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198-176
ORIGINATED TRANSMITTAL DATE: 6/25/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5502 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5502 2D-06B 50029211680200 Production Profile (PPROF) 12-Jun-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-176 T40613 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.25 08:15:54 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com (.9 r • • til CV _00 a;NE) C Us j�A L OOn ETL = L.. : 0 l� N N5A r faO��mw ❑ a a c, c a > o ,. -o J W r r- n )- r- n r- r r- I- r ''' v p Or m J Q '- r r r N L a U L J Q kD T T T T T T T T E 4., c -0 O V) 0 Co 10 Co IO to t0 fo )6 C C C C W C UCL 1 Q r N MN N N N N M M M O Lc DO� Z ce M1 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ CO v U OJ p L. yJ J J J J J J W J W J J M U 0 W W W W W W W W W W W W .1 a) V- LL LL LL LL LL LL LL LL LL LL LL LL Y a1 aJ CU Q J J J J J J J J J J J J a > y CU - [ U. 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December 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ," s DATA LOGGED Anchorage, Alaska 99501 - tZz9i2°' M.K.BENDER RE: Perforation Record: 2D-06B Run Date: 10/29/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2D-06B Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21168-02 scANwe PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: a fro�� I3ecart Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~' ~"/~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: D Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds Other Complete COMMENTS: Scanned by: Beverly Mildred Daretha~owell Date: ~/.,~)Is/ /~ TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si STATE OF ALASKA ~ ~ -~~ - AL~ OIL AND GAS CONSERVATION COM~ION ;,.3.,,fi,~ ts' ~. c?.,',. REPORT OF SUNDRY WELL OPERATIONS F~ F~,l. ! ~( 1. Operations Performed: r ^ Abandon ^ Repair Well Re-Enter Suspended Well ^ Plug Perforations ^ Stimulate ^ ® Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: Conoco Phillips Alaska Inc. ®Development ^ Exploratory 198-176 3. Address: ^ Service ^ Stratigraphic 6. API Number: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21168-02-00 7. KB Elevation (ft): 121, 9. Well Name and Number: • Kuparuk 2D-06B 8. Property Designation: 10. Field /Pool(s): ADL 025653 Kuparuk River Unit /Kuparuk River Pool _ 11. Present well condition summary Total depth: measured 11283' feet true vertical 6151' ' feet Plugs (measured) None Effective depth: measured 11283' feet Junk (measured) 8704' ' true vertical 6151' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 110' 110' Surface 4104' 9-5l8" 4104' 3160' 3520 2020 Intermediate 7185' 7" 7185' 5015' 4980 4330 Production Liner 2056' 3-1/2" 7024' - 9080' 4910' - 6110' 10160 10540 Liner 2289' 2-3/8" 11200 11780 8715' - 11004' xxx' - 6145' ~~ `'~b~~~~~ /Sub v `, `~:... C`~F: csC:t~7~ k~~cs" CS°-1 P rf ti D th MD ft ' ~"u•~C:L.:~.•~CZ.ttt ~~`~ •SrCC%~_~t`•~~tx~~4'~t:.~. ' F e ora on ep ( ): Slotted Liner: 8820 - 8850 ~ ~, ,~ ~~.-~:SS ~-dt- Perforation Depth TVD (ft): 6101' - 6112' 3-1/2", 9.3# L-80 7024' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker Packer 7032' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~~~ `/~~' '~ Q ~~~$ Treatment description including volumes used and final p ressure: Cut and pull 2-3/8" casing from 8725'. (See attached a- mail from Tom Maunder, dated 05/13/08) Drill 2D-066L1 with Coil Tubing. 2D-06B is no Ion er accessible due to the 2D-06BL1 liner to at 8625' coverin the whi stock and KB acker w/ standin valve . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Gary Eller, 263-4172 (Office) N/A Printed Name Terrie Hubble Title Drilling Technologist _ ~ Prepared By Name/Number: Signature Phone 263-4172 Date N DS Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 S , „~(_ ~ O ~Q~~ Submit Original Only O R I G I CIA L ~-~~~~~~ 1~.~ • Page 1 of 1 • Hubble, Terrie L From: Maunder, Thomas E (DOA) [tom.maunder@alaska.gov] Sent: Tuesday, May 13, 2008 4:13 PM To: Eller, Gary (ConocoPhillips) Cc: Hubble, Terrie L Subject: RE: 2D-06BL1 PTD (207-007) Covers Pulling 400' of 2-3/8" Liner? Gary, After finally getting in the right wellbore (the permit number had an extra 7), speaking with you and talking with Steve Davies; it is our consensus that you already have a valid permit to perform the planned operations. If you were drilling more than 499' beyond the permitted presently permitted depth/length a new permitting action would be needed. According to you, the directional trajectory is essentially the same. Stopping the well shorter than permitted is not an issue. The actual drilled BHL will be captured on the 407. It would appear that pulling the 2-3/8" liner section was also authorized when the permit was approved. Technically a sundry is probably needed due to pulling the top of the liner that is presently set in 2D-06B (198-176), but that additional paper would not really serve any purpose right now. Please be sure that a 10-404 updating the liner len th is filed for 2D-06B. A co y of this message should be included with that 404. We will return the recently submitted applications. I will place a copy o this message In both we I es over ere. Call or message with any questions. Tom Maunder, PE AOGCC From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, May 13, 2008 3:25 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L Subject: RE: 2D-06BL1 PTD Covers Pulling 400' of 2-3/8" Liner? Tom - We could be moving the rig as early as this weekend, depending on how quickly this last lateral drills. I assumed that you have seen the PTD for 2D-06BL1 - it was an amendment to a 10-401 that was approved in early 2007 (#207-007). The amended version was sent out last week. In short, we want to cut and pull 400' of 2-3/8" slotted liner that is inside of 3-1/2" cemented liner where we'll kickoff the Lt lateral. There is no mechanical problem whatsoever with pulling this 400' of liner -the liner top will still be above the existing window, and it's not providing pressure isolation anyway. Please let me know if you need anything else. -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 13, 2008 2:40 PM To: Eller, J Gary Cc: Venhaus, Dan E Subject: RE: 2D-066L1 PTD Covers Pulling 400' of 2-3/8" Liner? Gary, I have to take a look at the intended procedure. When does it look like you will get started? Tom From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, May 13, 2008 1:28 PM To: Maunder, Thomas E (DOA) Cc: Venhaus, Dan E Subject: 2D-06BL1 PTD Covers Pulling 400' of 2-3/8" Liner? Tom -You should have before you a 10-401 for well 2D-06BL1, a single CTD lateral of a gas lifted Kuparuk producer. That lateral calls for first cutting and pulling 400' of 2-3/8" slotted liner that was set high in 2D-06B back in 1998. Is that cut and pull of slotted liner covered by the 10-401 (once it gets approved), or is a separate 10-403 required? Thanks. 7. Gary Eller Wells Engineer ConocoPhillips -Alaska work:907-263-4172 cell: 907-529-1479 fax:907-265-1535 7/1/2~~8 • 2D-06BL1, Pre-Rig Work DATE SUMMARY OF OPERATIONS 3/25/08 T-POTS- PASSED, IC-POTS- PASSED, MV-PT -FAILED, SV-PT -PASSED, MITOA -PASSED, FUNCTION TEST LDS -PASSED 3/26/08 TIFL-(INCONCLUSIVE); MV PT/DD-(PASSED); SV DD-(PASSED); (PRE CTD). 4/1/08 TIFL -PASSED 4/5/08 ENCOUNTERED THICK CRUDE /ASPHALTENES BETWEEN 2344' & 2471' SLM. UNABLE TO DRIFT WITH 2.5" BAILER, RECOVERED SAMPLE. DISPLACE TBG WITH 95 BBL HOT DSL. 4/6/08 GAUGED TBG TO 2.77" TO 7000' SLM; BRUSH & FLUSH SCALE FROM GLMs. PULLED OV C~ 6978' &GLV @ 5220' RKB. ATTEMPTED PULL DV @ 6221' RKB. SET 3/16" OV @ 6978' RKB. LIB'd GLM C~3 6221', VERIFIED DV IN POCKET. 4/7/08 PULLED-GLV C~ 2461' RKB & DVs C~ 4006' & 6221' RKB. SET GLVs @ 6221', 5220,- 4006' & 2461' RKB. 4/8/08 RAN HOLEFINDER, TESTED TBG & GLV's, GOOD TEST. JOB COMPLETE. 4/10/08 RE-TIFL (PASSED ). 5/11/08 DRIFT TBG WITH 15' X 2.77" DMY GUN TO 8307' RKB. SET 2.79" CATCHER C 8281' SLM. DRIFT TBG TO 1.82" TO 8788' SLM. PULLED ORIFICE @ 6979' RKB (OV PLUGGED WITH ASPHALTENES). PULLED GLV @ 5220' RKB. RECOVERED SAMPLE. 5/12/08 PULLED GLV C~ 2461' RKB. REPLACED WITH DMY VLV. DROPPED DMY VLV WHILE TRYING TO SET @ 5220' RKB. SWEPT TBG WITH 2.60" BELL GUIDE & PULLING TOOL TO TOP OF CATCHER @ 8281' SLM. TBG CLEAR TO CATCHER. 5/13/08 RETRIEVED DMY VLV FROM CATCHER C~3 8281' SLM. SET LIGHT DMY VLV's @ 5220' & 6978' RKB's. LOAD IA WITH DIESEL & ATTEMPT MITIA. FAILED. IA ON VAC. CHECK SET STA #1, #3 & # 5. VLV'S IN POCKET. 5/14/08 SHOT FLUID LEVEL IN IA @ 528'. RAN HOLE FINDER & TESTED TBG C~ 7008' SLM. PASSED. RAN TEST TOOL TO 7050' SLM. FAILED. PASSED C~ 7020' SLM. ESTABLISHED INJECTIVITY RATE OF 1.5 BPM C~ 440# DWN IA. NO CHANGE IN TBG/ OA PRESSURES. 5/15/08 RAN TEST TOOL TO 7085' SLM. TESTED TBG TO 500#. PASSED. SET 2.79" CATCHER SUB 8281' SLM. PULL LGLV C~ 6221' & 4006' RKB. REPLACE WITH LIGHT DMY VLV's. PULL CATCHER SUB C~ 8281' SLM. MITIA TO 3000#. PASSED. JOB COMPLETE. 5/16/08 CUT THE 2 3/8" SLOTTED LINER AT 8725' WITH A 1 11/16" CHEMICAL CUTTER. SEVERING HEAD LOOKED GOOD AT SURFACE. 5/17/08 RIH WITH BAKER 3" G SPEAR AND LATCHED TOP OF LINER @ 8306' CTMD. PUH AND FOUND THAT LINER WAS NOT CUT, PULLED 15K OVER STRING WEIGHT AND STARTED JARRING. AFTER THREE JAR LICKS SEEM GOOD INDICATION THAT WE MOVED LINER. PUMP OFF FISH & NECK. POOH AND FOUND A 4" INCH SECTION OF THE FISHING NECK ON SPEAR. RDMO. JOB INCOMPLETE. 5/18/08 CUT THE 2 3/8" SLOTTED LINER AT 8715' WITH A 1 11/16" JET PowerCutter 5/19/08 SET BAITED BAKER SPEAR (3" BAIT SUB. X0. AND 2.023 SPEAR= 26 1/2" OAL) IN LINER TOP @ 8307 RKB. 6/6/08 SET C-SUB, PULLED DMYS @ 4006', 5220', 6221', 6978' RKB. 6/7/08 PULL DMY C~ 2461' RKB, SET GLV'S @ 2461', 4006', 5220', 6221' RKB, AND OV @ 6978' RKB. 618/08 PULL C-SUB W/MISSING RK RUNNING TOOL INSIDE. PERFORMED 30 MIN SBHPS=2480 psi, 122 deg F. 15 MIN GRADIENT STOP MADE @ 6936' RKB=2451 PSI. JOB COMPLETE. • BP AMERICA Page 1 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/21/2008 00:00 - 04:30 4.50 MOB P 04:30 - 07:45 3.25 MOB P 07:45 - 14:45 7.00 MOB P 14:45 - 19:00 4.25 RIGU P 19:00 - 00:00 5.00 RIGU P 5/22/2008 00:00 - 06:45 6.75 RIGU P 06:45 - 13:15 I 6.501 BOPSUpP 13:00 - 13:15 0.25 BOPSU P 13:15 - 14:30 1.25 BOPSU P 14:30 - 14:45 0.25 RIGU P 14:45 - 16:00 1.25 RIGU P 16:00 - 18:30 2.50 RIGU P 18:30 - 19:00 0.50 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 21:00 1.00 FISH P 21:00 - 22:45 1.75 FISH P 22:45 - 00:00 1.25 FISH P 15/23/2008 100:00 - 01:00 I 1.001 FISH I P PRE Pull off of well and relocate to CPF3 and stop PRE Wait on field crew change. PRE Continue on from CPF3 to DS 2D. PRE Prep location, lay herculite, set rig mats, spot rig over well. 19:00 R' PRE NU BOP stack mana ed ressure loo PU 2" E-free coil. PRE Continue with NU of BOP stack and Managed Pressure Loop. Install and test control lines for SSV on tree and wing. Change out pipe rams. Grease Mud Cross. PRE Test BOPE Mana ed Pressure Drillin Loo ,and Tiger tank hard line as per well plan and AOGCC reg's. AOGCC Witness waived by Bob Noble. PRE PJSM on pulling BPV PRE RU lubricator and ull BPV. 130 psi on the well when BPV was ulled. RD Lubricator PRE PJSM on Stabing injector and Stabing coil into injector. PRE PU injector, Pull test grapple connection on coil, Stab coil into injector. PRE Fill Coil and PT Inner reel valve and Packoff. DECOMP PJSM DECOMP Kill well with 1 bls seawater. 4.2 BPM at -400 WHP. Well went on a vacuum when um was shut down. Keep hole full with charge pump accross tree. MU 2" kendal connector. Pull test to 45000 and PT 4000 psi. DECOMP PU Baker fishing string DECOMP RIH. Weight check at 8250, 18500 up, 13000 down DECOMP fi h t 1 '. PUH to confirm I tch. Start jarring with 3000 overpull, straight pull to 32000 Increasing up weight 2000# increments to 18000 overpull jarring and 42000 over straight pull. After 22 jar hits with no movement, jars are going off before we get to 18000 overpull. Hold 42000 overpull and allow jars to cool down. DECOMP Continue jarring at 18000 over and pulling up to 42000 over. Up weight before latching into fish was 18500. On iar hit # 50 fish Dulled free and came up hole with weight at 01:00 - 03:15 2.25 FISH P DECOMP 03:15 - 03:30 0.25 FISH P DECOMP 03:30 - 05:30 2.00 FISH P DECOMP 05:30 - 08:30 3.00 EVAL N WAIT DECOMP 08:30 - 08:45 0.25 CLEAN P DECOMP POOH. At 515' hung up at nipple 10000 over pull up and 2-4000 down to get free. On fourth attempt pulled through and continued to surface PJSM Lay down fishing tools. Deployment sleeve at top of liner was severly coroded and the bait sub had been driven downinto it. This is what caused the hang up at 515' nipple. Lay down 6 solid and 8 slotted joints of 2 3/8" liner and one 7.5' jet-cut joint. Solid liner had numerous holes eroded through it. Slotted liner in decent shape. Jet cut was complete - no tab hanging onto liner below. Waiting on PDS. Shut well in, was taking 50 bbls/hour static with seawater. Talked to town, decided to make cleanout run since it looks like Printed: 6/30/2008 9:32:56 AM • BP AMERICA Operations Summary Report Page 2 of 12 ~ Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name.: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/23/2008 08:30 - 08:45 0.25 CLEAN P DECOMP solids were holding the fish in place. PJSM on RU jet nozzle BHA and Stabbing injector on well 08:45 - 09:15 0.50 CLEAN P DECOMP RU jet nozzle, stab on injector 09:15 - 11:20 2.08 CLEAN P DECOMP RIH, In Rate=.02 Out=O bbls/min Tag top of tubing stub at 8724' 11:20 - 12:35 1.25 CLEAN P DECOMP PU to 8000' and close choke, bullheading away. Pump rate= 2.95 bbls/min CP= 4000 psi Wash back down to 8720' from 8000' at 20 fUmin. _ Wash up from 8720' to 8000' at 30 fpm. Blead IA and OA down from 1000 psi / 390 psi to 24/95 psi. 12:35 - 13:30 0.92 CLEAN P DECOMP POOH keeping hole full WH Press=20psi IA=425 psi OA=180 psi 13:30 - 13:50 0.33 CLEAN P DECOMP PJSM while POOH on LD of nozzle and PU of PDS caliper tool. 13:50 - 14:00 0.17 CLEAN P DECOMP POOH. 14:00 - 14:45 0.75 CLEAN P DECOMP LD Nozzle BHA and PU PDS Caliper. 14:45 - 15:05 0.33 EVAL P DECOMP RIH with PDS cali er to in tool. 15:05 - 15:30 0.42 EVAL N HMAN DECOMP POOH at 1,600' after evaluating deployment timing of PDS tool to rest for more time. 15:30 - 15:55 0.42 EVAL N HMAN DECOMP Unstab injector, change out program sub of PDS tool with new timing set for 2 hours, Restab injector. Caliper should deploy at 17:45 15:55 - 16:15 0.33 EVAL N HMAN DECOMP RIH to 1600' MD 16:15 - 17:25 1.17 EVAL P DECOMP RIH to 8700' 17:25 - 17:50 0.42 EVAL P DECOMP Wait on Caliper deployment 17:50 - 18:10 0.33 EVAL P DECOMP Start to log up at 48 fpm from 8700'-7700' with In rate=1.51 bbl/min 18:10 - 19:45 1.58 EVAL P DECOMP POOH 19:45 - 20:00 0.25 EVAL P DECOMP LD caliper tools. Initial data from 20:00 - 21:00 1.00 CHEM P DECOMP Prep to blow down coil. Pump 50 bbls. fresh water, 10 bbls. inhibited water and 5 bbls. methanol. 21:00 - 21:30 0.50 EVAL P DECOMP PJSM for N2 blowdown 21:30 - 22:00 0.50 GASN2 P DECOMP Rig up N2 unit and cool down 22:00 - 22:30 0.50 GASN2 P DECOMP Displace fluids from coil with 25000 SCF N2 22:30 - 00:00 1.50 DEMOB P DECOMP RD reel iron. Install grapple and tail coil to reel. Secure pipe and lower reel to trailer 5/24/2008 00:00 - 04:00 4.00 WHIP P WEXIT PU 2" E-Coil. MU hard line and grapple Pull coil across to injector 04:00 - 04:40 0.67 WHIP P WEXIT MU Kendal CTC and pull test to 40K 04:40 - 05:30 0.83 WHIP P WEXIT Behead a-line and test 05:30 - 06:15 0.75 WHIP P WEXIT Fill coil. 06:15 - 06:40 0.42 WHIP P WEXIT Crew change and walk a rounds. 06:40 - 07:15 0.58 WHIP P WEXIT Pressure test Hard line. Pressure test inner reel va-ve. Printetl: 6/30/2008 9:32:58 AM L J • BP AMERICA Page 3 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-066 Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task ~ Code NPT Phase Description of Operations 5/24/2008 06:40 - 07:15 0.58 WHIP P WEXIT 07:15 - 08:00 0.75 WHIP P WEXIT 08:00 - 08:20 0.33 WHIP P WEXIT 08:20 - 08:40 0.33 WHIP P WEXIT - 08:40 - 09:25. 0.75 WHIP P WEXIT 09:25 - 12:00 2.58 WHIP P WEXIT 12:00-12:55 ~ 0.92~WHIP ~P ~ WEXIT 12:55-14:15( 1.33WHIP P I (WEXIT 14:15 - 15:50 1.58 WHIP P WEXIT 15:50 - 16:00 0.17 WHIP P WEXIT 16:00 - 16:55 0.92 WHIP P WEXIT 16:55 - 18:30 1.58 STMILL P WEXIT 18:30 - 18:50 0.33 STMILL P WEXIT 18:50 - 19:15 0.42 STMILL P WEXIT 19:15 - 21:20 ~ 2.08 ~ STMILL ~ N ~ DFAL ~ WEXIT 21:20 - 21:40 0.33 STMILL N DFAL WEXIT 21:40 - 23:00 1.33 STMILL N DFAL WEXIT 23:00 - 23:30 0.50 WHIP N DFAL WEXIT 23:30 - 00:00 0.50 WHIP N DFAL WEXIT 5/25/2008 00:00 - 01:00 1.00 WHIP N DFAL WEXIT 01:00 - 02:30 1.50 WHIP N DFAL WEXIT 02:30 - 02:45 0.25 WHIP N DFAL WEXIT 02:45-03:30 I 0.751WHIP IN (DFAL (WEXIT Pressure test coil connecter. PJSM on PU and Handling of Whipstock BHA. Install check valves and change lubricator below injector. Fill well and WO SLB pip tags. Install pip tags and finish PU of Whipstock assembly. RIH with WS. EDC open. Keeping hole full down BS with charge pump. In rate=1.76 no returns Gamma ray Logging 8435'-8524.5'. -37 ft Correction. Casing Collar logging from 8524' to 8650'. PU WT check. UP WT = 21,200 lbs. DWN WT = 1i,5001bs. RIH to 8650' too of whipstock PU to an UP WT of 20,200 lbs. Close EDC and filled coil at .8 bbl/min Pressure up coil to set Whipstock. In/out rate = .81 bbls/min. Pressure stabilized at 2200 psi. Packer appears to be set getting 1 for 1 returns in/out rate = 1.5/1.5 bpm ~ 2440 psi PT weal and packer to 1000 psi. with 15 psUmin bleed off per minute (very small leak). POOH while Circ with no losses. PJSM on LD of BHA and PU of window milling BHA. Lay down whipstock setting tool. Tool has stroked properly and setting rod sheared at bottom of threads. PU window milling BHA. RIH with milling BHA 1:1 returns while RIH at .3 BPM down coil Tie in at 8450' -38.5' correction Continue RIH Tagged whipstock at 8704_', indicated by weight and pressure increase POOH while discussing options for second whipstock, Pressure up well to 1000 psi to establish loss rate. bled to 100 WHP in < 10 min. Attempt to establish rate, 0.1 - 0.2 BPM ~ 400WHP Lay down milling BHA Waiting on new whipstock and packer. Reconfigure lubricator. PT CTC and UOC to 4000 psi Set up whipstock and packer. Install two PIP tags in whipstock. PJSM for PU whipstock Assemble packer/WS. Install double PIP tags. PU BHA RIH, circulate through open EDC Log tie in, -4' correction. SLB had re-aligned the counter wheel on the injector prior to RIH. RIH to 8657.65' bit depth, top of WS at 8645'. Orient to 180 deg for low side window Close EDC and slowly bring pressure up 200 psi per step. At 1200 psi setting tool sheared. Printed: 6/30/2008 9:32:56 AM ~~ l__.J • BP AMERICA Page 4 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 5/25/2008 02:45 - 03:30 0.75 WHIP N DFAL WEXIT Set down 4000#, pulled up clean. PT packer to 1000 WHP for 5 min. Holding good. 03:30 - 05:00 1.50 WHIP N DFAL WEXIT POOH, 1:1 returns 05:00 - 05:10 0.17 WHIP N DFAL WEXIT Lay down WS setting BHA 05:10 - 05:30 . 0.33 STWHIP N DFAL WEXIT PU window milting BHA with straight motor, 2.74' mi an 3 string reamer on BHI coiltrack TS. O~~Lt 05:30 - 07:00 1.50 STWHIP N DFAL WEXIT RIH circulating in 9.5 ppg 1# bio 07:00 - 07:15 0.25 STWHIP N DFAL WEXIT Log GR tie in from 8450'. Subtract 1' correction. 07:15 - 12:00 4.75 STWHIP P WEXIT RIH. Tag top of whipstock at 8646' pumping (top of window). Begin time milling from 8645.9' at 10 minutes per 0.1 ft. 1980 psi fs at 1.52 in/out. IA/OA/PVT: 146/168/ variable. WHP/BHP/ECD: 30/3119/10.29. Continue to displace well from seawater to 9.5 ppg 1 # biozan. Formation sand and metal observed in the returns. 12:00 - 14:00 2.00 Sl-WHIP P WEXIT Continue to mill ahead at 8649'. DHWOB: 1.5-2.5k#. Continue to get metal and sand back to surface. Drilling break at 8650.4'. Call this the window bottom. Mill ahead in formation to 8660'. 14:00 - 14:30 0.50 STWHIP P WEXIT Back ream window several times to dress same. Dry drift window. Smooth. 14:30 - 16:30 2.00 STWHIP P WEXIT Circulate out of hole. 1250 psi ~ 1.11 bpm. 16:30 - 17:30 1.00 DRILL P PROD1 Hold PJSM. At surface. Get off well. LD window milling motor and mill. Window mill gauged 2.74" going in, 2.73 no-go after run. MU 1.9 deg x-treme motor with rebuilt Hycalog bi-center bit. Stab coil. Test MWD tools. Get on well. 17:30 - 18:50 1.33 DRILL P PROD1 Run in hole. 18:50 - 19:15 0.42 DRILL P PROD1 Tie in log at 8430', -3' correction 19:15 - 19:45 0.50 DRILL P PROD1 Tag bottom at 8660.5'. Start drilling ahead, still on BIO. Waiting on Flo-Pro 19:45 - 21:30 1.75 DRILL N WAIT PROD1 Waiting on Flo-Pro. Roads are in bad shape to to torrential rains. Original call out for trucks was 10:00 AM... 21:30 - 00:00 2.50 DRILL P PROD1 Flo-pro arrived, start pumping DH and continue drilling ahead. 1.65 BPM, 3750 freespin, 120E TF, -25 fph with 3K WOB Drilled to 8720' at midnight 5/26/2008 00:00 - 04:00 4.00 DRILL P PROD1 Continue drilling build section. 3825 freespin, 90L TF, 2-3K WOB at 4100-4300 psi, 12.2 ECD, -25 FPH Drilled to 8810', ROP increased at 8770' to 70+ FPH 04:00 - 04:24 0.40 DRILL P PROD1 Wiper to window 04:24 - 05:15 0.85 DRILL P PROD1 Continue drilling, only getting 25 Deg. dog legs. Expected 35 deg. Drilled to 8839' Formation tops appear to be -10' higher than anticipated. Trip for AKO adjustment 05:15 - 05:45 0.50 DRILL P PROD1 Trip OOH for motor adjustment 05:45 - 06:10 0.42 DRILL P PROD1 Tie in from 8430'-8446', +1 correction. RIH and log RA marker at window 06:10 - 07:40 1.50 DRILL P PROD1 POOH from 8446'-1800' following pressure schedule. 07:40 - 07:50 0.17 DRILL P PROD1 PJSM on pressure undeployment of build BHA, while POOH 07:50 - 08:00 0.17 DRILL P PRODi Continue to POOH to surface. rnntea: a~urzuua a:~cao r•m :' KRU 2D-06BL1 A-sand Producer ' ~On4GDPh1~~1 S p Alaska, Inc. 3-1/2" Camco DS nipple, 2.812" min ID at 515' MD 3-1/2" 9.3# L-80 AB-mod EUE Tubing 3-'/" Camco MMM GLMs @ 2461', 4006', 5220', 6221', & 6978' MD 9-518" 40# J-55 ~ 4104' MD 7" 26# J-55 ~ 7185' MD 2D-06BL1 KOP @ 8645' MD (low-side exit) 3-'/" Camco D nipple, 2.80" min ID @ 7022' MD (milled to 2.80" during 1998 2D-066 sidetrack) Baker C-2 ZXP liner packer w/SBE @ 7032' MD 3'/Z' marker joints @ 8510' & 8526' RKB 2'/" liner top @ 8626' and 3" openhole 2'/" slotted liner 2D-066L1 southern lateral TD @ 11,350' and C7 • 2D-066 window @ 8767' MD ~ 3'/Z' KB packer/ whipstock with standing valve at 8645' 2'/" liner junction at 9673' MD i is 3'/2' KB packer/ whipstock with standing valve, fell to 8704' =-----_ 2g/" liner cut @ 8715' (5/18/08) (t~ 7024' MD 3" openhole 2'/" slotted liner 2D-06B east lateral TD @ 11004' md, drilled in 1998 6/4/08 • >LL L ____ _ _ T~'4fi/f~/CAL ._ __; ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 559-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~~~~~ ~U~ ~ Z~d~ Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1) 2) Caliper Report 23-May-08 2D-06B Caliper Report 29-May-08 1{}130 ~~`~- (~ ~ /(off Esc ~9~ -rrs3 t ~3~~ Signed Print Name: ( Y ln~r;:5~'fv~~ 1 VI~G w~o.~. 1 Report / EDE 1 Report / EDE 50-029-21168-02 50-029-22815-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL: '~~ ~7_.'d....._. WEBSITE .,5'] C:\Documents and Settings\Owner\Desktop\Transmit_Conoco.doc 3 • • Memory MultaFinger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2D-066 Log Date: May 23, 2008 Field: Kuparuk Log No.: 6231 State: Alaska Run No.: 1 API No.: 50-029-21168-02 Pipet Desc.: 3.5" 9.3 Ib. L-80 ABM-BTC SCC Top Log Intvl: 8,000 Ft. (MD) Pipet Use: Liner Bot. Log Intvl: 8,678 Ft. (MD) Inspection Type : Pre-Whipstock Placement Damage Inspection COMMENTS This caliper data is tied into the marker jo/nt collars at 8,512 ; 8,526' and 8,543' (FEND). This log was run to assess the condition of the liner with respect to corrosive and mechanical damage prior to whipstock placement. The caliper recordings indicate that 3.5" liner logged is in good to fair condition with respect to corrosive damage, with a 34°~ wall penetration recorded in an area of corrosion in joint 41 (8,336') and a 30% wall penetration recorded in an isolated pit in joint 40 (8,321'). Recorded damage appears in the forms of general corrosion and shallow, scattered pitting. No significant I.D. restrictions are recorded throughout the liner logged. Deposits restrict 1. D. to 2.77" in joint 42 (8,377'}. A 3-D log plot of the caliper recordings across the whipstock setting interval are included in this report, as well as cross-sectional illustrations of the most significant events recorded throughout the liner logged. MAXIMUM RECORDED WALL PENETRATIONS Corrosion (34°~} Jt. 41 @ 8,336 Ft. (MD) Isolated Pitting (30%) Jt. 40 @ 8,321 Ft. (MD) Shallow Corrosion (20°r6) Jt. 42 ~ 8,364 Ft. (MD} Shallow Pitting (20%) Jt. 46 ~ 8,490 Ft. (MD) Shallow Pitting (20%) Jt. 51 @ 8,610 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 6°~) are reco rded th roughout the finer logged. MAXIMUM RECORDED ID RESTRICTIONS Deposits Minimum I.D. = 2.77" Jt. 42 @ 8,377 Ft. (MD) Lt. Deposits Minimum I.D. = 2.79" Jt. 45 ~ 8,452 Ft. (MD) 1 Lt. Deposits Minimum I.D. = 2.83" Jt. 44 @ 8,448 Ft. (MD) Lt. Deposits Minimum I.D. = 2.87" Jt, 43 ~ 8,3~ Ft. (MD) Lt. Deposits Minimum I.D. = 2.87" Jt. 40 @ 8,313 Ft. (MD) ~~~ ~u~ ~ 2oa~ Field Engineer: ©. Cain Analyst: M. Lawrence Witness: D. Johnston ~ proactive Diagnostic Serrices, Inc, / P.O. Box 1369, Stafford, TX 77497 Phone: {281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS<a~memorylog.com ' Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot ~. S " Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2D-06B Date : May 23, 2008 Description : Detail of Caliper Recordings Across Whipstock Interval 1 e D5n0 Max ID (1/10_ 0~}50(7 D5~0 Min 1^ (~Hn00 in~ 35.00 24 0500 Nnminalll'1 35nn Joint 30 _ __ 8010 8020 Joint 31 8030 __ 8040 _ __ 8050 Joint 32 8060 ~. 8070 8080 Joint S3 8090 8100 8110 Joint 34 8120 8130 8140 Joint 35 8150 8160 _. _ _ . J i t 36 8170 8180 - -- o n 8190 8200 $210 Joint 37 8220 8230 8240 __ - --- Joint 38 _ 8250 - - - - 8260 8270 Joint 39 8280 8290 8300 Joint ao Isolated - - i ing _. 30% Wall $310 _ Penetration 8320 8330 Joint 41 -- Corrosion 34% Wall 8340 -- Penetration 8350 8360 Joint 42 - _ _ - - Shallow --- -- Corrosion ° 8370 20 ~ wall Penetration 8380 8390 Joint 43 Shallow $400 - Corrosion 14°~ Wall Penetration 410 _ - 8420 8430 Joint 44 8440 - 8450 8460 Joint 45 Lt. Deposits 8470 8480 8490 Joint as Shallow Pitting 20°~ Wall 500 _ Penetration 8510 Joint 47 8 20 - - Marker Jt. 5 8530 Joint 48 Marker Jt. 8540 - _ _ - __ 8550 ' _ _ Joint 49 8560 857 - - -- - - 0 8580 • • PDS Report Overview ~, ~. Body Region Analysis Well: 2D-066 Survey Date: May 23, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of rngers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 ABM-BTC SCC 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 30 - 20 10 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal sed total = 24 pene. 0 16 6 2 0 0 loss 0 24 0 0 0 0 Damage Configuration (body ) 10 (i isolated goncnl hne nng hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 7 3 4 0 0 0 Damage Profile (~° wall) ~ penetration body ,-~- rnetal loss body 0 50 100 30 40 50 Bottom of Survey = 53 Analysis Overview page 2 • • ~ Minimum Diameter Profile Well: 2D-066 Survey Date: May 23, 2008 Field: Kuparuk Tool: UW MFC No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters (In.) 1.69 1.79 1.89 1.99 2.09 2.19 2.29 2.39 2.49 2.59 2.69 2.79 2.89 2.99 30 31 32 33 34 35 36 37 38 39 40 i E a1 e Z e 42 'ii 43 44 45 46 47 48 49 50 51 52 53 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 ABM-BTC SCC Well: 2D-06B Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 23, 2008 Joint No. Jt. Depth (Ft.) Pc•n. t tlctic•~ Iln..) Pen. Body (Ins.) I'en. `%~ Met~cl I cs ,~~ Min. LD• (Ins.} Damage Profile Comments (%wall) 0 50 100 30 7975 t ~ 0.02 `~ 5 92 Sli h oval. 31 8007 t~ 0.0 7 ; 2.93 3 8038 tt 0.03 1O i 2.93 33 8070 U 0.02 i _' 2.93 34 8101 tt 0. 2 7 ~ 5 35 8133 t t 0.02 7 -1 2.94 36 8164 r t 0.02 8 ~ 2.93 37 8196 U 0.03 11 '~ 2.95 38 8227 t~ 0.0 `~ -1 2.95 39 8259 t ~ 0.02 `) -i 2.93 40 8291 (t 0.07 311 -1 2.87 Iso e ittin t. De s'ts. 41 8322 t) 0.09 i4 -I 2.88 Corr sio Lt. De sits. 42 8354 U 0 05 2U -l 2.77 Shallow cor osion. De sits. 43 8385 t) 0.04 14 ~ 2.87 Shallow corrosion. Lt. De osits. 44 8417 t) 0.03 I ' -1 2.83 I_t. De osits. 45 9 U 0.01 4 (> 2.79 Lt. De sits. 46 8480 tt 0.05 2U ~ 2.94 Shallow ~ttin . 47 8512 It 0.02 ~ .95 Marker oint. 48 8526 U 0.03 1l) s 2.94 Marker oint. 49 8543 U 0.03 1 U 5 2.90 Sli ht oval. 50 8574 t~ 0.02 ~) _' 2.93 Lt. De osits. 51 8606 (1 0.05 2U S 2.91 Shallow ittin . 52 8637 0.02 2.95 53 t;b6`)__~ __ (t.ttZ 2.93 Penetration Body Metal Loss Body Page 1 ~w ~^ ~ ~ ~ r ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ r ~~ _ ~+~ PDS Report Cross Sections Well: 2D-06B Survey Date: May 23, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 ABM-BTC SCC Anal st: M. Lawrence Cross Section for Joint 41 at depth 8335.93 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 54 ° Finger 17 Penetration = 0.086 ins Corrosion 0.09 ins = 34% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 PDS Report Cross Sections 4 Well: 2D-06B Survey Date: May 23, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f _L-80 ABM-BTC SCC Analyst: M. Lawrence Cross Section for Joint 40 at depth 8321.1 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 54 ° Finger 16 Penetration = 0.075 ins Isolated Pitting 0.07 ins = 30% Wall Penetration HIGH SIDE = UP r ~ ~ r ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~^^ • Cross Sections page 2 PDS Report Cross Sections 1„ ~~ „ Well: 2D-06B Survey Date: May 23, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA N'o. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 AB,1~1-BTC SCC Anal st: M. Lawrence Cross Section for Joint 51 at depth 8609.637 ft Tool speed = 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 56 ° Finger 10 Penetration = 0.05 ins Shallow pitting 0.05 ins = 20% Wall Penetration HIGH SIDE = UP • Cross Sections page 3 ~ ~ i ~ ~ ~ ~ ~ ~ ! ~ ~ ~ ~ ~ ~ ~ ~ ~ ~-~u ~+~ PDS Report Cross Sections Well: ZD-06B Survey Date: May 23, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 AB~~V-BTC SCC AnalvsC M. Lawrence Cross Section for Joint 42 at depth 8376.7 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 56 ° Finger 6 Projection = -0.212 ins Deposits Minimum I.D. = 2.77 ins HIGH SIDE = UP Cross Sections page 4 ConocoPhillips Alaska, Inc. KRU 2D-O6B I7 21?-068 API: 500292116802 Well T : PROD An le TS: 49 de 8553 NiP (515-5~s, oo:a sao) SSSV Type: NIPPLE Orig Com letion: 10/12/1998 Angle @ TD: 90 deg @ 11283 . Annular Fluid: DSL/SW Last W/O: Rev Reason: TAG SLM Reference L Ref Lo Date: Last U ate: 10/4/2007 Last Ta : 8780 TD: 11282 ftKB Last Ta Date: 9/20/2007 Max Hole An le: 97 d 10074 Gas LiR Cesin Strin -ALL MarWrewalve 1 D~cri lion Size To Bottom ND Wt Grade Thread (zasl-2as2, Surface 9.625 0 4104 3158 36.00 J-55 BTC Production 7.000 0 7185 5014 26.00 J-55 BTC Conductor 16.000 0 110 110 62.58 H-40 Welded Gas Lift Production 3.500 7024 9080 6108 9.23 L-80 ABM-BTC irxtrel/DUmmy Sidetrack Window 4.000 8767 8768 6072 0.00 VaNe2 (coos-aoo7 Casin Stri - SLOTTE LIN R , OD:6.o18) Descri lion Size To Bottom TVD Wt Grade Thread Liner 2.375 8307 11004 6143 4.60 L-80 FL4S Tubin Strin -Tubin Size To Bottom ND Wt G rade Thread Gas LiR 3.500 0 7024 4908 9.30 L-80 ABM-EUE MandrelNal~a Perforations Summa 3 5220.5221 Interval TVD Zone Status Ft SPF Date T a Comment ( , 8820 - 8850 6100 - 6109 A-4 C 30 0 9/13/1998 S z Stimulations 8 treatme nts Interval Date T Comment Gas Lift ~ ~ m 8820 - 8850 9/13/1998 CMT 5QZ PERFS lu ed back rior to Sidetrack va we a Gas Lift Mandrels/Valve s (6221-6222, oD:s.o1a) St MD ND Man Mfr Men Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2461 2209 CAMCO MMM CAMCO GLV 1.5 RK 0.250 1419 0/15/199 ~ 2 4006 3100 CAMCO MMM CAMCO DMY 1.5 RK 0.000 0 0/11/199 GasLiR MandrelNaWe I 3 5220 3803 CAMCO MMM CAMCO GLV 1.5 RK 0.250 1381 0/15/199 5 © { 4 6221 4399 CAMCO MMM CAMCO DMY 1.5 RK 0.000 0 0/11/199 (ss7ass7s, 5 6978 4878 CAMCO MMM CAMCO OV 1.5 RK 0.188 0 226/20 T~w Other u s ui ,et c. -COMPLETION ~ (47024 D th TVD T Descri lion ID , oD:3.5o0, 515 515 NIP CAMCO DS 2.812 ID:z.ss2) 7022 4907 NIP CAMCO D -MILLED OUT 9/13/1998 2.800 7032 4913 PKR Baker Liner Packer 2.810 7045 4922 SBE 2.992 11003 6143 Shce 0.000 PKR (7032-7033 Fish - FISH , OD:4.540) De ih Desai lion Comment 11250 FISH 1.5" Orifice Valve w/RK latch lost downhole 5/1/2001 General Not Date Note sse 0/12/199 NOTE: WELL SIDETRACKED 2nd TIME (7at5.7oas, OD 6 750 2/12/1999 NOTE: MIN ID= 1.995" THRU SLOTTED LINER : . ) Production (0.7185, OD:7.OD0, Wt:26.00) Production (70249080, OD:3.500, Wt:9.23) Pert (8820.8850) CMTSQZ (8820.8850) Liner (8307-11004, OD:2.375, Wt4.60) FlSH 1125411251, OD:1.500) Page 1 of 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 13, 2008 4:13 PM ~~;,~ MAY ~. ~ 2008 To: 'Eller, J Gary' Cc: Hubble, Terrie L Subject: RE: 2D-066L1 PTD (207-007) Covers Pulling 400' of 2-3/8" Liner? Gary, After finally getting in the right wellbore (the permit number had an extra 7}, speaking with you and talking with Steve Davies; it is our consensus that you already have a valid permit to perform the planned operations. If you were drilling more than 499' beyond the permitted presently permitted depth/length a new permitting action would be needed. According to you, the directional trajectory is essentially the same. Stopping the well shorter than permitted is not an issue. The actual drilled BHL will be captured on the 407. It would appear that pulling the 2- 3/8" liner section was also authorized when the permit w a rove chnically a sundry is probably needed due to pulling the top of the finer that is presently set i 2D-06 198-17~but that additional paper would not really serve any purpose right now. Please be sure that a 10-404 updating the liner length is filed for 2D-066. A copy of this message should be included with that 404. We will return the recently submitted applications. I will place a copy of this message in both well fifes over here. Call or message with any questions. Tom Maunder, PE AOGCC From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, May 13, 2008 3:25 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L Subject: RE: 2D-06BL1 PTD Covers Pulling 400' of 2-3/8" Liner? Tom - We could be moving the rig as early as this weekend, depending on how quickly this last lateral drills. I assumed that you have seen the PTD for 2D-06BL1 - it was an amendment to a 10-401 that was approved in early 2007 (#207-007}. The amended version was sent out fast week. In short, we want to cut and pull 400' of 2- 318" slotted liner that is inside of 3-1/2" cemented liner where we'll kickoff the L1 lateral. There is no mechanical problem whatsoever with pulling this 400' of liner -the liner top will still be above the existing window, and it's not providing pressure isolation anyway. Please let me know if you need anything else. -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 13, 2008 2:40 PM To: Eller, J Gary Cc: Venhaus, Dan E Subject: RE: 2D-06BL1 PTD Covers Pulling 400' of 2-3/8" Liner? Gary, I have to take a look at the intended procedure. When does it look like you will get started? Tom From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, May 13, 2008 1:28 PM To: Maunder, Thomas E (DOA) Cc: Venhaus, Dan E Subject: 2D-06BL1 PTD Covers Pulling 400' of 2-3/8" Liner? 5/13/2008 Page 2 of 2 • • Tom -You should have before you a 10-401 for well 2D-06BL1, a single CTD lateral of a gas lifted Kuparuk producer. That lateral calls for first cutting and pulling 400' of 2-318" slotted liner that was set high in 2D-06B back in 1998. Is that cut and pull of slotted liner covered by the 10-401(once it gets approved), or is a separate 10-403 required? Thanks. 7. Gary Eder Welts Engineer ConocoPhittips -Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 5/13/2008 . RECEIVED . 1. Operations Performed: Abandon 0 Repair Well 0 ' Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 198-176 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21168-02 7. KB Elevation (ft): 9. Well Name and Number: RKB 121' 2D-06B 8. Property Designation: ¡ltþ (.. ).~(, ~ .3 ,¡Ø /.'t.01 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 11283' , feet true vertical 6149' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 3983' 9-5/8" 4104' 3158' PRODUCTION 7064' 7" 7185' 5014' LINER 2056' 3-1/2" 9080' 6108' LINER 2697' 2-3/8" 11 004' 6143 Perforation depth: Measured depth: 8820' - 8850' true vertical depth: 6100' - 6109' SGANNED JAN 1 0 2007 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7024' MD. Packers & SSSV (type & measured depth) pkr= BAKER LINER PACKER pkr= 7032' SSSV= NIP SSSV= 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: BH 1 a 2007 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0, Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Marie McConnell 1 Perry Klein p~nted Name ", Marie ~cCon~ell .' ....~ Title Problem Well Supervisor Signature #~/ /" #:7t}¿4Øi" . . Phone 659-7224 Date 1/7/2007 JAN 0 9 2007 ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONS'aska Oil & Gas Cons. Commission STATE OF ALASKA . Form 10-404 Revised 04/2004 ORIGINAl ~I,~ .Aþ /.1.01 dSuqmit 9riginal Only ,¿z::--I (I()/d? . 2D-06B DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 12/25/2006ISET 3.5" WRP @ 700T. 1/5/2007 Rigged up N2 purge across IA & OA Removed top half of Tanko conductor head. Seal welded braidenhead threads with 3 pass seal weld. 1/6/2007 MITOA passed (post BH seal weld). See attached form. Conductor topped with 2 gallons of RG2401 corrosion inhibitor water proof sealant. 1/7/2007 Pulled WRP @ 700T. ~. ~ ~ Tf ffif[ Œ (ill~ /Æ ~ ¡t~ $ ~ ffi~ I i ! I / I FRANK H. MURKOWSKI, GOVERNOR . AliASIiA OIL AND GAS CONSERVATION COMMISSION ; i 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12,2004 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 ~q<v"' f7~ Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2D (KRU 2D) pad on May 6, 2004. Attached is a copy ,of the Inspection Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective May 6, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2D must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely. 1H ;(liel T. Seamount, Jr. Commissioner Attachment cc: AOGCC Inspectors (via email) Safety Valve & Well Pressures Test Report - Review Reviewed By: P.I. Suprv Comm Pad: KRU_20 Inspection Dt 5/6/2004 Inspected by Chuck Scheve Interval: InspectNo: svsCS040507072635 Src: Inspector Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Reason 90-Day Well Number Permit Number Sepal PSI Set PSI UP Trip Test Test Test Code Code Code Date SI Oil,WAG,GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI Yes/No Yes/No ! 20-13 1840120 98 70 60 P P I-OIL . 20-12 1840940 98 70 65 P P I-OIL -- ¡- 20-09 1841030 98 70 65 P P I-OIL I 20-08 1841270 98 70 65 P P I-OIL 20-068 1981760 98 70 65 P P I-OIL I 20-03 1841530 98 70 65 P P I-OIL I 20-15 1841600 98 70 50 P 4 l-OIL 1000 1000 ISO Yes Yes IAxOAcommunication 1---- L 20-01 1841710 98 70 0 10 P I-OIL ) Comments Performance Pilot on well 20-01 failed to trip on initial test,was replaced and passed retest. Surface Safety Valve on Well 20-15 had very slow leak when pressure tested. Valve to be repaired and retested by operator. Wens 8 Components 16 Failures 2 Failure Rate 12.5% ) Wednesday, May 12,2004 ,I Alaska Oil and Gas Conservation Commission Safety Valve SYstem Test Report Operator: Pril~, 'ps .,, Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU/2D pad Separator psi: LPS ,9,9 HPS 1/28/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed CAS or cYc~ 2D-01 1841710 ~99 70 65 P P OIL 2D-02 1841520 2D-03 1841530 ,,~,. 2D-05 1841260 3750 2000 1750 P 7 wAG 2D-06B 1981760 99 70 55 P P OIL 2D-07 1841430 3750 2000 1850' P P 'WAG 2D-08 1841270 99 70 60 P P OIL 2D-09 1841030 99 70 ,, 55 P P OIL 2D-10 1841010 2D-11 1840990 oil 2D-12 1840940 99 70 60 P P 2D-13 1840120 99 70 60 ~ P P OIL 2D-14 1841590 2D-15 1841600 '99 70 60 P P OIL 2D~16 1841610 Wells: 9 Components: 18 Failures: 1 Failure Rate: 5.50% Remarks: Surface, ,safety on 2D-05 not tested due a slow leaking win$ valve Grove valve could be closed due to snow drit~s. RJF 1/16/01 Page 1 of 1 SVS KRU 2D Pad 1-28-01 CS.xls Well Compliance Report · File on Left side of folder 198-176-0 KUPARUK RIV UNIT Roll #1: Start: Stop Roll #2: MD 11283 TVD 06149 Completion Date: 2D-06B 50- 029-21168-02 PHILLIPS ALASKA 1NC Start Stop 10/12/98 Completed Status: 1-OIL Current: Name D 8896 L GR-MD L GR-TVD L MEM GLS-SPIN R EOW RPT R SRVY LSTNG Daily Well Ops _____ -- __ Was the well cored? yes no Comments: FINAL FINAL FINAL Interval BH GR-MUD OH 8773-11282 OH 5949-6031 OH TEM/PRES 0-7100 CH 5 BHI 8737.-11282. OH BHI 7205.11282. OH Are Dry Ditch Samples Required? ye ~, o~ Analysis Description Received? yes Sent Received T/C/D 3/17/99 3/22/99 3/17/99 3/22/99 D 3/17/99 3/22/99 6/23/99 6/23/99 12/16/98 12/18/98 11/20/98 11/20/98 And Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 MEMORANDUM TO: THRU' FROM: .. Julie Heusser, ~%\~' Commissioner Tom Maunder, P. I. Supervisor Chuck Scheve; State of Alaska Alaska Oil and Gas Conservation Commission DATE: SUBJECT: Petroleum Inspector January 28, 2001 Safety Valve Tests KuparUk River Unit 2D & 2E Pads Sunday, January 28, 2001' I traveled t° the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2D & 2E Pads. As the attached AOGCC Safety Valve SyStem Test Report indicates I WitneSsed the testing of 9 wells and 18 components with one failure on 2D Pad and 5 wells and 10 components with one failure on 2E Pad. The SurfaCe SafetY Valve on Well 2E-16 ~ had a slow leak when pressure tested. This valve will be serviced and retested by the operator. The Surface Safety Valve on well 2D-05, a WAG injector, could not be tested due to a leaking wing valve. This valve will be tested as soon as the wing valve is repaired. , · Earnie Barndt conducted the testing today he demonstrated gOod test procedure and was a pleasure to work with . All the wellhouses entered at these lOcations were clean and all related equipment appeared to be in good condition. Summary:, I witnessed the semi annual SVS testing at 2D & 2E Pads in the Kuparuk River Field. 1 failure 5,56% failure rate 1 failure 10% failure rate KRU 2D Pad, 9 wells, 18 components, KRU 2E Pad, 5 wells, 10 comPonents, 24 wellhouse inspections Attachment: SVS KRU 2D & 2E Pads 1-28-01 CS X Unclassified Confidential (Unclassified if doC. Removed) SVS KRU 2D & 2E Pads 1-28-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Brandi ' , ,, , AOGCC Rep: Chuck Scheve Submitted By: Chuck schev~ Date: Field/Unit/Pad: Kuparuk / KRU / 2E Pad Separator psi: LPS L 99 HPS 1/28/01 Well Permit Separ Set L/P Test .Test Test Date Oil, WAG, GINJ, N, umber Number PSI PSI TriP: Code Code Code Passed GAS or CYCL~ 2E-07 1931040 ..... 12E-08 1931890 99 ' 76' ~0 "i/' 'P' - ' 2E-09 1842'400 ............ 2E-10 1842':~001 99 '70 60 'P P ' ' i2E-11 184226'6 99 70 50 - P P _ 2E-15 '1841890 99 7'0 50 · P ' P ...... ~E~16 1841900 99 70 " 50 P 4 Wells: 5 Components: 10 Failures: 1 Failure Rate: Remarks: 1 o.oo°~,o my .Surface ,safetY on 2E'~ 1'6, . had., Slow_ . . leak when,. . , p. re ~syu_r. e .t, ested. Valve will_ be Servicexi a ret, ested by operator.. ........... RJF 1/16/01 Page 1 of 1 SVS KRU 2E Pad 1-28-01 CS.xls 6/23/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATI'N: Sherrie NO. 12674 Company Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 2D-06B MEMORY GLS 990610 I 1 2H-16 (,,.(~ f ~.~, MEMORY INJECTION PROFILE 990611 1 1 , , 2K-02 PRODUCTION PROFILE 990619 ,,, 2T-TAB-01 ~ / C.._ INJECTION PROFILE 990514 I 1 2U-16 ~.( / C~ INJECTION PROFILE 990614 I 1 2V-02 ¢~ ! ~.,.. INJECTION PROFILE 990610 1 1 3A-03 PRODUCTION PROFILE 990616 1 1 3F-19 PRODUCTION PROFILE 990612 '1 1 3K-31 ~.~.? C~ .... INJECTION PROFILE 990618 1 1 3M-20 ~.,~ (' C., INJECTION PROFILE 990615 1 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: State of Alaska AOGCC, Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: 2D-06B Field: Kuparuk River Unit County: North Slope State: Alaska Date: 03/17/99 API No: 500292116802 BHI Job#: 100861 Enclosed is the following data as listed below: Log Type Bluelines Navigamma USMPR ~DL/~NP D~/~DL/MDP TOTALS: Log Type Navigamma USMPR MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolle~ Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks Survey Listing ASCII Disks LIS Tape Image File Disks LIS Verification Report & Listings Depth Shift Monitor Plot Upon Receipt, Please sign and fax to: Baker Hughes INTEQ Fax 21 Att~~~ '~rland Date: ~J~ Oil & Gas Cons. Commi~Jon O !::! I I--I-- I I~ G S ~::: FIL/I C E S WELL LOG TRANSMITTAL To: State of Alaska March 4, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPK-21, AK-MM-70042 1 LDWG formatted Disc with verification listing. API#: 50-029-22718-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMI'VrAL LETI'ER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Sign~' Note: This Data replaces any previous Data for well ( MPK-21 ). 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. --~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 16, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2D-06B (Permit No. 98-176) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2D-06B. If there are any questions, please call 263-4107. Sincerely, D. Hembling CTU Drilling Engineer AAI Drilling DH/skad STATE OF ALASKA ~__.ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~1 GAS []]] SUSPENDED [] ABANDONED~] SERVICE []~]. 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-176 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360~ 50-029-21168-02 4 Location of well at surface ; · = ~L~~i 9 Unit or Lease Name At Top Producing Interval 10 Well Number At Total Depth . ·. 11 Field and Pool : · . 1760' FNL, 676' FEL, Sec. 24, T11N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 31', Pad 114'I ADL 25653 ALK 2579 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. orAband. 115 Water Depth, if offshore 16 No. of Completions 04-Oct-98 11-Oct-98 12-Oct-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11283' MD & 6149' TVD 10973' MD & 6128' TVD YES X~J NOU N/A feet MD 1465' APPROX 22 Type Electric or Other Logs Run GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE VV¥ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 110' 24" 224 sx CS I 9.625" 36.0# J-55 SURF. 4104' 12.25" 1070 sx AS III, 765 sx Class G 7" 26.0# J-55 SURF. 7185' 8.5" 560 sx Class G & 41 bbls AS I 3.5" 9.2# L-80 7024' 9080' 6.125" 396 sx Class G 2.375" 4.6# L-80 8307' 11004' 2.75" not cemented, slotted liner 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" 7055' 7032' N/A 26 ACID, FRACTURE, CEMEN DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 10/16/98I Gas Lift Date of Test Hours Tested PRODUCTION FOI .OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/21/981 22 TEST PERIOE1 273 766 33 176 765 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 156 975 24-HOUR RATE: 266 203 35 18° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. ~ -J 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. Top Kuparuk C 8553' 5932' Bottom Kuparuk C 8598' 5961' Top Kuparuk A 8765' 6070' Bottom Kuparuk A 11283' 6149' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ .2~¢-~,,/ Title ..,Q~r¢ ~'~',,~¢'¢ DATE /,~//,,/~ Prepared by Name/Rumber Sharon AIIsup-Dra'ke/2~3-4612 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: 10/12/98 Page: 1 well_summary_CTU2D06B.txt ARCO ALASKA INC. WELL SUMYkARY REPORT COILED TUBING UNIT OPERATIONS WELL:2D-06B WELL_ID: STATE:ALASKA 168-02 FIELD: KUPARUK RIVER UNIT SPUD: START COMP: FINAL: RIG: NABORS4ES BLOCK: API NUMBER: 50-029-21 9/26/98 RDMO f/2K to 2D. Accept rig at 0300 hrs. N-J BOPs. 9/27/98 RU CTU. RU remOte check. Spot and clean tanks. BOP test. BPV. RIH. UR cement f/8420'. 9/28/98 Underream cement to 8785'. POOH. RU e-line. RIH with whipstock anchor. Stuck anchor. Work free & POOH. 9/29/98 E-line PBTD tag. Run & set whipstock anchor. Verify anchor orientation 9/30/98 MU & run TIW whipstock assy on coil, planned maintenance to rewire BOP control panel in ops cab, RIH w/window milling assy, milling window. 10/1/98 Mill window, POOH, RIH w/BHA #15, stalling on top of whipstock, POOH t o check mill and discuss options, RIH w/MWD and 2.5° motor w/flat bttm metal muncher mi 11, being time drilling procedure. 10/2/98 Start time drilling, out casing and drilled 6' open hole, log GR tie i n (6+' corr), POOH, C/O motor & mill, RIH w/polishing mill, orient, dress window FIT, POOH, pr essure imploy BHA #7. Page 1 well_summary_CTU2D06B.txt 10/3/98 PU BHA #3, build section, drilling from 8788'-8895,, finish curve, PO0 H, PU BHA #9, RIH, drill horizontal form 8895'-9120,. 10/4/98 Drilling from 9120' -9250', ST drill to 9372', ST, difficulty drilling at 9372' for a few ft, drill to 9461', St, drill to 9559', ST, drill to 9720', P0H for motor change. 10/5/98 POH, LD BHA #9, BOPE test, PU BHA #10, RIH to 235' SHT failed, no puls es, P0H C/0 MWD, swap old mud for new, RIH tie in RA tag (+8' corr.) Drill from 9720' to 987 0' . 10/6/98 Drill from 9870'-10,010, ST, POOH for MWD, }{IH w/BHA #11, Drill from 0,010' to 10276'. 10/7/98 Drill from 10276' to 10657'. Short trip & orient as required. 10/8/98 Drill from 10657' to 10830'. Unable to drill ahead. Replace mud system · Drill from 10830'-10973'. Orient and short trip as required. 10/9/98 Complete short trip. Drill from 10973' to 11075'. Change BHA. Drill fr om 11074' to 11198'. Short trip & orient as required. 10/10/98 Complete short trip. Drill from 11198' to 11260' (TD). Short trip & lo g tie-in. Displace well to 12.5 mud & brine. POOH & LD BHA. MU liner. 10/11/98 RIH w/liner. Displace well to seawater. POOH & freeze protect well. Se t BPV. NDNU. Clean pits. Release rig & CT unit. Prep to move. Page 2 Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) (deg) (deg) (R) (0,0) °/100fL LaL (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) LaL (Y) Dep. (X) 9830.00 92.20 128.90 5973.91 3140.67 9.76 4493.65 4177.20 128.67 4510.38 4159.13 5958832.96 533414.09 9863.00 94.80 131.80 5971.89 3169.68 11.79 4472.33 4202.30 131.57 4489.16 4184.32 5958811.74 533439.28 9897.00 94.90 135.30 5969.02 3198.59 10.26 4448.99 4226.85 135.07 4465.92 4208.96 5958788.50 533463.92 9939.00 93.30 139.80 5966.01 3232.71 11.35 4418.08 4255.12 139.57 4435.13 4237.35 5958757.71 533492.31 9969.00 91.00 142.80 5964.89 3255.94 12.59 4394.69 4273.86 142.57 4411.81 4256.18 5958734.39 533511.14 9991.00 89.70 142.30 5964.75 3272.69 6.33 4377.23 4287.24 142.07 4394.40 4269.63 5958716.98 533524.59 10030.00 91.60 141.10 5964.31 3302.75 5.76 4346.62 4311.40 140.87 4363.90 4293.92 5958686.48 533548.88 10074.00 96.50 140.80 5961.21 3336.93 11.16 4312.55 4339.05 140.57 4329.93 4321.70 5958652.51 533576.66 10128.00 92.40 139.90 5957.02 3379.21 7.77 4271.11 4373.39 139.67 4288.63 4356.21 5958611.21 5336117~ 10186.00 89.20 137.90 5956.21 3425.65 6.51 4227.41 4411.51 137.67 4245.09 4394.50 5958567.67 533649I - -- 10231.00 85.40 135.00 5958.33 3462.76 10.62 4194.84 4442.47 134.77 4212.64 4425.59 5958535.22 533680.55 10273.00 85.30 135.10 5961.73 3497.89 0.34 4165.22 4472.04 134.87 4183.14 4455.29 5958505.72 533710.25 10307.00 83.60 133.20 5965.02 3526.58 7.48 4141.65 4496.32 132.97 4159.66 4479.66 5958482.24 533734.62 10334.00 85.70' 130.70 5967.54 3549.90 12.06 4123.68 4516.31 130.47 4141.78 4499.72 5958464.36 533754.68 10373.00 84.20 127.60 5970.97 3584.50 8.80 4099.16 4546.44 127.37 4117.37 4529.94 5958439.95 533784.90 10413.00 84.90 126.00 5974.77 3620.68 4.35 4075.30 4578.32 125.77 4093.65 4561.92 5958416.23 533816.88 10447.00: 85.60 127.90 5977.59 3651.43 5.94 4054.94 4605.40 127.67 4073.39 4589.08 5958395.97 533844.04 10486.00 84.80 131.30 5980.85 3685.90 8.93 4030.17 4635.34 131.07 4048.74 4619.12 5958371.32 533874.08 10526.00 84.50 135.70 5984.58 3719.89 10.98 4002.76 4664.22 135.47 4021.45 4648.11 5958344.03 533903.07 10574.00 85.70 139.60 5988.68 3758.80 8.47 3967.42 4696.43 139.37 3986.25 4680.46 5958308.83 533935.42 10608.00 85.30 141.90 5991.35 3785.28 6.85 3941.18 4717.87 141.67 3960.09 4702.01 5958282.67 533956.97 10643.00 84.50 147.10 5994.47 3811.02 14.97 3912.81 4738.1.1 146.87 3931.80 4722.36 5958254.38 533977.32 10675.00 84.60 150.00 5997.51 3832.98 9.03 3885.63 4754.73 149.77 3904.69 4739.09 5958227.27 533994.05 10705.00 83.80 151.70 6000.54 3852.66 6.24 3859.57 4769.27 151.47 3878.68 4753.73 5958201.26 534008.69 10742.00 81.80 149.20 6005.17 3877.06 8.61 3827.64 4787.37 148.97 3846.83 4771.96 5958169.41 534026.92 10770.00 81.80 145.30 6009.17 3896.61 13.79, 3804.34 4802.36 145.07 3823.58 4787.04 5958146.16 534042.00 10806.00 83.30' 140.40 6013.84 3923.65 14.12 3775.90 4823.91 140.17 3795.23 4808.71. 5958117.81 534063.(~ 10841.00 85.80 137.60 6017.16 3951.52 10.70 3749.61 4846.76 137.37 3769.03 4831.67 5958091.61 5340861~. 10871.00 88.00 140.20 6018.79 3975.51 11.34 3727.03 4866.45 139.97 3746.54 4851.45 5958069.12 534106.41 10947.00 87.00 142.90 6022.10 4034.15 3.79 3667.58 4913.66 142.67 3687.27 4898.90 5958009.85 534153.86 10981..00 87.20 1,46.00 6023.82 4059.25 9.12 3639.95 4933.40 145.77 3659.73 4918.75 5957982.31 534173.71 11016.00 88.80 150.20 6025.05 4083.55 112.83 3610.27 4951.88 149.97 3630.12 4937.35 5957952.70 534192.31 11043.00 88.60 149.80 6025.66 4101.65 1.66 3586.89 4965.38 149.57 3606.79 4950.94 5957929.37 534205.90 11080.00 87.60 148.10 6026.89 4126.95 5.33 3555.21 4984.45 147.87 3575.19 4970.14 5957897.77 534225.10 11,112.00 86.60 144.90 6028.50 4149.79 10.46 3528.56 5002.09 144.67 3548.62 4987.88 5957871.20 534242.84 11147.00 87.10 141.10 6030.43 4176.21 10.93 3500.66 5023.11 140.87 3520.80 5009.02 5957843.38 534263.98 11179.00 89.50 138.00 6031.38 4201.60 12.25 3476.32 5043.86 137.77 3496.54 5029.87 5957819.12 534284.83 11213.00 91.80 138.40 6030.99 4229.08 6.87 3450.98 5066.52 138.17 3471.29 5052.63 5957793.87 534307.59 11238.00 91.00 139.40 6030.38 4249.10 5.12 3432.15 5082.95 139.17 3452.52 5069.13 5957775.10 534324.09 11.282.00 89.70 141.40 6030.11 4283.63 5.42 3398.25 5110.99 141.17 3418.74 5097.31 5957741.32 534352.27 EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Company: ARCO Alaska, Inc. Rig: Nabors 3s/CTU #4 Job No: Well: 2D-06B Field: Prudhoe Bay, Alaska AFE No: Calculation Method: Minimum Curvature Mag. Declination: 27.230 API No: Vertical Sect. Plane: 102.120 TRUE Grid Correction: 0.230 BHI Rep: David Mason Vertical Sect. Plane: 102.350 GRID Total Correction: 27.000 Job Start Date: Measured Depth from: RKB RKB Height: 121.00 Job End Date: True Vertical Depth: Sea level Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/~"' (deg) (deg) (ft) (0,0) °/100ft. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) 8737.00 49.03 350.30 5932.70 2650.47 2.55 40113.43 3572.71 350.07 4027.74 3556.57 5958350.32 532811.53 8765.00 48.79 351.10 5951.10 2642.77 2.32 4034.26 3569.30 350.87 4048.55 3553.08 5958371.13 532808.04 8779.00 53.10 352.00 5959.92 2638.95 3 I. 19 4045.01 3567.70 351.77 4059.30 3551.44 5958381.88 532806.40 8819.00 64.60 353.60 5980.58 2627.67 28.95 4078.91 3563.45 353.37 4093.19 3547.05 5958415.77 532802.01 8856.00 77.10 356.20 5992.69 2617.38 34.43 4113.66 3560.38 355.97 4127.92 3543.84 5958450.50 532798.80 8891.00 88.90 356.70 5996.95 2608.01 33.74 4148.27 3558.23 356.47 4162.52 3541.55 5958485.10 532796.51 8927.00 91.10 356.10 5996.95 2598.26 6.33 4184.20 3555.97 355.87 4198.44 3539.15 5958521.02 532794.11 8963.00 93.60 1.40 5995.48 2589.94 16.27 4220.14 3555.19 1.17 4234.38 3538.22 5958556.96 532793.1.8 8992.00 95.80 5.90 5993.10 2585.68 17.22! 4248.98 3557.03 5.67 4263.22 3539.94 5958585.80 532794.90 9030.00 ~ ..~ 93.60 11.30 5989.98 2583.36 15.30 4286.41 3562.69 11.07 4300.67 3545.45 5958623.25 532800.41 9058.00 90.10 14.50 5989.08 2583.74 16.93 4313.68 3568.94 14.27 4327.97 3551.59 5958650.55 532806.55 90~2.00 89.00 19.90 5989.35 2586.75 16.21 4346.14 3578.99 19.67 4360.48 3561.51. 5958683.06 532816.47 , , ~'9123.00 89.80 25.40 5989.67 2592.42 17.93 4374.74 3590.92 25.17 4389.12 3573.33 5958711.70 532828.29 9167.00 87.80 28.60 5990.59 2603.71 8.57 4413.93 3610.89 28.37 4428.39 3593.14 5958750.97 532848.10 9198.00 89.10 33.60 5991.43 2613.79 116.66 4440.45 3626.89 33.37 4454.98 3609.03 5958777.56 532863.99 9232.00 90.10 39.40 5991.67 2627.82 17.31 4467.77 3647.10 39.17 4482.38 3629.14 5958804.96 532884./.'!'~ :9263.00 91.20 44.60 5991.32 2643.25 17.14 4490.80 3667.84 44.37 4505.49 3649.78 5958828.07 532904.!~, 9296.00 92.80 52.20 5990.16 2662.75 23.52 4512.68 3692.48 51.97 4527.47 3674.33 5958850.05 532929.29 9334.00 94.10 54.40 5987.88 2687.72 6.72 4535.35 3722.89 54.17 4550.26 3704.65 5958872.84 532959.61 9368.00 94.00 61.80 5985.47 2712.10 21.71 4553.26 3751.66 61.57 4568.28 3733.35 5958890.86 532988.31 9397.00 94.70 66.80 5983.27 2734.93 17.36 4565.79 3777.71 66.57 4580.92 3759.35 5958903.50 533014.31 9427.00 93.40 70.90 5981.15 2759.94 14.30 4576.59 3805.61 70.67 4591.83 3787.21 5958914.41 533042.17 9458.00 89.50 74.00 5980.37 2786.86 16.07 4585.93 3835.15 73.77 4601.29 3816.71 5958923.87 533071.67 ~, 9489.00 88.80 78.20 5980.83 2814.71 13.73 4593.37 3865.23 77.97 4608.85 3846.76 5958931.43 533101.72 · 9519.00 91.90 84.20 5980.64 2842.72 22.51 4597.96 3894.86 83.97 4613.56 3876.37 5958936.14 5331.31.33 9551.00 93.50 89.80 5979.14 2873.56 18.18 4599.63 3926.77 89.57 4615.36 3908.27 5958937.94 533163.23 9590.00 94.10 95.90 5976.55 2911.95 1.5.68 4597.70 3965.62 95.67 4613.58 3947.13 5958936.16 533202.09 9631.00 95.10 103.60 5973.25 2952.75 18.88! 4590.79 4005.86 103.37 4606.83 3987.40 5958929.41 533242.36 9668.00 91.70 110.20 5971.06 2989.53 20.04 4580.05 4041.18 109.97 4596.24 4022.76 5958918.82 533277.72 9700.00= 88.80 116.30. 5970.92 3020.91 21.11 4567.43 4070.56 116.07 4583.73 4052.19 5958906.31 533307.15 9734.00 86.70 123.20 5972.26 3053.27 21.20 4550.58 4100.04 122.97 4567.00 4081.74 5958889.58 533336.70 9770.00 88.60 125.10 5973.73 3086.61 7.46 4530.39 4129.80 124.87 4546.93 4111.58 5958869.51 533366.54 9799.00 89.20 128.50 5974.29 3112.95 11.90 4513.03 4153.02 128.27 ..... .4529.66 4134.87 5958852.24 533389.83 ARCO Alaska, Inc. ,~~ Sfrucfure · Pad 2D Well · 6A ~' Field · Kuparuk River Unif LoceHon · North Slope, Alasko TRUE East (feet) -> 5500 · -~ 5600 5700 E~ 5800 5900 6000 6100 62OO 2400 2600 2800 5000 3200 5400 3600 5800 4000 4200 4400 4600 4800 5000 5200 5400 5600 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 4800 4600 9 4400 10 11 Tie on - 59.32.70 Tvd, 401,3.36 N, 3572. 12 5400 5200 :_ _: ..... 3000 ~ / ~as GO,Is, Commis$[g~ ~ 2800 nc, 8757.00 Md, 5952.70 Tvd, 2650.~7 2 ' off Point _~ 2D-O6ehs 2400 25;C 2600 2700 2:560 2900 3000 51 O0 3200 3500 3400 3500 3600 3700 3800 5900 4000 41 O0 4200 4300 4400 4500 Vertical Section (feet) -> Azimuth 102.12 with reference 0.00 S, 0.00 E from slot #6A 4200 4000 Z 0 3800 :~' 3600 ~ '-4- ARCO Alaska, Inc. Pad 2D 2D-O6B slot ~6A Kuparuk River Unit North Slope, Alaska SURVEY LISTING by Baker Hughes !NTEQ Your ref : 2D-O6B Our ref : svy339 License : AP! 50-029-21168-02 Date printed : 12-0ct-98 Date created : 12-0ct-98 Last revised : 12-0ct-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 17 9.387, w149 45 32.755 Slot location is n70 17 10.606,w149 45 47.613 Slot Grid coordinates are N 5954322.579, E 529254.957 Slot local coordinates are 124.00 N 510.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North I',lOV 20 1998 Oil ~ (~.~s cons. Oommission A~orage ORIGINAL ARCO Alaska~ Inc. Pad 2D~2D-O6B Kuparuk River Unit,North Slope, Al aska SURVEY LISTING Page 1 Your ref : 2D-O6B Last revised : 12-0ct-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 7205.00 48.72 42.62 4908.21 2923.26N 3599.73E 0.00 2905.73 532842.73 5957259.77 7420.00 46.76 23.90 5053.50 3054.96N 3686.59E 6.49 2963.00 532929.06 5957391.80 7515.00 46.04 14.90 5119.08 3119.71N 3709.43E 6.90 2971.73 532951.64 5957456.63 7609.00 46.90 7.40 5183.87 3186.48N 3722.56E 5.85 2970.55 532964.50 5957523.45 7702.00 46.00 358.47 5248.01 3253.66N 3726.04E 7.02 2959.85 532967.72 5957590.64 7795.00 46.28 351.81 5312.49 3320.40N 3720.36E 5.17 2940.28 532961.77 5957657.35 7889.00 47.96 350.16 5376.45 3388.43N 3709.55E 2.20 2915.43 532950.70 5957725.32 7984.00 47.94 348.20 5440.09 3457.71N 3696.31E 1.53 2887.94 532937.19 5957794.55 8078.00 48.66 349.42 5502.62 3526.56N 3682.69E 1.24 2860.17 532923.30 5957863.33 8172.00 49.21 350.50 5564.37 3596.34N 3670.34E 1.05 2833.44 532910.67 5957933.06 8266.00 48.80 345.79 5626.05 3665.74N 3655.78E 3.81 2804.64 532895.84 5958002.40 8359.00 48.95 345.60 5687.22 3733.62N 3638.47E 0.22 2773.46 532878.26 5958070.20 8453.00 49.61 345.30 5748.54 3802.58N 3620.57E 0.74 2741.48 532860.09 5958139.08 8548.00 49.44 346.50 5810.21 3872.67N 3602.97E 0.98 2709.55 532842.21 5958209.09 8642.00 49.97 347.36 5871.00 3942.50N 3586.76E 0.90 2679.04 532825.73 5958278.86 8737.00 49.03 350.30 5932.70 4013.36N 3572.75E 2.55 2650.47 532811.44 5958349.65 8765.00 48.79 351.10 5951.11 4034.18N 3569.34E 2.32 2642.77 532807.95 5958370.46 8779.00 53.10 352.00 5959.93 4044.93N 3567.75E 31.19 2638.95 532806.32 5958381.20 8819.00 64.60 353.60 5980.58 4078.84N 3563.49E 28.95 2627.67 532801.93 5958415.09 8856.00 77.10 356.20 5992.70 4113.59N 3560.42E 34.43 2617.38 532798.72 5958449.82 8891.00 88.90 356.70 5996.96 4148.20N 3558.28E 33.74 2608.01 532796.44 5958484.42 8927.00 91.10 356.10 5996.96 4184.12N 3556.02E 6.33 2598.26 532794.04 5958520.33 8963.00 93.60 1.40 5995.48 4220.07N 3555.23E 16.27 2589.94 532793.11 5958556.27 8992.00 95.80 5.90 5993.10 4248.90N 3557.07E 17.22 2585.68 532794.83 5958585.11 9030.00 93.60 11.30 5989.99 4286.33N 3562.73E 15.30 2583.36 532800.35 5958622.55 9058.00 90.10 14.50 5989.08 4313.60N 3568.98E 16.93 2583.74 532806.48 5958649.85 9092.00 89.00 19.90 5989.35 4346.07N 3579.03E 16.21 2586.75 532816.40 5958682.35 9123.00 89.80 25.40 5989.67 4374.67N 3590.96E 17.93 2592.42 532828.22 5958710.99 9167.00 87.80 28.60 5990.60 4413.86N 3610.93E 8.57 2603.71 532848.03 5958750.25 9198.00 89.10 33.60 5991.44 4440.38N 3626.93E 16.66 2613.79 532863.93 5958776.84 9232.00 90.10 39.40 5991.67 4467.70N 3647.15E 17.31 2627.82 532884.03 5958804.24 9263.00 91.20 44.60 5991.32 4490.73N 3667.88E 17.14 2643.25 532904.67 5958827.34 9296.00 92.80 52.20 5990.17 4512.61N 3692.52E 23.52 2662.75 532929.23 5958849.32 9334.00 94.10 54.40 5987.88 4535.27N 3722.93E 6.72 2687.72 532959.54 5958872.10 9368.00 94.00 61.80 5985.48 4553.18N 3751.71E 21.71 2712.10 532988.24 5958890.12 9397.00 94.70 66.80 5983.28 4565.72N 3777.75E 17.36 2734.93 533014.24 5958902.76 9427.00 93.40 70.90 5981.16 4576.51N 3805.66E 14.30 2759.94 533042.09 5958913.67 9458.00 89.50 74.00 5980.37 4585.86N 3835.19E 16.07 2786.86 533071.59 5958923.12 9489.00 88.80 78.20 5980.83 4593.30N 3865.28E 13.73 2814.71 533101.64 5958930.69 9519.00 91.90 84.20 5980.65 4597.89N 3894.91E 22.51 2842.72 533131.25 5958935.39 9551.00 93.50 89.80 5979.14 4599.56N 3926.81E 18.18 2873.56 533163.15 5958937.19 9590.00 94.10 95.90 5976.55 4597.63N 3965.66E 15.68 2911.95 533202.00 5958935.41 9631.00 95.10 103.60 5973.26 4590.71N 4005.91E 18.88 2952.75 533242.27 5958928.66 9668.00 91.70 110.20 5971.06 4579.98N 4041.22E 20.04 2989.53 533277.62 5958918.06 9700.00 88.80 116.30 5970.92 4567.36N 4070.60E 21.11 3020.91 533307.05 5958905.56 9734.00 86.70 123.20 5972.26 4550.51N 4100.08E 21.20 3053.27 533336.59 5958888.83 9770.00 88.60 125.10 5973.74 4530.32N 4129.85E 7.46 3086.61 533366.43 5958868.76 9799.00 89.20 128.50 5974.29 4512.95N 4153.06E 11.90 3112.95 533389.71 5958851.49 9830.00 92.20 128.90 5973.91 4493.57N 4177.25E 9.76 3140.67 533413.97 5958832.21 9863.00 94.80 131.80 5971.90 4472.25N 4202.35E 11.79 3169.68 533439.15 5958810.99 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #6A and TVD from RK8 (Nordic II) (121.00 Ft above mean sea level). Bottom hole distance is 6137.61 on azimuth 56.38 degrees from wellhead. Vertical section is from wellhead on azimuth 102.12 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 2D,2D-O6B Kuparuk River Unit,North Slope, Alaska Measured Inc[in Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D ! N 9897.00 94.90 135.30 5969.02 4448.92N 9939.00 93.30 139.80 5966.02 4418.01N 9969.00 91.00 142.80 5964.89 4394.62N 9991.00 89.70 142.30 5964.76 4377.15N 10030.00 91.60 141.10 5964.32 4346.55N 10074.00 96.50 140.80 5961.21 4312.48N 10128.00 92.40 139.90 5957.02 4271.04N 10186.00 89.20 137.90 5956.21 4227.34N 10231.00 85.40 135.00 5958.33 4194.77N 10273.00 85.30 135.10 5961.74 4165.14N 10307.00 83.60 133.20 5965.02 4141.57N 10334.00 85.70 130.70 5967.54 4123.61N 10373.00 84.20 127.60 5970.98 4099.08N 10413.00 84.90 126.00 5974.78 4075.23N 10447.00 85.60 127.90 597/.59 4054.86N 10486.00 84.80 131.30 5980.86 4030.10N 10526.00 84.50 135.70 5984.59 4002.69N 10574.00 85.70 139,60 5988.69 3967.35N 10608.00 85.30 141.90 5991.36 3941.11N 10643.00 84.50 147.10 5994.47 3912.73N 10675.00 84.60 150.00 5997.51 3885.56N 10705.00 83.80 151.70 6000.54 3859.50N 10742.00 81.80 149.20 6005.18 3827.57N 10770.00 81.80 145.30 6009.17 3804.26N 10806.00 83.30 140.40 6013.84 3775.82N 10841.00 85.80 137.60 6017.17 3749.53N 10871.00 88.00 140.20 6018.79 3726.96N 10947.00 87.00 142.90 6022.11 3667.51N 10981.00 87.20 146.00 6023.83 3639.88N 11016.00 88.80 150.20 6025.05 3610.19N 11043.00 88.60 149.80 6025.66 3586.82N 11080.00 87.60 148.10 6026.89 3555.14N 11112.00 86.60 144.90 6028.51 3528.49N 11147.00 87.10 141.10 6030.43 3500.59N 11179.00 89.50 138.00 6031.38 3476.25N 11213.00 91.80 138.40 6031.00 3450.91N 11238.00 91.00 139.40 6030.39 3432.08N 11282.00 89.70 141.40 6030.12 3398.18N ULAR ATES 4226.90E 4255.16E 4273.90E 4287.28E 4311.45E 4339.09E 4373.44E 4411.55£ 4442.51E 4472.09E 4496.37E 4516.36E 4546.48E 4578.36E 4605.44E 4635.38E 4664.26E 4696.47E 4717.92E 4738.15E 4754.77E 4769.31E 4787.41E 4802.40E 4823.95E 4846.81E 4866.49E 4913.70E 4933.44E 4951.92E 4965.42E 4984.49E 5002.13E 5023.16E 5043.91E 5066.56E 5082.99E 5111.04E SURVEY LISTING Page 2 Your ref : 2D-O6B Last revised : 12-0ct-98 Dogleg Vert G R ! D C 0 0 R D S Deg/lOOft Sect Easting Northing 10.26 3198.59 533463.79 5958787.75 11.35 3232.71 533492.18 5958756.96 12.59 3255.94 533511.01 5958733.64 6.33 3272.69 533524.45 5958716.23 5.75 3302.75 533548.74 5958685.7-5 11.16 3336.93 533576.52 5958651.77 7.77 3379.21 533611.02 5958610.47 6.51 3425.65 533649.31 5958566.93 10.62 3462.76 533680.39 5958534.48 0.34 3497.89 533710.08 5958504.98 7.48 3526.58 533734.45 5958481.51 12.06 3549.90 533754.51 5958463.62 8.80 3584.50 533784.73 5958439.22 4.35 3620.68 533816.70 5958415.49 5.94 3651.43 533843.86 5958395.24 8.93 3685.90 533873.89 5958370.59 10.98 3719.89 533902.88 5958343.30 8.47 3758.80 533935.22 5958308.09 6.85 3785.28 533956.77 5958281.94 14.97 3811.02 533977.12 5958253.65 9.03 3832.98 533993.84 5958226.54 6.24 3852.66 534008.48 5958200.54 8.61 3877.06 534026.71 5958168.68 13.79 3896.61 534041.79 5958145.44 14.12 3923.65 534063.45 5958117.09 10.70 3951.52 534086.41 5958090.89 11.34 3975.51 534106.18 5958068.40 3.79 4034.15 534153.62 5958009.14 9.12 4059.25 534173.47 5957981.60 12.83 4083.55 534192.06 5957951.99 1.66 4101.65 534205.65 5957928.66 5.33 4126.95 534224.85 5957897.06 10.46 4149.79 534242.59 5957870.49 10.93 4176.21 534263.72 5957842.67 12.25 4201.60 534284.57 5957818.42 6.87 4229.08 534307.32 5957793.17 5.12 4249.10 534323.82 5957774.40 5.42 4283.63 534352.00 5957740.62 RECEIVED I40V 2.0 1998 Alaska Oil & Gas 0OHS. r.,ornmissbn All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #6A and TVD from RK8 (Nordic II) (121.00 Ft above mean sea level). Bottom hole distance is 6137.61 on azimuth 56.38 degrees from wellhead. Vertical section is from wellhead on azimuth 102.12 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 2D,2D-068 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page Your ref : 2D-O6B Last revised : 12-0ct-98 Targets associated with this we[[path Target name 2D-O6ehs Geographic Location T.V.D. Rectangu[ar Coordin 534250.000,5958050 nnn ~'~ ..................... ares Revised 2D-O6bhs ~,u.uuuu 5980.00 3707 9;~ ................................. · ' 5010.25E lO-Aug-p8 532800-000,5958600.000,0.0000 5980.00 4263.78N 3562.30E lO-Aug-98 RECEIVED NOV 20 1998 Ala~,~a Oil & Gas ~ns. Commission TONY KNOWLE$, GOVERNO~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 9, 1998 Drew Hcmbling Area Drilling Engineer ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 2D-06B ARCO Alaska, Inc. Permit No: 98-176 Sur Loc: 124'FSL, 510'FEL, Sec. 23, T11N, R9E. UM Btmholc Loc. 1451'FNL, 777'FEL, Sec. 24, TI IN. R9E. UM Dear Mr. Hembling: Enclosed is the approved application for permit to rcdrill thc above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies? and does not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximatcly 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max,' be given by contacting the Commission petroleum field inspector on the North Slope pager.at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffEnclosurcs CC~ Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. · . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSIoN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~X Alter casing _ Change approved program 2. Name of Operator .ARCO Alaska, Inc. :3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 124' FSL, 510' FEL, Sec.23, T11N, RgE, UM At top of productive interval 1279' FNL, 2195' FEL, Sec. 24, T11 N, RgE, UM At effective depth At total depth 893' FNL, 2272' FEL, Sec 24, T11 N, RgE, UM Suspend _ Repair well _ Plugging __ Pull tubing 5. Type of Well: Development Exploratory _ Stratigraphic _ Service Operation Shutdown __ Re-enter suspended well _ Time extension_ Stimulate_ Vadance Perforate Other 6. Datum elevation (DF or KB) 121' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-06A 9. Permit number 96-116 10. APl number 50-029-21168-01 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: measured true vertical 9080 feet 6284 feet Plugs (measured) None feet Effective depth: measured true vertical 8982 6217 feet Junk (measured) None feet Casing Length Size Structural Conductor 110' 16" Surface 4104' 9.625" Intermediate Production 7185' 7" Liner 2056' 3.5" Cemented 224 sx CS I 1070 sx AS III & 765 sx Class G 560 sx Class G & 41 bbls AS I 396 sx Class G Measured depth 110' 4104' 7185' 9080' True vertical depth 110' 3160' 5016' 6284' Perforation depth: measured 8820'-8850' true vertical 6107'-6127' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7032' Packers and SSSV (type and measured depth) Baker C2 ZXP Liner Pkr @ 4,361' MD, No SSSV 13. Attachments Description summary of proposal X Detailed operation program BOP sketch X 14. Estimated date for commencing operation September 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so~tiv~ Plug integrity ~ ~a.tio .~le ~..a~, ce Approved by the order of the Commission Form 10-403 Rev 06/15/88 '--- ~ 15. Status of well classification as: Gas _ Suspended_ Date ~'/-~/.//2 oo' IIApproval No~;, STATE OF ALASKA %L~. ALAS~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Ddll E] Redrill X lb TypeofWell Exploratory E~ StratigraphicTest E~ Development Oil X Re-Entry r-'] Deepen [-] Service [""] Development Gas 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 121' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25653, ALK 2579 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 124' FSL, 510' FEL, Sec.23, T11 N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1461' FNL, 1502' FEL, Sec. 24, T11 N, R9E, UM 2D-06B #U-630610 At total depth 9. Approximate spud date Amount 1451' FNL, 777' FEL, Sec. 24, T11 N, R9E, UM November 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 10946' MD 777' @ Target feet No close approach feet 2560 6101' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 8765' feet Maximum hole angle 103° Maximum su~a~ 2500 psig At total depth ('rVD) 3056psig @ 6200' 18. Casing program Setting Depth size Specifications Top Bottom Quantity' of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data) 2.75" 2.375" 4.6# L-80 FL4S 2209' 8737' 6047' 10946' 6101' N/A Slotted Liner 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured dc.,;pth True Vertical depth Conductor ... Surface Intermediate Produc,on AUG Liner Perforation depth: measured Alaska 0it & Gas Opf~ L;01Tt~IS~I0n true vertical Anchorage 20. Attachments Filing fee X Property plat BI BoP Sketch X Diverter Sketch [~ Drilling program X Ddlling fluid program ["] Time vs depth plot BI Refraction analysis 21. I hereby certify that the foregoing is true and cgrre, ct to the best of my knowledge Signed¢~~' ~J'"' ~~'~~~'~ CommissionTitleuse Only Area Drilling Engineer P e n~;;~.m b,~j'.~, I API number §0. O.~.~;~ ,,2.//-O~'",~'-· ~ ~.... IApp'°va'date /~.., ~'.., ~'~;) Iseec°verletterf°r · . -- other requirements Conditions of approval Samples required E] Yes j~ No Mud Icg required r~ Yes ~] No Hydrogen sulfide measures 1~ Yes [--1 No Directional survey required [~ Yes r'~ No Required working pressure forBOPE r"] 2M E] 3M r~ ~ 1OM [~ 15M Othen ,..;,..f" , ~;~., -, Approved b¥ David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA ALAS-Fd~ OIL AND GAS CONSERVATION COMMi-SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill r% Redrill X lb Type of Well Exploratory E~ Stratigraphic Test ~ Development Oil X Re-Entry [-' Deepen F.~ service [~ Development Gas [~ Single Zone X Multiple Zone E~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 121' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25653, ALK 2579 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 124' FSL, 510' FEL, Sec.23, T111'4, RgE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1461' FNL, 1502' FEL, Sec. 24, T11N, RgE, UM 2D-06B #U-630610 At total depth 9. Approximate spud date Amount 1451' FNL, 777' FEL, Sec. 24, T11N, RgE, UM November 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 10946' MD 777' @ Target feet No close approach feet 2560 6101' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 8765' feet Maximum hole angle 103° Maximum surface 2500 psig At total depth (-R/D) 3056psJg @ 6200' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2.75" 2.375" 4.6# L-80 FL4S 2209' 8737' 6047' 10946' 6101' N/A Slotted Liner 19. To be completed for Reddll, Re-entry, and Deepen OperationS.Present well condition summary 0 ¢ ! ¢o ! L. Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size Cemented Measur~Etl~ E IVr~e .~j~ical depth Conductor Surface Intermediate AUG 2 0 1998 Production Liner Perforation depth: measured Alaska 0il & Gas Cons. C0rnmismon true vertical Anchorage 20. Attachments Filing fee X Property plat [~ BOP Sketch X DiverterSketch ~ Ddlling program X Drilling fluid program E~, Time vs depth plot ~ Refraction analysis [~ Seabed report [~ 20AAC 25.050 requirements ~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe~,,~., ,,~~~ Title Area Drilling Engineer Date O~/,~¢.~//~'~:~ ~' Commission Use Only ' ' Permi~;~l~j~pb_e2,,~,~, APl50_ O.;~-. '~number.- .2.. ,//'~' ~' " ~:~ .2.._. IAppr°val dat~1'''' ~ '" ,,~t~ Iseeotherc°verrequirementsletter for Conditions of approval Samples required [~ Yes '~ No Mud Icg required ~ Yes ,[~ No Hydrogen sulfidemeasures ~ Yes E No Directional surveyrequired ~ Yes ~ No Required working pressure for BOPE ~ 2M [~ 3M ~-~[--~ 10M ~ 15M Other:. 0riginal Signed By O v[d W, Johnston by orderof ¢" ~'~-' f~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate Kuparuk 2D-06B CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore with 17 ppg cement. Mill window in 3-1/2" liner. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" slotted liner. Intended Procedure: Cement squeeze the existing perforations with 17 ppg cement. Leave top of cement @ -8735' md to act as a cement whipstock. Mill window in 3-1/2" liner at 8765' md. Drill 10' of formation and perform leak off test to 0.5 ppg above the highest anticipated mud weight. Directionally drill 2-3/4" x -2181' horizontal well to access Kuparuk A4 reserves. · Run 2-3/8" slotted liner to TD. · Place on production. August 25, 1998 ._ · C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect - Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold % Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser I I Man e (3.5") Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve o.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus KRU 2D-06B Proposed CT Sidetrack Horizontal 3-1/2" Tubing D Nipple 7022' Tie-Back Sleeve 7024'~ Packer 7032' 3-1/2" Liner shoe @ 9080' 7" Casing 'Sidetrack @ 7185') Top of 2-3/8" Liner in 3-1/2" Liner above Window ,_,, ,.,.~W°i~°'w~ ' cut 'in 3-1/2" at 2-3/8" Slotted liner TD @ ~ 10,946' 2-3/4" Open hole Current perforations to be cement squeezed Kuparuk 2D-06B Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 3056 psi @ 6200' ss (9.5 ppg EMW) based on SBHPS Jan.'98. BHT 160 deg. Be prepared to increase mud weight in the event reservoir pressure is higher than anticipated. Plans are to drill near balanced reservoir pressure conditions. Monitor return line flow rate and pit volume continuously. Maximum anticipated WHP w/full column of gas: -2500 psi. No gas saturated intervals are expected. August 25~ 1998 ARCO Alaska, Inc. Structure · Pad 2D Well : 6A Field · Kuparuk River Unit Location · North Slope, Alaska East (feet) -> Created by planner Date plotted: 20-Aug-98 Ptot Reference is 2D-O6B CT Sidetrack, Coordinates ere in feet reference slot ~6A, '[rue Vertical Depths ere reference RKB (Nordic II), --- Baker Hugl3es N]EQ --- ~1 51i0 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 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 4600 s~ f 4500 2D-O6bh f 4300 4200 Kick off Point Tie on - 5926.01 Tvd, 4016.12 N, 3575.30 E ' 400o 6ehs 3700 } T.D. & End of Build - 5980.00 Tvd, 3707.99 N, 5010.25 E . ~6ehs 2D-O6b --~ _ 2500 2600 2700 2800 2900 3000 3100 3200 3~00 3400 3500 3600 3700 3800 3900 4000 4100 4200 VerHc~l Section (feet) -> Azimuth 102.12 with reference 0.00 N, 0.00 E from slot #6A ARCO Alaska, ]nc. Pad 20 6A slot ~6A Kuparuk River Unit North Slope, Alaska PROPOSAL L I ST I NG by Baker Hughes INTEQ Your ref : 2D-O6B CT Sidetrack Our ref : prop78 License : Date printed : 25-Aug-98 Date created : 11-Aug-98 Last revised : 20-Aug-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 17 9.387,w149 45 32.755 Slot location is nTO 17 10.606,w149 45 47.613 Slot Grid coordinates are N 5954322.579, E 529254.957 Slot local coordinates are 124.00 N 510.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 2D,6A Kuparuk River Unit,North Slope, Alaska Measured [nctin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : 2D-O6B CT Sidetrack Last revised : 20-Aug-98 Dogleg Vert Deg/lOOft Sect 8737.00 49.03 350.30 5926.01 4016.12 N 3575.30 E 0.00 2652.39 8765.00 48.79 351.10 5944.42 4036.94 N 3571.89 E 2.31 2644.68 Kick off Point 8800.00 60.95 352.89 5964.52 4065.24 N 3567.95 E 35.00 2634.88 8883.43 90.00 356.00 5985.22 4144.76 N 3560.36 E 35.00 2610.77 8884.51 90.04 356.38 5985.22 4145.85 N 3560.29 E 34.99 2610.47 3 8900.00 90.63 1.77 5985.13 4161.33 N 3560.04 E 34.99 2606.97 9000.00 94.07 36.62 5980.91 4254.24 N 3592.34 E 34.99 2619.05 9002.49 94.14 37.49 5980.73 4256.22 N 3593.83 E 34.99 2620.09 9012.28 94.41 40.91 5980.00 4263.78 N 3600.00 E 34.99 2624.53 9100.00 92.94 47.77 5974.37 4326.35 N 3661.15 E 7.98 2671.19 9200.00 91.22 55.57 5970.74 4388.27 N 3739.48 E 7.98 2734.77 9208.64 91.07 56.24 5970.57 4393.12 N 3746.64 E 7.98 2740.75 5 9269.75 90.00 61.00 5970.00 4424.92 N 3798.79 E 7.98 2785.06 9300.00 90.08 63.40 5969.98 4439.03 N 3825.55 E 7.93 2808.26 9400.00 90.35 71.32 5969.60 4477.50 N 3917.77 E 7.93 2890.35 9500.00 90.61 79.25 5968.76 4502.88 N 4014.41 E 7.93 2979.50 9600.00 90.86 87.17 5967.48 4514.69 N 4113.62 E 7.93 3074.02 9700.00 91.09 95.10 5965.77 4512.70 N 4213.50 E 7.93 3172.10 9800.00 91.31 103.03 5963.67 4496.96 N 4312.15 E 7.93 3271.86 9900.00 91.49 110.96 5961.23 4467.77 N 4407.68 E 7.93 3371.38 9945.92 91.57 114.60 5960.00 4450.00 N 4450.00 E 7.93 3416.49 10000.00 90.45 120.59 5959.04 4424.96 N 4497.90 E 11.26 3468.58 10100.00 88.39 131.66 5960.06 4366.11 N 4578.54 E 11.26 3559.77 10200.00 86.38 142.76 5964.63 4292.92 N 4646.29 E 11.26 3641.38 10300.00 84.52 153.90 5972.59 4208.22 N 4698.55 E 11.26 3710.26 10400.00 82.85 165.11 5983.62 4115.28 N 4733.30 E 11.26 3763.75 10500.00 81.46 176.40 5997.31 4017.67 N 4749.20 E 11.26 3799.79 10517.89 81.25 178.42 6000.00 4000.00 N 4750.00 E 11.26 3804.28 10600.00 85.52 162.92 6009.52 3919.79 N 4763.22 E 19.45 3834.05 10700.00 91.12 144.28 6012.47 3830.70 N 4807.47 E 19.45 3896.02 10800.00 96.61 125.56 6005.67 3760.55 N 4877.73 E 19.45 3979.45 10900.00 101.39 106.46 5989.89 3717.36 N 4965.99 E 19.45 4074.81 10946.35 103.21 97.42 5980.00 3707.99 N 5010.25 E 19.45 4120.04 Ali data is in feet unless otherwise stated. Coordinates from slot #6A and TVD from RKB (Nordic II) (121.00 Ft above mean sea level). Bottom hole distance is 6233.12 on azimuth 53.50 degrees from wellhead. Vertical section is from wellhead on azimuth 102.12 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 2D,6A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 2D-O6B CT Sidetrack Last revised : 20-Aug-98 Comments in wetlpath MD TVD Rectangular Coords. Co~ent 8765.00 5944.42 4036.94 N 3571.89 E Kick off Point 8884.51 5985.22 4145.85 N 3560.29 E 3 9002.49 5980.73 4256.22 N 3593.83 E 4 9208.64 5970.57 4393.12 N 3746.64 E 5 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 5926.01 4016.12N 3575.30E n/a 5980.00 3707.99N 5010.25E 5 1/2" Casing Targets associated with this we[[path Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2D-O6bhs 532800.000,5958600.000,0.0000 5980.00 4263.78N 3562.30E lO-Aug-98 2D-O6ehs 534250.000,5958050.000,0.0000 5980.00 3707.99N 5010.25E lO-Aug-98 ARCO ALaska, inc. Pad 2D 6A slot #6A Kuparuk River Unit North SLope, ALaska PROPOSAL L ] ST [MG by Baker Hushes [NTEQ Your ref : 2D-O6B CT Sidetrack Our ref : prop?8 License = Date printed : 25-Aug-98 Date created : 11-Aug-98 Last revised : 20-Aug-98 Field is centred on nTO 16 18.576,~150 5 56.536 Structure is centred on n70 17 9.387,w149 45 32.755 Slot Location is n70 17 10.606,u149 45 47.613 SLot Grid coordinates are N 5~54322.579, E 529254.95? SJot Local coordinates are 124.00 # 510.00 W Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Reference North is True North Kuparuk 2D-06B CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore with 17 ppg cement. Mill window in 3-1/2" liner. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" slotted liner. Intended Procedure: Cement squeeze the existing perforations with 17 ppg cement. Leave top of cement @ -8735' md to act as a cement whipstock. Mill window in 3-1/2" liner at 8765' md. Drill 10' of formation and perform leak off test to 0.5 ppg above the highest anticipated mud weight. Directionally drill 2-3/4" x -2181' horizontal well to access Kupamk A4 reserves. · Run 2-3/8" slotted liner to TD. · Place on production. August 25, 1998 Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Connect Quick ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I -- 7" Riser I I Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~- Flanged Fire Resistant Man--~ Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus KRU 2D-06B Proposed CT Sidetrack Horizontal 3-1/2" Tubing D Nipple 7022' Tie-Back Sleeve 7024'~ Packer 7032' 3-1/2" Liner shoe @ 9080' z 7" Casing 'Sidetrack @ 7185') Top of 2-3/8" Liner in 3-1/2" Liner above Window Window cut in 3-1/2" at 2-3/8" Slotted liner / 2-3/4" Open hole Current perforations to be cement squeezed TD @ ~ 10,946' Kuparuk 2D-06B Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 3056 psi @ 6200' ss (9.5 ppg EMW) based on SBHPS Jan.'98. BI-IT 160 deg. Be prepared to increase mud weight in the event reservoir pressure is higher than anticipated. Plans are to drill near balanced reservoir pressure conditions. Monitor return line flow rate and pit volume continuously. Maximum anticipated WHP w/full column of gas: -2500 psi. No gas saturated intervals are expected. August 25, 1998 ~ 5600- C- 5700- 5800 ~ 5900 6000 6100 2D-O6Ohs _//Kick off Point I I I I I I I I I I I I I 2500 2600 2700 2800 2900 3000 3100 ARCO ^la ka, Inc. Structure : Pad 2D Well : 6A Field · Kuparuk River Unit Location · North Slope, Alaska Craa{ed by plonner Dote plotted: 20-Aug-98 Plot Reference is 2D-068 CT Sidetrack. Coordinatel ere in feet reference elot ~6A. ['rue Vertical D~p[hs are reference RKB (Nordic ii). --- Boker Hughes INIEO --- East (feet) -> 3400 3500 3600 3700 5800 5900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 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 4600 ,,, ~ 4500 2D_O6bhs~ 4400 4300 , I 12 N. 3875.30 [ ' ,4o0o . 2D-O6ehs T.D. & End of Build/Turn - 103.21 Inc, 10946.35 Md, 5§80.00 Tvd, 4120.04 Vs I I I I I I I I I I I I I I I t I I I I I ,:3200 3300 3400 3500' 3600 3700 3800 3900 4000 4100 4200 Vertical Section (feet) -> Azimuth 102.12 with reference 0.00 N, 0.00 E from slot #6A 4200 I 4100 3900 3800 3700 3600 Z ARCO A [ aska, ! nc. Pad 20,6A Kuparuk River Unit,North Slope, Measured !nctin. Azimuth True Vert Depth Degrees Degrees Depth Alaska PROPOSAL LISTING Page 1 Your ref : 20-068 CT Sidetrack Last revised = 20-Aug-98 R E C T A N G U L A R DogLeg Vert C 0 0 R D I N A T E S Oeg/lOOft Sect 8737.00 49.03 350.30 5926.01 4016.12 N 3575.30 E 0.00 2652.39 8765.00 48.79 351.10 5944.42 4036.94 N 3571.89 E 2.31 2644.68 Kick off Point 8800.00 60.95 352.89 5964.52 4065.24 N 3567.95 E 35.00 2634.88 8883.43 90.00 356.00 5985.22 4144.76 N 3560.36 E 35.00 2610.77 8884.51 90.04 356.38 5985.22 4145.85 N 3560.29 E 34.99 2610.47 3 8900.00 90.63 1.77 5985.13 4161.33 N 3560.04 E 34.99 2606.97 9000.00 94.07 36.62 5980.91 4254.24 N 3592.34 E 34.99 2619.05 9002.49 94.14 37.49 5980.73 4256.22 N 3593.83 E 34.99 2620.09 4 9012.28 94.41 40.91 5980.00 4263.78 N 3600.00 E 34.99 2624.53 9100.00 92.94 47.77 5974.37 4326.35 N 3661.15 E 7.98 2671.19 9200.00 91.22 55.57 5970.74 4388.27 N 3739.48 E 7.98 2734.77 9208.64 91.07 56.24 5970.57 4393.12 N 3746.64 E 7.98 2740.75 5 9269.75 90.00 61.00 5970.00 4424.92 N 3798.79 E 7.98 2785.06 9300.00 90.08 63.40 5969.98 4439.03 N 3825.55 E 7.93 2808.26 9400.00 90.35 71.32 5969.60 4477.50 N 3917.77 E 7.93 2890.35 9500.00 90.61 79.25 5968.76 4502.88 N 4014.41 E 7.93 2979.50 9600.00 90.86 87.17 5967.48 4514.69 N 4113.62 E 7.93 3074.02 9700.00 91.09 95.10 5965.77 4512.70 N 4213.50 E 7.93 3172.10 9800.00 91.31 103.03 5963.67 4496.96 N 4312.15 E 7.93 3271.86 9900.00 91.49 110.96 5961.23 4467.77 N 4407.68 E 7.93 3371.38 9945.92 91.57 114.60 5960.00 4450.00 N 4450.00 E 7.93 3416.49 10000.00 90.45 120.59 5959.04 4424.96 N 4497.90 E 11.26 3468.58 10100.00 88.39 131.66 5960.06 4366.11 N 4578.54 E 11.26 3559.77 10200.00 86.38 142.76 5964.63 4292.92 N 4646.29 E 11.26 3641.38 10300.00 84.52 153.90 5972.59 4208.22 N 4698.55 E 11.26 3710.26 10400.00 82.85 165.11 5983.62 4115.28 N 4733.30 E 11.26 3763.75 10500.00 81.46 176.40 5997.31 4017.67 N 4749.20 E 11.26 3799.79 10517.89 81.25 178.42 6000.00 4000.00 N 4750.00 E 11.26 3804.28 10600.00 85.52 162.92 6009.52 3919.79 N 4763.22 E 19.45 3834.05 10700.00 91.12 144.28 6012.47 3830.70 N 4807.47 E 19.45 3896.02 10800.00 96.61 125.56 6005.67 3760.55 N 4877.73 E 19.45 3979.45 10900.00 101.39 106.46 5989.89 3717.36 N 4965.99 E 19.45 4074.81 10946.35 103.21 97.42 5980.00 3707.99 N 5010.25 E 19.45 4120.04 All data is in feet unless otherwise stated. Coordinates from slot #6A and TVO from RKB (Nordic 1!) (121.00 Ft above mean sea level). Bottom hole distance is 6233.12 on azimuth 53.50 degrees from wellhead. Vertical section is from wellhead on azimuth 102.12 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEO ARCO ALaska, Inc. Pad 2D,6A Kuparuk River Unit,North SLope, ALaska PROPOSAL LISTING Page 2 Your ref : 2D-O6B CT Sidetrack Last revised : 20-Aug-98 Coneents in weLLpeth 140 TVO RectanguLar Coords. Comment 8765.00 5944.42 4036.94 N 3571.89 E Kick off Point 888~.51 5985.22 4145.85 N 3560.29 E 3 9002.49 5980.73 4256.22 N 3593.83 E 4 9208.64 5970.57 4393.12 N 3746.64 E 5 Casing positions in string ~A~ Top MO Top TVO RectanguLar Coords. Bot MO Bot TVO RectanguLar Coords. Casing n/a 5926.01 4016.12N 3575.30E n/a 5980.00 3707.99N 5010.25E 5 1/2" Casing Targets associated with this weLtpath Target name Geographic Location T.V.D. RectanguLar Coordinates Revised 2D-O6bhs 5~2800.000,5958600.000,0.0000 5980.00 426~.78N 3562.~0E lO-Aug-98 2D-O6ehs 5~4250.000,5958050.000,0.0000 5980.00 3707.99N 5010.25E lO-Aug-98 · WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION COMPANY ,,,~__~._ ~_~ INIT CLASS _/~_;,Z_ _ /- ~')z 7 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4 Well Iocaled in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. API:~R .. DATE 26. ~_~_~j_~ 27, 28, 29. GEOLOGY Conductor string provided ................... Surface casing protects all known USDWs ........... CMl- vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ...... ~..~ . BOPE press rating appropriate; test to ,.~~ ' ' ' psigl Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N,/.___ ...................................................................................................................................... ' 31. Data presented on potential overpressure zones ....... ~__~..~ 32. Seismic analysis of shallow gas zones. ' .. 33 Seabed condition survey (if off-shore) ............. 34. Contact name/phon,e.for weekly progress reports .... ../ Y N [exploratory omyj -./ ................................................................... ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; ([')) will not damage producing formation or i~npair recovery from a po(fi; and (E) will not circurnvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N ENGINEERING: w~ar JDH__.~"' .~ COMMISSION: DWJ , ~---~.. __. RNC co co Comments/Instructions: Mnhelilisl r(':v 05/29/9B dlI:C \rll,~olfl(,l~\wo[cliRFl\rtir:lll;l\, h~( kh!,t Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: LIS **** REEL HEADER MWD 99/ 3/17 BHI 01 LIS Customer Format TaPe **** TAPE HEADER MWD 99/ 3/17 100861 01 1 3/4" NaviGamma, Gamma Ray Data LIS COMMENT RECORD(s): ~2345678901234567890123456789012345678901234567890123456789012345678901234567890 !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!t!!!!!!!1!!!!!!! Extract File: Header.las -Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame -Well Information Block #MNEM. UNIT STRT F STOP F STEP F NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL REF DATE. API #MNEM. UNIT FL SECT i TOWN. N RANG. PDAT. LMF . FAPD. FT DMF . EKB .M EDF .M EGL . M CASE. F OS2 . ~Remarks (1) (2) (3) (4) (5) Data Type Information 8700.0000: Starting Depth 11300.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: ARCO Alaska, Inc. WELL: 2D-06B FIELD: Kuparuk River Unit LOCATION: 124' FSL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1 3/4" NaviGamma JOB REFERENCE: 100861 LOG DATE: 10 Oct 98 API NUMBER: 500292116802 Value Description 510' FEL : Field Location 23 : Section lin : Township 9E : Range M.S.L. : Permanent Datum KB : Log Measured From 121 : Feet Above Perm. Datum KB : Drilling Measured From 121' : Elevation Of Kelly Bushing N/A : Elevation Of Derrick Floor N/A : Elevation Of Ground Level 8773 : Casing Depth DIRECTIONAL : Other Services Line 2 Ail depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is realtime data. Well 2D-06B is represented by runs 3, 4, 6, 7 and 8 which are all Directional with Gamma Ray. The well was kicked off from the wellbore of Well 2D-06A @ 8773' MD (5956' TVD) through a window cut in the liner. RECEIVED 22 3999 Alaska Oil & Gas Cons. Commi ' (6) Well 2D-06B was drilled to TD @ 11282' MD (6030' TVD) on Run 8. (7) Run 1 and run 2 were milling runs, and no logging data was acquired in new hole. (8) No data was aquired on Run 5 due to MWD failure. (9) The Gamma Ray interval from 11050' MD (6030' TVD) to 11234' MD 6030' TVD was depth shifted by 24' after a tie-in which resulted in a break in the log. (10) The interval from 11256' MD (6030' TVD) to 11282' MD (6030' TVD) was not logged due to the sensor to bit offset. (11) A Magnetic Declination correction of 27.23 degrees has been applied to the Directional Surveys. -Mnemonics -> GRAX = Gamma Ray MWD-API [MWD] (MWD-API units) -> ROPS = Rate of Penetration (ft/hr) -> TVD = True Vertical Depth (feet) -Sensor Offsets RUN GAMMA DIRECTIONAL 3 23.35 ft. 15.80 ft. 4 22.65 ft. 15.10 ft. 6 25.69 ft. 18.14 ft. 7 25.69 ft. 18.14 ft. 8 26.14 ft. 18.59 ft. Tape Subfile: 1 70 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS FILE HEADER MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alsaka, Inc. WN 2D-06B FN Kuparuk River Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~234567890~234567890~23456789~~23456789~~234567890~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAXMWD 68 1 4 2 ROPS MWD 68 1 4 * DATA RECORD (TYPE# O) Total Data Records: 61 1014 BYTES API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 t 4 99 995 99 1 8 Tape File Start Depth = 8759.000000 Tape File End Depth = 11284.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 15157 datums Rep Code: 79 2 datums Tape Subfile: 2 68 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER MWD 99/ 3/17 100861 01 **** REEL TRAILER **** MWD 99/ 3/17 BHI 01 Tape Subfile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 17 MAR 99 l:01p Elapsed execution time = 1.10 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GRAX 8759.0000 -999.2500 8759.5000 -999.2500 8800.0000 123.2550 8900.0000 100.9800 9000.0000 65.3400 9100.0000 41.5800 9200.0000 45.3960 9300.0000 57.3500 9400.0000 82.5330 9500.0000 57.1700 9600.0000 49.0050 9700.0000 64.7690 9800.0000 99.7560 9900.0000 97.4260 10000.0000 89.1000 10100.0000 80.1900 10200.0000 67.3930 10300.0000 95.5810 10400.0000 126.2250 10500.0000 120.2850 10600.0000 145.5300 10700.0000 124.2190 10800.0000 147.0150 10900.0000 49.7690 11000.0000 83.1600 11100.0000 99.2430 11200.0000 115.8300 11284.0000 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = Tape Subfile 3 is type: LIS ROPS -999.2500 -999.2500 32.7000 76.5000 81.8000 67.9000 76.5000 81.6890 80.0000 81.8000 69.2000 105.8000 81.0970 40.0000 84.9600 81.8000 64.2000 69.2000 32.7000 75.7890 94.7000 46.7000 72.5960 97.2000 63.1000 66.6000 72.2480 -999.2500 8759.000000 11284.000000 0.500000 Feet RECEIVED 1999
