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197-232
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. /~/~'- '~~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items- Pages: ~ Grayscale, halftones, pictures, graphs, charts - Pages: ~ [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type -OVERSIZED [] Logs of various kinds n Other COMMENTS: Scanned by: ~ver~y Mildred Dareth~owell r3 TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is/ STATE OF ALASKA AL. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell ! Plug Fbrforations r Ftrforate r Other rVesP - e ! Alter Casing r Pull Tubing f Stimulate - Frac r Waiver r Time Extension r Change Approved Program J"'"" Operat. Shutdow n r Stimulate - Other 1 Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r " 197 -232 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic (` Service 00 50-029-22840-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 ` -- 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5142 feet Plugs (measured) 4759 true vertical 4293 feet Junk (measured) None Effective Depth measured 5001 feet Packer (measured) 2487, 4382 true vertical 4152 feet .. (true vertucal) 1988, 3533 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 5087 7.625 5127 4278 SLANNED MAY 1 82012 RECEIVED MAY 112012 Perforation depth: Measured depth: 4484'- 4514', 4550'- 4610', 4648'- 4678', 4700' -4740' A OGCC True Vertical Depth: 3635'- 3665', 3701'- 3761', 3799'- 3829', 3851' -3891' /"1 v1VV Tubing (size, grade, MD, and TVD) 3.5, L - 80, 4303 MD, 3454 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED -THRU PACKER, SLB -MZ PACKER @ 2487 MD and 1988 TVD PACKER - BAKER GRAVEL PACK PACKER @ 4382 MD and 3533 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 102 100 45 -- 189 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development g' Service r Stratigraphic r 16. Well Status after work: - Oil Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r 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 Date /; MDMS MAY 11 7 - i ® Z Form 10-404 Revised 11/20 ��� Submit Original Only 1 D -115 Pre -Rig Well Work DATE SUMMARY 2/11/12 PRE -RWO T -POT (PASSED) ,-PPPOT (PASSED), FUNCTION TESTED S'S 3/13/12 PULLED SHEARED SOV FROM 4201' SLM, REPLACED W/ DV. PULLED 3 1/2" SLIPSTOP FROM 4225' SLM. P(JI 1 Fns 1/2" PACKOFF W/ 2 7/8" PCESP FROM 4227' SLM. PACKOFF AND ESP HUNG UP IN STA# 1 @ 3394' SLM. UPPER 22" OF PACKOFF BROKE OFF (FISHNECK AND RATCHET MANDREL). ATTEMPTED TO RETRIEVE RUBBER ELEMENT; NO SUCCESS. IN PROGRESS. 3/14/12 RAN 2.70" BLIND BOX. FOUND 3 1/2" D &D PACKOFF AND 2 7/8" PCESP @ 3394' SLM. BEAT FREE AND CHASED DOWNHOLE TO 4226' SLM. PULLED DV FROM 4201' RKB. POCKET LEFT OPEN. COMPLETE. 3/17- PUMPED 40 BBLS HOT DIESEL DOW TUBING AND 170 HOT DIESEL DOWN I /A. 3/18- FLUID LEVELS ON TUBING AND I/A ARE AT SUREFACE. CALLED FOR BPV TO BE INSTALLED. ICI a KUP • 1D-115 Conoc I Well Attributes Max Angle & MD TD AIaSIKa.IKK: Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) .... 500292284000 WESTSAK PROD 52.20 2,055.61 5,142.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NONE 0 9/26/2011 Last WO: 4/18/2012 12/24/1998 Well 601160. -1 D -115 4/262012 3: 03:36 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag' Rev Reason: WORKOVER ninam i 4/26/2012 HANGER, 26 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 40.7 5,127.2 4,277.9 29.70 L-80 ABM -BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd GRAVEL PACK 5.1 4.000 4,382.4 4,760.0 3,910.8 CONDUCTOR, ` I LINER 41 -121 t : Liner Details Top Depth (TVD) Top Incl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 4,382.4 3,533.2 0.96 PACKER BAKER GRAVEL PACK PACKER 76 B2-40 Mod SC -1 4.000 y 4,387.2 3,538.0 0.96 SBE 80-40 UPPER EXT 4.000 4,391.0 3,541.8 0.96 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 ESP p 4,393.5 3,544.4 0.96 SEAL 80-4OSEALBORE 4.000 MANDREL, ) 2.370 i 4,395.0 3,545.9 0.97 SBE 80-40 LOWER EXT 4.000 4,411.3 3,562.1 0.97 SAFETY JT SHEAR OUT SAFETY JOINT 6.059 4,489.4 3,640.3 0.99 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.5" x .020" 4.000 4,759.4 3,910.2 1.22 PLUG BAKER BULL PLUG 4.5" SEAL LOCK HT 0.000 PACKER, 2,487 T ubing Strings IIB ° >: r Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 26.5 4,302.7 3,453.6 9.30 L -80 EUE8RDMOD III Completion Details Top Depth ESP (TVD) Top Inc! Nomi... MANDREL. ! T (MO) MB) (1 Item Description Comment ID (in) 2.604 26.5 26.5 -0.13 HANGER VETCO GRAY TUBING HANGER 3.500 2,486.5 1,988.1 50.68 PACKER ESP FEED -THRU PACKER, SLB-MZ PACKER, S#: RACSC 2501 2.990 CATCHER, 4,212.8 3,363.8 3.30 GAUGE WELLLIFT DISCHARGE GAUGE UNIT (P /N:PWLE0018) 2.992 2.633 t 1 *ALI 4,270.2 3,421.2 2.81 INTAKE TTC RECEIVING XO COUPLING w/ PERFORASTED INTAKE 2.992 WRP, 2,635 (P/N:CSE8442XA) Li, i Et 4,275.0 3,426.0 2.76 SEAL TANDEM SEAL SECTION (S/N:12013267/12013242 ) 4,288.8 3,439.7 2.65 GEARBOX GEAR REDUCTION UNIT (SM:12071903) 11.42:1 ESP MANDREL, 4,290.6 3,441.5 2.63 MOTOR ESP MOTOR, 562MSP1, 60 hp/1240V/29 (S/N:12057561) 4.161 4,298.9 3,449.8 2.56 GAUGE WELLLIFT MOTOR GAUGE UNIT (S/N:192- 00787) IL 4,300.8 3,451.7 2.54 MOTOR CENTRALIZER (P /N: C63569) ® Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAUGE, 4,213 ®' (TVD) Top Inc! ar Top )ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 2,633 2,085.4 52.61 CATCHER 4/18/2012 0.000 III 2,635 2,086.5 52.59 WRP 2.78" WRP 4/18/2012 0.000 IIII INTAKE, 4,270 Perforations & Slots Shot SEAL, 4,275 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment GEARBOX, 4,484 4,514 3,634.8 3,664.8 WS D, 1D -115 3/7/1998 4.0 2 1/8" EJ BH 4,289 MOTOR, 4,291 4,550 4,610 3,700.8 3,760.8 WS B, WS A4, 3/4/1998 4.0 APERF 2 118" EJ BH ID-115 GAUGE, 4,299 cenaali:er, ' ' 4,648 4,678 3,798.8 3,828.8 WS A3, 1D- 115 3/1/1998 4.0 APERF 180 deg. phasing; 2 1/8" EJ BH 4,301 4,700 4,740 3,850.8 3,890.8 WS A2, 1D- 115 2/22/1998 4.0 IPERF 2 1/8" EJ BH Notes: General & Safety End Date Annotation li r 8/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 APERF, * rAg 4,464-0,514 APERF, rfl 4,550-0,610 Mandrel D To p Depth Top Port APERF, ii. (TVD) loci OD Valve Latch Size TRO Run 4,648.4,8 8 Stn Top(ftKB) (ftKB) ( Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,370.3 1,913.4 50.05 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 4/18/2012 IPERF, 2 2,603.6 2,062.3 50.73 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 4/18/2012 4,700 -0.740 #.t 3 4,160.7 3,311.9 3.75 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 4/18/2012 GRAVEL PACK F „ LINER, 4,382-0,760 I I SURFACE, 41 -5,127 -i__° TD, 5,142 • • Conoco'hitlips Time Log & Summary WeUwew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/15/2012 9:00:00 AM Rig Release: 4/20/2012 7:30:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/15/2012 24 hr Summary Completed Well 1 D -112 per Program. MIRU at 1 D -115 Well Slot. Kill Well. Install BPV. ND Tree. Install Blanking Plug. NU BOPE. 08:00 09:00 1.00 0 0 0 MOVE MOB P Move Rig Over from 1D-112 to 1D-115. Spot Rig over Well. 09:00 12:15 3.25 0 0 0 MOVE MOB P Rig Accepted at 09:00 hours. Spot Cutting Box. Rig Treating Iron to Kill Tank. Load Pits with KWF. Dispatch Wellhead Rep. 12:15 12:30 0.25 0 0 0 WELCTL SFTY P PJSM. Discuss Hazard for Pulling Back pressure test. 12:30 13:45 1.25 0 0 0 WELCTL MPSP P Load Lubricator Section to Rig Floor. RU and Pul 13:45 15:45 2.00 0 0 0 WELCTL OTHR T Fluid From Brine truck had a Trace of Diesel. RU Dirty Vac truck and remove dirty diesel from pits. Had De -Mag on Vac truck break down while on location. Wait on another Vac truck. Once truck is on location we can continue with removing diesel from pits. 15:45 16:45 1.00 0 0 0 WELCTL OTHR P Finish Loading KWF in Pits. 16:45 17:00 0.25 0 0 0 WELCTL SFTY P PJSM. Discuss Hazard for Killing Well. Notify Security and DSO before bleeding gas. 17:00 20:00 3.00 0 0 0 WELCTL CIRC P Check Kill Lines and PT Same, 200/3200 psi. Notify Security and DSO that we will be venting gas. Bleed gas through the Choke to Kill Tank. Bring Rig Pump on line at 3.5 bpm. Took 13 bbls to get returns Begin to kill Well with 8.8 lb/gal KCL -Sea water at 3.0 bpm /130 psi. Circulated a total of 310 bbls to clean up Well. 8.8 lb/gal returned. Monitor Well on a slight vacuum. Notify Security and DSO that we are done venting gas. 20:00 22:00 2.00 0 0 WHDBO NUND P PJSM. Install BPV. Nipple down Production Tree. Inspect Tubing Hanger Threads, good. Install Blanking Plug. 22:00 00:00 2.00 0 WHDBO NUND P Nipple up 11" x 5,000 psi Class 3 BOP Stack with 3 1/2" Solid Pipe Rams in the Upper Gate and the 2 7/8" x 5" VBRs in the Lower Gate. Page 1 of 7 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/16/2012 24 hr S ummary Preform Initial BOPE Test. Pull Blanking Plug and Back Pressure Valve. Circulate Well. Pull 3 1/2" ESP /HT Completion. Pick -up Clean out BHA. 00:00 00:30 0.50 0 0 WHDBO NUND P BOPE Nipple Up, completed. 00:30 05:30 5.00 0 WELCTL BOPE P Perform the initial BOPE Test per ConocoPhillips and AOGCC PP requirements at 250/3,000 psi. The L VB Pipe Rams and the Annular were tested with both the 2 7/8 and the 3 1/2" Test Joints. Perform Koomey Draw Down Test. All pressure test were recorded on a Chart. The State's right to witness the test was waived by AOGCC Field Inspector, J. Crisp. 05:30 06:00 0.50 0 WELCTL MPSP P Pull Blanking Plug + BPV, well on Vac. Install Side Port ISO Sleeve. 06:00 08:30 2.50 0 WELCTL CIRC P PU and MU Landing Joint + Floor Valve and Circulating Hoses. Circulate 8.8 ppg Brine down the TBG at 3 bpm, ICP =110, FCP =180 ( 292 bbls) with 72% returns. 08:30 09:30 1.00 0 WELCTL OWFF P Monitor Well for Flow. Well still on a vac. RD cicrulating hoses, MU to Top Drive. 09:30 09:45 0.25 0 WELCTL SFTY P PJSM. Discuss Hazard for Pulling Completion. 09:45 16:00 6.25 4,308 2,044 0 RPCOM PULL P Mark Landing Joint at Rig Floor, BOLDS and Pull Tension on Completion. C.ompletinn Pulled Free at 86k.(27.33 -ft LDJT- TOLDS) Pull Hanger to Rig Floor. Open Trip Tank until fluid was observed at surface (18 bbls). Estimated Fluid Lose (31.2 BPH). Cut ESP Cable and attached to Spooler. Start TOOH and UD Completion. Up Wt =85k 16:00 17:30 1.50 2,044 23 0 RPCOM PULL P Reached The End of Heat Trace. Secure Heat Trace Spool and Continue OOH with 3.5" Completion spooling ESP Cable. Up Wt =58k. Average Losses are 31.2 BPH. Finish out with the 3 1/2" Tubing. Page 2 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 22:30 5.00 23 0 0 RPCOM PULL P Recovered the PCP Pump left in thg Tubing from S -Line fishing operations. Lay down the PCP with no problems. OAL = 31.53 -ft. Centrilift perform de- completion checks on the ESP Assembly. Lay down same. Clear and clean floor. Count hardware. Off -load hardware and remainder of the 3 1/2" Tubing. Comments: Recovered 36 Lasalle clamps, 2 protectolizers, 354 - 6' flat guards, 21 - 4' flat guards, 17 - 3' flat guards, 1 - 6' end shoe clamp, and 1286 SS bands. Found fragments of rubber in the top portion of the pump jewelry as well as in the bottom of the cross -over undetermined on exact location of where it came from. Possibly could be portions of the pump stator out of the discharge, 147 Total Flat Bands. 22:30 23:00 0.50 0 0 0 RPCOM FCO P PJSM. Install Wear Bushing. 23:00 00:00 1.00 0 442 0 RPCOM FCO P Make -up BHA #1 as follows: Mule Shoe, 14 Jts 2 7/8" Hydril 511, XO, Double Pin Sub, 7 5/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar. 04/17/2012 TIH with Cleanout BHA. Cleanout Screen Assembly down to 4,754 -ft. Circulate Well clean. Trip out. Lay down BHA. Pick up and RIH with RBP and Test Packer. Test Casing. POOH. Lay down RBP and Test Packer. Pull Wear Bushing. Wash BOP stack. Load, Rack and Tally 3 1/2" TGB. Prep to run ESP completion. PU MU and begin service of lower ESP completion. 00:00 04:00 4.00 442 4,754 0 RPCOM TRIP P Trip in with BHA #1 with 3 1/2" Drill Pipe from the Derrick. Entered the SC -1 Packer at 4,375 -ft with no problems. Continue running inside the Screen Assembly looking for fill No Fill encountered. Tagged the Bull Nose at the bottom of Screen _ Assembly at 4,755 -ft. 04:00 05:30 1.50 4,754 4,754 0 RPCOM CIRC P Fill Hole with 25 bbls. Circulate Well with Clean filtered 8.8 lb/gal brine at 6.0 bpm /890 psi. B/D Top Drive. 05:30 07:30 2.00 4,754 0 0 RPCOM TRIP P POOH, standing back DP. Up Wt =90k / Dn Wt =78k 07:30 08:00 0.50 0 0 0 RPCOM PULD P Lay Down Scraper Assembly 08:00 09:00 1.00 0 0 0 RPCOM PULD P PJSM. Discuss Hazard for Swapping Spools. C/O Spools with crane. 09:00 09:45 0.75 0 0 0 RPCOM PULD P PJSM. Load RBP and Test Packer To Rig Floor. 09:45 11:00 1.25 0 36 0 RPCOM PULD P MU 7 -5/8" RBP and Test Packer. Page 3 of7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:00. 2.00 36 0 0 RPCOM SFTY T Hold PJSM and Discuss Hazard for TIH with BHA #2. RIH 36 -ft and the Lower section of the RBP was trying to Set. Centralizer and Slips are not working properly. Wait on Replacement. The setting segment was up side down on RBP. 13:00 14:15 1.25 36 1,450 0 RPCOM TRIP T Made repaires on location to the RBP. RIH to 1450 -ft and set RBP and Test Packer and PT Tools to 500 psi. 14:15 16:00 1.75 1,450 4,350 COMPZ RPCOM TRIP P RBP Tested Good. Continue In Hole With RBP and Test packer to 4,350 -ft. Up wt 95k, Dn wt. 75k �p 16:00 17:00 1.00 4,350 4,350 COMPZ RPCOM PRTS P Set RBP and PUH 5 -ft, test 7 -5/8" L casing to 1500 psi on chart 30 min. solid test. Release RBP, monitor well, well on vac. 17:00 20:00 3.00 4,350 0 COMPZ RPCOM TRIP P TOOH from 4,350 -ft, Up wt. 95k, standing back DP and splitting in derrick for move o next job. LD RBP and Test Packer. 20:00 20:30 0.50 0 0 COMPZ RPCOM OTHR P Pull wear bushing. Load , Drift and Tally 3 -1/2" completion tubing. 20:30 21:00 0.50 0 0 COMPZ RPCOM CIRC P Wash BOP Stack. 21:00 22:30 1.50 0 0 COMPZ RPCOM OTHR P Change over floors to run 3 -1/2" completion. Continue to Load, Drift and Tally 3 -1/2" completion tubing. 22:30 00:00 1.50 0 0 COMPZ RPCOM PULD P PU MU lower ESP components. begin to service ESP equipment. Transport on -site with load of filtered / corrosion inhibited seawater at 23:30 X4/18/2012 Load well with corrosion inhibited seawater. Service and RIH with 3 -1/2" ESP Completion. MU tubing hanger. Make final splice. Check cable integrity. Land completion. RILDS. Test packoffs. Clean and clear floors. 00:00 01:30 1.50 0 0 COMPZ RPCOM CIRC P Bullhead 200 bbls of filtered, corrosion inhibited (1% by volume) seawater 2 bpm at 550 psi. 01:30 02:30 1.00 0 0 COMPZ RPCOM OWFF P Monitor well, pressure bleeding down slowly. 02:30 03:15 0.75 0 0 COMPZ RPCOM SFTY P PJSM with Centrilift and Nordic crews, running procedures and safety hazards with running ESP equipment. pressure on well at 30 psi. continue to monitor well. 03:15 04:15 1.00 0 0 COMPZ RPCOM OWFF P Pressure on surface at 0 psi with no flow, monitor well for flow, losing approximately 2 bph. 04:15 09:30 5.25 0 1,810 COMPZ RPCOM PULD P Complete lower ESP service. Start to single in with the 3 1/2" ESP w /Freethru Packer Completion from the Pipe Shed as designed. Check ESP Cable at 1,100 -ft. Good. Continue to single in with the Completion to next Cable check. Page 4 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:15 2.75 1,810 1,810 COMPZ RPCOM PACK P Perform Electrical Inspection. MU Feed Thru Packer. Cut and Splice ESP Cable and attach to Packer. Up Wt & Dn Wt 54k. 12:15 16:30 4.25 1,810 4,276 COMPZ RPCOM RCST P Perform Electrical Inspection. RIH w/ remainder of 3 1/2" Completion. 16:30 16:45 0.25 4,276 4,276 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for MU Tubing Hanger. 16:45 17:00 0.25 4,276 4,276 COMPZ RPCOM PULD P MU TBG Hanger with side port isolation sleeve installed. 17:00 19:00 2.00 4,276 4,276 COMPZ RPCOM THGR P Make final splice of ESP cable to penetrator, check cable / motor integrity, good. Attatch BIW pig tail to penetrator for surface readout of ESP cable / motor integrity, checked good. 19:00 19:30 0.50 4,276 4,303 COMPZ RPCOM THGR P MU Landing Joint and Land Completion. RILDS. 19:30 20:00 0.50 4,303 4,303 COMPZ RPCOM DHEQ P Pressure test upper and lower tubing hanger pack -offs to 5,000 psi, held solid 15 min. LD landing joint. 20:00 20:45 0.75 4,303 4,303 COMPZ RPCOM OTHR T ESP cable / motor not testing phase -to- ground thru BIW pig tali, moisture possible problem due to pig tail connection does not seal. Confer with town engineer. 20:45 21:30 0.75 4,303 4,276 COMPZ RPCOM THGR T PJSM- MU landing joint. BOLDS. Pull tubing hanger to floor, inside penetrator dry, preform all ESP cable checks, good. Malfunctioning BIW pig tail. Tubing hanger seals need replaced. Replace all hanger seals. 21:30 22:00 0.50 4,276 4,303 COMPZ RPCOM THGR T MU Landing Joint and Land Completion, Up wt 81 k, Dn wt 70k. RILDS. 22:00 22:30 0.50 4,303 4,303 COMPZ RPCOM DHEQ T Pressure test upper and lower tubing hanger seals to 5,000 psi, both side held solid 15 min. 22:30 23:00 0.50 4,303 4,303 COMPZ RPCOM THGR P LD landing joint, remove side port isolation sleeve, MU landing joint for Slickline operations. Clamp count ran on new completion; 3 ea. protectolizers 4 ea. 5150 clamps 2 ea. 1 -1/2" SS bands 3 ea. 3500 -A -05P clamps 75 ea. 3500 -A -05 clamps 23:00 00:00 1.00 4,303 4,303 COMPZ RPCOM OTHR P Clean and clear floors / shed while waiting on Slickline to arrive, Slickline crew getting required 6 hrs _ un- interrupted rest. 04/19/2012 RU Slickline. Set WRP and catcher. Circulate gelled diesel into IA. Set DV in GLM #1. P/T IA 1,500 psi. Freeze protect tubing. Set DV in GLM #2. PfT tubing 3,000 psi. RD Slickline. Set TWC. Bleed IA per decompression schedule. Page 5of7 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment - 00:00 00:30 0.50 4,303 4,303 COMPZ RPCOM SLKL P MI and spot Slickline equipment. PJSM- Discussed hazards of Slickline rig up and operations. 00:30 08:30 8.00 4,303 4,303 COMPZ RPCOM SLKL P Load Slickline lubricator and surface equipment. Rig up Slickline. Pressure test equipment 1000 psi. Make 2.81" drift run to 2,750 -ft POOH. make correlation run to GLM #2 at 2,603 -ft, flag wire- POOH. RIH and set WRP at 2.635 -ft with Weatherford Slick Pump- POOH. RU Catcher Sub, RIH and set same above WRP, POOH. Stand back Slickline equipment. 08:30 08:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard with LRS & Nordic on pumping operation. 08:45 10:00 1.25 0 0 COMPZ RPCOM CIRC P Reverse Circulate 110 bbls of gelled diesel down IA at 2 bpm, 410 psi. 10:00 11:15 1.25 0 2,370 COMPZ RPCOM SLKL P RIH with Slick -line down to GLM #1 at 2,370 -ft and install dummy valve. 11:15 16:00 4.75 0 0 COMPZ RPCOM PRTS P RU LRS. PT IA Annular to 1500 psi and chart. Made several attempts to get solid test, confer w/ town engineer about charts, call out DHD to test w/ digital gauges. 16:00 18:00 2.00 0 2,603 COMPZ RPCOM SLKL P While watching IA test, had LRS circulate 25 bbls of Diesel down TBG at 2 bpm, 535 psi. RU slick -line and RIH and set 1" DV in GLM #2 at 2,603 -ft, POOH. 18:00 20:00 2.00 0 0 COMPZ RPCOM PRTS P Slickline on surface. Attempt to Pressure test tubing, leak at 8 rd connection, stand Slickline back and RU test equipment, Pressure test tubing to 3,100 psi, IA at 2,518 psi, tubing lost 200 psi in first 15 min. fail, Pressure tubing back up to Q 3,100 psi, IA at 2,515 psi, 15 minute ,0 reading tubing at 3,000 psi, IA at 2,515 psi, 30 minute reading tubing at 2,990 psi on chart, IA at 2,515 psi on digital gauge. Bleed tubing to 0 psi, IA pressure came down to 2,416 psi. RD Slickline, LRS and DHD crew. 20:00 00:00 4.00 0 0 COMPZ RPCOM PRTS P Start Bleeding Down IA following Decompression schedule. During IA bleed down, monitored tubing 1 hour for flow, tubing static, lay down landing joint, drain BOP stack, Vetco Gray rep. set TWC, remove riser and prep BOP stack for ND while continuing decompression schedule. 04/20/2012 Complete decompression schedule. Install TWCV. Nipple Down the BOP Stack. Test the ESP Cable. Nipple Up the Tree. Test Tree and Voids /Pack -offs to 5,000 psi. Perform the final ESP Cable checks. Pull TWCV. Install BPV. Secure Cellar. RDMO. Page 6 of 7 N . • Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 COMPZ RPCOM PRTS P Continuing decompression schedule to 0 psi. Start off loading pits 01:00 01:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor IA for flow 30 min. IA static. 01:30 03:00 1.50 0 0 COMPZ WHDBO NUND P ND BOPE and set back on stump. Make ESP cable / motor electrical integrity checks, good. 03:00 05:00 2.00 0 0 COMPZ WHDBO NUND P Nipple up Tubing Adaptor and Production Tree. (DSO verified the Tree Orientation). PT tree to 5000 psi, good. PT Hanger Void/ Packoffs to 5000 psi, good. 05:00 05:30 0.50 0 0 COMPZ WHDBO OTHR P Make final check of ESP cable/ motor electrical integrety, all good. 05:30 06:00 0.50 0 0 COMPZ WHDBO MPSP P Lubricate out Two -Way Check and install CIW 3" Type 'H' BPV. 06:00 07:30 1.50 0 0 COMPZ MOVE MOB P Back off Well Slot, Clean Tree and Cellar. Release Rig at 07:30 AM. • Page 7 of 7 WELE LQG S TRA/IISM/TTAL a~. PROAcrive Diagnosric SeavicES, Inc. To: AOGCC Christine ~~ S ~°'' {z$( 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTV 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 r , l' :c .~~~i~ Anchorage, AK 99518 ~=`~'~1 `f,~~"` ~ ~~" •~ Fax: (907) 245-8952 1) MTT Report 26,Jun-10 1D-115 1 Report 50-029-22840-00 2) Signed Print Name: QI ~ '"~~ RECE~~ JUG 2 2Q~ Date ail ~ A PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraaeCc~memoryloq.com WEesITE : www.merrloryloa.com C:\Doc~unen6 and Settings\Diane Williams\Desktop\Tiansmit_Conoco.docx • • Memory Magnetic Thickness Toot S Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-115 Log Date: June 26, 2010 Field: West Sak Log No.: 7418 State: Alaska Run No.: 1 API No.: 50-029-22840-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 ABM EUE Top Log Intvl1.: Surtace Pipet Use: Tubing Bot. Log Intvl1: 222 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib. L-80 BTC-MOD Top Log Intvl1.: Surtace Pipet Use: Surtace Casing Bot. Log Intvl1: 222 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe3 Use: Conductor Bot. Log Intvl1: 121 Ft. (MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool {MTT). The MTT responds to the total metal thickness of the 3.5" tubing and 7.625" 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 222'. Changes in metal volume are relative to the 1 calibration points at 47' and 146', 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. 1 A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates no signifiicant areas of metal loss throughout the interval logged. The sources of indications of a general increase in relative metal volume over the intervals {0' - 4'), {32' - 36') and from 64' to the bottom of the conductor are unknown. A log plot of the entire 5Hz pass and an 1 expanded log plot of -- top 30' of the 5Hz pass are included in this report. Indications of general isolated metal loss are recorded throughout the interval logged in the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the 1 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" easing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. 1 1 Field Engineer: Wm. McCrossan Analyst: HY. Yang & J. Burton Witness: J. Condio ~ 1 PraActive Diagnostic Ser/ices, Inc, ! P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888, 555-9085 Fax: (281} 565-1369 E-mail: PDS~cumenmaryiog.com Prudhoe Bay Field Office Phase; (907) 659-2307 Fax: (907; 659-2314 1 1 ~~~-a3a A a`~"' ~E"s SHz, ~z and 10Hz Delta Metal Thi~iess Passes Overlay -s ~ Fc'~ a ~ '~ 1 D-115 June 26, 2010 Pn°AmvE DIACIN°STIC SERVICES Database File: d:lwarriorldatal1d-1151overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Wed Jun 30 14:06:44 2010 Charted by: Depth in Feet scaled 1:150 Delta Metal Thickness 2x10 (10Hz) (%) 50 Delta Metal Thickness 2010 (8Hz) (%) 50 Delta Metal Thickness 2010 (SHz) (%) 50 0 20 10Hz Delta Metal Thickness 40 60 Bottom of 16" Conductor Delta Metal Thickne: Delta Metal Thickness 80 • 120 140 160 180 200 OHz Delta Metal Delta -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (SHz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (°J°) 50 o`~`"..e`~sA~n R~rded Magnetic Thickness ~ Data - 5HZ Pass a°' N 1 D-115 June 26, 2010 PROACTIVE OIA4ROSTIC SERVICES Database File: d:lwarriorldatal1d-11515hzpass.db Dataset Pathname: 5HzPass Presentation Format: 18 Dataset Creation: Wed Jun 30 14:34:21 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (°fo} 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ftlmin) -200 -7 MTTP12 (rad) 3 Tree ~Hanger~ Metal Thickness Tubing Jt. 1 20 7 5" 625" 40 Tubing Jt. 2 60 of 16" Conde Tubing Jt. 3 80 Tubing Jt. 4 120 ~~ 5~ Collar-~ ~-X7.625" Colla~ Tubing Jt. 5 140 3.5" Collar~~ ~ ~ -ter--~ ~~~~~ 160 625" Collar Tubing Jt. 6 180 5" Collar ~==i1 -~":; 200 Tubing Jt. 7 .625" Collar Metal Thickness 3.5" Collar , 220 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 ,~ o`~`"wE"s E,~anded 5Hz Pass Magnetic T~kness Log Data ~ ~c~sG ~ ~~- "' 1 D-115 June 26, 2Q10 Pfl°1>CT7VE ~IhGMOSTIC SEAMICFS Database File: d:iv~arriorldatalld-1151expanded 5hzpass.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Wed Jun 30 14:34:21 2010 Charted by: Depth in Feet scaled 1:60 -50 D elta Met al Thick ness (%) 50 1.8 MT TP0 1 (r ad) 1 1.8 0 Li ne S peed (f t/min) - 200 -7 MT TP1 2 (r ad) 3 Tree ,-. .. , _ .~.~ .~ Li S d .Hanger. I ~ f ~ I I . ,. n e pee I 1 r Delta Me tal T hickness L 7 _ _ i ~ 4- l _ __ y T 10 ~ #. z. 7 Tubing Jt. 1 ~ ~ - 0 ~~ ' 2 r?' d i 3.5" Co llar - 30 ~ -- i ~;.. ~- t ~ - i - - - ~ - - ~ ~_ -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0~ ~ Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 i ~~ ~ KUP ~ 1D-115 i~ ConOCOPI 'lillips ~ I II Att riblrtes Angle & M D TD s Il~~ `I ` 'Jvellbon 4 Pl'U'W'I Flefd Nama WYY 8 1 i , ~ hcl i°t UGi F B1 0 ~ ~ .fit Btrn i 4: f:AR . . - 500292284000 WEST SAK PROD 52.20 2,055 .6 5,14: . bommen i !1Fp HtS fppml CPte ~ rllt ;nnoh on B,d ~~ I tll+ k ( 1 Plg Releare P rlil SSSV: NONE 0 87760. Last W0: 41121199 12!24!19 Nmo on Last Tag: Gp I! KBj Bid 1 ,ll i Moo 11on Red Reason: Resent Pump Assy, GLV C!0 Lart MOd Bi Imasbor Brd Gib 9 titt 113020 Casing Strings sung [o rcnpbon s ng oe.. Stung 1D.. . Top( :Bj se [xp 1it.. sat Gp u;Tv Dj... S g~W .. s mog ... S ng Tap n;. Ili! CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H110 WELD E CarElg Da. cnpaon String r.G... Smnp Ri. .. Topf 'Bj SPt dpUr fi... SS lbpYl(Tr Di... Siting Vv .. 5 ng ... String Top T; F,1 SURFACE 751E 6.750 0.0 5,127.0 4,277.7 29.70 1-80 BTC-M co1PPCTOa, Ublllg $If111gS o-1=I bmg ua cnpaon smog GD.. smog lD. .. Top l; :Bj set rxpYl it... set cnpnur~Dj... stung wt.. s mog... smog rop e N E4T TP.1a~ TUBING 3112 2.992 0.0 4,252.0 3,442.9 9.30 L-00 ABME wrPE, ~ - er bt Hole (VV lreline retrievab le plugs, valves, pumps, fish, etc.) ' Top Tnp [ep ~TJDi TCp hCl -tt1. 81 fttl~. Bi i°i Wrcn bun ?;mmart F.un Ce4, ID'In- t?rP AV.IOPEL, 33 33.0 -0.13 HEATTRRCE Raychem Heat Tracelbottomdepth22fi4'j 4110/1999 0.000 3.{oL 33 33.0 -0.13 WIRE ESP Electric WJl wire Cable (battam depth 4410') 4!7011999 0.000 3:404 2,612G 33.58 ESF' L"RMCUIKBMMJ1i D1~AYiBKSiii Comment STA1 3J16iGU07 2.920 h.IANDREL w.loPSi, - 1 4201 3,352.1 3.40 ESP CAMCOlKBMM71lSOVIBK5720001 Comment: STA2 1242010 2.920 {'~1 MANDREL 4,249 3,400.0 2.99 SLIP STOP SLIPSTOP 1252010 1.500 4,250 3,401.0 2.98 PAC KOFF D6D PACKOFF ASSEMBLY!STINGER A9SEMBLY 1252010 1.610 auP stn P, ~ (DAL=92..5'j ''s 4,258 3,409.0 2.91 PUMP 3.5"TCCPCPESP(GAL=34'fi') 1242010 0.000 PfG PD iI, 4,273 3..124.0 2.78 GAUGE BAKER SENTRY GAUGE ATTACHED TO JOINTM7 4+1011999 '~' 4,289 3,439.9 264 NIPPLE Slo[ted npple 4/70/1999 2.992 4,292 3,442.9 2.62 SEAL ESP GSFT DB IL PFS S.130"seal assembly 4/10/1999 0.000 I. 4,306 3,456.9 2.50 GEARBOx ESP9:1535 Series 4/10/1999 0.000 G1uGE.{~J ~~ 4,307 3,7.9 2.43 MGTOR PCESPMOTOR57 HP131526 KMH 4110!1993 0.000 4,376 3,526.9 0.95 GRAVEL BAKER gravel pack packer 76 B2-0Cl Mod "SC-1" 4110/1999 4.000 PVMP. {.:5a PRCK }t , 4,377 3,527.9 0.96 TUBING 4/911999 4.400 IIPP LE, {,aa9 9 Y 4,33-; 3,535.3 0.36 "">LEEVE 80-00 Gravel Pack Slid'm9 Sle-eve 4/5153 4110!1393 4.700 ~ 4,237 3,537.9 0.9fi SBR 80-40 Seal Bare 4110?1399 4.000 4,42? 3,577.8 0.94 5CREEN Bakerwekl Gravel Pack Screen 4.5"s .020"Wfil99 4/10/1999 4.000 '~ % 4.?5`s 3,903.5 1.22 PLUG BAKERbull plug 4.5"Seal Lack HT4A'sJ99 4/10/1999 0.000 .,E•. L, a;.-e erf0~M 10115 $, S IOtS Etlrt GEa.P1ax, BM TopiNGl BOILiND1 snot Gen, •.L6 o ttK6 -ttHBi itth:Bi itth.Bi one fete 111... T e _ ~_nm ment 4,484 4,514 3,634.8 3,664.8 WS D, 1P-115 3!711998 4.0 ERF 21A3"EJ BH ~'~P' {'~' 4,550 4,610 3,700.8 3,7110.8 WS B, WS M, 3!4+1998 4.0 APERF 2 118" EJ BH i D-115 4,fi48 4,678 3,798.8 3,828.8 WSA3, iD-115 3/1/1998 4.0 APERF 180 deg.phasing;21B"EJ BH ~ 4,700 4,740 3,850.8 3,890.8 1NS F+2,1 D-115 222/1998 4.0 IPERF 2 118" EJ BH GPAVEL P.1G F:, x,316 TVIIIG, {~7 SIP, a,]aU 1P EP 1, - {,a6r{Sla AP EPf, ws'Dab is ~ 3CPEE1, - _.... AP EP t, al6s&{~678 tl IP EPf, _. jl {,ieGa,~ 10 PLUG, a,'~3 .^.U Pi.•G E, TP, S,Ik . . Conoc;p.,illips 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 (011 - ;;L3:;l- SGA..~ED JUL 1 ¡ 2007 Dear Mr. Maunder: .....- ,.. Enclosed please find a spreadsheet with a list of wells ftom 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 ftom 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 fonn 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. Surface 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 PTD# cement pumped cement date inhibitor sealant date ft bbls ft aal 1 D-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/912007 10-102 200-075 2" na 3.2 6/912007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 61912007 10-106 197-240 2" na 3.2 6/912007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/912007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 61912007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/9/2007 10-119 197-222 2" na 1 6/912007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/912007 1O-125a 200-044 2" na 1 6/9/2007 10-126 198-108 2" na 1 619/2007 10-127 198-109 8" na 2.5 6/912007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 619/2007 Kuparuk Field June 9,2007 0 !::t I I--I-- i I~ ~ S I::: I::1 ~J I 1-- I~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 14, 1998 RE: MWD Formation Evaluation Logs 1D-115, AK-MM-80059 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22840-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company T~ MA T~Rt~ VND~R Tn~S COVER ON OR BEFORE PL M ATE IA L E W UNDER T H I S M A R -------------.--_ ------~-----_.____ K E R- Well Compliance Report File on Left side of folder 197-232-0 KUPARUKRIV uwSAK "lD-115 50- 029222840-00 ARCO MD 0314_2_ TVD 02[293 ~~mpletion Date: .4/6/98 Completed Status: 1-OIL Current: T Name Interval /- D 8223 kff/ SPERRY MPT/GR/EWR4 Sent Received T/C/D OH 1/14/98 1/14/98 L DGR/EWR4-MD t~AL 120-5142 OH L DGR/EWR4-TVD .-FINAL 121-4293 OH R MWD SRVY /,8tCERRY 0.-5142. OH Daily Well Ops -' 3~? [ q g Are Dry Ditch Samples Required? yes Was the well cored? yes no Analysis Description Received? yes no Comments: IlO 1/14/98 1/14/98 1/14/98 1/14/98 1/13/98 1/14/98 And Received? yes no Sample Set # Monday, May 01,2000 Page 1 of 1 STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon__ Suspend_ Alter casing __ Repair well Change approved program __ Operation Shutdown __ Re-enter suspended well __ Plugging_ Time extension __ Stimulate__ Change-out ESP & Pull tubing__ Variance__ Perforate__ Other X Gravel Pack 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 61 FNL, 597' FEL, Sec. 23, T11N, FI10E, UM At top of productive interval 1061' FSL, 2512' FEL, Sec. 14, TllN, R10E, UM At effective depth At total depth 1062' FSL, 2526' FEL, Sec. 14, T12N, R10E, UM 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) 41' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-115 9. Permitnumber 97-232 10. APInumber 50-029-22840 11. Field/Pool Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total Depth: measured 5142 (approx) true vertical 4293 feet Plugs (measured) feet Effective depth: measured 5001 (approx) true vertical 4152 feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 80' 16" 5086' 7.625" Cemented Measured depth 9 cu yds High Early 121' 466 sxAS III LW & 5127' 368 sx Class G & 60 sx AS I True vertical depth 121' 4278' Perforation depth: measured 4648'-4678', 4550'-4610', 4484'-4514', 4700'-4740' true vertical 3799'-3829', 3701'-3761' 3635'-3665', 3851'-3891' ORIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 4406' Packers and SSSV (type and measured depth) No packer, No SSSV 13. Attachments Description summary of proposal X Contact Randy Thomas at 265-6830 with any questions. Detailed operation program __ BOP sketch X 14. Estimated date for commencing operation April 3, 1999 16. If proposal was verbally approve 15. Status of well classification as: Oil __ Gas __ Suspended__ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned ~, ~ Title Shallow Sands Team Leader Date FOR COMMISSION USE ONLY ~Approved Notify Commission so represe~ative may witness integrity _ BOP Test _/,," Location clearance __ Integrity Test_ Subsequent form require 10- ORIGINAL SIGNED. BY Robert N. Chdstenson by the order of the Commission Commissioner lapp royal No..~'~¢.... t~,,~ I Date ~--/--~ West Sak 1D-115 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH and pull Shear Valve from GLM @ 4317' leaving an open pocket. 2. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. 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 BOPE. 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 @ +/- 4375' 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 1-wire to penetrators. 14. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 15. ND/NU/Test 16. Freeze protect with diesel to +/- 2000' TVD. Lower Limit: 5.0 days Expected Case: 6.0 days Upper Limit: 7.0 days No problems encountered. Problems pulling ESP completion, cleaning out to PBTD or Gravel packing MAC 3/30/99 WEST SAK 1D-115 Worko . r Proposed Schematic Standard Frac For Sand Control FFSC to FFSCGP ARCO Alaska, Inc. Depths are based on original RKB Parker 245 7-5/8" Marker Joint (+/- 50' Above Top Perforation) Sand Plug : TD @ 5142' 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 16" 62.5# H-40 @ 121' MD Stage Collar @ 2132' MD Raychem Heat Trace @ +/- 2264' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. Directional KOP = 289' Max Angle = 52 Deg @ 2056' 3-1/2" x 1" Camco 'KBMM' GLM run open @ +/- 4310' MD. After the rig moves off location, the Wells Group will install a Shear Circulating Valve, pinned for 3000 psi Tbg / Csg differentia. I 2 Joints 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple) 10' Spaceout Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @ +/- 4,424' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift 'ITC Changeover Centrilift Tandem Seal Section: GSB3 DB IL H6PFS Centrilift PC Pump and Flex Shaft Assembly: KUDU 80TP2000 Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer Baker Model SC-1 Packer @ +/- 4375' MD Top of Screen @ +/- 4474' D-Sand Perfs: 4 SPF 4484' - 4515' Frac'd w/16-20 Carbolite and PropLock B / A4-Sand Perfs: 4 SPF 4550' - 4610' Frac'd w/16-20 Carbolite and PropLock A3-Sand Perfs: 4 SPF 4648' - 4678' Frac'd w/16-20 Carbolite and PropLock A2-Sand Perfs: 4 SPF 4700' - 4740' Frac'd w/16-20 Carbolite and PropLock PBTD @ +/-4760' MD 7-5/8" 29.7# L-80 BTC Mod @ 5127' MD MAC 3/16/99 ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 11, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-115 (Permit No. 97-232/399-055) Report of Sundry Operations Dear Mr. Commissioner: Enclosed is the corrected report of Sundry Operations for the recent workover operations on KRU 1D-115. This corrected report clarifies the RKB depth. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Drilling Engineering Supervisor Kuparuk Drilling GLA/skad Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 PHIELIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Mr. Howard Okland State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: iD-115 (Permit No. 97-232) Daily Operations Report Dear Mr. Okland: Enclosed is the daily operations report that you requested for the West Sak iD-115. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader Kuparuk Development PM/skad STATE OF ALASKA ALASI~A OIL AND GAS CONSERVATION coM~I~iSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging __ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ Change-out ESP 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X RKB 41' (Nordic 3 RKB 26.5" 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: 61' FNL, 597' FEL, Sec. 23, T11N, R10E, UN 1D-115 At top of productive interval: 9. Permit number/approval number: 1061' FSL, 2512' FEL Sec. 14, T11N, R10E, UN 97-232 / 399-055 At effective depth: 10. APl number: 50-029-22840 At total depth: 11. Field/Pool: 1062' FSL, 2526' FEL Sec. 14, T11 N, R10E, UN Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total Depth: measured 5142 Plugs (measured) Baker bridge plug @ 4760' true vertical 4293 Effective Deptt measured 4760 Junk (measured) true vertical 3911 Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Eady 121' 121' Surface 5086' 7.625" 466 sx AS III LW, 368 SX Class G, 5127' 4278' 60 sx AS I Production Liner Perforation Depth measured 4648'-4678' MD, 4550'-4610' MD, 4484'-4514' MD, 4700'-47z true vertical 3799'-3829' TVD, 3701 '-3761' TVD, 3635'-3665' TVD, 3851 '-38~ Tubing (size, grade, and measured depth) . ~ ~ ~,~"-i~.. 3.5", 9.3#, L-80 @ 4292' .~, 0it & 6as Cons. Packers and SSSV (type and measured depth) ^nch0rag8 Baker gravel pack pkr @ 4382' Nordic 3 RKB with 4.5" gravel pack screen @ 4760' Nordic 3 RKB, No SSS\ 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A. Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Woter-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations _~X Oil _~X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ E, 04,.~ Title: b~,l~ b~ 6~ ¢-~-/1~ Date 1,,i Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Date: 4/27/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-ii5 WO WELL_ID: 999369 TYPE: AFC: 999369 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:04/04/99 START COMP:04/03/99 RIG:NORDIC 3 BLOCK: .FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22840-00 04/03/99 (C1) TD: 5127' PB: 4760' 04/04/99 (C2) TD: 5142' PB: 4760' 04/05/99 (C3) TD: 5142' PB: 4760' 04/06/99 (C4) TD: 5142' PB: 4760' 04/07/99 (C5) TD: 5142' PB: 4760' BERM AROUND RIG. CLEAN MU MW: 0.0 SUPV:DONALD L. WESTER Move rig from 3K pad to iD pad. Spot rig over 1D-115. Accept rig 0 2200 hrs. UPCOMING OPERATIONS:KILL WELL N/U BOPE & PULL 3-1/2" ESP TBG SITP 600 PSI SICP 600 PSI SLIP AND CUT DRILLING LIN MW: 0.0 SUPV:DONALD L. WESTER Load rig pits w/8.7 brine kill fluid. Pump kill fluid down tubing. N/U BOPE and test to 250/3500 psi. UPCOMING OPERATIONS:STAND TBG BACK IN DERRICK. P/U DP RIH C/O TO NEW PBTD OF 4760' P/U 3.5" DP RIH TO 4850' MW: 0.0 SUPV:DONALD L. WESTER Pull ESP hanger to floor. PJSM. Pull 3.5" tubing. RIH w/ fishing mill. UPCOMING OPERATIONS:SET BP AND PICKLE PIPE. POOH FOR BAKER SCREENS. CIRCU AND MONITOR NTU AFT MW: 0.0 SUPV:DEARL W. GLADDEN RIH w/bridge plug and set 0 4760'. Clean pits, fload shed w/pkr, screens and gravel pack equip. Mix caustic wash. Load pits w/brine. UPCOMING OPERATIONS:DOWELL WILL PUMP ACID PICKLE - TOH - P/U BAKER GRAVEL PACK SCREEN ASSY - TIH W/ SAME R/U DOWELL MW: 0.0 SUPV:DEARL W. GLADDEN Safety meeting. Pump caustic wash and chase w/filtered brine. Circulate brine. Pump Zanris, hot brine, acid, and displace w/brine. RIH w/screens. UPCOMING OPERATIONS:GRAVEL PACK - TOH L/D DP - RUN ESP PUMP Date: 4/27/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/08/99 (C6) TD: 5142' PB: 4760' 04/09/99 (C7) TD: 5142' PB: 4760' 04/10/99 (C8) TD: 5142' PB: 4760' 04/11/99 (C9) TD: 5142' PB: 4760' 04/12/99 (Ci0) TD: 5142' PB: 4760' CIRC & CONDITION NTUS MW: 0.0 SUPV:DEARL W. GLADDEN RIH w/Baker packer screen assy. Tag bridge plug. Pressure up to set packer. PJSM. Pump gravel. Attempt to reverse out, seal assy will not move into reverse postion. Work pipe to attempt "free" Pipe moving, attempt reverse out, no go. When Pkr setting tool was reached it showed the pkr shear ring had sheared out & all assy was back at surface - seal assy only moving 7' and packed off at seal bore. RIH w/mill. Clean carb. off all threads. CBU. Circ out all oil & gas. UPCOMING OPERATIONS:TOH L/D MILL - RE-RUN BAKER GRAVEL PACK ASSY - GRAVEL PACK DO GRAVEL PACK MW: 0.0 SUPV:DEARL W. GLADDEN RIH, tag top of carbolite ~ 4613' Clean out carbolite from 4313' to 4760', reverse out carb. at 30' intervals. RU to run screens. Hold PJSM. RIH w/3.5" DP. UPCOMING OPERATIONS:GRAVEL PACK - TOH L/D 3 1/2" DP - RUN ESP COMPLETION RUN ESP MW: 0.0 SUPV:DEARL W. GLADDEN TIH w/3.5" DP and Baker gravel pack assy. Set packer. PJSM. Pump gravel pack. RIU w/ESP pump. UPCOMING OPERATIONS:RUN ESP - SPACE OUT - TEST TBG & CSG - M/U TREE - FREEZE PROTECT PRESSURE TEST PRODUCTION MW: 0.0 SUPViD. W. GLADDEN/ R. L. MORRISON RIH w/ESP and heat trace cable. ND BOPE. UPCOMING OPERATIONS:FREEZE PROTECT WELL. PREP TO MOVE RIG TO 31-11 RIG RELEASED AND MOVED TO MW: 0.0 SUPV:R. L. MORRISON ND BOPE. NU tree and test to 250/5000 psi. Freeze protect well. Move rig off well. Release rig at 1600 hrs. 4/12/99. UPCOMING OPERATIONS: MOVE BAKER SCREEN LINER 7 5/8" C,$g w/Perfs WELL: 1 D- 115 West Sak ARCO Alaska, Inc. DATE: 04/6/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS DP Pup Nordic Pup Joint 8' ~) 7.88 45 Stds 3,5" Drill pipe 4365.54 7.88 Setting Tool + XO + 3.5" pup jt 8.94 4373.42 Baker Gravel Pack Packer 76 B 2 - 40 Mod "SC-I" 4.80 4382.36 80-40 Upper Ext. 5.5" X 5' 17 Ib/ft L-80 3.80 4387.16 80-40 Gravel Pack Sliding Sleeve 2.56 4390.96 80-40 4.00" ID Seal Bore 1.48 4393.52 80-40 Lower Exten. 5"X16' 13.5 Ib/ft L-80w/5" Seal-Lock HT pin down 15.55 4395.00 X© XO Sub 5" box X 4.5 pin Seal-Lock HT .70 4410.55 Safety Jr 4.5" Shear out Safety Joint (~Set53K ~) 3.18 4411.25 Blank Pipe 4.5" 13.5 Ib/ft L-80 w/4.5" Seal-Lock HT box & pin 60.00 4414.43 w / blade type cent mid & pin end 4474.43 Pup Jt 4.5" X .020 Guage Screen 15.00 4474.43 9 Jts Bakerweld Gravel Pack Screen Size 4.5" X .020" guage X 30', w/ 4489.43 26' wrapped on 13.51b/ft L-80 base pipe, w/weld-on blade 4489.43 type cent at middle and pin end w/HT box & pin 270.00 4489.43 4759.43 Baker Bull Plug 4.5" Seal - Lock HT .57 4759.43 End of Assembly Nordic Rig #3 4760,00 Top of Gravel Pack Packer @ 4376' Original RKB Top of Gravel Pack Packer @ 4382' Nordic RKB Top of Bridge Plug @ 4754' Original RKB Top of Bridge Plug @ 4760' Nordic RKB Remarks: String Weights with Blocks: ??K# Up, ??K# Dn, ?K# Blocks. Ran joints of tubing. Used Arctic Grade APl Modified No Lead thread compound on all connections. Tubing is non-coated. All tubing is new Nordic Rig I13 Drilling Supervisor: Deafl W. Gladden ESP TUBING DETAIL TTCESPCP/Heat Trace 1 D-115 (E3) ARCO Alaska, Inc. DATE: 4/12/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Nordic Rig #3 RKB fo LDS 26.50" RKB 26.50 HGR ABB Vetco Gray Tbg Hanger (Penetrator to MU ring (2.07')' 4.17 26.50 Space Out 3 1/2" EUE 8rd AB Mod Pups (2.25+0.38+0.80) 3.43 30.67 Jts#28-134 3 1/2" 9.3# L-80 EUE 8rd AB Mod Tubing 3364.09 34.10 PUP 3 1/2" EUE 8rd AB Mod Pup 6.09 3398.19 GLM (~New~ 3 1/2" X 1" Camco KBMM GLM ( Run with DV Installed) 6.79 3404.28 PUP 3 1/2" EUE 8rd AB Mod Pup 6.61 3411.07 Jts# 3 - 27 3 1/2" 9.3# L-80 EUE 8rd AB Mod Tubing 777.72 3417.68 PUP 3 1/2" EUE 8rd AB Mod Pup 5.60 4195.40 GLM (RR~) 3 1/2" X 1" Camco KBMM GLM (Run Open -No DV) 6.75 4201.00 PUP 3 1/2" EUE 8rd AB Mod Pup 8~07 4207.75 Jt # 2 3 1/2" 9.3# L-80 EUE 8rd AB Mod Tubing 31.34 4215.82 Jt # 1 3 1/2" 9.3# L-80 EUE 8rd AB Mod Tubing (Sensor Placed 5' f/pin) 31.35. 4247.16 PUP .3 1/2" EUE 8rd AB Mod Pup 10.05 4278.51 3 1/2" Slotted Nipple 3.00 4288.56 3 1/2" Tubing 1ZC XO 1.42 4291.56 ESP Seal Section GSFT DB IL PFS - 5.130 OD 1'3.80 4292.98 ESP Gearbox 9:1 525 Series - 5.250 OD 1.31 4306.78 ESP PCESP Motor 57 HP 1315/26 KMH - 5.620 OD 6.81 4308.09 Bottom of Motor Nordic Rig #31 4314.90 Top of Gravel Pack Packer Original RKB 4376' Top of Gravel Pack Packer Nordic RKB 4382' Heat Trace Cable starts 2.88' up from the "Pin" end Jt# 63 RavChem 354 6' Heat TraceFlatguards 21 4' Heat Trace Flatguards 17 3' Heat Trace Flatguards 1 6' Heat Trace End Shoe 1139 Total Flat Bands Centriliff 147 Total Flat Bands 002 Protectolizers 036 LaSalle Clamps Remarks: String Weights with Blocks: 65K# Up, 50K# Dn, 6K# Blocks. Ran 134 oints of tubing. Drifted tubing, GLMs, & hanger with 2.867" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Tubing is non-coated. ***NOTE .... 4 Joints do not go = Jts 135,136,137 & 138 Nordic Rig #3 Drilling] Supervisor: Dearl W. Gladden ' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 16, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-115 (Permit No. 97-232) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-115. If there are any questions, please call 265-6890. Sincerely, 7. T. W. Mc Kay Senior Drilling Engineer Kuparuk Development 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 [] SUSPENDED [] ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, In¢ 97-232 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 .' . '" 50-029-22840 4 Location of well at surface .... ' ' ~~' 9 Unit or Lease Name 61' FNL, 597' FEL, Sec. 23, TllN, R10E, UM ~ At Top Producing Interval '-,;~,~Jh~:~"'" i I ~- ~~i~ 10 Well Number 1061' FSL, 2512' FEL, Sec. 14, T11N, R10E, UM . ~"~. _~C'"~ ' . ? West Sak 1D-115 At Total Depth ;' '- ' ~!' 11 Field and Pool 1062' FSL, 2526' FEL, Sec. 14, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 22-Dec-97 24-Dec-97 06-Apr-98 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 5142' MD & 4293' TVD 5001' MD & 4152' TVD YES xL~ NO U NA feet MD 1933' APPROX 22 Type Electric or Other Logs Run GPJRes 23 CASING, LINER AND CEMENTING RECORD SE'I-I'ING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24' 9 cu yds High Eady 7.625' 29.7# L-80 SURF. 5127' 9.875' 466 sx AS Ill LW, 368 sx Class G, 60 sx AS I 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' 4406' 4648'-4678' MD 3799'-3829' TVD 4550'-4610' MD 3701'-3761' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4484'-4514' MD 3635'-3665' 'FVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4648'-4678' MD, 4550'-4610' M see attachments 4 spf 4484'-4514' MD 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 4/4/98 Gas Lift Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [ GAS-OIL RATIO 4/11/9~ 4.00 TEST PERIOI: 4 0 36 0I 59 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 145 -15 24-HOUR RATE: 21 1 212 0° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A APF Alaska0il&(~ 2 0 19 8 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE --_ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 4478' 3629' Base West Sak Sand 4914' 4065' Annulus left open - freeze protected with diesel. 31. LIST OF A1ZACHMENTS Summary of Daily Drilling Reports, Directional Survey the foregoing is correct to the best of my knowledge ....... 32. I hereby certify that true and Title ..~-~ -~:~./~zV ?~-".~-----~ DATE Signed Prepared by Name/Number Sharon AIIsup-Drake/263-46'12 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: 05/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-ii5 RIG:PARKER 245 WI: 0% SECURITY:0 STATE:ALASKA API NUMBER: 50-029-22840-00 COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:12/22/97 START COMP:04/03/98 FINAL:04/06/98 12/22/97 (D1) TD/TVD: 1356/0 SUPV:DEB MW: 9.1 VISC: 310 PV/YP: 37/39 (1356) WIPER TRIP AT 1929' MD APIWL: 7.6 Move rig 45' from 1D-118 to 1D-115. Accept rig ~ 0500 hrs. 12/22/97. NU diverter and function test. Spud at 121' and drill to 1356' MD. 12/23/97 (D2) TD/TVD: 4294/0 SUPV:GRW MW: 9.2 VISC: 330 PV/YP: 36/54 (2938) DRILLING @ 4800' Drill from 1356' to 4294' APIWL: 8.2 12/24/97 (D3) TD/TVD: 5142/0 SUPV:GRW MW: 9.2 VISC: 235 PV/YP: 27/37 { 848) RUNNING CASING APIWL: 7.4 Drill from 4294' to 5412' MD. RIH w/hole opener BHA. POOH. 12/25/97 (D4) TD/TV1D: 5142/0 SUPV:GRW MW: 9.3 VISC: 112 PV/YP: 24/21 0) DRILLING STAGE COLLAR APIWL: 10.4 Safety meeting. Run 7-5/8" casing to 5127' Pump first and second stage cement. NU BOPE and test. 12/26/97 (DS) TD/TVD: 5142/0 SUPV:GRW MW: 8.3 VISC: 28 PV/YP: 1/ 0 0) RUNNING 3.5" KILL STRING APIWL: 0.0 Drill stage collar. Drill cement from 4779' to 5002' 12/27/97 (D6) TD/TVD: 5142/0 SUPV:GRW MW: 8.3 VISC: 28 PV/YP: 1/ 0 0) RIG RELEASED APIWL: 0.0 Safety meeting. RIH with 3.5" tubing. Pump caustic/hogwash. Freeze protect. N/D BOPE. N/U tree. Release rig at 2130 hrs. 12/27/97. Date: 05/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS -- WELL:iD-ii5 RIG:PARKER 245 WI: 0% SECURITY:0 STATE:ALASKA API NUMBER: 50-029-22840-00 COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:12/22/97 START COMP:04/03/98 FINAL:04/06/98 -- 04/03/98 (C7) TD: 5142' PB: 5142' 04/04/98 (C8) TD: 5142' PB: 5142' 04/05/98 (C9) TD: 5142' PB: 5142' 04/06/98 (Ci0) TD: 5142' PB: 5142' 04/07/98 (Cll) TD: 5142' PB: 5142' L/D 3.5" TUBING FRAC SAND MW: 8.8 KCL SUPV:DLW Accept rig @ 1330 hrs. 4/3/98. Filter KC1 completion fluid into pits. N/D tree, N/U BOPE and test BOPE 250/3000 psi. R/U TO P/U 3.5' TBG & RIH MW: 8.8 KCL SUPV:DLW POOH 3.5" tubing. Clean out 7-5/8" casing from 4452' to 4990' RUN 3.5" ESP COMPLETION SUPV:DLW RIH with 3.5" tubing. MW: 8.7 KCL N/D BOPE, N/U TREE MW: 8.7 KCL SUPV:DLW Continue to set Centrilift 3.5" retrievable pump. Set packoff and test to 2500 psi. OK. Run 3.5" ESP completion. RELEASE RIG MW: 8.7 KCL SUPV:DLW NU tree and test packoff to 5000. Test tree to 250/5000. Freeze protect well. Secure and move off well. Release rig ~ 0900 hrs. 4/7/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 JOB SCOPE PERFORATE, PERF SUPPORT JOB NUMBER 0205980741.1 DATE DAILY WORK UNIT NUMBER 02/25/98 FRAC A2 SANDS KEY PERSON DS-GALLEGOS Final Inner Ann 1000 PSI DAY OPERATION COMPLETE I SUCCESSFUL 3 YES I YES Initial Tbg Press ~Final Tbg Press I Initial Inner Ann 115 PSI~ 1000 PSII 90 PSI DAILY SUMMARY SUPERVISOR BRADLEY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI FRAC A2 SANDS. PUMP FRAC AT 20 BPM IN 2 - 9 PPG STAGES. PROPLOCK ADDED TO ALL SAND STAGES AFTER THE 2 PPG FLAT STAGE. WHITE DIE ADDED TO PROPPANT. PUMPED TOTAL OF 101073 # 16/20 PROPPANT. PLACED 100763# BEHIND PIPE WITH 9 PPG AT PERFS. TIME LOG ENTRY 09:00 12:20 13:25 14:45 17:15 MIRU DS FRAC CREW AND ASSOCIATED EQUIPMENT. HELD SAFETY MEETING (21 PEOPLE ON LOCATION). RU HOT OIL TO BACKSIDE AND PT TO 3500#. STAB TREESAVER AND PT TO 5100#. UNABLE TO GET TREESAVER CUPS TO HOLD PRESSURE. TOOL IS STROKED DOWN BUT WILL NOT HOLD PRESSURE. DECIDE TO LEAVE COMPANION VALVE CLOSED AND PROCEED WITH FRAC (TOOL WILL STILL ISOLATE PROPLOCK FROM TREE). PUMP 20 BBL IMPULSE TEST WITH SLICK DIESEL AT 20 BPM AND 3218 PSI. SD AND MONITOR PRESSURES. ISIP = 1050#. PUMP BREAKDOWN STAGE USING 70# HEC GEL W/3% KCL AT 30 BPM AND MAX PRESSURE OF 4100#. PERFORM STEP DOWN TEST W/4 RATES. SD AND MEASURE ISIP AT 1160#. FLUSH W/61 BBLS DIESEL AT 20 BPM AND 2900#. PERFORM PULSE TESTS AS REQUIRED. MONITOR PRESSURES. BEGIN PUMPING DATAFRAC. SD AFTER 33 BBLS & WAIT ON FUEL. FUEL EQUIPMENT. PUMP DATAFRAC FROM BEGINNING W/70# HEC - 3% KCL SW AND DIESEL. 156 BBLS TOTAL SLURRY VOLUME PUMPED. FINAL PRESSURE @ 3230 PSI W/ISIP OF 1180 PSI. MONITOR WHTP F/CLOSURE. ESTIMATED CLOSURE TIME 9 MINUTES. BASED ON CLOSURE VS TIME PLOT, INCREASE TO 36 BBL PAD (ORIGINAL DESIGN = 30 BBLS). START FRAC. PUMP PAD AT 5 BPM, INCREASE RATE TO 20 BPM AFTER 50 BBLS (14 BBLS INTO 2 PPG STAGE). PUMP FRAC AT 20 BPM IN 2- 9 PPG STAGES. PROPLOCK ADDED TO ALL SAND STAGES AFTER THE 2 PPG FLAT STAGE. WHITE DIE ADDED TO PROPPANT. PUMPED TOTAL OF 101073 # 16/20 PROPPANT. PLACED 100763# BEHIND PIPE WITH 9 PPG AT PERFS. TIME 18:00 18:30 20:00 LOG ENTRY REVERS_______[.E CIRCULATE 200 BBLS SLICK DIESEL AT 6 BPM WHILE HOLDING 500# ON CHOKE. BEGIN RD DOWELL. DOWELL RD. TURNED WELL OVER TO DSO TO BE LEFT SI. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 DATE O3/O 1/98 DAY 3 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK "A3" SAND FRAC OPERATION COMPLETE ISUCCESSFUL IKEYPERSON YES YES DS-GALLEGOS InitialTbgPress IFinalTbgPress IlnitiallnnerAnn IFinallnnorAnn 1385PSl 700PSl 335PSl 700PSl DAILY SUMMARY JOB NUMBER 0226980516.1 UNIT NUMBER SUPERVISOR CHANEY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI I"A3" SAND FRAC COMPLETED THRU FLUSH. INJECTED 100343 LBS OF PROP IN THE FORM W/8.5# PPA OF #16/20 @ THE PERF'S. PROP COATED W/ PROPLOK AND DYED "RED". TBG AND CSG FREEZE PROTECTED W/DIESEL. TIME 11:30 14:00 14:15 15:25 LOG ENTRY MIRU DOWELL FRAC EQUIP, HES PROPLOK EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCKS. HELD SAFETY MEETING (21 PEOPLE ON LOCATION) PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET TREESAVER & PT'D HIGH PRESSURE LINES TO 5000 PSI. PUMP IMPULSE TEST W/DIESEL @ 20 BPM. SLURRY VOLUME PUMPED 20 BBLS.MAXIMUM AND ENDING PRESSURE 3400 PSI. S/D AND OBTAINED ISlP OF 1058 PSI W/F.G. @ (.63). STOOD-BY FOR 1 HOUR. PUMP BREAKDOWN W/50# HEC - 3% KCL SW & DIESEL @ 30 TO 15 BPM.PUMPED 150 BBLS OF HEC THEN STEPPED RATE DOWN TO S/D AND OBTAINED EARLY ISlP OF 805 PSI W/F.G. @ (.66). PUMP FLUSH W/61 BBLS OF DIESEL S/D AND OBTAINED ISlP OF 1199 PSI W/F.G. @ (.67). TOTAL SLURRY VOLUME PUMPED 215 BBLS. MAXIMUM PRESSURE 4200 PSI AND FINAL ENDING PRESSURE 2375 PSI. MONITORED WHTP AND PULSED TO PICK CLOSURE. CLOSURE TIME OF 9MINS @ 1102 PSI. 16:15 PUMP DATAFRAC W/50# HEC - 3% KCL SW & DIESEL @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 131 BBLS. MAXIMUM & ENDING PRESSURE 2450 PSI. S/D AND OBTAINED ISlP OF 1260 PSI W/F.G. @ (.69). STOOD-BY AND MONITORED WHTP FOR CLOSURE. CLOSURE TIME OF 13 MINS @ 1125 PSI PAD VOLUME = 28 BBLS. TIME 17:30 LOG ENTRY PUMP FRAC W/50# HEC - 3% KCL SW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. PUMPED 100862 LBS OF #16/20 PROP. INJECTED 100343 LBS OF PROP IN THE FORMATION W/8.5# PPA OF #16/20 @ THE PERF'S. PROP COATED W/ PROPLOK AND DYED "RED". LEFT 519 LBS OF PROP IN THE WELLBORE AND EST FILL TO BE @ 4660'. 18:30 REVERSED OUT W/120 BBLS OF DIESEL (3 TBG VOLUMES). TBG AND CSG FREEZE PROTECTED W/DIESEL. STARTED R/D 19:30 20:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETED AND ALL EQUIP LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 JOB SCOPE PERFORATE, PERF SUPPORT JOB NUMBER 0205980741.1 DATE DAILY WORK UNIT NUMBER 03/01/98 PERFORATE, PERF SUPPORT KEY PERSON SWS-JOHNSON SUPERVISOR BLACK DAY OPERATION COMPLETE I SUCCESSFUL 6 YES J YES Initial Tbg Press Final Tbg Press I Initial Inner Ann 400 PSI 400 PSII 0 PSI DAILY SUMMARY Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSI PERFORATED "A3" FROM 4648 - 4678' ELM WITH 2-1/8" EJ BH @ 4 SPF & 180 DEG PHASED. TIME LOG ENTRY 05:00 06:30 MIRU SWS (JOHNSON & CREW) & LRS. MU GUN ASSEMBLY (30' 2-1/8" EJ DP/CCL/HD) TL-36'. ATTEMPT TO PT BOPE (COMPANION VALVE LEAKING). WO VALVE CREW. RU & ATTEMPT TO FIX STEM LEAK. UNABLE TO. WO APC TO CHANGE OUT VALVE. RU & CHANGE OUT CROSS & VALVE. PT BOPE TO 1500 PSI. LEAVE LUBRICATOR PRESSURED & OPEN SWAB. 09:30 RIH & FIND BOTTOM OF HOLE @ 4681' ELM. TIE IN W/2/22/98 SWS GR/CCL TIE IN LOG. PERFORATE "A3" FROM 4648 - 4678' ELM WITH 2-1/8" EJ DP @ 4 SPF & 180 DEG PHASED. GOOD SURFACE INDICATIONS. LOG OFF. 10:15 POOH. 11:00 AT SURFACE. ALL SHOTS FIRED. BEGIN RD. 11:30 RD COMPLETE. MOVE TO 1D-01. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 JOB SCOPE PERFORATE, PERF SUPPORT JOB NUMBER 0205980741.1 DATE DAILY WORK UNIT NUMBER 03/01/98 PERFORATE, PERF SUPPORT OPERATION COMPLETE I SUCCESSFUL YES J YES Initial Tbg Press Final Tbg Press I Initial Inner Ann 400 PSI 400 PSII 0 PSI DAY 6 KEY PERSON SWS-JOHNSON Final Inner Ann I I 0 PSI DAILY SUMMARY SUPERVISOR BLACK Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PERFORATED "A3" FROM 4648 - 4678' ELM WITH 2-1/8" EJ BH @ 4 SPF & 180 DEG PHASED. TIME LOG ENTRY 05:00 06:30 09:30 10:15 11:00 11:30 MIRU SWS (JOHNSON & CREW) & LRS. MU GUN ASSEMBLY (30' 2-1/8" EJ DP/CCL/HD) TL-36'. ATTEMPT TO PT DOPE (COMPANION VALVE LEAKING). WO VALVE CREW. RU & ATTEMPT TO FIX STEM LEAK. UNABLE TO. WO APC TO CHANGE OUT VALVE. RU & CHANGE OUT CROSS & VALVE. PT DOPE TO 1500 PSI. LEAVE LUBRICATOR PRESSURED & OPEN SWAB. RIH & FIND BOTTOM OF HOLE @ 4681' ELM. TIE IN W/2/22/98 SWS GR/CCL TIE IN LOG. PERFORATE "A3" FROM 4648 - 4678' ELM WITH 2-1/8" EJ DP @ 4 SPF & 180 DEG PHASED. GOOD SURFACE INDICATIONS. LOG OFF. POOH. AT SURFACE. ALL SHOTS FIRED. BEGIN RD. RD COMPLETE. MOVE TO 1D-01. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 JOB SCOPE PERFORATE, PERF SUPPORT JOB NUMBER 0205980741.1 DATE DAILY WORK UNIT NUMBER 03/04/98 PERFORATE A4/B SAND KEY PERSON OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press 0 PSI Final Tbg Press 0 PSI Initial Inner Ann 0 PSI DAY 7 Final Inner Ann I 0 PSI DAILY SUMMARY SUPERVISOR SCHUROSKY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PERFORATE A4/B SAND, 4550' TO 4610'. 4-SPF 2 1/8' ENERJET GUN WITH BIGHOLE CHARGES. TIME LOG ENTRY 13:00 14:00 AFTER GETTING MAST UNIT WHEEL REPAIRED. MIRU SWS, G. ELMORE AND CREW. HOLD TGSM, (MULTI. CONTRACTORS ON PAD). MAKE UP TOOLS AND GUN- 30', 2 1/8" ENERJET WITH 4SPF, BIGHOLE CHARGES.CCL.VVT BAR. TOTAL TOOL LENGHT 40.3'. 15:00 PT LUB AND BOP STACK TO 3000#. RIH TO 4530', MAKE TIE-IN PASS FOR DEPTH CONTROL. SHOOT GUN AT 4580' TO 4610' WITH GOOD INDICATION AT SURFACE GUNS FIRED.POOH 16:30 AT SURFACE, CHECK GUN, ALL SHOTS FIRED.MAKE UP 30' GUN SAME AS ABOVE. PT LUB. AND BOP STACK. RIH TO 4530'. MAKE TIE-IN PASS FOR DEPTH CONTROL, SHOOT GUN AT 4550' TO 4580' WITH GOOD INDICATION AT SURFACE GUN FIRED, POOH 18:00 AT SURFACE, CHECK GUN, ALL SHOTS FIRED. RDMO. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 DATE O3/O5/98 DAY 6 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK PUMP A-4 & [] SANDS FRAC OPERATION COMPLETE I SUCCESSFUL YES YES Initi~tl Tbg Press t 0 PSI I JOB NUMBER 0226980516.1 UNIT NUMBER IKEY PERSON SUPERVISOR DS-YOKUM JOHNS Final Tbg Press 0 PSI Initial Inner Ann I I 0 PSI Final Inner Ann 0 PSI Initial OuteroAnnpsl I Final Outer Ann 0 PSI DALLY SUMMARY I PUMPED A-4 & B SANDS FRAC THROUGH FLUSH ,PLACING 142,495# OF 16/20 PROPPANT WITH PROPLOCK INTO I FORMATION. TIME LOG ENTRY 06:30 MIRU DOWELL FRAC EQUIP., HALLIBURTON PROPLOCK, AND APC SUPPORT. 08:12 HELD JOB SITE SAFETY MEETING 08:50 PRESSURE TEST TREATING LINE TO 5800 PSI. 08:57 PUMPED IMPULSE TEST WITH 20 BBLS DIESEL AT 20 BPM AND 3072 PSI. 10:03 PUMPED BREAKDOWN WITH 50# HEC GEL, 39 BBLS AT 24 BPM AND 2884 PSI.FLUSH WITH 67 BBLS DIESEL. SHUTDOWN FOR ISIP 1158 PSI. 11:33 PUMP DATA FRAC AND FLUSH WITH 150 BBLS HEC AND 52 BBLS DIESEL. SHUT DOWN FOR ISIP 950 PSI. AND CLOSURE CALCULATIONS. 12:31 PUMP 40 BBLS PAD OF 50# HEC GEL, 5 TO 15 BPM AND 1465 PSI. 12:39 PUMP 142,495# OF 16/20 PROPPANT WITH PROPLOCK ADDED INTO A-4 & B SANDS. PUMPED 2PPA AND FINAL RAMP UP TO 10 PPA AT PERFS. 15 BPM AND 1323 PSI. 13:45 SHUTDOWN AND REVERSED OUT ANY SLURRY REMAINING IN TUBING WITH DIESEL. 14:00 TURN WELL OVER TO COIL TUBING FOR "D" SANDS PREP. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 JOB SCOPE PERFORATE, PERF SUPPORT OPERATION COMPLETE SUCCESSFUL YES YES PSI II Final Tbg Press 3OO JOB NUMBER 0205980741.1 0 PSI 0 PSI DATE DALLY WORK UNIT NUMBER 03/07/98 PERFORATE D SAND DAY IKEY PERSON SUPERVISOR _ 8 I SWS-ELMORE SCHUROSKY Initial Tbg Press Initial Inner Ann I Final Inner Ann Initial Outer Ann Final Outer Ann 300 PSI 0 PSII 0 PSI DAILY SUMMARY PERFORATED THE D SAND 4484' TO 4514' WITH 30' 2 1/8" ENERJET 4SPF WITH BIGHOLE CHARGES I TIME LOG ENTRY 01:00 MIRU SWS LOGGING UNIT, HOLD TGSM -- PERF GUN SAFETY AND RADOI SILENCE 02:00 MAKE UP 30'2 1/8" ENERJET, 4SPF,BIGHOLE CHARGES. 03:00 PT. LUB AND BOP STACK TO 3000#. RIH WITH GUN, WT. BAR, CCL, AND HEAD TOTAL LENGHT 35'. 04:00 TIE IN FOR DEPTH CONTROL WITH GR/CCL LOG DATED 2/22/98. 04:15 SHOOT GUN AT 4484' TO 4514' WITH GOOD INDICATION AT SURFACE THAT GUN FIRED.POOH. 04:45 AT SURFACE WITH TOOLS, CHECK GUN-- ALL SHOTS FIRED. RDMO ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-115(W4-6)) WELL 1D-115 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 0226980516.1 DATE DALLY WORK UNIT NUMBER 03/07/98 PUMP "D" SANDS FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 8 YES I YES DS-YOKUM JOHNS Final Tbg Press 950 PSI Initial Inner Ann 12OO PSI Initial Tbg Press 250 PSI Final Inner Ann I I 1200 PSI Initial Outer Ann I I 0 PSI Final Outer Ann 0 PSI DAILY SUMMARY PUMPED "D" SANDS FRAC WITH 119,560# OF PROPPANT TO 9 PPA. FLUSHED TO COMPLETION AND REVERSED OUT 2 VOLUMES OF TUBING FLUIDS. TIME LOG ENTRY 07:30 MIRU DOWELL FRAC EQUIP, HALLIBURTON PROP LOCK SKID AND APC SUPPORT. 08:49 HELD JOB SITE SAFETY MEETING. 09:10 PRESSURE TEST SURFACE LINES. TO 5600 PSI. 09:29 PUMP IMPULSE TEST WITH 20 BBLS DIESEL AND 20 BPM 3255 PSI. SHUT DOWN FOR ISIP 987 PSI. 10:27 PUMP BREAKDOWN WITH 200 BBLS OF 50# HEC AT 30 TO 15 BPM AND 4239 TO 1817 PSI. FLUSH WITH 64 BBLS DIESEL. SHUTDOWN FOR ISIP. 11:27 PUMP DATA FRAC AND DISPLACEMENT. WITH 100 BBLS HEC AND 49 BBLS DIESEL. SHUTDOWN FOR ISIP AND CLOSURE CALCULATIONS. 12:54 PUMP 23 BBLS PAD OF 50# HEC AT 5 BPM AND 1579 PSI. 12:59 PUMP 119,560 # OF 16/20 PROPPANT, 1040 BBLS OF 50# GEL SLURRY. 2 TO 9PPA TO PERFS. FINAL TREATMENT 1428 PSI. AT 15 BPM. 13:49 FLUSH WITH 39 BBLS DIESEL, AND REVERSE OUT 2 VOLUMES OF TUBING FLUIDS, GETTING BACK CLEAN DIESEL. 13:52 SHUT DOWN, RDMO SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA INC WEST SAK / 1D-115 500292284000 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 DATE OF SURVEY: 122297 MWD SURVEY JOB NUMBER: AKMM80059 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.50 121.00 121.00 9.50 170.01 170.01 58.51 199.87 199.87 88.37 288.87 288.79 177.29 0 0 N .00 E .00 .00N .00E .00 0 0 N .00 E .00 .00N .00E .00 0 4 S 49.33 W ,15 .02S .02W .01 0 15 N 10.20 E' 1.06 .04N .02W .04 4 15 N 60.93 W 4.70 1.84N 2.88W 3.41 379.12 378.54 267.04 468.70 466.96 355.46 557.98 554.13 442.63 650.01 642.54 531.04 739.44 726.89 615.39 7 39 N 57.'20 W 3.78 6.73N 10.86W 12.77 10 44 N 52.03 W 3.57 15.09N 22.46W 27.00 14 6 N 50.19 W 3.79 27.18N 37.37W 45.96 18 7 N 55.02 W 4.60 42.57N 57.72W 71.28 20 39 N 56.51 W 2.89 59.25N 82.27W 100.90 831.27 812.23 700.73 922.39 895.02 783.52 1013.26 974.55 863.05 1104.92 1052.13 940.63 1200.87 1131.53 1020.03 22 38 N 57.46 W 2.19 77.69N 110.68W 134.73 26 40 N 59.04 W 4.49 97.66N 143.02W 172.72 31 7 N 60.07 W 4.93 119.88N 180.89W 216.63 33 12 N 59.90 W 2.27 144.29N 223.14W 265.42 35 4 N 60..42 W 1.96 171.08N 269.85W 319.26 1294.10 1206.28 1094.78 1389.52 1279.62 1168.12 1485.14 1349.68 1238.18 1580.01 1415.48 1303.98 1674.77 1477.60 1366.10 38 18 N 59.16 W 3.57 199.12N 317.97W 374.96 41 13 N 58.60 W 3.07 230.67N 370.21W 435.98 44 31 N 58.46 W 3.46 264.63N 425.69W 501.01 47 37 N 59.08 W 3.30 300.05N 484.12W 569.32 50 26 N 60.19 W 3.09 336.20N 545.86W 640.87 1865.66 1598.20 1486.70 2055.62 1715.92 1604.42 2245.57 1834.33 1722.83 2438.01 1956.85 1845.35 2620.92 2073.22 1961.72 51 12 N 60.43 W .41 409.49N 674.40W 788.83 52 12 N 59.52 W .65 484.09N 803.46W 937.90 50 40 N 59.22 W .81 559.75N 931.25W 1086.40 50 14 N 58.93 W .25 636.01N 1058.55W 1234.78 50 44 N 59.47 W .36 708.26N 1179.76W 1375.88 2811.97 2194.01 2082.51 3002.47 2316.74 2205.24 3097.97 2380.59 2269.09 3188.97 2444.71 2333.21 3284.38 2516.11 2404.61 50 49 N 61.58 W .86 781.08N 1308.60W 1523.87 48 56 N 61.04 W 1.02 851.00N 1436.39W 1669.49 47 7 N 59.78 W 2.13 886.05N 1498.13W 1740.48 43 15 N 59.37 W 4.28 918.73N 1553.79W 1805.03 39 49 N 59.81 W 3.60 950.76N 1608.35W 1868.29 3378.59 2590.63 2479.13 3474.10 2670.37 2558.87 3567.62 2751.71 2640.21 3664.13 2837.95 2726.45 3759.19 2924.76 2813.26 35 34 N 61.06 W 4.58 979.21N 1658.44W 1925.89 31 10 N 61.63 W 4.63 1004.41N 1704.52W 1978.40 27 57 N 59.96 W 3.55 1026.89N 1744.80W 2024.52 25 21 N 59.58 W 2.69 1048.68N 1782.21W 2067.81 22 42 N 58.85 W 2.81 1068.48N 1815.47W 2106.52 ORigiNAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC WEST SAK / 1D-115 500292284000 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 DATE OF SURVEY: 122297 MWD SURVEY JOB NUMBER: AKMM80059 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3853.69 3012.96 2901.46 19 21 N 58.71 W 3.56 1086.05N 1844.47W 2140.42 3948.83 3103.75 2992.25 15 21 N 61.70 W 4.31 1100.22N 1869.04W 2168.78 4043.50 3195.89 3084.39 11 7 N 63.72 W 4.49 ll10.20N 1888.27W 2190.42 4138.00 3289.27 3177.77 6 19 N 65.20 W 5.07 11t6.43N 1901.18W 2204.71 4231.48 3382.42 3270.92 3 8 N 66.34 W 3.41 1119.62N 1908.20W 2212.39 4328.91 3479.73 3368.23 2 17 N 69.93 W .88 1121.36N 1912.48W 2216.96~ 4423.05 3573.83 3462.33 0 58 N 81.33 W 1.44 1t22.13N 1915.05W 2219.57 4610.65 3761.40 3649.90 1 4 N 82.73 W .05 1122.59N 1918.39W 2222.69 4802.72 3953.43 3841.93 1 13 N 89.99 W .11 1122.82N 1922.25W 2226.15 4992.13 4142.79 4031.29 1 15 S 87.12 W .04 1122.72N 1926.36W 2229.65 5085.35 4235.99 4124.49 1 16 N 89.78 W 5142.00 4292.63 4181.13 1 16 N 89.78 W .08 1122.67N 1928.42W 2231.41 .00 1122.68N 1929.69W 2232.51 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2232.51 FEET AT NORTH 59 DEG. 48 MIN. WEST AT MD = 5142 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 300.12 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,142.00' MD SPERRY-SUN DRILLING sERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC WEST SAK / 1D-115 500292284000 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 DATE OF SURVEY: 122297 JOB NUMBER: A_KMM80059 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.50 1000.00 963.16 851.66 2000.00 1681.83 1570.33 3000.00 2315.11 2203.61 4000.00. 3153.35 3041.85 .00 N .00 E 116.49 N 175.01 W 461.80 N 765.58 W 850.10 N 1434.76 W 1106.09 N 1880.14 W .00 36.84 36.84 318.17 281.33 684.89 366.72 846.65 161.76 5000.00 4150.66 4039.16 5142.00 4292.63 4181.13 1122.71 N 1926.53 W 1122.68 N 1929.69 W 849.34 2.69 849.37 .04 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC WEST SAK / 1D-115 500292284000 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 DATE OF SURVEY: 122297 JOB NUMBER: AKMM80059 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.50 111.50 111.50 .00 211.50 211.50 100.00 311.66 311.50 200.00 412.43 411.50 300.00 .00 N .00 .00 N .00 .13 N .10 2.79 N 4.52 9.41 N 14.82 E .00 E .00 .00 W .00 .00 W .16 .16 W · .93 .77 514.18 511.50 400.00 617.49 611.50 500.00 723.02 711.50 600.00 830.49 811.50 700.00 940.91 911.50 800.00 20.81 N 29.62 36.90 N 49.83 56.08 N 77.51 77.54 N 110.44 101.99 N 150.28 W 2.68 1.75 W 5.99 3.31 W 11.52 5.54 W 18.99 7.46 W 29.41 10.42 1056.44 1011.50 900.00 1176.40 1111.50 1000.00 1300.76 1211.50 1100.00 1432.42 1311.50 1200.00 1574.14 1411.50 1300.00 131.03 N 200.26 164.14 N 257.62 201.25 N 321.52 245.64 N 394.70 297.83 N 480.42 W 44.94 15.53 W 64.90 19.96 W 89.26 24.37 W 120.92 31.66 W 162.64 41.71 1727.99 1511.50 1400.00 1886.89 1611.50 1500.00 2048.40 1711.50 1600.00 2209.55 1811.50 1700.00 2367.10 1911.50 1800.00 356.60 N 581.46 417.66 N 688.79 481.20 N 798.54 545.49 N 907.31 607.88 N 1011.86 W 216.49 53.86 W 275.39 58.90 W 336.90 61.51 W 398.05 61.15 W 455.60 57.55 2523.47 2011.50 1900.00 2681.41 2111.50 2000.00 2839.66 2211.50 2100.00 2994.50 2311.50 2200.00 3142.60 2411.50 2300.00 669.91 N 1114.84 732.06 N 1220.10 791.30 N 1327.49 848.09 N 1431.13 902.30 N 1525.92 W 511.97 56.37 W 569.91 57.94 W 628.16 58.25 W 683.00 54.84 W 731.10 48.10 3278.36 2511.50 2400.00 3404.05 2611.50 2500.00 3521.76 2711.50 2600.00 3634.75 2811.50 2700.00 3744.78 2911.50 2800.00 948.81 N 1605.00 986.25 N 1671.20 1016.00 N 1725.62 1042.22 N 1771.18 1065.58 N 1810.66 W 766.86 35.76 W 792.55 25.69 W 810.26 17.71 W 823.25 12.99 W 833.28 10.03 3852.13 3011.50 2900.00 3956.85 3111.50 3000.00 4059.39 3211.50 3100.00 4160.35 3311.50 3200.00 1085.77 N 1844.01 1101.20 N 1870.87 1111.51 N 1890.91 1117.40 N 1903.28 840.63 7.35 845.35 4.72 847.89 2.54 848.85 .97 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA INC WEST SAK / 1D-115 500292284000 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 DATE OF SURVEY: 122297 JOB NUMBER: AKMM80059 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 4260.61 3411.50 3300.00 4360.70 3511.50 3400.00 4460.73 3611.50 3500.00 4560.74 3711.50 3600.00 4660.76 3811.50 3700.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH MD-TVD VERTICAL EAST/WEST DIFFERENCE CORRECTION 1120.26 N 1909.66 W 849.11 .25 1121.80 N 1913.68 W 849.20 .09 1122.23 N 1915.69 W 849.23 .02 1122.47 N 1917.46 W 849.24 .02 1122.71 N 1919.33 W 849.26 .02 4760.78 3911.50 3800.00 4860.81 4011.50 3900.00 4960.83 4111.50 4000.00 5060.85 4211.50 4100.00 5142.00 4292.63 4181.13 1122.82 N 1921.35 W 849.28 .02 1122.82 N 1923.49 W 849.31 .02 1122.75 N 1925.67 W 849.33 .02 1122.67 N 1927.88 W 849.35 .02 1122.68 N 1929.69 W 849.37 .02 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 13-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-115 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 5,142.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company I~) I:! I I_1_ I I~ G S E I:1 ~J I r- Eli S WELL LOG TRANSMITTAL To: State of Alaska January 14, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-115, AK-MM-80059 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-115: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22840-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22840-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December l 9, 1997 Michael Zanghi Drilling Superintendent ,ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: West Sak 1D-115 (E3) ARCO Alaska. Inc. Permit No 97-232 Sur. Loc.: 61'FNL, 597'FEL, Sec. 23, TllN, R10E, UM Btmhole Loc: 1051'FSL, 2514'FEL, Sec. 14, TllN, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf enclosures cc: Department of Fish 8: Game. Habitat Section w/o encl. Department of Environmental Consen, ation w/o end STATE OF ALASKA "~-~ ~' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory [--] StratigraphicTest F~ Development Oil X Re-Entry DeepenI Service r-] Development Gas E] SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' 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) 61' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1051' FSL, 2514' FEL, Sec. 14, T11N, R10E, UM West Sak 1D-115 (E3) #U-630610 At total depth 9. Approximate spud date Amount 1051' FSL, 2514' FEL, Sec. 14, T11N, R10E, UM 12/23/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-03 5120' MD 2514' @ TD feet 48.8' @ 602' feet 2560 4250' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 50.7° Maximum surface 1418 psig At total depth 1863 psig (-I-VD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOD 5079' 41' 41' 5120' 4250' 525 Sx Arcticset III & 310 Sx Class (3 & 60 sx AS I 19. To be completed for RedrilI, Re-entry, and Deepen Operations. REC~iVFDI,., ~" Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet OEO '~ ~ 1997 Effective depth: measured feet Junk (measured) Gas Cons. true vertical feet ,~a$~G'?, 0[~ & Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production PerforatioLinn2repth: measured ORIGINAL true vertical 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling 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 correct to the best of my knowledge Title Drilling Superintendent Date Commission Use Only Permit Number | APl number I Approval date I See cover letter for 77--.2--,..~-- /50-O'~--¢~ ~F--2-~-4-'/~4~ ~;~--~/f~.~','¢ other requirements Conditions of approval Samples required F Yes ~ No Mud Icg required [-' Yes [~ No Hydrogen sulfidemeasures DYes DNo Directional survey required [~Yes BI No Required workingpressureforBOPE [~2M ~ 3M [~ 5M [~ 1OM [~ 1SM Other: (ii-r' bawd W. Johnston by order of Date/¢;~./¢.~ ~¢ Approved by Commissioner the commission Form 10-401 Rev. 7-24-89 Submit in triplicate Drill and Case Plan for West Sak 1 D-115 (E3) Frac-for-Sand Control Producer General Procedure: , Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , 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. . Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. . Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. . Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and drill out stage collar. Clean out to PBTD. . Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Pick up 3-1/2" tubing deadstring and TIH. Circulate filtered brine to desired level. 11. Hang tubing in wellhead, install back pressure valve, and nipple down BOP stack. Nipple up and pressure test production tree. Secure well. 12. Release rig. TAB, 11/10/97, Rev.3 Page 1 Completion Plan for West Sak 1D-115 (E3) Frac-for-Sand Control Producer Four-Staqe, Frac-for-Sand Control Completion (Off Ri.q Fracs) General Procedure: Well Preparation · RECEIVED DEC 1997 N~k~ Oil & G~ Con~. Commission Anchorage 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. Stage 1 . 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 1 overbalanced, and POOH with E-line. , Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. . 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 1 from Stage 2 to follow. Pressure test sand plug as required. . RIH with slickline and confirm sand top above Stage 1 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 , 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. Page 2 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 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 3 13. Rig up thru-tubing perf 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. 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POQH 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 frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. 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 frac, E-line, CTU, and slickline equipment as required. 20. 21. Page 3 Pull Deadstring, Clean Out Well, Run ESP and Production Tubing 24. MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. 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 and 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. Change rams to 2- 7/8" and pressure test same unless VBR's are available. 31. Pick up Centrilift PCP-ESP (progressive cavity ESP) on 2-7/8" production tubing. 32. Run in well with PCP-ESP pump 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. 34. Position PCP-ESP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. TAB, 11/10/97, Rev.3 Page 4 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-115 (E3) Drillinq Fluid Type Extended Bentonite Slurry Drillin_cl 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 9.6-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drillinq 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 combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-115 (E3) 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. Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,622' MD/I'VD. 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/fi from the West Sak base to surface, the following MASP can be computed: MASP = (4050 ft)(0.46 - 0.11 psi/fi) = 1418 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 BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5~8" 29.7# LB0 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. A deadstring will then be run in the well in preparation for off-rig perforating and fracture stimulation treatments. A completion rig would then return to the well following fracture stimulation work to remove the deadstring, and to install the ESP pump, power cable, heat trace, and production tubing. Page 2 Drillincl Area Risks: Drilling risks in the West Sak 1D-115 (E3) 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. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-115 (£3). Well Proximity Risks: The nearest existing well to West Sak 1D-115 (E3) is KRU 1D-03. As designed, the minimum distance between the two wells would be 49' at 602' 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 an 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-115 (E3) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 7-5~8" combination surface / production casing and prior to the drilling rig moving off of the well. TAB, 12/04/97 Page 3 I Created t~ Cmch For: T Mci(AY: Dote plotted : 28-Dct-97 Plet Relersnce is WS 10-115/E3 Version ~4. C~ordinotes ore in feet reference slot ~115. T~e Vertical Depths are reference ~ (Per,er ~245) 240 480 72O 960 1200 1440 i 680 1920 2160 2400 264O 288O 5i20 3360 3600 3840 4080 4320 ARCO ALASKA,'c. Structure : Pad 1D Well: E3 Field : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 112' <- West (feet) 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 I I I I I I t I I I I I I I I I I I I I I I I . TARGET/TD LOCATION: ~ I 1051' FSL, 2514' FEL I / % [ SEC' 14'T11N' R10E I I _~A... I TARGET - A3 TARGET ~, '-'"-"~../Top Ugnu Sands TVD=3770 ~ ~ TMD=4640 ~ ~ OEP=221 6 ~. NORTH 1112 WEST 1917 '~~ermafrost EOC TVD=1408 TMD=1567 DEP=525 B/ PERMAFROST TVD=I 640 TMD=1955 DEP=808 K0P TVD=300 TMD=300 DEP=O 4.00 8.00 12.00 16.00 20.00 DLS: 4.00 deg per 100 ft 24.00 28.00 32.00 36.00 40.00 44.00 48.00 MAXIMUM ANGLE 50.67 DEG 300.12 AZIMUTH 2216' {TO TARGET) BEGIN ANGLE DROP TVD=2364 TMD=3075 DEP=1691 48.00 44.00 40.00 32.00 DLS: 4.00 deg per 100 ft 24.00 20.00 16.00 ~ 12.00 8.00 4.00 TARGET - W SAK A3 TARGET ANGLE VERTICAL T/ UGNU SNDS TVD=2912 TMD=5767 DEP=2102 END ANGLE DROP TVD=3472 TMD=4542 DEP=2216 T/ W SAK SNDS TVD=3622 TMD=4492 DEP=2216 TVD=3770 TMB=4640 DEP=2116 t B/ W SAK SNDS TVD=4050 TMD:4920 OEP=2216 JIL TD - cs~ ~T =VD:4250 ?MD:5120 DEP:22t6 i I I i i i i I I I i t i I i i I i i i 0 240 480 720 960 1200 1440 1680 1920 2160 Verfical Secfion (feet) -> Azirnuth 300.12 wifh reference 0.00 N, 0.00 E from slot #115 2400 200 [ 1400 1200 lO00 8OO 600 400 200 0 200 SURFACE LOCATION: 61' FNL, 597' FEL SEC. 23, T11N, R10E A Creo~ed b¥finch For: T McKAY Dote plotted : 28-0ct-97 Plat Reference is WS 10-115/E3 Version ~4. Coordlnoles ore in feet reference slot ~115. T~e Verficol Oepths are reference ~8 (Porker ARCO ALASKA, Inc. :Structure : Pod 10 Well; E5 Field : Kuporuk River Unit Locotion : North Slope, Alosko 480 440 40O 560 320 280 240 200 I 160 ,=1-- ~ 120 "~ 8o 0 Z 40 120 160 20O 240 <- West (feet) 520 480 440 400 560 320 280 240 200 1 60 1 20 80 40 0 40 80 t I I I I I I I I I I I I I I I I I I ~ I O~ ~ 480 160 220 \'"\ 2100I i 440 1500 "~,,,,, 1829000t ]i2600 400 ",, 1700 ~ ~ ,360 1400 '~, ~ 6oo ~ i 25oo \"\'\ 11'540000 ~ i 520 " 1300 %.. ,,, "-... \ 2400[ ~00, 5.'°/_. '"-. 1400 1200 "~.,, ~ ""- .... ,,,, oo, o; '""'-........ ~ 1 O0 k, '"-,~.......1300 \" ', )0~.~0~~J~O 200 1000'%, .300 -" ~ '""' .... .. ~o;',, ~o.o~,/~oo~ '"-,~ 1200 ,, auu ~ "-.. 800'; 2200 '""- ?00% ~ 2300 2200 ~ _ '-~ 1000 2100~ .... 2000 ~_ "'-..j6oo ~5oo ,, 55~--~3_soo soo"-.. ................ 2~oo ~o;~-'-... ~oo ./ ........ 700~.¢ .......... 2400 400~~ /~ 13 ............... ..... ,3OO,, ~/' ....... ~_ 2200 ~0'~1300 ! 40 ........... 2100 ............-'----.2000 300~e,~ 1200' ...... .._j_.~_oo .... ~ 300 ~ 4OO ~r- 300 0 ~ 300 ~ ~ 2o 2000 / 2100/' 160 2200/'" / / 200 / .~ 30o 2300/. ...... "'- 1200 h 240 i i I I i i I i i i i i i ! i i i i i i i I I I I i i i t 520 480 440 400 ,360 ,320 280 240 200 160 120 80 40 0 40 80 <- West (feet) /x 160 Z 0 120 ~ ARCO ALASKA, Inc. Pad 1D E3 slot #115 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-115/E3 Version #4 Our ref : prop2211 License : Date printed : 28-Oct-97 Date created : 17-Apr-97 Last revised : 28-Oct-97 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 n70 18 0.716,w149 30 36.313 Slot Grid coordinates are N 5959603.685, E 560490.456 Slot local coordinates are 61.00 S 597.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLE/tRANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8365'>,,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <0-9783'>,,2,Pad 1D PGMS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D PMSS <0-?????>,,H4,Pad 1D WS 1D-117/E7 Version #4,,ET,Pad 1D WS 1D-121/G5 Version #3,,G5,Pad 1D WS 1D-105/C7 Version #4,,CT,Pad 1D WS 1D-109/D4 Vets. #2,,D4,Pad 1D WS 1D-118/E5 Version #4,,ES,Pad 1D WS 1D-119/F4 Vers.#3,,F4,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-106/D6 Vers.#3,,D6,Pad 1D WS 1D-124/G3 Version #3,,G3,Pad 1D WS 1D-129/J3 Version #3,,J3,Pad 1D WS 1D-133/J5 Version #4,,J5,Pad 1D WS 1D-135/G7 Version #4,,G7,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 4-Aug-92 16-Oct-96 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 25-Oct-97 25-Oct-97 27-0ct-97 28-0ct-97 28-Oct-97 23-Oct-97 22-0ct-97 8-0ct-97 28-Oct-97 6-0ct-97 6 -0ct-97 8-0ct-97 22-0ct-97 22-0ct-97 22-Oct-97 22-0ct-97 256.9 541.7 182.0 62.1 48.8 167.0 302.0 422.0 345.0 345.0 30.0 120.0 189.5 112 0 45 0 9O 0 105 0 143 8 210 0 330 0 390.0 465.0 975.0 300.0 20.0 20.0 602.2 650.0 20.0 300.0 300.0 300.0 300.0 300.0 550.0 675.0 300.0 300.0 300.0 775.0 300.0 300.0 280.0 300.0 4540.0 4420.0 20.0 20.0 5119.9 650.0 20.0 300 0 300 0 300 0 300 0 5119 9 550 0 675.0 5119.9 5119.9 300.0 775.0 300.0 300.0 280.0 300.0 west Sak 1D-115 (E3) Pr0 ducer Well Four (4) Stage Frac-for-Sand Control with 3-1/2" Deadstring 7-5/8" Casing Marker Joint 29.7# L-80 BTC-MOD (set 50' MD above top perforation) m m m m m mm m 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD (Cemented to Sudace) m m m m m m m m m m m m m m mm m m m m m m m m m mm m m m mm m m m mm 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 3-1/2" Tubing Deadstring 9.3# L-80 EUE 8RD (to frac through off-rig) 3-1/2" Tubing Muleshoe (set +/- 75' above top of D Sand) m m m m D Sand Frac'd with Resin Coated Proppant m m m m B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant m m m m A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB,12/01/97, Rev. 1 West 1D-115 (E3) Comple ron Diagram Four (4) Stage Frac-for-Sand Control Completion 2-7/8" Production Tubing 6.5# L-80 EUE 8RD Power Cable for ESP Centrilift 7-5/8" Casing Marker Joint 29.7# L~80 BTC-MOD (set 50' MD above top perforation) 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD (Cemented to Surface) 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Camco 2-7/8" Gas Lift Mandrel with 1" side pocket Arctic Lift 3000 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift ESP Motor Section Centrilift D Sand Frac'd with Resin Coated Proppant ,-- B + A4 Sands Frac'd with Resin Caoted Proppant --- A3 Sand Frac'd with Resin Coated Proppant A2 Sand Frac'd with -,- Resin Caoted Proppant ARCO Alaska, Inc. TAB, 12/01/97, Rev.1 KUPARUK'RIVER UNIT - WEST~AK OPERATIONS 20" DIVERTER SCHEMATIC 6 4 I 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION 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. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLI3ORE 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 WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15,/97 J 8 .,o. ,7 , 6 13 5/8" 5000 i=SI BOP STACK Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST West 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 CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSi REMAINING PRESSURE. I I,/... I, ..... , I ,""-'-"d 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 AND 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 TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE lINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE ENES. 7. TEST TO 250 PS! AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA 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. BACKOFF RUNNING JT AND PULL OUTOF HOLE, CLOSE BLIND RAMS AND TESTTO 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 COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 6' OR 4-1/2' TO 7' PIPE ODS AS APPROPRIATE. 1. 16' - STARTING HEAD 2_ 11' - 5000 PSI HORIZONTAL TUBING HEAD 3. 11' 5000 PSI 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 DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" - 5000 PSI ANNULAR TWM, 9/22/97 ]ATE -ZY . '.]K I APP ~ DESCRIPTION 1 tg/02/97i AJR i ~C i i AS-BUILT PER KSB#K97082ACS Pood D.S. 1-D 0 1 105~ 2 t06 · O 3 i 115 $ 117 118 ~4 11g I 120 ~ 121 5 124 ;REVI 0ATE i ~'~ Z:< I APP I 14. 13 25 ~)~' AiRSTRiP ~'' ).S.18 .i 21 0ESCRIPTION iAS-BUILT PER KSBt~ Kg7082ACS WEST SAK-1 THIS SURVEY VICINITY MAP SCALE: 1" = I MILE IVO SOAL£ LEGEND 0 EX/STING CONDUCTORS NEW CONDUCTOR L OCA lION ARCO Alaska, Inc. LK610410 9/02/97 SEE SHEET ~ 2 FOR NOTES AND LOCATION INFORMATION LOUNSBURY & ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS AREA: 1D M00ULE XX DRILL SITE 1-D WEST SAK PHASE ! - WELL CONDUCTORS AS-BUILT nrA-nln×-6104.nln IS~EET:~n~ I"~'V:' UNIT' DI REVI '~,¥E ! ~'f ~, CK J APPI DESCRIPTION REVJ OATE J ~.._~_j., .'CK J Alap j 9ESCRIP~ON 1 Ig/02/B7j, AJR j PC ~ .] AS&B~ILT PER K~J K97082ACS ~, 2 j9/17/g7j AJR ,J PC J: AS-BUILT PER K~I Kg7~2A~ N 0 TLS . ( ,.~~ ~, ',,, I. CDORDINATES SHO~ ARE A.S.P. ZONE 4, N.A.D. 27. ~ --. ~ D.S.1B ~ ,'~ ~LEVA ~ONS SHO~ ARE BRI~SH PE~OLEUU MEAN r / 2. ~.4SIS OF LOCA nONS AND ELEVA nONS ARE D.S. ;-O ;PiT C r ~ i('/ XIO -, ~~ UONU"ENTS PER LHD AND ASSOCIA~S. J ', ~ ~R~ )q ~ ~ ~. C~NOUCTOR~ ARE LO~A~O ~IN PRO,ACCO SEC~ONS ~ ". PIT~ r' ~ 25, TO'SHIP 11 NOR~, RANGE '0 EAS~ U.M. 4. OA~ OF SUR~: 8/25, 29 ~ 50/97. hELD BK L97-24, ~,/ ~ ~ ~-~ i ~ o ,o oo' o,' 6. SEE DRA~NG NSK-~.5-~ FOR AS-BUILT LOCA~ONS OF CONOUCTORS ~1 ~ROUGH ~8. -..,,,,.. ~ ~/ 49th ~ ~ ." .....'.......~F~2..~:.. ... ...... · ..... ~I ~CINI TV · ~* ~2 % LS-8035 F ~ ~ ' No. A.S.P.s LA TITUDE LONGITUDE , S,~c. 14, T. 11 N., R. I O E. F S.L. IF.E.L. i 105 5,959,798.99 ~ 560,490.57 70' 18' 02.6~7' 149" ~0' ~6.26~' 1~4' ~ 595' 70.5' 62.0'~ 106 5,959,768.9~ 560,490.67 70' 18' OZ~41' 149' ~0' ~6.268" ~104' 595' 70.4' 62.~'~ ; 109 5,959,72~.89 560,490.60 70' 18' 01.898' ~49" ~0' ~6.280" 59' 596" 70.4' 62.7' ' S~C. 25, T. 11 N., . R, 1 0 ~. F.N.L.F.E.L.~ ~5 5,959,60~.93 560,490.68 70' 18' .00.718' 149" ~0' ~6.~' 61' 597'170.4' 6~4' i 117 ' 5,959,57~.95 ~0,490.~5 70" 18' ~.42~' ~ 149' ~0' ~.~4' 9~' 597' ~a I 5,959,558.9~ 560.~0.68 ~ 70' ~a' 00.276' , ~9 5,959,5~.a~ ~ 560,~90. z2 ~0' tz' ~9.8~2' ~' ~0' ~6.~26" ~5~' 598' zo. 6' 6~.0' ~20 5,9~9,~9.0~ 560,~90.7z zo' ~7' 59.~86" ~' ~0' 38.~2~" ~66' 598' zo. 6' 6~.0' i ~2~ 5,959,~a~.~9 5~0.~0.~7 70' ~z' 59.538' ~4~' ~0' 38.~5' ~a~' ! 598' 70.~' ~.0 ~2~ 5,959,~9~.96 ~60,~90. zo zo' tz' 58.65~' ~4~' ~0' 38.~5' 2~' 599' zo.3' 65.0' 129 5,959,27~.92 560,490.79 70' 17' 5Z472' 149' ~0' 36.~0' ~91' 6~' 70.~' 6~2' ~0 5,959,259.09 560,~90.8~ 70' tz' 5z~26' i ~' 30' 38.~' 4~' 600" zo.~' ~ 5,9~9,2~.a~ 5~0,4~0.~8 ~0' ~z' 56.~2' , ~' ~0' 38.~9~" 4~' 600' ~0.4' ~.0' ~5 5.95~,~9.02 5~0,490. a0 : 70' ~7' 5~.~46' ~' ~0' ~6.4~2' 526' ~0~' zo.5' 69.4' i , SUR~YOR'S CER~CA ~ ~o uCgNStO ~0 e~CnC~ ~0 SU~.~ ~N ~ A SURLY DONE BY ME O~ UNDER MY DIRECT SUPER~SiON AND ~A~ ALL DIMENSIONS AND O~ER ~/~k ~ ASSOCIAteS, INC. DETAILS ARE CORRECT AS OF AUGUST ~0, 199Z ~~-~~ p~s~ SUR~O~ ~EA' 1D U~U~' ~ UNIT' ~ DRILL Si~ 1-D ARCO Alaska, Inc. 47 ~ST SAK PHASE I - ~ CONDUCTORS AS-BUILT CADD FILE NO, j J ORA,NG N~J ET: J v: LK610410 9/02/97 CEA-D1DX-610~10 2 ~ 2 2 I Well 'Y' 'X' --$EC' JSE~)N~sJ PAO, ELEV, £L£F,O'G' 'No. A.S.P.S LA TITUDE LONGITUDE S,,.c. 14, T. 11 N., R. I O E. F S.L.!F.E.L. 105 5,959,798.99 560,490,57 70' 18' 02.6.]7" 149' JO' 36,263' 1,74' 595' 70.5' 62.0' 106 5,959,768.93 560,490,67 70' 18' 02.,.741' 149' JO' 36,268" 104' 595' 70.4' 62..,,T' 109 5,959.72,:7.89 560,490.60 70" 18' 01.898' 149' 3,0' 36,280" 59' 596' 70.4' 62.7' Si;c. 25, T. 11 N., R. 10 £. F.N.L.F.E.L.i 175 5,959,60.].93 560,490.68 70' 18' .00.718' 149' .]0' J6.$06' 61' 597' 70.4' 63,4' 117 5,959,573.95 5~0,490.65 70' 18' 00,423' 149" JO" 36. J14" 91' 597' 70.4" 63`4' 118 5.959,558.95 560,490.68 70' 18' 00.276' 149' 30' 36,.]16' 106' 597' 70,4' 63.4' 119 5,959,513.7.86 560,490.72 70' 17' 59,8.]2' 149' 30' 36,326" 15I' 598' 70.6' 66.0' ?20 5,959,499.01 560.490.77 70' 17° 59.686" 149' 30° 36,327" 166' 598' 70.6' 66.0' 121 5,959,48,3.89 560,490.67 70' 17' 59.5,:78' 149' 30' .]6.3`,75' 18I' 598' 70.5' 66.0 124 5,959, J95.96 560,490.70 70' 17' 58.65J' 149' JO' 36.$55' 27I' 599' 70,3' 65.0' 129 5.959,273.92 560,490.79 70' 17' 5Z472' 149' 30' 36,380' 391' 600' 70.$' 68,2' 130 5,959,259.09 560,490.81 70' 17' 5ZJ26' 149' 30' 36,383' 406' 600' 70,5' 68,2' /33 5,959,21J. 89 560,490.68 70' 17' 56,882' 149' 30' 36.397" 451' 600' 70.4' 69.0' 135 5,959, I.]9.02 560,490.80 70' 17' 56.146' 149' 30' 36.412' 526' 601' 70.5' 69.4' ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 5, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-115 (E3) RECEIVED Anchorage West Sak Phase lA 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 designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("PCESP") to artificially lift the well. 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 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 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany this area. There are also no shallow hazards expected at WS 1D-115 (E3), such as shallow gas. There have been eight (8) Kuparuk wells and several 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. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 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. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is December 23, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Operations Drilling Engineer Attachments: cc: West Sak 1D-115 (E3) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 ARCO .. Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 5, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-115 (E3) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: RECEIVED DEC 8 i997 Anchorage 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 designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("PCESP") to artificially lift the well. 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 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 ARCO Alaska, Inc. is a Subsidiary of AtlanticRJchfieldCompany this area. There are also no shallow hazards expected at WS 1D-115 (E3), such as shallow gas. There have been eight (8) Kuparuk wells and several 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. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 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. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is December 23, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Thomas A. Brockway ~,~ Operations Drilling Engineer RECEIVED Attachments: cc: West Sak 1D-115 (E3) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 DEC - 8 i99 ' 011 & Gas Cons. Commission Anchorage · WELL PERMIT CHECKLIST COMPANY ///'(_..~ WELL NAME ?~z~AFZ_..//',~-////.~(" PROGRAM: exp [] dev~redrll [] serv [] wellbore seg ,~: ann. disposal para req Li FIELD & POOL ~ ~4~ /,.~<2 INIT CLASS /~-.¢~ //-o., ~ GEOL AREA (~:~'4~ UNIT# /,2/g 0 ON/OFF SHORE ~/t..) ADMINISTRATION ~ENGINEERING APPR D~ 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operatoronlyaffectedparty ................... , YIN 10. Operator has appropriate bond in force ............ ~y~y ~N 11. Permit can be issued without conservation order ....... N 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... (,.~N 15. Surface casing protects all known USDWs ........... LY.,-' N 16. CMT vol adequate to circulate on conductor & surf csg ..... (~ N 17. CMT vol adequate to tie-in long string to surf csg ........ ~ N 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... ~(~ N 20. Adequate tankage or reserve pit ................. 42¢2 N 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. (~N 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 ._'7'~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ Y N 28. Work will occur without operation shutdown ........... Y N 29. Is presence of H2S gas probable ................. Y N REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ......... ~N 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. J Y N 34. Contact name/phone for we,ekly,prog, ress reDo, As ..... ,/. Y N lexp~orazory on~yj GEOLOGY: ENGINEERING: COMMISSION' JDH ~ RNC~ "' ' CO CO Comments/Instructions: HOW/lit - A \FORMS\chekhst rev 09/97 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 Drilling Services LIS Scan Utility Thu Jan 08 13:38:51 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/08 Origin ................... STS Reel Name ................ UNKNOWN- Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/01/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 1 AK-MM-80059 P. SMITH D. BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1D-115 500292284000 ARCO ALASKA, INC. SPERRY-SUN DRILLING 08-JAN-98 SERVICES 23 liN 10E 61 597 .00 111.40 70.40 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT 9.750 5142.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M WERNER OF ARCO ALASKA, INC. AND M MUNYAK OF SPERRY-SUN DRILLING SERVICES ON 01/07/98. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5142'MD, 4293'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 120.0 RPD 120.0 RPM 120.0 RPS 120.0 RPX 120.0 GR 120.0 ROP 121.5 STOP DEPTH 5098.0 5098.0 5098.0 5098.0 5098.0 5106.0 5142.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 120.0 5142 . 0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHM- 4 1 68 RPS MWD OHM- 4 1 68 RPM MWD OHM- 4 1 68 RPD MWD OHM- 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 120 5142.5 2631.25 10046 GR 11.3595 106.096 56.0144 9973 RPX 0.7709 2000 181.11 9957 RPS 0.8892 2000 173.878 9957 RPM 0.938 2000 164.877 9957 RPD 0.2245 2000 257.694 9957 ROP 11.4756 6967.97 258.936 10043 FET 0.0921 3.3435 0.417824 9957 First Reading 120 120 120 120 120 120 121.5 120 Last Reading 5142.5 5106 5098 5098 5098 5098 5142.5 5098 First Reading For Entire File .......... 120 Last Reading For Entire File ........... 5142.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/08 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 ....... 98/01/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ 120 0 120 0 120 0 120 0 120 0 120 0 121 5 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: 5098 5106 5142 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 5098.0 5098 0 5098 0 5098 0 0 0 5 24-DEC-97 ISC 5.06 CIM 5.46 MEMORY 5142.0 120.0 5142.0 .0 52.2 TOOL NUMBER P0913CRG6 P0913CRG6 9.750 9.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 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 S PUD MUD 176.90 330.0 9.0 450 8.2 4.000 3.190 4.600 3.600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1' 68 12 4 RPM MWD 1 OHMH 4 1 68 16 5 RPD MWD 1 OHMH 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 34.5 First Name Min Max Mean Nsam Reading DEPT 120 5142.5 2631.25 10046 120 GR 11.3595 106.096 56.0144 9973 120 RPX 0.7709 2000 181.11 9957 120 RPS 0.8892 2000 173.878 9957 120 RPM 0.938 2000 164.877 9957 120 RPD 0.2245 2000 257.694 9957 120 ROP 11.4756 6967.97 258.936 10043 121.5 FET 0.0921 3.3435 0.417824 9957 120 Last Reading 5142.5 5106 5098 5098 5098 5098 5142.5 5O98 First Reading For Entire File .......... 120 Last Reading For Entire File ........... 5142.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/01/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/01/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
