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Home My WebLink About198-178 • Page 1 of 2 Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Friday, January 04, 2013 2:42 PM To: Schwartz, Guy L (DOA) Subject: RE: McOH treatments for WS ESP wells W " 113 Guy /'T6 (? f — / 78 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 SCANNED APR 11 2013 Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (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 Prof 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 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 Cell (907) 943 -1687 :egrity Proj mber 16, 2012 3:55 PM L (DOA); 'Regg, James B (D0A)' 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 concems 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), 1 D -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 • • ConocoPh i l • ps RECEI Alaska VED P.O. BOX 100360 0C T 0 9 2012 ANCHORAGE, ALASKA 99510 -0360 AOGCC October 5, 2012 } Commissioner Dan Seamount 3 - Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 a ,r r , '` ,� Anchorage, AK 99501 c,A04 i €'� ' 3 s Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, i /6 Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/05/2012 1D,WSW,IF,2F,2L,2T,2Z,3G,31& 3M PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date c.... ft bbls ft gal 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1 F -11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 7'5" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 STATE OF ALASKA ALA* OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r Alter Casing I Rill Tubing 17 Stimulate - Frac r Waiver r Time Extension r- Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Development j Exploratory r - 198 -178 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50 029 - 22917 - 00 " 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 " — 10 - 113 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 6866 feet Plugs (measured) 3584 true vertical 4120 feet Junk (measured) None Effective Depth measured 6766 feet Packer (measured) 3440 true vertical 4028 feet (true vertucal) 2008 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 6811 7.625 6851 4106 1.. ED APR 2 7 'OIZ RECEIVED APR 2 3 2012 Perforation depth: Measured depth: 6282'- 6312', 6354'- 6374', 6407'- 6427', 6462'- 6482', 6530' -6547' /� C OGC True Vertical Depth: 3590'- 3617', 3655'- 3673', 3702'- 3720', 3752'- 3770', 3814' -3829' /`"1 V V Tubing (size, grade, MD, and TVD) 3.5, L 6153 MD, 3474 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED -THRU PACKER, WEATHERFORD HYDROW II PACKER @ 3440 MD and 2008 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 shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development pr b Service r Stratigraphic r 16. Well Status after work: Oil j' Gas r WDSPL II- Daily Report of Well Operations _XXX GSTOR r WINJ r WAG r GINJ r SUSP E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature / Phone: 265-6845 l Date 4� //Z - .Z 3 /L -° �y - -/ J ^r RBDMS APR 23 10 Form 10 -404 Revised 11/2011 Submit Original Only l t KUP • 1 D -113 Conoc 01 Well Attributes Max Angle & MD TD Alaska, Inc Wellbore APW WI Field Name Well Status Intl ( °) MD (ftKB) Act Btm (ftKB) ConocOPMhdlips 500292291700 WEST SAK PROD 65.88 3,836.22 6,866.0 " " ° ' Comment 17 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well Confa: 1 D -713, 4/73/20/2 10:05:16 AM SSSV: NONE 10 7/10/2009 Last WO: 3/27/2012 48.01 9/17/1998 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag RKB 6,060.0 1/7/2010 Rev Reason: WORKOVER osborl 4/13/2012 q , " Casing Strings 4A6IGEE,3P ; Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ■ ,:: , ,. CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H WELDED 'nom., r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ;'' SURFACE 75/8 6.875 40.6 6,851.5 4,106.3 2970 L -80 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 3 1/2 2.992 36.8 6,153.4 3,473.6 9.30 L -80 EUE CONDUCTOR. Completion Details 41 -121 P Top Depth (TVD) Topinel Noml... Top ((MB) (ftKB) ( °) Item Description Comment ID (in) 36.8 36.8 -1.65 HANGER Vetco Gray TUBING HANGER w/ 3.57 -ft Pupjt 2.950 ESP Cable, 37 3,439.8 2,007.7 65.71 PACKER ESP Feed -Thru Packer, Weatherford Hydrow II Dual- string packer 3.250 6,063.9 3,393.3 26.00 GAUGE WeIIL'Ift Discharge Gauge Unit 2.992 ESP C MANDREL, 6,121.2 3,444.7 25.90 INTAKE TTC Receiving XO Coupling w/ perforated intake 2.992 we 3, 376 6,125.7 3,448.7 25.89 SEAL Baker Tandem Seal Section. 47 / 6,139.5 3,461.1 25.87 GEAR Baker Gear Reduction Unit 6,141.3 3,462.8 25.87 MOTOR Baker ESP Motor, 562MSP1, 60 hp/1240V/29 A L 6,149.6 3,470.2 25.85 GAUGE Baker WeIILift Motor Gauge Unit r a t (/ PACKER, 3,440 6,151.4 3,471.9 25.85 Centralizer Baker Motor Centralizer 4.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Intl Top (ftKB) (RKB) ( °) Description Comment Run Date 8) (in) IF 36.8 36.8 -1.65 ESP Cable ESP Cable #1 wire 3/25/2012 0.000 ESP MANDREL, 3,580.0 2,065.4 65.77 CATCHER CATCHER SET ON TOP OF PLUG 3/25/2012 0.000 , .. 3,552 a 3,584.0 2,067.0 65.77 PLUG WRP SET @ WORKOVER 3/25/2012 0.000 6,187.0 3,503.9 25.79 GRAVEL GRAVEL PACKw /PACKER @6186', SLEEVE @6195', SBE 1/12/2006 PACK @6197, SCREENS @ 6277-6820', PLUG @6580' CATCHER, 3,580 «u; Perforations & Slots PLUG, 3,584 ''':',/;,:. ' Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment 6,282.0 6,312.0 3,589.5 3,616.6 WS D, 1D-113 11/10/1998 4.0 IPERF 21/8" ENERJET, BH; 0 deg phasing ,ter 6,354.0 6,374.0 3,654.6 3,672.6 WS 8, 1D-113 11/2/1998 4.0 APERF 21/8" ENERJET, BH; 0 deg phasing 6,407.0 6,427.0 3,702.3 3,720.4 WS A4, 1D-113 10/27/1998 4.0 APERF 21/8" ENERJET, BH; 0 deg phasing GAUGE, 6,064 6,462.0 6,482.0 3,752.0 3,770.1 WS A3, 10-113 10/15/1998 4.0 APERF 2 1/8" ENERJET, BH; 0 deg phasing 6,530.0 6,547.0 3,813.8 3,829.2 WS A2, 1D-113 10/9/1998 4.0 APERF 2 1/8" ENERJET, BH; 0 deg phasing Notes: General & Safety '..,� End Date Annotation 7/6/2008 NOTE: WORKOVER i ' 7/12/2008 NOTE: View Schematic w/ Alaska Schematic9.0 INTAKE, 6,121 SEAL, 6,126 GEAR, 8,139 ■( .1 MOTOR. 8,141 ■' a. Pt 4.4 GAUGE, 6,150 tat Centralizer, 6,151 '" i IPERF, is$4 6,2826,312 APERF, 6,354-6,374 GRAVEL PACK 8,187 APERF, M andrel Details 6,407 -6,427 T op Dept Top Pon ( rv D) Inc! OD Valve Latch Size TRO Run APERF, S tn Top (ftKB) (5KB) 11 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 6,482 -6,482 1 3,316.4 1,956.8 65.66 Camco KBMG 1 ESP DMY BK -5 0.000 0.0 3/24/2012 2 3,552.4 2,054.1 65.76 Camco KBMG 1 ESP DMY BK -5 0.000 0.0 3/24/2012 APERF, 1 i iii, 8.5 APERF, 7 4 SURFACE, 41 -6,851 N TD, 6,866 • 1 D -113 Pre -Rig Work DATE SUMMARY 2/2/12 PRE -RWO T POT- PASSED;OPPOT- PASSED; FUNCTION TESTED L 2/16/12 SET 3 1/2 CATCHER SUB @ 6063' RKB, PULLED 1" SOV @ 6026' RKB, SET 1" ` DMY VALVE @ SAME, PULLED 3 1/2 CATCHER SUB @ 6063' RKB, PULLED 3 1/2 TBG STOP @ 6063' RKB, PULLED 3 1/2 D &D PACKOFF @ 6064' RKB. IN PROGRESS. 2/17/12 PULLED 3 1/2 TTC ESP PUMP @ 6071' RKB. PUMPED 170 HOT DIESEL DOWN IA AND 55 HOT DIESEL DOWN TUBING, CALLED FOR BPV INSTALL. COMPLETE MOVE TO 1C -127 • • $" Time Log & Summary ConocoPhillips Wel!view Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/21/2012 1:30:00 AM Rig Release: 3/27/2012 2:00:00 AM Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 03/20/2012 24 hr Summary Standby for site prep. 18:00 21:00 3.00 MIRU MOVE MOB T Standby for site prep. waiting for water on pad to freeze. 21:00 00:00 3.00 MIRU MOVE MOB T DTH plus Roads and Pads haul in snow and mix with water. Shoot / Level grade. Lay down mats. 03/21/2012 Spot rig on well 1D-113. Wait on Weather. Spot and test support equipment. Pull BPV. Kill well. Set BPV. ND Tree. Set blanking plug. NU BOPE. Begin the Initial BOPE test 250/3000. 00:00 01:30 1.50 MIRU MOVE RURD P Move over 1D -124 Well (Drill Site Operator notified, not present, gave OK to proceed). Shim and level up Rig. Nordic Rig 3 accepted @ 01:30 hours. 01:30 06:30 5.00 MIRU MOVE RURD T Cold weather restrictions called, -35° amb. temps. Berm up and secure Cellar. Take on Filtered 8.6 lb /gal w /3% KCL fluid in Pits while waiting on weather. 06:30 10:15 3.75 MIRU MOVE RURD P Cold Weather Restriction where lifted. MIRU Kill tank and Kill lines. Load 75 more joints of 3 1/2" Drill Pipe & Tally same. Load 15 joints of 2 7/8" Hydril PH6 511 TBG and Tally same. 10:15 11:15 1.00 MIRU WHDBO PLUG P Call Out Vetco Gray Rep to Pull BPV. Load Lubricator to Rig Floor. 11:15 13:00 1.75 MIRU WHDBO PLUG P Vetco Gray Rep on Location. RU Lubricator To Wellhead and Pull BPV. 13:00 13:15 0.25 MIRU WELCTL SFTY P PJSM. Discuss Hazard for Killing Well. Notify Security and DSO before pumping operation starts. 13:15 15:00 1.75 MIRU WELCTL KLWL P Open Well and Obtain Initial pressure on wellbore. IA & TBG 195 psi. Wait on Call from DSO that location is clear to start well kill operation. Start Reverse circulating at 5 bpm at 600 psi ICP. 15:00 16:00 1.00 MIRU WELCTL KLWL P Circulated 290 bbls of 8.6 ppg of seawater w/ 3% KCL. and Monitor well for flow and check kill tank level. Still showing 80 psi SITP. Spot vac truck and Un -load Kill Tank. Page 1 of 7 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subc ode T Comment 16:00 17:00 1.00 MIRU WELCTL KLWL P Start Circulation again at 5 bpm, 460 psi until clean 8.6 ppg seawater is seen at surface. Pump a total of 405 bbls and 419 bbls returned. 17:00 17:30 0.50 MIRU WELCTL OWFF P Well shows to be static. Monitor well for flow (30 minutes). 17:30 18:00 0.50 MIRU WELCTLTHGR P Set BPV. 18:00 19:30 1.50 MIRU WELCTL NUND P ND Tree inspect threads, installed blanking plug (test dart) 19:30 22:30 3.00 MIRU WELCTL NUND P NU 11" 5M BOP stack with 3 -12 " Solid Ram Blocks in upper gate and 2 -7/8" X 5" VBR's in lower gate. RU test equipment, flood BOP stack. 22:30 00:00 1.50 MIRU WELCTL BOPE P PJSM. Begin the initial BOPE test per ConocoPhillips, AOGCC requirements at 250/3,000 psi. The State's right to witness the test was 1/ waived by AOGCC Field Inspector Lou Grimaldi. X3/22/2012 Perform the initial BOPE test. Rig up to pull the 3 -1/2" ESP Completion. Pull Tubing Hanger to Floor. Circulate and condition the hole. Single down the 3-1/2" ESP Completion. Clean and Clear Floors / Shed. Set wear ring. 00:00 05:00 5.00 MIRU WELCTL BOPE P Continue the initial BOPE test per ConocoPhillips, AOGCC requirements at 250/3,000 psi. Test Annular to 2 -7/8" and 3 -1/2" . The State's right to witness the test was waived by AOGCC Field Inspector Lou Grimaldi. Perform Koomey Draw Down Test. Good. All pressure tests were recorded on a chart. 05:00 06:00 1.00 MIRU WELCTLTHGR P Vetco -Gray Service Rep pull the Blanking Plug and the Back Pressure Valve. 06:00 07:00 1.00 COMPZ RPCOM THGR P MU Landing Joint. BOLDS, pull hanger to floor, 120k to un -seat hanger, 95k normal wt. 07:00 08:00 1.00 COMPZ RPCOM CIRC P Line Up Mud Pumps, circulate down TBG taking returns up the IA at 5 bpm, 320 psi 1+ hole volume. 08:00 08:30 0.50 COMPZ RPCOM OWFF P Shut down and observe well for flow. 08:30 09:00 0.50 COMPZ RPCOM PULD P Lay down Landing joint + hanger. Blow down Top Drive. 09:00 20:30 11.50 6,138 39 COMPZ RPCOM PULL P POOH f/ 6,138 -ft Up wt 95k, Laying down 3 1/2" TBG while spooling heat trace + ESP cable. 20:30 22:30 2.00 39 0 COMPZ RPCOM PULD P Inspect and lay down ESP Assembly. Motor rotation good. Seal Assembly samples taken. Cable checked good. No bands, Clamps or Flat guards were lost in the hole. 22:30 23:00 0.50 0 0 COMPZ RPCOM THGR P Set Wear Ring. Page 2 of 7 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 COMPZ RPCOM OTHR P Clean and clear floors, offload clamps and ESP equipment from shed. Load Baker equipment. 03/23/2012 PU & TIN with 7 -5/8" Casing Scraper / Clean -out Assembly, Clean out from 6,202 -ft to 6,580 -ft. TOOH with BHA #1. PU & TIH with 7 -5/8" RBP / Test Plug Assembly. 00:00 00:45 0.75 0 0 COMPZ RPCOM OTHR P Continue to offload clamps and ESP equipment from shed. Load Baker equipment. Change over floors to run 2 -7/8" equipment. 00:45 01:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards of making up BHA and running procedures. 01:00 02:30 1.50 0 472 COMPZ RPCOM PULD P PLL,Mi125L8" Casing ac.raper I. Clean -out assembly, BHA #1- mule -shoe on 2 -7/8" PH -6 Hydrill 511 tbg, XO, Double Pin Sub, 7 -5/8" Casing scraper, Bit Sub, Bumper Sub, Oil Jars. 02:30 03:00 0.50 472 472 COMPZ RPCOM OTHR P Change over floors to run 3 -1/2" equipment. Change out leaking fitting on spinners. Cold weather restrictions in effect at 02:50, loader in shop. 03:00 12:00 9.00 472 6,580 COMPZ RPCOM FCO P TIH with BHA #1 on 3 -1/2" Drill Pipe down to 6,180 -ft, stopped and reverse circulated 1.5 tubing volume, losses at 30% at 4 bpm, 280 psi. Unable to maintain 1 for 1. Continue down and tagged top of fill at 6202 -ft, line up mud pump and circulated down drill pipe taking returns up IA at 5 bpm, 700 psi. Wash down to 6580 -ft at same rate pumping High -Vis sweeps every stand. After cleaning down to target depth, pump another 20 bbl sweep and CBU until returns are clean. 12:00 12:45 0.75 6,580 6,080 COMPZ RPCOM TRIP P TOOH to 6,080 -ft and stop to Slip -N -Cut. 12:45 13:00 0.25 6,080 6,080 COMPZ RPCOM SFTY P Secure Well. Hold PJSM and Discuss the Hazard to Slip -N -Cut drilling line. 13:00 16:00 3.00 6,080 6,080 COMPZ RPCOM SLPC P Perform Slip -N -Cut on Drilling Line and Inspect Brake System while cover was off. 16:00 19:30 3.50 6,080 472 COMPZ RPCOM TRIP P Continue OOH with clean -out / scraper assembly 19:30 20:30 1.00 472 0 COMPZ RPCOM PULD P Lay down BHA #1 20:30 21:30 1.00 0 0 COMPZ RPCOM OTHR P Clean and change over floors. Bring in Baker equipment. Continue to rack and tally 3 -1/2" tbg. 21:30 21:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards of making up BHA and running procedures. Page 3 of 7 lime Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:15 0.50 0 35 COMPZ RPCOM PULD P PU MU Baker Model "G" Lock -set RBP, Model "L" Retrieving Head, XO Sub, Handling Pup, Model "EA" Retrievable Test Packer, Handling Pup. 22:15 00:00 1.75 35 2,936 COMPZ RPCOM TRIP P TIH with BHA #2 on 3 -1/2" Drill Pipe to 2,936 -ft. Up wt 60k, Dn wt 50k 03/24/2012 Continue to TIH with 7 -5/8" RBP / Test Plug Assembly. Set RBP at 6,158 -ft and Test 7 -5/8" casing to 1500 psi, good. TOOH with BHA #2. Load, Drift & Tally 3 -1/2" completion. Run TTC -ESPCP completion to Feed -thru Packer. / 00:00 02:00 2.00 2,936 6,158 COMPZ RPCOM TRIP P Continue to TIH with BHA #2 on 3 -1/2" Drill Pipe from 2,936 -ft. Set C-4) 7 -5/8" RBP at 6,158 -ft (Element at 6,151 -ft) release off RBP. Up wt 107k, Dn wt 68k 02:00 03:30 1.50 6,158 6,158 COMPZ RPCOM PRTS P Rig up test equipment. Pressure test 7 -5/8" casing 1500 psi x 30 minutes, good. test charted. Did not set test plug, not having to chase leaks. Rig down test euipment. Re- engage RBP and let equilize. 03:30 09:00 5.50 6,158 0 COMPZ RPCOM TRIP P TOOH with RBP / Test Plug assembly, single out 63 joints, standing back 42 stands 3 -1/2" Drill Pipe for next job, lay down BHA #2. 09:00 11:00 2.00 0 0 COMPZ RPCOM PULD P Load ESP Completion. 11:00 12:00 1.00 0 0 COMPZ RPCOM PUTB T Wait on Wind to lay down for Crane to swap out ESP spools. 12:00 13:00 1.00 0 0 COMPZ RPCOM PULD P PJSM. Un -load and Load ESP Spool 13:00 14:00 1.00 0 0 COMPZ RPCOM PULD P Change Out Floor Equipment and Clean Area for Running ESP Completion. 14:00 14:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Running Completion. Review Running Order and Tally for Completion. 14:15 20:00 5.75 0 89 COMPZ RPCOM ALFT P Check Cable Integrity. PU Motor centralizer, MGU and ESP Motor and check rotation. PU GRU and check rotation and assembly the gear reduction unit to the motor section and service same. RU cable sheave and motor cable. PU & MU TTC assembly to seal section with Protectolizers installed. Lower assembly into well, install Welllift gauge unit and connect the TEC wire from motor gauge. Check cable integrity. 20:00 00:00 4.00 89 2,714 COMPZ RPCOM RCST P Continue to RIH w/ remainder of ESP completion as designed to Weatherford Hydrow II Feed -thru Packer checking power cable every 1000 -ft Page 4 of 7 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/25/2012 24 h S umma ry Splice cable through packer. Run 3 -1/2" completion as designed. Splice cable at tubing hanger. Land P 9 p P 9 P 9 9 completion. RILDS. PT hanger pack -offs. Check Cable integrity. RU Slickline. Freeze protect tubing. Set WRP & catcher. RD Slickline. Load IA. 00:00 04:00 4.00 2,714 2,714 COMPZ RPCOM OTHR P _Splice cable through Weatherfotrd Feed -thru packer. check cable integrity. 04:00 08:30 4.50 2,714 6,117 COMPZ RPCOM RCST P Continue to RIH w/ remainder of ESP completion as designed checking power cable every 1000 -ft. 08:30 11:30 3.00 6,117 6,117 COMPZ RPCOM PULD P Check ESP cable integrity. PU Hanger and Make Final Splice to Penetrator. 11:30 13:00 1.50 6,117 6,153 COMPZ RPCOM THGR P Land Completion. RILDS and Pt lower and upper pack -off seals to 5000 psi. MIRU Slick -line Unit and Load Tools and Lubricator to Rig Floor 13:00 13:45 0.75 6,153 6,153 COMPZ RPCOM FRZP P MIRU LRS. PJSM. Discuss Hazard for High Pressure Operation. Line Up LRS pump and Circulate 50 bbls of Diesel down the 3 1/2" Tubing at 2 bpm, 550 psi. 13:45 23:30 9.75 6,153 6,153 COMPZ RPCOM SLKL P PJSM. RU SLick -line. MU & RIH for Drift / Tie -in run for setting WRP at bottom GLM at 3,543 -ft SLM (3,552 -ft RKB). MU RIH and Set a Weatherford 3-1/2" WRP at 3,576 -ft SLM (3,584 -ft RKB, Middle of the 1st full joint below the bottom GLM set at 3,552 -ft.) RU LRS and PT WRP to 500 psi for 5 minutes, good. MU RIH and Set Catcher (29" oal, 2.80" OD, 3" 'G' F /N) at 3,574 -ft SLM. RDMO Slick -line 23:30 00:00 0.50 6,153 6,153 COMPZ RPCOM CIRC P PJSM- RU LRS and Circulate 120_ bbls of Gelled Diesel down IA, ICP 2 bpm at 400 psi. 03/26/2012 Load IA w/ Gelled Diesel. MIT -IA failed. Confer with town. Bleed IA per decompression schedule. Set TWC. ND BOP. Check motor / cable integrity. NU Tubing head adapter and Tree. PT Tree. Test hanger voids. MIT -IA, passed. Set BPV. Bleed IA per decompression schedule. 00:00 01:30 1.50 6,153 6,153 COMPZ RPCOM CIRC T LRS continue to circulate 120 bbls of Gelled Diesel down IA, transport ran out at 100 bbls, upon further investigation wrong transport hooked up to pump, 100 bbls Neat Diesel pumped. FCP 2 bpm at 1250 psi. Make call to town engineer. PJSM- Swap out transports to 200 bbls Gelled Diesel ordered. 01:30 02:45 1.25 6,153 6,153 COMPZ RPCOM CIRC P PJSM- LRS Circulate 120 bbls of confirmed Gelled Diesel down IA, ICP 2 bpm at 800 psi. FCP 1.9 bpm at 1350 psi, shut down, IA at 825 psi and dropping slowly. Page 5 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:30 0.75 6,153 6,153 COMPZ RPCOM PACK P Line Up LRS and Pressure Up on Tubing to 3900 psi to set Hydmw II � Packer, IA at 700 psi, monitor 20 QO minutes tubing at 3600 psi, IA at 520 psi, bleed tubing down to 0 psi. 03:30 05:00 1.50 6,153 6,153 COMPZ RPCOM PRTS T Line Up LRS and PT IA to 1550 psi for 30 minutes and record on chart, monitor 15 min IA at 1450 psi, 30 min IA at 1350 psi, leak appears to _ bepenetrator,_ fluid i0 stack and bubbling, IA pressure at 1200 psi and slowing down, pressure IA back up to 1550 psi, same linear leak of —100 psi every 15 min. Confer with town engineer. 05:00 08:30 3.50 6,153 6,153 COMPZ RPCOM OTHR T Bleed IA down following the Centilift decompression schedule. 08:30 09:15 0.75 6,153 6,153 COMPZ RPCOM OWFF T Monitor Well For 45 minutes. 09:15 09:45 0.50 6,153 6,153 COMPZ WELCTL PULD T Back out Landing Joint. Install two -way- check. 09:45 10:00 0.25 6,153 6,153 COMPZ WHDBO SFTY T PJSM. Discuss Hazard for Nippling Down BOPE. 10:00 12:00 2.00 6,153 6,153 COMPZ WHDBO NUND T Drain Stack. NDBOP. Check ESP! Motor Cable Integrity. Good Integrity Test. 12:00 13:30 1.50 0 0 COMPZ WHDBO NUND T NU Tubing Head Adapter & Tree. 13:30 14:00 0.50 0 0 COMPZ WHDBO PRTS P Pt Hanger Void / Pack -off to 5000 psi for 30 minutes. Good Test. Fluid Pack and PT Tree to 5000 psi for 15 minutes, Good Test. 14:00 15:00 1.00 COMPZ WHDBO MPSP P Pull TWC and set 3" Type "H" BPV 15:00 18:30 3.50 0 COMPZ WELCTL PRTS P RU LRS and PT IA to 1702 psi, Hanger void 0 psi. 15 min IA 1593 psi, 30 min IA 1550 psi, 45 min IA 1540 psi, 1 hr IA 1520 psi, Hanger void holding 0 psi thru out test. Confer w/ town engineer bumc I 1780 psi, 15 min 1763 psi, 30 min 1748 psi, 45 min 1738 psi, 1 hr 1733 psi, Hanger void holding 0 psi thru out test. Confer w/ town engineer. 18:30 19:00 0.50 COMPZ WHDBO MPSP P PJSM- Bring in BPV liubricator. RU and Lubricate out BPV, 10 psi shown on lubricator gauge, bleed off puff of air, tubing at 0 psi, hanger void holding 0 psi, no change in IA pressure. leave lubricator on to monitor tubing pressure. 19:00 20:30 1.50 COMPZ WELCTL PRTS P New chart put on recorder at 19:00, start MIT -IA at 19:40, Tubing /IA/Hanger Void= 1695/0/0 psi, 15 min T /IA HV= 1690/0/0 psi, 30 min T /IA/HV= 1688/0/0 psi, MIT -IA passed, Confer w/ town engineer, proceed with move to 1D-118. Page 6 of 7 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 COMPZ WHDBO MPSP P Re -dress and Re -set 3" Type "H" BPV. Load out lubrictor 21:00 00:00 3.00 COMPZ WELCTI OTHR P Bleed IA down following the Centilift decompression schedule. 03/27/2012 Monitor well for flow. Make Final ESP motor / cable integrity checks. Prep for Rig Move. RDMO Nordic Rig 3 (Rig released at 02:00) 00:00 00:30 0.50 COMPZ WELCTI OWFF P Monitor well for flow 30 min. no flow at surface. Perform final ESP cable /motor electrical intergirty check. Tests Good. 00:30 02:00 1.50 COMPZ MOVE MOB P Clean Pits. Secure cellar and prep for Rig Move. (Rig released at 02:00 hours) Page 7 of 7 ~~~ Christine Po4el~rtk~el~ 'Jbtn~~zo/ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 To: AOGCC RE : Cased Hale/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj 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 ~~ ,~.~'s , x ^ +'-~; li +:~ 4 ~. ~ ~ ~ ". Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) MTT Report 22-Jun-10 1 D-113 1 Report 50-029-22917-0 MTT Report 23-Jan-10 1 D-123 1 Report 50-029-2291400 Signed Print Name: Date : JUL 2 ~i -20i~J tit ~ ins. s~ilChc3t PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : g~dsanchoraae(a~memoryloa.com WEBSITE : wvvw.memorvlog.com C:~Dxuman~ and Scttings~Dlana Williems~DuktoplTraruntit_Conoco:~iocx • • Memory MegnetiC Thickness Toot Log Results Summary Company: ConocoPhlllips Alaska, Inc. Well: 1 D-113 Log Date: June 22, 2010 Field: West Sak Lag No.: 10646 State: Alaska Run No.: 1 API No.: 50-029-22917-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 188 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 BTC Top Log Intvl.: Surtace Pipet Use: Production Casing Bot. Log Intvl.: 188 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 A4TT 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 188'. Changes in me#al volume are relative to the calibration points at 58' and 136', 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 SHz, 8Hz and 10Hz passes is included in this report. All three passes indicate a significant metal loss feature over the interval 3' - 15', with the 5Hz pass indicating up to 13% relative metal loss, the 8Hz pass indicating up to 8% relative metal loss and the 10Hz pass indicating up to 4°~ relative metal loss. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be mare representative of the relative overall metal loss from the outer concentric string(s) in this interval. A log plot of the entire 5Hz pass is included in this report. Indications of genera( isolated metal loss are recorded throughout the majority of the interval (ogged in the 5Hz pass. An expanded log plot of the top 30' of the 5Hz pass is included in this report as welt. A maximum ~13% circumferential metal loss is indicated in the interval between 3' and 15' in the 5Hz 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 & J. Burton Witness: B. Boehme ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: {281} or (888} 565-9085 Fax: {281} 565-1369 E-mail: PDS@memoryiog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907} 659-2314 a`~`" ~"`sA~~ 5Hz, ~z and 10Hz Delta Metal Thi~iess Passes Overlay a~ ~'~ ~ "' 1 D-113 June 22, 2010 Pn°Aerive Dinynosric Seavitfs Database File: d:iwarriorldata\1d-1131ds1overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Thu Jun 2416:13:35 2010 Charted bY: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 0 Pup Joi 5Hz Delta Metal Thickne: 20 Delta Metal 10Hz Delta Metal Thickness 40 ~1 60 so of 16" a`~~` ~""s'0~ R~rded Magnetic Thickness ~ Data - 5Hz Pass Q°' `'s ti `~ 1 D-113 June 22, 2010 Pn°ACrivt DisynosTic Stnvitcs Database File: d:lwarriorldataltd-1131ds15hzpass.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Fri Jun 25 09:0320 2(710 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness {%} 50 1.8 MTTP01 (rad} 11.8 0 Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 --- - Tree - -, . - - -- -~-_ ~ i 5" Col Delta Metal Thickness Metal Loss Tubing Jt. 1 20 7.625" 5" 40 Tubing Jt. 2 60 Tubing Jt. 3 of 16" Conducta --~ 80 625" Collar A o~E~,wEus Funded 5Hz Pass Magnetic ~ kness Log Data ~ Fc~yG '-t ~ '" 1 D-113 June 22, 2010 PROACTIVE DInElY05TlE SERVICES Database File: d:\warriorldata\1d-1131dslexpanded 5hzpass.db Dataset Pathname: 5HzPass Presentation Format: 18 Dataset Creation: Fri Jun 25 09:03:20 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ftlmin) T ~ -200 -7 MTTP12 (rad) 3 -~ = - - - - - - ~ ~ Tree = -- - ~-1 - - _ - - ~ - _._. I I - .~ i Hanger - ~ 3 " Lin e S pee i ~ d Pup ~ - ~ li ~ ~ ~ ~~ - _ _- T I ~ ~- .5 Co -- llar - - ~ - - ~ I_ . l _ :_. -- ~- Delt a M etal Thi ckness I i ~ - -- -- 13% Metal Loss 10 ~ ~ - ~ - l - - ~ ~ - ~ ~ .~ ~ ~= I I Tubing Jt. 1 20 ~ ~ f I s . t .1 1 I } -5D Delta Metal Thickness {%) 5D 1.8 MTTPD1 (rad) 11.8 0 .` T v~Line Speed (ft/min)^ -200 -7 MTTP12 {rad) 3 CanacoPhillips Alaska, Inc. TUBING (0-6093, OD:3.500, ID:2.992) Production - (0-6851, OD:7.625, ^ Wt:29.70) Gas Lift - MandreWalve 2 (60046005, ~~ 1 _f 1 GAUGE (60846085, OD:5.130) ~~ NIP (6092-6097, OD:4.500) „~,~~s,,, ~; r':.~ ~>, SEAL (6097-6111, OD:5.130) GEARBOX (6111-6124, OD:5.380) MOTOR (61246125, OD:6.800) ~~ GRAVEL PACK (6187-6580, OD:4.500) Pert (6282-6312) KRU 1 D-113 1D-113 API: 500292291700 Well T e: PROD An le TS: de SSSV T e : NONE Ori Com letion: 9/17/1998 An le TD: 24 de 6866 Annular Fluid: 3% KCI Last W/0: 1/12/2006 Rev Reason: PULL ESP ASSEMBLY Reference Lo : 27' RKB Ref Lo Date: Last U date: 5119/2007 Last Ta TD: 6866 ftKB Last Ta Date: Max Hole An le: 66 de 3836 Casin Stri n -ALL Descri tion Size To Bottom TVD Wt Grade Thread Production 7.625 0 6851 4106 29.70 L-80 BTC Conductor 16.000 0 121 121 62.58 H-40 WELDED Tubin Strin -TUBI NG Size To Bottom ND Wt Grade Thread 3.500 0 6093 3421 9.30 L-80 EUE Srd Perforation s Summa Interval TVD Zone Status Ft SPF Date T e Comment 6282 - 6312 3590 - 3617 WS D 30 4 11!10!1998 IPERF 2 1/8" ENERJET, BH; 0 deg hasin 6354 - 6374 3655 - 3673 WS B 20 4 11/2/1998 APERF 2 1/8" ENERJET, BH; 0 deg hasin 6407 - 6427 3702 - 3720 WS A4 20 4 10/27/1998 APERF 2 1/8" ENERJET, BH; 0 deg hasin 6462 - 6482 3752 - 3770 WS A3 20 4 10/15!1998 APERF 2 1/8" ENERJET, BH; 0 deg hasin 6530 - 6547 3814 - 3829 WS A2 17 4 10!9/1998 APERF 2 1!8" ENERJET, BH; 0 deg hasin Gas Lift Ma ndrelsNal ves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 4344 2386 CAMCO KBMG DMY 1.0 BK-5 O.ODO 0 1/12/2006 2 60D4 3342 CAMCO KBMG SOV 1.0 BK-5 0.000 2000 4/28/2006 Other lu s, ui . etc. - GOMPLETION De th TVD T e Descri tion ID 0 0 HEAT TRACE RAYCHEM HEAT TRACE 0.000 6084 3413 GAUGE BAKER GUARDIAN GAUGE 2.892 6092 3420 NIP Slotted ni le 2.880 6097 3424 SEAL Tandem Seal GS63 DB IL H6PFS 0.000 6111 3437 GEARBOX GRU 538 11.42:1.562 0.000 6124 3448 MOTOR Centrilift motor 57 HP 1315!26 KMH w/centralizer 0.000 6187 3504 GRAVEL PACK GRAVEL PACK w/PACKER @6186', SLEEVE @6195', SBE X6197', SCREENS @ 6279'-6820' PLUG 6580' 0.000 ,, ,. _ y,_. ~ ~, v - ~M. ~- '.. ;. r,,~ STATE OF ALASKA ~ I `~'-` ,~ ~ 1r ALASKA OIL AND GAS CONSERVATION COMMISSION '~ ~ ~ ~"~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other ~} Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work:, 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 198-178 / 3. Address: Stratigraphic ^ Service ^ ,6. API Number: P. O. Box 100360, Anchorage; Alaska 99510 , 50-029-22917-00 ' 7. KB Elevation (ft): i ~ ~ ~ ~~ ~i~ ~ ~ 9. Well Name and Number: ' _ t L- ' 1 ; ~, 1 D-113 8. Property Designation: 10. Field/Pool(s): ''~, ADL 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6866' feet true vertical 4120' feet Plugs (measured) 6580' Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 6824' 7-5/8" 6851' 4106' ~pQ ~ ' ~ ggp~~g~ tt(( i ~ "° 2008 Pertoration depth: Measured depth: 6282'-6312', 6354'-6374', 6407'-6427', 6462'-6482', 6530'-6547' true vertical depth: 3590'-3617', 3655'-3673', 3702'-3720', 3752'-3770', 3814'-3829' _ , Tubing (size, grade, and measured depth) 3-1/2", L-80, 6140.2' MD. Packers &SSSV (type & measured depth) gravel pack pkr with SBE 6186' no SSSV 12. Stimulation or cement squeeze summary: S~ 5<~ Sllw-~h? Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to welt operation 118 7 54 -- 162 Subsequent to operation 145 4 46 -- 172 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Jim E nis @ 265- 1544 Printed Name Ji n ~ ~ Title Wells Group Engineer ~®/ d ~ ~ Signature Phone: 265-1544 Date $ ( ' t Pre a b ha Allsu Drake 263-4612 Form 10-404 ed 04/ 0 ~ ~~ t Submit Original Only ~/ ~ ORIGINAL ~_ __ - , , i`4 ~ KU P _ _ _ ~ 1 D-113 ~~~~ ~ ~~~ / Well A_ ttnbutes ' ~ I'I 65.88 6,851.0 Ai ,,.~-:: ~ C002~22917 ~-~ M SST SAK Date AnnotVMViD... Entl D7/6/2008 Maximum mamatlon (-) iota! txptn (nnet (ppm) KB-Grouts Distarge (R) Rig Release Date ,.r ~ _ ,r ~ , c, ~-. - .... ~ ., as ---- 48.01 9/17!1998 ,.~,~.,.. ,~ __ Annotation Depth IRKB) End Date Annotation End Date ~ _ Rev Reason: WORKOVER, set ESP PUMP. GLV C/O 7113/2008 Casing Strings - V Cc. I on (C'.in IC 1 T.-p OMr, ~~tC FtY Ih.. S tL I I, I:C~ tt l tllFla I. f.y on~ Ilcor,L _I_F r.. I ,_I I I ,, L~LLL c L~~,~,1 ~,~ Lo~l LI r r,i nre ~„rL cu rc I rnrr.n Ir ~1 uL„ .~~ trr sal F~ E , I -. , _ e- r --- - - Tubing Strings u _ nl` ICi (in Top IR _ `,r - Ertl .Je lo~~. nr~ri,~n T b f_MS I. ion ,~G. 1 C~ytri tth _ L~rl r II.C~I ir[KE' Y.t Ilt. TULirn; ~.tv_ t -,e ~ ~~ EuC ;(;fir .. a oaeaar~WDl 0./21 I Completion Details HEAT TRACE, 3.02] GAS LIFT, 4,363 T r [Qr C. .~ GAS LIFT, 8,026 suPSroP, fi,060 PACKOFF, 6,063 ESP PUMP, 6,0]0 GAUGE, fi,f02 XO INTAKE, ~> 6,112 r•in a SEAL, 6,7 i6 GEAR BOX, 6,130 MOTOR, 6,131 - :ENTRALIZER, 8,138 IPERF, 8,28243, 3t2 APERF, 6.3548.374 GRAVEL PACK. 6.18] APERF, 6,407-8,427 APERF, 6,462-6,462 APERF, 6.5306.54] Perforations @ 6279'-6820', PLUG @6580' set SURFACE, 06,851 TD, 6,851 Other In Hole (plugs,_euip., Fish, etc.) Top (IU:G) Descnptgn Dunina:nt kua Date ID (rn) 6,060.0 SLIPSTOP ~$LIPSTOP SET ON TOP OF PACKOFF set 7/1212008 17/1212008 Notes: General & Safety Mandrel Details _...... set Depm ~ von Top ITw) Valve I Lateh Size TRO Run Stn I ItucB) (RKB) '. Make Made! OD (in) Type Type lint (psi) Run Date Comm_e_M 1 4,363.5 3,461.8jCAMCO jKBMG 1 DMY BK-1 0 O.~ A12/2008 I ~~ l ConoCa-Philips Time Log & Summary We,~~~, ~~~ R~~°~,n9 Report Well Name: 1 D-113 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept; 7/1/2008 10:00:00 PM Rig Release: 7/6/2008 6:00:00 AM '~ Time Lo s ~_ _-- -- 'Date Frorn To Dur S Depth E. Depth Phase Code Subcode T Comment I 7/01/2008 24 hr Summary Release Nordic Rig #3 @ 21:00 hrs and RDMO 1 D-133 and MIRU on 1 D-113 A~t~lordic Rig #3 on 1 D-113 lad 22'00 hrs. Lubricate out BPV and RU Circulatin lines to kill Tank. 21:00 22:00 1.00 MIRU MOVE MOB P Held PJSM and Move off 1D-133 and MIRU on 1D-113. 22:00 00:00 2.00 COMPZ RPCOM OTHR P Lubricate out BPV and RU Circulatin lines. 7/02/2008 Kill well w/ Filtered 8.6 ppg 6% KCL Sea water. Monitor well -had 100 psi gain. Kill well w/ Filtered 9.3 ppg 6% KCL Sea water. Monitor well -static. Set BPV and ND Tree NU BOPE. Test BOPE @ 250/2,500 psi. 24 hr notice was given to AOGCC @ 11:30 hrs on 7-1-08 and Witness of test was waived by Chuck Scheve 19:00 hrs on 7-1-08. 00:00 03:30 3.50 COMPZ RPCOM OTHR P Load Filtered 8.6 ppg w/ 6% KCL Seawater. Make up hardline, PT all lines to 2,500 si. 03:30 05:30 2.00 COMPZ WELCTL CIRC P Kill well w/ Filtered sea water w/ 6% KCL Reverse circulating staging pump up to 4bpm @ 890 psi ICP, 510 si FCP 05:30 12:00 6.50 COMPZ WELCTL OWFF T Monitor well, SI wellhead 100 psi. Called field eng. and found 2 injectors still on, shut injectors in and wait for well to stabilize while buildin 9.3# KWF and filterin . 12:00 13:00 1.00 COMPZ WELCTL OWFF P Continued monitor well while weighting up and filtering 9.3# brine. Chan ed out ESP s ools. 13:00 15:00 2.00 COMPZ WELCTL CIRC P Reverse circulated 9.3# KWF 3 BPM @ 370 psi. Pumped 280 bbls. until 9.3# all around. SI monitor well, ~ ~ s ti . 15:00 16:00 1.00 COMPZ WELCTL OTHR P Set BPV. BD & RD circ. lines. 16:00 17:00 1.00 COMPZ WELCTL NUND P PJSM. ND tree. 17:00 20:30 3.50 COMPZ WELCTI NUND P PJSM, NU BOPE 20:30 00:00 3.50 COMPZ WELCTL BOPE P Function test BOPE and PT @ 250/2,500 si. 7/03/2008 Continue to Test BOPE @ 250/2,500 psi. Pull POT and BPV. Install ISO sleeve, MU landing jt and BOLDS. Unland han er and reland. RILDS. Circ well w/ hot kill fluid. Pooh and la down ESP Com onents. r ~~ 1 of 4 Time Logs _ _ Date _ From To Dur S. Depth E De th Ph~s~__Code _. Subcode T Comment 00:00 01:00 1.00 COMPZ WELCTL BOPE P Continue to Test BOPE @ 250/2,500 psi. Koomey Drawdown 3,000 psi 1,800 psi after 200 psi in 17 seconds 3,000 psi in 1 minute 32 seconds 4 - N? Bottles 2,200 si 01:00 03:00 2.00 COMPZ RPCOM OTHR P Pull POT, BPV, install ISO Sleeve, MU Landing Jt, BOLDS, Unseat han er 160K, 85K up wt, 55K do wt. Land Han er and RILDS. 03:00 06:30 3.50 COMPZ RPCOM CIRC P RU Circ lines. Pump 245 bbls Hot Filtered 9.3 ppg sea water w/ 6% KCL w/ Safe Surf O down IA @ 3 bpm @ 200 psi taking returns to pit 1. RU to Reverse circ. Pump 245 bbls Hot Filtered 9.3 ppg sea water w/ 6% KCL followed by 35 bbls Cold Filtered 9.3 ppg sea water w/ 6% KCL takin returns to Ti er tank. 06:30 07:00 0.50 COMPZ RPCOM NUND P BD and RD circ. hoses and lines. 07:00 08:00 1.00 COMPZ RPCOM PULD P BOLDS. Pull hanger to rig floor.,, Remove penetrators and test ESP & Heat Trace. LD han er & landin 't. 08:00 22:00 14.00 6,125 41 COMPZ RPCOM PULD P POOH, thread 2 cables over sheave and onto spools. Continue POOH standing back 3 1/2" tubing to pump ass . 22:00 00:00 2.00 41 0 COMPZ RPCOM PULD P Test motor lead, disassemble EPS components. Found shaft parted at the to of U er seal section. 7/04/2008 Clear pipe shed and clean and clear rig floor. MU and Rih w/ Test packer and RBP to 6,150'. Test to 2,500 si. Pooh and la down Test a ui PU ESP Com onents and service. MU motor lead and uardian ua e. 00:00 02:00 2.00 0 COMPZ RPCOM OTHR P Clean floor, Clear pipe shed of old equip. Rack and Tally 5 jts 3 1/2 TBG. Load Packer and RBP. Recovered 20 LaSalle Clamps, 1185 SS bands, 369 -6' Flat Guards, 1 -4' Flat Guard, 31 X-Couplings single CC, 50 XCoupling dual CC, 79-5' CC, 7-4' CC. 02:00 08:30 6.50 0 6,160 COMPZ RPCOM TRIP P p_i____Gn ,~4u Test Pa .k _r an~,RBP Rih w/ Test packer assy on 3 1!2 tbg. to 2094' tagged, Retrievamatic set? Unset and continued in hole 6123', M_U TD, set RBP @ 6160'. Pull 1 jt and attempted to set packer (Retrievamatic) but after several attem is would not set. 08:30 09:30 1.00 6,160 6,161 COMPZ RPCOM DHEO P RU to test 7 5/8" casing &RBP. PT to 2500 psi and chart for 30 min. Test OK. 09:30 10:30 1.00 6,160 6,160 COMPZ RPCOM DHEQ P Bleed pressure. RIH and latched onto RBP and released. (torque 2700 ft/# max ~ r age 2 tsf 4 ~_ a• ~ Time Logs Date From To Dur S. De th E De th Phase Code SufJCOde T Comment 10:30 13:30 3.00 6,160 1,210 COMPZ _ RPCOM TRIP P POOH to 1210' standing back 3 1/2" tubin . 13:30 14:30 1.00 1,210 1,210 COMPZ RPCOM OTHR P Crane arrived and removed old ESP cable, re laced it with new. 14:30 15:30 1.00 1,210 0 COMPZ RPCOM TRIP P Continued POOH standing back completion. LD RBP and test Packer. 15:30 17:30 2.00 0 COMPZ RPCOM OTHR P Load pipe shed with clamps, bands and ESP a ui ment. 17:30 21:00 3.50 0 38 COMPZ RPCOM PULD P PU and Service ESP Components - discharge head flange holes wouldn't line up, swapped out w/ the one ulled from well. 21:00 00:00 3.00 38 38 COMPZ RPCOM OTHR P Install motor lead, Guardian guage and test same. 7/05/2008 Rih w/ ESP Completion. Land hanger, RILDS, Test Hanger seals, ND ROPE NU Tree. 00:00 04:00 4.00 38 2,200 COMPZ RPCOM RCST P Rih w/ ESP Completion to 2,200'._ 04:00 05:00 1.00 2,200 2,200 COMPZ RPCOM CIRC P Circulate 100 bbls of 9.3 ppg w/ 6% KCL filtered Na/CL @ 3 bpm @ 60 si 05:00 14:30 9.50 2,200 6,140 COMPZ RPCOM RCST P Rih w/ ESP Completion f/ 2,200' to 6140'. Heat Trace started at 3000'. Me cables OK. 14:30 17:30 3.00 6,140 COMPZ RPCOM DHEQ P MU tubing hanger. Make final splice of ESP cable, heat trace and TEC wire to penetrators. Count is as follows: 56 -Single Channel Clamps, 92 -Dual Channel Clamps, 446 - 5' Mid joint Cannon Clamps, 2 - 4' Mid joint Cannon Clamps, 2 - 3' Mid joint Cannon Clamps, 7 - Stainless Steel Bands, 2 -Flat Guards, 3 - Protectolizers. 17:30 18:00 0.50 COMPZ RPCOM HOSO P Land Han er. 85k up wt, 60k do wt, 35k block wt. 18:00 20:00 2.00 COMPZ RPCOM OTHR P RILDS, Test upper and lower hanger seals to 5,000 si. Set BPV. 20:00 22:30 2.50 COMPZ RPCOM NUND P Change out LPR's to 2 7/8. ND BOPE 22:30 00:00 1.50 COMPZ RPCOM NUND P Test Penetrators, NU Tree. 7/06/2008 Test Tree, Pull TWC, Freeze protect. Back off well and clean cel-ar w/super sucker. Released Nordic Rig 3 06:00 hrs on 7-6-08. 00:00 02:00 2.00 COMPZ RPCOM SFEQ P Test Tree, Pull TWC w/ Lubricator. 02:00 04:00 2.00 COMPZ RPCOM FRZP P RU Lines, PT @ 2,500 psi, Freeze protect IA w/ 90 bbls @ 2 bpm @ 1,000 psi to 2,646' MD and TBG @ w/ 30 bbls @ 2 bpm @ 1,450 psi. Final Shut in Pressures: 150 psi SICP, 200 si SITP Wage 3 s~f & Time Lis _ _ Date__From To Dur 5. De th_EDepth Phase Cade Subcode T Comment 04:00 06:00 2.00 COMPZ RPCOM OTHR P RD Lines, Set BPV w/ Lubricator, Secure well. Back Rig off and clean cellar w/Super sucker. Nordic Rig 3 was released @ 06:00 hrs on 7-6-08. P~~ ~ cif 4 1 D-113 Pre-Rig Workover Summary DATE SUMMARY 7/12/08 SET 3 1/2 TTC PCP ESP (40.48' OAL) @ 6112' RKB. SET 3 1/2 D&D PACKOFF ASSEMBLY W/ STINGER (92 1/2" OAL) @ 6071' RKB. TESTED PACKOFF TO 1000 PSI GOOD TEST ). PULLED SOV FROM @ 4364' RKB AND SET DGLV. PULLED DGLV FROM 6026' RKB AND SET SOV (STS 2000 # ). SET SLIP STOP ONTOP OF PACKOFF @ 6063' RKB. . . Conocó'Phillips Alaska RECEIVED .JUL 1 0 Z007 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 \ qlß -\ 116 iWLNjID JUL 1 J 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 of approx. 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 Well 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 6/912007 10-1 02 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 619/2007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/912007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/9/2007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 61912007 10-118 197-229 2" na 1 6/9/2007 10-119 197-222 2" na 1 6/9/2007 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 6/912007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 619/2007 10-128 198-133 2" na 1 6/912007 10-129 197-213 2" na 1 6/912007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2001 lD-113 (PTD 1981780) Failed ESP: (another) broken shaft, RWO r... . . Tom & Jim, The ESP failed in West Sak producer 10-113 (PTO 1981780) requiring a RWO to repair the ESP. Slickline diagnostics performed on 5/19/07 found the shaft is not turning, indicating it is broken. The well remains SI while waiting on a RWO to repair. There are no plans to attempt to gas lift this well while waiting on the RWO. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com :){;A!\JNED MAY.. 2 1 2007 From: NSK West Sak Prod Engr Sent: Saturday, May 19, 20074:41 PM To: Jenkins, Lubbie Allen Cc: Selisker, Gary R; Rodgers, James T; CPA Wells Supt; NSK Problem Well Supv; Dinkins, Walter R; Atol, Christopher Gerald; Campbell, Blaine M; Ennis, J J; CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; NSK Centrilift Fld Srv; NSK West Sak Prod Engr Subject: 10-113: (another) broken shaft, RWO required FYI. The "rotational test tool" was run today and it indicates 10-113 has also has broken shaft. We will need a RWO to get this well back online. The shaft breaking event happened on 5/12/2007 (sudden drop in VSO A Phase current, from 50A to 45A). The pump was pulled 5/18/2007 and came out of the hole with a locked rotor. The last rig workover on this well was completed 1/12/06. The well produced -120 bopd at -32% watercut. The "rotational test tool" was pinned to verify that it was properly seated and it was checked for rotation after it was pulled from the well. Let me know if you have any questions. Thanks -Hai Hai Hunt / Pete Nezaticky NSK West Sak Production Engineer ConocoPhiUips Alaska, Inc. Phone: (907) 659-7061 10f2 5/20/2007 9:39 AM - - Jim Ennis Wells Group Engineer Drilling & Wells ConocÓPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 February 22, 2006 Subject: Reports of Sundry Well Operations for 10-113 RECEIVED FEB 2 3 2006 Alaska Oil & Gas Cons. COfJI11ission Anchorage \qc¿-' \Î~ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the West Sak well 1 0-113. If you have any questions regarding this matter, please contact me at 265-1544. J. Ennis Wells Gr up Engineer CPAI Drilling and Wells /',"fr' & ~,S.~\¡;;;;Ç ~\;¡1V"U ~~ ~r-t..,; -. C· ('1ID' e" ,.. IÙ" ',ì (~, i:. c... ,'"' J E/skad - - KECt:IVEU FEB 2 3 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS A h OR\G\NAL nc orage 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 198-178 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 99510 50-029-22917 -00 7. KB Elevation (ft): 9. Well Name and Number: RKB 27' 10-113 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6866' feet true vertical 4120' feet Plugs (measured) 6580' Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' PRODUCTION 6824' 7-5/8" 6851' 4106' Perforation depth: Measured depth: 6282'-6312',6354'-6374',6407'-6427', 6462'-6482', 6530'-6547' true vertical depth: 3590'-3617',3655'-3673',3702'-3720', 3752'-3770', 3814'-3829' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6093' MD. Packers & SSSV (type & measured depth) gravel pack pkr @ 6186' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBOMS 8ft FEB 2 3 1006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation SI Subsequent to operation 102 2 1 - 145 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Jim Ennis @ 265-1544 Printed Name \yi nnis Title ~ Wells Group Engineer L!. Signature ~¿; Phone ,r' ~ <i 6'1 ) J ft,J - (ç- L Y ~:~:red:; h~: IIs~:rake 263-4612 Form 10-404 evised 04/2004 Submit Ori inal Onl g y Perf (6282-6312) GRAVEL PACK (6187-6580, ODA.500) MOTOR (6124-6125, OD6.800) - ....c:~ - GEARBOX (6111-6124. OD:5.380) - - SEAL (6097-6111, OD:5.130) NIP (6092-6097. ODA.500) PUMP (6092-6100. OD:2.880) GAUGE (6084-6085, OD:5.130) .. 6084 6092 6092 6097 6111 6124 6187 3413 3420 3420 3424 3437 3448 3504 NIP SEAL GEARBOX MOTOR GRAVEL PACK BAKER GUARDIAN GAUGE 31/2" GS ,2.88" TTCPCP 80 TP 2000 POGRESSIVE CAVITY PUMP 40' OAL TO-- +3; PACKOFF @ 6024'/SLlPSTOP @6018' SLM ASSEMBLY set 2/4/2006 Slatted nipple Tandem Seal GSB3 DB IL H6PFS GRU 53811.42:1.562 Centrilift motor 57 HP 1315/26 KMH w/centralizer GRAVEL PACK w/PACKER @6186', SLEEVE @6195', SBE @6197' 6279'-6820', PLUG @6580' SCREENS @ 2.880 0.000 0.000 0.000 0.000 Thread EUE8rd_·.~___ ----- Comment 2 1/8" ENERJET, BH; 0 deg phasinQ 2 1/8" ENERJET, BH; 0 deg phasinQ !2 1/8" ENERJET, BH; 0 deg .\ phasinQ 2 1/8" ENERJET, BH; 0 deg ;phasinQ 2 1/8" ENERJET, BH; 0 deg 6530 - 6547 3814 - 3829 Gas Lift MandrelslValves St MD TVD Man Mfr I Man Type V Mfr V Type VOD Latch .--. -.---" Date Vlv Run CmnL WSA2 17 4 1'0/911 998 Gas Lift ndrel/Dummy Valve 2 (6004-6005. OD:5.390) Size 2~_ufi I 1 3.500 ..§.~__~ L Perforations Summa Interval TV Loñë-- I Status 6282-6312 3590~ WSI)'l ¡ 30 4 6354 - 6374 3655 - 3673 ; ---\ÏV~-- ~I' 2õ 4 I i : 6407 - 6427 3702 - 3720 --l A4 I -.' T2õ 4 lu/27i 6462 - 6482 3752 - 3770·' ~- - 20 4 T6hSI1998 Ft l SPF 'r- APERF _ ï2ï1998 APE~F .- 1998 APERF JY~ IPERF Date 110/1998 Production (0-6851, OD:7.625. Wt:29.70) ,~ - ConocoPhiUips Alaska, Inc. RKB Size :-IoQ 7.625 0 1[000 ~-'o__ Well T e: PROD Qriii:Çompletion: 9/17/1998.. :..__ Last W/O: 1/12/2006 i =_Ffef b<1Q Date: ! - :_--==f- . . nu . . __ TO: 6866 ft~êu .. I .___ Mªx.ttole AnQle: : 66º~g.@ 3836 KRU Bottom 6851- 121 - Grade L-80 TVD 4106 121 .AI1Qle @ TS:~_geg @_ AnQle @ TD: i 24 de9..@ 6866 'Rev Reason:¡WORKOVERls,et ESÞ- ASSEMBLY _~:Cãst Update.:. 2/1]/2006 = -.-. .+- ..- 1)-113 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: <'. Date 1/8/2006 1/9/2006 1/10/2006 - - ConocoPhiUips Alaska' ..' Page 1 of 2.. Op'èrations Summa'ry R~port· 1 0-113 10-113 WORKOVER/RECOMP 1/8/2006 1/12/2006 Spud Date: 9/12/1998 End: 1/12/2006 Group: Start: Rig Release: Rig Number: Nabors 3S I. i Sub I From - To + Hours' Code! I Phase ...~-:tm"¡ C.~dej' ... ._~"'.. - 03:30 I 3.50 MOVE MOVE MOVE 03:30 - 06:00 06:00 - 09:00 09:00 - 12:00 12:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:30 02:30 - 06:30 06:30 - 11 :00 11 :00 - 12:00 12:00 - 13:30 13:30 - 19:30 19:30 - 00:00 ! 00:00 - 05:00 05:00 - 09:00 ' 09:00 - 13:00 13:00 - 16:00 Description of Operation~ ....--..... .....---.-.............---.... Pull pipe shed away and spot on other side of 1 D-113. Move pit module away for Carrier to move. Moved Carrier out and away from 2.50 MOVE I MOVE MOVE Moved crane in and picked BOP out from behind the well. Set in behind well #113. Wrap 1 D-134 well head with Herculite and set heater on it.Spot Carrier over well 113, pull forward and layout Herculite for I containment. 3.00 MOVE POSN MOVE Continue to spot rig sub wlpits, pipe shed. Pipe shed hydraulics have some issues. Able to continue after small delay 3.00 MOVE I RURD MOVE Set up handy berm, load pits, start engines and steam. Fire up pipe shed heater. Connect lines. 6.00 MOVE ') RURD MOVE Raise derrick. Pick up sheaves, hang ESP cables. Hook up pump lines for well kill. Prepare for BPV removal. RIG ACCEPTED @ 1500 I hrs. 1/8/2005. 1.00 WELLS~ PLGM DECOMP RU lubricator, pull BPV. 0.50 WELLS~ SFTY DECOMP Pre-job safety meeting lining everyone out on their job duties for well kill. 4.50 WELLS~ KILL DECOMP Opened well 340 psi. Pumped 580 bbls of hot filtered 3% KCL water @ I 4 BPM w/350 psi thru Super Choke to clean up ESP equip. Pumped ~ 281 bbls of 9.6 ppg filtered 3% KCL Brine @ 4 BPM w/21 0 psi. Good 9.6 ppg returns. Shut down check well for press. Well dead. 0.50 WELCT . KILL DECOMP Finish pumping well kill. Verify well dead. 0.50 WELLS PLGM DECOMP Install BPV. 1.50 WELLS PLGM DECOMP ND tree. Install Plug off tool. 4.00 WE LCTJ' BOPE DECOMP II' NU of BOPE, install HCR Kill & HCR Choke wI hoses, Koomey hoses I riser & turnbuckles. Function test BOPE. 4.50 WELCT BOPE DECOMP Test BOPE and chart. Choke manifold, floor valves ets. to 3,000 PSI I I 1200 PSI. 1.00 WELLS1 PLGM DECOMP Pull test dart & BPV and install seal sleave. 1.50 CMPL TN PULD 'DECOMP Pull hanger to floor. 75,000# to pull free of hanger bowl, 55,000 up wt. Take pictures for Anchorage of heat trace boot for penetrator. Lay down landing joint and prepare to POOH. 6.00 CMPL TN PULD DECOMP RU elephant trunk, run rope though sheave, RU Heat Trace spool & rope through sheave. Begin pulling and laying down pup joints. Pick up manual backup for tongs. Thread heat trace onto spool. Install air ¡slips. DECOMP Pull out of hole strapping, drifting tubing, cutting bands and removing clamps while spooling up ESP cable and heat trace. Out with 40 stands at end of report or 2600'. Fluid losses 52 bbls. Approx. 4 BPHI DECOMP Continue to POH with ESP completion. Strapping, drifting, and removing bands and clamps spooling up ESP cable and heat trace. Disconnect lead from pump and spool connector over sheave and tie off in spooler. Break down ESP motor and seal section etc. and put in Centrilift boxes. Clean rig floor. Prep all tools for running back in hole 'with new completion. Accounted for 1,719 bands. Clean floor, lay down old motor. DECOMP Pick up new ESP motor sIn 21 k0069929. Swap out new lower centrilizer with used pUlled previously from well Due to pipe thread i issues. RE-thread ESP cable for completion. Bring in new heat trace to pipe shed. .Recount clamps and bands. Swap out new ESP cable in spooling unit. First loader could not pick weight. DECOMP Plug in ESP cable and install protectalizers. Finish final service on i motor section. Splice on ESP cable landing on pup joint collar above 4.50 CMPL TN] PULD 5.00 WELLS~ PULD 4.00' WELLsl PULD ,DECOMP 4.00 WELLS1 PULD 3.00 WELL,J PULD · Printed: 2/16/2006 220:02 PM e - :. GonocoPhillips Alaska Operations Summary R.eport< Page 2 of 2 .,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-11 3 1 0-113 WORKOVER/RECOMP Start: Rig Release: Rig Number: 1/8/2006 1/12/2006 Spud Date: 9/12/1998 End: 1/12/2006 Group: Date Nabors 3S . I I ' : From - TOI Hours: 'L Code I ~~Je Phase 1<· .. '. Description of Opërations 1 ~~~: ~-f,f ~~~~~~~:~~g I g~g~~ [;i~,,~~;':"g~~~:= o~~~~~;~;~ :~~ ~~~~~~~r tho "Top - I I I· I ] Hat", or lower section of the TIC was bent. At first is was thought that " the ported pup was bent, however the "Top Hat" was actually bent 11 'I' apro x. 3 DEG. At 1730 the decision was made to utilize part of the old I ' TIC with the new TIC. This will take place in Prudhoe @ Baker Machine. I· 00:00 - 06:00 I 6.00 CMPL TN, RUNT CMPL TN 10ld Crossover with new internal parts back on location. Fill hole with 15 I I bbls 9.6 ppg brine and start running in the hole with new ESP BHA and I old tubing 106:00 - 07:30 1.50 CMPL TN OTHR CMPL TN i Crew change. Installation point for heat trace. Bring spool to rig floor I [and install. Swap out camp generators due to gen failure. 07:30 - 09:15 1.75 CMPL TN RUNT [' CMPL TN Continue to RIH with completion as perscribed. ii' 09:15 - 10:00 0.75 WAlTON ORDR CMPL TN lOut of 6' dual channel clamps. Discuss with Anchorge and stores as to I where the others went? After confirmation that clamps are not on . slope---continue to RIH utilizing flat gaurds from 1 D-134 that were , washed and ready for re-use as a back up. Good thinking crew! 10:00 - 12:30 2.50 CMPL TN' RUNT CMPLTN Continue to RIH. Using flat guards and bands. Slow process. 12:30 - 23:30 11.00 CMPLTN RUNT CMPLTN Tower meetin continue to RIH ,23:30 - 00:00 0.50 CMPL TN RUNT CMPL TN Begin to make surface splices and test in preparation for landing ! ! completion 00:00 - 03:30 3.50 CMPL TN, RUNT CMPL TN Continue making surface splices in preparation for landing completion 03:30 - 04:30 1.00 CMPL T~ SOHO CMPL TN Land completing and lock down hanger. 52K up WI. and 30K down WT pack offs tested good 04:30 - 05:00 0.50 WELLS PLGM' CMPL TN Pull landing jt and set two way check ND BOP's 05:00 - 14:00 9.00 WELLS NUND CMPL TN I Begin nipple down proceedures. Empty pits. 14:00 - 14:20 0.33 WELLS SEQT CMPL TN Raychem test of heat trace successful. 14:20 - 17:00 CMPL TN Tree pressure tested and charted to 5,000 PSI. Void tested to 5,000 PSI. Rig released at 19:00 hours on 1/12/2006 2.67: WELLSl SEQT ..----...... 1/10/2006 1/11/2006 1/12/2006 Printed: 2/16/2006 2:20:02 PM ) ) Tom, Here is the well orientation plot for the 1320 requested on 1E-114.. Also, included are the cementing reports for each one of these wells. Six wells were seen'to intersect the 1320 plot: 1E-168 v ~;,~, ö ~.. 7)0 () Î\ ,0 1E-123"f ~Jù'-\ -,0"1 \. ~~~o\OC(\~J <;S"1~ -OL~ 1D-116 '~\~(6- \- ~l.J 1D-113~ '~~-\'L~ lD-1l2 j. i~ <;ç - \ '6:' . 0::-, c 1D-103 ';)'0 ð,,-'Oq (~ -(è~\~~-${<:) ,It S' -0 L\ All the wells had good cementing operations with the exception of 1D-103. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and performed a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 T~~\5 ~ê)c..0M..c:."-\- .r-.1Ú"7 ~,-\ û\ -\~ fAL\4£ \- (}.\~S~s. SrL~ ~ð r \k"LT \I: .~ \\:: - \\~ ,- L~~ ~ - Ld, "1~. \:ð'\\,)\~\J~ \ ~\'- ~c.D'\~ ~ ~ $<L~~' \> '-0-ti:2~r\ "- ,\-~ Vè~F\-\V~ .ç~\ (;..... ~ ~ \ '->~ \"-~ \j'.)(.~c¿)Q ~\-.~\~J '\0 \'Û-0€- 0-c.œp~\Þ \Q \1!'-.:WJfì't ~ ' ß1-1v¿~ ~ ~ ;7-1 t c-O :> SCANNED FEB 1 4 2005 ") , , , ) l v ../ I Kuparuk ID Pad, ID-I03, ID-103 VI I I Ku Kuparuk IE Pad, lE-123, lE-123 V2 I 7000- ANTI-COLLISION SETflNGS 'YPh. .'18111Í1 CQnoco I . IpS 3538 3598 Interpolation Method:TVD Interval: 1.000 Depth Range From: 3478.000 To: 3788.250 MaxÙDum Range: 1376.200 Reference: DeCmitive Survey 1000- I Kuparuk lE Pad, IE-168, IE-168 VI I -if 3598 I Kuparuk ID Pad, ID-112, ID-112V2 l "'/.'1 " , ~ ~', I Kuparuk IE Pad, IE-114, IE-114 l ,'" ", ~~'6'ì , ", ~~'ò \ ' " "~788 ,11'6'6 3778 ,,'ì\ S \.""1'6 .../ \. "J~",,'6 3538 JJ Kuparuk IE Pad, lE-I68, lE-I68Ll V3 P 3~$~ ~ // 6000- 5000- 4000- '"2 ~ 0 0 0 =.. 3000- ..-, ::t 'Ê 0 ~ i3 ::s 0 IJJ 2000- ~ if / 3718 I Kuparuk ID Pad, ID-II6, ID-1l6 V2 l ~) 3658 ", ~1 , t ' ~ .i 3598 ''''~~ ! 718 ! 3538 , 36 "{:;;; J ;78 -IOOO~~~ \~ ~ } . ,.,,;;j~~~~*Î\ . - ~ ~~ '- ., :;:'::',~':¡::.-:,:'::f',:',.(:.',.i'."',:,': ' . ~% ' ,pad"I~-22' IE-22 VI ~'\~ '~' KUTru.,k IE PadJ1lKuparuk IE Pad, IE-33, IE-33 V2 III -' '?' ~ fd ' '" 34" - - ", -2000- "" I ] ruk I~ E-24 ~-24A V] """ I I l I I I I I I I I I f// I I I I I I I I I I I I I I 'I 2oðo 3000 4000 5000 6000 7000 =-- ~478 -~ 0-, / ~ / Circles of 1320' Radius ,'..: . I 8000 -~w .ray-sun ""AI" 'tNt'It --"'VI""""'" W est(- )/East( +) [I OOOft/in] \.1I.\I...........,n... .'u"'"''''''',, ) /D-'//ó ..,-. .,,, ARCO Alaska, Inc. AFC No. I Date AK9581 09/16/98 Well: 1D-113 ') Daily Drilling Report Rpt No 5 Depth (MDITVD) I Rig Accept - hrs 09/12/9804:00:00 6866/4119 Prey Depth MD: 6866 Cum Cost $ 639179 Next Csg: 7 5/8" @ 6970' Progress: 0 Est Cost To Date $ 950000 Shoe Test: N/A Days Since AccepUEst: 4.83 / 5.7 Contractor: PARKER Daily Cost $ 259437 Rig Name: RIG # 245 Last Csg: 16" @ 121' Operation At 0600: Complete Hog-Wash & Freeze Protect Upcoming Operations: N/D Wellhead/Set Tree & BPV MUD DATA MUD TYPE LSND WEIGHT' 9.7ppg VISCOSITY 79sqc PVIYP 32/26 GELS 7/24/ APIWL 5.2 HTHP WL N/Aml/30 min SOLIDS 9.5% HOLE VOLUME 315bbl MBT 15.0 ph 8.5 LGS 8.6% PIT VOL 420 DAILY MUD $525 TOTAL MUD $30452 COMPANY BAROID BHADESCRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: TIME I END 00:00 02:30 02:30 08:30 Rig Relase - hrs: DRILLING DATA BIT DATA EH&S DRlLLS/BOP..DA TA DEPTH BIT NO, BIT NO, INCIDENT LAST BOP/DIVERT LAST BOP/DRILL 6866 N TST 09/09/98 09/16/98 ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 0 06/08/98 09/14/98 PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 300K N SPACE 09/08/98 07/15/98 SOWT TYPE TYPE TYPE FUEL & WATER 105K AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 900 25/45 MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1500 25/45 09/16/98 BBLS TRQ BTM DEPTH IN DEPTH IN . POTABLE WATER 100 0 INJECTION USED - BBLS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 0 1R-18D PERSONNEL DATA PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of 37 3000 III I / 1D-113 PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 6 112131 LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 80° 5.5 I 5.5 I 5.5 I SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 31.85 6611661 Water Base Muds 2320 GPM2 JETS JETS ARCO PERSONNEL 2 489 I 1489 I 11111 II11I 0 0 SPS 1 BIT COST BIT COST CONTRACTOR 32 III 0 PERSONNEL 0 SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 9 III III III 2320 MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 5 9.7111 III III 6280 PERSONNEL TOTAL 48 197/8" BIT, NAVIDRILL, NMS, XO, XO, FRT, MWD, FS, NMS, 3 NMDC, 6 DC, XO, 4 HWDP, Jars (04376-UJ), 40 HWDP DRILLPIPE DATA 1 OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH 1717.09 4 3.34 14 5135 4" F.H. prem 2851.25 4 2.688 29.7 HWDP 4" F.H. prem 1329.93 84.34 HOURS 2.50 OPS CODE CASG HOLE SECT IPHASEOPS PROD Other 08:30 12:00 6.00 3.50 CASG CEMENT PROD PROD Other Casing and Cementing 12:00 12:30 0.50 CASG PROD Other 12:30 14:00 1.50 NU_ND PROD Other 14:00 15:00 1.00 RIGS PROD Other 15:00 16:30 1.50 NU_ND PROD Other 16:30 17:00 0.50 TEST PROD Other 17:00 19:30 2.50 BOPE PROD Other 19:30 00:00 4.50 PL_TBG PROD Other 24.00 Daily Drilling Report: 10-113 09/16/98 I OPERATIONS FROM 0000: 0000 Complete 7 518" Csg., 160 Jts. Hangar & Landing Jt.= (Run csg. slow, no Dn.Wt.) to 6850'. Circ. & Condo Hole & Mud @ 10 BPM 950 PSI=For CmlJob CmlW/Dowell 7 518"= Flush lines W/5bbls H20=Test Lines to 3500#. Test Good= Pump 3 bbls. cell flake= 20bbls pre-flush= 40 bbls spacer@ 10.5#= 578 bbls lead Cml@ 10.5#= drop plug= pump 72bbls tail Cmt@ 15.8#.= Drop plug= pump 20bbls H2O Dowell= 290bbls H2O Rig= Bump Plug & Check float equip.= Cmt. in place 11 :20= Cmt. returns 10.5# to 11.0# Pressure test 7 5/8" Csg. L-80 29.7# to 3000# PSI for 30 min. pressure drop to 2960# psi. UD Landing Jl & Csg. tools= NJD annular wash out bag Set spped head= Test 3000# psi 10 Min. NIU BOP P/U BOP test tools Test BOP All 300# & 3000# Koomi (BOP test witness waived Chuck Sheavey AOGC) PJSM= W/GBR-Parker- ARCO= Rig up to run 3.5" Tbg.= Run 3.5 Tbg. Page 1 09/18/98 FRI 12:36 FAX 907 f )2538 DOWELL-PRUDHOE ~ Dow.11 Cementing Service Report CUstomer ARca ALASKA INO Dowell LOOIItlon 9(15198 Well TVD Wetl LOc8tton (legal) 1D 113 Field FormaUon NamelType Deviation WEST SAK .County 6tatlllProvlhce BHP - Beechey PoInt AK SeMce VIa Rig Name Dr1I*, For Offsho" zone 011 Well Cla.8' o.pttt.1t 0 0 Land New Well Type Oevelopmeht , . PI.st1o Viscosity . Drilling Flu lei Type M"x. Density 0 Iblgsl DepU" 0 0 0 Cp S8fVfoe Une Job Type Cem Sur!ace Casing , Max. AlIOWèd Ann. Pressure WallHead eonneetlon Cementing MaX. AUoMJd Tubing Pl'enu,. 0 psi S4fVloe In structlons 0 psi Top. It 0 0 0 ARCO ALLOCATION $19,271.00 MATERIALS. 5% $39,616.59 TOTAL FIELD EST. $58,687.59 0212-9855 TmtDown " Casing Tubing VoL ) IaI 002 ~ Job Number 20018890 Job start Prudhoe Bay, AK Bit SIZe Well MD 0 Oln Oft Pore Press. Oradlent 0 ft BHST BHOT 08F. 0 o~ CasinglUner Weight, IbIft Orade. Th,...d 0 psi 0 psilft Size. In 0 0 Tubfng/Drill,~lpe S~ In WelØht. Iblft 0 0 Gf8de Thread 0 0 0 O' Perforatiohs/Open Hole Bottom, ft' spf - No. of SÞots 0 0 o. 000 000 Ptsplaooment P--*- Type T0t81 tnterAI 0 It Dlamet... 0 In hoker Óep1h 0 it . OpenHo'- Vol 0 bbt easlna Vol. "nnul.rVoI. 0 bbl 0 bbl 0 bbl 0 bbl Casing Tools - CaslngITublng Secured 0 1 Hole Volume Circulated prtorto caentln9[] squeeze J,ob lift Pressure: psi Shoe Type: SqU*dfI Type Pipe Ftotated 0 Pipe Reclprocate<[] Shoe Depth: Oft Tool 1YP« No. c.ntratIÞra: 0 Top t"uas: 0 ' Bottom Plugs: 0 Siage Tool Type: Too' Depth: Oft Cement HMd Type: stage Tool Depth: Oft T.II Pipe 5Iø: Din Job Scheduled For: Arrtwd 0" location: leave location: Collar Type: Tall PlpeDeptt\: Oft 9/15/98 23:00 9/16/98 12:00 Collar Depth: ft sqz Total Vol: Obbl : ' Fluid Pressures Message Time F1uid Type Rates Volumes Density C02IN2 Fluid Iner. Cum. Casing Tubing 2-4 hr cIoct( Iblgal bpm Þpm ÞÞI bbl psi psi 8:32 0 0 0 0 0 0 0 TEST LINES 3500 PSI 8:35 WATER 8.3 0 1.75 3 0 230 0 START GEL WITH FLAKES 8:36 WASH 8.3 0 5 20 3 500 0 START WASH 8:41 SPACER 10.5 0 6 40 23 740 0 START spACER 8:48 CMT 10.5 0 7 578 63 800 0 START LEAD CMT 9:24 10.5 0 7 0 315 150 0 FLAKES@SHOE 9:25 10.6 0 7 0 318 750 0 WASH@SHOE 9:27 10.5 0 7 0 338 700 0 SPACER@SHOE 9:34 10.5 0 7 0 378 740 0 LEAD@SHOE 9:59 10.5 0 7 0 563 1050 0 500 BBL AWAY 10:10 10.5 0 0 0 641 420 0 DROP BTM PLUG 10:11 CMT 15.8 0 5.76 73 641 '530 0 START TAIL CMT 10:26 15.8 0 0 0 714 50 0 DROP TOP PLUG 1 0:28 WATER 8.3 0 7 20 714 1030 0 START WATER BEHIND , 0:32 0 0 0 0 734 350 0 SHUT DOWN( RIG TO DI,SPlACE 11 :16 0 0 0 0 0 2190 0 BUMP PLUG 11 :16 0 0 0 0 0 0 0 125 BBl CMT. RETURNS RIGS 97 v2.Oø-SR Page 1 of2 ') ) Page 1 of 3 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-113 Common Well Name: 1 D-113 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 . Date From - To Hours Code Sub Phase Code 9/13/1998 00:00 - 10:30 10.50 DRILL DRLG PROD 10:30 - 11 :00 0.50 CIRC PROD 11 :00 - 11 :30 0.50 DRILL DRLG PROD 11 :30 - 12:30 1.00 CIRC PROD 12:30 - 14:30 2.00 TRIP PROD 14:30 - 16:30 2.00 PULD PROD 16:30 - 17:00 0.50 RIGMNT RSRV PROD 17:00 - 17:30 0.50 TRIP PROD 17:30 - 18:00 0.50 PROD 18:00 - 19:30 1.50 TRIP PROD 19:30 - 20:30 1.00 CIRC PROD 20:30 - 00:00 3.50 DRILL DRLG PROD 9/14/1998 00:00 - 20:00 20.00 DRILL DRLG PROD 20:00 - 21 :00 1.00 CIRC PROD 21 :00 - 00:00 3.00 TRIP PROD 9/15/1998 00:00 - 02:00 2.00 TRIP PROD 02:00 - 06:30 4.50 TRIP PROD 06:30 - 1 0:00 3.50 CIRC PROD 10:00 - 12:00 2.00 TRIP PROD 12:00 - 13:30 1.50 TRIP PROD 13:30 - 14:30 1.00 PROD 14:30 - 15:00 0.50 PROD 15:00 - 00:00 9.00 PROD 9/16/1998 00:00 - 02:30 2.50 PROD 02:30 - 08:30 6.00 PROD 08:30 - 12:00 3.50 CEMENT PLUG PROD 12:00 - 12:30 PROD 0.50 12:30 - 14:00 14:00 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 19:30 NUND PROD RIGMNT RSRV PROD NUND PROD PROD PROD 1.50 1.00 1.50 0.50 2.50 WELCTL BOPE 9/17/1998 19:30 - 00:00 00:00 - 02:00 02:00 - 02:30 4.50 WELLSR PROD 2.00 CASE RUNC PROD 0.50 CIRC PROD 02:30 - 06:00 CIRC PROD 3.50 06:00 - 06:30 06:30 - 08:00 TRIP PROD PROD 0.50 1.50 Spud Date: 9/12/1998 End: 9/17/1998 Group: Start: 9/12/1998 Rig Release: 9/17/1998 Rig Number: 245 Description of Operations Drlg 97/8" Hole from 2001' to 3899' ADT = 6.98 hrs. Gas & Oil to suface @ 3840'. Mud weight cut to 8.8 ppg. Circ out gas cut mud Drlg. 97/8" Hole from 3899' to 3994' ADT = .42 hrs Circ & Cond hole for bit trip POOH for bit, Tight from 1150' to 890' (25k over) UD UBHO sub, change bit, reset AKO, DIL LWD info, reprogram tools. Service Rig & Top Drive TI H with bit #2 to 870' Repair clamping cylinders on Iron Ruffneck spinner. Rig Repair Keep up on PM TIH to Bttm. Circ Bttms up, no gas or oil on bottoms up. Drlg 9 7/8" Hole from 3994' to 4563' ADT = 1.96 hrs Drlg 97/8" Hole from 4563' to 6866' ADT = 14.99 hrs Circ & Cond hole for trip TOOH for Hole opener PJSM= TOOH= Down Load Sperry Sun= UD BHA P/U Hole Opener-Bit Sub-2 Stab= TIH= Fill Pipe @ 3551'= Slow No DN WT = Bridges @ 5358' & 5642' Circ. & Condo Mud & Hole TOOH PJSM=Complete TOOH= UD 2 Stab.- Bit Sub- Hole Opener R/U to Run 7 5/8" Csg. PJSM W/GBR-Parker-ARCO Run 7 5/8" Csg.= Circ. Csg. Volume @ 2000' & 4000'= Push & Circ. Csg. in Hole from Base Permafrost Complete 7 5/8" Csg., 160 Jts. Hangar & Landing Jt= (Run csg. slow, no Dn.Wt) to 6850'. Circ. & Condo Hole & Mud @ 10 BPM 950 PSI=For CmtJob CmtW/Dowell 75/8"= Flush lines W/5bbls H20= Test Lines to 3500#. Test Good= Pump 3 bbls. cell flake= 20bbls pre-flush= 40 bbls spacer@ 10.5#= 578 bbls lead Cmt @ 10.5#= drop plug= pump 72bbls tail Cmt @ 15.8#.= Drop plug= pump 20bbls H2O Dowell= 290bbls H2O Rig= Bump Plug & Check float equip.= Cmt in place 11 :20= Cmt returns 10.5# to 11.0# Pressure test 75/8" Csg. L-80 29.7# to 3000# PSI for 30 min. pressure drop to 2960# psi. UD Landing Jt & Csg. tools= N/D annular wash out bag Set spped head= Test 3000# psi 10 Min. N/U BOP P/U BOP test tools Test BOP All 300# & 3000# Koomi (BOP test witness waived Chuck Sheavey AOGC) PJSM= W/GBR-Parker- ARCO= Rig up to run 3.5" Tbg.= Run 3.5 Tbg. Run 3.5" Tbg.= Tag Bottom @ 6770'= Pull up to 6765' Rig uo to displace hole= PJSM W/ARCO,MI,APC,Parker, on displacement procedure Displace & clean hole W/50bbls fresh H20= 50bbls caustic/hogwash= 25bbls sea H20= 33bbls. high Vis. pill= 265bbls sea H20= 290bbls. 3%KCUsea H20= finish W/18 NTU Laydown 20 Jts. of 3.5" tbg. Rig up & freeze protect to 2000' TVD, TMD 3421'= pumped147bbls Printed: 217/2005 9:17:09 AM ) ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 0-113 Common Well Name: 1 0-113 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 9/17/1998 06:30 - 08:00 1.50 PROD 08:00 - 08:30 0.50 PROD 08:30 - 09:30 1.00 NUND PROD 09:30 - 10:30 1.00 PROD 10:30 - 11 :00 0.50 RIGMNT RSRV PROD 12/1/1998 00:00 - 12:30 12.50 NUND CMPL TN 12:30 - 13:00 0.50 CIRC CMPL TN 13:00 - 21 :00 8.00 WELLSR CMPL TN 21 :00 - 21 :30 0.50 CMPL TN 21 :30 - 23:30 2.00 CMPL TN 23:30 - 00:00 0.50 CMPL TN RUNT CMPL TN 12/2/1998 00:00 - 06:00 6.00 CMPL TN RUNT CMPL TN 06:00 - 11 :30 5.50 CMPL TN 11 :30 - 22:30 11.00 CMPL TN 22:30 - 00:00 1.50 WELLSR CMPL TN 2.00 CMPL TN 1.50 CMPL TN 2.50 CMPL TN 0.50 RIGMNT RSRV CMPL TN 5.50 CMPL TN 12/3/1998 00:00 - 02:00 02:00 - 03:30 03:30 - 06:00 06:00 - 06:30 06:30 - 12:00 12:00 - 00:00 12.00 CMPL TN 12/4/1998 00:00 - 03:00 3.00 03:00 - 04:00 1.00 04:00 - 15:00 11.00 15:00 - 17:30 2.50 CMPL TN CMPL TN CMPL TN CI RC CMPL TN Page 2 of 3 Spud Date: 9/12/1998 End: 9/17/1998 Group: Start: 9/12/1998 Rig Release: 9/17/1998 Rig Number: 245 Description of Operations diesel Pick up Tbg. hangar & landing Jt. Land hangar= laydown landing Jt. N/D BOP Install production tree= test Tbg. hangar @ 5000# psi F/15min. Test OK= Test prod. tree 5000#psi F/10min. test OK Cut off drilling line= 90' & slip= (Release Rig @ 11 :OOHrs.= Off Line Power @ 10:00 Hrs.= Move Rig 15' to WeIl1-D 112 Finish testing BOPE = Test rams, choke, manifold to 3500 psi = Test annular to 3000 psi. Witnessed by John Spalding W/AOGCC. CBU = UD hanger & landing jt. POH UD 211 jts 3-1/2" EUE tbg. = Carbolite traces @ connections. Install wear ring, RILDS Test upper & lower Kelly valves 300/3500 psi = Remove drlg n. prfl. from top of Rot. Head & Install Rot. Head insert = Remove Saver Sub from Kelly & align BOPE stack w/table. P/U BHA ( 6-314" mill ) = RIH on 3-1/2" workstring. Continued to RIH w/6-3/4" mill and 3-1/2" tubing. Held PJSM w/ each crew on Rotating Head = Worked on Rotating Head = could not get stripping rubber section to seal off = installed flow rizer. Rotating Head. Incorrect equipment. Rotating head would not function properly. Rig down Rotating Head and locate correct equipment for next well. Started drilling up Carbo lite & circ. @ 6243', drilled out to 6283' by circ. long way when drilling and then reversing to clean up = When reversing, started packing off and losing fluid = Could not reverse, packing off w/ Carbolite & rubber = Could not move pipe without pumping loose. Carbolite. Inefficient hole cleaning while circulating the long way. Hole packing off when reversing. Packing off problem partially due to mill configuration. Get a functioning Rotating Head and change flow configuration in mills. POH UD singles by circ. out, tight hole when not pumping = Circ. long way to keep pipe free. POH circ. singles UD to 5206' See previous comment See previous comment Reverse circ. clean up hole = pipe free. See previous comment See previous comment Completed POH w/mill & tubing to change out mill. See previous comment See previous comment Service rig RIH w/mill w/larger ports and 3-1/2" tubing stopping, reverse circ. clean at 1000' intervals down to 6355'. PU Kelly, cont. to drill out Carbo lite by drilling 30', reversing clean and repeating = When plugging off, rotate until pressure drops and reversing OK = 6533' Continued to drill out Carbolite V6596' reverse out cuttings = surface return line plugged w/Carbolite. Dismantle and clean out plugged line. Carbolite. Surface return line plugged while circulating out proppant. Clean out return line. Consider increasing line size. Continue to drill out Carbo lite down to PBTD 9760'. Circulate out Carbolite and metal shavings clean hole = Circulate 2 hole volumes = 4 NTUs in = 28 NTUs out = recovered approximately 5 cu yrs of Carbolite from well. Printed: 2/7/2005 9:17:09 AM ) ) Page 3 of 3 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-113 Common Well Name: 1 D-113 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 12/4/1998 17:30 - 18:00 0.50 CMPL TN 18:00 - 20:30 2.50 WELLSR CMPL TN 20:30 - 00:00 3.50 CMPL TN RUNT CMPL TN 12/5/1998 00:00 - 02:30 2.50 TRIP CMPL TN 02:30 - 07:30 5.00 SUN CMPL TN 07:30 - 11 :00 3.50 CMPL TN 11 :00 - 12:00 12:00 - 12:30 12:30 - 00:00 1.00 WELCTL BOPE CMPL TN 0.50 CMPL TN 11.50 CMPL TN RUNT CMPL TN 12/6/1998 5.00 CMPL TN RUNT CMPL TN 00:00 - 05:00 05:00 - 09:30 4.50 CMPL TN RUNT CMPL TN 09:30 - 17:30 8.00 CMPL TN RUNT CMPL TN 17:30 - 18:00 0.50 RIGMNT RSRV CMPL TN 18:00 - 00:00 6.00 CMPL TN RUNT CMPL TN 1217/1998 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 03:00 0.50 CMPL TN SOHO CMPL TN 03:00 - 07:30 4.50 NUND CMPL TN 07:30 - 09:30 2.00 NUND CMPL TN 09:30 - 10:30 1.00 CMPL TN 10:30 - 12:00 1.50 MOVE RURD CMPL TN Spud Date: 9/12/1998 End: 9/17/1998 Group: Start: 9/12/1998 Rig Release: 9/17/1998 Rig Number: 245 Description of Operations Blow down and stnd back. POOH stnd back workstring = LD BHA P/U and RIH with 3-1/2" L-80, 9.3#. EUE drifted wi wireline re-entry guide wlstop in the bottom. P/U drift & RIH w/3-1/2" 8rd Mod. tubing to approx.6000' R/U wireline equip. = Run 2.80" drift . Slickline stuck 2.80" drift coming out at 1545' = Could not work loose = could not pump out or around = Cut slickline at surface = POH cutting wire every 90' and LD = Retrieved drift with metal debris from Perf. guns on top of it, sticking in tubing. Perforation Gun Debris. Stuck 2.80 inch drift @ 1545 ft while POOH. Improve hole cleaning. C/O Flow Rizer. Pull Wear Ring M/U ESP & I wire = 2 - 10' pups - 2 jts 3-1/2" tbg.= Set pump wlslickline & test to 3000 psi for 15 min. = RIH wIESP, cable & 3-1/2" tubing = started running Heat Trace cable 3' up on jt # 100. ESP cable test showed power line went to ground = POOH stand back tbg. = Visual inspect, found cable damaged at flat cable at pump ( hole worn in cable from slack). Damaged ESP power cable while RIH. Cable installed wi slack near the pump causing the damage. Pull completion assembly back out of the hole. Repair cable and install correctly. Pump checked OK = Replaced flat cable and resplaced =M/U to pump, put flat guards over flat cable on pump to protect from wear = Test cable, I line, OK. Damaged ESP. See previous comment See previous comment RIH w/ESP, 3-1/2" tubing, & cable = test cable every 1500' Service Rig = PJSM on running ESP. Continued to RIH w/ESP, cable, 3-1/2" tbg, & started heat trace 3' from pin end on jt # 100 = Space out & preped for splace = up wt= 75K, dwn wt= 30K. M/U ESP splice to Penetrator - Meg test continuity = Band top of heat trace. Land tubing hanger & RILDS = Install BPV. NID BOPE = Clean pits = N/U tree = install test plug, test tree, tighten packott nuts, tighten top flange on tree = test good to 250/5000 psi = Pull test plug. R/U circulating equip. in cellar = pump 175 bbls diesel dwn ann. = up 3-1/2" tubing for freeze protection. Let diesel swap = SICP- 220 = SITP = 230 psi Prepare to move rig from 113 to 112. Printed: 2/7/2005 9:17:09 AM ) ConocJP'hillips Alaska ') P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 t~'~'1'fb November 21,2004 NOV 2 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find two 10-404 Report Of Sundry Operations reports for wells 1D-113 and 1D- 141. The reports regard operations performed after approval to gaslift producing wells with failed ESPs. Please let me know if you have any questions regarding the reports. Sincerely, ~--Ic~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachments SCANNEr:!! NOV 2 4 2004 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 2004 NOV 2 REPORT OF SUNDRY WELL OPERATIONS ", co ~: Stimulate tJ Waiver D Abandon D RepairWell D Alter Casing D Pull Tubing D Change Approved Program 0 Operat. ShutdownD 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 112' 1. Operations Performed: 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth measured 6866' 4120' true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR PRODUCTION Length Size 121' 6739' 16" 7-5/8" Perforation depth: Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic D D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 198-178 1 6. API Number: 50-029-22917 -00 Exploratory D Service D 9. Well Name and Number: 1 0-113 10. Field/Pool{s): Kuparuk River Oil Field 1 West Sak Oil Pool feet feet Plugs (measured) Junk (measured) feet feet MD TVD Burst Collapse 121' 6851' 121' 4106' Measured depth: 6530'-6563',6462'-6482',6407'-6427', 6354'-6374', 6282'-6312' true vertical depth: 3814'-3844',3752'-3770',3702'-3720', 3655'-3673', 3590'-3617' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6206' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X Oil-Bbl 143 Not yet available RBDMS BFL NOV 2 :' 'ir~,~ Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 21 38 Casinq Pressure 200 Tubinq Pressure 167 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 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: 304-393 Contact MJ Loveland/Brad Gathman Printed Name Jerry Dethlef~ Signature ç~ C-~ Form 10-404 Revised 04/2004 WDSPLD Title Phone 907-659-7224 Problem Well Supervisors Date // Ä/./~ ý' ORtG\NAL Submit Original Only ConocoPhillips Alaska, Inc. West Sak WelllD-113 (PTD 1981780) REPORT OF SUNDRY OPERATIONS November 21, 2004 11/01/04: PULL SLIPSTOP & PACK-OFF @ 6042' SLM. OFF-SEAT PUMP @ 6077' RKB. 11/07/04: PULLED 3.5 ESP PUMP @ 6042'WLM, JOB IN PROGRESS 11/08/04: PULLED 1" SOY @ 6015'RKB, SET 1" X 1/4" OV @ SAME DEPTH 11/17/04: GASLIFT STARTED DOWN WELL. 11/21/04: RATE DATA IS NOT YET AVAILABLE NSK Problem Well Supervisor ~ Œ (ill AI,ASKA. OIL AND GAS CONSERVATION COMMISSION MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk 1D-113 Sundry Number: 304-393 Dear Ms. Loveland: 19~~'17g FRANK H. MURKOWSK/, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~-e' f ! ,/ ' . ~.; /./~ "" Jo ..x.Ñj>ñn~ alrm~ BY ORDER OF THE COMMISSION DATED this.¡q day of October, 2004 Enc!. SCANNEr:. NOV f) 3 2004 STATE OF ALASKA ~ A()¡ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ d- 'ì APPLICATION F?o~~~.~?RY APPROVAlRECEIVED ?~ Operation Shutdown D Perforate D 0 G+iv2 7 ro04Annular Disp. 0 Plug Periorations 0 Stimulate QUaska 011"& ~rfJc. ommis~ñr D Perforate New Pool D Re-enter suspendAW~1i~r~,¡;r 4. Current Well Class: 5. Permit to 'óril~ber: Development - 0 Exploratory D 198-178 Stratigraphic D Service 0 6. API Number: / 50-029-22917-00 9. Well Name and Number: 1 D-113 10. Field/Pool(s): Kuparuk River Oil Field I West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: "-6563',6462'-6482',6407'-6427', 6354'-6374', 6282'-b814'-3844', 3752'-3770', 3702'-3720', 3655'-3673', 3590'-361~ 3-1/2" Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch 0 14. Estimated Date for Commencing Operat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name MJ Loveland./ / / Signature ß7l~7~~ / Commission Use Only Abandon D Alter casing D Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Suspend 0 Repair well D Pull Tubing 0 1. Type of Request: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 112' 8. Property Designation: ADL 25650, ALK 468 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 6866' 4120' Casing Length Size CONDUCTOR PRODUCTION 121' 6739' 16" 7-5/8" October 31,2004 Date: MD 121' TVD 121' 6851' 4106' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: . Oil 0 GasD WAG D GINJ 0 Contact: Title: Phone 659-7224 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: -r",-\,,:> O\>Ç>'()~(},. \ Q'4-~\ \\(.. S \0 /~\ - U <.0. Subsequent Form Req . ed: ~C) '-\ Approve . -~ Form 10-403 Revised 12/2003 ORIGINAL fØ)MS Bfl COMMISSIONER BY ORDER OF THE COMMISSION INSTRUCTIONS ON REVERSE Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 6206' Service 0 Plugged D WINJ D Abandoned 0 WDSPL 0 MJ Loveland/Brad Gathman Problem Well Supervisors Date -:Z5-~C-J I> Y Sundry Number: 30Lj.-313 MO'I 0 1 Date: 1~1/ D'f Submit in Duplicate ConocoPhillips Alaska, Inc. West Sak WelllD-113 (PTD 1981780) SUNDRY NOTICE 10-403 VARIANCE REQUEST October 24, 2004 The purpose of this Sundry Notice is for approval to produce ConocoPhillips' West Sak welllD- 113 on gaslift. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. ID-113 produced via ESP post workover in 9/28/99 until 10/12/04, at which time diagnostics confinned the ESP had failed due to electrical grounding downhole. The AOGCC was notified of the failure 10/14/04. The tubing is configured with one gaslift mandrel at 6015' RKB (3351' TVD). Gaslift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gaslift valve. All production from the well will be through the tubing to surface facilities. Since there will not be annular flow with this configuration, supplemental corrosion/erosion inspections will not be undertaken. The latest production test on 10/11/04 (ESP production) recorded 162 BOPD, 45 BWPD (22% WC), and 56 MSCF of gas. Attached is a wellbore diagram of the well. ConocoPhillips proposes that: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. NSK Problem Well Supervisor 'MUR PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Frac String [ 1 D-113 (0-6206, .1 API: 500292291700 00:3.500, SSSV Type: NONE 10:2.992) . Annular Fluid: 3% KCI Production Reference Log: (0-6851, Last Tag: 00:7.625, Last Tag Date: Wt:29.70) Casing String - ALL Description Conductor : Production I Tubing String - ALL I Size I Top ! 3.500 0 : Perforations Summary Interval TVD 6282 - 6312 3590 - 3617 + 6354 - 6374 3655 - 3673 6407 - 6427 3702 - 3.720 6462 - 6482 3752 - 3770 6530 - 6547 3814 - 3829 KRU 1 D-113 Well Type: PROD Orig Completion: 9/17/98 Last W/O: 9/28/99 Ref Log Date: TD: 6866 ftKB Max Hole Angle: 66 deg ~ 3836 Angle ~ TS: deg ~ Angle ~ TD: 24 deg @ 6866 Rev Reason: Set SOV by ImO Last Update: 4/23/01 Size 16.000 7.625 Top 0 0 Bottom I 6206 Bottom 121 6851 Wt Grade Thread 62.58 H-40 WELDED 29.70 L-80 BTC TVD 121 4106 TVD 3521 Wt I Grade I 9.30 L-80 Thread EUE 8rd Zone Status Ft SPF Date Type Comment WSD 30 4 11/10/98 IPERF 2 1/8" ENERJET, BH; 0 deg phasing WSB 20 4 11/2/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing WSA4 20 4 10/27/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing WSA3 20 4 10/15/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing WSA2 17 4 10/9/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing Gas Lift MandrelsNalves i St MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv 11 Mfr Type Run Cmnt 6015 3351 CAMCO KBMM SOV 0.0 0.000 0 4/22/01 2500# Other ()Iugs, equip., etc.) - JEWELRY ! Depth TVD Type Description ID 6077 3406 PUMP CENTRILlFT Retrievable 180ML2000 KUDU pump RESET 3/26/01 0.000 6112 3437 NIP Slotted nipple 2.992 PUMP 6116 3441 SEAL Tandem Seal GSB3 DB IL H6PFS 0.000 (6077~112. 6123 3447 GEARBOX Gear reduction unit 9:1525 Series 0.000 00:2.313) 6124 3448 MOTOR Centrilift motor 57 HP 1315/26 KMH w/centralizer 0.000 6187 3504 GRAVEL 0.000 NIP (6112~116, 00:3.500) SEAL (6116-6123, 00:5.130) J GEARBOX (6123-6124, 00:5.250) Perf (6282-6312) GRAVEL (6187-6580, 00:4.500) G '- """ ~ \a CJ \ S- t:. ~ '< ~ Co \ ~ \.--\ E: b ~ ~ <'oë1()(p To~ '?~~ Q ~d-<6;ð- ~ ~ S \ -\'\1 '0 ~ ,\ç~~\~ ~s d- \ -\~2J ~5<; tJ -\- ~ 2J jJ:t ift1\ ,0 1;;-"" -0'1 1 D-113 failed ESP Subject: 1D-113 failed ESP From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Thu, 14 Oct 2004 19:19:17 -0800 To: tom_maunder@admin.state.ak.us Tom, The ESP on 1 0-113 (PTO 1981780) failed on 10/12/04. This well is SI and has a grounded electrical cable that will require a rig workover to fix the problem. There is a possibility we may want to produce this well using gas lift, if so, I will contact you about getting Sundry approval to produce this well in that manner. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 1 of 1 10/27/2004 12:04 PM /' ."7 --', G6¡?)r~iì.. .. MICROFILMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PA.GE Saved as M:/weepie/microfilrn - m arker. doc .r:!fY ,. ,» "- 198-178-0 KUPARUK RIV U WSAK 1D-113 50- 029-22917-00 PHILLIPS ALASKAINC Roll #1: Start: Stop Roll #2: Start Stop MD 06866 TVD 04120 Completion Date: 12/6/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8774 1,2 SPERRY MPT/GR/EWR4 OH 11/4/98 11/4/98 L DGR/EWR4-MD 1,2 121-6866 OH 11/11/98 11/12/98 L DGR/EWR4-TVD 1,2 121-4119 OH 11/11/98 11/12/98 R SRVY CALC BH 121-6866. OH 3/24/99 3/25/99 R SRVY RPT SPERRY 0-6866. OH 10/13/98 10/14/98 Thursday, January 18,2001 Page 1 of 1 PH., ,.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 June 13,2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1D-113 (198-178) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the ESP operations on the KRU well 1D-113. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEIVED ,JUN 2, 0 2001 Alaska Oil & Gas Cons. Commission Anch~age " STATE OF ALASKA '~-' 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 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 30' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ ~Sp~ 560491, 5959634) 6. Datum elevation (DF or KB feet) RKB 1 12 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-113 At top of productive interval 2378' FNL, 992' FEL, Sec. 14, TllN, R10E, UM At effective depth At total depth 2223' FNL, 4484' FEL, Sec. 14, TllN, R10E, UM (asp's 556576, 5962689) 9. Permit number / approval number 198-178 / 10. APl number 50-029-22917 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 121' 16" PRODUCTION 6739' 7-5/8" 6866 feet Plugs (measured) 4120 feet 6581 feet Junk (measured) 3860 feet Cemented 9 cu yds High Early 578 bbls AS III, 72 bbls Class G Measured Depth True vertical Depth 121' 121' 6851' 4106' Perforation depth: measured 6530'-6563', 6462'-6482',6407'-6427',6354'-6374',6282'-6312' true vertical 3814'-3844', 3752'-3770', 3702'-3720', 3655'-3673', 3590'-3617' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 6132' Packers & SSSV (type & measured depth) No packer No SSSV RECE V£D JUN 2 0 2001 Ala~a Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 166 Subsequent to operation 218 Representative Da y Avera.qe Production or Injection Data Gas-Md Water-Bbl 10 15 36 18 Casing Pressure Tubing Pressure - 204 194 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended_ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Michael Mooney _, Form 10-404 Rev 06/15/88 · Title Staff Engineer Questions? Ca//Mike Mooney 263-4574 · Date ~.A¢/~ // Prepared by Sharon Allsup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 1D-113 Event History 03/21/01 PULLED SLIP STOP & PACKOFF @ 6069' RKB. PULLED SOY @ 6015' RKB. DISPLACED IA W/270 BBLS DIESEL. FREEZE PROTECTED TBG & FLOWLINE.~ [ESP Work] 03/23/01 PULLED CENTRALIFT PUMP @ 6050'WLM~ [ESP Work] 03/25/01 PUMPED TWO STAGE DIVERTED HCL / MUD ACID TREATMENT AT AVERAGE RATE OF 1.4 BPM WITH 900 PSI MAX ON ANNULUS. SAW GOOD RESPONSE FROM FIRST HCL STAGE (ABLE TO INCREASE RATE FROM 1 BPM TO 1.75 BPM AT MAX PRESSURE), SMALLER RESPONSE FROM SECOND STAGE OF HCL (- 03/26/01 SET CENTRALIFT PUMP, PACK-OFF, SLIP STOP @ 6050'WLM. JOB COMPLETE~ [ESP Work] 04/20/01 MILL OUT ICE PLUG. RIH WITH 2.75 CHOMPS MILL TO 6015' SMALL AMOUNTS OF HYDRATES. FREEZE PROTECT WELL. TO REMAIN SHUT IN.~ [Hydrates-lce,CTU] 04/22/01 TAGGED SLIP STOP @ 6043' WLM. REPLACED SOV @ 6015' RKB & PT TBG TO 2000#. GOOD TEST.~ [Tag, ESP Work] Page 1 of 1 6/13/01 PhiLIPS 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-113 (198-178) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the acid treatment operations on the KRU well 1D-113. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEIVED I~AY 0 ~: 2001 Ata~ka 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 Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 30' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM 5. Type of Well: Development __X Exploratow___ Stratigraph lc__ Service__ (asp's 560491, 5959634) 6. Datum elevation (DF or KB feet) RKB 31 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-113 At top of productive interval 2378' FNL, 992' FEL, Sec. 14, T11N, R10E, UM At effective depth At total depth 2223' FNL, 4484' FEL, Sec. 14, T11N, R10E, UM (asp's 556576, 5962689) 9. Permit number / approval number 198-178 / 10. APl number 50-029-22917 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical 6866 feet 4120 feet Effective depth: measured 6581 feet true vertical 3860 feet Plugs (measured) Casing Length CONDUCTOR 121' PRODUCTION 6739' Junk (measured) Size Cemented 16" 9 cu yds High Early 7-5/8" 578 bbls AS III, 72 bbls Class G Measured Depth 121' 6851' True vertical Depth 121' 4106' Perforation depth: measured 6530'-6563',6462'-6482',6407'-6427',6354'-6374',6282'-6312' true vertical 3814'-3844', 3752'-3770', 3702'-3720', 3655'-3673', 3590'-3617' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 6132' ~ackers & SSSV (type & measured depth) No packer, No SSSV RECEIVED MAY 0 5 2001 A/~ka Oil 8, Gas Cons. Commission Ar~hocage 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 173 Subsequent to operation 122 Representative Da y Avera,qe Production or Iniection Data Gas-Mcr Water-Bbl 37 14 13 13 Casing Pressure Tubing Pressure - 217 172 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /¢.j¢ .//¢¢, _(,r~ -i-itle Staff Engineer Michael Mooney , ~ Date Prepared '~, OS~aron Al/sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date comment · ~ --,1D-113 Event History 03/25/01 PUMPED TWO STAGE DIVERTED HCL / MUD ACID TREATMENT AT AVERAGE RATE OF 1.4 BPM WITH 900 PSI MAX ON ANNULUS. SAW GOOD RESPONSE FROM FIRST HCL STAGE (ABLE TO INCREASE RATE FROM 1 BPM TO 1.75 BPM AT MAX PRESSURE), SMALLER RESPONSE FROM SECOND STAGE OF HCL (- Page 1 of 1 5/2/01 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-113 (Permit No. 98-178/399-178) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the Report of Sundry Well Operations for the recent workover operations on KRU 1D-113. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor Kuparuk Drilling ORIGINAL GCA/skad STATE OF ALASKA ..... ALASI/-~A 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 elavation (DF or KB feet): ARCO Alaska, Inc. Development ~ 31' Nordic RKB 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: 31' FNU 597' FEL, Sec. 23, T11 N, R10E, UN 1D-113 At top of productive interval: _. 9. Permit number/approval number: 2378' FNL, 992' FEL, Sec. 14, T11N, R10E, UN -~"- 98-178/399-178 At effective depth: 10. APl number: 50-029-22917 At total depth: 11. Field/Pool: 2227' FNL, 797' FWL, Sec. 14, T11N, R10E, UN Kuparuk River FieldWest Sak Oil Pool 12. Present well condition summary Total Depth: measured 6866' Plugs (measured) Baker bridge plug @ 6581' true vertical 4120' Effective Deptt measured 6581' Junk (measured) true vertical 3860' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 121' 121' Surface 6810' 7.625" 578 bbls AS III & 6851' 4106' 72 bbls Class G Production Liner Perforation Depth measured 6530'-6563', 6462'-6482', 6407' -6427', 6354'-6374', 6282'-63~2.' true vertical 3814'-3844', 3752'-3770', 3702'-3720', 3655'-3673', 3590'-36f?' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Baker 7.625" SC-1 packer @ 6187', No SSSV ~,~ ~' ' 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A ~ ~'~: ~:i.: 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 _~ Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. !Signed ~ 1~ (f~.~' Title: ~'~.t:,'~ Form 104'~04 Rev 06/15/88 SUBMIT IN DUPLICATE, Date: 10/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS --_ -- WELL:iD-113WO RIG:NORDIC 3 WELL_ID: 999408 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:09/20/99 START COMP:09/19/99 FINAL: WI: 0% SECURITY:0 AP1 NUMBER: 50-029-22917-00 09/19/99 (C1) TD: 6851' PB: 6766' 09/20/99 (C2) TD: 6851' PB: 6766' 09/21/99 (C3) TD: 6851' PB: 6766' 09/22/99 (C4 TD: 6851 ' PB: 6766 ' 09/23/99 (C5 TD: 6851' PB: 6766' 09/24/99 (C6 TD: 6851' PB: 6766' POOH WITH TUBING AND COMP MW: 8.7 KCL SUPV:P. LOCKWOOD/S. GOLDBERG Spot rig over well. Rig accepted 0300 hrs. 9/19/99. Safety meeting. N/D tree. Function test BOPE. POOH WITH MILL MW: 8.7 KCL SUPV:P. LOCKWOOD/S. GOLDBERG Safety meeting. POOH w/3.5" tubing. Wireline retrievable pump stuck in tubing and covered with 20 of sand. Attempt to fish lost bands. RIH w/6.75" mill, drill collars and jars. M/U 6 3/4" MILL - TIH W/S MW: 8.7 KCL SUPV:D. GLADDEN/R. 0VERSTREET Attempt to rev out w/mill, no go. RIH w/fishing tools. Mill and rotate to 6487' w/jet basket. Mill with pump off 6487' to 6491'. Attempt to plug bttm of jet basket w/sand. POH. Recovery with jet basket. TIH w/jet mill, still have possible junk on bttm. TIH W/MULESHOE, AND TANDE MW: 8.7 KCL SUPV:D. GLADDEN/R. OVERSTREET Washed down to 6500'. RIH w/6.75" mill. Drill to 6524' to 6578' Reverse circulate hole clean. Shut down, monitor well, flowing back 5 to 6 gpm gradually slowing down. Worked mill up and down from 6578'-6492', clean. RIH w/ bridge plug. Set bridge plug 0 6578' P/U GRAVEL PACK SCREEN AS MW: 8.7 KCL SUPV:D. GLADDEN/R. OVERSTREET Scheduled safety time out. Tag bridge plug 6581' PJSM. Pump caustic wash down DP. Pump Xanvis high vis pill. Hold scheduled safety time out. P/U ESP PUMP MW: 8.7 SUPV:D. GLADDEN/R. OVERSTREET RIH w/gravel pack screen assy. Set packer. PJSM. KCL Date: 10/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/25/99 (C7) TD: 6851' PB: 6766' 09/26/99 (C8) TD: 6851' PB: 6766' 09/27/99 (C9) TD: 6851' PB: 6766' 09/28/99 (Ci0) TD: 6851' PB: 6766' CHECKING ESP CABLE - WILL MW: 8.7 KCL SUPV:D. GLADDEN/R. OVERSTREET Run ESP motor assembly. Install TTCPCESP, test packoff. PJSM. Start running heat trace along with ESP cable. RIH WITH ESP. MW: 8.7 KCL SUPV:D. GLADDEN/R. OVERSTREET RIH w/3.5" tubing, ESP and heat trace cables. ESP cable test failed. Trouble shoot and determined short somewhere downhole. Pup diesel and seawater. POOH w/ESP completion. Inspect ESP motor leads. RIH w/6.125" magnet, retrieved no bands. RIH w/3 prong wireline grab to 6579' to retrieve bands. INSTALL CONNECTOR ON ESP MW: 8.7 KCL SUPV:D.GLADDEN/R.OVERSTREET Continue to recover bands. PJSM. Run ESP completion. HAVE MOVED RIG TO 1D-108 MW: 8.7 KCL SUPV:D.GLADDEN / S. GOLDBERG Continue to run completion assy, PCESP. N/D BOPs. N/U tree and test to 250/5000 psi. Freeze protect well. Move rig off well. Rig release ~ 1800 hrs. 9/29/99. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Re-enter Suspended weli_ " 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 41 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 31' FNL, 597' FEL, Sec. 23, T11N, R10E, UM 1D-113 At top of productive interval 9. Permit number/approval number 2378' FNL, 992' FEL, Sec. 14, T11N, R10E, UM 98-178 At effective depth 10. APl number 50-029-22917 At total depth 11. Field / Pool 2227' FNL, 797' FWL, Sec. 14, T11 N, R10E, UM Kuparuk River Field / West Sak Oil Pool 12. Present well condition summar Total depth: measured 6866 feet Plugs (measured) 6578' true vertical 4120 feet Effective depth: measured 6766 feet Junk (measured) true vertical 4028 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 9 cu yds High Early 121' 121' Surface 6810' 7.625" 578 bbls AS III, 72 bbls Class G 6851' 4106' Production ORIGINAL Perforation depth: measured 6530'-6563', 6462'-6482', 6407'-6427', 6354'-6374', 6282'-6312' -';: ii"' i;~'' :-:- ,~ .~. :~ ;':- ~"~' true vedical 3814'-3844', 3752'-3770', 3702'-3720', 3655'-3673', 3590'-3617' Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 6206' MD Packers & SSSV (type & measured depth) No packer, No SSSV :~,?~:~-:.~_ 13. Attachments Description summary of proposal ~X Detailed operations program __ BOP sketch ~X 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 15, 1999 16. If proposal was verbally approved Oil ~X Gas~ Suspended Name of approver Date approved Service __ 17. I hereby cedity that the foregoing is true and correct to the best of my knowledge. Questions? Carl Mark Chambers 265-1319 ~Z/~ , Title: Drilling Team Leader Date Signed RandF Thornas ~_~. ~_~.~ '~.. ,~.'rl.~../4~ ,~ Prepared by Sharon AIIsup-Drake ¢' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test__ Subsequent form required lO- Approved by order of the Commission r~,,k,~,.~ U 8hristenson Commissioner Date , ,., Approve~ Returrtec~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE West Sak 1D-113 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH and pull Shear Valve from GLM @ 6089' leaving an open pocket. 2. Set BPV in tubing. Install VR plug in annulus valve. 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. RIH 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 @ +/- 6172' 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. RII,DS, 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 9/3/99 , EST SAK D-113 Worko Proposed Schematic Standard Frac For Sand Control FFSC to FFSCGP ARCO Alaska, Inc. )epths are based on riginal RKB :arker 245 7-5/8" Marker Joint (+/- 50' Above Top Perforation) 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 Port Collar @ .......... 'MD Raychem Heat Trace @ +/- 3016' MD Directional KOP = 250' f~ax Angle = 65.88 Deg @ 3836' Avg Angle Thru W.Sak = 25 Beg 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1/2" x 1" Camco 'KBMM' GLM run open @+/- 5997' MD. After the rig moves off location, the Wells Group will install a Shear Circulating Valve, pinned for 3000 psi Tbg / Csg differentia. I 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. 1 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 I0' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @ +/- 6,112' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift -IFC 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 @ +/- 6172' D-Sand Peris: 4 SPF 6282' - 6312' Frac'd w/Carboiite and Prop Lock B / A4-Sand Peris: 4 SPF 6354' - 6374' / 6407' - 6427' Frac'd w/Carbolite and Prop Lock A3-Sand Perfs: 4 SPF 6462' - 6482' Frac'd w/Carbolite and Prop Lock A2-Sand Perfs: 4 SPF 6530' - 6563' Frac'd w/Carbolite and Prop Lock Top of sand plug @ +/- 6578' PBTD @ +/- 6766' MD 7-5/8" 29.7# L-80 BTC Mod @ +/- 6851' MD TD @ 6866' MD MAC 9/3/99 ARCO Alaska, Inc, Frac String (0-6206, 0D:3,500, tD:2.992) Production (0-685l, OD:7.625. Wt:29.70) Packoff Assy (6139-6147. OD:2.992) PUMP (6i47-6180. OD:2.313) NiP (6180-6184. 0D:3.500) SEAL 6184-6198. OD:5.130) ESF 6199-6206. 0D:6.800) Peff (6282-6312) GKA ID-113 APl: 500292291700 Well Type: PROD Angle ~..~S: deg @ SSSV Type: NONE Orig Completion: 9/17/98 ~.n..~..!~....@ TD:24 deg @ 68~ Annular Fluid: i3% KCI Last W/O: 12/7/98 Rev Reason: Old Perfs & Tag by --SL- ImO Reference Log: Ref Log Date: Last Update: 8/21/99 Last Tag: i6104 TD: 6866 ftKB .................. Last Tag Date: 6/20/99 Max Hole Angle: 66 deg @ 3836 casing String, ALL Size, Top , Bottom , TVD , Wt , Grade , Thread ................. I t 1 ii .......... - 6~.58 H-40 16.000 I 0 121 121 WELDED 7:~ I 0 I 6851 ' 4106 i 29,70 L-80 8TC ........................ ~ubi~g String ,ALL ~ Size I Top I Bottom __J TVD I Wt I Grade"'""'[ ...... Thread ~:~00 I 0 l 6206 ~ 3521 I 9,30 I ...... E-8°~l ~- EUE 8rd perf°rati°n's summary :~iL~ """' -- Interval TVD Zone Status Feet SPF Date Type Comment 6282 - 6312 3590 - 3617 3~ 4 11/10/98 IPERF 2 1/8" ENERJET, BH; 0 deg phasing 6354 - 6374 3655 - 3673 20 4 11/2/98 APERF 2 1/8" ENERJET, BH; 0 d,? phasing 6407 - 6427 3702 - 3720 20 4 10/27/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing 6462 - 6482 3752 - 3770 20 4 10/15/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing 6530 - 6547 3814 - 3829 17 4 10/9/98 APERF 2 1/8" ENERJET, BH; 0 deg phasing Gas Lift NlandrelsNalves §tn '~D TVD IVlan ~r'an V NIfr V Type V OD Latch Port TRO ......... Date vlv Mfr T__~e Run ;eminent 1 6089 3417 CAMCO KBMM CAMco sov 1.0 0.000 0 12/30/98 Other (PlUgS, equipl; etc~) ~ JEWELRY "TrT~:TT Depth TVD Type Description ID 6139 3461 Packoff 1.620 Assy 6147 3469 PUMP CENTRILIFT Retrievable 180ML2000 KUDU pump 0.000 6180 3498 NIP Slotted nipple 2.992 6184 3501 SEAL Tandem Seal GSB3 DB IL H6PFS 0.000 6198 3514 GEARBOX Gear reduction unit 9:1 525 Series 0.000 6199 3515 ESP Centrilift motor 57 HP 1315/26 KMH w/centralizer 0.000 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 24, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-113 (Permit No. 98-178) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-113. If there are any questions, please call 265-6120. Sincerely, T. W. Mc Kay Drilling Team Leader AAI Drilling TWM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~] GAS E~ SUSPENDED [~ ABANDONED~ SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-178 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22917 ,' ............................ ~ 9 Unit or Lease Name 4 Location of well at surface i ¢(~!'~i?! J:~}'!0~'~ ! . 31' FNL, 597' FEL, Sec. 23, T11N, R10E, UM ! ."1,",'!';: i ~lai~., Kuparuk River Unit At Top Producing Intervali ../'_.2-¢_.Z~_~'~_! ~ i 10 Well Number 2227' FNL, 797' FWL, Sec. 14, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71'I 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 12-Sep-98 14-Sep-98 06-Dec-98I NA feet MSL 1 17 Total Depth (MD+'I-VD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6866' MD & 4120' TVD 6766' MD & 4028' TVD YES X~ NO U N/A feet MD 1539 APPROX 22 Type Electric or Other Logs Run GR/Res, GR/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-10 SURF. 121' 24" 9 cu yds. High Eady :h~,iS.g_'.?~ 7.625" 29.7# L-80 SURF. 6851' 9.875" 578 bbls AS III, 72 bbls Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6206' N/A 6530'-6563' MD 3814'-3844' TVD 6462'-6482' MD 3752'-3770' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 6407'-6427' MD 3702'-3720' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6354'-6374' MD 3655'-3673' 'I-VD 6282'-6312', 6354'-6374', see attachments 6282'-6312' MD 3590'-3617' TVD 6407'-6427', 6462'-6482' 4 spf ~6547'-6563' 27 PRODUCTION TEST0RI6iNAL Date First Production3/2/99 Method of OperationFiowing(FIowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FO[~OIk-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 3/8/99 12.00 TEST PERIOB 58 I 66 100 51 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ~ress. 0 0 24-HOUR RATE: 111 6 ~3~ 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 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 6278' 3586' Bottom West Sak Sand 6756' 4019' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge.signed~~~'f/I/t~ t~*~ ~ TitlepreparedL~//~/'/'~~~__--c~~~//~by Name/Number SharonDATEAIIsup~Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-ii3 WELL ID: AK9581 TYPE: -- AFC: AK9581 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/12/98 START COMP:11/30/98 RIG:NORDIC ~ 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22917-00 09/12/98 (D1) MW: 9.5 VISC: 281 PV/YP: 42/50 APIWL: 5.6 TD: 2001' (2001 DRLG AT 3150' SUPV:LUTRICK / HERBERT Move rig from 1D-116 to 1D-113. NU diverter and function test. Drilling 9-7/8" hole from 121' to 2001' 09/13/98 (D2) MW: 9.6 riSC: 236 PV/YP: 44/51 APIWL: 4.8 TD: 4563'(2562 DRLG AT 5500' SUPV:LUTRICK / HERBERT Drilling 9-7/8" hole from 2001' to 3899'. Gas & oil cut to surface @ 3840'. Mud weight cut to 8.8 ppg. Drilling from 3899' to 3994' POOH to change out bit. CBU. No gas or oil on bottoms up. Drilling 9-7/8" hole from 3994' to 4563' 09/14/98 (D3) MW: 9.6 VISC: 320 PV/YP: 45/62 TD: 6866'(2303 RIH W/ HOLE OPENER SUPV:LUTRICK / HERBERT Drillin 9-7/8" hole from 4563' to 6866' APIWL: 4.6 09/15/98 (D4) MW: 9.7 VISC: 237 PV/YP: 45/54 TD: 6866'( 0) CEMENT 7 5/8" CSG. SUPV:CUNNINGHAM/BREEDEN Run 7-5/8" casing. APIWL: 4.0 09/16/98 (D5) MW: 9.7 VISC: 79 PV/YP: 32/26 APIWL: 5.2 TD: 6866' ( 0) COMPLETE HOG-WASH & FREEZE PROTECT SUPV:CUNNINGHAM/BREEDEN Complete 7-5/8" casing. Pump cement. NU BOPE and test to 300/3000%. Run 3.5" tubing. 09/17/98 (D6) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 6866' ( 0) RELEASED RIG FROM WELL 1D-113 @ 11:00 HRS. 5.29 DAYS SUPV:CUNNINGHAM/BREEDEN Run 3.5" tubing. Pump caustic/hogwash. Freeze protect. N/D BOP, install tree and test to 5000~ psi. Release rig @ 1100 hrs. 9/17/98. Move to well 1D-112. Date: 1/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:ID-ii3 WELL ID: AK9581 TYPE: -- AFC: AK9581 STATE:ALASKA 22917-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/12/98 START COMP:11/30/98 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029- 11/30/98 (C7) TD: O' PB: O' 12/01/98 (C8) TD: O' PB: O' 12/02/98 TD: 0' PB: 0' C9) 12/03/98 TD: 0' PB: 0' Cl0) 12/04/98 TD: 0' PB: 0' Cll) TESTING BOPE. MW: 8.7 BRINE SUPV:M.C. HEIM Move rig from 1D-126 to 1D-113. Accept rig @ 0700 hrs. 11/30/98. N/D tree, N/U BOPE. DRILLING OUT CARBOLITE W/ MW: 8.7 SUPV:RICK OVERSTREET Finish testing BOPE. Pull 3.5" tubing. RIH w/mill. SW POH TO 5206 WHERE PIPE CA MW: 8.7 SW SUPV:RICK OVERSTREET RIH w/6.75" mill and 3.5" tubing. Worked on rotating head, could not get stripping rubber section to seal off, installed flow rizer. Started drilling up carbolite and circ @ 6243', drilled out to 6283' by circ long way when drilling and then reversing to clean up, when reversing, started packing off and losing fluid. Could not reverse, packing off w/ carbolite and rubber, Could not move pipe without pumping loose. CONTINUE TO CLEAN OUT CAR MW: 8.7 SW SUPV:RICK OVERSTREET Reverse circ. clean up hole, pipe free. RIH w/mill w/larger ports and 3.5" tubing stopping, reverse circ., clean at 1000' intervals. Continue to clean out carbolite by drilling 30', reversing clean adn repeating. RIGGING DOWN SLICKLINE AF MW: 8.7 SW SUPV:RICK OVERSTREET Continue to drill out carbolite from 6596' reverse out cuttings, surface return line plugged w/Carbolite. Dismantle and clean out plugged line. Continue to drill out carbolite to PBTD 9760'. Circulate out carbolite and metal shavings clean hole. RIH w/3.5" tubing. Date: 1/14/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/05/98 (C12 TD: 0' PB: 0' CABLE SHORTED OUT, POH = MW: 8.7 SW SUPV:RICK OVERSTREET RIH w/3.5" tubing. Slickline stuck 2.8" drift coming out at 1545', could not work loose, could not pump out or around. Cut slickline at surface, POH. RIH w/ESP and 3.5" tubing. 12/06/98 (C13 TD: 0' PB: 0' NU TREE AND FREEZE PROTEC MW: 8.7 SW SUPV:RICK OVERSTREET Problems with ESP cable. POOH. RIH w/ESP, and 3.5" tubing. 12/07/98 (C14 TD: 0' PB: 0' MW: 8.7 SW SUPV:RICK OVERSTREET N/D BOPE, N/U tree and test to 250/5000%. Freeze protect well. Release rig @ 1200 hrs. 12/7/98. Date 10/09/98 Upc-o~ming E~] Well Name 1D-113 Job Num 1007981707.6 Service Type ELECTRIC LINE Unit AFC AK9581 0 Prop 18WSTF Uploaded to S Desc of Work PERFORATE "A2" SANDS Supervisor SCHWENDERMAN Contractor Key Person SWS-DECKERT Complete [~ Successful [~ Accident [~ Initial Tbg Press 0 Final Tbg Press 0 Injury E~ Initial Int Csg Press 0 Final Int Csg Press 0 Spill E~ Initial out csg Press 0 Final Out Csg Press 0 Summary RAN PERFORATING ASSEMBLY RUN #1 PERFORATE 7-5/8" CASING FROM 6563' - 6547' (16'). PERFFORATE ASSEMBLY RUN #2 PERF FROM 6547' - 6530' (17'). [Perf] Date printed: 01/14/99 at: 14:10:48 Date 10/10/98 Upcoming Well Name 1D-113 Service Type PUMPING Desc of Work FRACTURE STIMULATE A2 SAND Supervisor JORDAN Complete r-~ Accident ~ Injury ~] Spill ~ Summary Job Num Unit 1010981700.2 Contractor Key Person DS-YOKUM Successful r-] Initial Tbg Press 360 Initial Int Csg Press 386 Initial Out Csg Press 0 AFC AK9581 0 FinaITbg Press 360 Final Int Csg Press 386 Final Out Csg Press 0 Prop 18WSTF Uploaded to S A2 SAND FRAC SCREENED OUT EARLY AT 52,943 LBS TOTAL PROPPANT PUMPED, 37,289 LBS IN PERFS AND 15,654 LBS PROPPAN IN PIPE. ESTIMATED FILL AT 6651', BOTTOM PERFS 6563'. (88' EST RATHOLE) MAX TREATING PRESSURE 6546 PSI. [Frac-Refrac] Date printed: 01114/99 at: 14:12:19 Date 10/15/98 Up~(~ming [~ Well Name 1D-113 Job Num 1007981707.6 Service Type ELECTRIC LINE Unit 8305 Desc of Work PERFORATE A-3 INTERVAL Supervisor LIGENZA Contractor Key Person Complete [~ Successful [~ Accident F-~ Initial Tbg Press 100 Injury E~ Initial Int Csg Press 0 Spill E~ Initial out csg Press 700 Summary SWS-ELMORE PERFORATE A-3 SANDS @ 6462' TO 6482'. 20' X 2 1/8" E J, 4 SPF. O DEGREE PHASE. [Perf] AFC AK9581 0 Final Tbg Press 100 Final Int Csg Press 0 Final Out Csg Press 700 Prop 18WSTF Uploaded to S Date printed: 01/14/99 at: 14:14:23 Date 10/17/98 Well Name 1D-113 Service Type PUMPING Desc of Work A3 ZONE FRAC upcoming Job Num 1010981700.2 Unit Supervisor KRALICK Contractor Key Person DS-YOKUM Complete [~ Successful [~ Accident I~! Initial Tbg Press 133 Injury I--I Initial Int Csg Press 210 Spill I--] Initial Out Csg Press 0 Summary AFC AK9581 0 Prop 18WSTF Uploaded to S Final Tbg Press 120 Final Int Csg Press 620 Final Out Csg Press 0 FRAC A3 ZONE W/50# HEC @ 15 BPM - SCREENOUT W/APPROX. 40 PSI NET PRESS INCREASE - 45,077# OF 16/20 CARBOLITE TOT PUMPED (PROPLOC ADDED @ 3.1# STAGE) - 30,395# IN FORMATION - 14,682# IN PIPE (BEFORE REVERSE OUT) - 6 PPA IN PERFS - PSI (DATAFRAC) - MAX PRESS 5138 PSI DURING BREAKDOWN - BHP~2145 PSI [Frac-Refrac] Date printed: 01/14/99 at: 14:14:53 Date Well Name Service Type Desc of Work Supervisor JOHNS 10/27/98 1D-113 ELECTRIC LINE UpcOming PERFORATE "A-4" SANDS Job Num Unit 1007981707.6 Contractor Key Person Complete [~ Successful [~ Accident [~ Initial Tbg Press 300 Injury E] Initial Int Csg Press 0 Spill r~ Initial Out Csg Press 0 Summary SWS-ELMORE AFC AK9581 0 Final Tbg Press 300 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED "A-4" SANDS 6407' TO 6427' WITH 2-1/8" ENERJET BIG HOLE CHARGES 4 SPF . Prop 18WSTF Uploaded to S Date printed: 0t/14/99 at: 14:16:17 Date 10/28/98 Well Name 1D-113 Service Type Desc of Work Supervisor RIGGS Complete [~ Accident E] Injury ~] Spill ~ Summary FRAC THE A 4 SAN Upc~ing Job Num 1010981700.2 Unit AFC AK9581 0 Prop 18WSTF Uploaded to S Contractor Key Person DS-GALLEGOS Successful [~ Initial Tbg Press 300 Initial Int Csg Press 250 Initial Out Csg Press 0 Final Tbg Press 700 Final Int Csg Press 700 Final Out Csg Press 0 A4 SAND FRAC COMPLETE AS DESIGNED, FINAL TREATING PRESSURE WAS 4054 PSI MAX TREATING WAS 5158 PSI DURING THE 1 STAGE.84076 LBS PROPANT PUMPED W/73462 LBS AND 10 LB TO PERFS LEFT 10614 LBS IN PIPE REVERSED PROP OUT OF TUBIN OF SAND ESTIMATED 6183' MD A4 PERFS 6407' - 6427' SCREENED OUT 22 BBL INTO FLUSH [Frac-Refrac] Date printed: 01/14199 at: 14:17:28 Date 11/02/98 Well Name 1D-113 Service Type ELECTRIC LINE Desc of Work PERF"B" SANDS Supervisor JOHNS Complete Accident E~ Injury Spill Summary PERF'ED "B" SANDS FROM 6354' TO 6374' [Perf] Upcoming Job Num Unit 1007981707.6 Contractor Key Person Successful [~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 SWS-JOHNSON AFC AK9581 0 FinaITbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01114199 at: 15:14:46 Date 11/04/98 Upcoming Well Name 1D-113 Job Num 1010981700.2 Service Type PUMPING Unit Desc of Work WEST SAK B SAND FRAC Supervisor JORDAN Contractor Key Person DS-GALLEGOS Complete [~ Successful Accident [~ Initial Tbg Press 460 Injury r-~ Initial Int Csg Press 330 Spill [~ Initial Out Csg Press 0 Summary AFC AK9581 Prop 18WSTF Uploaded to S Final Tbg Press 0 Final Int Csg Press 330 Final Out Csg Press 0 B SAND FRAC TIP SCREEN OUT WITH 7PPA PROPPANT AT PERFS. 33,284 LBS PROPPANT PLACED IN PERFS, 5400 LBS PROPPANT LEFT IN WELLBORE. ESTIMATED FILL TOP AT 6210'. B SAND PERFS 6354'-6374'. MAX TREATING PRESSURE 4262 PSI. Date printed: 01114/99 at: 15:13:37 Date 11/10/98 UpcJ~ing [~ Well Name 1D-113 Job Num 1007981707.6 Service Type ELECTRIC LINE Unit 2128 Desc of Work PERFORATE D SANDS Supervisor LIGENZA Contractor Key Person Complete [~ Successful [~ Accident E~ Initial Tbg Press 200 Injury F-~ Initial Iht csg Press 0 Spill ~] Initial Out Csg Press 0 Summary PERFORATE FROM 6282' TO 6312'. 4 SPF. 0 DEG. PHASING. TAG FILL AT 6352'. SWS-JOHNSON AFC AK9581 0 Final Tbg Press 200 Final Int Csg Press 0 Final Out Csg Press 0 Prop 18WSTF Uploaded to S Date printed: 01/14/99 at: 15:11:37 Date 11/13/98 Well Name 1D-113 Service Type PUMPING Desc of Work FRAC THE D SAND Supervisor RIGGS Complete [~ Accident E~ Injury r-~ Spill [~ Summary U pCb--ming Job Num 1010981700.2 Unit AFC AK9581 0 Prop 18WSTF Uploaded to S Contractor Key Person Successful [~ Initial Tbg Press 500 Initial Int Csg Press 500 Initial Out Csg Press 0 DS-YOKUM Final Tbg Press 750 Final Int Csg Press 750 Final Out Csg Press 0 PUMPED THE D SAND FRAC PER NEW PROCEDURE. PUMPED 2 PPG TO 10 PPG 16/20 PROP IN 50# HEC GEL PUMPED 104952 LBS P 101908 LBS 10 LB TO PERFS. @ 30 BPM AND A MAX PRESSURE OF 5506 PSI . LEFT3044 LBS IN PIPE EXPECT TAG @ + - 6282 BOH A 2400 PSI. [Frac-Refrac] Date printed: 011t4/99 at: 14:58:31 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00349 Sidetrack No. Page 1 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245. Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#113/C1 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. WELL DATA of 2 Target TVD (F33 Target Coord. N/S Slot Coord. N/S -31.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ ssn- Target Description Target Coord. E/W Slot Coord. E/W -597.00 Magn. Declination 27.390 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 10Oft~ 30m~ 10m~, Vert. Sec. Azim. 308.19 Magn. to Map Corr. 27.390 Map North to: OTHER SURVEY' DATA Survey Survey Incl. Hole Course i Total Coordinate Build Rate i Walk Rate ! Date I Tool I I Vertical --- -- Depth Angle Direction i Length ~TV~D i Section N(+)/S(-) E(+)/W(-) DE Build(+) ~ Right(+) ~ ................. ~__ ....... ~ (FT) (DD) (DD) ~___(_.F!) ....................... , ...................... (FT) (FT) (Per ~00 F'r) Drop (-) ' Left (-) [ I 0'00 I 0.00 I 0'00 0.00 ! 0.00 0.00 0.00 ............. ! .............. TiE IN POINT ................................ 12~~: 121.00 0.00 0.00 ', 121.00 121.00 i 0.00 0.00 [ 0.00 0.00 0.00 i 18"MACH 1C-AKO-1.7deg. ................. ~- ' ~ ....... t + ..................................... f ' [ GYRO SIS ' ' ~ -5.74 2.52 2.50 i 12-SEP-98 i MWD ! 293.38 1 4.04 278.25 ,, 121.38 293.25 4.87 0.59 1 12-SEP-98I MWDI 381.44 6.93 293.42 i 88.06 380.90 ! 12.70 3.14 -13.68 3.64 3.28 i 17.23 12-SEP-98 ! MWDI 472.13 11.42 304.151 90.69 470.41 i 26.95 10.36 i -26.14 5.28 4.95 ! 11.83 ~-- ................................... : ............................... 12-SEP-98 MWD 563.26 17.58 305.27 91.13 558.60 49.72 23.39 -44.86 6.77 6.76 1.23 12-SEP-98 MWD 652.93 23.07 302.83 89.67 642.65 80.76 40.75 -70.70 6.19 6.12 -2.72 -- 12-SEP-98 MWD 743.78 29.02 304.95 90.65 724.24 120.52 63.04 -103.75 6.63 6.55 2.33 12-SEP-98 MWD 833.37 34.96 305.58 89.59 800.19 167.90 90.45 -142.47 6.64 6.63 0.70 12-SEP-98 MWD 924,63 42.42 305.23 91.26 871.37 224.84 123.46 -188.95 8.18 8.17 -0.38 12-SEP-98 MWD 1016.21 48.35 305.85 91.58 935.67 289.93 161.35 -241.96 6.49 6.48 0.88 · o .41 ,. ! ~ 2-sEP-98 MWD 1198.43 58.48 307.67 91.09 1043.65 436.36 249.23 -359.14 5.20 ' 5.15 0.83 ( .' 12-SEP-98 MWD 1288.79 61.04 308.50 90.36 1089.16 514.42 297.38 -420.58 2.94 2.83 0.92 12-SEP-98 MWD 1379.66 61.66 308.44 90.87 1132.73 594.16 346.99 -483.01 0.68 0.68 -0.07 12-SEP-98 MWD 1559.25 64.00 309.~8 ' i 79.59 ' 1214.73 753.90 447.78 -606.96 1.46 1.30 0.75 12-SEP-98 MWD 1840.27 64.88 309.35 281.02 1335.98 1007.34 609.26 -802.40 0.34 0.31 -0.15 13-SEP-98 MWD 2130.27 64.05 309.46 290.00 1460.98 1268.95 775.36 ;1004.59 0.29 -0.29 0.04 13-SEP-98 MWD 2414.50 65.16 311.47 264.23 1 582.89 1525.49 942.00 -1199.90 0.75 0.39 0.71 13-SEP-98 MWD 2695.97 65.75 308.76 281.47 1699.83 1781.35 1188.94 -1395.69 0.90 0.21 -0.96 13-SEP-98 MWD 2982.20 65.33 307.30 286.23 1818.35 2041.88 1267.45 -1600.90 0.49 -0.15 -0.51 ,. 13-SEP-98 MWD 3268.44 65.63 310.63 286.24 1937.17 2302.23 1431.1 9 -1803.35 1.06 O. 10 1.1 6 ._ 13-SEp-98 MWD 3552.56 65.76 310.21 284.12 2054.11 2560.98 1599.08 -2000.48 0.14 0.05 -0.15 i Company ARCO ALASKA. INC. Rig Contractor & No. PARKER DRILLING,CO - #245. Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#113/Cl Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -31.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL I~ ssE~ Target Description Target Coord. E/W Slot Coord. E/W -597.00 Magn. Declination 27.390 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mL-1 lomE] Vert. Sec. Azim. 308.19 Magn. to Map Corr. 27.390 Map North to: OTHER SURVEY DATA i Survey I Survey ! Incl.I Hole I Course Vertical Total Coordinate !1 Build Rate -~ Walk Rate Date i Tool t Depth Angle = Direction t Length TVD Section N(+) / S(-) [ E(+) / W(-) DL B,,uild (,+,) Right (+) Comment ___ i..._T._y_p_e___~ . (__~ I (DD) ! (DD) , (IT) (FT) (Fl') (IT) (Per ~0OFT)~ urop {-) [ Left (-) ._ , , ............................................................... , ,o-SEP-98'. MWD { 4122.18 I 64.93 :, -~i 285.96 2289.33 3O79.6O 1929.24 -2400.63 O.53; -0.33 i, 0.45 8'MACH 1C-AKO-1.4deg. 13-SEP-98 MWD' 4405.00T63.53-i 309.50[ 282.82 2412.28{ 5334.18 2092.38i -2596.21 o.54' -0.50i -0.23 ............................................. -~ ............. ; ............ _ ......................... ............................ ; ..................... i ! ......................... 14-SEP-98 MWD i 4688.74 ! 63.78 307.86 283.74 2538.21 i 3588.43 2251.28 i -2794.70 0.53: 0.09 [ -0.58 i 4977.57 i 64.11 304.59 I 288.83 2665.10 3847.71 2404.5 -3003.98 1.02 ' 0.11 -1.13 14-SEP-98: MWD i. 5165.62 ' 188.05 2751.72 4014.33 2500.30 I -3140.69 1.68 ' -1.64 0.44 14-SEP-98I MWD 5259.20 157.21 i 307.08 93.58 2799.74 4094.58 2547.76 -3205.46 4.36 -4.08 1.77 I _ 14-SEP-98 MWD 5355.53 52.89 / 308.93 96.33 2854.91 4173.52 2596.34 -3267.67 4.75 -4.48 1.92 14-SEP-98 . MWD 5449.02 48.38 I 309.16 93.49 2914.19 4245.77 2641.85 -3323.80 4.83 -4.82 0.25 14-SEP-98 MWD 5545.95 45.85 I 308.97 96.93 2980.15 4316.78 2686.61 -3378.94 2.61 -2.61 -0.20 14-SEP-98 MWD 5641.23 42.90 309.34 95.28 3048.25 4383.39 2728.67 -3430.60 3.11 -3.10 0.39 14-SEP-98 MWD 5735.38 40.00 308.63 94.15 3118.81 4445.70 2767.89 -3479.04 3112 -3.08 -0.75 14-SEP-98~ MWD 5831.47 35.52 308.39 96.09 3194.76 4504.53 2804.52 -3525.06 4.66 -4.66 -0.25 .$EP-98 MWD 5926.46 30.69 308.47 94.99 3274.30 4556.39 2836.75 -3565.70 5.08 -5.08 0.08 i' 14-SEP-98 MWD 6020.94 28.59 307.04 94.48 3356.42 4603.11 2865.37 -3602.62 2.35 -2.22 -1.51 14-SEP-98 MWD 6210.38 25.75 307.55 189.42 3524.92 4689.59 I 2917.76 -3671.43 1.50 -1.50 0.27 14-SEP-98 MWD 6496.79 25.27 308.25 286,43 3783.43 · 4612.94 2993.53 -3768.78 0.20 -0.17 0.24 . 14-SEP-98 MWD 6683.35 24.37 307.29 186.57 3952.76 4691.25 3041.51 -3830.67 0.53 -0.48 -0.51 14-SEP-98 MWD 6798.67 23.85 307.08 115.31 4058.01 4938.35 3069.98 -3868.20 0.46 -0.45 -0.18 14'SEP-98 MWD 6866.~ 23.85 307.08 67.33 4119.59 4965.57 3086.39 -3889.92 0.00 0.00 0.00 PROJ*BHC=4965.61' @ 308.43deg. WELL LOG TRANSMITrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November i 1. 1998 RE: MWD Formation Evaluation Logs 1D-113, AK-MM-80375 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' .Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, .anchorage, AK 99518 1D-113: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22917-00 · ~}11 511 : x TVD Resistivity & Gamma Ray Logs: 50-029-22917-00 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 A Halliburton Company WELL LOG TRANSMITTAL 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-113, AK-MM-80375 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 1 LDWG formatted Disc with verification listing. API#: 50-029-22917-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A nr~_~q~.r In~l L~fH~_q Inn ~nrnn~nv n IR I gl_l I~1 G SEEFRVII~ ~ S 13-0ct-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-113 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 6,866.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) OCT 14 1998 A~aska Oil & Gas ~ori~. 00mmissi0n 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 9, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1 D- 113 ARCO Alaska, Inc. Permit No: 98-178 Sur Loc: 3 I'FNL, 597'FEL, Sec. 23. T11N, R10E. UM Btmhole Loc. 2205'FNL, 737'FWL, Sec. 14. T11N, R10E, UM Dear Mr. McKav: . Enclosed is the approved application for permit to drill thc above referenced well. Thc permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of thc Permit to Drill application for Kuparuk Unit Well No. 1 D-113. Please note that any disposal of fluids generated from this drilling operation xvhich arc pumped down the surface/production casing annulus of a permitted existing well on Drill Site ID 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 for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given ector on the North Slope pager at 659-3607. · David W. Johnston ~ ~~ Chairman ~ - BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game, t labitat Section w/o encl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA ALAS'~oq OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll J lb Type of Well Exploratory Stratigraphic Test 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. RKB 4]', Pad ?]' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 3]' FNL, 597' FEI_,, Sec. 23, Ti ]Iq, R]0R, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2347' FNL, 914' FWL, Sec. 14, TIIN, R10E, UM iD-113 #U-630610 At total depth 9. Approximate spud date Amount 2205' FNL, 737' FWL, Sec. 14, T1 IN, R10E, UM 9/15/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-115 6970' MD 737' @ TD feet 15' @ 100' feet 2560 4205' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 64.65° Maximum surface 1409 psig At total depth ('rVD) 1852 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOl:: 6929' 41' 41' 6970' 4205' 718 Sx Arcticset III & 348 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations· Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet ~~IL~ Casing Length Size Cemented Measured depth Structural Conductor ISn~erframCeediate LPirn°edrUCti°n 0 R I 6! NA L Perforation depth: measured true vertical ~\,,&~.~\\~;~ ~[~/~ 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X '- Ddlling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and~.correc~to the best of my knowledge ...~/,...-...~,~' Signed~~'~'~ ~¢ ~ ~'/~o/~issSeO~i~'~h~ll~w sands Team Leader, Date Permit_Number I APl number [ ~ _ . L I Approval date ~' ... 6, 6'~ I See cover letter for c~ ~7 ?~2 other re mrements 150- z '/7 _1 t " I q Conditions 6f approval Samples required Yes /'~d~)'~ Mud log required Yes Hydrogen sulfide measures Yes /~ Dire'''''''~-' ctional survey required ~ No ~ Required working pressure for BOPE ~ -- · ' 2M ,~'~"~ 5M 1OM 15M Other:. Original Sig ,, by order of Approved by David Ur, J0h[l$[0i-. Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMi~Y3SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen[ Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RIF,~ 41', ?ad 7]' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 31' FNL, 597' FEL, Sec. 23, T1 IN, R10E, LTM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2347' FNL, 914' FWL, Sec. 14, TllN, RIOE, UM 1D-113 #U-630610 At total depth 9. Approximate spud date Amount 2205' FNL, 737' FWL, Sec. 14, T1 IN, R10E, UM 9/15/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-! 15 6970' MD 737' @ TD feet 15' @ 100' feet 2560 4205' 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 64.65° Maximum surface 1409 psig At total depth (TVD) 1852 psig 18. Casing program Setting] Depth size Specifications Top Bottom Quantity of cement Hole Casincj Wei~]ht Grade Coupling Len~lth MD TVD MD 1-VD (include sta~le data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 6929' 41' 41' 6970' 4205' 718 Sx Arcticset III & 348 Sx Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet ,,,,, ,~k (measured) true vertical feet ~ ~,~ Casing Length Size ~' ~" .~'~emented'~T Measured depth True Vertical depth Structural ~,~'~ ,~l~l~~ ~\~\~ Conductor Surface ? ~'~, Intermediate _ ~ Production r' ICATE Liner ~o~' nl ii'bi Perforation depth: truemeasuredvertical I~,~¢,,,~, ~:~.~&~.*~ UUr L,,' 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X Drilling program X Ddlling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and. correct, to the best of my knowledge ....~/,....- /' Signed ~ ' ,/~-.-/~/~ Title Shallow Sands Team Leader ~-"' Co~ssion Use Only Permit_Number __ I APl number~ { ! _ _ I Approval date .., /, .,., ,~ I See cover letter for 50 ~ ~ ~-~ ~ ~ ~' ~ ''~ -~ other requirements ?',t-/7¢' I - .,. . 2'/ I _ Y Y' ?'J I Condi~ior~s of approval Samples required Yes ~ Mud log required Yes sulfide measures Yes N('~o.,,,) Directional survey required ~ No Hydrogen Required working pressure for BOPE 2M //~/~ 5M 10M 15M Other:. r; ..... ina! Signed By ~. t it.j, by order of Approved by David W. Johnston Commissioner the commission Date ,,....,__,. ,_ .~_,, .... Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Devei'~'pment Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 28, 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-113 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 monobore 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-113, such as shallow gas. There have been ten (10) Kuparuk wells and (21) 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, Ibc. 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 15, 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-113 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 SENT BY: 9- 3-~8 : 7:$OAbt : 'ARCO AI_ASKA~ 007 276 7542:# 2/ 6 General Procedure: Drill and Case Plan for..,.West Sak 1D-113 (Cl) Frac-for-Sand Control Producer 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB, Weld landing3 ring on conductor. 2. Move in / rig up drilling rig. Install diverter & func;ion test same. 3. Spud and directionally drill 9 7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in ddll string as required for directional monitoring and formation data gathedng. 4. Condition hole for casing, trip out. 5. Run and cement 7 5/8" 29,7# LB0 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 first stage 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: TAM Port Collar will be placed in the 7 5/8" casing +1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after c~nsulting with the AOGCC. This is based on the cement thickening time and time required to trip i~ the hole and open the Port Collar to perform the second stage cement job. 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 ~nd freeze protect the upper +_2000' with diesel 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig 1D-113 (C1) Page I SG,09/02/98,v1 SENT BY: 9- 3--58 : 7 :-50Alii ; .~.CO ~tI_ASKA~ 907 276 7.542; ~ 3/ 6 Completion Plan for West Sak 1D-113 (C1.) Frac-for-$and Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Ri._q Fracs) General Procedure: Well Preparation 2, Stage 1 3. Rig up frac equipment on well, and pressure test lines and production tree_ Pull back pressure valve, and pressure test tubing and annulus. 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 log results and final completion design strategy. Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with perf 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 1 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. Staae 2 8. Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with peri guns, and position guns on ~epth. 9. Pedorate 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 fmc-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave fmc 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 perfs. Use CTU as required to jet sand plug top to desired PBTD. Sta~ie 3 13. Rig up thru-tubing peri guns for Stage 3 frac job which includes the West Sak A4 and B sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 1D-113 (C1) Page 2 SG,09t02/98,v 1 ~ SF~T BY: ~- 3~.58 : 7 :-50A~ : .~CO AI_ASKA~ 307 27~ 7.54~. ;# 4/ ~ 16. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. Mix epoxy / resin coated proppant and perform fmc-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. 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with peff guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for fmc job. Pressure test lines. Rig up, establist3 injectivity, and perform data frac on Stage 4 interval, 21. Mix epoxy / resin coated proppant and perform fmc-for-sand control fmc job on Stage 4 interval, pumping specified volume cFI proppant_ Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. 22. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. 23. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release fmc, E-line, CTU, and slickline equipment as required. Pvll Deadstring, Clean Out Well, Run ESP and .Pr.~dvctio~n Tubing 24. MIRU completion rig on welt. 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. 25. Pull back pressure valve. 26. Pull tubing hanger and circulate well to clean brine as required. 27. TOH and lay down deadstring. 28. Pick up rock bit a~d casing scraper and TIH with workstring. 29. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. 30. Circulate well to clean brine, TOH with workstring. 31. Pick up Centdlift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. 32. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. 33. 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. 1D-113 (Cl) Page 3 SG,09/02/98,v1 BY' 3- 3--58 · 7:-50~ · AI~CO ALtSKA- 907 276 7.542'# .5/ 6 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production lree. 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 coml~ietion rig has released from the well. 1D-113 (Gl) Page 4 SG,09/O2/98,v1 'SENT BY' B- 3-58 ' 7'50~'~t ' ARCO AL-~SKA-~ B07 276 7542'~ 6/ 6 Four (4) Stage Frac-for-Sar~d Con~ro~ Completion 3-1/2" Produc~o~ Tu~g Casing @ 80' Haychem Heat Tmc~ (through pemuaffmt) Wealhorford Oemoco 754HO 7-5/~ DV $1a~ Collar Stnd. Grade B¥C Thm~r~ (set 44- 200' TVB below p~rrna~rost) Power Cl~b~ for/SP (drcuia~e well for freeze pro~ec~or~ pu~g~ses) ESP Pump Cen~ 7.,5/~ Cas~g MaCfcer J~ir~ 29.7# L-80 BTC-Mod +/- 50, above lop ~erfomtton) 2g,7¢ L-80 BTC-MOD (+/. ~970, MO ! 4~05' TVD) ESP Motor S~tiot~ Cen~dli~ D Sand Frac'd Resin Ooa~t P~r~ Resin Coated Ag Sand Frac'd with Rer, tr~ Coated Proppam A2 Sand Frac'd with RetCh Coaqmd Proppar~ ARCO Alaska, Inc. ASG, 09/02/98, DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-113 (Cl) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Propert7 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 / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' 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-113 (C1) 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. 1D-113 (C1) Page 1 SG,08/28/98,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/h, or 8.2 to 6.8 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 3,595' 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 = (4025ft)(0.46-0.11 psi/fi) = 1409 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' 5/8" 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 7' 5/8" 29.7'# 1_80 BTC casing to be used has a burst rating of 6,890 psi; 7'0 % of this burst rating is 4,823 psi. Drilling Area Risks: Drilling risks in the West Sak 1D-113 (Cl) 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-113 (C1) is WS 1D-115. As designed, the minimum distance between the two wells would be 15.0' at 100' 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-113 (C1) 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. 1D-113 (C1) Page 2 SG,O8/28/98,v.1 O, otod bx ~.~h For: GOLDBERG Date ~ottcd: 24-~u~}-98 Plot R~erence is ~ 10-115/C1 Ve~ ~5. Caard[~t~ ore ~n fe~ reference slot Tree VeH~OI Oepths ore r~ence ~B (P~r~ TD LOCATION: 2205' FNL, 737' FWL SEC. 14, TllN, RIOE Alaska, Inc. Structure : Pad 1D Well: 113 Field : Kuparuk River Unit Location : North Slope, Alaska 4400 4000 I I f Ill, <- West (feet) 3600 5200 2800 2400 2000 1600 ! II I! I ! t I I I f I TD - Casing Pt Bose West Sak Sands TARGET - West Sak A5 ap West Sak Sands End Angle Drop Top Ugnu Sands Begin Angle Drop 308.19 AZIMUTH 4795' (TO TARGET) *** Plane of Proposol*** 400 800 1200 1600 2OO0 2400 28O0 3200 3600 4000 4400 LRKB ELEVATION: 112' K0P TVI)=250 TMD=250 DEP=0 46BEGIN TURN TO TARGET TVD=.333 TMD=333 DEP=3 '~2~.01 BLS: 6.00 deg per 100 ft x.x~1.97 MAXIMUM ANGLE 64.65 DEG B/ PERMAFROST TVD=1651 TMD=2561 DEP=1645 BEGIN ANGLE DROP TVD=2749 TMD=5125 DEP=3962 6i.66 5.3.66 T/ UONU SNDS TVD=2988 TMD=5555 DEP=4.318 45.66 37.66 29.66 END ANGLE DROP TVD=3415 TMD=6091 DEP=4656 T/ W SAK SNDS TVD=5595 TMD=6291 DEP=4724 TARGET A3 TVD=3740 TMD=6453 DEP=4795 TARGET ANGLE 26 DEG i i i i t 400 800 ! 200 B/ W SAK SNDS TVD=4025 TMD=6770 DEP=4934 TD - CSG PT TVD=4205 TM])=6970 DEP=5021 t i i i ! i i ii [ i ~ ]~ t i 1600 2000 2400 2800 3200 3600 4000 z-400 VerticalSection (feet)-> Azimuth 308.19 with reference 0.00 N, 0.00 E from slot #113 ~800 5200 1200 80O 400 0 TARGET LOCATION: 234-7' FNL, 914' SEC. 14, T11N, RIOE TARGET TVD=3740 TMD=6453 DEP=4795 NORTH 2964 WEST 3769 Base Permafrost EOC Begin Turn to Tar( 270 Az SURFACE LOCATION: 31' F~L, 597' F_~L SEC. 23, T11N, RI OE 4O0 5200 F 2800 2400 2OOO 1600 1200 800 4OO 4OO DLS: 4.00 deg per 100 ft Created by finch Dote I~otted: 24-Au(j-g8 Plot Reference ia Ccordinotes ore in fe~ reference aloe ~113. T~e Verticol Oe~t~a~~8 (Park~ i-nRCO Alaska, Inc. Structure : Pad 10 Well: 115 Field : Kuparuk River Unit Location : North Slope, Alaska A I <- West (feet) 240 220 200 180 160 140 120 100 80 60 40 20 0 20 40 60 ! ',, \ ', ~9oo ~ \ I.o~ ~ ; ~oo 4 ", ~ 'k ~ ~ ~ ~ u ~ / / ' ',, ~;ook ~, k ~ ~ =~Ol , ",,~ ", k, ~ L~;oo ~ ?'~" / / ; ' 1600 ',, k '~ ~ ~ 7oo ~ ~ ,' / 1 , "~ k ', ~ ~ ~ 50o ", ',, ~ '~ k ", k ~, ~{ 700 / q,oo~'.,"., , "",. / " " " '"~ ." '",,'"', '", 1200 '"' 800 ~' 800 ''~ 600 "' ~ '" " ~"""-- '"'",'"",, % '"", ~oo / "',,, '~'",,, ....~';o / "-. ". "~ 1200~ '~ uuu k ', k ", ~' ,'] ,' ~/ ~o~ .,.., ,,,..,, ~ ,,,. ~ ,,,, ~ ,,.~oo ,,,,/ ,,,, '~ '-, ", 1500 ',, ',, ~ ".. .,' ," 1500 '-. ', '. ', · ~ "- ~- 600~ ,' 1 .-..-...'... "',,. ,,, , " .... ' '~ ..- 600/ 10 0 200 "" " ' ' ' q "'.. "?<::>. % ~ ~ooN'',~°° ", ~4°t "'-. "',. %1'.. % %700 %",, ~ .~500 / '"-. ',,, ',:;;... % ~ % ',,, x~ 5oo 8 fl% '-., 9oo '-,. '%. % % 8oo% ',, 500, t~ "--.. "~.~ ,ooo N ~;oo "., %".. "., "oI -%'-....... %--",,., ~ ~ '-~;-. ~ '~ ~oo % "-. ,ooo'"'--....... '",..'%. 5 4 . "--....... "..,.. "-.:::;...~o~ "-?oo / ~ '"'... 800 x.x x... -...~ % 1200 '"-. / '~ "---.... "-... ~., ~'- ........ ~oo 60 ~ ~ '"- '", ", "" ........ ~ 1500 ~ ~ 8oo % '-., -,, ',, 4~ 1700 1600 ~]':'-. 700 '"'- 6& 1100 / ~ ~u --... ~ 4o8' ~ ~ oo 4O 2O .... ! 000 1300 600 40 900 ..... 500 ............ ,.800 ..... _7_o0 , , i i i i ' i ' 2~o ' 2~o ' :;o ',~o :~o 14o ~:o 16o <- West (feet) 320 i 500 280 260 240 22O 2OO 180 ~SO 140 ~ 20 ~ 4-0 1200 500 F 1400 '-1.0. 00 F 20 ,, i- 9OO '-~ i 500 r 0 9~o 500 40 20 0 20 4'0 6'0 Creoted by finch Oot¢ p~ottcd: 24-Au~-98 Plot Refer,rice ;I '~rS 10--115/C1 Verb;on ]~5. C~dinote~ or= in f~et reference slot ~113. [Tm~ Ve~icol Oeptns ore r~f~ence ~8 (~orker ~245 : ad 1D Well: 11.3 Field : Kuparuk River Unit Location : North Slope, AlaskaJ <- West (feet) 800 760 720 680 640 600 560520 480 440 400 360 320 280 240 200 I I I I I I I t I I I I I I I r I I I I I I i I I l %% % %0°0% ,.-~. 1200 720 ~ 2000 '"",, '",, "",, '",, 680 ~ "' " " 13o~k,, ,,, "", ~ "",,,,,,,, ~ 680 ,. ' . \'",.., '"',,,, "',,,,, 640 '"'....... ".. '".,.,. '". ",. "~ 1900 "', i- 640 600 ~'/ ''''~ 1900 '. ,,,'"'',,, '"'"'~, 1300 \ ~',. '""'. ' '"", ""~ 1500 '"" ~ i 600 \ i ~ "'. '". "\ 1800 ',; / 560 '"., "', '\,,~ "~ 1100 480 - '-.. '--. 1800 ~ ", ', '\ ", ', / A 1600 t "-.-............ -'--.....,..1.:: 0 0 ',. ',,, j- ",... "-,.. ~17oo ~ I ::r 1 --... --,.. '~- 320 4 1500 "~',. '-,"-%. ~ '-~ / ". '-, '.,", F 320 CD 2so fl '"..1 ~oo "'..j ',. "., '-,", 1600 1300'""'"'"", "i'~iii~!~i~ 240 ........"'""-- 1200"""'.. L 60 160 ................ "'. . ~ ~od"-. oooF 120 -'--.~. 1400 ~.~ ! -""--- ~ 120 80 ~%~L~3300 .2600 ........ .,. 1300 ~ ~ "'~ 2!00 2000 leO0 0 r 80 2500 2400 2300 2~80 3100 ~o ~ 2ob" ........ ~C% ~o 2900 ~ ..... 0 2700--~~ 0 8 0 760 720 680 640 600 580 520 480 ~ 0 4 0 3 0 320 280 240 200 <- West (feet) Creoted by finch 0ate I~otted : 24-Au9-98 P~ot Reference is WS IO-115/C1 Version ~fS. C~ordinate~ are in fee~ reference llot /~'11,~. True Vertica~ Oept~s are refeeence RK8 (Parker ~245). faP, C 0 Alaska, Structure : Pad 1D Well: 1 1.3 Field : Kuporuk River Unit Location : North Slope, Alasko 2OO0 1900 1800 7O0 1600 1500 1400 1300 1200 11oo IOO0 go0 80O 700 600 500 400 300 200 <- West (feet) 21 O0 2000 1900 1800 1700 1600 1500 1400 1300 1200 I 1 O0 1000 900 800 700 600 I I I I I I I I I I I I I I I I I I ! I I I I I I I I ~ i I ~ 2000 '", '"~, 2300 '"' ~ '" L ", " "%, 2100 '"'k 4100 "~ 1800 F 1900 · ,,, ,,,, ,, ~4ooo ,, L 2000 ,.,, ",,, ",,, "~ 3900 ",,, I ',, ", ', ',,,3800 ', I ', ', 2200 ', '. · ,,, ',,, ',., -'~ 3700 \, F1800 "' "' ",,. ~ooo \,;~oo ',, '",, '". ~'., .... % .3500 '"' i700 ~ ',, ,, x ~ r ~7oo 1900 ',, ', ',,. ",., 34-00 ', '",, ",. 21 O0 "",,, "~ 3300 ",, "'...2100 ',,,,,, ",,,,.. ",,,,,,, ~3200 ',,,,,, [ 1600 1800 ',, ", " 100 1500 ~oo"-..:'.,.~ooo~'" '.,,, ,,,~ooo '",, \ ~ooo I- '"':::::"' '"". ""x \'\ "/,, 2900 t 1400 2500"'~-...~ 1 900 1700 ",,. ",.,.. "",,. ~ F '' ", '", '", "I, 2800 ~-"i..~oo '""'%' ",, 'k ~ 9oo ",, 'k,' 1800 %,.%.. ~ 160~"', ", "' .2_30 2300 ", '".~ 1800 ', ..... r~ '""~'""';'.-~. 3-- -.23 , .~ l ouu r I ~ O0 ---..<~200 '"':b. '~. '" ", , i ' 3000 '~:'- ',. ', ', '--~.oO~oo ~oo'::::.._ '~. ', ',, ', r ~ 2800 '"'-'"- "". "- O ,oo ,,, ,. ..-.. ~ '~5oo . .. ~ 2600 '"-]'".. "~ '", '", '-.,"-. ',, ',. 1700 ~-....,_~oo ~,~<:::..... 'N.. .., ... "-~,.oo '"--:::--...~,o'~ ,,. ,,,, ~ ooo ~ "-....'~-.'. ~ ~ '"-.~2100 140{~", '"' ~ 2300 ".. "-. ~ '-, ", '.,. ',,, ? 800 o ~4o6"-.. '"-.. ~ '-~.2000 ".,.. ".... "-,%__ .~2100~ ", ' '"-.~ ......... ..~.o_o._o. ..<~u ---.. -,,,,, ~oo .... 1700 '- .... ..... ":'] .............. ~_~.~oo ~[ ......... ~t~t_ ~oo ........... ...... ' zz"~ 300 ~~ oo --L-7°° '~900 3800 ..... I ........ ~oo ........ ~ 200 2100 2000 1900 !800 1700 i600 1500 !400 t500 1200 i!00 1000 900 800 700 600 <- West (feet) A I Z Created by finch Dote plotted : 24-Au,]-98 P~ot Reference ia WS lO-113/C1 Version ]~5. Ceordinates are fn feet reference slot !True Verlical DeptHs ore reference RK8 (Porker il245). -'ARCO Alaska, in . Structure : Pad 1D Well: 115 Field : Kuparuk River Unit Location : North Slope, Alask( <- West (feet) 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 i 200 ooo 3800 '~ 3700 ", ~- 3800 '.,~ 31 O0'\, "' L '.., 3500 ', ",. '~ 2700 ~6oo ',. "', ',, L 3600 '"'. ' 3300 '", '. ',,...,, b 3400 3400 2900 '", '", ~ "..... '....3100 '"~ 2500 · 3200 -,,,,,, ',, ,,, k 3200 '.. 4100 " '",,~ ¢300 '".. 3900 2700 ~. 3ooo "'-~ 3700 ",.. ',~,29(~'0....~ 3900 '~ 3000 "-~ 3500 "", "". '""-.. 3500 '"-. 3300 '\ ", "-. 3300 2800 '.. "'.. "'\ '"'.~ 3100 2800 "-~. 31 O0 "'..... 2500'"~ '", '"'~ 2900 2600 '-. 2900 '"., 'k 2700 ... "'....... '",. \'. '".. 2700 2600 "'.. ".. '".. 2500 ~ 2400 A 2300 ~. ' / '-,. 2700 IEEE ""-,,, ', ',. 2500 , I 4100 ""-... "-. ". ' '" 2300F 2200 Z 3900' .. '".. '~ 0 3700"".. '"-, 2500 '.. '. ! 3500 "% '-.. '.. ".. '. k -*- 330{~'"'-. '"'.. 2100 ~, "', ". '.. 2300 ( 2000 '"'.. '"-.. 2300 2900'%. "-. ..,,.., ? 18oo "-.:',.. ~goo',,, ~700 '-..'.'-,2100 '%'%.k'~. k ~00 '""-'.-. F "400 2500% ~soo I '"-',, ~ [- %.. %. r- i200 ..~_~.o.o~.~ .~ ,,,~, ~O%o° ......... "-.. 6~oo ........... ~ .... ~ ~ ........ i' oo "'-%6100 .......... 2300 210~-,.~ k ~ 5900 --'- ...... 600 '"-......5700 ........... '"" k 600 -'----~oo .... ~-.~.t_o__o.. L ------~9oo ............ ~oo 400 -I ----dL%~oo .......... i- 400 200 [ , ~ ~ ~ , ~ , ~ , , , ~ ~ j , ~ ~ , , ~ , , , , , J , , , I 200 2400 2200 2000 : 800 ! 600 1400 1200 ~ 000 4200 4000 5800 .3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 ! 600 1400 1200 <- West (feet) "ARCO Alaska, Structure : Pad 1D Well: 115 Field : Kuparuk River Unit Location : North Slope, Alaska ~e ~'~ 0.00 0.~0 H0~ 250.00 0.C0 ~.l.,~n Turn m [~ql 333.3~ 5.~ End of ~u[Id/Tum 134~.45 Ifadof H~ld 5125.09 64.65 }E~ af arop~u~n~gl.3g 26.~ T~rg~ ~ 10-CI ~sd 2 6~2.72 26.~ J End of Held 6769.81 26.~ JT.D. & End ef Hold 696g.81 26.~ WELL PROFILE DATA ~'r 1VD No~h East 0.00 0.00 0.00 270.00250.000.00 0.0(3 270.003.33.23 0.00 -3.83 308.58t l`30.gg 315.65 -448.16 308.582748.67 2445.13 -3117.72 3O8.583415.24 2865.56 -36~.78 3O8.58374O.O0 2964.33 -3768.6~ 3O8.58¢025.O0 3051.02 -3877.27 3O8.584204.76 3105.6g - 394~5.80 V. Sect Oeg/lOa 0.00 O.OO 0.O0 a.oo 2.88 6.00 547.406.00 3g 62.17 0.00 4636.36 4.0O 4794.75 a.ao 4933.7,5 ~.flil 5021.42 0.~3 TRUE NORTH 350 0 10 34-0 20 330 210 soo 11o 320 " 310 500 Created by rfxse For: BRASSFIELD j Dote platted: 24--Au§-q8 Plot Reference ~ WS 1D-113/C1 Vorsic~ i{5. j Tr~e Coordinates ore in feet reference s~ot t{113. I Vertk:al Oe~3ths. ~ere reference RK8 (Porker .~24-5).j 290 70 28O 270 26O 2 0 I + 0 120 i 80 9OO 0 250 240 110 900 Normal 230 f i 220 2O0 160 190 180 !70 Plane Travelling Cylinder- Feet 30 -0 All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 113 slot #113 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : WS 1D-113/C1 Version #5 Our ref : prop2213 License : Date printed : 24-Aug-98 Date created : 17-Apr-97 Last revised : 12-Jun-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 1.011,wi&9 30 36.313 Slot Grid coordinates are N 5959633.681, E 560490.212 Slot local coordinates are 31.00 S 597.00 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G l/ L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 270.00 100.00 0.00 N 0.00 E 200.00 0.00 270.00 200.00 0.00 N 0.00 E 250.00 0.00 270.00 250.00 0.00 N 0.00 E 333.33 5.00 270.00 333.23 0.00 S 3.63 W 400.00 8.46 287.83 399.43 1.50 N 11.21 W 500.00 14.19 297.23 497.45 9.37 N 29.12 W 600.00 20.07 301.24 592.98 23.89 N 54.71 W 700.00 26.01 303.48 684.96 44.90 N 87.71 W 800.00 31.97 304.93 772.39 72.17 N 127.74 W 900.00 37.94 305.96 854.32 105.41 N 174.36 W 1000.00 43.92 306.75 929.84 144.25 N 227.08 W 1100.00 49.90 307.39 998.13 188.27 N 285.31 W 1200.00 55.88 307.92 1058.43 236.97 N 348.41 W 1300.00 61.87 308.38 1110.10 289.84 N 415.69 W 1346.44 64.65 308.58 1130.99 315.65 N 448.15 W 1346.45 64.65 308.58 1130.99 315.65 N 448.16 W 1500.00 64.65 308.58 1196.73 402.19 N 556.64 W 2000.00 64.65 308.58 1410.79 683.96 N 909.89 W 2500.00 64.65 308.58 1624.84 965.74 N 1263.13 W PROPOSAL LISTING Page 1 Your ref : WS 1D-113/C1 Version #5 Last revised : 12-Jun-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 2.86 Begin Turn to Target 6.00 9.74 6.00 28.68 6.00 57.77 6.00 96.65 6.00 145.02 6.00 202.22 6.00 267.67 6.00 340.64 6.00 420.35 6.00 505.92 6.00 547 6.00 547 0.00 686 0.00 1138 0.00 1589 .39 EOC .40 .16 .01 .87 2561.10 64.65 308.58 1651.00 1000.18 N 1306.30 W 0.00 1645.09 3000.00 64.65 308.58 1838.90 1247.52 N 1616.37 W 0.00 2041.72 3500.00 64.65 308.58 2052.95 1529.30 N 1969.62 W 0.00 2493.57 4000.00 64.65 308.58 2267.01 1811.08 N 2322.86 W 0.00 2945.42 4500.00 64.65 308.58 2481.06 2092.86 N 2676.11 W 0.00 3397.28 5000.00 64.65 308.58 2695.12 2374.63 N 3029.35 W 0.00 3849.13 5125.09 64.65 308.58 2748.67 2445.13 N 3117.72 W 0.00 3962.17 5200.00 61.66 308.58 2782.50 2486.80 N 3169.97 W 4.00 4029.00 5300.00 57.66 308.58 2833.01 2540.61 N 3237.42 W 4.00 4115.28 5400.00 53.66 308.58 2889.41 2592.09 N 3301.95 W 4.00 4197.83 5500.00 49.66 308.58 2951.44 2640.98 N 3363.25 W 4.00 4276.24 5555.24 47.45 308.58 2988.00 2666.80 N 3395.62 W 4.00 4317.64 5600.00 45.66 308.58 3018.78 2687.07 N 3421.02 W 4.00 4350.14 5~00.00 41.66 308.58 3091.12 2730.10 N 3474.97 W 4.00 4419.15 5800.00 37.66 308.58 3168.09 2769.89 N 3524.85 W 4.00 4482.96 Base Permafrost BeginAngle Drop Top l/gnu Sands 5900.00 33.66 308.58 3249.33 2806.24 N 3570.41 W 4.00 4541.23 6000.00 29.66 308.58 3334.43 2838.96 N 3611.43 W 4.00 4593.70 6091.39 26.00 308.58 3415.24 2865.56 N 3644.78 W 4.00 4636.36 End Angle Drop 6291.39 26.00 308.58 3595.00 2920.23 N 3713.32 W 0.00 4724.03 Top West Sak Sands 6452.71 26.00 308.58 3739.99 2964.33 N 3768.60 W 0.00 4794.75 TARGET - West Sak A3 6452.72 26.00 308.58 3740.00 2964.33 N 3768.60 W 0.00 4794.75 WS 1D-C1 Rvsd 22-Jan-98 6500.00 26.00 308.58 3782.49 2977.26 N 3784.80 W 0.00 4815.48 6769.81 26.00 308.58 4025.00 3051.02 N 3877.27 W 0.00 4933.75 Base West Sak Sands 6969.81 26.00 308.58 4204.76 3105.69 N 3945.80 W 0.00 5021.42 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #113 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Total Dogleg for wellpath is 104.44 degrees. Vertical section is from wellhead on azimuth 308.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : ws 1D-113/C1 Version #5 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 333.33 333.23 0.00 S 3.63 W Begin Turn to Target 1346.44 1130.99 315.65 N 448.15 W EOC 2561.10 1651.00 1000.18 N 1306.30 W Base Permafrost 5125.09 27%8.67 2%%5.13 N 3117.72 W Begin Angle Drop 5555.24 2988.00 2666.80 N 3395.62 W Top Uguu Sands 6091.39 3%15.2% 2865.56 N 36%4.78 W End Angle Drop 6291.39 3595.00 2920.23 N 3713.32 W Top West Sak Sands 6%52.71 3739.99 2964.33 N 3768.60 W TARGET - West Sak A3 6%52.72 37%0.00 296%.33 N 3768.60 W WS 1D-C1 Rvsd 22-Jan-98 6769.81 4025.00 3051.02 N 38??.2? W Base West Sak Sands 6969.81 420%.76 3105.69 N 3945.80 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 6969.81 %20%.76 3105.69N 39%5.80W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C1 Rvsd 22-Jan 556698.000,5962567.000,0.0000 37%0.00 2964.33N 3768.60W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,113 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 0 R D I N A T E S 0.00 0.00 0.00 0.00 31.00 S 597.00 100.00 0.00 270.00 100.00 31.00 S 597.00 200.00 0.00 270.00 200.00 31.00 S 597.00 250.00 0.00 270.00 250.00 31.00 S 597.00 333.33 5.00 270.00 333.23 31.00 S 600.63 400.00 8.46 287.83 399.43 29.50 S 608.21 500.00 14.19 297.23 497.45 21.63 S 626.12 600.00 20.07 301.24 592.98 7.11 S 651.71 700.00 26.01 303.48 684.96 13.90 N 684.71 800.00 31.97 304.93 772.39 41.17 N 724.74 PROPOSAL LISTING Page 1 Your ref : WS 1D-113/C1 Version #5 Last revised = 12-Jun-98 Dogleg Vert Deg/100ft Sect W 0.00 0.00 W 0.00 0.00 W 0.00 0.00 W 0.00 0.00 KOP W 6.00 2.86 Begin Turn to Target W 6.00 9.74 W 6.00 28.68 W 6.00 57.77 W 6.00 96.69 W 6.00 145.02 900.00 37.94 305.96 854.32 74.41 N 771.36 W 6.00 202.22 1000.00 43.92 306.75 929.84 113.25 N 824.08 W 6.00 267.67 1100.00 49.90 307.39 998.13 157.27 N 882.31 W 6.00 340.64 1200.00 55.88 307.92 1058.43 205.97 N 945.41 W 6.00 420.35 1300.00 61.87 308.38 1110.10 258.84 N 1012.69 W 6.00 505.92 1346.44 64.65 308.58 1130.99 284.65 N 1045.15 W 6.00 547.39 1346.45 64.65 308.58 1130.99 284.65 N 1045.16 W 6.00 547.40 1500.00 64.65 308.58 1196.73 371.19 N 1153.64 W 0.00 686.16 2000.00 64.65 308.58 1410.79 652.96 N 1506.89 W 0.00 1138.01 2500.00 64.65 308.58 1624.84 934.74 N 1860.13 W 0.00 1589.87 EOC 2561.10 64.65 308.58 1651.00 969.18 N 1903.30 W 0.00 1645.09 Base Permafrost 3000.00 64.65 308.58 1838.90 1216.52 N 2213.37 W 0.00 2041.72 3500.00 64.65 308.58 2052.95 1498.30 N 2566.62 W 0.00 2493.57 4000.00 64.65 308.58 2267.01 1780.08 N 2919.86 W 0.00 2945.42 4500.00 64.65 308.58 2481.06 2061.86 N 3273.11 W 0.00 3397.28 5000.00 64.65 308.58 2695.12 2343.63 N 3626.35 W 0.00 3849.13 5125.09 64.65 308.58 2748.67 2414.13 N 3714.72 W 0.00 3962.17 5200.00 61.66 308.58 2782.50 2455.80 N 3766.97 W 4.00 4029.00 5300.00 57.66 308.58 2833.01 2509.61 N 3834.42 W 4.00 4115.28 5400.00 53.66 308.58 2889.41 2561.09 N 3898.95 W 4.00 4197.83 5500.00 49.66 308.58 2951.44 2609.98 N 3960.25 W 4.00 4276.24 5555.24 47.45 308.58 2988.00 2635.80 N 3992.62 W 4.00 4317.64 5600.00 45.66 308.58 3018.78 2656.07 N 4018.02 W 4.00 4350.14 5700.00 41.66 308.58 3091.12 2699.10 N 4071.97 W 4.00 4419.15 5800.00 37.66 308.58 3168.09 2738.89 N 4121.85 W 4.00 4482.96 Begin Angle Drop Top Ugnu Sands 5900.00 33.66 308.58 3249.33 2775.24 N 4167.41 W 4.00 4541.23 6000.00 29.66 308.58 3334.43 2807.96 N 4208.43 W 4.00 4593.70 6091.39 26.00 308.58 3415.24 2834.56 N 4241.78 W 4.00 4636.36 End Angle Drop 6291.39 26.00 308.58 3595.00 2889.23 N 4310.32 W 0.00 4724.03 Top West Sak Sands 6452.71 26.00 308.58 3739.99 2933.33 N 4365.60 W 0.00 4794.75 TARGET - West Sak A3 6452.72 26.00 308.58 3740.00 2933.33 N 4365.60 W 0.00 4794.75 WS 1D-C1 Rvsd 22-Jan-98 6500.00 26.00 308.58 3782.49 2946.26 N 4381.80 W 0.00 4815.48 6769.81 26.00 308.58 4025.00 3020.02 N 4474.27 W 0.00 4933.75 Base West Sak Sands 6969.81 26.00 308.58 4204.76 3074.69 N 4542.80 W 0.00 5021.42 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, TllN, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Total Dogleg for wellpath is 104.44 degrees. Vertical section is from wellhead on azimuth 308.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : wS 1D-113/C1 version #5 Last revised ~ 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250 00 250.00 31.00 S 597.00 W KOP 333 33 1346 44 2561 10 5125 09 5555 24 6091.39 6291.39 6452.71 6452.72 6769.81 6969.81 333.23 31.00 S 600.63 W Begin Turn to Target 1130.99 284.65 N 1045.15 W EOC 1651.00 969.18 N 1903.30 W Base Permafrost 2748.67 2414.13 N 3714.72 W Begin Angle Drop 2988.00 2635.80 N 3992.62 W Top Ugnu Sands 3415.24 2834.56 N 4241.78 W End Angle Drop 3595.00 2889.23 N 4310.32 W Top West Sak Sands 3739.99 2933.33 N 4365.60 W TARGET - West Sak A3 3740.00 2933.33 N 4365.60 W WS 1D-C1 Rvsd 22-Jan-98 4025.00 3020.02 N 4474.27 W Base West Sak Sands 4204.76 3074.69 N 4542.80 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 31.00S 597.00W 6969.81 4204.76 3074.69N 4542.80W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C1 Rvsd 22-Jan 556698.000,5962567.000,0.0000 3740.00 2933.33N 4365.60W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : WS 1D-113/C1 Version #5 Last revise~ : 12-Jun-98 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 250.00 0.00 270.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 333.33 5.00 270.00 333.23 0.00 S 3.63 W 2.86 0.91 0.87 0.50 270.00 400.00 8.46 287.83 399.43 1.50 N 11.21 W 9.74 1.21 1.06 0.60 280.42 500.00 14.19 297.23 497.45 9.37 N 29.12 W 28.68 2.04 1.37 0.76 290.83 600.00 20.07 301.24 592.98 23.89 N 54.71 W 57.77 3.40 1.74 0.94 295.98 700.00 26.01 303.48 684.96 44.90 N 87.71 W 96.69 5.37 2.16 1.16 299.11 800.00 31.97 304.93 772.39 72.17 N 127.74 W 145.02 8.01 2.64 1.45 301.20 900.00 37.94 305.96 854.32 105.41 N 174.36 W 202.22 11.34 3.15 1.83 302.71 1000.00 43.92 306.75 929.84 144.25 N 22?.08 W 267.67 15.40 3.69 2.32 303.84 1100.00 49.90 307.39 998.13 188.27 N 285.31 W 340.64 20.17 4.23 2.92 304.73 1200.00 55.88 307.92 1058.43 236.97 N 348.41 W 420.35 25.62 4.75 3.63 305.44 1300.00 61.87 308.38 1110.10 289.84 N 415.69 W 505.92 31.68 5.22 4.45 306.03 1346.44 64.65 308.58 1130.99 315.65 N 448.15 W 547.39 34.63 5.43 4.85 306.25 1346.45 64.65 308.58 1130.99 315.65 N 448.16 W 547.40 34.63 5.43 4.85 306.25 1500.00 64.65 308.58 1196.73 402.19 N 556.64 W 686.16 44.38 6.12 6.20 306.78 2000.00 64.65 308.58 1410.79 683.96 N 909.89 W 1138.01 76.30 8.35 10.62 307.55 2500.00 64.65 308.58 1624.84 965.74 N 1263.13 W 1589.87 108.29 10.56 15.05 307.86 2561.10 64.65 308.58 1651.00 1000.18 N 1306.30 W 1645.09 112.21 10.83 15.59 307.88 3000.00 64.65 308.58 1838.90 1247.52 N 1616.37 W 2041.72 140.31 12.78 19.49 308.02 3500.00 64.65 308.58 2052.95 1529.30 N 1969.62 W 2493.57 172.33 14.99 23.93 308.13 4000.00 64.65 308.58 2267.01 1811.08 N 2322.86 W 2945.42 204.36 17.20 28.38 308.20 4500.00 64.65 308.58 2481.06 2092.86 N 2676.11 W 3397.28 236.39 19.41 32.82 308.25 5000.00 64.65 308.58 2695.12 2374.63 N 3029.35 W 3849.13 268.42 21.62 37.27 308.29 5125.09 64.65 308.58 2748.67 2445.13 N 3117.72 W 3962.17 276.43 22.17 38.38 308.30 5200.00 61.66 308.58 2782.50 2486.80 N 3169.97 W 4029.00 281.02 22.52 39.01 308.30 5300.00 57.66 308.58 2833.01 2540.61 N 3237.42 W 4115.28 286.71 23.03 39.80 308.31 5400.00 53.66 308.58 2889.41 2592.09 N 3301.95 W 4197.83 291.96 23.56 40.52 308.31 5500.00 49.66 308.58 2951.44 2640.98 N 3363.25 W 4276.24 296.73 24.11 41.17 308.32 5555.24 47.45 308.58 2988.00 2666.80 N 3395.62 W 4317.64 299.10 24.42 41.49 308.32 5600.00 45.66 308.58 3018.78 2687.07 N 3421.02 W 4350.14 301.01 24.67 41.74 308.32 5700.00 41.66 308.58 3091.12 2730.10 N 3474.97 W 4419.15 304.80 25.23 42.25 308.32 5800.00 37.66 308.58 3168.09 2769.89 N 3524.85 W 4482.96 308.08 25.78 42.69 308.33 5900.00 33.66 308.58 3249.33 2806.24 N 3570.41 W 4541.23 310.88 26.32 43.06 308.33 6000.00 29.66 308.58 3334.43 2838.96 N 3611.43 W 4593.70 313.21 26.83 43.37 308.33 6091.39 26.00 308.58 3415.24 2865.56 N 3644.78 W 4636.36 314.97 27.27 43.60 308.33 6291.39 26.00 308.58 3595.00 2920.23 N 3713.32 W 4724.03 318.82 28.24 44.11 308.33 6452.71 26.00 308.58 3739.99 2964.33 N 3768.60 W 4794.75 321.93 29.02 44.51 308.34 6452.72 26.00 308.58 3740.00 2964.33 N 3768.60 W 4794.75 321.93 29.02 44.51 308.34 6500.00 26.00 308.58 3782.49 2977.26 N 3784.80 W 4815.48 322.84 29.25 44.64 308.34 6769.81 26.00 308.58 4025.00 3051.02 N 3877.27 W 4933.75 328.05 30.56 45.32 308.34 6969.81 26.00 308.58 4204.76 3105.69 N 3945.80 W 5021.42 331.92 31.52 45.83 308.34 All data is in feet unless otherwise stated. Coordinates from slot #113 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Vertical section is from wellhead on azimuth 308.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref ~ WS 1D-113/C1 Version #5 Last revised : 12-Jun-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 69?0 ARCO (H.A. Mag) User specified 331.92 31.52 45.83 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 333.33 333.23 0.00 S 3.63 W Begin Turn to Target 13%6.44 1130.99 315.65 N 4%8.15 W EOC 2561.10 1651.00 1000.18 N 1306.30 W Base Permafrost 5125.09 27%8.67 24%5.13 N 3117.72 W Begin Angle Drop 5555.24 2988.00 2666.80 N 3395.62 W Top Ugnu Sands 6091.39 3415.24 2865.56 N 36%%.78 W End Angle Drop 6291.39 3595.00 2920.23 N 3713.32 W Top West Sak Sands 6%52.71 3739.99 2964.33 N 3768.60 W TARGET - West Sak A3 6452.72 3740.00 2964.33 N 3768.60 W WS 1D-C1 Rvsd 22-Jan-98 6769.81 4025.00 3051.02 N 387?.27 W Base West Sak Sands 6969.81 4204.?6 3105.69 N 3945.80 W TD - Casing Pt Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6969.81 4204.76 3105.69N 3945.80W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-Cl Rvsd 22-Jan 556698.000,5962567.000,0.0000 3?40.00 2964.33N 3768.60W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-113/Cl Version #5 Last revised : 12-Jun-98 Measured Inclin Azimuth True Vert R E C T A N ~ U L A R Dogleg Vert G R I D C 00 R D S Depth Degrees Degrees Depth C O 0 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 560490.21 5959633.68 100.00 0.00 270.00 100.00 0.00N 0.00E 0.00 0.00 560490.21 5959633.68 200.00 0.00 270.00 200.00 0.00N 0.00E 0.00 0.00 560490.21 5959633.68 250.00 0.00 270.00 250.00 0.00N 0.00E 0.00 0.00 560490.21 5959633.68 333.33 5.00 270.00 333.23 0.00S 3.63W 6.00 2.86 560486.58 5959633.65 %00.00 8.46 287.83 399.43 1.50N 11.21W 6.00 9.74 560478.99 5959635.09 S00.00 14.19 297.23 497.45 9.37N 29.12W 6.00 28.68 560461.02 5959642.81 600.00 20.07 301.24 592.98 23.89N 54.71W 6.00 57.77 560435.31 5959657.12 700.00 26.01 303.48 684.96 44.90N 87.71W 6.00 96.69 560402.15 5959677.86 800.00 31.97 304.93 772.39 72.17N 127.74W 6.00 145.02 560361.91 5959704.81 900.00 37.94 305.96 854.32 105.41N 174.36W 6.00 202.22 560315.01 5959737.66 1000.00 43.92 306.75 929.84 144.25N 227.08W 6.00 267.67 560261.99 5959776.07 1100.00 49.90 307.39 998.13 188.27N 285.31W 6.00 340.64 560203.41 5959819.60 1200.00 55.88 307.92 1058.43 236.97N 348.41W 6.00 420.35 560139.92 5959867.79 1300.00 61.87 308.38 1110.10 289.84N 415.69W 6.00 505.92 560072.22 5959920.11 1346.44 64.65 308.58 1130.99 315.65N 448.15W 6.00 547.39 560039.55 5959945.64 1346.45 64.65 308.58 1130.99 315.65N 448.16W 6.00 547.40 560039.54 5959945.65 1500.00 64.65 308.58 1196.73 402.19N 556.64W 0.00 686.16 559930.37 5960031.29 2000.00 64.65 308.58 1410.79 683.96N 909.89W 0.00 1138.01 559574.88 5960310.16 2500.00 64.65 308.58 1624.84 965.74N 1263.13W 0.00 1589.87 559219.40 5960589.03 2561.10 64.65 308.58 1651.00 1000.18N 1306.30W 0.00 1645.09 559175.95 5960623.11 3000.00 64.65 308.58 1838.90 1247.52N 1616.37W 0.00 2041.72 558863.91 5960867.90 3500.00 64.65 308.58 2052.95 1529.30N 1969.62W 0.00 2493.57 558508.42 5961146.77 4000.00 64.65 308.58 2267.01 1811.08N 2322.86W 0.00 2945.42 558152.93 5961425.64 4500.00 64.65 308.58 2481.06 2092.86N 2676.11W 0.00 3397.28 557797.44 5961704.51 5000.00 64.65 308.58 2695.12 2374.63N 3029.35W 0.00 3849.13 557441.95 5961983.38 5125.09 64.65 308.58 2748.67 2445.13N 3117.72W 0.00 3962.17 557353.02 5962053.15 5200.00 61.66 308.58 2782.50 2486.80N 3169.97W 4.00 4029.00 557300.44 5962094.40 5300.00 57.66 308.58 2833.01 2540.61N 3237.42W 4.00 4115.28 557232.56 5962147.65 5400.00 53.66 308.58 2889.41 2592.09N 3301.95W 4.00 4197.83 557167.62 5962198.59 5500.00 49.66 308.58 2951.44 2640.98N 3363.25W 4.00 4276.24 557105.93 5962246.99 5555.24 47.45 308.58 2988.00 2666.80N 3395.62W 4.00 4317.64 557073.35 5962272.5% 5600.00 45.66 308.58 3018.78 2687.07N 3421.02W 4.00 4350.14 557047.79 5962292.59 5700.00 41.66 308.58 3091.12 2730.10N 3474.97W 4.00 4419.15 556993.49 5962335.19 5800.00 37.66 308.58 3168.09 2769.89N 3524.85W 4.00 %482.96 556943.30 5962374.57 5900.00 33.66 308.58 3249.33 2806.24N 3570.41W 4.00 4541.23 556897.45 5962410.53 6000.00 29.66 308.58 3334.43 2838.96N 3611.43W 4.00 4593.70 556856.17 5962442.92 6091.39 26.00 308.58 3415.24 2865.56N 3644.78W 4.00 4636.36 556822.61 5962469.24 6291.39 26.00 308.58 3595.00 2920.23N 3713.32W 0.00 4724.03 556753.64 5962523.35 6452.71 26.00 308.58 3739.99 2964.33N 3768.60W 0.00 4794.75 556698.00 5962567.00 6452.72 26.00 308.58 3740.00 2964.33N 3768.60W 0.00 4794.75 556698.00 5962567.00 6500.00 26.00 308.58 3782.49 2977.26N 3784.80W 0.00 4815.48 556681.69 5962579.79 6769.81 26.00 308.58 %025.00 3051.02N 3877.27W 0.00 %933.75 556588.64 5962652.79 6969.81 26.00 308.58 4204.76 3105.69N 3945.80W 0.00 5021.42 556519.67 5962706.90 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #113 and TVD from RF, B (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Total Dogleg for wellpath is 104.44 degrees. Vertical section is from wellhead on azimuth 308.19 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,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref ~ WS 1D-113/Cl Version #5 Last revised : 12-Jun-98 Comments in we11path MD TVD Rectangular Coords. Comment 250.00 250.00 0 00N 0.00E KOP 333.33 333.23 1346.44 1130.99 2561.10 1651.00 5125.09 2748.67 5555.24 2988.00 6091.39 3415.24 6291.39 3595.00 6452.71 3739.99 6452.72 3?40.00 6769.81 4025.00 6969.81 4204.76 0 00S 315 65N 1000 18N 2445 13N 2666 80N 2865.56N 2920.23N 2964.33N 2964.33N 3051.02N 3105.69N 3.63W Begin Turn to Target 448.15W EOC 1306.30W Base Permafrost 3117.72W Begin Angle Drop 3395.62W Top Ugnu Sands 3644.78W End Angle Drop 3713.32W Top West Sak Sands 3768.60W TARGET - West Sak A3 3768.60W WS 1D-C1 Rvsd 22-Jan-98 3877.27W Base West Sak Sands 3945.80W 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 6969.81 4204.76 3105.69N 3945.80W 7 5/8" Casing Targets associated with this we11path Target n~.me Gecm~raphic Location T.V.D. Rectangular Coordinates Revised WS 1D-C1 Rvsd 22-Jan 556698.000,5962567.000,0.0000 3740.00 2964.33N 3768.60W 9-Oct-96 ARCO Alaska, Inc. Pad 1D 113 slot #113 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-113/C1 Version #5 Our ref : prop2213 License = Date printed : 24-Aug-98 Date created : 17-Apr-97 Last revised : 12-Jun-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 1.011,w149 30 36.313 Slot Grid coordinates are N 5959633.681, E 560490.212 Slot local coordinates are 31.00 S 597.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <377 - 6224'>,,134,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0-4414'>,,121,Pad 1D PMSS <0-4530'>,,120,Pad 1D PMSS <0-4515'>,,119,Pad 1D PMSS <O-4590'>,,118,Pad 1D PMSS <0-5205'>,,liT,Pad 1D PMSS <0-4850'>,,109,Pad 1D PMSS <0-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <0-5047'>,,124,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8365'>,,1,Pad 1D PGMS <O-8930'>,,5,Pad 1D PGMS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0 - 7340'>,,10,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 PG~4S <O-9783'>,,2,Pad 1D PGMS <0-7502'>,,4,Pad 1D PMSS <O-5142'>,,115,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 3-Aug-98 479.2 312.5 312.5 23-Jul-98 390.0 100.0 100.0 6-Aug-98 405.0 100.0 100.0 2-JuJz-98 149.1 333.3 333.3 2-Jun-98 134.5 333.3 333.3 2-Jun-98 119.1 333.3 333.3 2-Jun-98 75.0 100.0 100.0 2-Jun-98 58.3 333.3 333.3 2-jun-98 88.1 560.0 560.0 2-Jun-98 130.2 620.0 620.0 2-Jun-98 164.5 291.7 291.7 2-Jun-98 417.1 333.3 333.3 2-Jun-98 495,0 100.0 300.0 2-Jun-98 238.2 355.6 355.6 21-May-98 572.0 333.3 333.3 10-Dec-97 232.9 820.0 820.0 13-Nov-97 212.2 0.0 333.3 13-Nov-97 332.2 100.0 100.0 6-Nov-97 452.0 333.3 333.3 29-Apr-98 104.8 333.3 333.3 28-Apr-98 525.0 100.0 100.0 2-Jun-98 359.3 312.5 312.5 2-Jun-98 374.9 333.3 333.3 1-Jul-98 268.8 333.3 333.3 6-Jul-98 283.4 312.5 312.5 &-Aug-92 138.5 580.0 580.0 &-Aug-92 92.1 100.0 312.5 2-Jun-98 20.2 520.0 520.0 PMSS <0 - 6580~>,,12~ .... _.d 1D PMSS <291 - 5795~),,125,Pad 1D PMSS <0 - ???>,,114,Pad 1D PMSS <0 - 5445'>,,122,Pad 1D PG'MS <O-80?Ot>,,3,Pad 1D 1?-Aug-98 19-Aug-98 24-Aug-98 16-Aug-98 13-Aug-98 299.4 252.5 15.0 165.0 27.8 333.3 100.0 100.0 400.6 333.3 333.3 3100.0 100.0 6720.0 3-5/8" 5000 psi BOP ,C ack Kuparuk River Uni{ West Sak Operations - Producer Wells 4 3 2 I I L I 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8" 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the lADe report, The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.1 '0" DIVERTER SCHE~.~_,~.TIC Kuparuk River Unit West Sak Operations 6 4 3 2 ,_.1 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20"- 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line WilI Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20"- 2000 psi Annular Preventer TAB, 06/12/98, v.2 F ROM I KUPURt:IK TOOL HOUSE · Di/ KgSOITACS ~ P C D.S. I-D 110 123 126 127' '12,8 1J1 132 · · 24- .7.1 17-115 SURVEY SCALE: LEC, END 0 £~$11NC CONDUCTUS · 'aS-gUlf. T" CONDUCTOR ARCO Alaska, Inc. i ~6~ 04I 6 07/:~2/98 SF.E $1-tE,,,~ iF 2 FOR NOT£$ AND LOCATION INFORMATION CEA-D1OX-6104D16 '~~~ LOUNSBURY & ASSOCIATES, L~IC. ii I ARE'A: 10- ~ ~ U~T' ~T ~ILL ~ 1-0 ~ST 5~ PHA~ 19 - ~ A~OUILT L~A~ONS , , " i~ -- j ~T: i I I ., ~ONUMENTE PER ~D ANO A~A ~ ~ C~O~C~RS A~ L~A~ ~N PRO.ACCO ~4 ~ 23. ro~P ~ ~, R4N~ ~0 EAS~ ~ OR~ ~ ~-fl ~ N~ IS ~TA ~0 00' 01' ~' ~E ORA~NG N~-S. 5-1 F~ A~-BU~T L~~S ~A-O?DX-610~13 F~ CffiUC~S 9 ~ 1~ ~A-flfOX-6t~t5 F~ C~OUCT~ t2~-f~8 ~ 13L 07-27-90 ! THIS , , clN;n' ! Se~.. 14, T. 11 N., R. IO .C. i · .~ il , i __ __ iND.Y' ,~ LoL Lon~7. £,E.L.F'.F'-L~ Pod0.¢. t;O 5.959,?08..8S 560, a;0[..5~ 70' ia' O;.7EO' t49' vTO' ,.~.284' 44' ~ ?'~0.$' $4.$" Ill ,,5,959,695.93 5S0,4g0,60 I' 70' 18' 01,604" t49' ,.~" ..t&287' 2'9' 596' Sec. 23, T, 11 N,, R. 10 E. ~N.LF. ~.L. ;13 J 5.959,63J. 93 560,490.56J 70' ;8' 0;.013' Z49' 30' .~.J02' ,,TI' 591' 114 J 5,955,519.07 5~490.62 · ~0' I8' 01~,7" 149' ,,TO" 36,,~04'" ~1~' ~7' 70,6' ~%,2' 123 ~959,~5~ j ~4~.69 70' I~ 59.2~2' I49' ~' 3~1' 2ti' SM* ~6' 6~2' SURVEYOR°S CERTIFICA T~ AS OF J~Y 22. 1998. ARCO Alaska, Inc. FILE NO. LOUNSBURY a, AS~OgIATES, INC. AREA' 10 "' MOOUiF' XX ' ORK.L SITE 1-D WEs"r ~,K PHASE lB - WE],L CONDUCTORS AS-BUILT LOCATIONS CEA-D1DX-6104015 ' o; im UHtT: 01 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 28, 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-113 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 1D pad. The well is designated as a monobore 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-113, such as shallow gas. There have been ten (10) Kuparuk wells and (21) 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, l~c. 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 15, 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, Scott Goldberg Operations Drilling Engineer CC: West Sak 1D-113 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 SENT BY: 9- 3-$8 · 7:50A~1 ' ARCO ALASKA~ ~07 276 7542;~ 2/ ~ General Procedure: Drill and Case Plan for_West Sak 1D-113 (C1) 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 / dg 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 7 518" 29.7# LB0 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 first stage 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: TAM Port Collar will be placed in the 7 5/8" casing +1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip i;l the hole and open the Port Collar to perform the second stage cement job. 6, Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AC)GCC 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 end pressure test same. 9. Secure well, release rig 1D-113 (Cl) Page 1 SG,O9/O2/98,v1 SENT BY: 9- 8-88 ; 7:.50Alii ; Ai~CO ALASKA-,- ~O'~ z¥o '~.3,,z ;~: o/ ~ Completion Plan for West Sak 1D-113 (C1) Frac-for-$and ~;ontrol Producer Four-Stage, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: 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. 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 log results and final completion design strategy. Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands, RIH with perf 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 1 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 fmc sand inside casing to isolate Stage '1 from Stage 2 to follow_ Pressure test sand plug as required_ 7. RIH with slickline and confirm sand top above Stage 1 perfs. Use CTU as required to jet sand plug top to desired PBTD. Staae 2 8. Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate 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. Static 3 13. Rig up thru-tubing perf guns for Stage 3 frac job which inoludes the West Sak A4 and B sands. RIH with peri guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 1 D-113 (C1) Page 2 SG,09/02/98,v1 Stage 1 3. S~NT BY: ~- 3-.58 ; 7 :.50AM : ARCO ALASKA+ ~07 276 7.542 ;# 4/ 6 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. Staoe...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. Perforate Stage 4 overbalanced, and POOH with E-line. 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 fmc 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 1ail. 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 Prod~ti_o_.n 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 19. 20. 21. 22. 23. psi. 25. Pull back pressure valve, 26. Pull tubing hanger and circulate well to clean brine as required_ 27. TOH and lay down deadstring. 28, Pick up rock bit arId casing scraper and TIH with workstdng. 29. S£P 0 5 Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. 30. Circulate well to clean brine. TOH with workstring. 31. Pick up Centdlift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. 32. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. 33. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom nf heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 1D-113 (Cl) Page 3 SG,09/02/98,v1 SENT BY: 9- 3-58 · 7:50g{ · ARCO ALASKA~ ~07 270 7oaE;~ ~/ ~ 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections ee required, and set beck pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production lree. Pressure res! 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. 1D-113 (C1) Page 4 SG,09/02/98,v1 9.3# L-80 EUE 8FID-Mod Power Cable ter E~P Centrili~t B- 8-58 ' 7 'SOAN ' AKC0 ALASKA~ West Sak 1D-113 (Gl) Producer Well Four (4) Stage Frac-for-Sand Control Completion 16" CondUelor Ca, lng @ 80* Haychem Heat Tm~e (through pemmfr~t) Wea~herford Gemoce 754HO 7-5/8" DV S~age Collar Stnd. Grade B'fC Thm,er~-s (set +t- g~0' TV'O below peanahost) (drc~la~e well for freeze pcotectlon pur~C~ses) ESP Pump Section Centdtlft ESP Ge~¢~× 29.7# L-B0 BTC-Mod +/- 50' sbo~ top per~ot-a~ton) Combina~km Sud~aca/ProduclJon Cas~g, 2~,7# k.80 BTC-MOI~ Cemented to Surface 6970' MD / 4205' TVD) ESP Motor S~ction Cen~rllift D Sand Frac'd with Resin Coated Proppa~ Resin Coated Pmppa~ A3 Sand Frao'd with Re,tn Coated Proppam A2 Sand Frac'd with Resin Co4aa;ed Proppar~ ARCO Alaska, ~nc. ASG, 09102/98, DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-113 (Cl) 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 / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' 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-113 (Cl) 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. 1D-113 (C1) Page I SG,08/28/98,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.? ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,595' 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 = (4025 ft)(0.46 - 0.11 psi/fi) -- 1409 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 5/8" 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 7 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-113 (Cl) 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-113 (Cl) is WS 1D-115. As designed, the minimum distance between the two wells would be 15.0' at 100' 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-113 (C1) 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. 1D-113 (C1) Page 2 SG,08/28/98,v. 1 4OO BO0 1200 f- 1600 -4-- 2000 oI -E 2400 2800 3200 3600 4000 4400 C~.otod W f~n~h For: GOLDBERG Dote plotted: 24-Au<]-98 PIe. Reference [s WS 1D-113/C1 Ve~ion ~5. C~ardMates ore tn feet reference slot ~113. T~e VeH~I Depths ore ref~ence ~8 (Perk~ ~243). ARco Alaska, Sfrucfure : Pad 10 Well: 115 ~ Field : Kuporuk River Unif Locofion : Norfh Slope, AIDs <- West (feet) 4400 4000 3600 .3200 2800 2400 2000 1600 1200 800 400 0 400 TD LOCATION' i i I ; I ~ i i ~ i I i ~ ~ ~ ~ ~ m i ~ i i i i 2205' FNL, 737"FWL I SEC. 14, T11N RIOE I i-T~.TD - Cosing Pt I ~-~5<'-%Bose Wes[ Sek Sends I ~ ~'%]Top Wesl[ Sok Sends C. , , ROE ~End Angle Drop ~ TARGET '",~.Top Ugnu Sonds TVD=~740 ~ TMD=6453 '"% Begin Angle Drop DEP=4795 ~ ' NORTH 2964 WEST 3769 308.19 AZIMUTH. 4795' (TO TARGET) *** Plane of Proposol*** ' Begin Turn to Target ts RKB ELEVATION: 1 12' K0P TVl]=250 TMD=250 DEP=0 46 BEGIN TURN TO TARGET TVD=533 TMD=3.33 DEP=3 270 Az ~,2~.01 DLS: 6.00 deg per 100 fi[ T 1.97 %~3.92 SURFACE LOCATION: T 51' FNL, 597' FEL x'"55'88 MD=1346 DEP=547 SEC. 23, T11N, RIOE '"--....._ B/ PERMAFROST TVD=1651 TMD=2561 DEP=1645 MAXIMUM ANGLE 64.65 DEG 1 66 3'6T66~ DLS: 4,00 del per 100 fl[ 7.66 END ANGLE DROP TVD=3415 TMD=6091 0EP=4636 ~29.66 TARGET AG TVD=3?40 TMD=6453 DEP=4795 ~_ TARGET ANGLE T~ - cng ~T TvD=~o5 ~6 DEG i i i i [ i i i ii t i i i i i i i i i i t i i i i 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 Vertical Secfion (feet) -> Azimuth 308.19 with reference 0.00 N, 0.00 E from slot #113 3200 28OO 2400 A 2000 Z 1600 1200 --~ --i- 800 400 400 Created by finch Dote p~otted: 24-Aug-g8 Plot Reference is WS ID-115/C1 Version ~5. Coord;r~tes are ~n (ee~_ reference slot ~/113. TnJe Vertical Depths ore reference RKB (Parker RCO Alas lnC Structure: ~cd ID I1:~5 Yield : Kuporuk River Unit /ocoHon : North Dope, Alos 32O 300 28O 260 240 220 2O0 180 A 160 I ~ 140 Q~ Q~ 120 -I--- 0 Z lOO 80 60 40 20 20 4o 60 <- West (feet) 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 "'"' '..,.., \',, ',,,,~oo i \,~oo / < ',, ',, ,, ~, .,.1ooo \ ,,, ',: ,, ~,~oo , ',, 1,300 k \, " ; \ 20D~O0 , ", ~ ',, ", '\ ~, 1500 ,'" ,,' ;.,.~oo".,. x ',, ,, ,,,oo ~~oo ,,' ,,' :,,:'"-,,, ~ '",,,,. \ ',, ", '"'.,%°0 ,,'" ~oo~,,,",,,, ' '"'... \ ", ', ", ~ ;" ,, ., , ',, ,, \ ', ,, ,, /., % ,.,.,.,.,.,., ~ ,,,,,.,,.,~oo\ ,,,,~oo ,~oo ,,,~oo ~ '""- '"'. "'., ~ "k goo ~ \',, ",, ",,. /-%oo ~,"~oo/;7oo/~ -.... ,.,..,.1:oo~ "J~ \ '\ ", ",, ~oo* ,"I ," -,, ,-,, ,,,,,,,,,,,,,,,., , ,- '~, ", ", 1 ;.500 ", ',,',, '-.,,' 1500 ". ', ',, \ 1100 \ " "- ,,-'600 ,' 1 0 ". ', ', ', ", ', /' 600/ 10 0 "-,'" "'",.. i '\ " -qoo .,' :,.,.,.,,",,~ %~ ',,,,. \ ',, ~oo ~ooe"~oo .-"' '""'"" ' ',, ',, ',, /"6oo/ '"'..(',,.... x. "",,, ~oo \ ',,., ',, e--~;' / ~oo 9oo'*',-~,,, xx ~',,,. lOOO X, ",, ",, zoo./ "':C:,,.1~~oo ",,,, \ ',, ',,e--" '" ""'" \' \' " 1 ~ 1~0'o,."',:"-, X '\, k ',, ', 600 ~n,/12oot "-.. '",U::-., X "',. ~ook",6°° ', ~"~'7" ' "',, '":::',. k k %,',,,,,, ,¢ o~/11 oo I 1700 '""-. "'"",i"::::::-.. % ",,700k",. '" "',, '",_ '<:.',-,. % kk ~ "', 'k 5 0 0 Ce ~ ~ ~ "-. 900 "x, """,',-,. k "\,. 800k '",~ 50(~, ""-.. "~' .~..177,, X1300 "',,., kx~"., -...... ,~%~.oo \ ',-.,~ooX,'......~ '-..~. ~~:... \ '.....~oo ~'--..e 1000 "'",.... '"X,.. '"::~.:..... k '"XX. 600~ ~00 1600 '---......_ -',.... -'..::::.,.~o~,-... ~oo '"',°.800'",,_ "",."'"'. ~ 1200 "'". '".... ",.% 70 C~',,.1, 213 . ""-.~ 900'"-... -,.,, ,,,,, ?....~oo '-.. '.. ',. '-.... /uu 600 %-.. "% '. '"~ ....... -c-.~ 1500 ~~.~_800 1700 1600 ""'- 700 1100 ~ 800 "'-... 1100 1300 ~ "-- '. 1200 '"'-- _500 '-.o 600 1400 000 ~o, .': ?_o.. / ......... ~;'~7 /,~oo ............. ~?-___ ~ / 1200 /700~ ...... ~oo ~ .............. ~oo / / 6oo I I I I I I I I I i i I I I I i I / I 240 220 200 180 160 140 120 100 80 60 <- West (feet) 40 20 0 20 40 60 320 3OO 28O 260 240 220 200 180 160 A I ~4o oz 120 ~ --t- 1 O0 ~ 40 20 20 40 60 Created by finch Dote plotted : 24-Au<j-98 Plot Reference is WS 1D-115/C1 Version ~5. Coordinates ere in feet reference slot ~1 True Vortic~l Depths ore reference RKB (Porker ~245 IARC'O Alaska, In C. Structure : Pad 10 Well: 11.5 I Field : Kuparuk River Unit Locaffon : North Slope, Alas <- West (feet) 800 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 "'""'"' 720. ..... 2000 1200 720 2000 ',, '",,\,,,,, ",, 680 130C~"', '", '", 680 640 '"'... \",. 1900 '\' 640 60o ~ '"'-,~ 1900 'A\1300 "', 600 '"" '""- '- "~ 1 500 '" 560 C 1800 "',,\, 560 '"'.. 1 300 '"'.. ",. ",, \,, ",. 11 oo 520 \" ', '"'".. '"'". 1 200'"'. '"'. ",,, ',,, 520 '"', 1700 "'"-. '"'-.o 1800 ~ x.., ',,,, '\'"~,,,1200 480 480 440 1700 "..... '".... ~ ",,.",.. \,\ '.. "-. 1800 ". ". ', 440 A ""' '"" "" ''~ 1400 '\,, '"',~ 1200 '"'.. ",, ",, " A I 400 \ I ,, , 400 1600 -, '"...,\ ",,, ,.+_360 ,~, -,, '"-.. ~ ~oo'%',,. ',,, .,, ~- 320 1 500 '. 320 280 14-00 '"'%L100 ,,...., ioo "'"'-'- ' :;;::',% ..... 1200 '""-.. 160 .... - .... . 160 120 2600 ..... 80 ~ .... .,. 130~12U ....... ........ 2100 8O 2~oo 2~oo 2zoo - 40 3000 ~ 40 2800'"-~ 11 O0 ..... 0 2700~~~ 0 i i i i I i i i i i i i i i i i i i ii i i i i i i i i i i i 800 760 720 680 640 600 560 520 480 440 4-00 380 320 280 240 200 <- West (feet) Creoted by finch Dote plotted: 24-Aug-§8 Plot Reference ;s WS $D-I15/C1 Verslon Caordino[es are in feet reference slot ~1 rr~e Vertical Depths ore reference RKB (Porker tf245). aska, [ nCl1 Structure: Pad 1D Well: Field : Kuparuk River Unit Location : North Slope, AlaskaI 2000 1900 1800 1700 <- West (feet) 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 go0 800 700 600 '" ". 2300 '" \ 1500 2600"-...".,~ 2000 14OO 1300 1200 1100 1000 900 8O0 7OO 600 500 400 300 200 '",, "', '",~ 2100 k4100 ~ 1800 ',,~ ',, ,, '%[4000 2000 ', ", '\ X 3900 ". ',,,, ',,,, '\, k38oo ',, ',, ',. 2200 '", /,k 3700 '" '"'" '"" "\',, 2000 X 3600 '",% '",,, ~,, .... '".\ \ 3500 '"'~ 1700 1900',. ",, ',,,\. V400 ',, ,.,.....,?oo ,,,,,.,. V oo ,,,,.. '% ,,, \. ",, 1800 ',. ',, "",,,,, '~5100 x,,. '~. 2000 \',, ~ 3000 1700 %.,\ \\\, "'\",, '"', "',z 1900 '", '", ", 'k 1700 2000 1900 1800 1700 1600 1500 '-. '-. 1400 '"'[:". 2900 250 0%~'.'.'.,%' ' '"""""'""-'.-. 1900 X~x,x2800 1.300 1800 'x..%....~.~. ~ 1601~"', '"'. ',,,, 1200 [T~ '"'"t~%~-..50'xO~..2300 '", ""~ i 800 '"' 16^^ ' ' '. ,, -,, uu 11 --.....3200 "~:t-. ~ ,, , O0 3000 ";<'- ". ",, \,, '~0.02%00 170~::::.-...,. ~ '..... 2800 "" ", ', '"'-%28( '"'"""."-. 22'~. 1500 ' ' ~ 1000 -...37oo -...',>?.2o%.22oo ",, ",, '--~6oo '"'::'"-. ~- "" "" ~7o0 _ ',,.,',. ~ ~oo "'--..'.'.:--..,, o'~ .,,....... ~oo 8OO oo ...... .~. 2100 .............. 20.00 -"'"'~800 1300'%". '""- ......... ..,, .... ---. '-,..... ~ 500 700 "-. .......... .~..~..o_o_ ..... ~ -- 400 ...... ---,,. 1800 .......... ' ............~ 1700 ~ 500 ~4100 ~05700 ........ .1.600 ~~°~ ............. <~ ~oo I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I 21 O0 2000 1900 1800 1700 1600 1500 1400 1500 1200 11 O0 1000 900 800 700 600 <- Wesf (feel) Z 0 A Creoted bt' finch Dote I~o~ted : 24-Aufl-§8 Plot Reference [s WS 1D-115/C1 Version Cooed;notes ere ;n feet reference slot ~113. true Verticel Depths ere reference as Inc. Structure : Pad 1D II : 115 Field : Kuparuk River Unit Locofion : North Slope, Alaska 4000 5800 3600 3400 3200 3000 2800 26O0 A 2400 I 2200 2000 1800 1600 1400 1200 1000 8OO 600 400 20O <- West (feet) 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 I I I I I I r I I I I t I I I I I I I I I I I I I ~ 3700 ,%,,3,1 O0 ",.,,3500 ",, 2700 '",, '",. 3300 2900 "",, '",, "',, '"~ 3100 ~ 2500 '"-,,, .3700 ',,, 'A,290b-.,~. 5900 ".,,,3500 '",,, '",, '"'--.%3500 '-.,.,3300 ',,,, ',,, '-,,,.5300 ""-~, 31 O0 ,,,, ',,,, ',%? 1 O0 "-. 2500 '~ ", "'~ 2900 ", ", "~ 2700 · '% 2900 ", ', ",, "%. ",, ", ", 2700 '",,~ 2700 "., ",, "~ 2500 ~ ',, 2300 ~, ", ", I~L~' '.... ',,, ',~, 2500 ',,, 41 O0 '% "-, ",, ",, ", 3900 ""-. '".. ',, ',. '%, 2300 3700 "~-. "%., 2500 ",, ",, ',, 3500 "%., ",.. ',., ',, 33oo'". "-. 2~ oo "-.. "-. ", ',. 2500 v 31 O0 '%. '"-. '", ",, ",, "-~. 2300 ",, ',, 2~oo'"-...~-::.... "-,,',%,, 1900'%,, "',,210C 2700"~.~'-~, 2100 ",, ~ 1600 '" ': ":.' :::bQh>.,..~ ""~,.~ 250~":'""'%"! 900 t 1400 "¢?,. I-- 12oo aia.a oo ;`300 "'Q"-,.2`3oo / ..... .,,_.3 5oo 2,~oo '%. 3L~ -' ....... 2900 '"'""'-%2700 .... ~"l~..~ k lOOO "% 6500 ........ ~- ~ ' '"....6100 ........... 2300 ......... .~..,2_.J ?.0 600 -"'----.,~4-900 .......... 1900 -'----.~ 4700 '-'~-- -"------~45 O0 ......... 400 4300 ......... I I i I I ~ I i i I I I i I I i i I I I i I I I I I i i I ~ i 200 4200 4000 5800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 <- West (feet) 4000 3800 3600 3400 3200 3000 28OO 2600 2400 A I 2200 2000 1800 Structure: Pad 1D Well: 115 Field : Kuparuk River Unit Location : North Slope, WELL PROFILE DATA ..... Point ..... MD Inc [h'r ~/D North Eest V. Sec[ Deg/l(H~ T~e cn 0.00 0.00 0.00 0.00 0.00 0.00 O.O0 KOP 250.00 0.00 270.00250.00 0.00 0.00 0.00 0.0(~ e.~n Turn to T~g,~ 333.3.3 5.00 270.00533.230.00 --3.63 2.86 6.0~ End of 8uBd/Tum1346.45 64.65 ;~08.58 1130. gg 315.65--448.16 5~-7.40 End of Hold 5125.09 6¢.63 ,,,,x08.58 2748.67 2,~k5.15 -3117.72 3962.17 0.0'0 End of Drop/Turn 6091.39 26.00 3O8.583415.24 2865.56 --3644.78 4636.38 4.0C Tar(~et W~ 1 D-C1 Rvsd 2 6432.72 26.00 508.583740,00 2964.33 -3768.60 4794.75 O.OO! End of Hold 6789.81 26.00 508.584025.00 ,3051.02 --.3877.27 493.3.750.00 T.D. & End of Hold 6969.81 26.~3 508.584204.76 .3105.69 --3945.80 5025.42 0.00 33O 340 35O TRUE NORTH 0 210 10 2O 32O 310 3OO Created by rixse For: BRASSFIELD Dote ploffed: 24-Aug-S8 Plot Reference is t,¥$ 1D-113/C1 Version Coordinates ere in feet reference s~ot ~113. True Vertlcol Depths ore reference RKB (Porker 29O 7O 28O 270 2 90O 8O ~0 260 25O 240 110 goo 230 220 210 2O0 190 180 Normal Plane Travelling Cylinder- Feet 130 ~0 160 170 All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 113 slot #113 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING iNCLUDING POSITION UNCERTAINTIES by Baker Hughes INTBQ Your ref : WS 1D-113/C1 Version #5 Our ref : prop2213 License : Date printed : 24-Aug-98 Date created : 17-Apr-97 Last revised : 12-Jku=-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 1.011,w149 30 36.313 Slot Grid coordinates are N 5959633.681, E 560490.212 Slot local coordinates are 31.00 S 597.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,113 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 0.00 270.00 100.00 0.00 N 0.00 E 200.00 0.00 270.00 200.00 0.00 N 0.00 E 250.00 0.00 270.00 250.00 0.00 N 0.00 E 333.33 5.00 270.00 333.23 0.00 S 3.63 W 400.00 8.46 287.83 399.43 1.50 N 11.21 W 500.00 14.19 297.23 497.45 9.37 N 29.12 W 600.00 20.07 301.24 592.98 23.89 N 54.71 W 700.00 26.01 303.48 684.96 44.90 N 87.71 W 800.00 31.97 304.93 772.39 72.17 N 127.74 W 900.00 37.94 305.96 854.32 105.41 N 174.36 W 1000.00 43.92 306.75 929.84 144.25 N 227.08 W 1100.00 49.90 307.39 998.13 188.27 N 285.31 W 1200.00 55.88 307.92 1058.43 236.97 N 348.41 W 1300.00 61.87 308.38 1110.10 289.84 N 415.69 W 1346.44 64.65 308.58 1130.99 315.65 N 448.15 W 1346.45 64.65 308.58 1130.99 315.65 N 448.16 W 1500.00 64.65 308.58 1196.73 402.19 N 556.64 W 2000.00 64.65 308.58 1410.79 683.96 N 909.89 W 2500.00 64.65 308.58 1624.84 965.74 N 1263.13 W 2561.10 64.65 308.58 1651.00 1000.18 N 1306.30 W 3000.00 64.65 308.58 1838.90 1247.52 N 1616.37 W 3500.00 64.65 308.58 2052.95 1529.30 N 1969.62 W 4000.00 64.65 308.58 2267.01 1811.08 N 2322.86 W 4500.00 64.65 308.58 2481.06 2092.86 N 2676.11 W 5000.00 64.65 308.58 2695.12 2374.63 N 3029.35 W 5125.09 64.65 308.58 2748.67 2445.13 N 3117.72 W 5200.00 61.66 308.58 2782.50 2486.80 N 3169.97 W 5300.00 57.66 308.58 2833.01 2540.61 N 3237.42 W 5400.00 53.66 308.58 2889.41 2592.09 N 3301.95 W 5500.00 49.66 308.58 2951.44 2640.98 N 3363.25 W 5555.24 47.45 308.58 2988.00 2666.80 N 3395.62 W 5600.00 45.66 308.58 3018.78 2687.07 N 3421.02 W 5700.00 41.66 308.58 3091.12 2730.10 N 3474.97 W 5800.00 37.66 308.58 3168.09 2769.89 N 3524.85 W 5900.00 33.66 308.58 3249.33 2806.24 N 3570.41 W 6000.00 29.66 308.58 3334.43 2838.96 N 3611.43 W 6091.39 26.00 308.58 3415.24 2865.56 N 3644.78 W 6291.39 26.00 308.58 3595.00 2920.23 N 3713.32 W 6452.71 26.00 308.58 3739.99 2964.33 N 3768.60 W PROPOSAL LISTING Page 1 Your ref : WS 1D-113/Cl Version #5 Last revised = 12~Jun-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 2.86 Begin Turn to Target 6.00 9.74 6.00 28.68 6.00 57.77 6.00 96.69 6.00 145.02 6.00 202.22 6.00 267.67 6.00 340.64 6.00 420.35 6.00 505.92 6.00 547.39 EOC 6.00 547.40 0.00 686.16 0.00 1138.01 0.00 1589.87 0.00 1645.09 Base Permafrost 0.00 2041.72 0.00 2493.57 0.00 2945.42 0.00 3397.28 0.00 3849.13 0.00 3962.17 Begin Angle Drop 4.00 4029.00 4.00 4115.28 4.00 4197.83 4.00 4276.24 4.00 4317.64 Top Ugnu Sands 4.00 4350.14 4.00 4419.15 4.00 4482.96 4.00 4541.23 4.00 4593.70 4.00 4636.36 End Angle Drop 0.00 4724.03 To~ West Sak Sands 0.00 4794.75 TARGET - West Sak A3 6452.72 26.00 308.58 3740.00 2964.33 N 3768.60 W 0.00 6500.00 26.00 308.58 3782.49 2977.26 N 3784.80 W 0.00 6769.81 26.00 308.58 4025.00 3051.02 N 3877.27 W 0.00 6969.81 26.00 308.58 4204.76 3105.69 N 3945.80 W 0.00 4794.75 WS 1D-C1 Rvsd 22-Ja~-98 4815.48 4933.75 Base West Sak Sands 5021.42 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #113 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Total Dogleg for wellpath is 104.44 degrees. Vertical section is from wellhead on azimuth 308.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-113/C1 Version #5 Last revised : 12-Jun-98 Comments in wellpath ...... MD TVD Rectangular Coords. Comment 250.00 333.33 1346.44 2561 10 5125 09 5555 24 6091 39 6291 39 6452 71 6452 72 6769 81 6969.81 250 333 1130 1651 2748 2988 3415 3595 3739 3740 4025 4204 00 0.00 N 0.00 E KOP 23 0.00 S 3.63 W BeglnTurn to Target 99 315.65 N 448.15 W EOC 00 1000.18 N 1306.30 W Base Permafrost 67 2445.13 N 3117.72 W Begln Angle Drop 00 2666.80 N 3395.62 W Top Uffnu Sands 24 2865.56 N 3644.78 W End Angle Drop 00 2920.23 N 3713.32 W Top West Sak Sands 99 2964.33 N 3768.60 W TARGET - West Sak A3 00 2964.33 N 3768.60 W WS 1D-C1 Rvsd 22-Jan-98 00 3051.02 N 3877.27 W Base West Sak Sands 76 3105.69 N 3945.80 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 6969.81 4204.76 3105.69N 3945.80W 7 5/8" Casing Targets associated with this wellpath ___ Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C1 Rvsd 22-Jan 556698.000,5962567.000,0.0000 3740.00 2964.33N 3768.60W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,113 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 31.00 S 597.00 100.00 0.00 270.00 100.00 31.00 S 597.00 200.00 0.00 270.00 200.00 31.00 S 597.00 250.00 0.00 270.00 250.00 31.00 S 597.00 333.33 5.00 270.00 333.23 31.00 S 600.63 400.00 8.46 287.83 399.43 29.50 S 608.21 500.00 14.19 297.23 497.45 21.63 S 626.12 600.00 20.07 301.24 592.98 7.11 S 651.71 700.00 26.01 303.48 684.96 13.90 N 684.71 800.00 31.97 304.93 772.39 41.17 N 724.74 900.00 37.94 305.96 854.32 74.41 N 771.36 1000.00 43.92 306.75 929.84 113.25 N 824.08 1100.00 49.90 307.39 998.13 157.27 N 882.31 1200.00 55.88 307.92 1058.43 205.97 N 945.41 1300.00 61.87 308.38 1110.10 258.84 N 1012.69 1346.44 64.65 308.58 1130.99 284.65 N 1045.15 1346.45 64.65 308.58 1130.99 284.65 N 1045.16 1500.00 64.65 308.58 1196.73 371.19 N 1153.64 2000.00 64.65 308.58 1410.79 652.96 N 1506.89 2500.00 64.65 308.58 1624.84 934.74 N 1860.13 PROPOSA/~ LISTING Page 1 Your ref = WS 1D-113/C1 Version #5 Last revised : 12-Jun-98 Dogleg Vert Deg/100ft Sect W 0.00 W 0.00 W 0.00 W 0.00 W 6.00 0.00 0.00 0.00 0.00 KOP 2.86 Begin Turn to Target W 6.00 9.74 W 6.00 28.68 W 6.00 57.77 W 6.00 96.69 W 6.00 145.02 W 6.00 202.22 W 6.00 267.67 W 6.00 340.64 W 6.00 420.35 W 6.00 505.92 W 6.00 547.39 EOC W 6.00 547.40 W 0.00 686.16 W 0.00 1138.01 W 0.00 1589,87 2561.10 64.65 308.58 1651.00 969.18 N 1903.30 W 0.00 3000.00 64.65 308.58 1838.90 1216.52 N 2213.37 W 0.00 3500.00 64.65 308.58 2052.95 1498.30 N 2566.62 W 0.00 4000.00 64.65 308.58 2267.01 1780.08 N 2919.86 W 0.00 4500.00 64.65 308.58 2481.06 2061.86 N 3273.11 W 0.00 5000.00 64.65 308.58 2695.12 2343.63 N 3626.35 W 0.00 5125.09 64.65 308.58 2748.67 2414.13 N 3714.72 W 0.00 5200.00 61.66 308.58 2782.50 2455.80 N 3766.97 W 4.00 5300.00 57.66 308.58 2833.01 2509.61 N 3834.42 W 4.00 5400.00 53.66 308.58 2889.41 2561.09 N 3898.95 W 4.00 5500.00 49.66 308.58 2951.44 2609.98 N 3960.25 W 4.00 5555.24 47.45 308.58 2988.00 2635.80 N 3992.62 W 4.00 5600.00 45.66 308.58 3018.78 2656.07 N 4018.02 W 4.00 5700.00 41.66 308.58 3091.12 2699.10 N 4071.97 W 4.00 5800.00 37.66 308.58 3168.09 2738.89 N 4121.85 W 4.00 5900.00 33.66 308.58 3249.33 2775.24 N 4167.41 W 4.00 6000.00 29.66 308.58 3334.43 2807.96 N 4208.43 W 4.00 6091.39 26.00 308.58 3415.24 2834.56 N 4241.78 W 4.00 6291.39 26.00 308.58 3595.00 2889.23 N 4310.32 W 0.00 6452.71 26.00 308.58 3739.99 2933.33 N 4365.60 W 0.00 6452.72 26.00 308.58 3740.00 2933.33 N 4365.60 W 0.00 6500.00 26.00 308.58 3782.49 2946.26 N 4381.80 W 0.00 6769.81 26.00 308.58 4025.00 3020.02 N 4474.27 W 0.00 6969.81 26.00 308.58 4204.76 3074.69 N 4542.80 W 0.00 1645.09 Base Permafrost 2041.72 2493.57 2945.42 3397.28 3849.13 3962.17 Begin Angle Drop 4029.00 4115.28 4197.83 4276.24 4317.64 Top Ugnu Sands 4350.14 4419.15 4482.96 4541.23 4593.70 4636.36 End Angle Drop 4724.03 Top West Sak Sands 4794.75 TARGET - West Sak A3 4794.75 WS 1D-C1 Rvsd 22-Jan-98 4815.48 4933.75 Base West Sak Sands 5021.42 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Total Dogleg for wellpath is 104.44 degrees. Vertical section is from wellhead on azimuth 308.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-113/C1 Version #5 Last revised : 12-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 31.00 S 597.00 W KOP 333.33 333.23 31.00 S 600.63 W Begin Turn to Target 1346.44 1130.99 284.65 N 1045.15 W E0C 2561.10 1651.00 969.18 N 1903.30 W Base Permafrost 5125.09 2748.67 2414.13 N 3714.72 W BeginAngle Drop 5555.24 2988.00 2635.80 N 3992.62 W Top Ugnu Sands 6091.39 3415.24 2834.56 N 4241.78 W End Angle Drop 6291.39 3595.00 2889.23 N 4310.32 W Top West Sak Sands 6452.71 3739.99 2933.33 N 4365.60 W TARGET - West Sak A3 6452.72 3740.00 2933.33 N 4365.60 W WS 1D-C1 Rvsd 22-Jan-98 6769.81 4025.00 3020.02 N 4474.27 W Base West Sak Sands 6969.81 4204.76 3074.69 N 4542.80 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 31.00S 597.00W 6969.81 4204.76 3074.69N 4542.80W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C1 Rvsd 22-Jan 556698.000,5962567.000,0.0000 3740.00 2933.33N 4365.60W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth R E C T A N G U L A R Vert COORDINATES Sect PROPOSAL LISTING Page 1 Your ref = WS 1D-113/C1 Version #5 Last revised = 12-Jun-98 Ellipse Semi Axes Minor Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 250.00 0.00 2?0.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 333.33 5.00 270.00 333.23 0.00 S 3.63 W 2.86 0.91 0.87 0.50 270.00 400.00 8.46 287.83 399.43 1.50 N 11.21 W 9.74 1.21 1.06 0.60 280.42 500.00 14.19 297.23 497.45 9.37 N 29.12 W 28.68 2.04 1.37 0.76 290.83 600.00 20.07 301.24 592.98 23.89 N 54.71 W 57.77 3.40 1.74 0.94 295.98 700.00 26.01 303.48 684.96 44.90 N 87.71 W 96.69 5.37 2.16 1.16 299.11 800.00 31.97 304.93 772.39 72.17 N 127.74 W 145.02 8.01 2.64 1.45 301.20 900.00 37.94 305.96 854.32 105.41 N 174.36 W 202.22 11.34 3.15 1.83 302.71 1000.00 43.92 306.75 929.84 144.25 N 227.08 W 26?.67 15.40 3.69 2.32 303.84 1100.00 49.90 307.39 998.13 188.27 N 285.31 W 340.64 20.17 4.23 2.92 304.73 1200.00 55.88 30?.92 1058.43 236.97 N 348.41 W 420.35 25.62 4.75 3.63 305.44 1300.00 61.87 308.38 1110.10 289.84 N 415.69 W 505.92 31.68 5.22 4.45 306.03 1346.44 64.65 308.58 1130.99 315.65 N 448.15 W 547.39 34.63 5.43 4.85 306.25 1346.45 64.65 308.58 1130.99 315.65 N 448.16 W 547.40 34.63 5.43 4.85 306.25 1500.00 64.65 308.58 1196.73 402.19 N 556.64 W 686.16 44.38 6.12 6.20 306.78 2000.00 64.65 308.58 1410.99 683.96 N 909.89 W 1138.01 96.30 8.35 10.62 307.55 2500.00 64.65 308.58 1624.84 965.74 N 1263.13 W 1589.87 108.29 10.56 15.05 307.86 2561.10 64.65 308.58 1651.00 1000.18 N 1306.30 W 1645.09 112.21 10.83 15.59 307.88 3000.00 64.65 308.58 1838.90 1247.52 N 1616.37 W 2041.72 140.31 12.78 19.49 308.02 3500.00 64.65 308.58 2052.95 1529.30 N 1969.62 W 2493.57 172.33 14.99 23.93 308.13 4000.00 64.65 308.58 2267.01 1811.08 N 2322.86 W 2945.42 204.36 17.20 28.38 308.20 4500.00 64.65 308.58 2481.06 2092.86 N 2676.11 W 339?.28 236.39 19.41 32.82 308.25 5000.00 64.65 308.58 2695.12 23?4.63 N 3029.35 W 3849.13 268.42 21.62 37.27 308.29 5125.09 64.65 308.58 2948.6? 2445.13 N 3117.72 W 3962.17 276.43 22.17 38.38 308.30 5200.00 61.66 308.58 2782.50 2486.80 N 3169.97 W 4029.00 281.02 22.52 39.01 308.30 5300.00 57.66 308.58 2833.01 2540.61 N 3237.42 W 4115.28 286.71 23.03 39.80 308.31 5400.00 53.66 308.58 2889.41 2592.09 N 3301.95 W 4197.83 291.96 23.56 40.52 308.31 5500.00 49.66 308.58 2951.44 2640.98 N 3363.25 W 42?6.24 296.73 24.11 41.17 308.32 5555.24 47.45 308.58 2988.00 2666.80 N 3395.62 W 4317.64 299.10 24.42 41.49 308.32 5600.00 45.66 308.58 3018.78 2687.0? N 3421.02 W 4350.14 301.01 24.67 41.74 308.32 5700.00 41.66 308.58 3091.12 2730.10 N 3474.9? W 4419.15 304.80 25.23 42.25 308.32 5800.00 37.66 308.58 3168.09 2769.89 N 3524.85 W 4482.96 308.08 25.78 42.69 308.33 5900.00 33.66 308.58 3249.33 2806.24 N 3570.41 W 4541.23 310.88 26.32 43.06 308.33 6000.00 29.66 308.58 3334.43 2838.96 N 3611.43 W 4593.70 313.21 26.83 43.37 308.33 6091.39 26.00 308.58 3415.24 2865.56 N 3644.78 W 4636.36 314.97 27.27 43.60 308.33 6291.39 26.00 308.58 3595.00 2920.23 N 3713.32 W 4724.03 318.82 28.24 44.11 308.33 6452.71 26.00 308.58 3739.99 2964.33 N 3768.60 W 4794.75 321.93 29.02 44.51 308.34 6452.72 26.00 308.58 3740.00 2964.33 N 3768.60 W 4794.75 321.93 29.02 44.51 308.34 6500.00 26.00 308.58 3782.49 2977.26 N 3784.80 W 4815.48 322.84 29.25 44.64 308.34 6769.81 26.00 308.58 4025.00 3051.02 N 3877.27 W 4933.75 328.05 30.56 45.32 308.34 6969.81 26.00 308.58 4204.76 3105.69 N 3945.80 W 5021.42 331.92 31.52 45.83 308.34 All data is in feet unless otherwise stated. Coordinates from slot #113 and TVD from RK~ (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Vertical section is from wellhead on azimuth 308.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = WS 1D-113/C1 Version #5 Last revised = 12-Jun-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6970 ARCO (H.A. Mag) User specified 331.92 31.52 45.83 i Ellipse dimensions are half axis. 2 Casing dimensions are not included. 3 Ellipses are calculated on 2.58 standard deviations. 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 333.33 333.23 0.00 S 3.63 W Begin Turn to Target 1346.44 1130.99 315.65 N 448.15 W E0C 2561.10 1651.00 1000.18 N 1306.30 W Base Permafrost 5125.09 2748.67 2445.13 N 3117.72 W Begin Angle Drop 5555.24 2988.00 2666.80 N 3395.62 W Top Ugnu Sands 6091.39 3415.24 2865.56 N 3644.78 W End Angle Drop 6291.39 3595.00 2920.23 N 3713.32 W Top West Sak Sands 6452.71 3739.99 2964.33 N 3768.60 W TARGET - West Sak A3 6452.72 3740.00 2964.33 N 3768.60 W WS 1D-C1 Rvsd 22-Jan-98 6769.81 4025.00 3051.02 N 3877.27 W Base West Sak Sands 6969.81 4204.76 3105.69 N 3945.80 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 6969.81 4204.76 3105.69N 3945.80W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C1 Rvsd 22-Jan 556698.000,5962567.000,0.0000 3740.00 2964.33N 3768.60W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref = WS 1D-113/C1 Version #5 Last revised = 12-jun-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 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 560490.21 5959633.68 100.00 0.00 270.00 100.00 0.00N 0.00E 0.00 0.00 560490.21 5959633.68 200.00 0.00 270.00 200.00 0.00N 0.00E 0.00 0.00 560490.21 5959633.68 250.00 0.00 270.00 250.00 0.00N 0.00E 0.00 0.00 560490.21 5959633.68 333.33 5.00 270.00 333.23 0.00S 3.63W 6.00 2.86 560486.58 5959633.65 400.00 8.46 287.83 399.43 1.50N 11.21W 6.00 9.74 560478.99 5959635.09 500.00 14.19 297.23 497.45 9.37N 29.12W 6.00 28.68 560461.02 5959642.81 600.00 20.07 301.24 592.98 23.89N 54.71W 6.00 57.77 560435.31 5959657.12 700.00 26.01 303.48 684.96 44.90N 87.71W 6.00 96.69 560402.15 5959677.86 800.00 31.97 304.93 772.39 72.17N 127.74W 6.00 145.02 560361.91 5959704.81 900.00 37.94 305.96 854.32 105.41N 174.36W 6.00 202.22 560315.01 5959737.66 1000.00 43.92 306.75 929.84 144.25N 227.08W 6.00 267.67 560261.99 5959776.07 1100.00 49.90 307.39 998.13 188.27N 285.31W 6.00 340.64 560203.41 5959819.60 1200.00 55.88 307.92 1058.43 236.97N 348.41W 6.00 420.35 560139.92 5959867.79 1300.00 61.87 308.38 1110.10 289.84N 415.69W 6.00 505.92 560072.22 5959920.11 1346.44 64.65 308.58 1130.99 315.65N 448.15W 6.00 547.39 560039.55 5959945.64 1346.45 64.65 308.58 1130.99 315.65N 448.16W 6.00 547.40 560039.54 5959945.65 1500.00 64.65 308.58 1196.73 402.19N 556.64W 0.00 686.16 559930.37 5960031.29 2000.00 64.65 308.58 1410.79 683.96N 909.89W 0.00 1138.01 559574.88 5960310.16 2500.00 64.65 308.58 1624.84 965.74N 1263.13W 0.00 1589.87 559219.40 5960589.03 2561.10 64.65 308.58 1651.00 1000.18N 1306.30W 0.00 1645.09 559175.95 5960623.11 3000.00 64.65 308.58 1838.90 1247.52N 1616.37W 0.00 2041.72 558863.91 5960867.90 3500.00 64.65 308.58 2052.95 1529.30N 1969.62W 0.00 2493.57 558508.42 5961146.77 4000.00 64.65 308.58 2267.01 1811.08N 2322.86W 0.00 2945.42 558152.93 5961425.64 4500.00 64.65 308.58 2481.06 2092.86N 2676.11W 0.00 3397.28 557797.44 5961704.51 5000.00 64.65 308.58 2695.12 2374.63N 3029.35W 0.00 3849.13 557441.95 5961983.38 5125.09 64.65 308.58 2748.67 2445.13N 3117.72W 0.00 3962.17 557353.02 5962053.15 5200.00 61.66 308.58 2782.50 2486.80N 3169.97W 4.00 4029.00 557300.44 5962094.40 5300.00 57.66 308.58 2833.01 2540.61N 3237.42W 4.00 4115.28 557232.56 5962147.65 5400.00 53.66 308.58 2889.41 2592.09N 3301.95W 4.00 4197.83 557167.62 5962198.59 5500.00 49.66 308.58 2951.44 2640.98N 3363.25W 4.00 4276.24 557105.93 5962246.99 5555.24 47.45 308.58 2988.00 2666.80N 3395.62W 4.00 4317.64 557073.35 5962272.54 5600.00 45.66 308.58 3018.78 2687.07N 3421.02W 4.00 4350.14 557047.79 5962292.59 5700.00 41.66 308.58 3091.12 2730.10N 3474.97W 4.00 4419.15 556993.49 5962335.19 5800.00 37.66 308.58 3168.09 2769.89N 3524.85W 4.00 4482.96 556943.30 5962374.57 5900.00 33.66 308.58 3249.33 2806.24N 3570.41W 4.00 4541.23 556897.45 5962410.53 6000.00 29.66 308.58 3334.43 2838.96N 3611.43W 4.00 4593.70 556856.17 5962442.92 6091.39 26.00 308.58 3415.24 2865.56N 3644.78W 4.00 4636.36 556822.61 5962469.24 6291.39 26.00 308.58 3595.00 2920.23N 3713.32W 0.00 4724.03 556753.64 5962523.35 6452.71 26.00 308.58 3739.99 2964.33N 3768.60W 0.00 4794.75 556698.00 5962567.00 6452.72 26.00 308.58 3740.00 2964.33N 3768.60W 0.00 4794.75 556698.00 5962567.00 6500.00 26.00 308.58 3782.49 2977.26N 3784.80W 0.00 4815.48 556681.69 5962579.79 6769.81 26.00 308.58 4025.00 3051.02N 3877.27W 0.00 4933.75 556588.64 5962652.79 6969.81 26.00 308.58 4204.76 3105.69N 3945.80W 0.00 5021.42 556519.67 5962706.90 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #113 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5021.42 on azimuth 308.21 degrees from wellhead. Total Dogleg for wellpath is 104.44 degrees. Vertlcal section is from wellhead on azimuth 308.19 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,113 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTINO Page 2 Your ref = WS 1D-113/C1 Version #5 Last revised = 12-Jun-98 Comments in we11path MD TVD Rectangular Coords. Comment 250 00 250.00 0.00N 0.00E KOP 333 1346 2561 5125 5555 6091. 6291. 6452. 6452. 6769. 6969. 33 333.23 0.00S 3.63W Begin Turn to Target 44 1130.99 315.65N 448.15W EOC 10 1651.00 1000.18N 1306.30W Base Permafrost 09 2748.67 2445.13N 3117.72W Begin Angle Drop 24 2988.00 2666.80N 3395.62W Top U~nu Sands 39 3415.24 2865.56N 3644.78W End Angle Drop 39 3595.00 2920.23N 3713.32W Top West Sak Sands 71 3739.99 2964.33N 3768.60W TARGET - West Sak A3 72 3740.00 2964.33N 3768.60W WS 1D-C1 Rvsd 22-Jan-98 81 4025.00 3051.02N 3877.27W Base West Sak Sands 81 4204.76 3105.69N 3945.80W 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 6969.81 4204.76 3105.69N 3945.80W ? 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C1 Rvsd 22-Jan 556698.000,5962567.000,0.0000 3740.00 2964.33N 3768.60W 9-0ct-96 ARCO Alaska, Inc. Pad 1D 113 slot #113 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-113/C1 Version #5 Our ref : prop2213 License : Date printed : 24-Aug-98 Date created : 17-Apr-97 Last revised : 12-Ju~-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 1.011,w149 30 36.313 Slot Grid coordinates are N 5959633.681, E 560490.212 Slot local coordinates are 31.00 S 597.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object we11path 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 <0-4530'>,,120,Pad 1D PMSS <0-4515'>,,119,Pad 1D PMSS <0-4590'>,,liS,Pad 1D PMSS <0-5205'>,,liT,Pad 1D PMSS <0-4850'>,,109,Pad 1D PMSS <0-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <0-5047'>,,124,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <O-8365'>,,1,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <O-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0 - 7340'>,,10,Pad 1D PMSS <0-5462'>,,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,Pad 1D PGg(S <0-7502'>,,4,Pad 1D PMSS <0-5142'>,,liS,Pad 1D Closest approach with 3-D Last revised Distance M.D. 3-Aug-98 479.2 312.5 23-Jul-98 390.0 100.0 6-Aug-98 405.0 100.0 2-Jun-98 149.1 333.3 2-Jun-98 134.5 333.3 2-Jun-98 119.1 333.3 2-Jun-98 75.0 100.0 2-Jun-98 58.3 333.3 2-Jun-98 88.1 560.0 2-Jun-98 130.2 620.0 2-Jun-98 164.5 291.7 2-Jun-98 417.1 333.3 2-Jun-98 495.0 100.0 2-Jun-98 238.2 355.6 21-May-98 572.0 333.3 10-Dec-97 232.9 820.0 13-Nov-97 212.2 0.0 13-Nov-97 332.2 100.0 6-Nov-97 452.0 333.3 29-Apr-98 104.8 333.3 28-Apr-98 525.0 100.0 2-Ju~-98 359.3 312.5 2-Jun-98 374.9 333.3 1-Jul-98 268.8 333.3 6-Jul-98 283.4 312.5 4-Aug-92 138.5 580.0 4-Aug-92 92.1 100.0 2-Ju~-98 20.2 520.0 Minimum Distance method Diverging from M.D. 312.5 100.0 100.0 333 3 333 3 333 3 100 0 333 3 560 0 620 0 291.7 333.3 300.0 355.6 333.3 820.0 333.3 100.0 333.3 333.3 100.0 312.5 333.3 333.3 312.5 580.0 312.5 520.0 ~ss <o - 6SSO,>,,12S-~A~d 1~ PMSS <291 - 5795~>,,125,Pad 1D PMSS <0 - ???>,,114,Pad 1D PMSS <0 - 5445~>,,122,Pad 1D PGT/S <O-80?O~>,,3,Pad 1D 17-Au9-98 19-Aug-98 24-Aug-98 16-Au9-98 13-Aug-98 299.4 252.5 15.0 165.0 27.8 333.~~ 333.3 100.0 100.0 400.6 333.3 333.3 3100.0 100.0 6?20.0 .... 3-5/8" 5000 psi BOP S" Kuparuk River Unit West Sak Operations - Producer Wells 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8" 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.1 ~.~3" DIVERTER SCHEM ...... TIC Kuparuk River Unit West Sak Operations L 6 4 3 2 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20"- 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line WilI Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20" - 2000 psi Annular Preventer TAB, 06/12/98, v.2 F ROM: KUPUR~K TOOL HOUS£ HO.: 659 7681 KgBOI 7AC$ ' g?-2?-gla 13:I5 I _ i C ._ D.S. 1-D 110 112t ~ 115 ~ :15 127 12:~ 1.11 1~2 · · 14. 13 2.3 24. [ 21 THIS SURVEY' ECALE: ;"= % ~ N LEGEND 0 £X~$TINC ~ ',45-BUE 1" CGNDUCT~ LOCA -ARCO Alaska, Inc. CAI:lO riLE NO. ! ~ K610~16 07/22/98 I DRAWt~G N~' SEE SHEET l~ 2 FOR NOTES AND LOCATION INFORMATION CEA-D1DX-6104D16 P .02 UNIT m~um: KUPUR~K TOOL HOUSE ~X NO z. ~s ~ ~o~,~s ~o ~v~,~s ~ o ~ ~-o ~ ~ ~ I ~-~ N~ L ~~' See. 14, [11 N., R. IO [ i . jl i , i ~o. I ~ ~ ~,. ~. ~.~.~.~.~. ~,. o.~. 110 5,959, Z0~86 5~,4gO~ ~' 18' OI. TEO" t4g* ~' J~2~4" 44' ~' ~6' 64.~' llt 5,959,6ffJ.~ ~0,4~.60 ~ 70' 1~' 0I.~4' 149' ~' J~2~7' : ~' 5~' 70,6' i , Sec. 23, T. 11 N., R. I O E. ~N.~.~.~L. P== , ii i . ~Z2 5.9~9,6~.~ 5~0,~9~05 I 70' ~8' O~.t60' ~,9' ~' ~.296' 16' 598' 7~8' ;13 I 5.959,6~.93 ~0,49~56~ 70' 18' O;.01J' I~' ~' ~.J02' ~' 59~ 7~8' li4 I ~ES~,619.07 58~490.62 · ~' 18' 0~' 149' JO' 36. J~' 4E' 5~ 7~* ~2' 122 5,959,469.06 ~0,490.~1 70' 1~ 59~92' %49' JO' ~.~Y" ~ 1~' 59B' 70,6' . . I I i i i i i iii ~EA' lO M~U~' ~ ~T: DI ~ D~ m~ ~-D ARGO~'--~--,.~., Inc. ~r ~ ~ ..~ ~. - ~ AS-~ILT LO~ LKEIO*16 07/22/98 CEA-DI. pX-610~16 2 m 2 · WELL PERMIT CHECKLIST F,ELD POOL ADMINISTRATION 1. 2. 3 4 5. 6. 7. 8. 9. 10. 11. COMPANY ,/----~L..~ WELL NAME/'~~../,/~--'./'//~ PROGRAM: exp [] de~v,,~edrll [] serv [] wellbore segll ann. disposal para req I INIT CLASS ,~m_~.~ ,//-'.,~/.~/' GEOL AREA _~-'~ [JNIT# ///_~'"("'~ ON/OFF SHORE O ~ . , ENGINEERING Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected pady ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMl 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... N N N N N N ~ AjA APP. R ,. DATE 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~(~(5~-'~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... GEOLOGY 29. Is presence of H2S gas probable ................. / 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ 31. Data presented on potential overpressure zones ....... Y/'F~r x~' J ,,~ ............................................................. 32. Seismic analysis of shallow gas zones ..... ' ........ /~F N ,/r .~'/__V ~./__ 33. Seabed condition survey (if off-shore) ............. /// Y N ........................................................................................................................................................................................... 34. Contact nam, e/phon,e.for weekly progress reports ..... [exploratory on~yj ............................................................................................................................................................................................. ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G_E._~~_..: COMMISSION: M:chel~lisl u;v dll (; \m,mlh( .~!\wnrdial i\diru ul\, ,I ,~< I, ht,t Y N ENGIN_E_~N__G_: U I C__~nT~_ a__r JDH../" DWJ~ ............... RNC co A, nnular disposal has not been rcqucstcd as part of thc Permit to Dril application for Kuparuk Ri 'er Umt Well No. 1D-~--5_~ · Please notc that an.',' disposal of fluids generated from this drilling~'~' ' ~ - operation which arc pumped down thc surf'acc/production casing m~nulus of a pcrmitt,cg cxisting/$ well on Drill Site ID must comply with thc rcquircmcnts and limitations of 20 AAC z5.080. 1~ .-kpproval of this pcrrnit to drill docs not authorize disposal of drillintt xx'astc in a xolumc urcater than 35.000 barrels through thc annular space ora singlc xvcll or for a pcriod longer than one \'car. 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 Drillir Services LIS Scan Uti~:~cy Mon Nov 02 14:32:14 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin~ Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SAK) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 1D-113 500292291700 A/~CO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 02-NOV-98 MWD RUN 1 AK-MM-80375 S. BURK}{ARDT D. LUTRICK MWD RUN 2 AK-MM- 80375 S. BURK}{ARDT D. LUTRICK 23 liN 10E 31 597 .00 112.10 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2~N-D STmING 3RD STRING PRODUCTION STRING REMARKS: 9.875 6866.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH MIKE WERNER OF ARCO ALASKA, INC. ON 10/13/98. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA P~AY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. THIS WELL REACHED A TOTAL DEPTH OF 6866'MD, 4119'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. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE A/UMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 110 0 6820.5 RPD 110 0 6820.5 RPM 110 0 6820.5 RPS 110 0 6820.5 RPX 110 0 6820.5 GR 110 0 6828.0 ROP 112 0 6866.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REM~KS: BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3994 . 0 2 3994.0 6866.0 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 AJ~sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 RPX MWD OHMM 4 1 68 4 2 RPS MWD OHMM 4 1 68 8 3 RPM MWD OHMM 4 1 68 12 4 RPD MWD OHMM 4 1 68 16 5 ROP MWD FT/H 4 1 68 20 6 FET MWD HOUR 4 1 68 24 7 GR MWD API 4 1 68 28 8 Name Min Max DEFT 110 6866.5 RPX 1.878 2000 RPS 1.9605 2000 RPM 0.5148 2000 RPD 0.1652 2000 ROP 8.9614 2084.77 FET 0.0717 9.2162 GR 7.4074 127.309 Mean Nsam 3488.25 13514 37.4588 13422 49.6646 13422 69.0852 13422 96.0826 13422 277.185 13510 0.400663 13422 64.926 13437 First Reading For Entire File .......... 110 Last Reading For Entire File ........... 6866.5 First Reading 110 110 110 110 110 112 110 110 Last Reading 6866.5 6820.5 6820.5 6820.5 6820.5 6866.5 6820.5 6828 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/02 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 ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3tW 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 STOP DEPTH FET 110.0 3948.0 RPD 110.0 3948.0 RPM 110.0 3948.0 RPS 110.0 3948.0 RPX 110.0 3948.0 GR 110.0 3955.5 ROP 112.0 3994.0 $ 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: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MI/D 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): 13-SEP-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 3994.0 121.0 3994.0 .0 65.9 TOOL NUMBER -~--~.~ P1063CRG6 ~' - P1063CRG6 9.880 9.9 SPUD 9.50 281.0 10.4 400 5.6 11.000 .MUD AT MAX CIRCULATINC ~ERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined AtDsent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.670 8.500 4.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MWD 1 OHMM 4 1 68 4 2 RPS MWD 1 OHMM 4 1 68 8 3 RPM MWD 1 OHMM 4 1 68 12 4 RPD MWD 1 OHMM 4 1 68 16 5 ROP MWD 1 FT/H 4 1 68 20 6 FET MWD 1 HOUR 4 1 68 24 7 GR MWD 1 API 4 1 68 28 8 28. First Name Min Max Mean Nsam Reading DEPT 110 3994 2052 7769 110 RPX 3.8232 2000 57.7579 7677 110 RPS 2.1239 2000 78.4934 7677 110 RPM 0.5148 2000 112.719 7677 110 RPD 0.1652 2000 159.571 7677 110 ROP 27.2199 2084.77 282.952 7765 112 FET 0.0717 1.3814 0.313248 7677 110 GR 7.4074 125.971 63.9227 7692 110 Last Reading 3994 3948 3948 3994 3948 3955.5 First Reading For Entire File .......... 110 Last Reading For Entire File ........... 3994 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Next Fi~le Name ........... STS! .003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NIIMBER: 3 R_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 3948 5 6820 5 RPD 3948 5 6820 5 RPM 3948 5 6820 5 RPS 3948 5 6820 5 RPX 3948 5 6820 5 GR 3956 0 6828 0 ROP 3994 5 6866 5 $ LOG HEADER DATA DATE LOGGED: 14-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46/EWP4 1.38 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6866.0 TOP LOG INTERVAL (FT) : 3994.0 BOTTOM LOG INTERVAL (FT) : 6866.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 23.9 MAXIMUM ANGLE: 64.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P1063CRG6 P1063CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 9.880 9.9 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : LSND 9.50 265.0 MUD, PH: MUD CHLORIDES (PPM) : ~ ~ FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.5 500 2.0 11.000 8.218 7.0OO 3.900 Name Service Order Units Size Nsam Rep DEPT FT 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 GR MWD 2 API 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28. 8 37.8 Name DEPT RPX RPS RPM RPD ROP FET GR Min 3948.5 1.878 1 9605 1 9922 2 2081 8 9614 0 0939 13 5343 Max Mean Nsam 6866.5 5407.5 5837 98.2989 10.3332 5745 87.3822 11.1409 5745 85.7886 10.7784 5745 83.5748 11.2432 5745 980.019 269.39 5745 9,216 0.517475 5745 127.309 66.2693 5745 First Reading 3948.5 3948.5 3948.5 3948.5 3948.5 3994.5 3948.5 3956 ~Re~- 6866.5 6820.5 6820.5 6820.5 6820.5 6866.5 6820.5 6828 First Reading For Entire File .......... 3948.5 Last Reading For Entire File ........... 6866.5 File Trailer Service name ............. STSLIB.003 Servica Sub Level Name... Version Number ........... Date of Generation ....... 98/11/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 98/11/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File