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Home My WebLink About179-059 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER 1 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-099/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 179-059/ TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop Kuparuk 1A-09 50-029-20669-00 181152_1A-09_IPROF_27May2022 1A-15 50-029-20711-00 182017_1A-15_iProf_02Jun2022 1A-22 50-029-22127-00 191003_1A-22_RBP-LSL_22June2022 191003_1A-22_SBHPS-RBP_09June2022 1B-101 50-029-23173-00 203133_1B-101_MechCut_24Jun2023 1B-14 50-029-22452-00 194030_1B-14_CHC_15Mar2022 194030_1B-14_RCT Cutter_24Feb2022 194030_1B-14_UPCT Cutter_20Jun2022 194030_1B-14_Whipstock_13Apr2022 19430_1B-14_CHC_21Mar2022 1C-09 50-029-20859-00 182185_1C-09_IPROF_15Jan2023 1C-133 50-029-23013-00 201077_1C-133_RBP_07Apr2022 1C-152 50-029-23548-00 215114_1C-152_IPROF_20Mar2023 1C-15L1 50-029-22932-60 203032_1C-15L1_CHC_04Feb2022 1D-01 50-029-20393-00 179059_1D-01_PPROF_25Jun2023 1of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38308 T38309 T38310 T38312 T38311 T38274 T38276 T38314 T38315 T38316 2/29/2024 1D-01 50-029-20393-00 179059_1D-01_PPROF_25Jun2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:11:35 -09'00' . STATE OF ALASKA ALA OIL AND GAS CONSERVATION COIVSSION WY 2 3 2013 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well j Rug Perforations Perforate { O th Alter Casing I— Pull Tubing (;I . Stimulate - Frac f` Waiver E Time Extension I Change Approved Program EOperat. Shutdow n 1' Stimulate - Other f Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Development r • Exploratory j"°` 179 -059 • — 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service I 50 029 - 20393 - 00 ° 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool • 11. Present Well Condition Summary: Total Depth measured 8365 • feet Plugs (measured) 7664' true vertical 6916 feet Junk (measured) None Effective Depth measured 8260 feet Packer (measured) 7585, 7647 true vertical 6807 feet (true vertical) 6246, 6298 Casing Length Size MD TVD Burst Collapse CONDUCTOR 109 16 114 114 SURFACE 2741 10.75 2772 2702 PRODUCTION 8276 7 8306 6864 SCANNED ilk JUL 2 2 2013 Perforation depth: Measured depth: 7765 -7832, 7837 -7845, 7851 -7860, 7866 -7876 True Vertical Depth: 6398 -6455, 6459 -6466, 6471 - 7479, 6484 -6493 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7627 MD, 6281 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'FHL' PACKER @ 7585 MD and 6246 TVD PACKER - BAKER SAB -3 PERM PACKER W/ K -22 ANCH SEAL ASSY @ 7647 MD and 6298 TVD NIPPLE - CAMCO 'DS' NIPPLE @ 501.5 MD and 501.5 TVD 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 Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory 1 Development r4i • Service r Stratigraphic I- 16. Well Status after work: Oil W. Gas r WDSPL E Daily Report of Well Operations XXX GSTOR E WINJ C" WAG °" GINJ I"°` SUSP 1 - SPLUG (l 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 Jonathan Coberly aa. 265 -1013 Email Jonathan.Coberly ancop.com Printed Name Jonathan Coberlv Title Senior Wells Engineer Signature '349--- Phone: 265 -1013 Date 5p5 / 2 0 l 3 v`LF 7 3/ l3 RBDMS MAY 2 3 201 /1 7734' Form 10 -404 Revised 10/2012 Submit Original Only KUP • 1D-01 ConocoPhillips "` Well Attributes Max Angle & MD TD F1:.itk<i I1u. - Wellbore APWWI Field Name Well Status Ind ( °) MD (ftKB) Act Mill (ftKB) cc.µ.Phing. ; 500292039300 KUPARUK RIVER UNIT PROD 47.13 4,600.00 8,365.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (R) Rig Release Date Well Goa,' - - o1 5r16r20136:20 .30AM SSSV: NIPPLE 90 8/14/2012 ,Last WO: 5/1/2013 38.99 11/28/1979 schematic - Actual Annotation !Depth (RKB) !End Date !Annotation Last Mod ... End Date Last Tag: SLM 8,074,0 5/15/2013 Rev Reason: PULL CA -2 PLUG, TAG ! osborl ! 5/16/2013 HANGER, 27 WV Casing Strings i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 32.0 141.0 141.0 65.00 H - 40 WELDED , Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 103/4 9.950 31.2 2,772.0 2,701.8 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ' PRODUCTION 7 6.276 29.8 8,305.8 6,864.1 26.00 K -55 BTC CONDUCTOR, Tubing Strings 32 -141 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd III TUBING WO 2013 31/2 2.992 27.0 7,627.0 6,281.2 9.30 L -80 EUE8rdABMOD NIPPLE, 501 „11- Completion Details Top Depth (TVD) Top Incl Nomi... Top (ftKB) (RKB) (1 item Description Comment ID (in) 27.0 27.0 0.27 HANGER CIW GEN IV PORTED TUBING HANGER 2.992 501.5 501.5 0.27 NIPPLE CAMCO DS' NIPPLE 2.875 7,553.8 6,220.1 33.71 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 21.68' long 2.990 7,562.0 6,226.9 33.60 PBR Baker 80-40 x 20-6 PBR 4.000 R 7,585.5 6,246.3 33.29 PACKER BAKER 'FHL' PACKER 2.900 7,6072 6,264.5 33.00 NIPPLE CAMCO 'DS' NIPPLE 2.812 ilk 7,618.7 6,274.2 32.85 OVERSHOT BAKER POOR BOY OVERSHOT 3.590 GAS LIFT, _ Tubing Description String 0... String ID ... Top (R1(8) 'Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 2,650 TUBING WO 1998 ! 3 1/2 ! 2.992 ! 7,625.0 ! 7,674.0 ! 6,320.9 ! 9.30 ! J -55 ! EUE8RDMOD Completion Details Top Depth (TVD) Top Ino1 Nomi... Top (ftKB) (RKB) (°) Item Description Comment ID (in) SURFACE, _...J . 7,647.1 6,298.2 32.47 PACKER BAKER SAB-3 PERM PACKER w/ K -22 ANCH SEAL ASSY 2.937 31 - 2.772 7,663.9 6,312.4 32.25 NIPPLE CAMCO D NIPPLE w/ 2.750" NO GO PROFILE w12.25" NIPPLE 2.250 REDUCER 7,673.1 6,320.1 32.13 SOS BAKER SHEAR OUT SUB, SEAT PINNED FOR 3500 PSI 2.958 GA5LIFT, Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 4,408 Top Depth (TVD) Top Inc! Top (ftKB) (MB) ( °) Description Comment Run Date ID (in) 7,663.9 6,312.4 32.25 REDUCER 2.75" x 2.25" D NIPPLE REDUCER 11/13/2007 2.250 GAS ,5 LIFT, 583 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (6066) (ftKB) (ftKB) Zone Date (.h... Type Comment GAS LIFT, 7,765.0 7,782.0 6,398.2 6,412.6 UNIT D, C-4, 1/4/1980 4.0 IPERF 0 deg phasing 6,417 10-01 111.11.111111 7,783.0 7,832.0 6,413.5 6,455.1 C-4, C-3, 10 -01 1/9/1980 4.0 IPERF 0 deg phasing 7,837.0 7,845.0 6,459.4 6,466.2 C-3, 10 -01 1/9/1980 4.0 IPERF 0 deg phasing GAS LIFT, 7,851.0 7,860.0 6,471.3 6,478.9 C -2, 1D -01 1/9/1980 4.0 IPERF O deg phasing 7,066 . 7,866.0 7,876.0 6,484.0 6,4925 C -2, 1D -01 1/9/1980 4.0 IPERF 0 deg phasing MN Stimulations & Treatments Bottom GAS LIFT - Min Top Max Btm Top Depth Depth 7,490 Depth Depth (TVD) (TVD) (ftKB) (R1(13) , (RKB) (RKB) Type Date Comment 7,765.0 7,876.0 6,398.2 6,492.5 FRAC 2/12/2001 C SAND FRAC Notes: General & Safety End Date Annotation 4/14/1998 NOTE: WORKOVER SEAL A - 7,554 10/28/2002 NOTE: WAIVERED WELL: 1A X OA COMMUNICATION ,ss4 PBR. 7,562 8/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER, 7,585 -- IF 1 NIPPLE, 7,607 M U. OVERSHOT, 7,619 I t PACKER, 7.647 REDUCER, 7,664N NIPPLE, 7,664 1 SOS, 7,673 " Mandrel Details Top Depth Top Port IPERF, S... (TVD) Inc! OD Valve Latch Size TRO Run 7,765 -7,782 N... lop ,649. (ftKB8 2,594 (RKB) .3 27. ( ° 82 ) Ca Mmco ake MM 4 6,416.6 5,314.2 41.30 Camco MMG Model (in) Sery Type Type (18) (psi) Run Dale Cont.., IPERF, 1 2 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/30/2013 7,783 - FRAC, 7,765 2 4,408.5 3,900.2 46.88 Camco MMG 1 1/2 12 GAS GAS LIFT LIFT DMY DMY RK RK 0.000 0.000 0.0 0.0 44/30/30/2/2013 013 IPERF, 3 5,583.0 4,708.2 45.45 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/30/2013 7,837 - 7,845 1 IPERF, 5 7,065.6 5,818.6 36.38 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/302013 7.851 - 7,860 6 7,497.9 6,173.1 33.33 Camco MMG 1 12 GAS LIFT SOV RK 0.000 0.0 4/30/2013 IPERF. 7,886 -7,876 PRODUCTION, 30 -8,306 Ns TD, 8,365 • 1D-01 Well Work Summary • DATE SUMMARY • 1/4/2013 (PRE RWO) : POT -T PASSED, PPPOT -T PASSED, POT -IC PASSED, PPPOT -IC PASSED, FUNCTION TESTED T & IC LDS'S (ALL GOOD). 3/20/2013 LOCKED OUT TRDP © 1805' RKB. SET AVA C -SUB @ 6689' RKB. PULLED OV, GLV @ 6339' , 5586' RKB. SET DV @ 6339' RKB. IN PROGRESS. 3/21/2013 PULLED GLVs @ 4430', 2715' RKB. ATTEMPTED SET DVs @ 5587', 4430', 2715' RKB, NO SUCCESS. SET BTM LATCH DV @ 2715' RKB. IN PROGRESS. 3/22/2013 SET BOTTOM LATCH DVs @ 5587' AND 4430' RKB. PULLED CATCHER @ 6689' RKB, 2.25" CA -2 PLUG @ 7664' RKB. MEASURED BHP @ 7820' RKB: 3015 PSI. SET 2.25" CA -2 PLUG @ 7664' RKB. IN PROGRESS. 3/23/2013 PULLED DV @ 7562' RKB (OPEN POCKET). READY TO LOAD WELL. 3/24/2013 DUMPED SAND ON 2.25" CA -2 PLUG @ 7664' TO 7651' RKB. LRS LOADED TBG/ IA WITH 240 BBL DSL. COMBO MIT 2500 PSI, PASSED. READY FOR E -LINE. 3/29/2013 CUT TUBING WITH RCT, CUT DEPTH AT 7625' CCL TO CUT 10.9' CCL STOP AT 7614.1' PRIOR TO CUT SHOOT STRING SHOT WITH MID SHOT AT 7625' CCL TO MID SHOT 10.2' CCL STOP AT 7614.8'. JOB COMPLETE • • CanocoPhillips Time Log & Summary Wel/view Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/27/2013 10:30:00 PM Rig Release: 4/30/2013 4:30:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/27/2013 24 hr Summary Load Tree in cellar, MIRU on 1 D -01. Set down and Berm up 21:30 22:30 1.00 MIRU MOVE MOB P Move Nordic 3 to 1D-01, Pull over well and set down on mats. Accept Nordic Rig 3 @ 22:30 hrs. 22:30 00:00 1.50 MIRU MOVE RURD P Berm up and spot ancillary equipment. 04/28/2013 Continue to RU, PT kill lines, Load pits. Load well w/ 9.6 ppg brine. ND Tree NU BOPE. Conduct inital BOP Test. Pull Blanking plug and BPV. 00:00 01:00 1.00 MIRU MOVE RURD P Continue to MIRU kill tank and lay hard line w/ KTDH. Berm Up around rig and cuttings box. 01:00 03:00 2.00 MIRU MOVE MPSP P Load lubricator and PT @ 1,000 psi, Pull BPV. Open up TBG 1,100 psi, IA = 1,050 psi and OA = 0 psi 03:00 04:30 1.50 MIRU MOVE RURD P RU circulating hoses, Load pits w/ 549 bbls of 9.6 ppg NaCI Brine. Mix 25 bbl 3 lb per bbl high visc sweep. 04:30 05:30 1.00 MIRU WELCTI KLWL P PT kill lines against well head and kill tank @ 250 / 3,500 psi - good test. Held PJSM on killing well. Open up well 750 psi TBG, 780 psi IA. Pumped 7 bbls 3 bpm @ 1180 psi into IA, circulating point at 7,625 -ft. and holding 1050 psi on choke. 05:30 07:30 2.00 MIRU WELCTI KLWL T Choke stem failed. Secure well. Blow down kill lines. Repair manual choke, re -test @ 250 / 5,000 psi. 07:30 10:00 2.50 MIRU WELCTI KLWL P Continue with well kill. Reverse circulate 25 bbl sweep followed by 374 bbls 9.6 ppg w/ 373 bbls returned. While pumping @ 3 bpm @ 1,250 psi while maintaining 1,050 psi on choke manifold. Final Circulating pressures on 130 psi @ 3 bpm and 350 psi @ choke manifold. 10:00 10:30 0.50 MIRU WELCTI OWFF P monitor well for flow 30 mins. 10:30 11:30 1.00 MIRU WHDBO THGR P install BPV in hanger and test to 1000 psi 11:30 12:00 0.50 MIRU WHDBO OWFF P no flow for 30 mins. 12:00 17:00 5.00 MIRU WHDBO NUND P ND tree & NU BOPE Page 1 of 5 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 22:30 5.50 MIRU WHDBO BOPE P Test BOPE to 250/3500 PSI, 24 hr Notice was given to AOGCC @ 19:22 hrs on 4 -27 -13 and Right to witness waived by Jeff Jones @ 06:45 hrs on 4- 28 -13. Test #1 - Kill side HCR, Blind Rams, 3 -1/2" IF FOSV, TD Hyd, Choke Manifold 4, 11, & 12 Test #2 - Kill side Manual, 3 -1/2" IF Dart Valve, TD Manual, Choke Manifold 3, 7, 9, & 10 Test #3 - Choke Manifold 2, 5, & 8 Test #4 - Choke Manifold 6, 3 -1/2" 8rd FOSV Test #5 - LPR / 2 -7/8 x 5" VBR's w/ 3 -1/2" Test Joint, Choke Manifold 1 Test #6 - Annular w/ 3 -1/2" Test Joint Test # 7 - UPR / 2-7/8 x 5" VBR's w/ 3 -1/2" Test Joint, Choke side HCR Test # 8 - Choke side Manual Draw down System pressure = 3,000 psi After closure = 1,800 psi 200 psi build = 17 seconds Full psi build = 91 seconds N2 - 4 bottle ave. = 2,000 psi. Replace Mud Manifold - Kill line Valve SN# 32655 and PT at 250 / 5,000 psi 22:30 23:15 0.75 MIRU RIGMNT RGRP P PT Kill line valve and manual choke bonnet for integrity of dedicated system @ 250 / 5,000 psi on chart after repair and replacement 23:15 00:00 0.75 COMPZ WHDBO MPSP P Pull blanking plug and BPV X4/29/2013 MU landing jt, BOLDS, Pre -spud, Unland hanger, Rev. Circ. 2 TBG vol., POOH laying down de- completion. PU and RIH w/ csg scraper assy while PU and RIH w/ completion TBG to 6,969 -ft 00:00 00:30 0.50 COMPZ RPCOM OTHR P MU 3 -1/2 ", 9.3 #, L -80, EUE 8rd landing pup joints and screw in Top Drive. BOLDS. 00:30 01:00 0.50 COMPZ RPCOM SFTY P Held Pre -Spud with Rig personnel, Mud engr and Service hands. 01:00 01:30 0.50 7,625 7,620 COMPZ RPCOM PULL P Un land hanger @ 60k, pull 40k osw of 110k up wt, (max pull, leave hang and cut pulled in to.) 75k do wt. 01:30 02:00 0.50 7,620 7,620 COMPZ RPCOM CIRC P Close annular and reverse circulate 140 bbls of 9.6 ppg NaCI @ 7 bpm @ 720 psi 02:00 06:30 4.50 7,620 5,825 COMPZ RPCOM PULD P Lay down landing joint, TBG hanger w/ 4 -ft pup joint, X -O joint, connect .25" control line to spooler and continue to POOH laying down 3 -1/2 ", 9.3 #, J -55, IBT -M Tubing from cut @ 7,625 -ft. to 5,825 -ft. RD Spooling unit and off load same. Page 2 of 5 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:30 16:00 9.50 5,825 0 COMPZ RPCOM PULL P continue to POOH W/ 242 jts IBT -M tubing and GLM's cut @ 7626 ft. found hole @ 6695 ft . 6 ft in the patch. off load production string . 16:00 17:30 1.50 0 231 COMPZ RPCOM PUTB P Make up 5" wash shoe and 7" scraper BHA # 1 17:30 00:00 6.50 231 6,969 COMPZ RPCOM PUTB P PJSM, pick up and RIH with BHA #1 and 217 jts of 3.5" 9.3# L -80 AB -M EUE 8rd tubing with csg scraper to 6,969- ft. 100k up wt, 80 dn wt 04/30/2013 Continue to RIH to 7,613 -ft and wash over stub @ 7,618 -ft to 7,649 -ft. No go TBG stub @ drive sub. CBU, POOH and lay down BHA #1, RIH w/ 3 -1/2" Stacker Packer completion and set packer. Shear out PBR and space out. Load csg w/ CI SW. Land hanger, RILDS. PT Tbg @ 3,000 psi, PT IA @ 2,500 psi. Shear SOV @ 2200 psi. Install BPV - test from below @ 1,000 psi. Wash BOP stack. 00:00 01:00 1.00 6,969 7,613 COMPZ WELLPF PULD P Continuer to RIH PU 3- 1/2 ",9.3 #, L -80, EUE 8rd AB -Mod TBG from 6,969 -ft to 7,613 -ft. 107 up wt, 83k dn wt. 01:00 03:00 2.00 7,613 7,610 COMPZ WELLPF WASH P MU TD and washover stub @ 7,618 -ft (had to rotate over at 1,600 ft/lbs free tq) (6.5 -ft in on jt 240), continue to wash over to 7,641 -ft and no -go on Top sub, (2.70 -ft out on jt 240) Circulating @ 8 bpm for 200 bbls @ 1,020 psi, Increase pump rate to 10 bpm and circulate another 200 bbls @ 1,420 psi while reciprocating over stub. Pull off stub and attempt to slide over w/ no pumps - unable to slide over - made 2 attempts. Blow down top drive. 03:00 07:00 4.00 7,610 233 COMPZ WELLPF TRIP P POOH standing back 3 -1/2 ", 9.3#, L -80 TBG to 233 -ft 07:00 08:00 1.00 233 0 COMPZ WELLPF PULD P POOH laying down BHA #1 08:00 08:30 0.50 0 0 COMPZ RPCOM PULD P PJSM, Offload Baker Tools, Change out Floor Equipment 08:30 13:30 5.00 0 7,615 COMPZ RPCOM RCST P PJSM, MU 3 -1/2" Completion Assembly as per run order. RIH with Tubing out of the Derrick to 7615'. Up 104k #, down 80k# 13:30 14:30 1.00 7,615 7,615 COMPZ RPCOM CIRC P PJSM, Circulate 10 bbls of CI Sea Water (CRW 132), followed by 65 bbls of 9.6 ppg SW at 3 bpm at 190 psi, down Tubing returns up IA. 14:30 15:00 0.50 7,615 7,627 COMPZ RPCOM RCST P Locate NoGo on the Tbg Stub at 7621'. PU to 7627' and drop 1- 5/16" Ball & Rod. 15:00 15:30 0.50 7,627 7,596 COMPZ RPCOM RCST P Roll on Puumps and pressure up Tubing to 2690 psi to set Packer. Hold pressure for 10 minutes for Packer to square out at 7627'. Bleed pressure down to 2000 psi and pull up and shear PBR at 20k #. Bleed off pressure. Page 3 of 5 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 7,596 7,590 COMPZ RPCOM RCST P Pull up and out of PBR. Roll the pump at 70 psi and ease down see pressure as PBR Seals engage. Bleed off pressure and RIH to NoGo at 8.22' in on Joint 239 (pup). Calculate space out while laying down Joints 239 and 238. No pups required. 16:00 16:45 0.75 7,545 7,545 COMPZ RPCOM RCST P MU Hanger to Joint 237. Roll the pumps and check space out. OK. Pull up above PBR and prepare to reverse circulate CI SW. 16:45 18:15 1.50 7,545 7,545 COMPZ RPCOM CIRC P Reverse Circulate a 30 bbl HiVis Sweep, Followed by 75 bbls SW, followed by 235 bbls of CI SW at 6 bpm at 650 psi, chase with 15 bbls SW 18:15 19:45 1.50 7,545 7,575 COMPZ RPCOM THGR P Drain stack, Land tubing hanger, RILDS 19:45 22:30 2.75 7,575 0 COMPZ RPCOM PRTS P RU test equipment, PJSM, PT Tubing @ 3,000 psi for 15 minutes on chart, Bleed Tubing back to 1,500 psi. While monitoring the open IA. Pressure up on IA to 2,500 psi for 30 minutes on chart. Bleed off IA to zero and then bleed Tubing back to zero. Pressure up on IA and shear out SOV @ 2,200 psi @ 7,498 -ft. Circulate 2 bbls of SW @ 2 bpm @ 140 psi. RD Test Equipment. 22:30 23:00 0.50 0 0 COMPZ WHDBO MPSP P Monitor well for flow thru the IA while Pulling landing joint, Install 3" Type "H" BPV, preeure up on IA and test below BPV @ 1,000 psi. 23:00 00:00 1.00 0 0 COMPZ WHDBO OTHR P MU 3 -1/2 IF Snozzlator and circulate @ 5 bpm and rotating @ 20 rpm's, wash BOP stack. 05/01/2013 Continue to wash BOP stack. ND BOPE NU Tree. Change out IA Valve and test. Test hanger pack off seals. and tree. RU LRS and FP. Swap TBG x IA. Dress tree and RDMO. 00:00 00:30 0.50 0 0 COMPZ WHDBO OTHR P Continue to wash BOP stack. Blow down Top Drive. 00:30 03:30 3.00 0 0 COMPZ WHDBO NUND P Drain stack and ND BOPE 03:30 10:00 6.50 0 0 COMPZ WHDBO NUND P Install Test dart, NU 7- 1/16" 5M x 3 -1/8" 5M Adapter. NU 3 -1/8" 5M tree. Change out 2- 1/16" 5M IA valve SN: MD 00059198 with 2- 1/16" 5M SN: 603777 -02, Test Tree 250 / 5000 psi- OK. Test IA Valve 250 / 3,500 psi- OK. 10:00 13:00 3.00 0 0 COMPZ WHDBO CIRC P PJSM, RU LRS Hoses, Pull BPV, PT Lines 250 / 5000 psi. Freeze protect with Diesel down IA up Tbg at 2 bpm. ICP 600 psi, FCP 950 psi - total 75 bbls. Allow Well to U -Tube. Blow down Hardline. Suck out Kill Tank. Page 4 of 5 Time Logs • s Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:00 1.00 0 0 COMPZ WHDBO MPSP P PJSM, Set BPV, Dress Tree. Final Pressures: Tbg/ IN OA = 0/ 0/ 0 psi 14:00 16:00 2.00 0 0 COMPZ WHDBO RURD P PJSM, RDMO 16:00 16:30 0.50 0 0 COMPZ WHDBO RURD P Move Mats / Liner from around Well, Suck out Cellar Box with Super Sucker Release Nordic Rig 3 @ 16:30 hrs 4. Page 5 of 5 C) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record/ String Shot Record: 1 D-01 Run Date: 3/29/2013 April 1, 2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1D-01 Digital Data in LAS format, Digital Log Image file 50-029-20393-00 1 CD Rom 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: 5112- t 3 Signed: A4't' WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT)/Leak Detect Log: 1 D-01 Run Date: 10/13/2012 RECEIV, j4 5� MAR 2 6 201.3 ,AOGCC March 22, 2013 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-01 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20393-00 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: Vi°—os°1 • 22e?' WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 19, 2012 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT)/Leak Detect Log: 1D-01 Run Date: 10/13/2012 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-01 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20393-00 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. SCANNED "` . Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 3 6 Signed: /\'3 • ConocoPhillips Aaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7t' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: i q9 i ®� SH 2 3 2010 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 corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 16 and September 9, 2010. The corrosion inhibitor/sealant was pumped September 10 thru September 14, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 9/19/10 IC. 1 D. 1E. IG & 1 L PAD Well Name AP ISTD # Initial top of cement Vol. of cement pumped Final top of Cement top off cement date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1A-07 50029206580000 1811370 21" NA 21" NA 1.7 9/14/2010 1A-10 5002920673yy0�.000 181 00 22" NA 22" NA 2 9/14/2010 IC -05 5002920 0 •: 1810050 34'8" 4.12 17" 8/16/2010 1.7 9/10/2010 1C-12 50029227190000 1961770 SF NA 18" NA 2.5 9/10/2010 1C-104 50029230760000 2020610 50" NA 50" NA 7.6 9/10/2010 1C-109 50029230470000 2012030 5" NA 5" NA 4.25 9/10/2010 1 D-01 50029203930000 1790590 45" 0.48 13" 8/16/2010 2.5 9/10/2010 1 D-02 50029204290000 1791110 12" NA 12" NA 2.5 9/10/2010 1 D -04A 50029204160100 2080840 2" NA 2" NA 1.4 9/10/2010 1D-05 50029204170000 1790950 3" NA 3" NA 1.7 9/11/2010 1D-112 50029229190000 1981830 12" NA 12" NA 11.9 9/11/2010 1D-114 50029229080000 1981590 8' 1.07 14" 8/16/2010 8.6 9/11/2010 1D-118 50029228390000 1972290 23" NA 23" NA 4.5 9/11/2010 1D-124 50029228330000 1972170 22' 4.75 42" 8/16/2010 13.6 9/11/2010 1D-135 50029228160000 1971840 22" NA 22" NA 4.1 9/11/2010 1E-12 50029207360000 1820600 33'3" 4.35 25" 9/8/2010 5.1 9/14/2010 1E-14 50029207510000 1820790 6'8" 1.00 4" 9/8/2010 1.7 9/14/2010 1E-18 50029209040000 1830160 27'9" 3.00 24" 9/8/2010 5.1 9/14/2010 1 E-20 50029208950000 1830050 16'9" 4.00 26" 9/8/2010 5.95 9/14/2010 1 E-26 50029208400000 1821660 5'9" 0.50 12" 9/8/2010 2.5 9/14/2010 1 E-27 50029208370000 1821630 13'4" 2.50 7" 9/8/2010 1.7 9/14/2010 1G-01 50029208050000 1821300 12'5" 1.50 22" 9/8/2010 4.25 9/12/2010 1G-02 50029208130000 1821380 21" NA 8" NA 1.7 9/12/2010 1G-03 50029208240000 1821490 11'10" 3.25 14" 9/8/2010 2.5 9/13/2010 1 G-04 50029208350000 1821610 76' 9.50 49" 9/8/2010 15.3 9/13/2010 1 G-05 50029209080000 1830200 37" NA 37" NA 7.65 9/13/2010 1 G-06 50029208900000 1822200 23" NA 23" NA 1.7 9/13/2010 1G-07 50029208720000 1822010 37.6 4.25 21" 9/8/2010 4.25 9/13/2010 1G -08A 50029208490100 2041010 227" 2.25 15" 9/8/2010 2.5 9/13/2010 1G-09 50029210010000 1831240 31" NA 31" NA 2.5 9/12/2010 lG-10A 50029210030100 1961400 31" NA 31" NA 6.8 9/12/2010 lG-11 50029210080000 1831310 21" NA 21" NA 2.5 9/12/2010 lG-12 50029210090000 1831320 25" NA 25" NA 1.7 9/12/2010 1G-14 50029210170000 1831410 10'3" 2.00 19" 9/8/2010 3.4 9/12/2010 lG-15 50029210240000 1831480 43'3" 5.25 41" 9/8/2010 10.2 9/12/2010 lG-16 50029210310000 1831550 9'6" 1.00 6" 9/8/2010 1.7 9/12/2010 1 L -03A 50029211820100 1990370 44'8" 6.00 15" 9/8/2010 6.8 9/11/2010 1L-07 50029211710000 1841450 7' 1.50 12" 9/8/2010 3.4 9/11/2010 1L-10 50029220260000 1900350 11' 1.50 16" 9/8/2010 5.1 9/11/2010 1L-14 50029221320000 1910100 14'4" 3.00 14" 9/8/2010 5.1 9/11/2010 1L -20A 50029220270100 2000360 17" NA 17" NA 1.7 9/11/2010 1L-22 1 50029221140000 1901640 13" NA 13" NA 11.9 9/11/2010 1 L -25A 50029221740100 2051750 32" NA 32" NA 15.3 9/11/2010 • ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~ NqV 2 7 ~Q01 ~la~ka Qii & Gas Cons. Camrriia~an Anchorag® ~,i~ D£C ~. ~ 20fl7 Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 1D-O1 (PTD 1790590). The report records the completion of the tubing patch installation and integrity test. ~~ Please call myself or Martin Walters at 659-7224 or MJ Loveland or Perry Klein at 659- 7043 if you have any questions. Sincerely, /i / ~ Brent Rogers Problem Well Supervisor Attachments ~ ~~ci~~~ STATE OF ALASKA ~~~ ~,, ~' ~(J~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~~ Oil & Gas Cone. CommisxiAh •__L ___ 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 ^ 179-059 '' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20393-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' - 1 D-01 ' 8. Property Designation: 10. Field/Pool(s): ADL 25650 ~ALK 468 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8365' ~ feet true vertical 6916' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 141' 16" 141' 141' SURFACE 2667' 10-3/4" 2772' 2702' PRODUCTION 8200' 7" 8305' 6863' Perforation depth: Measured depth: Intervals from 7765' - 7876' true vertical depth: Intervals from 6398' - 6493' Tubing (size, grade, and measured depth) 3-1/2" , J55/L80, 7674' MD. Packers &SSSV (type & measured depth) pkr= BAKER'SAB-3' PERM PACKER W!K-22 ANCH SEAL ASSY pkr= 7647' SSSV= Camco TRDP-4E SSSV= 1806' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured) Treatment descriptions including volumes used and final pressure: ° ?k~s _ ~~`~ ~ `~ ~~Q~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N!A N/A N/A 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: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certity 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 Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signaturep,~~ Phone 659-7224 Date / / „ ~/ ~~" / Form 10-404 Revised 04/2004 /?'//.b7 Submit Oljginal l/_/,,,_, • i 1 D-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11I01l07 11/13/07 11/22/07 11/25/07 LEAK DETECTION LOG: PUMPED DOWN THE IA AT 0.5 BPM, 1400 PSI TAKING RETURNS TO THE FORMATION. LEAK FOUND AT 6701'. NO OTHER TUBING LEAKS FOUND. BRUSHED /FLUSHED TBG, CONCENTRATING @ 6600' TO 6750' SLM AND D NIPPLE. DRIFTED TBG WITH 26' x 2.74" DUMMY PATCH TO 7600' SLM; TBG CLEAR. SET 2.75" D x 2.25" D NIPPLE REDUCER AT 7664' RKB. READY FOR TBG PATCH. RAN HALIBURTON 1 RUN PATCH. SET PATCH FROM 6688.7'-6720'. EFFECTIVE SEAL OF PATCH=31.32' passe _ ressure up wi iese . _ 800/1500/620/0. 15 min T/I/O/OOA= 800/1460/620/0. 30 min T/I/O/OOA= 800/1460/620/0. Bled IA, final T/I/O/OOA= 750/700/620/0. Summary Set 32' Halliburton permanent patch from 6688.7' - 6720'. ~• NO.4482 Schlumberger -DCS ';;% - 2525 Gambell Street, Suite 400 " Anchorage, AK 99503-2838 ~~ ATTN: Beth _ ~~ ~ l.~l!1~~~~~ ~~~ `~ ~, ~~ ~~°. Well Job # Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description ~ ,_4._ Date BL Co{or CD 11 /07/07 3J-10 11850465 SBHP SURVEY J ~ 10/31/07 1 1B-08A 11839682 INJECTION PROFILE ~. - 10/31/07 1 1D-01 11846458 LDL 11/01/07 1 2A-15 11846459 PRODUCTION PROFILE 5 - '~ (p 11/02/07 1 1E-02 11850470 _ PRODUCTION PROFILE ~ -(~ 11!04/07 1 2N-310 11745242 SCMT 11/04/07 1 1E-119 10687772 OH LDWG EDIT Q} <f 04/08/04 1 1E-119 10687772 CMR ~pL - 04/08/04 1 1 E-119 10687772 MDT 04/08/04 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. To: AOt~ Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659.5102 RE : Cased Hote/Open Hole/Mechanical Logs and /or Tubing InspectionjCaliper j MTT) The technical data 1'~sted below is being submitted herewith. Please acknowledge receipt by resuming a signed copy of this transmittal letter to the foNowing : BP Exploration (Ala6kaj, inc. Petrcytechr~al Dana Cater Attn: Andy 1Farrria~ LR2.1 9~ E Raison Blvd Anchorage, Alaska 99508 and ~~~,-~~ NOV ~ ~ 2007 ProActive Diagnostic Services, inc. Attn: Rabat a Richey 130 West intee~nationai Airport Road Suite C Anchorage, AK 99518 Fax f9m~ 2Ar6951 1) Caliper Report 04Qc~07 1 t}01 2) Signed : ~~ X ~ Print Name: (' ~ i ~j,,, • ~ U) A ~ (~ ti lam, 1 Report / EDE 50.0'29-2039300 ~~ !1 ~ ~ ~ :~~ Date : ~ ~ ~ ~ 7~~~ PaoAc~nv~ ~avnosnc seevas. 1NC., 1xo W. ~Nr~~4 A~RPan' Ro swTa C. Axc~opaQE, AK gs518 PNONE: (geT)?,a6.E9s1 EAx: (94n245~8952 E-Nlpui.: IA-r~s1iE o- c~y_oo rnsnNC~-z wmd~n171rat~t 13ta~mir_omg~et Mew.doc ~~-~ - o~~~ ~ ~ 5sa~ ii • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhlllips Alaska, Inc. Well: 1D-01 Log Date: fJctofSer 4, 2007 Field: Kuparuk Log No.: 8635 State: Alaska Run No_: 1 API No.: 50-029-20393-00 Pipet Desc.: 3.5" 9.3 Ib. ,l55/L80 STC-MOD Top Log lntvl1.: Surface Pipet Use: Tubing Sot. Log intvl1.: 7,658 Ft. (MDj Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This log is tied into the GLM 6 ~ 7,562' (Driller's depth). This log was run #o assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing interval fogged is in good to fair condition with respect to corrosive damage. A maximum wall penetratign of 26% is recorded in joint 67(c~ 2,086'. The damage appears in the form of isolated pitting. No areas of significant cross-sectional metal foss or i.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (26%) Jt 67 C~! 2,086 Ft. (MD) Isolated Pitting { 24%} Jt 147 ~ 4,584 Ft. {MD} isolated Pitting {2290 Jt 165 ~ 5,147 Ft, (MD) No other significant wall penetrations {> 20%) are recon:ied. MAXIMUM RECORDED CROSS-SEC110NAL METAL LOSS: No areas of significant cross-sectional wall loss (> 9%} are recorded. MAXIMUM RECORDED iD RESTRICTIONS: No significant I.D. restrictions are recorded. ' Field Engineer: K Miller Analyst: 8. Qi Witness: C. Kennedy i'roActive Diagnostic Services, inc. ,i P.~. Box 1369, Stafford, TX ?7~9? Phone; (281) or (888) 555-9085 Fax: {281) 565-1369 E-mail: PDS@memarylo ~' P Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 ®~~ ~. ~S ! ~ IS~C~~ ~Ia~t'tl~Ctai~~ ~.,.~.,. l `~ e~CC~-~ • Correlation of Recorded Damag ~~ Pipe 1 3.5 in (13.2' - 7647.6') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 1D-01 Kuparuk ConocoPhilips Alaska, Inc. USA Ocrober 4, 2007 ^ A pprox. Tool Deviation ^ A pprox. Borehd e Profil e 1 13 760 1541 2336 GLM 1 3113 p ~i 3888 •~ s Y B. Q~ GI_M 2 ~ 4677 5460 GLM 3 GLM 4 6246 GLM 5 7027 GLM 6 243.2 7648 0 5 0 1 00 Da mage Profile (% wall) / Tod D eviatio n (degr ees) Bottom of Survey = 243.2 25 50 75 100 `v E Z 125 150 175 e 225 • PDS Report Overview ~~~ ~. Body Region Analysis Well: 1D-01 Survey Date: October 4, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal t: B. i Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 BTC-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ._.: metal loss body 250 200 150 100 50 0 0 to 1 to 10 ro 1% 10% 20% 20 ro 40 ro over 40% 85% 85% Number of'oints anal se d total g 248 pene. 1 213 31 loss 19 227 2 3 0 0 0 0 0 Damage Configuration (body ) 30 20 10 0 isolated general line ring hde /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total ~ 22 22 0 0 0 0 Damage Profie (% wall) ~ penetration body „~~ metal bss body 0 50 100 GLM 1 GLM 2 GLM3 GLM 4 GLM 5 GLM 6 Bottom of Survey = 243.2 - - Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf }55 / L-80 Well: 1 D-01 Body Wall: 0.254 in Field: Kuparuk Upset WaN: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October4, 2007 Joint No. Jt. Depth (Ft.) I'e•n. Uhsc•t (Inc.j Pen. Body (Ins.) Pen. % 'v1c•t•il luti "'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 13 t) 0.01 5 6 .97 45 U 0. 1 5 ' 2 9 3 76 (a 0.01 Z ' 96 4 107 I) 0.01 6 ,! 2.95 139 ~) 0.0 (~ .94 6 1 9 U 0.01 4 v 2.98 7 1 9 t) 001 ~ .9 8 231 U 0.01 ~ I 2.96 9 262 (! 0.01 5 ? 2.95 10 93 t ~ 0.01 4 I 2.96 1 324 U 0. 1 4 ' .95 1 353 U 0 01 (i 3 2.96 13 384 a 0.02 t3 _' 2. 9 14 415 ~~ 0. 1 ~ .00 15 447 i~ 0. 2 6 S .9 16 475 U 0.01 5 ' .99 17 07 ~) 0.01 4 2 2.98 18 539 (~ 0.01 4 1 3.00 19 570 t ~ .01 4 I .96 20 02 !! 0.01 ~ .9 21 633 r ~ 0.01 4 (~ 2.94 2 665 c 1 0.0 10 ' 2.99 3 696 t ~ 0.02 7 ' .98 24 728 ~) 0.00 2 0 2.97 5 760 it .Ot 2 ' 96 26 791 O 0.01 4 (~ 2.96 27 2 ~~ 0.01 4 1 .98 28 854 ~ ~ 0.02 F3 ? 3.00 884 U 0.02 £3 .95 30 915 tl 0.01 Z 3 2.93 31 945 t) 0.02 ~) ? 2.97 32 976 U 0.01 2 1 ? 3.00 3 1008 t t 0.01 2 ) 2.96 34 1039 t ~ 0.03 11 2 2.96 5 1070 tl 0.01 5 ~ 2.9 36 1102 (? 0.02 7 ~ 2.96 7 1133 U 0. 7 ') .99 38 1165 tt 0.01 4 1~' 3.00 39 119 U 0.01 2 .96 40 1227 ~~ 0.01 5 2 2.97 41 1258 U 0.01 4 I .97 42 1290 O 0. 1 4 ? 2.97 4 13 U 0. 1 4 ' 97 44 1353 U 0.01 2 (, 2.97 45 1384 U 0 01 4 .96 46 1415 U 0.01 5 ~~ 2.97 47 1447 (1 0.01 2 .98 48 1478 !) 0.01 4 2.99 49 1510 0.01 2.99 50 1541 0.02 2.96 ~ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf }55 / L-80 Well: 1 D-01 Body Wall: 0.254 in Field: Kuparuk Upset WaU: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 4, 2007 Joint No. Jt. Depth (Ft.) Pc~n. Upset Iln~.i Pen. Body (Ins.) I'c~n. % ~t~~~l loss "<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 1570 ~ ~ 0.01 7 .97 t~ 52 1602 i) .0 4 I .98 3 1633 (~ 0.01 6 _' 2.98 54 1665 ~ ~ 0.01 1 ? 2.95 55 1695 U 0.0 i I 2.97 5 1723 t~ 0.01 1 2.98 57 17 4 i> 0.01 -1 I .92 57.1 1785 i ~ 0.04 l 4 a 2.93 PUP hallow iffi 57. 17 1 U 0 U ~~ 2.81 S S 57.3 1797 U 0.0 ti 5 .94 PUP 5 1803 U 0. 1 5 .96 59 183 t~ .01 E~ 1 .98 60 1 l) 0. 1 (~ 2.9 61 1898 l ~ 0.02 % 2.9 62 1930 ~ ? 0.01 4 ~' 2.97 63 1961 a 0.02 7 ~:, .97 64 1992 ! > 0.0 5 7 2.96 65 2023 U 0.01 4 1 8 0 4 O 0.0 i ti 2.9 67 208 U 0 07 26 ~ 2.93 ated i tin Lt. De sits. 68 116 ~~ 0.01 ~ !~ 2.93 69 147 ~ ~ 0.0 4 2.98 70 2178 ~? .01 a _' z.9a 71 2210 U 0.01 6 (~ 2.96 72 24 ~~ 0. 1 1 2. 6 73 2273 ~~ 0.01 4 ~ 2.96 74 230 ~~ 0. I ~ ~ 89 Shallo it' Lt. a its. 75 2336 U 0.01 4 3 2.95 7 2 64 U 0.0 7 7 .97 77 2396 cl 0.01 4 - 2.97 78 2428 (1 0.01 i 1 2.97 79 2459 ~ ~ 0.01 ~1 (: 2.95 80 2489 a 0.02 7 b 2.97 81 2521 ~ ~ 0.01 4 _ 2.96 8 551 (~ 0.01 4 7 2.95 83 2582 U 0.02 8 I 2.96 614 ~~ 0.0 ~ 5 .94 85 2641 ! ~ 0.03 1~~' ; 2.93 6 2671 O 0.01 2 (~ .95 86.1 2703 U 0 0 U N A GLM 1 Latch ~ 1:30 87 2709 tl 0.0 9 4 .96 88 2 741 ~ 1 0.01 5 ? 2.96 89 2771 U 0.01 1 (~ .95 90 2802 (~ 0.02 ~ 2.95 91 2833 U 0.01 ~ (~ 2.96 92 2865 a 0.01 1 2.93 93 2896 a .0 7 (~ 2.96 94 2928 U 0.01 5 ~ 2.96 5 2959 ~ ~ 0.0 ' .96 96 2990 ~) 0.01 (~ 2.95 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf }55 /L-80 Well: 1D-01 Body Wall: 0.254 in field: Kuparuk Upset WaR: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 4, 2007 Joint No. Jt. Depth (Ft.} Pt~n. Ulnc~ (ln~.l Pen. Body (Ins.) Pen. % ~1ct,il loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3021 I ~ 0.01 5 7 6 98 3052 I ~ 0.02 8 ~ 2.93 99 3083 (I 0.0 8 6 2.95 1 113 (~ 0.01 4 v 2. 6 101 144 l1 0.01 4 i 2 10 3176 (I 0.01 Z t, 2.97 10 320 ~ ~ 0.01 0 `> 2.95 104 3237 ~~ 0.01 5 I 2. 7 105 3268 ~ ~ 0.03 I 1 7 2.97 106 3299 c ~ 0.01 5 b 2.94 107 3331 ~ ~ 0.01 ~ ~' .96 108 3 61 t~ 0. 1 U 2 2 97 109 3393 i ~ 0.02 7 2. 7 11 3424 ~ ~ 0.0 t3 ~ .9 111 3454 ~ 1 0 01 ' ? 2.95 112 3484 ~ ~ 0.01 5 0 .9 11 351 t~ 1 Z 2.98 4 35 6 t~ 0.0 ~> (~ 6 115 3577 t ~ 0.00 1 3 96 116 3608 u 7 3 .97 117 3639 U 0.01 5 2.99 118 3670 t) 0 01 :i -1 2.96 11 3701 t) 0.0 i i, 2.96 120 3732 ~) 0.02 8 ? 2.93 1 1 376 ~ t 0.0 7 t, .96 122 3794 a 0.01 2 ? 2.95 1 3 3825 a 0.01 5 t; 2.97 124 3857 t I 0.03 1 1 ~ 2.98 125 3888 tl 0.01 5 I 2. 7 126 3919 tl 0.02 ti i~ 2.95 1 7 3951 I) 0.01 i 5 2.93 128 3982 i ~ 0.02 t3 -1 2.95 129 4014 a 0.02 7 ~' 2.95 130 4046 a 0.01 5 ~~ 2.93 131 77 t1 0.01 4 5 2.95 132 4108 a 0.01 5 ~ 2.96 1 3 4139 U 0.01 5 - 2.96 134 4171 ~ ~ 0.01 _' 2.96 135 4201 ~ ~ 0.01 5 `~ 2.95 136 4233 ~ ~ 0.04 I ~ (, 2.95 Shallow it6n . 137 4 64 U 0.0 £3 (, 95 138 4296 tl 0.01 ~ ~ 2.98 9 4 26 ~~ 001 4 ' 2.9 140 4358 a 0.02 6 ~' 2.95 141 4389 t ~ 0.03 1O 6 2 96 141.1 4421 ~ ~ 0 t~ ~ ~ N A GLM 2 Latch ®7:00 142 4428 ~ ~ 0.03 I 1 1 2.97 143 4459 ~ ~ 0.02 7 2 2.96 144 4490 ~ ? 0.0 ~ _ 2.96 145 4521 i ~ 0.03 1 t l 2.94 Penetration Body Metal Loss Body Page 3 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf }55 /L-80 Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in Well: 1 D-01 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: October 4, 2007 Joint No. Jt. Depth (Ft) I'rn. Upset (Ills.) Pen. Body (Ins.) Pen. %, Mc~i,il loss °i~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 146 455 U 0.04 1 G ~' 2.96 Shallow it' 147 458 ~) .0 24 Z 95 'tti 1 4615 ~) 0.01 4 3. 0 149 4646 ~) 0.02 ti ~ ~ .94 150 4 77 t) 002 2. 2 151 4709 ~) 0.03 I ; 2.94 Sh Ilo ite 1 2 4740 ~) 0.0 t3 2.94 153 4771 O 0.02 ti 2.92 154 4802 ~) 0.04 17 b 2.96 S low 'td 1 4834 ~) 0 Ol S ~ 4 15 6 u 0. 1 5 6 157 4896 ~) 0.0 4 -t .9 58 4928 ~) 0.03 I i 3 2.95 Shall w 'tin 15 4959 ~! 0.04 15 ? 2.94 Shallow itli 160 49 1 ~) 0.04 17 (> 2.95 Shall w 'tti 161 5022 t~ 0.0 ~ 2.95 1 5053 U 0.01 2 5 .96 1 3 083 ~ ~ 0.01 (i ~ 4 1 5115 t) 0.01 6 5 2.96 165 5146 U .06 Z2 ~ 2.96 ated itti 166 5177 ~~ 0.0 2U !, 2.94 Isola a 'ttin 167 5209 ~) 0.04 15 4 2 3 Sh I w ~t6 168 5241 i ~ 0.02 i Z 2.93 169 5272 ~) 0.01 4 !, 2.97 17 0 u ~ 9 171 5336 c) 0.01 4 5 2.94 17 5366 ~) 01 4 a 2.95 173 5398 ~) 0.02 ~) t. 2. 6 174 5430 ~) .05 I ~) :' .98 hall w it 175 5460 ! 1 0.01 2 5 2.94 176 5493 ~) 0.02 9 F, 2.94 177 552 c) 0.02 9 _' 2.91 178 5554 ~) 0.02 9 5 2.96 178.1 5586 u 0 0 i) N A GLM 3 Latch ®800 179 559 ~~ 0.01 ~ 4 2 6 180 5624 U 0.04 15 5 .96 Shallow 'tOn . 181 56 t) 0. 1 ' ' 182 5686 ~) 0.01 i ~ 2.95 183 5716 U 0.0 11 !~ 2.97 184 5747 U 0.01 ~~ 2.96 185 5779 t) .0 4 2 95 186 5810 U 0.01 z '> 2.95 187 584 ~) 0 Ol 5 t .9 188 5873 ~) 0.02 9 ~ ~ 2.92 189 590 U 0.01 5 .96 190 5936 ~) 0.01 6 i 2.96 191 5967 ~) 0 0 7 2 5 192 5998 ~) 0.01 4 ~, 2.94 193 602 9 ~) 0.01 ~ ~ 2.96 _ __ __._ _ _ ~~ ~ 194 6059 a ~ 0.01 4 ~ 2.93 ~ ~ I i Penetration Body Metal Loss Body Page 4 • . PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf }55 / L-80 Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in Well: 1 D-01 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: October 4, 2007 Joint No. Jt. Depth (Ft.) I'en. t Jpse•t (ln>.) Pen. Body (Ins.) I'~•n. °i~, ~tc•c~l I o~ ".~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 195 091 U 0.0 ~~ ~ 2.94 196 122 a 0.01 ~ ~ 2 95 197 6152 U 0.01 -3 ~ 2.93 198 6184 U 0 02 ti 6 2.95 199 6 14 U 0.01 -1 3 2.94 200 6246 U 0.04 15 3 2.97 hallow itUn . 201 6278 U 0.0 11 5 2.95 202 6308 U 0.02 9 7 2.9 202.1 6340 U 0 U t) N GLM 4 Latch ®4:0 03 6347 U 0 4 1 i i .9 Sh I ow ittin . 204 637 U 0. 4 17 V 3 hallow it ~n . 205 6410 U 0.01 -1 5 .96 206 6441 U 0.0 t3 b 2.95 207 6471 U 0.01 a )i 2.98 208 6503 U 0.0 t3 3 2.96 209 6530 U 0.01 6 2.94 10 6 60 U 0.01 ,t 2. 8 211 6591 U 0. 1 Z 5 2.94 2 6621 U 0.01 4 3 .95 213 6653 U 0.01 5 4 2.97 214 6684 U 0.01 ' 2.98 15 6716 U 0.01 4 t> 2.95 21 6747 U 0.01 5 - .93 217 6777 U 0.01 ~ 2.96 8 680 i) .0 -t - .9 219 6835 U 0.02 - ~ 2.96 20 864 U 0.01 4 Z 2.98 221 6894 t t 0.01 ~1 ~t 2.94 22 69 6 U 0.02 7 ~ 2.95 223 6957 0 0.03 I ? 1 2.96 223.1 6987 U 0 U u N A GLM 5 Latch ~ 12:1 224 6994 U 0.01 a ~ 2.93 225 7027 U 0. 1 ~ I 2.97 226 7054 U 0.01 4 i 2.95 227 7085 U 0.01 5 6 2.96 228 7117 U 0.01 5 ~ 2.96 229 7148 U 0.01 ? 4 2. 4 230 7180 U 0.02 t3 ~ 2.93 231 7212 U 0.02 `t - .93 232 7242 U 0.01 5 i 2.94 233 7274 U 0.02 ~) ~) .98 234 7305 U 0.02 `) 5 2.92 23 7337 U 0.0 1 U ti 2.96 236 7368 0 0.01 ~ (~ 2.97 237 7400 U 0.04 14 4 2.93 Shallow itU 238 7432 U 0.03 II a 2.93 239 7463 U 0.0 ~) I .93 240 7493 (~ 0.01 4 1 2.93 41 75 4 t t 0.0 7 2.92 241.1 7552 U 0.03 12 -J 2.97 PUP Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINTTABUTATION SHEEP Pipe: 3.5 in 9.3 ppf }55 /L-80 Well: 1D-01 Body Wall: 0.254 in Field: Kuparuk Upset Waq: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 4, 2007 Joint No. Jt. Depth (Ft) I'en. UI>sc~t (Ins.) Pen. Body (Ins.) I'en. `%~ a1e4~1 loss °~o Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 241.2 7562 U 0 U U N A GLM 6 Latch ~ 3:1 S 241.3 7 71 O .03 12 4 .93 P P 242 757 O 0.03 12 I .88 24 .1 7 9 l) 0 O a 2. 1 mco Ni le 24 7611 U 0.04 I -l _' .90 hallow ~ ~ 43.1 7 U I , ~ .93 PUP Shall ittin 43.2 7648 U 0 U (1 2.98 Seal Ass . _ Penetration Body Metal Loss Body Page 6 ~ ~ PDS Report Cross Sections Well: 1 D-O1 Survey Date: October 4, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No, of Fingers: 24 Tubing: 3.5 ins 9.3 ppf I-55/L-80 Analyst: B. Qi Cross Section for Joint 67 at depth 2085.55 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.5 Tool deviation = 15 ° Isolated Pitting .07 ins = 26% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 ~~ PDS Report Cross Sections Well: 1 D-O1 Survey Date: October 4, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f -55 L-80 _ _ __ Analyst: B. Oi Cross Section for Joint 147 at depth 4584.11 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.5 Tool deviation = 47 ° Isolated Pitting .06 ins = 24% Wall Penetration HIGH SIDE = UP • • Cross Sections page 2 ~i~ 1 ConacoPhillips Alaska, Inc. • KRU 1D-01 -o, API: 500292039300 Well T : PROD A le TS: 32 d 7766 SSSV Type: TRDP Orig Com lotion: 11/28/1979 Angle ~ TD: 29 deg ~ 8365 sssv 1s°s 1s°7 Annular Fluid: Last W/O: 4!14/1998 Rev Reason: TAG FILL ( - ' 00:3.500) Reference L Ref L Date: Last U ate: 12/6/2004 TUBING Last T : 7874 TD: 8365 f1K6 (a767a, Last T Dete: 11 /9/2004 Max Hole An le: 47 d 4600 oD:3.5o0, ID:2 98a) Cesin Strip - ALL STRING S . >RODUCrION eacri lion Size T Bottom ND Wt Grade Thread (0-$~5. CONDUCTOR 16.000 0 141 141 65.00 H-40 WELDED OD 7 00ti~ vuc 26 o0 SURFACE 10.750 0 2772 2702 45.50 K-55 . . ) PRODUCTION 7.000 0 8305 6863 26.00 K-55 Tubi Strip -TUBING Gas Lirt , Si e T Bottom ND Wt G de Thread Manarewahe 3.500 0 7674 6321 9.30 J55/L80 BTC-MOD 1 (z715.z71s Perforations Summ , Interval ND Zone Statue Ft SPF Date T Comment 7765 - 7782 6398 -6413 UNIT D C~ 17 4 1/4/1980 IPERF 0 deg phasing 7783 - 7832 6413 -6455 C11,C-3 49 4 1/9/1980 IPERF 0 d sin 7837 - 7845 6459 -6466 C-3 8 4 1/9/1980 IPERF 0 d basin 7851 - 7860 6471 -6479 C-2 9 4 1!9/1980 IPERF 0 d basin 7866 - 7876 6484 - 6493 C-2 10 4 1/9/1980 IPERF 0 d asin Stimulations Treatments Gas ~M Interval Date T Com ant MandrewaMe 7765 - 7876 2/12/2001 FRAC C SAND FRAC 2 (aa3o-aa31 Gas Lift Ma ndrel a Nalves , St MD ND Man fr Men Type V Mtr V Type V OD Latch Port TRO Date Run Vlv C nt 1 2715 2652 Camco KBUG GLV 1.0 BK 0.156 1234 2/18/2001 Gas rm MargreWaNe 2 4430 3915 Camco KBUG GLV 1.0 BK 0.188 1270 2/18/2001 3 3 5587 4711 Camco KBUG GLV 1.0 BK 0.250 1366 2!18/2001 (~7-~, 4 6340 5257 Camco KBUG OV 1.0 BK 0.250 0 8/30/2004 5 6988 5756 Camco KBUG DMY 1.0 BK 0.000 0 2/18/2001 6 7562 6227 Camco MMM DMY 1.0 RK 0.000 0 2/18/2001 eras lift a ui ebo. -JEW LRY MandrewaNe De th TVD Descri ~ ID a (s3ao~3a1 1806 1800 SSSV Camco TRDP-4E 2.813 , 7608 6265 NIP Camco'W Selective Profile 2.813 7647 6298 PKR Baker'SAB-3' Perm Packer w!K-22 Anch Seal Ass 2.984 7664 6313 NIP Camco'D' Ni No Go 2.750 Gaa girt „~~D,~.,my 7673 6320 SOS Baker 2.953 vaNe5 7674 6321 TTL 2.984 (~&~~~ OD 5 13 Goner I o : .3 ) Date NOte 028/200 WAIVERED WELL: 1A X OA COMMUNICATION Gas LiR ~ ndreWunmy Valve 6 (7562-7563, OD:5.313) NIP (760&7609, OD:3.500) PKR (7647-7648, OD:3.500) NIP (7664-7665, OD:3.500) SOS (7673-7674, OD:3.500) Pert (nss77s2) Pert (77s3-7aaz> Luc (ns5-7s7s) ID-Ol (PTD 1790590) & ID-36 (PT.001300) failed TIFL's Regg, James B (DOA) . Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, August 17, 200710:15 AM To: Maunder, Thomas E (OOA); Regg, James B (OOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 10-01 (PTO 1790590) & 10-36 (PTO 2001300) tailed TIFL's Attachments: 10-36 schematic. pdt; 10-3690 day TIO plot.jpg; 10-01 schematic. pdt; 10-01 90 day TIO plot.jpg Tom & Jim, ,,/ Kuparuk gas lifted producer 10-01 (PTO 1790590) tailed a TIFL on 08/16/07 and has been added to the SCP report. The TIO v immediately prior to SI tor the TIFL was 135/1150/740. A leaking GLV check is suspected. Slickline will troubleshoot the tubing leak and repair it possible. Kuparuk gas lifted producer 10-36 (PTO 2001300) tailed a TIFL on 08/16/07 and has been added to the SCP report. The TIO immediately prior to SI tor the TIFL was 145/1290/540. A leaking GLV check is suspected. Slickline will troubleshoot the tubing leak and repair it possible. Attached are the schematics and 90 day TIO plots tor both wells. Please let me know it you have questions. «10-36 schematic. pdt» «10-3690 day TIO plot.jpg» «10-01 schematic. pdt» «10-01 90 day TIO plot.jpg» Brent Rogers Problem Wells SupeNisor 659-7224 S~~NfD AUG .2 3 20D7 . 8/21/2007 . . KRU 1 D-01 API: 500292039300 Well Tvoe: PROD Anale (cì) TS: 32 dea (âJ 7766 SSSV Type: TRDP Orig 11/28/1979 Angle @ TD: 29 deg @ 8365 Comoletion: sssv Annular Fluid: Last W/O: 4/14/1998 Rev Reason: PULL PLUG, GLV (1806-1807, OD:4.250) C/O TUBING Reference Loo: Ref Loo Date: Last Uodate: 2/12/2007 (0-7674, Last Taa: 7855' TD: 8365 ftKB OD:3.5oo, LastT.te: 11/19/2006 Max Hole Anale: 47 ill 4600 ID:2.984) ~RODUCTlON (0-8305, DeserlDtion Size Tal> Bottom TVD Wt Grade Thread OD:7.0oo, CONDUCTOR 16.000 0 141 141 65.00 H-40 WELDED Wt:26.oo) SURFACE 10.750 0 2772 2702 45.50 K-55 PRODUCTION 7.000 0 8305 6863 26.00 K-55 Gas Lift t MandrelNalve Size Tal> Bottom TVD Wt ì Grade T Thread I 1 (2715-2716, I 3.500 I 0 I 7674 I 6321 T 9.30 T J55/L80 I BTC-MOD I , ~ Interval TVD Zone Status Ft SPF Date fVriA Comment 7765 - 7782 6398 - 6413 UNIT 17 4 1/4/1980 IPERF o deg phasing D,C-4 7783 - 7832 6413-6455 C-4 C-3 49 4 1/9/1980 IPERF o dea Dhasing 7837 - 7845 6459 - 6466 C-3 8 4 1/9/1980 IPERF o dea ohasing 7851 - 7860 6471 - 6479 C-2 9 4 1/9/1980 IPERF o dea ohasing 7866 - 7876 6484 - 6493 C-2 10 4 1/9/1980 IPERF ~1iìtiIii Gas Lift MandrelNalve I Interval Date I TVl>e I I 2 Comment (4430-4431, I 7765 - 7876 I 2/12/2001 I FRAC I C SAND FRAC I "-' St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Gas Lift Cmnt MandrelNalve 1 2715 2652 Cameo KBUG GLV 1.0 BK 0.156 1266 2/4/2007 3 2 4430 3915 Cameo KBUG GLV 1.0 BK 0.188 1312 2/4/2007 (5587-5588, 3 5587 4711 Cameo KBUG GLV 1.0 BK 0.188 1314 2/4/2007 4 6340 5257 Cameo KBUG OV 1.0 BK 0.250 0 2/4/2007 5 6988 5756 Cameo KBUG DMY 1.0 BK 0.000 0 2/18/2001 Gas Lift 6 7562 6227 Cameo MMM DMY 1.0 RK 0.000 0 2/18/2001 MandrelNalve . 4 (6340-6341, DeDth TVD TVDe Descrintion ID 1806 1800 SSSV Cameo TRDP-4E 2.813 7608 6265 NIP Cameo W' Selective Profile 2.813 GasLIfI 7647 6298 PKR Baker 'SAB-3' Perm Packer w/K-22 Aneh Seal Assv 2.984 .ndrellDummy 7664 6313 NIP Cameo 'D' Nioole No Go 2.750 Valve 5 7673 6320 SOS Baker 2.953 (6988-6989, 7674 6321 TTL 2.984 OD:5.313) ''<-~ Date Note Gas Lift 10/28/2002 NOTE: WAIVERED WELL: 1A X OA COMMUNICATION .ndrel/Dummy Valve 6 (7562-7563, OD:5.313) NIP (7608-7609, OD:4.520) PKR (7647-7648, OD:6.000) NIP (7664-7665, OD:4.5OO) SOS (7673-7674, OD:3.500) Perf =: ~ (7765-7782) <.; Perf 1·-'_ (7783-7832) ~ ~ FRAC ~ (7765-7876) \-- ....,,<;:. 10-01 (PTD 1790590) Report ofIA SCP . Tom & Jim. 10-01 a gas lifted producer was found with sustained pressure on the IA while SI on 1/281107. The TIIIO on 1/28107 = SII2025/1000 psi. A leaking GLV check is suspected as the source of TxlA communication. The well is waivered for minor IAxOA communication as reported on the quarterly SCP report. A tbg plug was set early this morning and the IA was successfully bled to reduce the pressure. The ¡/ T/I/O on 1/29/07 after secured = 100/1150/870 with no pressure build up. Slickline will troubleshoot the leak and replace any leaking GLVs. Attached is a 90 day TIO plot and a schematic. Please let me know if there are any questions. SCANNED FEB 2 6 2007 Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com «10-01 90 day TIO plot 1-29-07.gif» «10-01.pdf» Content-Description: ID-OI 90 day no plot 1-29-07.gif ID-Ol 90 day TIO plot 1-29-07.gif Content-Type: image/gif Content-Encoding: base64 Content-Description: ID-01.pdf ID-01.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 1/31/20079:45 AM -01 90 no . . KRU 1 D-01 API: 500292039300 Well Type: PROD Angle @ TS: 32 dea (cì) 7766 SSSV Tvoe: TRDP Orig Completion: 11/28/1979 Angle @ TD: 29 dea (cì) 8365 sssv Annular Fluid: Last W/O: 4/14/1998 Rev Reason: TAG FILL (1806-1807, Reference Loa: Ref Log Date: Last Update: 11/24/2006 00:4.250) Last Taa: 7855' TD: 8365 ftKB TUBING Last Taa Date: 11/19/2006 Max Hole Angle: 4711I4600 (G-7674, 00:3.500, Description TVD Wt Grade Thread 10:2.984) Size Top Bottom CONDUCTOR 16.000 0 141 141 65.00 H-40 WELDED SURFACE 10.750 0 2772 2702 45.50 K-55 PRODUCTION 7.000 0 8305 6863 26.00 K-55 Gas Lift Size I Top I Bottom I TVD I Wt I Grade I Thread MandrellValve 3.500 I 0 I 7674 I 6321 I 9.30 I J55/L80 I BTC-MOD 1 (2715-2716, ..øratìol\l'liim'm.li:II. ;Œ;fff@ffifi 00:5.313) Interval TVD Zone Status Ft SPF Date Type Comment 7765 - 7782 6398 - 6413 UNIT 17 4 1/4/1980 IPERF o deg phasing D,C-4 7783 - 7832 6413 - 6455 C-4,C-3 49 4 1/9/1980 ¡PERF o deg phasina 7837 - 7845 6459 - 6466 C-3 8 4 1/9/1980 ¡PERF o deg phasina 7851 - 7860 6471 - 6479 C-2 9 4 1/9/1980 ¡PERF o deg phasina 7866 - 7876 6484 - 6493 C-2 10 4 1/9/1980 IPERF o deg phasina Ilìm:QI~11 ww iiiii: EUEE Gas Lift Interval I Date Type Comment MandrellValve 7765 - 7876 I 2/12/2001 FRAC C SAND FRAC 2 (443G-4431, fU: 00:5.313) St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt Gas Lift 1 2715 2652 Cameo KBUG GLV 1.0 BK 0.156 1234 2/18/2001 MandrellVal1ie 2 4430 3915 Cameo KBUG GLV 1.0 BK 0.188 1270 2/18/2001 3 (5587-5588, 3 5587 4711 Cameo KBUG GLV 1.0 BK 0.250 1366 2/18/2001 00:5.313) 4 6340 5257 Cameo KBUG OV 1.0 BK 0.250 0 8/31/2006 5 6988 5756 Cameo KBUG DMY 1.0 BK 0.000 0 2/18/2001 6 7562 6227 Cameo MMM DMY 1.0 RK 0.000 0 2/18/2001 Gas Lift MandrellVal1ie 4 (6340-6341, DeDth TVD Type Description ID 00:5.313) 1806 1800 SSSV Cameo TRDP-4E 2.813 7608 6265 NIP Cameo W' Selective Profile 2.813 7647 6298 PKR Baker 'SA B-3' Perm Packer w/K-22 Aneh Seal Assy 2.984 7664 6313 NIP Cameo 'D' Nipple No Go 2.750 7673 6320 SOS Baker 2.953 7674 6321 TTL 2.984 .~·].Q~eij w Date I Note ~ 0/28/2002 W AIVERED WELL: 1A X OA COMMUNICATION NIP (7608-7609, 00:4.520) PKR (7647-7648, 00:6.000) NIP (7684-7665, 00:4.500) SOS (7673-7674, 00:3.500) Perf ~ þ: (7765-7782) <. t'> Perf < (7783-7832) 15 --'- ~ '-.-- .. nmm" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 105 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service Kuparuk Unit 4. Location of well at surface 8. Well number 237' FSL, 601' FEL, Sec.14, T11 N, R10E, UM (asp's 560483, 5959903) 1D-01 At top of productive interval 9. Permit number / approval number 1409' FNL, 1361' FEL, Sec.14, T11 N, R10E, UM (asp's 559690, 5963531) 179-059 At effective depth 10. APl number 50-029-20393 At total depth 11. Field / Pool 1113' FN L, 1326' FEL, Sec.14, T11 N, R10 E, UM (asp's 559723, 5963827) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8365 feet Plugs (measured) Tagged Fill (2/16/01) @ 8008' MD. true vertical 6916 feet Effective depth: measured 8008 feet Junk (measured) true vertical 6605 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" 21 6 Sx AS II 114' 114' SURF CASING 2667' 10-3/4" 3000 Sx AS II 2772' 2702' PROD CASING 8200' 7" 1600 Sx Dowell 8305' 6863' Perforation depth: measured 7765 - 7782'; 7783- 7832'; 7837 - 7845'; 7851 - 7860'; 7866 - 7876~ J~ C ~ i V E D APR O9 200 true vertical 6398 - 6413'; 6413 - 6455'; 6459 - 6466'; 6471 - 6479'; 6484 - 6493' ;?',laska OiJ & Gas Cons. CornrnissJo~ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J55 & L80 Tubing @ 7674' MD. Anchorage Packers & SSSV (type & measured depth) Baker 'SAB-3' Perm Packer w/K-22 Anchor Seal Assy @ 7647' MD. Camco TRDP-4E @ 1806' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 589 683 923 229 Subsequent to operation 1209 926 624 240 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Date ~///~//~/ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1 D-01 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 2/10/01' RIH & tagged PBTD at 8025' MD. 2/12/01' MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 16/20 & 12/18 mesh proppants, through the 'C' sand perforation intervals located at: 7765- 7782' MD 7783- 7832' MD 7837- 7845' MD 7851-7860' MD 7866-7876' MD Pumped Breakdown w/192 bbls of 20# Linear Gel @ 30 bpm, followed by Shutdown. ISIP @ 1789. Resumed pumping Data Frac w/100 bbls of 50# Crosslinked Gel @ 15 bpm, followed by Shutdown. ISIP @ 2215. Resumed pumping Frac Treatment w/120 bbls Crosslinked Pad, followed by Crosslinked Slurry stages w/proppant ramped in stages from 2 to 10.3 ppa, followed by Flush, followed by Shutdown. Placed 78,200 lbs of proppant in the formation. RD. 2/13/01: RIH w/CT & jetted a proppant fill cleanout to 8095' MD. 2/16/01' RIH & tagged fill at 8008' MD. Returned the well to production w/gas lift & obtained a valid well test. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 28, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-01 (Permit No. 79-59) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent workover operations on KRU 1D-01. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kupamk Drill Site Development WSI/skad RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well /. ,-h ? .r) ?, L OIL ~] GAS r~ SUSPENDED F-] ABANDONED [~]SERVICE [~] ,~l~_qk~ 0il S Gas 2 Name of Operator 7 Permit Number Anchorage ARCO Alaska, Inc 79-59 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20393 4 Location of well at surface 9 Unit or Lease Name 237' FSL, 601' FEL, Sec. 14, T11N, R10E, UM f ] '~f~l~~ Kuparuk River Unit ~ :~ - ; il- -~[~ ]i 10 Well Number 1409' FNL, 1361' FEL, Sec. 14, T11N, R10E, UM -- ~' : ~,~~I 1D-01 At Total Depth ~ .... ! ~., ~ i 11 Field and Pool ~.~. · . 1113' FNL, 1326' FEL, Sec. 14, TllN, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 8 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 105'I ADL 25650 ALK 468 12 Date30.Oct_ToSpUdded 13 Date16-Nov-79T'D' Reached 14 Date13-Apr-98Comp', Susp. or ~and. 15 WaterNADepth, ff offshorefeet MSL 16 No.2of Completions 17 Total Depth {MD+B/D) 18 Plug Back Depth {MD+'I'VD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 8365' MD & 6903' 'I'VD 8260' MD & 6807' 'I-VD YES U NO ~ 1806 feet MD 1465' APPROX 2:?. Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD J CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 65# H-40 SURF. 114' 24' 216 sx ASII 10.75' 45.5# K-55 SURF. 2772' 13.75' 3000 sx AS II 7' 26.0# K-55 SURF. 8305' 9.875' 1600 sx Dowell 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' 7674' 7647' 7765'-7832' MD 7837'-7845' MD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7851'-7860' MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7866'-7876' MD 8066'-8080' MD 4 spf 0 Date First Production IMethod of Operation (Flowing, gas lift, etc.) r'~ I L,~. Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing ;Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ;ommissiota Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 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. 31. LIST OF ATrACHMENTS Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. · Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 4/27/98 ARCO ALASKA INC. WELL SUMlZ_ARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-01 WELL_ID: 999220 TYPE: AFC: 999220 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:04/07/98 START COMP:04/07/98 RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-20393-00 04/07/98 (C1) TD: 8260' PB: 8260' SUPV:MC CIRC SEAWATER MW:10.7 LSND Move rig from 1D-115 to 1D-01. Rig up. Valve leak. Service leaking 7" annular valve. Accept rig @ 1000 hrs. 4/8/98. 04/08/98 (C2) TD: 8260' PB: 8260' SUPV:MC CIRCULATING TO EVEN OUT 1 MW:ll.2 LSND Pump seawater down tubing taking returns through choke. Reverse circulate seawater down annulus taking returns through choke. Build kill weight fluid. 04/09/98 (C3) TD: 8260' PB: 8260' SUPV:MC POOH W/3.5" TUBING & PACK MW:ll.2 LSND Continue to raise surface volume to 11.3 ppg. Continue to circulate 11.3 ppg kill weight fluid until no pressure of flow. Well dead. ND tree. NU BOP. Test BOPE @ 300/3000 psi. Unable to shear SBR in packer. Work pipe. 04/10/98 (C4) TD: 8260' PB: 8260' SUPV:MC RIH W/ 6-1/8" BIT & CASIN MW:ll.3 LSND Packer free. Well flowing. Circulate well to 11.3 ppg mud. Well dead. POOH. Well beginning to swab. CBU. Returns carrying large amount of rubber to surface. (No noticible gas.) Well flowing. Build mud wt in pits back to 11.3 ppg. Well dead. Continue POOH slowly. Well swabbing slightly. 04/11/98 (C5) TD: 8260' PB: 8260' SUPV:MC POOH L/D 3-1/2" DP. MW:ll.3 LSND Continue POOH standing back 3-1/2" tubing. L/D Baker EL-1 SBR, 1-Joint Tubing, Baker FHL Packer, 1-Joint Tubing 'D' Nipple, Pup Joint and Shear Out Sub. 04/12/98 (C6) TD: 8260' PB: 8260' SUPV:MC RIH W/ 3 1/2" COMPLETION MW:ll.3 LSND Test BOPE to 3500 psi. POOH laying down 3-1/2" DP and BHA ~1. RU to run completion. Date: 4/27/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/13/98 (C7) TD: 8260' PB: 8260' SUPV:MC 04/14/98 (C8) TD: 8260' PB: 8260' SUPV:MC MW:ll.3 LSND Rib with 3.5" completion string drifting tubing. Set packer and test tubing @ 2500 psi. ND BOPE and NU tree. Test tree @ 250/5000 psi. Displace well to seawater. PREPARE TO RELEASE RIG MW: 0.0 LSND Freeze Protect well. Clean Pits. Secure well and release rig @ 0700 hrs. End of WellSummary for We11:999220 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh.~_?~n, DATE: April 9, 1998 Chairmarf,;r THRU: Blair Wondzell,~ FILE NO: .DOC P. I. Supervisor FROM: Larry Wade,~._ SUBJECT: BOP Test. Petroleum idispe¢_,, tor Nordic 2 ' KRU 1D-01 PTD 79-59 April 9,1998: I traveled to Kuparuk to witness a BOP test on Nordic 2. 1D pad is very busy with 2 rigs and the West Sak start-up. It was crowded but orderly They were ready to start when I arrived on location. In testing the BOP's we encountered a Graylok leak, a ram door leak and a flange leak under the hydril. The leaks were fixed and there were no component failures. SUMMARY: i witnessed a BOP test on Nordic 2. 4 hours 0 failures Attachments: aavgdife.xIs cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:~ Workover: X DATE: 9-Apr-98 Drlg Contractor: Nordic Rig No. 2 PTD # 79-59 Rig Ph.# 659-7565 Operator: ARCO Rep.: Mark Chambers Well Name: ~ F,_U 1D-01 Rig Rep.' Ron Holmes - . . Casing Size: 7" Set @ 8306' Location: Sec. T. R. ~ Meridian Test: Initial X Weekly Other Test Hazard Sec. X PTD On Location X Standing Order Posted MISC. INSPECTIONS: Pressure P/F Location Gen.: ok Well Sign X 250/5,000 P Housekeeping: ok (Gen) Drl. Rig ok 250/5,000 'P' 50/5,ooo ' 250/5,000 P FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP 1 Lower Kelly / IBOP Ball Type 1 Inside BOP BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 1 250/2500 I 250/5,000 250/5,000 250/5,000 f 250/5,000 I 250/5,000 I 250/5,000 250/5,000 MUD SYSTEM: Visual Trip Tank X Pit Level Indicators X Flow Indicator X Meth Gas Detector X H2S Gas Detector X P/F Test P CHOKE MANIFOLD: Pressure P No. Valves 12 250/5,000 No. Flanges 36 250/5,000 P Manual Chokes '! Functioned P Hydraulic Chokes I Functioned P P P/F P P ACCUMULATOR SYSTEM: System Pressure 3000 I Pressure After Closure 2100 I Alarm 200 psi Attained After Closure ~ minutes 18 sec. X System Pressure Attained 1 minutes 22 sec. X Blind Switch Covers: Master: X Remote: X X Nitgn. Btl's: 2'!00, 2200, 2200, 2200 X Psig. X Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7,542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12/94) aavgdife.xls / / Drill Site lA · Well No. '" 1A-4 "'"lA- 5 '~lA-7 ~1A-9 "1A-11 "1A-12 %IA-14 '~ 1A-15 ",.lA-16A ATTACHMENT II KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82~ d - 5/7/82,,) ~ 1/25/82'-%~'~ 3/23/83 / ,¢, · 1/19/83'") ~"- 3/21/83/ 3/8/82 4/1/82 6/5/82 5111182,% '-- u8/8 ,,, ,o Drill Site Well No. Log Date ~'~18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81~'--~ '~ 3/12/82/ ~-18-6 11/18/81~ "~ 9/10/82~ "18-7 11/23/81 ~-18-8 12/28/81"% "~ 8~4/82/ %18-9 ~ 6/24/82.__-,~.), ",., 8/3/84-- lB _/ Drill Site 1C Wel 1 No. '"~lC-1 "~1C-2 "1C-3 "~1C-4 '%~1C-5 "~1C-6 "~1C-7 '~ 1C-8 Log-Date 5/9/8'1 5/8181 7/13/81 11/8/81-~ 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Log Date ~- 5/23/83/.. '~lD-3 8/5/80'm' 1D-4 ~7/30/80%' ~ ~8/13/80/~m ~'"lD-5 6/11/81 .._ ~1D-6 6/9/81 'F-... ~1D-7 6/8/81 . · . . ~1D-8 (WS-8) 5110178 ' ~ ._ · _ - . -. .. . . _ ARCO Alaska, inc. : '--- -.~' ) 3£'- :-. '.: ,~ ~- z~-L:: ~.~';~' - : ~ ~. ,;cr',.~ ~- 277 5~3T Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis 1C-1 Static BHP lC-5 " " 1C-6 Gas Disp. 1C-7 PBU 1C-9'~fFalloff Test 1C-lO~ --~_ " " 1D-1 Static BHP 1D-5 Falloff Test 1E-12 Flow BHP/GLV 1E-17 Static BHP 1E-18 " " 1E-24 Injectivity 4/12/84 Camco 4/13/84 " 5/16/84 Otis 4/20~21 Camco 4/29/84 " 5/06/84 " 4/19/84 " 4/29/84 Otis 7/01/8484 Camco 1/8-11/84 Otis 1/03/84 " 6/21-22/84" 2F-8 T Log PBU 2F-11 Initial PBU 2F-12 Initial Well 2F-13 " " 2F-14 PBU 2F-15 PBU State /cat Receipt Acknowledged: B. Adams 5/06/84 Otis 5/22/84 Camco 5/15/84 '-' 5/14/84 Otis 5/03/84 " 4/26/84 Camco D&M DISTRIBUTION W.V. Pasher ~. K. amman 'fz F.G. Baker P. Baxter BPAE Drilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska Sohio Union Chevron NSK Operations RaD Well riles ARCO Alaska, Inc. Post Office B(,.. ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 18, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton: Enclosed are revised well completion reports and gyroscopic surveys for the following wells: 1D-1 1D-2 1D-4 1D-5 1D-6 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG: tw GRU4/L110 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany "~ ' ' ' .----., STATE OF ALASKA ,----, ~ ALASK; - AND GAS CONSERVATION ( MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well R~¥T S]~) Classification of Service Well OILX[~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number t/ ARCO Alaska, Inc. 79-59 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20393 4. Location of well at surface 9. Unit or Lease Name 237' FSL, 601' FEL, Sec.14, T11N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1428' FNL, 1334' FEL, Sec.14, TllN, R10E, UM 1D-1 At Total Depth 11. Field and Pool 1126' FNL, 1321' FEL, Sec.14, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupa ruk Ri vet 0i 1 Pool 105' RKB ADL 25650 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/30/79 11/16/79 11/28/79' N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8365'MD,6915'TVD 8259'MD,6823'TVD YES [] NO [] 1910 feet MDI 1400' (Approx) 22. Type Electric or Other Logs Run DIL/SP/GR, DL/CNL/BHCS, 4-arm Cal, CBL/VDL/GR/CCL, LL, CO, Spectralog 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 71' 24" 216 sx AS II 10-3/4" 45.5# K-55 Surf 2772' 13-3/4" 3000 sx AS II 7" 26.0# K-55 Surf 8305' 9-7/8" 1600 sx Dowell self-stre:;s cmt 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) 7765' - 7782' 3-1/2" 7670' 7633' 7832' - 7783' w/4 spf 7866' - 7876' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7851 ' - 7860' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7837' - 7845' All perforated 3000 gal - 7-1/2% HCL & intervals 9000 gal - 12-3 Mud Acid 2000 oal WF40J-347 Pad & 22.000 gal Stra'r. afra~_ w/7G;l~00~ san 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 01/05/80I F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO 1/5-26/80 162.5 TEST PERIOD I1~ 9746.1 3784.1 - 96/64 388 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 240 0 24-HOUR RATE ~ 1933 757 - 23.0° APl 28. COF~ E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE · . Form 10-407 GRU4/WC16 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 7766' 7910' 8052' 8163' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies} 32. 30. FORMATION TESTS TRUE VERT. DEPTH 6399' 6521' 6643' 6739' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. See results attached to original completion report. ' I hereby certify that the foregoing is true and correct to the best of my knowledge / - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 only 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' Indicatk 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' if no cores taken, indicate "none". KUPARUK ~iNEERINS Bose/Shelby J. Matthews TranSmitted herewith are the fol lowing- - PLEASE I',DTE' BL - BLUELI NE, S - SEPIA, F F I LM, T - TAPE, l( t( '1 IPT A~¥LEDSED: ' PLEASE ~ RECE ! PT TO: ARCO ALASKA, INC. ATTN: SHELBY J. MA'F[HB~'~ - ATO/111 5-B: P. O. BOX 100360 A,NCHCR4GE, Al(. 9951O KU-PARUK ~GINEERING TO: William VanAlen Transmitted her~ith are the following: · D. W. Bose/Lorie I,. Johnson P!,FASE NOTE: BL~- BLUELINE, S - SEPIA, F - FIlet, T - TAPE, ' ARCO ALASKA, INC. AT1/q: LORIE L. JOHNSON AFA/31~~'~ ~ .... -- "r'.'~ I, ~';. P. O. BOX 360 ANCHdR~GE', AK. 99510 - -,- ----~ STATE OF ALASKA ALASKA C._AND GAS CONSERVATION CO-'. .... ,.ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' Classification of Service Well 1. Status of Well . OIL F-IX GAS [] SUSPENDED [] ABANDONED [] .SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 79-59 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 5o- 029-20393 4. Location of well at surface 237'FSL, 601'FEL, Sec 14, TllN, R10E, UM 9. Unit or Lease Name Kuparuk 25650 At mop Producing lnterval 1409'FNL, 1361'FEL, Sec 14, T11N, R10E, UM 10. WellNumber 1D-1 At Total Oepth 1113'FNL, 1326'FEL, Sec 14, T11N, R10E, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 105' RKB[ ADL 25650 Kuparuk River 0il Pool 12. Date Spudded 10/30/79 13. Date T.D. Reached 11/16/79 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns 11/28/79 feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thicknesso'f Permafrost 8365' 6903' 8259' 6807' YES []X NO [] 1910' feet MD 1650' (approx.) 22. Type Electric or Other Logs Run DIL/SP/GR, DL/CNL/BHCS, 4-arm Cal, CBL/VDL/GR/CCL, LL, CO, Spectralog 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZEIWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# Wel~ted H-40 Surf 71' 24" 216 sx Aretieset 1T emt 10 3/4" 45.5# B,~tt K-55 Surf. 2772' 13 3/t~ 3000 sx Areticset II cmt · . 7" 26# BuU- K-55 Surf 8305' 9 7/8 1600 sx Dowell se :f stress cmt . 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) 7765 ' -7782' ~ I/2" 7~7f~' 7~' 7866 ' -7876' 7851 '-7860' w/4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7837 '-7845' -- DEPTH INTEBVA.L (MD) AMOUNT & KIND OF MATERIAL USED 7832'-7783' 77KS'-7RTK' ~lql3f~ n~l 7 1/2o~ 14Pl ~nH 'cH]lq 8066'-8080' ~] 1:~_=~ M,,,4 a,.,;,4 ~nnn -' ~ ':' gag ,,, -ru~,-.,-r, , 27. PRODUCTION TEST Date First Production Method of.Operation (Flowing, gas lift, etc.) . 12/15/81 Flowinc Date of Test Hours Tested PRODUCTION FOR' OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/5-26/80 162.5 : TESTPER OD I~ 97t*(-,_'1 378~:7 9&/~/a. 388 Flow Tubing Casing Pressure CALCULATED-i~ OtL-BBL GAS-MCF WATER-BBL oil (~'R~&QITY-API (corr) Press. 220 :. 24-HOUR RATE ~ ' 1933 757 -- 23.0°API 28. CORE DATA -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A - : ,- · MAR 6ommi~iorl Cons. Form 10-407 Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk River Form. Base Kuparuk River Form. GEOLOGIC MARKERS MEAS. DEPTH 7770' 8164' /RUE VERT. DEPTH 6388' 6727' 30. FORMATION TESTS Include interval tested, pressure data, at', fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ '%~d ' ~) ' C~ INSTRUCTIONS TitleArea Ops. Engr. Date MAR 1 O' 1982 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". TRAi!SM!TTAL .~ ~J~. FRCM: J. J. Pawel.ek/Ann Simonsen o · Transmitted herev;ith are the following' -,.. PLEASE NOTE': 'BL - BLU=L!:~, S - SEP!.-',, F - FILM, T - TAPE DATE' ARCO AI_,,_;~.,, Ii:C. ATT:" A:;~ qI , ~ ,.:~ .... [, - AFA/311 P.O. gO:,: 360 A;~Ci;O~I--- ." cc510 RECEIVEI OCT i 4 l.qSl Alaska Oil & Gas Corm. Co~lm]i$$io;] Aflchuia§~ ., -. STATE OFALASKA ALASKA .,IL AND GAS CONSERVATION C..,¢IMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, 3. Address P.O. Box 4. Location of Well 360, Inc. Anchoraqe, AK 99510 Surface Location: 237' Sec. 5. Elevation in feet (indicate KB, DF, etc.) KB-! !0.0 12. FSL, 601' FEL, 14, TllN, R10E 6. Lease Designation and Serial No. I_AD T, 25650 7. Permit No. 79-59 8. APl Number 50- 029-20393 9. Unit or Lease Name Kuparuk 25650 10. Well Number D-1 (32-14-11-10) 11. Field and Pool Kuparuk River Field Kuparuk River Oil P Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began cleanout operations on 8/23/81. RU, tested CTU to 4000 psi and Flow Lines to 1700 psi. RIH pumping diesel. 'Change over to 6% KCL WTR w/30 ppg Gel mi(.., pumped 130 bbl KCL/Gel WTR. Change over to diesel circulate 70 bbl @ 8268'. POH & RD CTU. Pumped total 119 bbl diesel. RU perf unit & test Lub to 3000 psi. Perf'd interval 8066'-8080' with Schlumberger 2-1/8" Enerjet w/4 SPF. Flowed well f/clean-up. Will be tested later. SI well on 8/25. RECEIVE!) OCT 1~ 198] A/aska 0ii & Gas Cons. CornrnissJor~ ~chorage 14. I hereby certify~that~oing is true and correct to the best of my knowledge. ~~ ~~_~3~ Area Operations Engineer Signed . ~ ~ Title The space I~l~w for Commission u4 Conditions o'"f Approval, if any: Date By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate NORTH ~LOPE ~I,GIi'~EERIHG J. J. Pawelek/Ann Simonsen Transmitted herewith are the following' PLEASE NOTE BLUELI~.,E SEPIA, F- FILM, T - TAPE ~-'~ ~' R~UR~ REu~_.PT TO' RECEIPT r,~,~,,iu,',"LED E DATE ARco ALAS~CA, INC. · I, ,0,-I~ ~_I-, AFA/311 ATTN ANH S ;x '~q~'~ - P.O. BOX 360 nOR~ AK 99510 ANC" '~ ~.e~, RECEIVED Oil & 6as ~ons. Commission Anchorage STAT.E OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. ,pR. ILLING WELL -'~ CO'MPLETED WELL {~ OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 79-59 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20393 4. Location of Well 9. Unit or Lease Name Surface location' 237' FSL, 601' FEL, Sec. 14, Kuparuk 25650 TllN, R10E ~0. well Number D-1 (32-14-11-10) 11. Field and Pool Kuparuk River Field 5. Elevation in feet ~,inoicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oil Poe KB = 110.0 ADL 25650 i2. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate i~ Abandon E] Stimulation Repair Well :_~ Change Plans [] Repairs Made Pul! Tubing ~ Other ~ Pulling Tubing (Note: Report multiple completions on Form !0-407 with a submitted Form 10-407 for each comp4-etion.) (Submit in Duplicate) [] Altering Casing [-] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). .. ARCO Alaska, Inc. proposes to cleanout frac sand in cased well D-1 which covers the lower perforations of the Kuparuk sands. The work will be done using a coil-ed tubing unit with BOP assembly tested to 4000 psi. A 3000 psi lubricator will be used for all wireline work. Ail circulated and flowed fluids will be diverted to tanks on location. The Lower Kuparuk Sand will be perforated and the well will be tested subsequent to the cleanout. The expected starting date is 8/23/81. REC[IV[D AUG 2 0 ]98] Alaska 0il & Gas Cons. O0mrnissi0,~ Subsequent ~,Vork F-,eported Anchorage S~gned14' I here~y. ~'~ ~'~'certify tha~egoing.~) ~~s true ,:-.Dp roved oy and correct to the best of my knowledge. ORIGIflA[ SIGHED BY LOHfii[ C. SMITH Title Operations Area Eh'gineer Date 8/18/81. _ COM?.-IISSiO:~ E R Approved .'o.?Y Return~J [~'10:der of The Comm,ss~oq Date Fo~m i 0~403 :-'e.. 7-] -E:3 Subm,t "Intentions" in Triplicate 0nd ,.c , ., ~t~:3$e,.iuo. rl', .~,epo:ls ~n DuPi,cale NORTH SLOPE Date. From:. J. J. Pawelek / Leo Lash Transmitted herewith are the following' Please note: BL - Blueline, S - Sepia, F - Film, T - Tape ~E RETUP~,N RECEIPT TO- ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 ARCO-Oil and Gar '-npany Alaska Ui:;i ..... Post O[lice F3ox :;00 Anci~orage, Alaska Telephone 907 27'~ September 24, 1980 Mr. Hoyle Hamilton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 c-oMM "1 co,,v M ' ] 4 ENO ' 3 GEOL ' STAT TEC STAT TEC Subject' As-Built Survey Plats FIEF:, ,.(; , .. ~..,; ti s Dear S ir' //(~4¢/~,.L~.~ ~ ~ / In an effort to insure that your files are complete, we have attached copies of our well location as-built survey plats for all wells permitted thus far in 1980, excluding those included in our original drilling permit applications. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK/jh Attachments ~ W~LL ~ ~',~I~.LL ~I Y - 5,959,904- 19 ' : ~,o,' I ~ x ~ ~60,48~,. ~ i ///._,.. LAT 70 18'~.~72" < I LONG = 149°30'36.426' . I I I ' WELL ~2 Y- 5,959,784.20 ~iiI_ x - ~60 485.20 LAm = 70 18502.492'' ~_ / WELL .~.'~ Y = 5,959,664.22 ~ 1~ I$ x= - ~o,~8~j~ I - LAT = 70 18~O1. 12" I < (~It~)RIOE,UM') WELL .~/4 = i Y 5,959,544.23 i '~~' x = ~60,487 32 D~__-L LAT-70 18'00.~31" .?' ~ LONG : 1~9°30'36.~18~ <P~ ~,i WELL ;:5 Y : 5,959,~2~.25 ~ X : ~60,~88.38 ~ ' ~ ~ LAT 70 17'58.951" o~ ~L LO.~ : ,~9°~o'~.~'~' v ~ WELL ~'6 Y = ' ~[ ~ x = ~o,~89.~ ~ mi I : LAT = 70~]7'57.771'' D~ L > < ~ LONG 149°30'36.413' I I O' A WELL ;:7 Y = 5,959,184,28 O~ ,~ X = ~60,~90.51 '~WE~T ~AKB LAT : 7o~17'~6.591'' < ~F]~ . , ........ LONG 1~9°)O~)6.609' . , : ~'.. L ) WELL ~8 Y = 5,959,O6q.29 m ] ~t L~;'' ~.~ ~"'~ ~ ~ X ~ A60, OC~L~: I":~OO' ~ LAT ~ 70~).7'55.~11" LONG' l ~9°30 ' 36. ~O7" ... ~1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ~*/49~ ~ N*~. TO PRACTICE LAND SURVEYING IN ~~~~~~' ......................... ~ THE STATE OF ALAS~ AND THAT. m~ ~~~~. C~~ <~ ~ BUILT SURVEY MADE BY HE, AND ~,%$-.[No. ,2zz-S ..'~ ' =~AT A~ ~,~S~O~S A,D 0=,~ · . ........ .-:.i~-- '~f~mm,~~ DATE ~/7/~ ' WELLS 1,2,5,~,.5,6,7,~ LOCATION5 AS-BUILT I AllanlicRichfieldCompany ~ DATE: DRAWING D,V,S,O. DlS=.,C= KU. RUK I I I I DATE' -cO / ', RES ENG /Lt E..J. 4 ENG 1 I [__~fT~ -r~c_l WELL NAME: /~"~,x::~/ NORTH SLOPE DISTRICT ENGINEERING Transmitted herewith are the following for the subject well' DATE SCALE XEROX BL SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.)- Core No. Directional Survey - Gyro Single Shot Mul ti -shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Su'rvey Fluid Density-- Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR: .. /~ DATE' PLEASE RETURN RECEIPT TO' RECE 'VE , ARCo Oi 1 A~fi~t~s Company Attn- Mr. Pete Woodring P.O. Box 360- Rm. #340-FAB Anchorage, AK 99510 ARCO O, il and Ga/~-'3mpany North Alas!~? District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 15, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS D-l, Permit No. 79-59 Dear Sir- Enclosed please find the Completion Report for DS D-1 reporting production information, along with the Perforating History. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/cr Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany =. . Form P--7 SUBMIT IN DUP%,.~,,., E* STATE OF ALASKA (See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: .~L ~_:~'I:L'L~ ' GAS WELLI I DRY ~'~ Other b. TYPE OF COMPLETION: NEW ~ WORK ~1 DEEP-~ PLUG [~1 DIFF. WELL~ OVER ~ EN ~ BACK.~ RESER. ~ Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR · P.O. Box 360 Anchorage, AK 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 237'FSL & 601'FEL, Sec 14, TllN, RIOE, ug At top prod. interval reported below 1409'FNL & 1361'FEL, Sec 14, TllN, RIOE, Ug qtIQtal doeth ll3'FNL & 1326'FEL, Sec 14, TllN, RIOE, Ug 5. APl NUMERICAL CODE 50-029-20393 6. LEASE DESIGNATION AND SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kuparuk 25650 9. WELL NO. D-1 (32-14-11-10) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Kuparuk River 11. SEC., T., R., M., (BOTTOM HOLE 0i i Pool OBJECTIVE) Sec 14, TllN, RIOE, UM 12. PERMIT NO. 79-59 18. TOTAL DEPTH, MD&TVD 119. PLUG BACK MD&TVDI20. IF MuLTIPLECOMPL., I ' ' - 8365'MD 6903'TVD ~2~'~I~D 6807'TVD I HOWs~An~ie I2,' ROTARY TOOLs INTERVALS ?RILLED B~ cABLE TOOLS All I 22. PRODUCING INTERVAL(S).OFTHISCOMPLETIQN--TOP BOTTOM. NAME (MD&TVD)* 123. WAS DIRECTIONAL Top Kup River Sands I 7766'MD 6384'TVD 'Top Kup River Sands III 8052'MD 6629'TVD! SURVEYMADE Base Kup River Sands I 7910'MD 6507'TVD Base Kup River Sands III 8108'MD 6678'~VD Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/GR, DL/CNL/BHCS, 4-arm Cal, CBL/VDL/GR/CCL, LL, CO, Spectralog 25. CASING RECORD (Report all strings set in well) f WEIGHT, LB/FT. I GRADE ] DEPTH SET (MD) HOLESlZE 5# Welded J H-40I 5.5# Butt I K-551 6# Butt I K-55 I CASING SIZE 16" 10-3/4" 7" 26. 71' 2772' 8305' LINER RECORD CEMENTING RECORD AMOUNT PULLED 24" 216 sx Arcticset II cmt 13-3/4" 3000 sx Arcticset II cmt 9-7/8" 1600 sx Dowell self stre.< 27. SIZE 3-1/2" TUBING RECORD DEPTH SET (MD) ;s cmt; SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) 28. PERFORATIONS OPEN TO PRODUCTION 7765' -7782' 7832"-7783' 78'66 ' '7876 '~" - 7851 '-7860' w/4 spf 7837' -7845' 30. (Interval, size and number) 7670' PACKER SET (MD) 7633' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) All Perforated Intervals PRODUCTION AMOUNT AND KIND OF MATERIAL USED 3000 gal - 7½% HCL & 9000 gal 12-3 Mud Acid 2000 gal WF40J-347 Pad & 22000 gal Stratafrac w/760001bs. Sand DATE FIRST PRODUCTION 1/05/80 PRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) F10wi ng IWELL STATUS (Producing or shut-In) S I DATE OF TEST. I HOURS TESTED 1/05-26/80 ] 162.5 PREss.FLOW TUBING240 ICASING- ;R ESSUR E - 31. DISPOSITION OF GAS (Sold, used for fuel Flared CHOKE SIZE PROD'N FOR OIL--BBL. ITEST PERIOD 96/64 > I 9746.1 32. LIST OF ATTACHMENTS Perforatin9 History CALCULATED OIL--BBL. GAS--MCF. 24-HOUR RATE ~ J 1933 1757 vented, etc.) GAS--MCF. WATER-BBL. JGAS--OIL RATIO I 3784.7 J - J 388 WATER-BBL. .JelL GRAVITY-APl (CORR.) J - J 23 O°API J TEST .- ~, WITNESSED BY :: J 33. I hereby certify that the foregoing ~d attached information is complete and correct as determined from all available records, *(See instructions and Spaces for Additional Data on Reverse Side) 2/15/8o INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. , Item: 16: Indicate which elevation is used as reference (where no't otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. · Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). , , 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME Summary MI:AS, DEPTH ITRUE VERT. DEPT See Attached Top Kup Sands I 7766' 6384' Base Kup Sands 7910' 6507' Top Kup Sands I I 8052' 6629' Base Kup Sands II 81 08' 6678!- .., 36. CORE DATA, ATTACH BRIEF DESCRiPTiONS OF L~THOLOGY, POROSITY, FRACTURES, APPARENT D~P$ · AND DETECTED SHOVVS OF O~L, GAS OR VVATER. None ,.. Perforating Hi story Kuparuk D-1 (32-14-11-10) API 50-029-20393, ADL 25650, Permit No. 79-59 Began rigging up for perf operations 1/3/80. Tstd tree valves & choke manifold to 4000 psi. Perf'd intervals 7765'-7782' w/4 shots per foot. Ran HP press survey @ 1000' increments. Fl-owed well. Well SI for 48 hr build up. Ran spinner survey fr/7700'-7800'. Perf'd intervals 7866'-7876', 7851 '-7860', 7837'-7845', & 7832'- 7783' RIH w/press, spinner, temp, gradiomanometer tool, taking press grad. Position tool @ 7731'. Flowed well for stabilized rate. SI well for 48 hr press build up. Took static grad. sur. Took bottom hole samples. Performed acid job w/9000 gal 12-3 Mud Acid & 3000 gal 7½% HCL. Ran press temp, spinner Sur across perfs. Set tool @ 7735'. Flowed well. Ran spinner sur f/7700'-7900', 8 passes. SI well 48 hrs to take build up measurements. Displ tbg w/diesel. Pumped frac job, 2000 gal WF40J-347 Pad & 22000 gal Stratafrac w/76000 lbs sand. RIH w/temp, spinner & gradiomanometer tool for flow test. Flowed well to stabilize. SI well 48 hrs for press build up. POOH w/prod tools taking grad. every 1000'. RD wire- line. Clean up location. Completed perf operations 1/29/80. KUPARUK D-1 TEST SUMMARY OF FORMATION TESTS Test No. Test FBHP, SIBHP, Oil, Gas, Interval psig psig STBO MSCF 7765'-7782' 1365.0 3225.5 750.1 302.5 7765'-7782' 7783'-7832' 7837'-7845' 7851'-7860' 7866'-7876' 1484.5 321 3.4 2464.5 937.5 Same as 2 1520.1 3214.4 1048.0 387.2 P~?~ Same as 2 1642.0 3198.3 5628.5 2157.5 Post Frac NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL DATE' /~//~~ NELL NAME: Transmitted hereWith are the following for the subject well- 'DATE SCALE XEROX BHC Sonic/Gamma Ray Log · Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog . Formation Density Log Formation Density Log/Gamma Ray Location Plat TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log SEPIA BL LINE ! f i / / / / I RECEIPT ACKNOWLEDGED FOR' DATE' P~~LEASE RETURN RECEIPT TO' ARCo Oil and Gas Company ~'-" Attn' Mr. Pete Noodring : P.O. Box 360- Rm. #449 Anchorage, AK 99510 1/10/80 ,~t/' ?I-CO~- NORTH-SLOPE DISTRICT ENGIHEERI?-iG TRANSMITTAL ~~ · ' Z NO- DATE: /~ / ~ ~~ WELL NAME: ~~~~ ~-~ ~ ~TAT TEC Transmitted hereWith are the following for the subject well' DATE " · SCALE //-d~ ~FC Sonic/Gamma-Ray Log · _=;,~_n~ Bond Log/VDL /~-~=~7 S~mpensated .Formation Density Log /r-~-2~ Compensated Neutron-Formation Density Comgensated Neutron Log. Core Analysis - Interval Core No. Core Description (SWC) - Interval Core DeScription (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. r/-~ Dual Induction ........ ~ . Formation Density Log Formation Density Log/Gamma Ray Location Plat , , . TVD-DIL Differential Temperature Log Spinner Survey. Fluid Density Casing Collar Log Perforating Record Nuclear Flo-log . XEROX SEPIA BL LINE ? t RECEIPT ACKNOWLEDGED FOR' DATE' ~.~PLEASE RETURN RECEIPT TO':'~ ARCo Oil and Gas Co!npany Attn' Mr. Pete Woodring P.O. Box 360- Rm. #449 Anchorage, AK 99510 BY' 1/t0/80 ARCO Oil and Gas Company c . : ,..., _ December 19, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Dear Sir' DS 6-9, Permit No. 79-73 DS 12-5, Permit No. 79-55 {~~Permit No. 79-59 Enclosed please find a Completion Report for the above-mentioned wells along with the required Gyroscopic Surveys. Very truly yours, P. A. VanDusen District Drilling Engineer /ms Attachments Form P--7 SUBMIT IN DUF ...... E* STATE OF ALASKA (See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* b. TYPE OF COMPLETION: NEW ~ WORK["--I DEEP-I---I PLUG r--I - DIFF. WELL~ OVER I I EN I I BACKI I RESER.I I Other 2. NAME OF OPERATOR Atl anti c Ri chfi el d Company 3. ADDRESS OF OPERATOR - P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsu~! ESL & 601' EEL Sec 14, TllN, R10E, UM At top prod. interval reported below 1409.'FNL & 1361'FEL Sec 14, TllN, R10E UM At total depth lll3'FNL & 1326'FEL Sec 14, TllN, R10E, UM 5. APl NUMERICAL CODE 50-029-20393 6. LEASE DESIGNATION AND SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. D-1 (32-14-11-1 0) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Kuparuk River 0il 1. SEC., T., R., M., (BOTTOM HOLE Pool OBJECTIVE) Sec 14, TllN, R10E, UM 12. PERMIT NO. 79-59 18 TOTAL DEPTH MD&TVD I19. PLUG BACK MD&TVDI20 IF MULTIPLECOMPL NTERVALS DRILLED BY · ' I DEPTH ~ ' HOW MANY* " 21. ROTARY TOOLS CABLE TOOLS 8365'MD6903'TVD 18259'MD 6807'TVD I Single ] All [ 22. PRODUCING INTERVAL(S), OF THIS COMPLETIC)N --TOP BOTTOM. NAME (MD&TVD)* J23. WAS DIRECTIONAL Top Kup. River Sands I 7766'MD 6384'TV[~ Top Kup. 'River Sands III 8052'MD 6629'TVpSURVEYMADE Base Kup. River Sands I 7910'MD 6507'TVD Base Kup. River Sands III 8108'MD6678'T~D Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/GR~ DL/CNL/BHCS~ 4-arm Cal~ CBL/VDL/GR/CCL~ LL~ C0~ Spectralo,q 25. CASING RECORD (Report all strings set in well) ~/ We!der_ 24" 216 sx Arcticset I I cmt 16I' 10-3/4" 45: ~)~f Butt 7" J ?fi# I GRADE J DEPTH SET {MD) H-40 I 71' J K-55 J 2772' I I R305' I-- I 26. LINER RECORD BOTTOM (MD) SACKS CEMENT* 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) N/A 30. DATE FIRST PRODUCT ON N/^ DATE OF TEST. 13-3/4" J 31IQF) sx Arctic_~_t IT cmtJ 9-7/8"J 1600 sx gowe!! self stre~s cmt ' J ' / SCREEN (MD) SIZE DEPTH SET (MD) 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. FLOW TUBING DEPTH INTERVAL (MD) N/A PRODUCTION JPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) JHOURS TESTED JCHOKE SIZE J PROD'N FOR OIL--BBL. TEST PERIOD ICASING PRESSURE ICALCULATED OIL--BBL. GAS--MCF. PACKER SET (MD) 7633' IAMOUNT AND KIND OF MATERIAL USED GAS--MCF. I I WE LL STATUS (Producing or shut-In) jWATER--BBL. JGAS-OIL RATIO PRESS. 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) : iWATER-BBL. I OIL GRAVITY-APl (CORR.) I TEST WITNESSED BY 32. LIST OF ATTACHMENTS Drillin§ History and Gyroscopic Survey 33. I hereby certify that the foregoing and,attached information is co~nplete and correct as determined from all available records. DAT~ 12/18/79 *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16' 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item' 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,. 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35, GEOLOGIC MARKE.RS WATER AND MUD NAME MEAS. DEPTH TRUE VER'r. DEPTI NONE Top Kuparuk Riw r 7766' 6384' Sands I Base Kuparuk Ri er 7910' .6507' Sands I ,. Top Kuparuk Riw r 8052' 6629' .~- Sands II I ~ .... Base Kuparuk Ri er 81 08' 6678' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. Ri ver Sands I I I ,,, NONE Drilling Hi story Kuparuk D-1 (32-14-11-10) API 50-029-20393, ADL 25650, Permit No. 79-59 Spudded well @ 2400 hrs 10/30/79. Drld 13-3/4" hole to 2785'. Ran DI/SP/GR, FDC/CNL/BHCS, and 4-arm CAL logs. Ran RFT. Ran 10-3/4" 45.5# K-55 csg set @ 2772'. Cmtd w/3000 sx Arcticset II cmt. Did 90 sx top job. Installed and tstd pkoffs to 2000 psi. NU BOPE & tstd to 3000 psi. Tstd Hydril to 1500 psi. Drld FC, shoe, & 12' new hole. Performed form leakoff tst to 12.5 ppg EMW. Drld 9-7/8" hole to 8365'. Ran DI/BHCS/GR. Unable to get past 4118'. RIH to 8365'. Bridge @ 4118'. Ran DI/BHCS/GR, FDC/CNL/GR, 4-arm CAL/GR, CBL/VDL/CCL/GR. RIH to 3105'. Unable to get past tight spot. Wsh & rmd to 4419' Rind to 7810'. Ran RFT tool. Tool stuck @ 5520'. RU stripping tools. Cut wireline. Stripped in hole, tagged tool, could not rec fish. RIH w/Tri-State tools. Rec fish. Ran 7" 26# K-55 csg w/shoe set @ 8305'. Cmtd csg w/1600 sx Dowell self stre~s cmt. Dropped DV dart & circ ann. RIH w/model R pkr. T6g DV. Circ ann. Pumped 126 bbls Arcticpak followed by 100 sx Arcticset cmt. Closed DV. Drld DV @ 2320', LC @ 7520', & cmt to 8259'. Tstd csg to 1500 psi. Ran Gyro & spectra log. Ran CO log, LL, & CBL logs. Ran 3-1/2" 9..2# J-55 BTC tbg w/tail set @ 7670'. Installed & tstd pkoff to 3000 psi. ND BOPE stack. NU Xmas tree & tstd to 3000 psi. Reversed out oil base mud w/diesel. Set pkr. Tstd tbg w/3000 psi, 7" x 3-1/2" ann w/2000 psi. Rig Released @ 1800 hrs 11/28/79. ARC:O AI....A.SKA, INC. F'AFI 1D, WELL NO: I SIGMA-GYRO d[..IB NO: AO983Z0201 KUF'ARU~,'. FIELD, NORT~t...$LORE., ..... ~L~$K~ .................................................................................................................................................................................... '.SIGMA/GMSO-o~,..~'"'~-~'P MD, SURVEYOR: ._IAHN/CORAM DATE RUN: 2-8EP-83 SIGMA 175 NO: 18179, PROBE NO: FORESIGHT; 1&2.1136. SURVEY TAKEN FROM WELLHEAD RECORD OF SURVEY ............................... _E~D I U8 ..OF...._CURVBTUEE...ME_T.~IOD ..................................................... ARCO ALASKA, INC. · .... ; ......... :::'.'~ ................................................................................... COMF:UTATION ................. PAGE NO. ......... 1 PAD 1D WELL NO: I ':'IOMA-GYRO ~'"';'"~":"' ,JOB NO: A0983Z0201 TIME DATE z '-' '%/i',~ ~ ~--.,, . KLIPARLIK FI ELD, NORTH SLOPE ALASKA ':':: ~] '~'C~:,..~.:~ 13: 46:24 07-0CT-8:3 TRLI~ , .... -'.' ;,.,.;L.'?m,:' MEASURED DRIFT DRIFT COLIRSE VERT~CJAU'":'~ERT'i'~:AE SUBSEA R E C T A N O LI L A R C L 0 S U R E DOGLEG DEF"rH ANGLE DIREC:TION LENGTH .... DEPTH .........SECTION:...,.; ......TVD ................. C.-.-O-.,O-R.-.D-[-.,N,.A..%.. E-.-.S-.DI~ANCE .......... DIRECTION SEVERIT'", F'EE'r D M D M FEET FEET FEET FEET FEET FEET D M DG/100F' 100. 200. 300. 400. 0.. 0 0 ...........0 ...... 0 .................... 0 ................... 0 ,-00 ..................... 0 ..00 ...... =105 ..00 ................... 0 ..00 ................ 0 ..00 ........................ 0..0.0 ........... 0 .... 0 . 0.00 0 16 N 78 4:3 E 100. 100.00 0.00 -5.00 0.05 N 0.23 E 0.23 N 78 43 E 0.27 0 16 S 84 31 E 100. 200.00 -0'.07 95.00 0.07 N 0.71 E 0,71 N 84 2:3 E 0.08 0 19 S 78 37 E.. 100. ............. 300..00 ......... c, c= ~ ..... . ,,- ~. . ....... , -=0..~4 ......... 1..~o..C~0 .......... 0,.0.~-~ ............... 1-...~o--E .............. 1....-~ ......... 0..-.89..-.41 ....E 0 06 0 14 S 60 17 E 100. 400.00 -0.50. 295.00 0.18 S 1.70 E 1.71 S 8:3 50 E 0.1"2 500. 600. '700. 800. · , 0 16 S 77 18 E 100.. .......49~,,~9 .............. =0.75 ........ 3~4.~9 ................ 0.,35--.S---: ................. 2....1,3--.E .......... ,2-...1~, ....... S-.80..-37-.E 0.09 0 14 S 88 43 E 100. =c,~, . 2. ~' .. ~,~-z.99 -0.89 494.'~9 0 41 S 5,~ E 2.61 ~3,~- '~1 2 E 0 07 0 9 N 36 28 E 100. 699.99 -0.80 594.99 0.26 S 2.~'~'c,~ E 2.89 c-._, 84 5_.0 E 0.19. 0 3. $~, 63...29.. W .... 100 ....... ~.99...99 .............. =~.68 ............ ~9~.~3t3 ................. 0....15--.S .................... 2..,79-.E ............... 2....~9 ...... S...Sb. 55. E ... O. 22 0 11 S 27 36 E 100. 899.99 -0.85 794.~9 0.34 S 2.72 E 2.75 S 82 55 E 0.20 0 1 N .4.. 2 W 1.,~,,~, ~9. .85 E ..2~87. ........ S.....83.57.E.. 0.21 0 45 N 15 38 W 1~ '1099.~~~.~¢~"":-~ ' ~.~ -~';~ N ~~.74 E 2.76 N 82 22 E 0.74 2 19 N 20 51 W 1 19'~,95 .89 E 3.4u N 32 ~ . 4 28 N 18 21 W 1(~ ." ' ' ' ' ' N O. 10 ..51 ..... 0..-3.~ ~ 15 1000. 1100. 1 ':.ZOO. 1300. 1400. 1500. '.;/ 35 N 15 10. W 100 ......... 1A~.8....1.1 ................ 33.53 ..... 13c~3.1.1 .............. 33..02... N ............. 5, 80 .W ....... 33.53 ..... N . .~... 58 W 2.28 16AO. 10 6 N 17 21 W 100. 15~6.64 50.55 1491.64 '49.44 N 10.59 W 50.56 N 12 6 W 0.65 1700. 8 14 N 15 4 W 100. 16~5.35 66.44 15~0.35 64.76 N 15.05 W 66.48 N 13 5 W 1.' 1800 8 27. N-14.-30- W ....... 100 ...... ~-7~.J~- .... JQ.~i~~ 78~0 N - --1~15~- , 8~~-~.-13..-23.,.W ......... O.. ~_. 1900. 10 3 N 12 45 W 100. 1892.99 96.99 1787.99 94.42 N 22.54 W 97.08 N 13 26 W 1.6:3 2000. 12 22 N 11 13 W 100 ........ 1~1...07 ........ 116..~3 .......1886.07 ......... 113...~5._...N ......... 26...59._W ........1.16.52 N..._13 11W 2.34 2100. 15 31N 10 37 W 100. 2088.11 140.54 1983.11 137.12 N 31.15 W 140.61 N 12 48 W 3.14 2200. 18 23 N ~ 31W 100. 2183.75 16~.69 2078.75 165.82 N 36.25 W 16~.74 N 12 20 W 2.8~ 2300. 20 10 N 7 38 W... 100 .... 2278...1~ ....... 202.68 ........217~..1~ ............. 1.98..~Z.N .......... ~1..18._W .......... 202.~70__.N_.11.. 43. W 1.89 2400. 23 28 N 6 48 g 100. 2370.96 239.77 2265.96 235.34 N 45.85 W 239.77 N 11 2 g 3.32 2500. 26 52.N 7.. 2 W 100 ..... 2~61..~ .......... 282..2O__2356~4 277.5'Z_~ ___~O..~8_W__~.~E;.2.2~__I'i_ID..2~..W ....... 3.40 2550. 27:33 N 10 52 W 50. 2505.~1 305.06 2400.~1 300.16 N 54.54 W 305.07 N 10 18 W 3.76 2600. 27 37 N 15 58 W 50. 2550.22 328.18 2445.22 322.68 N 59.91W 328.1~ N 10 31W 4.73 2700.. 28 1N 24 20 W ilO0 ......2638.66 ........ 37~..22.__2533~66 ...... 366..~6_N_._.~.75~9_W _374,.25___N._/.~3.W ..... ~.~3 2800. 30 10 N 27 31W 100. 2726.03 421.19 2621.03 410.19 N 97.26 W 421.56 N 13 20 W 2.64 ARCO ALASKA, INC. f:'AD 1D, WELL NO: I SIGMA-GYRO ?~,~. .... lOB NO: AO983Z0201 TIME DATE KUF'ARUK FIELD, NORTH SLOPE, ALASKA '~"~"%~ ~ ~? ~> ~'2~::':?~ 13: 4&: 24 07-0CT-8:3 ' MEASURED [,RIFT DRIFT COURSE VERT/'~i~E:.:¥E~'~J~AE.':~ SUBSEA R E C T A N O U L A R C L 0 S U R E DC, OLEG DEPTH ANGLE DIRECTION LENGTH DEPTH ........ SEgTI~ ............... T~B ............ ~_~......O._~_D_I_N_G._.T._.E_.S_~iS~CE ..... BI~ECTIDN SEVERIT' FEET D M D M FEET FEET FEET FEET FEET FEET D M DO/100F 2900,.' 31 .3.4 N. 27.,..~ ,~ ......... 1~0 .......281.1..~51 ...... .470...~,~ ......... 270b..8~ ............. 455. b2..1~ .... 121.,13...~ .......... AZ.I.~ :'3000. :34 23 N 28 38 W 100. 2895.72 522.30 2790.72 503.5~ N 14~,.93.W 524.5~ N 1 3100. :36 31 N 28 51 W 100. 2977.17 577.53 2872.17 554.42 N 174.84 W 581.33 N 17 30 W 2.1:3 :~;200. 3~ 2~ N 28 31 ~ 10~ ~05~..~ ...... b~b..1.~ ....... 2~..~ ~..~.~._~20A..~~_~1~..8~ ...... :~....1~ 34 .W .... 2.9E: 3:300. 42 7 N 28 20 W 100. 3131.64 6~8.50' 3026.&4 6&~.88 N 235.51 W 70&.31 N :::4£K~.. 44 57 N 27 ...47 14 . 1~0 ..... ~20~..12 ..........?~.~.~2 ...... S_Q~.I,2 ....... '..~2&...&&..N ..... 2&Z..~2....~ ....... ~Z~..._~ ..... N..20.,..l~ 3500. 45 45 N 27 9 W 100. 3274.3~ 832.53 31&~.39 787.78 N 300·75 W 845.10 N 20 3~,00. 4~ 54 N 27 ~, W 100. 3344.07 ~01.43 323~.07 853.&3 N 333.45 W ~1~,.44 N 21 20 W 0.1~, 3700. ~& 17.N. 2Z...12 W ....... 1OD .......3~1~..~,1 ..... ~.ZO..A2~3~..A1 ...... ~,LT~5._~...3&&,33_~ ......... ~.88~,I.& ...... N_21 ~&. 3800. 4t, 25 N 27 25 W 100. 3482.43 1040.05 3377.43 ~82.03 N 39~.55 W 10&0.20 N 22 8 W 0.20 4ooo se w 1DO ..... 3~9A..2~ ..... 1~73.3~ ~78~.2A ...... 1~0.1..5~.. N ...... 512.32 H .... ~2,..2~ .... N 20. 5 H 0.14 100. 3~&2.44 1~46.52 38~7.44 1473.49 N 525.70 ~ 15&4.4& N 4400. ~4~, 5S? N 10 21 W 4500. 47 0 N 10 44 W 4E, 00. 47 8 N 10 21 W 100· 4030.5~, 1619.73 3925·56 1545.47 N 539.09 W 1~,36.80 N 19 14 W 0.3' '] 4700. _46.5_4..N_ 1~ _.ID .W ....... 1.~._. ~4Cl~El~_~l__l&~2..,':19 3~'~3.73 ~1A17- _4&_1~_~.52._12 W 17CL~L~.~I~I_iEI..,5L~ W ...... O. 2~ . ' ! 4E:00. 4~, 3:3 N I0 E: W 100. 4167.23 17~,5.72 40~,2.23 1689.1~, N 5~,4.97 W 1781.14 N 1E: 30 W 0.27 47'00. 4~. 37 N 10 2:3 H. 100 ..... · 5000. 4~_. 41 N 9 4~/ W 100. 4:304.~6 1911.10 4199.5~:. 1832.26 N 590.67 H 192~.12 N 17 ~2 ~ 0.42 5100. 46 4~ N 9:38 W 100. 4373.13 1983.89 4268.13 1904.02 N 602.96 W 19'~7.21 N 17 34 W O. 15 ~i200. 4t. 31 N ~ 31 W 100. .A~1..80 .... 5:300. 4~. IGN 9 30 W 100. 4~10.7~ 2128.'~ 4405.7~ 2047·13 N 627.01 W 2141.00 N 17 2 W 0.22 5400. ~& I N ~..2& W. 1QO ..... ~80.02 .... 2201~.07' ~ZS..O2~IlEL..2EI_N ._&S~..SZ_I~__--~=~2i2..~ .... N__i~..~7..H .... ~500. 45 37 N ~ 10 W 100. 4~4~.71 2272.75 4544.71 218~.0~ N &50.47 W 2283.~ N 16 33 W 0.44 5&00. 45 19 N 8 41W 100. 4719.84 2343.99 4~14.84 2259.47 N &&l.~2 W 2354.32 N l& 19~ W 0.4t, 5700. ~4 33 N 8 1~ W 100 ..... _4~90.&3 ..... 2A1_4.5~ .... _4&85..&3 ...... 232~L..32._~ ...... ~1..~&__W__24-?~..31__~__1&___&.W., 0.81 5800. 44 13 N 8 1W 100. 48~2.10 2484.42 4757.10 2398.5~ N ~,81.90 W 2493.&1 N 15 52 W 0.39 PAD 10. WELL.. NO: 1 SIGMA-GYRO ~c ...... .,,l,>;;~,J ,.lOB NO: AO?83Z0201 TIME ELATE KIJPARUK FIELD, NORTH SI_OPE, AL~,SI<Ai. J;ili ~ ':}i?s ~.~?:?, ~i:~!!'i!~Tiij 13: 46:24 07-0CT-83 ' TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL L:;UBSEA R E C T A N O U L A R C L 0 S U R E DOGLE('~ DEPTH ANGLE DIRECTION LENGTH DE~TH SECTION ..... ~ ........ .T~D .......... C.-O...O-~-D--I--.N.A...T.....E-$-DISTANCE .... DIRECTION ::.;EVERIT FEET D M D M FEET FEET FEET FEET FEET FEET D M DO~IOOF:' 6000. 43 36 N 6 50 W 100. 5006.22 2622.83 4901.22 2536.05 N 699.93 W 2630.86 N 15 26 W 0.55 6100. 42 52 N 6 22 W 100. 5079.08 26<21.13 4974.08 2604.09 N 707.80 W 26~8.57 N 15 12 W 0.80 6200. 42 22 N 6 2 W 100 .......5152..67 ...... ~58.6~ ...... 50~. 6~ ..... ~6~1~.~N ...... ~,.15..12-.W ........ ~5.,46 ..... ~-.~ ~.,-,.5~ W ...... 0.,55 - m m m m ~ 6:30('~. 42 0 N 5 39 W 100 5226 77 2825.49 5121 77 .2738 20 N 721.95 W ~831.78 N 14 46 W 0.45 6400. 41 23 N 4 23 W 100 ........ 5301,4...4 ....... 28~1.,.6~3 ......51~6, 44 .......... 2804.,..46.-N .........-7.27.,..7.,:Z-.W..-.28~.7+35 ......... N..-1~..33. W 1.04 6500, 40 55 N 3 7 W 100, 5:376,74 2956,93 5271,74 2870,12 N 732,07 W 2962,01 N 14 1'~ W 0.96 6600, 40 1'? N 3 7 W 100, 5452,.65 3021,42 5347,b5 2935,12 N 735.61 W 3C)25,90 N'14 4 W 0,60 6700. 39 1~ N ..... 1,.,,39,..W 100 .......552~,.5Q 308~.. 68 .... 5~2~,..50 ........ 2~.~..04,-N .......... 738.27.-W ...... 3,088.,58 .......~ ,,.1.3...,50 ..W ..... 1.43 6800 .38 37 N I 53 W 100. 5607 30 3146 70 5502.30 3061 84 N 740.~1 W ':1~0 04 N 13 ~'5 ...... ¢ · ¢,~ W 0.63 'zoot,. 0 " "' .leu u 7 0.77 7100 '-~ 7200. 35 27 N 0 --.. N 740.4e u 3440. o6 N 26 W 7400. 34 13 N 0 18 E 100 .... 6091....A3 ..... 349A.30 ...... 5986.43 ..... 341,5.~8..N ...... 73~...70,_W ..... 3~95...15 ...... N 12..13 W .... Q.73 7500. 33 20 N 1 32 E 100. 6174.55 3548.70 6069.55 3471.57 N 738.81W 3549.31 N 12 1W 1.12 7600. :33 6 N 2 12 E 100. 6258.21 3602.12 6153.21 3526.32 N 737.03 W 3602.52 N 11 48 W 0, -\ 7700. -31 ~ N ...... 3 3.E ......... 100 ...... 7800. 31 51N 3 15 E 100. 6427.59 3705.37 6322.59 3632.52 N 731.67 W 3705.48 N 11 23 W 0.13 7900. 31 29 N 2 25 E _100 ....... 6512..Zl ..... 3756.35_.6~07._71 ..... 368~.._~5._,N ...... 72~.O8...W.._~756.38 .... N'..11_12 W .... 0.57 8000. 3:0 54 N 2 26 E 100. 6598.25 3806.74 6493.25 3736.70 N 726.88 W 3806.74 N 11 0 W 0.58 8100. 30 3 N 2 32 E 100. 6684.43 3856.06 6579.43 3787.36 N 724.68 W 3856.07 N 10 50 W 0.85 8168. 29 16 N 2 2 E 68. 6743.52-._3888~82 ...... 6638.52 .... 3820.~8:N ......... ~23.3A..W ...... 3888.85 ..... N-10 43..W .... 1.21 PROJECTED TO PBTD 8259. 29 16 N 2 2'E 91. 6822.91 3932.17 6717.91 3865.44 N 721.76 W 3932.25 N 10 3:5 W (~.00 .PROJECTED TO TD 8365. 29 16 N 2 2 E 106. 6915.38 3982.66 6810.38 3917.23 N 719.92 W 3~82.84 N 10 25 W 0.00 FINAL CLOSURE - DIRECTION: " I"[ lr '::"f' ~, KII-'~': / N 10 DEG8 24 M INS 50 SEC$ W ."::9R'7,...'z-:Zl FP-P'T ARCO ALASKA, INC. . PAD 1D, WELL NO: 1 SIGMA-GYRO dOB NO: AO~/83Z0201 KUP. ARUK ,.F..IELD. NORTH. SLOI~.E, ...... AL~SI~A. ' SIGMA/GMS ~' ~' ~'=.¢~ , ~,-o,.~...~ MD SURVEYOR: JAHN/COSAM DATE ~UN: 2-SEP-83 SIGMA 17~ NO: 18179, PROBE NO: 064 I::O~ES I ~HT: 162.1 136 · SURVEY TAKEN FROM WELLHEAD L Eastm. an 0 · ARC:O ALASKA, INC. . ' COM~UTATION ........................ PAGE. NO,,-.i ........ 1. ' PAD 1D, WELL NO: 1 SIGMA-GYRO ,_lOB NO: AO.983Z0201 TIME DATE . ,'. KUPARLIK FIELD, NORTH SLOPE, ALASKA 14: 0.9:08 07-0CT-83 MARKER TRUE SUBSEA [:ODE. MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL ..... NAME DEPTH .......... ~.- DEP--TH ............. DI F-F-. D~F'.TH .......... C-O.-.-O-IR ..-.D--I.--.N-A .-T.--.E ...~E:.--D I $-T. ANCE- ....... D,I RECTt, ON ..TH I CKNESS FEET FEET FEET FEET FEET FEET D M · TOP UPPER :.:;AND .................... 7766. O0 ........,~;.3~8..70.--,1367.3 .........62.9':3..70 ........ 361..4..,~,,5-.,N ........ 732..~.,4. W ...... 3688.15 ...... N,. 11....27.. W BASE LIF'F'ER SAND 7.910.00 ~,521.26 1388.7 6416.26 36.90.15 N 728.84 W 3761.44 N 11 10 W . ~8._~.41 N 10 55 W TOP LOWER ~ ~ '" =~. .- .=.AN[ ,=,Oc, z O0 6643.06 1408. ~ 6538.06 3763.07 N 725 73 W '- "~' BASE LOWER SAND 8163.00 ~.73$~.,18 1423.8-~ ~.34..-.18 ....... 381.8~5~-N ..... 7~3...43--W ....... ,388&.~46 N-IO-.44-.W ................. LEastman ,., . Whipstock' ,A t:"[: I H()I AN[: (?()It4t:~NY _. _ : ............. ~ ............................. ;_ ............... · ............ ~ ................. ~ ..... :. ....... : ^. ................................... : .................... __ _.FAB: :I:_;:_::.WEL2.~: NO :- _:::':;:'SIi~--GYEO::;-T.- ::: ::::::::::::::::::::::::7 ;::-:-.'--S~-~£-::-~:-i;,'-.:':~::S~.:FEET~ .... .... KUP^RUK F-: ELD:,--- NOR-T-B --StOPE-,-:-^-t--^SK^ ~--: .................... ::-_:: ..... ,:DEPTj~:I~D_I.~t:OB-'.._-~.IWD--':-:. ---: ..... : .... : ...... r ......... ~--- ..... : ....... ~ .................r- ................. ~ ........... L ............... ~.. - ' ::::!:::7--::--::::::--:: i ......... :-::::::: .............. ;'- '" ': 7_~ :-_F~T. MAN- ,:::: .... :_:_-7._::: :_-__ - - ..... : .... -:: -: .......... , .............. ~ .... 7 ............ : ~ ~ i : :' : ~; ' - - ' ' ~' ~ ' i.~ · I . ~. , , . ~ .; - t---- , "' i :· .$ ·' I ~ '' J ~ ' .J- " i ! ' . J , ' , i :' .. ! ' i I:*' ' ' · ._~._.:,_...__j._;.___: ..... .-{--j ~ _.~_-.'-.~ ; : ~ : · . . . -. J : , , ! : ~ : ~ ! - - ~ !'. ~ I . ! ~ , : ~ . __ __ --,---- ..... T ~ : ~ ! : ! , · . .... --: ......... : ....... ~. ........... ~__ ....... : ...... ~: ----F~N~L-$~t~iON: :-:-? : j- .'_. --, .. .... . ...... :______~_~~I3t-:~~¢::~9:1.~...'Ut:~_~ : · -.:: ;: .-~ .... : ......... : .....: ....... : .... h---- ...... ~- ....... h' CL-OSURE-:~982;8~-~'~2~-'-_4.?--W~ ' -! - :-'-::~-:_'1_:__:. · . ....... : ......... : ...... :-.'---'-----~'-----T ....... "-T :-- ----7.. - ' :' - : ....... :-'---- ...... ~- ........... . ..... 7-':'-~--- .... ,-~--' . ~: . ;.', j -::: : : :: : ~7---.:-: :- - -: ',[ :--:-':: :7-:::-:'-, ...... :----:.: :--:: -: '" : : ' ;' ' ' ' ' ' ~ *' : T : : . . . .- .: ...... : · .... : .... ....... .< ......... . .... ~~__~- ..... ~ : ' ...... ~ .... ~____ ......--. _.+___ ~ -~- .... : _ , , __ '___S____ __: : ' '---i-' . ' - 'i : ~ ~ : f ' ' ' . ' : : ' , ~ ' * 'i-- ' :'' "' , . : ~ ~ : : . : · ~ : = J : . - . . , : ~ . . , . . · . : . J · ~ , .t t : ~ J . ! - . : . . , , ...... : :' ' ' '':'' :' I :~ ' :! ..... ' : . . i : i : · ' * : : ; ~ ~ .' i . ..' , i . ....... · .... : :---4 ' !. ': J .: :! .· , : ~, : ;.,· ! · : ~ :. : - ...... ! ' "- - · - .... ~ ,~ . i : ~. : ........ ~ ~ i .', I'' i. !~ ' ' i ' ', I' · ' ~ i · ~ - , . . . , - - ' ~ ~ ~ ~ : :: ': ~ J : ~i ~ ' "' ~' T---~'-: ' ' ~i~'' --t' l ' ii l J:. ! : : ~ · . . ..... ~ : ' ~ :------~-4--~---:--., : ;.-'----' :-- : !'", · i , I , , i i; J ' i: . : ' ---~-~: '--~ ! i- '''i' : __ ,: .:_) --T i ~' ·, i- : I i : ; ,,.~ L ' . · , . . ....... --~ i ~ .__ .................. 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COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY F M LINDSEY & ASSOC RECORD OF SURVEY 12 DEC 79 WELL KUPARUK D=I K B ELEV 105 FT JOB (3804J ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER~ TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M 5UB DRIFT SEA DIREC DEG. TOTAL COORDINATES C L 0 $ U R £ S DISTANCE ANGLE D N 5 DOG LEG SEVERITY DEG/iOoFT SEC T I ON D 1 STANCE 0 0 0 100 0 0 100.00 200 0 0 200.00 300 0 0 300,00 400 0 0 400.00 500 0 0 500.00 600 0 0 600.90 700 0 0 700,00 800 0 0 800.00 900 0 0 900.00 0.00 -105,00 N O.OOE -4.99 N13,00W 95.00 N13,14W 195.00 N13,39W 295,00 N13,64W 395.00 N13.78W 495.00 N14.03W 595.00 N14.28W 695.00 N14,39W 795.00 N14.66W 1000 0 0 1000.00 895,00 N14.91W 1100 1 0 1099,99 994.99 N26.99E 1200 3 30 1199.90 1094,90 N20,25W 1300 6 0 1299,55 1194.55 NlO.44W 1400 9 0 1398.69 1293.69 N12.34W 1500 10 15 1497,28 1392.28 N22.44W 1600 9 0 1595.87 1490.87 N18.64W 1700 8 30 1694.70 1589.70 N16.91W i 800 9 30 1793.47 1688.47 N19.13W 900 11 15 1891.83 1786.83 N18.28W 2000 14 30 1989.30 1884.30 N17.46W 2100 17 0 2085.54 1980.54 N14,75W 2200 20 0 2180,36 2075.36 N13.OBW 2300 22 15 2273,64 2168,64 N 8'59W 2400 25 30 2365,07 2260.07 Nll.79W 0.00 S 0.00 W 0,00 5 0.00 W 0,00 5 0.00 W 0.00 $ 0.00 W 0,00 & 0,00 0.00 5 0,00 W 0.00 5 0,00 W 0,00 $ 0,00 W 0.00 $ 0.00 W 0,00 S 0,00 W 0,00 5 0.00 W 0.84 N 0.08 E 4.65 N 0,31 E 12.63 N 1.87 W 25.4Z N 4.45 W 41.36 N 9.44 W 57.01 N 15.30 W 71.50 N 19.95 W 86.37 N 24e79 W 103.43 N 30,56 W 124.63 N 37.40 W 150.71 N 44J93 W 181.50 N 52.55 W 216,89 N 59,33 W 255.71 N 66.49 W 0,00 $ 0 0 0 W 0.00 5 0 0 0 W 0,00 S 0 0 0 W 0,00 $ 0 0 0 W 0,00 5 0 0 0 W 0.00 S 0 0 0 W 0.00 $ 0 0 0 W 0.00 S 0 0 0 W 0,00 5 0 0 0 W' 0,00 $ 0 0 0 W 0.00 $ 0 O 0 W 0,85 N 6 2 24 E 4,66 N 3 51 28 g 12,77 N 8 26 23 W 25.81N 9 55 51W 42.42.N 12 51 55 W 59.03 N 15 1 42 W 74,23 N 15 35 28 W 89,86 N 16 0 49 W 107,85 N 16 27 46 W ,130.12 N 16 42 1'3 W 157.26 N 16 36 I W 168,96 N 16 8 59 W 224,86 N 15 17 57 W 265.18 N 14 31 14 W 0.000 0.000 0,000 '0o000 0.000 0,000 0.000 0.000 0.000 0.000 0.000 1,000 2.506 2,502 3,000 1.290 1,253 t0.501 1.002 1,750 3.250 2.511 3.006 2,340 3,304 0.00 0.00 0o00 0.00 0.00 0o00 0.00 0.00 0,00 , 0,~ 4.52 12.76 25,81 42,38 58.84 73.93 89,43 107.26 129.35 156,36 188.02 Z24,05 264.52 kRCO O/G KUPARUK D-1 GYROSCOPIC SURVEY DEC 79 JO~ {3804) RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE lEAS, DRIFT VERTICAL )EPTH ANGLE DEPTH D H SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 2500 27 15 2454.66 2349,66 N16.09W 2600 27 15 2543.56 2438,56 N22,48W 2700 29 0 2631.75 2526.75 N27.86W 2800 30 30 2718,56 2613.56 N29,56W 2900 32 45 2803.71 2698.71 N28.61W 3000 35 30 2886.48 2781.48 N29.04W 3100 37 0 2967.12 2862.12 N28.50W 3200 40 30 3045.10 2940,10 N29.03W 299.82 N 343,01 N 385.66 N 429,18 N 475.00 N 524,14 N 575,97 N 630,83 N 3300 44 30 3118.81 3013,81 N29.OOW 689,90 N 3400 46 0 3189,21 3084.21 N28,31W 752,22 N 3500 46 45 3258.21 3153.21 N28.68W 815.84 N 3600 46 15 3327.04 3222.04 N28.23W 879.61N 3700 46 0 3396e35 3291.35 N29.99W 942.59 N 3800 46 0 3465.82 3360.82 N26.73W 1005.88 N 3900 45 30 3535.59 3430.59 N20.53W 1071.47 N 4000 46 30 3605.06 3500.06 N13.34W 1140.24 N 4100 46 30 3673.89 3568.89 Nll.64W 1211.06 N 4200 46 30 3742.73 3637.73 Nll.48W 1282.12 N 4300 46 30 3811.57 3706.57 Nlle29W 1353.23 N 4400 47 0 3880.08 3775.08 NiO.61W 1424.74 N 4500 47 15 3948.12 3843.12 Nll.58W 1496.66 N 4600 46 30 4016e48 3911e48 Nll.18W 1568.21 N 4700 47 0 4085.00 3980.00 NlO.48W 1639.75 N 4800 46 15 4153.68 4048.68 NiO.O$W 1711.27 N 4900 46 15 4222.83 4117.83 N 9.14W 1782.49 N 5000 46 30 4291.82 4186.82 N 8.69W 1854.00 N 5100 46 30 4360.66 4255.66 N 9.3bW 1925.64 N 5200 46 30 4429.49 4324.49 N 9.69W 1997.18 N 5300 46 0 4498.64 4393.64 N 7.84W 2068.57 N 77.19 W 92.30 W 112.34 W 136.18 W 161.66 W 188.71 W 217.17 W 247.28 W 280.04 W 314,10 W 348,63 W 383.20 W 418.26 W 452.43 W 481.12 W 502.06 W 517.75 W 532 · 29 W 546.61 W 560.44 W 574.54 W 588.94 W 602-. 63 W 615.60 W 627.66 W 638.88 W 650.26 W 662.26 W 673.27 W CLOSURES DISTANCE ANGLE D H S DOG LEG SEVERITY OEG/iOOFT 309.59 N 14 26 14 W 355.21N 15 3 40 W 401.69 N 16 14 27 W 450.26 N 17 36 15 W 501.76 N 18 47 46 W 557.08 N 19 48 3 W 615.55 N 20 39 32 W 677.57 N 21 24 18 W 744.57 N 22 5 36 W 815.16 N 22 39 49 W 887.21N 23 8 19 W 959e46 N 23 32 24 W 1031.g2 N 23 55 43 W 1102.94 N 24 13 3 W 1174.5~ N 24 10 54 W 1245.88 N 23 45 52 W 1317.09 N ~3 8 51W 13~8.23 N 22 32 47 W 1459.46 N 21 59 42 W 1531.01 N 21 28 Z2 W 1603.15 N 21 0 4 W 1675.15 N 20 35 2 W 1746.98 N 20 10 4~ W 1818.63 N 19 47 7 W 1889.77 N 19 23 54 W 1960.99 N 19 0 49 W 2032.47 N 18 39 32 W 2104.12 N 18 20 43 W 2175.38 N 18 i 43 W 1.969 2.925 2.159 1.553 2.267 2.754 1.513 3.507 '4.000 1,542 0.77~ 0.552 0.944 2.345 3e913 1,233 0.138 0.618 0.580 0.779 J0.625 0.779 0.679 0.344 0.486 0.239 1.0~0 SECTIQN DISTANCE 308.85 354.07 399.64 446.76 495.45 549.68 605,82 b65'.23 729.26 796.72 865.55 934.54 1002.83 1071.27 i140,98 1212 ~ 1284.90 1357,42 1429.95 1502.79 1~76.06 1649.04 1794.56 1866,79 1939,15 2011,66 2084.19 21~6,39 ', ARCO O/G KUPARUK D-1 GYROSCOPIC SURVEY RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER DEC 79 JOB (3804l TRUE ~EAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D H SUB DRIFT SEA DiREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE O M $ 5400 46 15 4567,95 4462.95 N 8,61W 2139,91N 5500 45 30 4637,57 4532,57 N 9,81W 2210.77 N 5600 45 0 4707,98 4602.98 N 9,56W 2280.77 N 5700 45 0 4778.69 4673.69 NlO,23W 2350,fl3 N 5800 45 0 4849.40 4744,40 NlO.56W 2419,98 N 5900 44 0 4920.72 4815e72 NIOeO4W 2488,94 N 6000 44 15 4992'50 4887.50 N 9.11W 2557'59 N 6100 44 0 5064.29 4959.29 N 9,34W 2626,31 N 6200 42 30 5137.12 5032,12 N 4.68W 2694'30 N 6300 42 0 5211.14 5106.14 N 4.73W 2761,31N 6400 41 30 5285.75 5180.75 N 3,88W 2827,71N 683.58 W 695,07 W 707.02 W 719.17 W 731.93.W 744,46 W 756.04 W 767,20 W 775.56 W 781,07 W 786.07 W 6500 41 30 5360.64 5255.64 N 3,99W 2893.62 N 790.62 W 6600 39 45 5436,54 5331,54 N 2,61W 2958.81N 6700 39 0 5513,84 5408.84 N 2.25E 3022.23 N 794.57 W 6800 38 30 5591,83 5486,83 N 0.39W 3084,81 N 793,55 W 6900 38 0 5670.36 5565,36 N 0.34W 3146.72 N 793,95 W 7000 37 0 5749,69 5644.69 N 2,755 3207.57 N 792,67 W 7100 36 0 5830,08 5725.08 N 2.88E 3266,98 N 789,74 W 7200 35 30 5911.24 5806,24 N 3,81E 3325.31 N 786,34 W 7300 35 0 5992.90 5887,90 N 3,88E 3382,89 N 782,47 W 7400 34 15 6075.19 5970.19 N 4,84E 3439,55 N 778,15 W 7500 33 0 6158.45 6053,45 N 4,91E 3494,72 N 773.44 W 7600 31 30 6243,02 6138.02 N 5.06E 3547,88 N 768.80 W 7700 31 30 6328e29 6223.29 N 5,7BE 3599,90 N 763,89 W 7800 31 30 6413,55 6308.55 N 6,39E 3651,86 N 758,38 W 7900 31 0 6499,04 6394,04 NlO,36E 3703,17 N 750,82 W 8000 30 30 6584,98 6479.98 N 6elgE 3753,76 N 743,46 W 8100 30 0 6671.37 6566e37 N 3.08L 3803,96 N 739.39 W 8200 28 30 6758.61 6653,61 N 7,25E 3852.61 N 735,00 W 2246.44 N 17 42 56 W 2317,46 N 17 27 11W 2387.84 N 17 13 22 W 2457.99 N 17 0 45 W 2597.89 N 16 39 8 W 2667,00 N 16 2~ 4 W 2736,08 N 16 17 3 W 2803,70 N 16 3 ~1W 2869,65 N 19 47 39 W 2999,88 N 15 16 51W 79~.37 W 3063,59 N 15 1 41W 3124,94 N 14 43 48 W 3185.25 N 14 25 34 W 3245.34 N 14 9 38 W 3304,07 N 13 52 bl W 3361.08 N 13 3~ 23 W 3417.02 N 13 18 15 W 34.72,21 N 13 1 24 w 3526,47 N 12 44 ~k W 3579,29 N 12 2~ 45 W 3630.22 N 12 13 36 W 3680,05 N ~1 58 49 W 3729,77 N 11 43 54 W 3778,52 N 11 27 41W ~826,67 N 11 12 10 W 387~.16 N 10 59 59 W 3922.10 N 10 48 3 W DOG LEG SEVERITY DEG/iOOFT 0.473 0,967 0.515 0,474 0.233 1.031 0,517 0,274 '2.603 0,501 0,624 0.073 1.~39 2,066 1,139 0,500 1.501 1,001 0,590 0,501 0.809 1.250 tl,~O1 0.350 0.345 1.166 1.185 0.924 1,77~ SECTION DISTANCE ) 2228,42 2300,19 2371.20 2512,62 2582.71 2652.32 2721.93 2790.30 2857.20 2989,24 3053,84 311b,24 3177.%9 3238 ~ 3998.1b 3356,05 341Z,79 3~68,72 3~23.65 3~77.O5 3628.49 3678.75 3777.93 3826,35 3874.96 3922.03 ~RCO 0/6 KUPARUK D-1 GYROSCOPIC SURVEY 12 DEC 79 JOB (3~04) RECORD OF SURVEY ALL CALCULATIONS PERFORNED BY I B M ELECTRONIC CONPUTER TRUE 4EAS, DR!FT VERTICAL )EPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 8257 28 30 6808,71 6703.71 N 7,08E 3879.60 N 8365 28 30 6903.62 6798,62 N 7,08E :~930.74 N 731.60 W 725.25 W 30TTOM HOLE CLOSURE 3997.09 FEET AT N 10 27 14 W C L 0 $ U R E $ DISTANCE ANGLE D 3947,98 N 10 40 45 W 3997.09 N 10 27 14 W DOG LEG SEVERITY DEG/10(,)FT 0,142 0.000 SEC T I ON I.) I STANCE. ) ~947.9~ 3997.09 %RCO O/G KUPARUK D-1 GYROSCOPIC SURVEY INTERPOLATED TRU~ V~.~=T~CAL .DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE "3D~:' !'.~5 "¢' '- ~_ A.~U,~:,LD VERTICAL '~ A M E D E P T H D E P T H TOTAL COORDINATES C L 0 ,'S U'R E DISTANCE ANGLE D M S 12 DEC 79 JO8 (3804) ,SUB SEA '.- 1 -~..~ :."-1 B,4SF, :.-3 TOP ~-~ BAS~ 7766 6384.56 3634.23 N 760.69 W 7910 6507,52 3708.24 N 749.94 W ~052 6629.85 3779.94 N 7z~1.07 W 8108 5678,30 3807°95 N 739.17 W 3712.99 N I1 49 19'W 5279.56 3783.32 N 11 25 59 W 6402.62 '3B51.90 N 11 5 32 W 6524,8~ 3879.03 N 10 59 7 W 657~,30 · kRCO O/G tEASURED KUPARUK D-1 DEPTH AND OTHER DATA GYNOSCOP I C. SURVEY FOR hVERY EVEN 100 FgET OF SUB SEA DEPTH, 12 DEC 79 gO~ MEASURED DEPTH TRUE VERTICAL DEPTH SUB SEA MD-TVD DIFFEREN[E VERT I CAL CORRECTION TOTAL COORDINATE5 205 305 405 505 605 '/05 805 905 1005 1105 1205 1305 1406 1508 1609 1'710 1812 1913 2016 2120 2226 2334 2444 2557 2669 2784 2901 3023 3148 3281 3423 3568 3712 3856 4000 205, 305, 405, 505, 605, 705, 805. 905, 1005. 1105, 1205. 1305, 1405. 1505. 1605, 1705, 1805, 1905e 2005. 2105. 2205, 2305, 2405. 2505. 2605. 2705. 2805. 2905, 3005, 3105. 3205. 3305. 3405. 3505. 3605. 100 0 0 200 0 0 300 0 0 400 0 0 500 0 0 600 0 0 700 0 0 800 0 0 900 0 0 1000 0 0 1100 0 0 1200 0 0 1300 1 1 1400 3 2 1500 4 1 1600 5 1 1700 6 1 1800 8 2 1900 11 3 2000 15 4 2100 21 6 2200 29 8 2300 39 10 2400 52 13 2500 64 12 2600 79 15 2700 96 17 2800 117 21 2900 142 25 3000 175 33 3100 217 42 3200 263 46 3300 307 44 3400 351 44 3500 394 43 0,00 $ 0.OO 0,O0 S 0,00 0,OO S 0,00 S 0.00 $ 0,00 $ 0.00 N 0.93 N 4,94 N 13,15 N 26,34 N 42,64 N 5B,35 N 72,92 N 88.21 N 105,89 N 128.52 N 150,48 N 190,31 N 229e9~ N 275,50 N 324.51 N 372.52 N 422.38 N 475,4B N 535.78 N 601.92 N 678.34 N 766.69 N 859.49 N 950,15 N 1042.50 N 1140,34 N 0.00 0,00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0,13 0,20 1.96 4.65 9.95 15,73 20,36 25,42 31.36 38.57 46,35 54,48 61,28 70.52 85.07 105,28 131e74 161.92 195.13 231,10 273,62 321,80 371,84 422.42 468,97 501,53 W W W W W W W W W E E W W W W W W W W W W W W W W W W W w W W W W NRCO O/G KUPARUK D-1 GYROSCOPIC SURVEY IEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 12 DEC 79 JOb 4145 3705. 3600 440 46 4290 3805. 3700 485 4436 3905. 3800 531 4583 4005. 3900 578 4729 4105. 4000 624 46 4874 4205, 4100 669 45 5019 4305e 4200 714 5164 4405. 4300 759 45 5309 4505. 4400 804 5453 4605. 4500 848 5596 ~705. 4600 891 5737 4805. 4700 932 5878 4905. 4800 973 6017 5005. 4900 1012 39 6156 5105. 5000 1051 39 6292 5205. 5100 1087 36 6426 5305, 5200 1121 34 6559 5405. 5300 1154 33 6688 5505. 5400 1183 29 6817 5605. 5500 1212 29 6944 5705. 5600 1239 27 7069 5805. 5700 1264 25 7192 5905. 5800 1287 23 7315 6005. 5900 1310 23 7436 6105. 6000 1331 21 7555 6205. 6100 1350 19 7673 6305. 6200 1368 7790 6405. 6300 1385 17 7907 6505. 6400 1~02 17 8023 6605. 6500 1418 16 8139 6705. 6600 1434 16 8253 6805. 6700 1448 1243.10 1346,21 1450.68 1556.18 1660,60 1763,97 1867,65 1971.49 2074,99N 2177.67 2277.96 2376.20 2473,99 2569,30 266~.71 2755,85 2844,72 2932,31 3014,68 3095,~7 3173.57 3248.70 3320.71 3391.33 3459,62 3524,26 3585,71 3646.69 3706,69 3765.35 3823.11 3877.61 523,98 W 544,74 W 565,10 W 586,11 W 606,31W 624.54 W 640,82 W 657,52 W 674,06 W 689.07 W 705.71 W 723.71 W 741.45 W 757.89 W 772.32 W 779.86 W 786.96 W 792.4~ W 794.59 W 793.55 W 793.74 W 791.23 W 787.44 W 782.01 W 776.74 W 771.23 W 765.49 W 759.43 W 750,21 W 742.32 W 738.13 W 731.93 W ~,RCO O/G KUPARUK D-1 GYROSCOPIC SURVEY INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL $U8 DEPTH DEPTH SEA TOTAL COORDINATES 1000 1000. 895, 2000 1989. 3000 2886. 2781, 4000 3605. 3500. 5000 4291' 6000 4992. 4887. 7000 57/+9e 8000 6584, 6/+79. 0.00 S 124.68 N 524.29 N 185~,08 N 2557.61 N 3207.58 N 3753.79 N 0.00 W 37.26 W 188,43 W 501,54 W 6B8,36 W 755.95 W 792,88 W 7/+3.71 W 12 DEC 79 JOB (3804) HORIZONTAL VIEW ............................... ARCO OIL & GAS KUPARUK D- I RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE i%1000' ..... DEC;. 7, 1979 ·.. _ 6800 ......... 6400 ........ : : ..... : ...... ........ 6000 .... : ...... ; .........'_ _.: .... : ...... '._: .... 5600 __ _! .................. : ....... - ........ : .................. 5200 : : ~ 4800 - .- ...... i .... ' ..... ' · .. . 4400 ___ ~ ...... '_' ................ 4000 . : . .:5600 _ . · 3200 . · ....... ~ . 2800 ..... - . _.- ...................... 2400 ...... - . .' ......... . .................... :--.' ......... ; ............................................................ -7 ............................................. . ...... ............................................ ~ ...................... . ..................... - .............. ALL 'DEPTHS SHOWN ............ . .......... AR E TVD. . · -- - 400 _ - - 800 _ . .... 1200 . . 1600 .......... 2. E .......... - _ ,_' : ........ ,- . _ _ _ ...... · . ......... _ ._ VERTICAL SECTION.· ARCO OIL 8~ GAS KUPARUK D-! . RADIUS OF CURVATURE ..... GYROSCOPIC SURVEY SCALE I"= I000' DEC. 7, 1979 . - . _ ... _ _ _ _ _ . . ............ - -: ........... [ ARE TVD. . . . . . _ . _ . . ._ . . - 660o-*'~ TVD = 6,809' ................................ TMD = 8~257' .......... _. . ARCO Oil and (~ '3mpany North AI,~:_-,,.,~_ District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 12, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: D-1 Dear Mr. Hamilton' Enclosed please find a Sundry Notice outlining out plans for the above- mentioned well. Very truly yours, ~.P.A. VanDusen District Drilling Engineer PAV: mb Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. Ow~LLLD GAS D OTHERWELL 5, APl NUMERICAL CODE 50-029-20393 6. LEASE DESIGNATION AND SERIAL NO. ADL 2565O 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME ARCo Oil and Gas Company Kuparuk 25650 ADDR~S OF OPERATOR 9. WELL NO. P.O. Box 360, Anchorage, Alaska 99510 D-1 4. LOCATION OF WELL At surface 237' FSI_ & 601'FEI_ Sec 14, TllN, RIOE, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 71'GR, 105'RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 14, TllN, RIOE, UM 12. PERMIT NO. 79-59 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF l-----J PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate, Test, & Treat SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ].5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. ARCo Oil & Gas Company proposes to perforate and flow test selected intervals within the Upper Kuparuk Sands. The intervals will then receive a fracture treatment and again flow tested. An acid treatment may then be preformed on the interval. Selected intervals in the Lower Kuparuk Sands will be perforated and flow tested. A 5000 psi wireline BOP/Lubricator will 'be utilized with all wireline work. All perforated intervals and test volumes will be reported on a subsequent report. Expected start date December 17, 1979. 16. I hereby~Zing~~rTTcorrect~/~j ir .- Dist. D~lg. Engineer A""ROVED BY ~-/~ CONDITIONS OF APPROVAL, I : TITLE ............ ~ ~' ..... ~ [ ~ ' ~ ~ Instructions On Reverse Side , DATE Approved Copy Returned ARCO Oil and Ga.~'"'"'~mpany North-'Afask ,.)istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 8, 1979 Mr. Hoyle H. Hamilton State of A1 aska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject{~~Permit No. 79-59 ---DS 3-12, Permit No. 79-58 DS 12-5, Permit No. 79-55 Dear Sir- Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly you~.~ ~P. A. VanDusen District Drilling Engineer PAV'jh Enclosures RECEIVED N0V J. !979 Alaska 011 & G~,s ¢;r~ns. boi~rnisslon Ano~orage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $. APl NUMERICAL CODE 50-029-20393 6. LEASE DESIGNATION AND SERIAL NO. ADL 25650 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Kuparuk 25650 3.ADDRESS OF OPERATOR 9.WELL NO. P.O. Box 360, Anchorage, Alaska 99510 'D - 1 (xx-14-11-10) 4.LOCATION OF WELL SEC 14 , T ll N, R l0 E, UM 240' FSL, 600'~ WEL, 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay~ Kuparuk River Oil 11. SEC. T. R. M. (BOTTOM HOLE ~r~"01 OBJECTIVE) SEC 14 , T 11 N, R 10 E, UM 12. PERMIT NO. 79-59 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK lN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for October, 1979 Spudded t, lell @ 2400 hrs 10/30/79 Drld 13-3/4" hole to 1808'. As of 10/31/79, dyna drilling and surveying at PD of 1808'. 14.1 hereby~j .~ify t~at tye~egd true/find correct S,GNEIJO/d't ' t'gO/,e,, Pti"/. T,TLEDistrict Drilling Enginee6ATE 11/6/ 79 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. FoTm No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE "~'~' STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE N ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20393 6. LEASE DESIGNATION AND SL:RIAI. NO. ADL 25650 WELL WELL OTItER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic RichfSeld Company Kuparuk 25650 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360, Anchorage, Alaska 99510 D - 1 (xx-14-11-10) 4. LO(~ATION OF WELL 240' FSL, 600' WEL, SEC 14 , Tll N, R l0 E, UM 10. FIELD AND FOOL, OR WILDCAT Prudhoe Bay, Kuparuk Riv. er Oil Ii. SEC. T. R. bi. (BOTTOM IIOLE 1JO~l OBSECTIVE) SEC 14 , T 11 N, R 10 E, UM 12. PERMIT NO. 79-59 13. REPORT TOTAL DEPTH AT END OF MONTH, CtlANGES IN tlOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEFI'it SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS F1SHING JOBS JUNK IN HOLE AND SIDE-TRACKED IlOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for October,' 1979 Spudded I, Jell@ 2400 hrs 10/30/79 Drld 13-3/4" hole to 1808'. As of 10/31/79, dyna drilling and surveying at PD of 1808'. RECEIVED NOV 011 & Gas f;ons, bommisslon 14. , hereb~Xj?Z~ ?~l~e~nd correc, s,c~:,~x-t,o,~s~-- ~ ~/,__Tn~EDistrict Drilling En.qineero.XTE 11/6/ 79 'NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Alaska Oil and Gas Conservation Commission Hoyle ~. Hamilton i~t' November 13, 1979 Chairman of the Lonnie C. Smith Commissioner Ben H. LeNorman Petroleum Inspector B.O.P.E. Tests on ARCO' s Kuparuk D-i, Sec.14, TllN, R10E, UM Kuparuk River Field Monday, November 5 - I departed my home at 2:00 PM for a 2z30 PM showup and scheduled 3:30 PM departure via the Sohio-BP charter for Deadhorse. Bad weather at Prudhoe Bay delayed our departure until 5:00 PM and we arrived at Deadhouse at 6:30 PM. Weather: 25"F, winds 25 MPH from the North, low visibility. Tuesday, No~.mber 6 - B.O.P.E. test on Sohio's X-2 completed, the subject of a separate report. Wednesday, November 7 - B.O.P.E. test on ARCO's DS 6-9 completed, the subject of a separate report. ThurSday, November 8 - B.O.P.E. test on ARCO's Kuparuk D-1 were completed at 2:45 AM with results attached. I departed Deadhorse via Wien Flt. #10 at 1:40 PM arriving in Anchorage at 3220 PM and at my home at 3:50 PM. In summary, I wintessed successful B.O.P.E. test on ARCO's Kuparuk D-1. A1 ~ Oil and Gas Conservation Co~ '~ion Field Inspaction of Bl~¢ou~ Prcvonkion Equipment Operator /~,~ ~o Well /<'o to~~,~' 0 - ~ I_~ation: Sec /~ T i1~ R y~ M ~ Drilling Con~ractor ~~~ Date Repr ese nta t ive_-2~_ _~- ~_ '.~r.zK_-'-_-~~ PelTai t # 7~ - ~ IO~//~asing Set Rig f-~' P.%ores~nk~ive__~___~__~_!~ Location, General Wel 1 Sign General Housd~eeping Reserve pi~ Rig POPE S tacJ{ Annular Preventer Pipe Rams. B 1 ind Rams Choke Line Valves H.C.R. Valve Kill LJ_ne valves CI~c::]: Valve Test Results: Test Pressure __ ~ ooo 8 ooo / ACCUPYOLATOR SYST~4 Full Charge Pressure .... ~o~ psig Pres's~e After Clos~e.__~_O~ psig 200 psig P~ve Pred~auge ALhai.ned:___min ~se~ ~11 O~arge Pressure ..... ' "~- ~ min~a~e~ N2 ~1~-0~ ~meo~ Con~ols: Master _~.~ ...... Re~ote__O~B 1 in~s switdi cover Failures Ka:ll ~nc Fleer ~a}tetv Valves Upper Kel 1y .~rest P.[~es~:~ 1cot Prossu:-e Lcz~r Kelly. "~" ., Bal 1 ~e Test Inside ~P ~ Test Pressure Choke N~nifo'ld 'Pcs [: No. Valw:s /_ ~ - "' ~'-~-~Aa]u~ ~::,. le ,~ ~t-~_ ....................... ~ .......................... . . Repair 'or Replac~ent of failed equipmel',~ to be made wiU]in ~ d. ~ys and Inspector/Commission office notified. Distribution orig. - AO&GCC cc - Field operator/sur:mrvisor /~=l~×.~ ~-~.~a cc - Drilling ~pt. Suparintendent ~~ ~/~~ ___ September i7, 1979 Re: KuparUk 25650 Well No. D-1 ARCO Oil and Gas Company Permit No. 79-59 Sur. Loc.: 240'FSL, 600'WEL, Sec 14, TllN, ~10E, UM(proposed) Bottomho!e Loc.: 1320'SNL, 1320'~L, Sec 14, TllN, R10E, UM. ~r. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ing the digitized log information on all logs shall be submitted for .copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of~any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25650 #D-! -2- September 17, 1979 commencing operations you may k~ contacted by a representative of the DePar ~tment of Environmental Conservation. PursUant to AS 38.40, Local ~ire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office .within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dril lc4. In the event of suspension or abandonment, please give this office adc ~CfUate advance notification so that we may have. a wi~ess present. Very truly yours~ Hoyle H. Hamilton Alaska. Oil & Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. r- Depar~ent of Labo , Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas:'~'~mpany Alaska Regic._ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 7, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99051 Subject: D-1 Dear Mr. Hamilton: Enclosed is our Application for Permit to Drill, a sketch of the surface diverter system, and the $100.00 filing fee. The required survey plat will be sent as soon as it is available. We do not plan to core this well since West Sak #A8 was cored and these wells are on the same pad. Very truly yours, P. A. VanDusen District Drilling Engineer PAV-jh Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401 REV. 1-1-71 SUBMIT IN Till. ~TE (Other instructions on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMM~E PERMIT TO DRILL OR DEEPEN la~ TYPE OF WORK DRILL E~] b. TYPE OF WELL OIL GAS WELL [~ WELL [] OTHER NAME OF OPERATOR ARCO Oil and Gas Company 3. ADDRESS OF OPERATOR P. 0. Box 360, ^nchorage, ^laska 99510 4. LOCATION OF WELL At surface 240'FSL, 600'WEL, Sec 14, TIIN, RIOE, UM (Proposed) At proposed orod. zone @ 6380'ss 1320'SNL, 1320'WEL, Sec 14, TllN, RIOE, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 30 miles Northwest of Deadhorse API #50-029-20393 5. 6. LEASE DESIGNATION AND SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25650 9. WELL NO. D-1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oil 11. SEC., T., R., M., (BOTTOM Pool HOLE OBJECrlVE) Sec 14, TllN, RIOE 14. BONI) IN-FOPJV.~TION: Oi 1 & Gas Bond r~EStatewide S~e~and/or.No. #8011-38-40 (Federal Insurance Co.) 15. DISTANCE FROM PROPOSED * [ 16. No. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR ~s~ u~, ~. 4680' 2560 (~so to n~est ddg, u~t, ff any) 18. DIST~CE FROM PRO~SED ~CATION 19. PRO~SED DE~H TO ~A~T ~LL D~LLING, CO~LETED, OR ~PLIED FOR, ~. 8~0I e6810'TVD ~ount $1 00,000 17. NO,ACRES ASSIGNED TO THIS WELL 3 2 0 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START Not surveyed - approx 70' GL October 7, 1979 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 24" 16" 65 H-40 80'+MD cmt to surf - approx 200 ft3 3-3/4" 10-3/4" 45:5 K-55BTC 2200'.+MD Cmt to surf - approx 1800 ft3 9-7/8" .7" : 26 K-55BTC 8200'+MD Cmt with approx 1600 ft3 . ARCO Oil and Gas Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to approximately ±8200'MD, ±.6810'TVD. Selected intervals will be logged and tested. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psig RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report, A downhole safety valve will be installed and tested upon conclusion of job. A certified survey plat will be submitted before spudding. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If prOposal is to drill or deepen dixectionally, give pertinent data on sub~uxface locations and measured and true vertical depths. Give blowout preventer program. SIGNED~, .q¢ m~'~/_~.~~ DATE. - . _~/./~7_~P UTLEDistrict Drilling Engr. ~s space for State office use) ~NDITIONS OF ~PROVAL, IF ~Y: S~PLES ~ CORE C~ REQ~RED I M~ L~ ff o I []YES DI~IONAL S~Y ~qm~D ~ ~ ~o qq- q ~See Instruction On ~e~rse Side I O THER REQUIREMENTS: A.P.I. NUMERICAL CODE ~PROVAL DATE DATE. 9/17/79 SURFACE DIVERTE~ SYSTE~-I / 2. 3. 4. 16'""x' 20" X-over 20" 2000 psi dr~llin~j spool 20" 2000 psi annular preventer 6" butter, fly valves SURFACE DIVERTEd, SYSTE~'! [- o- 2. 3. 4. 16'"-'x' 20" X-over 20" 2000 psi drillin(j spool 20" 2000 psi annular preventer 6" butter, fly valves e 3. Is a ue!jistered survey plat attached ................................ is ~,:~-'l[ ', <:atr--3ff [.)u~>[~r distaxtce frc~ property line .................. 5. Is well located proper distance frcm other wells ..... ............... Is .~3,.tff'i:~ient ur~]ordicated acreage available in this pool ........... . ; .~..~ well to ke deviated ...................................... ' , :,3. Is operator the only affected Party ....................... . .......... 9. Can permit ke approved before ten-day umit ...................... '... .!.0.. Does operator have a bond in forCe., , ................ 12. ,.~ Is a co~.servation order needed ' ' ' ' , · . Is administrative apprOVal needed .. ~3. Is conductor string provided ......................................... (3) Admin 14.' Is enough cement used to cir. culate on conductor and surface ......... ~ · !5: ~'7ill cc:nt tie in surface a3x~ intermediate or production strings .... ~ __ . ,. .~urface casing protect fresh w~ter zones ............ ~ .......... ~j~ 18. Will all casJ~g give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to gooo psig .. ~ :3ditional Requirements :. · Geology: JP~ .Engineering: LCS ...." BE~ Well Histo.ry File APPENDIX Information of detailed nature that is not padiculady 9ermane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIx. · .. No special'effort has been made to chronologically organize this category of information. Reservoir Fluid Study ARCO OIL & GAS COMPANY Kuparuk D-1 Well Kuparuk Field North Slope, Alaska RFL 81216 Reservoir Fluid Analysis May 28, 1981 750! STEMMONS FFIEEWAY. BOX 47547, DALLAS, TEXAS 75247 · 214 ,'631-8270 CORE LABORATORIES, INC. "'~'~ :~':' ~':' ' Reservoir Fluid Analysis ARCO Oil & Gas Co. P. O. Box 2819 Dallas, TX 75221 Attention: Wo V. Pasher Subject: Reservoir Fluid Study Kuparuk D-1 Well Kuparuk Field North Slope, Alaska RFL 81216 Gentlemen: This report contains the results of a reservoir fluid study that was performed in our Dallas laboratory using fluid samples from the subject well. The reservoir fluid that was used in the study was prepared by ARCO, and was delivered to us in Coleman cylinders numbered 101 and 104. For our study, the fluids from the Coleman cylinders were mixed in equal proportions at 5000 psig and 70°F. The composite sample was used in all laboratory tests. The composition of the fluid was measured by low temperature fractional distillation, and is presented on page two. The pressure-volume relations of the fluid were measured at 160°F. The bubble point of the fluid was determined to be 3083 psig at this tempera- ture. The reservoir fluid was subjected to differential pressure depletion at 160°F., and evolved 462 standard cubic feet of gas per barrel of residual oil. The associated formation volume factor was 1.232 barrels of fluid at the bubble point per barrel of residual oil. Separator tests were performed at specified separator pressures and temperatures using the reservoir fluid and two differential oils that were specially prepared. The viscosity of the liquid phase was measured at 160°F. over a wide range of pressures. The viscosity varied from 2.02 centipoises at the bubble point to 9.13 centipoises at one atmosphere.' The pressure-volume relations of the fluid were also determined at 100°F. The bubble point pressure at this temperature was 2825 psig. A differential pressure depletion test was performed at 100°F., and the differential gas-oil ratio was determined to be 440 standard cubic feet of gas per barrel of residual oil. The formation volume factor at the bubble point was 1.181 barrels per barrel of residual oil. ARCO Oil & Gas Company Kuparuk D-1 Well Page Two The viscosity of the reservoir liquid was measured at 100°F., and varied from a minimum of 4.56 centipoises at 2825 psig to 26.88 centipoises at atmospheric pressure. No further testing was requested. It was a pleasure to cooperate with ARCO Oil & Gas Company by performing this reservoir fluid study. Please do not hesitate to call on us if you have any questions or comments concerning the data or if we may be of any additional assistance. Very truly yours, CORE LABORATORIES, INC. James R. Fortner Assistant Manager Reservoir Fluid Analysis 'JRF:JB:km 7cc: Addressee suBSURFACE SAMPLING DATA S~T Operator ~~O Field, Borough, State P,w. Sw.RVOIR DATA Lease & Well No. Orig. Reservoir: Press.~Z~(psig) at,III (ft). Date Current Reservoir: Press.~~d_' (psig) at_~?~ ! (ft)' Date Orig. Gas-Oil Ratio ~ SCF/STB Current Gas-Oil Ratio · BH~ Datum Plane --~Z~d) (ft Sub Sea) Reservoir Temp.. drCrO ., SC~/~. ~.N:r,T, DATA -/8 ~:US~g' Zn~erw-als'P¢~-U 78Z~ )~8~-TS~Z/- Producing: Fonr~tion Current .~rod. Rate I~! E BO?D Current Water Cut O % BZ'iTOM HOLE' CO'k'.'-DITIO:~S'- - --ii/~_ ~ Elevation !0~ (m) TubL~ SizeS/z ff,Z(L~.) Oil Gravity .Z~ (OAp: C~ent Gas-Oil ~tio ~ S~/S~ . ~t~ted B:~ Flowing ~~ (psi~ . . Original Well B. H. Pressure C~rent Well B. H. Pressure Date Shut In Depth Press. (houz~) (f%) (psig) S~J.,~.LL]~ DATA · Container No. Date Well S~-mpled TLme Well S~_mzpted Hounds Well Shut In (hrs) Fluid Level (ft) Oil Water Contact (ft) S'-~qoling Depth (ft) Sa.,,~sling Depth Press. (psig) S-~r,plin-g Tubing Press. (psig) Static '~-~ = C=.~-no Press. (psig) S~u~ler Press. After Valve Opening (psJg) S~le Transfer Press. (psig) _ ~5Cro .. 4~00 SUBSURFACE S~j~,~PLING DATA SH~. RES~RVOLR DATA C~"r) (-F,, z..~ ~,~,) Orig. Reservoir- Press.~~_(psig) at.~! (ft). Date C~)_. C-~z~ s..s) SCF/STB BHP Dar'urn Plane -- ~Z.~O. (ft Sub Sea) Reservoir Temp. Igo (°F) ~',?.T ,r, DATA ' · '7S wt'-'78~; ~; s ~C'~s ~/:' (rt) Elevation J,O~- (ft) Tubing Siz~/? ~ 9, Z~in. ) Oil Oravity · Current Prod. Rate J ~- ! f ~PD C~rent Gas-Oil ~tio . . C~'rent Water Cut ~ % Est~ted ~, F10wi~ (°APr) SCF_/ST~ (psig) BO'iTOM HOT~E CONDITIONS Original Well B. H. Pressure Cur'rent Well B. H. Pressure Date~ Shut In Depth Press. (houz~) ( ft ) (i) sig) S.a2;~LING DATA Container No. Date Well Sampled Time Well Smv~. led Hours Well Shut In (hrs) Fluid Level (ft) Oil Water Contact (ft) Savpling Depth (ft) S~,?ling Depth Press. (psig) S~spling Tubing Press. (psig) Static Casing Press. (psig) Sm~ler Press. After Valve Opening (psig) Startle Transfer Press. (psig) Sample No. ~ 1/~/8o _ 8' '~t~ - - CORE LABORATORIES, INC. Reservoir Fluid Analysis Page 1 of 28 File RFL 81216 Company ARCO Oil & Gas Company Date Sampled Well Kuparuk D-1 County North Slope Field Kuparuk State Alaska FORMATION CHARACTERISTICS Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas-Oil Ratio Production Ratio Separator Pressure and Temperature Oil Gravity at 60°F. Datum Original Gas Cap Ps~c @ PSIG , 19 Ft. SCF/Bbl Bbl/Day OF. °API Ft. Subsea WELL CHARACTERISTICS Elevation Total Depth Producing Interval Tubing Size and Depth Productivity Index Last Reservoir Pressure Date Reservoir Temperature Status of Well Pressure Gauge Normal Production Rate Gas-Oil Ratio Separator Pressure and Temperature Base Pressure Well Making Water Ft. Ft. Ft. In. to Ft. Bbl/D/PSI @ Bbl/Day PSIG @ Ft. , 19 160 °F. @ Ft. Bbl/Day SCF/Bbl PSIG, OF. 14.696 PSIA % Cut SAMPLING CONDITIONS Sampled at Status of Well Gas-Oil Ratio Separator Pressure and Temperature Tubing Pressure Casing Pressure Sampled by Type Sampler Ft. SCF/Bbl oF PSIG, . PSIG PSIG ARCO Fluids from cylinders 101 and 104 were mixed in equal proportions and used in this study. ~ These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. T[qe Interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc- tivity, proper operation, or profitableness of any oil, gas or oti~er mineral well or in connection with which such report IS used relied upon. CORE LABORATORIES, INC. R eservoir Fluid Analysis Page 2 of File RFL 81216 Well Kuparuk D-1 28 TABLE I HYDROCARBON ANALYSIS OF RESERVOIR FLUID SAMPLE Component Mol Weight Dens ity, °API Molecular Percent Percent Gm/Cc @ 60°F. @ 60°F. Weight Hydrogen Sulfide 0.00 0.00 Carbon Dioxide 0.60 0.18 Nitrogen 0.23 0.04 Methane 42.37 4.63 Ethane 4.09 0.84 Propane 2.56 0.77 iso-Butane 0.75 0.30 n-Butane 1.42 0.56 iso-Pentane 0.59 0.29 n-Pentane 0.69 0.34 Hexanes 1.09 0.64 Heptanes plus 45.61 91.41 100.00 100.00 0. 9190 22.3 294 These analyses, opinions or interpretations are based on observations and material SUPDIled by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc- tivity, proper operation, or profitableness of any oil, gas or other mineral well or in connection with which such report Is used relied upon. CORE LABORATORIES, INC. R eservoir Fluid A nalysis Page 3 of File RFL 81216 -Well Kuparuk D-1 28 S~Y OF PVT DATA - PROPERTIES OF BUBBLE POINT FLUID AT 160°F. · , , Reservoir Fluid Sample Bubble Point Pressure Reservoir Temperature Compressibility: Slightly above bubble point pressure Slightly below bubble point pressure Density at 3083 PSIG & 160°F. (Experimental) Viscosity at 3083 PSIG & 160°F. *Primary Separator Gas-Oil Ratio *Stock Tank Gas-Oil Ratio *Flash Gas Solubility *Flash Formation Volume Factor **Primary Separator Gas-Oil Ratio **Stock Tank Gas-Oil Ratio **Flash Gas Solubility **Flash Formation Volume Factor Differential Gas Solubility Differential Formation Volume Factor *Separator Conditions for Flash Data: Primary Separator: 50 PSIG & 100°F. Stock Tank : 0 PSIG & 145°F. **Separator Conditions for Flash Data: Primary Separator: 50 PSIG & 100°F. Stock Tank : 0 PSIG & 60°F. 3083 PSIG 160°F. 8,85 64.5 Vols/MM Vols/PSI Vols/MM Vols/PSI 49.89 Lbs./CF 0.346 PSI/Ft. 2.02 Centipoises 448 SCF/STB 23 SCF/STB 471 SCF/STB 1.231 RVB/STB 436 SCF/STB 19 SCF/STB 455 SCF/STB 1.225 RVB/STB 1. 232 g,-~ ~. ] R,r)~, These analyses, opinions or interpretations are Dased on observations and material supl~lled by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc- tivity, proper ol~eration, or profitableness of any oil, gas or other mineral well or in connection with which such report is used relied upon. CORE LABORATORIES. INC. R eservoir Fluid Analysis Page 4 of File RFL 81216 Well - 28 Kuparuk D-1 TABLE II FLASH PVT DATA - - Pressure, PSIG Formation Volume Factor, RVB/STB 5OOO 4500 4000 3500 3083 2000 1000 Total Gas Stock Tank in Solution, Oil Gravity, SCF/STB °API@ 60°F. 1.214 471 23.4 1.218 471 23.4 1.222 471 23.4 1.227 471 23.4 1.231 471 23.4 1.175 319 23.5 1.123 177 23.5 Separator Conditions: Primary Separator: Stock Tank : 50 PSIG & 100°F. 0 PSIG & 145°F. Pressure, PSIG Formation Total Gas Stock Tank Volume Factor, in Solution, Oil Gravity, RVB/STB SCF/STB °API@ 60°F. 5OOO 4500 4000 3500 3083 2000 loOo 1.209 455 23.7 1.212 455 23.7 1.216 455 23.7 1.220 455 23.7 1.225 455 23.7 1.170 303 23.8 1.117 167 23.9 Separator conditions: Primary Separator: Stock Tank : 50 PSIG & 100°F. 0 PSIG & 60°F. These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and conflclentlal use, this report is made. The interpretations or opinions expressed represent the best juclgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, inc. and its officers and employees, assume no resl3onsibility and make no warranty or representations as to the produc- tivity, proper operation, or profitableness of any oil, gas or other mineral well or in connection with which such report Is used relied upon. CORE LABORATORIES, INC. Reserpoir Fluid Analysis Page File Well 5 of 28 RFL 81216 Kuparuk D-1 SEPARATOR TESTS OF RESERVOIR FLUID SAMPLE Separator Pressure, Temp., PSIG OF. Gas/Oil Gas/Oil Tank Oil Formation Separator Ratio Ratio Gravity, Volume Volume Gas (1) (2) °API@ 60°F. Factor(3) Factor(4) Gravity 50 100 435 to 0 145 22 448 1.030 0.700 23 23.4 1.231 1.035 0.990 471 50 100 423 to 0 60 19 436 1.030 0.703 19 23.7 1.225 1.000 0.830 45'5 (1) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F. per barrel of oil at indicated pressure and temperature. (2) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F. per barrel of stock tank oil at 60°F. (3) Formation Volume Factor is barrels of saturated oil at 3083 psig and 160°F. per barrel of stock tank oil at 60°F. (4) Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best juclgement of Core L. aboratorles, Inc. (all errors and omissions exceptec~); Put Core laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc- tivity, proper operation, or pro?.".-ta~leness of any oil, gas or other mineral well or in connection with which such report Is used relied upon. CORE LABORATORIES, INC. Reservoir Fluid Analysis Page 6 of File RFL 81216 Well Kuparuk D-1 28 SEPARATOR TESTS OF 2000 PSIG DV OIL SAMPLE Separator Pressure, Temp., PSIG °F. Gas/Oil Gas/Oil Tank Oil Formation Separator Ratio Ratio Gravity, Volume Volume Gas (1) (2) °API@ 60°F. Factor(3) Factor(4) Gravity 50 100 287 to 0 145 22 296 1.032 0.720 23 23.5 1.175 1.035 0.980 319 50 100 278 to 0 60 18 285 1.026 0.720 18 23.8 1.170 1.000 0.830 303 (1) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F. per barrel of oil at indicated pressure and temperature. (2) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F. per barrel of stock tank oil at 60OF. (3) Formation Volume Factor is barrels of saturated oil at 2000 psig and 160~F. per barrel of stock tank oil at 60~F. (4) Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. These analys~, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc- tivity, proper operation, or profitableness of any oil, gas or other mineral well or in connection with which such report is used relied upon. CORE LABORATORIES, INC. Reservoir Fluid Analysis Page 7 of File RFL 81216 Well Kuparuk D-1 28 Separator Pressure, Temp., PSIG OF. SEPARATOR TESTS OF 1000 PSIG DV OIL SAMPLE Gas/Oil Gas/Oil Tank Oil Formation Separator Ratio Ratio Gravity, Volume Volume Gas (1) (2) °API@ 60°F. Factor(3) Factor(4) Gravity 50 100 147 to 0 145 24 152 1.036 0.754 25 23.5 1.123 1.035 0.984 177 50 100 146 to 0 60 16 151 1.031 0.749 16 23.9 1.117 1.000 0.830 167 (1) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F. per barrel of oil at indicated pressure and temperature. (2) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F~ per barrel of stock tank oil at 60°F. (3) Formation Volume Factor is barrels of saturated oil at 1000 psig and 160°F. per barrel of stock tank oil at 60°F. (4) Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. These analys~, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted}; but Core Laboratories, Inc. and its officers and employees, assume no responsibility anQ make no warranty or representations as to the produc- tivity, proper operation, or Profitableness of any oil, gas or other mineral well or in connection with which such report is used relied upon. CORE LABORATORIES, INC. Reservoir Fluid Analysis Page ~ or File RFL 81216 Well Kuparuk D-1 Pressure, PSIG Relative Volume, V/Vsat.(1) TABLE III DIFFERENTIAL AND TOTAL VOLUME PVT DATA Differential Liberation at 160°F. Gas Formation Gas in Conve?sion Liberated Volume Factor, Solution, Factor Gas Gravity, RVB/RDB SCF/RDB SCF/RVB (Air=l. 000) Calculated Gas Viscosity, Centipoises(2) 5000 0.9858 1.215 462 4500 0.9892 1.219 462 4000 0.9928 1.223 462 3500 0.9965 1.228 462 3400 0.9973 1.229 462 3300 0.9981 1.230 462 3200 0.9990 1.231 462 3100 0.9999 1.232 462 3083 1.0000 1.232 462 1.215 417 1007 0.635 0.0185 1.202 382 921 0.632 0.0177 1.190 348 829 0.626 0.0169 1.178 314 734 0.623 0.0161 1.165 278 637 0.622 0.0154 1.152 244 540 0.623 0.0148 1.139 209 444 0.626 0.0142 1.126 174 351 0.633 0.0137 1.113 138 259 0.643 0.0132 1.099 101 171 0.663 0.0127 3050 1.0019 3018 1.0039 2927 1.0097 2750 2730 1.0244 2515 1.0448 250O 2343 1.0655 2250 2118 1.0992 2000 1913 1.1381 1750 1675 1.2006 1500 1450 1.2845 1250 1217 1.4106 1000 1.5790 792 1.8514 75O 608 2.2605 50O 443 2.8965 310 3.9371 250 1.083 62 86 0.731 0.0121 92 1.066 30 34 0.899 0.0112 0 1.042 0 5 1.290 0.0101 @ 60°F. = 1.000 Gravity of residual oil = 23.2°API @ 60°F. (1) Relative Volume, V/Vsat. is total volume data for constant composition (no gas removal' expansion of bubble point fluid at 160°F. (g) Gas viscosity data calculated from gas gravity and using method of Carr, Kobayashi, and Burrows: Petroleum Transactions AIME, Vol. 201: p. 267 (1954). These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc- tivity, proper oPeration, or profitableness of any oil, gas or other mineral well or in connection with which such report Is used reliec~ upon. CORE LABORATORIES, INC. Reservoir Fluid Analysis Page 9 of File RFL 81216 Well Kuparuk D-1 28 TABLE IV VISCOSITY OF RESERVOIR FLUID AT 160°F. DURING DIFFERENTIAL LIBERATION Pressure, Viscosity, PSIG Centipoises 5000 2.41 4500 2.31 4000 2.20 3500 2.10 3083 2.02 2750 2.17 2500 2.30 2250 2.46 2000 2.64 1750 2.80 1500 3.02 1250 3.28 1000 3.52 750 3.80 500 4.45 250 5.40 0 9.13 These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is maee. The interpretations or opinions expressed represent the best jucJgement of Core Laboratories, Inc. (all errors anc~ omissions exceptecl); but Core Laboratories, inc. ancl its officers ancl employees, assume no responsibility and make no warranty or representations as to the produc- CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS~ TEXAS FIGURE I Page 10 of 28 File RFL 81216 1.9 Company ARCO OIL g GAS COMPANY Well KUPARUK D- 1 Formation County Field KUPARUK State NORTH SLOPE ALASKA 1.8 1.7 1.6 1.5 ~ 1.4 1.3 1.2 1.1 1.0 0.9 0 500 1000 1500 2000 2500 30'00 3500 4000' PRESSURE' PSIG Figure, II Page 11 of 28 Compressibilities of Oil and Gas at 160°F. File RFL 81216 --~ Well Kuparuk D-1 ....................... ~-.~ i. '.i ,--.. 4___ __ + ~ Free Gas ~- t _ 8__~ - ................ t - ": '~i ~___~ ~ ~ ~~ Saturated Oil --~ ..... ' '~ ;. ~ . ~ --~ ~--~~--- i _~~~~ : _ ~ _' _ ~ _ _ ~ - : ................. ~ ......................... -] , ~- ndersaturated 0 5_ ~ ~: ....... ~ ..... t ...... ~ .... ' ....... ~ ....... ~ - .... ~ __ ::~-~-~ . ..:'.. :. :~':~ ' __._~__[.]_: ~' : i ' ~ 3083 PSIO __~.~ 0 1000 2000 S000 4000 5000 6000 7000 1.50 1.45 1.40 1.35 1 30 . · 1.25 1.20 1.15 1.10 1.05 1.00 Petroleum Rese"~oir Engineering DALLAS~ TEXAS FIGURE III Company ARCO OIL & GAS COMP/LNY Well KUPARUK D- ] Field KUPARUK Formation County State File RFL 8~2~6 NORTH SLOPE ALAS~5 Figure III Formation Volume Factors at 160°F. Legend Differential Data Flash Data (145°F. ST) Flash Data ( 60°F. ST) Units Line RVB/RDS RVB/STB -- --- RVB/STB .... Bubble Point 3083 PSIG 0 500 1000 1500 2000 2500 3000 3500 4000 PRESSURE' PSIG CORE LABOrATORIEs, INC. Petroleum Reservoir Engineering DALLAS~ TEXAS FIGURE IV Page 13 of 28 File RFL 81216 1.030 1.025 Company ARCO OIL & GAS COMPANY Well KUPARUK D- 1 Field KUPARUK Formation County NORTH SLOPE State ALASKA Figure IV Ratio of Flash to Differential Formation Volume Factor, at 160°F., RDB/STB 1.020 1.015 1.olo .. r'--,] r-', , m~mld< ~c~. m 1.005 1. 000 0.995 0.990 °F. ST iJiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiii~i-Filiiiilli ....... iilllllj ,,,,II,,,,,,,,,,,,,,tt,,,,,,,,,,,,,,,,,,,,,,,I,,,,,,,,,,,,,,,,, ,,,,,,,, llll IIIIIlllllllll IIIIIlillllllllllllllll Illllllllllllllll Jlllllll IOllllllllllllllllllllll II}lllllllllllllllllllllllllllll IIIllll IIIIIIII lJ I ! I I I I I I I I I I I I I I I I I I I I I I I I 1.1 I I I I I I I I I I I I I I I I I ! I I i I I I I i i i i i i i i I I I I I I1 1 II IIIIII II Iii II I II I I II Il Illl II II II I I II Il ]Ill IIiill illllj I ill ill J.lJllJJ] IJ I I I I I I I I ! I ! 11 I I I I I 1,4-LLI I I I I.I I I I I I I I I I I I I I I I I I I i i 11 i i i i i i i I i i i I I I I I I 11 i~ I I I I I I I I I I I I I I I I I I fl I I I I i ~ f-f --t-i-,l-id I 1 ! I I I I I I I I I I I I i Ij i i i i i i i ! j i I I I I I I 11 ~llJilllll-t-f-F-.I-4.J.J_lllllllllllllllll, IIIl~ll! 60°F. ST 0. 985 Bubble Point 3083 PSIG 0.980 0 500 1000 1500 2000 2500 3000 3500 4000 PRESSURE: PSIG $00 450 4OO $$0 300 250 2o0 150 100 5O 0 0 500 e~ Point 1000 ~'SIc 150 2000 PRESSURE: PSIG 25O $00 SSO0 4000 CORE LABOR~'rORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS FIGURE VI Page 15 of 28 File RFL 81216 +25 +20 +15 ~a +10 < +5 ? -- -15 -2O -2S Field Compcmy ARCO OIL & GAS COMPA~NY Formation Well KUPARUK D-1 County NORTH SLOPE KUPARUK State ALASKA i.I I 11 I I I ! I I I I I 1.1 I I I I I I I I i t I I'! I I ! I I I I ] I I I I ! ! :J I I I I 1 I I I ! 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I I ] J I I !T"1-.4~11 ! I I I I I I I I I I ! I I 1'1 I I I ! I I I I I ! I i I I I I ] ! I I I I I I I ! I I I I I r"r-,I.d.I I I I I I I 1 I I I I I 1 I I I I ! I I I I I I I I I I IJ ] I I I I 1 I i I I I I I I I I I I I I I I I I 11 I I I I I ! I I I I I I I i ! I q"'"tM~ I I I 11 I I I I i I I I I I I ! I I I I I I I I I I I I ! I ! I I !11 I I I I I I I I I I ! I i J I 11 I I ! ! J J t I I I I ! I I LI I I F't"4.d_l I I I I I I I ! I I I I I 1 11 I I I I ! I I I I I I I.J I ! I I I I I I I I I I I I Il t I I I I I J i J J J I I I I I I I I J i ! 11 I J I T"l.-d~ ! I I ! I I I I I I I 1 11 ! I I ! I ! ! I I I I I I IIIIIII!11111 tlllll!tllllllllllllllllllllllll~lllllilJlllllllllllllllll I I I I I I I I I I I 11 I I I I ! I I I I I I I I I I I I I ! I I I I I I I ! I I I I I I I I T"',t,.&I I I I ! I 11 I I ! I I I I I I I I I I I I I I ! I I I I j I I I I I I I I I I I I I I I I I I I I 11 I I I i I I I I I I I I ! I I I I I I I'T".,t,~ I ! I I I I I I I I I 11 I I I I I 1 I! I I I I I I I I ! I I I ! i I I I ! ! I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ID,,,.I I I I I I i I I I I I I ! I I I I I I I I 11 I I I 11 I t I I I I I I I I ~l I I I I I l.I I I I I I I I I I I I I I ! I I I I LI I 11 I I I I I I I I I I I i I I I ! I I ! [ IJlllllllllll lllllllllJll IIIIIIIII1111111 IIil1111111111111111.111111111111 IIIIII1111III !!111111111 11 IIIIIII1111 !1111111111111111 J ' IIl'lJJJlllllllllllllilll IIIIIl. lllillililJ]lllllJ]llll iillllliJIllllililllllllll JJllll jjj IIIIIlllllli]lii Illii]ll IJJIIlllllll~ IIIII IIIIil111111111111111IIii11111111111111111111111111111 lJ~tl[]~]liii I[I]l illi. i~iliil]i[lillll.llillililiililiil[ll.l]llliiiiil]li Illllllllllli II111 III111111111111111111111111111111111111111111111111111 IJliil~llliil lllll Illilllli!lllltlllllJrlllllllt/IJIIJIIllllllllll!!jlll I111111111111 IIIii llllllllllltllill~i~ti~tllllllllllllllllllllllllll JJJ Ii I I I I I I I I I I I ! I I I I I I I i I I I I I I I I I I !1 lITTI I I I I i I I I I I I I i 11 !! 11 I I ! I ! I I I I1 I I I I~11111111111 !1111 IIIllllllllllliltlilllllllllllllllllllllllllllllllllli III!111111111 IIIII IIJllillllllllllllillllllllillllllilllllllllllllllllll I111111111111 III11 IIIIIIIIlliltl II11111111111111111111111111111111111111 LilIIIII] IIII IIIII 1 llllllllllllllilllJ]lJl]]lllllllillll Iii]Ill ' II I!!111 II111 I111 · Iliiiiiliiilllillililiill[ Bubble Point IIIIIIll II II I I II II1111111 III I]111 II Illl ,,,,,,,,,,,,, , . ,,,,,!,,,,,,,i,,l!,,,tillll][ soasPS G II!1111tliiii. II111 11111111111111111111111]!1111 LI ] I I I I I I I I I I ! i I I I I i I I.! ! I I I I I I I I I I I i I J I I I I J I ! I i i I I I i J 111 ! 11 I ! I I I ! I 11 I I I I I ] II11 Ill Il I II I !11 ! I I ! I I il i I I! I J J I II I I I Jl ! I I II I I] I I il I ! ~ lJ !1 1 11 111 I !1 II I I I IIIIIIIIIIlil IlllJ II111]111111111111111111111111111111~!1111111111IllIIll [IIIIlJllllll] III11 IIII!ii11111II iJllllllill[]JJjJJJJ]J~lJJ. J]JJJ]llJllllll 0 500 1000 1500 2000 2500 3000 3500 4000 PRESSURE' PSIG CORE LABOR'ATORiES, INC. Petroleum Reservoir Engineering DALLAS~ TEXAS FIGURE VII Page 16 of. 28 File RFL 81216 2000 Company ARCO OIL 6 GAS COMPANY Well KUPARUK D-1 Field KUPARUK Formation County State NORTH SLOPE ALASKA 1800 1600 1400 1200 1000 800 6OO 4OO 200 0 0 500 1000 1500 2000 2500 300'0 3500 4000 PRESSURE' PSIG Company Well Field 0.020 0.015 0.010 0.005 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS~ TEXAS FIGURE VIII ARCO OIL & GAS COMPANY KUPARUK D- 1 KUPARUK Formation County State Page 17 of 28 File RFL 81216 NORTH SLOPE ALASKA 1.1 1.0 0 9 0.7 0.6 0.5 0 500 1000 1500 2000 2500 3000 3500 4000 PRESSURE' PSIG ~ CORE IABoR~ATORi'ES, INC. Petroleum Reservoir Engineering DALLAS~ TEXAS FIGURE IX Page 18 of. 28 File RFL 8}216 10 Company ARCO OIL & GAS COMPANY Well KUPARUK D-1 Field KUPARUK Formation County State NORTH SLOPE ALASKA 0 u 4 1~1 1000 800 Oim600 E-.-, 400 I, iI 200 0 0 500 1000 1SO0 2000 2500 $000 $500 4000 PRESSURE' PSIG CORE LABORATORIES, INC. Reservoir Fluid Analysis Page 19 of File RFL 81216 Well Kuparuk D-1 28 SUMMARY OF PVT DATA - PROPERTIES OF BUBBLE POINT FLUID AT 100°F. Reservoir Fluid Sample Bubble Point Pressure Reservoir Temperature compressibility: Slightly above bubble point pressure Slightly below bubble point pressure Density at 2825 PSIG & 100°F. (Experimental) Viscosity at 2825 PSIG & 100°F. Differential Gas Solubility Differential Formation Volume Factor 2825 PSIG iO0°F 6.60 Vols./MM Vols/PSI 49.0 Vols./MM Vols/PSI 51.40 Lbs./CF 0.357 PSI/Ft. 4.56 Centipoises 440 SCF/RDB 1.181 RVB/RDB These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc- tivity, orooer operation, or profitableness of any oil, gas or other mineral well or in connection witl~ which such report Is used relied upon. CORE LABORATORIES, INC. Reservoir Fluid Analysis Page 20 of File RFL 81216 Well Kuparuk D-1 Pressure, PSIG TABLE III(A) DIFFERENTIAL AND TOTAL VOLUME PVT DATA Differential Liberation at 100°F. Gas Relative Formation Gas in Conversion Liberated Volume, Volume Factor, Solution, Factor Gas Gravity, V/Vsat.(1) RVB/RDB SCF/RDB SCF/RVB (Air=l.000) Calculated Gas Viscosity, Centipoises(2) 5OOO 4500 4000 3500 3100 3000 2900 2825 2786 2756 2682 2536 2500 2290 2250 2032 2000 1788 1750 1535 1500 1318 1250 1093 1000 918 782 750 656 512 500 377 270 250 93 0 0.9866 0.9895 0.9925 0.9956 0.9982 0.9988 0.9995 1.0000 1.0021 1.0038 1.0084 1.0185 1.0402 1.0720 1.1145 1.1788 1.2649 1.3944 1.5458 1.7189 1.9357 2.3564 3.0052 4.0015 1.165 440 1.169 440 1.172 440 1.176 440 1.179 440 1.180 440 1.181 440 1.181 440 1.167 395 1.156 362 1.144 329 1.132 294 1.120 259 1.108 225 1.096 189 1.084 152 1.071 112 1.056 68 1.040 32 1.016 0 @ 60°F. = 1.000 1101 0.604 0.0179 989 0.601 0.0169 872 0.599 0.0159 754 0.597 0.0151 634 0.598 0.0143 517 0.600 0.0136 404 0.605 0.0129 296 0.613 0.0124 194 0.627 0.0119 97 0.656 0.0114 39 0.784 0.0107 5 1.110 0.0095 Gravity of residual oil = 23.9°API @ 60°F. (1) Relative Volume, V/Vsat. is total volume data for constant composition ('no gas remOVal.) - expansion of bubble point fluid at 100°F. (Z) Gas viscosity data calculated from gas gravity and using method of Carr, Kobayashi, and Burrows: Petroleum Transactions AIME, VOl. 201: p. 267 (1954) These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the produc~ fiuif~J r~r~.r~ar nneration_ or orofitableness of any oil. gas or other mineral well or in connection with which such report Is used relied upon. CORE LABORATORIES, INC. Reservoir Fluid Analysis Page 21 of File RFL 81216 Well Kuparuk D-1 28 TABLE IV(A) VISCOSITY OF RESERVOIR FLUID AT 100°F. DURING DIFFERENTIAL LIBEILiTION Pressure, Viscosity, PSIG Centipoises 5000 5.29 4500 5.12 4000 4.95 3500 4.79 3000 4.61 2825 4.56 2500 5.06 2250 5.44 2000 5.86 1750 6.30 1500 6.80 1250 7.33 1000 8.03 750 8.93 500 10.25 250 12.00 0 26.88 These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the Drocluc- tivity, proper operation, or profitableness of any oil, gas or other mineral well or in connection with which such report Is used relied upon. coRE LABC~RATORiES, INC. Petroleum Reservoir Engineering DALLAS) TEXAS FIGURE ! {A') Page. 22 of 28 File RFL 81216 1.9 Company ARCO OIL & GAS COMPANY Well KUPARUK D- 1 Field KUPARUK Formation County State NORTH SLOPE ALASKA 1.8 1.7 1.6 1.2 1.1 1.0 0.9 5OO 1000 1500 2000 PRESSURE' PSIG 25OO 3OOO 3500 40OO 9_ 8_ 7_ Figure II (A) ~ ~---, Page 23 of 28 ~ Compressibilities of Oil and Gas at 100*F. :, : ~ ', : File RFL 81216 ',.~ ! i ', ! 'i : i ;Well Kuparuk D-1 =.~. . - .... -'-. ~__=~-~ = "L=_ ~ . J 6_ r.__ ____ ._______._-~ Free Gas -d=-'-~ ............ .... -I.----= ~.---==--_-.-~..=_-?:=_:7~~ .~.= :--r =--_~ -=-- .'~--~'.! = . - . :'. -: ~.:'. . . : -.. -'~'~ t 190 _ ' __, ......... J __ ._- ..... ~ ,_ ~_ : ; i ' i ' ' 9_ _ _ · ] ................................. " 8 2 . ~ .... ~ . ~ , _ ~ · ~ ..... ' i J ' - 8_ ::= -- ~ $7:=-~ ~:~: ~;~'--~:~:=~':~C~-:::=-~'-' :::=:'::: '" : '~ :'- ; i'~': : ':'-~ _~7 ~-i:Si' i-: -:-~ - ..... , .......................... ~::':::~:::~:- ~5.~ :_::.: .: 7_~ .... Unde~satutated 0~1 ~"" 5_ [ ~ ~ :: ~ z:: : ~ :::: : .... ~-~ -'-::::-':_:~:---:::: .... ::::-;. ::.':_:..:.:...'_'_:__:'~___: + , : ~ ~=== -~ ~_~-=:':==-::__'I :-=: :..': '.: ': ..... ~ ......... : ~ .... ~ _ ~_i ...... :~ ~ ............... [: _.~ ~ 2825 PSIG ' , , ' ...... 0 1000 2000 3000 4000 5000 6'GU0 PRESSURE' PSIG CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS FIOURF. III (^) Page 24 of 28 File. RFL 81216 0 U O :> O 1.50 1.4S 1.40 1.35 1.30 1.25 1.20 1.15 1.10 1.05 1.00 Company Well Field ARCO O11. & GA.q COMPANY KUPARUK D- 1 KIIPARIIK Formation County State NORTH SLOPE ALASKA Figure III (A) Formation Volume Factors at iO0°F. IIII_IJLIIlilIIIIIIIIIIIIIIIIIIIIII Legend .., Units Differential Data RVB/RDB Bubble Point 2825 PSIG 0 500 1000 1500 2000 2500 3000 3500 4000 PRESSURE' PSIG CORE LABORAToR'IES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS FIGURE V Page 25 of. 28 File RFL 8--1.21.6 500 450 400 350 30O 250 200 150 100 50 Company Well Field ARCO OIL 6- GAS COMPANY KUPARUK D-1 KUPARUK Formation County NORTH SLOPE State ALASKA Figure V (A) Total Solution Gas Solubilities at 100*F. . Legend Differential Data Units SCF/RVB Bubble Point 2825 PSIG 0 500 1000 1500 2000 2500 3000 5500 4000 PRESSURE' PSIG CORE LABORATOI~IES, iNC. Petroleum Reservoir Engineering DALLAS, TEXAS FIGURE VII Page 26 of 28 File. RFL 81216 C. ompany ARCO OIL & GAS COMPANY Formation Well KUPARUK D-1 County NORTH SLOPE Field KUPARUK State ALASKA 2000 1800 1600 1400 1200 1000 800 ! I I I I II I I II I III II I i III Iii il II I II I IIIIIIII I I II III I I Figure .VII (A) Gas COnversion Factor at 100°F. -. , , , , · · · · · · · [ · ,~, · 600 · · 400 .... · :,~ 200 , ./' II Bubble Point 2825 PSIG ~ I I I I I I I III I ! I I I I I ~' I Il Jill ~ II I! II I / I I I I i I I III I I I I I I I 0~ li I i I I ! 11II I Iii i i 0 500 1000 1500 2000 2500 3000 3500 4000 PRESSURE' PSIG CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS FIGURE VIII (A) Page 27 of 28 File RFL 81216 Company Well Field 0.020 0.015 0 010 . O.OOS ARCO OIL & GAS COMPANY KUPARUK D-1 KUPARUK Formation County State NORTH SLOPE ALASKA 1.1 1.0 0.9 '-'0.8 0.5 0 SOO 1000 1500 2000 2500 3000 3500 4000 PRESSURE' PSIG CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS FIGURE IX Page 28 of 28 File. RFL 81216 25 Qompany ARCO OIL & GAS COMPANY Well KUPARUK D- 1 Field KUPARUK Formation County State NORTH SLOPE ALASKA > 10 2500 2000 1500 ~ 1000 o 500 0 0 500 1000 1500 2000 2500 3000 3500 4000 PRESSURE' PSIG 11 000000 7777777777 000000 11 000000 7'777'77'7777 000000 ~ oo oo 7~ oo oo 1111 O0 O0 77 O0 O0 11, O00000 77 O00000 11 O00000 7'7O00000 ~ oooo oo '~v ooOo. oo ~.~ oooo oo 77 oooo oo ~, 0000 oo 7'~ 0000 oo ~ 0000 oo 77 0000 oo 11 O0O0 77 O0O0 ~ oooo ~7 oooo ~~ oooooo7v oooooo ~,,~, oooooo',7 oooooo '777 'l 777777 77777'77777 77 77 77 77 77 77 77 77 77 '77 77 ~6~ oooooo aaaa~3 oooooo 666666 000000 3,3333,3000000 ~ oo oo aa :~::~ oo oo ~ oo oo :~a '~,:~ oo oo ~ oo oooo :~aoo oooo ~ oo oooo ,a:~ oo oooo 66666666 O0O0 O0 3:3O0O0 O0 ~6~~ O0O0 O0 :~3O0O0 O0 ~ ~ 0000 O0 3~ 0000 O0 66 66 0000 O0 33 0000 O0 66 66 O0O0 33 ,]3O0O0 ~ 6~ O0O0 ~3 ,~3O0O0 ~6~ 000000 3~333 000000 ~~6 000000 3~3333 000000 666666 666666 66 66 66 66 66666666 66666666 66 66 66 66 66 66 66 66 666666 666666 SSSS Fi' [;' ~' F' L PPPP IaRRR U U DDDD Id Fi 000 EEEEE S F L P P R R U U D D H Id O O E S B' L P P R R U U D D H Id O O E SSS FB l:'F L ..... PPPP RRRR U O D D HHBidid O 0 EEEE S F L P R R U U D D M Id U 0 E S F L P R R U O D D H H O O E SSSS F LLLLL P R R UUUUU DDDD H H OOO EEEEE *START* USER PCAb [10707,60306] dOB SIdIP SEW. 6223 DA'r~: 12-APR-80 19:00:50 MONITOR SWS KL10E34 JUL-79. *START* *START* USER PCAL [10!07,60306] dOB SHIP SEO 6223 DATE 12-APR-80 19:00:50 MONITflR SW$ KLlOE34 JUL 79. *START* ' SS SS SS SS SSSSSSSS SSSS$SSS SSSSSS SSSSSS SS SS SS SS SSSSSSSS SSSSSSSS lq H H H I, ! HH Hft I I ,I-iH I-I14 HH HHH H HHHH!~.I-t HHHHHHHHHH HH HH HH HH HH H H HH HH HH II HH HH I I I 11 I I I I I II I,I II I I II II II I,I II I 11 I I i I I PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP 'T T T T T T T T T T 0.00000 T T T T TT T T T T O0000[] TT 00 O0 T T 00 00 TT O0 O0 TT O0 O0 TT O0 0[) TT O0 O0 TT O0 O0 TT O0 O0 TT O0 O0 TT O0 O0 TT 0,0[)000 TT 000000 *START*. USER PCAL [10Z07,60306] ,JOB SHiP SEO 622) MONITOR SWS KLlOE34 JUL 79. *START* ' FILE: DSKH:SHIP.TO<255>[i0707 60306] CREATED: 12-APR-80 PRINTED: 12-APR 80 1~:01:06 QUEUE SWITCHES: /tribE:FORT /COPIES:I /SPACING:I /6iMIT:131 /FORMS:NORMAL DATE 12-APR-80 18:51:28 19:00:50 SHIPPING INSTRUCTI. ONS ,ISSUED 12-APR-80 18:51 S H I P TO : PCCC THANKS..... BY' S~L PCCC V¥ V V EEEEEEEEEE RRRRRRRB ¥¥ yV EEEEEEEEEE RRRRRRRf{ V ¥ ~ V EE RR RR V1/ VV EE RR RR V V V V E E R ~ R R VV V V EE RR RR VV VV EEEEEEEE RRRRRRRR VV VV EEEEEEEE ,RRRRRRRP VV V V EE RR RR V V V' V E E R R R R VV VV EE RR RR 'V V V ~/ E E: R B R R VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR RR II, IIII Iiiiii Ii 1I II II II II II II II, II Iillii IIIIII FF[~I/'FFFF YY YY y Y Y Y~ 000000 000000 222222 000000 000000 2'22222 00 O0 00 00 22 22 00 00 00 00 22 22 00 0000 00 0000 22 00 0000 00 0000 22 00 O0 O0 ()0 00 00 22 00 O0 O0 00 00 00 22 0000 00 0000 O0 22 0000 00 0000 00 22 00 O0 00 00 22 O0 O0 00 O0 22 000000 000000 2~22222222 000000 000000 2 22222222 *START, USE~ PCAL [1,0707,60306] dOB SHiP 8EO MONIrt.,R SWS KL10E34 JUL-79 *START* FILE: DSKH:VERIF'i,O0~<057>[10707 60306] CREATED: P~.INTED: 12 APR-80 ,19:0{:15 QUEUE SWITCHES: /f'iLE:FURT /COPIES:I /6PACING:! /LIMiT:131 /FORMS:NORMAL 6223 DATE 12-APR-80 I2-APR-80 18:59:35 19:00:50 SCHLUMBERGER COMPUTING CENTER 10707,60306 REE£i HEADER REEL CONTINUATI, ON NUMBER: 01 PREVIO'U$ REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 80/ 4/12 TAPE HEADER LENGTH: 132 B'ZTES TAPE NAME;: 60306 DATE: 80/ 4/12 SERVICE NAME: ED1T TAPE CONTINUATION NUMBER: 01 ~ PREVIOUS TAPE NAME: C(]MMENTS: U.NI(~UE WELL IiDENTiF'ICAT1ON NUMBER IS 50-029-20393 TAPE C(]MMENTS CSNG DR1LLER 16.~l.I()/B1T SIZE 13.75/TYPE FLUID FRESH-GEL/DENS 10.7/ VISC '70/PH 8.5/~'LUID bOSS IO.5/RM 4.78064 DF/RMF 3.71Ca64 DF/ RMC 5.50064 DF/RM@BHT N-A/ TAKEN FROM RUN ONE BHC LOGGED 5NOV79 ' FILE EEADER LENGIH: 62 BYTES F'ILE NAME: EDIT .001 MAXIMU~ PHYSICAL RECORD LENGTH: 1024 BYTES PREVIOUS FILE NAME: FiLE COMMENTS RUN ONE AND TWO (60051,60052,60306) WELL SiTE INE'ORMATION HECORD LENGTH: COMPANY: WELL: FIELD: RANGE,: T[IW N: SECTION: COLJN1Y: 172 BYTES ATLANTIC RICHF'IELD CO. D-1 KUPARUK lOE lin 14 N . SLOPE A L A $ :K A DATA ~ORMAT SPgCI, FICA. TION LE,NGTH: 610 BYTES ~,:;NTR~. BLOCKS: SIZE 1 P, EP CODE E :N T R ~ 0 DATUM SPECIFiCATI(]N BLOCKS: ENTRY lC TOOL SVORD# UNITS AP1 APl API API FILE# SIZE EXP PROC SAM REP DEPT SHI, FT DEPT' SP D iL i L D D I L 1LM OiL LLSU Dill GR CNL CALl CNb DRHL) I;DC NPHI CNL RHOB CNL NRAT CNL NCNL (]Nil ~"CN L CNL GR ,B MC DT BHC FT 0 0 0 0 0 4 0 0 1 68 0 0 MV 7 I 0 0 0 4 0 0 1 68 0 0 0 H M M 7 12 46 () 0 4 0 0 1 68 0 0 (]HMM 7 1,2 44 0 0 4 0 0 1 68 0 0 OHMM 7 22 8 0 0 4 0 0 1 08 0 0 GAPI 42 31 32 0 0 4 0 0 1 68 0 0 I N 42 28 1 0 0 4 0 0 I 68 0 0 G/C] 42 44 0 0 0 4 0 0 1 68 0 0 P U 42 68 2 0 0 4 0 0 1 68 0 0 G/C3 42 i~5 1 0 0 4 0 0 1 68 0 0 C/C 42 42 ! 0 0 4 0 0 1, 68 0 0 CPS 42 34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 69 0 0 GAP:][ 60 3I 1320 0 4 0 0 1, 68 0 0 US/F 60 52 :320 0 4 0 0 168 0 0 DEPTH t96,000 8300.000 8200. 000 8100,000 8000.000 '7900.000 7800.000 7700.000 7600,000 7500.000 7400.000 MN ~:M [].N IC GR. R H O B GR SP RHC]B GR SP GR RHOB GR S,P RHOB GE SP GE RH00 GR SP GR GE SP GE RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR R H L} B GR VALUE '999.250 124..438 2.467 -999.250 -999.250 102.56,3 2.502 93.313 -999.250 109.188 2.461, 101.000 -999.250 41.750 2.535 42.906 -999.250 87.000 2.449 87.563 -999.250 65.625 2.559 69.875 -999.250 60.000 2.580 52.813 -999.~50 127. O0 2.434 121.125 -999.250 132.250 2.449 128.250 -999.250 -999.250 -999.250 182.250 -999.250 -999.250 -999.250 224.125 MN EMON IC I. bD CALI NRAT DT I, LD CALl NRA, T DT 1LD CALl NRAT DT IbD CAb I NRAT DT 1LD CAL,I NRAT DT ILD CALl NRAT DT ILO CALl NR.AT DT ILD CALI NRAT DT ILD CALl NRAT DT 1LD CALI NRAT DT ILD CALl NRAT DT V A b -999 9 -99~ 2 10 3 99 2 10 3 109 6 9 1 58 4 1,,0 2 92 4 1,0 2 67 29 9 2 76 3 111 2 10 3 106 2 -999 -999 104 2 -999 -999 112 .250 .875 .348 .250 .37,3 .570 .424 .000 .074 .500 .809 .000 ,801 .797 .866 .000 ,273 ,383 ,928 ,750 .422 .219 .]16 .750 .859 .453 .854 .563 .633 .906 .959 .750 ,131 .734 .598 .563 .604 .250 .250 .750 .762 .250 .250 .750 MNEMON lC ibm DRHO N C ,N L i LM DR,HO NCNb ILM D R,H 0 NCNb iLM DRHO NC,Nb DRHO NCNb DRHO NCNb DR80 NC,Nb ILM DRHO NCNb IbM DRHO NCNb NCNb DRHU NC,NL "VALUE -999.250 -0.005 1576.000 2.539 0.034 1608.000 2.178 0 5 9.492 0.061 2950.000 4.328 0.011 1820.000 4.836 O. 0:56 2282.000 28.828 0.071 1818.000 1.768 0.025 1.659.000 2.207 0.019 1578.000 2.631 -999.250 -999.250 2.828 -999.250 -999.250 MNEMO.NIC 'VALUE L,L8U -999.250 NPH1 39.160 FCNL 443.500 bbSU -999.250 NPHi .]9.063 FCNL 446.750 LbSU -999.250 NPHI 46.094 FCN,6 368.000 hb8O -999.250 NPHI 15.283 FCNL 1402.000 LLSU -999.250 NPHI 30.51.8 FCNL 559.000 LLSU -999.250 NPH1 21.533 F'CNL 883.000 LLSU -999.250 NPHI 30.518 FCNL 595.000 LLSU -999.250 NPHI 48.389 FCNL 3'73.250 LLSU -999.250 NPHi 41.943 FCNL 386.250 LLSU -999.250 NPHI -99925.000 FCNL -999.250 LLSO -999.250 NPHI -99925.000 FCNL -999.250 ',) DEPTH 7300,000 7200. 000 7 100.000 7000.000 6900,000 6800,000 6700.000 6600.000 6500.000 6400.000 6300.000 M N EMONIC SP GR RHOB GR GR GR SP GR, R H [) [5 GR SP GR R H 0 B GR SP GR R H [1B GR SP GR RHOB GR SP GR RHOB GR SP GR R H O B GR GR RH[~B GR SP GR RHUB GR SP GR RHOB GR V A L -999 -999 -999 151 -999 -999 -999 106 -999 -999 -999 11 '7 -999 -999 -999 158 -999 -999 -999 151 -999 -999 --999 137 -999 -999 -999 161 -999 -999 -999 155 -999 -999 -999 141 UE ,250 ,250 ,250 .8'75 .250 ,250 ,250 .563 .250 .250 .250 .938 ,250 ,250 ,250 ,500 .250 .250 .250 .375 .250 .250 .250 .625 .250 .250 .250 .375 .250 .250 .250 .125 .250 .250 .250 .500 -999.250 -999.250 -999.250 145.750 -999. 155. 2. 149. 250 500 367 250 M.N EMON IC ILD CA[, I N R A T DT ILD CALl ' NRAT DT ILD CALI NRAT DT 1LD CALl NRAT DT ILL CALI NRAT DT I L D CALl NRAT DT iLD CALI NRAT DT ILD CALl NRAT DT iLO CALl NRAT DT ILD CALI NRAT DT ILD CALl NRAT DT V AD U E 1 . 4'76 -999.250 -999 °s 2.1.15 -999.250 -999.250 97.75O 3 537 -999:250 -999,250 121.750 2.658 -999.250 -999.250 110.375 3.275 -999.250 -999.250 105.188 1.661 -999.25O -999.250 109.188 2.260 -999,250 -999,250 96,563 1.828 -999.250 -999.250 103.375 2,428 -999,250 -999,2¢0 94.3 5 1.957 -999,250 -999.250 119.750 1.885 11.031 3.510 113.000 MNEMON lC DRHO NCNb i Ih M DRHO .NCNb DRHO NCNb I L.M DRHO NCNb DRHO NCNb I LM DRHU NC.N L IbM DRHO NCNb ibm DRHO NCNL DRH. O NCNb 1LM DRHO NCNb DRHO NCNb VALUE, 1.591 -999.250 -999.250 2..436 -999.250 -999.25O 3.518 -999,250 -999.250 2.033 -999.:250 -999.250 3.361 -999.250 -999.250 1.629 -999.250 -999.250 2.295 -999.250 -999,250 1,931 -999.250 -999.250 2.387 -999.250 -999.250 1.956 -999.250 -999.250 2.000 0.014 1587.000 MNEMONIC 'VALUE bL8U -999.250 NPHi. -99925.000 FCNb -999.250 LLSU -999.250 NPHI -99925.000 FCNL -999.250 LL8U -999.250 .NPHi. -99925.000 .FCNb -999.250 bh8O -999.250 NPHI-99925.000 FCNL -999,250 LL8U -999,250 NPHI -99925,000 FCNL -999,250 hhSO -999,250 NPHI -99925.000 FCNb -999.250 bhSO -999.250 NPHI -99925.000 FCNL -999.250 LL8U -999.250 NPH! -99925.000 FCNb -999.250 LLSU -999.250 NPHI -99925.000 FCNb -999.250 LLSU -999.250 NPH1 -99925.000 FCNL -999.250 bbSU -999.250 NPHi 40.283 FCNL 423.250 ¸5' D E P T :[4 6200.000 6100. 000 6000,000 5900,000 5800,000 5700,000 5600.000. 5500,000 5400.000 5300.000 5200,000 MNEMONiC SP GR R H 0 B GR R H I::') B GR SP GR R H O ,B GR SP GR RHOB GR SP GR RHOB GR SP GR GR SP GR RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR RH(JB GR VAL -999 103 -999 105 2 104 -999 108 2 103 -999 93 2 95 -999 96 -999 -999 -999 93 -999 -999 -999 101 -999 -999 -999 95 -999 -999 -999 91 -999 -999 -999 94 -999 -999 -999 91 U E 43 30 :, oo .25O .063 ,322 .563 .250 .063 .385 .750 .250 .250 ,387 .438 ,250 .625 .354 . 31, 3 ,250 ,250 ,250 ,250 ,250 .250 .250 .938 ,250 ,250 .250 ,250 .250 .250 .250 .000 .250 .250 .250 .188 .250 .250 .250 .375 MNEMONIC ILL CALl NR.AT DT ILD CALI N R A T DT 1 LO C.AL I N R A T DT i L D CALI NRAT DT iLD CALi NRAT DT iLD C.AL I NRAT DT iLL CALI .NRAT DT 1LD CALl NRAT DT ILL CALI NRAT DT ILD CALl NRAT DT ILD CALl NRAT DT 'V A L, ti 0 , 10. 3 · 107. . 1,0. 3. 102. 047 852 393 188 996 922 406 375 508 898 127 563 2 7,48 o:875 3,184 99,188 2 10 3 100 2 -999 -999 104 3 -999 -999 103 3 -999 -999 104 4 -999 -999 106 3 -999 -999 106 -99~ -999 109 .850 .844 ,258 .188 .969 25O ~250 .375 .063 .250 .250 .188 .951 .250 .250 .750 .582 ,250 ,250 .188 .705 .250 .250 .000 289 ~250 .250 .000 MNEMONIC iL.M DRHO NCNb DRHO N C .N L DRHO NCNb DRHO NCNb DRHO NCNb 1bM DRHO NCNb ILM. DRHO NCNb DRHO NCNb DRHO NCNb IbM DRHO NCNb DRHU NCNL VALUE 2.113 -0.005 18'86.000 2.021 0,002 1883.000 2.531 0.022 2006.000 2.770 0.057 2120.000 2.877 0.029 2011.000 2.832 -999.250 -999.250 3.057 -999.250 -999.250 4.031 -999.250 -999.250 5.359 -999.250 -999.250 3.820 -999.250 -999.250 3.273 -999.250 -999.250 MNEMONIC VALUE LL8U -999,25~ NPHI. 3.8.23 FCNL 499.250 LL8U -999,250 NPH1 38.428 .FCNL 5.30.000 LL8U -999,250 NPHi 33.008 FCNL 63'1,500 LGSU -9~94.250 .NPHI .473 FCNL 641.500 hbSU -999.250 NPHI 35.791 FCNL 600.500 LLSU -999.250 NPHi -99925.000 FCNL -999.250 LLSO -999,250 NPHI -99925.000 FCNL -999.250 LLSU -999.250 NPHI -99925.000 FCNL -999.250 LLSU -999.250 NPHI -99925.000 FCNL -999.250 LLSU -999.250 NPHI -99925.000 FCNL -999.250 LL8U -999.250 NPHI -99925.000 FCNL -999.250 DEPTH 5100.000 5000.000 4900,000 4800.000 4700.000 4600,00O 4500.000 4400.000 4 30O. 000 4200.000 4100.000 MNEM[,INiC SP GR RHOB GR SP GR SP GR R H 0 B GR SP GR RHOB SP GR RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR R H 0 B GR SP GR RHOB GR SP GR RHUB GR SP GR GR VALU -999, -999, -999. 122, -999. -999. -999. 121. -999, -999. -999, 100, -999, -999, -999, 120. -999. -999. -999, 124, -999, .80, 2. 98, -999. 81. 2, 109. -999. 64, 2, 115. -999, 73, 2, 79, -999, 70. 2. 91. -999, 59. 2. 67. 250 250 250 438 250 25O 250 750 250 250 250 375 250 250 250 063 250 25O 250 000 2.50 875 229 000 250 813 223 688 250 938 162 813 250 750 189 250 250 813 232 625 250 750 115 688 MNEMONIC iLD C.Abi NRAT DT ILD CALl NRAT DT ILD C AL i NRAT DT 1 LD CALl .NRAT DT ILD CALl NRAT DT ,ILD CALl NRAT DT ILD CALI NRAT DT ILD CALl NRAT DT ILD CALI NRAT DT ILD CALl NRAT DT ILD CALl NRAT DT VALUE 3.531 999 250 -'999:250 109. 563 · 4. 840 -.999 ! 250 999 72~0 110 0 2,762 -999,250 -999,250 115.000 3.7013 -999,250 -999 250 4.3'71, -999 250 -999:250 11,1,750 5,840 11.008 3,1~4 109,7 0 4,738 1,1.047 3,518 113.188 16,922 9,742 3.383 127,000 8.836 10.406 3,791 123,750 13.180 10.281 .3.773 121.000 43.688 9,727 3.730 128,375 MNEMON lC ILM DRHO N C N b iLM DR,HO NCNb i LM DRHO NCNb D R H 0 NCNb DRHO NCNb ILM DRHO NCNb ILM DRHO NCNb IbM DRHO NCNb IbM DRHO NCNb IbM ,DRHU NCNb iLM DRHO NCNb VALUE 13.492 -999,250 -999,250 4,684 -999,250 -999,250 2,457 -999,250 -999,250 3.672 -999.250 -999.250 NNEMO. lC VAbUE LbSU -999.250 NPHi -99925,000 F'CNb -999,250 LP8U -999,250 NPHI -99925,000 FCNL -999,250 hbSU -999,250 NPHI -99925.000 FCNL -999,250 Lb8U -999.250 NPHI -99925.00,0 FCN,b -999.250 4,352 bbSO -999,250 -999.250 'NPHI -99925.000 -999,250 FCNL -999,250 5.961 0.084 1661.000 4,496 0.081 1455.000 1,8.594 0.017 1545.000 8.594 0.043 1672.000 12.719 0.016 1580.000 42.563 0.006 1511.000 LLSU -999,250 NPH1 34.229 FCNb 488,250 LLSU -999,250 NPHi 40.381 FCNL 384,750 LLSU -999,250 NPHi 39.551 P'CNL 414.500 LL8U -999.250 NPHI 45.947 FCNb 387.000 LLSU -999,250 NPHI 45,752 FCNL 415,250 LLSU -999.250 NPHI 45.801 FCNL 416.500 D E. P I' H 4000,000 3900.000 3 ~00. 000 3700.000 3600.000 3500.000 3400.000 3300.000 3200.000 3100.000 3000.000 M N ,E M (] ,N I C SP GR RHI]B GR P R R H (] B GR SP GR R H O B GR SP GR R H []B GR RH[IB GR SP GR RHOB GR SP GR RHOB GR SP GR RHUB GR SP GR R H o B GR SP GR RHOB GR SP GR RHOB GR VAL -999 82 2 108 -99g 56 2 84 -999 59 2 109 -999 69 2 117 -999 66 2 11.7 UE .250 .3'75 .262 .125 .250 .469 .193 .563 .250 . 750 .223 .000 ,250 ,1.25 .182 ,500 .250 .000 .166 .375 -999.250 7.9,125 2.346 106.438 -999. 55. 2. 99. -999. 73. 2. 74. -999. -999. -999. 70. -999. -999. -999. 44. -999. -999. -999. 43. 250 781 160 125 250 563 193 875 250 250 250 313 250 250 250 188 250 250 25O 938 N:NEMONIC i bO CAb I NRAT DT ILD CALl NR,AT DT 1hD CALl NRAT DT ILD CALl NRAT DT iLD CALl, ,NRAT DT ILD CALI NRAT DT ILD CALl NRAT DT ILD CALl NRAT DT ILD CALl NRAT DT ILD CALI NRAT DT ILD CALl NRAT DT VAL 8 16 11,8 9 9 .3 132 8 11, 3 99 9 10 3 156 8 10 3 132 9 10 3 127 10 10 3 132 10 10 3 127 4 -999 -999 157 10 -999 -999 149 12 -999 -999 147 U E .O86 .766 .2.34 .961 .549 .750 .469 .922 .740 .188 .406 .023 .637 .:375 .672 .000 .383 .422 .633 .000 .766 .328 .588 .375 .875 .953 .641 .188 .914 .250 .250 .000 ,391 .250 .250 .750 .727 .250 .250 .500 MNEMONIC DRHO NCNb DRHO NCNb I L M DRHO NCNb ibm DR, HO NCNb iLM DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCNb DRHU NC,N b DRHO NCNb DRHU NCNb VALUE 7.953 0.119 1.532.000 9.27.3 -0.002 I'419.000 9.188 0.047 1590.000 9.72'1 -0.001 17:35.000 8.961, 0.031 1551,000 9.336 0.032 1796.000 11.016 0.016 1643.000 10.852 0.001 1659.000 4.766 -999.250 -999.250 10.359 -999.250 -999.250 14.656 -999.250 -999.250 MNEMONIC VALUE bhSU -999.250 .NPHI 35.107 FCNG 442.500 bbSU '999.250 NPHI 42.236 FCNL 402.000 bb8O -999.250 NPHI 43.994 FCNL 362.500 LL8U -999.250 NPHI 43.701 FCNL 427.500 5580 -999.250 N P H I, 40. :332 FCNG 404. 500 hbSO -999.250 ,NPHI 43.066 F'CNL 444.750 LL8U -999.250 NPHI 42.383 FCNL 461.000 LLSU -999.250 NPMI 42.627 FCNL 437.500 LLSU -999.250 NPHI -99925.000 FCNL -999.250 bUBO -999.250 NPHI -99925.000 FCNL -999.250 LLSU -999.250 NPHI -99925.000 FCNb -999.250 2900,000 2800.000 2700.000 2600,000 2500.000 2400.000 2300,000 2200,000 2100,000 2000,000 1900.000 ,M N 'V A -99 -99 -99 6 -99 -99 -99 11 -6 4 3 -10 5 5 - 1,3 8 5 -16 4 3 -16 6 5 -17 3 3 -18 6 5 -16 1 2 -18 4 3 LUE 9,250' 9.250 9,250 7.938 9.250 9.250 9,250 1.250 3.250 9.656 2.088 8.1,25 3.750 6,563 2.121 1.500 2.250 1.188 2.033 9.344 5.500 1.188 2.094 0,828 1,750 3.438 2.191 6.313 1.750 8.844 2.031 5.594 4,000 4.063 2.2O5 3.031 7.000 9.922 2.010 1.984 0.750 1.406 2.072 7.000 MmEMONIC I L O CALl NM, AT DT 1LD CALl NM.AT DT I, LD CALI .NRAT DT IbD CALl NRAT DT CALI NRAT DT ILD CALl NRAT DT ILD CALl NRAT OT 1LD CALl NRAT DT CALl NRAT DT ILD CALl NRAT DT ILD CALl NRAT DT VA -99 -99 13 '99 -99 14 1 1 13 1 1 1,4 1 1 15 1 1 14 1 14 22 15 ! 1 15 3 1. 15 LUE 7,602 250 1.1,25 4,863 9,250 9,2~0 3.3 5 2.,352 4.289 3,895 .4,375 1,469 4,16.4 1. 2.359 4.766 4.223 0,500 2,070 4.750 3.889 6,125 9,328 4,422 3,902 5.125 8.8'75 6.266 4.336 0.375 2,875 4,250 3,914 0,500 6,891 4,266 5.051 0,]75 2,688 4,078 ],990 5.375 MNEMONIC i,LM ORHO NCNb ibm DRHO NCNb ILM DRHO NCNb DRHO NCNb DRHO NCNb DRHO NCN.L DRHO NCNL DRHO NCNb DRHU NCNb IbM DRHO NCNb DRHU NCNb VALUE 7,992 9 25~ 4.441 -999.250 -999.250 12,117 -0.015 1773.000 11.367 -0,006 1769,000 10,688 0.061, 1, 703,000 11.336 0.001 1.601.000 8,88] 0.014 1862.000 50.844 0.08,3 1333.000 12.156 0.009 1829.000 6.027 0,003 1302.000 32.156 -0.008 1911.000 MNEMONIC V,ALUE hh8U -999,250 NPHi -99925,000 FCNb -999,250 5580 -999.250 NPHi -99925.000 FCNb '999.250 bh8U 11,594 NPH1 45,654 FCNb 402,500 bbSO 11.313 NPHI 48.682 FCNL 414.000 hh8O 9.188 NPHI, 51.367 FCNL 366.000 LLSU 11.820 NPH1 45.313 FCNL 418.000 bb8O 8,773 NPHI 45,703 FCNL 413,750 bh8U 407.750 NPHi 52,637 FCNL 331.250 LL8U 13,133 NPHi 46.045 FCNb 431,750 LL8U 3.096 NPHI 66.455 FCNL 233.125 bL8O 35.656 NPHI 47.461 FCNb 435.250 D~,?Ttt 1800,000 !700.000 1,600.000 ! 500.000 1, 400. 000 1, 300. 000 1200.000 11,00.000 1000.000 900.000 800,000 MNEMONIC SP GR RHOB GR SP GR R H 0 B GR SP GR R H 0 B GR GR RHOB GR RHOB GR SP GR RHOB SP GR RHOB GR SP GR RHOB GR SP GR Gk SP GR RHOB GR SP GR BHOB GR VAL -192 64 -200 56 2 47 -160 ,,'t 6 2 ]7 -162 59 2 57 -169 55 2 38 -1.77 54 2 53 OE .00 .31 .18 .12 .75 .90 .18 .21 .25 .12 .10 .37 .12 . 37 .00 .12 .10 .81 .75 .28 .14 .53 -187.75 51.28 2.06 43.53 -186. 52. 2. 38. -204. 64. 2. 51. -189. 58. 2. 47. -168. 35. 1. 29. 25 59 O0 18 O0 31 O0 62 25 37 13 56 75 96 9] 54 MNENO.NIC ill) CALl NRAT DT I L D CALI NRAT DT ILO CALI NRAT DT I, L D CALl, NRAT DT iLD CALl NRAT DT iLD CALI NRAT DT ILl) CALl NRAT DT iLD CALl NRAT DT ILD CALl NRAT OT ILD CALl NRAT DT ILD CALl NRAT DT VAL 14 14 3 151 3O 14 3 152 178 16 157 4 181 48 1,5 4 186 5 16 4 188 16 16 4 179 106 16 4 181 36 16 4 188 34 14 4 190 224 16 4 105 UE .875 .078 .902 .500 .234 .289 951 :500 .375 .750 62 :7750 969 ~656 .266 .500 .406 .500 770 :500 .039 .750 .492 .750 .266 .719 .676 .375 .063 .688 .410 .875 .563 .688 .531 .375 .438 .859 .637 .750 .250 .719 .]95 .750 N{NEMONiC DR,HO NCNb NCNb i:LM DRH, O NCNb IbM DRHO NCNb ILM DRHO NC,NL i LM D R I-t 0 NCNb iLM DRHO NCNL iLM DRHO NCNL DRHU NCNb iLM DRHO NCNb ILM NCNL VALUE 13.898 0.014 1,712.000 26.656 0.024 1.857.000 159.250 0.008 2066.000 31,.89I 0.02 1541.000 38.000 0.005 1,559.000 5.199 0.031 1395.000 14.289 0.003 1271.000 60.719 0.019 1475.000 26.828 0.030 1499.000 25.734 0.102 1374.000 88.375 0.052 1314.000 LL8U NPHI FCNL LL8U NPHI FCNL L h 8 U NPHI LL8U NPHI FCNL GLSU NPHi FCNL LL8U NPHi FCNL LL8U NPHi FC.NL LL8U NPHi FCNL LLSU NPHI FCNL LLSU NPHI FCNL bL8U NPH1 FCNL VALUE 15.242 45.898 426.000 26.21.9 46.680 424.250 1617.3'75 42.090 508.750 31.92~ 51.2'1 355.500 52.969 60.791 289.250 15.992 55.273 295.000 18.484 58.594 265,500 86.125 53.760 311.250 30.766 56.006 304.750 48.156 58.740 279.750 244.25O 53.516 274.000 D g P T H 700.000 600.000 500°000 400.000 ]00.000 200,000 100.000 59.000 M N E M {] N I C SP GR RHOB 5P GR RHOB GR SP GR RHOB GR SP GR R H 0 B GR SP GR · R H [) B GR SP GR RHOB GR SP GR RHOB GR SP GR RHOB GR 'V AL U E -1,90. 41. 1. 34. -168. 64. 2. 50. -172. 63. 2. 46. -199. 35. 2. 33 . -202. 28. 1. 22. -243. 37. 2. 34. -86. 20. 1. 19. -82. -99g. -999. 18. 000 938 965 81 3 250 250 059 719 5OO 781 05 3 1,25 250 31,3 1.17 750 000 391 907 500 500 344 410 406 000 313 101 063 750 250 250 609 MN EMON IC CALl N R,A T DT C A L I NRAT DT ILD CAb I NRAT DT ,I, L D CALI NRAT DT ILD CALl NRAT DT I L,D CALl NRAT DT 1LD CALl NRAT DT ILD CALl NRAT DT V' A L [,1E 331.750 16,766 4.539 145.750 70.063 16.766 4.285 153.750 111.875 16.297 4.410 150.000 249.375 16.766 4.180 115.188 2000.000 16.766 91,8 68.750 16.766 2.488 119.375 47.313 15.578 5.582 -999.250 2000.000 -999.250 -999.250 -999.250 MNEMONIC IbM DRHO NCNb ibm DRHO NCNb IBM DRHO NCNb DR,HO NCNb iLM DRHO ,NCNb 1L.M DRHO NCNb i LM ,D R H 0 NCNb DRHU NCNb VALUE 58.531 0.042 1,458.000 40.688 -0.004 1775.000 46.750 0.010 168.:3.000 50.21,9 0.009 1513.000 121.313 0,046 1,342.000 30.922 0.112 2710.000 2000.000 -0.601 1186.000 9.477 -999.250 -999.250 N N E M 0 N I C LLSU N P H I FCNb LL8U NPHI FCNL L [,8 O NPHI. FCNb LLSU NPHI FCNb bbSU NPHI FCNb hbSU NPHI FCNG hhSU NPHI FCNL LL8U NPHI FCNL 'V AL UE 275.750 56.104 278.500 131.250 51.514 400.750 1.61.1,25 54.004 369.500 372.250 49.658 309.000 19:19.000 62.9,39 268.500 127.375 21.143 1044.000 2.574 75.439 240.625 2.346 -99925.000 -999.250 SUMMARY JIF DATA ~Ur~BE,[.~ OF RECORDS: 1043 I.,ENGTH L)F RECORDS: 966 BYTES I,ENGTH 0~' LAST RECORD: 186 B¥~ES FILE TEAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT FILE NAME: 1024 BYTES TAPE TRAILER LENGTH: 1132 BYTES TAPE NAME: 60306 DATE: 80/ 4/12 SERVICE NA,ME: EDIT TAPE CONTINUATION NUMBER: Ol NEXT TAPE; NAME: COMMENTS: UNIQUE WELL IDENTIFICATION NUMBER IS 50-029-20,~93