73.740 310.330 2055.98 2209.28 3181.89 73.440 312.470 2064.70 2218.00 3239.74 74.780 313.250 2080.54 2233.84 3271.61 74.510 311.800 2088.98 2242.28 3334.51 74.850 313.540 2105.60 2258.90 3397.62 74.490 311.230 2122.29 2275.59 3434.39 74.280 311.380 2132.18 2285.48 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) 866.10 N 855.25W 5912834.21N 460052.39 E 886.34 N 875.51W 5912854.55 N 460032.23 E 911.31N 902.11W 5912879.66 N 460005.76 E 930.30 N 924.56W 5912898.76 N 459983.41 E 949.71N 947.59W 5912918.29 N 459960.48 E 968.58 N 970.71W 5912937.28 N 459937.46 E 987.61N 994.16W 5912956.44 N 459914.10 E 1006.72 N 1017.49W 5912975.66 N 459890.88 E 1026.48 N 1040.88W 5912995.55 N 459867.59 E 1046.20 N 1063.62W 5913015.38N 459844.95 E 1066.09 N 1086.30W 5913035.39 N 459822.37 E 1086.45 N 1108.87W 5913055.86 N 459799.91E 1106.66 N 1131.60W 5913076.19 N 459777,28 E 1126.50N 1154.24W 5913096.15 N 459754.75 E 1147.29 N 1175.89W 5913117.05 N 459733.20 E 1168.16 N 1198.23W 5913138.03N 459710.97 E 1207.15 N 1244.60W 5913177.26 N 459664.80 E 1227.33N 1267.93W 5913197.57N 459641.58 E 1247.25 N 1290.68W 5913217.60 N 459618.93 E 1266.83 N 1312.89W 5913237.30 N 459596.83 E 1304.68 N 1353.67 W 5913275.35 N 459556.24 E 1325.45 N 1376.32 W 5913296.24 N 459533.70 E 1366.57 N 1420.92 W 5913337.59 N 459489.31 E 1407.59 N 1465.87 W 5913378.85 N 459444.57 E 1430.97 N 1492.48 W 5913402.36 N 459418.09 E Dogleg Rate (°ll00ft) 5.01 12.94 19.02 5.43 7.31 0.81 1.87 5.90 2.18 2.32 0.37 6.26 7.55 6.58 11.13 15.85 1.28 7.20 5.42 6.72 2.65 4.47 2.72 3.58 0.69 Vertical Section 1216.72 1245.36 1281.84 1311.18 1341.24 1370.99 14o1.1o 1431.15 1461.72 1491.78 1521.92 1552.30 1582.7o !612.77 1642.79 1673.36 1733.82 1764.62 1794.83 1824.41 1880.04 1910.77 1971.42 2032.26 2067.64 Phillips Alaska Kuparuk 2N Comment Continued... 20 November, 2000 - 17:05 - 5- DrlllQueet 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 3551.51 74.280 311.520 2163.91 2317.21 3583.22 74.370 310.640 2172.48 2325.78 3614.85 74.390 310.440 2181.00 2334.30 3646.45 74.100 313.120 2189.58 2342.88 3677.49 73.790 309.780 2198.17 2351.47 3709.80 73.670 308.850 2207.22 2360.52 3741.47 73.570 307.630 2216.15 2369.45 3773.17 74.060 309.300 2224.99 2378.29 3836.34 78.120 315.810 2240.19 2393.49 3867.58 78.370 316.330 2246.55 2399.85 3899.34 78.220 316.480 2252,99 2406.29 3930.82 77.090 316.140 2259.72 2413.02 3961.92 77.230 315.850 2266,64 2419.94 3993.67 77.240 315.870 2273.65 2426.95 4025.40 76.730 315.710 2280.80 2434.10 4057.10 75.770 314.960 2288.33 2441.63 4088.60 74,330 314.230 2296.46 2449.76 4120.27 73.g80 314.100 2305.10 2458.40 4151.25 73.520 313.090 2313.77 2467.07 4183.61 73.230 312.500 2323.03 2476.33 4215.22 73.480 314.610 2332.09 2485.39 4246.89 73.650 316.260 2341.05 2494.35 4278.36 73.200 314.660 2350.03 2503.33 4310.02 73.230 314.160 2359.17 2512.47 4342.08 72.930 314.350 2368.50 2521.80 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1505.60 N 1576.98W 5913477.42 N 459333.97 E 1525.66 N 1599.99W 5913497.61N 459311.06 E 1545.46N 1623.14W 5913517.52 N 459288.02 E 1565.72N 1645.82W 5913537.90 N 459265.44 E 1585.46 N 1668.17W 5913557.76 N 459243.19 E 1605.11 N 1692.17W 5913577,53 N 459219.30 E 1623.92 N 1716.03W 5913596.46 N 459195.53 E 1642.86 N 1739.87W 5913615.52 N 459171.79 E 1684.32 N 1784.98W 5913657.21 N 459126.90 E 1706.34N 1806.20W 5913679.35 N 459105.79 E 1728.87 N 1827.64 W 5913701.98 N 459084.46 E 1751.10 N 1848.88 W 5913724.33 N 459063.34 E 1772.91 N 1869.95 W 5913746.25 N 459042.38 E 1795.13 N 1891.51 W 5913768.58 N 459020.94 E 1817.29 N 1913.07 W 5913790.85 N 458999.49 E 1839.19 N 1934.71W 5913812.86 N 458977.96 E 1860.56 N 1956.39W 5913834.34N 458956.40 E 1881.79 N 1978.24W 5913855.68 N 458934.66 E 1902.30 N 1999.78W 5913876.30 N 458913.22 E 1923.36 N 2022.53W 5913897.48N 458890.58 E 1944.23 N 2044.48W 5913918.46 N 458868.74E 1965.87N 2065.79W 5913940.21N 458847.54 E 1987.37 N 2086.95W 5913961.82 N 458826.50 E 2008.58 N 2108.60W 5913983.14 N 458804.95 E 2029.98 N 2130.57W 5914004.66 N 458783.10 E Dogleg Rate (°llOOft) 0.12 2.69 0.61 8.21 10.39 2.79 3.71 5.29 11.89 1.82 0.66 3.74 1.01 0.07 1.68 3.80 5.09 1.17 3.46 1.96 6.44 5.03 5.08 1.51 1.09 Vertical Section 2180.29 2210.79 2241.20 2271.59 2301.40 2332.32 2362.56 2392.87 2454.13 2484.69 2515.76 2546.48 2576.78 2607.72 2638.61 2669.39 2699.82 2730.29 2760.03 2791.03 2821.32 2851.68 2881.83 2912.14 2942.81 Phillips Alaska Kuparuk 2N Comment Continued... 20 November, 2000- 17:05 -6- DrillQuest 2. 00.02 Sperry-Sun Drilling Services Survey Report for 2N.316 Your Ref: API501032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth Incl. Azim, Sub-Sea Depth (fi) Vertical Depth (ft) 4373.79 72.960 312.950 2377.80 2531.10 4434.92 73.470 312.510 2395.45 2548.75 4498.79 73.990 311.320 2413.35 2566.65 4531.11 74.680 311.190 2422.07 2575.37 4594.38 76.510 311.810 2437.81 2591.11 4626.06 77.650 312.490 2444.90 2598.20 4657.31 78.100 312.600 2451.46 2604.76 4689.04 78.120 312.420 2458.00 2611.30 4720.64 77.090 311.300 2464.78 2618.08 4752.17 75.750 311.330 2472.18 2625.48 4783.82 74.860 312.680 2480.21 2633.51 4815.20 73.900 311.870 2488.66 2641.96 4846.60 74.320 312.230 2497.26 2650.56 4878.41 74.310 311.120 2505.86 2659.16 4910.26 73.320 312.530 2514.74 2668.04 4941.93 72.260 312.880 2524.11 2677.41 4973.66 72.710 312.910 2533.66 2686,96 5004.93 72.950 311.510 2542.89 2696.19 5036.68 72.720 310.430 2552.26 2705.56 5068.19 73.290 309.610 2561.47 2714.77 5099.79 72.770 310.610 2570.69 2723.99 5131.33 72.600 311.480 2580.08 2733,38 5163.10 73.190 310.800 2589.43 2742.73 5194.76 73.410 311.970 2598.52 2751.82 5224.06 73.290 312.830 2606.92 2760,22 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2050.91 N 2152.50W 5914025.70 N 458761.27 E 2090.62N 2195.49W 5914065.63 N 458718.48 E 2131.58 N 2241.12W 5914106.83 N 458673.07E 2152.10 N 2264.51W 5914127.47N 458649.78 E 2192.70 N 2310.41W 5914168.31N 458604.10 E 2213.42 N 2333.30W 5914189.15 N 458581.32 E 2234.08 N 2355,81W 5914209.92 N 458558.91 E 2255.06 N 2378.70W 5914231.02N 458536.13 E 2275.66 N 2401.68W 5914251.73 N 458513.26 E 2295.89 N 2424.70W 5914272.09 N 458490.34 E 2316.38 N 2447.45W 5914292.69 N 458467.70 E 2336.71 N 2469.81W 5914313.13 N 458445.44 E 2356.93 N 2492.24W 5914333.48 N 458423.12 E 2377.30 N 2515.11W 5914353.96 N 458400.35 E 2397.69 N 2537.90W 5914374.47N 458377.67E 2418.21N 2560.14W 5914395.10 N 458355.54 E 2438.81N 2582.30W 5914415.81N 458333.48 E 2458.88 N 2604.43W 5914436.00 N 458311.46 E 2478.77N 2627.34W 5914456.01 N 458288.65 E 2498.14 N 2650.41W 5914475.50 N 458265.68 E 2517.62N 2673.53W 5914495.09 N 458242.66 E 2537.39 N 2696.24W 5914514.98 N 458220.06 E 2557.36 N 2719.11W 5914535.08 N 458197.29 E 2577.41N 2741.86W 5914555.24 N 458174.65 E 2596.34N 2762.59W 5914574.28 N 458154.01E Dogleg Rate (°/lOOft) 4.22 1.08 1.97 2.17 3.04 4.16 1.48 0.56 4.75 4.25 4.99 3.94 1.73 3.36 5.27 3.51 1.42 4.35 3.33 3.08 3.45 2.69 2.76 3.61 2.84 Vertical Section 2973.12 3031.64 3092.92 3124.Ol 3185.24 3216.10 3246.65 3277,69 3308.54 3339.16 3369.76 3399.97 3430.15 3460.76 3491.33 3521,57 3551.83 3581.69 3611.99 3642.O6 3672.22 3702.30 3732.63 3762.93 3791.00 Phillips Alaska Kuparuk 2N Comment Continued,,. 20 November, 2000 - 17:05 - 7- DrillQueet 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 5255.00 73.480 312.340 2615.77 2769.07 5289.27 73.850 311.840 2625.40 2778.70 5320.80 73.870 310.780 2634.17 2787.47 5352.36 74.030 309.060 2642.90 2796.20 5384.17 73.660 310.310 2651.75 2805.05 5415.38 73.150 311.360 2660.66 2813.96 5446,80 73.460 312.820 2669.69 2822.99 5478.12 73.840 314.110 2678.50 2831.80 5509.91 74.300 315.840 2687.23 2840.53 5540.95 74.610 317.240 2695.55 2848.85 5573.14 74.830 315.800 2704.03 2857.33 5604.85 74.010 316.400 2712.55 2865.85 5636.56 72.640 314.900 2721.65 2874.95 5668.23 73.050 313.840 2730.99 2884.29 5699.64 71.970 313.670 2740.43 2893.73 2750.62 2761.66 2772.36 2782.83 2792.71 5730.71 69.750 312.260 5762.71 69.890 311.050 5794.29 70.500 308.900 5825.96 70.880 307.430 5857.73 72.900 307.720 2903.92 2914.96 2925.66 2936.13 2946.01 5888.94 75.810 309.610 2801.12 2954.42 5920.50 77.130 310.610 2808.51 2961.81 5952.20 78.980 312.120 2815.07 2968.37 5989.69 77.570 312.790 2822.68 2975.98 6015.28 76.890 313.420 2828.34 2981.64 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2616.40 N 2784.42W 5914594.45 N 458132.29 E 2638.45 N 2808.82W 5914616.62 N 458108.00 E 2658.44N 2831.57W 5914636.73 N 458085.35 E 2677.90 N 2854.83W 5914656.31 N 458062.19 E 2697.41N 2878.34W 5914675.95 N 458038.78 E 2716.97 N 2900.97W 5914695.62 N 458016.25 E 2737.14 N 2923.31W 5914715.91N 457994.02 E 2757.81N 2945.12W 5914736.69 N 457972.32 E 2779.42 N 2966.74W 5914758.41N 457950.81E 2801.13 N 2987.31W 5914780.22 N 457930.35 E 2823.66 N 3008.68W 5914802.86 N 457909.10 E 2845.67N 3029.86W 5914824.98 N 457888.04 E 2867.39 N 3051.09W 5914846.81N 457866.92 E 2888.55 N 3072.72W 5914868.08 N 457845.39 E 2909.27 N 3094.36W 5914888.91 N 457823.86 E 2929.27N 3115.83W 5914909.03 N 457802.49 E 2949.23N 3138.28W 5914929.11N 457780.15 E 2968.32 N 3161.04W 5914948.31N 457757.48 E 2986.79 N 3184.54W 5914966.90 N 457734.08 E 3005.20 N 3208.47W 5914985.44 N 457710.25 E 3023.98 N 3231.93 W 5915004.33 N 457686.88 E 3043.75 N 3255.40 W 5915024.22 N 457663.52 E 3064.24 N 3278.67 W 5915044.84 N 457640.35 E 3089.02 N 3305.76 W 5915069.75 N 457613.40 E 3106.07 N 3323.98 W 5915086.90 N 457595.26 E Dogleg Rate (°/100ft) 1.64 1.77 3.23 5.26 3.95 3.61 4.56 4.13 5.43 4.46 4.37 3.16 6.26 3.45 3.48 8.33 3.58 6.69 4.54 6.42 11.00 5.19 7.47 4.15 3.58 Vertical Section 382o.64 3853.51 3883.77 3914.03 '3944.51 3974.38 4004.46 4034.51 4065.07 4094.94 4125.96 4156.47 4186.83 4217.09 4247.05 4276.40 4306.41 4336.06 4365.80 4395.82 4425.75 4456.37 4487.36 4524.05 4549.01 Phillips Alaska Kuparuk 2N Comment Continued... 20 November, 2000 - 17:05 - 8 - DrillQuest 2.00.02 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth Sperry-Sun Drilling Services Vertical Depth (ft) 6047.11 75.870 314.270 2835.84 2989.14 6079.10 74.550 314.420 2844.00 2997.30 6110.98 74.060 313.570 2852.63 3005.93 6142.74 73.660 313.040 2861.46 3014.76 6173.82 73.390 312.550 2870.27 3023.57 6205.34 72.970 312.610 2879.39 3032.69 6237.25 72.290 311.610 2888.92 3042.22 6268.82 72.100 311.940 2898.57 3051.87 6300.70 73.300 313.050 2908.05 3061.35 6332.37 73.200 314.030 2917.18 3070.48 6361.61 72.950 313.630 2925.69 3078.99 6395.78 72.200 312.190 2935.92 3089.22 6427.27 71.810 311.990 2945.65 3098.95 6458.29 73.560 312.570 2954.88 3108.18 6489.80 73.330 312.650 2963.86 3117.16 Survey Report for 2N-316 Your Ref: API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 6521.19 72.590 311.740 2973.06 3126.36 6552.38 72.040 311.040 2982.54 3135.84 6584.06 74.990 310.730 2991.52 3144.82 6615.30 75.240 311.330 2999.55 3152.85 6647.48 74.520 310.450 3007.94 3161.24 6679.13 74.020 310.180 3016.52 3169.82 6710.92 73.230 309.770 3025.49 3178.79 6742.12 72.780 309.660 3034.61 3187.91 6773.79 72.110 308.770 3044.16 3197.46 6805.39 73.780 310.460 3053.43 3206.73 Local Coordinates Global Coordinates Northings Eaatings Northings Eastings (~t) (ft) (ft) (ft) 3127.50 N 3346.29W 5915108.44N 457573.06 E 3149.12 N 3368.41W 5915130.18 N 457551.06 E 3170.44N 3390.48W 5915151.61N 457529.09E 3191.36 N 3412.69W 5915172.65 N 457507.00 E 3211.61 N 3434.56W 5915193.01 N 457485.23 E 3232.02 N 3456.77W 5915213.54 N 457463.12 E 3252.45 N 3479.36W 5915234.08 N 457440.63 E 3272.47N 3501.78W 5915254.22 N 457418.32 E 3293.03N 3524.22W 5915274.89 N 457395.99 E 3313.92 N 3546.20W 5915295.90 N 457374.11E 3333.29 N 3566.38W 5915315.37 N 457354.03 E 3355.49 N 3590.26W 5915337.69 N 457330.27 E 3375.57 N 3612.49W 5915357.88 N 457308.15 E 3395.49 N 3634.40W 5915377.92 N 457286.34E 3415.94 N 3656.63W 5915398.48 N 457264.22 E 3436.09 N 3678.86 W 5915418.75 N 457242.09 E 3455.74 N 3701.15 W 5915438.52 N 457219.90 E 3475.62 N 3724.12 W 5915458.52 N 457197.04 E 3495.44 N 3746.89 W 5915478.45 N 457174.37 E 3515.78 N 3770.38 W 5915498.91 N 457150.99 E 3535.49 N 3793.61W 5915518.74 N 457127.86 E 3555.08N 3816.98W 5915538.46 N 457104.59 E 3574.15 N 3839.93W 5915557.64N 457081.74E 3593.24 N 3863.32W 5915576.85 N 457058.44 E 3612.50 N 3886.59W 5915596.23 N 457035.27 E Dogleg Rate (°llOOff) 4.12 4.15 2.99 2.04 1.74 1.34 3.67 1.16 5.02 2.98 1.56 4.58 1.38 5.92 0.77 3.64 2.77 9.36 2.02 3.46 1.78 2.78 1.48 3.41 7.35 Vertical Section 4579.94 4610.87 4641.56 4672.07 4701.87 4732.03 4762.48 4792.52 4822,94 4853.27 4881.24 4913.84 4943.78 4973.38 5003.58 5033.58 5063.27 5093.61 5123.76 5154.79 5185.20 5215.63 5245.40 5275.50 5305.63 Phillips Alaska Kuparuk 2N Comment Continued.,. DrillQuest 2.00.02 20 November, 2000 - 17:05 - 9 - Sperry-Sun Drilling Services , Survey Report for 2N-316 Your Ref: API501032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6836.76 73.630 310.590 3062.23 3215.53 6869.02 73.210 309.980 3071.43 3224.73 6900.59 72.590 310.160 3080.72 3234.02 6931.91 71.940 309.640 3090.26 3243.56 6963.78 72.890 310.140 3099.89 3253.19 6995.50 72.590 310.660 3109.30 3262.60 7024.40 71.580 309.680 3118.19 3271.49 7056.68 73.770 310.530 3127.80 3281.10 7090.20 74.480 311.080 3136.97 3290.27 7121,90 74.920 310.150 3145.33 3298.63 7152.33 75.250 308.680 3153.17 3306.47 7184.46 75.370 307.440 3161.31 3314.61 7216.99 75.820 308.980 3169.41 3322.71 7279.04 75.180 312.230 3184.95 3338.25 7311.18 74.900 312.890 3193.24 3346.54 7342.60 74.150 312.220 3201.63 3354.93 7374.37 74.050 311.440 3210.33 3363.63 7406.08 73.930 311.910 3219.08 3372.38 7437.80 73.450 313.940 3227.99 3381.29 7469.59 72.800 314.300 3237.21 3390.51 7501.02 71.740 313.890 3246.79 3400.09 7532.57 70.860 313.440 3256.90 3410.20 7564.60 70.150 312.950 3267.59 3420.89 7596.28 70.610 313.710 3278.23 3431.53 7627.93 70.140 313.600 3288.86 3442.16 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3632.07N 3909.48W 5915615.92 N 457012.49 E 3652.06N 3933.07W 5915636.03 N 456989.00 E 3671.48N 3956.16W 5915655.57 N 456966.01E 3690.62 N 3979.04W 5915674.82 N 456943.23 E 3710.10 N 4002.35W 5915694.43 N 456920.02E 3729.73 N 4025.42W 5915714.18 N 456897.05 E 3747.47 N 4046.43W 5915732.03 N 456876.13 E 3767.32 N 4070.00W 5915752.00 N 456852.67E 3788.39 N 4094.40W 5915773.19 N 456828.37 E 3808.30 N 4117.61W 5915793.22 N 456805.26 E 3826.97 N 4140.33W 5915812.00 N 456782.64 E 3846.13 N 4164.80W 5915831.29 N 456758.27E 3865.61N 4189.56W 5915850.91N 456733.62 E 3904.70N 4235.16W 5915890.23 N 456688.22 E 3925.71 N 4258.03W 5915911.35 N 456665.46 E 3946.18 N 4280.34W 5915931.94 N 456643.26 E 3966.56 N 4303.10W 5915952.44 N 456620.60 E 3986.83 N 4325.87W 5915972.82 N 456597.93 E 4007.56 N 4348.16W 5915993.67N 456575.75 E 4028.74N 4370.00W 5916014.96 N 456554.02 E 4049.57 N 4391.50W 5916035.90 N 456532.63E 4070.20 N 4413.12W 5916056.65 N 456511.12 E 4090.87 N 4435.13W 5916077.43 N 456489.21E 4111.35 N 4456.84W 5916098.02N 456467.61E 4131.92 N 4478.40W 5916118.71 N 456446.15 E Dogleg Rate (°llOOfl) 0.62 2.23 2.04 2.61 3.33 1.83 4.76 7.24 2.64 3.15 4.79 3.75 4.79 5.17 2.17 3.15 2.38 1.47 6.33 2.31 3.59 3.10 2.64 2.69 1.52 Vertical Section 5335.69 5366.55 5396.66 5426.43 5456.74 5486.98 5514.42 5545.17 5577.37 5607.90 5637.22 5668.15 5699.51 5759.48 5790.52 5820.80 5851.34 5881.80 5912.23 5942.65 5972.59 6002.47 6032.67 6062.51 6092.32 Phillips Alaska Kuparuk 2N Comment Continued... DrillQueet 2.00.02 20 November, 2000 - 17:05 - 10- Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: AP!501032034200 Job No. AKMMO0089, SUrveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (fi) 7659.56 69.550 313.880 3299.76 3453.06 7691.71 71.300 313.770 3310.53 3463.83 7722.72 70.830 313.590 3320.59 3473.89 7754.17 71.950 313.710 3330.63 3483.93 7785.80 71.330 313.820 3340.59 3493.89 7817.32 72.250 314.640 3350.44 3503.74 7848.73 71.320 314.530 3360.26 3513.56 7880.44 71.980 314.080 3370.24 3523.54 7912.33 71.220 314.160 3380.31 3533.61 7943.73 72.960 313.510 3389.96 3543.26 7975.84 72.820 313.430 3399.41 3552.71 8007.02 74.770 313.020 3408.11 3561.41 8038.57 74.760 312.870 3416.40 3569.70 8070.34 76.880 312.610 3424.18 3577.48 8102.21 77.080 312.450 3431.36 3584.66 8133.81 79.520 312.630 3437.77 3591.07 8165.48 78.310 313.150 3443.86 3597.16 8196.82 77.730 312.600 3450.37 3603.67 8228.53 77.220 311.820 3457.24 3610.54 8260.05 76.800 311.770 3464.33 3617.63 8291.45 76.190 311.260 3471.66 3624.96 8323.02 75.660 310.420 3479.34 3632.64 8354.63 75.260 310.100 3487.27 3640.57 8386.41 76.180 310.310 3495.11 3648.41 8418.08 75.980 310.510 3502.73 3656.03 Local Coordinates Global Coordinates Northings Easflngs Northings EastingS (ft) (ft) (ft) (ft) 4152.45 N 4499.86W 5916139.35 N 456424.81 E 4173.43 N 4521.71W 5916160.43 N 456403.06 E 4193.69 N 4542.92W · 5916180.80 N 456381.95 E 4214.26 N 4564.49W 5916201.48 N 456360.49 E 4235.02 N 4586.17W 5916222.36 N 456338.92 E 4255.91 N 4607.62W 5916243.36 N 456317.58 E 4276.85 N 4628.87W 5916264.41 N 456296.43 E 4297.88 N 4650.41W 5916285.54 N 456275.00E 4318.94 N 4672.13W 5916306.72 N 456253.39 E 4339.63N 4693.69W 5916327.52 N 456231.95 E 4360.75 N 4715.96W 5916348.75 N 456209.78 E 4381.25 N 4737.77W 5916369.37 N 456188.07E 4401.99 N 4760.06W 5916390.22 N 456165.90 E 4422.89 N 4782.68W 5916411.24N 456143.38E 4443.88 N 4805.56W 5916432.35 N 456120.61E 4464.80 N 4828.36W 5916453.39 N 456097.92E 4485.95 N 4851.13W 5916474.65 N 456075.26 E 4506.81N 4873.59W 5916495.63 N 456052.90 E 4527.61N 4896.52W 5916516.55 N 456030.08 E 4548.08N 4919.42W 5916537.13 N 456007.29 E 4568.32 N 4942.28W 5916557.49 N 455984.53 E 4588.34N 4965.45W 5916577.63 N 455961.47E 4608.12 N 4988.80W 5916597.53 N 455938.23 E 4628.00N' 5012.32W 5916617.53 N 455914.81E 4647.92 N 5035.72W 5916637,58 N 455891.50 E Dogleg Rate (°/lOOft) 2.04 5.45 1.61 3.58 1.99 3.82 2.98 2.48 2.40 5.88 0.50 6.38 0.46 6.72 0.80 7.74 4.15 2.52 2.89 1.34 2.50 3.08 1.60 2.96 0,88 Vertical Section 6122.01 6152.30 6181.63 6211.44 6241.46 6271.40 6301.23 6331.33 6361.58 6391.46 6422.15 6452.09 6482.53 6513.32 6544.37 6575.30 6606.38 6637.03 6667.97 6698.67 6729.18 6759.76 6790.30 6821.04 6851.73 Phillips Alaska Kuparuk 2N Comment Continued... 20 November, 2000 - 17:05 -11- DrlllQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N.316 Your Reft API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Meesured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8449,56 75.280 309.210 3510.54 3663.84 8481.21 74.710 309.310 3518.74 3672.04 8512.89 73.990 308.500 3527.28 3680.58 8544.34 73.650 308.420 3536.05 3689.35 8576.18 75.130 309.810 3544.62 3697.92 8607.73 75.120 310.200 3552.72 3706.02 8639.38 74.400 310.130 3561.04 3714.34 8671.05 73.740 308.970 3569.73 3723.03 8702.47 73.290 308.980 3578.64 3731.94 8734.07 74.300 309.760 3587.46 3740.76 8765.76 74.280 310.120 3596.04 3749.34 8797.30 73.820 309.600 3604.71 3758.01 8829.08 73.430 308.900 3613.67 3766.97 8860.80 73.270 309.350 3622.76 3776.06 8892.46 73.190 309.480 3631.89 3785.19 8923.87 73.780 310.850 3640.82 3794.12 8955.50 73.370 311.190 3649.77 3803.07 8986.93 73.200 311.300 3658.81 3812.11 9018.38 73.110 311.230 3667.92 3821.22 9050.09 72.860 310.500 3677.20 3830.50 9081.58 73.030 310.540 3686.43 3839.73 9113.52 72.970 310.320 3695.77 3849.07 9144.61 74.040 311.810 3704.60 3857.90 9176.29 74.030 312.190 3713.31 3866.61 9208.23 73.980 312.320 3722.12 3875.42 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (~t) (ft) (~t) 4667.47N 5059.13W 5916657.24 N 455868.20 E 4686.81 N 5082.80W 5916676.71 N 455844.63 E 4705.97 N 5106.54W 5916695.99 N 455820.99 E 4724.76N 5130.19W 5916714.90 N 455797.43 E 4744.10 N 5153.98W 5916734.37N 455773.74 E 4763.71 N 5177.34W 5916754.09 N 455750.49 E 4783.40 N 5200.68W 5916773.91 N 455727.26 E 4802.79 N 5224.16W 5916793.42 N 455703.87 E 4821.74N 5247.58W 5916812.49 N 455680.55 E 4840.99 N 5271.04W 5916831.86 N 455657.19 E 4860.58 N 5294.43W 5916851.56 N 455633.90 E 4880.01N 5317.70W 5916871.12 N 455610.73 E 4899.31N 5341.32W 5916890.53 N 455587.22 E 4918.48 N 5364.89W 5916909.83 N 455563.74E 4937.73N 5388.31W 5916929.20 N 455540.42 E 4957.15 N 5411.32W 5916948.74 N 455517.51 E 4977.06 N 5434.21W 5916968.77 N 455494.72 E 4996.91 N 5456.85W 5916988.73N 455472.19 E 5016.76 N 5479.47W 5917008.70 N 455449.67E 5036.60 N 5502.40W 5917028.66 N 455426.84 E 5056.16 N 5525.29W 5917048.34 N 455404.06 E 5075.97 N 5548.54W 5917068.27 N 455380.91 E 5095.55 N 5571.01W 5917087.97 N 455358.54 E 5115.93 N 5593.65W 5917108.46 N 455336.01E 5136.58 N 5616.37W 5917129.23 N 455313.39 E Dogleg Rate (°/lOOft) 4.58 1.83 3.35 1.11 6.27 1.20 2.28 4.09 1.43 3.98 1.10 2,15 2,44 1.45 0.47 4.58 1.66 0.64 0.36 2.34 0.55 0.68 5.74 1.15 0.42 Vertical Section 6882.15 6912.63 6943.02 6973.10 7003.66 7034.09 7064.57 7094.94 7124.96 7155.22 7185.66 7215.91 7246.31 7276.6O 7306.83 7336.88 7367.18 7397.26 7427.33 7457.61 7487.67 7518.16 7547.94 7578.38 7609.08 Phillips Alaska Kuparuk 2N Comment Continued... DrillQueet 2.00.02 20 November, 2000 - 17:05 - 12 -. Sperry-Sun Drilling Services Survey Report for 2N.316 Your Ref: API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9239.77 72.960 311.360 3731.09 3884.39 9271.33 72.580 311.340 3740.44 3893.74 9303.09 72.470 311.290 3749.97 3903.27 9334.58 71.880 310.270 3759.61 3912.91 9366.03 73.020 311.260 3769.10 3922.40 9397.81 72.720 310.710 3778.46 3931.76 9428.41 72.050 310,960 3787,72 3941.02 9460.18 71.400 310.780 3797.68 3950.98 9491.70 72.100 310.190 3807.55 3960.85 9523.61 71.780 310.020 3817.44 3970.74 9555.18 71.270 309,700 3827.45 3980.75 9586.36 71.760 311.090 3837.33 3990.63 9617.77 70.830 310.430 3847.41 4000.71 9649.55 71.300 312.110 3857.72 4011.02 9681.27 71.080 312.100 3867.95 4021.25 9712.97 72.600 313.040 3877.83 4031.13 9745.61 72,390 313.620 3887.65 4040.95 9776.02 73.130 314.160 3896.66 4049.96 9807.54 73,010 314.160 3905.84 4059.14 9839.04 72.500 313.770 3915.18 4068.48 9870.33 72.370 313,160 3924.62 4077.92 9901.55 75.020 312.550 3933.38 4086.68 9933.29 75,470 313.110 3941.47 4094.77 9965.49 74.760 312.830 3949.74 4103.04 9996.50 74,120 312,260 3958.06 4111.36 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5156.75 N 5638.90W 5917149.51 N 455290.97 E 5176.66 N 5661.53W 5917169.54 N 455268.44 E 5196.66 N 5684.28W 5917189.66 N 455245.79 E 5216.24 N 5706.98W 5917209.36 N 455223.19 E 5235.82 N 5729.69W 5917229.05 N 455200.58 E 5255.74 N 5752.62W 5917249.09 N 455177.76 E 5274.81 N 5774.68W 5917268.27 N 455155.79 E 5294.55 N 5797.50W 5917288.13 N 455133.08 E 5313.99 N 5820.26W 5917307.68 N 455110.42 E 5333.53 N 5843.47W 5917327.35 N 455087.31 E 5352.72 N 5866.45W 5917346.66 N 455064.43 E 5371.88 N 5888.97W 5917365.94 N 455042.01E 5391.31N 5911.51W 5917385.48 N 455019.58 E 5411.14 N 5934.10W 5917405.42 N 454997.09 E 5431.27N 5956.37W 5917425.67N 454974.91 E 5451.64N 5978.56W 5917446.16 N 454952.84 E 5473.01 N 6001.20W 5917467.64 N 454930.31 E 5493.14 N 6022.13W 5917487.88 N 454909.48 E 5514.15 N 6043.76W 5917509.00 N 454887.96 E 5535.03N 6065.41W 5917529.99 N 454866.41E 5555.55 N 6087.07W 5917550.63 N 454844.87 E 5575.93 N 6109.03W 5917571.12 N 454823.01E 5596,80 N 6131.54W 5917592.10 N 454800.61E 5618.01N 6154.31W 5917613.43 N 454777.95 E 5638.21N 6176.32W 5917633,74 N 454756.04E Dogleg Rate (°ll00fl) 4.36 1.21 0,38 3.61 4.71 1.90 2.32 2,12 2.84 1.12 1,88 4.51 3.57 5.21 0.69 5.56 1.81 2.97 0.38 2.00 1.90 8.69 2.22 2,36 2.72 Vertical Section 7639.30 7669.41 7699.68 7729.62 7759.56 7789.90 7819.o2 7849.15 7879.04 7909.32 7939.19 7968.71 7998.42 8028.45 8058.46 8088.58 8119.7o 8148.75 8178.90 8208.98 8238,81 8268.77 8299.46 8330.58 8360.44 Phillips Alaska Kuparuk 2N Comment Continued... 20 November, 2000 - 17:05 - 13 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N.316 Your Ref: API501032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) 10028.35 10060.08 10O91.52 10122.92 10154.18 Incl. 73.75o 74.370 74.1o0 72.900 75.380 10185.65 10217.40 10249.27 10281.05 10312.50 76.160 75.500 74.860 74.550 74.030 10344.07 1o375.82 104o7.31 10438.95 10470.67 75.600 75.890 75.450 75.130 74.770 74.250 73.360 73.200 72.570 72.740 10502.25 10534.95 10566.05 10597.76 10629.27 Azim. 312.41o 312.97o 313.610 312.28o 312.38o 313.45o 312.930 312.43o 312.890 311.790 312.70o 313.080 312.370 311.86o 31o.91o 311.140 310.260 310.500 310.250 310.140 Sub-Sea Depth (fi) 3966.87 3975.58 3984.13 3993.04 4001.59 4OO9.32 4017.10 4025.25 4033.63 4042.15 4050.42 4058.23 4066.03 4074.06 4082.30 4090.73 4099.85 4108.80 4118.13 4127.53 Vertical Local Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 412o.17 4128.88 4137.43 4146.34 4154.89 4162.62 417o.40 4178.55 4186.93 4195.45 4203.72 4211.53 4219.33 4227.36 4235.60 4244.03 4253.15 4262.1o 4271.43 4280,83 10660.87 72.51o 310.64o 4136.96 4290.26 10692.05 71.95o 309.850 4146.48 4299.78 10723.70 73.550 31o.o2o 4155.86 43o9.16 10755.37 73.940 310.59o 4164.73 4318.03 10787.03 75.940 31o.61o 4172.95 4326.25 Global Coordinates 5658.82 N 6198.94W 5917654.47 N 5679.51N 6221.37W 5917675.27 N 5700.25 N 6243.39W 5917696,13 N 5720.77N 6265.43W 5917716.76 N 5741.01N 6287.66W 5917737.12 N 5761.78 N 6310.00W 5917758.01 N 5782.85 N 6332.44W 5917779.19 N 5803.74 N 6355.09W 5917800.19 N 5824.51 N 6377.63W 5917821.08 N 5844.90 N 6400.01W 5917841.59 N 5865.39 N 6422.56W 5917862.19 N 5886.33N 6445.11W 5917883.25 N 5907.03 N 6467.52W 5917904.06 N 5927.55 N 6490.22W 5917924,70 N 5947.80 N 6513.21W 5917945.07N 5967.78 N 6536.17W 5917965.17 N 5988.26 N 6559.97W 5917985.77 N 6007.55 N 6582.66W 5918005.18 N 6027.19 N 6605.75W 5918024.93 N 6046.60 N 6628.72W 5918044.46 N 6066.14 N 6651.69W 5918064.12 N 6085.32'N 6674.36W 5918083.42 N 6104.72 N 6697.53W 5918102.94 N 6124.39 N 6720.72W 5918122.73 N 6144.29 N 6743.93W 5918142,74 N Eastings (ft) 454733.52 E 454711.20 E 454689.29 E 454667.36 E 454645.23 E 454623.OO E 454600.67 E 454578.13 E 454555.69 E 454533.42 E 454510.97E 454488.54 E 454466.23 E 454443.63E 45442O,76 E 454397.90 E 454374.20 E 454351.61E 454328,63E 454305.75 E 454282.88 E 454260.32E 454237.24 E 454214.16 E 454191.05 E Dogleg Rate (°/lOOft) 1.25 2.59 2,14 5.58 7.94 4.12 2.62 2.52 1.70 3.75 5.70 1.48 2.59 1.86 3.11 1.79 3.75 0.90 2.12 0.63 1.68 3.01 5.08 2.12 6.32 Vertical Section 8391.04 8421.55 8451.80 8481.90 8511.96 8542.46 8573.25 8604.05 8634.70 8664.96 8695.42 8726.19 8756.69 8787.28 8817.89 8848.29 8879.65 8909.38 8939.63 8969.65 8999.76 9029.39 9059.55 9089.90 9120.43 Phillips Alaska Kuparuk 2N Comment Continued... DrlllQuest 2.00.02 20 November, 2000 - 17:05 - 14 - Sperry-Sun Drilling Services Survey Report for 2N.316 Your Ref: API501032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 10818.72 75.600 310.900 4180.74 10850.37 75.150 310.700 4188.74 10882.15 74.720 310.700 4197.00 10913.84 74.150 310.320 4205.50 10945.41 73.480 309.530 4214.30 10976.96 74.130 310.240 4223.10 11008.76 73.950 310.460 4231.84 11040.52 73.280 309.780 4240.80 11071.72 72.880 309.770 4249.88 11103.12 73.560 309.820 4258.95 11134.61 73.530 309.520 4267.87 11166.29 72.960 309.090 4277.00 11198.37 73.730 308.930 4286.19 11230.04 73.740 309.040 4295.06 11261.99 73.040 309.120 4304.20 11293.79 73.050 309.700 4313.47 11324.86 73.010 310.100 4322.54 11355.54 72.510 309.720 4331.63 11387.27 72.450 310.450 4341.18 11419.43 72.220 310.440 4350.94 11451.33 71.620 310.340 4360.84 11483.07 71.200 310.100 4370.96 11515.21 70.810 310.900 4381.42 11547.39 71.150 311.270 4391.91 11579.46 70.850 311.190 4402.35 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4334.04 6164.34N 6767.20W 5918162.92 N 454167.89 E 4342.04 6184.35 N 6790.38W 5918183,05 N 454144.81 E 4350.30 6204.36 N 6813.65W 5918203.18 N 454121.65 E 4358.80 6224.19 N 6836.86W 5918223.13 N 454098.54 E 4367.60 6243.65 N 6860.11W 5918242.71 N 454075.39 E 4376.40 6263.08 N 6883.36W 5918262.25 N 454052.24 E 4385.14 ~ 6282.87 N 6906.66W 5918282.17 N 454029.04E 4394.10 6302.51 N 6929.96W 5918301.92 N 454005.85 E 4403.18 6321.60 N 6952.90W 5918321.14 N 453983.00 E 4412.25 6340.85 N 6976.00W 5918340.50 N 453960.00 E 4421.17 6360.13 N 6999.24W 5918359.90 N 453936.86 E 4430.30 6379.34N 7022.71W 5918379.24 N 453913.49 E 4439.49 6398.69 N 7046.60W 5918398.70 N 453889.70 E 4448.36 6417.81N 7070.23W 5918417.95 N 453866.17 E 4457.50 6437.11 N 7093,99W 5918437.38 N 453842.50 E 4466.77 6456.42 N 7117.50W 5918456.81N 453819.10 E 4475.84 6475.49 N 7140.29W 5918475,99 N 453796,40 E 4484.93 6494.29 N 7162.77W 5918494.90 N 453774.03E 4494.48 6513.77N 7185,92W 5918514.51N 453750.98 E 4504.24 6533.65 N 7209.24W 5918534.51N 453727.76 E 4514.14 6553.30 N 7232.34W 5918554.28 N 453704.76 E 4524.26 6572.73N 7255.31W 5918573.82 N 453681.89 E 4534.72 6592.46 N 7278.42W 5918593.67N 453658.89 E 4545.21 6612.45 N 7301.35W 5918613.79 N 453636.06 E 4555.65 6632.44 N 7324.15W 5918633.89 N 453613.36 E Dogleg Rate (°/lOOft) 1.39 1.55 1.35 2.14 3.21 2.99 0.87 2.94 1.28 2.17 0.92 2.22 2.45 0.33 2.20 1.74 1.24 2.01 2.20 0.72 1.90 1.50 2.65 1.52 0.96 Vertical Section 9151.10 9181.69 9212.33 9242.81 9273.06 9303.29 9333.81 9364.22 9393.99 9423.99 9454.11 9484.35 9514.98 9545,28 9575.79 9606,12 9635.77 9665.01 9695.21 9725.80 9756.07 9786.10 9816.44 9846.83 9877.12 Phillips Alaska Kuparuk 2N Comment Continued,.. DrillQueet 2.00.02 20 November, 2000 - 17:05 - 15 ' Sperry-Sun Drilling Services Survey Report for 2N.316 Your Ref: API501032034200 Job No, AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (fi) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (ft) 11611.56 71.020 311.770 4412.84 4566.14 11643.46 70.440 312,690 4423.36 4576.66 11675.40 70.690 313,560 4433.99 4587.29 11707.33 70.330 312,760 4444.65 4597.95 11739.34 71.540 313.000 4455.10 4608.40 11771.34 72,470 313,670 4464.99 4618.29 11803.40 72,950 313.450 4474.52 4627.82 11835.29 73,270 313.640 4483.78 4637.08 11868.09 74.060 312.970 4493.01 4646.31 11899.94 74.070 314.030 4501.75 4655.05 11931.93 73.490 313.060 4510.69 4663.99 11964.07 74.960 312.490 4519.42 4672.72 11995.80 75,100 312.300 4527.62 4680.92 12027.97 75.970 312.450 4535.66 4688.96 12059.84 75.510 312.660 4543.51 4696.81 12092.06 75.040 312.080 4551.70 4705.00 12123.92 74.550 311.780 4560.05 4713.35 12155.63 75.730 311.520 4568.18 4721.48 12187.68 75.560 311.220 4576.13 4729.43 12219.67 75.090 310.990 4584.23 4737.53 12251.85 74.680 310.780 4592.63 4745.93 12283.88 75.090 311.740 4600.98 4754.28 12316.08 74.160 311.530 4609.51 4762.81 12348.00 73.460 310.840 4618.41 4771.71 12380.17 73.010 310.660 4627.69 4780.99 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6652.54 N 7346.88W 5918654.10 N 453590.73 E 6672.77N 7369.18W 5918674.45 N 453568.54 E 6693.36 N 7391.16W 5918695.16 N 453546.67E 6713.95 N 7413.12W 5918715.86 N 453524.82 E 6734.54 N 7435.29W 5918736.56 N 453502.75 E 6755.43 N 7457.42W 5918757.56 N 453480.73 E 6776.52 N 7479.61W 5918778.77N 453458.65 E 6797.54 N 7501.72W 5918799.91 N 453436.64 E 6819.13 N 7524.63W 5918821.61N 453413.85 E 6840.21N 7546.84W 5918842.81N 453391.74 E 6861.37 N 7569,11W 5918864.09 N 453369.59 E 6882.38 N 7591.81W 5918885,21 N 453347.00 E 6903.04 N 7614.45W 5918905.99 N 453324.46 E 6924.04 N 7637,46W 5918927.10 N 453301.56 E 6944.93 N 7660.21W 5918948.11N 453278.92 E 6965.93 N 7683.24W 5918969,23 N 453256.00E 6986.47N 7706.11W 5918989.89 N 453233.24 E 7006.84 N 7729.01W 5919010.38 N 453210.44 E 7027.36 N 7752.31W 5919031.02 N 453187.25 E 7047.71N 7775.63W 5919051.48 N 453164.03 E 7068.04 N 7799.12W 5919071.94 N 453140.65 E 7088.44N 7822.36W 5919092.45 N 453117.51 E 7109.06 N 7845.57W 5919113.20 N 453094.42 E 7129.25 N 7868.63W 5919133.50 N 453071.45 E 7149.35 N 7891.97W 5919153.73N 453048.22 E Dogleg Rate (°/100ft) 1.79 3.27 2.69 2.62 3.85 3.52 1.63 1.15 3.11 3.20 3.43 4.88 0.73 2.74 1.58 2.27 1.79 3.80 1.05 1.63 1.42 3.16 2.96 3.02 1,50 Vertical Section 9907.44 9937.54 9967.66 9997.76 10028.01 1o058.44 10089.05 10119.56 10151.04 10181.66 10212.38 10243.30 10273.95 10305.09 10335.97 10367.12 10397.85 10428.48 10459.50 10490.42 10521.44 10552.34 10583.36 10613.99 10644,75 Phillips Alaska Kuparuk 2N Comment Continued... 20 November, 2000- 17:05 - 16- DrillQueet 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (ft) 12418.26 73.490 310.450 4638.67 4791.97 12450.32 72.740 310.180 4647.98 4801.28 12482.37 72.780 309.810 4657.48 4810.78 12514.45 72.450 309.440 4667.07 4820.37 12546.25 72.040 308.450 4676.77 4830.07 12578.38 72.180 310.280 4686.64 4839.94 12604.47 71.380 310.150 4694.79 4848.09 12633.91 70.970 309.730 4704.29 4857.59 12666.00 70.710 309.020 4714.83 4868.13 12698.42 72.100 308.170 4725.16 4878.46 12736.37 71.930 308.320 4736.88 4890.18 12768.82 71.840 307.480 4746.97 4900.27 12800.71 73.170 307.960 4756.56 4909.86 12826.26 72.540 308.390 4764.09 4917.39 12858.32 72.050 307.680 4773.84 4927.14 12890.16 71.530 307.140 4783.79 4937.09 12922.25 71.530 308.490 4793.96 4947.26 12986.66 72.330 311.660 4813.94 4967.24 13050.28 73.990 314.110 4832.37 4985.67 13114.25 75.950 315.520 4848.96 5002.26 13178.52 76.410 315.640 4864.31 5017.61 13248.72 76.800 315.600 4880.58 5033.88 13313.04 74.740 314.820 4896.39 5049.69 13377.57 75.060 314.950 4913.20 5066.50 13441.71 75.760 314.590 4929.35 5082.65 Local CoordinateS' Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (~) 7173.07N 7919.68W 5919177.59 N 453020.63 E 7192.92 N 7943.07W 5919197.56 N 452997.34E 7212.59 N 7966.52W 5919217.35 N 452973.99 E 7232.12 N 7990.10W 5919237.00 N 452950.51E 7251.15 N 8013.66W 5919256.15 N 452927.06 E 7270.54 N 8037.30W 5919275.67 N 452903.52 E 7286.55 N 8056.22W 5919291.77 N 452884.68 E 7304.43 N 8077.58W 5919309.77 N 452863.41 E 7323.66 N 8101.02W 5919329.12 N 452840.08 E 7342.83 N 8125.03W 5919348.41 N 452816.16 E 7365.17 N 8153.38W 7384.12 N 8177.72W 7402.73 N 8201.77W 7417.82N 8220.97W 7436.64 N 8245.02W 7455.01N 8269.05W 7473.67N 8293.09W 7513.09 N 8339.94W 7554.53 N 8384.54W 7598.07 N 8428.36W 7642.65 N 8472.05W 7691.45N 8519.81W 7735.70 N 8563.73W 7779.66 N 8607.87W 7823.38 N 8651.94W 5919370.90 N 452787.93 E 5919389.97 N 452763.69 E 5919408.70 N 452739,73 E 5919423.89 N 452720.61E 5919442.83 N 452696.66 E 5919461.33 N 452672.73 E 5919480.11 N 452648.78 E 5919519.77 N 452602.14 E 5919561.44 N 452557.75 E 5919605.21N 452514.15 E 5919650.01N 452470.70E 5919699.07N 452423.19 E 5919743.54 N 452379.50 E 5919787.73 N 452335.59 E 5919831.67N 452291.74 E Dogleg Rate (°/lOOft) 1.37 2.47 1.11 1.51 3.23 5.44 3.10 · 1.94 2.24 4.96 0.58 2.48 4.41 2.94 2.61 2.29 3.99 4.84 4.52 3.73 0.74 0.56 3.41 0.53 1.22 Vertical Section 10681.16 10711.79 10742.33 10772.87 1O803.O4 10833.53 10858.26 10886.07 10916.29 10946.89 10982.82 11013.50 11043.75 11068.O5 11098.44 11128.5o 11158.77 11219.87 11280.75 11342.51 11404.89 11473.14 11535.47 11597.75 11659.82 Phillips Alaska Kuparuk 2N Comment Continued... DrillQuest 2.00.02 20 November, 2000- 17:05 - 17- Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (it) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13536.69 75.110 314.080 4953.24 5106.54 7887.62 N 8717.69W 5919896.25 N 452226.33 E 13623,46 76.080 313.770 4974.82 5128.12 7945.92 N 8778.22W 5919954.87 N 452166.10 E 13692.00 76.080 313.770 4991.31 5144.61 7991.94 N 8826.26W 5920001.13 N 452118.29 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 313.750° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13692.00ft., The Bottom Hole Displacement is 11906.89ft., in the Direction of 312.160° (True). Dogleg Rate (°/100ft) 0.86 1.17 o,o0 Vertical Section 11751.74 11835.78 119o2.31 Phillips Alaska Kuparuk 2N Comment Projected Survey Comments Measured Depth (ft) 13692.00 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 5144.61 7991.94 N 8826.26 W Projected Survey Continued... DrlllQuest2.00.02 20 November, 2000 - 17:05 - 18- Sperry-Sun Drilling Services Survey Report for 2N-316 Your Ref: API501032034200 Job No. AKMMO0089, Surveyed: 28 July, 2000 Kuparuk River Unit Phillips Alaska Kuparuk 2N Survey tool program From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (fi) 0.00 0.00 1983.20 1753.04 1983.20 1753.04 13692.00 5144.61 Survey Tool Description MWD Magnetic AK-6 BP_IFR-AK DrillQuest 2.00.02 20 November, 2000 - 17:05 - 19 - .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development __X Exploratory _ Stratigraphic __ Service _ 4. Location of well at surface 44' FNL, 690' FEL, Sec. 3, T9N, R7E, UM (ASP: 460903, 5911964) At top of productive interval 2467' FNL, 1965' FWL, Sec. 28, T10N, R7E, UM (per APD) At effective depth At total depth 2364' FNL, 1293' FWL, Sec. 28, T10N, R7E, UM (ASP: 452355, 5920253) 6. Datum elevation (DF or KB feet) RKB 35 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-316 9. Permit number / approval number 200-090 10. APl number 50-103-20342-00 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 13692 feet Plugs (measured) true vertical 5145 feet Effective depth: measured 13558 feet Junk (measured) true vertical 5112' feet Casing Length Size Cemented Conductor 83' 16" 9 cu. Yds High Early Surface 3463' 7.625" 350 sx AS III Lite, 250 sx Class G Intermediate 12708' 5.5" X 260 sx Class G & 540 sx Class G Production 943' 3.5" (included above) Measured Depth True vertical Depth 118' 118' 3498' 2303' 12743' 4892' 13686' 5143' Perforation depth: measured no perforations true vertical N/A ORIGINAL RECEIVED Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3.5", 9.3#, L-80 @ 12760' No SSSV, Baker Seal Receptacle @ 12743' SEP 1 4 2000 Alaska ~ & Gas Cons. Commission 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch LOT test, surface cement details and casing detail sheets __X 15. Status of well classification as: 14. Estimated date for commencing operation September 15, 2000 16. If proposal was verbally approved Name of approver Date approved Oil ___X Gas ~ Suspended __ Se~ice~ 17. I hereby j:ertify that ~ng is true and correct to the best of my knowledge. Signed '~J(~~t''~-~~ """"=- t~~'~'A'~'~- Title: Drilling Engineering Supervisor James Trantham FOR COMMISSION USE ONLY Questions? Call Tom Brassfield 265-6377 Prepared by Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrily Test _ Subsequent form required 10- ~ ~? ORIGINAL SIGNED ~"~ _A_ppr?~ed by order of the Commission D Taylor Seamount Commissioner I Appr°val n°~l~ O0 .,~~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLI CATE CASING TEST and FORMATION INTEGRITY TEST · Well Name: 2N-316 Date: 7/13/00 Reason(s) for test: Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-5/8", 29.7#, L-80 BTC-MOD Casing Setting Depth: 3,498' TMD Hole Depth: 2,305' TVD Mud Weight: 9.5 ppg Length of Open Hole Section: 3,530' TMD 2,314' TVD 32' EMW = Leak-off Press. + Mud Weight = 750 psi 0.052 x TVD o.o52 x 2,314' EMW for open hole section = 15.7 ppg + 9.5 ppg Pump output = 0.1000 bps Fluid Pumped = 3.8 bbl 2,200 psi 2,1120 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi t,500 psi- 1,400 psi' 1,300 psi 1,200 psi 1,100 psi 1,00(3 psi 900 psi 800 psi 7[]0 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi --e-- LEAK-OFF TEST --a--CASING TEST ...... ~"-' LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME ; TIME LINE STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE , ................ .-. ................ .r ................. ,~ , ................. ~- ............... ~ ................. 0 stks , 0 psi ... 0 stks 0 psi 4 stks 200 psi 2 stks 150 ~si i ................ J ................ ,[ ................. J i ................. I. ............... ,a .......... % ...... ................... LS..s..tk_.s_ ...... .4_ .e_ .O_. .p.s_ ! .... ..................... .2..O..s._tk_.s. ...... ~.0_..p.s_j .... ..................... _2. .4_ .s. _t.k. ?. ....... .4_ .4_ .O_. _p.s_ ! .... ..................... _2..8_.s__tk_.s- ...... .4..4..O...p.s.! .... .................... .3..2..sj.k..s. ...... .4_ .4. .O_. .p.s_ j .... .................... .3..6..s..tk_.s_ ...... .4_.4_.O_._p.s.j .... .................... _3..8_.s__tk_.s' ...... .4..3..O.._p.s_! .... i ................ J ................ .[ ................. J i I ................ ,J ................ .~ ................. .i ! ! _.S._".U_.T_I~ ~[ .,' ............... _S__._U2_~~ .... .o_:.o_..m.l.n...j ................ l_____4_s_fi.p~! .... · ! ~ 1.0m~n i ~ 400ps~ '--E~--/~ih--- ~ ................. F--'~/-~-~i .... ................ '1 ................ ? ~.o m!~___i ............... i....a._o__o._.~! .... '-'V~'7~ih"-~ ................ i-"~i/~"~'~i-- .... ~-.o_..m_L~_] ................ i____a_~.o...p~! .... 7.0rain i .i 380 psi ....°.-9...m.!?...j ................ i._..a.~.°...~.L. 9.0 rain ' ~ 380 4 stks 260 psi i ................. r"-iF~¥[~ ....... '~iiF[,'~i'" ~ .................... ~.?.t.k~. ...... _.~_°_.°_.~..?.L.j ................... ~fi.?.tk.?. ..... .!,_t.o.o..p..s. Lj 12 stks ~ 1,350 p~ ..................... .l_.4...s.t._k.s._. j...1.,.S..2.0., p_.,.. _ _. .................... .! fi .?.t .k?. ..... .!,?_.7.s...p..s.t.i ~.Z_.s!~.s. ..... ~,.o__o_o_.p..s.t.i i i .................................. i ................. i ! ................................. ~ ................. i ................................. ................. ................................. ,~ ................. I I I I SHUT IN TIME I SHUT IN PRESSURE f ................................. I ' I ' ~ 0.0 m~n t 2,000ps~ j i ................. r ............... ' ................. i 1.0min ! ~ 2,000p_s~ ,,. .......... ... .... ,,. ........................... .,__ ~ 2.0mm n 2,000[ i- ................ it- ............... . L__.~:.o...m..~.n....,,. .................. ~,.o..o.o..p_.s_t.. L___~_..o._.m.2n.._.[ ............... j__.2_,.o..o.o..p__s_[_, .....s...o___m__Ln. .................... i...2.,_o..o.o._p..s.L 6.0 min ,- i 2,000 p_si ..__.8...o...m.).n. ................... j...2.,.o..o.o..p__s_L .... 9.:.o...m.j.n_ .................... t ..2..,.o.9.o.. p__s_L' 10.0 min ] 2,000 psi 15.0 min 2,000 psi 200min ~ I 2,000osi ...... .: .......... I. ............... -I ........... ~- ..... ....~..~:.o_..m.j.n_..[ ............... !...2.,.0..0.0.._p_.s.L NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-316 Date: 8/6/00 Reason(s) for test: Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-5/8",29.7#,L-80 BTC-MOD Casing Setting Depth: 3498' TMD 2305' TVD Mud Weight: 9.5 ppg Length of Open Hole Section: EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 700 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE Hole Depth: 10,675' TMD ! 20stks 300 psi ~ ~ ................ .J ................................. 4,295' TVD ! 30 stks 325 psi #VALUE! ~li.~ . 50stks . 425psi : ........... 0.052 x 4,295' EMW for open hole section = 12.6 ppg Pump output = 0.0580 bps Fluid Pumped = 10.4 bbl 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi I I I ~ LEAK-OFF TEST j ...... g~,,-...-,- LOT SHUT IN TIME -~ CASING TEST SHUT IN TIME : - TIME LINE 80 stks 525 psi .................... _9__o__s_ !_k._s. ...... .S..S_.S__p.s_i ................... _t _O_ _O_ _s_ !_k_ _s_ ..... .6..O..O.._p.s_] ................... .U_ _O_ _s_ !_k_ _s_ ..... .s_.2_.s_..Rs.] .... 120 stks 650 psi .................... .!_3_.O_.s.!.k..s_ ..... Z.o_.o_._P.S_] .... .................... _l__4__O__s_!.k..s..~ 700 psi ................... ! .S_.O_ .s_ !.k_ .s_ ..... .6_7_.5_..p. sj .... ................... !.6_.O__s_!.k_.s_ ..... .6_ Z .S_. .P.S. j .... ................... !.7._O..s_!.k_.s. ...... .6_ Z .S_ . .P.s. .i .... ................... .! .8. 9. .s. !.k_ .s_ ...... .6_7_.s.._p. sj .... a, ................. LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE , ................ -. ................ ~ ................. .~ ,. ................ ~. ............... .~ ................. j ..................... _o__sj~_s_ ........ .o..p..s! ......................... .o...s.t..k.s._ ........ .O_._p..s.[ ..... 2 stks 150 psi ................ i. ............... a ................. .J , i · I 4stks , 260ps~ , ............ J : 6stks 540 os~ ..................... .,.._s!._~.s.. ...... ..~_o__o...p..s!_.j .................... !o.._s!3.s. ..... !,L0.0..R.s.U 12 stks 1,350 psi_! 16 stks J 1,975 psi ; ................. r ............... '1 ................. , i ' , , 17stks , 2,000 psi , ................. ' ............... -I ................. -I , 1 i , , ................. i. ............... .i ................. . ................. I I I SHUT IN TIME SHUT IN PRESSURE ........... '.' .... r ................................. 00m~n , 2,000Bsi , .... L'.' .......... ~ ........................... ~ .... 1.0 min 2,000 psi ! , , ~ .... ~:~b'~-i~ ...................... i~;ii6~'~· ..S..H.U._T. LN.~.M_E- ................ .S..H.U..T. LN..P..~.E..S_S_U..R~E 3.0 min 2,000 p. ~ .... .o.:_o._.m._Ln_ ....................... .?ZLm .... L_._l_:_o___m_i.n_ ........................ .5..o..o.._p_s_j ..... 5.0 min 2,000 psi j : .... 2.0 mln : 500 DSl 3.0 min 500 psi .................................................... L_.4_:.o_..mj.n_ ........................ _s..o..o._.p.s.] .... 5.0 min 475 psi ..................................................... 6.0 min 450 psi ................ ~ ................ ~1 ................. a ___z:g_..m_lp_._: ................ :___4__s_o__.p_s.i .... ___.8_:9_..mj_n__j ................ .:___~_s_9___p_s_J .... 9.o min ' ~ 450 psi 7.0 min 2,000 .____~:_o_._m_!n. ...................... .2.:9.9.°.. .___?:.o...m..i.n. ...................... &9.9.o..p..s.U .... _t°_:_°_._m..i.n. .................. j..~,.°..°.°...p_?_Lj 15.0 min i 2,000 Dsi i , . __2_o_:_o___m_i_n. .................. j _ _ .2_, 9. 9_ .O_p_s_i_ _ ....2..5:.O...m_j_n_ .................. j._.2_:9..0.0.. ° ~ ~ ~ ~ ~ a ~ ~ ~ ~ ~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska Drilling Cementing Details Well Name: 2N-316 Report Date: 07/12/2000 Report Number: 7 Rig Name: Nabors 19E AFC No.: AK0068 Field: TARN · Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: I % washout: 7-5/8' 9-7/8 74 3498I 3413 I Centralizers State type used, intervals covered and spacing Comments: 35 BOW SPRING, JTS 1-12 & EVERY 3 J'rS TO SURFACE Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.2 25 17 40 11 Gels before: Gels after: Total Volume Circulated: 11/29 4/9 3+ Wash 0 Type: Volume: Weight: Comments: · ARCO B47 20 8.34 i ' Spacer 0 Type: Volume: Weight: comments: .:: : ARCO B45 40 10.2 : · : i : ~ : . i Leadcernent :0 ~.. Type:I Mix wtr temp: No. of Sacks: Weight: Yield: ;ommentS:: . i. AS III Lite 75 350 10.7 4.44 : i · i ':i .. : i :i: Additives: .:i i . ~ ..... . ~. G + 50% D124, 9.0%D44, .4% D46, 30% D$3,1.$% SI, 1.5% D79 Taii Cementl i 0 ::.: : Type: Mix wtr temp: No. of Sacks: Weight: Yield: CommentS:' i : 75 250 15.8 1.17 :;)i ~i... :: ': ...: .. · : Additives: i:' :~:::: i.' i::~': :i : G+1%S1,0.2%D46,.3%D65, DiSPl~Cenient :' 0 ~ ii ~:: ::' i.i ': ii ': :! Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: ~o~m~htS: :; ..:: i:~ i .. i:.: :: .i .': 5.4 5 75 DiSP~¢ ED::W/MUD W/RIG:: :~:D!B~::~HAR~Ei:~i~$: Reciprocation length: Reciprocation speed: Str. Wt. Down: ON!ONE:PUMP::.i~IIBBL/S~K:' :30 I STK/MIN 40 95%iEFFi¢!ENCY; :.~ ~:.: ~ i i: i i ~ Theoretical Displacement: Actual Displacement: Str. Wt. in mud: Calculated top of cement: CP: Bumped plug: Floats held: CMT TO SURFACE Date:7/12/00 YES YES Time:0430 Remarks:BROACHED OUTSIDE SUB WHILE DRILLING, BROACHING STOPPED BUT STARTED UP $0 BBL INTO MIXING LEAD, HOOKED VACUMN TRUCKS TO BOTH SIDES OF CONDUCTOR (4" NIPPLES) BROACHING STOPPED USING VACUMN TRUCKS TO RELIEVE AND ASSIST CIRCULATION. UTILIZED EMERGENCY SLIPS. 2+ BBL GOOD CEMENTTO SURFACE. , Cement Company: Rig Contractor: Approved By: Dowell NABORS R.W. SPR NGER PHILLIPS Alaska, Inc. DRAFT #1 Casing Detail 7-5/8" surface casino WELL: 2N-316 DATE: 7/11/00 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors19E RTto GL=34.50' TOPS Above RKB 4.54 7 5/8" Landing Joint (38.97 total) 1.62' CUT OFF JT #83 34.50 4.54 FMC EMERGENCY SLIPS 39.04 jts.60-83 7 5/8", 29.7#, L-80 BTC-MOD 993.55 39.04 Tam Port Collar 2.44 1032.59 jts 3-59 7 5/8", 29.7#, L-80 BTC-MOD 2377.03 1035.03 Gemeco Float Collar 1.39 3412.06 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 82.93 3413.45 Gemeco Float Shoe 1.49 3496.38 BTM OF SHOE @ ..... >>>>> 3497.87 TD of 9 7/8" hole = 3510'MD 35 TOTAL, Gemeco Bow Spring Centralizers 3, Centralizers in center of jts. 2, 59 and 60 over stop collars 92 ,Centralizers over collars of jts. 1, 3-12, 15, 18, 21,24, 27, 30, 33 36, 39, 42, 45, 48, 51,54, 57, 63, 66, 72, 75,81 Remarks: String Weights with Blocks: 75 k Up, 40 k Dn, 28k Blocks. Ran 83 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Ten joints surplus, including one used as landing jt w/cut-off stub attached. PHILLIPS ALASKA INC CASl NG TALLY PAGE: 1 of 2 WELL: 2N-316 Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 7/11/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 41.68 26 40.60 51 42.42 76 42.63 101 126 151 176 2 41,25 27 42.60 52 39.16 77 42.61 102 127 152 177 3 41.34 28 42.61 53 41,66 78 42.57 103 128 153 178 4 41.10 29 42.38 54 40.30 79 42.62 104 129 154 179 5 42,60 30 42,64 55 42.59 80 42.57 105 130 155 180 6 40.49 31 42.62 56 42,60 81 40.32 106 131 156 181 7 42.67 32 41,24 57 42,62 82 42.36 107 132 157 182 8 41,41 33 42,63 58 42.63 83 40.75 108 133 158 183 9 42,23 34 42,47 59 42.30 84 42,22 109 134 159 184 10 41.04 35 40.61 60 39.32 85 42,58 110 135 160 185 11 40.31 36 42,58 61 40,65 86 42,66 111 136 161 186 12 42,60 37 42,09 62 42,58 87 112 137 162 187 13 39,54 38 40,41 63 37,87 88 113 138 163 188 14 42,64 39 42.31 64 41,36 89 114 139 164 189 15 40.50 40 42,58 65 42,65 90 115 140 165 190 16 39.93 41 42.59 66 42,24 91 116 141! 166 191 17 42.41 42 42.60 67 42.60 92 117 142 167 192 18 42.51 43 40,21 68 37.01 93 118 143 168 193 19 39.68 44 39,19 69 39.05 94 119 144 1691 194 20 42,58 45 41.27 70 42,56 95 120 145 1701 195 21 42,63 46 40,76 71 42.56 96 121 146 171 196 22 42,50 47 41.67 72 40,98 97 122 147 172 197 23 41,39 48 40,50 73 42.57 98 123 148 173 198 24 42,58 49 42.58 74 40.77 99 124 149 174 199 25 42,29 50 42,04 75 42.35 100 125 1501 175 200 Tot 1039.90 Tot 1043.78 Tot 1033,40 Tot 463.89 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3580.97 TOTAL JOINTS THIS PAGE = 86 DIRECTIONS: Float Shoe = 1,50 Float Collar = 1,32 Stage Collar = 2,50 Fluted Hanger = 1,32 PHILLIPS ALASKA INC CASING TALLY PAGE: 2 of 2 WELL NUMBER: Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 7/11/00 Column9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 ;332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 38z 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 1365 390 216 241: 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 2941 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 37' 396 222 :247 272 297 322 347 372 397 223 !248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 3580.97 TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 86 Average Jt = 41.64 DIRECTIONS: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner THRU: Blair Wondzell~~' P.I. Supervisor FROM: John H. Spaulding~/& Petroleum InspectOfr NON-CONFIDENTIAL DATE: July 24, 2000 SUBJECT: Blowout Preventer Test Nabors 19E Phillips Alaska Inc 2N-316 200-090 Kuparuk I Kuparuk River Unit Operator Rep.: Dearl Gladden Contractor Rep.: Jon West Op. phone: 263-3140 Rig phone: 263-3141 Op. E-Mail: ' Rig E-Mail: Test Pressures Rams: 3500 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location P Hazard: ,. Standing Order: BOP STACK: Quantity Size P/F Annular Preventer 1 11" P Pipe Rams 1 4" P Lower Pipe Rams 1 4" P Blind Rams 1 P Choke Ln. Valves 1 3" P HCR Valves 2 2"~3" P Kill Line Valves 1 2" P Check Valve N/A N/A N/A Annular: 2500 Choke: 3500 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly 1' P Ball Type 1 P inside BOP 1 P CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Man. Chokes 1 P Hyd. Chokes 1 P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P ACCU M ULATOR SYSTEM: Time/Psi' P/F System Pressure 3100 After Closure :t900 200 psi Attained 37 sec. Full Pressure 1:42 Blind Covers (All StatiOns): yes N2 Bottles (avg): 4 @1950 avg Test's Details Excellent test. Choke manifold was tested on the way out of the hole. *The lower kelly valve failed and was replaced and tested ok. Total Test Time: .~3,1'12 Number of failures: 1_ cc.' Attatchments: none bop nabors 19e 7-24-00js.xls 8/7/00 2N 316 Well Status Subject: 2N 316 Well Status Date: Wed, 12 Jul 2000 10:28:01 -0900 From: "Tom J Brassfield" <TBRASS~ppco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us> CC: "Randy L. Thomas" <RLTHOMAS~ppco.com>, "James A Trantham" <JTRANTH~ppco.com>, "Chip Alvord" <CALVORD~ppco.com> Blair, as you requested the status of the 2N 316 well is as follows: The surface casing was run and cemented with CIP at approx. 0430 hrs 7/12/00. The cement job went OK with full returns and cement to surface. The broach to the pad appeared to heal itself until end of the displacement when a small amount of fluid was noted. Thanks, Tom 1 of 1 7/12/00 2:04 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount ~ Commissioner ~//~ ~ FROM' Jeff Jones SUBJECT: Petroleum Inspector Blair Wondzell, P. I. Supervisor DATE: July 11,2000 Well Broach Nabors 9ES KRUfTarn Field Well 2N-316 Permit # 200-090 July 11, 2000: I traveled to Phillips Alaska Inc.'s Kuparuk River Unit, Tarn Field to inspect a broached well, # 2N-316, where personnel on Nabors Rig 9ES were in the process of installing surface casing. On arrival at the location I spoke with the operator representative, Ray Springer, regarding the possible causes for the broached well and solutions to the problem. He indicated that he had noted no unusual circulation pressures, but had experienced broaching problems while drilling other wells on this pad, and that possible causes were: 1) Well centers spaced too close together, allowing heat generated from producing wells to thaw the soil. 2) High water content and poor compaction of the soil. He also indicated that possible solutions to the problem would be to space the wells farther apart and set the conductor pipe deeper in the ground, but that this would have an economic impact to the operator. I relayed to him the importance of getting a good cement job all the way to surface and he said that he was prepared to do whatever it takes to accomplish it. I inspected the area of the broach and took some photographs~ which will be added to this report when developed. The area around the broach had been diked and contained approximately 15 gallons of drilling fluid. No drilling fluid had escaped the pad. I contacted Ray Springer again the next morning to get an update on the cementing. He told me that some cement had come up through the broach during cementing, and that he then had a vacuum truck hook up to the outlet nipples on the conductor pipe to help pull the cement up to surface. He Broach KRU Tam 2N-316 7-11-00 JJ estimated a three-barrel cement return at surface in the cellar, and a small amount to the surface through the broach. SUMMARY: I inspected a well broach at Phillips Alaska Inc.'s well 2N-316 in the Kuparuk River Unit, Tarn Field. I took photographs of the area of the broach and investigated possible causes and solutions. Attachments: Photographs when developed CONFIDENTIAL Broach KRU Tam 2N-316 7-11-00 JJ Re: 2N 316 Revised BHL Subject: Re: 2N 316 Revised BHL Date: Tue, 11 Jul 2000 14:15:52-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tom J Brassfield <TBRASS~ppco.com> Tom, I see no need to do any additional paper at this point. Consider this approval for the change in bottom hole location, provided a spacing exception or someting similar is not needed. Thanks, Blair Wondzell, 7/11/00. Tom J Brassfield wrote: > Blair, per our discussion today here are the requested changes to our 2N 316 > directional plan. The request is based on the recently drilled 2N 332 results > which were slightly under the estimated net pay projections. Nabors 19E is > currently drilling surface hole on 2N 316 at 3000' MD and should TD sometime > early tomorrow morning. > The surface hole directional plan~plot does not change per the PTD #200-090. > The BHL change ~ TD is from 1934' FNL, 1447' FWL to 2334' FNL, 1228' FWL in > Sec. 28,TlON, R7E. > This equates to 435' SSW of the original permitted target TD. > Thanks, Tom 1 ofl 7/11/00 2:17 PM ALASIIA OIL AND GAS CONSERVATION cOPi)llSSiON Chip Alvord Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kupamk River Unit 2N-316 Phillips Alaska, Inc. Permit No: 200-090 Sur Loc: 44'FNL, 690'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 1934'FNL, 1447'FWL, Sec. 28, T10N, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authOrize conducting drilling operations until all other required permitting determinations are made. You have indicated that you will submit an application for annular injection following drilling operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~.~ ~ c/ day of June 2000 dlffEnclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 2N 316 Permit To Drill Subject: 2N 316 Permit To Drill Date: Tue, 20 Jun 2000 14:27:27 -0900 From: "Tom J Brassfield" <TBRASS@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak. us> CC: "Randy L. Thomas" <RLTHOMAS@ppco.com>, "Chip Alvord" <CALVORD@ppco.com> Tom, per your request here are some additional comments on the PTD for 2N 316: SOP's for handling hydrates: (The first two wells on 2N Pad in the Phase 3 drilling program have seen small amounts of hydrates while drilling surface hole i.e. approx. 1000 unitsof gas or less) -Check all gas detection equipment. -Hold a pre spud meeting with all crews and discuss any hazards. -Keep mud viscosities Iow to aid the removal of gas. This is a balancing act- sometimes the viscosities are raised to help hold back the running sands and gravels. -Pre-treat the system with Driltreat (Ledthin) and DriI-N-Slide prior to drilling the hydrate section. -Maintain the mud/make-up water as cool as possible. -Control drill as conditions dictate. -Optimiae flow rates. Proximity risks with 2N 315 -2N 315 will be secured until we reach a depth of approx. 2000' MD. A tubing tail plug will be installed and kill weight fluid circulated into the tubing and production casing annulus. This procedure meets our internal proximity/separation guidelines. If there are any additional questions, please advise. Thanks, Tom 1 of 1 6/22/oo lO:O4 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work: Drill [] Redrill ri I ,b. Type ct well. Exploratory Q StratigraphJc Test Q Development Oil J~J Re-entry Q Deepen DJ Service Q Development Gas D Single Zone ~] Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Properly Designation ~ :~75-~3'7~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 380054 ALK 4602 ~ Tarn Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 44' FNL, 690' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2467' FNL, 1965' FWL, Sec. 28, T10N, R7E, UM 2N 316 #U-630610 At total depth 9. Approximate spud date Amount 1934' FNL, 1447' FWL, Sec. 28, T10N, R7E, UM June 21, 2000 $200,000 12. Distance to nearest property line J 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) 1447 @ TD feetJ 2N-315 11.5' @ 694' feet 2560 13874 ' MD /5189 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250' MD Maximum hole angle 73.85 Maximum surface 1903 psig At total depth (TVD) 2400 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantib/of Cement Hole Casin~l Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 83' 35' 35' 118' 118' 9 cy High Early 9.875" 7.625" 29.7# L-80 BTCM 3451' 35' 35' 3486' 2300' 350 sx AS III L & 240 sx Class G 6.75" 5.5"x 15.5# L-80 LTC Mod 12652' 35' 35' 12687' 4860' 635 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 1187' 12687' 4860' 13874' 5189' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate ~,-~,~ ! Production O R / G / " "I · " 0 8 2000 Per, ora. on depth: measured ' ~ Ala~k~ Oil & Gas C~s, Oommimio~ A~chorage true vertical 20. Attachments Filing fee r~ Property Plat E] BOP Sketch [~] Diverter Sketch ~ Drilling program r~ Drilling fluid program E] Time vs depth plot E]Refraction analysis E] Seabed report E] 20 AAc 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Ca//Torn Brassfie/d265-65~, Signed ~ '1~, ~ Title: DrillingEngineeringSupervisor Date Preoared bv Torn Rrasafielc Commission Use Onl~ Permit Number ~ c~O _ Cb~ O I APl number 50- //OS-- "'~'~ ~Z' ~J Appr~l~,~e~ ~' J See cover letter .r'~ I:~(.~ Jtor other requirements Conditions of approval Samples required E] Yes [~ No Mud logrequired r~ Yes [] No Hydrogen sulfidemeasures E] Yes [~ No Directional surveyrequired ,~ Yes E] No Required working pressure tor BOPE D2M; Q 3M; F1 5M; Q lOM;Q J~] Other: ORIGINAL SIGNED B~ by order of Approved by D Taylor Se~moun? commissioner the commission Date , ~ Form 10-401 Rev. 12/1/85 · Submit in triplicate ( .... Phillips Alaska, Inc. ( GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PFIODUCER KRU 2N-316 1. Move in and rig up Nabors 19e. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. 4. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface. If cement does not circulate to surface, a Top ,lob will only be performed after consulting with the AOGCC. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 5. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 6. Drill 6-1/2"x7-1/2" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(0). 8. Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. Set TWC, ND BOPE and install production tree. 12. Secure well. Rig down and move out. 13. Hydrocarbon intervals will be tested after the rig move. REC,_ !v D ,.'U~; 0 8 2000 Alaska Oi~ & Gas C~s, Commission Phillips Alaska, Inc. ( DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N-316 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-1 O.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 __.10% Drill out to TD 9.0 - 11.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-10 <11% Drillinq Fluid System: ,.~ ...~,.., 0 8 2000 Al~ka Oil & Gas Cons. Commission ~chemge Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a reservoir pressure of 2400 psi at a target mid-point of 4974' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MAS P=((2400/4974)-0.1 )*4974 MASP=1903 psi Therefore ARCO will test the BOP equipment to 3500 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.49 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.86 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4974'. Target (Midpoint T2 T3) (2400+150)/(0.052'4974)=9.86. Phillips Alaska, Inc. Well Proximity Risks: The nearest well to 2N-316 is 2N-315. The wells are 11.5' from each other at a depth of 694' MD. Drillinq Area Risks: The primary risk in the 2N-316 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.5 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is possible lost circulation at approximately 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.0-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well through the reservoir. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Recent information has indicated the possibility of gas migration from the reservoir to a shallower sand interval. However, NO overpressured zones were encountered while drilling the recent 2N-347 wellbore. Log, tracer, pump-in test, and offest BHPBU evaluations indicate any migration has occurred outside of the wellbore interval and is most likely isolated below the TOC and/or below the Iceberg interval. In the event gas migration has occurred into the Iceberg interval at 4389' TVD, the highest required MW would be 10.5 ppg. Annular Pumpinq Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N~3t6 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, ARCO Alaska, Inc. will submit application for approval of 2N-316 for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified , :~?~ 0 8 LO00 A~a~ka Oii& Gas Cons. Commission (" Phillips Alaska, Inc. maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. = (12.0 ppg) * (0.052) * Max Pressure = 2,935 psi Shoe TVD) + 1,500 psi (2,300') + 1,500 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade !Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). .... 0 8 2000 A~aska ~ & Gas Cons. Commission Anchorage . LEAK OFF TEST PROCEDURE Tarn After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2000 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the AAI LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. , Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. , . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in l-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered, Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. TJB 5/19/OO 08 2000 A~ask~ 0il & G~s C0r~s. Commission Anch0mg~ IPHILLIPS Alaska, Inc. Sh-uoture: Torn D~I Sire 2H Well: ,516 Field: Tom Development Field Locoflon: North Slol~, Nosko 2750 3~00 J 385O 4950 % RKB ELEVATION: 154' .00 KOP §.-00 DL5:5.00 deg per 100 ft 1'00port Collar O.%oBose Permofrost 9.00 W Sok 5.00 1.00 57.00 Bose W Sok -~...~ 5/8 Cosi. g TANGENT ANGLE 73.85 DEG 315.81 AZIMUTH 11356' (TO TARGET) Alaska Oi! & ~?,.~a,~ ~: Cons. Commission C50 ~ ~o ~ Ice~rg Target Mid '- C55 _ ~ TD - CosJng Pt ~ 5500 ! I i i i i i i i i i i I i i i i i I i i i i i I i i i i i i i i i i ! i i i i ! i i i i i i i 550 O 550 11 O0 1650 2200 2750 3300 3850 4400 4950 5,.=A)O 6050 5600 7150 7700 8250 8800 9,T50 9900 10450 11000 11~ 12100 12650 Vertical Section (feet) -> Azimuth 515.81 with referenoe 0.00 N, 0.00 E from slot //516 IPHILLIPS Alaska, Inc. $ffu~tur~: Iarn Drill $lt~ 2N W~II: Fl~ld: T~rn D~lopm~n! Field cooofioa: North $1op~, 4aoo 4200 <- West (feet]) 9000 8400 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 1800 1200 600 0 600 9800 I I I ,~ I I I I I I I I I I I I I I I I I I I I I I I I I t I 9600 ~,~f~'~ ~.~>O 9000 9000 8400 O~,(~e"" 8400 7800 7800 :315.81 AZIMUTH nee 11:3{50' (TO TARGET) ~oo 6600 6600 I 'rD LOCATION: I 6000 1934' FNL, 1447' FWL .m 6000 SEC, 28, TION, R7E I TARGET LOCATION; 2467' FNL, 1965' FWL SEC. 28, TI ON, RTE 4200 3000 3000 2400 2400 1800 ,%~ 1800 1200 1200 Alaska Oil a Gas Co~,;s. Cora~ission 600o /:~IchCr~.£~e ~'*~ 800 o 600 44' FNI., 690' FEL 600 SEC. 3, T9N, R7E 1200 ~ i ~ I ~ ~ ~ ~ ~ ~ , I ~ ~ ~ ~ ~ , : ~ ~ [ , ~ ~ ~ , ~ ~ ~ ~ 1200 9000 8400 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 1800 12D0 600 0 600 <- West (feet) A 4800 I Z 0 3600 *,.-I- IPHILLIPS Alaska, Inc. $truolur.: Tarn Drill :SHe 2}t Wall: $16 Field: Tam Development Field Location: Nodh Slope, AIQSka E COMMENT DATA Point MD KOP 250.00 Port Collar 1020.75 Bose Permafrost 1248.93 W Sak 1527.06 Base W Sak 2460.55 EOC 2711.65 7 5/8 Casing Pt 5486.40 C80 4176.62 Comp Sand 4262.90 C50 8397.04 C40 9432.37 Iceberg 10996.15 TS. 1 12761.25 T5 12887.07 Target Mid Bermuda 13099.17 T2 13304.08 C35 13573.70 :TD - Caslnq Pt 13875.70 Inc Dir TVD North East V. Sect 0.00 515.81 250.00 0.00 0.00 0.00 25.12 315.81 1000.00 110.00 -106.95 155.42 29.97 515.81 1204.00 183.07 -177.99 255.54 38.31 315.81 1434.00 294.89 -286.71 411.29 66.52 315.81 1999.00 819.28 -796,56 1142.68 75.85 315.81 2084.48 988.42 -961.01 1578.59 75.85 515.81 2300.00 1521.99 -1479.79 2122.79 73.85 315.81 2492.00 1997.53 -1941.95 2785.76 73.85 515.81 2516.00 2056.74 -1999.72 2868.64 73.85 315.81 3666.00 4903.83 -4767.88 6839.61 75.85 515.81 5954.00 5616.84 -5461.12 7854.07 75.85 315.81 4389.00 6693.78 -6508.20 9556.14 75.85 515.81 4880,00 7909.57 -7690.08 11051.57 75.85 515.81 4915.00 7996.02 -7774.35 11152.42 75.85 515,81 4974.00 8142.09 -7916.55 11556.15 75.85 515.81 5051.00 8285.20 -8055.55 11552.97 75.85 315.81 5106.00 8468.88 -8234.09 11811.95 75.85 515.81 5189.45 8675.48 -84.34.96 12100.11 Deg/lO0 0.00 5.00 5.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IPHILLIPS Alaska, Inc. Tara Drill ~!~ 214 W~ll: 31 $ 310 320 330 340 TRUE NORTH 0 1700 2O 3O 4O 5O 3OO O0 3300 7O 280 8O 270 260 9O 900 1 O0 250 110 1300 ! ! ! ! ! ! ! 1900 :00 ¢ 3ooo ~f 190 Normal Plane Travelling Cylinder - Feet 180 ~ 170 700 1 6O 140 1300 120 1900 2100 2300 All depths shown are Measured depths on Reference Well , ...,,~.~ 0 8 2000 2:000 IPHILLIPS Alaska, Inc jSfruoture: Tarn DHII Site 2N Well: 516 JField: Tarn Development Field Location : North Slope. Alas 28O 260 240 220 20O <- West (feet) 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 I .I. ....... I ........ ,,ri! I I I I I I I I I I I I I I I I I I I I I ! I I I I \ · \\·· & "'~ 1300 120 300 1 ·., \ · 1100 \ % "¥~1200 180 ,~1.~0 1200 \ \% ·· 160 "".. · le,,1100 1000 1100 ",,,.,.1200 ",, ',. 11( · 1900 " " " '· " ,, "~. 1000 "%~1100 ·· 1000 · · 900 % \ " 1200 ',%900 ",%1000 ~0,,~,' ', ,, 90 go0 ~ ~ ~ BO0 .. -. 800 %, 900 ', · ",~ 800 "'~,,900 "~' 60 1400 1200 ,. 800~,, · ,. 800 ', ~., 700 ~ ~ 700 700 \ 800 x~O0 ~00 1§00 "., 700 000 · ~o ::~'~;~o-' ~oo , 1200 O0 ', 500 600 1400 % 600 0 8.00 600 "" 500 ~730:~ 300 299 11 O0 ' - -...700~'~ 500 1300 ~- ~300' ~000 '--~0 5? 300e 3OO 20 ~ 900 400'~ 3(~3~00 8O i '1'" i '"'i Ii 260 240 220 2~o~8o .... ~6o 4o ',2o' ' ~o ' ~ ' 6'o ' 4'o ' ~'o ' ~ ' 2'o ' ,¢o ' <- West (feet) A 140 I 120 100 2BO 260 240 220 200 180 160 140 A I Z 120 0 1 O0 80 4O 2O 2O IPHILLIPS Alaska, Inc. field: Torn Development field Location: North Slope, Alaska <- West (feet) 800 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 160 800 800 7601 ~'~,~ ~ ~1600 760 ",, ,, '~ 1900 720 ~0 ] ~o ",,.N ",,X~ ",, .... X ~o 440 ~ 4~ ~ 400 ~ ~ 1900 ~ 3~ ": ~ ~ ~ ~ ~x 1500 ~ ~ x 360 ~o ~?o ~o 2o~ ~3Oo~~ _ X 200 200 160 160 8~ 760 720 680 640 6~ 560 520 480 440 400 560 320 2~ 240 200 160 <- Wesf (feel) 520 ~ 480 ~ PHILLIPS Alaska, Inc. Structure: Tam DHII Site 2N Well: 316 Field: Tam Development Field Lo~c~lon: North Slope, AIc~ka 2400 2300 - 2200- 2100 2000 1900 1800 - 17OO- . 1600- - 1500- 1400- 1300 - 1200 11oo lOO0 8oo 7oo <- West (feet) 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 goo 800 700 I I ,......_1 ........ ! ...... i i I ~ i i i i i i i ! i ~ i i i I t i i i t i i i i ~, ~ ~ %~oo ..oo ',, \ 'f~\ . ,, ,, ~ ~~ - ~, ',, ', \ \ X -~,oo ~ ', ',, k k~ ",, X ',, -',,5 5 % - ',. ~ ',, k k k ~-,,oo A _ "'-,,- ",,,, k k ' ' - 1600 Z ~~ "-,X"', ",,5 k~oo / 2100 1200 700 ~ 2700 ~ ~x ~ 2100 %~ 1100 ~oo '", ~oK,, ~ ~ ~000 · ~xx 2500 i i ....... i ........ i-''r' i i i i i i I i i i i i i "i i i i I i i i i i I i i i/ / 22~ 2100 20~ 1900 1800 17~ 1600 1~0 1400 13~ 12~ 1100 1~0 9~ 8~ 7~ <- West ~feef) IPHILLIPS Alaska, Inc. Strucfure: Tom Drill SHe 2N Well: 316 Reid .' Tam Development Field Looatiofl: North Slope, Alaska <- West (feet) 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 4800 · · '- " 4800 · · % 4500 %% ·,~ 3700 4600 " · 350( · 4600 % % · · ~ 3500 · % · 4400 · ·· 5500 % % · · 4400 %% · · % ·. 3500 __ _ 4200 ",, · · 330(3 ,'3d~O 4200 % · % · '"~. · ... 4000 4000 ~. ],31/I · · · · ', -",. 5500 ', ', k\ ~00 ' ,,. 3700 "',,. ', ',, 3300 57oo'~ \ 3800 <.-.- '..,,oo '.. ',. ~,oo \\ _ ^- -,,,,--,?,oo ',,, ,,, ,__\ . oo^ I \ -. ~ \31oo ,, \ 3500 . I '"' \ ',.~oo',d*°° ', ', \ .,.~ z '~ 3400 ~.. 3700 "' x ~ '~', ~ 3100 N - v,.v O · 'q .... -... '..? ...',. M,,- .,:~oo \ -... ~. ...... \ .~oo.. I: X. 3500 ', ....'N, 45oo ,, ', - zO 3000 ~ k '~::- ~ .~fO0 ,,, -3000 ~"+' '".,33oo X '-. 'N, 4300 ', ,,,2,oo - 2600 31~,N~'~3100 -,. '~ ',, , -2600 .... ~ '- "~,g,. '~.~. ' -. N..3*00 % x 2400 2400 - "-,.3,00 ~ ". "k" , , ' 2200 O0 x., - 2200 %%· 50~,- 2500 L ,)nan 2000 ,, / i i i i i i i i i i i ! i ! I i i i i i i i 4800 4600 4400 4200 4000 3800 3600 3400 5200 3000 2800 2600 2400 2200 2000 1800 <- West ('feet) IPHILLIPS Alaska, Inc. Structure: Tarn Drill SHe 2N Well: ,316 Field: Tam Development Reid Looatlon: North Slope, Alaska <- West (feet) 9600 9200 8800 8400 8000 7600 7200 6800 6400 6000 5600 5200 4800 4400 4000 3600 3200 9200 9200 . 8800 - 8800 ~ 5189 % - 8400 ~ 5100 ,,, - 8400 % ~. - 8000 ~ '~4900~~~ 5300~ .' 8000 7600 " 5100 ~. ,,, - 7600 \ ~,t 4700 ', 4900 ~.. ' % 7200 % ,, - 7200 4700 '1~ . "" .~4500 ~" .,.~.4900 ~ - 6800 ,, ...~700 4500 \ "', '(5004300 " ~, ~oo I ",~ ',,. 4300 '~ Z ~,t 4100 '~t 4300 6000 ..~ x,,,, "xx 4100 ~-x ' · , ~ - 5000 [~. ~ , ,4~°° , ~ ~%900 5300 ' ' ' '~- ~ ~ ~ I /5 52004900 ' '~" 5300 ~ ~ 100 4700 ".,'~ '~ 4500 "'-. -' -- ~. '~ 3700 ~ ~ -,.~oo -. ~ooo,, , , m 4800 ~ 4300 '" .... ~ x x x x ~- 4800 _ '~,~O0 '. ~4700~ ,, '3700 L 4500 ...:,~ 4500 ~. 3500 ~ ~ .oo-m ,, , ..oo _ ..~,oo '..~oo '-k~oo ,, 4000 - ' ' '.~4700 '"'N~41 O0 ~... ~ "~,,~Juu - 4000 "-.. "~. 4100W~ "~--'~. ~5500 ', '-- ? '"~ 39o0 .... \ '-~?,. ~ ', ' ~600 '- ._ "'~ 3900'x '-. N 5,00,,~'°°. ~00 ·., 4~0 3700 ",. 4900 ~-~ 3200 - 5200 . '-.. ~oo'--~5oo ~ N -~. 2800 2400 , , , , , , , , , , , ~ , , , ~ , , , , , , , ~ , , , , , , , 2400 9600 9200 8800 6400 8000 7600 7200 6800 6400 6000 5600 5200 4800 4400 4000 5600 3200 <- West (feet) ....... ~ ..... ~ ...... ~ 68~ 6000 PHILLIPS Alaska, Inc. Tarn Drill Site 2N 316 slot #316 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 316 Version #11 Our ref : prop3976 License : Date printed : 5-Jun-2000 Date created : 31-May-2000 Last revised : 5-Jun-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.530,w150 18 52.762 Slot Grid coordinates are N 5911963.649, E 460903.154 Slot local coordinates are 43.18 S 690.02 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9553'>, PMSS <0-9134'>, PMSS <0-9690'>, PMSS <0-8500'>, PMSS <8085-8239'> PMSS <0-10520'>, PMSS <0-8960'>, PMSS <288-8750'> PMSS <0-7039'>, PMSS <0-10655'>, PMSS <7090-10245'> 323,Tarn Drill Site 2N 313,Tarn Drill Site 2N 329,Tarn Drill Site 2N 317,Tarn Drill Site 2N ,339,Tarn Drill Site 2N 308,Tarn Drill Site 2N 307,Tarn Drill Site 2N ,309,Tarn Drill Site 2N 319,Tarn Drill Site 2N 337,Tarn Drill Site 2N ,337A,Tarn Drill Site 2N PMSS <266'-l1061'>,,320,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <5303 - l1526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <10920 - l1225'>,,331,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance 20-May-2000 105.1 4-Aug-1998 10-May-2000 14-Aug-1998 9-0ct-1998 24-Feb-1999 8-Mar-1999 30-Mar-1999 9-Oct-1998 18-Jun-1998 29-Ju1-1998 9-Feb-1999 16-May-2000 29-Feb-2000 21-Dec-1998 21-Dec-1998 10-May-2000 27-Oct-1998 30-Sep-1998 28-Feb-2000 21-Ju1-1998 4-Jun-2000 44.5 180.8 14.8 336.8 120.0 134.2 104.1 41.4 311.9 311.9 49.9 11.5 75 3 75 3 120 7 225 0 248 3 373 5 402 1 421 3 463 9 M.D. 20.0 316 7 694 4 372 2 538 9 0 0 272 2 250 0 527 8 483 3 483 3 550 0 694 4 2O 0 20 0 794 4 20 0 950 0 483 3 472 2 694 4 427 8 Diverging from M.D. 438.9 316.7 694.4 372.2 538.9 0.0 272.2 250.0 527.8 483.3 483.3 550.0 694.4 1083.3 7780.0 794.4 20.0 950.0 483.3 472.2 694.4 427.8 Alaska 0~ & Gas Co~s~ Commission A~'~chora§e PHILLIPS Alaska, Inc. Tarn Drill Site 2N 316 slot #316 Tarn Development Field North Slope, Alaska Alaska Oil & Gas Cons. Commission Anchor.~g~ 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 316 Version #11 Our ref : prop3976 License : Date printed : 5-Jun-2000 Date created : 31-May-2000 Last revised : 5-Jun-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.530,w150 18 52.762 Slot Grid coordinates are N 5911963.649, E 460903.154 Slot local coordinates are 43.18 S 690.02 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.G. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath 349(to312'sTgt)Ver#2,,349,Tarn Drill Site 2N 305 Version #1, 305,Tarn Drill Site 2N PMSS <0-9553'>, 323,Tarn Drill Site 2N PMSS <0-9134'>, 313,Tarn Drill Site 2N PMSS <0-9690'>, 329,Tarn Drill Site 2N PMSS <0-8500'>, 317,Tarn Drill Site 2N PMSS <8085-8239'> ,339,Tarn Drill Site 2N PMSS <0-10520'>, 308,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'>,,337A,Tarn Drill Site 2N PMSS <266'-l1061'>,,320,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N 314 Version #4,,314,Tarn Drill Site 2N 318 Version #5,,318,Tarn Drill Site 2N 322 Version #31,,322,Tarn Drill Site 2N PMSS <5303 - l1526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028°>,,32iA,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance 23-Mar-2000 25-Feb-2000 20-May-2000 4-Aug-1998 10-May-2000 14-Aug-1998 9-0ct-1998 24-Feb-1999 8-Mar-1999 30-Mar-1999 9-Oct-1998 18-Jun-1998 29-Ju1-1998 9-Feb-1999 16-May-2000 1-Jun-2000 2-Jun-2000 2-Jun-2000 29-Feb-2000 21-Dec-1998 21-Dec-1998 1446.1( 1163.6( 1104.3( )42.7.( 1175.9 112.8 )332.7 1119.4 1132.7 1102.4 )38.3 1309.1 1309.1 )46.0( )4.3( 115.7( 119.4( )88.5( )64.6( )64.6( 1113.0( M.D. Diverging from M.D. 1372.2 1372.2 272.2 272.2 494.4 4280.0 383.3 383.3 716.7 11640.0 383.3 383.3 583.3 583.3 200.0 10400.0 294.4 294.4 272.2 272.2 538.9 538.9 516.7 12800.0 516.7 12800.0 572.2 11420.0 772.2 11740.0 1472.0 2800.0 1183.0 1216.0 283.3 4500.0 1138.9 10880.0 1138.9 7080.0 827.8 827.8 PMSS <10920 - l1225'>,,331,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N 332 Version 14,,332,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N 10-May-2000 27-Oct-1998 30-Sep-1998 28-Feb-2000 21-Ju1-1998 1-Jun-2000 4-Jun-2000 )224.0( )239.4( )370.7( )398.7( )416.7( )238.7( )461.5( 350.0 980.3 516.7 505.6 727.8 283.3 472.2 13860.0 12240.0 12620.0 13320.0 6500.0 283.3 13360.0 O 8 000 PHILLIPS Alaska, Inc. CLEARANCE LISTING Page 2 PHILLIPS Alaska, Inc. Tarn Drill Site 2N 316 slot #316 Tarn Development Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 316 Version #11 Our ref : prop3976 License : Date printed : 5-Jun-2000 Date created : 31-May-2000 Last revised : 5-Jun-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.530,w150 18 52.762 Slot Grid coordinates are N 5911963.649, E 460903.154 Slot local coordinates are 43.18 S 690.02 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ~ '"' 0 8 2000 Oil & Gas Co~';s. Commissioi~ Anchorage PHILLIPS Alaska, Inc. Tarn Drill Site 2N,316 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES 0.00 0.00 315.81 0.00 0.00 N 250.00 0.00 315.81 250.00 0.00 N 350.00 3.00 315.81 349.95 1.88 N 450.00 6.00 315.81 449.63 7.50 N 550.00 9.00 315.81 548.77 16.86 N 650.00 12.00 315.81 647.08 29.92 N 750.00 15.00 315.81 744.31 46.66 N 850.00 18.00 315.81 840.18 67.02 N 950.00 21.00 315.81 934.43 90.95 N 1020.75 '23.12 315.81 1000.00 110.00 N 1050.00 24.00 315.81 1026.81 118.38 N 1150.00 27.00 315.81 1117.06 149.25 N 1248.93 29.97 315.81 1204.00 183.07 N 1250.00 30.00 315.81 1204.93 183.45 N 1350.00 33.00 315.81 1290.18 220.91 N 1450.00 36.00 315.81 1372.59 261.52 N 1527.06 38.31 315.81 1434.00 294.89 N 1550.00 39.00 315.81 1451.91 305.16 N 1650.00 42.00 315.81 1527.95 351.72 N 1750.00 45.00 315.81 1600.47 401.07 N 1850.00 48.00 315.81 1669.30 453.07 N 1950.00 51.00 315.81 1734.24 507.58 N 2050.00 54.00 315.81 1795.11 564.46 N 2150.00 57.00 315.81 1851.74 623.54 N 2250.00 60.00 315.81 1903.99 684.66 N 2350.00 63.00 315.81 1951.70 747.66 N 2450.00 66.00 315.81 1994.74 812.37 N 2460.53 66.32 315.81 1999.00 819.28~N 2550.00 69.00 315.81 2033.01 878.60 N 2650.00 72.00 315.81 2066.38 946.18 N 2711.63 73.85 315.81 2084.48 988.42 N 3000.00 73.85 315.81 2164.70 1187.01 N 3486.40 73.85 315.81 2300.00 1521.99 N 3500.00 73.85 315.81 2303.78 1531.35 N 4000.00 73.85 315.81 2442.87 1875.69 N PROPOSAL LISTING Page 1 Your ref : 316 Version #11 Last revised : 5-Jun-2000 Dogleg Vert Deg/100ft Sect 0.00 E 0.00 0.00 0.00 E 0.00 0.00 KOP 1.82 W 3.00 2.62 7.29 W 3.00 10.46 16.39 W 3.00 23.51 29.09 W 3.00 41.74 45.36 W 3.00 65.08 65.16 W 3.00 93.48 88.43 W 3.00 126.85 106.95 W 3.00 153.42 Port Collar 115.10 W 3.00 165.12 145.11 W 3.00 208.16 177.99 W 3.00 255.34 Base Permafrost 178.37 W 3.00 255.87 214.79 W 3.00 308.12 254.27 W 3.00 364.75 286.71 W 3.00 411.29 W Sak 296.70 W 3.00 425.62 341.97 W 3.00 490.56 389.95 W 3.00 559.38 440.51 W 3.00 631.91 493.51 W 3.00 707.95 548.81 W 3.00 787.27 606.25 W 3.00 869.68 665.68 W 3.00 954.93 726.93 W 3.00 1042.80 789.85 W 3.00 1133.05 796.56 W 3.00 1142.68 Base W Sak 854.24 W 3.00 1225.43 919.95 W 3.00 1319.68 961.01 W 3.00 1378.59 EOC 1154.10 W 0.00 1655.58 1479.79 W 0.00 2122.79 7 5/8" Casing Pt 1488.89 W 0.00 2135.85 1823.69 W 0.00 2616.11 4176.62 73.85 315.81 2492.00 1997.33 N 1941.95 W 0.00 2785.76 C80 4262.90 73.85 315.81 2516.00 2056.74 N 1999.72 W 0.00 2868.64 Camp Sand 4500.00 73.85 315.81 2581.95 2220.03 N 2158.48 W 0.00 3096.38 5000.00 73.85 315.81 2721.04 2564.37 N 2493.27 W 0.00 3576.64 5500.00 73.85 315.81 2860.13 2908.70 N 2828.06 W 0.00 4056.91 6000.00 73.85 315.81 2999.21 3253.04 N 3162.85 W 0.00 4537.17 6500.00 73.85 315.81 3138.30 3597.38 N 3497.65 W 0.00 5017.44 7000.00 73.85 315.81 3277.38 3941.72 N 3832.44 W 0.00 5497.70 7500.00 73.85 315.81 3416.47 4286.06 N 4167.23 W 0.00 5977.97 8000.00 73.85 315.81 3555.55 4630.40 N 4502.02 W 0.00 6458.24 8397.04 73.85 315.81 3666.00 4903.83 N 4767.88 W 0.00 6839.61 C50 8500.00 73.85 315.81 3694.64 4974.74 N 4836.82 W 0.00 6938.50 9000,00 73.85 315.81 3833.73 5319.08 N 5171.61 W 0.00 7418.77 9432.37 73.85 315.81 3954.00 5616.84 N 5461.12 W 0.00 7834.07 C40 9500.00 73.85 315.81 3972.81 5663.42 N 5506.40 W 0.00 7899.03 Ail data is in' feet unless otherwise stated. Coordinates from slot #316 and TVD from RKB (Nabors 19E) (154.00 Ft above mean sea level). Bottom hole distance is 12100,11 on azimuth 315.81 degrees from wellhead. Total Dogleg for wellpath is 73.85 degrees. Vertical section is from wellhead on azimuth 315.81 degrees. Calculation uses the minimum curvature method. ~3~ ..~ .,~--%~~ ,~. , Presented by Baker Hughes INTEQ ~.~ ~ ~ ~'~:~ :000 Alaska CAi & G.~s Cons. Co;nmission Anchom~ PHILLIPS Alaska, Inc. Tarn Drill site 2N,316 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING~ Page 2 Your ref : 316 Version #11 Last revised : 5-Jun-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 10000.00 73.85 315.81 4111.90 6007.75 N 5841.19 W 0.00 8379.30 10500.00 73.85 315.81 4250.98 6352.09 N 6175.99 W 0.00 8859.56 10996.15 73.85 315.81 4389.00 6693.78 N 6508.20 W 0.00 9336.14 Iceberg 11000.00 73.85 315.81 4390.07 6696.43 N 6510.78 W 0.00 9339.83 11500.00 73.85 315.81 4529.16 7040.77 N 6845.57 W 0.00 9820.10 12000.00 73.85 315.81 4668.24 7385.11 N 7180.36 W 0.00 10300.36 12500.00 73.85 315.81 4807.33 7729.45 N 7515.15 W 0.00 10780.63 12761.25 73.85 315.81 4880.00 7909.37 N 7690.08 W 0.00 11031.57 T3.1 12887.07 73.85 315.81 4915.00 7996.02 N 7774.33 W 0.00 11152.42 T3 13000.00 73.85 315.81 4946.41 8073.79 N 7849.95 W 0.00 11260.89 13099.17 73.85 315.81 4974.00 8142.09 N 7916.35 W 0.00 11356.15 Target Mid Bermuda 13304.08 73.85 315.81 5031.00 8283.20 N 8053.55 W 0.00 11552.97 T2 13500.00 73.85 315.81 5085.50 8418.13 N 8184.74 W 0.00 11741.16 13573.70 73.85 315.81 5106.00 8468.88 N 8234.09 W 0.00 11811.95 C35 13873.70 73.85 315.81 5189.45 8675.48 N 8434.96 W 0.00 12100.11 TD - Casing Pt Ail data is infeet unless otherwise stated. Coordinates from slot #316 and TVD from RKB (Nabors 19E) (154.00 Ft above mean sea level). Bottom hole distance is 12100.11 on azimuth 315.81 degrees from wellhead. Total Dogleg for wellpath is 73.85 degrees. Vertical section is from wellhead on azimuth 315.81 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 0 8 000 Alaska Oil & (3as Oor~s. Commission Aachom§a PHILLIPS Alaska, Inc. Tarn Drill Site 2N,316 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 316 Version #11 Last revised : 5-Jun-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 250 00 1020 75 1248 93 1527 06 2460 53 2711 63 3486 40 4176 62 4262 90 8397.04 9432.37 10996.15 12761.25 12887.07 13099.17 13304.08 13573.70 13873.70 250. 1000 1204 1434 1999 2084 2300 00 2492 00 2516 00 3666 00 3954 00 4389 00 4880.00 4915.00 4974.00 5031.00 5106.00 5189.45 00 00 0O O0 00 48 0.00 N 0.00 E KOP 110.00 N 106.95 W Port Collar 183.07 N 177.99 W Base Permafrost 294.89 N 286.71 W W Sak 819.28 N 796.56 W Base W Sak 988.42 N 961.01 W EOC 1521.99 N 1479.79 W 7 5/8" Casing Pt 1997.33 N 1941.95 W C80 2056.74 N 1999.72 W Camp Sand 4903.83 N 4767.88 W C50 5616.84 N 5461.12 W C40 6693.78 N 6508.20 W Iceberg 7909.37 N 7690.08 W T3.1 7996.02 N 7774.33 W T3 8142.09 N 7916.35 W Target Mid Bermuda 8283.20 N 8053.55 W T2 8468.88 N 8234.09 W C35 8675.48 N 8434.96 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3486.40 2300.00 1521.99N 1479.79W 7 5/8 Casing 0.00 0.00 0.00N 0.00E 13873.70 5189.45 8675.48N 8434.96W 5 1/2 Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-316 Rvsd i-Jun-00 453029.000,5920145,000,0.0000 4974.00 8142.09N 7916.35W 25-Feb-2000 0 8 2000 Oil & Gas Ce,~s. Commission Anchors§~, ~.._i?Phillips Alaska, Inc. Diverter Schematic Nabors 19e Flowline 21 ¼" 2,000 psi WP DRILLING SPOOL ,w/16" Outlet 16-3/4" 2M SOW Starting Head 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 5 16" OD DIVERTER LINE 16-3/4" x 21-1/4" x 2M Psi DSA Flange 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) Phillips Alaska, Inc. Nabors 19e 11" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT L 1 1 I- 11" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 11" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE MANUAL GATE VALVE ~ , KILL LINE ~~'~~~ 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator I / DSA 13-5/8" 5,000 psi WP -"'""~L x 11" 3,000 psi WP \ ~_J ~raulic actuator h 11" 5,000 psi WP I__~ ~ DRILLING SPOOL w/two 3" 5M psi WP outlets J SINGLE 11" 5,000 psi WP, I HYDRIL MPL BOP w/pipe rams ,.._,., 0 0 2000 A~k~ Oil &Gas Cons. Commission Anch0rEJ~ Phillips Alaska, Inc. i" , Post Office Box 100360 '""'/ Anchorage, Alaska 99510-0360 June 7,2000 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-316 Surface Location: 44' FNL 690' FEL Sec 3 T9N R7E, UM or ASP4, NAD 27 coordinates of X=460,903 & Y=5,911,964 Target Location: 2467' FNL, 1965' FWL Sec. 28, T10N, R7E, UM Bottom Hole Location: 1934' FNL, 1447' FWL Sec. 28, T10N, R7E, UM Dear Commissioner Christenson, Phillips Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-316, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M'Pad. Nabors Rig 19e will drill the well. If commercial, the well will also completed with Nabors 19e. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be Preferentially ground at the on-site ball mill and injected down an approVed, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, Phillips has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Doug Hastings, Geologist 265-6967 (20 AAC 25.071) If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 265-6120 in our Anchorage office. Sincerely, i3hip Alvord Drilling Engineering Supervisor RECEIVED Attachments cc: KRU 2N-316 Well File Phillips Alaska, Inc. is a Subsidiary of Phillips 66 0 8 2000 Alaska 0i! & Gas Cons. Commission Anch0r~e ,'0000~,00c~c;8"' ,:08~,c30~,~E,.~,: OC~ c~o000,' ~;~ ~-;;;~~: .... ' '-:' "'-",, ,,, ~'~- . Pl~e note ~at ~y disposal of fluids generated from'this drilling operation which are pumped down the suffa~production ~ing ~nulus of a well approved for ~ular disposal on Drill Site 1D nmst comply with ~e requirements ~d limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling w~te in a volume grater th~ 35,000 ba~els through flae ~nular spa~ of a single well or to use ~at well for disposal pu~oses for a period longer flama one y~r. FIELD & POOL ~-"~-/~, ~ [N'~' ~17- -~'---~- __ ,f'~::)//--- GEOL AREA ADMINISTRATION 1. 2. APPR Permit fee attached. Lease number approl~ri~t~.~, i '.:~-.~ ~..-~. ti'~.'/~.'; './~'! ~.~'.'/ 3. Unique well name and number .................. 4. Well located in a defined pool .................. ~ 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N ,DATE 12. Permit can be issued without administrative approval ...... (~, I?,..L..~ 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE ¢.,- ( (k, 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a to-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 'zj.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. devv/ reddl . serv ~) ~ UNIT# ann. disposal para req ~ ON/OFFSHORE GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. 32. DATE 33. 34. A~,,)R ~,/Z-'DC> ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. (~N Data presented on potential overpressure zones ...... ,..,, ~ N Seismic analysis of shallow gas zones ........... ~ Y N Seabed condition survey (if off-shore) ........ ~ '. Y N Contact. name/phone for weekly progress report~(ploratory only] Y N Y N Y N Y N Y N Y N GEOLQ~Y: ENGINEERING: UIC/Annular COMMISSION: Commentsllnstructions: c:~msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry 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 SRevision: 3 $ LisLib SRevision: 4 $ Wed Jan 03 17:11:01 2001 Reel Header Service name ............. LISTPE Date ..................... 01/01/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/01/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit (Tarn Pool) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-00089 B. HENNINGSE R. SPRINGER 2N-316 501032034200 PHILLIPS Alaska, Inc. Sperry Sun 03-JAN-01 MWD RUN 5 AK-MM-00089 B. HENNINGSE D. GLADDEN MWD RUN 6 AK-MM-00089 B. HENNINGSE D. GLADDEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 7 AK-MM-00089 J. MARTIN D. GLADDEN MWD RUN 8 AK-MM-00089 J. MARTIN D. GLADDEN 3 9 N 7 E MWD RUN 9 AK-MM-00089 J. MARTIN D. GLADDEN FNL: 44 FSL: FEL: FWL: 690 ELEVATION (FT FROM MSL 0) KELLY BUSHING: 153.30 DERRICK FLOOR: 151.97 GROUND LEVEL: 119.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 9.625 3494.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED 3. MWD RUNS 4 - 9 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITH-DENSITY (SLD) . DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 9/28/00. MWD DATA CONSIDERED PDC. 5. GAMMA RAY LOGGED BEHIND CASING TO 3494' MD, 2302' TVD. 6. MWD RUNS 1 - 9 REPRESENT WELL 2N-316 WITH API # 50-103-20342-00. THIS WELL REACHED A TOTAL DEPTH OF 13692' MD, 5145' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: MUD WEIGHT: MUD FILTRATE SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 7.5" & 6.75" 9.50 - 9.7 PPG 300 PPM CHLORIDES 19,149 PPM CHLORIDES 1.00 G/cc 2.65 G/cc SANDSTONE 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 GR NPHI NCNT FCNT RPX RPS RPM RPD FET RHOB DRHO PEF ROP $ BASELINE CURVE FOR SHIFTS: START DEPTH 3447.0 3484 5 3484 5 3484 5 3485 0 3485 0 3485 0 3485 0 3485 0 3492 0 3492 0 3492 0 3510 5 STOP DEPTH 13638.0 13589 5 13589 5 13589 5 13645 0 13645 0 13645 0 13645.0 13645.0 13605.5 13605.5 13605.5 13691.5 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGED MAIN PASS. $ 3447 0 6069 5 7363 5 10611 0 12688 5 12886 5 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 MERGE BASE 6069 0 7363 0 10610 5 12688 0 12886 0 13691 5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 3447 13691.5 8569.25 20490 ROP MWD FT/H 1.47 1460 90.976 20363 GR MWD API 43 223.97 121.857 20383 RPX MWD OHMM 1.34 31.96 5.04027 20321 RPS MWD OHMM 1.53 36.82 5.33752 20321 RPM MWD OHMM 1.69 2000 6.57259 20321 RPD MWD OHMM 1.73 2000 7.20383 20321 First Reading 3447 3510.5 3447 3485 3485 3485 3485 Last Reading 13691.5 13691.5 13638 13645 13645 13645 13645 FET MWD HR 0.45 81.1 NPHI MWD PU-S 4.67 61.94 FCNT MWD CP30 112.46 1401.28 NCNT MWD CP30 13807.3 36445.4 RHOB MWD G/CM 1.39 3.26 DRHO MWD G/CM -0.36 0.88 PEF MWD B/E 1.32 10.21 2.34389 20321 34.9857 20211 235.827 20211 18863.6 20211 2.2888 20228 0.0740933 20228 2.84647 20228 3485 3484.5 3484.5 3484.5 3492 3492 3492 13645 13589.5 13589.5 13589.5 13605.5 13605.5 13605.5 First Reading For Entire File .......... 3447 Last Reading For Entire File ........... 13691.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 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 ....... 01/01/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW 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 GR 3447.0 NPHI 3484.5 NCNT 3484.5 FCNT 3484.5 RPD 3485.0 RPX 3485.0 RPS 3485.0 RPM 3485.0 FET 3485.0 RHOB 3492.0 DRHO 3492.0 PEF 3492.0 STOP DEPTH 6005 5 5957 0 5957 0 5957 0 6012 5 6012 5 6012 5 6012 5 6012 5 5973 0 5973 0 5973 0 ROP 3510.5 $ 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 EWR4 SLD CTN $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON 6069.0 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 Loggin9 Direction ................. Down 17-JIJL-00 Insite 4.05.2 .41 Memory 6069.0 72.3 78.4 TOOL NUMBER PBO1565GR4 PBO1565GR4 PBO1428NL4 PBO1428NL4 7.500 LSND 9.60 46.0 9.0 250 .8 1.910 1.297 1.850 1.940 74.0 112.2 67.0 66.0 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 MWD040 FT/H 4 1 68 4 2 · GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HR NPHI MWD040 PU-S FCNT MWD040 CP30 NCNT MWD040 CP30 RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 B/E Min 3447 7.52 49.2 1 96 2 65 2 35 2 11 0 45 9 81 120 32 13807.3 1.56 -0.33 1.99 Max Mean Nsam 6069 4758 5245 390.11 77.7169 5118 155.79 105.565 5118 26.7 4.59814 '5056 36.82 4.93747 5056 2000 8.92354 5056 2000 10.5188 5056 81.1 2.56204 5056 55.67 39.2381 4946 1039.53 200.79 4946 31823.5 18416.3 4946 2.76 2.1515 4963 0.59 0.0856901 4963 10.21 3.69556 4963 First Reading 3447 3510.5 3447 3485 3485 3485 3485 3485 3484.5 3484.5 3484.5 3492 3492 3492 Last Reading 6069 6069 6005 5 6012 5 6012 5 6012 5 6012 5 6012 5 5957 5957 5957 5973 5973 5973 First Reading For Entire File .......... 3447 Last Reading For Entire File ........... 6069 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 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 ....... 01/01/03 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI FCNT NCNT RHOB DRHO PEF GR RPX RPS RPM FET RPD ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5957.5 5957.5 5957.5 5973 5 5973 5 5973 5 6006 0 6013 0 6013 0 6013 0 6013 0 6013 0 6069 5 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: 7315 7315 7315 7315 7315 7363 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM~LAP~AY EWR4 ELECTROM_AG. RESIS. 4 SLD STABILIZED LITHO DEN STOP DEPTH 7260.5 7260 5 7260 5 7276 5 7276 5 7276 5 7308 5 5 5 5 5 5 0 19-JUL-00 Insite 4.05.2 .41 Memory 7363.0 71.6 76.9 TOOL NUMBER PBO1565GR4 PBO1565GR4 PBO1428NL4 CTN $ COMP THERMAL NEUTRON 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 PBO1428NL4 7.500 LSND 9.60 43.0 9.5 250 3.8 1.960 1.269 1.940 1.920 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 t 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 NPHI MWD050 PU-S 4 1 68 FCNT MWD050 CP30 4 1 68 NCNT MWD050 CP30 4 1 68 RHOB MWD050 G/CM 4 1 68 DRHO MWD050 G/CM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 68.0 108.7 68.0 68.0 PEF MWD050 52 14 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HR NPHI MWD050 PU-S FCNT MWD050 CP30 NCNT MWD050 CP30 RHOB MWD050 G/CM DRHO MWD050 G/CM PEF MWD050 B/3 Min 5957.5 3.79 75 14 2 99 3 31 3 53 3 95 0 53 18 12 170 59 15753.8 1.76 -0.04 1.89 Max 7363 307.91 141.26 8.17 8.73 10.02 9.25 19.64 42.14 591.06 27859.1 2.53 0.51 4.57 Mean Nsam 6660.25 2812 80.4166 2588 110.661 2606 4.11682 2606 4.3521 2606 4.54176 2606 4.75539 2606 2.28229 2606 34.666 2607 229.408 2607 18726.2 2607 2.24294 2607 0.060537 2607 2.60146 2607 First Reading 5957.5 6069.5 6006 6013 6013 6013 6013 6013 5957.5 5957.5 5957.5 5973.5 5973.5 5973.5 Last Reading 7363 7363 7308.5 7315 5 7315 5 7315 5 7315 5 7315 5 7260 5 7260.5 7260.5 7276.5 7276.5 7276.5 First Reading For Entire File .......... 5957.5 Last Reading For Entire File ........... 7363 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 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 ....... 01/01/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 7261.0 FCNT 7261.0 NPHI 7261.0 PEF 7277.0 DRHO 7277.0 RHOB 7277.0 GR 7309.0 FET 7316 0 RPD 7316 0 RPM 7316 0 RPS 7316 0 RPX 7316 0 ROP 7363 5 $ 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 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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: STOP DEPTH 10507.5 10507.5 10507.5 10523 0 10523 0 10523 0 10555 5 10563 0 10563 0 10563 0 10563 0 10563 0 10610 5 23-JUL-00 Insite 4.05.2 .41 Memory 10610.0 79.5 69.5 TOOL NUMBER PBO1565GR4 PBO1565GR4 PBO1428NL4 PBO1428NL4 7.500 LSND 9.60 46.0 9.4 30O 3.6 1.200 .883 1.900 1.500 84.0 116.6 84.0 84.0 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 DEPT FT 4 1 68 ROP MWD060 FT/H 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HR 4 1 68 NPHI MWD060 PU-S 4 1 68 FCNT MWD060 CP30 ~4 1 68 NCNT MWD060 CP30 4 1 68 RHOB MWD060 G/CM 4 1 68 DRHO MWD060 G/CM 4 t 68 PEF MWD060 B/E 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min DEPT FT 7261 ROP MWD060 FT/H 2.63 GR MWD060 API 43 RPX MWD060 OHMM 1.34 RPS MWD060 OHMM 1.53 RPM MWD060 OHMM 1.91 RPD MWD060 OHMM 2.23 FET MWD060 HR 0.52 NPHI MWD060 PU-S 4.67 FCNT MWD060 CP30 112.46 NCNT MWD060 CP30 14616.7 RHOB MWD060 G/CM 1.39 DRHO MWD060 G/CM -0.36 PEF MWD060 B/E 1.5 Max 10610.5 320.64 223 97 17 08 13 25 17 63 19 42 20 65 61 94 1401 28 36445.4 3.26 0.88 6.06 Mean 8935.75 105.797 133.705 4.34881 4.61407 5.00176 5.24656 1.412 35.0835 229.447 18583.9 2.32647 0.0638796 2.55891 Nsam 6700 6495 6494 6495 6495 6495 6495 6495 6494 6494 6494 6493 6493 6493 First Reading 7261 7363.5 7309 7316 7316 7316 7316 7316 7261 7261 7261 7277 7277 7277 Last Reading 10610.5 10610.5 10555.5 10563 10563 10563 10563 10563 10507.5 10507.5 10507.5 10523 10523 10523 First Reading For Entire File .......... 7261 Last Reading For Entire File ........... 10610.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 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 ....... 01/01/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P~AW 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 NPHI 10508 0 12582.5 FCNT 10508 0 12582 5 NCNT 10508 0 12582 5 RHOB 10523 5 12598 0 DRHO 10523 5 12598 0 PEF 10523 5 12598 0 GR 10556 0 12630 5 RPX 10563 5 12637 5 RPS 10563 5 12637 5 RPM 10563 5 12637 5 FET 10563 5 12637 5 RPD 10563 5 12637 5 ROP 10611 0 12688 0 $ LOG HEADER DATA DATE LOGGED: 28-JUL-00 soFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: .41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 12688.0 70.3 76.0 TOOL NUMBER PBO1565GR4 PBO1565GR4 PBO1428NL4 PBO1428NL4 7.500 LSND 9.70 44.0 9.0 300 3.6 2.200 1. 115 1.800 2.200 Name Service Order Units Size Nsam Rep Code Offset Channel 58.0 121.0 58.0 58.0 DEPT ROP MWD070 GR MWD070 RPX MWD070 RPS MWD070 RPM MWD070 RPD MWD070 FET MWD070 NPHI MWD070 FCNT MWD070 NCNT MWD070 RHOB MWD070 DRHO MWD070 PEF MWD070 FT FT/H API OHMM OHMM OHMM OHMM HR PU-S CP30 CP30 H/CM G/CM B/3 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 0 4 8 12 16 20 24 28 32 36 40 44 48 52 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Service Unit DEPT FT ROP MWD070 FT/H GR MWD070 API RPX MWD070 OHMM RPS MWD070 OHMM RPM MWD070 OHMM RPD MWD070 OHMM FET MWD070 HR NPHI MWD070 PU-S FCNT MWD070 CP30 NCNT MWD070 CP30 RHOB MWD070 H/CM DRHO MWD070 H/CM PEF MWD070 B/3 Min 10508 5.07 69 01 1 87 2 03 2 29 2 61 0 59 12 43 160 15 15226.1 1.56 -0.16 1.32 Max 12688 289 78 186 94 8 69 10 54 13 87 14 53 36 73 43 32 751 25 29025.2 3.1 0.73 5.52 Mean 11598 90.5393 129.142 4.76012 4.9595 5.25541 5.48667 2.34882 32.2475 255.904 19116.4 2.40571 0.0876265 2.58572 Nsam 4361 4155 4150 4149 4149 4149 4149 4149 4150 4150 4150 4150 4150 4150 First Reading 10508 10611 10556 10563.5 10563.5 10563.5 10563.5 10563.5 10508 10508 10508 10523.5 10523.5 10523.5 Last Reading 12688 12688 12630.5 '12637.5 12637.5 12637.5 12637.5 12637.5 12582.5 12582.5 12582.5 12598 12598 12598 First Reading For Entire File .......... 10508 Last Reading For Entire File ........... 12688 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 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 ....... 01/01/03 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 12583.0 12780 5 NCNT 12583.0 12780 5 NPHI 12583.0 12780 5 PEF 12598.5 12796 5 RHOB 12598.5 12796 5 DRHO 12598 5 12796 5 GR 12631 0 12829 0 RPM 12638 0 12836 0 FET 12638 0 12836 0 RPS 12638 0 12836 0 RPD 12638 0 12836 0 RPX 12638 0 12836 0 ROP 12688 5 12886 0 $ LOG HEADER DATA DATE LOGGED: 29-JUL-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: .41 DATA TYPE (MEMORY OR REAL-TIME~ : Memory TD DRILLER (FT) : 12886.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL iFT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 70.7 MAXIMUM ANGLE: 73.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1565GR4 EWR4 ELECTROMAG. RESIS. 4 PBO1565GR4 SLD STABILIZED LITHO DEN PBO1428NL4 CTN COMP THERMAL NEUTRON PBO1428NL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: 7.500 LSND 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 9.60 46.0 8.5 300 3.2 2.000 .988 2.700 2.200 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD080 FT/H 4 1 68 GR MWD080 API 4 1 68 RPX MWD080 OHMM 4 1 68 RPS MWD080 OHMM 4 1 68 RPM MWD080 OHMM 4 1 68 RPD MWD080 OHMM 4 1 68 FET MWD080 HR 4 1 68 NPHI MWD080 PU-S 4 1 68 FCNT MWD080 CP30 4 1 68 NCNT MWD080 CP30 4 1 68 RHOB MWD080 G/CM 4 1 68 DRHO MWD080 G/CM 4 1 68 PEF MWD080 B/E 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 58.0 124.3 58.0 58.0 Name Service Unit Min Max DEPT FT 12583 12886 ROP MWD080 FT/H 2.65 165.74 GR MWD080 API 113.43 153.84 Mean Nsam 12734.5 607 52.8852 396 135.102 397 First Reading 12583 12688.5 12631 Last Reading 12886 12886 12829 RPX MWD080 OHMM 1.86 RPS MWD080 OHMM 1.94 RPM MWD080 OHMM 1.75 RPD MWD080 OHMM 1.73 FET MWD080 HR 1.13 NPHI MWD080 PU-S 24.95 FCNT MWD080 CP30 150.39 NCNT MWD080 CP30 14729.1 RHOB MWD080 G/CM 1.64 DRHO MWD080 G/CM -0.01 PEF MWD080 B/E 1.66 5 38 5 89 6 19 6 39 37 77 45 65 344 66 22049 2.66 0.42 3.38 0 . 3.79715 3.97287 4.20461 4.38144 11.0226 33.2584 238.564 18384.8 2.33821 0828212 2.60181 397 397 397 397 397 396 396 396 397 397 397 12638 12638 12638 12638 12638 12583 12583 12583 12598.5 12598.5 12598.5 12836 12836 12836 12836 12836 12780.5 12780.5 12780.5 12796.5 12796.5 12796.5 First Reading For Entire File .......... 12583 Last Reading For Entire File ........... 12886 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 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 ....... 01/01/03 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: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPM 9 .5000 START DEPTH 12781 0 12781 0 12781 0 12797 0 12797 0 12797 0 12829 5 12836 5 STOP DEPTH 13589.5 13589 5 13589 5 13605 5 13605 5 13605 5 13638 0 13645 0 RPS 12836.5 RPD 12836.5 FET 12836.5 RPX 12836.5 ROP 12886.5 $ 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: 13645.0 13645.0 13645.0 13645.0 13691.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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: 01-AUG-00 Insite 4.05.2 .41 Memory 13692.0 71.5 76.8 TOOL NUMBER PBO1565GR4 PBO1565GR4 PBO1428NL4 PBO1428NL4 6.750 LSND 9.70 46.0 9.5 300 3.3 1.900 1.040 2.200 2.000 65.0 124.3 65.0 65.0 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 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HR 4 1 68 28 8 NPHI MWD090 PU-S 4 1 68 32 9 FCNT MWD090 CP30 4 1 68 36 10 NCNT MWD090 CP30 4 1 68 40 11 RHOB MWD090 G/CM 4 1 68 44 12 DRHO MWD090 G/CM 4 1 68 48 13 PEF MWD090 B/E 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD090 FT/H GR MWD090 API RPX MWD090 OHMM RPS MWD090 OHMM RPM MWD090 OHMM RPD MWD090 OHMM FET MWD090 HR NPHI MWD090 PU-S FCNT MWD090 CP30 NCNT MWD090 CP30 RHOB MWD090 G/CM DRHO MWD090 G/CM PEF MWD090 B/E Min Max Mean Nsam 12781 13691.5 13236.3 1822 1.47 1460 100.797 1611 84.31 152.48 121.936 1618 1.5 31.96 11.7082 1618 1.55 33.47 12.383 1618 1.69 47.01 12.7614 1618 1.76 79.84 13.7412 1618 0.59 36.98 3.36016 1618 16.09 44.04 29.5559 1618 165.27 682.05 326.714 1618 15859.2 28061.5 21043.2 1618 1.77 2.76 2.32066 1618 -0.08 0.58 0.0644994 1618 1.8 4.41 2.51963 1618 First Reading 12781 12886 5 12829 5 12836 5 12836 5 12836 5 · 12836 5 12836 5 12781 12781 12781 12797 12797 12797 Last Reading 13691.5 13691.5 13638 13645 13645 13645 13645 13645 13589 5 13589 5 13589 5 13605 5 13605 5 13605 5 First Reading For Entire File .......... 12781 Last Reading For Entire File ........... 13691.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/01/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/01/03 Origin ................... STS Tape Name ................ UNKlgOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/01/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File