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198-187
• • -Zso,t2 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY Conoco Phillips Alaska Inc BP Exploration (Alaska) Inc. (mandatory) Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME 1M-17; 1D-108;CD2-53;2L-311 900 E. Benson Blvd. 9/'tj/2016 K.BENDER (mandatory) Anchorage, Alaska 99508 FIELD KUPARUK RIVER UNIT;W.SAK;ALPINE;TARN to acknowledge receipt of this data. (mandatory) COUNTY North Slope LOG TYPE MVRT-WireLine (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: TODAYS DATE: 29-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares EMAIL: Paul.CanizaresAbakerhughes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS Ldi9itaVimage) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS' '#OF1'RINI "#OF COPIES #OF COPIES #OF COPIES 1 ConocoPhillips Alaska Inc. 0 1 Attn:Ricky Elgaricio ATO 3-344 riII 8/ D 1700 G Street SEP AK 99510 SEP 0 1 2W3 2 State of Alaska -AOGCC 0 1 r4QG CT (Attn:Makana Bender 333 W.7th Ave,Suite 100 'Anchorage,Alaska 99501 3 Chevron/KRU Rep 0 1 Attn:Glenn Fredrick 310 K Street,Suite 406 Anchorage,AK 99501 4 BP Exploration(Alaska)Inc. 0 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Douglas 5 DNR-Division of Oil&Gas *** j 0 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 i***Stamp"confidential"on all material deliver to DNR 6 ConocoPhillips Alaska Inc. 0 1 0 Attn:Mick Davasher ATO-1490 700 G Street Anchorage,AK 99510 TOTALS FOR THIS PAGE: 0 0 5 0 0 0 TOTALS FOR ALL PAGES: 0 0 5 0 0 0 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. /C~- / ~,' '~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: 1~ L..~ ~'J~' ~ Poor Quality Original - Pages: Other - Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED Logs of various kinds Other COMMENTS: Scanned by: Beverly Mildred Daretha a~Lowell Date: ,,~.//9 Isl~'/~ TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Oaretha~well • Page 1 of 2 Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878 ©conocophillips.com] Sent: Friday, January 04, 2013 2:42 PM 1 C?� To: Schwartz, Guy L (DOA) 7p Subject: RE: McOH treatments for WS ESP wells / (V— /cf Guy There are no changes to surface piping, we would just have a tank on site that a pump truck would tie into and pump directly into the wellhead. There will be a PSV on the pump truck. We can provide a drawing of the wellhead, if that would be of use. All 3 wells have shear out valves below the packer. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's CeII (907) 943 -1687 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz ©alaska.gov] Sent: Friday, January 04, 2013 9:52 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]RE: McOH treatments for WS ESP wells Oh forgot to add that a drawing of the surface piping/ safety valves for the injection system should be submitted to the AOGCC. You could just email them to me. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Friday, January 04, 2013 9:49 AM To: 'NSK Well Integrity Proj' Subject: RE: McOH treatments for WS ESP wells MJ, I don't see any reason for requiring sundry approval or reporting for the methanol operation. With inhibitor added I don't see much risk with corrosion on the casing or tubing in the short term. Just to make sure is there still a shear out valve below the packer for this setup in case the ESP overpressures the tubing if there is a surface shut in? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/4/2013 • 1 Page 2 of 2 From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Thursday, January 03, 2013 5:33 PM To: Schwartz, Guy L (DOA) Subject: FW: McOH treatments for WS ESP wells Guy, Just following up. Please let me know if we need to provide any specific information or 10- 403/404 for this work. Thank you. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's CeII (907) 943 -1687 :egrity Proj mber 16, 2012 3:55 PM L (DOA); 'Regg, James B (DOA)' irity Proj; NSK Problem Well Supv, Patterson, Amanda treatments for WS ESP wells Guy, ConocoPhillips plans to replace the packer fluid in West Sak packer ESP wells with corrosion inhibited methanol for the purpose of injecting daily McOH treatments into the production stream to prevent hydrates and freezing issues. The treatments will be approximately 20 bbls per day and enter the tubing via a bellowed gaslift valve placed above the ESP. Methanol related corrosion concerns will be mitigated with a Baker Hughes corrosion inhibiting chemical. Our plan is to try it on the following wells 1 D -108 (PTD 198 -187), 1D-113 (PTD 198 -178), and 1 D -134 (PTD 198- 11) Please let me know if there are any AOGCC concerns or questions with the plan. Additionally please advise if there will be any 10- 403/404 Sundry requirements. Thank you MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 1/4/2013 STATE OF ALASKA AL/ OIL AND GAS CONSERVATION COMINSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Nrforations r Perforate r Other ,/ est I- P Alter Casing r Pull Tubing Stimulate - Frac r Waiver r Time Extension r Change Approved Rogram r Operat. Shutdow n r Stimulate - Other r" Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development IV Exploratory r _ - 198 -187 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-029-22921-00' do - 7. Property Designation (Lease Number): 8. Well Name and Number: r ADL 25650 ° 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ., none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7150 feet Plugs (measured) 6888 true vertical 4210 feet Junk (measured) None Effective Depth measured 6990 feet Packer (measured) 3397, 6495 true vertical 4058 feet (true vertucal) 2008, 3595 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 7092 7.625 7133 4194 JUL RECEIVED UL 2 r �� JUN 15 2012 Perforation depth: Measured depth: 6590'- 6620', 6656- 6686', 6722'- 6752', 6782'- 6800', 6840' -6874' AOGCC True Vertical Depth: 3683'- 3711', 3745'- 3772', 3806-3834', 3863'- 3879', 3917' -3949' l� Tubing (size, grade, MD, and TVD) 3.5, L -80, 6439 MD, 3544 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED - THRU PACKER, WEATHERFORD HYDROW II DUAL - STRING PACKER @ 3397 MD and 2008 TVD GRAVEL PKR - BAKER GRAVEL PACK PACKER @ 6495 MD and 3595 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 100 12 14 -- 148 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development R.- .. Service r Stratigraphic r 16. Well Status after work: - Oil 1- Gas r WDSPL !— Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ fl SUSP E SPLUG f 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer Ca. 265 -6845 Printed Name Brett Packer Title Sr. Wells Engineer Signature ., Lam/( l�^' r „ i / L Phone: 265 -6845 Date (` /( z_ r Form 10 -404 Revised pis JUN 15 201 V I- Z I Z,.r I �� � S ubmit Original Only , I KUP • 1D-108 Conoc 1/1160 Well Attributes Max Angle & MD TD Ai<lSkci, It, Wellbore APIIUWI Field Name Well Status Inc' (") MD (ftKB) Act Btm (ftKB) q 500292292100 WESTSAK PROD 65.88 5,357.61 7,150.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NONE 10 2/9/2012 Last WO: 5/15/2012 10/7/1998 Well Confle -10 -108, 5/22/2012 2'35'30 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WORKOVER ninam 5/21/2012 HANGER, 37 Casing Strings '. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 40.8 121.0 121.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd -- PRODUCTION 75/8 6.875 40.7 7,133.1 4,193.5 29.70 L -80 ABM -BTC Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 41 - 121 TUBING 31/2 2.992 37.4 6,439.0 3,544.2 9.30 L -80 EUE8RDMOD Completion Details ".. Top Depth I i (TVD) Top Incl Nonni... / Top (ftKB) (ft (1 Item Description Comment ID (in) 1 37.4 37.4 -1.43 HANGER VETCO TUBING HANGER 2.950 3,396.6 2,001.6 62.20 PACKER ESP FEED -THRU PACKER, WEATHERFORD HYDROW II 3.250 DUAL-STRING PACKER ESP 6,349.5 3,463.8 27,19 DISCHARGE WELLLIFT DISCHARGE GAUGE UNIT (S/N: 12064963.00) 2.992 MANDREL, - - Illir 6,406.8 3,514.9 25.53 INTAKE TTC RECEIVING XO COUPLING w/ PERFORATED INTAKE (PM: 2.992 3,272 CSE8442XA) - 6,411.3 3,519.0 25.40 SEAL TANDEM SEAL SECTION (S/N: 12064707 / 12064492 ) 6,425.1 3,531.5 25.00 GEAR GEAR REDUCTION UNIT (S/N: 11985666) 11.42:1 El 6,426.9 3,533.1 24.95 MOTOR ESP MOTOR, 562MSP1, 60 hp/1240V/29 (S/N: 12059548) PACKER, 3,397 ',"1 `,:,,,,' 6,4352 3,540.7 24.71 GAUGE WELLLIFT MOTOR GAUGE UNIT (S/N: 192 - 00823) i 6,437.1 3,542.4 24.65 Centralizer MOTOR CENTRALIZER (P /N: C63569) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc,) Top Depth (TVD) Top Incl ESP - Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) MANDREL, -- - 3,540 2,069.0 62.54 CATCHER 5/16/2012 0.000 3,509 3,541 2,069.5 62.54 WRP 2.78" WRP 5/16/2012 0.000 6,495 3,595.3 22.98 GRAVEL PKR BAKER GRAVEL PACK PACKER 10/7/1999 4.000 CATCHER, 6,541 3,637.9 21.89 SCREEN BAKER SCREEN ASSEMBLY 10/7/1999 4.500 � 4�n1 6,888 3,961.5 18.80 PLUG BAKER BULL PLUG 10/7/1999 3,540 ithiiri WRP. 3,541 1 //F/ + Perforations & Slots f Shot Top (TVD) Btm (ND) Dens ESP Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh- Type Comment MANDREL, -- 6,590 6,620 3,683.2 3,711.0 WS D, 1D -108 12/27/1998 4.0 APERF 21/8" EJ BH Strip gun; 0 degree 6,297 phase - 6,656 6,686 3,744.5 3,772.4 WS B, 1D-108 12/22/1998 4.0 APERF 2 1/8" EJ BH Strip gun; 0 degree phase, down �_, 6,722 6,752 3,806.1 3,834.3 WS A-4, WS A -3, 12/9/1998 4.0 APERF 2 1/8" EJ BH Strip gun -- - 1D -108 DISCHARGE, . 6,350 6,782 6,800 3,862.5 3,879.3 WS A3, 1D-108 12/4/1998 4.0 APERF 21/8" EJ BH Strip gun 6,840 6,874 3,916.8 3,948.8 WS A2, 1D -108 11/18/1998 4.0 IPERF 2 1/8" EJ BH Strip gun Notes: General & Safety •_'-'.. End Date Annotation 8/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 INTAKE, 6,407 SEAL, 6,411 GEAR, 6,425 MOTOR, 6,427 1 GAUGE, 6,435 i rGiZ2s Centralizer, J 6,437 1 GRAVEL PKR, 8,495 SCREEN, 8,541 APERF, 6 IF .590 -6,620 APERF, 6,656 -6,686 APERF, 6,7228,752 LE= Mandrel Details Top Depth Top Port APERF, (TVD) Incl 0D Valve Latch Size TRO Run 6,782-6,800 III I Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Cont.. 1 3,272.5 1,955.6 65.02 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/15/2012 IPERF, ■ 2 3,509.5 2,054.8 62.47 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/15/2012 6,840 -6,874 3 6,297.4 3,418.5 30.99 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/15/2012 PLUG, 8,888__.,,__._____. PRODUCTION, • 1 L 41 -7,133 TD, 7,150 1 D -108 Well Work Summary DATE SUMMARY 2/24/12 PRE RWO T -POT BONNET( IOSED ), T -PPPOT BONNET ( PASSED ), T -POT UPPER BODY ( PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED ), T -PPPOT LOWER BODY ( PASSED ), GRAYLOC PPT PASSED ), FT -LDS ALL NORMAL. 5/7/12 CONFIRMED SOV SHEARED. MEASURED BHP @ 4800' RKB. BAILED SAND FROM 6297' TO 6330' SLM. IN PROGRESS. 5/8/12 BAILED SAND ON TOP OF SLIPSTOP. PULLED SHEARED SOV FROM 6312' RKB, AND REPLACED W/ DV. PULLED SLIPSTOP FROM 6368' RKB. PULLED PACKOFF ASSEMBLY @ 6375' RKB. ATTEMPTED TO LATCH PCESP, W/O SUCCESS. IN PROGRESS. 5/9/12 CLEARED SAND FROM TOP OF PUMP. PULLED 41.5' x 3 1/2" PCESP FROM 6376' RKB. COMPLETE. Note: Tbg and IA displaced with diesel as per procedure. 5/16/12 * ** RIG JOB * ** TBG OPEN TO 2.78" TO 3600' SLM. SET 2.78" WRP @ 3541' RKB, GOOD TEST. NORDIC PUMPED INHIBITED KWF DOWN IA, SET PACKER. MONITORED 30 MIN, GOOD. TESTED IA 1500 PSI, 30 MIN, GOOD TEST. BLED IA PER. DECOMPRESSION SCHEDULE. PULLED DV @ 3272' RKB. SET CATCHER @ 3541' RKB. LRS PUMPED 35 BBL DSL & 110 BBL GEL DSL DOWN IA UP TBG. SET DV @ 3272' RKB. COMPLETE. • • ConocoPhillips Time Log & Summary WelNiew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/11/2012 6:00:00 PM Rig Release: 5/17/2012 5:00:00 PM Time Logs Bate From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/11/2012 24 hr Summary Completed Well 1 D -131 Program. RDMO. MIRU at Well Slot 1 D -108. PJSM. Pull BPV. Begin Well Kill. 16:00 20:30 4.50 MIRU MOVE DMOB P RDMO Well 1D-131. MIRU on 1D-108. Accept rig at 18:00 hrs. Spot equipment and Cutting Box and Load Pits with Filtered 3% KCL Sea Water. Empty out KIII Tank (175 bbls) 20:30 22:00 1.50 COMPZ WELCTL KLWL P PJSM. Pick -up Lubricator. Pull BPV. Lay down same. Tbg = 130 psi. IA = 130 psi. 22:00 00:00 2.00 COMPZ WELCTL KLWL P PJSM. Pressure test lines at 250/3,500 psi. Good. Notify DSO and Security that we will be venting gas. Reverse in at 3.0 bpm /170 psi. with 110 bbls of Hot Filtered 3% KCL Sea Water to recover the Diesel Freeze Protect in the Tubing and to "wash" the ESP /HT Cable. Swap lines and begin the Well Kill pumping the long way at 5.0 bpm /470 psi, holding 120 psi back pressure on the Choke, routing returns to the Kill Tank (bbl /bbl returns). 05/12/2012 Complete Well Kill. Install BPV. CO Swab Valve. NU Tree. Install Blanking Plug. NU BOP Stack. Perform Initial BOPE Test. Pull Blankinc_Plug and BPV. Install Side Port Isolation Sleeve. Circulate Well. Pull Tbg Hanger to Rig floor. Prep to pull Completion. 00:00 03:00 3.00 0 WELCTL KLWL P Complete Well Kill Operations at 5.0 bpm /520 psi. Circulate and condition with a final rate = 3.0 bpm/ 170 psi. Total volume pumped = 410. Returns = 8.5 lb /gal. Monitor Well on vacuum. 03:00 05:00 2.00 0 WHDBO NUND P Install BPV. Nipple Down Tree. Inspect Tubing Hanger Threads. Good. Install Blanking Plus. 05:00 08:00 3.00 0 WHDBO NUND P . Nipple up BOP Stack w/ STA. 08:00 09:00 1.00 0 WHDBO RURD P PJSM. R/U Testing Equipment. Fill Stack and Lines. 09:00 16:30 7.50 COMPZ WHDBO PRTS P PJSM. Start Initial Test On BOPE. Function & PT rams, choke manifold and annular to 250/3000 psi. Kill HCR Failed. C/O HCR and PT same. 16:30 17:00 0.50 COMPZ WELCTL MPSP P Pull Blanking Plug & BPV. Install side Port Isolation sleeve.Monitor Well. Page 1 of 6 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:30 2.50 COMPZ WELCTLCIRC P PJSM. Rig up Lines. Fill Well with 20 bbls. Static Fluid Level was at — 450 -ft. Circulate and condition Well, 1.5 times with Filtered 3% KCL Sea Water at 5.0 bpm /600 psi. Returns = clean 8.5 lb /gal. Monitor Well on vacuum. Blow dow lines. Rig down lines. 19:30 21:30 2.00 6,433 6,400 COMPZ RPCOM THGR P Rig up Floor to pull Tubing Hanger. BOLDS. Pull Tubing Hanger free at 125K. Pull Tubing Hanger to Floor at 95K. Remove ESP /HT Penetrators. Flow Check Well = 25 bbls /hr loss. 21:30 00:00 2.50 6,400 5,446 COMPZ RPCOM TRIP P PJSM. Begin to single down the 3 1/2" ESP /HT Completion. Spooling ESP and HT Cables. Kick -out 3 1/2" Tubing from the Pipe Shed as needed. Depth at Midnight 5,456 -ft. Up Weight = 84K. Down Weight = 56K. 05/13/2012 Continue to single down the 3 1/2" ESP /HT Completion. Pick -up BHA #1, Reverse Circulating Junk Basket. TIH to the SC1 Packer. Work RCJB. Trip out with BHA #1. Recovered 6 pieces of a mangled up SS Band. 00:00 10:30 10.50 5,446 17 COMPZ RPCOM PULD P Continue to single down the 3 1/2" ESP/FITCompTetion. Spooling ESP and HT Cables. Kick -out Tubing from Pipe Shed as needed. 10:30 12:30 2.00 17 0 COMPZ RPCOM PULD P Lay Down Lower ESP Assembly Count all bands and clamps remove from completion. Clean & Clear Floor. Drain BOP Stack, set plug in hanger and Function BOP Rams and check for any lose bands. Recovered (465) 6' Flat guards, (18) 4' Flat Guards, (41) 3' Flat Guards, (56) LaSalle Clamps, (2) Pot -head protectors, (1724) SS Flat Bands. 12:30 13:30 1.00 0 0 COMPZ RPCOM PULD P PJSM. Install Wear Bushing. C/O Handling Equipment. Load Baker Tools to Rig Floor and Prep to MU BHA #1. 13:30 14:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Making Up BHA and TIH with Drill pipe with Nordic Crew and Baker Rep. 14:00 18:00 4.00 28 6,496 COMPZ RPCOM TRIP P MU & RIH with 5 3/4" Reverse Circulating Junk Basket on 3 1/2" IF Drill Pipe down to top of SC -1 Packer. Wash and work RCJB. 18:00 22:00 4.00 6,496 27 COMPZ RPCOM TRIP P Trip out with BHA #1, standing Drill Pipe back in the Derrick from 6,496 -ft. Up Weight = 110K. Down Weight = 68K. BHA at surface. 22:00 22:30 0.50 27 0 COMPZ RPCOM PULD P Lay down BHA #1. Empty RCJB. Recovered 6 small twisted pieces of Band. Total recovery = — one complete band. 22:30 23:30 1.00 0 0 COMPZ RPCOM RURD P PJSM. Clear floor. Rig up to handle 2 7/8" Hydril 511 Tubing. Page 2 of 6 • • • Time Logs Date From To . Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 441 COMPZ RPCOM PULD P Pick -up BHA #2, 2 7/8" Clean -Out String with 7 5/8" Casing Scraper. .5/14/2012 PU BHA #2, 2 7/8" Clean -Out String. RIH on 3 1/2" Drill Pipe. Reverse Well clean. TOOH. PU Test Packer and Retrievable Bridge Plug. RIH. Set RBP and test Casing. TOOH and lay down Packer and Bridge Plug. Pre. to run 3 1/2" Completion. 00:00 03:00 3.00 441 6,741 COMPZ RPCOM RIP P Trip in with BHA #2 with 3 1/2" Drill Pipe from the Derrick. Entered the top of the SC -1 Packer at 6,496 -ft. with no problems. Continue to ease down inside the Screen Assembly, lookin• for fill. Tagged fill at 6,741 -ft. COMPZ 03:00 06:00 3.00 6,741 6,885 • • P Wash Fill with ease at 3.0 bpm /300 psi, with no problems down to 6,826 -ft. Swap over to reverse circulate at 3.0 bpm /200 psi. Reverse 2 Drill Plpe Volumes with 33% return Fluid Loss. Saw some Sand and Silt on the tail end of the returns. Swap back over to circulating at 2.0 bpm /190 psi. Continue to wash Fill down to the end of the Screen Assembly (Bull Plug) at 6,885 -ft dpmd. Swap back to Reversing circulating at 3.0 bpm /220 psi. Reverse 3 Drill Pipe volumes for the final clean -up. . :00 09:00 3.00 6,885 825 COMPZ RPCOM PJSM. POOH f/ 6,826 -ft. Up Wt 125k / Dn Wt 65k. • :00 10:00 1.00 825 825 COMPZ RPCOM Stop and Hold PJSM. Discuss hazard for swapping out spools. Un -load Used ESP Cable and Heat Trace spool and Load New ESP spool. COMPZ 10:00 10:30 0.50 825 441 • Continue OOH and L.D. Scraper Assembly. COMPZ 10:30 11:30 1.00 441 0 • Continue OOH Laying down Hydril 511 TBG. COMPZ 11:30 12:15 0.75 0 28 • PU and MU BHA #3. RBP and Test Packer. 12:15 16:45 4.50 28 6,450 • - Z RPCOM RIP P TIH with Test Assembly. COMPZ 16:45 17:15 0.50 6,450 6,440 • On Depth to set RBP. Set RBP and PUH 10 -ft and Fill Stack. Up Wt 114k / Dn 64k. COMPZ 17:15 18:00 0.75 6,440 6,440 • RU Testing Equipment & Pressure Q \` Test CSG to 1500 psi and Record Test on Chart for 30 minutes. Good Test. Release Retrievable Bridge 11 Plus. Monitor Well. Takin• Fluid. 18:00 22:00 4.00 6,440 0 COMPZ RPCOM TRIP P Trip out from 6,440 -ft with Test Packer and Retrievable Bridge Plug, standing back Drill Plpe. (Finish loading, drifting, and strapping the Completion Tubing). Lay down Pkr and RBP. Recovered complete. 22:00 22:30 0.50 0 COMPZ RPCOM RURD P Clear and clean floor. Change handling equipment. Page 3 of 6 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subc ode T Comment 22:30 23:00 0.50 0 COMPZ RPCOM OTHR P Pull Wear Bushing. 23:00 00:00 1.00 0 COMPZ RPCOM RURD P PJSM. Prep and rig up for ESP Completion. X5/15/2012 Pick -up and service the ESP Assembly. Single in with the 3 1/2" ESP Completion as designed. Make -up Tbg :Hanger Install Penetrators. Make top ESP Connection Splice. Land Tbg Hanger. Test Pack -Offs. Install BPV. ND BOP Stack. 00:0004:00 - 4.00 0 124 COMPZ RPCOM RCST P PJSM. Pick -up and service ESP Assembly. Rig up Cable Sheave. Attach Motor Lead and TEC Wire. Install WeIlLife discharge Unit and attach TEC Wire. Check ESP Cable. 04:00 08:00 4.00 124 3,042 COMPZ RPCOM RCST P Begin to single the 3 1/2" Completion from the Pipe Shed. 08:00 08:30 0.50 3,042 3,042 COMPZ RPCOM SFTY P PJSM before making up Feed -thru packer with Weatherford and Nordic crew and Centrilift. Perform electrical inspection. 08:30 13:00 4.50 3,042 3,042 COMPZ RPCOM PULD P PU & MU weatherford feed -thru packer assembly and make ESP splice. Perform electrical inspection. 13:00 18:00 5.00 3,042 37 COMPZ RPCOM TRIP P Continue RIH w/ remainder of ESP Completion. 18:00 22:00 4.00 37 37 COMPZ RPCOM PULD P PJSM- PU & MU Vetco -Gray tubing hanger with side port isolation sleeve. Install penetrators. Make ESP splice. Perform electrical inspection. 22:00 22:30 0.50 37 0 COMPZ RPCOM THGR P Land tubing hanger. Up wt 105k, Dn wt 55k. RILDS. Clamp count ran on new completion; 3 ea. protectolizers 4 ea. 5150 clamps 3 ea. 3500 -A -05P clamps 110 ea. 3500 -A -05 clamps 22:30 23:00 0.50 0 0 COMPZ RPCOM PRTS P Pressure test upper and lower pack -off to 5000 psi for 15 minutes, good. 23:00 23:30 0.50 COMPZ RPEQP1 MPSP P Lay down landing joint. Drain stack. Pull side port isolation sleeve., Install BPV. 23:30 00:00 0.50 COMPZ RPEQP1 NUND P PJSM with Weatherford and Nordic 3 crews about ND of BOPE and Weatherford Safety Tensioning Adapter. 05/16/2012 ND BOP Stack. NU Tree and Test. Prep for S -Line ops. Drift and Correlate for WRP. Set WRP. Pump Corr Inhib SW down IA. Set Pkr. Test IA. Use decompression sch to bleed pressure. Pull DV. FP Well. 00:00 01:00 1.00 COMPZ RPCOM NUND P Continue ND of BOPE and Weatherford Safety Tensioning Adapter. Make ESP electrical check. Page 4 of 6 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:00 3.00 COMPZ RPCOM NUND P PJSM- NU Tubing head adapter and tree. Pressure test hanger void 5000 psi x 15 minutes. Install 2nd Swab valve back on tree. Split DP in derrick for weight distribution while NU tree. 04:00 04:30 0.50 COMPZ RPCOM MPSP P Pull BPV and set TWCV. PJSM- Slickline onsite, start loading slickline equipment to rig floor. 04:30 06:00 1.50 COMPZ RPCOM PRTS P Fill tree, rig up test equipment and test tree to 5000 psi x 5 minutes on chart. RD test equipment. 06:00 06:30 0.50 COMPZ RPCOM SFTY P PJSM- discussed slickline procedures and hazards, watch your hand placement. 06:30 13:00 6.50 COMPZ RPCOM SLKL P MIRU Slickline. P/T Lub, RIH w/ 2.78" Drift to 3600' SLMD. RIH w/ KOT to 3,492' SLMD. _RIH w/ WRP + set @ 3541' RKB, PT same to 500 _ psi for 5 minutes. 13:00 15:00 2.00 COMPZ RPCOM CIRC P PJSM. Bullhead down IA w/ 120 bbls of CRW at 2 bpm. ICP 250 psi / FCP 480 psi. 15:00 15:15 0.25 COMPZ RPCOM OTHR P RU Hoses to Set Packer. 15:15 15:45 0.50 COMPZ RPCOM PACK P Pressure up on TBG and Set Hydrow • II Packer per Weatherford Rep. Packer set at 3,150 psi. 15:45 16:45 1.00 COMPZ RPCOM PRTS P RU Gauges and Hoses and PT IA to 1500 psi while holding 1000 psi on the TBG for 30 minutes and chart same. 16:45 20:00. 3.25 COMPZ RPCOM OTHR P Start the Bleeding Down IA following the decompression schedule. 20:00 21:30 1.50 COMPZ RPCOM SLKL P PJSM- RU Slickline, MU Catcher and RIH w/ KOT, chase catcher to 3,400 -ft, PUH and latch DV at 3,272 -ft RKB, POOH w/ DV on BK latch. Redress KOT to run while pumping freeze protect. 21:30 22:30 1.00 COMPZ RPCOM RURD P MI LRS and spot equipment. PJSM- discussed pump procedure and hazards. RU LRS and transport. Pressure test lines. 22:30 23:45 1.25 COMPZ RPCOM CIRC P Reverse circulate 35 bbls diesel (neat) followed by 76 bbls Gelled Diesel (initial order 105 bbls gelled diesel, transport manifest indicates 108 bbls loaded, metered, sight glass showed 90 bbls) followed by 30 bbls neat diesel at 2 bpm, ICP 500 psi, FCP 550 psi. 23:45 00:00 0.25 COMPZ RPCOM SLKL P PJSM- RU Slickline. 05/17/2012 Set DV. PT Tbq. RD S -Line. Make Final ESP electical check. Set TWC. Change out Production Valve on tre _Tg t break tt tree. Pull T WC. Set BPV. Se cure cellar. Release Rig. Page 5 of 6 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 COMPZ RPCOM SLKL P RIH w/ KOT and set DV in upper GLM at 3,272 -ft, pressure IA to 200 psi, POOH, DV set. Bleed IA to 0 psi. PJSM- RDMO Slickline. 02:00 03:00 1.00 COMPZ RPCOM PRTS P RU test equipment and pressure up tubing to 3010 psi on chart. lost 110 +n psi in first 15 minutes and 50 psi inv the next 15 minutes. IA held 30 psi for 30 minutes. bleed tubing and IA to 0 psi. RD test equipment and LRS. 03:00 03:30 0.50 COMPZ RPCOM OWFF P Monitor Tubing and IA for flow 30 minutes, well static. 03:30 04:00 0.50 COMPZ WHDBO MPSP P Drain tree. Set TWCV. Make final ESP electric) checks. 04:00 05:15 1.25 COMPZ WHDBO NUND P PJSM- ND production valve with (ROV) and NU new production valve with manual valve operation orientated same as ROV as per night lead DSO. DSO waived witness to orientation. 05:15 09:00 3.75 COMPZ WHDBO PRTS P Fill tree with diesel and test production valve break and tree 5000 psi x 5 minutes on chart. RD test equipment. 09:00 13:00 4.00 COMPZ WHDBO MPSP P Pull T.W.C. Call Valve crew out to help Vetco Gray Rep lubricator TWC from hanger. Two way check was bad, and gamage seals. Rebuild and Install. 13:00 15:00 2.00 COMPZ WHDBO PRTS P Starting testing tree again. Continue to chase the ghost leak? Finally achieved a test after several attempt. 15:00 16:30 1.50 COMPZ WHDBO MPSP P Rig Down Testing equipment. Pull TWCV and install CIW 3" Type "H" BPV. 16:30 17:00 0.50 COMPZ MOVE MOB P Secure cellar and RDMO. Rig released at 17:00 hrs. Page 6 of 6 • WELL LOG S TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245.8952 1) MTT Report 21,Jun-10 1 D-1O5A 1 Report 50-029-22843-01 2) MTTReport 21-Jun-10 1Q1O8 1 Report 50-029-22921-00 ~~r -aaa ~~~- <~s~ Signed Print Name: ~ ~i '~ JJJ~~~FFF,,,+++0001I~w,. , '~~ ~* Date : II11 ~ ,~~~+~~ _~ ,, ~ Win. ~.xnmi~si:>Y ~ fir; PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAI<.: pdsanchoraae(~memorvloa.com WEBSITE : www.memorvloa.com C:\Documents and Settings\Diane Williams\Desktop\TTansmit_Conoco.docx ~S Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillipsAlaska,lnc. Well: 1D-108 Log Date: June 21, 2010 Field: West Sak Log No.: 10644 State: Alaska Run No.: 1 API No.: 50-029-22921-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD MOD Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 197 Ft. (MD} Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BTC Top Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 197 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surtace Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" production casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 197'. Changes in metal volume are relative to the calibration points at 31' and 131', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates minor metal loss over the intervals 38' - 41' and 62' - 72' in all three passes. Log plots of the entire 10Hz and 5Hz passes and an expanded log plot of -top 30' of the 5Hz pass are included in this report. A maximum ~3% circumferential metal loss is indicated in the interval between 38' - 41' and 62' - 72' in the 10Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: G. Etherton Analyst: HY. Yang, M. Lawrence & J. Burton Witness: 8. Boehme ProActive Dicgnostic Services, Tnc. P, O. Box 1359, Stafford, TX 77497 Phone: (281) or (888j 565-9085 Fax: {281j si65-1369 E-mail: PDS(d~memorylog.cam Prudhoe Bay Field Office Phone: (907j 659-2307 Fax: (907} 659-2314 o1~MwErrs SHz, ~z and 10Hz Delta Metal Thi~iess Passes Overlay 1 Q4 AFn~9 F 1 D-108 June 21, 2010 ' P11°I<CTIVF ~I.AF~NBSTIC SERVICES ' Database File: d:lwarrior\datal1d-1081overlay.db Dataset Patl-u-lame: overlay Presentation Format: overlay Dataset Creation: Tue Jun 22 1 i :16:03 ?010 Charted by: Depth in Feet scaled 1:150 ' -Jd -50 -50 ! I 0 20 Delta Metal Thickness X010 (10Hz) (%) Delta Metal Thickness '?010 (8Hz} (%} Delta Metal Thickness 010 (5Hz} (%} Joints Joint 40 Inverted Casing Collar (8Hz and 1 1 - - - - - 60 - 1 ~ ~ ~ ~ ~ ~ 10Hz Delta Nletal ao Bat 1 i I I i .-- of 16" z D i Ita Metal Th Delta Metal Thic 50 50 50 A Q`£MwEt`s R~rded Magnetic Thickness Lr~Data - 10Hz Pass C~ Fm's w ~' ~ __.~"' 1 D-108 June 21, 2010 PnoAcTivc DinynosTic Senviccs Database File: d:lwarriorldata\1d-1081passes.db Dataset Patf~man~~e: 10HzPass Presentation Format: 30 Dataset Creation: Wed Jun 23 14:02:11 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (°io) 50 3 MTTP01 (rad) 13 0 Line Speed (tt/min) -200 i-5 ~ MTTP1:? (radl 4? Hanger n Pups 3.5" Collar Pup Collar ~ 20 Delta Metal Thickness Tubing Jt. 1 3% Metal Loss 40 7.625" Collar (Inverted Respo 5" Collar -~, 60 ncd Jt. 2 Metal Bottom of 16" Conductor 5" Collar ~ _ ~ 80 6?5" Collar ng Jt. 3 ii i~ t A o`~~wE"s R~rded Magnetic Thickness I.~ Data - 5Hz Pass .~ ~q• W ----~~„~ 1 D-108 June 21, 2010 P°oAcrivE D14yry°STIC SEnvicEs Database File: d:lwarriorldatal1d-1081passes.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Tue Jun 22 17:48:00 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness {°ro) 50 1.8 MTTP01 (rad) 11.8 ..._ ___e__. _._____.~ _. 0 Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 ~ -~.-~i----- ----------- - --- - ~~ ~ 1(,~~I ~~ v , ~ i P ~, Line 5 pee d~ f I = ~ i _ `~ ~ ~ s i zr~~ 3.5" Collar Pup W ide spre ad I sola ted Met al L oss .5" Collar 20 ~ Delta Met al Thickness Tubing Jt 1 . ~ - - -- 3 ~ 40 7.6 25" Collar i '. "` 3 5" Collar ; ~ _.. . n ~ 7 } t 60 ,.~ Tubing Jt. 2 2% Me tal L oss , Botto m of 16" Conductor 3. 5" Colla _ - -- ~ ~ ~~ 80 r: 7.625" C ollar ~. r Tubing Jt. 3 100 ~ `+ A o`E~,wE"s Eianded 5Hz Pass Magnetic ~j~ckness Log Data 4~ ac's 1 D-108 June 21, 2010 P110ACTIVE UI.AE~MOSTIC SERVICES Database File: da4varriorldatal1d-1081expanded 5hzpass.db Dataset Patl~rnarne: SHzPass Presentation Format: 18 Dataset Creation: Tue Jur-i 22 1 i :4$:00 2010 Charted by: Depth in Feet scaled 1:60 -~0 Delta Metal Thickness {%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min) -200 -r MTTP12 {rad) 3 t__. _ Hanger .... i ~ _ ~~ I I Pups I i I , ~~ ~ {r - 3. 5" C ollar ,7, f ~> s Line S pee d` 0 1 Pu p z f c a f i Widesr ead Isol r ( ated Me tal ; e Loss a I~ i z I I ~ ~ I t* - I 3.5" Coll ar - --- - ~0 f ~ g. x I ~ ~ . s .2 ~ a De lta M I eta I l Th ickness ~ ~ 30 p t y { A ,' I ~ -50 Delta Metal Thickness {°i°j 50 1.8 MTTP01 {rad) 11.8 0 Line Speed (ft/min) -200 -i MTTP12 {rad) 3 GonacaPhillips Alaska, Inc, KRU 1 D-108 1 D-108 API: 500292292100 Well T e: PROD An le TS: de SSSV Type: NONE Orig Com letion: 10!7/1998 Angle @ TD: 19 deg @ 7150 Tubing (°-sa1a, OD:3.500, ID:2 992) Annular Fluid: 3%KCI Last W/O: 10/8/1999 Rev Reason: Reset Pump, Slipstop, Packoff, SOV . ~ROOUCnoN Reference L Ref Lo Date: Last U date: 1 21612 0 04 (x7133, Last Ta 6370' to of um TD: 7150 ftKB oD:7.sz5, wt:zs 7o Last Ta Date: 4/20/2000 Max Hole An le: 66 de 5358 . ) Casin Strin -All Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED PUMP PRODUCTION 7.625 0 7133 4193 29.70 L-80 ABM-BTC (s3a7-s3as, 750) OD:2 Tubin Strin -TUBING . Size To Bottom TVD Wt Grade Thread 3.500 0 6414 3522 9.30 L-80 EUE 8rd-MOD Perforations Summar Interval TVD Zone Status Ft SPF Date T e Comment 6590 6620 3683 - 3711 WS D 30 4 12/27/1998 APERF 2 1/8" EJ BH Strip gun; 0 de ree hase GAUGE 6656 - 6686 3745 - 3772 WS B 30 4 12/2211998 APERF 2 1/8" EJ BH Strip gun; 0 de ree hase down (63936394, oD:a.DOO) 6722 - 6752 3806 - 3834 WS A4,WS A3 30 4 12!911998 APERF 2 118" EJ BH Strip gun 6782 - 6800 3862 - 3879 WS A3 18 4 12/4/1998 APERF 2 1/8" EJ BH Stri un 6840 - 6874 3917 - 3949 WS A2 34 4 11/18/1998 IPERF 2 1/8" EJ BH Stri un Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt NIP 1 6318 3436 CAMCO KBMM CAMCO SOV 1.0 BK 0.000 2000 1/30/200 (sala-sa19, OD:3.500) Other lu s e ui .etc. -JEWELRY De th ND T Descri lion ID 6347 3462 PUMP PCP PUMP (OAL 41.2') MODEL 80TP 2000/SN# BM813, set 11/27/04 - 2.313 w/PACKOFF & SLIPSTOP ASSEMBLY set 11/30/04 sEAL 6393 3503 GAUGE BAKER SENTRY GAUGE 5000 PSI SET 2' UP FROM PIN ON JOINT #1 3.500 (sa19-sa25, OD:5.130) 6414 3522 NIP , Slotted ni le 2.992 GEARBOX 6419 3526 SEAL Tandem seal GS63 DB IL H6PFS 0.000 (saz5-sazs: 6425 3532 GEARBOX Gear reduction unit 9:1 525 series 0.000 OD:5.250) 6426 3532 MOTOR Motor 57 HP 1315/26 KMH 0.000 MOTOR 6495 3595 GRAVEL PKR BAKER GRAVEL PACK PACKER 4.000 (sazs-6x27, 6541 3638 SCREEN BAKER SCREEN ASSEMBLY 4.500 OD:5.620) 6888 3962 PLUG BAKER BULL PLUG 0.000 GRAVEL PKR (6495-6496, OD:6.700) ' • ' • • ' • • • • • . SCREEN (6541-6542. OD:6.700) Pert (6590.6620) PeR (66566686) Pert (6782-6800) Pert (6840.6874) PLUG (6888-6889, OD:6.700) .. 1 .~.~,n..e _: ,~ . ~, ~ :.. .. ~ : " _ ~ a~ a ~~~€ ~." .~.. ~-----gi p; ~ :ate ~: '~.. 4 +M"r. ~..~ t.?g-~i~~ tJ~+~V :{5.-df• i~j~ ~Ca~ Qr ~W~k 'F,~ N~M'4 . ~v~_ ,,..~ - 'i .L.43.4F JF ~..-;. ., , ~ .. _ - r G ~~ ~ ~ 7 "" p '+"~ x- '~ 3 ~ ~ flr~l~,~ i~ 3ts ~_is £:~=,.i ~A -..,, £~,~_ ~.. i` ,.+.A,F 'b-. ~s~,f ~ ~ ~`t~~ $ ~ ""tr~ i t~ q~`#.ic•, ~ ~ ~.. ~ - «: r+C, v ` ~i l '~,€ ~ s ~ ~ v ~ ~ °.°` xt ~34~, t(~ ..i ~ ~,~.°'..~- ~..~ 'Y, L:.w" 3 t}~... •,~ ...,.-~ ~+ ~^q p • ~ t q ±' q g {~ , .~ ,~~~ ~.~3 F ~ 'f .._. '. ~'@$ ~' Z , .b# i.."t.~ l'' t~.3~ is is c~i~(~'~ u~a.4'.~' ~~ ~ ~ ~" + 'r t^"~`~ ~ .,..~... ++yy k ~l .u - _ ~`t„ot~h~~` A`s~r~~~~ ~~{~ ~ ? r~4 ~. 'G a~ ~.~r~ xd.~~; ._s,, ;~ , e:-. s.~,...~ .. -~ ~~P .s r P1 31 gg ~1 t ~.'^r', 1 ~,`~ ~C'~ ~~ ~..,''~ W .. { . [. C~, z cs;. u y~-.s,..~~~~t~®T~~+~u3~ ~ ~P+~, Y. !R ii.`~.7 ~t~ ~~'~Fky,,,i ~t~~"} _ .. - - ~ #.~`~.i`.+6~ 4°ai'a~~ °Y~~. s r... ~AA E ~ b~~ 4~i ~M P i..Y d ~,.I a2 ~i°~i6 i J t ~. a..~+~.- ~ i~0 q _. ~ I 8 r y .S+~f Y. ~y m.,.. td+~ ri' . ~ ,,~~ p j ~ ['y "p~s ~ y~ - 'emu !v.4X'~~3 ~k'F.:~~'~ .~Y 1F•L [fr-! ~ ,~ ~ J ~ wpm 4 @ ;; a f.,;g 7%?~ti d i isr l. ~`5- ~ ~"~i ~Y'/ L~: S[~r" f '° ~o"' ~ ~' ~'f ~ : . . . . o ~ i~ i ~,~ ~~~ m.. ... a~~_ N'~"e.°'a~ P~'i 6 ~ ~4 •f~`,,~~fJ T~' ~A.~~`C~ +,J'L3~~ +sA~&..~C'9.A7 i '+.'`~.J/V ~~ ~4E.9 ~(~ qe~} ,~ ~?~.~ } {, ~~',,~,~~~ qS ~i4 ~-~'0~ 4.'~ ~~4~~M11~'c: Zi _ ~ t 9* ,,.~ 3 ,.. . .~ : ~~-,...a...c..y-,,. ~.~-~.K.«... -- .,~.,~.~..,...,.. . ~..+cc,r „h ~. ~ ., _ #` ...~......,v.,u..... j ~(, i a^~°.~~°----~ --~ ..~~ e::.~~ ~'`$ ~ . d, .~............,t. .,..~_ ..~ "" + } ~~i~ ....-.d ~~*~a C~d# S a.~l.~ ~.~~{ ~.+d~Y(t9 ~',..M E~4 ~z ~iJP~ ~} i'aj ~! w~Llk~i~ ~ ~ i~1~ ~S-ciiS~ ~~g,..,N.,.. »,,.,,. ~~~~^x~ °~iid'a` ~'t{a-? 'S€~ «. ~~~)'a'~~ a~.Res~~'t~~~~~ a .^+ ,trnS~ 6'"~3~`? -., ""' .+t~ `,~ F l a.~..1 ~ • ~: c „_ $ S ~ ;.....o.m.•__:. may: .. - - __~.~.,.. _. ~.......~..~~~,......~,... ..P«.,~+...,...~,.---.'.tea _... - ~t]~~rlfitl1 ~~@i1~t~~1~1 ~ , ~' ~~. ~ ~'~C~Y`J'«i~~~-~ ~ fit` ~ia~~ ~«~t~w ......~,_:.k --_.~.~ ~.~...... ~, _.w_~...~,. ~.~ ,.~.~,-,,_~~F~~ a~ i i~~l~ ern ~ ~ntr~i€ t`A~~~''~~ °~c~t~31~~_ ~ . ~~,.~.w~..._~ ~,~ ~a, ~q, ,~ _ WA_ ~`~Xr~.}~- ~9t r~;; ~~ q~ tCr~ tJ~'4. +~~~ ~~3~k`S, x.;7!"1 I ,~C?t~'iRa - ;i~+e .~°~ .,~ ~ ~ ?~ §~~,,~ e3d ~~'~~"!~i„-,f :+1?~ ~: '~,; 3~~f"SCS S~j~:~~_~~~ Leif?~3- ~~ ~ ~ 1et§ a'`i~ ~~s ~~, '"~ ~ ~ ~.: : .,,..,,^.^. . =` "' ..~.'~''^+~., .~^.. ir:,.. tics .~-.1."h `L~.~, ~.~~~w.k ,.'w~ ~-E~~'6t '~. ..+.F ....s. .'~1r. ~1~`s!4,,~~$:^~. a.; E.~~~~'S.~ ~~„.~,.•..,,~.. .~.~, wr„ ..~.> ,.... .. _ ______ .,. ~~' , _ .~.ww. .~.~. - ,,,~ >... - - ~.Nr~ ~..~.,v.....nr,.... . . Conoc~illips Alaska RECEIVED JUL 1 0 2007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 s'CANNED JUL 11 20D7 \q<b~\Cb1 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level ofapprox. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips W ell Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name pro # cement pumped cement date inhibitor sealant date ft bbls ft oal 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/912007 10-103 202-096 5" na 8 6/9/2007 10-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/912007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 61912007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/9/2007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/9/2007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/912007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/9/2007 1 0-126 198-108 2" na 1 6/912007 10-127 198-109 8" na 2.5 6/912007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/912007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 PIi .LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 2, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1D-108 (198-187) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the acid treatment operations on the KRU well 1D-108. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEIVED MAY 0 ~[ ZOO1 Alaska Oil & Gas Cons. Commission Anchorage "- - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 41 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 5203' FNL, 596' FEL, Sec. 14, T11 N, R10E, UM (asp's 560491, 5959739) 1D-108 At top of productive interval 9. Permit number / approval number 522' FNL, 2446' FEL, Sec. 14, T11N, R10E, UM 0 198-187/ At effective depth 10. APl number 50-029-22921 At total depth 11. Field / Pool 333' FNL, 2505' FEL, Sec. 14, T11 N, R10E, UM (asp's 558528, 5964593) Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total depth: measured 7150 feet Plugs (measured) true vertical 4210 feet Effective depth: measured 6990 feet Junk (measured) true vertical 4058 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' PRODUCTION 7021' 7-5/8" 568 sxAS ~L, 34O sx C~ass G & 7133' 4193' Perforation depth: measured 6590'-6620', 6656'-6686', 6722'-6752', 6782'-6800', 6840'-6874' RECEIVED true vertical 3683'-3711', 3745'-3772', 3806'-3834', 3862'-3879', 3917'-3949' ~,~' 0'5 Z 00 1 Alaska Oil & Gas Cons. Commissi~ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 6414' MD. ,~rlchorage ~ackers & SSSV (type & measured depth) No packer, No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached descr/ption Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 180 35 24 - 145 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed MichaelMooney ~,~'~C~ Title Staff Engineer Date .~/~'//~f Prepared b~ Sharon Al/sup-Drake 263°4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICAT~ " ...... 1D-108 Event History Date Comment 05/19/00 PUMP ACID TREATMENT CONSISTING OF 20 BBL XYLENE PREFLUSH, 200 BBLS OF 7 1/2% HCL AND 300 BBL OVERFLUSH OF 3% KCL. FINAL DISPLACEMENT WITH 100 BBLS DIESEL. JOB PUMPED AT 3 BPM AND 1100 PSI WHTP, NO SIGNIFICANT BREAKBACKS. ****READY FOR SOV AND FLOWBACK ..... [OTH E R STI M] Page 1 of 1 5/2/01 -i98~187-0 ............................ KUPARUK RIVU WSAK 1D-108 50. 02912292i]00 ~5'HILLIPS'~A[~KAINC Roll #1: Start: Stop Roll #2: Start Stop MD 07150 TVD 04209 Completion Date: 1/24/99 Completed Status: I-OIL Current: Name Interval 8759 1,2 SPERRY MPT/GR/EWR4 OH 10/28/98 10/28/98 DGR/EWR4-MD 1,2 121-7150 ~z~ ~:~_ OH 11/4/98 11/4/98 DGR/EWR4-TVD 1,2 121-4210 t~a ~],~ OH 11/4/98 11/4/98 GRAVEL PACK FINAL 6450-6900 3~,2~- CH 5 10/14/99 10/27/99 USIT FINAL BL(C) 0-6092 CH 5 4/8/99 4/27/99 SRVY RPT SPERRY 0-7150. OH 11/10/98 11/12/98 Sent Received T/C/D Thursday, January 25, 2001 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .v November 17, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-108 (Permit No. 98-187/399-182)Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the Report of Sundry Well Operations for the recent workover operations on KRU 1D-108. If there are any questions, please call 265-6120. Sincerely, OR ¢INAL G. C. Alvord Drilling Engineering Supervisor Kuparuk Drilling GCA/skad ~ .:/ STATE OF ALASKA -x~ ALASKA OIL AND GAS CONSERVATION COMMISSION · REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging_ Perforate_ pull tubing _ Alter casing _ Repair well Other X ESP Change-out 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development X RKB 37' 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 74' FSL, 596' FEU Sec. 14, T11 N, R10E, UN 1 D-108 At top of productive interval' 9. Permit number/approval number: 522' FNL, 2446' FEL, Sec. 14, T11N, R10E, UN 98-187/399-182 At effective depth: 10. APl number: 50-029-22921 At total depth: 111. Field/Pool: 338' FNU 2504' FEL, Sec. 14, T11 N, R10E, UN iKuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total Depth: measured 7150' Plugs (measured) cement retainer @ 6889' true vertical 4209' Effective Deptt measured 6889' Junk (measured) true vertical 3963' Casing Length Size Cemented Measured depth True vertical depth Conductor 84' 16" 9 cu yds High Early 121' 121' Surface 7096' 7.625" 568 sx AS IIIL & 7133' 4193' 340 sx Class G & Production 60 sx AS I Liner Perforation Depth measured 6840'-6874', 6782'-6800', 6722'-6752', 6656'-6686', 6590'-66Z~' true vertical 3917'-3949', 3862'-3879', 3806'-3834;, 3745'-3772', 3683'-37l ~' Packers and SSSV (h/pe and measured depth) Gravel Pack packer @ 6495', No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) ~.-~.; i~.ii~:_..:' ::~..~? N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure · Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _Z Oil _Z Gas _ Suspended _ Service _ 17. I hereby· certify that the foregoing is true and correct to the best of my knowledge. Form 10~'-zi04 Rev 06/15/88 SUBMIT IN DUPLICA~.~ Date: 10/22/99 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-108W0 RIG:NORDIC 3 WELL_ID: 999409 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD: START COMP:09/28/99 FINAL: ARCO ALASKA INC. Page: 1 WELL SUMMARY REPORT ! WI: 0% SECURITY: 0 API NUMBER: 50-029-22921-00 09/28/99 (C1) TD: 0' PB: 6990' 09/29/99 (C2) TD: 0' PB: 6990' 09/30/99 (C3) TD: 0' PB: 6990' 10/01/99 (C4) TD: 0' PB: 6990' 10/02/99 (C5) TD: 0' PB: 6990' 10/03/99 (C6) TD: 0' PB: 6990' 10/04/99 (C7) TD: 0' PB: 6990' KILL WELL MW: 8.7 KCL SUPV:D. GLADDEN / S. GOLDBERG Move rig to 1D-108. Accept rig @ 1900 hrs. PJSM. Start kill procedure. POOH WITH 3 1/2" TUBING MW: 8.7 KCL SUPV:D. GLADDEN / S. GOLDBERG PJSM and pre-spud meeting. Spot viscosified pill. ND tree and NU BOPE and atest BOPE to 250/3500 psi, OK. Evacuate rig for Pool 6 gas alarm. Pull tubing. POOH WITH REVERSE BASKET MW: 8.7 KCL SUPV:D. GLADDEN / S. GOLDBERG Pull ESP completion. Hold safety time out. RIH with workstring. Drop ball break circulation to seat ball and divert flow to jets. Wash and core to 6854' POOH WITH MILL MW: 8.7 KCL SUPV:P. LOCKWOOD / S. GOLDBERG POOH with reverse basket. RIH with second reverse basket. Tag fill at 6853'. CBU. POOH. RIH w/cleanout mill. Tag sand at 6859' Reverse circulate and cleanout to 6872'. SERVICING RIG MW: 8.7 KCL SUPV:P. LOCKWOOD / S. GOLDBERG Continue reverse circulating to clean out from 6872' to 6889'. PJSM. Pump caustic wash. Pump CE101 pill, acid pickle. POOH POST GRAVEL PACK MW: 8.7 KCL SUPV:Po LOCKWOOD / S. GOLDBERG PJSM. RIH w/gravel pack screens, inner string and packer. Set packer. GRAVEL PACKING MW: 8.7 SUPV:P. LOCKWOOD / S. GOLDBERG Pump gravel. Safety meeting. Wash sand out to 6889' Reverse circulate sand out of well. KCL Date: 10/22/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/05/99 TD: 0' PB: 6990' C8) 10/06/99 TD: 0' PB: 6990' C9) 10/07/99 C10) TD: 0' PB: 6990' 10/08/99 (Cll) TD: 0' PB: 6990' TIH W/LOGGING RUN #1 MW: 8.7 KCL SUPV:D. GLADDEN / R. OVERSTREET TIH w/gravel pack assy. PJSM. Pump silica. Reverse out excess sand from 6797' to 6889' RUN ESP COMPLETION MW: 8.7 KCL SUPV:D. GLADDEN / R. OVERSTREET Log gravel pack, tag ~ 6900 WLM. PJSM. Test packoff to 500 psi. Set test plug and test to 3000 psi, OK. Run ESP completion, install Baker sentry tool. MOVING'RIG TO 1D-112 MW: 8.7 KCL SUPV:D. GLADDEN / R. 0VERSTREET Continue to run ESP completion. Space out heat trace. N/D BOPs. N/U tree and test to 5000 psi. OK. RIG RELEASED 4:30 HRS AM MW: 8.7 KCL SUPV:D. GLADDEN / R. OVERSTREET N/U tree and test to 250/5000 psi, OK. Freeze protect well. Release rig ~ 0430 hrs. 10/8/99. Schlumberger NO. 12867 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Color Well Job # Log Description Date BL Sepia Print 1D-108 GRAVEL PACK W/RST (SIGMA & C/O) 991006 I 1 2H-12 PRODUCTION PROFILE W/PSP 991007 I 1 3K-18 b. lc.- INJECTION PROFILE W/PSP 991003 I 1 3K-30 t/I c INJECTION PROFILE W/PSP 991003 I I Please sign and return c~e copy of this transmittal to Sherrie at the above address or fax to (907)'~77! & {~aS C0115, C0111ffii.[011 10114~99 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ ESP change-out 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 37 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 74' FSL, 596' FEL, Sec. 14, TllN, R10E, UM 1D-108 At top of productive interval 9. Permit number / approval number 522' FNL, 2446' FEL, Sec. 14, T11N, R10E, UM 98-187 At effective depth 10. APl number 50-029-22921 At total depth 11. Field / Pool 338' FNL, 2504' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Field / West Sak Oil Pool 12. Present well condition summer Total depth: measured 7150 feet Plugs (measured) true vertical 4209 feet Effective depth: measured 6990 feet Junk (measured) true vertical 4058 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 84' 16" 9 cu yds High Early 121' 121' Surface 7096' 7.625" 568 sx AS IIIL & 340 sx Class G 7133' 41 93' Production & 60 sx AS I ORIGINAL Perforation depth: measured 6840'-6874', 6782'-6800', 6722'-6752', 6656'-6686', 6590'-6620' true vertical 3917'-3949', 3862'-3879', 3806'-3834', 3745'-3772', 3683'-3711' Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 6478' MD Packers & SSSV (type & measured depth) No packer, No SSSV 13. Attachments Description summary of proposal __X Detailed operations program Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ 14. Estimated date for commencing operation 15. Status of well classification as: September 27, 1999 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Ca//Mark Chambers 265-1319 Signed ~ ,~ Title: Drilling Team Leader Date ?(1'4~'(9~) ~4~ Prepared by Sharon AIIsup-Drake Ra,~d~,Tho,~as ~_~ ("'3.~.( '~ ~'"'I'd¢'~F4FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness [ Approval no. ~,~-¢ / Mechanical Integrity Test__ Subsequent form required 10- ~O ORIGINAL SIGNED'BY Approved by order of the Commission .~.-..~._-.~ ."_' .~.~..-!=;~ ........ o'~ ,~, Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE West Sak 1D-108 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH and pull Shear Valve from GLM @ 6414' leaving an open pocket. 2. Set BPV in tubing. 3. Prepare Location for Nordic Rig 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 8.7 ppg filtered 3% KCL kill weight brine. Displace tubing and annulus with kill weight brine. SI well and monitor pressure to ensure well is dead. Set BPV. 3. ND / NU and test B OPE. 4. Screw in landing joint. POOH standing back 3-1/2" tubing and spooling up ESP Cable and Heat Trace. 5. Load, strap and drift 3-1/2" drill pipe. 6. P, IH w/cleanout assembly PU 3-1/2" drill pipe off rack. 7. Cleanout to PBTD and POOH standing back 3-1/2" drill pipe. 8. RIH w/muleshoe and dual scrapper assembly. Spot sand plug and pump caustic wash and pickle. 9. POOH standing back 3-1/2" drill pipe. 10. PU and RIH w/gravel pack assembly. 11. Set packer @ +/- 6480' and perform gravel pack. 12. POOH laying down 3-1/2" drill pipe. 13. RIH w/3-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable and I-wire to penetrators. 14. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 15. ND/NU/Test 16. Freeze protect with diesel to +/- 2000' TVD. Lower Limit: 6.0 days Expected Case: 7.0 days Upper Limit: 9.0 days No problems encountered. Problems pulling ESP completion, cleaning out to PBTD or Gravel packing MAC 9/13/99 WEST SAK 1D-108 Proposed Schematic Standard Frac For Sand Control FFSC to FFSCGP ARCO Alaska, inc. Depths are based on )riginat RKB Parker 245 7-5/8" Marker Joint (+/- 50' Above Top Perforation) TD @ 7150' MD 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 16" 62.5# H-40 @ 121' MD Stage Tool @ 3052' MD Raychem Heat Trace @ +/- 3014' MD Directional KOP = 250' Max Angle = 65.88 Deg @ 5358' Avg Angle Thru W.Sak = +/- 20 Beg 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1/2" x 1" Camco 'KBMM' GLM run open @ +/- 6299' MD. 6' handling pups installed on top and bottor After the rig moves off location, the wells group will install a Shear Circulating Valve (pinned for 3000 psi Tbg / Csg differential) 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. I Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple). 10' Spaceout Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @ +/- 6420' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift TTC Changeover Centrilift Tandem Seal Section: GSB3 DB IL H6PFS Centrilift PC Pump and Flex Shaft Assembly: KUDU 180ML2000 Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer Baker Model SC-1 Packer @ +/- 6480' MD D-Sand Perfs: 4 SPF 6590' - 6620' Frac'd w/Carbolite and Prop Lock B / A4-Sand Perfs: 4 SPF 6656' - 6686' / 6722' - 6743' Frac'd w/Carbolite and Prop Lock A3-Sand Perfs: 4 SPF 6743' - 6752'/6782' - 6800' Frac'd w/Carbolite and Prop Lock A2-Sand Perfs: 4 SPF 6840' - 6874' Frac'd w/Carbolite and Prop Lock Top of sand plug @ +/- 6889' MD PBTD @ +/- 7004' MD 7-5/8" 29.7# L-80 BTC Mod @ 7133' MD MAC 9/13/99 ARCO Alaska, Inc. Tubing (0-6478, OD:3.500, ID:2.992) Production (0-7133, OD:7.625, Wt:29.70) PUMP (6475-6476, OD:2.750) NIP (6504-6505, OD:3.500) SEAL (6508-6509. OD:5.130) GEARBOX (6522-6523, OD:5.250) MOTOR (6523-6524, OD:5.620) Perf (6590-6620) Peri (6656-6686) Perf (6722-6752) Peff (6782-6800) GKA tD-108 ....... A--PITI500292292100 Well Type: jPROD ] Angle @ TS: Annular Fluid: 3%KCI Last W/O: Rev Reason: TAGGED FILL BY VG Reference Log: I Ref Log Date: I I Last Update: 16/20/99 Last Tag: 16377 _T_D~I? ~!~E I Top Bottom I TVD L wt ] Grade I Thread ~:00~ ~ 0 121I 121 I 62.58 I H-40 I WELDED _7_: ~_~ ~ .......... ~ 0 [ 7133 I 4193 ABM-BTC TUbing string, TUbing/F~C STRING_z: ,~!,~,? I Top Bottom TVD ] Wt IGrade I Thread _ 3.5oo _ I 0 l 6478.__ I 358o L_9,3_0 ~__L-80 J EUESrd TVD phase 3862 - 3879 3917 - 3949 Gas Lift MandrelsNalves StnI ~D TVDJ Man Man VMfr J VType , , , , ,JvoD~LatchJP°rtJTROI Date J Vlv j J J ~fr J Type J J J j J J J Run pomment ~"~r~r______.'~"~Z]'"'"'rrr~'5.~2..2,,,LCkMCO I KBMM I CAMCOI DCK j 3.5 LBK j2.992j 0j 6/6/99 j(1) ... 1. tubing shear valve Other (~lugs, e ~Tg:D I- - Description ~UMP J180ML200 KUDU ESP pump 6504J 36041 NiP ]~lotted nipple 6508J 3607J SEAL JTandem seal GSB3 DB IL HGPFS .6522 36201 GEARBOX jGearreduction un~e-~--525~-~-~es 65..~3 3621 MOT0.R' I Motor 57 HP 1315/26 KMH 0.000 0.000 ARCO Alaska, Inc. ~: Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-108 (Permit No. 98-187) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-108. If there are any qUestions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad Alaska 0d & Gas Cons. bra. ~ch0rage 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 E~] GAS E~ SUSPENDED E~ ABANDONED~] SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-187 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22921 ! ¢_~I 9 Unit or Lease Name At Top Producing Interval 522' FNL, 2446' FEL, Sec. 14, T11N, R10E, UM74' FSL,Depth596' F EL, Sec. 14, T11N, R10E, U M i~~i~ ;/iz. ~,~¢=; ! ?"~'"~'~ [ ,"l ~~'~ ' ' '" i ,' 10 Welll D-108KuparukNumberRiVer Unit At Total - · .~;,/ 11 Field and Pool 338' FNL, 2504' FEL, Sec. 14, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 30-Sep-98 03-Oct-98 24-Jan-99 /I 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 7150' MD & 4209' TVD 6990' MD & 4058' TVD YES M NO U NA feet MD 2585 APPROX 22 Type Electric or Other Logs Run GPJRes,CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 121' 24" 9 cu yds High Early 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKFR SET (MD) 3.5" 6531' N/A 6840'-6874' MD 3917'-3949' 'I'VD 4 spf 6782'-6600~ MD 3862'-3679' 'I'VD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ~['C 6722'-6752' MD 3806'-3834' 'I'VD 4 spf DEPTH INTERVAL {MD) AMOUNT & KIND OF MATERIAL USED 6656'-6686' MD 3745'-3772' TVD 4 spf 6640'-6874', 6782'-6600' see attachments 6590'-6620' MD 3683'-3711' TVD 4 spf 6722'-6752", 6656'-6686' 6590'-6620' Date First Production IMethod of Opera/ion (Flowing, gas lift, etc.) 4/25/§9 Date of Test Hours Tested PRODUCTION Fei OIL-BBL GAS-MCF WATER-BBt CHOKE SIZE I GAS-OIL RATIO 4/25/99 3.00 TEST PERIOI: 21 0 1 100I 23 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBt OIL GRAVITY-APl (corr) ;Press. 166 0 24-HOUR RATE: 1<50 4 9 0 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 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, iMEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Wesf Sak Sand 6583' 3677' Base West Sak 7046' 4111' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I herebYsigned ~ ~""-"'~¢*~'~certify that the foregoing~is true~ ~and correct to the~..____.best of my knowledge. ~ /~ t~,,~,,/,4 ~Title ~L/--~t~ ~:~ DATE '~---3~7 7// ~' ~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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: 1/28/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-108 RIG:NORDIC % 2 WELL ID: AK9549 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:09/30/98 START COMP:01/19/99 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22921-00 09/30/98 (D1) TD: 2470'(2470) SUPV:DONALD LUTRICK MW: 9.7 VISC: 275 PV/YP: 38/57 DRLG AT 3900' APIWL: 5.8 Move rig from ID-il0 to 1D-108. NU diverter system and test. Drilling from 121' to 2470' 10/01/98 (D2) TD: 4562' (2092) SUPV:DONALD LUTRICK MW: 9.6 VISC: 250 PV/Y?: 43/50 DRLG AT 5400' APIWL: 3.8 Drilling from 2470' to 4180' Ream from 3930' to 4180' Drilling from 4180' to 4562' 10/02/98 (D3) TD: 7039' (2477) SUPV:DONALD LUTRICK MW: 9.6 VISC: 340 PV/YP: 55/76 POH Drilling f/4562' to 7039' APIWL: 3.3 10/03/98 (D4) TD: 7150'(111) SUPV:DONALD LUTRICK MW: 9.9 VISC: 200 PV/YP: 45/57 CIRC AND CONDITION MUD FOR CEMENT APIWL: 3.3 Drilling from 7039' to 7150'. RIH w/7-5/8" casing to 4370' 10/04/98 (D5) TD: 7150' ( 0) SUPV:DONALD LUTRICK MW: 9.6 VISC: 67 PV/YP: 26/24 APIWL: 4.5 POH RIH w/7-5/8" casing. Pump cement. ND diverter. NU BOPE. and test to 300/2000 psi. Drill out stage tool. 10/05/98 (D6) TD: 7150' ( 0) SUPV:DONALD LUTRICK MW: 8.3 VISC: RUN USIT LOG 0 PV/YP: 0/ 0 APIWL: 0.0 Clean out cement to baffle collar at 7005'. Test casing to 3000 psi, OK. Displace well w/FW. Wiper trip to stage collar. 10/06/98 (D7) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 7150'( 0) SET BPV & NU TREE SUPV:DONALD LUTRICK/CUNNINGHAM Run USIT log. Run 3.5" tubing. Pump caustic wash. Freeze protect well. Date: 1/28/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/07/98 {D8) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 7150' ( 0) RIG RELEASE SUPV:DONALD LUTRICK/CUNNINGHAM ND BOPE. NU tree and test to 5000 psi. Release rig .@ 0700 hrs. 10/7/98. REMEDIAL AND COMPLETION OPERATIONS WELL:iD-108 RIG:NORDIC # 2 WELL ID: AK9549 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:09/30/98 START COMP:01/19/99 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22921-00 01/19/99 (C9) TD: 0' PB: 0' 01/19/99 (Ci0 TD: 7150' PB: 6500' 01/20/99 (Cll TD: 7150' PB: 6500' 01/21/99 (C12 TD: 7150' PB: 6500' 01/22/99 (C13) TD: 7150' PB: 6500' 01/23/99 (C14) TD: 7150' PB: 6500' 01/24/99 (C15) TD: 7150' PB: 6500' Move rig MW: 8.7 SUPV:RICK OVERSTREET Moved rig off well, problem w/flat tire. BRINE LAYING DOWN 3 1/2" TBG. MW: 8.7 BRINE SUPV:M.C. HEIM Finish tire repair on rig. Move over well. Rig accepted @ 0700 1/19/99. N/D tree. N/U BOPE and test to 250/3500. CLEANING OUT WELL @ 6695. MW: 8.7 BRINE SUPV:M.C. HEIM Rebuild and retest 1 choke and 1 kill line valve. Circ bottoms up and filter brine (6 bph fluid loss). POH laying down 3.5" tubing. RIH w/6.75" mill. Cleaning out carbolite from 6509 to 6590' Plugging off w/large chunks. LAYING DOWN 3 1/2" DP. MW: 8.7 BRINE SUPV:M.C. HEIM Clean out well by reversing from 6695' to 6910'. Recovered lots of perforation trash and chunks of carbolite w/proplock. Finish cleaning from 6910' to 6990' PICKING UP 3 1/2" TBG. SUPV:M.C. HEIM POOH w/ 3.5" DP. MW: 8.7 BRINE RUNNING COMPLETION. SUPV:M.C. HEIM RIH /3.5" completion w/heat trace. MW: 8.7 BRINE PUMPING FREEZE PROTECT. SUPV:M.C. HEIM Finish running completion. MW: 15.4 UNKNW 01/25/99 (C16) TD: 7150 ' PB: 6500 ' PREP RIG F/ STACKING. MW:15.4 DOILW SUPV:M.C. HEIM N/U tree and test tree & packoff to 5000%, OK. Freeze protect well. Release rig @ 1500 hrs. 1/25/99. Date 11/30/98 Well Name 1D-108 Service Type PUMPING Desc of Work RE-FRAC A-2 SANDS- U~°ming Job Num Unit 1016981828.3 AFC AK9549 Prop 18WSTF 0 Uploaded to S Supervisor JOHNS Contractor Key Person DS-YOKUM Complete [~ Successful [~ Accident E~ Initial Tbg Press 200 Final Tbg Press 700 Injury ~ Initial Int Csg Press 0 Final Int Csg Press 0 Spill E] Initial out csg Press 0 Final Out Csg Press 0 Summary PUMPED 72057 # OF 16/20 PROPPANT IN PERFS. SCREENED OUT 40 BBLS SHORT OF COMPLETE FLUSH . REVERSED GEL AND PR OUT OF WELL BORE AT TUBING TAIL AT 6479'. [Frac-Refrac] Date printed: 01128199 at: 10:27:58 Date 11/18/98 0~¢'8°ming r-~ Well Name 1D-108 Job Num 1016981828.3 Service Type ELECTRIC LINE Unit 2128 Desc of Work PERFORATE A2 SAND Supervisor LIGENZA Contractor Key Person SWS-ELMORE Complete [~ Successful [~ Accident [~] Initial Tbg Press 0 Injury ~ Initial Int Csg Press 0 Spill E~ Initial out csg Press 0 Summary PERFORATED A2 SAND FROM 6840' TO 6874' W / E J, BH 4SPF, 0 DEG PHASE. [Pert'] AFC AK9549 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01128199 at: 10:23:04 Date 11/19/98 LJ-~0ming E~ Well Name 1D-108 Job Num 1016981828.3 AFC AK9549 Prop 18WSTF Service Type PUMPING Unit 0 Uploaded to S Desc of Work FRAC A2 SAND Supervisor SCHUROSKY Contractor Key Person DS-YOKUM Complete [~ Successful E~] Accident E~ Initial Tbg Press 155 Final Tbg Press 500 Injury ~ Initial Int Csg Press 0 Final Int Csg Press 0 Spill ~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary PUMP 'A2' SAND FRAC. NEAR WELLBORE SCREENOUT. PUMPED TOTAL OF 36351 LBS PROP. 25459 LBS INTO PERFS, LEFT 10892 L PIPE. 4 PPA AT PERFS WHEN STOP PUMPING. MAX TREATMENT PRESSURE 5221 PSI. NO TIP SCREENOUT. REVERSEOUT WITH DI DOWN CASING AND OUT TBG. Date printed: 01128199 at: 10:22:36 Date 12/04/98 Well Name 1D-108 Service Type ELECTRIC LINE Desc of Work PERFORATE A 3 SAND Supervisor SCHUROSKY Complete [~ Accident ~ Injury I--I Spill ~] Summary L)~'~Eo mi n g Job Num Unit 1016981828.3 AFC AK9549 0 Prop 18WSTF Uploaded to S Contractor Key Person STEPHENSON Successful [~ InitiaITbg Press 75 Initial Int Csg Press 0 Initial Out Csg Press 0 Final Tbg Press 75 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATE 'A3' SAND 6782' TO 6800' WITH 18' X 2 1/8" ENERJET, 4 SPF 0 DEG PHASE, DOWN. TAGGED FILL AT 6845' AFTER PERF. [Per-f, Tag] Date printed: 01128/99 at: 10:21:18 Date 12/06/98 Well Name 1D-108 Service Type PUMPING ~6ming Job Num 1016981828.3 Unit Desc of Work "A3" FRAC Supervisor CHANEY Contractor Key Person Complete [~ Successful [~ Accident E~] Initial Tbg Press 350 Injury ~1 Initial Int Csg Press 350 Spill E] Initial out csg Press 0 Summary AFC AK9549 0 Prop 18WSTF Uploaded to S DS-GALLEGOS Final Tbg Press 700 Final Int Csg Press 700 Final Out Csg Press 0 "A3" SAND FRAC PUMPED 57012 LBS OF PROP INTO THE WB & PLACED 53977 LBS OF PROP IN THE FORM WI#10 PPA OF #16/20 @ PERF'S. REDUCED RATE AT THE END OF THE FLUSH FOR SO. ESTIMATE TOP OF FILL TO BE @ 6677' RKB. MAXIMUM PRESSURE 62 F.G (.68). REVERSED OUT TBG I & 1/2 VOLS W/DIESEL. [Frac-Refrac] Date printed: 01128/99 at: 10:26:01 Date 12/09/98 t. Ji~'oming [~ Well Name 1D-108 Job Num 1016981828.3 Service Type ELECTRIC LINE Unit 2128 Desc of Work PERFORATE A4 SAND Supervisor LIGENZA Contractor Key Person Complete [~ Successful [~ Accident BI Initial Tbg Press 350 Injury [~ Initial Int Csg Press 0 Spill [~ Initial Out Csg Press 0 Summary SWS-ELMORE PERFORATED A4 SAND FROM 6752' TO 6722' W/EJ BH 4 SPF. TAGGED FILL AT 6772'. [Perf] AFC AK9549 0 Final Tbg Press 200 Final Int Csg Press 0 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01/28/99 at: 10:20:49 Date 12/10/98 ~bming ~ Well Name 1D-108 Job Num 1016981828.3 AFC AK9549 Prop 18WSTF Service Type PUMPING Unit 0 Uploaded to S Desc of Work FRAC THE A 4 SAND Supervisor RIGGS Contractor Key Person DS-GALLEGOS Complete [~ Successful [~ Accident r~ Initial Tbg Press 375 Final Tbg Press 1150 Injury E~] Initial Int Csg Press 375 Final Int Csg Press 1150 Spill [-'-] Initial Out Csg Press 0 Final Out Csg Press 0 Summary PUMPED A 4 SAND FRAC PER PROCEDURE WI70# HEC GEL @ 30 BPM PUMPED 2PPG 4PPG RAMPED TO 10 PPG PROPANT. PUMPE 104,019 LBS OF 16/20 PROP W/103,195 LBS OF 10 PPG TO PERFS LEFT 800 LBS IN PIPE EXPECT TAG +- TOP PERF AT 6700' DID NO SCREENE OUT. AVG TREATING PRESS 4300PSI, MAX PRESSURE 5600 PSI. NO TIP SCREEN OUT. HES CAME IN AT END OF JOB AND THAT THEY DID NOT PUT ANY SURFACTANT IN JOB. JOB IS A DO OVER [Frac-Refrac] Date printed: 01/28199 at: 10:25:25 Date 12/14/98 U~0ming ~'] Well Name 1D-108 Job Num 1016981828.3 Service Type PUMPING Unit 2128 Desc of Work REFRAC THE A4 SAND Supervisor RIGGS Contractor Key Person DS-GALLEGOS Complete [~ Successful [~ Accident E~ Initial Tbg Press 340 Injury ~] Initial Int Csg Press 340 Spill ]---] Initial Out Csg Press 0 Summary AFC AK9549 0 Prop 18WSTF Uploaded to S Final Tbg Press 400 Final Int Csg Press 400 Final Out Csg Press 0 REFRAC THE A4 SAND. PUMPED THE FRAC PER PROCEDURE USING 70# HEC GEL AND 3 % KCL WATER 30 BPM. PUMPED 110,115 PROP WITH 109, 370 # AND 10 PPG IN FERFS, LEFT 745 # PROP IN PIPE EXPECT TAG @ OR NEAR THE TOP PERF 6722'. THE MAX PRESSURE PUMPED ON JOB WAS 4642 PSI. DID NOT GET TIP SCREEN OUT, DID NOT SCREEN OUT AT ALL. PUMPED FLUSH AND REVERSED OUT TBG. W/DIESEL. [Frac-Refrac] Date printed: 01128199 at: 10:20:27 Date 12/22/98 Well Name 1D-108 Service Type ELECTRIC LINE Uj:yebming Job Num Unit 1O16981828.3 Desc of Work PERF"B" SANDS Supervisor JOHNS Contractor Key Person Complete ~ Successful [~ Accident ~ Initial Tbg Press 400 Injury [~ Initial Int Csg Press 0 Spill [~] Initial Out Csg Press 0 Summary CYCE AFC AK9549 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED "B" SANDS INTERVAL 6,656' TO 6,686' RKB WITH 2-1/8" ENERJET BH . TAGGED FILL AT 6710' RKB. [Frac-Refrac, Perf] Prop 18WSTF Uploaded to S Date printed: 01128199 at: 10:18:55 Date 12/24/98 U~Ebming ~ "--~ Well Name 1D-108 Job Num 1016981828.3 AFC AK9549 Prop 18WSTF Service Type PUMPING Unit 0 Uploaded to S Desc of Work FRAC THE B SAND Supervisor RIGGS Contractor KeyPerson DS-YOKUM Complete [~ Successful [~ Accident ~ Initial Tbg Press 270 Final Tbg Press 720 Injury ~ Initial Iht Csg Press 18 Final Int Csg Press 500 Spill E~ Initial out csg Press 0 Final Out Csg Press 0 Summary PUMPED THE B SAND FRAC PER PROCEDURE WI70 # HEC GEL @ 20 BPM AND 2700 PSI. MAX. PRESSURE ON JOB WAS 6244 PSI. P 70, 731 LBS OF 16/20 PROPANT VV/69, 714 AND 9 PPG IN PERFS. LEFT 1,017 LBS IN PIPE. REVERSED OUT, EXPECT TAG AT TOP PEP, 6656' NO TIP SCREEN OUT. [Frac-Refrac] Date printed: 01128199 at: 10:18:42 Date 12/27/98 U'~ming Well Name 1D-108 Service Type ELECTRIC LINE Desc of Work PERFORATE "D" SANDS Supervisor JOHNS Complete [~ Accident E~] Injury E] Spill ~ Summary Successful Job Num Unit 1016981828.3 Contractor Key Person ALLDREDGE InitiaITbg Press 200 Initial Int Csg Press 0 Initial Out Csg Press 0 PERFORATED "D" SANDS 6590' RKB TO 6620' RKB' . TAGGED SAND TOP AT 6643' RKB. [Perf] AFC AK9549 0 FinaITbg Press 300 Final Int Csg Press 0 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01128199 at: 10:17:41 Date 12/28/98 Ui:;~-0ming E~ Well Name 1D-108 Job Num 1016981828.3 AFC AK9549 Prop 18WSTF Service Type PUMPING Unit 0 Uploaded to S Desc of Work FRAC D SAND Supervisor RIGGS Contractor Key Person DS-YOKUM Complete [~ Successful Accident E~ Initial Tbg Press 498 Final Tbg Press 900 Injury E~ Initial Int Csg Press 406 Final Int Csg Press 800 Spill E~ Initial out csg Press 0 Final Out Csg Press 0 Summary PUMP D SAND FRAC PER PROCEDURE W/70 # HCE GEL @ 20 BPM AND 2700 AVG. PRESS. MAX PRESSURE OF 6248 PSI. PUMPED LBS OF 16/20 PROPANT W/99,521 LBS AND 10 PPG IN PERFS. LEFT 1728 LBS IN PIPE. EXPECT TAG @ + -6500' JUST ABOVE TOP PERF.GOT TIP SCREEN OUT [Frac-Refrac] Date printed: 01128199 at: 10:17:29 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-108 (Permit No. 98-187) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the comPletion on West Sak 1D-108. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad Kuparuk Unit Kuparuk 1D 1D-I08 Job No. AKMMS0393, Surveyed: 3 October, 1998 NOV 1 ? 1998 Anchorage S UR VEY REPORT 4 November, 1998 Your Ref: API-500292292100 KBE- 1'/2. f' Surface Coordinates: 5959738.82 N, 560490.57 E (70° rS' 02.0450" N, 149° 30' 36.2775" W) ORIGINAL sper~r~-sun D I:! I I-- I- I N I~i S I~ I~l,,V I C Ei S Survey Ref: svy91 Sperry-Sun Drilling Services Survey Report for 1D-108 Your Ref: API-500292292100 Job No. AKMMS0393, Surveyed: 3 October, 1998 Kuparuk Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -112.10 0.00 121.00 0.000 0.000 8.90 121.00 202.74 1.400 282.440 90.63 202.73 291.79 4.840 301.000 179.54 291.64 382.31 8.650 315.160 269.42 381.52 473.66 12,960 324.040 359.14 471.24 563.45 18.560 325.180 445.52 557.62 652.84 24.750 330.010 528.56 640.66 742.95 30.470 333.830 608.39 720.49 834.28 35.590 334.490 684.93 797.03 925.62 41.500 335.480 756.34 868.44 1016.94 48.410 336.820 820.92 933.02 1108.28 55.240 336.350 877.34 989.44 1198.23 59.460 336.410 925.86 1037.96 1289.66 60.810 337.740 971.39 1083.49 1470.62 61.910 337.560 1058.12 1170.22 1745.00 62.650 340.590 1185.78 1297.88 2033.87 64.120 340.580 1315.18 1427.28 2317.87 65.150 341.040 1436.84 1548.94 2505.77 64.710 338.770 1516.47 1628.57 2788.75 64.810 338.580 1637.14 1749.24 3075.52 64.570 338.370 1759.73 1871.83 3360.71 65.220 338.290 1880.73 1992.83 3645.52 62.790 337.890 2005.55 2117.65 3929.83 63.460 337.030 2134.08 2246.18 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Dogleg Rate (°/100ft) 0.00 N 0.00 E 5959738.82 N 560490.57 E 0.00 N 0.00 E 5959738.82 N 560490.57 E 0,000 0.22 N 0.98W 5959739.03 N ' 560489.59 E 1.713 2.39 N 5.26W 5959741.16 N 560485.29 E 3.976 9.18 N 13.34W 5959747.89 N 560477.16 E 4.562 22.35 N 24.20W 5959760.98 N 560466.19 E 5.044 42.25 N 38.28W 5959780.76 N 560451.95 E 6.246 70.16 N 55.78W 5959808.53 N 560434.23 E 7.201 107.04 N 75.30W 5959845.25 N 560414.41 E 6.642 151.84 N 96.97W 5959889.87 N 560392.38 E 5.620 203.40 N 121.00W 5959941.24 N 560367.94 E 6.505 262.40 N 147.03W 5960000.02 N 560341.43 E 7.637 328.24 N 175.56W 5960065.64N 560312.37 E 7.488 397.62 N 205.90W 5960134.77 N 560281.48 E 4.692 470.64N 236.78W 5960207.54 N 560250.01 E 1.942 617.53 N 297.17W 5960353.94 N 560188.44 E 0.614 844.37 N 383.88W 5960580.07 N 560099.90 E 1.014 1087.94 N 469.73W 5960822.94 N 560012.10 E 0.509 1330.29 N 554.07W 5961064.61N 559925.81E 0.391 1490.12 N 612.54W 5961223.96 N 559866.06 E 1.119 1728.56 N 705.62W 5961461.64 N 559771.06 E 0.070 1969.72 N 800.74W 5961702.03 N 559674.00 E 0.107 2209.72 N 896.10W 5961941.25 N 559576.71 E 0.229 2447.21N 991.61W 5962177.96 N 559479.29 E 0.862 2681.43 N 1088.83W 5962411.40 N 559380.19 E 0.358 Vertical Section (ft) 0.00 0.00 0.56 4.17 13.48 29.75 53.45 85.87 127.36 177.01 233.81 298.25 369.99 445.67 524.94 683.75 926.57 1184.59 1440.94 1611.04 1866.99 2126.23 2384.48 2640.45 2894.03 Kuparuk 1 D Comment Continued... 4 November, 1998 - 11:20 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-108 Your Ref: API,500292292100 Job No. AKMMS0393, Surveyed: 3 October, 1998 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4115.13 63.080 337.280 2217.42 2329.52 2833.95 N 1153.08 W 5962563.39 N 559314.71 E 4310.30 62.370 340.550 2306.88 2418.98 2995.76 N 1215.49 W 5962724.70 N 559251.00 E 4495.28 65.860 339.900 2387.62 2499.72 3152.34 N 1271.80 W 5962880.82 N ' 559193.44 E 4786.79 62.850 340.660 2513.77 2625.87 3399.69 N 1360.48 W 5963127.44 N 559102.77 E 5070.03 64.920 339.810 2638.44 2750.54 3639.01 N 1446.49 W 5963366.06 N 559014.83 E 5357.61 65.880 336.590 2758.18 2870.28 3881.73 N 1543.60 W 5963608.00 N 558915.77 E 5641.10 64.030 337.050 2878.19 2990.29 4117.82 N 1644.70 W 5963843.26 N 558812.77 E 5736.81 60.230 335.950 2922.92 3035.02 4195.40 N 1678.42 W 5963920.57 N 558778.43 E 5830.46 56.570 340.730 2972.01 3084.11 4269.46 N 1707.90 W 5963994.39 N 558748.35 E 5926.72 51.680 338.550 3028.40 3140.50 4342.57 N 1734.99 W 5964067.28 N 558720.68 E 6022.33 46.350 339.360 3091.09 3203.19 4409.90 N 1760.91 W 5964134.40 N 558694.21 E 6114.13 40.810 340.200 3157.56 3269.66 4469.25 N 1782.80 W 5964193.57 N 558671.85 E 6207.89 35.210 341,020 3231.41 3343.51 4523.68 N 1801.99 W 5964247.85 N 558652.23 E 6305.68 30.560 341.370 3313.51 3425.61 4573.92 N 1819.11 W 5964297.95 N 558634.70 E 6399.88 25.730 342.040 3396.54 3508.64 4616.09 N 1833.07 W 5964340.01 N 558620.40 E 6495.28 22.970 342.400 3483.45 3595.55 4653.54 N 1845.09 W 5964377.36 N 558608.08 E 6685.22 20.930 343.230 3659.61 3771.71 4721.36 N 1866.08 W 5964445.01 N 558586.54 E 6874.22 19.670 342.280 3836.87 3948.97 4783.99 N 1885.51 W 5964507.47 N 558566.61 E 7084.42 18.800 342.330 4035.33 4147.43 4849.96 N 1906.55 W 5964573.27 N 558545.03 E 7150.00 18,800 342.330 4097.42 4209.52 4870.09 N 1912.97 W 5964593.36 N 558538.46 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.380° (29-Sep-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 338.170° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7150.00ft., The Bottom Hole Displacement is 5232.33ft., in the Direction of 338.555° (True). Dogleg Rate (°~'~OOft) 0.238 1.533 1.913 1.059 0.779 1.071 0.669 4.098 5.844 5.401 5.611 6.068 5.997 4.759 5.138 2.897 1.086 0.689 0.414 0.000 Vertical Section (ft) 3059.50 3232.93 3399.21 3661.80 3915.94 4177.37 4434.12 4518.68 4598.39 4676.33 4748.47 4811.71 4869.37 4922.38 4966.71 5005.95 5076.71 5142.06 5211.13 5232.21 Kuparuk'lD Comment Projected survey Continued... 4 November, 1998 - 11:20 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-lO8 Your Ref: AP1-500292292100 Job No. AKMMS0393, Surveyed: 3 October, ~998 Kuparuk Unit Kuparuk 1 D Comments Measured Depth (ft) 0.00 7150.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4209.52 4870.09 N 1912.97 W Comment Tie-on Survey Projected survey 4 November, 1998 - ~1:20 - 4 - DriflQuest 4/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12491 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date Color Sepia Floppy Print Disk W SAK 1D-108 99159 USIT 981006 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: C] F! I I-.I- I N CS 10-Nov-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 D-108 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 7,150.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company rt I:t I I_1_ I IM [~ WELL LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs November 4, 1998 1D-108, AK-MM-80393 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 11)-108: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22921-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22921-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 o IN I I_1-1 ~ G WELL LOG TRANSMTI~AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-108, AK-MM-80393 October 28, 1998 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22921-00 5631 Silverado Way, Suite G - Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 23, 1998 Tom McKav Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1D-108 ARCO Alaska, Inc. Permit No: 98-187 Sur Loc: 74'FSL, 596'FEL, Sec. 14, T1 iN, R10E, UM Btmhole Loc. 311'FNL, 2555'FEL, Sec. 14. T11N, R10E, UM Dear Mr. McKav: 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-108. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D.must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by co~mmh~g the ~on,gcSroleum field inspector on the North Slope pager at 659-3607. David W. Joh/~t,,0,n ~ Chairman ~ BY ORDER OF THE COMMISSION dlffEnclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ~ ALASI~A-~OIL AND GAS CONSERVATION COMMI~iON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll lb Type of Well Exploratory StratigraphicTest Development Oil X Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RED 4]', ?ad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650,' ALE. 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 74' FSL, 596' FEL, Sec. 14, T1 IN, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 496' FNL, 2483' FEL, Sec. 14, T11N, R10E, UM 1D-108 #U-630610 At total depth 9. Approximate spud date Amount 311' FNL, 2555' FEL, Sec. 14, TllN, R10E, UM 9/28/98 $200,000 12. Distance to nearest 13. Distance to nearest well t4. Number of acres in property 15. Proposed depth (MD and 'P/D) property line ID- 109 7255' MD 311' @ TD feet 14.7' @ 250' feet 2560 4297' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 64.44° Maximum surface 1440 psig At total depth (-rVD) 1892 psig 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) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 7214' 41' 41' 7255' 4297' 741 Sx Arcticset IIIL & 345 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: ,~ueeaSvUe~t~cdal :eeee: Plugs (measured, 0 R IG!N A L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ISnt~erframC~diate R E C ElY E D Production Liner Perforation depth: measured S EP I ! 1998 true vertical 20. Attachments Filing fee X Property plat BOP Sketch X Diverter~kt~l~¢I' ~ ._~~mmngprogram X An Ddlling fluid program X Time vs depth plot Refraction analysis Seabed report 2 5.050 requirements X 21. I hereby certify_ that the foregoipg is tree and;correct to thebest~.~.~ .,~ ~¢,~°f my knowledge ~.... ~¢. -'~/~- ~"~-- /' ¢"~¢',,.~f,~ O/' ¢.,,-' ¢.,~../~ SigneJ"~~¢..~ ~- ~ j~)~¢~/,(~ ,~/'Cor~missionTitleuse Only Shallow Sands Team Leader Date---- """7~' Permit Number_ _ I APl number I ! q -18 / 15o- o,q- ~zRz ( IAppr°valdate ~""~'~"¢''~;~ ISeec°verletterf°rother requirements Conditions of approval Samples required Yes ~ Mud Icg req~red Yes Hydrogen sulfide measures Yes ~~ ]~'~tional survey required ~ No Required working pressure for DOPE 2M /(3M) 5M 10M 15M Other: dl-lgJrla, SJglq~o d~,, by orderof ¢'"" Approved by David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Sept 10, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-108 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designated as a production well using a single 7 5/8" casing string, with 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-108, such as shallow gas. There have been ten (10) Kuparuk wells and (23) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is September 28, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely, Operations Drilling Engineer CC: West Sak 1D-108 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 General Procedure: Drill and Case Plan for West Sak 1D-108 (A3) Frac-for-Sand Control Producer 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9 7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7 5/8" 29.7# L80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: Weatherford Gemaco Stage Collar will be placed in the 7 5/8" casing +200' MD below the base of the Permafrost. 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Rig up and run workstring to TD. Circulate the well with seawater and freeze protect the upper +2000' with diesel 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig 1 D-108 (A3) Page I SG,09/10/98,vl Completion Plan for West Sak 1D-108 (A3) ~3 ~ ~ ~-, Frac-for-Sand Control Producer ~~~ ~" ~ ~ ~ Four-Stage, Frac-for-Sand Control Completion (Off Rig Fracs) ~'~ ~[ ~ ~0~;~ General Procedure: , 'J~.~,,~ Off ~; ~as CODS. Anchorage Well Preparation 1. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. 2. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on Icg results and final completion design strategy. Stage 1 3. Rig up thru-tubing peri guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with per guns, and position guns on depth. 4. Perforate Stage I overbalanced, and POOH with E-line. 5. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage I interval. 6. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage I from Stage 2 to follow. Pressure test sand plug as required. 7. RIH with slickline and confirm sand top above Stage I perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 8. Rig up thru-tubing peri guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with per guns, and position guns on depth. 9. PeRorate Stage 2 overbalanced, and POOH with E-line. 10. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 11. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. 12. RIH with slickline and confirm sand top above Stage 2 peris. Use CTU as required to jet sand plug top to desired PBTD. Stage 3 13. Rig up thru-tubing per guns for Stage 3 frac job which includes the West Sak A4 and B sands. RIH with per guns, and position guns on depth. 14. PeRorate Stage 3 overbalanced, and POOH with E-line. 1 D-108 (A3) Page 2 SG,09/09/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Deadstring, Clean Out Well, Run ESP and Production Tubinq MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. Pull back pressure valve. Pull tubing hanger and circulate well to clean brine as required. TOH and lay down deadstring. Pick up rock bit and casing scraper and TIH with workstring. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. Circulate well to clean brine. TOH with workstring. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 21. 22. 23. Pull 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 1 D-108 (A3) Page 3 SG,09/09/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1 D-108 (A3) Page 4 SG,09/09/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-108 (A3) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A 7 5/8" surface / production casing string will be run to total depth (TD). This combination surface / produ'ction casing will be cemented to surface. A Weatherford Stage Collar will be placed at approximately 1700' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-108 (A3) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1 D-108 (A3) Page I SG,09/09/98,v.1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,684' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP - (4113ft)(0.46-0.11 psi/fi) - 1440 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7' 6/8" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The ? 5/8" 29.7# LB0 BTC casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Drillinq Area Risks: Drilling risks in the West Sak 1D-108 (A3) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-108 (A3) is 1D-109. As designed, the minimum distance between the two wells would be 14.7' at 250' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-108 (A3) surface casing will be filled with diesel and/or non-freezing brine after cleaning out the 7 5/8" casing and prior to the drilling rig moving off of the well. 1 D-108 (A3) Page 2 SG,09/09/98,v. 1 3-1/2" Production Tubing 9.3# L-80 EUE 8RD-Mod Power Cable for ESP Centrilift West Sak 1 !)-108 (A3) Producer Well Four (4) Stage Frac-for-Sand Control Completion 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' MD below permafrost) Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Amtic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) ESP Motor Section Centrilift D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 7255' MD / 4297' TVD) A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, inc. ASG, 09/09/98, v.2 1 D-108 Cement Volumes Surface Hole Surface Casing Casing Depth Casing OD Casing Weight Hole Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' TVD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess Class Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time !hours i% Class Additive 1 Additive 2 Additive 3 Additive 4 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours 583 741 bbls sacks 73 345 bbls sacks 350 350 7O0 1050 14-00 1750 2100 2450 I--- 2800 I 3150 3500 3850 4200 4550 RCO Alaska, Inc.' -"l For: GOLDBERG Structure : Pod lO Well : 108 ~,ws,o-ms/~v,¢,.~. [ Field : Kuparuk River Unit Location : North Slope, Alaska] <- Wes* (feet) 21 O0 1750 1400 1050 700 350 0 350 I [ [ [ ~ , [ [ ] ! t , i ~ ~ i 5250 [ TO LOCATION: ] [ 311' FNL, 2555' FEL[ ~ ..... . / SEC. 14 TllN RIOE ~ULLV21¢~u- u°sm9 r~t / ' ' I <~¢~Base West Sak Sands /' '~. ~TARGET - West Sek A5 ~ ~ )Top Wes[ Sok Sends ~EndAngle Drop 338.17 AZIMUTH ~~'op u~u 5074' (TOTARGET) ~eg[nAsgleDrop · ~4200 · **Plane of Proposal*** ~ - - ~ ~ ~ TARG~ LOCATION: [ ~ 5850 } 496' FNL, 2485' FELI ~ I sEc~4, T~N. R~OE I ~ TARG~ ~ ~ 5500 . ~0=5829 TMB=6746 DEP=5074 ~ ~ NORTH 4710 ' ~~ J3~50 WEST 1887 2~00 . RK~ ELEVATION: 112' ~19.95 ~ z,~O ~25.77 DLS: 6.00 deg per 100 ft k31.65 % 37.57 ~ [1750 M 55.41 TMD=1351 DE =5 6 ~o~ P 4 Bose Permafrost 14C0 MAXIMUM ANGLE ~ ~ ' BEGIN ANGLE DROP WD=3012 TM0=569 64.32 g2 DLS' 6 00 350 de~ per i00 ft 28.32 END ANGLE DROP ~0=3500 T~0=6389 DEP=~935 TARGET- A3 T%D:3~g,- Z:"?~6 DEP:50?~ 'I'AKG~'I' A!N UL~ c s PT ' 4~3 DEG ~ - s w~=~9, ~s=,~ss ~=s2,a i i i i i i i i i i i i i ii i i ii i i i ii i I i i i i t i 1 ;50 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5800 Verffcol Section (feet) -> Azimuth 338.17 with reference 0.00 N, 0.00 E from slot #108 c,~t~ ~y ~;.~. For: GOLDRERG Oale plotted : 8-$ep-98 F~ot Reference ~s ~ 10-10~/~ V~. ~5. Ca~d;nat~ are ;n fe~ r~ference slot ~108. T~e ve~ical 0epics are ref~ence ~8 (Pork~ ~2~)- [~k c o x 1 c7 ol aska, In r 3tructure : Pod 10 Well: 108 I Field : Kuparuk River Unit Locefion : North Slope, Alask A <- West (feet) 260 240 220 200 180 160 14{3 120 100 80 60 4(3 20 0 20 40 60 I I [ I I I I I I I I I I I [ I I I I I I I I I I t I I ; I zoo "~ ~ ooo ", "',,~ "',, - ~ ,oooi 2~o ',,, \ ",, ', k ~ 2000 \,,. 1500k,, ",, ",, ~ 900 \ k2200 260 11 O0 ",,. N '"' '" i \ ',,,, \ ',,, ',,,, ', ~, ,~oo \ ; ' [ 2~00 220 \ '",.14-00~ ",, '", ! ~ ] / N '",,, .... ~ ", \ i800 ~. 1800 ~ / ~oo ",,, ~, ",,,~oo , ! \ ~ ,,,,,, ~oo~ ~ "N N 1200 1000'~,,, ~ \,, \ '", ~.1400 ~ / ~o r;,, ~ x,, ",, ~zoo\ '",, '"' \ ~, ~oo 2000 ~ ,~,o ....... ~ k "'"'., \ '"', ", ", ,¥';oo ,,~o ,~o_ ,,,,,~ooo N\ ",, \" ~ " -* ,"i ,' '"'"",,,,,,,,,,,,,,,,. 'i:° ,,:,ii ~o ~Zo ,, · ',,, ,, --....~ ~oo,.,, ,.,,, ,oo '"'",,,,, N, ,,,,,~,o% .., ,, %....~oo~..~.~oo7~ "'",, '"",, "'", '"',, ..-"' ,,' .,,.,x,N ",.,. \ '.,,~oo x~oo e-'~oo ...." ~° '", \N '", \ '" "' -"'~°°/'i~oo '"',~oo\* .oo'.,. .",,',, ~ ...... ' /~oo "-C~ \N "',,., oo& ",,, ",, ~o ~;x "".,. ,oooNNJ ~oo '"., N '". '" e'" ~7/_ N.?Z. ,., ~uuu N N ", ~ ', " .... ?oa / /1 "-. '-, ~ 'x \. X \, ,~ ouu ./ / '-. ',. ',, ~ 600 ', '--,,,,.,... "",,,... ,,,, ~o ~.. -.....~.o.~. '"'-.,...~oo >Y,~oo .,,,,..,,~oo.~..~:,,..., 40 ~ '""-.. %-. ~ 1 ~soo 500 260 240 220 200 180 1 60 140 120 1 O0 80 60 40 20 0 20 40 60 <- Wesf (feel) 320 3CO 280 260 240 220 2OO 18O 16O 140 i 2o IC0 80 6O 4o 20 40 6O Z 0 f~ For: GOLDBERG Dote clotted: 8-Se~-g8 Referencl iB W~ 10-108/A,3 V~, ~5. C~d/~tea ore ;n fe~ reference al~[ ~1~8. Oep~s ere r~ence ~8 (Porker ~243). RCO A1 aska, Inc. Structure : Pad lO Well: 108 Field : Kuparuk River Unit Location : North Slope. Alask 26oo 2500 2400 2300 2200 2100 2000 1900 A I 18oo 1700 ¢' 1600 Iii 0 7 1500 1400 1300 1200 1100 1000 <- West (feet) 600 1500 1400 1,500 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 ~ '~ 2200 2700 ", ',, '~ 2400 28oo '\. 4800 "\, 2600 2500 ',,\,\ · \ 2400'~'\,, \, 2300~'\ 2100 '", 2000 4700 ~ 2300 4600 , '~ 2200 4500 ', '\'\ 4400 2200~, ~ 210o \\\ ~ 1900 4300 230O \ , 2100~" &200 ~ 2000 ', x,\, 4200 \ \ ~100 \ '. k 1800 "~ 2000 ' 4000 \ 4100 - 2200 \\, 3900 "\\ "".. 2000~\ 3800 \ "'.. "\ 3700 ~ 4000 ",. ",, 3600 \, '" \, 3500 "~ 1900 \'~ 1700 ' 2100 '\', 3400 ' "',....\. \'.,.,, 390C 1906~" 3300 '\ \, '"'..... '\',\ 3200 \'\ 380 ~ k 3100 "~ 1600 '",,,, 2000 \ 1800~,, ",..... ,\\ 3000 ',,,.,, 3700 '.~ '\\\, 2900 3600 '"', 1900 "\ 900 800 7O0 1800 66b0 64q0 6~oo 1\00 6~00 1700 ~8oo ~700 5600 5500 2900 2500 2800 2400 2700 2300 2000~ - 2200 2~oo ~ i 2000 2400!! ~oo 1800 ~ 1800 1700 1 7OO 1600 1500 ! 600 1400 i 300 ! 500 1200 1too 10oo 9OO 800 54O0 ", 1700~,, 2800 ',. 1500 , \ 5300 /z~...2400 '"... ',, '\,, ~~ ,, ,,, =oo ,, ~oo i.~ -. ,,, ',, ,\ k 5100 43°q2 ',,7-.....,....%~ '"'\ 1800 ",~ ~2600 "\ 3400 V000 i~ "-.... N~300 ,,,. . 1~00,,\ \ ;, 1400 X 4900 1400 '"... ~ '". k ',. ~ 2500 ',, i \4800 ~oo--... N '-.,,\ ",, k ',,,, ~oo\ ~oo -....... % .,,..1~',, .~oo',, ,',,.~ ~oo '"... "'.. 2200 '". k '"' \ ", ;20 ,~ .~. 17~'~"-.. ~ "..,,,,,,x%~700 1, ,,\,~2500 % 1300 4500 '"" ", 2200", i i i i i i i i i i i I i i i I I i i i i i 1600 1,500 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 .300 200 1 O0 0 <- West (feet) 700 Z O cr~t~ b~ ~.ch For: GOLDHERG Oet¢ olokted: 8-Sep-98 ~e~ Reference ;~ '~ 1D-108/~ Ve~. ~5. Ca~di~t~ are in fe~ reference ~l~t r~e Ve~e~ Oep~s are ref~ence ARCO Alaska, Structure : Pad 1D Field : Kuparuk River Unit Inc. Well : 108 Location : North Slope, Alaska 4300 4200 4100 4O00 3900 3800 3700, 3600 3500 I ~ 3400 ,-I-- .q_. '---' 3300 -I--- k_ 0 3200 Z 3100 3000 2900 28O0 2700 26O0 2500 2400 <- West (feet) 2100 2000 lgO0 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 " 4200 · '\, 6900 ~ 41 O0 '""'\, I~ 4000 ',, 6700 2900 , q 3900 \ \ 3900 ~ 3700 6500 ,,, \ 3800 , ; 3500 J F ,,,,, 3600 6100 r-, ~-'r~ ~1 qC~_'''~-~,~ ~ 'l, 3100 ~ 2700 ;::: i-' ?'' q !.:? .u ~.: \ 'al~ska 0]] a Gas Cons. gr~ohoraoe ,,\, \ ; ,.., " 5700 \ '~, 2500 ',, ssoo "\' ~ 310 o \, ,\ '\ 270O ~ ,, ",, ; 3000 ",, ~ s3oo % ~t, 2900 ~ ..... ~_4~1_ O0 3900 '3700 ,% ........ ,oo : oo "'"'- 250O '"-,..2~00 "\ 2700 ',,, '\ '",, 2500 ,, ,"¢ ¥ :¢i° ' 2400 i i I i i i i I I i i i i i i i i i I 2100 2000 1900 1800 1700 1600 1500 1400 1,500 1200 1100 1000 900 800 700 600 <- West (feet) 3500 I 3400 Z O 3300 ~- 3200 ~ Structure : Pod lO Well: Field : Kuporuk River Unit Location : North Slope, Alask WELL PROFILE DATA ..... Pd~ ..... UD ;~¢ OV TVO ,'e~.m £<~t V..~ 0~q/1~3 0.~ 0,~ 0.~ 0.~ 0.~0 0.00 0.~ 0.~ 250.~ 0.~ ~.~ 2~.~ O.O0 O.O0 0,~ 0.~ Turn to Terg~ 400.~ g.~ ~05.~~gg.~ 6.7¢ -9.63 g.8¢ 5.~ ~d~um 1~1.~8 64.443~.75113~.42 4g0.05 -246.02546.~~.~ ~e~um ~4 ~5~01 64.44~30,75 ~l 1.51 4144.77 -- 1567.~ ~67.57 0.~ 6~8.75 2~ 5~,753~gg.sg 4~.08-18~.~ 4934.62 ~ ID--~ ~ 2 &7~627 2~ 338.75 ~2g.~ 4710.27 -1887.11 5074.~1 0.~ H~ 7054.~ 25.~ 3~.754113.~4822.~2 --1951.01 5194.~ 0.~ E~d g Ho~ 7254.~ 23.~ 3~.7542~7.10 4895.46 --19~,34 5273,~ 0.~ 35O 540 330 TRUE NORTH 0 10 2O 310 520 3O 4O 5O 300 6O 290 7O 280 8O 270 ;0 150 1 9O 260 100 250 1!0 240 .... h zoo 2~0 (ff~ .............. i~oo 22O 2~-'" 200 120 % 190 180 Normal Plane Travelling Cylinder- Feet 7O 150 140 11oo % All depths shown ore Measured depths on Reference Wel', ARCO Alaska, Inc. Pad 1D 108 slot #108 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT Bake~ Hughes INTEQ Your ref : WS 1D-108/A3 Vets. #5 Our ref : Drop2218 License : Date printed : 8-Sep-98 Date created : 17-Apr-97 Last revised : 8-Sep-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 2.044,w149 30 36.284 Slot Grid coordinates are N 5959738.676, E 560490.359 Slot local coordinates are 74.00 N 596.00 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Obi ect wellpath PMSS <377 - 6224*>,,134,Pad 1D PMSS <0 - 6472*>,,131,Pad 1D PMSS <467 - 5802*),,132,Pad 1D PMSS <O-4414~>,,121,Pad 1D PMSS <O-4530'>,,120,Pad 1D PMSS <O-4515~>,,119,Pad 1D PMSS <O-4590'>,,118,Pad 1D PMSS <0-5205'>,,liT,Pad 1D PMSS <0-4850'>,,109,Pad 1D PMSS <O-~126~>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <1957-5265~>,,133,Pad 1D PMSS ¢0-5015'>,,135,Pad 1D PMSS <O-5047'>,,124,Pad 1D TOTCO Sur~rey,,WS-8,Pad 1D PGMS <O-8365'>,,1,Pad 1D PGMS <O-8930~>,,5,Pad 1D PGMS <O-8610~>,,6,Pad 1D MSS <3311-8200*>,,7,Pad 1D PMSS <556-7024~>,,9,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D PMSS <O-5462~>,,129,Pad 1D PMSS <O-4778'>,,130,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 7432~>,,127,Pad 1D PGMS <0-9783~>,,2,Pa~ 1D PGMS <O-7502~>,,4,Pad 1D PMSS <O-5142'>,,115,Pad 1D Closest approach with 3-D Minimum Distance Last revised Distance M.D. Diverging 3-Aug-98 584.3 250.0 23-Jul-98 495.0 100.0 6-Aug-98 510.0 100.0 2-Jun-98 254.7 250.0 2-Jun-98 239.8 250.0 2-Jun-98 224.5 250.0 2-Jun-98 180.0 100.0 2-Jun-98 164.0 270.0 2-Jun-98 14.7 250.0 2-Jun-98 29.8 440.0 2-Jun-98 56.4 420.0 2-Jun-98 522.7 270.0 2-Ju~1-98 600.0 100.0 2-jun-98 344.2 270.0 21-May-98 677.0 100.0 10-Dec-97 93.3 800.0 13-Nov-97 317.1 0.0 13-Nov-97 437.2 0.0 6-Nov-97 557.0 250.0 29-Apr-98 210.0 250.0 28-Apr-98 630.0 100.0 2-Jun-98 464.4 250.0 2-Jtul-98 480.0 250.0 1-Jul-98 374.4 270.0 6-Jul-98 388.7 270.0 4-Aug-92 30.6 500.0 4-Aug-92 197.1 100.0 2-Jun-98 133.0 366.7 method from M. D. 250.0 100.0 7140.0 250 0 250 0 250 0 100 0 270 0 250 0 440.0 420.0 270.0 100.0 270.0 100.0 7254.8 0.0 0.0 250.0 6400.0 100.0 250.0 250.0 270.0 270.0 500.0 100.0 366.7 PMSS <0 - 6580'~,,128,P~1D PMSS <291 - 5795t>,,125,Pad 1D PGMS <O-8070~,,3,Pad 1D PMSS <0 - 5445'~,,122,Pad 1D PMSS <0 - 6270t),,114,Pad 1D PMSS<0-?045~>,,111,Pad 1D GSS <0-173~>,,123,Pad 1D PMSS <287-6055~,,123,Pad 1D GSS <0-175t>,,116,Pad 1D PMSS <290-???>,,116,Pad 1D 17-Aug-98 19-Aug-98 13-Aug-98 29-Aug-98 2-Sep-98 3-Sep~98 4-Sep-98 8-Sep~98 8-Sep-98 8-Sep~98 404.8 358.2 76.7 270.0 120.0 45.0 285.0 285.0 150.0 149.0 270.0 250.0 100.0 100.0 200.0 100.0 100.0 100.0 270.0 250.0 270.0 250.0 100.0 100.0 200.0 100.0 100.0 100.0 270.0 ARCO Alaska, Inc. Pad 1D 108 slot #108 KuparukRiver Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : WS 1D-108/A3 Vets. #5 Our ref : prop2218 License : Date printed : 8-Sep-98 Date created : 17-Apr-97 Last revised ~ 8-Sep-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 2.044,w149 30 36.284 Slot Grid coordinates are N 5959738.676, E 560490.359 Slot local coordinates are 74.00 N 596.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,108 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 0,00 0.00 0.00 N 0.00 E 100.00 0.00 305,00 100.00 0.00 N 0.00 E 200.00 0.00 305,00 200.00 0.00 N 0.00 E 250.00 0.00 305.00 250.00 0.00 N 0.00 B 350.00 6.00 305.00 349.82 3.00 N 4.29 W 400.00 9.00 305.00 399.38 6.74 N 9.63 W 500.00 14.27 319.67 497.32 20.64 N 24.03 W 600.00 19.95 326.34 592.86 44.25 N 41.47 W 700.00 25.77 330.11 684.98 77.32 N 61.77 W 800.00 31.65 332.57 772.65 119.49 N 84.71 W 900.00 37.57 334,31 854.92 170.30 N li0.04 W 1000.00 43.51 335.65 930.88 229.18 N 137.47 W 1100.00 49.46 336,72 999.71 295.51 N 166.71 W 1200.00 55.41 337.61 1060.65 368.53 N 197.44 W 1300.00 61.38 338.39 1113.03 447.47 N 229.31 W 1351.38 64.44 338.75 1136.42 490.05 N 246.02 W 1500.00 64.44 338,75 1200.54 615.01 N 294.62 W 2000.00 64.44 338.75 1416.23 1035.42 N 458.12 W 2500.00 64.44 338.75 1631.92 1455.83 N 621.62 W 2572.04 64.44 338.75 1663.00 1516.40 N 645.18 W 3000.00 64.44 338.75 1847.62 1876.24 N 785.12 W 3500.00 64.44 338.75 2063.31 2296.64 N 948.63 W 4000.00 64.44 338.75 2279.01 2717.05 N 1112.13 W 4500.00 64.44 338.75 2494.70 3137.46 N 1275.63 W 5000.00 64.44 338.75 2710.40 3557.87 N 1439,13 W 5500.00 64.44 338.75 2926.09 3978.28 N 1602.63 W 5698.01 64.44 338.75 3011.51 4144.77 N 1667.38 W 5700.00 64.32 338.75 3012.37 4146.44 N 1668.03 W 5800.00 58.32 338.75 3060.33 4228.17 N 1699.81 W 5830.93 56.47 338.75 3077.00 4252.46 N 1709.26 W PROPOSAL LISTING Page 1 Your ref : WS 1D-108/A3 Vets. #5 Last revised : 8-Sep-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 6.00 0.00 0.00 0.00 0.00 KOP 4.38 6.00 9.84 6.00 28.09 6.00 56.50 6.00 94.75 6.00 142.43 6.00 199.01 6.00 263.87 6.00 336.31 6.00 415.53 6.00 500.66 Begin Turn to Target 6.00 546.40 EOC 0.00 680.47 0.00 1131.53 0.00 1582.59 0.00 1647.57 Base Permafrost 0.00 2033.65 0.00 2484.71 0.00 2935.77 0.00 3386.83 0.00 3837.89 0.00 4288.95 0.00 4467.57 Begin Angle Drop 6.00 4469.37 6.00 4557.06 6.00 4583.12 Top Ugnu Sands 5900.00 52.32 338.75 3117.20 4304.78 N 1729.61 W 6.00 4639.26 6000.00 46.32 338.75 3182.35 4375.44 N 1757.09 W 6.00 4715.06 6100.00 40.32 338.75 3255.06 4439.35 N 1781,95 W 6.00 4783.64 6200.00 34.32 338.75 3334.55 4495.84 N 1803.91 W 6.00 4844.24 6300.00 28.32 338.75 3419.93 4544.27 N 1822.75 W 6.00 4896.20 6388.75 23.00 338.75 3499.89 4580.08 N 1836.68 W 6.00 4934.62 6500.00 23.00 338.75 3602.30 4620.59 N 1852,43 W 0.00 4978.09 6588.75 23.00 338.75 3684.00 4652.91 N 1865.00 W 0.00 5012.76 6746.26 23.00 338.75 3828.99 4710.27 N 1887.31 W 0.00 5074.31 6746.27 23.00 338.75 3829.00 4710.27 N 1887,31 W 0.00 5074.31 End Angle Drop Top West Sak Sands TARGET - West Sak A3 WS 1D-A3 Rvsd 22-Jan-98 7000.00 23.00 338.75 4062.56 4802.67 N 1923.25 W 0.00 5173.44 7054.80 23.00 338.75 4113.00 4822.62 N 1931.01 W 0,00 5194.85 Base West Sak Sands 7254.80 23.00 338.?5 4297.10 4895.46 N 1959.34 W 0.00 5273.00 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #108 and TVD from RKB (Parker #245) (112.00 Ft a~ove mean sea level). Bottom hole distance is 5273.00 on azimuth 338.19 degrees from wellhead. Total Dogleg for wellpath is 107.53 degrees. Vertical section is from wellhead on azimuth 338.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,108 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-108/A3 Vets. #5 Last revised : 8-Sep-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 400.00 399 1351.38 1136 2572.04 1663 5698.01 3011 5830.93 3077 6388.75 3499 6588.75 3684 6746.26 3828 6746.27 3829 7054.80 4113 7254.80 4297 .38 6.74 N 9.63 W Begin Turn to Target .42 490.05 N 246.02 W EOC .00 1516.40 N 645.18 W Base Permafrost 51 4144.77 N 1667.38 W Begin Angle Drop 00 4252.46 N 1709.26 W Top Ugnu Sands 89 4580.08 N 1836.68 W End Angle Drop 00 4652.91 N 1865.00 W Top West Sak Sands 99 4710.27 N 1887.31 W TARGET - West Sak A3 00 4710.27 N 1887.31 W WS 1D-A3 Rvsd 22-Jan-98 00 4822.62 N 1931.01 W Base-West Sak Sands 10 4895.46 N 1959.34 W TD - Casing Pt Casing.positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7254.80 4297.10 4895.46N 1959.34W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A3 Rvsd 22-Jan 558565.000,5964433.000,0.0000 3829.00 4710.27N 1887.31W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,108 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C 0 0 R ANGULAR DINATES PROPOSAL LISTING Page 1 Your ref : WS 1D-108/A3 Vets. #5 Last revised : 8-Sep-98 Dogleg Deg/100ft 0.00 0.00 0.00 0.00 74.00 N 596.00 W 0.00 100.00 0.00 305.00 100.00 74.00 N 596.00 W 0.00 200.00 0.00 305.00 200.00 74.00 N 596.00 W 0.00 250.00 0.00 305.00 250.00 74.00 N 596.00 W 0.00 350.00 6.00 305.00 349.82 77.00 N 600.29 W 6.00 Vert Sect 0.00 0.00 0.00 0.00 KOP 4.38 400.00 9.00 305.00 399.38 80.74 N 605.63 W 6.00 9.84 500.00 14.27 319.67 497.32 94.64 N 620.03 W 6.00 28.09 600.00 19.95 326.34 592.86 118.25 N 637.47 W 6.00 56.50 700.00 25.77 330.11 684.98 151.32 N 657.77 W 6.00 94.75 800.00 31.65 332.57 772.65 193.49 N 680.71 W 6.00 142.43 900.00 37.57 334.31 854.92 244.30 N 766.04 W 6.00 199.01 1000.00 43.51 335.65 930.88 303.18 N 733.47 W 6.00 263.87 1100.00 49.46 336.72 999.71 369.51 N 762.71 W 6.00 336.31 1200.00 55.41 337.61 1060.65 442.53 N 793.44 W 6.00 415.53 1300.00 61.38 338.39 1113.03 521.47 N 825.31 W 6.00 500.66 1351.38 64.44 338.75 1136.42 564.05 N 842.02 W 6.00 546.40 1500.00 64.44 338.75 1200.54 689.01 N 890.62 W 0.00 680.47 2000.00 64.44 338.75 1416.23 1109.42 N 1054.12 W 0.00 1131.53 2500.00 64.44 338.75 1631.92 1529.83 N 1217.62 W 0.00 1582.59 2572.04 64.44 338.75 1663.00 1590.40 N 1241.18 W 0.00 1647.57 3000.00 64.44 338.75 1847.62 1950.24 N 1381.12 W 0.00 2033.65 3500.00 64.44 338.75 2063.31 2370.64 N 1544.63 W 0.00 2484.71 4000.00 64.44 338.75 2279.01 2791.05 N 1708.13 W 0.00 2935.77 4500.00 64.44 338.75 2494.70 3211.46 N 1871.63 W 0.00 3386.83 5000.00 64.44 338.75 2710.40 3631.87 N 2035.13 W 0.00 3837.89 5500.00 64.44 338.75 2926.09 4052.28 N 2198.63 W 0.00 4288.95 5698.01 64.44 338.75 3011.51 4218.77 N 2263.38 W 0.00 4467.57 5100.00 64.32 338.75 3012.37 4220.44 N 2264.03 W 6.00 4469.37 5800.00 58.32 338.75 3060.33 4302.17 N 2295.81 W 6.00 4557.06 5830.93 56.47 338.75 3077.00 4326.46 N 2305.26 W 6.00 4583.12 5900.00 52.32 338.75 3117.20 4378.78 N 2325.61 W 6.00 4639.26 6000.00 46.32 338.75 3182.35 4449.44 N 2353.09 W 6.00 4715.06 6100.00 40.32 338.75 3255.06 4513.35 N 2377.95 W 6.00 4783.64 6200.00 34.32 338.75 ~334.55 4569.84 N 2399.91 W 6.00 4844.24 6300.00 28.32 338.75 3419.93 4618.27 N 2418.75 W 6.00 4896.20 6388.75 23.00 338.75 3499.89 4654.08 N 2432.68 W 6.00 4934.62 6500.00 23.00 338.75 3602.30 4694.59 N 2448.43 W 0.00 4978.09 6588.75 23.00 338.75 3684.00 4726.91 N 2461.00 W 0.00 5012.76 6746.26 23.00 338.75 3828.99 4784.27 N 2483.31 W 0.00 5074.31 6746.27 23.00 338.75 3829.00 4784.27 N 2483.31 W 0.00 5074.31 7000.00 23.00 338.75 4062.56 4876.67 N 2519.25 W 0.00 5173.44 7054.80 23.00 338.75 4113.00 4896.62 N 2527.01 W 0.00 5194.85 7254.80 23.00 338.75 4297.10 4969.46 N 2555.34 W 0.00 5273.00 Begin Turn to Target E0C Base Permafrost Begin Angle Drop Top Ugnu Sands End Angle Drop Top West Sak Sands TARGET - West Sak A3 WS 1D-A3 Rvsd 22-jan-98 Base West Sak Sands TD - Casing Pt Ai]chorage All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RF~B (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5273.00 on azimuth 338.19 degrees from wellhead. Total Dogleg for wellpath is 107.53 degrees. Vertical section is from wellhead on azimuth 338.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,108 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-108/A3 Vets. #5 Last revised = 8-Sep-98 Comments in we11path MD TVD Rectangular Coords. Comment 250.00 250.00 74.00 N 596.00 W KOP %00.00 399.38 80.74 N 605.63 W Begin Turn to Target 1351.38 1136.42 564.05 N 8%2.02 W EOC 2572.0% 1663.00 1590.40 N 1241.18 W Base Permafrost 5698.01 3011.51 4218.77 N 2263.38 W Begin Angle Drop 5830.93 3077.00 4326.46 N 2305.26 W Top Ugnu Sands 6388.75 3499.89 4654.08 N 2%32.68 W End Angle Drop 6588.75 3684.00 4726.91 N 2461.00 W Top West Sak Sands 67%6.26 3828.99 4784.27 N 2483.31 W TARGET - West Sak A3 67%6.27 3829.00 478%.27 N 2483.31 W WS 1D-A3 Rvsd 22-Jan-98 7054.80 4113.00 4896.62 N 2527.01 W Base-West Sak Sands 7254.80 4297.10 4969.46 N 2555.34 W TD - Casing Pt Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rec.tangular Coords. Casing 0.00 0.00 74.00N 596.00W 725%.80 4297.10 4969.46N 2555.34W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A3 Rvsd 22-Jan 558565.000,5964433.000,0.0000 3829.00 4784.27N 2483.31W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,108 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C O O R 0.0d 0.00 0.00 0.00 0.00 100.00 0.00 305.00 100.00 0.00 200.00 0.00 305.00 200.00 0.00 250.00 0.00 305.00 250.00 0.00 350.00 6.00 305.00 349.82 3.00 ANGULAR DINATES PROPOSAL LISTING Page 1 Your ref : WS 1D-108/A3 Vets. #5 Last revised : 8-Sep-98 Vert Ellipse Semi Axes Minor Sect Major Minor Vert, Azi. N 0.00 E 0.00 0.00 0.00 0.00 N/A N 0.00 E 0.00 0.26 0.26 0.15 N/A N 0.00 E 0.00 0.52 0.52 0.30 N/A N 0.00 E 0.00 0.65 0.65 0.38 N/A N 4.29 W 4.38 0.99 0.92 0.53 305.00 400.00 9.00 305.00 399.38 6.74 N 9.63 W 9.84 1.23 1.06 0.60 305.00 500.00 14.27 319.67 497.32 20.64 N 24.03 W 28.09 2.04 1.38 0.76 313.59 600.00 19.95 326.34 592.86 44.25 N 41.47 W 56.50 3.26 1.74 0.94 319.44 700.00 25.77 330.11 684.98 77.32 N 61.77 W 94.75 4.92 2.16 1.16 323.48 800.00 31.65 332.57 772.65 119.49 N 84.71 W 142.43 6.99 2.64 1.45 326.41 900.00 37.57 334.31 854.92 170.30 N li0.04 W 199.01 9.49 3.15 1.82 328.62 1000.00 43.51 335.65 930.88 229.18 N 137.47 W 263.87 12.39 3.69 2.30 330.35 1100.00 49.46 336.72 999.71 295.51 N 166.71 W 336.31 15.65 4.22 2.90 331.74 1200.00 55.41 337.61 1060.65 368.53 N 197.44 W 415.53 19.26 4.74 3.60 332.88 1300.00 61.38 338.39 1113.03 447.47 N 229.31 W 500.66 23.16 5.22 4.41 333.84 1351.38 64.44 338.75 1136.42 490.05 N 246.02 W 546.40 25.23 5.45 4.85 334.26 1500.00 64.44 338.75 1200.54 615.01 N 294.62 W 680.47 31.24 6.12 6.15 335.14 2000.00 64.44 338.75 1416.23 1035.42 N 458.12 W 1131.53 51.54 8.35 10.55 336.58 2500.00 64.44 338.75 1631.92 1455.83 N 621.62 W 1582.59 71.89 10.58 14.97 337.20 2572.04 64.44 338.75 1663.00 1516.40 N 645.18 W 1647.57 74.82 10.90 15.61 337.25 3000.00 64.44 338.75 1847.62 1876.24 N 785.12 W 2033.65 92.24 12.81 19.40 337.55 3500.00 64.44 338.75 2063.31 2296.64 N 948.63 W 2484.71 112.61 15.03 23.83 337.76 4000,00 64.44 338.75 2279.01 2717.05 N 1112.13 W 2935.77 132.98 17.25 28.26 337.92 4500.00 64.44 338.75 2494.70 3137.46 N 1275.63 W 3386.83 153.35 19.47 32.69 338.03 5000.00 64.44 338.75 2710.40 3557.87 N 1439.13 W 3837.89 173.72 21.69 37.12 338.11 5500.00 64.44 338.75 2926.09 3978.28 N 1602.63 W 4288.95 194.09 23.91 41.55 338.18 5698,01 64.44 338.75 3011.51 4144.77 N 1667.38 W 4467.57 202.16 24.79 43.30 338.20 5700.00 64.32 338.75 3012.37 4146.44 N 1668.03 W 4469.37 202.24 24.80 43.32 338.20 5800.00 58.32 338.75 3060.33 4228.17 N 1699.81 W 4557.06 206.00 25.30 44.12 338.21 5830.93 56.47 338.75 3077.00 4252.46 N 1709.26 W 4583.12 207.05 25.47 44.33 338.21 5900,00 52.32 338.75 3117.20 4304.78 N 1729.61 W 4639.26 209.41 25.84 44.81 338.22 6000,00 46.32 338.75 3182.35 4375.44 N 1757.09 W 4715.06 212.42 26.40 45.40 338.23 6100.00 40.32 338.75 3255.06 4439.35 N 1781.95 W 4783.64 215.03 26.95 45.89 338.23 6200.00 34.32 338.75 3334.55 4495.84 N 1803.91 W 4844.24 217.21 27.49 46.27 338.24 6300.00 28.32 338.75 3419.93 4544.27 N 1822.75 W 4896.20 218.96 27.99 46.56 338.24 6388,75 23.00 338.75 3499.89 4580.08 N 1836.68 W 4934.62 220.19 28.39 46.75 338.24 6500.00 23.00 338.75 3602.30 4620.59 N 1852.43 W 4978.09 221.74 28.90 46.98 338.25 6588,75 23.00 338.75 3684.00 4652.91 N 1865.00 W 5012.76 222.97 29.31 47.17 338.25 6746,26 23.00 338.75 3828.99 4710.27 N 1887.31 W 5074.31 225.16 30.03 47.51 338.26 6746,27 23.00 338.75 3829.00 4710.27 N 1887.31 W 5074.31 225.16 30.03 47.51 338.26 7000.00 23.00 338.75 4062.56 4802.67 N 1923.25 W 5173.44 228.69 31.18 48.05 338.26 7054,80 23.00 338.75 4113.00 4822.62 N 1931.01 W 5194.85 229.45 31.43 48.17 338.26 7254,80 23.00 338.75 4297.10 4895.46 N 1959.34 W 5273.00 232.24 32.35 48.60 338.27 All data is in feet unless otherwise stated. Coordinates from slot #108 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5273.00 on azimuth 338.19 degrees from wellhead. Vertical section is from wellhead on azimuth 338.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,108 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-108/A3 Vets. #5 Last revised : 8-Sep-98 POSITION UNCERTAINTY SUM3h%RY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 7255 ARCO (H.A. Mag) User specified 232.24 32.35 48.60 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in we11path MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 400.00 399.38 6.74 N 9.63 W Begin Turn to Target 1351.38 1136.42 490.05 N 246.02 W EOC 2572.04 1663.00 1516.40 N 645.18 W Base Pez~afrost 5698.01 3011.51 4144.77 N 1667.38 W Begin Angle Drop 5830.93 3077.00 4252.46 N 1709.26 W Top Ugnu Sands 6388.75 3499.89 4580.08 N 1836.68 W End A~gle Drop 6588.75 3684.00 4652.91 N 1865.00 W Top West Sak Sands 6746.26 3828.99 4710.27 N 1887.31 W TARGET - West Sak A3 6746.27 3829.00 4710.27 N 1887.31 W WS 1D-A3 Rvsd 22-Jan-98 7054.80 4113.00 4822.62 N 1931.01 W Base West Sak Sands 7254.80 4297.10 4895.46 N 1959.34 W TD - Casing Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7254.80 4297.10 4895.46N 1959.34W 7 5/8" Casing Targets associated with this wellpath ========================= Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A3 Rvsd 22-Jan 558565.000,5964433.000,0.0000 3829.00 4710.27N 1887.31W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,108 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-108/A3 Vets. #5 Last revised : 8-Sep-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 560490.36 5959738.68 100.00 0.00 305.00 100.00 0.00N 0.00E 0.00 0.00 560490.36 5959738.68 200.00 0.00 305.00 200.00 0.00N 0.00E 0.00 0.00 560490.36 5959738.68 250.00 0.00 305.00 250.00 0.00N 0.00E 0.00 0.00 560490.36 5959738.68 350.00 6.00 305.00 349.82 3.00N 4.29W 6.00 4.38 560486.05 5959741.64 400.00 9.00 305.00 399.38 6.74N 9.63W 6.00 9.84 560480.67 5959745.34 500.00 14.27 319.67 497.32 20.64N 24.03W 6.00 28.09 560466.17 5959759.11 600.00 19.95 326.34 592.86 44.25N 41.47W 6.00 56.50 560448.53 5959782.58 700.00 25.77 330.11 684.98 77.32N 61.77W 6.00 94.75 560427.96 5959815.48 800.00 31.65 332.57 772.65 119.49N 84.71W 6.00 142.43 560404.68 5959857.46 900.00 37.57 334.31 854.92 170.30N i10.04W 6.00 199.01 560378.95 5959908.06 1000.00 43.51 335.65 930.88 229.18N 137.47W 6.00 263.87 560351.04 5959966.71 1100.00 49.46 336.72 999.71 295.51N 166.71W 6.00 336.31 560321.27 5960032.79 1200.00 55.41 337.61 1060.65 368.53N 197.44W 6.00 415.53 560289.95 5960105.56 1300.00 61.38 338.39 1113.03 447.47N 229.31W 6.00 500.66 560257.44 5960184.23 1351.38 64.44 338.75 1136.42 490.05N 246.02W 6.00 546.40 560240.38 5960226.66 1500.00 64.44 338.75 1200.54 615.01N 294.62W 0.00 68'0.47 560190.78 5960351.21 2000.00 64.44 338.75 1416.23 1035.42N 458.12W 0.00 1131.53 560023.88 5960770.24 2500.00 64.44 338.75 1631.92 1455.83N 621.62W 0.00 1582.59 559856.98 5961189.26 2572.04 64.44 338.75 1663.00 1516.40N 645.18W 0.00 1647.57 559832.94 5961249.63 3000.00 64.44 338.75 1847.62 1876.24N 785.12W 0.00 2033.65 559690.08 5961608.29 3500.00 64.44 338.75 2063.31 2296.64N 948.63W 0.00 2484.71 559523.19 5962027.31 4000.00 64.44 338.75 2279.01 2717.05N 1112.13W 0.00 2935.77 559356.29 5962446.34 4500.00 64.44 338.75 2494.70 3137.46N 1275.63W 0.00 3386.83 559189.39 5962865.36 5000.00 64.44 338.75 2710.40 3557.87N 1439.13W 0.00 3837.89 559022.50 5963284.39 5500.00 64.44 338.75 2926.09 3978.28N 1602.63W 0.00 4288.95 558855.60 5963703.41 5698.01 64.44 338.75 3011.51 4144.77N 1667.38W 0.00 4467.57 558789.50 5963869.36 5700.00 64.32 338.75 3012.37 4~46.44N 1668.03W 6.00 4469.37 558788.84 5963871.02 5800.00 58.32 338.75 3060.33 4228.17N 1699.81W 6.00 4557.06 558756.39 5963952.49 5830.93 56.47 338.75 3077.00 4252.46N 1709.26W 6.00 4583.12 558746.75 5963976.69 5900.00 52.32 338.75 3117.20 4304.78N 1729.61W 6.00 4639.26 558725.98 5964028.85 6000.00 46.32 338.75 3182.35 4375.44N 1757.09W 6.00 4715.06 558697.93 5964099.27 6100.00 40.32 338.75 3255.06 4439.35N 1781.95W 6.00 4783.64 558672.56 5964162.97 6200.00 34.32 338.75 ~334.55 4495.84N 1803.91W 6.00 4844.24 558650.13 5964219.27 6300.00 28.32 338.75 3419.93 4544.27N 1822.75W 6.00 4896.20 558630.90 5964267.54 6388.75 23.00 338.75 3499.89 4580.08N 1836.68W 6.00 4934.62 558616.69 5964303.23 6500.00 23.00 338.75 3602.30 4620.59N 1852.43W 0.00 4978.09 558600.60 5964343.61 6588.75 23.00 338.75 3684.00 4652.91N 1865.00W 0.00 5012.76 558587.77 5964375.83 6746.26 23.00 338.75 3828.99 4710.27N 1887.31W 0.00 5074.31 558565.00 5964433.00 6746.27 23.00 338.75 3829.00 4710.27N 1887.31W 0.00 5074.31 558565.00 5964433.00 7000.00 23.00 338.75 4062.56 4802.67N 1923.25W 0.00 5173.44 558528.32 5964525.09 7054.80 23.00 338.75 4113.00 4822.62N 1931.01W 0.00 5194.85 558520.39 5964544.98 7254.80 23.00 338.75 4297.10 4895.46N 1959.34W 0.00 5273.00 558491.48 5964617.57 All data in feet =less othe~ise st.ted. Cal==lation uses minim~ cu~ature meth~chora~e Coordinates from slot #108 and TVD from RF~B (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5273.00 on azimuth 338.19 degrees from wellhead. Total Dogleg for wellpath is 107.53 degrees. Vertical section is from wellhead on azimuth 338.17 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 1D,108 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-108/A3 Vets. #5 Last revised : 8-Sep-98 Comments in wellpath =2============== .... MD TVD Rectangular Coords. Comment 250 00 250.00 0.00N 0.00E KOP 400 00 399.38 1351 38 1136.42 2572 04 1663.00 5698 01 3011.51 5830 93 3077.00 6388.75 3499.89 6588.75 3684.00 6746.26 3828.99 6746.27 3829.00 7054.80 4113.00 7254.80 4297.10 6.74N 9.63W Begin Turn to Target 490.05N 246.02W 1516.40N 645.18W Base Permafrost 4144.77N 1667.38W Begin Angle Drop 4252.46N 1709.26W Top Ugnu Sands 4580.08N 1836.68W End Angle Drop 4652.91N 1865.00W Top West Sak Sands 4710.27N 1887.31W TARGET - West Sak A3 4710.27N 1887.31W WS 1D-A3 Rvsd 22-Jan-98 4822.62N 1931.01W Base-West Sak Sands 4895.46N 1959.34W TD - Casing Pt Casing positions in string ~A~ ===================== Top HD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7254.80 4297.10 4895.46N 1959.34W 7 5/8" Casing Targets associated with this wellpath ===================================== Target na~e Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-A3 Rvsd 22-Jan 558565.000,5964433.000,0.0000 3829.00 4710.27N 1887.31W 9-Oct-96 KUPUR~ TOOL HOUSE Fi:iX HO.: P.~2 C O.S.' I-D 111 THIS SURVEY LEGEND L, 0 'A$-EKgL T" ~TOR LOCA ~ 1! SEE 514~ ~ 2 FOR NOTES ANO LOC~TION ~iRDRMATION i i i · mmLOUNSBURY & ASSOCIATEg, ~C. ARCO Alaska, Inc. CIRAW~G NO: 044 6 07/22/98 I i I I ~iIE~II :AR[A: 10 XX DRILL SITE 1-O WEST 5AK PHASE 19 - WELL C:ONDUCTORS AS-BU[T LOCATIONS LedT' OT NOTE5 r. COOROa~ArE$ SHOHN A~eE A, IP. ZONE FOR' a?-2?-gg ! '1 THIS Pi, _VICYNITY' MAP . ! - Se~,. 14, T.I! N., R. IO F_ ARCO Alaska, Inc.`aL LK6I D,1,15 LOU~SBURY ASSOCIATES. flOC. AR[A: TD klOOULE: ~ ~E:ST SAK PHASE 19 - RELL CONiX/CTORS AS-BUILI' LOCATIONS CEA-DIDX-6104015 2 ~ 2 UtaT: D! · WELL PERMIT CHECKLIST COMPANY ~t- Y'/~.~.--~ WELL NAME V.,~L/,.. I O - I O ~ .. PROGRAM: exp [] dev/8~ redrll [] serv [] wellbore seg II ann. disposal para req II FIELD & POOL INIT CLASS '~ ~ ~ ) - O I C.- GEOL AREA g c~ ~_-~ __ UNIT# I I I (~ ~ ON/OFF SHORE ____O__/~__ ............ ADMINISTRATION A~R DA-rE.,~ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in 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 DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... '17. CM'F vol adequate to tie-in long string to surf csg ........ 18. CM']' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~O-E~ C") _psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide mea~ 31. Data presented on potential overpressur~j.p_.~z-ene~ ....... 32. Seismic analysis of shallo~s ..... ' ........ 33. Seabed conditi~y (if off-shore) ............. ~e.,s~ reports ...... exploratory only] ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (,E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N Y® Y N Y N Y N Y N Y N Y N .................................................................................................................................................................................. Y N GEOL~G._Y: ENGINEERING: .... COMMISSION: RNC ~ CO Comments/Instructions: Mchel~list u;v 05/2919B dlfC Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drillin9 Services LIS Scan Utility Thu Oct 22 13:12:31 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writin~ Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/10/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin~ Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUDARUK RIVER UNIT (WEST SA/<) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 1 AK-MM-80393 S. BURKHARDT D. LUTRICK 1D-108 (WEST SAK) . 500292292100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 22-OCT-98 MWD RUN 2 AK-MM- 803 93 S. BURKHARDT D. LUTRICK 74 596 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 112.10 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 7150.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER' S DEPTHS. DEPTH CORRECTION IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MIKE WERNER AND A. TURKER ON 10/13/98. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7150'MD, 4210 ' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/22 Maximum Physical Record. o65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE ' START DEPTH FET 121.0 RPD 121.0 RPM 121.0 RPS 121.0 RPX 121.0 GR 121.0 ROP 122.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 7105.0 7105.0 7105.0 7105.0 7105.0 7112.0 7150.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 4180.0 2 4180.0 7150.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 121 7150.5 3635.75 14060 121 Last Reading 7150.5 GR RPX RPS RPM RPD ROP FET 8 4353 0 0978 0 0783 0 0962 0 0828 6 2866 0.0756 136.305 69.255 13983 2000 49.5789 13969 2000 68.4441 13969 2000 113.169 13969 2000 174.36 13969 2611.23 271.013 14058 12.653 0.400101 13969 121 121 121 121 121 122 121 7112 7105 7105 7105 7105 7150.5 7105 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 7150.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NI/MBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ 121 0 121 0 121 0 121 0 121 0 121 0 122 0 STOP DEPTH 4138 5 4138 5 4138 5 4138 5 4138 5 4146 0 4180 0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMITM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER3kTURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined 01-0CT-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 4180.0 121.0 4180.0 1.4 65.2 TOOL NUMBER P1067CRG6 P1067CRG6 9.880 9.9 SPUD 9.70 275.0 8.3 300 5.8 4.500 3. 645 5.000 3.500 31.1 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 FT/H 4 1 68 MWD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 121 8 4353 0 0978 0 0783 0 0962 0 0828 26 3501 0 0756 Max Mean 4180 2150.5 134.562 67.7699 2000 78.8555 2000 111.224 2000 189.061 2000 295.256 2611.23 290.93 1.4477 0.253789 Nsam 8119 8051 8036 8036 8036 8036 8117 8036 First Reading 121 121 121 121 121 121 122 121 Last Reading 4180 4146 4138.5 4138.5 4138.5 4138.5 4180 4138.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4180 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... VersiOn Number ........... 1.0.0 Date of Generation ....... 98/10/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4135.0 7105 0 RPD 4135.0 7105 0 RPM 4135.0 7105 0 RPS 4135.0 7105 0 RPX 4135.0 7105 0 GR 4143.0 7112 0 ROP 4181.5 7150 5 $ LOG HEADER DATA DATE LOGGED: 03 -OCT- 98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERS ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 18.8 MAXIMUM ANGLE: 65.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3~TURE (MT): ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 7150.0 4180.0 7150.0 TOOL NUMBER P1067CRG6 P1067CRG6 9.880 9.9 LSND 9.60 250.0 8.7 300 3.8 4.500 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP*ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAArDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.211 5.000 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 2 OHMM 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 36.7 Name Min Max Mean Nsam DEPT 4135 7150.5 5642.75 6032 GR 13.8116 136.305 71.2289 5939 RPX 1.9489 2000 9.93078 5941 RPS 2.0452 318.173 10.5143 5941 RPM 2.0271 114.091 10.3943 5941 RPD 2.1666 101.832 10.6306 5941 ROP 6.2866 1742.71 243.762 5939 FET 0.079 12.6532 0.614327 5941 First Reading 4135 4143 4135 4135 4135 4135 4181.5 4135 Last Reading 7150.5 7112 7105 7105 7105 7105 7150.5 7105 First Reading For Entire File .......... 4135 Last Reading For Entire File ........... 7150.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File
