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ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 1D-39 50029229970000 2002160 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 27, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-39 KUPARUK RIV UNIT 1D-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/27/2025 1D-39 50-029-22997-00-00 200-216-0 W SPT 6200 2002160 1550 910 912 910 910 0 0 0 0 INITAL P Sully Sullivan 12/28/2024 Initial MIT-IA after RWO. OA is CMT to surface. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-39 Inspection Date: Tubing OA Packer Depth 140 2000 1960 1955IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241228174143 BBL Pumped:2.6 BBL Returned:2.4 Monday, January 27, 2025 Page 1 of 1 9 9 9 9 9 9 999 9 9 99 9 6XQGU\ 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.27 00:33:24 -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 13545'feet None feet true vertical 6279' feet None feet Effective Depth measured 13377'feet 6033', 12118', 12215'feet true vertical 6567'feet 4284', 6169', 6200'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 12201' 12221' 6195' 6202' Packers and SSSV (type, measured and true vertical depth)6033' 12118' 12215' 4284' 6169' 6200' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk 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: 6231' 4346' Burst Collapse Production Liner 6063' 12337' Casing 4304' 6251' 6097' 12371' 13545' 6626' 6197' 120'Conductor Surface Tie-Back String 20" 9-5/8" 88' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-216 50-029-22997-00-00 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: ADL0025650, ADL0025661 Kuparuk River Field/ Kuparuk Oil Pool KRU 1D-39 Plugs Junk measured Length 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) N/A Gas-Mcf MDSize 120' Well Shut-In 324-457 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB AZIP ECP Packer: SLB BluePack RH Max Packer: BAKER ZXP Liner Top SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049 RWO Engineer 13070-13340' 6467-6554' 1337' 3-1/2" Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Page 1/11 1D-39 Report Printed: 11/19/2024 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) 10/16/2024 00:00 10/16/2024 00:30 0.50 MIRU, MOVE DMOB P Trucks on location, move service module away from rig take down to end of pad and turn around. Stage out of way. 0.0 0.0 10/16/2024 00:30 10/16/2024 01:30 1.00 MIRU, MOVE MOB P Pull Drilling Sub off well 05, Pull pits around Drilling Sub 0.0 0.0 10/16/2024 01:30 10/16/2024 02:30 1.00 MIRU, MOVE MOB P Hang Tree in cellar, confirm/stage well head equipment on matting board. 0.0 0.0 10/16/2024 02:30 10/16/2024 03:30 1.00 MIRU, MOVE MOB P Spot Drilling Sub over well 1D-39. Set front mats and herculite, remove driller side well hand rails to make room for rig, set down Sub. Release from truck. 0.0 0.0 10/16/2024 03:30 10/16/2024 04:30 1.00 MIRU, MOVE MOB P Spot in pits, set mats and herculite release truck, set down Service Module, 0.0 0.0 10/16/2024 04:30 10/16/2024 05:00 0.50 MIRU, MOVE MOB P RU interconnect, berm in cellar, Service Module, and front of Drill Sub. Spot in cuttings tank, continue post rig move check list. 0.0 0.0 10/16/2024 05:00 10/16/2024 08:00 3.00 MIRU, WELCTL RURD P Rig Accepted @ 5am, began taking on Workover fluid into pits. Notified SW truck pony motor is not functioning. Call for replacement truck. RU circulating lines in cellar *** Note: Initial Pressures, Tubing 0, IA 0, OA 40 0.0 0.0 10/16/2024 08:00 10/16/2024 08:30 0.50 MIRU, WELCTL PRTS P Walk kill tank lines, PT lines T/3,500 psi, shut down repair 2nd 1502 union from choke manifold, continue PT. (good test) 0.0 0.0 10/16/2024 08:30 10/16/2024 11:00 2.50 MIRU, WELCTL DISP Displace well to 8.5ppg SW down the tubing @ 5 bpm, ICP 1,200 psi, taking returns to kill tank, FCP 1650, 432 bbls pumped total, Sim-ops - Load and strap DP in pipeshed starting number 390 0.0 0.0 10/16/2024 11:00 10/16/2024 11:30 0.50 MIRU, WELCTL OWFF P Check well for flow. (good no flow) 0.0 0.0 10/16/2024 11:30 10/16/2024 12:00 0.50 MIRU, WELCTL MPSP P Set H-type BPV w/T-bar, test down the IA T/1,000 psi 0.0 0.0 10/16/2024 12:00 10/16/2024 13:15 1.25 MIRU, WHDBOP RURD P Pull tree, secure in corner of cellar hanging, clean top of BPV and Test Dart, inspect threads. Good 0.0 0.0 10/16/2024 13:15 10/16/2024 16:15 3.00 MIRU, WHDBOP NUND P NU BOPE, Annular, 3.5"x5.5" VBR's,/Bllind Rams/Mud Cross/7' Fix bore rams. *** Note: Obtain RKB's 0.0 0.0 10/16/2024 16:15 10/16/2024 17:30 1.25 MIRU, WHDBOP RURD P Install riser, Fluid pack stack and surface lines. Bring 3.5" and 7" test joints to rig floor. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 2/11 1D-39 Report Printed: 11/19/2024 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) 10/16/2024 17:30 10/17/2024 00:00 6.50 MIRU, WHDBOP BOPE P Test BOPE 250 psi low/3,500 psi high, 7" test joint & 3.5" test joint: 1.) Blind Rams, CMV 1,2,3, & 16, Rig Floor Kill, Outer test spool valve, IBOP. 2.) CMV 4,5, & 6, HCR Kill, Inner Test Spool Valve & Manual IBOP. (fail/pass inner test spool valve, greased) 3.) 7" TJ, LWR Pipe Rams, HT-38 TIW & HT-38 Dart (Test fitting leaked twice) 4.) 7" TJ, Annular, CMV 7, 8, 9 & Manual Kill (fail/pass manual kill, greased) 5.)Hydraulic Super Choke & Manual Adjustable Choke (1,500 psi Test) 6.) 3-1/2" TJ, UPR rams, 3.5 FOSV, CMV 10-11 7.) 3-1/2" TJ, Annular, CMV 12-13-15 8.) CMV 14 9.) HCR Choke 10.) Manual Choke Perform Koomey Drawdown Test: Manifold Pressure 1600 psi, Accumulater Pressure 3,050 psi Pressure after all rams functioned=1,650 psi Upper Ram=6 sec Lower Ram=6 sec Annular=25 sec Blind=6 sec HCR Kill=1 sec HCR Choke=1 sec 200 psi Recovery=16 sec Full System Recovery=122 sec 5 Koomey Bottles @ 2,070 psi Test Witness Waived by Kam StJohn w/AOGCC 0.0 10/17/2024 00:00 10/17/2024 00:30 0.50 MIRU, WHDBOP BOPE P Finish up BOPE test 250 psi low/ 3500 psi high Koomey Unit Draw down 0.0 0.0 10/17/2024 00:30 10/17/2024 01:30 1.00 COMPZN, RPCOMP RURD P RD and blow down testing equipment 0.0 0.0 10/17/2024 01:30 10/17/2024 02:00 0.50 COMPZN, RPCOMP MPSP P Pull BPV and Pull Test Dart Valve 0.0 0.0 10/17/2024 02:00 10/17/2024 03:30 1.50 COMPZN, RPCOMP PULL P Prep RF for laying down tubing operations MU Nabors Tongs 0.0 0.0 10/17/2024 03:30 10/17/2024 04:00 0.50 COMPZN, RPCOMP PULL P MU landing joint to hanger, pull hanger to RF, PUW=60k, 100k breakover, PUW moving 95k 12,195.0 12,167.0 10/17/2024 04:00 10/17/2024 15:30 11.50 COMPZN, RPCOMP PULL P LD 3.5" 9.3# L-80, tubing *** Note: Cut joint 13.95' 12,167.0 0.0 10/17/2024 15:30 10/17/2024 16:30 1.00 COMPZN, WELLPR CLEN P Clean RF and continue processing DP 100 joints to go. 0.0 0.0 10/17/2024 16:30 10/18/2024 00:00 7.50 COMPZN, WELLPR BHAH P MU 6.125" tandem string mill drift w/junk mill. Sim-ops continue loading and tallying DP in pipe shed. 0.0 290.6 10/18/2024 00:00 10/18/2024 10:30 10.50 COMPZN, WELLPR TRIP P RIH with BHA #1 drift BHA w/ junk mill, string mills, boot baskets, string magnets, fishing jars and six 6-3/4" DC. 290.6 12,158.0 10/18/2024 10:30 10/18/2024 11:00 0.50 COMPZN, WELLPR TRIP P PUW=170, SOW=95k, lightly tag stump @ 12,191' 7ES RKB. 12,158.0 12,191.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 3/11 1D-39 Report Printed: 11/19/2024 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) 10/18/2024 11:00 10/18/2024 12:00 1.00 COMPZN, WELLPR CIRC P PUH, PUW 170k, circulate SxS with 25 bbl sweep of 200 vis, pumping 7 bpm/2,700 psi, Recip pipe @ 20 rpm, Free torque=7,300 ft/lbs, ROT WT=120k, F/12,180' T?12,115' *** Note: Dirty fluid w/diesel and gas. Send overboard 224 bbls, clean returns bring return back inside. 12,191.0 12,115.0 10/18/2024 12:00 10/18/2024 16:30 4.50 COMPZN, WELLPR TRIP P TOOH on stands F/12,115' T/sruface. UWT=170K / SOW = 100K 12,115.0 167.0 10/18/2024 16:30 10/18/2024 18:00 1.50 COMPZN, WELLPR BHAH P LD drift assembly BHA #1 Clean Magnets and Boot Baskets. 167.0 0.0 10/18/2024 18:00 10/18/2024 20:00 2.00 COMPZN, WELLPR RURD P RU E-line Yellow Jacket. 0.0 0.0 10/18/2024 20:00 10/18/2024 22:30 2.50 COMPZN, WELLPR ELOG P RIH W/WellTec Tractor and CBL Tools to 6350' and log up to surface. 0.0 0.0 10/18/2024 22:30 10/18/2024 23:30 1.00 COMPZN, WELLPR RURD P RD E-line Yellow Jacket. 0.0 0.0 10/18/2024 23:30 10/19/2024 00:00 0.50 COMPZN, WELLPR SVRG P Service top drive, blocks and Crown. 0.0 0.0 10/19/2024 00:00 10/19/2024 04:30 4.50 COMPZN, WELLPR BHAH P MU, BHA #2 G-lok RBP F/20' 0.0 20.3 10/19/2024 04:30 10/19/2024 05:00 0.50 COMPZN, WELLPR TRIP P TIH F/20' T/6,250', PUW=110k, SOW 85k 20.3 6,250.0 10/19/2024 05:00 10/19/2024 05:30 0.50 COMPZN, WELLPR MPSP Set G-lok @ 6,254' COE, Release from RBP 6,250.0 6,250.0 10/19/2024 05:30 10/19/2024 06:00 0.50 COMPZN, WELLPR MPSP P PT RBP to 1,000 psi for 10 mins charted. 6,250.0 6,254.0 10/19/2024 06:00 10/19/2024 12:30 6.50 COMPZN, WELLPR OTHR P Stand back one stand RU KB-1000, dump 22 // 60 lb sacks of sand 6,254.0 6,160.0 10/19/2024 12:30 10/19/2024 14:00 1.50 COMPZN, WELLPR SLPC P Allow sand to fall Slip and cut Drill Line (75') 6,160.0 6,160.0 10/19/2024 14:00 10/19/2024 14:30 0.50 COMPZN, WELLPR TRIP P TIH, no tag 6,247', stop, (top of plug @ 6,250') 6,160.0 6,204.0 10/19/2024 14:30 10/19/2024 17:00 2.50 COMPZN, WELLPR CIRC P TOOH F/5,681', started pulling wet 4th stand out, KBU, bring pump online slowly, pressure up to 335 psi pressure broke back 289 psi, circulated 1.5 bpm/130 psi. Continue circulating @ 1.5 bpm/130-300 psi until DP was clear of sand, 650 stks. 6,204.0 5,681.0 10/19/2024 17:00 10/19/2024 19:30 2.50 COMPZN, WELLPR TRIP P TIH to tag sand F/5,681' T/6250' Circulate surface to surface at 8 BPM /1550 psi. Latch on to G-lok, pull 15K then release from G-lok to confirm it is still at 6254' COE. 5,681.0 6,250.0 10/19/2024 19:30 10/19/2024 20:30 1.00 COMPZN, WELLPR MPSP P PT G-loc T/1000 psi for 10 min. Good test. Blow down kill line and top drive. 6,250.0 6,250.0 10/19/2024 20:30 10/19/2024 23:00 2.50 COMPZN, WELLPR TRIP P TOOH F/6250 T/Surface. PUW 115K 6,250.0 0.0 10/19/2024 23:00 10/19/2024 23:30 0.50 COMPZN, WELLPR BHAH P LD BHA #2 RBP running Tool. PU BHA #3 Mule shoe. 0.0 0.0 10/19/2024 23:30 10/20/2024 00:00 0.50 COMPZN, WELLPR TRIP P TIH F/surface T/1800 50K SOW 0.0 1,800.0 10/20/2024 00:00 10/20/2024 02:00 2.00 COMPZN, WELLPR TRIP P TIH F/1800' T/6251' 1,800.0 6,251.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 4/11 1D-39 Report Printed: 11/19/2024 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) 10/20/2024 02:00 10/20/2024 06:30 4.50 COMPZN, WELLPR MPSP P RU KB-1000 sand hopper, pump out stack, begin dumping sand down DP while keeping stack sucked out, dump 11 sacks, reciprocate pipe 2 hrs, dump 13 sacks, reciprocate pipe, Circulate 1.0 bpm/70 psi, PUH to safety T/6,060' 6,251.0 6,060.0 10/20/2024 06:30 10/20/2024 08:00 1.50 COMPZN, WELLPR TRIP P TIH F/6,060' T/6,243' with no tag. 6,060.0 6,243.0 10/20/2024 08:00 10/20/2024 10:00 2.00 COMPZN, WELLPR TRIP P Notify town team. TOOH F/6,243' T/4,170', start pulling WET, assuming we are plugged off, brake circulation @ 1.0 bpm/200 psi Shut down pump, 6,243.0 4,170.0 10/20/2024 10:00 10/20/2024 10:30 0.50 COMPZN, WELLPR CIRC P TBIH T/5,218' Bring pump online 5 bpm/580 psi, 20 RPM, TQ=3k, ROTWT=90k 4,170.0 5,218.0 10/20/2024 10:30 10/20/2024 11:30 1.00 COMPZN, WELLPR SVRG P Service rig while hesitating for sand to fall out of fluid. 5,218.0 5,218.0 10/20/2024 11:30 10/20/2024 14:00 2.50 COMPZN, WELLPR TRIP P TOOH on stands F/5218' T/surface 5,218.0 4.1 10/20/2024 14:00 10/20/2024 14:30 0.50 COMPZN, WELLPR BHAH P LD 3.5" Mule Shoe 4.1 0.0 10/20/2024 14:30 10/20/2024 15:00 0.50 COMPZN, WELLPR BHAH P MU Baker 6-1/8" PRT polish Mill w/no side cutting structure. 0.0 4.1 10/20/2024 15:00 10/20/2024 17:30 2.50 COMPZN, WELLPR TRIP P TIH w/Baker PRT Mill, Working each single in and out of hole. UWT=115K SOW=75K 4.1 6,145.0 10/20/2024 17:30 10/20/2024 19:30 2.00 COMPZN, WELLPR TRIP P TOOH from 6145' w/PUW 115K to 3030' w/PUW=78K 6,145.0 3,030.0 10/20/2024 19:30 10/20/2024 23:30 4.00 COMPZN, WELLPR TRIP P TIH w/Baker PRT Mill, Working each single in and out of hole. UWT=120K SOW=75K Attempt to push sand to bottom. No sand to tag. 3,030.0 6,145.0 10/20/2024 23:30 10/21/2024 00:00 0.50 COMPZN, WELLPR SVRG P Service iron rough neck 6,145.0 6,145.0 10/21/2024 00:00 10/21/2024 02:00 2.00 COMPZN, WELLPR MPSP P RU sand hopper, dump six 5 gallon buckets of 16/20 frac sand down DP at one bucket per 10 minutes. 6,145.0 6,145.0 10/21/2024 02:00 10/21/2024 04:00 2.00 COMPZN, WELLPR TRIP P TOOH from 6145' w/PUW 115K to 3030' w/PUW=78K 6,145.0 3,030.0 10/21/2024 04:00 10/21/2024 04:30 0.50 COMPZN, WELLPR TRIP P TIH, F/3,030' SOW=73k, T/6,240', SET DN 7k on top of sand, 3,030.0 6,240.0 10/21/2024 04:30 10/21/2024 06:30 2.00 COMPZN, WELLPR TRIP P PUW=120k, SOW=75k, Reciprocate each joint then full stand, attempt T/push sand down hole 6,240.0 6,240.0 10/21/2024 06:30 10/21/2024 07:30 1.00 COMPZN, WELLPR TRIP P TOOH, PUW=120k, SOW=75k 6,240.0 3,030.0 10/21/2024 07:30 10/21/2024 10:30 3.00 COMPZN, WELLPR CIRC P Circulate to cleanout DP, pump 25 bbls 200 vis sweep down DP @ 8 bpm/680 psi, reciprogate pipe at 15 RPM, TQ=1K, ROT WT=75k, sand at shaker. 3,030.0 3,505.0 10/21/2024 10:30 10/21/2024 12:30 2.00 COMPZN, WELLPR TRIP P RIH, F/3,505' T/6,240' Tag sand again 3,505.0 6,240.0 10/21/2024 12:30 10/21/2024 14:30 2.00 COMPZN, WELLPR TRIP P TOOH F/6,240' T/Surface LD Sand Saver 3000, PUW 110k, SOW=80 6,240.0 0.0 10/21/2024 14:30 10/21/2024 15:00 0.50 COMPZN, WELLPR BHAH P MU Johnny Wacker Jet stack 10 bpm, observe sand from wear ring. 0.0 0.0 10/21/2024 15:00 10/21/2024 17:30 2.50 COMPZN, CSGRCY NUND P Nipple down BOPE, rack back on pedistal and secure to shakles. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 5/11 1D-39 Report Printed: 11/19/2024 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) 10/21/2024 17:30 10/21/2024 19:30 2.00 COMPZN, CSGRCY OTHR P Prep, PJSM RU Cameron compression flange and casing growth system. Grow casing 19.625" total growth. hesitate for 30 mins 0.0 0.0 10/21/2024 19:30 10/22/2024 00:00 4.50 COMPZN, CSGRCY NUND P Pull packoff and MU spear assy. ND tubing head. Pull 50 over block weight and set E-slips on 7" casing. Cut off excess 7" CSG with WACHS cutter. Total Growth 19.625" and stretched 66.5" to get 86.13" 0.0 0.0 10/22/2024 00:00 10/22/2024 03:30 3.50 COMPZN, CSGRCY NUND P NU BOP stack, TQ flanges to spec, Install riser turnbuckles. 0.0 0.0 10/22/2024 03:30 10/22/2024 05:00 1.50 COMPZN, CSGRCY BHAH P L/D Spear BHA used for stretching CSG. 0.0 0.0 10/22/2024 05:00 10/22/2024 05:30 0.50 COMPZN, CSGRCY OTHR P Fill stack, and check for leaks. Add air to leaking air boot on riser. 0.0 0.0 10/22/2024 05:30 10/22/2024 06:00 0.50 COMPZN, CSGRCY BHAH P P/U BHA # 6 (MSC). Inspect cutter blades. 0.0 10.0 10/22/2024 06:00 10/22/2024 09:30 3.50 COMPZN, CSGRCY TRIP P RIH W/ BHA # 6 to 6080'. Start pumps @ 420 GPM @ 1530 PSI. Locate collar @ 6083'. 10.0 6,080.0 10/22/2024 09:30 10/22/2024 10:00 0.50 COMPZN, CSGRCY CPBO P Start pumps @ 420 GPM @ 1530 PSI. Locate collar @ 6083'. Set down 5K. Turn off pumps, and RIH to 10' Bellow collar @ 6093'. Obtain free rotating torque @ 65 RPM @ 4K TQ (W/O pumps). Start pumps @ 420 GPM @ 1530. Start pumps @ 420 GPM @ 1530 PSI. Rotate @ 65 RPM @ 4.8- 5.4K TQ. Observe pressure drop to ~ 530 PSI, TQ fall to 4 K. 6,080.0 6,093.0 10/22/2024 10:00 10/22/2024 11:00 1.00 COMPZN, CSGRCY CIRC P CBU @ 168 GPM @ 1262 PSI. 6,093.0 0.0 10/22/2024 11:00 10/22/2024 13:30 2.50 COMPZN, CSGRCY TRIP P POOH F/ 6093' to Surface. 6,093.0 0.0 10/22/2024 13:30 10/22/2024 13:45 0.25 COMPZN, CSGRCY BHAH P L/D MSC. Good indications of cut on knife blades. 0.0 0.0 10/22/2024 13:45 10/22/2024 14:00 0.25 COMPZN, CSGRCY BHAH P P/U BHA # 7 (Spear BHA). 0.0 0.0 10/22/2024 14:00 10/22/2024 14:30 0.50 COMPZN, CSGRCY FISH P RIH and engage top of 7" at well head. P/U to 165K broke over to 150K. P/U 2'. 0.0 6,093.0 10/22/2024 14:30 10/22/2024 16:30 2.00 COMPZN, CSGRCY CIRC P Close annuluar and Pump 120° F Sea water @ 3 BBL/Min @ 230 BBLS. Circulate until clean sea water returned to surface. R/U GBR equipment on rig floor. 6,093.0 6,093.0 10/22/2024 16:30 10/22/2024 18:00 1.50 COMPZN, CSGRCY FISH P Pull spear and 7" Casing to surface. L/D Spear and cut joint. Change out elevators and pull joint with slips to surface. FMC Remove casing slips. 6,093.0 6,013.0 10/22/2024 18:00 10/23/2024 00:00 6.00 COMPZN, CSGRCY PULL P POOH L/D 7" CSG F/ 6013' T/1052'. UWT=145K / DWT=110K 6,013.0 1,052.0 10/23/2024 00:00 10/23/2024 01:00 1.00 COMPZN, CSGRCY PULL P POOH L/D 7" CSG F/ 1052' to surface. Cut Jt. 11.31'. total of 148 Jts. 7" L/D. 11 Centralizers recovered. 1,052.0 0.0 10/23/2024 01:00 10/23/2024 01:30 0.50 COMPZN, CSGRCY CLEN P CLean and clear rig floor. R/D GBR CSG equipment. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 6/11 1D-39 Report Printed: 11/19/2024 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) 10/23/2024 01:30 10/23/2024 03:30 2.00 COMPZN, CSGRCY BOPE P Set test plug fill stack and purge air out of lines.. Test Break between BOP stack and CSG spool to 250 PSI low 3500 PSI High 5 min each: GOOD TEST. Pull test plug. 0.0 0.0 10/23/2024 03:30 10/23/2024 06:30 3.00 COMPZN, CSGRCY BHAH P M/U BHA # 8 (Drift BHA). 0.0 273.0 10/23/2024 06:30 10/23/2024 09:00 2.50 COMPZN, CSGRCY TRIP P RIH F/ 273' to 6093'. Set down 10K 2x to verify top of 7" stump. PUWT: 110 K SOWT: 80 K 273.0 6,093.0 10/23/2024 09:00 10/23/2024 09:45 0.75 COMPZN, CSGRCY CIRC P Pump around 20 BBL 180 Vis sweep. 336 GPM @ 1480 PSI. 6,093.0 6,093.0 10/23/2024 09:45 10/23/2024 10:00 0.25 COMPZN, CSGRCY OWFF P Flow check well 15 Min: static. 6,093.0 6,093.0 10/23/2024 10:00 10/23/2024 12:00 2.00 COMPZN, CSGRCY TRIP P POOH F/ 6093' to 273' 6,093.0 273.0 10/23/2024 12:00 10/23/2024 12:30 0.50 COMPZN, CSGRCY BHAH P L/D BHA # 8. No abnormal wear or markings on BHA. 273.0 0.0 10/23/2024 12:30 10/23/2024 14:00 1.50 COMPZN, CSGRCY BHAH P P/U BHA # 9 (Dress off BHA) 0.0 296.0 10/23/2024 14:00 10/23/2024 16:00 2.00 COMPZN, CSGRCY TRIP P RIH w/ Dress off BHA F/ 296' to 6093' UWT=110K/ SOW=80K 296.0 6,093.0 10/23/2024 16:00 10/23/2024 17:30 1.50 COMPZN, CSGRCY MILL P Dress off CSG stump F/6093' T/6094.5' @ 3BPM, PSI off bottom 330 psi, on bottom 550 psi. TQ off bottom 2.9K, TQ on bottom 7K ROT WT 98K, WOB 5 to 20 K 6,093.0 6,095.0 10/23/2024 17:30 10/23/2024 19:00 1.50 COMPZN, CSGRCY CIRC P Circulate and condition 25 bbl /200 vis sweep all the way around @ 8 BPM/ 1400 psi 6,090.0 6,090.0 10/23/2024 19:00 10/23/2024 19:30 0.50 COMPZN, CSGRCY OWFF P 15 min NFT: good no flow 6,090.0 6,090.0 10/23/2024 19:30 10/23/2024 22:00 2.50 COMPZN, CSGRCY TRIP P TOOH F/6090 T/296' UWT 110K/ DWT 85K 6,090.0 296.0 10/23/2024 22:00 10/23/2024 23:30 1.50 COMPZN, CSGRCY BHAH P LD Dress off BHA #9 296.0 0.0 10/23/2024 23:30 10/24/2024 00:00 0.50 COMPZN, CSGRCY SVRG P Greas the crown. 0.0 0.0 10/24/2024 00:00 10/24/2024 12:30 12.50 COMPZN, CASING PUTB P RIH with 7 " 26# L-80 HYD 563 casing. Torque turn each connection to 9400 ftlb. F/ Surface to 6058'. PUWT: 145 K SOWT: 110 K 0.0 6,058.0 10/24/2024 12:30 10/24/2024 13:00 0.50 COMPZN, CASING PUTB P P/U pup joints and space out. 6090' 6,058.0 6,090.0 10/24/2024 13:00 10/24/2024 13:45 0.75 COMPZN, CASING PUTB P Slack off and tag top of 7" w/ bottom of CSG Patch @ 6095.59' set down 5K. P/U 10', slack off set down 5K. P/U 10'. Rotate string 3/4 of a turn. Slack off observe 3-5K bobble @ 609.59'. Continue to slack off to 6095.78' Set down 30K P/U 55K over to 200K. S/O and set down 40K. P/U to 55K over (200K HKLD). 6,090.0 6,098.8 10/24/2024 13:45 10/24/2024 14:45 1.00 COMPZN, CASING RURD P R/U to test CSG patch, and purge air out of lines. 6,098.8 6,098.8 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 7/11 1D-39 Report Printed: 11/19/2024 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) 10/24/2024 14:45 10/24/2024 15:15 0.50 COMPZN, CASING PRTS P Pressure test CSG patch to 500 PSI for 10 min: GOOD TEST. * Load plug in CMNT head w/ HAL rep. Company rep witness function of flag, and 11.5 Turns of plug release valve. 6,098.8 6,098.8 10/24/2024 15:15 10/24/2024 15:45 0.50 COMPZN, CEMENT RURD P R/U HAL Cement head, and all lines. 6,098.8 6,098.8 10/24/2024 15:45 10/24/2024 16:15 0.50 COMPZN, CEMENT PACK P Open SLB ECP per SLB proceedure. Pressure up to 500 PSI and hold for 5 min. Pressure up to 1500 PSI @ .5 BBL/min. hold for 3 Min. Increase pressure 100 psi holding each step for 1 min. F/ 1500 PSI to 2300 PSI observe pressure drop over the 1 min pause indicating ECP inflating. Steps @ 2500, 2600 pressure remained stable indicating ECP inflation valve shut. Pressure up to 2869 PSI, HAL ES cementer sheared open. Returns up annulus. Pressure dropped to 0 PSI. 6,098.8 6,098.8 10/24/2024 16:15 10/24/2024 18:30 2.25 COMPZN, CEMENT CIRC P Line up and CBU 2 X @ 8 BPM @ 550 PSI. 6,098.8 6,098.8 10/24/2024 18:30 10/24/2024 19:00 0.50 COMPZN, CEMENT PRTS P PJSM and Pressure test Halliburton equipment yo 4000 psi. 6,098.8 6,098.8 10/24/2024 19:00 10/24/2024 22:00 3.00 COMPZN, CEMENT CMNT P Pump 20 BBLS spacer with red die followed by 265 BBLS 15.3 PPG cement. Chase wtih 20 BBLS of water. Chase with rig pumps @ 4 bpmi. ICP 400 PSI. FCP 2300 PSI. Bumped plug @ 212 BBLS. Hold 2800 psi for 5 min. Bleed pressure and check for flow @ flow line: No flow. Cement in place @ 2200 hours. 84 BBLs returned to surface. 6,098.8 0.0 10/24/2024 22:00 10/24/2024 22:30 0.50 COMPZN, CEMENT OWFF P Flow check well for 30 minutes. No flow. 0.0 0.0 10/24/2024 22:30 10/25/2024 00:00 1.50 COMPZN, CEMENT NUND P Flush rig and surface lines with contam pill. R/D cement head, R/D HES cementers. Blow down rig and lines to tank. ND BOPE and de-energize Koomey. 0.0 0.0 10/25/2024 00:00 10/25/2024 03:00 3.00 COMPZN, WELLPR NUND P Split the stack, set emergency slips and use Wacks cutter to cut 7" casing. 0.0 0.0 10/25/2024 03:00 10/25/2024 04:00 1.00 COMPZN, WELLPR NUND P Pull Cut 7" joint to the rig floor. Rack back BOP. 0.0 0.0 10/25/2024 04:00 10/25/2024 05:30 1.50 COMPZN, WELLPR NUND P Install Pack off and N/U Tubing spool. 0.0 0.0 10/25/2024 05:30 10/25/2024 06:00 0.50 COMPZN, WELLPR PRTS P Attempt to pressure test pack off. Unable to get pressure test. Observe leak from annulus valve. 0.0 0.0 10/25/2024 06:00 10/25/2024 08:30 2.50 COMPZN, WELLPR NUND T N/D Tubing spool. Pull pack off. Observe cut on lower pack off seal. Redress cut on 7" CSG. Reinstall Pack off. Upper packoff seal rolled off during setting of pack off. Pull Pack off, and redress seals. Reinstall pack off. N/U tubing spool. 0.0 0.0 10/25/2024 08:30 10/25/2024 09:30 1.00 COMPZN, WELLPR PRTS P Test pack off to 4000 PSI for 10 min: GOOD test. 0.0 0.0 10/25/2024 09:30 10/25/2024 11:30 2.00 COMPZN, WELLPR NUND P Install test plug in tubing spool. N/U BOP. 0.0 0.0 10/25/2024 11:30 10/25/2024 12:00 0.50 COMPZN, WELLPR BOPE P R/U and test Break on BOP 250 low, 3500 PSI high 5 min each: GOOD test. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 8/11 1D-39 Report Printed: 11/19/2024 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) 10/25/2024 12:00 10/25/2024 12:30 0.50 COMPZN, WELLPR SVRG P Service rig floor equipment, top drive, and crown. 0.0 0.0 10/25/2024 12:30 10/25/2024 14:00 1.50 COMPZN, WELLPR BHAH P P/U BHA # 10 (Cement clean out BHA). F/ Surface to 287'. 0.0 287.0 10/25/2024 14:00 10/25/2024 15:30 1.50 COMPZN, WELLPR TRIP P RIH F/ 287' to 5781' PUWT: 110 K SOWT: 80 K. 287.0 5,781.0 10/25/2024 15:30 10/25/2024 15:45 0.25 COMPZN, WELLPR WASH P Wash down F/ 5781' to 5912'. @ 5912' hit stringer w/ 10 K. 220 GPM @ 880 PSI 5,781.0 5,912.0 10/25/2024 15:45 10/25/2024 20:30 4.75 COMPZN, WELLPR DRLG P P/U 10' Start rotary @ 60 RPM and wash and ream down to top of cement @ 5988'. Continue to drill out Cement and ES cementer to 6240'. POOH one stand and Circulate High Vis Sweep. PUWT: 110 K SOWT: 80 K ROTWT: 95 K. 60 RPM @ 4.5 K Free torque 5K @ 10 K WOB. 220 GPM @ 880 PSI. 5,912.0 5,863.0 10/25/2024 20:30 10/25/2024 21:00 0.50 COMPZN, WELLPR OWFF P Flow check well for 15 minutes. 5,863.0 5,863.0 10/25/2024 21:00 10/25/2024 22:30 1.50 COMPZN, WELLPR SLPC P Slip and cut 92' drill line. 5,863.0 5,863.0 10/25/2024 22:30 10/25/2024 23:00 0.50 COMPZN, WELLPR CIRC P Pump a 20 bbl dry job. 5,863.0 5,863.0 10/25/2024 23:00 10/26/2024 00:00 1.00 COMPZN, WELLPR TRIP P TOOH F/5863' - T/4300' UWT=125K/DWT=75K 5,863.0 4,300.0 10/26/2024 00:00 10/26/2024 01:30 1.50 COMPZN, WELLPR TRIP P POOH with BHA #10 (mill tooth bit) 4,300.0 288.0 10/26/2024 01:30 10/26/2024 03:00 1.50 COMPZN, WELLPR BHAH P LD BHA #10 (mill tooth bit). 288.0 0.0 10/26/2024 03:00 10/26/2024 04:30 1.50 COMPZN, WELLPR BHAH P P/U BHA # 11 (RCJB). 0.0 279.0 10/26/2024 04:30 10/26/2024 07:00 2.50 COMPZN, WELLPR TRIP P RIH F/ 279' to 6240'. PUWT: 120 K SOWT: 75 K 279.0 6,240.0 10/26/2024 07:00 10/26/2024 08:00 1.00 COMPZN, WELLPR WASH P Turn on pumps to wash down. Observed abnormal pressure. Worked pressures, and cleared restriction in BHA. Pressures reduced to calculated pressure. Wash down F/ 6240' to 6245' @ 168 GPM @ 2600 PSI. 6,240.0 6,245.0 10/26/2024 08:00 10/26/2024 10:00 2.00 COMPZN, WELLPR CIRC P Pump High vis sweep. CMNT debris over shaker. Continue to circulate until good fluid in and out. 168 GPM @ 2640 PSI. 6,245.0 6,245.0 10/26/2024 10:00 10/26/2024 10:30 0.50 COMPZN, WELLPR OWFF P Flow check well: Static. Blow down top drive. 6,245.0 6,245.0 10/26/2024 10:30 10/26/2024 12:30 2.00 COMPZN, WELLPR TRIP P POOH F/ 6245' to 279' 6,245.0 279.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 9/11 1D-39 Report Printed: 11/19/2024 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) 10/26/2024 12:30 10/26/2024 14:30 2.00 COMPZN, WELLPR BHAH P L/D BHA # 11. Found pieces of ES cementer landing ring, plug rubber, and CMNT in RCJB. 279.0 0.0 10/26/2024 14:30 10/26/2024 15:00 0.50 COMPZN, WELLPR SVRG P Service top drive, blocks, iron roughneck, and pipe skate. 0.0 0.0 10/26/2024 15:00 10/26/2024 15:30 0.50 COMPZN, WELLPR OTHR P Unannounced man down drill. CRT: 97 seconds. Crew response excellent. AAR held with crew. 0.0 0.0 10/26/2024 15:30 10/26/2024 16:30 1.00 COMPZN, WELLPR BHAH P P/U BHA # 12. 0.0 279.0 10/26/2024 16:30 10/26/2024 20:30 4.00 COMPZN, WELLPR TRIP P RIH F/ 279' to 6177' PUWT: 125K / SOWT: 75K Fill pipe every 1000' 4BPM @ 500 psi 279.0 6,177.0 10/26/2024 20:30 10/26/2024 23:30 3.00 COMPZN, WELLPR WASH P Wash/Ream sand and junk off G-plug Circ 2BPM @170 psi, Drop RCJB ball and Pump 5.5 BPM @ 2580 psi until tag G-plug at 6250'. Set down 5K WOB 3X. Pump 20 BBL Hi -VIS sweep SXS 6BPM @ 3030 psi. 6,177.0 6,250.0 10/26/2024 23:30 10/27/2024 00:00 0.50 COMPZN, WELLPR OWFF P 15 minute flow check 6,250.0 6,250.0 10/27/2024 00:00 10/27/2024 02:30 2.50 COMPZN, WELLPR TRIP P POOH with RCJB BHA #12 6,250.0 279.0 10/27/2024 02:30 10/27/2024 05:00 2.50 COMPZN, WELLPR BHAH P LD RCJB BHA #12 279.0 0.0 10/27/2024 05:00 10/27/2024 05:30 0.50 COMPZN, WELLPR BHAH P P/U BHA # 13 (G-plug running tool). 0.0 30.0 10/27/2024 05:30 10/27/2024 08:00 2.50 COMPZN, WELLPR TRIP P RIH F/ 30' to 6160'. Attempt to kelly up to next stand. Torque stall prior to spinning into top drive. PUWT: 100 K SOWT: 74 K 30.0 6,160.0 10/27/2024 08:00 10/27/2024 08:30 0.50 COMPZN, WELLPR SVRG P Rig service. Service top drive. Trouble shoot torque issues. 6,160.0 6,160.0 10/27/2024 08:30 10/27/2024 19:00 10.50 COMPZN, WELLPR OTHR T Trouble shoot top drive. Remove torque booster motor from top drive and install block off plate. Rebuild Blak Jak. 6,160.0 6,160.0 10/27/2024 19:00 10/27/2024 21:00 2.00 COMPZN, WELLPR CIRC P Engage retreival tool into G-plug per Baker rep. Verify plug is free and circulate 40 bbl 100 vis sweep at 5 BPM /650 psi. UWT=120K/SOW=78K. Flow check well, no flow. 6,160.0 6,160.0 10/27/2024 21:00 10/28/2024 00:00 3.00 COMPZN, WELLPR TRIP P TOOH F/ 6160' T/2500' UWT=120K/DWT=78K 6,160.0 2,500.0 10/28/2024 00:00 10/28/2024 01:30 1.50 COMPZN, WELLPR TRIP P TOOH F/2500' T/12' UWT=120K/DWT=78K LD BHA#13 (G-plug retrieval tool). 2,500.0 0.0 10/28/2024 01:30 10/28/2024 02:30 1.00 COMPZN, WELLPR MPSP P PT 7" casing to 3,000 psi against plug at 12,293' for 30 minutes charted. 0.0 0.0 10/28/2024 02:30 10/28/2024 04:00 1.50 COMPZN, WELLPR BHAH P MU BHA #14 Dress off mill for tubing stub. 0.0 297.0 10/28/2024 04:00 10/28/2024 10:00 6.00 COMPZN, WELLPR TRIP P TIH F/297 T/12,127' UWT=195K/ DWT=90K 297.0 12,127.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 10/11 1D-39 Report Printed: 11/19/2024 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) 10/28/2024 10:00 10/28/2024 12:00 2.00 COMPZN, WELLPR REAM P Circ 2BPM/300 psi tag tbg stump at 12,200'. Set down 5K WOB. Increase pump rate 4.5 BPM/1030 psi. Set down 10K WOB. Pump pressure increase to 1580 psi, PU off bottom. EST ROT 75 RPM/11K TQ. Clean uip TBG stump as per BOT Rep. Pump 45 BBL sweep. Pump SXS STKS 5.5 BPM/1380 psi. UWT=195K/DWT=90K/ROT WT=115K 12,127.0 12,200.0 10/28/2024 12:00 10/28/2024 12:30 0.50 COMPZN, WELLPR OWFF P Flow check well for 15 minutes, Good test. 12,200.0 12,200.0 10/28/2024 12:30 10/28/2024 22:30 10.00 COMPZN, WELLPR TRIP P TOOH F/12200' T/279' UWT=195K/DWT=90K 12,200.0 279.0 10/28/2024 22:30 10/29/2024 00:00 1.50 COMPZN, WELLPR BHAH P LD BHA#14 F/ 279' to 100' 279.0 100.0 10/29/2024 00:00 10/29/2024 00:30 0.50 COMPZN, WELLPR BHAH P Cont. L/D BHA #14 F/ 100'' 100.0 0.0 10/29/2024 00:30 10/29/2024 01:00 0.50 COMPZN, RPCOMP OTHR P Pull wear bushing. 0.0 0.0 10/29/2024 01:00 10/29/2024 02:00 1.00 COMPZN, RPCOMP RURD P R/U GBR pipe handling equipment, prepare pipe shed for P/U tubing. 0.0 0.0 10/29/2024 02:00 10/29/2024 17:00 15.00 COMPZN, RPCOMP PUTB P RIH with 3-1/2" HYD563 completion. F/surface T/12195' 0.0 12,195.0 10/29/2024 17:00 10/29/2024 18:00 1.00 COMPZN, RPCOMP HOSO P Space out completion. located top of cut at 12,195' (7ES RKB) PUW=105K SOW= 65K Sat down on shear screws sheared screws W/12K down. Located fully set down at 12,202' 5K down. Place space out pups 1 full joint under hanger. 12,195.0 12,202.0 10/29/2024 18:00 10/29/2024 19:00 1.00 COMPZN, RPCOMP THGR P MU TBG HGR to string. MU circulation lines. 12,190.0 12,190.0 10/29/2024 19:00 10/29/2024 22:30 3.50 COMPZN, RPCOMP CIRC P Circulate corrosion inhibited seawater SxS at 3 BPM 440 PSI. 420 BBL's total pumped. 12,190.0 12,190.0 10/29/2024 22:30 10/30/2024 00:00 1.50 COMPZN, RPCOMP RURD P RD circ lines drop ball and rod. allow 30 minutes for rod to fall. 12,190.0 10/30/2024 00:00 10/30/2024 02:00 2.00 COMPZN, RPCOMP PACK P Pressure test tubing to 3500 PSI for 30 minutes with open 7" annulus. bleed tubing pressure back to 1500 PSI pressure test casing to 3000 PSI for 30 minutes. Bleed Tbg off and shear SOV. 12,200.0 12,200.0 10/30/2024 02:00 10/30/2024 03:30 1.50 COMPZN, RPCOMP RURD P RD testing equipment blow down surface lines. LD landing joint. 12,200.0 12,200.0 10/30/2024 03:30 10/30/2024 04:00 0.50 COMPZN, RPCOMP MPSP P Set BPV and pressure test to 1000 PSI for 10 minutes down IA. 12,200.0 12,200.0 10/30/2024 04:00 10/30/2024 10:30 6.50 COMPZN, WHDBOP NUND P Change rams in BOP stack to 2-7/8" x 5" VBR in lower. ND BOP's and rack back remove DSA. 12,200.0 12,200.0 10/30/2024 10:30 10/30/2024 12:30 2.00 COMPZN, WHDBOP NUND P NU Adapter and tree. 12,200.0 12,200.0 10/30/2024 12:30 10/30/2024 13:00 0.50 COMPZN, WHDBOP PRTS P Fluid pack and test hanger void to 250 low 5000 PSI for 10 min: Good test. 12,200.0 12,200.0 10/30/2024 13:00 10/30/2024 14:00 1.00 COMPZN, WHDBOP RURD P R/U circulating lines, and fluid pack tree diesel. 12,200.0 12,200.0 10/30/2024 14:00 10/30/2024 14:30 0.50 COMPZN, WHDBOP PRTS P Test tree to 5000 PSI 12,200.0 12,200.0 10/30/2024 14:30 10/30/2024 15:00 0.50 COMPZN, WHDBOP OTHR P Pull test dart, and BPV. 12,200.0 12,200.0 10/30/2024 15:00 10/30/2024 16:30 1.50 COMPZN, WHDBOP FRZP P PJSM. Flood and pressure test lines from LRS. Reverse circulate in 80 BBLs of Diesel freeze protect. 2 BBL/Min @ 350 PSI. 12,200.0 12,200.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Page 11/11 1D-39 Report Printed: 11/19/2024 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) 10/30/2024 16:30 10/30/2024 17:30 1.00 COMPZN, WHDBOP FRZP P U-tube diesel for 1 hour. 12,200.0 12,200.0 10/30/2024 17:30 10/30/2024 21:00 3.50 COMPZN, WHDBOP RURD P RD U-tube lines. Perform checklist to lay down derrick. Load out trucks. D/D R/D cellar lines secure cellar. 12,200.0 12,200.0 10/30/2024 21:00 10/31/2024 00:00 3.00 DEMOB, MOVE DMOB P Continue with rig move checklist. Lay over Derrick. Disconnect pits and interconnect. Blowdown steam. 12,200.0 12,200.0 10/31/2024 00:00 10/31/2024 00:00 DEMOB, MOVE DMOB P Continue with rig move check list. Trucks on location at XX:XX Prep to move rig. 12,200.0 10/31/2024 00:00 10/31/2024 05:00 5.00 DEMOB, MOVE MOB P Continue with rig move checklist. Lay over Derrick. Disconnect pits and interconnect. Blowdown steam. Install jeep onto pits, and pull away from sub. Load shop, and hook up to rig office. 12,200.0 12,200.0 Rig: NABORS 7ES RIG RELEASE DATE 10/31/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 13,377.0 1D-39 9/4/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig wellwork 1D-39 11/9/2024 claytg Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/23/2010 ninam 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 20 19.05 34.7 120.8 120.7 91.50 H-40 WELDED SURFACE 9 5/8 8.83 33.6 6,231.4 4,346.4 40.00 L-80 BTC-MOD 7" Tie-back String 7 6.28 33.6 6,097.0 4,304.3 26.00 L-80 HYD 563 PRODUCTION 7 6.28 6,093.0 12,370.5 6,250.7 26.00 J-55 BTC-MOD LINER 3 1/2 2.99 12,207.8 13,545.0 6,625.5 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 12,200.8 String Max No 3 1/2 Set Depth 6,195.1 Tubing Description Tubing - Production Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 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) 28.8 28.8 0.11 Hanger 10.880 FMC Gen V tubing hanger FMC Gen V 3.060 4,329.9 3,773.2 69.90 Mandrel GAS LIFT 5.968 3.5" x 1.5" MMG, GLM, SN#:24657- 18 SLB MMG 2.920 12,059.7 6,149.6 71.34 Mandrel GAS LIFT 5.968 3.5" x 1.5" MMG, GLM, SN#:24657- 12 SLB MMG 2.920 12,118.4 6,168.5 71.19 PACKER 5.999 7" x 3 1/2" SLB Bluepack Max Packer, SN#:C23P-1918 SLB Bluepac k max 2.894 12,173.4 6,186.2 71.19 Nipple 4.545 3 1/2" x 2.813 DS Nipple, SN#: 5461 -3 SLB DS 2.813 12,193.9 6,192.8 71.16 Overshot 6.000 3.5" INNO poor boy overshot (2' off fully located) Inno 4.500 Top (ftKB) 12,195.9 Set Depth 12,221.2 String Max No 3 1/2 Set Depth 6,201.7 Tubing Description Tubing - Production Wt (lb/ft) 9.30 Grade L-80 Top Connection 8RD MOD 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) 12,210.9 6,198.3 71.10 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 12,211.9 6,198.7 71.09 SEAL ASSY 5.000 BAKER SEAL ASSEMBLY 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 12,195.0 6,193.2 71.16 CUT WELLTEC MECHANICAL TUBING CUT. TATTLE-TAIL INDICATED 3.61" BLADE EXTENSION. 9/9/2024 2.992 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) 4,329.9 3,773.2 69.90 1 INJ DV RK 1 1/2 11/8/2024 Camco MMG 12,059.7 6,149.6 71.34 2 INJ DMY RK 1 1/2 10/29/2024 Camco MMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.6 33.6 0.12 HYD 563 x Butress X/O for CMNT head 0.000 HYD 563 x Butress X/O for CMNT head 0.000 6,017.5 4,278.7 71.25 Collar - Stage 8.150 HES Cementer 7" HAL ES II 6.276 6,032.9 4,283.6 71.24 PACKER 8.150 7"x9-5/8" SLB AZIP ECP Packer SLB ECP-C 6.276 12,207.8 6,197.3 71.11 TIE BACK 7.000 LINER TIE BACK SLEEVE 5.250 12,215.1 6,199.7 71.08 PACKER 7.000 BAKER ZXP FLEXLOCK LINER TOP PACKER w/ 5" TKC COUPLING 5.250 12,293.5 6,225.3 70.78 NIPPLE 4.520 HOWCO XN NIPPLE: 2.81" polish bore w/ 2.75" NO GO 2.750 13,477.0 6,601.5 69.33 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,070.0 13,090.0 6,467.0 6,472.9 C-4, 1D-39 4/24/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,090.0 13,130.0 6,472.9 6,484.9 C-4, 1D-39 11/2/2008 6.0 APERF 2.5: PJ 2506 HMX 13,130.0 13,160.0 6,484.9 6,494.3 C-4, 1D-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 13,160.0 13,180.0 6,494.3 6,500.6 C-4, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,181.0 13,216.0 6,501.0 6,512.3 C-4, 1D-39 6/5/2011 6.0 IPERF 2.5" RDX Prospector, 60 deg phasing, 11 gram 13,216.0 13,256.0 6,512.3 6,525.5 C4, C3, C2, 1D- 39 5/22/2011 6.0 IPERF 2.5" RDX Prospector, 60 deg phasing, 11 gram 13,256.0 13,286.0 6,525.5 6,535.7 C-2, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 1D-39, 11/26/2024 3:44:33 PM Vertical schematic (actual) LINER; 12,207.8-13,545.0 IPERF; 13,320.0-13,340.0 IPERF; 13,310.0-13,320.0 APERF; 13,285.0-13,310.0 IPERF; 13,256.0-13,286.0 IPERF; 13,216.0-13,256.0 HPBD; 13,070.0 IPERF; 13,181.0-13,216.0 IPERF; 13,160.0-13,180.0 APERF; 13,130.0-13,160.0 APERF; 13,090.0-13,130.0 IPERF; 13,070.0-13,090.0 PRODUCTION ; 6,093.0- 12,370.5 CUT; 12,195.0 Nipple; 12,173.4 PACKER; 12,118.3 Mandrel GAS LIFT; 12,059.7 SURFACE; 33.6-6,231.4 7" Tie-back String; 33.6-6,097.0 Mandrel GAS LIFT; 4,329.9 Intermediate String 1 Cement; 33.6 ftKB CONDUCTOR; 34.7-120.7 Hanger; 28.8 KUP INJ KB-Grd (ft) RR Date 2/7/2001 Other Elev 1D-39 ... TD Act Btm (ftKB) 13,545.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292299700 Wellbore Status INJ Max Angle & MD Incl (°) 74.55 MD (ftKB) 5,624.87 WELLNAME WELLBORE1D-39 Annotation Last WO: End Date 11/22/2005 H2S (ppm) DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,285.0 13,310.0 6,535.3 6,543.8 C-1, 1D-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 13,310.0 13,320.0 6,543.8 6,547.2 C-1, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,320.0 13,340.0 6,547.2 6,554.0 C-1, 1D-39 4/22/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 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) 13,070.0 13,340.0 1 HPBD 5/1/2001 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 33.6 6,095.0 33.6 4,303.6 Intermediate String 1 Cement Good cement job, 84 bbls back to surface. 10/24/2024 1D-39, 11/26/2024 3:44:33 PM Vertical schematic (actual) LINER; 12,207.8-13,545.0 IPERF; 13,320.0-13,340.0 IPERF; 13,310.0-13,320.0 APERF; 13,285.0-13,310.0 IPERF; 13,256.0-13,286.0 IPERF; 13,216.0-13,256.0 HPBD; 13,070.0 IPERF; 13,181.0-13,216.0 IPERF; 13,160.0-13,180.0 APERF; 13,130.0-13,160.0 APERF; 13,090.0-13,130.0 IPERF; 13,070.0-13,090.0 PRODUCTION ; 6,093.0- 12,370.5 CUT; 12,195.0 Nipple; 12,173.4 PACKER; 12,118.3 Mandrel GAS LIFT; 12,059.7 SURFACE; 33.6-6,231.4 7" Tie-back String; 33.6-6,097.0 Mandrel GAS LIFT; 4,329.9 Intermediate String 1 Cement; 33.6 ftKB CONDUCTOR; 34.7-120.7 Hanger; 28.8 KUP INJ 1D-39 ... WELLNAME WELLBORE1D-39 Originated: Delivered to:12-Sep-24 Alaska Oil & Gas Conservation Commiss 12Sep24-NR ATTN: MeredithGuhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24 CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24 CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24 2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39555 T39556 T39557 T39558 T39559 T39560 T39561 T39562 T39564 T39565 T39566 T39567 T39668 T39563 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.13 08:31:59 -08'00' 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 T39565 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13545' 6625' 13278'2988 None None Casing Collapse Conductor Surface Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-265-6049 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 TVD Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 12215'MD/6200'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650, ADL0025661 200-216 P.O. Box 100360, Anchorage, AK 99510 50-029-22997-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 12221' MD 120' 4346' 6251' 120' 6231' 20" 9-5/8" 88' Baker ZXP Liner Top SSSV: None 7"12337' 6197' Perforation Depth MD (ft): 12371' KRU 1D-39 13070'-13340' 3-1/2" 6467'-6554' 9/20/2024 13545'1337/ 3-1/2" 6626' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-457 By Grace Christianson at 8:04 am, Aug 07, 2024 10-407 DSR-8/12/24VTL 9/5/2024 A.Dewhurst 22AUG24 X BOP test to 3500 psig Annular preventer test to 2500 psig X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.06 14:45:22 -07'00'09/06/24 RBDMS JSB 091024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 31, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Injector 1D- 39 (PTD# 200-216). Well 1D-39 was drilled and completed in February of 2001 by Nabors 16E as a Kuparuk C sand injector. A rig workover was performed in 2005 to replace the 3-1/2” tubing. The well has had a healthy life since the workover until it was found with a fluid level near surface in the conductor in July of 2023. Subsequent diagnostics identified bubbling in the conductor and a surface casing leak at ~150’ after a small amount of nitrogen was pumped into the OA. The well has been shut in since July of 2023 and requires a workover to remediate the surface casing leak. To repair the SC leak, we request approval to proceed with a subsidence-style RWO. The 3-1/2” tubing will be pulled from a pre-rig cut above the liner top packer, 7” production casing will be pulled and replaced, then the 7” x 9-5/8” annulus will be cemented to surface. A 3-1/2” completion including a non-sealing overshot and a stacked packer will be installed. Additionally, we are requesting a variance from 20 AAC 25.412(b) to stack the packer greater than 200’ MD above the top perforation. The 4/12/2001 CBL of the 3-1/2” liner shows TOC at ~12,250’ RKB (bottom of SBE on ZXP packer). The production casing has an estimated TOC at 11488’ RKB per the 1/21/2001 cementing detail report. The anticipated packer set depth is ~12110’ RKB. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 1D-39 Kuparuk Injector Tubing Swap with Subsidence Repair PTD: 200-216 Page 1 of 2 PPre-Rig Work 1. T-POT/PPPOT and IC-POT/PPPOT. 2. Function test LDS. 3. SBHP. 4. Set plug in liner. 5. CMIT-TxIA against plug. 6. CDDT-TxIAxOA. 7. Tubing cut at ~12,195’ RKB. Punch hole in tubing above cut if necessary for circulation point. 8. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1D-39. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. 7” Casing Subsidence Repair 6. RU E-Line and log 7” casing from tubing stub to surface to verify free pipe. a. No Arctic Pack cement was pumped in this well. 7. Set plug in 7” casing. PT to confirm plug is set. Dump sand on top of plug. 8. ND BOPE. ND tubing head using Hydratight as needed to grow casing. Pull casing in tension and land in slips. NU BOPE to casing head. a. Test flange break as soon as practical once test plug can be installed. 9. RIH and cut 7” casing. a. Shut in annular and circulate freeze protect out of OA as needed. 10. Pull 7” casing from cut. a. Make additional cuts in 7” casing to remove in sections if necessary. 11. Install test plug and test BOPE flange break to 250/3,500 psi. 12. RIH with mills to ensure drift for overshot casing patch, cementer and 7” x 9-5/8” packer. a. Bore out 9-5/8” casing to create drift as necessary. 13. MU and RIH with overshot casing patch, ES cementer, 7” x 9-5/8” packer and new 7” casing. 14. Engage overshot, set packer, PT casing to 3,000 psi. 15. Cement 7” x 9-5/8” annulus to surface. 16. ND BOPE, set casing slips, cut excess 7” casing and install packoffs. NU new tubing head and BOPE. Test breaks to 250/3,500 psi. 17. RIH and mill up cement and plugs in cementer. 18. RIH and wash sand from top of plug. Retrieve plug. 1D-39 Kuparuk Injector Tubing Swap with Subsidence Repair PTD: 200-216 Page 2 of 2 19. Perform additional cleanout runs if necessary. Install 3-1/2” Completion with Stacked Packer 20. RIH to tubing stub and dress off stub as needed. 21. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 22. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 23. Land tubing hanger, RILDS, PT packoffs, drop ball/rod, and set packer. 24. Pressure test tubing to 3,500 PSI. 25. Pressure test IA to 3,000 PSI. ND BOP, NU Tree 26. Shear out SOV with pressure differential. 27. Install BPV and test. ND BOPE. NU tree. 28. Pull BPV and freeze protect well. 29. RDMO. PPost-Rig Work 1. Pull SOV and replace with DV. 2. Pull any plugs and ball/rod used for setting packer. General Well Information: Estimated Start Date: 9/20/2024 Current Operations: Shut-In Well Type: Injector Wellhead Type: FMC Gen V. 11”5M casing head top flange. 11” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 3,611 psi / 6,227’ TVD measured on 5/24/2023 MPSP: 2,988 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut, perform subsidence-style repair to remediate SC leak, install a new 3-1/2” completion with a stacked packer. Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Reservoir Surveillance Engineer: Cody Keith Production Engineer: Banabas Dogah Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 13,278.0 1D-39 5/16/2011 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Welded a 9" conductor extension 1D-39 6/2/2023 bsgreen Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/23/2010 ninam 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 20 19.05 34.7 120.8 120.7 91.50 H-40 WELDED SURFACE 9 5/8 8.83 33.6 6,231.4 4,346.4 40.00 L-80 BTC-MOD PRODUCTION 7 6.28 33.6 12,370.5 6,250.7 26.00 J-55 BTC-MOD LINER 3 1/2 2.99 12,207.8 13,545.0 6,625.5 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 20.4 Set Depth … 12,221.2 Set Depth … 6,201.7 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8RD MOD 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) 20.4 20.4 0.07 HANGER 11.000 FMC TUBING HANGER 2.992 470.6 470.5 2.88 NIPPLE 4.520 CAMCO DS LANDING NIPPLE 2.875 4,256.9 3,747.0 68.03 GAS LIFT 5.390 CAMCO KBUG 2.920 12,210.9 6,198.3 71.10 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 12,211.8 6,198.6 71.09 SEAL ASSY 5.000 BAKER SEAL ASSEMBLY 2.990 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) 4,256.9 3,747.0 68.03 1 GAS LIFT DMY BK 1 0.0 11/29/2005 11:30 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,207.8 6,197.3 71.11 TIE BACK 7.000 LINER TIE BACK SLEEVE 5.250 12,215.1 6,199.7 71.08 PACKER 7.000 BAKER ZXP FLEXLOCK LINER TOP PACKER w/ 5" TKC COUPLING 5.250 12,293.5 6,225.3 70.78 NIPPLE 4.520 HOWCO XN NIPPLE w/ 2.75" NO GO 2.750 13,477.0 6,601.5 69.33 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,070.0 13,090.0 6,467.0 6,472.9 C-4, 1D-39 4/24/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,090.0 13,130.0 6,472.9 6,484.9 C-4, 1D-39 11/2/2008 6.0 APERF 2.5: PJ 2506 HMX 13,130.0 13,160.0 6,484.9 6,494.3 C-4, 1D-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 13,160.0 13,180.0 6,494.3 6,500.6 C-4, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,181.0 13,216.0 6,501.0 6,512.3 C-4, 1D-39 6/5/2011 6.0 IPERF 2.5" RDX Prospector, 60 deg phasing, 11 gram 13,216.0 13,256.0 6,512.3 6,525.5 C4, C3, C2, 1D- 39 5/22/2011 6.0 IPERF 2.5" RDX Prospector, 60 deg phasing, 11 gram 13,256.0 13,286.0 6,525.5 6,535.7 C-2, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,285.0 13,310.0 6,535.3 6,543.8 C-1, 1D-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 13,310.0 13,320.0 6,543.8 6,547.2 C-1, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,320.0 13,340.0 6,547.2 6,554.0 C-1, 1D-39 4/22/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 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) 13,070.0 13,340.0 1 HPBD 5/1/2001 0.0 0.00 0.00 1D-39, 6/2/2023 4:58:34 PM Vertical schematic (actual) LINER; 12,207.8-13,545.0 FLOAT SHOE; 13,543.2- 13,545.0 FLOAT COLLAR; 13,510.1- 13,511.3 LANDING COLLAR; 13,477.0- 13,478.1 IPERF; 13,320.0-13,340.0 IPERF; 13,310.0-13,320.0 APERF; 13,285.0-13,310.0 IPERF; 13,256.0-13,286.0 IPERF; 13,216.0-13,256.0 HPBD; 13,070.0 IPERF; 13,181.0-13,216.0 IPERF; 13,160.0-13,180.0 APERF; 13,130.0-13,160.0 APERF; 13,090.0-13,130.0 IPERF; 13,070.0-13,090.0 PRODUCTION; 33.6-12,370.5 FLOAT SHOE; 12,369.0- 12,370.5 NIPPLE; 12,293.5-12,294.9 FLOAT COLLAR; 12,287.8- 12,289.1 SBE; 12,234.6-12,255.8 HANGER; 12,222.7-12,234.6 PACKER; 12,215.1-12,222.7 SEAL ASSY; 12,211.8 TIE BACK; 12,207.8-12,215.1 NIPPLE; 12,210.9 SURFACE; 33.6-6,231.4 FLOAT SHOE; 6,229.7-6,231.4 FLOAT COLLAR; 6,145.7- 6,147.2 GAS LIFT; 4,257.0 NIPPLE; 470.6 CONDUCTOR; 34.7-120.7 HANGER; 33.6-37.1 HANGER; 33.6-35.5 HANGER; 20.4 KUP INJ KB-Grd (ft) RR Date 2/7/2001 Other Elev… 1D-39 ... TD Act Btm (ftKB) 13,545.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292299700 Wellbore Status INJ Max Angle & MD Incl (°) 74.55 MD (ftKB) 5,624.87 WELLNAME WELLBORE1D-39 Annotation Last WO: End Date 11/22/2005 H2S (ppm) DateComment SSSV: NIPPLE 1D-39 Proposed Schematic COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 120.8 120.7 20 19.05 91.5 H-40 Weld Weld Surface 6231.4 4346.4 9-5/8 8.835 40 L-80 BTC-MOD BTC-MOD Production 12370.5 6250.7 7 6.276 26 J-55 BTC-MOD BTC-MOD Liner 13545 6625.5 3-1/2 2.992 9.3 L-80 SLHT SLHT Tubing 12221.2 6201.7 3-1/2 2.992 9.3 L-80 EUE 8rd M EUE 8rd M PROPOSED 7" SUBSIDENCE REPAIR 7" L-80 Casing to Surface 7" HES Cementer 7" x 9-5/8" Packer 7" Overshot Casing Patch PROPOSED COMPLETION 3-1/2" L-80 9.3# Hyd563 Tubing to Surface 3-1/2" x 1-1/2" Gas Lift Mandrel @ 4250' RKB 3-1/2" x 7" Packer 3-1/2" DS Landing Nipple Profile (2.813" ID) 3-1/2" Non-sealing Overshot EXISTING COMPLETION Camco DS Nipple @ 12210' RKB (2.813" ID) Baker Locator Seal Assembly @ 12211' RKB Liner TieBack Sleeve @ 12208' RKB Baker ZXP FlexLock Liner Top Packer @ 12215' RKB Howco XN Nipple Profile @12293' RKB (2.75" ID) Surface Casing 6231' RKB Production Casing 12370' RKB Conductor 120' RKB C-sand perfs 13070' - 13320' RKB Liner 12207' - 13545' RKB From:Eller, Cy To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]RE: KRU 1D-39 10-403 RWO Date:Wednesday, September 4, 2024 10:59:03 AM Hi Victoria, The only CBL that I have been able to find is the one that was run on 4/12/2001. This well was drilled and completed with Nabors 16E, and they ran the 3-1/2” completion on 2/7/2001 so the CBL was only able to log the cement on the backside of the 3-1/2” liner up to the liner top packer. The cement detail for the production casing cement job stated that the estimated TOC was calculated at 11,488’ RKB. Based on this, the production casing TOC should be well above the anticipated packer set depth for the workover. Thank you, Cy From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, September 4, 2024 10:13 AM To: Eller, Cy <Cy.Eller@conocophillips.com> Subject: Re: [EXTERNAL]RE: KRU 1D-39 10-403 RWO I’m concerned about the packer being placed where the CBL shows no cement behind the production casing even though this was approved for the initial packer. Please provide depths and zones open above the TOC as determined by the CBL. Victoria Sent from my iPhone On Sep 4, 2024, at 9:15ௗAM, Eller, Cy <Cy.Eller@conocophillips.com> wrote: Hi Victoria, Would it be possible to get verbal approval to make the pre-rig cut on KRU injector 1D-39? The well is roughly two weeks out on the rig schedule, and we would like to get started with the pre-rig work this coming weekend if possible. Please let me know if you have any questions. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska Office: 907-265-6049 Cell: 907-232-4090 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, August 7, 2024 8:09 AM To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Cc: Eller, Cy <Cy.Eller@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]RE: KRU 1D-39 10-403 RWO CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. This application has been received for processing. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 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 Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Tuesday, August 6, 2024 3:58 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Cc: Eller, Cy <Cy.Eller@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: KRU 1D-39 10-403 RWO Hello – See attached 10-403 for 1D-39 RWO. Please let me know if you need additional information. Thank you, Jenna CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1D-39 (PTD# 200-216) Conductor Date:Monday, July 10, 2023 9:07:10 AM From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, July 7, 2023 12:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1D-39 (PTD# 200-216) Conductor Chris— KRU injection well 1D-39 (PTD# 200-216) was found with a fluid level near surface in the conductor. To follow up on this, DHD today pumped a small amount of nitrogen into the surface casing and observed bubbling in the conductor. Our intent is to have the well WAG’d to water injection in order to displace the tubing to fluid. Then the well will be shut-in and freeze-protected as soon as operationally feasible. DHD will conduct diagnostics and the well will remain shut-in until we can submit paperwork for a path forward. Please let me know if you have any questions or disagree with the plan. Travis Travis Smith 907-350-9119 Travis.T.Smith@conocophillips.com Coverage for: Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 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: Conductor Extension 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 13,545' feet N/A feet true vertical 6,625' feet N/A feet Effective Depth measured feet 12,215' feet true vertical feet 6,200' feet Perforation depth Measured depth 13,070' - 13,340'feet True Vertical depth 6,467' - 6,554'feet Tubing (size, grade, measured and true vertical depth) 3 1/2" L-80 12,221' 6,202' Packers and SSSV (type, measured and true vertical depth) 471' MD 471' TVD 12,212' MD 6,199' TVD 12,215' MD 6,200' TVD 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: 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: 322-500 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SSSV: CAMCO DS LANDING NIPPLE Packer: BAKER SEAL ASSEMBLY 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Liner 12,337' 1,337' Casing Length 86.75' 6,197' Conductor Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure KUPARUK RIV UNIT 1D-39 measured true vertical Packer N/A ADL0025650 / ADL0025661 KUPARUK RIVER / KUPARUK RIVER OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-216 5002922997-0000 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ConocoPhillips Alaska, Inc. P.O. Box 100360, Anchorage, AK 99510 3. Address: Plugs Junk measured 120.75'20" Size 120.75' measured TVDMD Surface 6,251' 6,231' 4,346' 7" 12,371' 9 5/8" Production Burst Collapse Packer: BAKER ZXP FLEXLOCK LINER TOP PACKER 3 1/2" 13,545' 6,626' Brennen Green & Roger Mouser N1927@conocophillips.com 907-659-7506Well Integrity Field Supervisor N/A p k ft t Fra O s 200 6. A G L PG , n Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.06.02 18:23:03-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green Date Event Summary Executive Summary Welded Conductor Extension 08/30/22 Received AOGCC sundry # 322-500 for conductor extension 03/11/23 9" Tree rise. Gas readings in the cellar and conductor are normal. 06/01/23 NES Welder welded a 9" long X 20" diameter X 0.500" wall Conductor extension to the existing Conductor P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 2, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for well KRU 1D-39 (PTD # 200-216) 9 Conductor extension. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.06.02 18:21:52-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 13,278.0 1D-39 5/16/2011 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Welded a 9" conductor extension 1D-39 6/2/2023 bsgreen Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 8/23/2010 ninam 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 20 19.05 34.7 120.8 120.7 91.50 H-40 WELDED SURFACE 9 5/8 8.83 33.6 6,231.4 4,346.4 40.00 L-80 BTC-MOD PRODUCTION 7 6.28 33.6 12,370.5 6,250.7 26.00 J-55 BTC-MOD LINER 3 1/2 2.99 12,207.8 13,545.0 6,625.5 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 20.4 Set Depth 12,221.2 Set Depth 6,201.7 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8RD MOD 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) 20.4 20.4 0.07 HANGER 11.000 FMC TUBING HANGER 2.992 470.6 470.5 2.88 NIPPLE 4.520 CAMCO DS LANDING NIPPLE 2.875 4,256.9 3,747.0 68.03 GAS LIFT 5.390 CAMCO KBUG 2.920 12,210.9 6,198.3 71.10 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 12,211.8 6,198.6 71.09 SEAL ASSY 5.000 BAKER SEAL ASSEMBLY 2.990 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) 4,256.9 3,747.0 68.03 1 GAS LIFT DMY BK 1 0.0 11/29/2005 11:30 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,207.8 6,197.3 71.11 TIE BACK 7.000 LINER TIE BACK SLEEVE 5.250 12,215.1 6,199.7 71.08 PACKER 7.000 BAKER ZXP FLEXLOCK LINER TOP PACKER w/ 5" TKC COUPLING 5.250 12,293.5 6,225.3 70.78 NIPPLE 4.520 HOWCO XN NIPPLE w/ 2.75" NO GO 2.750 13,477.0 6,601.5 69.33 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 13,070.0 13,090.0 6,467.0 6,472.9 C-4, 1D-39 4/24/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,090.0 13,130.0 6,472.9 6,484.9 C-4, 1D-39 11/2/2008 6.0 APERF 2.5: PJ 2506 HMX 13,130.0 13,160.0 6,484.9 6,494.3 C-4, 1D-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 13,160.0 13,180.0 6,494.3 6,500.6 C-4, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,181.0 13,216.0 6,501.0 6,512.3 C-4, 1D-39 6/5/2011 6.0 IPERF 2.5" RDX Prospector, 60 deg phasing, 11 gram 13,216.0 13,256.0 6,512.3 6,525.5 C4, C3, C2, 1D- 39 5/22/2011 6.0 IPERF 2.5" RDX Prospector, 60 deg phasing, 11 gram 13,256.0 13,286.0 6,525.5 6,535.7 C-2, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,285.0 13,310.0 6,535.3 6,543.8 C-1, 1D-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 13,310.0 13,320.0 6,543.8 6,547.2 C-1, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,320.0 13,340.0 6,547.2 6,554.0 C-1, 1D-39 4/22/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 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) 13,070.0 13,340.0 1 HPBD 5/1/2001 0.0 0.00 0.00 1D-39, 6/2/2023 4:58:34 PM Vertical schematic (actual) LINER; 12,207.8-13,545.0 FLOAT SHOE; 13,543.2- 13,545.0 FLOAT COLLAR; 13,510.1- 13,511.3 LANDING COLLAR; 13,477.0- 13,478.1 IPERF; 13,320.0-13,340.0 IPERF; 13,310.0-13,320.0 APERF; 13,285.0-13,310.0 IPERF; 13,256.0-13,286.0 IPERF; 13,216.0-13,256.0 HPBD; 13,070.0 IPERF; 13,181.0-13,216.0 IPERF; 13,160.0-13,180.0 APERF; 13,130.0-13,160.0 APERF; 13,090.0-13,130.0 IPERF; 13,070.0-13,090.0 PRODUCTION; 33.6-12,370.5 FLOAT SHOE; 12,369.0- 12,370.5 NIPPLE; 12,293.5-12,294.9 FLOAT COLLAR; 12,287.8- 12,289.1 SBE; 12,234.6-12,255.8 HANGER; 12,222.7-12,234.6 PACKER; 12,215.1-12,222.7 SEAL ASSY; 12,211.8 TIE BACK; 12,207.8-12,215.1 NIPPLE; 12,210.9 SURFACE; 33.6-6,231.4 FLOAT SHOE; 6,229.7-6,231.4 FLOAT COLLAR; 6,145.7- 6,147.2 GAS LIFT; 4,257.0 NIPPLE; 470.6 CONDUCTOR; 34.7-120.7 HANGER; 33.6-37.1 HANGER; 33.6-35.5 HANGER; 20.4 KUP INJ KB-Grd (ft) RR Date 2/7/2001 Other Elev 1D-39 ... TD Act Btm (ftKB) 13,545.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292299700 Wellbore Status INJ Max Angle & MD Incl (°) 74.55 MD (ftKB) 5,624.87 WELLNAME WELLBORE1D-39 Annotation Last WO: End Date 11/22/2005 H2S (ppm) DateComment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y Samantha Carlisle at 8:32 am, Aug 22, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1 & 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ ( Q #FRQRFRSKLOOLSVFRP 5HDVRQ ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ \RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ $'/ 6)' 6)' '65 3KRWR GRFXPHQW DOO VWHSV RI WKH SURFHGXUH LQFOXGLQJ ZLQGRZ FXWWLQJ OHDN UHSDLU DQG VLWH FOHDUDQFH ; 97/ GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.30 12:40:39 -08'00' RBDMS JSB 090122 32%2; $1&+25$*($/$6.$ $XJXVW &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 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Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-39 KUPARUK RIV UNIT 1D-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 1D-39 50-029-22997-00-00 200-216-0 W SPT 6200 2002160 1550 1876 1878 1877 1877 64 69 69 69 4YRTST P Austin McLeod 7/13/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-39 Inspection Date: Tubing OA Packer Depth 690 2710 2645 2640IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220714083949 BBL Pumped:2.4 BBL Returned:2.3 Thursday, August 18, 2022 Page 1 of 1 9 9 99 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:13:48 -08'00' • • 2 (,)•-•Z�Co WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 %v/%5/2015 K.BENDER Anchorage, Alaska 99501 - OCT 0 8 2015 RE: Multi Finger Caliper(MFC): 1D-39 AOGCC Run Date: 9/1/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-39 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22997-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED 6 0 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: P')/(40.474J-/.) lo—e'ti"e„ Imagi" ~roject Well History File Cover,(~ ~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~00-~.i-~- Well History File Identifier RESCAN Color items: Grayscale items: Poor Quality Originals: Other: NOTES: DIGITAL DATA Diskettes, N, ~ [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds · [:J, Other Project Proofing BY: BEVERL. Y ROBIN VINCENT SHERYGWINDY Scanning Preparation _~ x 30 : /20 BY: BEVERLY ROBIN VINCENI" SHERY~INDY TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ........... ~. ~ 1 PAGE COUNT IVIA'FCHES NUMBER IN SCANNING PREPARATION: ~.' YES ......... NO Stage 2 IF NO IN STAGE t, PAGE(S) DISCREPANCIES WERE FOUND: ................... YES ...................NO BY' BEVER~INC~NT SHERYL. MARIA WINDY DA'TE:~_O'/~3/S/'/~% (SCANNING I$ COMPLETI= AT THIS POINT UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVDUAL PAGE BASISDUE TO QUALITY, G~YSOALEo. oo,o. III II I I II I I Ill Il III RESCANNEDB~': BEVERL, Y ROBIN VINCENI' SHERYL MARIA WINDY DATE: tsl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 26, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 L.. 1 3 2.n RE: Perforating Record: 1D -39 Run Date: 5/22/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -39 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22997 -00 g I t 6 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: / Signed: 1.0 01 _ aZ. — AC 4 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 7, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1D -39 Run Date: 6/5/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -39 Digital Data in LAS format, Digital Log Image file 1 CD Rom,.- 50- 029 - 22997 -00 4k 1 1 fp PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood ;VANES) SEP 1 2, 201i 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 1 v q Signed: V amp - (0 STATE OF ALASKA ' ALASKA•AND GAS CONSERVATION COMMIS, REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell E Plug Perforations r Stimulate r Other r Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r" Operat. Shutdown r Perforate f;,7 Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ " 200 -216 3. Address: Stratigraphic r Service Fe' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 - 50- 029 - 22997 - 00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, 25650 Y 1 D - 9. Field /Pool(s): .. Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 13545 feet Plugs (measured) None true vertical 6625 feet Junk (measured) None Effective Depth measured 13476 feet Packer (measured) 12215 true vertical 6592 feet (true vertucal) 6200 Casing Length Size MD TVD Burst Collapse CONDUCTOR 86 20 120 120 SURFACE 6198 9.625" 6231 4347' PRODUCTION 12337 7" 12371 6251 LINER 1337 3.5" 13545 6626 iE'! Perforation depth: Measured depth: 13070'-13340' mkt .i s t �v1i True Vertical Depth: 6467' -6554' i� ` ketIllliniOn Tubing (size, grade, MD, and ND) 3.5, L -80, 12275 MD, 6219 TVD ; M O. Packers & SSSV (type, MD, and ND) PACKER - BAKER ZXP FLEXLOCK LINER TOP PACKER @ 12215 MD and 6200 ND NIPPLE - CAMCO 'DS' LANDING NIPPLE @ 471 MD and 471 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 3566 1891 Subsequent to operation 3446 1963 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service" 17 Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ WA GINJ I" SUSP r SPLUG r 16. 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: none Contact John Peirce @ 265 -6471 Printed Name John Peirce Title Wells Engineer Signature t: Phone: 265 -6471 y Date / /? �/� 1"." Phone: JUN z 81011 ' � • Z /( Form 10 -404 Revised 10/2010 Submit Original Only 1..l6Ar (96 bbi 12c 1D-39 Well Work Summary DATE SUMMARY 5/15/11 DRIFT W/ 2.5" DMY GUN (MAX OD "), 2.64" CENT (OAL= 24') TO TAG @ 1 , 8' SLM. READY FOR E- LINE. 5/22/11 PFRFORATF 13216'- 13256' WITH (2)- 2.5" 20' GUNS 11GRAM RDX PROSPECTOR CHARGES 60DEG PHASE 6SPF (120SHOTS /GUN) JOB IN PROGRESS FINISH 13,180'- 13216' TOMORROW 6/2/11 ATTEMPT TO PERFORATE 13180'- 13216'. SPOT EQUIPMENT ON LOCATION, JOB CANCELED BY CPAI. 6/5/11 PERFORATE FROM 13181' - 13216' WITH 2 -1/2 ", PROSPECTOR DP, 6 SPF, 60 DEGREES , 11G CHARGES. FIRST RUN 13196' - 13216'. SECOND RUN 13181' - 13196'. tr' KUP 4110 1 D - 39 Well Attributes Max Angle & MD T D a k ,, Wellbore APUUWI Feld Name Well Status Inc! (°) MD (kKB) A Bari ( Alsa Inc,' ,l 500292299700 KUPARUK RIVER UNIT INJ 74.55 5,624 87 1 Comment H2S (ppm) Date Annotation End Data KB (ft) Rig R Date •••• a1oa1(w.; 1 3e v s Igo A _.. SSSV NIPPLE _ / Last WO: I 11/22/2005 2 19/25 ,4 oration .� - - _ S dijagar-ACNaI A pth (ftKB) End Date Annotation (Last Mod .IE Date Last Tag: SLM !Depth 5/16/2011 Rev Reason: ADD PERFS !Imam 6/14/2011 6/1 4/2011 I I g Strings ,Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd CONDUCTOR (QC) 20 19.052 33.7 120.0 120.0 91.50 H - 40 W Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) I. D) ... String W.. String ... String Top Thrd SURFACE (QC) 9 5/8 8.835 33.6 6,231.4 4,346.5 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftl(B) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd glir H r PRODUCTION (QC) 7 _ 6 276 33 6 12.370.5 6 .250 8 ... . 26.00 oing BT -M OD C sing Des , ption Str g 0... String ID ... Top (ftKB) Sot Depth (f... Set Depth ( ND) .. String Wt... String .. String Top T h nt LINER (QC) 3 1 2 992 12 207. 1 3 , 545.0 6,625.5 9 3 L 80 SLH Liner Details Top Depth I (TVD) Top Inc! Nomi... Top t( ((BL (fiKB) (°) Item Description Comment ID (In) 12,207.8 6,197.3 71.11 TIE BACK LINER TIE BACK SLEEVE 5.250 CONDUCTOR (DC), 34 12,215.1 6,199.7 71.08 PACKER BAKER ZXP FLEXLOCK LINER TOP PACKER 5.250 12,222.7 6,202.2 71 05 HANGER BAKER FLEXLOCK LINER HANGER 2.992 �.,.: NIPPLE, 471 12,234.6 6,206.1 71.00 SBE BAKER 80-40 SBE 4 000 - 12.293.5 6,225.3 70.67 NIPPLE HOWCO XN NIPPLE 2.150 Tubing Strings Tubing Des rip String 0 -_ String ID . - Top (1160) ISet Depth (f... Set Depth (ND) Siring Wt.... String .. String Top Thrd I UBING 3 1/2 2. 902 I 0 0 12,2/5 0 6,219.2 9 30 L EUE 8r4 INJECTION, - -- 4,257 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ' . /1 Top Depth (TVD) Top Inc' Top (ftKB) (kKB) 0) Deson o_ Comment Run Date ID (in) j 471 470.9 3.11 NIPPLE CAMCO 'DS' LANDING NIPPLE 11/22/2005 2.875 j 4,257 3,746.0 67.50 INJECTION CAMCO/KBUG/1/OMYB14// Comment STA 1 11/29/2005 2.920 12,210 6,198.1 71.10 NIPPLE CAMCO DS' NIPPLE 11/22/2005 2.812 12,213 6,199.0 71.09 SBE BAKER 80 -40 SBE 11/22/2005 4.000 SURFACE __.,_"A Y:. 12,215 6,199.7 71.08 PACKER BAKER ZXP FLEXLOCK LINER TOP PACKER 11/22/2005 5.250 (QC), 34 - 6,231 12,226 6,203.3 71.04 SEAL BAKER GHB -22 SEALS 11/22/2005 3.000 Perforations & Slots NIPPLE, 12,210 11._ -.- -. Shot Top (160) Btm (TVD) Dens Top (ftKB) Btm (kKB) (ftKB) (ftKB) Zone Date (sh -- Type Comment 13,070 13,090 6,467.0 6,472.9 C -4, 1D -39 4/24/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg ph, random orientation SBE, 12,213 1 )1ire 13,090 13,130 6,472.9 6,485.2 C -4, 10-39 11/2/2008 6.0 APERF 2.5: PJ 2506 HMX If 13,130 13,160 6,485.2 6,494.3 C -4, 113-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 1.- • ms..,.. . i 13,160 13,180 6,494.3 6,500.1 C -4, 1D -39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg ph, random PACKER, orientation 12215 - . � c 'j 13,181 13,216 6,500.5 6,512.1 6/5/2011 6.0 IPERF 2.5" RDX Prospector, 60 deg phasing, 11 gram 1 ` ��" 13,216 13,256 6,512.1 6,525.5 C4, C3, C2. 52212011 6.0 IPERF 2.5" RDX Prospector, 60 deg 10-39 phasing, 11 gram 13,256 13,286 6,525.5 6,535.7 C -2, 1D -39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random SEAL, 12,226 - - orientation ` 1 ' 13,285 13,310 6,535.3 6,543.8 C -1, 10-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX ' 13,310 13,320 6,543.8 6,547.2 C -1, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,320 13,340 6,547.2 6,554.0 C -1, 10-39 4/22/2001 4.0 IPERF 2.5" HC /DP, 60 -120 deg ph, random orientation Stimulations & Treatments Bottom Min Top Max Bon Top Depth Depth Depth Depth (TVD) (TVD) (kKB) (ftKB) (ftKB) (ftKB) Type Date Comment " 13,070.0 13,340.0 6,467.0 6,554 0'� HPBD 5/1/2001 Notes: General & Safety End Date Annotation PRODUCTION 8/23/2010 NO E Vi222 Schematic w/ Alaska Schematio9.0 (QC), 34- 12,371 - -_ IPERF, 1 13,070 0 13,090 - 13,130 �yy APERF, • HS 13,130 - 13,160 PERF, 13,160- 13,160^^ IPERF, ( W 13,1 81 - 13,216 -- "s___ If: HPBD, 13,070 ^°^? 4 IPERF, ▪ ° X ' 13,216- 13,256 ,. (' IPERF, Details 13.256 - 13.2}16 __ -_ -. ___._ -:.. Top Depth Top Port 1 Inc! e (TVD) 1 OD Valve Latch S TRO Run APERF, 'k Stn Top MKS) ( el Make Mode! (in) Sear Type Typo (in) HMI) Run Date Corn... gam, 13$85 - 13,310 4 ro"k"+ • "°" 1 4,257.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/292005 IPERF, _, .w' - - - 13,310- 13,320 V ?at- IPERF, 1 ; 13,320- 13,340 - AA "4• LINER(OC), 12208 - 13,545 a T0,13,545 • • WELL LOG TRANSMITTAL PROACTIVE DiAgNOSTic SERVICES, INC_ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road $ Suite C i .A AR 1 6 20 n Anchorage, AK 99518 Fax: (907) 245 -8952 Caliper Report 05 1 1 D 1 Report / EDE 50 - 22 - 2) Caliper Report 06- Mar -11 3G-05 1 Report / EDE 50:027-20132-00 N (2 =4.71 -1A i'..--: ';:vm MAR 7 I 2 O1 Signed : L„ Date : Print Name: :. s < _ c ,, ...- .. ; -+. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E -MAIL : pdsanchorageOmernOretio(.com WEBSITE : www.memory oG.COr C:\Documents and Settings\Diane Williams \Desktop \Transmit_Conoco.docx 1 • • 1 ilP1 .....i. Multi- Finger Caliper Log Results Summary I Company: Conoco Phillips Alaska, Inc. Well: ID-39 Log Date: March 5, 2011 Field: Kuparuk River Unit Log No.: 10258382 ZX70 State: Alaska I Run No.: 1 API No.: 50-029-22997-00 Pipet Desc.: 3.5" 9.3 Ib. L -80 EUE 8rd Top Log Intvll.: Surface Pipet Use: Tubing & Liner Bot. Log Intvll.: 12,300 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to the jewelry schematic per HES MIT Log Comments. This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical I damage. The caliper recordings indicate the tubing and liner are in good to poor condition with respect to corrosive and mechanical damage. A possible hole is recorded in the first joint of the liner, where the caliper recorded an 85% wall penetration at 12,292' and 21% cross - sectional wall loss at 12,274'. A 3 -D log plot of the caliper recordings across this interval is included in this report. 1 ' Wall penetrations from 20% to 62% are recorded throughout the log interval. The damage appears predominantly in the form of lines of pits, with intermittent areas of scattered pitting, general corrosion and line corrosion. No significant I.D. restrictions are recorded throughout the 3.5" tubing or liner logged. 1 This is the second time a caliper has been run in this well and the first time the 3.5" tubing has been I logged since the rig work over on November 22, 2005. 1 This summary report is interpretation of data provided by Halliburton Energy Services. I MAXIMUM RECORDED WALL PENETRATIONS: Possible Hole ( 85 %) Jt. 390 @ 12,292 Ft. (MD) Line Corrosion ( 62 %) Jt. 105 @ 3,304 Ft. (MD) I Isolated Pitting ( 57%) Jt. 295 @ 9,267 Ft. (MD) Isolated Pitting ( 56%) Jt. 88 @ 2,751 Ft. (MD) Line of Pits ( 53 %) Jt. 125 @ 3,925 Ft. (MD) 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: Corrosion ( 21 %) Jt. 390 @ 12,274 Ft. (MD) I No other significant areas of cross - sectional wall loss (> 13 %) are recorded throughout the 3.5" tubing and liner logged. I MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the 3.5" tubing and liner logged. 1 I I Field Engineer: E. Regnier Analyst: M. Lawrence Witness: J. Condio ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 c)bd - a /(,.9 2-O 0 1 • • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. F ield : K u ■ p Y P Kuparuk River Unit P Well : 1D-39 Date : March 5, 2011 ■ Description : Detail of Caliper Recordings Across Top of 15" Liner and Possible Hole at 12,292' Comments Depth Max. Pen. ( %) Max. I.D. (ins.) 3-0 Log Image Map 1ft:175ft 0 100 t 2.5 inches 3.5 1 f 27° X 0 90° 180° 270° 0° Min. I.D. (ins.) 2.5 inches 3.5 I Nominal I.D. 2.5 inches 3.5 I Joint 389 ■ AN 12210 - -- - ■ ■, I DS Nipple ��� 12220 ■■7tlr■■ Pup Joint 389.1 ■■ ■` €�M■■■ Immognmill 12230 t ° ` ■ ■■ ■■ _ at 12240 - - -- ----- GHB-22 Seals MU i de 1 12250 - - -- -- -- tri — I NM No EMI 1 12260 4 - - - -- ■ Baker 80 -40 SBE ■ ■■■ I 12270 ■■■ ?■■ • ■ ■■t ■liE ■■■S ■■-�■ ' Top of 3.5" Liner MIME EVAN MEME LAIN Possible Hole 12280 I III olatiAilliii (12,292') ME I 21% ■ ■ ■� E Wall Cross -Sectional Loss ■■■MIM� l Loss 12290 (12,2741 ■■ FA - 1 MN 11 1. A ^19(1(1 i - 1 1 1 1 • • Correlation of Recorded Damage to Borehole Profile 1 • Pipe 1 3.5 in (12.0' - 12266.5) Well: 1D-39 Field: Kuparuk River Unit I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: March 5, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 < 15 50 - 1553 I is- 1 100 — 3117 - `T INJ 1 I 150 4712 0 1 200 6278 .., Z s 250 7838 0 300 Moms— 9405 Ni 3.50 10969 I 390 12266 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 Bottom of Survey = 390 1 1 1 • • 1 PDS Report Overview Body Region Analysis I Well: 1D-39 Survey Date: March 5, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8rd Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE 8rd 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) I 400 -�-- Penetration body IMO Metal loss body 0 50 100 0 III 300 ilii 200 . 49 1 100 0 9 <) I 0 t 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 395) INJ 1 I 54 304 36 1 147, I Damage Configuration ( body) 197 i 400 mil -.-- 247 200 - 1 300 mil ,���� 100 297 _ Isolated General Line Other Hole/ 347€ Pitting Corrosion Corrosion Damage Pos. Hole - 1 Number of joints damaged (total = 382) ` ` II , 366 4 11 0 1 Bottom of Survey = 390 I 1 I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U % inset Body Loss I.D. Comments ( %wall) (Ins.) (Ins.) °A° (Ins.) 0 50 100 I 0.1 12 0 0.01 6 1 2.94 Pup 1 15 0 0.03 12 4 2.92 Lt. Deposits. 1.1 46 0 0.03 1 1 2 2.91 Pup Lt. Deposits. 2 54 0 0.03 11 5 2.92 Lt. Deposits. 1 I 3 86 0 0.03 12 4 2.89 Lt. Deposits. ■ 4 117 0 0.03 12 5 2.93 Lt. Deposits. 5 149 0.03 0.03 13 7 2.90 Shallow Pitting. Lt. Deposits. i 6 180 0.04 0.03 13 5 2.92 Shallow Pitting. Lt. Deposits. 7 211 0 0.03 13 5 2.92 Shallow Pitting. Lt. Deposits. 8 242 0 0.04 14 3 2.92 Shallow Pitting. Lt. Deposits. ■ 9 2 74 0 0.03 11 5 2.92 Lt. Deposits. ■ 10 305 0 0.03 11 6 2.92 Lt. Deposits. ■ 1 1 337 0 0.03 12 6 2.92 Shallow Pitting. Lt. Deposits. a I 12 368 0 0.03 13 6 2.92 Shallow Pitting. Lt. Deposits. 13 399 0 0.04 15 5 2.92 Shallow Pitting. Lt. Deposits. 14 431 0 0.04 17 6 2.93 Shallow Line of Pits. Lt. Deposits. 14.1 462 0 0 0 0 2.86 Camco "DS' Landing Nipple I 15 464 0 0.04 15 5 2.92 Shallow Pitting. Lt. Deposits. 16 495 0 0.04 15 7 2.92 Shallow Pitting. Lt. Deposits. 17 526 0 0.05 19 6 2.91 Shallow Line of Pits. Lt. Deposits. i 18 557 0 0.04 14 _ 4 2.92 Shallow Pitting. Lt. Deposits. 19 587 0 0.03 12 6 2.93 I 20 619 0 0.03 13 5 2.93 Shallow Pitting. Lt. Deposits. 21 650 0 0.04 17 6 2.93 Shallow Pitting. Lt. Deposits. 22 681 0.03 0.04 15 5 2.92 Shallow Line of Pits. Lt. Deposits. 23 712 0 0.04 15 6 2.92 Shallow Pitting. Lt. Deposits. 1 I 24 743 0 0.04 16 7 2.92 Shallow Line of Pits. Lt. Deposits. i 25 775 0.04 0.04 17 6 2.93 Shallow Pitting. Lt. Deposits. 26 806 0 0.04 15 6 2.93 Shallow Line of Pits. 27 837 0 0.03 13 4 2.93 Shallow Pitting. Lt. Deposits. I 28 869 0 0.04 17 5 2.92 Shallow Line of Pits. Lt. Deposits. 29 899 0 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. is 930 0 0.04 17 5 2.92 Shallow Pitting. Lt. Deposits. ■ 31 961 0 0.07 29 9 2.92 Line of Pits. Lt. Deposits. 1 32 993 0 0.06 22 7 2.92 Isolated Pitting. Lt. Deposits. 1 I 33 1024 0 0.04 17 4 2.92 Shallow Pitting. Lt. Deposits. ■ 34 1055 0 0.04 14 7 2.92 Shallow Line of Pits. Lt. Deposits. a 35 1087 0 0.04 14 5 2.91 Shallow Pitting. Lt. Deposits. ■ 36 1117 0 0.05 20 4 2.92 Line of Pits. Lt. Deposits. ■ I 37 1148 0 0.05 20 5 2.93 Line of Pits. Lt. Deposits. ■ 38 1180 0 0.05 19 0 2.93 Shallow Line of Pits. Lt. Deposits. 39 1211 0.04 0.08 32 5 2.91 Line of Pits. Lt. Deposits. 40 1242 0 0.06 24 6 2.92 Line of Pits. Lt. Deposits. 1 I 41 1273 0 0.05 20 .5 2.92 Isolated Pitting. Lt. Deposits. 42 1304 0 0.03 12 5 2.93 Shallow Pitting. Lt. Deposits. 43 1336 0 0.05 20 5 2.91 Shallow Line of Pits. Lt. Deposits. 44 1367 0 0.04 17 5 2.92 Shallow Pitting. Lt. Deposits. I 45 1398 0 0.04 15 5 2.93 Shallow Pitting. Lt. Deposits. 46 1429 0 0.03 13 6 2.91 Shallow Line of Pits. Lt. Deposits. 47 1459 0 0.04 14 5 2.93 Shallow Line of Pits. Peneation Body I Metal Loss Body Page 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 5, 2011 I Joint Jt. Depth Perr. Pen. Pen. Metal Min. Damage Profile No. (Ft.) l)pset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 48 1490 0 0.04 15 4 2.93 Shallow Line of Pits. Lt. Deposits. ■ 49 1521 0 0.03 13 5 2.93 Shallow Pitting. Lt. Deposits. ■ 50 1553 0 0.06 24 4 2.93 Isolated Pitting. Lt. Deposits. ■ 51 1584 0 0.04 17 4 2.92 Shallow Pitting. Lt. Deposits. ■ 52 1614 0 0.04 15 5 2.91 Shallow Pitting. Lt. Deposits. ■ I 53 1645 0.04 0.06 22 5 2.91 Isolated Pitting. Lt. Deposits. um 54 1676 0 0.07 27 6 2.92 Isolated Pitting. Lt. Deposits. um 55 1708 0 0.05 19 5 2.91 Shallow Pitting. Lt. Deposits. ■o 56 1739 0 0.07 26 6 2.93 Line of Pits. Lt. Deposits. I• I 57 1770 0 0.07 29 4 2.92 Line of Pits. Lt. Deposits. ■mei 58 1801 0 0.08 32 5 2.92 Line of Pits. Lt. Deposits. Bow 59 1832 0 0.09 35 5 2.93 Line of Pits. ■1 60 1864 0 0.07 27 5 2.93 Line of Pits. Lt. Deposits. ■l� I 61 1895 0 0.07 29 6 2.92 Isolated Pitting. Lt. Deposits. 62 1927 0 0.11 42 6 2.93 Line of Pits. Lt. Deposits. ■� I� 63 1958 0 0.06 22 5 2.93 Isolated Pitting. ■w 64 1989 0 0.05 21 6 2.91 Isolated Pitting. Lt. Deposits. no I 65 2020 0 0.08 31 6 2.93 Isolated Pitting. Lt. Deposits. �� 66 2052 0.05 0.07 28 5 2.93 Isolated Pitting. Lt. Deposits. ■w 67 2083 0 0.06 23 5 2.93 Line of Pits. ■m 68 2114 0 0.07 27 4 2.94 Line of Pits. ■m 69 2145 0 0.06 22 5 2.93 Isolated Pitting. Lt. Deposits. ■ I 70 2177 0 0.04 17 4 2.92 Shallow Pitting. Lt. Deposits. ■� 71 2207 () 0.07 28 6 2.92 Isolated Pitting. Lt. Deposits. gm 72 2238 0 0.05 21 5 2.91 Line of Pits. Lt. Deposits. ■ 73 2270 0 0.04 15 5 2.92 Shallow Line of Pits. Lt. Deposits. ■� I 74 2301 0 0.04 14 5 2.88 Shallow Pitting. Lt. Deposits. ■ 75 2332 0 0.06 24 5 2.93 Isolated Pitting. Lt. Deposits. ■ 76 2363 0 0.03 12 6 2.93 Lt. Deposits. ■ 77 2395 0 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. ■ I 78 2426 0 0.03 11 5 2.93 Lt. Deposits. ■ 79 2458 0 0.05 20 6 2.93 Shallow Pitting. Lt. Deposits. ■ 80 2489 0 0.03 12 6 2.93 Lt. Deposits. o' 81 2520 0 0.05 19 6 2.93 Shallow Pitting. Lt. Deposits. ■m I 82 2552 0 0.07 28 6 2.93 Line of Pits. Lt. Deposits. ■� 83 2583 0 0.08 31 6 2.93 Line of Pits. Lt. Deposits. no 2615 0 0.11 44 6 2.93 Line of Pits. Lt. Deposits. ■� 85 2646 0 0.08 33 6 2.92 Line of Pits. Lt. Deposits. ■w 86 2678 0 0.09 37 6 2.94 Line of Pits. ■E I 87 2709 0 0.10 38 7 2.91 Line of Pits. Lt. Deposits. om 88 2740 0 0.14 56 7 2.92 Isolated Pitting. Lt. Deposits. om 89 2772 0.04 0.08 32 6 2.93 Line of Pits. Lt. Deposits. ■■ 90 2803 0 0.12 47 6 2.93 Line of Pits. Lt. Deposits. ■m I 91 2834 0.08 0.11 42 7 2.93 Line of Pits. Lt. Deposits. �� 92 2865 0.04 0.10 39 6 2.92 Line of Pits. Lt. Deposits. ■m 93 2897 0 0.09 33 6 2.92 Line of Pits. Lt. Deposits. NE 94 2928 0.05 0.10 38 5 2.92 Isolated Pitting. Lt. Deposits. ■w I 95 2960 0 0.10 41 5 2.93 Line of Pits. no 2991 0.07 0.10 40 6 2.92 Line of Pits. Lt. Deposits. Elm 97 3023 0.05 0.10 41 5 2.94 Line of Pits. Pt Body I Meta enetra l Loss ion Body Page 2 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 5, 2011 I Joint Jt. Depth Puri. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 98 3054 0 0.08 31 4 2.94 Line of Pits. -, 99 3085 0 0.07 29 5 2.93 Line of Pits. Lt. Deposits. mEE 100 3117 0 0.09 34 4 2.93 Line of Pits. Lt. Deposits. mu 101 3148 0.0> 0.12 46 7 2.93 Line of Pits. INN 102 3180 0.05 0.10 37 7 2.93 Line of Pits. mai I 103 3211 0 0.10 38 6 2.92 Line of Pits. Lt. Deposits. Num 104 3242 0 0.12 48 5 2.93 Line of Pits. Lt. Deposits. ENE 105 3274 0 0.16 62 6 2.93 Line Corrosion. Lt. Deposits. NE 106 3305 0 0.10 38 4 2.93 Line of Pits. Lt. Deposits. MN I 107 3337 0.05 0.10 41 4 2.92 Line Corrosion. Lt. Deposits. Nu 3368 0.04 0.11 44 7 2.93 Line of Pits. Lt. Deposits. IE� 109 3400 0 0.12 49 6 2.89 Line of Pits. Lt. Deposits. EN 110 3431 0 0.08 32 6 2.92 Line of Pits. Lt. Deposits. MIN I 111 3463 0 0.09 36 5 2.92 Line of Pits. Lt. Deposits. um 3494 0 0.10 38 6 2.92 Line Corrosion. Lt. Deposits. ��� 113 3525 0 0.08 33 5 2.93 Line of Pits. Lt. Deposits. Em 114 3557 0 0.12 49 6 2.93 Line of Pits. NM I 115 3588 0 0.09 35 6 2.94 Line Corrosion. ��� 116 3620 0 0.11 42 7 2.94 Line of Pits. um 3651 0 0.08 33 6 2.93 Line of Pits. Lt. Deposits. IN 118 3682 0.05 0.07 28 4 , 2.93 Line of Pits. .N 119 3713 0.06 0.09 37 4 2.92 Line of Pits. Lt. Deposits. ME I 120 3745 0.04 0.10 38 5 2.94 Line of Pits. NE 121 3776 0 0.09 35 4 2.94 Line of Pits. 122 3807 0 0.07 30 6 2.92 Line of Pits. Lt. Deposits. ENO 123 3839 0 0.10 37 6 2.91 Line of Pits. Lt. Deposits. , 1E 124 3870 0 0.06 22 6 2.92 Line of Pits. Lt. Deposits. � I 125 3902 0.03 0.14 53 5 2.90 Line of Pits. Lt. Deposits. �� NI 126 3933 0.06 0.07 26 4 2.92 Line of Pits. Lt. Deposits. IN 127 3965 0.04 0.07 28 5 2.94 Line of Pits. ■ I 128 3997 0 0.07 26 6 2.92 Line of Pits. Lt. Deposits. �� 129 4028 0.04 0.07 28 7 2.92 Line of Pits. Lt. Deposits. �� 130 4059 0.05 0.06 24 4 2.93 Line of Pits. Lt. Deposits. IN 131 4090 0.04 0.07 28 8 2.93 Line of Pits. Lt. Deposits. NI 132 4122 0.04 0.07 28 4 2.93 Line of Pits. Lt. Deposits. ■ I 133 4154 0 0.08 32 4 2.92 Line of Pits. Lt. Deposits. 134 4184 0 0.07 30 7 2.92 Isolated Pitting. Lt. Deposits. IEE 135 4215 0.06 0.09 36 4 2.94 Line of Pits. NINI 135.1 4246 0 0.08 31 7 2.91 Pup Line of Pits. Lt. Deposits. " 135.2 4257 0 0 0 0 2.88 Injection Mandrel 1 (Latch @ 11:30) 135.3 4263 0 0.09 35 3 2.92 Pup Line of Pits. Lt. Deposits. rim 4273 0 0.09 35 4 2.92 Isolated Pitting. Lt. Deposits. EiE 137 4304 0.03 0.08 31 4 2.93 Line of Pits. Lt. Deposits. NM I 138 4335 0.05 0.08 32 7 2.92 Line of Pits. Lt. Deposits. 139 4367 0.05 0.07 26 6 2.93 Line of Pits. Lt. Deposits. �� 140 4398 0 0.09 36 6 2.93 Line of Pits. mg 141 4430 0 0.06 24 6 2.94 Line of Pits. . 142 4461 0 0.08 32 5 2.94 Line of Pits. NM I 143 4492 0.09 0.08 33 10 2.94 Line of Pits. 144 4524 0.04 0.07 26 5 2.95 Line of Pits. Ei Penetrat I Metal Loss ion Body Page 3 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) I)L�set Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 145 4555 0 0.08 31 6 2.94 Line of Pits. 146 4586 0.04 0.06 23 7 2.93 Line of Pits. Lt. Deposits. 147 4618 0.03 0.07 28 5 2.92 Line of Pits. Lt. Deposits. 148 4649 0.05 0.07 28 6 2.93 Isolated Pitting. Lt. Deposits. I 149 4681 0 0.08 31 6 2.94 Line of Pits. 150 4712 0 0.08 32 3 2.94 Line of Pits. 151 4744 0 0.06 24 4 2.95 Line of Pits. 152 4775 0.05 0.07 29 6 2.96 Line of Pits. 153 4806 0.03 0.11 42 4 2.95 Line of Pits. I 154 4837 0.03 0.07 27 4 2.94 Line of Pits. 155 4868 0 0.10 37 6 2.94 Line of Pits. 156 4900 0.04 0.09 35 7 2.92 Line of Pits. Lt. Deposits. 157 4932 0.0') 0.07 29 4 2.93 Line of Pits. Lt. Deposits. I 158 4963 0.07 0.08 31 8 2.93 Line Corrosion. 159 4995 0 0.08 30 6 2.93 Line of Pits. 160 5026 0.03 0.10 41 7 , 2.95 Line of Pits. 161 5058 0.05 0.09 37 4 2.93 Line of Pits. Lt. Deposits. I 162 5088 0.03 0.07 29 5 2.94 Line of Pits. 163 5120 0 0.07 28 5 2.93 Line of Pits. Lt. Deposits. 164 5150 0.03 0.05 21 7 2.94 Line of Pits. 165 5181 0.04 0.07 28 6 2.95 Line of Pits. 166 5213 0.06 0.09 35 7 2.92 Isolated Pitting. Lt. Deposits. I 167 5244 0.05 0.07 29 4 2.95 Line of Pits. 168 5276 0.04 0.08 31 4 2.93 Line of Pits. 169 5306 0 0.07 27 6 2.94 Line of Pits. 170 5337 0 0.08 31 6 2.94 Line of Pits. I 171 5368 172 5400 0 0.07 28 6 2.93 Line of Pits. 0 0.07 27 7 2.94 Line of Pits. 173 5431 0 0.08 31 6 2.93 Line of Pits. Lt. Deposits. 174 5463 0 0.07 27 7 2.94 Line of Pits. 1 175 5494 0.04 0.07 26 3 2.95 Line of Pits. 176 5526 0.05 0.07 26 4 2.95 Line of Pits. 177 5557 0.05 0.08 31 4 2.95 Line of Pits. 178 5589 0.04 0.06 25 3 2.95 Line of Pits. 179 5620 0.03 0.07 28 4 2.94 , Line of Pits. I 180 5651 0 0.06 24 6 2.93 Line of Pits. Lt. Deposits. 181 5683 0 0.08 30 5 2.94 Line of Pits. 182 5714 0.03 0.08 30 5 2.94 Line of Pits. 183 5745 0 0.08 30 7 2.93 Line of Pits. I 184 5776 0 0.08 32 6 2.93 Line of Pits. Lt. Deposits. 185 5807 0.04 0.08 32 6 2.93 Line of Pits. Lt. Deposits. 186 5838 0 0.06 25 7 2.94 Line of Pits. 187 5870 0.04 0.08 33 6 2.93 Line of Pits. 1 188 5901 0.05 0.06 22 5 2.95 Line of Pits. 189 5933 0 0.06 25 6 2.94 Line of Pits. 190 5964 0 0.08 33 6 2.94 Line of Pits. 191 5996 0 0.06 23 5 2.94 Line of Pits. I 192 6027 0 0.06 22 7 2.93 Line of Pits. Lt. Deposits. 193 6059 0 0.09 35 6 2.93 Line of Pits. Lt. Deposits. 194 6090 0.06 0.09 35 5 2.93 Line of Pits. Lt. Deposits. Penetration Body Metal Loss Body Page 4 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 195 6121 0 0.09 35 5 2.94 Line of Pits. 196 6152 0.04 0.07 28 5 2.90 Line of Pits. Lt. Deposits. 197 6184 0.06 0.06 24 6 2.95 Line of Pits. 198 6215 0.05 0.09 34 5 2.92 Line of Pits. Lt. Deposits. 199 6246 0 0.09 36 5 2.93 Line of Pits. Lt. Deposits. I 200 6278 0.04 0.07 28 5 2.93 Line of Pits. 201 6309 0.03 0.06 24 6 2.95 Line of Pits. 202 6340 0.04 0.08 30 7 2.94 Line of Pits. 203 6372 0.04 0.07 27 6 2.95 Line of Pits. I 204 6403 0 0.07 26 5 2.95 Line of Pits. 205 6434 0.03 0.06 25 5 2.92 Line of Pits. Lt. Deposits. 206 6464 0.03 0.06 23 6 2.95 Line of Pits. 207 6496 0 0.09 35 5 2.94 Line of Pits. I 208 6527 0.04 0.11 42 5 2.93 Line of Pits. Lt. Deposits. 1 209 6558 0.06 0.07 28 5 2.94 Line of Pits. l 210 6589 0.06 0.09 36 4 2.94 Line of Pits. t sol 211 6621 0.08 0.07 29 3 2.94 Line of Pits. I 212 6651 0.04 0.09 34 6 2.95 Line Corrosion. 213 6682 0.04 0.07 26 4 2.94 Line of Pits. 214 6713 0 0.06 24 6 2.93 Line of Pits. Lt. Deposits. 215 6744 0 0.07 27 6 2.94 Line of Pits. 216 6776 0.04 0.07 29 5 2.95 Line of Pits. I 217 6807 0.04 0.06 24 6 2.93 Line of Pits. �■ 218 6838 0.05 0.06 23 5 2.94 Line of Pits. ■ 219 6870 0 0.09 36 4 2.94 Line of Pits. m 220 6901 0 0.07 29 6 2.92 Line of Pits. Lt. Deposits. N I 221 6932 0 0.06 25 4 2.93 Line of Pits. Lt. Deposits. ■� 222 6963 0 0.07 29 7 2.94 Line of Pits. i. 223 6995 0 0.08 30 5 2.94 Line of Pits. • 224 7026 0 0.07 28 6 2.92 Line of Pits. Lt. Deposits. Ni I 225 7057 0 0.08 30 4 2.94 Line of Pits. m 226 7089 0 0.07 29 6 2.94 Line of Pits. 227 7120 0 0.06 24 6 2.93 Line of Pits. IN 228 7152 0 0.06 23 6 2.93 Line of Pits. N 229 7183 0.04 0.08 32 4 2.93 Line of Pits. el I 230 7214 0.07 0.11 42 6 2.93 Line of Pits. Lt. Deposits. Ni 231 7246 0 0.06 22 5 2.94 Line of Pits. N 232 7277 0.03 0.08 32 4 2.94 Line of Pits. Nu 233 7308 0 0.07 26 6 2.91 Line of Pits. Lt. Deposits. III I 234 7340 0 0.08 31 6 2.94 Line of Pits. 235 7369 0 0.09 35 4 2.93 Line of Pits. Lt. Deposits. • 236 7400 0.03 0.07 28 6 2.95 Line of Pits. N 237 7431 0.03 0.09 34 5 2.95 Line of Pits. so I 238 7462 0.04 0.09 35 5 2.94 Line of Pits. 239 7493 0.05 0.08 33 6 2.95 Line of Pits. el IN 240 7525 0.03 0.07 28 5 2.89 Line of Pits. Lt. Deposits. • 241 7556 0.03 0.06 23 7 2.93 Line of Pits. Lt. Deposits. EN 242 7588 0.06 0.08 30 6 2.94 Line of Pits. I 243 7619 0 0.07 26 5 2.94 Line of Pits. 244 7650 0 0.07 28 5 2.94 Line of Pits. I. I Penetration Body Metal Loss Body Page 5 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 245 7681 0.03 0.10 39 6 2.94 Line of Pits. no 246 7713 0.05 0.09 35 6 2.92 Line of Pits. Lt. Deposits. um 247 7744 0.04 0.08 30 4 2.94 Line of Pits. ■E 248 7776 0.04 0.06 25 6 2.93 Line of Pits. Lt. Deposits. om I 249 7807 0.04 0.07 28 7 2.94 Line of Pits. rn 250 7838 0 0.07 28 6 2.94 Line Corrosion. om 251 7868 0 0.08 31 4 2.93 Line Corrosion. ■m 252 7900 0.04 0.07 26 6 2.95 Line of Pits. in 253 7931 0.04 0.09 35 7 2.94 Line of Pits. rm I 254 7962 0 0.07 26 6 2.94 Line of Pits. �� 255 7993 0 24 4 2.95 Line of Pits. ■lm 256 8025 0 0.07 30 5 2.93 Line of Pits. me 257 8056 0 0.08 32 5 2.92 Line of Pits. Lt. Deposits. ow ' 258 8088 0.04 0.07 28 7 2.94 Line of Pits. �� 259 8119 0.03 0.06 25 6 2.93 line of Pits. Lt. Deposits. ■o 260 8151 0.04 0.10 38 7 2.90 Line of Pits. Lt. Deposits. IN 261 8182 0 0.08 31 5 2.93 Line of Pits. Lt. Deposits. OM I 262 8213 0 0.08 30 6 2.94 Line of Pits. �� 263 8245 0 0.10 40 7 2.93 Line of Pits. HE 264 8276 0.03 0.08 30 4 2.94 Isolated Pitting. ■m 265 8308 0 0.08 30 6 2.94 Line of Pits. um 266 8339 0.04 0.09 37 6 2.94 Line of Pits. no I 267 8370 0 0.08 30 5 2.88 Line of Pits. Lt. Deposits. ■m 268 8401 0.04 0.07 28 7 2.94 Line of Pits. am 269 8433 0.07 0.10 38 7 2.92 Line of Pits. Lt. Deposits. um 270 8464 0.05 0.06 25 7 2.93 Line of Pits. no I 271 8496 0.04 0.07 28 4 2.94 Line of Pits. ■� 272 8527 0.05 0.07 28 5 2.93 Line of Pits. In 273 8558 0.03 0.08 31 7 2.94 Line of Pits. um 274 8590 0.05 0.08 30 3 2.94 Line of Pits. so I 275 8620 0.05 0.07 30 5 2.93 Line of Pits. ■M 276 8652 0.04 0.07 26 6 2.95 Line of Pits. BM 277 8683 0.04 0.08 31 6 2.94 Isolated Pitting. IM 278 8714 0 0.07 26 6 2.94 Line of Pits. ■= I 279 8746 0.10 40 6 2.93 Line of Pits. Lt. Deposits. HO 280 8778 0 0.07 26 6 2.94 Line of Pits. om 281 8809 0 0.07 28 6 2.92 Line of Pits. Lt. Deposits. om 282 8840 0 0.07 26 5 2.94 Line of Pits. so 283 8872 0 0.10 39 7 2.93 Isolated Pitting. Lt. Deposits. um I 284 8903 0 0.08 32 7 2.93 Line of Pits. Lt. Deposits. i■ 285 8935 0.03 0.08 33 8 2.94 Line of Pits. um 286 8966 0 0.10 39 4 2.92 Line of Pits. Lt. Deposits. ■m 287 8997 0 0.07 28 5 2.93 Isolated Pitting. im ' 288 9028 289 9060 0 0.06 22 5 2.93 Line of Pits. �� 0 0.08 31 0 2.93 Line of Pits. im 290 9092 0.04 0.08 30 6 2.95 Isolated Pitting. no 291 9123 0.08 0.11 43 7 2.94 Line of Pits. in I 292 9154 0.06 0.08 32 4 2.96 Isolated Pitting. moo 9186 0.03 0.11 44 5 2.93 Line of Pits. Lt. Deposits. ■m 294 9216 0 0.06 24 8 2.94 Line of Pits. t Metal Loss ion Body I 1 Page 6 Penetra 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 5, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 295 9249 0.07 0.14 57 6 2.92 Isolated Pitting. Lt. Deposits. ��� 296 9280 0.00 0.08 30 4 2.94 Line of Pits. -. 297 9311 0.0 0.08 30 6 2.95 Line Corrosion. mo 298 9342 0.06 0.08 31 5 2.95 Line of Pits. No 299 9374 0.04 0.09 35 4 2.93 Line of Pits. Lt. Deposits. mo 1 300 9405 0 0.09 35 6 2.93 Line of Pits. Lt. Deposits. ow 301 9435 0.06 0.13 52 5 2.93 Line of Pits. ■n 302 9467 0.03 0.08 32 6 2.93 Line of Pits. Lt. Deposits. uni 303 9499 0 0.11 42 7 2.95 Line of Pits. um I 304 9531 0.03 0.07 28 5 2.92 Line of Pits. Lt. Deposits. �� 305 9562 0 0.08 31 7 2.94 Line of Pits. om 306 9593 0.04 0.09 36 6 2.94 Line of Pits. no 307 9624 0.03 0.07 28 6 2.93 Line of Pits. Lt. Deposits. ,.n 308 9656 0.03 0.11 43 7 2.95 Line of Pits. um 309 9687 0.06 0.09 36 5 2.93 Line of Pits. -. 310 9718 0.06 0.09 33 5 2.96 Line of Pits. n■ 311 9749 0 0.11 43 6 , 2.92 Line of Pits. Lt. Deposits. ■AI• 312 9781 0.04 0.10 40 7 2.94 Line of Pits. t�� 313 9812 0.07 0.08 31 4 2.94 Line of Pits. no 314 9843 0.04 0.09 37 7 2.90 Line of Pits. Lt. Deposits. im 315 9874 0 0.07 26 6 2.93 Line of Pits. to3 316 9906 0 0.07 26 5 2.93 Line of Pits. Lt. Deposits. no I 317 9937 0 0.08 32 4 2.93 Line of Pits. Lt. Deposits. no 318 9969 0.08 0.09 34 4 2.94 Line of Pits. 319 10000 0.04 0.06 25 5 2.94 Line of Pits. IN 320 10031 0 0.09 34 4 2.94 Line of Pits. I 321 10063 0.06 0.07 28 7 2.94 Line of Pits. ��' ��� 322 10094 0.04 0.11 43 5 2.92 Line of Pits. Lt. Deposits. 323 10125 0.04 0.10 39 6 2.92 Line of Pits. Lt. Deposits. to 324 10157 0.05 0.07 28 4 2.92 Line of Pits. Lt. Deposits. -� I 325 10186 0 0.07 28 6 2.93 Line of Pits. �� 326 10218 0.05 0.08 30 4 2.94 Line of Pits. MN 327 10249 0.08 0.09 34 5 2.95 Line of Pits. MIN 328 10280 0.06 0.08 31 4 2.94 Line of Pits. M. 329 10311 0.08 0.09 36 4 , 2.95 Line of Pits. EMI I 330 10343 0.05 0.08 31 6 2.93 Line of Pits. 331 10374 0.04 0.07 29 6 2.93 Line of Pits. on 332 10406 0.04 0.07 29 8 2.95 Isolated Pitting. um 333 10437 0.03 0.07 29 6 2.95 Line of Pits. on I 334 10468 0.05 0.09 36 7 2.94 Line of Pits. on 335 10499 0.04 0.07 29 7 2.94 Line of Pits. nun 336 10531 0.03 0.08 32 7 2.94 Line of Pits. Inn 337 10562 0.05 0.08 32 8 2.93 Line of Pits. Iwo I 338 10594 0 0.08 32 6 2.92 Line of Pits. Lt. Deposits. ��, 339 10625 0.04 0.07 30 6 2.93 Line of Pits. Lt. Deposits. Er 340 10656 () 0.09 35 5 2.94 Line of Pits. 341 10688 0 0.07 28 7 2.94 Line of Pits. iii 342 10719 0.04 0.07 28 5 2.94 Line of Pits. I 343 10750 0 0.08 31 5 2.92 Line of Pits. Lt. Deposits. 344 10782 0 0.06 22 6 2.94 Line of Pits. in I Penetration Body I Metal Loss Body Page 7 1 I • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Well: 1 D -39 Body Wall: 0.254 in Field: Kuparuk River Unit Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 5, 2011 I Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 345 10813 0.04 0.08 32 6 2.93 Line of Pits. Lt. Deposits. �� 346 10843 0.07 0.07 28 6 2.91 Line of Pits. Lt. Deposits. la 347 10875 0.07 0.09 36 5 2.92 Isolated Pitting. Lt. Deposits. IN 348 10906 0.05 0.07 29 4 2.93 Line Corrosion. on 349 10938 0 0.12 45 7 2.91 Line of Pits. Lt. Deposits. In I 350 10969 0.05 0.09 35 6 2.92 Line of Pits. Lt. Deposits. �� 351 11001 0.06 0.07 29 4 2.93 Line Corrosion. Lt. Deposits. ■N 352 11032 0.05 0.07 27 5 2.93 Line of Pits. ■w 353 11063 0 0.06 24 7 2.94 Line of Pits. mi I 354 11095 0 0.06 25 6 2.95 Line of Pits. �� 355 11125 0 0.06 22 7 2.94 Line of Pits. in 356 11156 0 0.06 24 7 2.93 Line of Pits. Lt. Deposits. ii■ 357 11188 0 0.08 31 6 2.93 Line of Pits. Lt. Deposits. ■M ' 358 11217 0 0.08 33 6 2.93 Line of Pits. Lt. Deposits. �� 359 11249 0.05 0.10 39 4 2.94 Line of Pits. no 360 11280 0.05 0.10 38 7 2.92 Line of Pits. Lt. Deposits. IN 361 11312 0 0.06 25 7 2.93 Isolated Pitting. Lt. Deposits. No 1 362 11343 0.08 0.08 30 6 2.93 Line of Pits. Lt. Deposits. �� 363 11374 0 0.06 22 5 2.94 Line of Pits. MI 364 11405 0 0.07 28 6 2.93 Line of Pits. Lt. Deposits. III 365 11436 0 0.10 39 5 2.92 Line of Pits. Lt. Deposits. no 366 11468 0.06 0.08 31 6 2.95 Line of Pits. in I 367 11499 0.03 0.08 31 6 2.93 Line of Pits. OM 368 11531 0.0 3 0.06 24 6 2.94 Line of Pits. OM 369 11562 0 0.06 2.i 5 2.93 Line of Pits. Lt. Deposits. ■m 370 11593 0.05 0.06 24 6 2.95 Line of Pits. NM II 371 11624 0.05 0.10 41 7 2.93 Line of Pits. r■ 372 11656 0.08 0.08 31 3 2.94 Line of Pits. ■� 373 11687 0.04 0.11 42 9 2.92 Isolated Pitting. Lt. Deposits. n 374 11718 0 0.09 34 6 2.91 Line of Pits. Lt. Deposits. MI 375 11750 0 0.09 36 5 2.93 Isolated Pitting. Lt. Deposits. ■N 376 11780 0.04 0.08 31 7 2.94 Line of Pits. imi 377 11812 0 0.10 38 6 2.92 Line of Pits. Lt. Deposits. in 378 11844 0.05 0.09 35 13 2.93 Corrosion. • 379 11875 0 0.08 31 7 2.93 Corrosion. Lt. Deposits. IN 1 380 11907 0.04 0.07 26 8 2.93 Isolated Pitting. Lt. Deposits. in 381 11938 0.05 0.09 36 10 2.95 Line of Pits. n 382 11969 0.04 0.08 33 10 2.93 Corrosion. Lt. Deposits. • 383 12001 0.06 0.07 28 6 2.94 Line of Pits. on 1 384 12032 0.06 0.11 41 7 2.92 Lt. Deposits. in 385 12062 0.0;;3 0.08 31 7 2.91 Line of Pits. Lt. Deposits. in 386 12093 0 0.07 28 10 2.93 Corrosion. m 387 12124 0.04 0.07 28 6 2.92 Line of Pits. Lt. Deposits. on 388 12156 0 0.08 30 4 2.93 Line of Pits. �� 389 12187 0 0.08 30 4 2.95 Line of Pits. III 12217 0 0 0 0 2.80 Camco'DS' Landing Nipple 389.2 12218 0.03 0.06 24 5 2.92 Pup Line of Pits. Lt. Deposits. il 389.3 12225 0 0 0 0 2.96 Baker GHB-22 Seals 389.4 12264 0 0 0 0 2.96 Baker 80-40 SBE 390 12266 0.12 0.22 85 21 2.96 Possible Hole! rat Metal Loss ion Body Page 8 Penet 1 1 • • 1 PDS Report Cross Sections I Well: 1 D -39 Survey Date: March 5, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 III Tubing: 3.5 ins 9.3 ppf L -80 EUE 8rd Analyst: M. Lawrence 1 1 1 Cross Section for Joint 390 at depth 12292.110 ft Tool speed = 30 Nominal ID = 2.992 I Nominal OD = 3.5 _ _ Remaining wall area = 83% � Tool deviation = 72° / N 1 I \It 1 I f I ‘ ,4 1 4.. 1 1 _,_......___.- 1 I Finger = 6 Penetration = 0.216 ins Possible Hole 0.22 ins = 85% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections 0. I Well: 1 D -39 Survey Date: March 5, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8rd Analyst: M. Lawrence 1 1 Cross Section for Joint 105 at depth 3304.360 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 38 °� \ \ 1 1 1 1 1 1 / , 1 1 il lr I Finger = 16 Penetration = 0.157 ins Line Corrosion 0.16 ins = 62% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 I 1 1 • • 1 PDS Report Cross Sections 11.3, S, I Well: 1 D -39 Survey Date: March 5, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8rd Analyst: M. Lawrence i 1 Cross Section for Joint 295 at depth 9266.600 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 96% / '�— Tool deviation = 74° 1 1 / \ 1 1 I i I 1 Finger = 15 Penetration = 0.145 ins Isolated Pitting 0.15 ins = 57% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 VS PDS Report Cross Sections I Well: 1D-39 Survey Date: March 5, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8rd Analyst: M. Lawrence 1 1 Cross Section for Joint 390 at depth 12273.880 ft Tool speed = 30 Nominal ID = 2.992 I Nominal OD = 3.5 �■�_ Remaining wall area = 79% � Tool deviation = 72° / - / \ 1 ` 1 1 1 - 1 1 / 1■,,, 1 ,/ / I Finger = 3 Penetration = 0.127 ins Corrosion 21% Cross - Sectional Wall Loss HIGH SIDE = UP 1 1 1 1 1 1 I _ KUP 1 D -39 ConocoPhillips = \ Attributes ogle & MD TD We11t1oreAMR1Wl Pletd Name Well Status Ind (°) NV (RK Act Bhn (RKB) i 500292299700 KUPARUK RIVER UNIT INJ 74.55 5,624.87 13,545.0 CanorierrThi "" Comment H2S (ppm) Date AmotarIon End Date KB-Grd (ft) Rig Release Date I Well Conk, -loos 017/2010 i 1 oz a5 nN1 -`-~ SSSV: NIPPLE Last WO: 11/22/2005 2/7/2001 Schematic - Actual Annotation Depth (RYB) End Date Annotation Last Mod By End Date Last Tag: SLM 13,465.0 10/27/2008 Rev Reason: ZONE CORRECTION Imoshor 8/7/0 Casing Strings String OD String ID Set Depth Sel Depth (TVD) Strirg Wt Strlrg Casing Description flM 1�1 Top grace) ) (RKB) (RIB) fl Grade String Top 201 ThM 1 CONDUCTOR, ,. ',I CONDUCTOR 20 19.052 0.0 120.0 120.0 91.50 H - WELDED 120 f SURFACE 9 5B 8.697 0.0 6,231.0 4,346.4 40.00 L-80 BTC -MOD PRODUCTION 7 6.059 0.0 12,370.0 6,250.6 26.00 J-55 BTC -MOD LINER 31/2 2.992 12,207.0 13,545.0 6,625.5 9.30 L -80 SLHT NIPPLE.471 I Tubing Strings SM OD SMng ID Se Depth Set Depth (TVD) String WI Shing Tubi Descnpllon OM ng (1n) Top(mcB) IRKBI MKS) flh6) Grade smngTOp Ttrd TUBING 3 112 2.992 0.0 12,275.0 6,219.2 9.30 L-80 EUE 8rd Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) IN.ECTION, Top Depth d257 (TVD) Top Ind I Top (M.:13) MRS) P) Desenptlon Comment Rut Date ID (In) 471 470.9 3.11 NIPPLE AMCO'DS' LANDING NIPPLE 11/22/2005 2.875 SURFACE. 4,257 3,746.0 67.50 INJECTION CAMCO /KBUGl1 /DMY /BKI / /Commem: STA 11/29/2005 2.920 6731 12,210 6,198.1 71.10 NIPPLE CAMCO'DS' NIPPLE 11/22/2005 2.812 12,213 6,199.0 71.09 SBE BAKER 80 SBE 11/22/2005 4.000 I 12,215 6,199.7 71.08 PACKER BAKER ZXP FLEXLOCK LINER TOP PACKER 11/22/2005 5.250 12,226 6,203.3 71.04 SEAL BAKER GHB-22 SEALS 11/22/2005 3.000 1, 12,293 6,225.1 70.67 NIPPLE HOWCO XN NIPPLE 11/22/2005 2.750 NPPLE, 12,210 13,543 6,624.8 69.33 SHOE POST WORKOVER BAKER FLOAT SHOE 11/22/2005 I - Perforations & Slots Shot Top (TVD) Blm (TVD) Dens Top (RIB) 0110 (B) (m ( 8 ) Zone Date fart type Comment SBE, 12,213 13,070 13,090 6,467.0 6,472.9 C-4, 1D-39 4/24/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg ph, random ES orientation I 13,090 13,130 6,472.9 6,485.2 C-4, 1D-39 11/2/2008 6.0 APERF 2.5: PJ 2506 HMX 13,130 13,160 6,485.2 6,494.3 C-4, 1D -39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX PACKER 13,160 13,180 6,494.3 6,500.1 C -4, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg ph, random 12215 orientation I 13,256 13,286 6,525.5 6,535.7 C -2, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg ph, random orientation 13,285 13,310 6,535.3 6,543.8 C -1, 1D -39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX SEA_ 12726 13,310 13,320 6,543.8 6,547.2 C -1, 1D-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg ph, random orientation 13,320 13,340 6,547.2 6,554.0 C -1, 1 D -39 4/22/2001 4.0 IPERF 2.5" HC/DP, 60 -120 deg ph, random I orientation Stimulations & Treatments Bottom Min Top Max Ban Top Depth Depth Depth Depth (TVD) (TVD) NIPPLE, 12293 I ��` anus) (f�) MKB) (We) type Date Conner[ 13,070.0 13,340.0 6,467.0 6,554.0 HPBD 5/1/2001 PROW 12 0 12.370 I IPERF. 13,070 - 13,090 • APERF, 13,090- 13,130 APERF. 13.130-13.160 I IPERF, 13,160 - 13,180 1 HPBD.13,070 IPERF, 13,256-13 286 APERF, 13,285 - 13,310 I • I IPERF, 13,310- 13,320 1 PERF, 13,320- 13,340 • 1 SHOE, 13,543 1 LINER. lags , TD, 13,545 • MEMORANDUM To: Jim Regg P.I. Supervisor I ~ 1 ~(ZZ' 1 ~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-39 KUPARUK RIV UNIT 1D-39 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~.~ Comm Well Name: KUPARUK RIV UNIT 1D-39 Insp Num: mitRCN100718161208 Rel Insp Num: API Well Number: 50-029-22997-00-00 Permit Number: 200-216-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-39 1Type Inj. N. TVD 6200 '~ jA 820 2818 a 276s 2760 ~ P.T.D' 2002160 ypeTest SPT Test psi 2818 ~ OA 100 132 133 133 - Interval axxTST p/F P Tubing zo7s zo7s 2o7s 2o7s Notes: ~~~1~ r~~ ~~- ~~~o~~ P.{kj, Thursday, July 22, 2010 Page 1 of 1 n • • ~ ~~ ' '/~"j STATE OF ALASKA ~AF~ ~} `~ %~JS ALASKA OIL AND GAS CONSERVATION COMMISSION ~ REPORT OF SUNDRY WELL OPERAT~"~ ~ Gas Corls° ~olnmissoof~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other /^ WI to wAG Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Conversion Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 200-21 6 3. Address: Strati re hic g p ^ Service / ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22997-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' 1 D-39 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25650 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13545' feet true vertical 6625' feet Plugs (measured) Effective Depth measured 13394 feet Junk (measured) true vertical 6572 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 120' 20" t2o~ 120' SURFACE 6126' 9-5/8" 6231' 4346' PRODUCTION 12265' 7" 12370' 6250' LINER 1338' 3-1/2" 13545' 6625' ~~, Perforation depth: Measured depth: 13070' - 13180', 13256' - 13340' ~/~''•~`:'~ ~~~~~ `~T ~~l~a true vertical depth: 6467' - 6500'; 6526' - 6547' Tubing (size, grade, and measured depth) 3-1/2", L-80, 12275' MD. Packers & SSSV (type & measured depth) Baker ZXP Liner Top Packer 12215' Camco 'DS' Nipple 471' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2997 798 1961 Subsequent to operation 2607 338 3277 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service /^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAG^/ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt. N/A Contact g. Christensen/ D. Humphrey Printed Name obe D. Ch 'stensen Title Production Engineering Specialist Signature x ~ Phone: 659-7535 Date Form 10-404 Revised 04/2004 ~~~`3 Submit Original Only ~ R 1 D-39 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/05/09 Commenced WAG EORX Gas In'ection ~~ KUP ~ 1D-39 COIIOCOPf'II~~IpS well Attributes ~~"'~' ' ~' I ~ We110ora API/UWI Field Name Well 3tatua ProdllnJ Well Type Inc! (°) MD (ftl(B) TD (max) (R... ' 500292299700 KUPARUK RIVER UNIT INJ PWI 74.55 5,624.87 13,545.0 Comment H23 (ppm) Daba Annotation End Dale KB-0rd (R) Rlg Raleasa Date SSSV:NIPPLE 0 7/1/2008 Last WO: 11/2212005 2/7/2001 wco~n.-to- 1v112oofiz z3ssPM mane- n,al Annotation Dap[h (/tl(B) E nd Date Annotation End Dete Last Tag: SLM 13,465.0 1027!2008 Rev Reason: CORRECT PERF DATA 11/11/2008 Casio Strin s string oD stoop ID set Daptn sat Deptn (rvD) slang we smog Casing Descrlptlon Ilnl IIN Top (ffKB) (RKB) (RNB) (IbeRt) Orbs String Top Thrd CONDUCTOR, 1 CONDUCTOR 2 0 19.052 0.0 120.0 120.0 91.50 H-00 WELDED 12D I ' SURFACE 951 8 8.697 0.0 6,231.0 4,346.4 40.00 L-80 BTGMOO PRODUCTION 7 6.059 0.0 12,370.0 6,250.6 26.00 J-55 BTC-MOD LINER 31/ 2 2.992 12,207.0 13,545.0 6,625.5 9.30 L-80 SLHT NIPPLE, 071 Tubin Strin s string oD sering lD set Deptn sat Deptn (rvD) slring wt slring Tu bing Descrlptlon (In) (In) Top (RKB) (RKe) (RNB) (Ibattt) Grade Strln To Thrd TUBING 31/ 2 2.992 0.0 12,275.0 6,219.2 9.30 L-80 EUEBrd Other In Hole All Jewel :Tubin Run 8 Retrievable Fish etc. INJECTION, Top Oapth 4,257 (TVD) Top Top (RKB) (RKB) Inc! (°) Descrlptlon Comment Run Date ID (In) 471.0 470.9 3.11 NIPPLE AMCO'DS' LANDING NIPPLE 11222005 2.875 suRFACE. ~ 4 257.0 3,746.0 67.50 INJECTION CAMCO/KBUG/1IDMYIBK///COmmeM: STA 1 11292005 2.920 _ 6.231 , 12,210.0 6,198.1 71.10 NIPPLE CAMCO'DS'NIPPLE 11222005 2.812 12,213.0 6,199.0 71.09 SBE BAKER SOdO SBE 11222005 4.000 12,215.0 6,199.7 71.08 PACKER BAKER ZXP FLEXLOCK LINER TOP PACKER 11222005 5.250 12,226.0 6,203.3 71.04 SEAL BAKER GHB-22 SEALS 11222005 3.000 NIPPLE 12 210 12,293.0 6,225.1 70.67 NIPPLE HOWCO XN NIPPLE 11222005 2.750 , , 13,543.0 6,624.8 69.33 SHOE P0.ST WORKOVER BAKER FLOAT SHOE 11222005 Perforatlons Shot Top (TVD) Blm (TVD) Dane Top (RNB) Btm (RNB IRKS) (RKB) Zone Date (°n... Type Comment 68E. 12.213 13,070.0 13,090.0 6,467.0 6,472.9 C-4, 10.39 4/24/2001 4.0 (PERF 2.5" HGDP, 60.120 deg ph, random orientatlon 13,090.0 13,130.0 6,472.9 6,485.2 G1, 10.39 1122008 6.0 APERF 2.5: PJ 2506 HMX 13,130.0 13,160.0 6,485.2 6,494.3 Gi, 10.39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX PAOKER. I , ~ 13,160.0 13,180.0 6,494.3 6,500.1 C-4, 1D-39 423/2001 4.0 (PERF 2.5" HGDP, 60.120 deg p11, farldOrrl 1z.21s t,. ~ orlentatlon 13,256.0 13,286.0 6,525.5 6,535.7 C-2, 10.39 423/2001 4.0 (PERF 2.5" HGDP, 60-120 deg ph, randan orientafion 13,285.0 13,310.0 6,535.3 6,543.8 G1, 1DJ9 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX SEAL, 12226 13,310.0 13,320.0 6,543.8 6,547.2 C-1, 10.39 4!23/2001 4.0 (PERF 2.5" HGDP, 60-120 deg ph, random orientatlon 13,320.0 13,340.0 6,547.2 6,554.0 C-1, 10.39 4/22/2001 4.0 IPERF 2.5" HGDP, 60.120 deg IJF1, random orientation Stlmulatlons 8 Treatments Min Tap Max Blm iop DepN Bottom DepBl Depth DepM IrvD) ITVD) NIPPLE, 12,293 - (RNB) (RNs) (RKB) (RKB) Type Dane Comment 13,070.0 13,340.0 6,467.0 6,554.0 HPBD 5/1/2001 PRODUCTION, 12,3]0 I~ IPERf, it 13,070.13.090 -'{ APERF, 13,090.13,130 APERF, 13,130.13,180 , (PERF, ` 13.160.13.180 _ HPBD, 13,070 IPERF, 13,25&13,288 APERF, 13.28813.310 IPERF, 13,370-13,320 (PERF, 13,320.13,310 SHOE, 13,513 LINER, 13,515 I TD. 13.515 ,~ ~.- ^F C'x 3 ~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT~~I,; 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillipS Alaska, InC. Development ^ Exploratory ^ 200-216 / 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22997-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 35' 1 D-39 8. Property Designation: 10. Field/Pool(s): ADL 25661'& 25650 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13545' feet true vertical 6625' ~ feet Plugs (measured) 12293' Effective Depth measured 13394' feet Junk (measured) true vertical 6572' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 120' 120' SURFACE 6196' 9-5/8" 6231' 4346' PRODUCTION 12335' 7" 12370' 6250' LINER 1338' 3-1/2" 13545' 6625' Perforation depth: Measured depth: 13070'-13090', 13090'-13160', 13160'-13180', 13256'-13286', 13285'-13340' true vertical depth: 6467'-6473', 6473'-6494', 6494'-6500', 6526'-6536', 6535'-6554' f(~ /x^x~ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12275' MD. Packers & SSSV (type & measured depth) Baker ZXP liner top pkr @ 12215' Camco 'DS' nipple @ 471' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 2887 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^ y Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer Signature ,_ Phone: 265-6471 Date ~""~ Z,'"© 8 P ared b Sha n All u -Drake 263-4612 / ./j9 /~• ~3•~ Form 10-4`04 Revise 04/2006 ~~ ~ ~ ~ >~~ •° '~'*~ ~j. ~~~~~~~ ~. ~ ~Q~~ Submit Original Only ~~ 1 D-39 Well Work Summary DATE SUMMARY 11/1/08 PERFORATED WITH 2.5" P~RJET 6SPF HSD CHARGES FROM 131 13160' AND FROM 13285'-13310. "JOB CONTINUED ON 11/2* 11/2/08 PERFORATED FROM 13090'-13130' WITH 2.5" POWERJET 6SPF HSD CHARGES. - C~nocoPhillips ~ =~ corvoucroR. 1z6 NIPPLE, 471 KUP Attributes e APVU WI Fieltl Name 2299700 IKUPARUK nt H' NIPPLE Set INJECTION, x,257 SURFACE. _ 6,231 80-40 SBL NIPPLE. 12,210 1 1 E Comment: STA 1 1 D-39 TD (max) (ft 7 13,545.0 Release Data 2/7/2001 late l l l l i /2008 ', ToP (TVD) Bim (TVD) Dens • Top (ftKB) Bim (flK8) (ftKB) (fl KB) Zone Dab (sh-~ Type Comment sBE. 1z,zi3 13,070.0 13,090.0. 6,467.0'1 6,472.9 C-0, 10.39 4/248001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random ', orientation 13,090.0 13,130.0 ~: 6,472.9 6,485.2 C-1, 1D-39 11/2/2008 6.0 APERF 2.5: PJ 2506 HMX I sEAL,1z,z26 NIPPLE. 12,293 PRODUCTION, 12.370 IPERF. 13.070~13.09G APERF, 13.090-13.130 APERF, 13.13013,160 IPERf. 13.18013:180 HPBD. 13.070 IPERF, 13,25613,286 APERF, 13.265-13.310 IPERF. 13,310-13,320 IPERF, 13.320-13,340 SHOE. 13,543 LINER, 13,565 TD. 13,565 ~- 13,130.0 13,160.0 ~ 6,485.2 6,494.3 C-1, 1D-39 1111/2008 6.0 APERF 25: PJ 2506 HMX 13,160.0 13,180.01 6,494.3 6,500.1 C-0, iD-39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13.256.0 13.286.0 6.525.5 6,535.7 C-2, 10.39 4/23/2001 4.0 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13,285.0 13,310.0 6,535.3 6,543.8 C-1, 1D-39 11/1/2008 6.0 APERF 2.5: PJ 2506 HMX 13,310.0 __. __ 13,320.0 6,543.8 6,547.2 C-1, 10.39 4/23/2001 4.0 IPERF 2.5" HC/DP,60-120 deg ph, random orientation 13,320 0 13,340.0 6,547.2 6 554 O C-1, 1 D-39 482/2001 4 0 IPERF 2 5" HC/DP 60-120 deg ph, random onentation stimula ' tions & Treatments enftnm I - -- - - --- - ---- Min Top ~ Top Depth I, Depth Max Btm Depth Depih i (ND) ~, (TVO) ftKB ( ) flK8 1 (ftKB) (ftKB) ( ) Type Date Comment 13.070.0 13,340 0 - 6,4670 '~, Q554.0 HPBD 5/1/2001 _ _ . . ConocJ>'hillips Alaska RECEIVED AUG 1 3 2007 AIa$ka OB & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 JðD-d-I~ SCANNED AUG 1 4'2007 Dear Mr. Maunder: 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 a corrosion inhibiter, RG2401, 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 corrosion inhibitor/sealant was pumped August 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, (4¢.' £ Lo~~:~ ConocoPhillips Well Integrity Projects Supervisor ~ . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 0-32 200-173 10" nla nla nla 6.8 8/812007 1 0-36 200-130 20" nla nla nla 4.2 8/8/2007 1 0-37 200-204 20" nla nla nla 4.2 8/812007 1 0-38 200-077 24" nla nla nla 4.2 8/8/2007 1 0-39 200-216 27" nla nla nla 7.6 8/8/2007 10-40 200-190 13" nla nla nla 3.4 8/8/2007 10-41 205-188 12" nla nla nla 1.7 8/8/2007 1 0-42 200-164 16" nla nla nla 3.4 8/8/2007 10-131 198-110 6" nla nla nla 2 8/8/2007 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg J7eq¿:. 7!,rz.;;'f'o/. P.I. Supervisor 1 ( ( LV DATE: Wednesday, July 12, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 10-39 KUPARUK RIV UNIT 10-39 2Ð6,~)J~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .J~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 10-39 API Well Number 50-029-22997-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ0607I1180707 Permit Number: 200-216-0 Inspection Date: 7/l0/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 10-39 !Type Inj.~ TVD---L 6200 I IA I 1225 I 2705 2675 I 2665 I j i ¡ P.T. i 2002160 !TypeTest i SPT i Test psi i 1550 i OA i 400 540 i 540 I 540 1 I - / Tubing i I Interval 4YRTST P/F P / 2095 i 2090 I 2110 I 2085 ! Notes 2 bbls diesel pumped. I well house inspected; no exceptions noted, ~ ~ ! ) Wednesday, July 12,2006 Page I of I e e KRU 1 D-39 API: 500292299700 Well Type: INJ i Anole @ TS: 73 dea @ 13054 ruSING : I 1 SSSV Type: ¡NIPPLE I Ono Completion: 1217/2001 Anole @ TD: 69 deo @ 13545 I (0-12275, ::. ! Annular FI uid: I I Last W/O: 111/22/2005 Rey Reason: TAG FILL, setDMY, I ,. 00:3.500, ~ i PULL PLUG 10:2.992) ':; I i Reference Log: 1 I Ref Log Date: i Last Update: 2/1112006 I SURF j Last Taa: i 13271 TD: 13545 ftKB : CASING ,', II 1 Last Tao Date: 12/112005 Max Hole Anole: '75 deo @ 5625 I (0-6231, iCasincStrinc~. ALL ... 00:9,625, ',' j Description j Size Top Bottom TVD j Wt I Grade Thread Wt:40,00) CONDUCTOR 20,000 0 120 120 , 91.50 I H-40 WELDED .., SURF CASING 1 9.625 0 6231 4346 I 40.00 I L-80 BTC-MOD ': PROD CASING j 7,000 0 12370 6250 I 26,00 ! J-55 BTC-MOD j ~ LINER 1 3,500 12207 13545 13545 I 9,30 i L-80 SLHT " Tubing Strlng.-.TUBING . ". ," ... < .'. .. PROD ¡" Size 1 Top ! Bottom I TVD I Wt i Grade I Thread CASING 3,500 1 0 12275 1 6219 i 9,30 I L-80 EUE 8rd (0-12370, 'PerforationsSurnrnarv : , . 00:7.000, Wt:26,00) Interval TVD 1 Zone Status I Ft ISPFI Date I Type Comment I 13070 - 13090 6467 - 6473 I C-4 , I 20 I 4 I 4/24/2001 ¡IPERF 2,5" HC/DP, 60-120 deg ph, i I random orientation I I 13160 - 13180 6494 - 6501 I C-4 I 20 i 4 I 4/23/2001 ¡IPERF 2,5" HC/DP, 60-120 deg ph, i i I i random orientation ':: j . 13256 - 13286 6526 - 6536 i C-2 ! 30 I 4 I 4/2312001 ! IPERF 2.5" HC/DP, 60-120 deg ph, I ~ random orientation LINER :12207-13545, II 13310 - 13320 6544 - 6547 i C-1 I 10 I 4 I 4/23/2001 IPERF 2.5" HCIDP, 60-120 deg ph, I 00:3,500, I random orientation Wt:9,30) : 13320 - 13340 6547 - 6554 I C-1 \ 20 I 4 I 4/2212001 I IPERF 2,5" HC/DP, 60-120 deg ph, ¡ random orientation ,StimUlatíoD$ & Treatments ..' I Interval I Date i Type I Comment 13070 - 13340 5/112001 IHPBD ~: Injection. MalldrelslValves '. .... SSE ! St I MD I TVD I Man Mfr Man Type I V Mfr I V Type I VOD I Latch I Port I TRO I Date I Vlv :12213-12214, " ¡1::.:I;lill I I Run Cmnt 00:5.000) .' , 1 4257 3747 CAMCO I KBUG DMY 1,0 BK i 0,000 1 0 i 11/29/2005 I ., other CI1.JCIS, .eauiD.·. etc. )-JEWELRY (POST WORKOVERl .. '.. ~ ......... ........ Depth TVD Tvpe Description ID ., ~ 471 471 NIP CAMCO 'OS' LANDING NIPPLE 2,875 12210 6198 NIP CAMCO 'OS' NIPPLE 2,812 " , I 12213 I 6199 SSE BAKER 80-40 SBE 4,000 ;= .. ~ I 12215 6200 PACKER SAKER ZXP FLEXLOCK LINER TOP PACKER 5,250 PACKER I 12226 6203 SEAL BAKER GHB-22 SEALS 3,000 :12215-12216, I 12293 6225 NIP 'HOWCO XN NIPPLE 2,750 00:7,000) 13543 6625 SHOE I BAKER FLOAT SHOE 0,000 ~ .... . '. ~ ;¡ " SEAL : :12226-12227, > ....... 00:4.000) ~ , " ~ '., ~ ~ .------ ~ : .' , ": NIP > :12293-12294, II " 00:4.520) , " Perf ~)¡ :13070-13090) Perf ~, :13160-13180) ~' ~[ Perf ~i :13256-13286) , f Perf ~r :13310-13320) iJ j l ConocoPhilUpsAlaska, tnc. 11D-39 MEMORANDUM e TO: ~ d \<fÙ{17't! û i.p Jim Regg P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector Well Name: KUPARUK RIV UNIT ID-39 Insp Num: mitLG060425 132938 ReI Insp Num Packer Well I ID-39 IType Inj. ¡wi TVD I . P.T. ¡ 2002160 !TypeTest I SPT i Test psi Interval INITAL PIF P State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 15,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-39 KUPARUK RIV UNIT ID-39 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22997-00-00 Permit Number: 200-216-0 Depth 6200 e o #..~\{, ðß Reviewed B~:. / ) 12p P.I. Suprv . V¡""- Comm Inspector Name: Lou Grimaldi Inspection Date: 4/25/2006 ! , IA I 720 ¡ O~ 370 Tubing I 1870 Initial 15 Min. 30 Min. 45 Min. 60 Min. I 1680 1655 I 1655 -- i 450 445 445 I 1850 1840 1850 ;/ Pretest 1550 Notes Observed pretest conditions for 45 minutes to satisfy 500 psi D.P. requirement. Monday, May IS, 2006 . \1\' ./ .: ")1\ nt: :j'CANNED JU¡~ 1 ';\: ,-uwU Page I of I Re: KRU 1D-39 ~ ., • ~ ~~ii ~~~. "~~f `~'~ V..I C~`~ ~ ~~ ~i~~ ~~c- ~~~~~ Ennis, J J wrote, On 4/27/2006 9:03 AM: ~D ~` ~ ~~4~V~~~C-~~ ~ ? Good morning Tom, 76~(~(}~~~. .~~ .:~~ ~ ~,~; ~( ~ ~~~ r At my request, Sharon held off on submitting the 404 until the well was returned to injection which finally occurred on 4/13/06. I don't consider the work complete until this occurs but this dragged out excessively. If you would prefer that we submit the 404 regardless of ~ well status, we'll institute immediately and I'11 apologize now for the q~aG. 1D-39 tardy submittal. Let us know which way you'd like to proceed. CJ ~( Jim Ennis /~y ~' 2~.~ j. j• er:n =s~` ca-~ccopY3.iwlips. com (907)265-1544 (W) r,- ,~ ~' (90~) 632-~2a1 (c) ~ '~ .~~j'~r~ ~_ ~:~'"~.~L~,,~ . ~.,E ~. ~~ -----Original Message----- From: Allsup-Drake, Sharon K Sent: Thursday, April 27, 2006 8:53 AM To: Ennis, J J Subject: FW: KRU 1D-39 Jim - do you think I should reply? Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder [mail;o:tozn mr~uxzder«?~dm.i_x~..sta~e.ak.us] Sent: Thursday, April 27, 2006 8:51 AM To: Allsup-Drake, Sharon K Subject: KRU 1D-39 Sharon, You may not have been involved with this reporting. It was signed by Jim Ennis, however it appears I don't have his email. I'd appreciate if you would forward this. We have received the 404 for the workover on 1D-39. I was curious, the summary shows the work to have been completed in late November but the 404 was not sent until late April. The summary does not indicate that there was any post-rig work that would have delayed submitting the report. Regulations require the 404 to be submitted within 30 days of finishing the work. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 4/27/2006 2:04 PM U 1111 Q11U J11Qi Vll ~ I will check with my colleagues over here and get back to you Tom • , ~ N • ~onoCOPh~lltps April 18, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • • Jim Ennis Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 Subject: Report of Sundry Well Operations for 1 D-39 (APD # 200-216 / 305-133) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operation on the Kuparuk well 1 D-39. If you have any questions regarding this matter, please contact me at 265-1544 Since ly, .~.~ ~r' J. Ennis , Wells Engineer CPAI Drilling and Wells JE/skad • • • • ~~~~~~~~ STATE OF ALASKA ~~~"~f~ ~ ~ ~~~j,~~` ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~a~~a ~"~ ~ ~`~° ~~"~. ° ~~~~~~6on F2 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ~ Stimulate ^ Other Alter Casing ^ Pull Tubing ^/ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnoCOPhillipS Alaska, InC. Development ^ Exploratory ~ 200-216 / 305-133 3. Address: Stratigraphic ^ Service ^~ 6. API Number: ~ P. O. Box 100360, Anchorage, Alaska 99510 50-029-22997-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 35' 1 D-39 ' 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25650, ALK 471 Kuparuk River Field / Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 13545' ~ feet true vertical 6625' ' feet Plugs (measured) 12293' Effective Depth measured 13394' feet Junk (measured) true vertical 6572' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 120' 120' SURF CASING 6196' 9-5/8" 6231' 4346' PROD CASING 12335' 7" 12370' 6250' LINER 1338' 3-1/2" 13545' 6625' Perforation depth: Measured depth: 13070'-13090', 13160'-13180', 13256'-13286', 13310'-13340' true vertical depth: 6467'-6473', 6494'-6501', 6526'-6536', 6544'-6554' Tubing (size, grade, and measured depth) 3-1l2" , L-80, 12275' MD. ~ Packers & SSSV (type & measured depth) Baker ZXP pkr @ 12215' Camco'DS' nipple @ 47T 12. Stimulation or cement squeeze summary: Intervals treated (measured) 1 3070'-13340' Treatment descriptions including volumes used and final pressure : HPBD 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation -- -- SI ' Subsequent to operation -- -- 3100 ~ 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~ ~ '-• ~~~ l~ contact Jim Ennis @ 265-1544 Printed Name J~ nnis Title Wells Engineer Signature ~ Phone Date ~ f~ ~ ~ ~- Pre a2d b Sharo Allsu -Drake 263-4612 ~• ZL-Uc- ` I ~' j ~ /~,j ~~~ ~~.~ h,iJu i: Es ~D09 ~~'! ~~ ~ su,b.,~~ t yo~ ~ Form 10-404 Revised 04/2004 ~/J L°~ '~ _ - iG~i Y""~al Only /~ • Legal Well Name: 1 D-39 Common Well Name: 1 D-39 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S 11/17/2005 I 08:00 - 17:00 I 9.00 I MOVE I RURD I MOVE 17:00 - 18:30 1.50' MOVE MOVE MOVE 18:30 - 21:00 2.50 MOVE RURD MOVE 21:00 - 00:00 3.00 MOVE RURD MOVE 11/18/2005 00:00 - 03:00 3.00 MOVE RURD MOVE 11l19/2005 11 /20l2005 11 /21 /2005 03:00 - 12:00 I 9.001 MOVE I RURD I MOVE 12:00 - 15:00 I 3.00 i MOVE I RURD I MOVE 15:00 - 21:30 I 6.50 i MOVE I RURD I MOVE Spud Date: 1/16/2001 Start: 11/18/2005 End: Rig Release: 11/22/2005 Group: Rig Number: Rig was released from 1 E-166 @ 8:00 AM on 11/17/05. Freeze protect tubing and IA to 2500' with diesel on 1 E-166. Prep rig for rig move to 1 D-39. Move the rig from 1 E to 1 D-pad. Spot rig camp. Line up rig to wellhead. Prep well sight for rig. Spot BOPE behind welihead. Made several attempts to spot rig over welihead. Had to call out welder and DSM to remove section of flowline on 1 D-40. Welder had to cut away metal floor brackets. Lay out herculite. Spot rig over wellhead. Spot pits and pipe shed. Continue rig up. Contacted AOGCC John Spalding declined to witness BOP test. Standing up derrick and continuing to rig up. Derrick up working on burming rig and rigging up guy wires. Piant line on tree, tubing head adapter, and tubing head. Take pictures of tree for reference at end of workover. Ready pits for brine. Verify well is dead. Accept riq (cD_ 19:00 on 11l18/2005. 21:30 - 23:30 23:30 - 00:00 00:00 - 06:00 06:00 - 16:00 2.00 ~ MOVE j 0.50 j MOVE 6.00 ~ WELCT 10.00; WELCT RURD RURD NUND BOPE MOVE MOVE DECOMP DECOMP ND wellhead and adapter flange. Inspect lift threads and make up blanking plug. Install blanking plug. Load pits with 260 bbls of 9.7 ppg brine. Start NU BOP, Function test BOPE. Pressure test rams and annular to 250 / 3000 si. ' Witnessing waived by AOGCC (John Spalding} 16:00 - 21:00 5.00 i WELLS PULD DECOMP BOP test completed. Pull Blanking plug Pump threw BPV to insure well boar is open Pull BPV and screw in landing joint attempt to pull tubing free of SBE. Verify well is stable. BOLDS. Unland tubing hanger at 80K. Tubing pull free at 100K. Lay down tubing hanger. 21:00 - 22:00 1.00; WELLS RURD DECOMP Rig up head pin and prep to circulate hole. 22:00 - 00:00 2.001 WELLS CIRC DECOMP Circulate hole clean (430 bbls) 00:00 - 06:00 6.00 ~ WELLS PULD DECOMP Tower Safety meeting continuing to decompleting well pulling old tubing ; to surface laying down sideways. 06:00 - 12:00 6.00; WELLS PULD DECOMP Bad corrosion on the inside of tubulars 't. 240 severe ittin . ` j Continue to pull tubing 12:00 - 18:00 6.00! WELLS PULD DECOMP Tower meeting, Continuing to pull completion. 18:00 - 20:00 2.00' RIGMNT RSRV DECOMP Rig service. Repair tubing tongs. 20:00 - 2230 2.50'; WELLS PULD DECOMP On surface with BHA, full recoverv. Seal look qood on seal assemblv. I , Lay down BHA. Remove remaining tubing (Old completion) from pipe 2230 - 00:00 I ' 1.50 j CMPLTN PULD CMPLTN shed. Start strapping and drifting tubing for completion run on tubing ' ~ ~ previousiy loaded in pipe shed. " 00:00 - 10:00 10.00 I CMPLTN PULD CMPLTN Continue loading pipe shed with new 3.5 completion. Very slow I progress do to handling -38 degree pipe, trouble removing end caps for ' drift. 10:00 - 12:00 ' 2.00 RIGMNT RGRP CMPLTN No hydraulic pressure to the power tongs shut down waiting on rig 12:00 - 18:00 '; 6.00 I CMPLTN RUNT , CMPLTN Run new completion consistinq of 358 its. of new 3.5 " L-80 8rd MOD 18:00 - 00:00 11 /22/2005 ' 00:00 - 02:30 I I ~ tubin a 44' Baker seal assembl with 11.5' of seals and 36.7' to the ~ No-Go, a 2.812" ID nipple @ 12204', one GLM @ 4241' with a 1" DV, a ; 2.875 ID nipple @ 454'. New seal rings and Jet Lube Run-N-Seal dope ; used on all connections. Hole remains stable. 6.00 CMPLTNi RUNT CMPLTN Tower meeting discus landing the tubing and ND, NU procedures, 155 ~ jts in the we11234 jts to go, continue to run new completion 330 jts of ~ 389 jts. 2.50 CMPLTNj RUNT CMPLTN Continue in hole with completion. Printed: 1/6/2006 9:26:13AM C~ Legal Well Name: 1 D-39 Common Well Name: 1 D-39 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S 11/22l2005 I 02:30 - 0430 04:30 - 05:30 05:30 - 0930 0930 - 12:30 12:30 - 18:00 18:00 - 20:30 20:30 - 00:00 Spud Date: 1/16/2001 Start: 11/18/2005 End: Rig Release: 11/22/2005 Group: Rig Number: 2.00 I CMPLTNI SOHO CMPLTN Get weights, UP=85k / down=45k. Rig up head pin on joint 390; ~~ establish rate with charge pump, see pressure increase. Pick up joint 391, tag seal assembly locator 2.5" in on joint 391. Lay down joints j i 391/390/389. Add 8' pup joint and joint 389. Rig up head pin. 1.00 CMPLTN CIRC CMPLTN ; Circulate in / spot corrosion inhibited brine. 4.00 CMPLTN SOHO ; CMPLTN ~ Make up tubing hanger and landing joint. Land tubing hanger. RILDS. ~ We had problems landing hanger seal ass.Appeared to be hanging up ~ as the seals entered the seal bore (suspect debris on top of polish bore). Removed hanger and pumped down the tubing to clear obstruction, worked the qipe in and out of the seai bore, makin more footaae each time. Pulled up free and reinstalled the hanaer: landed without an problems. 13' of sea~s in the polished bore, NO-GO 1.5' up from tag. Hanger set and lock downs in place. 3.00 CMPLTNi DEQT CMPLTN Pressure test tubina to 2500 osi, hold for 30 min and chart. bleed down ; Bleed tubing to 0 psi shear out SOV 5.50 CMPLTN~ NUND CMPLTN Pull landing joint, install two-way check and ND BOP stack, NU i Wellhead. 2.50I CMPLTN SEQT CMPLTN Test pack-offs and tree to 5000 psi-- good. Pu112-way check and ~ installed BPV. Release riq at 8:30 am. 11/22/05. 3.50', MOVE I DMOB DEMOB Prep for rig move. Printed: 1/6/2006 9:26:13AM r l ~, r' ~ ~ +~~t~~r~"~illips 1~ ~~ In~. i a-~s APL• ' ' 7uBING SSSV T e: (o-i2275, Annular Fluid: OD:3.5o0, Reference Lo : ID2.9s2) Last Ta : SURF Last Ta Date: ~ CASING Casin" Strin'' - ~o~2s~, oD:9 s25 Descri tion . , Wt:ao.oo) CONDUCl PROD CASING (0-12370, OD:7.000, Wt:26.00) LINER 12207-13545, OD:3.500, Wt:9.30) SBE 12213-12214, OD:5.000) PACKER 1 221 5-1 2216, OD:7.000) SEAL 12226-12227, OD:4.000) NIP 12293-12294, OD:4.520) PLUG 12293-12294, OD2.750) Perf 13070-13090) Perf 13160.13180) ~ ~ 120 KRU 'D-39 r~~ ~vk~auti~~a e~caeuauear Interval ND Zone Status Ft SPF Date T e Comment 13070 - 13090 6467 - 6473 C-4 20 4 4/24/2001 IPERF 2.5" HClDP, 60-120 deg ph, random orientation 13160 - 131 SO 6494 - 6501 C-4 20 4 4/23/2001 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13256 - 13286 6526 - 6536 C-2 30 4 4/23/2001 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13310 - 13320 6544 - 6547 C-1 10 4 4/23/2001 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation 13320 - 13340 6547 - 6554 C-1 20 4 4/22/2001 IPERF 2.5" HC/DP, 60-120 deg ph, random orientation Stirriulatic~ns & Treatments Interval Date T e Comment 13070 - 13340 5/1/2001 HPBD ~FI ~ CtIO[I ~S( i~CB~S}~O~V@S ' St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Viv Perf 13256-13286) Perf ;13310-13320) ) ) C~\ i::.'"7.:J :"fw ,,'I "I ,.~ III ~\ . ~ ;.. I, " © rU ._M_, 'r? J..¡, J",,"u ,,' rJ I: I 'I ',: ¡I¡,F" ~,: ~ fñ""-" "Ü' J' ,j.1""'" i:' .¡ l II ,;:.:;¡ II ¡ : ¡ il r' \~: U FRANK H. MURKOWSKI, GOVERNOR ATfASIiA OIL AND GAS CONSERVATION COltDllSSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~ï,,~¡_'(\c.l,,:( ~' ~'E1V (7"'i",k!? Jim Ennis W ells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk ID-39 Sundry Number: 305-133 SC/-\NNED JUN 1 4 2005 Dear Mr. Ennis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field i~:;pëctor at (9ûï) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. a l / i71 I l~ oNrm'0 ~ ~~ DATED thisti'::ay of May, 2005 Encl. ) Jim Ennis ) Staff Wells Engineer Drilling & Wells , ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 May 27,2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 2 7 2005 Alaska Oil & G!JS COilS. Commi~~Úij1ì'~ Ai1chor~g€: Subject: Application for Sundry Approval for 1 D-39 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 1 0-39. We are planning to workover this well to pull and replace the tubing. If you have any questions regarding this matter, please contact me at 265-1544. Sincerely, ~ Jim Ennis Staff Neils Engineer CPAI Drilling and Wells JE/skad r)R,(,'r'JAL l ! '\. I 0 11\ ) STATE OF ALASKA ~/);;lß RECEIVE[~ ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 7 2005 ~(;l' APPLICATION FOR SUNDRY APPROV ALAlaska OH & Gas Con~. Comn:.., 20 AAC 25.280 km;hß1r~~p. D Suspend D Operation Shutdown D Perforate D Waiver D ' Other 0 D Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 50-029-22997-00 9. Well Name and Number: 1 D-39 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6572' MD 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 35' 4. Current Well Class: Development Stratigraphic o o Exploratory D Service 0 8. Property Designation: ADL 25661 & 25650, ALK 471 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 13545' 6625' 13394' Casing Length Size TVD 120' CONDUCTOR 80' 20" SURF CASING 6196' 9-5/8" PROD CASING 12335' 7" LINER 1338' 3-1/2" 120' 6231' 12370' 13545' 4346' 6250' 6625' Perforation Depth MD (ft): Perforation Depth TVD (ft): 13070'-13090',13160'-13180', 13256'-13286', 13310'-13340' 6467'-6473',6494'-6501',6526'-6536',6544'-6554' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ZXP pkr @ 12215' Camco 'OS' nipple @ 526' 12. Attachments: Description Summary of Proposal D 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch D Exploratory D Development D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 15, 2005 Oil D Gas D 16. Verbal Approval: Date: WAG D GINJ 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name \\~~nniS Signature N .-/ \ j Tubing Size: 3-1/2" Contact: Title: Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test ~ Mechanical Integrity Test ~ Location Clearance 0 Other: ~~C (J Q~ \ ~~ ~CJV~~ RBDMS 8Ft .IUN 06 Z005 APPROVED BY COMMISaf<1 G I NTf\C~MMISSION ~ Form 10-403 Revised 11/2004 5. Permit to Drill Number: '200-216 ..,¿: 6. API Number: /' Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 12275' Service 0 Plugged D WINJ 0 Abandoned D WDSPL D Jim Ennis @ 265-1544 Wells Engineer 1'/ '_ / Date $ / J. 't 0 r Sundry Number: 3Ds-"-/83 Date: f/t1-~f Submit in Duplicate ) ') Rig Workover Procedure Well 1 D-39 Kuparuk Injector Repair tubing leaks Well History and RWO Obiectives: 10-39 was originally completed in February 2001 as a 3.5" single injector (see wellbore diagram). Recently a tubing collar leak at 11979' RKB was diagnosed. A patch of the tubing leak was considered but a caliper revealed the tubing ID to be in poor condition with 85% wall loss in several locations. The procedure outlined below will replace all the tubing with new to restore injection. Pre-rig Work: Work accomplished to date: 2/05/05 FCO w/ mtr & mill to 13484'. 2/06/05 D&T w/ 2.75" @ 13478' RKB, 38' rathole. 2/11/05 IPROF and LOS's function tested and torqued to 450 ftllbs. 2/12/05 MITIA failed. MITOA failed. PPPOT-T & IC passed. Master & swab valves PT'd OK. 2/17/05 Set SV @ 12293'. CMIT 2500 psi, OK. 3/12/05 Replaced OV in GLM. Set 'XXN' @ 12293'. MIT failed. 3/17/05 Pulled 'XXN'. 3/29/05 LDL, leak in tubing at 11979' RKB (collar). 4/01/05 Roundtrip Panex to 13325' MO (6549' TVD), 3229 psi. (EMW 9.5 ppg, MASP 2574 psi) 4/29/05 Log POS caliper 12255' to 10066' WLM. Remaining work: 1. Submit sundry application for injector tubing leak repair. 2. Rig up Slickline. 3. Set 'PX' plug in 'XN' nipple @ 12293' RKB. 4. Load well with 9.6 ppg brine circulating through tbg leak @ 11979'. Maintain OA below 1000 psi while circulating. 5. PT plug to 2500 psi. Bleed well down to zero. 6. Prepare location for workover rig. 7. Set FMC 3" ISA BPV within 24 hrs of MIRU. Rig Work: 1. Verify sundry approval for injector tubing leak repair. 2. MIRU N3S. Verify well is dead. Paint line on tree, tbg head adapter and tbg head. Take photo of tree position for reference at end of workover. 3. NO tree. NUBOP. Function test BOP. Pull BPV and install test plug. PT BOP rams to 250/3000 psi and annular to 250/3000 psi. Pull test plug. (Note: 24 hr advance notification to AOGCC required prior to testing BOPE.) 4. Unland tbg hanger. Attempt to pull tbg from Baker SBE. If unsuccessful @ 80% tbg yield (166M#), rig up E-line and shoot string shot followed by chemical-cut of tbg in middle of first full joint above packer. POOH w/ 3.5" tbg laying down. No equipment shall leave location until surveyed for NORM. Equipment disposition: Tree Tbg hanger and adapter Tubing/Pups Gaslift mandrels I nspect and re-use Inspect and re-use Inspect and re-stock I nspect and re-stock Jim Ennis Page 1 5/26/05 Draft ) ) Rig Workover Procedure Well 1 D-39 Kuparuk Injector Repair tubing leaks ~ *<t> 5. If tbg was chemical cut, go to step'K, If seal assembly pulled OK, RIH wI 3.5" completion, drifted to 2.867", as follows: Seal assembly Re-dress and re-use · Use Jet Lube Run-N-Seal connection dope. · Record OD's and ID's of all auxiliary equipment on tbg detail. a) Seal assembly wI locator b) 2.812" Camco 'OS' nipple. c) New 3-1/2", 9.3#, L-80, EUE 8RD AB mod tubing wI KBUG 1" GLM @ -4300' RKB (loaded wI 1500 psi SOV) · 3.5", 9.3#, L-80, 8RC AS mod torque (ft-Ibs): 1680 min, 2240 optimum, 2800 max d) 2.875" Camco 'OS' nipple @ 500' (3.5" tbg above must drift 2.91 ") 6. If tbg was chemical cut, RIH wI 3.5" completion, drifted to 2.867", as follows: · Use Jet Lube Run-N-Seal connection dope. · Record OD's and ID's of all auxiliary equipment on tbg detail. e) Baker slick 3.5" overshot f) 2.812" Camco 'OS' nipple wI RHC plug installed g) 1 joint 3.5" tbg h) Baker FHL packer (pinned 60M# shear) & PBR (pinned 40M# shear) i) New 3-1/2", 9.3#, L-80, EUE 8RD AB mod tubing wI KBUG 1" GLM @ -4300' RKB (loaded wI 1500 psi SOV) · 3.5",9.3#, L-80, 8RC AS mod torque (ft-Ibs): 1680 min, 2240 optimum, 2800 max j) 2.875" Camco 'OS' nipple @ 500' (3.5" tbg above must drift 2.91 ") 7. Locate SBE or tbg stub. Spot corrosion inhibited brine (2% by volume Baker Petrolite CRW-132) in IA below GLM prior to stabbing inlover. If necessary, drop ball and rod, set FHL wI 2500 psi and shear PBR. Space-out, land tbg hanger. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed off tubing pressure to 1500 psi. Holding the tubing pressure at 1500 psi, PT IA to 2500 psi for 30 minutes. Bleed off tubing pressure to shear the dump kill valve in bottom GLM. Install BPV. NDBOP. NUWH. Pull BPV. Install test plug. Test tree and packoffs to 5000 psi. Pull test plug. Install BPV. RDMO. Turn well over to Production via Handover Form. Jim Ennis Page 2 5/26/05 Draft ) ) Rig Workover Procedure Well 1 D-39 Kuparuk Injector Repair tubing leaks Post Rig Work 1. Circ out brine above GLM wI corrosion inhibited brine (2% by volume Baker Petrolite CRW-132) and freeze protect well wI diesel. 2. RU slickline. 3. Replace shear valve with dummy. PT tbg 2500 psi. 4. If necessary, retrieve ball and rod and RHC plug. 5. Retrieve 'PX' plug. Jim Ennis Page 3 5/26/05 Draft NIP (526-527, 00:4,562) Injection ,drel/Oummy Valve 1 (4306-4307, 00:5,968) NIP 2192-12193, 00:4.520) PACKER 2215-12216, 00:7,000) SSE 2234-12235, 00:5.000) SEAL 2238-12239, 00:4,000) NIP 2293-12294, 00:4.520) HPBO 3070-13340) Perf 3160-13180) Perf 3256-13286) Perf 3310-13320) ) ConocoPhilUpsAlaska, Inc. ~ ) KRU 1 D-39 Well Type: INJ Angle @2 TS: 73 deg @2 13054 Orig Completion: 2/7/2001 Angle @2 TD: 69 deg @2 13545 Last W/O: Rev Reason: TAG Ref Log Date: Last Update: 4/30/2005 ID: 13545 ftKB Max Hole 75 5625 Size Top Bottom TVD Wt Grade Thread 20.000 0 120 120 91.50 H-40 WELDED 9.625 0 6231 4346 40.00 L-80 BTC-MOD 7.000 0 12370 6250 26.00 J-55 BTC-MOD 3.500 12207 13545 13545 9.30 L-80 SLHT Bottom TVD Wt Grade Thread 12275 6219 9.30 L-80 EUE 8rd AP I: 500292299700 SSSV Type: NIPPLE Annular Fluid: Reference Log: Last Tag: 13394 WLM Last Date: 4/29/2005 Description CONDUCTOR SURF CASING PROD CASING LINER TubingStrlna. . TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 13070 - 13090 6467 - 6473 13160 - 13180 6494 - 6501 Zone C-4 Status Ft SPF Date Type Comment 20 4 4/24/2001 IPERF 2.5" HC/OP, 60-120 deg ph, random orientation 20 4 4/23/2001 IPERF 2.5" HCIDP, 60-120 deg ph, random orientation 30 4 4/23/2001 IPERF 2.5" HC/OP, 60-120 deg ph, random orientation 10 4 4/23/2001 IPERF 2.5" HC/OP, 60-120 deg ph, random orientation 20 4 4/22/2001 (PERF 2.5" HC/DP, 60-120 deg ph, random orientation Comment 13310 - 13320 6544 - 6547 C-1 13256 - 13286 6526 - 6536 C-2 C-4 13320 -13340 6547 - 6554 C-1 Stimulations & Interval Date Type 13070 - 13340 5/1/2001 HPBD St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 4306 3765 CAMCO MMG CAMCO DMY 1.5 RK 0.000 0 4/25/2001 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description ID 526 526 NIP Camco 'OS' Nipple wl2.875" No-Go profile 2.875 12192 6192 NIP Camco 'OS' Nipple wl2.818" No-Go profile 2.812 12215 6200 PACKER Baker 7" x 5" ZXP Liner Top Packer wl5" TKC coupling 5.000 12234 6206 SBE Baker 80-40 SBE w/TKC couplings & XO 4.000 12238 6207 SEAL Baker 4" x 3" GBH-22 Seal Assembly w/17' seals 3.000 12293 6225 NIP Howco XN Nipple 2.750 13543 6625 SHOE Baker Float Shoe 0.000 SChlumberger NO. 3357 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth éRðO - 2e/~ 02/28/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 SCj,NNED JUN 1 (7 2005 Field: Well Job # Log Description Date BL i'ð'5 -c5D 2V-12 10942845 PROD PROFILE/DEFT 02/16/05 1 1~t.f"153 20-03 10922538 PROD PROFILE/DEFT 02/06/05 1 &l. lK) , 2.ì it:? 1 D-39 10942838 INJECTION PROFILE 02/11/05 1 /flj- -Cqf> 2V-10 10942846 PROD PROFILE/DEFT 02/17/05 1 ~Ol- JtB3 1C-131 10942848 INJECTION PROFILE 02/19/05 1 190 - /tp/ 1A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /79...C/O 2N-308 10942843 PRODUCTION PROFILE 02/14/05 1 (~~_~h 1 L-17 10942850 INJECTION PROFILE 02/21/05 1 1 B-15A 10922540 SCMT 02/24/05 /ì /.., ()& (p 1 L-24 (REDO) 10942834 RST WFL & PPROF 01/26/05 1 SIGNuM)! !ith~ Please sign and return%ne copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. DATE: Kuparuk Color - CD 1 -' ~~- / ' F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Permit to Drill 2002160 MD 13545 ~' TVD DATA SUBMITTAL COMPLIANCE REPORT 4118/2003 Well Name/No. KUPARUK RIV UNIT 1D-39 Operator CONOCOPHILLIPS ALASKA INC 6625 ? Completion Dat 4/22/2001 -~ Completion Statu 1WINJ Current Status 1WINJ APl No. $0-029-22997-00-00 UIC Y REQUIRED INFORMATION Mud Log No Sample No Directional Survey ~--I~o-~_~, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type .Media Fmt Ver LIS Verification Ver LIS Verification D Interval Log Log Run Name Scale Media No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments ~C Cement Bond Log 5 Directional Survey PGSS Directional Survey PGSS Directional Survey Directional Survey Directional Survey MWD Directional Survey MWD (~EINA~ 12100 13468 1 6190 13497 1 6198 13490 FINAL FINAL FINAL FINAL FINAL FINAL ch 6/1/2001 Open 4/26/2002 Open 1/3/2002 ch 3/7/2001 ch 3/7/2001 ch 3/7/2001 ch 3/7/2001 ch 3/7/2001 ch 3/712001 10793 10515 12100-13468 Color Print Directional Survey Digital Data Directional Survey Paper Copy Directional Survey Digital Data Directional Survey Paper Copy Directional Survey Digital Data Directional Survey Paper Copy Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y it~ Chips Received? Analysis R~.r.R. ivP. d ? Daily History Received? Formation Tops Permit to Drill 2002160 MD 13545 Comments: TVD DATA SUBMITTAL COMPLIANCE REPORT 411812003 Well Name/No. KUPARUK RIV UNIT 1D-39 Operator CONOCOPHILLIPS ALASKA INC 6625 Completion Dat 4/22/2001 Completion Statu 1WINJ APl No. 50-029-22997-00-00 Current Status 1WINJ UIC Y Compliance Reviewed By: 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 January 21, 2002 RE: MWD Formation Evaluation Logs 1D-39, AK-MM-10023 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 1D-39: Digital Log Images 1 CD Rom RECEIVED ~ ~ ~ £00~ Alaska Oil & 6ss Cons. Commissio~ Anchorage To: WELL LOG TRANSMITT~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 18, 2001 MWD Formation Evaluation Logs 1 D-39, AK-MM- 10023 1 LDWG formatted Disc with verification listing. API#: 50-029-22997-00 'PLEASE ~,CKN0WLEI)GE RECEIPT BY SiG,NING. AND RETURNING, A coPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: R.ECFiVED 5/2312001 Schlumberger NO. 1155 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print DATE: ,.)g! t 0 1 ?-001 - I Alaska Oil l Gas Cons. C0mmisston Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank yot~l~ 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 May 11, 2001 Commissioner Cammy Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1D-39 (200-216) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 1D-39. If you have any questions regarding this matter, please contact me at 265-6434 or Todd Mushovic at 265-6974. Sincerely, J. Trantham Drilling Engineering Supervisor PA1 Drilling JT/skad RECEIVED MAY 1'5 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended r'] Abandoned r-~ service [~] Produced Water Injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-216 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22997-00 .4. Location of well at surface ' - ' .... ~ ~m.--..-."-.-'. "[,OC~i 9. Unit orLease Name 5PP' FNL, 421' FEL, Sec. 23, T11N, R10E, UM (ASP: 560671, 5959144)~ At Top Producing Interval i 10. Well Number 1960' FSL, 586' FEL, Sec. 25, T11 N, R10E, UM (ASP: 565856, 5951111 )! 1 D-39 ._~~. i ~'~J'~! 11. Field and Pool At Total Depth 1565' FSL, 344' FEL, Sec. 25, T11N, R10E, UM (ASP: 566101, 5950718)':, ........................ ,.~-.~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 35 feetI ADL 25661 & 25650 ALK 471 12. Date Spudded 13. Date T.D. Reached 14. Date _~omp.,~Susp. Or Aband. ~15. Water Depth, If ol/shore 16. No. of Completions January 16, 2001 February 4, 2001 2oo1, i,/A ,.,MSL 1 I 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 13545' MD /6625' TVD 13476' MD /6592' TVD YES [~] No ~]I N/A feet MD 1418' 22. Type Electric or Other Logs Run GR/Res/Neu Dens, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE V~rl'. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 120' 30" 382 sx AS I 9.625" 40# L-80 Surface 6231' 12.25" 548 sx ASlII Lite, & 540 sx LiteCmte 7" 26# J-55 Surface 12371' 8.5" 170 sx Class G 3.5" 9.3# L-80 12262' 13545' 6.125" 250 sx Class G 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" 12275' 12215' 13310'-13340' MD 6544'-6554' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13256'-13286' MD 6526'-6536' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13160'-13180' MD 6494'-6501' TVD 4 spf see attachment for HPBDdetails 13070'-13090' MD 6467'-6473' TVD 4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas li~t, etc.) Injector Date o! Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') press, xxx psi 24-Hour Rate > 28. CORE DATA Brie~descripti~n~f~~th~~~gy~p~r~sity~fract~res~ap~arentdipsand~ressence~f~i~~gas~rwater~ Submit core chips. RECEIVED N/AMAY 1 '5 2001 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE OEIGII Ai .... Submit in duplicate ~' t 30. ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. RECEIVED Top Kuparuk O 13054' 5462' BaseKuparukC 13349' 6557' ~'~'V 1 5 ~01 Top Kuparuk A 13545' 6625' Base Kuparuk A 13545' 6625' AJaska 0il & Gas Cons. Commission Anchor~je Annulus lef~ open - freeze pro~ec~ed wi~h diesel. ~"1. LIST OF ATTACHMENTS Summ~ry of D~ily Opsm~ions, Directional Survey 32. I hereby certify that the following is tree and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 /,. ,.,,/. Signed Title Drillin,q En,qineerln,q Supervisor Date ,~//~/~'/ / / 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 OIRI6IIqAL Operations Summary 1 D-39 Rpt Date 01/15/01 01/15/01 01/15/01 01/15/01 01/15/01 01 /16/01 01/16/01 01/16/01 01/16/01 01/16/01 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM Begin 18:00 19:00 20:00 22:00 23:00 00:00 03:30 06:30 07:30 10:00 Time End Time 19:00 20:00 22:00 23:00 00:00 03:30 06:30 07:30 10:00 21:30 Comments Prep. rig for rig move Roads & Pads level pad around 1 D-39 Move rig f/1 D-37 to 1 D-39 Button up cellar, Berm same Nipple up Diverter. Rig accepted on 1D-39 @ 2300 hrs Nipple up diverter system Pick up BHA Test Diverter system, Hold prespud meeting Fill hole & check for leaks-OK, Spud @ 0745 hrs, Drill f/135' to 205' ART- 1 hr/AST- .75hr/Gyro .25hr Rig down time, Repair Main Auger bearings- replaced 3 hangers, 2 connecting shafts, Elecric motor & belts, mounting plates 01/16/01 01/17/01 01/17/01 01/17/01 01/17/01 01/17/01 01/18/01 01/18/01 01/18/01 01/18/01 01/18/01 01/18/01 01/18/01 01/19/01 01/19/01 01/19/01 01/19/01 01/19/01 01/19/01 01/19/01 01/20/01 01/20/01 01/20/01 01/20/01 01/20/01 01/20/01 01/20/01 01/20/01 01/21/01 01/21/01 01/21/01 01/21/01 01/21/01 01/22/01 01/22/01 01/22/01 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM 21:30 00:00 03:00 04:00 22:30 23:30 00:00 01:30 02:00 12:00 13:00 17:00 18:30 00:00 08:30 09:30 13:00 14:30 19:30 21:00 00:00 01:30 04:00 05:00 08:00 08:30 11:00 12:30 00:00 05:30 07:00 09:00 10:30 00:00 05:00 07:00 00:00 03:00 04:00 22:30 23:30 00:00 01:30 02:00 12:00 13:00 17:00 18:30 00:00 08:30 09:30 13:00 14:30 19:30 21:00 00:00 01:30 04:00 05:00 08:00 08:30 11:00 12:30 00:00 05:30 07:00 09:00 10:30 00:00 05:00 07:00 13:30 Drill f/205' to 253' ART= .75hr, Run Gyro surveys Drill f/253' to 400' ART=I hr, AST= 1 hr Rig down time due to oiler pump in Ball mill Drill f/400' to 1700' KOP ART- 8.25hrs, AST-3.75hrs Pump sweep, Monitor well, Pump dry job Wipe hole Short Trip ti DC's, RIH, no problems, proper fill. Circ Bttms up. Drilling f/1700' to 2475' ART=3.25 hr. AST=4.25 hrs. Clean out auger f/pits to Ball Mill. Packed w/clay. Drilling f/2475' to 2867' ART=I hr. AST=1.75 hrs Change out end bearings on auger shaft. Drilling f/2867' to 3252' ART=2.25 hrs AST=2.75 hrs. Drill f/3252' to 3809' ART= 2.75hrs, AST- 4.25hrs Pump sweep & Circ. hole clean Monitor well, Wipe hole to 1700'-OK Circ. Btm's up & Cond. mud Drill f/3809' to 3991' ART=2.5hrs, AST=l.5hrs Pump sweep & Circ. hole clean Monitor well, Pump dry job, POOH f/new bit POOH, Service MWD, Change Bits-(Found a piece of metal in bit) TIH w/BHA, Test MWD, TIH to 3991'-OK Circ. Btm's up Drill f/3991' to 4130' ART= 1 hr, AST- 1.5hrs Repair Pump #2- Replace 2 valves, Clean screens Drill f/4130' to 4183' ART- 2hrs Repair Pump #2- Clear junk out from under valves Drill f/4183' to 4940' ART= 6.25hrs, AST- 2.5hrs Drill f/4940' to 5310' ART= 3.5hrs, AST- .75hr Pump sweep, Circ. hole clean, Monitor well, Pump dry job Wipe hole to 3900'-OK Circ. Btm's up Drill f/5310' to 6000' ART= 9.0hrs, AST- 1.25hrs Drill f/6000' to 6241' ART= 3.75hrs Pump sweep, Circ. Btm's up, Monitor well, Pump dry job Wipe hole to HWDP- Hole in good shape 01/22/01 12:00 AM 01/22/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/23/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/24/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/25/01 12:00 AM 01/26/01 12:00 AM 01/26/01 12:00 AM 01/26/01 12:00 AM 01/26/01 12:00 AM 01/26/01 12:00 AM 01/26/01 12:00 AM 01/26/01 12:00 AM 01/27/01 12:00 AM 13:30 16:30 00:00 00:30 02:30 11:00 14:00 15:00 17:00 18:30 21:30 22:30 00:00 01:00 02:30 06:30 08:30 12:00 13:00 15:00 15:30 17:00 18:00 19:00 19:30 20:00 00:00 00:30 04:00 05:00 06:00 07:30 08:30 09:30 10:00 00:00 15:00 16:00 18:30 19:30 21:30 22:30 00:00 16:30 00:00 00:30 02:30 11:00 14:00 15:00 17:00 18:30 21:30 22:30 00:00 01:00 02:30 06:30 08:30 12:00 13:00 15:00 15:30 17:00 18:00 19:00 19:30 20:00 00:00 00:30 04:00 05:00 06:00 07:30 08:30 09:30 10:00 00:00 15:00 16:00 18:30 19:30 21:30 22:30 00:00 11:30 Operations Summary 1 D-39 Pump sweep, Circ hole clean (Reduce vis to 170 sec.), Monitor well, Pump dry job POOH f/9 5/8" csg.(SLM-NO correction), Lay down DC's & BHA, Clear rig floor of tools Clear floor in preparation for running casing. Safety meeting and rig up casers. Safety meeting on running casing M/U float and shoe jts. and RIH w/9-5/8" casing. Break circulation @ 2000' and 4000'. M/U hanger and landing jt. Circ and condition mud. L/D fillup tool and P/U cement head. PJSM, Test lines to 3500 psi. Mix and Pump 20 bbl chemical wash, Drop plug, 42 bbl Mud push, 435 bbl Lead and 256 bbl Tail, Drop plug, Clear tub w/5 bbl water. Displace w/rig pump. Did not bump plug. Floats OK. Circ 92 bbl cement to surface. Clear floor. R/D cement head, M/U kelly hose, Change bales M/U washtool. Wash out diverter N/D diverter system N/D Diverter system N/U speedhead and test to 1000 psi N/U BOPE. M/U test jt and Install test plug. Fill BOPE w/water. Test BOPE Blow down choke manifold and topdrive. Pull test plug L/D test jt P/U bha and orient motor. Install strip-o-matic Load mwd and finish p/u bha Cut and slip drilling line Service rig and top drive RIH P/U 5" d.p. Check sperry-sun's block height calibrations RIH p/u 5" out of derrick and start running stands from derrick RIH tag cmt @ 5873' Cleanout cmt to 6140' Circ Test casing to 2500 psi for 30 min.-OK Drill float equipment cement and 35' of new hole to 6276' Circ and swap to new mud R/U and do LOT to 14.1 ppg EMW. Perform PWD baseline test Drill from 6276' to 7745' Drill from 7745' to 9058' Circ. Monitor well. Pump dry job POOH to shoe (30 stds) Service rig and top drive RIH Circ. Had 1800 units trip gas. Check well-no flow Drill from 9058' to 9153' Drill from 9153' to 10192' 01/27/01 01/27/01 01/28/01 01/28/01 01/28/01 01/28/01 01/28/01 01/28/01 01/28/01 01/29/01 01/29/01 01/29/01 01/29/01 01/29/01 01/29/01 01/29/01 01/29/01 01/30/01 01/30/01 01/30/01 01/30/01 01/30/01 01/30/01 01/30/01 01/31/01 01/31/01 01/31/01 01/31/01 01/31/01 01/31/01 01/31/01 01/31/01 02/01/01 02/01/01 02/01/01 02/01/01 02/01/01 02/01/01 02/01/01 02/01/01 02/01/01 02/02/01 02/02/01 02/02/01 02/02/01 02/02/01 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 AM 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM 11:30 12:00 00:00 13:00 15:00 20:30 21:30 22:00 23:00 00:00 00:30 06:00 08:00 13:00 14:30 16:30 20:00 00:00 01:30 06:00 08:00 11:00 15:00 17:30 00:00 01:00 07:30 11:00 13:30 15:00 16:00 16:30 00:00 06:00 07:00 08:30 09:30 13:00 14:00 15:00 16:30 00:00 09:30 11:00 12:30 16:30 12:00 00:00 13:00 15:00 20:30 21:30 22:00 23:00 00:00 00:30 06:00 08:00 13:00 14:30 16:30 20:00 00:00 01:30 06:00 08:00 11:00 15:00 17:30 00:00 01:00 07:30 11:00 13:30 15:00 16:00 16:30 00:00 06:00 07:00 08:30 09:30 13:00 14:00 15:00 16:30 00:00 09:30 11:00 12:30 16:30 19:00 Operations Summary 1 D-39 Replace swab in #1 pump Drill from 10192' to 10890' Drill from 10890' to 11973' Pump sweep. Circ hole clean. Monitor well. POOH 5 stands. Hole tight. Pump out of hole. RIH to 11038' Circ 2210 stks R IH to 11973' Circ Circ Drill from 11973' to 12385' Circ sweep then cbu Pump out 10 stds. Pump dry job. POOH to 6150' Circ Do LOT to 12.6 ppg EMW. Rig down test equipment. RIH break circ @ 8590' and 10850' Circ and condition mud for casing Circ hole clean. Monitor well. Pull 2stds. 30K over. Pump out 5 stds, pull 5 stds wet. Pump dry job and POOH to shoe Circ pill out. Hole not balanced. Continue POOH L/D bha. Download MWD. Prep to run 7" casing Safety meeting. Run 140 jts 7" casing. Break cir¢ at 2000' and 4000'. CBU @ shoe Continue running 7" casing. Break circ at 8000' and 10000' Circ and condition mud Pump 10 bbl water. PT lines to 3000 psi. Pump 20 bbl preflush, 30 bbl Mudpush, Drop plug, Pump 35 bbl slurry, Drop plug, Pump 10 bbl water through tub and Displace w/460 bbl mud w/ rig pump. Bump plug and Checked floats-OK R/D cement head, L/D landing jt. change bales and elevators Set packoff and test to 5000 psi-OK. R/D cement hose R/U floor to L/D 5" d.p. L/D 5" d.p. out of derrick L/D 5" d.p. out of derrick Change lower PR's to 4" Change top drive and floor equipment to 4" d.p. R/U to test BOPE Test BOPE to 250/5000 psi R/D test equipment. Pull test plug. Set wearring. L/D test jt R/U kelly hose to topdrive M/U 36 jts of d.p. and stand back in derrick M/U bha. Upload MWD. P/U 4" d.p. and RIH to 12280' Circ and condition mud R/U and test casing to 3500 psi for 30 min-OK Drill cmt and float equpment. Drill to 12415' Stand back I stand and displace hole w/new mud 02/02/01 02/02/01 02/02/01 02/03/01 02/03/01 02/03/01 02/04/01 02/04/01 02/04/01 02/04/01 02/04/01 02/04/01 02/04/01 02/04/01 02/04/01 02/04/01 02/04/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/05/01 02/06/01 02/06/01 02/06/01 02/06/01 02/06/01 02/06/01 02/06/01 02/07/01 02/07/01 02/07/01 02/07/01 02/07/01 02/07/01 02/07/01 02/07/01 02/07/01 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM AM 19:00 20:00 21:00 00:00 19:00 22:00 00:00 02:30 05:00 06:30 07:30 08:00 09:00 11:00 13:00 14:00 23:00 00:00 01:00 01:30 02:30 03:00 05:30 14:30 17:00 17:30 18:00 22:30 23:00 00:00 00:30 01:00 03:00 04:00 17:30 18:30 00:00 06:00 07:00 08:30 10:00 13:00 13:30 14:30 15:30 20:00 21:00 00:00 19:00 22:00 00:00 02:30 05:00 06:30 07:30 08:00 09:00 11:00 13:00 14:00 23:00 00:00 01:00 01:30 02:30 03:00 05:30 14:30 17:00 17:30 18:00 22:30 23:00 00:00 00:30 01:00 03:00 04:00 17:30 18:30 00:00 06:00 07:00 08:30 10:00 13:00 13:30 14:30 15:30 17:00 Operations Summary 1 D-39 R/U and do LOT to 14.5 ppg EMW. Bled off 1.2 bbl to trip tank Perform PWD baseline test Drill from 12415' to 12504' Drill from 12504' to 13327' Change out topdrive brake solenoid valve. (TDS brake had locked up) Drill from 13327' to 13380' Drill from 13380' to 13545' Circ hi vis sweep around. Hole losing 10 bph @ 7 bpm. Reduce rate to 4-1/4 bpm and no losses Pump out of hole to 7" shoe Cut and slip driling line Service top drive RIH w/no problems Cir¢ and condition mud for liner Pump out of hole to shoe Monitor well, pump dry job, drop rabbit and blow down lines. POOH L/D BHA L/D bha Download MWD L/D MWD R/U casers P/U 40 jts of liner and liner hanger RIH w/liner on 4" d.p. Circ and condition mud at shoe RIH w/liner tag @ 13545' R/U cement head Circ and condition mud Circ while batchmixing cement. Test lines to 5000 psi Pump 20 bbl preflush, 30 bbl mudpush Xl, 53 bbl slurry and drop plug. Displace w/139 bbl mud. Displace Cmt. w/139 bbls mud, bump plug, CIP 00:24 hrs Set liner hanger & packer, Release f/liner TOL @ 12207' Circ. DP & Csg. Clean, Est. 5 bbls cmt. returns Lay down cmt. head Pump dry job, Lay down 4" DP & Liner running tools Pull wear bushing, Disconnect kelly hose f/top drive, Pull strip-o- matic, Rig tbg. tongs PJSM, Run 3.5" completion string, Freeze protect 9 5/8"X 7" ann. w/200 bbls water & 75 bbls diesel Run 3.5" completion string to TOL @ 12207' Rig to circ., Work & wash thru possible cmt., Tag Iocator-OK Circ. Btm's up f/csg, test Test csg. to 3500 PSI f/30 min.-OK Change well over to Seawater, Monitor well 15 min-OK Pick up pups to space out & Hanger- Cross thread hanger Change out hanger & pup Land tbg.hanger, Run in lock down screws, Rig pump hoses Test tbg. to 3000 PSI 15 min OK Bleed to 500 PSI Test ann. to 3000 PSI 15 min. OK Shear DCR valve 02/07/01 12:00 AM 02/07/01 12:00 AM 02/07/01 12:00 AM 02/08/01 12:00 AM 02/08/01 12:00 AM 17:00 19:00 21:00 00:00 01:30 19:00 21:00 00:00 01:30 04:30 Operations Summary 1 D-39 Pump 60 bbls diesel down ann. & U-tube to tbg. Set BPV Change Btm pipe rams to 4.5"X 7" Nipple down BOPE Nipple down BOP, Remove DSA, Set back stack Install & nipple up tree, Test tree to 250 PSI Iow & 5000 PSI high- OK, Install BPV 1D-39 Description of Work Completed Summary 4/22/01: PERFORATED: 13320' TO 13340', 2-1/2" HC, 4 SPF, DP [Perf] 4/23/01: PERFORATED: 13310'-13320', 13256'-13286', 13160'-13180', 2-1/2" HC, 4SPF, DP [Perf] 4/24/01: PERFORATED 13070'-13090' RKB W/2-1/2" HC/DP/4SPF/60-120 PHASING (6 SPF GUN LOADED 4 SPF)/RANDOM ORIENTATION [Pelf] 5/1/01: PUMPED INITIAL HPBD IN 3 STAGES. FIRST STAGE - HPBD/SCOUR. SAW 350 PSI PRESSURE DROP WITH SAND THROUGH PERFS. SECOND STAGE - DIVERSION/SCOUR/HPBD. HAD GOOD DIVERISON WITH FIRST HALF OF ROCK SALT ON PERFS, SAW GOOD BREAKDOWN FOLLOWING DIVERSION. 3RD STAGE - DIVERISON/SCOUR/HPBD, SAW GOOD DIVERISON WITH BOTH ROCK SALT SLUGS. PUMPED SCOUR AND HPBD, LEFT WELL ON INJECTION. [HPBD] 01-Mar-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1D-39 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 354.00' MD 'MD 13,545.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED Kuparuk River Unit Phillips Alaska Kuparuk f D, Slot ~D-39 ~D-39 Surveyed: 4 February, 2001 DEFINITIVE S UR VEY REPORT March, 2001 Your Reft AP1 - 500292299700 Surface Coordinates: 5959~44. f2 N, 560670.96 E (70° ~7' 56.0643" N, f49° 30' 3~.~936" W) Kelly Bushing: ~04.55ft above Mean Sea Level D RIL. I-I N(S SERVICE=. A Halllburlon Company Survey Reft svy9391 Kuparuk River Unit Measured Depth (fi) Incl. Azim. 354.00 1.500 271.000 504.90 3.280 269.710 594.50 3.740 266,620 657,96 4,080 292.120 743,43 3.830 299,710 Sub-Sea Depth (ft) 249.44 400.20 489.63 552.95 638.21 Vertical Depth (ft) 353.99 504.75 594.18 657.50 742.76 833.82 1,650 275.100 728.50 833.05 930,72 0,260 254,550 825.38 929.93 1023.08 0.790 61,030 917.74 1022.29 1121.29 1.070 96.910 1015.94 1120.49 1212.39 0.370 216,280 1107.03 1211.58 1307,49 0.510 305.000 1202.13 1306.68 1401.45 0.400 0,620 1296.09 1400.64 1497,14 0.550 306.670 1391.78 1496.33 1589.47 0.470 255.530 1484.10 1588.65 1682.61 0.460 25.760 1577.24 1681.79 Sperry-Sun Drilling Services Survey Report for 'iD-39 YourRef:AP,-500292299700 DEFINITIVE Surveyed: 4 February, 2001 1777.03 1.570 75,160 1671.65 1776.20 1872.14 3.840 91.420 1766.64 1871.19 1963.47 6.030 94,870 1857.63 1962.18 2057.16 8.200 106.200 1950.60 2055.15 2149.91 10.080 109,980 2042.17 2146.72 2243.63 12,350 111.370 2134.09 2238.64 2341.37 13.490 116,340 2229.36 2333.91 2430.97 15.470 120.380 2316.11 2420.66 2531.16 17.980 125.150 2412.06 2516.61 2619.39 21,060 124.910 2495.21 2599.76 2713.58 23,860 128.400 2582.25 2686.80 2807.56 26.520 130.650 2667.29 2771.84 2903.53 28.150 136,350 2752.55 2857.10 2996.94 30.980 139.420 2833.80 2938.35 3088.38 33.090 144.010 2911.32 3015.87 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Easfings Rate Section (ft) (fi) (fi) (fi) (°/100fi) 0.71 N 0.68W 5959144.83 N 560670.28 E -0.96 0.72 N 6.97W 5959144.79 N 560663.98 E 1.18 -4.33 0.54 N 12.45W 5959144.56 N 560658.51 E 0.55 -7.10 1.27 N 16.61W 5959145.25 N 560654.34 E 2.77 -9.93 3.83 N 21.90W 5959147.77 N 560649.03 E 0.68 -14.92 5.44N 25.82W 5959149.35 N 560645.09 E 2.69 -18.37 5.50 N 27.42W 5959149.40 N 560643.49 E 1.45 -19.28 5.76 N 27.07W 5959149.66 N 560643.84 E 1.13 -19.31 5.97 N 25.57VV 5959149.89 N 560645.35 E 0.64 -18.69 5.64 N 24.90W 5959149.55 N 560646.02 E 1.42 -18.04 5.63 N 25.42W 5959149.55 N 560645.49 E 0.66 -18.32 6.20 N 25.76W 5959150.11 N 560645.15 E 0.46 -18.98 6.81 N 26.13W 5959150.72 N 560644.78 E 0.47 -19.69 6.98 N 26,85W 5959150.88 N 560644.05 E 0.48 =20.22 7.22 N 27.06W 5959151.12 N 560643.84 E 0.91 -20.54 7.89 N 25.64W 5959151.80 N 560645.25 E 1.40 -20.35 8.15 N 21.20W 5959152.09 N 560649.70 E 2.50 -18.20 7.66 N 13.36W 5959151.67 N 560657.54E 2.42 -13.61 5.38 N 2.04W 5959149.48 N 560668.88 E 2.75 -5.64 0.76 N 11.94 E 5959144.98 N 560682.90 E 2.13 5.73 5,69 S 28.99 E 5959138.66 N 560699.99 E 2.44 20.28 14.56 S 48.94 E 5959129.95 N 560720.01 E 1.63 38.42 25.24 S 68.61 E 5959119.43 N 560739.78 E 2.48 57.95 40.91 S 92.79 E 5959103.96N 560764.08 E 2.85 84.09 57.82 S 116.93 E 5959087.24 N 560788.35 E 3.49 111.27 79.35 S 145.74E 5959065.95 N 560817.34 E 3.29 144.85 104.83 S 176.57 E 5959040.72 N 560848.37 E 3.01 182.84 135.17 S 208.46 E 5959010.64 N 560880.50 E 3.21 225.52 169.38 S 239.31 E 5958976.67 N 560911.63 E 3.44 270.91 207.46 S 269.30 E 5958938.84 N 560941.92 E 3.52 319.12 Phillips Alaska Kuparuk l D Comment Tie on point AK-6 BP IFR-AK 1 March, 2001 - 14:14 Page 2 of 7 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for I D-39 Your Ref: APl - 500292299700 Surveyed: 4 February, 2001 Kuparuk River Unit Measured Depth fit) 3182.31 3279.76 3375.56 3471.12 3564.74 3655.80 3749.69 3842.43 3937.10 4031.22 4124.62 4216.19 4311.32 4405.33 4501.97 4594.02 4689.76 4777.75 4877.10 4973.52 5065.79 5159.44 5253.07 5346.26 5437.63 5531.46 5624.86 5716.44 5816.79 5910.52 Incl. 36.570 38.510 41.590 44.200 47.130 49.550 51.520 54.56O 58.310 63.340 64.710 67.090 69.290 72.380 72.300 72.140 71.840 71.420 70.740 72.620 72.710 72.590 73.010 73.660 73.850 73.680 74.550 73.550 72.560 72.100 Azim. 147.600 147.700 146.900 146.030 147.100 147.140 146.970 145.860 147.170 146.480 146.200 144.610 142.160 142.840 142.690 144.230 144.610 144.650 144.980 144.740 144.550 145.030 147.690 148.190 149.520 150.060 150.230 150.160 149.790 149.650 Sub-Sea Depth (ft) 2988.42 3065.68 3139.01 3209.01 3274.43 3334.96 3394.63 3450.39 35O2.72 3548.59 3589.49 3626.88 3662.23 3693.09 3722.41 3750.52 3780.12 3807.85 3840.06 3870.37 3897.86 3925.79 3953.48 3980.20 4005.76 4032.00 4057.56 4082.73 4111.97 4140.42 Vertical Depth (ft) 3092.97 3170.23 3243.56 3313.56 3378.98 3439.51 3499.18 3554.94 3607.27 3653.14 3694.04 3731.43 3766.78 3797.64 3826.96 3855.07 3864.67 3912.40 3944.61 3974.92 4002.41 4030.34 4058.03 4084.75 4110.31 4136.55 4162.11 4187.28 4216.52 4244.97 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Easfings (ft) (ft) 251.85 S 299.37 E 5958894.69 N 560972.35 E 302.01S 331.14 E 5958844.79 N 561004.53 E 353.87 S 364.45 E 5958793.20 N 561038.25 E 408.08 S 400.39 E 5958739.29 N 561074.63 E 463.96 S 437.27 E 5958683.70 N 561111.96 E 521.09 S 474.20 E 5958626.88 N 561149.35 E 581.91S 513.62 E 5958566.37 N 561189.26 E 643.63 S 554.61 E 5958504.99 N 561230.75 E 709.42 S 598.11E 5958439.55 N 561274.78 E 778.18 S 643.07 E 5958371.16 N 561320.30 E 848.06 S 689.61 E 5958301.65 N 561367.40 E 916.86 S 737.08 E 5958233.25 N 561415.41E 987.73 S 789.76 E 5958162.80 N 561468.66 E 1058.17 S 843.80 E 5958092.80 N 561523.28 E 1131.49 S 899.52 E 5958019.93 N 561579.59 E 1201.91S 951.71E 5957949.94 N 561632.34 E 1275.96S 1004.68 E 5957876.32 N 561685.91E 1344.05 $ 1053.02 E 5957808.61 N 561734.80 E 1420.86S 1107.18 E 5957732.24 N 561789.57 E 1495.71 $ 1159.86 E 5957657.83 N 561842.86 E 1567.54S 1210.83 E 5957586.40 N 561894.40 E 1640.58 S 1262.36 E 5957513.79 N 561946.53 E 1715.04S 1311.91E 5957439.73 N 561996.67 E 1790.70 S 1359.29 E 5957364.46 N 562044.67 E 1865.77 S 1404.66 E 5957289.75 N 562090.64 E 1943.62 S 1449.99 E 5957212.27 N 562136.60 E 2021.54S 1494.71 E 5957134.72 N 562181.94 E 2097.94S 1538.48 E 5957058.67 N 562226.33 E 2181.05 S 1586.51 E 5956975.95 N 562275.03 E 2258.18 S 1631.54 E 5956899.19 N 562320.68 E Dogleg Rate (°/lOOft) 4.30 1.99 3.26 2.80 3.23 2.66 2.10 3.41 4.13 5.38 1.49 3.04 3.33 3.36 0.17 1.60 0.49 0.48 0.75 1.96 0.22 0.51 2.75 0.87 1,41 0.58 0.95 1.09 1.05 0.51 Vertical Section 372.71 432.08 493.71 558.73 625.67 693.70 766.17 840.24 919.09 1001.23 1085.17 1168.68 1256.72 1345.14 1436.87 1524.27 1615.17 1698.55 1792.40 1883.82 1971.76 2061.03 2150.44 2239.71 2327.42 2417.45 2507.20 2595,18 2691.10 2780.35 Phillips Alaska Kuparuk 1D Comment 1 March, 2001- f4:14 Page 3 of 7 DrillOuesf 2.00.06 Sperry-Sun Drilling Services Survey Report for '1D-39 Your Ref: APl - 500292299700 Surveyed: 4 February, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Easflngs (ft) (ft) (ft) (ft) (ft) 6005.88 71,260 150.670 4170.40 4274.95 6098.28 71.200 151.190 4200.13 4304.68 6183.67 71,850 151.620 4227.19 4331.74 6259.68 72.590 154.050 4250.40 4354.95 6294.93 72,500 153.590 4260.98 4365.53 6352.16 72,230 154,050 4278.31 4382.86 6442.31 71.320 152.130 4306.51 4411.06 6538.89 70.660 147.610 4337.98 4442.53 6631.44 70,310 146.630 4368.90 4473.45 6723.46 69.780 147.230 4400.31 4504.86 6814.37 69.200 148,730 4432.16 4536.71 6911.35 69.660 148,330 4466.23 4570.78 7005.48 70,720 147,590 4498.14 4602.69 7100.94 72,190 147.000 4528.50 4633.05 7193.97 72.460 146.310 4556.74 4661.29 7286.27 72,020 147.210 4584.90 4689.45 7378.81 73.110 146.590 4612.62 4717.17 7474.02 72.930 146,320 4640.43 4744.98 7579.59 72.430 145.580 4671.86 4776.41 7666.53 72.320 146.200 4698.18 4802.73 7762.59 71,930 145,200 4727.67 4832.22 7857.16 71.510 148,530 4757.34 4861.89 7951.24 71.300 152.230 4787.35 4891.90 8045.93 72,880 151,570 4816.47 4921.02 8141.26 72.390 150.920 4844.92 4949.47 8235.19 72,680 151,360 4873.11 4977.66 8328.78 72.160 151.350 4901.38 5005.93 8422.68 72,890 152,180 4929.57 5034.12 8518.27 72,910 152.840 4957.68 5062.23 8611.50 72.400 152,890 4985.48 5090.03 2336.70 S 1676.59 2413.16 S 1719.09 2484.27 S 1757.85 2548.66 S 1790.89 2578.84S 1805.73 2627,78 S 1829.79 2704.14 S 1868.54 2783.09 S 1914.36 2856.35 S 1961.71 2928.83 S 2008.91 3001.02 S 2054.06 3078.46S 2101.46 3153.53 S 2148.44 3229.68 S 2197.34 3303.73 S 2246.06 3377.24 S 2294.24 3451.20 S 2342.46 3527.10 S 2392.78 3610.60 S 2449.21 3679.20 S 2495.67 3754.73 S 2547.19 3829.91S 2596.27 3907.41 S 2640.33 3986.88 S 2682.77 4066.65 S 2726.54 4145.12 S 2769.79 4223.42 S 2812.56 4302.33 S 2854.93 4383.38 S 2897.10 4462.57 S 2937.69 5956821.03 N 562366.36 E 5956744.92 N 562409.48 E 5956674.12 N 562448.81 E 5956610.00 N 562482.37 E 5956579.94 N 562497.45 E 5956531.19 N 562521.91E 5956455.16 N 562561.27 E 5956376.58 N 562607.72 E 5956303.70 N 562655.67 E 5956231.60 N 562703.45 E 5956159.78 N 562749.18 E 5956082.72 N 562797.20 E 5956008.04 N 562844.79 E 5955932.28 N 562894.30 E 5955858.63 N 562943.62 E 5955785.51N 562992.40 E 5955711.94 N 563041.21E 5955636.46 N 563092.14 E 5955553.41N 563149.24 E 5955485.18 N 563196.25 E 5955410.08 N 563248.38 E 5955335.30 N 563298.06 E 5955258.16 N 563342.75 E 5955179.03 N 563385.83 E 5955099.62 N 563430.24 E 5955021.50 N 563474.12 E 5954943.55 N 563517.52 E 5954864.98 N 563560.53 E 5954784.28 N 563603.35 E 5954705.41 N 563644.58 E Dogleg Rate (°/t00ft) 1.34 O.54 0.90 3.20 1.27 0.90 2.26 4.48 1.07 0.84 1.67 0.61 1.35. 1.65 0.76 1.04 1.34 0.33 0.82 0.69 1.07 3.37 3.73 1.80 0.83 0.54 0.56 1.15 0.66 0.55 Vertical Section 2870.80 2958.15 3038.98 3111.07 3144.51 3198.74 3284.00 3375.22 3462.44 3548.93 3634.07 3724.86 3813.42 3903.92 3992.54 4080.42 4168.70 4259.73 436O.47 4443.28 4534.64 4624.41 4713.47 48O3.33 4894.15 4983.60 5072.64 5161.99 5253.O4 5341.68 Phillips Alaska Kuparuk 1 D Comment DrillQuest 2.00.06 March, 2001 - 14:14 Page 4 of 7 Sperry-Sun Drilling Services Survey Report for rD-39 Your Ref: APl - 500292299700 Surveyed: 4 February, 200f Kuparuk River Unit Measured Depth (ft) Incl. 8699.91 73.430 8793.91 73.180 8888.23 72.930 8984.92 72.460 9079.03 72.090 9172.70 71.670 9265.60 72.530 9360.53 72.370 9455.55 73.890 9548.86 73.950 Azim. 152.160 152.820 151.550 151.78O 152.480 153.180 150.180 149.810 151.150 150.27O Sub-Sea Depth (ft) 5011.45 5038.45 5065.94 5094.71 5123.36 5152.49 5181.05 5209.67 5237.25 5263.09 Vertical Local Coordinates Global Coordinates Depth Northings Easfings Northings Easfings (fi) (fi) (fi) (fi) (fi) 5116.00 4537.55 S 2976,68 E 5954630.75 N 563684.17 E 5143.00 4617.40 S 3018.27 E 5954551.24 N 563726.41 E 5170.49 4697.20 S 3060.37 E 5954471.78 N 563769.15 E 5199.26 4778.45 S 3104.18 E 5954390.88 N 563813.62 E 5227.91 4857.70 S 3146.08 E 5954311.98 N 563856.16 E 5257.04 4936.90 S 3186.74 E 5954233.11 N 563897.45 E 5285.60 5014.71S 3228.67 E 5954155.64 N 563940.01 E 5314.22 5093.09 S 3273.94E 5954077.63 N 563985.91E 5341.80 5172.21S 3318.73 E 5953998.87 N 564031.34 E 5367.64 5250.41S 3362.60 E 5953921.03 N 564075.84 E 9642.37 73.970 150.950 5288.93 5393.48 9737.06 73.250 148.770 5315.65 5420.20 9832.21 72.730 148.390 5343.49 5448.04 9924.19 72.760 147.970 5370.77 5475.32 10018.74 72.740 147.620 5398.81 5503.36 10112.95 72.110 147.670 5427.26 5531.81 10200.89 71.760 150.150 5454.53 5559.08 10294.27 71.620 149.230 5483.87 5588.42 10394.68 71.310 145.570 5515.80 5620.35 10487.96 70.600 146.190 5546.24 5650.79 10579.81 70.260 147.060 5577.00 5681.55 10674.56 70,640 148.510 5608.71 5713.26 10769.85 71.100 147,930 5639.94 5744.49 10865.84 70.480 149.520 5671.52 5776.07 10959.98 70.980 149.470- 5702.59 5807.14 11051.98 71.400 149.440 5732.25 5836.80 11147.66 72.830 150.760 5761.64 5866.19 11242.59 73.120 149.830 5789.43 5893.98 11337.14 72.490 150.730 5817.39 5921.94 11429.99 72.170 150.980 5845.57 5950.12 5328.71 S 3406.70 E 5953843.09 N 564120.57 E 5407.27 S 3452.31E 5953764.90 N 564166.81E 5484.91 S 3499.74 E 5953687.64 N 564214.87 E 5559.55 S 3546.05 E 5953613.38 N 564261.78 E 5635.95 S 3594.18 E 5953537.37 N 564310.52 E 5711.82 S 3642.24 E 5953461.89 N 564359.20 E 5783.41 S 3685.41 E 5953390.65 N 564402.94 E 5859.94S 3730.15 E 5953314.48 N 564448.30 E 5940.13 S 3781.43 E 5953234.71 N 564500.22 E 6013.13 S 3830.89 E 5953162.12 N 564550.27 E 6085.40 S 3878.50 E 5953090.23 N 564598.46 E 6160.94S 3926.09 E 5953015.08 N 564646.67 E 6237.47 S 3973.51E 5952938.94 N 564694.70 E 6314,94 S 4020.57 E 5952861.85 N 564742.38 E 6391.50 S 4065.68 E 5952785.65 N 564788.10 E 6466.50 S 4109.94E 5952711.01 N 564832.97 E 6545.44S 4155.32 E 5952632.44N 564878.99 E 6624.28 S 4200.30 E 5952553.97 N 564924.60 E 6702.72 S 4245.08 E 5952475.89 N 564970.01 E 6779.99 S 4288.16 E 5952398.98 N 565013.72 E Dogleg Rate (°/100ft) 1.41 0.72 1.32 0.54 0.81 0.84 3.21 0.41 2.09 0.91 0.70 2.34 0.67 0.44 0.35 0.67 2.71 0.95 3.47 0.99 0.97 1.50 0.75 1.69 0.53 0.46 1.99 0.99 1.13 0.43 Vertical Section 5425.89 5515.62 5605.58 5697.68 5787.06 5875.74 5963.92 6054.37 6145.19 6234.73 6324.49 6415.26 6506.24 6594.08 6684.38 6774.19 6857.77 6946.37 7041.55 7129.68 7216.20 7305.49 7395.51 7486.14 7574.96 7662.01 7752.99 7843.67 7933.91 8022.25 Phillips Alaska Kuparuk 1 D Comment DrillQuest 2.00.06 March, 2001.14:14 Page 5 of 7 Sperry-Sun Drilling Services Survey Report for rD-39 Your Ref: APl - 500292299700 Surveyed: 4 February, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 11523.21 71,770 149.850 5874.42 5978.97 6857.07 S 4331.93 E 11618.14 71,260 150.750 5904.52 6009.07 6935.27 S 4376.53 E 11709.17 70.850 151,030 5934.07 6038.62 7010.50 S 4418,42 E 11805.04 71.670 148.780 5964.88 6069.43 7089.04S 4463.94 E 11900,39 71,750 148,540 5994.80 6099.35 7166.36 S 4511.03 E 11996.11 71.640 150,520 6024.87 6129.42 7244.68 S 4557.11 E 12091.11 71.190 150.210 6055.15 6159.70 7322.95 S 4601.64E 12187.28 71,190 148,410 6086.16 6190.71 7401.23 S 4648.10 E 12281.83 70.820 146,140 6116.93 6221.48 7476.43 S 4696.42 E 12312.74 70.710 147.110 6127.12 6231.67 7500.81S 4712.48 E 12401.66 70.910 142,690 6156.36 6260.91 7569.49 S 4760.75 E 12499.08 70.590 143,550 6188.48 6293.03 7643.06S 4815.95 E 12594.98 71,870 143,030 6219.33 6323.88 7715.85 S 4870.23 E 12692.25 71.220 143.110 6250.13 6354.68 7789.60 S 4925.66 E 12788.55 72,570 145.800 6280.06 6384.61 7864.07 S 4978.86 E 12886.63 72.710 144.560 6309.32 6413.87 7940.92 S 5032.31 E 12979.11 73.480 147,160 6336,22 6440.77 8014.15 S 5081.96 E 13075.52 72,980 148,220 6364.04 6468.59 8092.17 S 5131.30 E 13172,78 71,410 148.320 6393.78 6498.33 8170.93 S 5180.00 E 13268.13 70.270 148,150 6425.07 6529.62 8247.50 S 5227,42 E 13363.82 70,070 148.700 6457.53 6562.08 8324.19 S 5274.55 E 13451.63 69.330 148,980 6487.99 6592.54 8394.66 S 5317.16 E 13545.00 69,330 148,980 6520.95 6625.50 8469.53 S 5362.18 E Global Coordinates Northings Easfings (ft) (ft) 5952322.25 N 565058.11 E 5952244.41 N 565103.34E 5952169.52 N 565145.84 E 5952091.35 N 565191.99 E 5952014.41N 565239.70 E 5951936.47 N 565286.41 E 5951858.56 N 565331.57 E 5951780.66 N 565378.66 E 5951705.85 N 565427.59 E 5951681.60 N 565443.84 E 5951613.31 N 565492.67 E 5951540.19 N 565548.46 E 5951467.84 N 565603.32 E 5951394.54 N 565659.35 E 5951320.50 N 565713.15 E 5951244.08 N 565767.22 E 5951171.26 N 565817.46 E 5951093.64 N 565867.43 E 5951015.28 N 565916.76 E 5950939.09 N 565964.79 E 5950862.78 N 566012.54 E 5950792.66 N 566055.72 E 5950718.16 N 566101.35 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. Magnetic Declination at Surface is 26,320° (15-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 147.770° (True). Dogleg Rate (°/100ft) 1.23 1.05 0.54 2.38 0.25 1.97 0.57 1.77 2.30 2.98 4.70 0.90 1.43 0.67 3.00 1.22 2.82 1.17 1.62 1.21 0.58 0.89 0.00 Vertical Section 8110.79 8200.74 8286.71 8377.42 8467.95 8558.77 8648.73 8739.72 8829.11 8858.29 8942.14 9033.81 9124.33 9216.29 9307.65 9401.17 9489.59 9581.90 9674.50 9764.56 9854.57 9936.91 1OO24.25 Phillips Alaska Kuparuk 1 D Comment Projected survey DrillQuest 2.00.06 1 March, 2001 - 14:14 Page 6 of 7 S=errv-Sun Drilling Services Based upon Minimum Curvature type calculations, at a ~easur~'d D_~_~._I_~j~(~, · Th~ Bottom Hole Displacement is 10024.27fl., in the Direction of Surveyed: 4 February, 2001 ummerts.... paruK Kwer Unit Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 354.00 353.99 0.71 N 0.68 W 13545.00 6625.50 8469.53 S 5362.18 E Comment Tie on point Projected survey Phillips Alaska Kuparuk 1 D Survey tool program for 1D-39 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 354.00 353.99 354.00 353.99 13545.00 6625.50 Survey Tool Description Good Gyro (1D-39PGSS) AK-6 BP_IFR-AK (1 D-39) DrillQuest 2.00.06 f March, 2001 - 14:14 Page 7 of 7 01-Mar-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 1D-39PGSS Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 354.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Kuparuk River Unit Phillips Alaska Kuparuk f D, Slot f D-3g ~D-39 PGSS Surveyed: 4 February, 200'/ SURVEY REPORT March, 2001 Your Reft APl 500292299700 Surface Coordinates: 5959144.12 N, 560670.96 E (70° 17' 56.0643" N, Kelly Bushing: I04.55ft above Mean Sea Level ~49° 30' 3f.1936" I/V) DRILLING SERVICE=; A Halliburton Company Survey Reft svy9392 Kuparuk River Unit Sperry-Sun Drilling Services Survey Report for '1D-39 PGSS Your Ref: APl 500292299700 Surveyed: 4 February, 200f Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Easfings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings . Rate Section (ft) (ft.) (°llOOff) 0.00 0.000 0.000 -104.55 0.00 0.00 N 0.00 E 5959144.12 N 82.00 0.300 60.000 -22.55 82.00 0.11 N 0.19 E 5959144.23 N 169.00 0.300 73.000 64.45 169.00 0.29 N 0.60 E 5959144.41 N 265.00 0.300 313.000 160.45 265.00 0.53 N 0.66 E 5959144.66 N 354.00 1.500 271.000 249.44 353.99 0.71 N 0.68 W 5959144.83 N 560670.96 E 0.00 560671.15 E 0.37 0.01 560671.56 E 0.08 0.08 560671.61 E 0.54 -0.10 560670.28 E 1.45 -0.96 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. Magnetic Declination at Surface is 26.320° (15-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 147.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 354.00ft., The Bottom Hole Displacement is 0.98ft., in the Direction of 316.414° (True). Phillips Alaska Kuparuk 1D Comment Tolerable Gyro Survey tool program for I D-39 PGSS From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 354.00 353.99 Survey Tool Description Tolerable Gyro DrillQuest 2.00.08.002 March, 2001 - 16:15 Page 2 of 2 01-Mar-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-39MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 13,545.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ,0 DEFINITIVE Kuparuk River Unit Phillips Alaska Kuparuk f D, Slot ~D-39 ~D-39 MWD Surveyed: 4 February, 200~ SURVEY REPORT March, 200~ Your Ref: API500292299700 Surface Coordinates: 5959144.12 N, 560670.96 E (70° 17' 56.0643" N, Kelly Bushing: 104.55ft above Mean Sea Level 149° 30' 31.1936" W) DRII_i-INI~ SERVICE=_ A Hallibu~on Company Survey Ref: svyg3g3 Sperry-Sun Drilling Services Your Ref: APISO0292299700 DF_.FINIT Surveyed: 4 February, 2001 Kuparuk River Unit Measured Depth (ft) Incl. 354.00 1.500 271,000 377.17 1.570 264.600 504.90 3.280 269.320 594.50 3.740 266.030 657.96 4.080 292.010 Sub-Sea Depth (ft) 249.44 272.6O 400.21 489.64 552.96 Vertical Depth (ft) 353.99 377.15 504.76 594.19 657.51 743.43 3.830 299,720 638.22 742.77 834.78 1.650 275.090 729.47 834.02 930.72 0.260 254,660 825.39 929.94 1023.08 0.790 61,260 917.75 1022.30 1116.91 1.070 96.920 1011.57 1116.12 1212.39 0.370 215.970 1107.04 1211.59 1307.49 0.510 305.180 1202.14 1306.69 1401.45 0.400 0.660 1296.10 1400.65 1497.14 0.550 306.460 1391.78 1496.33 1589.47 0.470 255.410 1484.11 1588.66 1640.50 0.410 104.020 1535.14 1639.69 1682.61 0.460 25.760 1577.25 1681.80 1777.03 1.570 75.290 1671.66 1776.21 1872.14 3.840 91.400 1766.65 1871.20 1963.47 6.030 94.860 1857.64 1962.19 2057.16 8.200 106.210 1950.61 2055.16 2149.91 10.080 109.900 2042.18 2146.73 2243.63 12.350 111.140 2134.10 2238.65 2341.37 13.500 116.100 2229.37 2333.92 2430.97 15.470 120.190 2316.12 2420.67 2531.16 17.980 124.980 2412.06 2516.61 2619.39 21.060 124.760 2495.21 2599.76 2713.58 23.860 128.280 2582,25 2686.80 2807.56 26.520 130.430 2667,29 2771.84 2903.53 28.150 136.050 2752,56 2857.11 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) fit) (ft) (°/100ft) 0.71 N 0.68W 5959144.83 N 560670.28 E -0.96 0.69 N 1.30W 5959144.80 N 560669.66 E 0.80 -1.27 0.48 N 6.69W 5959144.55 N 560664.26 E 1.35 -3.98 0.25 N 12.17W 5959144.27 N 560658.79 E 0.56 -6.70 0.95 N 16.33W 5959144.94N 560654.62 E 2.82 -9.51 3.50 N 21.63W 5959147.45 N 560649.30 E 0.69 -14.50 5.13 N 25.59W 5959149.05 N 560645.33 E 2.66 -17.99 5.20 N 27.17W 5959149.10 N 560643.75 E 1.47 -18.89 5.45 N 26.82W 5959149.35 N 560644.10 E 1.13 -18.91 5.65 N 25.38W 5959149.57 N 560645.53 E 0.67 -18.32 5.30 N 24.68W 5959149.22 N 560646.24 E 1.35 -17.64 5.29 N 25.20W 5959149.21 N 560645.72 E 0.66 -17.92 5.86 N 25.54W 5959149.78 N 560645.37 E 0.46 -18.58 6.47 N 25.91W 5959150.38 N 560645.00 E 0.47 -19.29 6.64N 26.63W 5959150.54 N 560644,28 E 0.48 -19.82 6.54N 26.65W 5959150.44 N 560644.25 E 1.67 -19.75 6.66 N 26.44W 5959150.56 N 560644,47 E 1.31 -19.73 7.33 N 25.02W 5959151.24 N 560645.88 E 1.40 -19.54 7.58 N 20.57W 5959151.53 N 560650.32 E 2.49 -17.38 7.10 N 12.74W 5959151.11N 560658.17 E 2,42 -12.80 4.81 N 1.42W 5959148.92 N 560669.51 E 2.75 -4.83 0.21N 12.57 E 5959144.43 N 560683,53 E 2.12 6.53 6.20 S 29.63 E 5959138.16 N 560700.64 E 2.44 21.05 14.99 S 49.63 E 5959129.53 N 560720.7t E 1.63 39.15 25.60 S 69.35 E 5959119.08 N 560740.51 E 2.48 58.64 41.19 S 93.58 E 5959103.69 N 560764.86 E 2.86 84.75 58.04 S 117.76E 5959087.03 N 560789.19 E 3,49 111.90 79.49 S 146.63 E 5959065.81 N 560818.22 E 3.30 145.44 104.88 S 177.52 E 5959040.67 N 560849.33 E 2.99 183.40 135.08 S 209.55 E 5959010.73 N 560881.60 E 3.18 226.03 Phillips Alaska Kuparuk 1D Comment Tie On Point MWD Magnetic March, 2001 - ~6:27 Page 2 of 7 DrillQuest 2.00.08.002 Sperry-Sun Drilling Services Survey Report for rD-39 MWD Your Ref: API500292299700 Surveyed: 4 February, 200f Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 2996.94 30,980 138,990 2833.80 2938.35 3088,38 33,090 143.630 2911.32 3015.87 3182.31 36.570 147.170 2988.42 3092.97 3279.76 38.510 147,210 3065.69 3170.24 3375.56 41.580 146.370 3139.02 3243.57 3471.12 44.210 146.080 3209.02 3313.57 3564.74 47.130 146.340 3274.43 3378.98 3655.80 49.550 146,240 3334.96 3439.51 3749.69 51.520 146.120 3394.63 3499.18 3842.43 54.560 145.260 3450.39 3554.94 3937.10 58.310 147.470 3502.72 3607.27 4031.22 63.340 147.050 3548.59 3653.14 4124.62 64.710 144.930 3589.50 3694.05 4216.19 67.090 143.840 3626.89 3731.44 4311.32 69.280 141.050 3662.25 3766.80 4405.33 72.380 141.470 3693.11 3797.66 4501.97 72.300 140.720 3722.43 3826.98 4594.02 72.140 142.940 3750.54 3855.09 4689.76 71.840 143.180 3780.14 3884.69 4777.75 71.420 143.860 3807.87 3912.42 4877,10 70.740 145.390 3840.09 3944.64 4973.52 72,620 145.550 3870.39 3974.94 5065.79 72.710 143.510 3897.89 4002.44 5159.44 72.590 148,550 3925.83 4030.38 5253.07 73.010 149.500 3953.52 4058.07 5346.26 73.660 151.590 3980.25 4084.80 5437.63 73.850 147.900 4005.82 4110.37 5531.46 73,680 148.960 4032.05 4136.60 5624.86 74.550 149.210 4057.61 4162.16 5716.44 73.550 148.530 4082.78 4187.33 169.10 S 240.63 E 206.96 S 270.88 E 251.14 S 301.27 E 301.04 S 333.44E 352.60 S 367.21E 406.66 S 403.37 E 462.31S 440.61E 518.90 S 478.36 E 579.11S 518.70 E 640.31 S 560.48 E 705.99 S 604.13 E 775,08 S 648.57 E 644.67 S 695.54E 912.62 S 744.21 E 982.61S 798.05 E 1051.86 S 853.61 E 1123.52 S 911.44 E 1192.43 S 965.61 E 1265.20 S 1020.32 E 1332.34 S 1069.97 E 1408.97 S 1124.38 E 1464.38 S 1176.26 E 1556.10 S 1227.37 E 1630.21 S 1277.30 E 1706.89 S 1323.33 E 1784.63 S 1367.22 E 1860.38 S 14tl.42 E 1937.14 S 1458.58 E 2014.21 S 1504.73 E 2089.58 S 1550.25 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5958976.97 N 560912.95 5958939.35 N 560943.50 5958895.42 N 560974.25 5958845.78 N 561006.82 5958794.50 N 561041.00 5958740.73 N 561077.60 5958685.38 N 561115.28 5958629.10 N 561153.49 5958569.21N 561194.32 5958508.36 N 561236.59 5958443.03 N 561280.77 5958374.30 N 561325.77 5958305.09 N 561373.29 5958237.54 N 561422.52 5958167,99 N 561476.92 5958099.18 N 561533.03 5958027.99 N 561591.44 5957959.53 N 561646.16 5957887.20 N 561701.47 5957820.46 N 561751.65 5957744.27 N 561806.68 5957669.29 N 561859.17 5957597.98 N 561910.85 5957524.28 N 561961.38 5957447.96 N 562008.03 5957370.59 N 562052.55 5957295.19 N 562097.35 5957218.82 N 562145.13 5957142.13 N 562191.91 5957067.12 N 562238.03 E 3.40 E 3.54 E 4.28 E 1.99 E 3.25 E 2.76 E 3.13 E 2.66 E 2.10 E 3.36 E 4.41 E 5.36 E 2.51 E 2.82 E 3.57 E 3.32 E 0.74 E 2.30 E 0.39 E 0.88 E 1.61 E 1.96 E 2.11 E 5.14 E 1.07 E 2.26 E 3.88 E 1.10 E 0.97 E 1.30 Vertical Section 271.37 319.54 373.12 432.49 494.11 559.12 626.06 694.06 766.51 840.56 919.40 1001.55 1085.46 1168.90 1256.82 1345.03 1436.49 1523.67 1614.41 1697.69 1791.52 1882.98 1970.91 2060.22 2149.64 2238,81 2326,46 2416,54 2506,35 2594,39 Phillips Alaska Kuparuk 1D Comment f March, 200f - 16:27 Page 3 of 7 DrillQuest 2.00.08.002 Sperry-Sun Drilling Services Survey Report for rD-39 MWD Your Ref: API500292299700 Surveyed: 4 February, 200f Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 5816.79 72.560 148.380 4112.03 4216.58 5910.52 72.100 148.720 4140.48 4245.03 6005.88 71.260 149.960 4170.45 4275.00 6098.28 71.200 151.750 4200.19 4304.74 6183.67 71.850 150.810 4227.25 4331.80 6259.68 72.600 153.430 4250.45 4355.00 6294.93 72.500 152.960 4261.02 4365.57 6352.16 72.230 153.160 4278.36 4382.91 6442.31 71.320 151.620 4306.56 4411.11 6538.89 70.660 146.840 4338.03 4442.58 6631.44 70.310 146.040 4368.95 4473.50 6723.46 69.780 146.470 4400.36 4504.91 6814.37 69.200 147.700 4432.21 4536.76 6911.35 69.660 147.430 4466.28 4570.83 7005.48 70.720 146.850 4498.18 4602.73 7100.94 72.190 145,460 4528.54 4633.09 7193.97 72.460 144.670 4556.79 4661.34 7286.27 72.020 145.650 4584.95 4689.50 7378.81 73.110 145.790 4612.67 4717.22 7474.02 72,930 145.660 4640.48 4745.03 7570,18 72.420 150.380 4669.13 4773.68 7579.59 72.430 146.100 4671.97 4776.52 7666.53 72.320 146.410 4698.29 4802.84 7762.57 71.930 145.530 4727.77 4832.32 7857.16 71.510 148.080 4757.45 4862.00 7951.24 71.300 151.840 4787.46 4892.01 8045.93 72.880 152.310 4816.57 4921.12 8141.26 72.390 150.820 4845.03 4949.58 8235.19 72.680 150.610 4873.22 4977.77 8328.78 72.160 150.910 4901.49 5006.04 Local Coordinates Northings Eastings (ft) (ft) 2171.39 S 1600.47 E 2247.58 S 1647.07 E 2325.45 S 1693.23 E 2401.85 S 1735.84 E 2472.87 S 1774.76 E 2536.85 S 1808.60 E 2566.86 S 1823.76 E 2615.49 S 1848.47 E 2691.36 S 1888.15 E 2769.79 S 1934.84E 2842.49 S 1983.07 E 2914.41 S 2031.11 E 2985.88 S 2077.38 E 3062.52 S 2126.08 E 3136.90 S 2174.13 E 3212.06 S 2224.54E 3284.73 S 2275.30 E 3356.87 S 2325.51E 3429,82 S 2375.24 E 3505.07 S 2426.52 E 3582.91S 2475.13 E 3590.53 S 2479.85 E 3659.43 S 2525.88 E 3735.18 S 2577.03 E 3810.33 S 2626.20 E 3887.50 S 2670.83 E 3967.11S 2713.02 E 4047.12 S 2756.34 E 4125.27 S 2800.17 E 4203.12 S 2843.75 E Global Coordinates Northings Eastings (ft) (ft) 5956985.72 N 562288.91E 5956909.91N 562336.12 E 5956832.42 N 562382.91E 5956756.36 N 562426.13 E 5956685.65 N 562465.62 E 5956621.96 N 562499.98 E 5956592.06 N 562515.39 E 5956543.64 N 562540.49 E 5956468.09 N 562580.78 E 5956390.04N 562628.10 E 5956317.74 N 562676.91 E 5956246.21 N 562725.54 E 5956175.11 N 562772.38 E 5956098.87 N 562821.70 E 5956024.87 N 562870.35 E 5955950.12 N 562921.36 E 5955877.87 N 562972.70 E 5955806.13 N 563023.50 E 5955733.58 N 563073.81E 5955658.75 N 563125.70 E 5955581.31N 563174.93 E 5955573.73 N 563179.72 E 5955505.20 N 563226.30 E 5955429.87 N 563278.06 E 5955355.12 N 563327.84 E 5955278.31N 563373.09 E 5955199.04N 563415.92 E 5955119.39 N 563459.89 E 5955041.59 N 563504.34 E 5954964.10 N 563548.55 E Dogleg Rate (°/100ft) 1.00 0.60 1.52 1.84 1.29 3.43 1.30 0.58 1.91 4.73 0.90 0.72 1.42 O.54 1.27 2.07 0.86 1.12 1.19 0.23 4.72 43.36 0.36 0.96 2.60 3.79 1.73 1.58 0.38 0.63 Vertical Section 2690.37 2779.67 2870.16 2957.52 3038.35 3110.52 3143.99 3198.30 3283.65 3374.90 3462.11 3548.57 3633.71 3724.50 3813.06 3903.52 3992.06 4O79.87 4168.10 4259.10 4350.86 4359.83 4442.66 4534.02 4623.81 4712.90 4802.74 4893.52 4983.01 5072.10 Phillips Alaska Kuparuk 1D Comment March, 200~ - 16:27 Page 4 of 7 DrillQuest 2.00.08.002 Sperry-Sun Drilling Services Survey Report for rD-39 MWD Your Ref: AP1500292299700 Surveyed: 4 February, 2001 Kuparuk River Unit Measured Depth (ft) Sub-Sea Depth fit) Vertical Depth (ft) 8422.68 72.900 152.210 4929.68 5034.23 8518.27 72.910 151.770 4957.78 5062.33 8611.50 72.400 152.280 4985.57 5090.12 8699.91 73.430 151.580 5011.54 5116.09 8793.91 73.180 152.330 5038.55 5143.10 8888.23 72.930 150.730 5066.04 5170.59 8984.92 72.460 150.960 5094.80 5199.35 9079.03 72.090 151.570 5123.45 5228.00 9172.70 71.670 152.230 5152.59 5257.14 9265.60 72.530 149.610 5181.14 5285.69 9360.53 72.370 149.210 5209.77 5314.32 9455.55 73.900 150.670 5237.34 5341.89 9548.86 73.950 149.500 5263.17 5367.72 9642.37 73.970 150.160 5289.01 5393.56 9737.06 73.250 147,880 5315.73 5420.28 9832.21 72.730 147.670 5343.57 5448.12 9924.19 72.760 146.820 5370.85 5475.40 10018.74 72.740 146.530 5398.89 5503.44 10112.95 72.100 146.610 5427.35 5531.90 10200.89 71.760 149.130 5454.63 5559.18 10202.12 71.770 149.290 5455.01 5559.56 10294.27 71.620 148.410 5483.95 5588.50 10394.68 71.310 144.640 5515.88 5620.43 10487.96 70.600 145.610 5546.32 5650.87 10579.81 70.270 145.860 5577.08 5681.63 10674.56 70.640 147.270 5608.78 5713.33 10769.85 71.100 147.290 5640.01 5744.56 10865.84 70.480 148.870 5671.59 5776.14 10959.98 70.980 149.410 5702,66 5807.21 11051.98 71.400 148.910 5732.32 5836.87 Local Coordinates Global Coordinates Northings Eastings Northings Easfings fit) (ft) (ft) (ft) 4281.88 S 2886.40 E 5954885.69 N 563591.84 E 4362.54 S 2929.31 E 5954805.37 N 563635.40 E 4441.13 S 2971.06 E 5954727.12 N 563677.77 E 4515.70 S 3010.82 E 5954652.88 N 563718.14 E 4595.16 S 3053.15 E 5954573,76 N 563761.11 E 4674.47 S 3096.16 E 5954494.80 N 563804.76 E 4755.09 S 3141.14 E 5954414.55 N 563850.38 E 4833.69 S 3184.23 E 5954336.29 N 563894.11 E 4912.22 S 3226.16 E 5954258.10 N 563936.68 E 4989.47 S 3269.13 E 5954181.21 N 563980.27 E 5067.38 S 3315.19 E 5954103.66 N 564026.95 E 5146.09 S 3360.73 E 5954025.33 N 564073.13 E 5223.80 S 3405.45 E 5953947.98 N 564118.47 E 5301.49 S 3450.61 E 5953870.66 N 564164.26 E 5379.37 S 3497.37 E 5953793.16 N 564211.64 E 6456.34S 3545.88 E 5953716.58 N 564260.78 E 5530.22 S 3593.41 E 5953643.09 N 564308.90 E 5605.67 S 3643.02 E 5953568.05 N 564359.12 E 5680.62 S 3692.49 E 5953493.50 N 564409.20 E 5751.41S 3736.96 E 5953423.07 N 564454.23 E 5752.41 S 3737.55 E 5953422.07 N 564454.83 E 5827.28 S 3782.81E 5953347.57 N 564500.69 E 5906.68 S 3835.30 E 5953268.60 N 564553.83 E 5979.01S 3885.72 E 5953196.67 N 564604.83 E 6050.54 S 3934.45 E 5953125.54N 564654.13 E 6125.05 S 3983.65 E 5953051.43 N 554703.93 E 6200.79 S 4032.31E 5952976.08 N 564753.20 E 6277.73 S 4080.24 E 5952899.54 N 564801.74 E 6354.01 S 4125.82 E 5952823.62 N 564847.94 E 6428.78 S 4170.46 E 5952749.22 N 564893.19 E Dogleg Rate (°/100ft) 1.54 0.44 0.76 1.39 0.81 1.64 0.54 0.73 0.81 2.84 0.44 2.18 1.21 0.68 2.43 0.59 0.88 0.29 0.68 2.75 12.38 0.92 3.57 1.24 0.44 1.46 0.48 1.68 0.76 0.69 Vertical Section 5161.47 5252.59 5341.34 5425.62 5515.42 5605.44 5697,62 5787.10 5875.89 5964.15 6054.63 6145.49 6235.08 6324.89 6415.70 6506.69 6594.52 6684.8O 6774.59 6858.19 6859.35 6946.83 7041.98 7130.06 7216.55 7305.82 7395.85 · 7486.49 7575.33 7662.39 Phillips Alaska Kuparuk 1D Comment DrillQuest 2.00.08.002 I March, 2001- ~6:27 Page 5 of 7 Sperry-Sun Drilling Services Survey Report for 1D-39 MWD Your Ref: API500292299700 Surveyed: 4 February, 200~ Kuparuk River Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 11147.66 72.830 150.420 5761.71 5866.26 11242.59 73.120 149.620 5789.50 5894.05 11347.14 72.490 150.040 5820.41 5924.96 11429.99 72.170 150.750 5845.56 5950.11 11523.21 71.770 149.520 5874.41 5978.96 11618.14 71.260 150.500 5904.51 6009.06 11709.17 70.850 150.580 5934.07 6038.62 11805.04 71.680 147.890 5964.86 6069.41 11900.39 71.750 147.830 5994.78 6099.33 11996.11 71.640 150.410 6024.85 6129.40 12091.11 71.180 150.430 6055,13 6159.68 12187.28 71.190 148.260 6086.15 6190.70 12281.83 70.830 145.920 6116.92 6221.47 12312.74 70.710 146.250 6127.10 6231.65 12401.66 70.910 140.790 6156.35 6260.90 12499.08 70.590 141.780 6188.47 6293.02 12594.98 71.870 141.500 6219.33 6323.88 12692.25 71.220 141.770 6250.12 6354.67 12788.55 72.570 144.580 6280.05 6384.60 12886.63 72.710 143.370 6309.32 6413.87 12979.11 73.480 146.110 6336.21 6440.76 13075.52 72.980 147.180 6364.03 6468.58 13172.78 71.410 147.270 6393.77 6498.32 13268.13 70.280 146.810 6425.06 6529.61 13363.82 70.070 147.340 6457.51 6562.06 13451.63 69.330 147.530 6487.97 6592.52 13545.00 69.330 147.530 6520.93 6625.48 Global Coordinates 6507.37 S 4216.44E 5952671.00 N 6585.99 S 4261.80 E 5952592.75 N 6672.34 S 4312.00 E 5952506.81 N 6740.98 S 4350.99 E 5952438.49 N 6817.85 S 4395.13 E 5952361.98 N 6895.82 S 4440.14 E 5952284.37 N 6970.79 S 4482.48 E 5952209.75 N 7048.79 S 4528.92 E 5952132.12 N 7125.45 S 4577,08 E 5952055.85 N 7203.44S 4623.72 E 5951978.25 N 7281.74 S 4668.17 E 5951900.30 N 7360.05 S 4714.58 E 5951822.37N 7435.10 S 4763.15 E 5951747.72 N 7459.32 S 4779.43 E 5951723.63 N 7526.81S 4829.34E 5951656.54N 7598.57 S 4886.87 E 5951585.25 N 7669.77 S 4943.22 E 5951514.51 N 7742.11 S 5000.48 E 5951442.63 N 7815.38 S 5055.33 E 5951369.81N 7891.09 S 5110.39 E 5951294.55 N 7963.33 S 5161.46 E 5951222.72 N 8040.43 S 5212.21E 5951146.03 N 8118.29 S 5262.34E 5951068.58 N 8193.86 S 5311.34E 5950993.41N 8269.42 S 5360.27 E 5950918.24 N 8338.83 S 5404.60 E 5950849.20 N 8412.53 S 5451.50 E 5950775.87 N Eastings (ft) 564939.80 E 564985.79 E 565036.68 E 565076.23 E 565120.99 E 565166.62 E 565209.57 E 565256.64 E 565305.42 E 565352.69 E 565397.77 E 565444.81E 565493.98 E 565510.46 E 565560.91E 565619.01E 565675.94 E 565733.79 E 565789.22 E 565844.89 E 565896.54 E 565947.92 E 565998.67 E 566048.28 E 566097.82 E 566142.7O E 566190.20 E Dogleg Rate (°/100ft) 2.12 0.86 0.71 0.90 1.33 1.12 0.46 2.79 0.09 2.56 0.48 2.14 2.37 1.08 5.80 1.01 1.36 0.72 3.11 1.19 2.95 1.18 1.62 1.27 0.57 0.87 0.00 Vertical Section 7753.39 7844.09 7943.90 8022.76 8111.32 8201.28 8287.28 8378.03 8468.57 8559.41 8649.35 8740.34 8829.73 8858.91 8942.62 9034.00 9124.28 9216.02 9307.24 9400.65 9489.00 9581.29 9673.88 9763.94 9853.96 9936.31 10023.67 Phillips Alaska Kuparuk t D Comment Projected survey March, 2001-16:27 Page 6 of 7 DrillQuest 2.00.08.002 Sperry-Sun Drilling Services Survey Report for ~D-39 MWD Your Ref: API500292299700 Surveyed: 4 February, 200~ Kuparuk River Unit 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. Magnetic Declination at Surface is 26.320° (15-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 147.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13545.00ft., The Bottom Hole Displacement is 10024.45ft., in the Direction of 147.056° (True). Phillips Alaska KuParuk 'ID Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 354.00 353.99 0.71 N 0.68 W 13545.00 6625.48 8412.53 S 5451.50 E Comment Tie On Point Projected survey Survey tool program for ~D.39 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 354.00 353.99 354.00 353.99 13545.00 6625.48 Survey Tool Description Tolerable Gyro (1D-39 PGSS) MWD Magnetic (1D-39 IVlWD) March, 200~ - ~6:27 Page 7 of 7 DrillQuest 2.00.08.002 MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 11, 2001 · SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder j/.L"~u,~57 Phillips P.I. Supervisorr..~""~ '-'"'-- ',.-- ' 1D Pad ~'('t~''O~, 1 D-32, 1 D-39, 1 D-40A FROM: Chuck Scheve KRU Petroleum Inspector Kuparuk NON- CONFIDENTIAL ,Packer Dept. h ,. Pretest Initial 15 Min. 30 Min. . . . Well! 1D-32 .ITypelnj:l S I T.V.D. 16276 I Tubing{ 2050. 12050 12050 12050 I lntervall ,,I P.T.D.I 200-173 Typetestl. P ITestpsil 1569 I CasingI 1850 I 25o0 I 2450 1.24,50 I P/F I _.P Notes: Wel!.U.~3~..~%l~y~,'.lnj..1 $ IT'V-D'I6200'1 Tubing' I' 2°5°1 20501 20501 2050 I lntervall' I 'P-T~~!i~g~i:'{es{1 P I Testpsil ,1550 l, Casi, ngl 12501 25oo' I 2475'I 2475..! P/I Note~.' '- w.,,I, 1D-40A I Type,.j.I S ii~,~ I Tubingl 50So'l ~0~0'1 ~0~0 I 2050"l,nterva,I , P'T'D'I 200-190 I.Typetestl P' ITestp~il 1494.1 casing l 7,50 ,,[' 2550 I 2500 ~ 2500 Notes: Welll ,I Type Inj. I I T.V.D. I . I Tubing I I I, I' I lnterVa'll .P'T'D-I , ITypetestl. ,, ITestpsil I. Casing l . I .. I I I..P,/F .I Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test · 4= Four year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 1D Pad in the Kuparuk river field and witnessed the initial MIT on wells 1D-32, ID-39 and 1D-40A. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: _3 Attachments: Number of Failures: 0 Total Time during tests: 3 hours CC: MIT report form 5/12/00 L.G. MIT KRU 1-D Pad 5-11-01 CS 5/18/01 S T A T E OF ALASKA TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSER VA TION COMMISSION James Trantham Drilling Engineer Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 PHONE: (907) 279-1433 FAX: (907) 276-7542 ge~ Kuparuk River Unit ID-39 Phillips Alaska, Inc. Permit No: 200-216 Sur Loc: 523'FNL, 421'FEL, Sec. 14, TllN, R10E, UM Btmhole Loc. 1516'FSL, 351'FEL, Sec. 25, TllN, R10E, UM Dear Mr. Trantham: 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. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. 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 COMAMISSION DATED this. ,5- -~.-/2 . day of January, 2001 rill/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [~] Redrill [-'1 lb. Type of well. Exploratory r-1 Stratigraphic Test r"] Development Oil E~] Re-entry D Deepen D Service r~l Development Gas D Single Zone [~1 Multiple Zone B 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation C) ~5-,~,5~ ~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 AD~ ALK 591~])Z.-~=:~:,j.,, 'j~ Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 523' FNL, 421' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1921' FSL, 582' FEL, Sec. 25, T11N, R10E, UM 1D-39 59-52-180 At total depth 9. Approximate spud date Amount 1516' FSL, 351' FEL, Sec. 25, T11N, R10E, UM January 5, 2001 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 351 @ Target feetI 1D-40A 13.5' @ 343' feet 2560 13571 ' MD/6624' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035 (e)(2)) iKickoff depth: 300 MD Maximum hole angle 72° Maximum surface 2915 psig At total depth (TVD) 3550 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~ Weight Grade Couplin~ Length MD TVD MD TVD {include sta~le data) 20" 16" 91.5# H-40 Weld 85' 35' 35' 120' 120' 230 sx ASI 12.25" 9.625" 40# L-80 BTCM 6133' 35' 35' 6168' 4341' 450 sx ASLite 720 sx LiteCrete 8.5" 7" 26# J-55 BTCM 12479' 35' 35' 12514' 6298' 170 sx Class G 6.125" 3.5" 9.3# L-80 SHLT 1207' 1236z 6252 13571' 6624' 250 sx Class GasBIok 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) tree vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEIVED Pedoration depth: measured true vertical A~ka 0il & Gas Cons. Commission Anchorage 20. Attachments Filing fee BI Property Plat r-] BoP Sketch BI Diverter Sketch F~ Drilling program r~ Drilling fluid program BI Time vs depth plot r--IRefraction analysis BI Seabed report [--I 20 AAC 25.050 requirements BI 21. I hereby cer~fy that the foregoing is true and correct to the best of my knowledge Questions? Call Todd Mushovic 265-697L~ Signed i ~¢'-~{ ~&,.... Title: Drilling Engineering Supervisor Date ¢'~..O DeC. ~ J. Tra'~tham Pre~ared bv Sharon AIIsumDrak~ Commission Use Onl) .e,m, IApp~ovaldate . I See cover letter 50-O Z..~,.- Z ~ ¢¢~ --~)~), O//t/,~.~/~ ~/ I,or other requirements Conditions of approval Samples required D Yes [~] No Mud Id'g requirelil' BI Yes [~ No Hydrogen sulfidemeasures [] Yes D No Directional surveyrequired [] Yes [~ No Required working pressure for BOPE O2M; D 3M; ~ ~ O 10M;D E] etna,: cw' , by order of Approved by D 'Tavlor "~,e;IrrlOU i~t · Commissioner the commission Date . , Form 10-401 Rev. 12/1/85 · / Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE EBA INJECTOR KRU 1 D-39 General Procedure: 1. Excavate cellar, install cellar box, set and cement 20" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/6168 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' minimum to 50' maximum 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). 8. Directionally drill 8-1/2" hole to base HRZ (12514' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Perform second LOT at to evaluate long string option. If LOT is adequate to long string, drill to well total depth (13571' MD), run 7" 26.0# J-55 BTCM casing to surface and cement, and continue with step #17. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 9. If LOT is inadequate to long string, Run 7" 26.0# L-80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 10. Nipple up BOPE and test to 5000 psi. Record results. 11. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 12. Drill out cement and 20' minimum to 50' maximum 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). 13. Drill 6-1/8" hole to well total depth (+/- 13571' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 14. Run open hole e-line or drill pipe conveyed logs as needed. 15. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/Flexlock hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 16. RIH with clean out BHA. Scrape casing. Displace welltocompletionbrine. RECEIVED 17. Run and land 3-1/2" tubing with gas lift completion. DEC 2, 1 ~000 A~Ii,O~2~~2 "' r'.~,, r'.~s. Commi~n 18. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 19. Freeze protect well. Set BPV. Release rig and turn well over to production. 20. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage TJM, 12/19/00, v2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1 D-39 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" Surface Casin[I 8.5-10.2 16-26 25-50 100-200* 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin~ 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 20-30 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Two possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1 D-39 well path. 1) MASP can be calculated using an expected leak-off of 13.3 ppg EMW (0.69 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2518 psi. The leak off EMW was chosen based on an open hole LOT on well, 1 D-32, taken to 13.3 ppg (0.69 psi/ft). MASP = (4341 ft)(0.69-0.11) = 2518 psi RECEIVED DEC % i ?nn Alaska Oil & Gas OCs. 6ommi~i~ 2) If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can be calculated based on a reservoir pressure of 3550 psi at 6624' TVD (0.55 psi/fi) and a gas gradient of 0.11 psi/ft. In this case, MASP would occur at 2915 psi. MASP = (6624 ft)(0.55 - 0.11) - 2915 psi Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing. In the event that the well has to be topset above the Kuparuk, the maximum anticipated pressure for the intermediate casing string would continue to 2915 psi as calculated previously. Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an intermediate string is needed. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based no potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.0 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6624'. MW = [(6624 ft)(0.55)+150]/6624/.052 = 11.0 ppg In order to allow for a long string design, the minimum LOT in the HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 11.5 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 1 D-39 is 1D-40A. As designed, the minimum distance between the two wells would be 13.5' at 343' MD. Drillinq Area Risks: Risks in the 1D-39 drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D- shale based upon those results. Annular Pumping 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 iniected 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 1D.-39 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 form~~,,~ r.-. ,~ ~r.-- ~,~ I CL,,r- IV .LJ DEC 2 1 ?nno Alaska Oil & Gas Cons. Commission Anchorage At the end of drilling operations, a request for 1D-39 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1D pad, per regulation 20 AAC 25.080, will be submitted. 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 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 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 J-55 3 BTCM 4,320 psi 3,672 psi 4,980 psi 4,233 psi 3¥2"* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi *ifneeded 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). DEC % 1 ? OO 0il & Gas r. zms. commission KRU 1 D-39 Inject(' Proposed Completion Schematic Topset Base Case PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY 20" 91.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 6168' MD / 4341' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. Intermediate csg. 7" 26.0# J-55 BTCM (+/- 12514' MD / 6298' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+/- 13571' MD / 6624' TVD) 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), set @ +/- 12364' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 17' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Halliburton 'XN' nipple w/2.75" No-Go Profile, 3-1/2" SLHT box x pin 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe RECEIVED DEC 2 i ZOO0 Alaska Oil & Gas Cons. Comm~ior, Anchorage TJM, 12/19/00, vl KRU 1D-39 Inject( PHI .LIPS Alaska, Inc. Proposed Completion Schematic A Subsidiary of PHILLIPS PETROLEUM COMPANY Long String Contingency Case 20" 91.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 6168' MD / 4341' TVD) Future Perforations Production csg. 7" 26.0# J-55 BTCM (+/- 13571' MD / 6624' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple RECEIVED DEC 2 j 2nno Alaska 0tl & Gas Cons. Commission Anchorage 3-1/2" x 1-1/2" camco 'MMG' Mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. I jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 7" x 3-1/2" Baker 'SAB-3' permanent packer w/KBH-22 seal assembly, 3-1/2" x 6' L-80 EUE8RD handling pup on top I jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'D' nipple w/2.75" No-Go Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 3-1/2" x 10' L-80 EUE8RD pup joint 3-1/2" Baker Shear Out Ball Seat Sub. Tubing tail +/- 50' above top of proposed perforations TJM, 12/20/00, vl CreotecI by finch For: T Mushovie C~te plotLea: ]8-Dec-2000 P~ot Reference Ls 39 Version ~1. Coord~notes ore in feet reference slot 239. ~Tcue Vertlcol Depths ore reference est. RKB(Nobors 16E).~ I N'I*EfO Phillips Alaska, Inc. Structure : Pod 1D Well : 39 Field : Kuporuk River Unit Locofion : North Slope, Aloskoi PROFILE COMMENT DATA Point Begin D'nl Nudge Drop To Vert iBase Permafrost iKOP iTop Ugnu iTop W Sak iEOC iBeg Right Turn iEOC iBase W Sok 19 5/8 Csg Pt C80 C50 C40 C50 C20 7 Csg/Base HRZ iTGT/Top C4/Top D iTop C3 !Top C2 iTop C 1 MD 500.00 600.00 1417.62 1700.00 2600.00 3160.38 4155.42 4388.70 5200.00 5337.12 5519 96 61 68 42 6894 69 9961 90 0798 41 1803 52 2286 62 2513 58 2795 66 3074 50 3155.56 5217.1 6 3282.01 [nc 0.00 4.50 0.00 0.00 20.92 35.29 64.98 72 O4 72 04 72 04 72 04 72 04 72 04 72 04 72 04 72 04 72 04 72 04 72.04 72.04 72.04 72.04 72.04 Dir 0.00 284.00 284.00 284.00 125.00 144.19 145.00 145.00 145.00 149.32 149.32 149.32 149.32 149.32 149.32 149.32 149.32 149.32 149.32 149.32 149.32 149.32 149.32 !Top B Shale 13,327.40 72.04 149.52 i.i..D_, v. CscLE!; .................................................... .1_~.~._7_0_._5.Z ........... ~7~_.04 1~4~.32 TVD 300.00 599.69 1417 O0 1699 38 2582 03 3076 O0 3706 O0 3792 14 4042.50 4084.61 4141.00 4341.00 4565.00 5511.00 5769.00 6079.00 6228.00 6298.00 6385.00 6471.00 6496.00 6515.00 6535.00 6549.00 6624.00 North East V. Sect 0.00 0.00 0.00 2.85 - 11.43 -8.50 5.70 -22.85 - 1 7.01 5.70 -22.85 - 17.01 -55.70 t I 1.58 106.63 -245.72 289.55 562.27 -862.57 721.65 1114.53 -1041.79 847.14 1333.06 -1 673.98 1289.81 2103.92 -1783.54 1360.52 2254.51 -1933.14 1449.25 2408.18 -2463.67 1763.95 3024.80 -3057.86 2116.42 571 5.41 -5567.26 3604.95 6632.02 -6251.65 4010.92 7427.45 -7073.97 4498.70 8583.21 -7469.21 4755.15 8842.59 -7654.90 4843.30 9058.41 -7885.68 4980.19 9326.64 -8113.80 5115.51 9591.78 -8180.12 5154.85 9668.86 -8230.52 5184.75 9727.44 -8283.57 5216.22 9789.10 -8320.71 5238.25 9832.26 -8519.66 5356.26 10063.50 Deg/lO0 0.00 1.50 0.00 0.00 5.00 5.00 3.00 3.00 0.00~ 5.00 o.oo o.oo 0.00 0.00 0.00 o.oo 0.00 o.ooi 0.00; 0.00: o 0.00~ ~. 0.00 ~. 0.00 Dote plotted: 18-0ec-2000 Plot Reference is 39 Vets;on ~1. Coord;nates ~re ;n feet reference slot Ved~cal Depths are reference est. RKB(N~ors INTEQ Phillips Alaska, Inc. Structure : Pad 10 Well : 59 Field : Kuporuk River Unit Location : North Slope, Alaska 5OO 1aaa 1500 · '+- 2000 2500 ~-~ 3o0o .-- 3500 >. 4000 4500 I V Est. RKB ELEVATION: 106' Begin D'nl Nudge .50 Drop To Vert 1.50 Base Permafrost KOP 2.00 6.00 147.77 AZIMUTH 959a' (TO TARGET) ***Plane of Proposal*** , DLS: 5.00 deg per 100 fi TRUE 5.26 ~x 25.74 % 30.95 ~'~ DLS: 3.00 de9 per 100 ft Top Ugnu '~ 42.00 '% 48.00 '"%..54.00 BLS: 5.00 deg per 100 ft ~o TO"E~C~ak ~ .... Beg Right Turn -~-,~.j z.u,~ EOC ~ Base W Sok ~/~c .... g AVERAGE ANGLE 73.04 DEG 500O 5500 -"~...........~C 50 6000 ~C50c20 Csg/Bose HRZ 6500 TOT/Top C4/'fop D Top C5 TD - Csg Pt 7000 i i [ t , i i i i t i i i i i i i i i ~ i ~ i i i i i i i ~ I ] i ~ f i i i i 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 Vertical Section (feet) -> Azimuth 147.77 with reference 0.00 N, 0.00 E from slot #59 Phillips Alaska, Inc. Structure : Pod lO Well : ,.39 Field : Kuparuk River Unit Location : North Slope, Alaska DEC 21 A/askaI L PS C50 East (feet) -> 450 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 i i i i i i i i i i Begin D'nl Nudge ;284 . A Drop To Vert - 'a~(j,~NxB6se Permafrost N op Ugnu ESTIMATED I SURFACE LOCAT ON 523' FNL. 421' FEL[ SEC. 14. TI_~IN, RIO______EE ] NTop W Sak "~ Beg Right Turn g,~EOC e W SaR 9 5/8 Casing .~...~ 147.77 AZIMUTH 9592' (TO TARGET) ***Plane of Proposal*** ~..o TRUE TARGET LOCATION: 1921' FSL, 582' FEL SEC. 25, T11N, RIOE TD LOCATION: 1516' FSL, 551' FEL SEC, 25, T11N, RIOE C30 C40 450 450 9OO 1350 1800 2250 2700 3150 3600 0 4O5O 4500 ..+. I 4950 V 5400 585O 6300 675O 72OO 7650 8100 8550 C20 7 Csg/Bose HRZ K-1 TOT/Top C4/Top D Top C3 Top C2 Top C1 Top B Shale TD - Csg Pt 2000 Commission 1 aa '~ 7O0 21oo / - ~L/I_.---''~' .~o~ ~ ?~ ~10 Phillips Alaska, Inc.! Structure : Pad 1D Well : 39 t Field : Kuparuk River Unit Location : North Slope, Alasl<ai TRUE NORTH 0 ...... ~-~ ...................... ., 19oo 3~ 20 - 30 ......................... 40 1100 29O 7O 280 8O 270 1~oo 70O 9O 260 lO0 25O 110 240 5100 "~:~ 3O 1500 2300 )1900 2OO 160 190 150 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 1Phillips Alaska Inc l ' ' n.:h For: T Mushovic I Structure : Pad 10 Well : 39 Dot. I~on,.d: aotR~...~;.J~v~.~/t , Field : Kuparuk River Unit Location : North Slope, Alasko Eosl (feel) -> 60 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 120 , , ',',~ 1300 160 1 200 240 280 320 360 29001,, ' , ', '-~ 1400 160~'" '%3000,, 240C 1700 ""~.,_ ~, 1500 ,,~'--..~,! 8o'a ., 160O 3200K, 1700 ~, i i i i i i i i i i i i I i i i i i i ~>-~._~oo ............ 2300 2400 .......... ~ .................... 2500 2900 250O 2000 ', 3000 2400 160 200 240 280 320 360 ~ 440 480 -i.,- 0 520 V 560 "',., 2600 2200 3900 '~x,,x ',, 2300 ~ " ' 3100 2500 ' 1700 ~, 400 1800 ~300 ',, 2600 400 2000 ' 4000'~X 440 0 2100 ~ '., ~ ~ -. '.34oo \ ' 4~o ~ ~1700 '~. ' k ', 1800 ~ % --~ ',, \ ',, x, 21oo \ % '% ', 280% ,, --..~, ~ ,.. 4100% 52o 2600 1800 '~~~~ ~~2~~~ ~ 580 V ~ '~ 1900 640 ', x 760 ~,¢7002000"~ m i i m I m ~ I I m m m m I m m m m , m 160 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 Eost (feet) -> 640 680 760 8O0 840 88O 120 r 1 c,~ ~ ,~.ch For: T Mushovic i lPhillips Alaska, Inc. Structure : Pod 1D Well : 3g Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 600 600 700 4101 700 800 ~" ' ~, 37'~0 900 31ho ' lOOO ~,, ' 500 c' ~ 1600 ..~ 0 1700 I v 1100 1200 ~[ 1300 O0 1400 X~ 1800 3900 1900 3500 '~, 2100 \ 2300 3300 4300 370 "' "k 3900 4100 4500 2500 2000 2100 4300 2200 2300 t 2600 / , , , , ¥ , , i ~ i i i 500 600 700 800 900 1000 1100 2700 5300 8OO 90O 1000 2900 1100 25OO 4500 ,, 3100 '..4700 .. · · 4100 3300 4500 2700 ,, 1200 i ~ i i i ~ ~ ~ i i i i i i i i 1200 1300 1400 1500 1600 1700 1800 1900 2000 21 O0 1300 14OO 0 1500 e- l600 ? 1700 I 1800 1900 2000 _ -2100 2200 I2300 2600 East (feet) -> For: T Mushovic I~EQ 1600 1800 Phillips Alaska, Inc.. Structure: Pod 1D Well : 39 Field : Kuparuk River Unit Location : North Slope, Alaska! East (:feet) -> 4100 ', 1800 , 4900~ 290C 2000 ',,,~ ~4 2000 2200 ~,2900 ', 2200 ',~, 5100 4300 2400 2600 2800 3000 3200 Q) 3400 · +- 3600 0 3800 v 4000 4200 4400 4600 4800, 5OOO 5200 54O0 4300 · · ',, ,, 31 O0 3700 ,, 5100 ', 4500 3900 ,, 5300 ~o 2900 ,, 5500 ' '~ 3500 5700 " 5900 '" 3700 ,. ~, 31~ 3900 6100 " ,, ~ 4100 6300 ' 4300 6500 , 6700 ', O0 '., 3300 4500 4700 ~. 3500 5100 5 i ~ i ~ i i i 3100 '~, 5300 ,, ,, 5500 · , ,, 5700 4900 ,. ,. ~,~5100 ' 3700 , 3900 3500 i i i i ~ i , ~ i i I i i 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 East (feet) -> 560O 2400 4500 '~-~ 2600 2800 3000 6100 '~ .. ., , '% i i i 4000 4200 3200 0 3400 C 3600 '~ 3800 v 4000 4200 4400 4600 480O 5OOO 52OO 5400 5600 Structure : Pod 1D Well: 39 I Field : Kuparuk River Unit Location : North Slope, Aloskoj East (feet) -> 5000 5200 5400 5600 5800 6OO0 6200 6400 ~ 6600 6800 0 7000 I 7200 7400 7600 78OO 8OOO 8200 8400 8600 8800 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 ~m~5500~x~~x~~~ 5500 ~4500 ~ 57o0 ~, 4300 ~, 4500 ,, , ,. ' ~ 6100 j. 4700 ., ,. ,. 5100 '~ 5500 ',~ 5300 .. i i i ~ , i i i i J ~ i i i i i i , , i , , i q ~ i i , i i i 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 East (feet) -> 50OO 52OO 5400 5600 5800 6000 6200 6400 6600 6800 7000 I 7200 V 7400 7600 7800 8000 8200 _ -8400 8600 8800 Gas Cons Anchora~' Commission Phillips Alaska, Inc. Pad 1D 39 slot #39 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 39 Version #1 Our ref : prop2176 License : Date printed : 18-Dec-2000 Date created : 15-Apr-1997 Last revised : 18-Dec-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.172,w149 30 31.181 Slot Grid coordinates are N 5959143.175, E 560670.189 Slot local coordinates are 523.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Pad 1D,39 Kuparuk River Unit,North Slope, Ala~~ Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 300.00 0.00 0.00 300.00 0.00 N 0.00 E 400.00 1.50 284.00 399.99 0.32 N 1.27 W 500.00 3.00 284.00 499.91 1.27 N 5.08 W 600.00 4.50 284.00 599.69 2.85 N 11.43 W PROPOSAL LISTING Page Your ref : 39 Version Last revised : 18-D~? 000 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 Begin D'nl Nudge 1.50 -0.95 1.50 -3.78 1.50 -8.50 Drop To Vert 700.00 3.00 284.00 699.47 4.43 N 17.77 W 1.50 -13.23 800.00 1.50 284.00 799.39 5.38 N 21.58 W 1.50 -16.06 900.00 0.00 284.00 899.38 5.70 N 22.85 W 1.50 -17.01 1000.00 0.00 284.00 999.38 5.70 N 22.85 W 0.00 -17.01 1417.62 0.00 284.00 1417.00 5.70 N 22.85 W 0.00 -17.01 Base Permafrost 1500.00 0.00 284.00 1499.38 5.70 N 22.85 W 0.00 -17.01 1700.00 0.00 284.00 1699.38 5.70 N 22.85 W 0.00 -17.01 KOP 1800.00 2.00 105.00 1799.36 5.25 N 21.16 W 2.00 -15.72 1900.00 4.00 105.00 1899.22 3.89 N 16.11 W 2.00 -11.88 2000.00 6.00 105.00 1998.84 1.64 N 7.69 W 2.00 -5.49 2100.00 8.00 105.00 2098.08 1.52 S 4.08 E 2.00 3.46 2200.00 10.00 105.00 2196.85 5.57 S 19.19 E 2.00 14.94 2300.00 12.55 113.13 2294.92 12.08 S 37.57 E 3.00 30.26 2400.00 15.26 118.49 2391.98 22.63 S 59.14 E 3.00 50.69 2500.00 18.07 122.24 2487.77 37.19 S 83.83 E 3.00 76.16 2600.00 20.92 125.00 2582.03 55.70 S 111.58 E 3.00 106.63 2700.00 23.26 129.99 2674.69 78.64 S 141.34 E 3.00 141.90 2800.00 25.74 134.09 2765.69 106.45 S 172.07 E 3.00 181.81 2900.00 28.31 137.51 2854.77 139.04 S 203.69 E 3.00 226.25 3000.00 30.95 140.39 2941.69 176.34 S 236.10 E 3.00 275.09 3100.00 33.64 142.86 3026.22 218.24 S 269.22 E 3.00 328.20 3160.38 35.29 144.19 3076.00 245.72 S 289.53 E 3.00 362.27 Top Ugnu 3200.00 36.38 145.00 3108.12 264.63 S 302.97 E 3.00 385.43 3287.37 39.00 145.00 3177.25 308.38 S 333.60 E 3.00 438.78 3387.37 42.00 145.00 3253.29 361.57 S 370.85 E 3.00 503.64 3487.37 45.00 145.00 3325.82 417.95 S 410.33 E 3.00 572.39 3587.37 48.00 145.00 3394.64 477.37 S 451.93 E 3.00 644.83 3687.37 51.00 145.00 3459.58 539.65 S 495.54 E 3.00 720.78 3787.37 54.00 145.00 3520.45 604.63 S 541.04 E 3.00 800.01 3887.37 57.00 145.00 3577.08 672.13 S 588.30 E 3.00 882.32 3987.37 60.00 145.00 3629.33 741.96 S 637.20 E 3.00 967.47 4087.37 63.00 145.00 3677.04 813.94 S 687.60 E 3.00 1055.24 4153.42 64.98 145.00 3706.00 862.57 S 721.65 E 3.00 1114.53 Top W Sak 4187.37 66.00 145.00 3720.08 887.87 S 739.37 E 3.00 1145.38 4287.37 69.00 145.00 3758.35 963.54 S 792.35 E 3.00 1237.65 4387.37 72.00 145.00 3791.73 1040.75 S 846.41 E 3.00 1331.80 4388.70 72.04 145.00 3792.14 1041.79 S 847.14 E 3.00 1333.06 EOC 4500.00 72.04 145.00 3826.46 1128.52 S 907.87 E 0.00 1438.81 5000.00 72.04 145.00 3980.63 1518.13 S 1180.68 E 0.00 1913.89 5200.00 72.04 145.00 4042.30 1673.98 S 1289.81 E 0.00 2103.92 Beg Right Turn 5300.00 72.03 148.15 4073.16 1753.36 S 1342.20 E 3.00 2199.01 5337.12 72.04 149.32 4084.61 1783.54 S 1360.52 E 3.00 2234.31 EOC 5500.00 72.04 149.32 4134.84 1916.80 S 1439.57 E 0.00 2389.20 5519.96 72.04 149.32 4141.00 1933.14 S 1449.25 E 0.00 2408.18 Base W Sak 6000.00 72.04 149.32 4289.05 2325.87 S 1682.22 E 0.00 2864.65 D£C £ 1 2000 Alaska Oil & Gas Cons.' Con~nission Anchorage Ail data is in feet unless otherwise stated. Coordinates from slot #39 and TVD from est. RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10063.50 on azimuth 147.84 degrees from wellhead. Total Dogleg for wellpath is 88.77 degrees. Vertical section is from wellhead on azimuth 147.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,39 Kuparuk River Unit,North Slope, Alas~" Measured Inclin. Azimuth True Vert R E C Depth Degrees Degrees Depth C 00 TANGULAR RDINATES PROPOSAL LISTING Page 2 Your ref : 39 Version #1 Last revised : 18-D~'"' 900 Dogleg Vert Deg/100ft Sect 6168.42 72.04 149.32 4341.00 2463.67 S 1763.95 E 0.00 3024.80 9 5/8 Csg Pt 6500.00 72.04 149.32 4443.27 2734.94 S 1924.87 E 0.00 3340.10 6894.69 72.04 149.32 4565.00 3057.86 S 2116.42 E 0.00 3715.41 C80 7000.00 72.04 149.32 4597.48 3144.01 S 2167.52 E 0.00 3815.55 7500.00 72.04 149.32 4751.69 3553.08 S 2410.18 E 0.00 4291.00 8000.00 72.04 149.32 4905.90 3962.15 S 2652.83 E 0.00 4766.45 8500.00 72.04 149.32 5060.11 4371.22 S 2895.48 E 0.00 5241.90 9000.00 72.04 149.32 5214.33 4780.29 S 3138.14 E 0.00 5717.35 9500.00 72.04 149.32 5368.54 5189.36 S 3380.79 E 0.00 6192.80 9961.90 72.04 149.32 5511.00 5567.26 S 3604.95 E 0.00 6632.02 C50 10000.00 72.04 149.32 5522.75 5598.43 S 3623.44 E 0.00 6668.24 10500.00 72.04 149.32 5676.96 6007.50 S 3866.09 E 0.00 7143.69 10798.41 72.04 149.32 5769.00 6251.65 S 4010.92 E 0.00 7427.45 C40 11000.00 72.04 149.32 5831.17 6416.57 S 4108.75 E 0.00 7619.14 11500.00 72.04 149.32 5985.39 6825.64 S 4351.40 E 0.00 8094.59 11803.52 72.04 149.32 6079.00 7073.97 S 4498.70 E 0.00 8383.21 C30 12000.00 72.04 149.32 6139.60 7234.71 S 4594.05 E 0.00 8570.04 12286.62 72.04 149.32 6228.00 7469.21 S 4733.15 E 0.00 8842.59 C20 12500.00 72.04 149.32 6293.81 7643.78 S 4836.71 E 0.00 9045.49 12513.58 72.04 149.32 6298.00 7654.90 S 4843.30 E 0.00 9058.41 7 Csg/Base HRZ 12795.66 72.04 149.32 6385.00 7885.68 S 4980.19 E 0.00 9326.64 K-1 13000.00 72.04 149.32 6448.02 8052.85 S 5079.36 E 0.00 9520.94 13074.50 72.04 149.32 6471.00 8113.80 S 5115.51 E 0.00 9591.78 1D-39 7-Dec-00 13155.56 72.04 149.32 6496.00 8180.12 S 5154.85 E 0.00 9668.86 Top C3 13217.16 72.04 149.32 6515.00 8230.52 S 5184.75 E 0.00 9727.44 Top C2 13282.01 72.04 149.32 6535.00 8283.57 S 5216.22 E 0.00 9789.10 Top Cl 13327.40 72.04 149.32 6549.00 8320.71 S 5238.25 E 0.00 9832.26 Top B Shale 13500.00 72.04 149.32 6602.23 8461.92 S 5322.01 E 0.00 9996.39 13570.57 72.04 149.32 6624.00 8519.66 S 5356.26 E 0.00 10063.50 TD - Csg Pt Ala~a 0il & Gas Cons. Anchorage C°~ssion All data is in feet unless otherwise stated. Coordinates from slot 939 and TVD from est.RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10063.50 on azimuth 147.84 degrees from wellhead. Total Dogleg for wellpath is 88.77 degrees. Vertical section is from wellhead on azimuth 147.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,39 Kuparuk River Unit,North Slope, Ala~: PROPOSAL LISTING Page 3 Your ref : 39 Version #1 ,, Last revised : 18-D~ 000 Comments in wellpath MD TVD Rectangular Coords. Comment 300 00 300.00 0.00 N 0.00 E Begin D'nl Nudge 600 1417 1700 3160 4153 4388 5200 5337 5519 6168 6894 9961 10798 11803 12286 12513 12795 13074 13155 13217 13282 13327 13570 00 599. 62 1417. 00 1699. 38 3076. 42 3706 70 3792 00 4042 12 4084 96 4141 42 4341 69 4565 90 5511 41 5769 52 6079 62 6228 58 6298 66 6385 50 6471 56 6496 16 6515 01 6535 40 6549 57 6624 69 2.85 N 11.43 W Drop To Vert 00 5.70 N 22.85 W Base Permafrost 38 5.70 N 22.85 W KOP 00 245.72 S 289.53 E Top Ugnu 00 862.57 S 721.65 E Top W Sak 14 1041.79 S 847.14 E EOC 30 1673.98 S 1289.81 E Beg Right Turn 61 1783.54 S 1360.52 E EOC 00 1933.14 S 1449.25 E Base W Sak 00 2463.67 S 1763.95 E 9 5/8 Csg Pt 00 3057.86 S 2116.42 E C80 00 5567.26 S 3604.95 E C50 00 6251.65 S 4010.92 E C40 00 7073.97 S 4498.70 E C30 00 7469.21 S 4733.15 E C20 00 7654.90 S 4843.30 E 7 Csg/Base HRZ 00 7885.68 S 4980.19 E K-1 00 8113.80 S 5115.51 E 1D-39 7-Dec-00 00 8180.12 S 5154.85 E Top C3 00 8230.52 S 5184.75 E Top C2 00 8283.57 S 5216.22 E Top C1 00 8320.71 S 5238.25 E Top B Shale 00 8519.66 S 5356.26 E TD - Csg Pt RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 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 6168.42 4341.00 2463.67S 1763.95E 9 5/8 Casing 0.00 0.00 0.00N 0.00E 12513.58 6298.00 7654.90S 4843.30E 7 Casing 0.00 0.00 0.00N 0.00E 13570.57 6624.00 8519.66S 5356.26E TD Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1D-39 7-Dec-00 565851.000,5951072.000,0.0000 6471.00 8113.80S 5115.51E 12-Sep-2000 Phillips Alaska, Inc. Pad ID 39 slot #39 Kuparuk River Unit North Slope, Alaska DEc £ I Alaska Oil & Gas Cons Anchorage' C°mn~ission PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 39 Version #1 Our ref : prop2176 License : Date printed : 18-Dec-2000 Date created : 15-Apr-1997 Last revised : 18-Dec-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.172,w149 30 31.181 Slot Grid coordinates are N 5959143.175, E 560670.189 Slot local coordinates are 523.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Pad 1D,39 Kuparuk River Unit,North Slope, Alsi' Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C 0 0 R ANGULAR DINATES PROPOSAL LISTING Page 1 Your ref : 39 Version #1 Last revised : 18~D~ 900 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 300.00 0.00 0.00 300.00 0.00 N 0.00 E 0.00 1.43 1.43 0.77 N/A 400.00 1.50 284.00 399.99 0.32 N 1.27 W -0.95 2.11 1.91 1.03 14.00 500.00 3.00 284.00 499.91 1.27 N 5.08 W -3.78 2.99 2.39 1.29 14.00 600.00 4.50 284.00 599.69 2.85 N 11.43 W -8.50 3.94 2.87 1.56 14.00 700.00 3.00 284.00 699.47 4.43 N 17.77 W -13.23 4.91 800.00 1.50 284.00 799.39 5.38 N 21.58 W -16.06 5.90 900.00 0.00 284.00 899.38 5.70 N 22.85 W -17.01 6.22 1000.00 0.00 284.00 999.38 5.70 N 22.85 W -17.01 6.56 1417.62 0.00 284.00 1417.00 5.70 N 22.85 W -17.01 8.15 1500.00 0.00 284.00 1499.38 5.70 N 22.85 W -17.01 8.46 1700.00 0.00 284.00 1699.38 5.70 N 22.85 W -17.01 9.28 1800.00 2.00 105.00 1799.36 5.25 N 21.16 W -15.72 9.32 1900.00 4.00 105.00 1899.22 3.89 N 16.11 W -11.88 9.47 2000.00 6.00 105.00 1998.84 1.64 N 7.69 W -5.49 9.72 2100.00 8.00 105.00 2098.08 1.52 S 4.08 E 3.46 10.07 2200.00 10.00 105.00 2196.85 5.57 S 19.19 E 14.94 10.51 2300.00 12.55 113.13 2294.92 12.08 S 37.57 E 30.26 11.02 2400.00 15.26 118.49 2391.98 22.63 S 59.14 E 50.69 11.59 2500.00 18.07 122.24 2487.77 37.19 S 83.83 E 76.16 12.21 3.35 1.82 3.83 2.08 4.31 2.34 4.78 2.59 6.78 3.67 7.17 3.88 8.12 4.39 8.60 4.65 9.08 4.92 9.55 5.18 10.03 5.45 10.51 5.73 11.00 6.03 11.50 6.34 12.02 6.67 , .oo 14.00 14.00 14.00 14 oo 13:75 13.33 12.51 ~.~1 3~.1~ 31.~0 31.7~ 2600.00 20.92 125.00 2582.03 55.70 S 111.58 E 106.63 12.88 12.57 7.02 32.59 2700.00 23.26 129.99 2674.69 78.64 S 141.34 E 141.90 13.57 13.14 7.41 33.97 2800.00 25.74 134.09 2765.69 106.45 S 172.07 E 181.81 14.27 13.74 7.82 35.34 2900.00 28.31 137.51 2854.77 139.04 S 203.69 E 226.25 15.00 14.39 8.26 36.47 3000.00 30.95 140.39 2941.69 176.34 S 236.10 E 275.09 15.73 15.08 8.74 37.15 3100.00 33.64 142.86 3026.22 218.24 S 269.22 E 328.20 16.46 15.83 9.26 37.08 3160.38 35.29 144.19 3076.00 245.72 S 289.53 E 362.27 16.90 16.31 9.60 36.14 3200.00 36.38 145.00 3108.12 264.63 S 302.97 E 385.43 17.19 16.63 9.82 35.53 3287.37 39.00 145.00 3177.25 308.38 S 333.60 E 438.78 17.83 17.39 10.33 31.10 3387.37 42.00 145.00 3253.29 361.57 S 370.85 E 503.64 18.61 18.31 10.97 13.28 3487.37 45.00 145.00 3325.82 417.95 S 410.33 E 572.39 19.57 19.14 11.64 342.10 3587.37 48.00 145.00 3394.64 477.37 S 451.93 E 644.83 20.76 19.86 12.36 330.93 3687.37 51.00 145.00 3459.58 539.65 S 495.54 E 720.78 22.11 20.53 13.12 327.24 3787.37 54.00 145.00 3520.45 604.63 S 541.04 E 800.01 23.62 21.18 13.91 325.65 3887.37 57.00 145.00 3577.08 672.13 S 588.30 E 882.32 25.29 21.80 14.75 324.86 3987.37 60.00 145.00 3629.33 741.96 S 637.20 E 967.47 27.11 22.39 15.61 324.44 4087.37 63.00 145.00 3677.04 813.94 S 687.60 E 1055.24 29.11 22.96 16.52 324.21 4153.42 64.98 145.00 3706.00 862.57 S 721.65 E 1114.53 30.53 23.32 17.13 324.13 4187.37 66.00 145.00 3720.08 887.87 S 739.37 E 1145.38 31.27 23.50 17.45 324.08 4287.37 69.00 145.00 3758.35 963.54 S 792.35 E 1237.65 33.58 24.02 18.41 324.02 4387.37 72.00 145.00 3791.73 1040.75 S 846.41 E 1331.80 36.04 24.50 19.39 324.00 4388.70 72.04 145.00 3792.14 1041.79 S 847.14 E 1333.06 36.07 24.51 19.41 324.00 4500.00 72.04 145.00 3826.46 1128.52 S 907.87 E 1438.81 38.86 25.04 20.51 324.00 5000.00 72.04 145.00 3980.63 1518.13 S 1180.68 E 1913.89 51.86 27.39 25.46 324.13 5200.00 72.04 145.00 4042.30 1673.98 S 1289.81 E 2103.92 57.19 28.32 27.43 324.18 5300.00 72.03 148.15 4073.16 1753.36 S 1342.20 E 2199.01 59.64 28.78 28.42 324.36 5337.12 72.04 149.32 4084.61 1783.54 S 1360.52 E 2234.31 60.53 28.95 28.78 324.44 5500.00 72.04 149.32 4134.84 1916.80 S 1439.57 E 2389.20 64.42 29.69 30.38 324.76 5519.96 72.04 149.32 4141.00 1933.14 S 1449.25 E 2408.18 64.90 29.78 30.58 324.79 6000.00 72.04 149.32 4289.05 2325.87 S 1682.22 E 2864.65 76.44 31.94 35.29 325.52 Ail data is in feet unless otherwise stated. Coordinates from slot #39 and TVD from est.RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10063.50 on azimuth 147.84 degrees from wellhead. Vertical section is from wellhead on azimuth 147.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PhilliDs Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1D,39 Your ref : 39 Version #1 Kuparuk River Unit,North SloDe, Alas~ Last revised : 18-De~ 90 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C O 0 R D I N A T E S Sect Major Minor Vert. Azi. 6168.42 72.04 149.32 4341.00 2463.67 S 1763.95 E 3024.80 80.51 32.69 36.94 325.71 6500.00 72.04 149.32 4443.27 2734.94 S 1924.87 E 3340.10 88.54 34.16 40.18 326.07 6894.69 72.04 149.32 4565.00 3057.86 S 2116.42 E 3715.41 98.13 35.89 44.04 326.39 7000.00 72.04 149.32 4597.48 3144.01 S 2167.52 E 3815.55 100.69 36.35 45.07 326.47 7500.00 72.04 149.32 4751.69 3553.08 S 2410.18 E 4291.00 112.88 38.53 49.96 326.79 8000.00 72.04 149.32 4905.90 3962.15 S 2652.83 E 4766.45 125.09 40.69 54.84 327.04 8500.00 72.04 149.32 5060.11 4371.22 S 2895.48 E 5241.90 137.33 42.83 59.71 327.25 9000.00 72.04 149.32 5214.33 4780.29 S 3138.14 E 5717.35 149.58 44.96 64.59 327.42 9500.00 72.04 149.32 5368.54 5189.36 S 3380.79 E 6192.80 161.83 47.07 69.47 327.56 9961.90 72.04 149.32 5511.00 5567.26 S 3604.95 E 6632.02 173.17 49.02 73.97 327.68 10000.00 72.04 149.32 5522.75 5598.43 S 3623.44 E 6668.24 174.10 49.18 74.34 327.69 10500.00 72.04 149.32 5676.96 6007.50 S 3866.09 E 7143.69 186.38 51.28 79.21 327.80 10798.41 72.04 149.32 5769.00 6251.65 S 4010.92 E 7427.45 193.71 52.52 82.12 327.85 11000.00 72.04 149.32 5831.17 6416.57 S 4108.75 E 7619.14 198.66 53.37 84.08 327.89 11500.00 72.04 149.32 5985.39 6825.64 S 4351.40 E 8094.59 210.94 55.45 88.95 327.98 11803.52 72.04 149.32 6079.00 7073.97 S 4498.70 E 8383.21 218.40 56.71 91.91 328.02 12000.00 72.04 149.32 6139.60 7234.71 S 4594.05 E 8570.04 223.23 57.52 93.82 328.05 12286.62 72.04 149.32 6228.00 7469.21 S 4733.15 E 8842.59 230.28 58.71 96.61 328.09 12500.00 72.04 149.32 6293.81 7643.78 S 4836.71 E 9045.49 235.52 59.60 98.69 328.12 12513.58 72.04 149.32 6298.00 7654.90 S 4843.30 E 9058.41 235.85 59.65 98.82 328.12 12795.66 72.04 149.32 6385.00 7885.68 S 4980.19 E 9326.64 242.79 60.82 101.57 328.15 13000.00 72.04 149.32 6448.02 8052.85 S 5079.36 E 9520.94 247.82 61.66 103.56 328.18 13074.50 72.04 149.32 6471.00 8113.80 S 5115.51 E 9591.78 249.65 61.97 104.29 328.18 13155.56 72.04 149.32 6496.00 8180.12 S 5154.85 E 9668.86 251.64 62.30 105.08 328.19 13217.16 72.04 149.32 6515.00 8230.52 S 5184.75 E 9727.44 253.16 62.56 105.68 328.20 13282.01 72.04 149.32 6535.00 8283.57 S 5216.22 E 9789.10 254.75 62.82 106.31 328.21 13327.40 72.04 149.32 6549.00 8320.71 S 5238.25 E 9832.26 255.87 63.01 106.75 328.21 13500.00 72.04 149.32 6602.23 8461.92 S 5322.01 E 9996.39 260.11 63.72 108.43 328.23 13570.57 72.04 149.32 6624.00 8519.66 S 5356.26 E 10063.50 261.85 64.01 109.12 328.24 RECEIVED DEC 1 Alaska Oil & Gas Cons. Commission Anchorage Ail data is in feet unless otherwise stated. Coordinates from slot #39 and TVD from est. RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10063.50 on azimuth 147.84 degrees from wellhead. Vertical section is from wellhead on azimuth 147.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. ~ %" Pad 1D,39 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING ~ ~e 3 Your ref : 39 Version #1 Last revised : 18-Dec-2000 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 13571 M~rD + IFR (Alaska) - Corrected Dar User specified 261.85 64.01 109.12 1 Ellipse dimensions are half axis. 2 Casing dimensions are not included. 3 Ellipses are calculated on 2.58 standard deviations. 4 Uncertainty calculations start at drill depth zero. 5 Surface position uncertainty is not included. 6 Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300 00 0.00 N 0.00 E Begin D'nl Nudge 600.00 1417.62 1700.00 3160.38 4153.42 4388 70 5200 00 5337 12 5519 96 6168 42 6894 69 9961 90 10798 41 11803 52 12286 62 12513 58 12795 66 13074 50 13155 56 13217 16 13282 01 13327 40 13570 57 599 1417 1699 3076 3706 3792 4042 4084 4141 4341 4565 5511 5769 6079 6228 6298 6385 6471 6496 6515 6535 6549 6624 69 2.85 N 11 00 5.70 N 22 38 5.70 N 22 00 245.72 S 289 00 862.57 S 721 14 1041.79 S 847 30 1673.98 S 1289 61 1783.54 S 1360 00 1933.14 S 1449 00 2463.67 S 1763 00 3057.86 S 2116 00 5567.26 S 3604 00 6251.65 S 4010 00 7073.97 S 4498 00 7469.21 S 4733 00 7654.90 S 4843 00 7885.68 S 4980 00 8113.80 S 5115 00 8180.12 S 5154 00 8230.52 S 5184 00 8283.57 S 5216 00 8320.71 S 5238 00 8519.66 S 5356 43 W Drop To Vert 85 W Base Permafrost 85 W KOP 53 E Top Ugnu 65 E Top W Sak 14 E EOC 81 E Beg Right Turn 52 E E0C 25 E Base W Sak 95 E 9 5/8 Csg Pt 42 E C80 95 E C50 92 E C40 70 E C30 15 E C20 30 E 7 Csg/Base HRZ 19 E K-1 51 E 1D-39 7-Dec-00 85 E Top C3 75 E Top C2 22 E Top C1 25 E Top B Shale 26 E TD - Csg Pt RECEIVED 2 1 Alaska Oil & Gas Cons. Commission Anchorage 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 6168.42 4341.00 2463.67S 1763.95E 9 5/8 Casing 0.00 0.00 0.00N 0.00E 12513.58 6298.00 7654.90S 4843.30E 7 Casing 0.00 0.00 0.00N 0.00E 13570.57 6624.00 8519.66S 5356.26E TD Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1D-39 7-Dec-00 565851.000,5951072.000,0.0000 6471.00 8113.80S 5115.51E 12-Sep-2000 Phillips Alaska, Inc. Pad iD 39 slot #39 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 39 Version #1 Our ref : prop2176 License : Date printed : 18-Dec-2000 Date created : 15-Apr-1997 Last revised : 18-Dec-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.172,w149 30 31.181 Slot Grid coordinates are N 5959143.175, E 560670.189 Slot local coordinates are 523.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED DEC 1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1D,39 Kuparuk River Unit,North Slope, Ala~' \ Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 0.00 0.00 0.00 0.00 0.00N 0.00E 300.00 0.00 0.00 300.00 0.00N 0.00E 400.00 1.50 284.00 399.99 0.32N 1.27W 500.00 3.00 284.00 499.91 1.27N 5.08W 600.00 4.50 284.00 599.69 2.85N 11.43W 700.00 3.00 284.00 699.47 4.43N 17.77W 800.00 1.50 284.00 799.39 5.38N 21.58W 900.00 0.00 284.00 899.38 5.70N 22.85W 1000.00 0.00 284.00 999.38 5.70N 22.85W 1417.62 0.00 284.00 1417.00 5.70N 22.85W 1500.00 0.00 284.00 1499.38 5.70N 22.85W 1700.00 0.00 284.00 1699.38 5.70N 22.85W 1800.00 2.00 105.00 1799.36 5.25N 21.16W 1900.00 4.00 105.00 1899.22 3.89N 16.11W 2000.00 6.00 105.00 1998.84 1.64N 7.69W 2100.00 8.00 105.00 2098.08 1.52S 4.08E 2200.00 10.00 105.00 2196.85 5.57S 19.19E 2300.00 12.55 113.13 2294.92 12.08S 37.57E 2400.00 15.26 118.49 2391.98 22.63S 59.14E 2500.00 18.07 122.24 2487.77 37.19S 83.83E 2600.00 20.92 125.00 2582.03 55.70S 111.58E 2700.00 23.26 129.99 2674.69 78.64S 141.34E 2800.00 25.74 134.09 2765.69 106.45S 172.07E 2900.00 28.31 137.51 2854.77 139.04S 203.69E 3000.00 30.95 140.39 2941.69 176.34S 236.10E 3100.00 33.64 142.86 3026.22 218.24S 269.22E 3160.38 35.29 144.19 3076.00 245.72S 289.53E 3200.00 36.38 145.00 3108.12 264.63S 302.97E 3287.37 39.00 145.00 3177.25 308.38S 333.60E 3387.37 42.00 145.00 3253.29 361.57S 370.85E 3487.37 45.00 145.00 3325.82 417.95S 410.33E 3587.37 48.00 145.00 3394.64 477.37S 451.93E 3687.37 51.00 145.00 3459.58 539.65S 495.54E 3787.37 54.00 145.00 3520.45 604.63S 541.04E 3887.37 57.00 145.00 3577.08 672.13S 588.30E 3987.37 60.00 145.00 3629.33 741.96S 637.20E 4087.37 63.00 145.00 3677.04 813.94S 687.60E 4153.42 64.98 145.00 3706.00 862.57S 721.65E 4187.37 66.00 145.00 3720.08 887.87S 739.37E 4287.37 69.00 145.00 3758.35 963.54S 792.35E PROPOSAL LISTING Page 1 Your ref : 39 Version #1 Last revised : 18-~ 000 GRID C 00 R D S GEOGRAPHIC Easting Northing C 00 R D I N A T E S 560670.19 5959143.18 n70 17 560670.19 5959143.18 n70 17 560668.92 5959143.48 n70 17 560665.10 5959144.40 n70 17 560658.74 5959145.93 n70 17 560652.38 5959147.46 n70 17 560648.57 5959148.38 nT0 17 560647.30 5959148.69 n70 17 560647.30 5959148.69 n70 17 560647.30 5959148.69 n70 17 560647.30 5959148.69 n70 17 560647.30 5959148.69 n70 17 560648.98 5959148.25 n70 17 560654.05 5959146.93 n70 17 560662.49 5959144.75 nT0 17 56.17 w149 30 31.18 56.17 w149 30 31.18 56.18 w149 30 31.22 56.18 w149 30 31.33 56.20 w149 30 31.51 560674.28 5959141.69 n70 17 560689.42 5959137.76 n70 17 560707.85 5959131.40 n70 17 560729.50 5959121.02 n70 17 560754.31 5959106.67 n70 17 56.22 w149 30 31.70 56.23 w149 30 31.81 56.23 w149 30 31.85 56.23 w149 30 31.85 56.23 w149 30 31.85 560782.20 5959088.39 nT0 17 560812.15 5959065.69 nT0 17 560843.10 5959038.14 n70 17 560874.98 5959005.81 n70 17 560907.69 5958968.77 n70 17 56.23 w149 30 31.85 56.23 w149 30 31.85 56.22 w149 30 31.80 56.21 w149 30 31.65 56.19 w149 30 31.40 56.16 w149 30 31.06 56.12 w149 30 30.62 56.05 w149 30 30.09 55.95 w149 30 29.46 55.81 w149 30 28.74 55.62 w149 30 27.93 55.40 w149 30 27.06 55.13 w149 30 26.16 54.80 w149 30 25.24 54.44 w149 30 24.30 560941.15 5958927.15 n70 17 54.03 w149 30 23.33 560961.68 5958899.84 n70 17 53.76 w149 30 22.74 560975.27 5958881.04 n70 17 53.57 w149 30 22.35 561006.25 5958837.55 n70 17 53.14 w149 30 21.46 561043.93 5958784.66 n70 17 52.62 w149 30 20.37 561083.86 5958728.61 n70 17 52.06 561125.94 5958669.54 nT0 17 51.48 561170.05 5958607.63 n70 17 50.86 561216.07 5958543.02 n70 17 50.23 561263.88 5958475.92 n70 17 49.56 561313.34 5958406.49 n70 17 48.88 561364.32 5958334.92 n70 17 48.17 561398.76 5958286.59 n70 17 47.69 561416.68 5958261.43 n70 17 47.44 561470.27 5958186.20 n70 17 46.70 4387.37 72.00 145.00 3791.73 1040.75S 846.41E 561524.95 5958109.44 n70 17 4388.70 72.04 145.00 3792.14 1041.79S 847.14E 561525.69 5958108.41 n70 17 4500.00 72.04 145.00 3826.46 1128.52S 907.87E 561587.11 5958022.18 n70 17 5000.00 72.04 145.00 3980.63 1518.13S 1180.68E 561863.06 5957634.83 n70 17 5200.00 72.04 145.00 4042.30 1673.98S 1289.81E 561973.44 5957479.89 nT0 17 w149 30 19.22 w149 30 18.01 w149 30 16.74 w149 30 15.41 w149 30 14.03 5300.00 72.03 148.15 4073.16 1753.36S 1342.20E 5337.12 72.04 149.32 4084.61 1783.54S 1360.52E 5500.00 72.04 149.32 4134.84 1916.80S 1439.57E 5519.96 72.04 149.32 4141.00 1933.14S 1449.25E 6000.00 72.04 149.32 4289.05 2325.87S 1682.22E w149 30 12.61 w149 30 11.14 w149 30 10.14 w149 30 09.63 w149 30 08.08 45.94 w149 30 06.51 45.93 w149 30 06.49 45.07 w149 30 04.72 41.24 w149 29 56.77 39.71 w149 29 53.59 562026.46 5957400.95 n70 17 38.93 w149 29 52.06 562045.03 5957370.92 n70 17 38.63 w149 29 51.53 562125.15 5957238.32 n70 17 37.32 w149 29 49.22 562134.97 5957222.07 n70 17 37.16 w149 29 48.94 562371.10 5956831.28 n70 17 33.30 w149 29 42.15 RECEIVED DEC 2, 1 .nn0 Alaska Oil & Gas Cons. Commission Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot ~39 and TVD from est.RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10063.50 on azimuth 147.84 degrees from wellhead. Total Dogleg for wellpath is 88.77 degrees. Vertical section is from wellhead on azimuth 147.77 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. ~ Pad 1D,39 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 6168.42 72.04 149.32 4341.00 6500.00 72.04 149.32 4443.27 6894.69 72.04 149.32 4565.00 7000.00 72.04 149.32 4597.48 7500.00 72.04 149.32 4751.69 RECTANGULAR COORDINATES PROPOSAL LISTING ~' ,e 2 Your ref : 39 Version #1 Last revised : 18-Dec-2000 8000.00 72.04 149.32 4905.90 8500.00 72.04 149.32 5060.11 9000.00 72.04 149.32 5214.33 9500.00 72.04 149.32 5368.54 9961.90 72.04 149.32 5511.00 GRID C O O R D S GEOGRAPHIC Easting Northing C 0 0 R D I N A T E S 10000.00 72.04 149.32 5522.75 10500.00 72.04 149.32 5676.96 10798.41 72.04 149.32 5769.00 11000.00 72.04 149.32 5831.17 11500.00 72.04 149.32 5985.39 2463.67S 1763.95E 562453.94 5956694.17 n70 17 31.94 w149 29 39.77 2734.94S 1924.87E 562617.04 5956424.23 n70 17 29.27 w149 29 35.08 3057.86S 2116.42E 562811.19 5956102.91 n70 17 26.10 w149 29 29.50 3144.01S 2167.52E 562862.99 5956017.19 n70 17 25.25 w149 29 28.02 3553.08S 2410.18E 563108.94 5955610.14 nT0 17 21.23 w149 29 20.95 11803.52 72.04 149.32 6079.00 12000.00 72.04 149.32 6139.60 12286.62 72.04 149.32 6228.00 12500.00 72.04 149.32 6293.81 12513.58 72.04 149.32 6298.00 3962.15S 2652.83E 563354.88 5955203.10 n70 17 17.20 w149 29 13.88 4371.22S 2895.48E 563600.83 5954796.05 n70 17 13.18 w149 29 06.82 4780.29S 3138.14E 563846.78 5954389.01 n70 17 09.15 w149 28 59.75 5189.36S 3380.79E 564092.73 5953981.96 n70 17 05.13 w149 28 52.69 5567.26S 3604.95E 564319.93 5953605.93 n70 17 01.41 w149 28 46.16 12795.66 72.04 149.32 6385.00 13000.00 72.04 149.32 6448.02 13074.50 72.04 149.32 6471.00 13155.56 72.04 149.32 6496.00 13217.16 72.04 149.32 6515.00 5598.43S 3623.44E 6007.50S 3866.09E 6251.65S 4010.92E 6416.57S 4108.75E 6825.64S 4351.40E 13282.01 72.04 149.32 6535.00 13327.40 72.04 149.32 6549.00 13500.00 72.04 149.32 6602.23 13570.57 72.04 149.32 6624.00 7073.97S 4498.70E 7234.71S 4594.05E 7469.21S 4733.15E 7643.78S 4836.71E 7654.90S 4843.30E 564338.67 5953574.92 n70 17 01.11 w149 28 45.62 564584.62 5953167.87 n70 16 57.08 w149 28 38.56 564731.41 5952924.94 n70 16 54.68 w149 28 34.34 564830.57 5952760.83 n70 16 53.06 w149 28 31.50 565076.51 5952353.78 n70 16 49.03 w149 28 24.43 565225.81 5952106.69 n70 16 565322.46 5951946.74 n70 16 565463.45 5951713.40 n70 16 565568.41 5951539.69 n70 16 565575.09 5951528.64 n70 16 46.59 w149 28 20.15 45.01 w149 28 17.37 42.70 w149 28 13.33 40.98 w149 28 10.31 40.87 w149 28 10.12 7885.68S 4980.19E 565713.84 5951299.00 n70 16 38.60 w149 28 06.14 8052.85S 5079.36E 565814.35 5951132.65 n70 16 36.96 w149 28 03.26 8113.80S 5115.51E 565851.00 5951072.00 n70 16 36.36 w149 28 02.20 8180.12S 5154.85E 565890.87 5951006.01 n70 16 35.71 w149 28 01.06 8230.52S 5184.75E 565921.17 5950955.86 n70 16 35.21 w149 28 00.19 8283.57S 5216.22E 8320.71S 5238.25E 8461.92S 5322.01E 8519.66S 5356.26E 565953.07 5950903.07 n70 16 34.69 565975.40 5950866.12 n70 16 34.32 566060.30 5950725.60 n70 16 32.93 566095.01 5950668.15 n70 16 32.37 w149 27 59.27 w149 27 58.63 w149 27 56.20 w149 27 55.20 RECEIVED DEC 2, i 2nn. q Alaska C~I & Gas Cons, Commission Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #39 and TVD from est.RKB(Nabors 16E) (106.00 Ft above mean sea level). Bottom hole distance is 10063.50 on azimuth 147.84 degrees from wellhead. Total Dogleg for wellpath is 88.77 degrees. Vertical section is from wellhead on azimuth 147.77 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1D,39 ~ Kuparuk River Unit,North Slope, Ala PROPOSAL LISTING .Page 3 Your ref : 39 ~ on #1 Last revised 18-D~ 000 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 300.00 300 00 0 00N 0.00E Begin D'nl Nudge 600.00 599 1417.62 1417 1700.00 1699 3160.38 3076 4153.42 3706 4388.70 3792 5200.00 4042 5337.12 4084 5519.96 4141 6168.42 4341 6894.69 4565 9961.90 5511 10798.41 5769 11803.52 6079 12286.62 6228 12513.58 6298 12795.66 6385 13074.50 6471 13155.56 6496 13217.16 6515 13282.01 6535 13327.40 6549 13570.57 6624 69 2 00 5 38 5 00 245 00 862 14 1041 30 1673 61 1783 00 1933 00 2463 00 3057 00 5567 00 6251 00 7073 00 7469 00 7654 00 7885 00 8113 00 8180 00 8230 00 8283 00 8320 00 8519 85N 11.43W Drop To Vert 70N 22.85W Base Permafrost 70N 22.85W KOP 72S 289.53E Top Ugnu 57S 721.65E Top W Sak 79S 847.14E EOC 98S 1289.81E Beg Right Turn 54S 1360.52E EOC 14S 1449.25E Base W Sak 67S 1763.95E 9 5/8 Csg Pt 86S 2116.42E C80 26S 3604.95E C50 65S 4010.92E C40 97S 4498.70E C30 21S 4733.15E C20 90S 4843.30E 7 Csg/Base HRZ 68S 4980.19E K-1 80S 5115.51E 1D-39 7-Dec-00 12S 5154.85E Top C3 52S 5184.75E Top C2 57S 5216.22E Top C1 71S 5238.25E Top B Shale 66S 5356.26E TD - Csg 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 6168.42 4341.00 2463.67S 1763.95E 9 5/8 Casing 0.00 0.00 0.00N 0.00E 12513.58 6298.00 7654.90S 4843.30E 7 Casing 0.00 0.00 0.00N 0.00E 13570.57 6624.00 8519.66S 5356.26E TD Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1D-39 7-Dec-00 565851.000,5951072.000,0.0000 6471.00 8113.80S 5115.51E 12-Sep-2000 2, 1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad ID 39 slot #39 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 39 Version #1 Our ref : prop2176 License : Date printed : 18-Dec-2000 Date created : 15-Apr-1997 Last revised : 18-Dec-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 56.172,w149 30 31.181 Slot Grid coordinates are N 5959143.175, E 560670.189 Slot local coordinates are 523.00 S 421.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath Last revised PMSS IFR <O-16053'>,,34,Pad ID 23-0ct-2000 PGMS <0-8850'> 28-May-81,,MP 1 17-ii-ii,Pad 1D 23-Apr-1999 PMSS IFR <O-12044'>,,30,Pad ID PGMS <0 - 6400'>,,WS-8,Pad ID PMSS <0 - 7340'>,,10,Pad 1D PMSS <0-5142'>,,l15,Pad iD PMSS <0 - 6270'>,,l14,Pad 1D PMSS <293 - 6866'>,,l13,Pad iD PMSS <294 - 8250'>,,l12,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0-8702'>,,14,Pad iD PMSS <0-9250'>,,12,Pad iD PMSS<0-7045'>,,lll,Pad iD PMSS <0-4850'>,,109,Pad 1D PMSS <0 - 7150'>,,108,Pad iD PMSS <291 - 5795'>,,125,Pad 1D PMSS <0-5047'>,,124,Pad ID PMSS <290-6245'>,,l16,Pad 1D GSS <0-175'>,,l16,Pad iD PMSS <287-6055'>,,123,Pad iD GSS <0-173'>,,123,Pad iD PMSS <0 - 5445'>,,122,Pad 1D PMSS <0 - 6580'>,,128,Pad iD PMSS <0 - 7432'>,,127,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0-4530'>,,120,Pad 1D PGMS <0-8070'>,,3,Pad 1D PMSS <0-4515'>,,l19,Pad 1D PMSS <0-5462'>,,129,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PGMS <0-9783'>,,2,Pad iD PMSS <381-6092'>,,105,Pad iD PGMS <0-8930°>,,5,Pad 1D PMSS <0-4590'>,,l18,Pad 1D PMSS <0-11234'>,,il,Pad 1D PMSS <0-4414'>,,121,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <0-5205'>,,l17,Pad 1D PMSS <256 - 5973'>,,l10,Pad 1D PMSS <377 - 6224'>,,134,Pad iD PMSS <5155'- 5905'>,,l10A, Pad 1D PMSS <1957-5265'>,,133,Pad 1D Closest approach with 3-D Minimum Distance method 2-0ct-2000 27-Apr-2000 28-Apr-1998 2-Jun-1998 2-Sep-1998 22-Sep-1998 21-Sep-1998 29-Apr-1998 6-0ct-1999 21-Jan-2000 3-Sep-1998 2-Jun-1998 28-0ct-1998 19-Aug-1998 2-Jun-1998 17-Sep-1998 8-Sep-1998 13-Sep-1998 4-Sep-1998 29-Aug-1998 17-Aug-1998 6-Ju1-1998 1-Ju1-1998 2-Jun-1998 13-Aug-1998 2-Jun-1998 2-Jun-1998 2-Jun-1998 23-Ju1-1998 4-Aug-1992 2-Jun-1998 13-Nov-1997 2-Jun-1998 30-Dec-1999 2-Jun-1998 6-Nov-1997 2-Jun-1998 24-Apr-2000 3-Aug-1998 17-May-2000 2-Jun-1998 Distance 75 9 7175 6 132 5 170 0 89 5 494 4 496 6 522 5 536 4 417 8 749 6 739 6 578 6 607 7 622 1 291 5 299 6 480 4 480 4 357 6 358 5 371 8 250 2 273 0 284 5 363.3 537.5 404.9 222.4 198.4 206.0 660.1 678.9 270.2 436.3 150.6 331.2 173.7 466.5 593.4 180.1 593.4 182.1 M.D. 260 0 5720 0 614 3 1725 0 980 0 160 0 742 9 100 0 100 0 900 0 814 3 1380 0 485 7 100 0 100 0 642 9 814.3 100.0 100.0 280.0 160.0 100.0 785.7 100.0 100.0 1600.0 885.7 714.3 200.0 700.0 100.0 642.9 328.6 1725.0 871.4 871.4 2175.0 671.4 100.0 100.0 260.0 100.0 685.7 Diverging from M.D. 13570 6280 614 1725 4042 160 742 100 100 9OO 814 1380 485 100 100 642 814 12540 100 280 160 4O0 785 100. 100. 1600. 885. 714. 200. 700. 100. 642. 328. 1725. 871.4 871.4 2175.0 671.4 385.7 100.0 6100.0 100.0 4680.0 PMSS <0-3252'>,,133PB1,Pad iD PMSS <0-5126'>,,106,Pad 1D PMSS (IFR) <0-8660'>,, 42, Pad PMSS IFR <0-11660 >, 36,Pad 107 PMSS <0 - 6550'>,,36,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <4674'-5639'>,,125A,Pad 1D 37 GSS <0 - 503'>,,101,Pad 1D 37 PMSS <567 - 6100'>,,lO1,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8365'>,,1,Pad 1D PMSS <3682-7663'>,,140L1,Pad 1D PMSS <5493-8117'>,,140,Pad 1D PMSS IFR <548-4120'>,,140,Pad 1D PMSS <4168-6156'>,,140PB1,Pad 1D 136 PMSS <519 - 5680'>,,136,Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PMSS <O-1288'>,,138PB1,Pad 1D PMSS <0-6543'>,,138,Pad 1D 139 <PMSS 515 - 4838'>,,139,Pad 1D 141 PMSS <0-9550'>,,141,Pad 1D 141L1 PMSS<5475'-9480'>,,141L1,Pad 1D PMSS IFR <0-14324'>,,38,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <0-14138'>,,32,Pad 1D PGMS <0-8610'>,,6,Pad 1D L1 PMSS <4338-7400'> Sperry,,102L1,Pad 1D PMSS <0-5354'>,,102PB1,Pad 1D PMSS <5181-6454'>,,102PB2,Pad 1D PMSS <6143-6767'>,,102PB3,Pad 1D PMSS <6527-7378'>,,102,Pad 1D PMSS IFR <0-12225'>,,40,Pad 1D PMSS IFR<7060 - lll10'>,,40A, Pad iD 21-Sep-2000 2-Jun-1998 6-Nov-2000 2-Oct-2000 29-Nov-2000 6-Aug-1998 24-Apr-2000 28-Nov-2000 29-Nov-2000 4-Aug-1992 10-Dec-1997 13-Nov-2000 13-Nov-2000 13-Nov-2000 13-Nov-2000 5-Jun-2000 2-Jun-2000 18-May-2000 18-May-2000 18-May-2000 6-Sep-2000 26-Sep-2000 2-Oct-2000 2-Jun-1998 4-Dec-2000 13-Nov-1997 27-Jul-2000 28-Jul-2000 27-Jul-2000 27-Jul-2000 28-Jul-2000 13-Dec-2000 18-Dec-2000 182 1 642 3 43 6 45 7 629 7 199 0 291.4 735.4 735.4 423.3 769.4 638.4 638.4 638.4 638 4 164 7 201 5 208 9 203 7 227 2 427 6 1450 3 14.4 39.2 106.0 59.5 109.4 109.4 109.4 109.4 109.4 13.5 13.5 685 7 920 0 240 0 428 6 814 3 100 0 642 9 342 9 342.9 885.7 1000.0 1737.5 1737.5 1737.5 1737.5 1120.0 771 4 814 3 757 1 120 0 1420 0 8240 0 485 7 1420 0 120.0 1875.0 2733.3 2733.3 2733.3 2733.3 2733.3 342.9 342.9 685 7 920 0 0 {' o 814 3 414 3 642.9 342.9 4388.7 885.7 1000.0 1737.5 1737.5 1737.5 1737 5 5680 0 6080 0 814 3 7380 0 4400 0 8020 0 8240 0 485.7 1420.0 13340.0 4900.0 4780.0 4980.0 4980.0 4980.0 4980.0 342.9 342.9 Alaska 0tl & Gas Cons. Anchorage Cornrniss/on PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY December 20, 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 1 D-39 Surface Location: 523' FNL, 421' FEL, Sec 14, T11N, R10E, UM Target Location: 1921' FSL, 582' FEL Sec. 25, T11 N, R10E, UM Bottom Hole Location: 1516' FSL, 351' FEL Sec. 25, T11N, R10E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. submits this Application for Permit to Drill the development well KRU 1D- 39 Nabors Rig 16e will drill and complete this well as an injector. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1D, or hauled to an approved Prudhoe or GKA Class II disposal well. 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 Bill Raatz, Geologist 263-4952 (20 AAC 25.071) If you have questions or require additional information, please contact Todd Mushovic at 265- 6974 or me at 265-6434 in our Anchorage office. Sinc!~rely, -------'-r----, . ,James Trantham Drilling Engineering Supervisor Attachments cc: KRU 1D-39 Well File RECEIVED DEC 2 1 2000 Naska 0it & Gas Cons. Commi~ Anchorage Date: IZ-Zl- oo To: Alaska State Dept of Revenue 300:L Porcupine Street Anchorage, AK Re: Filing fee for Permit to Drill Well # ..... /'~'- ~,,~, . $100.00 check attached. (check # //./iD .,, ) Sharon AIIsup-Drake Engineering Aide (ATO-~.S30) Wells/Drilling Phillips Alaska 700 G Street Anchorage~ AK 9950Z RECEIVED 4reerica~ EXPress , . WELL pERMIT CHECKLIST COMPANY T~.~I'/~ WELL NAME ln-~ FIELD & POOL ~/~L~/~_(~ INI~ CLAS~ ~,.~E~/C_~-~' ,~'~c,)/xV~ GEOL AREA ADMINISTRATION PROGRAM: exp dev redrll serv ~'~ UNIT# .---'~-I~ 1. Permit fee attached. ~_~~~~ . - 2. Lease number approl~fi~t~.~i ~iC~~~)i ~ ~-~] ' ' /~~ ~ ~ Unique well name and number ..................' N N i' v/ wellbore seg ann. disposal para req (~?//.~(._~ ON/OFF SHORE ,.~ DATE 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 drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 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 ................. Ia/~ DATE /z.Zt 21. If a re-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. DOPEs, do they meet regulation ........ ~.(~) .... 26. DOPE press rating appropriate; test to 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 ................. 30. 31. 32. 33. 34. Pe~it can be issued w/o hydrogen sulfide measures ..... Y ~ ~ ,. t ' ~ / c~ ' Data presented on potential overpressure zones~ ...... y~ .,~ /o ~'~ ~, - ~~ ~ ~ -~~ ~~'~ ~/~c~ Seismic analysis of shallow gas zones ............. ~[~ N ~ ~~~~. ~"~-~i/(~ ~. ~~"_ ~~ Seabed condition su~ey (if off-shore) ......... . . ./I~'' Y N ~ ~ ~ ~ ~-~~ ~ ~ ~' - ' Contact name/phone for weekly progress repo~s [explo~ only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... 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. Y N Y N " Y N Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: C3 O Z O Z .-I '1- c:\msoffice\wordian\diana\checklist (rev. 11101//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ,, 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 $ Thu Dec 20 14:36:19 2001 Reel Header Service name ............. LISTPE Date ..................... 01/12/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/12/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. RECEiVeD 0 5 2002 ~aska Oil 8, Gas Cons. Commission .~c~rage Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE 1ST STRING 12.250 2ND STRING 8.500 MWD RUN 3 AK-MM-10023 T. MCGUIRE G. WHITLOCK (IN) 1D-39 500292299700 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 10-DEC-01 MWD RUN 4 AK-MM-10023 P. SMITH G. WHITLOCK 14 lin 10E 523 421 .00 104.55 70.90 CASING SIZE (IN) 20.000 9.625 DRILLERS DEPTH (FT) 120.0 6231.0 3RD STRING 6.125 7.000 12369.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 5. MWD RUN 4 WAS DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL DATED 11/27/01 FROM D.SCHWARTZ (PHILLIPS ALASKA) TO B.BRYANT (SSDS). THIS E-MAIL QUOTES AUTHORIZATION FROM J.HARRISON (PAI). 7. MWD RUNS 3 & 4 REPRESENT WELL 1D-39 WITH API#:50-029-22997-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13545'MD / 6626'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. 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. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 11.0 PPG MUD SALINITY: 500-550 PPM CHLORIDES FORMATION WATER SALINITY: 15000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START RPX 6190 RPS 6190 RPM 6190 RPD 6190 GR 6198 FET 6241 ROP 6241 FCNT 12300 NCNT 12301 NPHI 12301 PEF 12316 RHOB 12364 DRHO 12364 $ BASELINE CURVE FOR SHIFTS: DEPTH 0 0 0 0 5 5 5 5 0 0 0 5 5 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 13497 0 13497 0 13497 0 13497 0 13490 0 13497 0 13544 5 13462 0 13462 0 13462 0 13477 0 13477 0 13477 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 6190.0 12386.5 4 12386.5 13544.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN 68 68 68 68 68 68 68 68 68 68 68 68 68 68 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 DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/CM DRHO MWD G/CM PEF MWD BARN Min 6190 0.21 22 71 1 05 1 31 0 22 0 O5 0 17 24 13 89 35 12818.9 1.63 -0.16 2.69 Max 13544.5 987.07 422.1 2000 2000 2000 2000 111.74 63.03 578.14 30348.8 3.32 0.71 19.25 Mean Nsam 9867.25 14710 151.96 14607 135.08 14584 4.74072 14615 7.32466 14615 12.313 14615 20.5479 14615 1.65957 14512 42.6412 2323 227.437 2324 19653 2323 2.46463 2226 0.0756289 2226 7.13256 2323 First Reading 6190 6241.5 6198.5 6190 6190 6190 6190 6241.5 12301 12300.5 12301 12364.5 12364.5 12316 Last Reading 13544.5 13544.5 13490 13497 13497 13497 13497 13497 13462 13462 13462 13477 13477 13477 First Reading For Entire File .......... 6190 Last Reading For Entire File ........... 13544.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 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 ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX RPS RPD RPM GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 6190 0 6190 0 6190 0 6190 0 6198 5 6241 5 6241 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: 12341 12333 12386 STOP DEPTH 12333 5 12333 5 12333 5 12333 5 0 5 5 TOOL STRING ('TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 29-JAN-01 Insite 65.44 Memory 12385.0 6241.0 12385.0 69.2 74.0 TOOL NUMBER 1816HWRGV6 1816HWRGV6 8.500 6231.0 Water Based 9.90 47.0 8.5 600 4.2 2.700 1.463 6.000 1.700 65.0 125.7 65.0 65.0 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 DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD030 FT/H 4 1 68 MWD030 API 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min 6190 0.21 22 71 1 16 1 31 0 22 0 05 0 17 Max 12386.5 987.07 422.1 2000 2000 595.61 2000 11.59 Mean Nsam 9288.25 12394 169.188 12291 137.57 12286 4.34279 12288 5.54556 12288 6.81114 12288 17.2243 12288 0.781163 12185 First Reading 6190 6241.5 6198.5 6190 6190 6190 6190 6241.5 Last Reading 12386.5 12386.5 12341 12333.5 12333.5 12333.5 12333.5 12333.5 First Reading For Entire File .......... 6190 Last Reading For Entire File ........... 12386.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 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 ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT NPHI NCNT PEF RPD RPX RPM FET RPS GR RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 12300 5 12301 0 12301 0 12316 0 12334 0 12334 0 12334 0 12334 0 12334 0 12341 5 12364 5 12364 5 12387 0 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: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : STOP DEPTH 13462 0 13462 0 13462 0 13477 0 13497 0 13497 0 13497 0 13497 0 13497 0 13490 0 13477 0 13477 0 13544 5 04-FEB-01 Insite 4.15 Memory 13545.0 12385.0 13545.0 69.3 73.5 TOOL NUMBER 1832GR4 1832GR4 1832GR4 1832GR4 6.125 12369.0 LSND 11.00 56.0 8.5 550 3.6 1.700 .877 1.100 1.900 65.0 132.4 65.0 65.0 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 MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HOUR 4 1 68 NPHI MWD040 PU-S 4 1 68 FCNT MWD040 CNTS 4 1 68 NCNT MWD040 CNTS 4 1 68 RHOB MWD040 G/CM 4 1 68 DRHO MWD040 G/CM 4 1 68 PEF MWD040 BARN 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 DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU-S FCNT MWD040 CNTS NCNT MWD040 CNTS RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 BARN Min 12300.5 1.26 37 58 1 O5 1 48 2 18 2 37 0 59 24 13 89 35 12818.9 1.63 -0.16 2.69 Max 13544.5 149.6 284.42 862.64 2000 2000 2000 111.74 63.03 578.14 30348.8 3.32 0.71 19.25 Mean 12922.5 60.5321 121.764 6.84207 16.7195 41.3663 38.0986 6.25924 42.6412 227.437 19653 2.46463 0.0756289 7.13256 Nsam 2489 2316 2298 2327 2327 2327 2327 2327 2323 2324 2323 2226 2226 2323 First Reading 12300.5 12387 12341.5 12334 12334 12334 12334 12334 12301 12300.5 12301 12364.5 12364.5 12316 Last Reading 13544.5 13544.5 13490 13497 13497 13497 13497 13497 13462 13462 13462 13477 13477 13477 First Reading For Entire File .......... 12300.5 Last Reading For Entire File ........... 13544.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/12/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
