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198-110
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. /~/-//0 File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: Grayscale, halftones, pictUres, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] OVERSIZED [] Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: Scanned by: Beverly Mildred Daretha ~Lowell Date.: '~/~' I TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha ~owell 1itGEIVED STATE OF ALASKA Abe. OIL AND GAS CONSERVATION COM ION ..'J1■ 0 7 2012 REPORT OF SUNDRY WELL OPERATIONS / 1. Operations Performed: Abandon r Repair well r Rug Perforations r Perforate r P Alter Casing r Pull Tubing 17 Stimulate - Frac r Waiver r Time Extension l t f;t4e- - Change Approved Program J- Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development F, Exploratory r _ • 198 - 110 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic I Service • 50 - 029 - 22891 - 00r 00 7. Property Designation (Lease Number): 8. Well Name and Number: ..P, ADL 25650 1D 9. Logs (List Togs 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 6472 feet Plugs (measured) none true vertical 4124 feet Junk (measured) none Effective Depth measured 6323 feet Packer (measured) 3391 true vertical 3979 feet (true vertucal) 2009 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 6415 7.625 6457 4110 Perforation depth: Measured depth: 5832'- 5860', 5894'- 5914', 5938' 5978', 6050' - 6086' ED J UL 0 3 2.0 WOWED True Vertical Depth: 3503'- 3530', 3566- 3582', 3606- 3644', 3714'-3749' Tubing (size, grade, MD, and TVD) 3.5, L -80, 5821 MD, 3475 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED -THRU PACKER, WEATHERFORD HYDROW 11 DUAL - STRING PACKER @ 3391 MD and 20( NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development )✓ . Service r Stratigraphic r 16. Well Status after work: - Oil J 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 Erik Nelson ta' 263 -4693 Printed Name rik N o Title Senior Wells Engineer / Signature 3/‘4 Phone: 263-4693 Date o u Z�/ � z RBDMS JUN 07 � 12 6. / Form 10 -404 Revised 11/2011 6 / , � Submit Original Only 1D-131 Well Work Summary DATE SUMMARY 2/25/12 PRE RWO T -POT BONNET( P. ED ), T -PPPOT BONNET ( PASSED ), POT UPPER BODY ( PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED ), T -PPPOT LOWER BODY ( PASSED ), GRAYLOC PPT ( PASSED ), FT -LDS ALL NORMAL. 3/29/12 PULLED SLIP STOP & PACKOFF (P/0 MISSING PIECE OF ELEMENT). DEPLOYED CATCHER. PULLED SOV @ 5684' RKB. IN PROGRESS. 3/30/12 SET DV @ 5684' RKB. PULLED CATCHER. PULLED PCESP © 5739' RKB. PUMPED 200 HOT DIESEL DOWN I /AAND 55 HOT DIESEL DOWN TUBING. SHOT FLUID LEVEL NEXT DAY, BOTH AT SURFACE, 100 PSI ON TUBING AND 140 PSI ON I /A, BPV INSTALLED ON 4/2. Pi- , r �-t, • • Conoc ©Phillips Time Log & Summary We/Mew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/8/2012 12:01:00 AM Rig Release: 5/11/2012 4:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/06/2012 24 hr Summary MIRU at 1D -131 Well slot. Center and berm up Rig. 23:00 00:00 1.00 MIRU MOVE MOB P MIRU at 1D -131 Well Slot. Center and berm up Rig. Accept Rig at 00:00 hrs, 05/07/2012 05/07/2012 Complete RU. Pull BPV. Kill Well. Install BPV, NU Tree. Install Blanking PLug. NU BOPE. Perform the Initial BOPE Test. Circulate Well. PUII Tubing Hanger to the Floor. Prep to single down the 3 1/2" ESP /HT Completion. 00:00 02:00 2.00 COMPZ RPCOM 02:00 03:00 1.00 COMPZ WELCTL MPSP P Pick -up Lubricator. Pull Back Pressure Valve. Lay down same. 03:00 04:00 1.00 COMPZ WELCTL PRTS P Pressure test Lines at 3.500 psi. Good test. (Wait on load of hot Filtered 3% KCL Sea Water). Notify DSO and Security before venting Gas. 04:00 04:00 0.00 COMPZ WELCTL KLWL P Open Well. TP = 110, IAP = 140. Bring Pump on line at 2.0 bpm/60 psi. Breed Gas through Choke. Continue to bleed mostly gas with fluid slugs (Well appears to have swapped over to gas). 04:00 04:30 0.50 COMPZ WELCTL OWFF P Monitor well for flow - slight vac on TBG and IA. 04:30 05:00 0.50 COMPZ WELCTL MPSP P Vetco Gray dry rodded 3" BPV. 05:00 06:00 1.00 COMPZ WHDBO NUND P PJSM, ND Tree and install Blanking plug 06:00 07:30 1.50 COMPZ WHDBO NUND P PJSM, NU BOP w/ Weatherford Safety Tension Adapter. RU riser and gather measurements. 07:30 14:00 6.50 COMPZ WHDBO BOPE P PJSM, Fill BOP stack with water. RU test equipment. Shell test 11 " 5M Class III BOP stack 250 / 3,000 tr psi. 24 hr notice was given at 17:02 hrs on 5 -6 -12, Right to Witness was waived by Jeff Jones at 17:02 hrs on 5 -6 -12. Shoot Fluid level with DHD F/L @ 280 -ft 14:00 15:00 1.00 COMPZ WHDBO MPSP P Pull Blanking Plug, Back Pressure Valve, and install the Side Port Isolation Sleeve. Make up Landing Joint. Page 1 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 17:30 2.50 COMPZ RPCOM CIRC P Rig up hoses to circulate. (Fill Well = 12 bbls). Circulate Well 1.5 times at 5.0 bpm /440 psi with Filtered 3% KCL Sea Water. Monitor Well on Vacuum. 17:30 18:30 1.00 0 30 COMPZ RPCOM THGR P Make -up Top Drive to the Landing Joint. BOLDS. Pull Tubing Hanger free at 110K Pull Tubing Hanger to the floor at 95K. 18:30 19:30 1.00 30 30 COMPZ RPCOM RURD P Rig up to single down the 3 1/2" ESP /HT Completion while spooling the ESP Cable, Heat Trace Cable, and the TEC Wire. 19:30 21:00 1.50 30 4,873 COMPZ RPCOM PULD P PJSM. Begin to single down the 3 1/2" ESP /HT Completion. Kick out Completion Tubing from the Pipe Shed as needed. Depth at midnight = 4,873 -ft. Up Weight = 83k. Down Weight = 58K. X5/08/2012 Continue to single down the 3 1/2" ESP /HT Completion. RIH with the Clean -out String. Reverse Circulate Well. POOH. Trip in with test Packer and Retrievable Bridge Plug. 00:00 08:00 8.00 4,873 0 COMPZ RPCOM PULL P Continue to single down the 3 1/2" ESP /HT Completion. 08:00 09:30 1.50 0 0 COMPZ RPCOM PULD P Disassembly QuantX Gauage / ESP + Motor and LJD Same. 09:30 11:00 1.50 0 0 COMPZ RPCOM PULD P PJSM. Disassembly Guardian Guage / ESP + Motor and L/D Same. 11:00 12:00 1.00 0 0 COMPZ RPCOM PULD P PJSM. Offload Clamps, Clean & Clear Floor, C/O Floor Equipment. Install wear bushing. 12:00 13:00 1.00 0 0 COMPZ RPCOM PULD P PJSM. Offload Clamps, Clean & Clear Floor, C/O Floor Equipment. Install Wear Bushing. 13:00 14:30 1.50 0 512 COMPZ RPCOM PULD P PJSM. Load and Make-up BHA #1. 6 3/4" Bit and 7 5/8" Casing Scraper with 4 3/4" Bumper sub and oil jars. 14:30 16:00 1.50 0 511 COMPZ RPCOM PULD P PJSM. Pickup and M/U BHA #1. 6 3/4" Bit, 7 5/8" Casing Scraper, Bumper Sub and Oil Jars. 16:00 18:30 2.50 512 6,325 COMPZ RPCOM TRIP P Continue In Hole with Casing Scraper on Drill Pipe down to 6,325' RKB with no problems. Up Wt 113k / Dn wt 67k 18:30 21:00 2.50 511 6,325 COMPZ RPCOM TRIP P Continue In Hole with BHA #1 on Drill Pipe down to 6325' RKB. No fill encountered. Up Wt 113k / Dn Wt 67k. 21:00 22:30 1.50 6,325 6,325 COMPZ RPCOM CIRC P Reverse circulate 1.5 BU or until returns are clean at 3 bpm, 150 psi. 6,325 6,325 COMPZ RPCOM CIRC P Reverse Circulate 1.5 BU or until returns are clean. 6,325 COMPZ RPCOM TRIP P TOOH racking back Drill Pipe. 22:30 00:30 2.00 6,325 465 COMPZ RPCOM TRIP P TOOH racking back 3.5" Drill Pipe. Stop Tripping out. Crane arrived on location to swap out ESP Spools. Page 2 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:30 2.00 465 465 COMPZ RPCOM OTHR P Spot Crane. PJSM. Discussed Crane operations. Swap out ESP Cable Spools with no issues. Meg new ESP Cable before & after installed in stand on the rig floor. Good. 02:30 03:00 0.50 465 0 COMPZ RPCOM TRIP P Resume trip out with Drill Pipe. Break out 6 3/4" Bit. 03:00 03:30 0.50 0 0 COMPZ RPCOM PULD P Make up Baker Model "G" Retrievable Bridge Plug and the Baker Retrievamatic Packer. 03:30 06:30 3.00 0 5,800 COMPZ RPCOM TRIP P Trip in with the Test Packer and the Retrievable Bridge Plug on 3 1/2" Drill Pipe from the Derrick to 5,800 -ft. Up Weight = 118 K. Down Weight = 65K. 05/09/2012 Set Retrievable Bridge Plug. Test Casing. Slip and Cut Drilling Line. Release RBP. Circulate Well. TOOH with Pkr and RBP. Rig up to handle the Completion. Single in 3 1/2" ESP Completion. 00:00 00:30 0.50 5,800 5,800 COMPZ RPCOM PACK P Set the Baker "G" Lock -Set Retrievable Rrirlge Plug at 5J flf1 - 00:30 01:00 0.50 5,800 5,800 COMPZ RPCOM PRTS P Pressure test the 7 5/8" Casing from 5,800 -ft back to surface at 1,500 psi x 30 minutes. Good test. Test recorded on a chart. 01:00 03:00 2.00 5,800 5,800 COMPZ RPCOM SVRG P PJSM. Slip and Cut Drilling Line (84 -ft). Inspect Drawworks. Check Crown -O- Matic. 03:00 03:30 0.50 5,800 5,800 COMPZ RPCOM PACK P Release Retrievable Bridge Plug. 03:30 05:00 1.50 5,800 5,800 COMPZ RPCOM CIRC P Circulate and condition Well at 5.0 bpm /560 psi x 1.5 volumes. 05:00 08:30 3.50 5,800 0 COMPZ RPCOM TRIP P Blow Down Top Drive, TOOH f /5,800 -ft and LD BHA #2 08:30 11:15 2.75 0 0 COMPZ RPCOM OTHR P PJSM. Pull Wear Bushing. C/O Floor Equipment. Wash Out BOP Stack. Prep to Run ESP Equipment. 11:15 11:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss the hazard for running ESP Completion with Centrilift and Nordic Personal. 11:30 16:00 4.50 0 94 COMPZ RPCOM PULD P P/U Lower ESP Section and Service same. Check breakaway and rotational shaft torque of motor, gear reduction and tandem seal section. Install the WeIILiftUnit and connect the TEC Wire from the Motor Guage. 16:00 18:00 2.00 94 1,390 COMPZ RPCOM RCST P Continue to RIH w/ remainder of ESP Completion. 18:00 20:00 2.00 1,390 2,431 COMPZ RPCOM RCST P Continue to single in with the 3 1/2" ESP Completion as designed. Check ESP Cable. 20:00 00:00 4.00 2,431 2,431 COMPZ RPCOM OTHR P Make up the Weatherford Hydrow II Feedthru Packer. Centrilift Service Reps make the bottom and top Feedthru Packer connection splices. Page 3 of6 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/10/2012 24 hr Summary Complete Feedthru Pkr connection splices. Finish in with 3 1/2" ESP Comp. Land Tbg Hanger. Test. RU S -Line. Set WRP. Pump Corr Inhib SW down IA. Set Pkr. Use decompression sch to bleed pressure. Pull DV. FP Well. Set DV. PT Tbg. RD S -Line. 00:00 03:00 3.00 2,431 2,431 COMPZ RPCOM OTHR T Completed the Top Feedthru Packer • ESP Connection Splice. However it was discovered that the bottom connection was just short of the needed length to make -up to the sleeve between the bottom and the top connection. An attempt to find "slack" in the ESP Cable below the Packer was un- successful. Lay down the 30.65 -ft Jt below the Packer and replace with a 29.70 -ft Jt. Re -cut ESP Cable and redo the bottom Feedthru Packer connection splice. Connect Bottom and Top Connections to Packer. Check ESP Cable. Good. 03:00 06:00 3.00 2,431 4,295 COMPZ RPCOM RCST P Resume running the 3 1/2" ESP Completion as designed with singles from the Pipe Shed. 06:00 07:00 1.00 4,295 4,295 COMPZ RPCOM RCST T While making up joint section, the back -up on the eckel slipped and damage the armor on the ESP cable. Cable tested good, make patch on armor. 07:00 10:00 3.00 4,295 5,785 COMPZ RPCOM RCST P Continue to single in with the 3 1/2" ESP Completion from 4,295 -ft. Up Weight = 97K. Down Weight = 60K. 10:00 13:00 3.00 4,295 5,765 COMPZ RPCOM RCST P Continue to RIH f/4,296 -ft down to 5,765 -ft. Up Wt 97k / Dn Wt 60k. 13:00 15:00 2.00 5,785 5,785 COMPZ RPCOM THGR P Make -up Tubing Hanger. Install Penetrator. Make the final top ESP Connector splice. Test Cable. Good. 5,765 5,765 COMPZ RPCOM THGR P MU Hanger, Install Penetrator and Make Final ESP Splice. 15:00 16:00 1.00 5,785 5,820 COMPZ RPCOM THGR P Land Tubing Hanger. RILDS. Pressure test Pack -offs at 5,000 psi x 15 minutes. Good test. Pull side Port Isolation Sleeve. 16:00 22:00 6.00 5,820 5,820 COMPZ RPCOM SLKL P PJSM. Bring S -Line equipment to the Rig Floor. Rig -up. Pressure test Lubricator at 1,000 psi. Good test. RIH with a 2.780" WRP Drift. RIH with KO Tool and locate GLM. Flag Line. RIH with the WRP and park at 3,521 -ft slmd. Wait for the Setting Tool timer to begin the setting cycle. Saw Setting Tool shear free form the WRP. POOH with Setting Tool and Park inside Lubricator. Pressure test WRP at 500 psi. Good. Set back S -Line equipment. Page 4 of 6 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment - 22:00 00:00 2.00 5,820 COMPZ RPCOM CIRC P PJSM. Line up to pump Corrosion Inhibited Sea Water. Start Corr Inhib Sea Water down the 7 5/8" c 3 1/2" Annulus at 1.0 bpm. Increase rate to 2.0 bpm /175 psi. Total volume pumped = 120 bbls at a final of 2.0 bpm /340 psi. Flush Pump and Lines with 3% KCL Sea Water. IAP fell to "0" psi in just a few minutes. 00:00 00:30 0.50 COMPZ RPCOM PACK P Line up to pump down the Tubing. Begin setting the Weatherford Hydro II Packer at 500 psi. Bring pressure up in steps to a final of 3,200 psi. (Note: saw Packer set at 1,700 psi). Hold Tubing pressure for 20 minutes. Record all on Chart. 00:30 01:00 0.50 COMPZ RPCOM PRTS P Line up to pump down the 7 5/8" x 3 1/2" Annulus. Pressure up on the Packer and the Casing to 1,500 psi x 39 minutes (lost a total 40 psi during the test). Good test. Record on Chart. 01:00 03:00 2.00 COMPZ RPCOM PRTS P Begin to release the pressure from the 7 5/8" x 3 1/2" Annulus, following the decompression schedule as per Step 13 -C in the Program. 05/11/2012 Complete IA pressure release using the decompression schedule. RU S -Line. Pull DV from top GLM. Freeze Protect Well. Install DV in top GLM. PT Tbg. RD S -Line. Install TWCV. ND BOPE. NU Tree. Test Tree. Pull TWCV. Install BPV. Secure Cellar. Release Rig. 00:00 02:00 2.00 COMPZ RPCOM PRTS P Complete releasing the pressure to "0" psi off of the 7 5/8" x 3 1/2" Annulus using the decompression schedule in the Program. 02:00 04:30 2.50 COMPZ RPCOM SLKL P Wait on relief S -Line Crew to arrive on Location. PJSM. Rig S -Line back up on the Well. "Drop install" Catcher Sub. Pressure test Lubricator at 1,000 psi. Good. Run in with 3 1/2" OK -1 w/1 1/4 JDC. and pull the Dummy Valve from the top GLM. 04:30 06:00 1.50 COMPZ RPCOM CIRC P Rig Up pumping hose and PT same to 2500 psi. Circulate down IA w/ 37 bbls of Diesel at 2 bpm, 575 psi follow by 120 bbls of Gelled diesel at 2 bpm, 600 psi. 06:00 07:30 1.50 COMPZ RPCOM SLKL P RIH with Slick -line and set DV in the Upper GLM, stand by S -line. 07:30 08:30 1.00 COMPZ RPCOM PRTS P Rig Up Hoses and Pt TBG to 3000 psi and record PSI on chart. 08:30 09:00 0.50 COMPZ RPCOM OTHR P Monitor Well. (Static) 09:00 09:30 0.50 COMPZ RPCOM SLKL P PJSM. RDMO Slick -line. 09:30 10:00 0.50 COMPZ RPCOM MPSP P R/D Hoses. Set BPV. 10:00 12:00 2.00 COMPZ RPCOM NUND P PJSM. Nipple Down BOPE. Dispatch Centrilift. Page 5 of 6 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 COMPZ RPCOM OTHR P Test ESP Cable. 13:00 14:00 1.00 COMPZ RPCOM NUND P N/U Tree. Test Packoff to 5000 psi for 15 minutes. PT Tree to 5000 psi For 15 minutes and record on chart. Dispatch Centrilift. 14:00 14:45 0.75 COMPZ RPCOM OTHR P Make Final Integrity Test ESP Cable for all three phases. Pull TWCV and Install CIW 3" Type 'H' BPV 14:45 16:00 1.25 COMPZ MOVE DMOB P RDMO. Release Rio at 1600 hours. Page 6of6 KUP • 1D-131 i ConocoPhillips .4 Well Attributes Max Angle & MD TD Alaska, Inc, , Wel!bore API /UWI Field Name Well Status Ind (°) MD (ftKB) Act Btm (ftKB) carloc4iaK 500292289100 WESTSAK PROD 67.70 4,389,24 6,472.0 " Comment H2S (ppm) Date Annotation End Date KB.Grd (ft) Rig Release Date ••' _SSSV: NONE 0 9/26/2011 Last WO: 5/8/2007 41.59 11/18/1998 Well Config: -0D-,92. : Schemat131ic - 5IiActual 012 3 36 38 PM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 5,663.0 10/19/2006 Rev Reason: WORKOVER ninam 5/19/2012 - - Casing Strings „:: C asing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String... String Top Thrd HANGER 37 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 (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.750 41.4 6,456.8 4,109.6 29.70 L -80 ABM -BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth ( f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR, ____ • la Tubing I 31/2 2.992 37 I 5,820.9 3 I 9 L80 EUE8RDMOD 41-121 1 Completion Details ESP Cable, 41 i Top Depth (TVD) Top Intl Nomi... r Top (ftKB) (ftKB) ( ") Item Description Comment ID (in) 37.4 37,4 -0.96 HANGER VETCO GRAY TUBING HANGER 2.950 3 3,390.5 2,009.1 64.30 PACKER ESP FEED -THRU PACKER, WEATHERFORD HYDROW II 3.250 1 DUAL - STRING PACKER ESP ® 5,7 3,405.7 15.14 GAUGE WELLLIFT DISCHARGE GAUGE UNIT (P /N: PWLE0018) 2.992 MANDREL ) '°' 5,788.4 3,461.0 14.97 INTAKE TTC RECEIVING X0 COUPLING w/ PERFORATED INTAKE (P/N: CSE8442XA) !i 5 ,793.2 3,465.6 14.96 SEAL TANDEM SEAL SECTION. (S/N: 12064714/12064529 ) ' r) * 5,807.0 3,478.9 14.92 GEARBOX GEAR REDUCTION UNIT (S/N: 11985648) 11.42:1 `. ....... 5,808.8 3,480.7 14.91 MOTOR ESP MOTOR, 562MSP1, 60 hp/1240V/29 (S/N: 12057566) 5,817.1 3,488.7 14.89 GAUGE WELLLIFT MOTOR GAUGE UNIT (S/N: 192 - 00829) PACKER, 3.391 .,_l as 5,819.0 3,490.5 14.89 Centralizer MOTOR CENTRALIZER Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) � I� Top Depth (TVD) Top Inc! l 99 Top (ftKB) (ftKB) r) Description Comment Run Date ID (In) 41 41.0 - 0.92 ESP Cable ESP 5/10/2012 ESP MANDREL, al Perforations & Slots 3,501 1 Shot I l Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (MB) (ftKB) Zone Date (ch... Type Comment 1 1 j 5,832 5,860 3,503.1 3,530.2 WS D, 1D- 131 8/30/1998 4.0 IPERF 21/8" EJ, BH 0 PH 5,894 5,914 3,563.1 3,582.4 WS B, 1D- 131 8/27/1998 4.0 IPERF 21/8" EJ, BH 0 PH I , .. 5,938 5,978 3,605.7 3,644.4 WS A -4, WS A -3, 8/24/1998 4.0 IPERF 2 1/8" EJ, BH 0 PH ESP MANDREL, 8 1D-131 5,679 6,050 6,086 3,714. 3,749.1 WS A2, 1D -131 8/15/1998 4.0 IPERF 2 1/8" EJ, BH 0 PH 1 1 Notes: General & Safety I End Date Annotation 8 /14/2008 NOTE: View Schematic w/ Alaska Schematic9.0 i 11 GAUGE, 5 731 1 II INTAKE, 5,788 y SEAL, 5.793 GEARBOX, 5,807 p MOTOR, 5,809 @ ETI GAUGE, 5,817 .1 Centralizer. 1 5,819 I IPERF. 5,832 -5,880 - IPERF, 5,894-5,914 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run IPERF, Stn Top (ftKB) (ftKB) C) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 5,9385,978 1 3,267.1 1,955.0 63.90 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/5/2012 2 3,501.5 2,056.5 64.66 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/5/2012 3 5,679.0 3,355.5 15.28 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/5/2012 IPERF, 6,0505,086 1 SURFACE, 41 -8,457 00, 6,472 • a • _~~ ~__ ~~, PROACTIVE DIAGNOSTIC SERVICES INC. ~~ ~~- r~,~~~r~ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 J MTT Report O1,Ju1-10 1 C-126 1 Report 50-029-22889-00 2J MTT Report 01-Ju1-1O 1C-131 1 Report 50-029-22591-0 IC,~'cs~.~%"$.i`r6r~ ti~.t!,~ Iw~r ~U~GI ~Jq~'~t - ~ 1~ ~S f "'.j~~ 17 ~ r ~7 v f ~e0 ~ ._ c -;~~~ '~ Signed . ~~~~ to ~ ,, _,~ Print Name: " ~ -- ~' -=~i<^y5 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-IUTAIL : ~dsae~c~T®r~ae(r~sT~e~ICSry9mp.~®rn WEBSITE : ~~rww.rreret®r4lic:g.~~I~n C:',Document~ and SettingslDiane Williams\Desktop\Trensmit_Conoco.docx • • Memory Magnetic Thickness ToQI Log Results summary Company: ConocoPhillipsAlaska, Inc. Well: 1D-131 Log Date: July 1, 2010 Field: West Sak Log No.: 7424 State: Alaska Run No.: 1 API No.: 50-029-22891-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 222 Ft. (MD} Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BTC Top Log Intvl.: Surtace Pipet Use: Surtace Casing Bot. Log Intvl.: 222 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surtace Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" surtace 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 surtace to 222'. Changes in metal volume are relative to the calibration points at 44' and 141', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates an area of up to 14% relative metal loss over the interval (54' - 76') in the 10Hz pass. Over the same interval, the 8Hz pass indicates up to 10% relative metal loss and the 5Hz pass indicates up to 4% relative metal loss. A log plot of the entire 5Hz pass and an 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 majority of the interval logged in the 5Hz pass. A maximum -14% circumferential metal loss is indicated in the interval between 54' and 76' in the 10Hz pass, and a maximum ^4% circumferential metal loss is indicated in the same interval in the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surtace casing, the percent metal loss from that pipe alone is probab{y higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. ' Field Engineer: Wm. McCrossan Analyst: HY. Yang & J. Burton Witness: P. Bessette ProActive Diagnostic Seruices, Inc, J P,L7. Box 1369, Stafford, TX 77497 Phone: (281} or (8880 565-9085 Fax: (28i j 565-1369 E-mail: PDS amemorylog.com Prudhoe Bay Field office Phone: (907) 659-2307 Fax: (9Q7) 659-2314 1 ~~~-~~a A o`~~ ~E"s 5Hz, ~z and 10Hz Delta Metal Thi~iess Passes Overlay Q4 Fc's N 1D-131 July 1, 201Q P°°Amvc Disynosiic Scav+[cs Database File: d:Iwarriorldatal1d-1311overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation Fri Jul 02 09:06:42 2010 Charted bY: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) -50 Delta Metal Thickness 2010 (8Hz) (%) -50 Delta Metal Thickness 2010 (5Hz) (%) 0 2G 40 60 inq Collar 8Hz Delta Metal Thickness 50 50 50 10Hz Delta Metal Thickness 5Hz Delta Metal I I i i Bottom of 16" Conductor ~ ~ SO 100 120 140 160 Delta Metal T 180 200 10Hz Delta Metal 220 Delta Metal -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz} (%} 50 -50 Delta Metal Thickness 2010 (5Hz} (%} 50 o"~~`wE"spy R~rded Magnetic Thickness ~ Data - 5Hz Pass 4 0,. yi Vr . 1 D-131 July 1, 2010 Pn°AttivE Dinyrv°sric SERVICES Database File: d:\warrior\datal1d-131\5hzpass.db Dataset Pathname: 5HzPass 1 Presentation Format: 18 Dataset Creation: Fri Jul 02 09:57:59 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 1.8 A_TT__.-__ __.....___.__--_~._~~___~ 0 Line Speed (ft/min) -200 -7 Line c 7. 625" Col lar " Co 3.5 llar 7. 625" Co llar 3.5" Co llar 7.625" Co llar 3.5" Co llar Tree Metal Thickness Tubing Jt. 1 20 40 Tubing Jt. 2 Tubing Jt. 3 Metal Loss 3ottom of 16" Conductor -~--~~ 80 MTTP01 (rad) 11.8 MTTP12 (rad) 3 ~~ 3 5" Co llar . " 7. 625 Co lla -- - ' " 3.5 Co lla I 2 " C ll 7. 5 6 o ar 3 5" C ll . o ar l 1 100 Tubin Jt.4 Jt. 5 140 160 Tubing Jt. 6 180 Tubing Jt. 7 200 Delta Metal Thickness 7.625" Collar ~ , Line Spee Tubing Jt. 8 220 -- - -50 Delta Metal Thickness {%) 50 1.8 0 Line Speed (ft/min) -200 -7 MTTP01 (rad) 11.8 MTTP12 {rad) 3 a`~`"wE"s E~anded 5Hz Pass Magnetic T~kness Log Data C~ AF~9 N 1 D-131 July 1, 2010 P/tUACT14E DIAE~NQ~TIC SER41Cf5 Database File: d:\warrioridatat1d-1311expanded 5hzpass.db Dataset Pathname: SHzPass Presentation Format: 18 Dataset Creation: Fri Jul 02 D9:57:59 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ftlmin) -200 -7 MTTP12 (rad} 3 - - i i ._ - --~ ~ fi-=-~ =. Tree _Hanger_ -- - ~ -~- ~ - Lin e S peed ~ ~ I' . 625" Col lar ¢ :~ _ ~ i Delta Me tal Thickness 10 ~; ti 5 S { Tubing Jt. 1 ~ ~ ~ v~ I ~ 20 , ~~ ' .5 Co lar ~ i` .,~ i ~ i '- i . ~ ~ i` I- ~ , 30 - __- - - -5D Delta Metal Thickness (%) 5D 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min} -200 -7 MTTP12 (rad) 3 ~~~ KUP ~ 1D-131 ConocoPhillips ~ y II Attributes Angle & MD TD ly I 'Jv'ellbore kPl'UJJI Reltl Name 'Jv's113 a hcli''~ MGi I•:Bl i:e A.ct ittk l=_~jl 500292289100 NfEST 9AK PROD 67.?0 4.389.2 6,472. tvmment ;,;jY H231.ppm1 Corte i4 Mno lion BPtlDRID - F:8+3rtlf J RlgP.elesee Fflit Last W0: 5/812007 SSS'uh NDNE t1 9nr2u . 41.59 11/18/19 Mnotatlon Oep !( PB'1 BiG m t.'tft Anna on Lart Mao B• Bid ~ t-.flit Last Tag: 5,663.0 10/19 Rev ReasorcGLV Ci0 Imasbor 1f25R0 Casing Strings ' •_a nog [RUnp on smog oD. .. s ng t0... Topi F.Bi set Depnr if.. S a rPptniru Di... s ng ww .. smog ... smog TOP n;-flit CONDUCTOR 16 15.062 41A 121.0 1""<7.0 62.58 H-00 `NELDE NnRGEP.3i ~emg Oeeeflpllwn smog O0. . Stung ID... Top ittF B1 se Deplll i,t.. S e [leplle iTu Dj... smog Jv't.. smog ... 3 ng Top TI t-,iqt _ SURFACE 7518 6.750 41.4 6,456.9 4,109.6 29.70 L~0 ABM-B Tubing Strings Tubing Cr wnp on smog uD... Stung lC.... Top (ttP:ei Se Crap r1t.. 8e GP iTcD}... s ng Jot.. sfing... s np TOpns-,tit TUBING ^a tt2 2.992 37.0 5,804.7 3,476.7 3~0 L~0 EUE8r Coinpletlon Details 9'aii Top Tap [eptl~ iT/Gi Top llcl Ilom l_ irtP:61 ritl~El !°) I dm DIRCII non ~~mment IDilni 37.0 37.0 -0.37 H ANGER TUBING HANGER 3.000 cououc-roa, ao-al - ~ 5,764.1 3,437.5 1504 G AUGE Ouant>r Gauge 2.992 xE1T TP.4C~E, 5,774.1 3,447.2 15.01 R U INTAKE 1CC XD Rssy 2.952 5,778.8 3,451.7 i5A0 S EAL Seal Sec[ion 0.000 5,732.6 3,465.0 14.96 G EAR BOX Gear Reduction Unit 0.000 5,794.2 3,466.5 14.36 M OTOR ESPMotorQ6HPKM) 0.000 5,8025 3.474.6 14.93 X D Crossover Nipple 2.063 - 5,303.0 3,475A 14.53 C ENTRRLI2... BAKER'HDME MADE'CENTRALIZER 5.000 ~ Other in Hole MFireline retrievabl e plugs, valves, pumps, fish, etc.) Eda _ Top [ep , Trip Ti•ji 1L:1 i rtl~: 61 irll~6i LBlen ncn ~_Omment N.Vn Cwb IC~IInI J. i 38 38.0 -0.96 H EAT TRACE HEAT TRACE SB2007 0,000 - 5,774 3,447.1 15.01 P UMP 312"PCP(OAL=40'6'J C~5774'RKB,SET PACKOFF ASSY 9212009 1.000 (92" OAL.NO CHECK OR K.O.J. SET D AND D SLIP STOP ~P R4PpPEl, ~ DN TOP DF PACKOFF a,33a PerfwatioPis 8r Slots 1 rl~ BBn Top iTi Di etm iTv 61 9110 Ctlnl ' To ittF 61 ittF'BI ittFB1 itt461 =one C9te ieh... T. 4 Comment 5,832 5,560 3,503.1 3,5302 W S D, 1D-131 5130/1998 4.D IPERF 2 1~"EJ, BHO PH 5,894 5,914 3,563.1 3,5$2.4 W S B, iD-131 SY2711998 4.0 IPERF 2 118"EJ, BHO PH 5,938 5,978 3,605.7 3,644.4 W 5 A-0, WSAJ, 8124!199$ 4.0 IPERF 2 1r%"EJ, BHO PH !cP rv.PDPEL,- sF~aa I:.a 1 D-131 6,050 6,086 3,714.2 3,749.1 W 5 A2, 1D-131 $!15!199$ 4.0 IPERF 2 1~"EJ, BHO PH Motes: General A Safety t ° II' ma Date wlrlotaBwrl R/14f2008 NOTE: VIEW SCHEMATIC wIAlaska Schematic9.0 cru~E, s,TEa nn mT•.nE, x sae. ~ 8 3 PUMP, S,TTa ~E.L, S,TT9 I I GESP BO%, 5,793 EgTOP 5 T9a ~ , , f(rf^J b'e _ GEBTP~LGEP, SA63 IP ER 1, 9¢3i`i$L IP ER 1, 5$9a3,91a IP EP t, 5,93B-'a~a 6A396AB6 anJ~ei Details Bait Top Oep r rort Tap i7v DI Tcp UD LetGlt %189 TP.C9 RUn Sfi ittR: 61 iRF: 61 holi`1 McPe MOdel ilnY 39rv Yel veT B T a ilnl i V'I ftVn CYb arom... ~URf/~G E, 16 K}' 1 4,3342 2,405.0 68.83 Camco KBMG 1 ESP DMY BKS 0.000 0.0 5A62007 . ~~ To,E.a. 2 5,684.4 3,360.7 1527 Camco KBMG 1 ESP SOV' BKS 0.000 2,000.0 1AG6i20T0 Jul 91 1fl t74 05~ ~- ~I'~,+~L~ Eit~1r'?>1i~ 1'~:~~~. <~14;1?2'~5 PQS Prudhoe 19~76~14 ,- p,4 - ---- Darker Rig X245 Dr,';iing Super/isc~r.• ~7or:aki tutn.'ck CASING J TUBING !LINEN DETAIL Tubina or Lrner Descriation WELL: 1 D-139 AFtCO Alaska, InC. DATE: 7J15t98 ,ui 01 "d 04:d5p t:?E;~~I~t~t~ 07,~`61/~~±10 1~:0~. rc;id31'1~~ pDS Prudhoe CASING f TUBING !LINER DETAIL 7 5t8" Csa ARCO Alaska, Inc. Subsidiary of AtiamiC R:Ctttield CaTpany 1907614 p.7 WELL: 1 D-131 DATE: 7J13t98 1 nF 1 Pdf~FC # !TENS COMPLETE DESCRIPTION OF EQUIPMENT RUN i~NG7H DEPTf~ RKB to LDS on Tu6in Head = 37.43' TOPg ;RKB to Landn Rin ~1.g7 Vetco Gra i=iuted Mandrel Gasin Han er & u 2.92 4".87 68 J.s 7-5J8°, 29.7#, L-80, ABM-BTC Gasin (Jts #81 - #148' 287b.86 44.79 Jaitti '8` 7-5i8", 29.7#, L-B0, ABM-BTC Gasin -Baker Locked 41.35 2920.65 Gemoco 754' Ste a Ct3mentin Tool 2.81 2962.GG Joint A' 7-518'. 29.7#, L-$0. ABtlt-BTC Casir. -Baker Lacked 42.30 2964.81 S4 Jts 7-518", 29.7#, L-Btu. ~rFiL1-BTC Gasin 'Jts #17 - #80 2732.61 3607 ' 1 Marker Pu Jt: 7-8tt3", 29.7#, L-80, ABM-BTC Gasin ^.9.01 5739.72 Marker Pu Jt: 7-Stt3", 29.7# L-80, ASM-BTC Gasin 19.60 5758.73 13 .;ts 7-5J8", 25-7#, L-80, AB?rl-B-G Gasin 'Jts #~4 - #16 551.57 577$.33 Gernoeo Insert Shut-Off Baffle PBTD 6329.90 1 !t 7-518", 29.7#, L-S0, ABM-8TC Gasin Jt #3 4G.84 6329.90 Gemaco Float Collar 1.32 63 i0.7d 2 Jts 7-5J8". 29.7#, L-8Q, ABM-BTC Gasin Jts #1 & #21 $3.29 6372.06 Gemoco Ffoat Shoe '.SG 6455.35 6456.8 TD ~172.C0 Rat Dole 15.15 Centralizers Jt #1 1 Bow S vino an sto caller Jt #2 2 S ' fides wJ 1 sto collar ,It #3 1 Bow S rin on stop cellar Jt# 4 -15 2 S i !ides wi 1 sto collar r" ~ J~! 16 -20 1 Rotcc Strai h Blade xJ 1 sto colar r `t Jt A - B 1 Bow S rin or stop collar e; °1 1 Bavr s rir. on cp; ai Jt # 23, 26, 29, 32, 35, 38, 41.44, 47, 5G, 53, 56, 59.62, 65, 68 71, 74. 77, 83. 80 89. 92, 93. 88, 101, 104, 107. 11G. 113, 110. i19, 122. ".25, :2$. 131, 134. 137. 140, 143. 146 Total 4~ Bow S :ins 26 5 iro ;ides 5 St~ai ht B'ace Jts Ou: = Ji#14a -160 '12 J'S1 rlcrreoins, v~eu tart 7V1UC! ~ nreaa cope Up Wt - 225< d7 Wt - 120k Psrker Rig #245 ,~rii;~n_g Supervisor. l.~;trick/CunnF~ham . . Conoccl"hillips Alaska RECEIVED AUG 1 3 2007 Alaka Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 S'CANNED AU G 14 '2007 \C\~~tlO Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ~- ConocoPhillips Well Integrity Projects Supervisor ,~ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 1 0-32 200-173 10" n/a n/a n/a 6.8 8/8/2007 1 0-36 200-130 20" n/a n/a n/a 4.2 8/8/2007 1 0-37 200-204 20" n/a n/a n/a 4.2 8/8/2007 1 0-38 200-077 24" n/a n/a n/a 4.2 8/8/2007 1 0-39 200-216 27" n/a n/a n/a 7.6 8/8/2007 1 0-40 200-190 13" n/a n/a n/a 3.4 8/8/2007 1 041 205-188 12" n/a n/a n/a 1.7 8/8/2007 1042 200-164 16" n/a n/a n/a 3.4 8/8/2007 10-131 198-110 6" n/a n/a n/a 2 8/8/2007 . RECEIVED STATE OF ALASKA. MAY 3 ALASKA OIL AND GAS CONSERVATION COMMISSION Ala k 0 2007 REPORT OF SUNDRY WELL OPERATIONS s a Oil & Gas C ons. f",.,_ 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other 111lCnf!Jge ''''UII Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D . 198-110/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22891-00 / 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' / 10-131 , 8. Property Designation: 10. Field/Pool(s): ADL 25650,/ ALK 468 Kuparuk River Field / West Sak Oil Pool .- 11. Present Well Condition Summary: Total Depth measured 6472' / feet true vertical 4124' / feet Plugs (measured) Effective Depth measured 5663' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' PRODUCTION 6416' 7-5/8" 6457' 4110' S~ANNEDJUN 1 4 2007 Perforation depth: Measured depth: 5832'-5860',5894'-5914', 5938'-5978', 6050'-6086' true vertical depth: 3503'-3530', 3563'-3582', 3606'-3644', 3714'-3749' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5774' MD. Packers & SSSV (type & measured depth) no packer no SSSV 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 Casino Pressure Tubinn Pressure Prior to well operation SI Subsequent to operation 152 8 24 -- 155 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Brett Packer @ 265-6845 Printed Name ~~c~~ -j'~ Title Wells Group Engineer Signature Phone ffo'T) <?lr - ?Lrt- Date Ç2'f-O 7- 1"7-) Z'r-- ,,~ PrenarRrl bv Sharon AII·u~DrakA 263-4612 Form 10-404 Revised 04/2006 0 R , G , N A L RBDMS 8Fl JUN 112007 6VY ~ 1',3,.07 ~r~~~ · '! ¡¡r¡¡V'" ConocoPhillips Time Log Summary Wel/Yiew Web Reportíng Well Name: 1 0-131 Job Type: RECOMPLETION 05/04/2007 10:00 12:30 2.50 DEMOB MOVE RURD P PJSM, RD, prepare move to 1D-131. 12:30 18:00 5.50 MIRU MOVE MOB P Mob rig, move rig / camp t01 D pad. 18:00 22:00 4.00 MIRU MOVE RURD P PJSM, spot rig, RU on well1D-131. 22:00 22:30 0.50 COMPZr RPCOI\ OTHR P PJSM, 500 psi tbg / csg, RU lubricator, pull BPV. Accept Nordic Riq 3, this date 5/4/07,2200 hrs. 22:30 00:00 1.50 COMPZI RPCOl\ SFEQ P PJSM, test hard lines, load brine to Dits. 05/05/2007 00:00 04:30 4.50 COMPZI WELCT COND P Cont. offload brine, mix to 9.7 ppg / 6% KCL 04:30 09:30 5.00 COMPZI RPCOI\ CIRC P RR / circ warm diesel to well, 1.5 bpm / 800 DSi. Returns clean. 09:30 11:30 2.00 COMPZI WELCT KLWL P PJSM, circ 9.7 ppg kill fluids to well. ICP = 1.5 bpm /800 psi. FCP = 1.5 bDm /150 psi. 11 :30 12:30 1.00 COMPZt WELCT OWFF P Monitor well, "0" psi tbg / csg. Well static. 12:30 13:00 0.50 COMPZt RPCOI\ RURD P RD circ equip, set TWC. 13:00 13:30 0.50 COMPZt RPCOI\ SFEQ P Test tbg hgr seals in prep for ND tree. Set BPV. 13:30 14:30 1.00 COMPZt WELCT NUND P PJSM, ND prod tree. 14:30 22:00 7.50 COMPZr WELCT NUND P PJSM, NU BOPE. C/O lower pipe rams to 3 1/2". 22:00 00:00 2.00 COMPZr WELCl BOPE P Test BOPE to 250/2500 psi. Waiver of witness by Bob Noble w/ AOGCC / NS Inspectors Office. 05/06/2007 00:00 01:00 1.00 COMPZ WELCT BOPE P Finish BOP test all components 250 / 2500 psi, all OK. 01:00 01:30 0.50 COMPZr WELCT OTHR P Pull TWC and set BPV. 01:30 02:30 1.00 COMPZr RPCOI\ RURD P RU sheave for heat trace in derrick. String both for spooling operations when POOH w/ tbg and ESP. Prep floor for POOH w/ completion. RU to circulate when tbq hanqer unseated. 05/06/2007 02:30 04:00 1.50 COMPZt RPCOI\ CIRC P PJSM wI Centrilift, TYCO, Vetco and crew fl TOH and spooling activities. BLDS, PU and unseat tbg hanger. Unseat wI 105 klbs pull. PU wt pulling hanger to floor 100 klbs. At floor, CBU wI KWF while disconnecting heat trace and ESP penetrators on hanger. Circulate at 68 spm 1190 psi, had gassed fluid on bottoms up. Decide to circulate longer to clear gas from annulus. 04:00 04:30 0.50 COMPZr RPCOI\ CIRC P CBU to clear gas from annulus. 04:30 15:00 10.50 COMPZr RPCOI\ TRIP P TOH wI removing Cannon clamps and reeling cables on rig floor. TOH fl 5795' - ESP assy. 15:00 16:30 1.50 COMPZr RPCOI\ PULD P PJSM, LD ESP assy, inspect all components. "NORM" all components not to be used and load out. All clamps and hardware acounter for. 16:30 17:30 1.00 COMPZt RIGMN SVRG P Clear floor, press spray oily residue from equip. 17:30 20:00 2.50 COMPZt RPCOI\ RURD P PJSM. C/O ESP cable spool wI crane. 20:00 22:30 2.50 COMPZt RPCOI\ RURD P PJSM. RU to run ESP. 22:30 00:00 1.50 COMPZt RPCOI\ PULD P PU ESP Motor and seal assembly. 05/07/2007 00:00 01:30 1.50 COMPZr RPCOI\ RURD P Finish picking up, assembling ESP motor wI gear reduction and seal assembly. Confirm free rotation of ESP components, fill assembly wI oil. 01:30 04:00 2.50 COMPZt RPCm RURD P Splice ESP connectors to cable and connect to motor. Test all, OK. Prepare for RIH wI ESP motor and cable. 04:00 06:00 2.00 COMPZr RPCOI\ RCST P RIH wI ESP on 3 1/2" completion string per procedure. PU GLM's and install as required. 06:00 07:30 1.50 COM PZt RPCOI\ RCST P Cont RIH wI ESP U 2700'. 07:30 08:00 0.50 COMPZt RPCOI\ RCST P RU and start Heat trace at 3100'. 08:00 12:00 4.00 COMPZt RPCm. RCST P Continue RIH wI ESP motor, wI attaching Heat-trace and ESP cable to tubing wI cannon clamps. 12:00 18:30 6.50 COMPZt RPCOI\ RCST P PJSM @ crew change. Cont RIH wI ESP motor wI installing cabling fl 4040' - 5734'. 18:30 19:00 0.50 COMPZ RPCOl\ PULD P PU tubing hanger wI landing jt. Make up into string. 19:00 19:30 0.50 COMPZI RPCOI\ OTHR P Install penetrators in hanger. Cut ESP and Heat trace-cable, install connector ends and test same, OK. Connect to hanger. Total protector clamps installed as follows: (48) ESP cross coupling single channel clamps, (455) 5" Cannon Clamps, (1) 4' cannon clamp, (92) Dual channel cross coupling ESP & Heat trace clamps for total of (596) clamps and (5) stainless flat bands wI crim s. COMPZ RPCOII. RCST P Land hanger. PU 93klbs, SO 57klbs. Visual on correct land & seat of han er, OK. RILD. COMPZ RPCOII. P Test upper and lower hanger body seals to 5000 psi f/10 min ea, OK. BO landing jt, remove side port isolation sleeve, set BPV. COMPZ P PJSM, ND BOPE. COMPZ P E-test penetrators I cable on ESP & Heat Trace, OK. Inspect tree, remove swab and master valve for re lacement. RU lines for freeze protect operations wI waiting on two replacement valves for tree. PJSM, Take delivery new tree valves (Old valves leaked) NU tree, pull BPV, setTWC. PJSM, test tree 250/5000 psi 10 min. Test successful, no re-tests. PJSM, RU I freeze protect well. 145 bbls total, FCP = 875 psi at 2 bpm. "U" tube leaving 260 psi on tbg. RD lines, ull TWC, set BPV. DEMOB MOVE DMOB P PJSM, secure well, prep rig for move, moveoff1D-131. Nordic rig 3 released this date 518107 at 1300 hrs. 23:00 23:30 0.50 23:30 00:00 0.50 05/08/2007 00:00 03:00 3.00 03:00 05:00 2.00 05:00 05:30 0.50 COMPZ RPCOII. RURD P 05:30 07:00 1.50 COMPZ RPCOII. NUND P 07:00 07:30 0.50 COMPZ RPCOII. SFEQ P 07:30 12:00 4.50 RPCOII. FRZP P 12:00 13:00 1.00 . . ConocoPhiUips Alaska, Inc. KRU 1 D-131 ~ Heat Trace - API: 500292289100 Well Type: PROD Anç¡le@TS: deç¡@ (3008-5792, SSSV Type: NONE Oriç¡ Completion: 11/18/1998 Angle @ TD: 13 de ¡ @ 6472 00:1.000) Annular Fluid: DSUSW Last W/O: 5/8/2007 Rev Reason: SET ESP ASSEMBLY TUBING - Reference Loa: 37' RKB Ref Loo Date: Last Update: 5/19/2007 Last Tao: 5663' TD: 6472 ftKB (0-5774, Last.Date: 10/19/2006 MaXHole~~4389 00:3.500, 10:2.992) I DescriDtion I Size I TOD Bottom I TVD I Wt I Grade I Thread I CONDUCTOR , 16.000 0 121 I 121 62.58 I H-40 I WELDED I 'ROOUCTION - (0-6457, 00:7625, W\:29.70) 3.500 0 5774 9.30 L-80 Interval TVD Zone Status Ft SPF Date TYPe Comment 5832 - 5860 3503 - 3530 WSD 28 4 8/30/1998 IPERF 2 1/8" EJ, BH 0 PH 5894 - 5914 3563 - 3582 WSB 20 4 8/27/1998 IPERF 2 1/8" EJ. BH 0 PH 5938 - 5978 3606 - 3644 WS A4,WS 40 4 8/24/1998 IPERF 21/8" EJ, BH 0 PH A3 6050 - 6086 3714 - 37 2 1/8" EJ. BH 0 PH St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 4334 2404 CAMCO KBMG DMY 1.0 BK-5 0.000 0 5/6/2007 2 5684 3360 CAMCO KBMG SOY 1.0 BK-5 0.000 2000 5/1712007 DeDth TVD TVDe DescriDtion ID XO- 37 37 HANGER 3.500 (5774-5775, 3008 1843 Heat Trace EXTERNAL HEAT TRACE 0.000 00:5.130) 5764 3437 GAUGE QUANTX GAUGE 0.000 5774 3447 PUMP 31/2" PCP (OAL=40' 6") @ 5774' RKB,SET PACKOFF ASSY (92" OAL,NO CHECK 0.000 PUMP - OR K.O.\. SET D AND D SLIP STOP ON TOP OF PACKOFF 5/16/2007 (5774-5779, 5774 3447 XO BAKER TTC XO 0.000 5779 3452 SEAL CENTRILlFT TANDEM SEAL GSB3 0.000 00:2.790) 5793 3465 GEARBOX CENTRILlFT 11.4:1 0.000 SEAL - 5794 3466 MOTOR CENTRILlFT KMH 78 HP MOTOR 0.000 (5779-5793, 5804 3476 Centralizer BAKER 'HOME MADE' CENTRALIZER 0.000 OD:5.130) GEARBOX - (5793-5794, 00:5.380) MOTOR - (5794-5804, 00:5.130) Centralizer - (5804-5805, 00:5.130) Perf --...- "_on (5832-5860) - - - - - - - - _..~ - - Perf - - (5894-5914) - - --. -...... - - - - - - Perf == == (5938-5978) - - - - - - - - - - -- == Perf - (6050-6086) - - - - - - - - - - ..."..----. -.. ) ') Jim Ennis Wells Group Engineer Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 January 19, 2006 RECEIVED JAN 2 4 ?006 Alarka Oil & G as Cons. C . Anchorage OTnm,ss;on Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: GC{¡"\\O \-\ Subject: Reports of Sundry Well Operations for 10-131 ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the West Sak well 1 0-131. If you have any questions regarding this matter, please contact me at 265-1544. Sincerel~_ ~ SCANNED) \\U\I~\' 2 ~J 2.0Ub J. Ennis Wells Group Engineer CPAI Drilling and Wells J E/skad 1. Operations Performed: ) ) RECEIVED JAN 2 4 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Cornmissi REPORT OF SUNDRY WELL OPERATIONS Anchorage o Time Extension 0 Re-enter Suspended Well 0 Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Other Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41', Pad 71' 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION Perforation depth: 5. Permit to Drill Number: 198-11 0 1 6. API Number: 50-029-22891-00 Exploratory 0 o Service 9. Well Name and Number: 1 0-131 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool measured 6472' feet true vertical 4124' feet measured 5804' feet true vertical feet Length Size MD 80' 16" 121' 6416' 7-5/8" 6457' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4110' Measured depth: 5832'-5860',5894'-5914',5938'-5978', 5979'-5986',5996'-6002',6008'-6014', 6020'-6026', 6050'-6088' true vertical depth: 3503'-3530',3563'-3582',3606'-3644', 3645'-3652', 3662'-3668', 3673'-3679', 3685'·3691', 6050'-6088' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5800' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft .IAlV ~), ,i 7006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation SI Subsequent to operation 201 6 154 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Printed Name Signature Jim Ennis @ 265-1544 ~J.lin::¡...EnniS 10---="" ¿" \ Title Phone f,.. ) Wells Engineer \. ~ \ l J (, 5' - I r- L.. i Date I b ç, J 0 to Prepared bv Sharon k~p-Drake 263-4612 ORIGINAL Form 10-404 Revised 04/2004 Submit Original Only ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ... ....C9nocQRhinjþ~iAlâ~~ª... (}pcaratiøl1s:··$lIrn.målrY..··~~!P()rt 10-131 1 D-131 WORKOVER/RECOMP Nabors 38 IFrdrn~..Td !Hours· .GOdé£b~~ Phase 12/5/2005 02:00 - 06:00 06:00 - 09:00 4.00 MOVE MOVE MOVE 3.00 MOVE MOVE MOVE 09:00 - 11 :00 2.00 MOVE POSN MOVE 11 :00 - 11 :30 0.50 MOVE SFTY MOVE 11 :30 - 15:00 3.50 MOVE SFTY MOVE 15:00 - 18:00 3.00 MOVE POSN MOVE 18:00 - 00:00 12/6/2005 00:00 - 03:00 03:00 - 05:00 05:00 - 06:30 06:30 - 10:00 10:00 - 11 :00 11 :00 - 15:00 15:00 - 17:00 17:00 - 20:00 20:00 - 00:00 12/7/2005 00:00 - 01 :00 ; 01 :00 - 06:00 ! 06:00 - 08:00 : ·08:00 - 10:00 : 10:00 - 20:00 I 6.00 MOVE POSN MOVE 3.00 MOVE RURD RIGUP 2.00 MOVE RURD RIGUP 1.50 WELLSR RURD WRKOVR 3.50 WELLSR RURD WRKOVR 1.00 WELLSR RURD WRKOVR 4.00 WELLSR RURD WRKOVR Start: 11/28/2005 Rig Release: 12/15/2005 Rig Number: Spud Date: 7/9/1998 End: G rou p: . . . ::..."..:" .": "'. .... Pøscrlptiþn :òfbperátions Prep rig for moving to 1 D-131. Disconnect pipe shed pit module. Scope derrick down and lower to carrier. Start moving rig off of 1 D-133 and over to 1 D-131. Pulled pipe shed and pit module out, moved sub base or carrier forward away from well. Moved BOPE out from behind well and over behind 1 D-131, removed rig mats and herculite. Fill mouse hole and cleaned around well head. Made room for LRS to get on well and freeze protect. Attempted to back carrier upto 1 D-131 and line up several times but wing valve on 1 D-130 and annulus valve on 1 D-132 too close and has to be removed. Safety shut down. Wait for Drill Site Maintenance to rotate wing valve on 1 D-130 and remove annulus valve on 1 D-132. Back carrier up over the well and line up. Pull forward, layout all rig mats and Herculite for containment. Back carrier up spot over well, jack down and level up. Move in pipe shed; lay mats, set down jacks and level. Rig equipment (hydraulics, etc.) moving slowly due to cold. Spot up pits. Continued. Rig spotted. Begin rigging up. Temp is close to minimum for raising derrick. Currently -35 deg ambient. Verify temp is within limitation, -34 deg. Inspect derrick and conduct pre-job Raise rig derrick and telescope out. Completed hooking up lines etc. Load pits with 9.9 ppg brine w/3% KCL. Accepted rig @ 06:30 12-6-2005. Perform PJSM. Install boards in cellar for safe working area. Rig up lubricator to pull BPV. Called AOGCC and talked to John Crisp. He asked to be given a call after we have BPV set and are ready to test BOPE. Finish pulling BPV. Rig up kill line system. Supervisors performing Tap Root investigation. 2.00 RIGMNT RGRP WRKOVR Attempted to Pressure test all surface equip for well kill operations. Engines quit, begin working to start back up. Alternator failed. re-install new and change batteries to operate pumps. 3.00 WELLSR SEQT WRKOVR Pressure test all surface equipment to 2,000 PSI. Prepare to begin well kill after changeout. 4.00 WELLSR CIRC WRKOVR Everything PT to 2000 PSI. Held PJSM with night crew. Phase II conditions. Relieve personel watching return tanks often. Start pumping 290 bbls hot 130 degree seawater down IA @ 4 BPM, taking returns to kill tanks, getting 1:1 returns. Followed by 250 bbls of 9.9# brine with 3% KCL. Complete pumping brine. Monitor well 15 mins. Casing pressure 80 PSI 1 tubing pressure 50 PSI. Bleed tubing and IA to zero. Monitor pressures, both pressures coming up. Pump another two tubing volumes with similar results. Getting a little better each time. Pump another 1.5 tubing volume. Monitor pressures. Tubing pressure 20 PSI/IA 40 PSI and falling. Had to bleed remaining : 20 PSI off IA. Watch pressures 30 mins. Well dead. 2.00' WELCTL NUND DECOMP Set BPV. ND tree. NUND well kill equipment. 2.00 WELCTL NUND DECOMP I Bleed hanger void prepare to ND tree. Measure LDS clearence. Set : test dart 16 turns to right. clean work area. 10.00! WELCTL NUND DECOMP Nipple up BOPE. Open IA to tanks and monitor for pressure. Check . tanks every half hour. Sweeny wrench failed. Begin manual install via hammer wrenches. Initial cycle test to ensure proper hook ups. 1.00 WELLS~ CIRC WRKOVR I I I 5.00! WELLS~ CIRC I, WRKOVR Printed: 1/19/2006 3:44:29 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-131 1 0-131 WORKOVER/RECOMP Nabors 3S ""Date . 'Sub. From.. To HÖÜrsCddë CodePhase< 12/7/2005 10:00 - 20:00 10.00 WELCTL NUND DECOMP 20:00 - 00:00 4.00 WELCTL BOPE DECOMP 12/8/2005 00:00 - 05:00 5.00 WELLSR RURD DECOMP 05:00 - 05:30 05:30 - 07:00 0.50 WELLSR SFTY DECOMP 1.50 FISH PULL DECOMP 07:00 - 08:00 1.00 FISH CIRC DECOMP 08:00 - 09:00 1.00 FISH CIRC DECOMP 09:00 - 17:00 8.00 WAlTON SPL Y DECOMP 17:00 - 20:00 3.00 FISH CIRC DECOMP 20:00 - 21 :00 1.00 FISH CIRC DECOMP 21 :00 - 00:00 3.00 FISH PULL DECOMP 12/9/2005 00:00 - 06:00 6.00 FISH PULL DECOMP 06:00 - 08:30 2.50 RIGMNT RGRP DECOMP 08:30 - 18:00 9.50 FISH PULL DECOMP 18:00 - 21 :00 3.00 FISH PULL DECOMP 21 :00 - 22:00 1.00 FISH PULL DECOMP 22:00 - 00:00 2.00 FISH ,PULL DECOMP 12/1 012005 00:00 - 02:00 I 2.00 FISH PULL DECOMP 02:00 - 05:00 : 3.00 ¡ WELLSR PULD DECOMP 05:00 - 08:30 3.50 I WELLSR PULD ' DECOMP : .08:30 - 18:00 I 9.50 I WELLSR TRIP I DECOMP Start: 11/28/2005 Rig Release: 12/15/2005 Rig Number: Spud Date: 7/9/1998 End: G rou p: . . Dé$<RriÞtio~l. dfOp~rätions Several missed. Initial pressure test proved replacement of seals. Fill stack, pressure up and bleed air. Begin BOPE test, function and PT BOP rams and choke manifold to (250/3000) PSI annular to (250/2500) PSI. AOGCC Jon Crisp waived witnessing test. Lay down test joint, blow down all lines. Check pressures. Pull test plug and BPV, well appears to be static. Install isolation sleeve and make up landing joint and change elevators. Rig up sheaves and all other equipment for ESP and heat trace cable removal. Held safety meeting with all personnel involved in pulling completion. BOLDS. Check pressures. 10 psi on lA, bleed off IA to kill tanks, close IA. Work up weight to 100K, hanger pulled free, pulled to rig floor. Removed penetrators from hanger, filled hole with 2 bbls. Monitor well for gas brake out. Line up to begin pumping down IA taking returns to pit 1. Crude in returns, divert to pit three. 70 BBLS in pits to start. Pump pit three to outside tanks to remove crude from pits. 30 BBLS 9.9 PPG brine left in pit 1. Monitor well for returns. Mud wt in 9.9 PPG Weight out 8.7 PPG. Pump system not correctly lined up to reverse. Pumped 40 BBLS dwn tubing taking returns up the IA. Discussed why we reverse on these programs. Call out 200 BBLS of 9.9 PPG brine from Prudhoe. Peak transport. Crew to clean pits, blow dwn lines, dig mouse hole, and wash rig floor. Break circulation every 30 min for 1/2 BBL to ensure no freezing. Peak on location. Tool box safety meet. Inspect plumbing to confirm reverse out will happen. Pump 1 1/2 bottoms up. Pump at 2.5 BPM - 160 psi pump pressure. Monitor well, well dead. Blow down circulating hose. Begin pulling pipe, standing back in the derrick. Five stands out, slow going spooling heat tracelpower cable and cutting bandslremoving channel. Continue pulling 3.5" ESP completion, standing back in the derrick. Losing approximately 4 bbls per hour of brine. Total of 25 stands out. Rig saver failure. Could not reset system. Continue to POOH.Stilllosing 4 BBLS per hour. Continue to POOH with ESP completion. Lay down four single joints of tubing and GLM On surface with completion. Made several attempts to pull wireline conveyed ESP/pack-off from tubing. Lots of formation sand in pump assembly. Appeared to be some scale as well. Made several attempts to pull wireline conveyed ESP/Pack-off I assembly from tubing were unsuccessful. Had to lay down assembly in I tubing. , Count all clamps/bands. Full recovery of all clamps/bands. Lay down all : spooling equipment. Clear rig floor of all completion equpment. Clean rig floor. Install wear ring. Make up test packer/RBP BHA. Had issues with wear ring. Re-measure to LDS and ring fit loosely until LDS tightened up. . Pick up PH-6 pipe handling equipment and prepare to RIH. RIH with Baker test packer assembly of a model EA retrievamatic 6.66" OD. 17.31' long, Model Glock-set RBP. 15.66' Long. 6.66" OD. Begin RIH monitoring losses. Continue 4 BBLS per hour loss. UP WT = 45K Printed: 111912006 3:44:29 PM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .'Çon9cô~þlllips·.Alåskª ~.perati Ör1s.·.Surnma..y·.,RelpÂrt 10-131 10-131 WORKOVER/RECOMP Start: 11/28/2005 Rig Release: 12/15/2005 Rig Number: Spud Date: 7/9/1998 End: G rou p: Nabors 3S Sub From- Tp HÓUrsCÓde .Cbde 08:30 - 18:00 18:00 - 19:30 Date 12/1 012005 19:30 - 23:00 12/11/2005 23:00 - 00:00 00:00 - 04:00 04:00 - 07:00 07:00 - 14:00 14:00 - 14:45 14:45 - 18:00 18:00 - 00:00 12/12/2005 00:00 - 05:00 05:00 - 06:45 06:45 - 10:30 10:30 - 12:30 12:30 - 18:00 18:00 - 21 :30 12/13/2005 I 121 :30 - 22:30 I 122:30 - 00:00 I I 100:00 - 01 :00 . 101 :00 - 08:00 i .08:00 - 14:00 . ",. ..... ... ... .. ....... ... '., D~~criþtic>ndf bparåtip:n~" 9.50 WELLSR TRIP DECOMP DWN wt = 28K. 1.50 WELLSR TRIP DECOMP Set RBP @ 5800' with 5000 ftllbs torque (56k up weight, 28k down) Release off of RBP. 3.50 WELLSR PLGM DECOMP Make up head pin. PT lines 2500 psi. PT 7 5/8" casing to 2500 psi for 30 mins. Good test- 50 psi drop 30 mins. Latch and release RBP. Lay down head pin. 1.00 WELLSR TRIP DECOMP POOH wi PH-6 and packerlRBP assembly. 4.00 WELLSR TRIP DECOMP Continue OOH wi test packer/RBP. Monitoring fluid lost (4 bbls per hour). Last 8 stands were wet. Due to scale plugging off RBP. 3.00 WELLSR RURD DECOMP Lay down test packer assembly. RBP packed off with scale. Make up clean out BHA. Clean out BHA consist of 6 5/8" 5 bladed mill with a 1 3/4" 35 Deg off center bottom port for solids to travel thru. 4 3/4" jar along with 6 ea. 4 3/4" drill collars. 7.00 WELLSR TRIP DECOMP Rig up on stand number 90 to break circulation for slow pump pressure. 1 BPM @ 50 PSI. Break pump lines dwn and prepare to rih with stand 91 & 92. Current up wt = 60K Dwn wt = 35K. 0.75 WELLSR TRIP DECOMP RIH with stand 91 & 92. Begin rig up of reverse out system. Begin batching up 2.5 PPB Biozan pill in pit three. 3.25 WELLSR WASH DECOMP Reverse circulate 1.5 tubing volume. Begin clean out @ 2 BPM 150 psi 6.00 WELLSRWASH DECOMP Wash to bottom from joint 188 to 190. Tag fill @ 6035'. Increase pump rate to 3 BPM. Losing 20-25 bbls per hour. Able to work thru fill. Getting crude and formation sand in returns. 5.00 WELLSR WASH DECOMP Continue cleaning 7 5/8" casing from 6035' to 6329'. Circulating rate 2 bpm @ 150 psi. Minimal sand returns below perfs. Losing 18 - 22 bbls per hour. UP and down weights 85k and 34k. 1.75 WELLSR CIRC DECOMP Pump 15 barrel pill sweep to surface. 3.75 WELLSR CIRC DECOMP Returns during circulation = sand, scale, and some crude. 2-2.5 BPM @ 150 PSI pump pressure. 500 PSI on annular. Monitor well for 20 min. Well flowing. Begin second circulation of hole volume. increase rate to 3.5 BPM @ 390 PSI Losses during reverse circulation = 18 BPH9.8 heavy in and 9.8 heavy out. 2.00 WELLSR OBSV DECOMP Monitor well for flow. ISIWHP = 60PSI. ISIDPP = 50 PSI. Allow pressures to bleed off slowly. Pit gain = 17.5 BBL. service blocks while waiting for well to bleed off. Pressure near 0 PSI. Prep to POOH. 5.50 WELLSR TRIP DECOMP POOH monitoring well for flow. Up Wt = 85K While pulling OOH trip tank indicates well breathing pipe displacement. 1.5 BBL per 10 joints every other count. Continue to POOH. DECOMP Well appears to be stable. On surface with BHA. Lay down drill collarsljarslmill. DECOMP Pull wear ring DECOMP Change out power tongs. Clear and clean rig floor. Service rig. Drive i lines/blocks. CMPL TN Rig up to run ESP motor assembly. Pick up motor centralizerl motor (76hp KMHG 1369VI 34A) I Gear reduction unit. Unable to make up I seal assembly. Missing coupler between the gear reduction unit and the ,seal section. 7.00 I CMPL TN PULD CMPL TN Centrilift rep. made several attempts to retrieve coupler from old assembly. No Luck. Hot shot to Milne point to look for another. No Luck. Call warehouse to see if one is available. Found one at warehouse. 6.00 CMPL TN PULD CMPL TN Continue to install ESP motor. Motor BHA consist of 6" O.D. centrilizer below motor, 1.75' long. 2" line pipe crossover to bottom of motor. Motor serial number = 21 K0071400, 8.3' long 5.62" O.D. GRU serial 3.50 WELLSR TRIP 1.00 I WELLS~ RURD 1.50 WELLS.J RURD 1.00 CMPL TN: PULD I Printed: 1/19/2006 3:44:29 PM ) ) COhòcpPhillip$ .Alé:1Øka .. .", .... . : :: :. . OpératiorH;; Su¡mm~ ry·R~port 6.00 CMPL TN PULD CMPL TN number = GRU0000608, 5.38" O.D. by 1.57' Long. Model 5.387 11.4:1. Seal section serial number = 31 G00942, Model number GSB3DB H6 PC92 AFLAS/HSN, length = 13.8', 5.13" O.D. TTC cross over serial number = TXA0000006 SLOTTED 3 1/2" 4.5" 0.0. 4.67' Long. Discharge head type 250-B-1800 length = 26' O.D. = 2.88". Splice Guardian gauge. Inspect and test. Guardian gauge type PM925 RIH ESP completion, drift pipe with 2.867" from derrick, clamp first six collars, then every other, test cable at 1000' intervals. Continue in hole with completion. Install Raychem heat trace on stand # 43. Continue to check cable every 1000'. Continue RIH wi completion, installing clampslbands as per program, checking cable every 1000'. Well is static. Make up hanger to tubing string, install landing joint. Install penetrators, cut cables and make splices, test, heat tracelpower cable tested. Had to troubleshoot gauge cable and resplice, tested. Final count on clamps/bans/etc. 2 Flatguard, 4 Protectalizers, 3 Bands, 48 2' ESP clamps, 456 5' ESP clamps, 3 4' ESP clamps, 2 3' ESP clamps, 89 2' Cross couplings, 2 Bolts on Guardian clamps. Up wt.= 58K Down wt.= 27K, land tubing. Check orientation of hager in wellhead. RILDS. Back out landing joint. Remove side port isolation slleve. Install BPV. Pressure test hanger void/pack-off to 5000 psi. ND BOPE. Checked ESP cable and heat trace cable for electrical integrity. Re-check BHP gauge, everything checked out good. NU tubing adapter and 5M tree Perform void test to 5000psi. held good. Pull BPV, install two way check. Test tree to 5000 psi (charted) Good test. Pull check. Put flange on choke hose. Rig-up LRS. Freeze protect with diesel @ 2 BPM down casing, in progress. LRS finished pumping 150 bbls diesel down casing, rig down LRS. Rig-up U-tube line from casing to tubing. U-tube diesel for freeze protection. Freeze protect complete. Rig-up BPV lubricator, install BPV, Lay down lubricator. Empty and clean pits. 2 to 3 feet of sand in pits. Completed pit cleaning. Released rig @ 5:00 on 12/15/05. Prep rig for rig move. Begin moving to 1 D-1 05A Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-131 1 D-131 WORKOVER/RECOMP Nabors 38 H· 0·· .·.·u··· r·s· ......' ···c·. .·.o·.·d..e·. .'......... 8Ùb ·Ph····· . Côdè. ... ,ase 12/13/2005 08:00 - 14:00 14:00 - 15:35 1.58 CMPL TN PULD CMPL TN 15:35 - 18:00 2.42 CMPL TN TRIP CMPL TN 18:00 - 00:00 6.00 CMPL TN TRIP CMPL TN 12/14/2005 00:00 - 08:00 8.00 CMPL TN TRIP CMPL TN 08:00 - 13:00 5.00 CMPL TN RURD CMPL TN 13:00 - 15:30 2.50 WELLSR NUND CMPL TN 15:30 - 18:00 2.50 WELLSR NUND CMPL TN 18:00 - 21 :30 3.50 WELLSR NUND CMPL TN 21 :30 - 23:30 2.00 WELLSR SEQP CMPL TN 23:30 - 00:00 0.50 WELLSR FRZP CMPL TN 12/1 512005 00:00 - 01 :30 1.50 WELLSR FRZP CMPL TN 01 :30 - 04:30 3.00 WELLSR PLGM CMPL TN 04:30 - 06:00 1.50 MOVE RURD MOVE Start: 11/28/2005 Rig Release: 12/15/2005 Rig Number: Spud Date: 7/9/1998 End: Group: .' Oescriptipn ··ofpþer$tio ns' Printed: 1/19/2006 3:44:29 PM 0.000 0.000 0.000 0.000 Description SLlCKLlNE RETRV PUMP; set pump (41' 2") packoff (8') & slipstop (24") REDRESSED & RESET 7/29/99 BAKER SENTRY GAUGE CENTRILlFT TANDEM SEAL CENTRILlFT CENTRILlFT KMH MOTOR 5760 3434 GAUGE 5778 3451 SEAL 5792 3464 GEARBOX 5793 3465 MOTOR ID 0.000 6050 - 6086 3714 - 3749 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 5683 3359 CAMCO KBMM CAMCO Other ( Jlugs, equip., etc.~ - JEWELRY Depth TVD Type 5736 3410 PUMP Vlv Cmnt Port TRO Date Run 0.000 3000 7/29/1999 V Mfr BK2 1.0 SOV V Type V aD Latch 4 8/25/1998 IPERF 21/8" EJ, BH 0 PH 36 Annular Fluid: DSUSW Reference Log: Last Tag: 5804 Last Tag Date: Casing Strin~ - ALL Description PRODUCTION CONDUCTOR Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD Zone 5832 - 5860 3503 - 3530 WS D 5938 - 5978 3606 - 3644 WS A4,WS A3 WSA2 Status Ft SPF Date Typel Comment 28 4 8/30/1998 IPERF 21/8" EJ, BH 0 PH 40 4 8/24/1998 IPERF 21/8" EJ, BH 0 PH Bottom TVD Wt Grade Thread 6457 4110 29.70 L-80 ABM-BTC 121 121 62.58 H-40 WELDED Wt I Grade I Thread 9.30 L-80 EUE-8RD TVD 3472 Bottom 5800 Top o o Size 7.625 16.000 Rev Reason: Add Gauge by ImO Last Update: 4/27/2002 Well Type: PROD Orig 11/18/1998 Completion: Last W/O: Ref Log Date: TD: 6472 ftKB Max Hole Angle: 68 deg cœ. 4389 API: 500292289100 SSSV Type: NONE Angle cœ. TS: deg cœ. Angle @ TD: 13 deg @ 6472 [\ .. ..~', ,. I,¡' Perf (605G-6086) Perf (5938-5978) Perf (5832-5860) MOTOR (5793-5794, 00:5.130) GEARBOX (5792-5793, 00:5.130) SEAL (5778-5792, 00:5.130) ~ODUCTION (G-6457, 00:7.625, Wt:29.70) PUMP (5736-5737, 00:2.800) Gas Lift v1andrelNalvE 1 (5683-5684, 00:5.390) TUBING (G-5800, 00:3.500, 10:2.992) PHilliPS Alas~..lt, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY - - 1D-131 1 D-131 ') KRU Re: FW: ID-131 Motor Failure ) ) l <;~- \ \"0 Subject: Re: FW: ID-131 Motor Failure From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 13 Jun 2005 11: 11 :41 -0800 To: NSK Problem Well Supv <nI617@conocophillips.com> Hi MJ, Keep us in the loop on any plans forward. Until then, this notice is sufficient. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom The ESP on West Sak Well 1 0-131 (PTO 198-110) has failed and will require a rig workover to repair. The well is currently SI and it is unknown whether ConocoPhillíps will pursue gaslìft in the future. Please let me know if you have any questions MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCANNE[) JUN 1 4.: 2005 -----Original Message----- From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Sunday, June 12, 2005 1:33 PM To: Rodgers, James T; Ennis, J J; Jenkins, Lubbie Allen Subject: 1D-131 Motor Failure 1 D-131 went down 6/10. James (Centrilift Rep) checked out the VSD and did not find any problems. When he checked the electrical resistance at the wellhead, the unit was grounded and unbalanced phase to phase. This probably means a burnt motor or at least a bad cable or connection downhole which will require a RWO to repair. This completion has been running since 12/98. The pump required several frequency increases since Dec. of 04 in an attempt to keep the BHP from climbing. Prior to the BHP increases the well was producing 180 bopd @ 550 psi suction pressure. The last few test had this well producing 120 bopd @ 870 psi suction pressure. Thanks, Peter Nezaticky I Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 6/13/2005 11: 11 AM ARCO Alaska, Inc. ' - ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 12, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-131 (Permit No. 98-110) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-131. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer AAI Drilling TWM/skad STATE OF ALASKA ~-~,LASKA OIL AND GAS CONSERVATION COMMISSION ..... R ~CE ~ rED WELL COMPLETION OR RECOMPLETION REPORT AND LOG _ __ . 1 Status of Well Classification of Service Well JAN 13 OIL E~] GAS E~ SUSPENDED E~ ABANDONED~ SERVICE [] 2 Name of Operator 7 Permit Number ~as~. 0il & Gas 00r~$. ~{ ARCO A~aska, ,nc 96-110 Anchoraoe 3 Address 8 APt Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22891 4 Location of well at surface ,:~~'~" !9 Unit or Lease Name 421' FNL, 600' FEL, Sec. 23, 111 N, R10E, UM .~'.-':' : ,':~: ' Kuparuk River Unit A 10 Well Number 1367' FSL, 2374' FWL, Sec. 23, T11N, R10E, UM , · _. 'tr~ ~_. ~._.;~q~,.,,~,, West Sak 1D-131 At Total Depth - ',~ .I: I~ ~,: '. i~ 11 Field and Pool 1238' FSL, 2289' FWL, Sec. 23, T11N, R10E, UM: r._ . -. i KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 09-Jul-98 11-Jul-98 18-Nov-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+-FVD) ;19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6472' MD & 4124' TVD '6323' MD & 3979' TVD YES M NO U NA feet MD 1513' APPROX 22 Type Electric or Other Logs Run GR/Res, USIT, CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24" 246 sx AS II 7.625" 29.7# L-80 SURF. 6457' 9.875" 1. 175 sx DLW, 325 sx Class G 2. 419 sx DLW, 60 sxAS 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) 6050'-6088' MD 3714'-3751' 'I'VD 4 spf 3.5" 5800' N/A 5938'-5978' MD 3606'-3644' TVD 4 spf 5894'-5914' MD 3563'-3582' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5832'-5860' MD 3503'-3530' 'T-VD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5979'~5986' MD 3645'-3652' 'T-VD 5 spf 6050'-6088', 5938'-5978' see attachments 5996'-6002' MD 3662'-3668' q'VD 5 spf 5894'-5914', 5832'-5860' 6008'-6014' MD 3673'-3679' 'T'VD 5 spf 6020'-6026' MD 3685'-3691' TVD 5 spf 27 PRODUCTION TESTORIGINAL Date First Production12/27/98 Method of OperationFiowing(FIowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOf',OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 12J28/98 6 TEST PERIOD 23 0 0 100I 236 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 227 0 24-HOUR RATE: 84 20 0 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 5830' 3501' Base West Sak Sand 6270' 3928' Annulus left open - freeze protected with diesel. 31. LIST OF ATrACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form lOo407 Date: 10/14/98 ARCO ALASKA INC. WELL SUM~LARY REPORT Page: 1 WELL:iD-131 WELL_ID: AK9653 TYPE: AFC: AK9653 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/09/98 START COMP: RIG:RIG # 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22891-00 07/08/98 (D1) TD: 121'(121) SUPV:MCH/MC 07/09/98 (D2) TD: 3313'(3192) SUPV:MCH/MC 07/10/98 (D3) TD: 5213'(1900) SUPV:LC/MC 07/11/98 (D4) TD: 6472' (1259) SUPV:LC/MC 07/12/98 (D5) TD: 6472'( SUPV:LC/MC 0) 07/13/98 (D6) TD: 6472'( SUPV:LC/MC 0) 07/14/98 (D7) TD: 6472'( SUPV:DCL o) MW: 8.8 VISC: 178 PV/YP: 28/49 APIW-L: 9.6 Drilling and survey Move rig from 1D-127 to 1D-131. Accept rig ~ 1800 hrs. 7/8/98. N/U diverter system and test. MW: 9.6 VISC: 325 PV/YP: 40/60 APIWL: 8.2 Drilling and surveys Drill from 121' to 3313' MW: 9.5 VISC: 220 PV/YP: 33/40 APIWL: 7.2 Drilling Drilling from 3313' to 5213' MW: 9.6 VISC: 192 PV/YP: 38/49 APIWL: 6.5 POH w/hole opener Drilling from 5213' to 6472' POH. Tight from 1100' to 357' Did not swab. RIH w/hole opener. MW: 0.0 VISC: 192 PV/YP: 0/ 0 APIWL: 0.0 NU BOPE RIH with 7-5/8" casing. Wash casing down from 5494' to 6457' Pump cement. MW: 8.6 VISC: 56 PV/YP: 10/16 APIWL: 14.5 R/U SWS Bump plug on 1st stage cement job. Pump 2nd stage cement job. Drill out stage tool. MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 NU tree Run USIT log from 6300' to surface. RIH w/3.5" tubing. Pump caustic hog wash. Date: 10/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/15/98 (D8) TD: 6472'( SUPV:DCL 0) MW: 8.5 VISC: Rig released 0 PV/YP: 0/ 0 APIWL: 0.0 ND BOPE. Nil tree and test to 3000 psi. Release rig ~ 0700 7/15/98 Date: 12/30/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-131 WELL ID: AK9653 TYPE: -- AFC: AK9653 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/09/98 START COMP:11/12/98 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22891-00 11/12/98 (C9) TD: 6472' PB: 6330 ' 11/13/98 (C10) TD: 6472 ' PB: 6330 ' ii/14/98 (Cji) TD: 6472' PB: 6330 ' li/i5/98 (Ci2 TD: 6472' PB: 6330' 11/16/98 (C13 TD: 6472' PB: 6330' 11/17/98 (C14 TD: 6472' PB: 6330' LAYING DOWN 3 1/2" TBG. MW: 8.7 BRINE SUPV:M.C. HEIM Move rig from 1D-134 to 1D-131, accept rig @ 1300 hrs. N/D tree, N/U BOPE and test. REVERSE CIRC.=CLEAN UP CO MW: 8.7 BRINE SUPV:M.C. HEIM Pull tubing. RIH w/mill. Milling and cleaning out from 5782' to 6323' REVERSE CIRC. SAND @ 2415 MW: 8.7 BRINE SUPV:M.C. HEIM Attempt to pull above perfs, pulling tight. Pull 6 stands thru perf, tight. Reverse circ. Filtering completion fluids. Hole flowing back, well dead. Make up perf guns. Guns stop @ 2144'. Work. Install second set of rollers on tool, rib to 2144', same problem, line twisted and damaged same. POH. REVERSE CIRC. @ 6323=FILT MW: 8.7 BRINE SUPV:M.C. HElM Clean out sand out of casing from 2450' to 2100'. Reverse circ till hole clean. RIH w/perf guns, tight @ 2900' Reverse circ hole clean, recovered frac sand. Cleaned out to 3983' POH W/ 3.5" TBG. MW: 8.7 BRINE SUPV:M.C. HEIM Continue cleaning out by reverse circulate. RIH w/perf guns and perforate. RUNNING COMPLETION @ 5000 MW: 8.7 BRINE SUPV:M.C. HEIM Running 40' x 2.8" drift on slick line, tight @ 4447', work same, no success. RIH w/completion. Date: 12/30/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/18/98 (C15) TD: 6472' PB: 6330 ' NEW WELL. MW: 8.7 BRINE SUPV:M.C. HEIM Run completion w/ESP cable. N/D BOPE. N/U tree and test to 5000%, OK. Freeze protect well. Release rig @ 2230 hrs. 11/18/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(1D-131(W4-6)) .. WELL JOB SCOPE JOB NUMBER 1 D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/15/98 PERFORATE "A2" INTERVAL 'DAy OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I NOJ NO SWS-STEPHENSON SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE AK9653 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 50 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY RAN 2-1/8" ENERJET PERF ASSEMBLY ( 20' GUN/BH/4 SPF/0 DEG/O DEG ORIENT) TIE IN GUN DID NOT FIRE.POH CHANGED TOOL RIH TOOL STOPPING AT 4352', POH. ADD MORE WEIGHT,RIH PERFORATED 7-5/8" CASING F/6088' - 6068' RKB. #2 RUN PERFORATED F/6068'- 6050' RKB. ALL SHOTS FIRED TOTAL (36'). [Perf] TIME 08:00 LOG ENTRY MIRU SWS (STEPHENSON AND CREW) TGSM WORKING HIGH PRESSURE. PRESSURE TEST CASING TO 3000 PSI, 15 MIN, GOOD. MU 2-1/8" ENERJET PERF ASSEMBLY (20' GUN/SAFE/MPD/FLEX JT/PGGT/WT/SWIVEL/HEAD) TL-- 44'. PT LUB TO 3000 PSI,OK. RIH. TIE IN W/SPERRY SUN MWD LOG DATED 7/10/98. ATTEMPT TO PERFORATE, GUN DID NOT FIRE. POH. 10:00 12:00 AT SURFACE RD. CHANGED ASSEMBLY, MU (18' GUN/SAFE/MPD/CCL/WT/ROLLER/SWIVEL/HEAD) TL= 38'. RIH. UNABLE TO GET PAST 4352' RKB STOPPING AT A COLLAR. 14:00 POH. ADD WT BAR TO SAME ASSEMBLY, TL= 44'. RIH TIE IN AND PERFORATE 7-5/8" CASING (18') FROM 6086' TO 6068' RKB. GOOD SURFACE INDICATIONS. POH. 15:30 16:00 AT SURFACE RD. ALL SHOTS FIRED. MU #2 PERF ASSEMBLY, (18' GUN/SAFE/MPD/CCL/WT/ROLLER/ WT/SWIVEL/HEAD) TL=44'. RIH. TIE IN AND PERFORATE 7-5/8" CASING FROM 6068' TO 6050' RKB. HAD GOOD SURFACE INDICATIONS. POH. 18:30 AT SURFACE RD. ALL SHOTS FIRED. LEAVE WELL SHUT IN FOR FRAC. NOTIFIED DSO. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~Y K1(1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/17/98 A SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI NO DS-GALLEGOS JORDAN FIELD AFC# CC# Signed ESTIMATE AK9653 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 96 PSI 600 PSI 0 PSI 600 PSI 0 PSII 0 PSI DAILY SUMMARY A SAND FRAC SCREENED OUT EARLY WITH 20 PPA PROPPANT AT PERFS DURING 7 PPA STAGE DUE TO OPERATIONAL PROBLEM WITH BLENDER. 51,336 LB PROPPANT PUMPED WITH 37,715 LB PLACED IN FORMATION. 10,544 LB PROPPANT REVERSED OUT WITH 3077 LB PROPPANT LEFT IN CASING. MAX TREATING PRESSURE 5245 PSI. TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT - GALLAGOS; APC; HES. TGSM. PT SURFACE LINES 7000 PSI OK. 10:00 LOAD BACKSIDE WITH DIESEL. CIRCULATE 113 BBL DIESEL DOWN CASING TAKING RETURNS TO TANK THROUGH TUBING. 10:25 PUMP HIGH RATE BREAKDOWN WITH SW. PULSE TEST AT SHUTDOWN. PC 2258 PSI. 10:45 PUMP DATA FRAC WITH 50# HEC GEL. SD ISIP 1200 (ANN) WITH PC 2370 PSI.PUMP SCHEDULE CHANGED BY ONSITE ENGINEER. 12:19 STARTED PUMPING PAD, 15 BPM, 1223 PSI. 12:32 STARTED PUMPING PROPPANT- 2PPA WITH RAMP TO 7PPA. 12:48 OPERATIONAL PROBLEM WITH BLENDER RESULTED IN 20 PPA SPIKE IN PROPPANT DURING 7PPA STAGE. START 10 PPA RAMP EARLY TO TRY AND FINSIH JOB IF WELL TOOK SPIKE. 12:54 FRAC SCREENED OUT EARLY WITH 20 PPA PROPPANT AT PERFS. 51,336 LB PROPPANT PUMPED WITH 37,715 LB PLACED IN FORMATION. 10,544 LB PROPPANT REVERSED OUT WITH 3077 LB PROPPANT LEFT IN CASING. MAX TREATING PRESSURE 5245 PSI. 15:00 RD DS FRAC UNIT. TUBING AND CASING DISPLACED WITH DIESEL. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1 (1D-131 (W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/19/98 REFRAC A2 SAND DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 NO NO DS-YOKUM JONES FIELD AFC# CC# Signed ESTI MATE AK9653 18WST F7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 250 PSI 0 PSI 370 PSI 370 PSII 400 PSI 400 PSI DALLY SUMMARY DISPLACED A TOTAL OF 10,223 LBS 16/20 PROP IN PERFS W/HRS PROP LOC. DURING 7 PPG STAGE PROP RATE WENT TO 19 PPG. STOPPED PUMPING & REV TBG CLEAN W/DIESEL. ATTEMPT TO DISPLACE PROP BELOW TBG TAIL INTO PERFS, UNABLE TO GET RATE ABOVE 1 BPM @ 4000 PSI, PUMPED 8 BBLS. [Frac-Refrac] TIME LOG ENTRY 07:00 MIRU DS 08:00 TGSM - MUSTER BEHIND FRAC TANKS - RIG ON LOCATION 08:15 PUMP 5 BBLS DIESEL DOWN BACKSIDE W/HOT OIL TO ASSURE IT WAS FREE TO PUMP 09:00 HIGH RATE BREAKDOWN - 30 BPM - 122 BBLS- STRAIGHT WATER - 11.3 MIN CLOSURE 09:25 DATAFRAC STRAIGHT WATER 15 BPM - 150 BBLS W/STEP RATE TEST TO 9 BPM AND 5 BPM 10:27 STAGE 4 AND 5 DATA FRAC AND FLUSH 15 BPM HEC AND WATER FLUSH - 870 ISIP. WAIT FOR FRAC TO CLOSE & DESIGN MAIN FRAC. 14:30 PUMPED 25 BBLS 50# PAD, 70 BBLS 2 PPG, 50 BBLS 4.5 PPG RAMP. 47 BBLS INTO THE 7 PPG STAGE, THE PROP RATE WENT TO 19 PPG. PUMPED @ 15 BPM, 1830 PSI AVERAGE. PLACED A TOTAL OF 10,223 LBS 16/20 PROP W/HRS PROP LOC IN PERFS. PUMPED TOTAL OF 26,088 LBS PROP. 14:45 STOPPED PUMPING, REV TBG CLEAN W/DIESEL. ATTEMPT TO FLUSH PROP BELOW TBG TAIL INTO PERFS, UNABLE TO GET ABOVE 1 BPM @ 4000 PSI, PUMPED 8 BBLS DOWN TBG. 15:15 DS START RIG DOWN - ALL TREE SAVER RUBBERS RETURNED 17:30 OFF WELL - INFORMED DSO OF WELL STATUS - UNSURE OF EXACTLY HOW MUCH PROP IN THE CASING BECAUSE OF REVERSE OUT AFTER THE SHUTDOWN ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/21/98 REFRAC A2 SAND DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 6 YES NO DS-YOKUM KRALICK FIELD AFC# CC# Signed ESTIMATE AK9653 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 365 PSI 400 PSI 425 PSI 850 PSII 0 PSI 0 PSI DAILY SUMMARY SCREENOUT W/6.9 PPG 16/20 CARBOLITE W/PROP LOC AT PERFS - 47,615# BEHIND PIPE W/14,000# IN PIPE - REVERSE J OUT W/130 BBLS DIESEL- 95,500# PROP BEHIND PIPE TOTAL AFTER 3 FRACS[Frac-Refrac] I TIME LOG ENTRY 06:00 MIRU DS/LRS/HALLIBURTON 08:00 08:30 09:00 P/T HARD LINE TO TREE SAVER TO 7000 PSI - TGSM ( RIG AND APC INFORMED) HIGH RATE BREAKDOWN 150 BBLS 30 BPM SW W/STEP DOWN TEST AT THE END OF 'THE STAGE DATA FRAC 15 BPM HEC 150 BBLS - PUMP PULSES AND WAIT ON CLOSURE - CHANGE TO 100 BBLS PAD - ISIP 1197 PSI (BACKSIDE) - CLOSURE 2369 PSI (BOTTOM HOLE) W/.66 FRAC GRADIENT START FRAC W/50#HEC AND 150 BBL PAD 13:00 13:20 START 2 PPA 16/20 PROP AND RAMP STAGES W/HEC @ 15 BPM - 80 BBLS 13:30 CONTINUE RAMP @ 15 BPM - 300 BBLS 4.5 PPG 13:45 CONTINUE RAMP @ 15 BPM -40 BBLS - PRESSURE INCREASE - FLUSH - PERF SCREENOUT W/6.7# PROP @ PERFS - 47615# IN PERFS/14,0244f IN PIPE/61639# TOTAL PUMPED 14:00 REVERSE OUT W/130 BBLS DIESEL- 600 PSI BACKPRESSURE 15:00 CLEAN OUT PUMPS AND LINES 15:30 PULL TREE SAVER - RDMO DS - INFORMED OPERATOR OF WELL STATUS ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ,~r K1(1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/24/98 PERF A4 SANDS FOR FRAC 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 9 YESI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTI MATE AK9653 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 300 PSI 330 PSI 300 PSI 330 PSII 0 PSI 0 PSI DAILY SUMMARY SWS PERFED A4 SANDS IN 2 RUNS USING 2 1/8" ENERJET, BH, 4 SPF, 0 PHASED, DOWN FROM 5938' TO 5978' USING 450 PSI I WHP.[Perf] I TIME LOG ENTRY 13:45 SWS MIRU, HELD TGSM. ARMED SAFE GUN & PT LUB TO 3000#. 14:45 MIH W/20'- 2 1/8" EJ, BH, 4 SPF, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, ROLLER, HEAD. CORR TO SWS PERF JEWERLY LOG 8-15-98. PERFED FROM 5958' TO 5978' USING 450 PSI WHP. 16:00 POH & LD GUN, ALL SHOTS FIRED. 16:45 MU SAFE GUN & PT LUB TO 3000#. MIH W/20' EJ GUN AS ABOVE, CORR TO ABOVE LOG & PERF FROM 5938' TO 5958' USING 450 PSI WHP. 17:30 POH & LD GUN, ALL SHOTS FIRED. 18:15 RIG DOWN. 19:00 RELEASE SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~ K1 (1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/25/98 FRAC A3/4 SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 10 YESJ YES DS-YOKUM JONES FIELD AFC# CC# Signed ESTIMATE AK9653 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSIII0 PSI 0 PSI DALLY SUMMARY I FRAC A3/4 ZONE. PLACED 80,343 LBS PROPPANT IN PERFS. 3866 LBS PROPPANT LEFT IN PIPE.[Frac-Refrac] LOG ENTRY TIME 06:00 MIRU DS/LRS/HALLIBURTON 09:20 50# HEC GEL 15 BPM 65 BBL ISIP 792 PSI W/STEP RATE TEST- PUMP PULSES 08:30 TGSM - MUSTER BEHIND FRAC TANKS - RIG ON LOCATION - PERF UNIT ON LOCATION 08:40 P/T HARD LINE TO 5780 PSI 08:50 BEGIN HIGH RATE BREAKDOWN 30 BPM - 100 BBLS - 650 ISIP (TBG) - PUMP PULSES DATA FRAC WATER 15 BPM 150 BBLS 1550 PSI TREATING PRESSURE 09:05 10:05 PUMP DATAFRAC 50# HEC GEL @ 15 BPM 35 BBLS AND FLUSH 70 BBLS WATER - 828 PSI ISIP. 10:20 WATCH FOR FRAC CLOSURE. FIGURE MAIN FRAC. 13:00 PUMPED AT 15 BPM, MAX TP 5076 PSI, AVERAGE TP 1900 PSI. PUMPED 130 BBLS 50# GEL PAD, 14 BBLS 2 PPG, 350 BBLS 2 - 7 PPG RAMP, 52 BBLS 7 PPG, 15 BBLS 7 - 10 PPG RAMP, 40 BBLS 10 PPG. FLUSH W/5 BBLS WATER & 46 BBLS DIESEL. TIP SCREEN OUT W/4 BBLS LEFT IN FLUSH. TOTAL 16/20 PROP IN PERFS 80353. 13:40 REV TBG CLEAN W/DIESEL. 14:00 RIG DOWN. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT '~' K1(1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/27/98 PERFORATE B SANDS 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 11 YESI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE AK9653 18WSTFTSC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 380 PSI 390 PSI 380 PSI 390 PSI 0 PSII 0 PSI DAILY SUMMARY SWS RAN CCL LOG TOOLS, UNABLE TO GET BELOW 3000'. RIH & PERFORATED B SANDS FROM 5894' TO 5914' W/2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN. TAGGED SAND @ 5926' = 12' ABOVE A4 SAND PERFS.[Perf] TIME LOG ENTRY 22:30 SWS MIRU, HELD TGSM. MU TOOLS & PT LUB TO 3000#. 00:15 MIH W/1 11/16" CCL, 2 1/8" WB, ROLLER, HEAD. UNABLE TO GET BELOW 3000'. 01:15 POH & LD TOOLS. 02:00 MU SAFE GUN & PT LUB TO 3000#. 02:45 MIH W/20' - 2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, ROLLER, HEAD. CORR TO SWS GR/CCL LOG 8-15-98. PERF FROM 5894' TO 5914'. TAG SAND TOP @ 5926' -- 12' ABOVE A4 SAND PERFS. 04:15 POH & LD GUN, ALL SHOTS FIRED. 05:00 RIG DOWN. 05:30 RELEASE SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~" K1(1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/28/98 1 D-131 B SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 12 YESI YES DS-YOKUM JORDAN FIELD AFC# CC# Signed ESTIMATE AK9653 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 310 PSI 500 PSI 392 PSI 500 PSII 0 PSII 0 PSI DALLY SUMMARY PUMPED B SAND FRAC AS DESIGNED. FRAC SCREENED OUT AT 40 BBL INTO 53 BBL FLUSH STAGE.77,273 LBS PROPPANT PLACED IN PERFS. 1,952 LBS PROPPANT LEFT IN PIPE. TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT - YOKUM; LRS; APC. TGSM. PT LINES TO 7200 PSI. 07:40 PUMP HIGH RATE BREAKDOWN. SD ISIP 820 PSI. PUMP WATER DATAFRAC ISIP 846 PSI.PUMP GEL DATAFRAC. ISIP 884 PSI. MAX TREATING PRESSURE 5163 PSI. 09:52 PUMP BREAKDOWN AND SCOUR STAGE. SD ISIP 950 PSI. SB FOR ENGINEERING ANALYSIS.SB FOR HES. 16:54 PUMP B SAND FRAC AS DESIGNED. FRAC SCREENED OUT 40 BBL INTO 53 BBL FLUSH STAGE.77,273 LBS TOTAL PROPPANT PLACED IN PERFS. 4,766 LBS PROPPANT LEFT IN WELLBOREWITH 2774 LBS REVERSED OUT. ESTIMATED TOP OF FILL 5855'. 19:00 RD DS FRAC UNIT. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~, K1(1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/30/98 PERFORATE D SANDS 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 14 YESI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE AK9653 18WSTFTSC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 200 PSI 300 PSI 200 PSI 300 PSI 0 PSII 0 PSI DAILY SUMMARY ISWS PERFORATED D SANDS FROM 5832' TO 5860' W/2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN. TAGGED SAND @ 5874', GOOD.[Perf] TIME LOG ENTRY 13:15 SWS MIRU, HELD TGSM. MU SAFE GUN & PT LUB TO 3000#. 16:00 MIH W/28' - 2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL, SWIVEL, ROLLER. CORR TO SWS GR/CCL LOG 8-15-98 & PERFED D SANDS FROM 5832' TO 5860'. TAGGED SAND @ 5874', GOOD. 17:15 POH & LD GUN, ALL SHOTS FIRED. 18:00 RIG DOWN. 18:30 RELEASED SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1(1D-131(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-131 FRAC, FRAC SUPPORT 0813981038.1 DATE DAILY WORK UNIT NUMBER 08/31/98 1D-131 D SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 15 YESI YES DS-YOKUM JORDAN i:IELD AFC# CC# Signed ESTI MATE AK9653 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 417 PSI 2445 PSI 384 PSI 1399 PSII 0 PSII 0 PSI DALLY SUMMARY SAND FRAC. PLACED 77,500 LB PROP IN PERFS WITH 844 LBS PROP LEFT IN PIPE. MAX TREATING PRESSURE 4932 PSI. I TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT - YOKUM; LRS; HES; APC. TGSM-19 ON LOCATION. PT LINES TO 6700 PSI. 07:45 PUMP BREAKDOWN STAGE 30 BPM, MAX 4932 PSI. SD ISIP 834 PSI. 09:00 PUMP SW DATAFRAC 15 BPM, 2347 PSI. SD ISIP 856 PSI. 10:07 PUMP 50# HES DATAFRAC 15 BPM, 2440 PSi. SD ISIP 861 PSI. 10:14 PPUMP BREAKDOWN/SCOUR STAGE 15 BPM, 2004 PSI. SD ISIP 950 PSI. 11:51 PUMP D SAND FRAC AS DESIGNED THROUGH 8.5 PPA. 15 BPM, 1400 PSI. 12:23 ALL PROPPANT ON LOCATION PUMPED, INITIATE FLUSH STAGE. 12:26 SD. PLACED 77,500 LB PROP IN PERFS WITH 844 LBS PROP LEFT IN PIPE. MAX TREATING PRESSURE 4932 PSI DURING BREAKDOWN. REVERSED OUT TUBING WITH DIESEL.NOTIFY WELL MAINT TO INSTALL BPV. 14:00 RDMO DS FRAC UNIT. WELL HANDOVER TO CPF-1 SUPV. Kuparuk Unit Kuparuk 1D 1D. 131 SURVEY REPORT i7 August, 1998 Your Reft API.500292289100 Last Survey Date 1 l-July~98 Job# AKMM80277 KBE- 112.00' ORIGINAL RECEIVED DRILLING SERVICES Survey Ref: svy48 Sperry-Sun Drilling Services Survey Report for '!D.'131 Your Ref: API.500292289100 I ' Kuparuk Unit Measured Depth Incl. Azim. 0.00 0.000 0.000 121.00 0.000 0.000 186.00 0.750 259.000 290.57 4.950 254.530 379.12 8.000 236,070 469.52 13.120 228.920 560.64 20.080 218.730 649.43 27.090 216,810 743.75 32.530 216.140 833.29 38.380 215.910 925.24 42.980 216.850 1015.40 48.520 216.330 1106.52 53.260 216.010 1197.18 55.540 215.420 1287.69 57.990 214.190 1378.97 61.290 213.090 1650.73 62.200 214.640 1839.48 64.660 211.190 2122.75 65.050 212.090 2408.07 65.770 212.090 2503.11 63.640 211.570 2786.54 64.260 212.330 3070.04 64.200 211.910 3353.84 64.180 211.580 3635,57 65.090 211.390 3919.50 64.120 212.330 4202.14 66.940 213.320 4389.24 67.700 213.110 4486.40 65.700 212.740 4580.78 62.270 213.130 Sub-Sea Depth (fi) -112.00 9.00 74.00 178.42 266.40 355.24 442.53 523.85 605.66 678.57 748.28 811.17 868.63 921.40 971.01 1017.14 1145.79 1230,23 1350.60 1469.33 1509.93 1634.40 1757.66 1881.22 2001.91 2123.67 2240.74 2312.88 2351.31 2392.70 Ve~ical Depth (fi) 0.00 121.00 186.00 290,42 378.40 467.24 554.53 635.85 717.66 790.57 860.28 923.17 980.63 1033.40 1083.01 1129.14 1257.79 1342.23 1462.60 1581.33 1621.93 1746.40 1869.66 1993.22 2113.91 2235.67 2352.74 2424.88 2463.31 2504.70 Local Coordinates Nothings (fi) 0.00 N 0.00 N 0.08 S 1.42 S 5.88 S 16.14 S 35.16 S 63.27 S 100.98 S 142.97 S 191.20 S 243.04 S 300.10 S 359.95 S 422.11S 487.68 S 686.43 S 828.14 S 1046.45 S 1266.25 S 1339.25 S 1555.30 S 1771.53 S 1988.80 S 2205.89 S 2423.74 S 2639,88 S 2784.30 S 2859.20 S 2930.38 S Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/100~) (~) 0.00E 5959244.05N 560490.74 E 0.00 0.00E 5959244.05N 560490.74E 0.000 0.00 0.42W 5959243.97N 560490.32E 1.154 0.30 5.44W 5959242.59 N 560485.31E 4.019 4.18 14.24W 5959238.06 N 560476.55 E 4.128 12.76 27.20W 5959227.70 N 560463.67 E 5.836 28.47 44.81W 5959208.53 N 560446.22 E 8.252 54.05 66.48W 5959180.24 N 560424.77 E 7.941 89.45 94.33W 5959142.32 N 560397.23 E 5.778 136.26 124.86W 5959100.08 N 560367.04 E 6.535 188.13 160.42W 5959051.57 N 560331.87 E 5.047 247,97 198.89W 5958999.42 N 560293.82 E 6.158 312.43 240.60W 5958942.02 N 560252.57 E 5.209 383.04 283.62W 5958881.83 N 560210.03 E 2.570 456.69 326.82W 5958819.32 N 560167.33 E 2.936 532.37 370.43W 5958753.40 N 560124.25 E 3.762 611.12 503.83W 5958553.58 N 559992.45 E 0.604 850.48 595.49W 5958411.14 N 559901.94 E 2.091 1019.24 730.01W 5958191.76 N 559769.18 E 0.319 1275.53 867.83W 5957970.86 N 559633.13 E 0.252 1534.89 913.15W 5957897.49 N 559588.40 E 2.295 1620.78 1047.90W 5957680.36 N 559455.39 E 0.325 1875.32 1183.65W 5957463.05 N 559321.39 E 0.135 2130.55 1318.07W 5957244.71N 559188.72 E 0.105 2385.92 1451.02W 5957026.55 N 559057.52 E 0.329 2640.33 1586.40W 5956807.62 N 558923.90 E 0.454 2896.72 1725.86W 5956590.37 N 558786.19 E 1,047 3153.92 1820.42W 5956445.18 N 558692.79 E 0.419 3326,55 1868.92W 5956369.90 N 558644.89 E 2.088 3415.78 1915.03W 5956298,35 N 558599.36 E 3.653 3500.58 Comment Kuparuk 1D Continued... 17August, 1998 - 8:59 - 2- DH#Quest Sperry-Sun Drilling Services Survey Report for 1D-131 Your Ref: API-500292289100 Kuparuk Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth Nothings (~) (fi) (fi) (fi) 4674.10 57.640 213.630 2439.41 2551.41 2997.82 S 4770.00 53.100 214.350 2493.90 2605.90 3063.24 S 4864.04 48.610 214.730 2553.25 2665,25 3123.30 S 4960.20 44.050 214.940 2619.63 2731.63 3180.38 S 5055.70 39.800 215.230 2690.67 2802.67 3232.59 S 5151.46 36.050 215.350 2766.19 2878.19 3280.62 S 5247.28 31,970 215.500 2845.60 2957.60 3324.29 S 5342.07 27,610 216.040 2927,85 3039.85 3362.50 S 5436.30 23.050 215.650 3012.99 3124.99 3395.16 S 5530.13 18.530 215.770 3100.69 3212.69 3422.20 S 5625.82 15.580 214.700 3192.16 3304.16 3445,11S 5814.06 14.900 214.910 3373.78 3485,78 3485.74 S 5909.14 14.630 214.030 3465.72 3577.72 3505.71 S 6003.87 14.220 213.740 3557.47 3669.47 3525.30 S 6098.14 14.020 214.010 3648.89 3760.89 3544.40 S 6193.78 13.760 213.500 3741.73 3853.73 3563.48 S 6287.69 13.530 212.390 3832.99 3944.99 3582.07 S 6405.64 13.270 212.290 3947.73 4059.73 3605.17 S 6472.00 13.270 212.290 4012.32 4124.32 3618,04S Local Coordinates Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (~) (fi) (fi) (°/100~) (~) 1959.45W 5956230.55N 558555.48E 4.983 3581.34 2003.54W 5956164.78N 558511.92E 4.774 3660.22 2044.88W 5956104.39 N 558471.07 E 4.785 3733.12 2084.59W 5956046,99 N 558431.81E 4.745 3802.64 2121.26W 5955994.49 N 558395.57 E 4.455 3866.41 2155.25W 5955946.19 N 558361.97 E 3.917 3925.23 2186.31W 5955902.27 N 558331.26 E 4.259 3978.78 2213.82W 5955863.84N 558304.06 E 4.608 4025.83 2237.43W 5955830.99 N 558280.72 E 4.842 4066.10 2256.86W 5955803.79 N 558261.50 E 4.817 4099.37 2273.07W 5955780.76 N 558245.48 E 3.100 4127.42 2301,31W 5955739.90 N 558217.57 E 0,362 4176.88 2315.02W 5955719.82 N 558204.01E 0.369' 4201.11 2328.18W 5955700.12 N 558191.01E 0.439 4224.71 2341.00W 5955680.92 N 558178.35 E 0.223 4247.71 2353.76W 5955661.73 N 558165.75 E 0.300 4270.66 2365.80W 5955643.05 N 558153.85 E 0.371 4292.82 2380.43W 5955619.84 N 558139.41E 0.221 4320.15 2388.56W 5955606.90 N 558131.38 E 0.000 4335.37 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to ?[~'&ll. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 213.490° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6472.00ft., The Bottom Hole Displacement is 4335.38ft., in the Direction of 213.432° (True). Comment Projected Survey Kuparuk 1D Continued... 17 August, 1998 - 8:59 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-131 Your Ref: AP1-500292289100 Kuparuk Unit Kuparuk 1D Comments Measured Depth 0.00 6472.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4124.32 3618.04 S 2388.56 W Comment Tie-on Survey Projected Survey 17 August, 1998 - 8:59 - 4 - DrillQuest MEMORANDUM State of Alaska TO: Alaska Oil and Gas Conservation Commission _ David John~ DATE: July 8,1998 Chairman THRU: Blair Wondzell, ~ P. I. Supervisor4 7/ FROM' Larry Wade, ~1¢//'~I¢/' SUBJECT: Petroleum Inspector FILE NO: .DOC Diverter Test Parker 245 ARCO KRU 1 D-131 PTD 98-110 July 8,1998: I drove to Kuparuks 1D-pad to witness a diverter test on a West Sak well 1D-131. The test went well and the pad and rig were in an orderly fashion, even with all the construction going on. The rig hands were experienced and helpful which expedited the test. SUMMARY: Witnessed a diverter function test on Parker 245, 0 failures, 1 hr. Attachments: eaxgghfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Development Drlg Contractor: Parker Rig No. 245 PTD # Operator: ARCO Oper. Rep.: Dink Helm Well Name: 1D-131 Rig Rep.: John Crisp Location: Sec. 23 T. 11N R. 10E Merdian Umiat Date: X Exploratory: 98-110 Rig Ph. # 7/8/98 MISC. INSPECTIONS: Location Gen.: ok Well Sign: X Housekeeping: ok (Gen.) Drlg. Rig: ok Reserve Pit: n/a Flare Pit: n/a DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: 16 Valve(s) Auto & Simultaneous: X Vent Line(s) Size: 16 Vent Line(s) Length: Line(s) Bifurcated: n/a Line(s) Down Wind: X Line(s) Anchored: X Turns Targeted / Long Radius: n/a in. Jin. 90' -' ft. ACCUMULATOR SYSTEM: Systems Pressure: 3000 psig Pressure After Closure: 1500 psig 200 psi Attained After Closure: min. 30 sec. Systems Pressure Attained: 2 min. 55 sec. Nitrogen Bottles: 1800, 2200, 2200, 2200, 2175, 1900 psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: X X Mud Pits: X X Flow Monitor: X X GAS DETECTORS: Light Alarm Methane X X Hydrogen Sulfide: × X North ! I Rig ~rection Non Compliance Items Remarks: Repair Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c- Inspector AOGCC REP.' Larry Wade OPERATOR REP.: Dink Helm OVTRINSP.XLT (REV. 1/28/97) L.G. eaxgghfe.xls Report prepared 7/10/98 c,~ot~ ~). f~h For: M1ROCK~AY Dote plotted: 28-~y-98 ~ P~e[ Reference is ~ 10-151/L3 Ve~. ~5. I C~o~d~nates ere ~n (eet re~e~ence slot ~tSl. J RCO Alaska, Inc. Structure: Pad 1D Well: 151 Field : Kuparuk River Unit Location : North Slope, Alas 560 600 640 <- West (feet) 760 720 680 640 600 560 520 480 440 400 360 520 280 24C~/ 200 160 120 200 , I , , I , , , I I I I I I I I I ^1 I I I ~1 , , , , 200 -IDO0 //' /' 240 ./ /' . 240 /(200 // // 320 /q 200 / ' 320 /' / ' 1100 / /' 600 ' 360 /~ .// 1 O0 / /, / 360 ./~ 30O 1800 4oo 1200 1700 .' 40o 440 ,, ~' 1200 440 .~,"~ 300 ." / '" " " / 480 480 / /' ,, / //1 400 . 520 ,/~ -' " " /, / 1200 ; ,../ /' / K'~ ,' ~' ~ 300 / 2100 / / 1400 / / ~000 ,," / / / / 2200 ,,' / / 680 / 680 // O0 ,/1300 .. 1 / / 720 1500 ,,, ~ 14-00 720 '" / 760 760 ,' 22OO " / / / / " / 800 800 ,, !400 ,, / / 840 2500 ,," / 840 .' ~ 1500 400 880 2500 /'1 ! 880 / / / / / / / 920 ,' ; 920 // / / I I I I I I I I ] I I I I I I I I I I I I I I I I I I I I 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 160 120 <- West (feet) 520 0 560 600 640 ] v c,~of~. W ~h For: BROCI~¥AY Dote plotted: 28-Yoy-gfl Plot Reference ;s Co.al[notes ore ~n feet reference slot ~151. ~e Verdcol Oept~s ore reference ~8 (Pork~ ~24~). 6OO 800 lO0O 12o0 1400 1600 1800 2O00 2200 "+-- 2400 2600 aska, Iric. JStructure : Pad 1D Well: 151 J Field : Kuparuk River Unit Location : North Slope, Ale J 2800 3000 5200 5400 3600 3800 4000 4200 4400 <- West (feet) 2,400 5200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 I I I I I I I I I I I I I I I I I I I I I I t I I I I I I 2300.,,-- ...... .-~"1'~00 1500.,"/" 2500~-'" .-"' /'?'1700 ' ' ,'5" 1700, 2700.~ ....... . ....... .'? 2900.., ...... - ..... '21 O0 1700,,,'~" 31oo.. .... ..--'" ":::"' 5300~-"' .--" .;::~'{ 900 1900 37oo..--' ....-%oo ./:- 3.~00 4100 .-'/" ../' " ri-~l' . ...... 1 g 00.¢;/';' 57,,00.' .... ~'~500 .'~2100 210( /'1700 ..- - - /// // --"' 5300 ,' / 230,0¢' O0 ,/ / 500 " / 1900 /.-/ ; / 250~''/'/ ;700 " / ,.';"~' 2500 ,, ,..;;,',' ,900 ,, /2100 2700,,,-';/' ,, ,-,'// 2500 !-100 ,, :, /' 2900/'//'/ ,/ / .,' 2300 31oo/.,,,' / 3300,,,,'"~,'" 2700 ,/ / :~700 5700/ ,/ ,,' / 3900 ..' /' / / 4100#./ ,./ / ¢" 2900 ~ ./"" 2900 ; ,/2500 / ,, / 31 oo / / " / 3500 /'~700 ,,,' / 3500 " / 3700 /'2900 ,, / 3900 ,/'31 O0 / 41 O0 /'3300 .~ 3500 /3700 ~ 3900 [ ' 4100 6OO ,," 800 ~?~00 ~ 1000 700 d' 1200 o 2100 1400 1900 I I I I I I I I I I I I I I I I I I II I I I I I ,3400 ,3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 <- West (feet) 1600 1800 2300 2000 2500 ! / ! ~ 35oc i ! / ! i 3700 ! ~ 3900 / ~ 41 O0 ! / ! ! ! / ~ 4300 / ! ! / 450o i i [ i i 2200 2400 2600 28OO 3000 3200 5400 3600 3800 4000 42O0 4400 0 I v ARCO Alaska, Inc. Pad 1D 131 slot #131 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref ~ WS 1D-131/L3 Vets. #3 Our ref ~ prop2191 License ~ Date printed : 28-May-98 Date created ~ 16-Apr-97 Last revised = 27-May-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 57.175,w149 30 36.399 Slot Grid coordinates are N 5959243.707, E 560490.383 Slot local coordinates are 421.00 S 600.00 W Projection ty~e: alaska - Zone 4, Spheroids Clarke - 1866 Reference North is True North Report is llmited to clearances less than 500 feet' DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0 - 7340'>,,10,Pad 1D PMSS <556-7024'>,,9,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <0-8610'>,,6,Pad iD PGMS <O-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <O-9783'>,,2,Pad 1D PG~MS <0-8365'),,1,Pad 1D 1DoD Version #2,,1D-D,Pad iD 1D-F Version #2,,1D-F,Pad iD 1D-B Version #3,,1D-B,Pad 1D TOTCO Suz-vey,,WS-8,Pad 1D PMSS <0-5462'),,J3,Pad 1D WS 1D-127/L1 Vets #3,,127,Pad 1D WS 1D-128/K2 Vets #3,,128,Pad 1D WS 1D-126/J1 Vets #5,,126,Pad 1D WS 1D-132/K4 Vets #3,,132,Pad 1D WS 1D-134/L5 Vets #3,,134,Pad 1D WS 1D-110/C3 Vets #3,,110,Pad 1D WS 1D-125/H2 Vets, #3,,125,Pad 1D WS 1D-123/G1 Vets. #3,,123,Pad 1D WS 1D-122/F2 Vets. #3,,122,Pad 1D WS 1D-116/E1 Vets. #3,,ll6,Pad 1D WS 1D-114/D2 Vets. #3,,ll4,Pad 1D Closest approach with 3-D Last revised 2S-Apr-98 29-Apr-98 6-Nov-97 13-Nov-97 13-Nov-97 4-Aug-92 4-Aug-92 4-Aug-92 10-Dec-97 24-Nov-97 24-Nov-97 24-Nov-97 21-May-g8 1-Dec-97 27-Ma¥-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 Distance 131.0 285.0 52.9 57.2 177.5 297.7 418.1 537.9 658.0 73.0 43.2 43.0 127.7 30.0 105 0 9O 0 120 0 15 0 76 9 463 0 133 0 207.9 223.0 343.0 3?3.0 Minimum Distance M.D. Diverging 600 0 100 0 580 0 333 3 291 7 333 3 0 0 333 3 333 3 291 7 500 0 291 7 820 0 100 0 250 0 250 0 250 0 200 0 660 0 291 7 291 7 333 3 291 7 291 7 270 8 method from M.D. 600.0 100.0 6498.3 333.3 291.7 333.3 333.3 333.3 333.3 291.7 500.0 6498.3 820.0 940.0 250.0 250.0 250.0 6380.0 660.0 291.7 291.7 333.3 291.7 291.7 270.8 WS 1D-113/C1 Vets. #3,,113,~d 1D WS 1D-112/A1 Vets. #3,,ll2,Pad 1D WS 1D-Iii/B2 Vets. #3,,ill,Pad 1D WS 1D-136/J7 Vets. #1,,136,Pad 1D PMSS <0-4414 >,,GS,Pad 1D PMSS <0-4530 >,,F6,Pad 1D PMSS <0-4515 >,,F4,Pad 1D PMSS <0~4590 > PMSS <0-5142 > PMSS <0-5205 > PMSS <0-5047'> PMSS <0-4850'> PMSS <0-5126'> PMSS <381-6092' WS 1D-158 WS 1D-141 WS 1D-142 WS 1D-140 WS 1D-139 WS 1D-143 WS 1D-144 WS 1D-145 WS 1D-146 WS 1D-147 WS 1D-148 WS 1D-149 WS 1D-152 WS 1D-150 WS 1D-153 WS 1D-154 WS 1D-155 WS 1D-156 WS 1D-157 WS 1D-159 ,E5,Pad 1D ,E3,Pad 1D ,E7,Pad 1D ,G3,Pad 1D ,D4,Pad 1D ,D6,Pad iD ,,C7,Pad 1D 'Lll Vets. #1,,158,Pad 1D 'All Vets. #1,,141,Pad 1D 'B10 Vets. #1,,142,Pad 1D 'A9 Vets. #1,,140,Pad 1D 'B8 Vets. #1,,139,Pad 1D 'C9 Vets. #1,,143,Pad 1D /DS Vets. #l,,144,Pad 1D /Cll Vets. #1,,145,Pad 1D /D10 Vets. #1,,146,Pad 1D /E9 Vets. #l,,147,Pad 1D /Ell Vets. #1,,148,Pad 1D /F8 Vets. #1,,149,Pad 1D /G9 Vets. #1,,152,Pad 1D /Fl0 Vets. #1,,150,Pad 1D /H10 Vets. #1,,153,Pad 1D /Jll Vets. #1,,154,Pad 1D /H8 Vets. #1,,155,Pad 1D /J9 Vets. #1,,156,Pad 1D /K10 Vets. #1,,157,Pad 1D /L9 Vets. #1,,159,Pad 1D WS 1D-160?K8 Vets. #1,,160,Pad 1D WS 1D-161/L7 Vets. #1,,161,Pad 1D WS 1D-138/K6 Vets. #1,,138,Pad 1D WS 1D-151/G11 Vets. #1,,151,P&d 1D WS 1D-107/B4 Vets. #1,,107,Pad 1D WS 1D-102/A5 Vets. #3,,102,Pad 1D WS 1D-103/B6 Vets. #3,,103,Pad 1D WS 1D-104/A7 Vets. #3,,104,Pad 1D WS 1D-108/A3 Vets. #3,,108,Pad 1D PMSS <1957-5265'>,,JS,Pad 1D WS 1D-101/C5 Vets. #3,,101, Pad 1D PMSS <O-5015'>,,GT,Pad 1D PMSS <0-4778'>,,H4,Pad 1D 27-May-98 27-May-98 27oMay-98 27-May-98 8-Dec-97 19-Dec-97 16-Dec-97 22-Dec-97 30-Dec-97 7-J~n-98 6-Jan-98 12-Jan-98 19-Jam- 98 27-Jan-98 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-A~r-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 27-May-98 27-M&y-98 27-May-98 27-M&y-98 27-M&y-98 24-Nov-97 27-May-98 13-Nov-97 9-Nov-97 388.0 403.0 448.0 99.8 240 0 255 0 270 0 314 7 360 0 330 0 150 0 480 0 525.0 554.5 231.6 209.1 201.7 217.2 226.0 195.3 189.8 185.3 182.0 179.9 179.0 179.4 187.9 181.0 192.9 199.0 206.0 213.8 222.4 241.4 251.7 262.5 151.3 183.9 508.0 598.0 583.0 568.0 493.0 26.3 613.0 84.4 15.0 291.7'--~-~ 333.3 291 7 640 0 100 0 100 0 100 0 333 3 100.0 100.0 100.0 100.0 100.0 291.7 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 440 0 250 0 291 7 291 7 291 ? 291 7 291 7 440 0 291 7 660 0 100 0 291.7 333.3 291.7 640.0 100.0 100.0 100 0 333 3 100 0 lO0 0 lO0 o lo0 0 loo 0 291 7 250 0 250 0 5880 0 5680.0 250.0 250.0 250.0 250.0 6022.2 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 440.0 250.0 291.7 291.7 291.7 291.7 291.7 440.0 291.7 660.0 100.0 Sak 1 D-131 (L3) ProduEer Well Four (4) Stage Frac-for-Sand Control with 3-1/2" Deadstring 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 Deadstdng 9.3# L-80 EUE 8RD-Mod (to frac through off-rig) 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 6498' MD / 4134' 'I'VD) A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB, 05/18/98, v. 1 West Sak 1 D-131 (L3) Producer Well Four (4) Stage Frac-for-Sand Control Completion 16" Conductor Casing @ 80' 3-1/2" Production Tubing 9.3# L-80 EUE 8RD-Mod Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centrilift Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) ESP Motor Section Centrilift D Sand Frac'd with Resin Coated Preppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 6498' MD / 4134' TVD) A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB, 05/18/98, v.2 KUPARUK RIVER UNIT - WEST SAK OPI=RATIONS 20" DiVERTER SCHEMATIC 6 I4 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVEAND 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 THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5, ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER, DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20'- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 I 8 ,7 , 6 5 13 5/8" 5000 BOP STACK West Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. ~ 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 PS! AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. MNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PS! HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. & 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 BUND RAMS AND TESTTO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSi: 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG 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 DRILMNG 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 11' - 5000 PSI HORIZONTAL TUBING HEAr_, 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 DESCRIPTION DESCRIPTION Rood C D.S. 1-D G 1 105~ 2 1 . 111 12 115 14 16 ll5 117 I1 4 119 22~ 121 125 ® 5 125~ 124 127~ 126 128 G 6 151 130 132 ® 7 6 8 14 13 25 24. II LEGEND .0 EXISTING CONDUCTORS · "AS-STAKED" CONDUCTOR LOCATION "PROPOSED" CONDUCTOR LOCATION ARCO Alaska, Inc. WEST SAK- 1 THIS SURVEY VICINITY MAP SCALE: 1" = I MILE N NO SCALE SEE SHEET # 2 FOR NOTES AND LOCATION INFORMATION .~ LOUNSBURY & ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS AREA: 1D MODULE XX DRILL SITE 1-D WEST SAK PHASE lB - WELL CONDUCTORS AS-STAKED LOCATIONS N_C:;K R_ 104.-dl 4 I SHEET: ! REV: 1 OF2 0 UNIT · D1 DESCRIPTION DESCRIPTION NO TES COORDINATES SHOWN ARE A,S.P. ZONE 4, N.A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES SHOWN ARE TRUE. 2. BASIS OF LOCA DONS AND ELEVATIONS ARE D.S. 1-D MONUMENTS PER LHD AND ASSOCIATES, J. CONDUCTORS ARE L OCA TED ~ THIN PRO TRA C TED SEC TIOIVS 14 & 23, TOWNSHIP. 11 NORTH, RANGE 10 EAST, U.M. 4. DATE OF SURVEY: 5/16/98, FIELD BK. L98-42 Pgs. 8-14. 5. DRILL SITE I-D GRID NORTH IS ROTATED 00' 0I' 05" WEST FROM ,4. S.P. ZONE 4 GRID NOR TH. ~. SEE DRA~NG NSK-3.5-t FOR AS-BUILT LOCATIONS OF CONDUCTORS 1-81 CEA-DIDX-6104DIO FOR CONDUCTORS 105,106, I09,115,117-12I, 124,129, l JO, lJJ & 1551 AND CEA-D1DX-6104DIJ FOR CONDUCTORS 9 & I0. WEST SAK-1 THIS SUR VE Y WCINITY MAP SCALE: 1" -- I MILE A.S.P.s 'Y' 'X' LA TI TUDE L ONGI TUDE ** 5, 959, 738. 9 ** 5, 959, 708. 9 ** 5, 959, 693. 9 5, 959, 648. 9 5, 959, 633. 9 5, 959, 618. 9 5, 959,588. 9 5, 959, 469. 0 5, 959, 453. 9 5,959,379.2 5, 959, 363. 9 5, 959, 348. 9 5, 959, J34. I 5, 959, 244. 0 5, 959, 229. 2 5, 959,153. 8 560, 490. 6 560, 490. 6 560, 490. 6 Sec. 14, T. 11 N., 70' 18' 02.05" 70' 18' 01. 75' 70' 18' 01.60' R. IO E. 149' 30' 36.28" 149' 30' J6.28" 149' 30' 36.29" 560, 490, 6 560, 490, 6 560, 490. 6 560, 490. 6 560, 490. 7 560, 490, 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 8 Sec. 23, T. 11 N., 70' 18' 0I. I6" 70' 18' 01.01" 70' 18' 00.87* 70' 18' 00.57" 70' 17' 59.39" 70' 17' 59.24" 70' 17' 58.5I* 70' 17' 58. J6" 70' 17' 58.21' 70" 17' 58. 06' 70' 17' 57.18" 70* I7' 57.03" 70" 17' 56.29" R. IO E. 149' 30' 36. 30" 149' 30' 36.30" 149' 30' 36. 30 * 149' 30' 36.31" 149' 30' 36.34" 149' 30' 36.34" 149' 30' 36. 36" 149' JO' 36.36" 149' 30' 36. 36" 149' 30' 36.37" 149' 30' 36.39" 149' JO' 36.39" 149' JO* 36.41" Proposed Iocotion, work in progress · ARCO Alaska, Inc. ~ k,'~lCta, nla. =~/1R/qR LOUNSBURY & ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS AREA: 1D MODULE: XX DRILL SITE 1-D WEST SAK PHASE lB - WELL CONDUCTORS AS-STAKED LOCATIONS NSK 61.1 04--d14- i SHEET: I REV: 20F2 0 UNIT: D1 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor June 2, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-131 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 ("ESPCP") 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 and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-131, such as shallow gas. There have been eight (10) Kuparuk wells and (14) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 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 June 25, 1998. 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 ~" Attachments: cc: West Sak 1D-131 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 General Procedure: Drill and Case Plan for West Sak 1D-131 (L3) Frac-for-Sand Control Producer 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' 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. . . . . . 10. 11. 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 2,000 psi for 30 minutes per AOGCC regulations. Record results. Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. Pick up 3-1/2" tubing deadstring and TIH. Circulate filtered brine to desired level. 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. 1D-131 (L3) Page I TAB,06/01/98,v1 Completion Plan for West Sak 1D-131 (L3) Frac-for-Sand Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation 1. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. 2. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Sta.qe I 3. Rig up thru-tubing perf guns for Stage I frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth. 4. Perforate Stage I overbalanced, and POOH with E-line. 5. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. . Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage I from Stage 2 to follow. Pressure test sand plug as required. 7. RIH with slickline and confirm sand top above Stage I perfs. Use CTU as required to jet sand plug top to desired PBTD. StaRe 2 8. Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. 10. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 11. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. 12. RIH with slickline and confirm sand top above Stage 2 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. 1 D-131 (L3) Page 2 TAB,O6/O1/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. Mix gel for frae job. Pressure test lines. Rig up, establish injectivity, and perform data frae 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 frae sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Deadstrin.q, Clean Out Well, Run ESP and Production Tubinq MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. Pull back pressure valve. Pull tubing hanger and circulate well to clean brine as required. TOH and lay down deadstring. Pick up rock bit and casing scraper and TIH with workstring. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. Circulate well to clean brine. TOH with workstring. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 20. 21. 22. 23. Pull 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 1 D-131 (L3) Page 3 TAB,06/01/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1 D-131 (L3) Page 4 TAB,06/01/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-131 (L3) Drillinc~ Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps I *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. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-131 (L3) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1D-131 (L3) Page I TAB,06/01/98,v. 1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, 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,$24' MD/'TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3939 ft)(0.46 - 0.11 psi/ft) = 1379 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# L80 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. Drillinq Area Risks: Drilling risks in the West Sak 1D-131 (L3) 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 ddlling of West Sak 1D-131 (L3). Well Proximity Risks: The nearest existing well to West Sak 1D-131 (L3) is WS 1D-130 (H4). As designed, the minimum distance between the two wells would be 15.0' at 100' MD. Annular Puml~inq Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-131 (L3) 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. 1 D-131 (L3) Page 2 TAB,06/01/98,v. 1 I V C,',,ot~d ~:~ r~,:h For: BROCKWAY O~t.e p[~Red: 28-M~-98 Ploi R~f~nca is ~ 1~131/L3 V~. ~3. Coord;~tes ~e in fe~ r~{r~nce slo~ ~131. T~e Vegetal OeptM are r~mence RK8 (Parker 300 0 3oo 6oo goo 12oo 1500 18oo 2100 2400 2700 3000 3300 3600 3900 4200 i 300 ARCO Alaska, Inc. Structure : Pad 1D Well : 131 Field : Kuparuk River Unit Location : North Slope, Alaska 213.49 AZIMUTH 4210' (TO TARGET) ***Plane of Proposal*** 2800 2400 2000 I I I I I <- West (feet) 1600 1200 800 I I I I I I I 400 0 I I I ESTIMATED SURFACE LOCATION: 421' FNL, 600' FEL SEC. 23, T11N, RIOE 270 Az Begin Turn to Target TARGET LOCATION: 1348' FSL, 2357' F-WL SEC. 23, T11N, RIOE Permofrost RKB ELEVATION: 112' KOP TVD=250 TMD=250 DEP=0 BEGIN TURN TO TARGET TVD=333 TMD=533 DEP=2 7.84 13.26 19.03 24.91 DLS: 6.00 deg per 100 ft 30.83 56.78 42.74 48.70 54.68 EOC TVD=1151 TMD=1367 DEP=548 MAXIMUM ANGLE 64.66 DEG TARGET TVD=3670 TMD=6022 DEP=4210 SOUTH 3511 WEST 2323 Angle Drop Sands {GET - West Sak A3 Base West Sok Sands - 7 5/8 Casing Pt B/ PERMAFROST TVD=1625 TMD=2475 DEP= 1550 TD LOCATION: I 1258' FSL, 2299' FWL SEC. 23, T11N, RIOE 400 400 0 40O 800 1200 1600 2000 2400 2800 3200 3600 4000 I V TARGET ANGLE 13 DEG BEGIN ANGLE DROP TV0=2551 TMD=4639 DEP=3506 61.62 51.62 46.62 41.62 T/ UGNU SNDS TVD=2930 TMD=5233 36.62 DLS: 5.00 deg per 100 ft 51.62 26.62 21.62 16.62 END ANGLE DROP TVD=3329 TMD=5672 DEP=4132 T/ W SAK SNDS %/0=3524 TMD=5872 DEP=4177 TARGET - A3 TVD=3670 TMD=60gg DEP=4gI0 B/ W SAK SNDS TVD=3939 TMD=6298 OEP=4272 TD - CSG PT TVD=4134 TMD=6498 DEP=4317 I I I I I 0 300 600 i i i i i i i I i Ii i I i i i i I i 900 1200 1500 1800 21 O0 2400 2700 3000 3300 3600 VerticalSection (feet)-> Azimuth 213.49 with reference 0.00 N. 0.00 E from slot ~/131 I i I i i i 5900 4200 4500 ARCO Alaska, Inc. Sfrucfure : Pod 1D Well : 1;51 Field : Kuparuk River Unif Locotion : North Slope. Alosko 4o 20 20 80 100 12o 140 115o 180 20O 220 240 260 28O 300 320 <- West (feet) 240 220 200 180 160 140 120 100 80 60 40 20 0 ./800 .. 200 1000,.-' ./'/ 900 ~500 2800 / / / ,' / / / /' .)900 ,' .- z'go0 / .. ,, / / / /'1000 / / ,. 30O ,' 11 O0 / / /800 .,' ,/ 000 800 1200 5OO 1100 ,/ ! / I I I ! / / / I ! / ~ ooo ! / / / / / ! 2O 40 6O I /, ~500 400 .//" .X1200 .-~oo 5oo~-.~13oo ...'" ~_~o"~.goo '/" ~ ~ 1 40~'''''~ 1000 .,-' /500 ,~uu~ ... .'" ~ ~ 500 ~ ",~1100 ..... ~ ', 200 / ,.,/ /" 1600 .,' ,, ~oo ,~oo\ ~oo ,-~oo /'5oo~ /' / O0 700 8~ // 900 ., #'~00 ~ / / Z 700 /500 600 ~ 1000 1300 )0 3000 250~ 1400 900 80O 700 1500 ~ 1000 2100 1600 I I [ I I r I i i [ I i i I I 24.0 220 200 18,0 160 1~0 120 100 80 60 4-0 20 <- West (feet) 6O 40 2O 20 6O 8O 1 oo 0 eS_ _q_O_. f_O.O 120 ~ "-,. 800 "' '"'"-.. 900 140 "-.%5o0 -~ ~ 60 V ".~ 600 · 180 ~oo ,,,,,.,,, "%, 700 200 220 · · ',, \~ 240 8OO % 2~0 2~0 5O0 32O i 0 20 40 6'0 O~ot.d ~ ~=~ For: BROCKWAY Oot~ p~o'~ed: 28-Moy-g8 Ca~d{nal~ era in feet reference ~ot ~1~1. r~e Ve~ical Oep~s are r~ence ~8 (Pomer ~2+~). ARCO Alaska, Inc. Structure : Pad 1g Well : 151 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 760 720 680 640 600 560 520 480 440 4-00 360 ,320 280 240~ 200 160 120 200 I I I I I I I I I I I I I I I I I~ I I I ~ I 200 ~,.-1 //' /' 14-00 240 ..///' 'f/2/' 240 · #' O0 280 /' /' 1100 320 - ..-'t'~00 .//" 360 .//"/ //'//' / //' .-'l'.~ 00 1800 / /' 1200 1700 / 400 ' /' .- /' 440 ./ /. / / / ; · /'Goo .-'" ," 480 ." / " ,/ //' · ,/ . ,/ ,.,-" ,,-'(~oo /, 520 I~ "' 2000, ~/1 200 '+- 560 .,' ' '"-- 21 O0 ,,' ~ 600 / O 1400 (/l !000 ,,,./ I s~o /, V / 2200 ,/- ¢' 680 .. O0 /' 1300 / / 720 1 500 ,' ,/ / / 760 ,. 2200 ,' ,' / 800 .' ~.400 .' ,' ,' .,- ,' ,' 840 2500 ,' ,, ,' ,' ,' ,' ..' 1 400 880 2500 ,' ,' ,' ,' ,' ,' 920 ,' ,' ,' ,,' ,' 960 ' ' ' 6 ' ' ' ~ ' ~ ..... 760 720 680 640 6 0 560 .5 0 4 0 440 400 <- West (feel) 1500 280 ,' 520 100 ~' 1200 / / / ; / / ; / ! /. 1300 1400 ! ! / i i i I / i i I 360 320 280 240 360 4-00 440 480 52O O 560 '-'- (D 600 (D 640 I v 680 720 76O BO0 840 880 920 960 200 160 120 c,,~.,..~ u), ~.c. For: t]ROCK~AYI O~tc p)oRcd: 28-Hey-98 I 600 800 lOO0 12oo 1400 1600 1800 2O00 2200 2400 2600 0 2800 3000 3200 3400 360O 3800 4000 4200 4400 ARCO Alaska, Inc. Structure : Pad 10 Well : 131 Field : Kuparuk River Unit Location : NoRh Slope, Alaska <- West (feet) 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 I I I I I I I I I I I I I I I I I ! I I ! ! 23~~'~' .... ~00 2500~ .... ' ..--" 270~...~'" 290~--'"' ....-"' 2100 600 /'.'/' 1700 ..,.;;,;/' 1700 170¢,;/ ..;;;;.-' · ' 800 / ,, V~'!~oo ¢ ,ooo ,' / / 29009,(j-'" 3100#"~," 3300~/.5..-' 2700 3700~,/// 3900#/ /' 4100#/ ./' J~ ./'2900 /' ~ 9 oo../:.':'19oo '2100 .,,/" / ..~,.~. 'uoo ,," 2300 / 2300 .,,~ z ] O0 ,, / / ,5oo /'~ 9oo · 2soo...:::" ~oo ,'" . ..';- 2300 / ,-;,"' ,/ /5;/ ~9oo / 2700,,~,.5/' ,'/21 O0 /-;/' 2500 ~100 ; / / / / / ! / ,/2300 / / / / ./2700 / / ,' · ' / / / / /" 2900 /2500 , ,' / · ' / / ~100 ,' ; 3100 / · ' / " ' 3300 /"2700 / / 35oo / , /'2900 / 3700 ,' / 3900 ,,,'~'~ aa / ~oo /'3300 O0 ~ 3500 y' 3700 z 3900 j ' 4100 !,900 1700 / / 1200 19oo 3>60 : 3~o / 37,~o ; / /'1700 : 1400 / / 1900 / / 16oo .2100 2300 ' 2500 1800 2OOO 220O ! I 2400 / / 2600 / ! 2800 i3700 ; , 3000 3900 32OO / I ! ! i 4~oo ! l I I / ! ! ~ 4300 / ! ! ! / 1 45oo i i i 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 /-- ~A/,-,~+ /f,',,-+'~ 3400 3600 3800 4000 4200 4400 ~tRCO Alaska, Inc. Pad 1D 131 slot 9131 Kupak-uk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-131/L3 Vets. #3 Our ref ~ prop2191 License : Date printed : 28-May-98 Date created : 16-Apr-97 ~ast revised : 27-May-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 57.175,w149 30 36.399 Slot Grid coordinates are N 5959243.707, E 560490.383 Slot local coordinates are 421.00 S 600.00 W Projection tYlOe: alaska - Zone 4, Spheroid: Clarke - 1866 Rs~erence North is True North Report is limited to clearances less than 500 feet ' DECRF~SING CLEZ/~ANCES of less than 1000 feet ere indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0 - 7340~>,,10,Pad 1D P~S <556-7024'>,,9,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <0-8610'>,,6,Pad 1D PGq~S <0-8930~>,,5,Pad 1D P~MS <0-7502~>,,4,Pad 1D PGMS <O-8070~>,,3,Pad 1D PGMS <0-9783~>,,2,Pad 1D PGMS <0-8365~>,,1,Pad 1D 1D-D Version #2,,1DoD,Pad 1D 1D-F Version #2,,1D-F,Pad 1D 1D-B Version #3,,1D-B,Pad 1D TOTCO Survey,,WS-8,Pad 1D PMSS <0-5462~>,,J3,Pad 1D WS 1D-127 WS 1D-128 WS 1D-126 W5 1D-132 WS 1D-134 WS 1D-110 WS 1D-125 WS 1D-123 WS 1D-122 W$ 1D-116 WS 1D-114 '~1 Vets #3,,127,Pad 1D 'K2 Vets #3,,128,Pad 1D 'J1 Vets #5,,126,Pad 1D /K4 Vets #3,,132,Pad 1D /h5 Vets #3,,134,Pad 1D /C3 Vets #3,,110,Pad 1D /H2 Vets, #3,,125,Pad 1D /Gl Vets. #3~,123,Pad 1D /F2 Vets. #3,,122,Pad 1D /El Vets. #3,,116,Pad 1D 'D2 Vets. #3,,ll4,Pad 1D Closest approach with 3-D Last revised Distance 28-Apr-98 131.0 29-Apr-98 285.0 6-Nov-97 52.9 13-Nov-97 57.2 13-Nov-97 177.5 4-Aug-92 297.7 4-Aug-92 418.1 4-Aug-92 537.9 10-Dec-97 658.0 24-Nov-97 73.0 24-Nov-97 43.2 24-Nov-97 43.0 21-May-98 127.7 1-Dec-97 30.0 27-May-98 105.0 27-Hay-98 90.0 27oMay-98 120.0 27-Ma¥-98 15.0 27-May-98 76.9 27-May-98 463.0 27-May-98 133.0 27-May-98 207.9 27-May-98 223.0 27oMay-98 343.0 2T-May-98 373.0 MinlmumDistance method M.D. Diverging from M.D. 600.0 600 0 100.0 100 0 580.0 6498 3 333.3 333 3 291.7 291 ? 333,3 333 3 0.0 333 3 333.3 333 3 333.3 333.3 291.7 291.7 500.0 500.0 291.7 6498.3 820.0 820.0 100.0 940.0 250.0 250.0 250.0 250.0 250.0 250.0 200.0 6380.0 650.0 660.0 291.7 291.7 291.7 291.7 333.3 333.3 291.7 291.7 291.7 291.7 270.8 270.8 _ ,.r WS 1D'113/Cl Vets. #3,,113,Pad 1D WS 1D-112/A1 Vers. #3,,112,Pad 1D WS 1D-IIi/B2 Vets. #3,,1Il,Pad 1D wS 1D-136/J7 Vets. #1,,136,Pad 1D PMSS <0-4414'>,,GS,Pad 1D PMSS <0-4530'>,,F6,Pad 1D PNSS <0-&515'>,,F4,Pad 1D PHSS <0-4590'>,,ES,Pad 1D PHSS <0-$142'),,E3,Pad 1D PMSS <0-5205'>,,E7,Pad 1D P~SS <0-5047'>,,G3,Pad 1D PMSS <0-4850'>,,D4,Pad 1D PMSS <O-5126'>,,D6,Pad 1D PMSS ~381-6092'>,,CT,P&d 1D WS 1D-158/~11 VerB. 91,,158,Pa~ 1D WS 1D-141/All VerB. #1,,141,Pad 1D WS 1D-142/B10 Vets. #1,,142,Pad 1D WS 1D-140/A9 Vets. #1,,140,Pad 1D WS 1D-139/B8 VerB. #l,,139,Pad 1D WS 1D-143/C9 Vets. #1,,143,Pad 1D WS 1Do144/D8 VerB. #1,,144,Pad 1D WS 1D-145/Cll Vets. #1,,145,Pad 113 WS 1D-146/D10 Vets. #1,,146,Pad 1D WS 1D-14?/E9 Vets. #1,,147,Pa~ 1D WS 1D-148/E11 VerB. #1, o148,Pad 1D WS 1D-149/F8 Vets. #1,,149,Pad 1D WS 1D-152/G9 VerB. #1,,152,P&d 1D WS 1D-LS0/F10 Vets. #l,,150,Pad 1D WS 1D-153/H10 VerB. #1,,153,Pad 1D WS 1D-154/J11 Vets. #1,,154,P&d 1D WS 1D-L55/H8 VerB. #1,,155,Pad 1D WS 1D-~56/J9 VerB. #1,,156,Pad 1D WS 1D-157/K10 Vets. #1,,157,Pad 1D WS 1D-159/L9 VerB. #1,,159,Pad 1D WS 1D-160/K8 VerB. #1,,160,Pad 1D WS 1D-161/L7 Vets. #l,,161,Pad 1D WS 1D-138/K6 VerB. #1,,138,Pad 1D WS 1D-151/G11 VerB. #1,,151,P&d 1D WS 1D-107/B4 Vets. #1,,107,Pad 1D WS 1D-102/A5 Vets. #3,,102,Pad 1D WS 1D-103/B6 VerB. #3,,103,Pad 1D WS ID-104/A7 VerB. #3,,104,Pad 1D WS 1D-108/A3 VerB. #3,,108,Pad 1D PMSS ~1957-5265'>,,JS,Pad 1D WS 1D-101/C5 Vets. #3,,101,Pad 1D PMSS ¢0-5015e),,GT,Pad 1D PMSS <0-4778'),,H4,Pad 1D 27-May-98 27-May-98 27-May-98 27-M&y-98 8-Dec-97 19-Dec-97 16-Dec-97 22-Deco97 30-Dec-97 7oJan-98 6-Jan- 98 12-Ja~a-98 19-Ja~-98 27-M&y-98 27-May-98 27-M&y-98 27oM&y-98 15-Apr-97 15oApr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-A~r-97 15-Apr-97 27oM&y-98 27-May-98 27-~ay-98 27-May-98 1S-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 27-~y-98 24-Nov-9? 27-May-98 13-Nov-97 9-Nov-97 388.0 403.0 448.0 99.8 240.0 255,0 270.0 314.7 360.0 330.0 150.0 480.0 525.0 554.5 231.6 209.1 201.7 217.2 226.0 195.3 189.8 185.3 182.0 179.9 179.0 179.~ 187.9 181.0 192.9 199.0 206.0 213.8 222.4 241.4 251.7 262.5 151.3 183.9 508.0 598.0 583.0 568.0 493.0 26.3 613.0 84.4 15.0 291.7 333.3 291.7 640.0 100.0 100.0 100.0 333.3 100.o 100.0 100.0 100.0 100.0 291.? 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 440.0 250.0 291.7 291.7 291.7 291.7 291.7 440.0 291.7 660.0 100.0 291.7 333.3 291.7 640.0 100.0 100.0 100.0 333.3 100.0 100.0 100.0 100.0 100.0 291.7 250.0 250.0 5880.0 5680.0 250.0 250.0 250.0 250.0 6022.2 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 440.0 250.0 291.7 291.7 291.7 291.7 291.7 440.0 291.7 660.0 100.0 West Sak 1 D-131 (L3) Producer Well Four (4) Stage Frac-for-$and Control with 3-1/2" Deadstring 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 6498' MD / 4134' TVD) 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-Mod (to frac through off-rig) D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB, 05/18/98, v. 1 3-1/2" Production Tubing 9.3# L-80 EUE 8RD-Mod Power Cable for ESP Centd~ift West Sak 1 D-131 (L3) Producer Well Four (4) Stage Frac-for-Sand Control Completion 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pre4oaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centdiift 7-5/8" Casing Marker Joint 29,7# L-80 BTC-M(xt (set +/- 50' above top perforation) ESP Motor Section Centdlift D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29~7# L-80 BTC-MOD Cemented to Surface (+/- 6498' MD / 4t34' TVD) A2 Sand Frac'd with Resin Coated Pmppant ARCO Alaska, Inc. TAB, 05/18/98, v.2 KUPARUK RIVER UNIT - WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC 3 2 i 5 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTE~NANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVEAND 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 WEM. BORE 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~DN 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, ~1E~97 6 3 8 13 5/8" 5000 P§I BOP STACK West Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILLAOCUMULATOR 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 UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 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. :~ 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 MINUTE~ INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. S CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. ENES. AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. .TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. ~ OPEN PIPE RAM& BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BUND RAMS AND TESTTO 3000 PS! FOR 3 MINUTES. BLEED TO ZERO PSI: 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PS! FOR 3 MINUTES. 1~_ TEST KELLY COCKS AND INSIDE BOP TO 3000 PSt 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/Z' TO 7' PIPE ODS AS: APPROPRIATE. 1. 16'-STARTING HEAD 2. I 1' - 5000 PSI HORIZONTAL TUBING HEAD 3. 1 !' 50(30 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' - 50(X) 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. 13-5J8'- 5000 PSI ANNULAR TWM, 9/22/97 D S 1-D PIT ~ 111 112~ 11~ 117 ~ .8'~ ~ S~E: ~ = ~ ~/LE 12o~ 119 ~ 122~t ,~ 123 b5 I 125 126 127 128 ~ 6 1~1 !~ . , i , LEGENDSEE SHE~ t 2 FOR NOTES ~O L~TION INFORMAT~N .o Ex~s~N~ CO~OUCFO~S ~OUNSBURY · 'AS-STAKEO" CONOUCTOR LOCA ~ ~/J~ ~_ & ASSOCIATES, INC. ~ 'PROPOSED' CONDUCTOR LOCA ~ON ~-E~N~ P~N~S SU~O~ m AREA' 1D M~ XX UNIT' D1 Mma~a"'--"-, Inc. ~kD,,~ s,~ ~-D ARCO ~ ~s~ s~ ..~sE ~B - ~ CO. DUC~O.S AS-STAKED LOCA~ONS ...... , i ............ m ~T. m ELEVAn~S ~0~ ARE BRITISH PETROLEUM MEAN S,T ,-o ,s 00' 0,' ~sr ~RO, ~.S.P. ZONE, SR, O ~0~. ~ ~ ~ h~ SUR~ymlS ~R ~ ~-Jg CONDUCTORS 1-8; CEA-OIOX-6104OlO FOR CONDUCTORS 21 ~ 2 ~05, ~06.109, I ~, ~17- ~2~, 124,129, I~0, ~$ ~ ~5: AND CEA-OIDX-6104OI$ FOR CONDUCTORS 9 ~ 10. WClNI ~ MA P SCALE: ~' = I MILE No.W~I ,y, A.S.P. s 'X' LA TI ~DE L ONGI TUDE ~SEC' SEC~ ELE~PAD ELEEO' . SeC. 1~, T. ll N., R. IO E. ~S.L.~E.L. 108 ~5,~5~.~38.~ 560,~0.6 70' 18, 02.05' I4~' ~0' 36.28' 74' 5g~' 70.4' 110 ~5,~5~.708. g 560,490.6 70' la' 01.75' 14~' 30' ~6.2~' 44' 5~' 70.4' II1 ~5,959,693.~ 560,4~0.~ 70' 18' 01.~0' ~4~" 30' 3~.2~' 2~' 5~" 70.4' Sec. 23, T. 11 N., R. 10 E. F.N.L. F.E.L. ~12 ,, 5,~5~,~48.~ 5~0,490.~ 70' Ia' 01. ~6' ~4~' ~0' ~6.30' ~6' 597' 70.4' 11~ ~ 5,~5~,63~.~ 560,~0.~ 70' 18' 01.01' I4~' ~' ~.~0' 3I' 5~ 70.4' 114 ~ 5,95~,6~8.~ 560.~g0.~ 70' ~8' ~.~7' 14~' 30' ~6.30' 4~' 5~7' 70.4' I16 ,~5,959,588.9 560,490.6 70' I8' 00.57' I49' 30' 36.31" 76' 597' 70.4' 63.3' ~22 5,959,469.0 560,490.7 70' I~' 59.39' ~49' ~0' 36.~4' ~96' 598' 70,5' 64.~' ~23 5,959,453.9 560,490,7 70' 1~' 59.24' 149' ~0' ~6.~4' 21~' 598' 70.4' 64.2' t25 5,959,379.2 560,490.7 70' I~' ~.51 ~49' ~0' ~6.~' 286' 599' 70.3' 126 5,939,363.9 560,490.7 70' 17' 5&~' 149' 30' 36.36' 3Or' 599' 70.3' 64.3' 127 5,959,34&9 560,490,7 70' I7' ~.21' ~49' ~0' ~6.~' 3~6' 599' 70.3' 64,3' t28 5,959,~4. I 560,490. 7 70' 1~' ~.06' ~49' ~0' ~6.37' 3~' 599' 70.3' 64.5' t31 5,959,244.0 560,490.~ 70' 1~' 5Z18" 149' 30' ~6.~9' 42~' 6~' 70.5' 69.9' 132 5,959,229.2 560,490.7 70' 17' 5Z03' I49' ~0' ~6.39' 436' 600' 70,4' 69.8' 134 5,959,153.8 560,490.8 70' 17' 56.29" 149' ~0' ~6.4~" 511' 601' 70.5' 69, t' ** Proposed IocoUon, work in progress ' LOUNSBURY ' & ASSOCIATES, INC. ~ DRILL Sim 1-D ARCO Alaska, Inc. ~sT SAK PHASE lB- ~ CONDUCTORS *S-STAKED LOCA ONS , , WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 7, 1998 .. 1D-131, AK-MM-80277 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-131: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22891-00 2" x 5" TVD Resistivity & Gamma Rav Logs: 50-029-22891-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries, Inc. Company D F! I I_1-- I IM 13 S I== I::1 ~/I I~ E ~:; To: WELL LOG TRANSM1TrAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-131, September 30, 1998 AK-MM-80277 1 LDWG formatted Disc with verification listing. API#: 50-029-22891-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATrACHED COPY OF THE TRANSMITTAL LETTER TO THE ATYENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500. Fax (907) 273-3535 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11476 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 9/4/98 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date Color RF Sepia Floppy Pr. int--~. Disk WS 1D-126 ~-IO~ 98373 REPROCESSEDUSlT 980629 ,,'"' 1 ,t WS 1D-127 C~-I~ 98373 REPROCESSEDUSrr 980707 WS 1 D-131 ~ ~- I ~ O 9 S 373 REPROCESSED usrr 98071 4\ 1 S I G N E D: ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 I:! I I_1_ I I~l G S El I:l~J I r- E S 19-Aug-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-131 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 6,472.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) AUG 26 1998 Alaska Oil & Gas Cons. ~mm~ss~on 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. TONY KNOWLE$, GOVERNOR ~kLASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 23. 1998 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Rc~ Kuparuk River Unit 1 D- 131 ARCO Alaska, Inc. Permit No.: 98-110 Sur. Loc.: 421'FNL. 600'FEL. Sec. 23, TllN. R10E. UM Btmholc Loc: 1258'FSL 2299'FWL, Sec. 23, T11N, R10E. UM Dear Mr. McKav: Enclosed is thc approved application for permit to drill thc above referenced well. Thc permit to drill docs 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 pcrmitting determinations arc made. Bloxvout prcvcntion equipment (BOPE) must be tcstcd in accordancc with 20 AAC 25.035. Sufficient noticc (approximatcly 24 hours) of the BOPE tcst performed before drilling below the surface casing shoe must bc given so that a representative of thc Commission mav witness the test. Notice may be given by contacting the Commission pctrolcum ficld inspector on the North Slopc pagcr at 659-3607. Robert N. Christcnson Commissioner BY ORDER OF THE COMMISSION dlffcnclosurcs CC~ Dcpartmcnt of Fish &Gamc. Habitat Scction w/o cncl. Dcpartmcnt of Environmcntal Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory FI StratigraphicTest F1 Development Oil X Re-Entry Deepen Service [--I Development Gas Fl SingleZone X Multiple Zone Fl 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) 421' FNL, 600' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1348' FSL, 2357' FWL, Sec. 23, T11N, R10E, UM 1D-131 #U-630610 '/ At total depth 9. Approximate spud date Amount 1258' FSL, 2299' FWL, Sec. 23, T11N, R10E, UM 6/25/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-130 6498' MD 1258' @ TD feet 15' @ 100' feet 2560 4134' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 64.66° Maximum surface 1379 psig At total depth 1812 psig (TVD) 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 79' 41' 41' 120' 120' _+200 CF 9.875" 7.625" 29.7# L-80 BTC MOD 6457' 41' 41' 6498' 4134' 688 Sx Arcticset Ill & 305 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. :~ ? Present well condition summary ~'% 5¢ Total depth: measured feet Plugs (measured) .. true vertical feet Effective depth: measured feet Junk (measured) true vertical feet 2&i~SK3 ¢*':' Casing .. Length Size Cemented Measured depth True Vert~a depth Structural Conductor Surface Intermediate Production Perforation depth: measured (..~ ~ '~ true vertical 20. Attachments Filing fee X Property plat [] BOP Sketch X 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, . ,.~.~r'"'~~certify/~.~.,~,..,,tthat the f~. ,s~e best of my knowledge S'gned ! ~,~ - Title Shallow Sands Team Leader Date . · Commission Use Only Permi~_ il~ 50- 0~ 2.'~. ~ t '~ -~ ~ ~ other requirements Conditions of approval Samples required ~ Yes [~ No Mud log required I~ Yes [2~ No Hydrogen sulfidemeasures Fi Yes ~o Directional surveyrequired [~Yes F! No wor ,n .ressure,or.O.. D UI [5 Other: ,,';iGINAL SIGNED BY by order of Approved by Robert N. Chr~stensorl commissioner the commission Date 0~ Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. - ' Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor June 2, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-131 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 1 D 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 ("ESPCP") 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 and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-131, such as shallow gas. There have been eight (10) Kuparuk wells and (14) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Drill and Case Plan for West Sak 1D-131 (L3) Frac-for-Sand Control Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7-5/8" 29.7# L80 BTC 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. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. 7. 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. 8. Shut in BOP's and pressure test casing to 2,000 psi for 30 minutes per AOGCC regulations. Record results. 9. 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. 1 D-131 (L3) Page I TAB,O6/O1/98,v1 Completion Plan for West Sak 1D-131 (L3) Frac-for-Sand Control Producer Four-Staqe, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation . Stage 1 3. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth. 4. Perforate Stage 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 I 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 I perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 . 11. 12. 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. Perforate Stage 2 overbalanced, and POOH with E-line. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 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. 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 sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. Sak A4 and B 1 D-131 (L3) Page 2 TAB,06/01/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. 21. 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. 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. Pull back pressure valve. Pull tubing hanger and circulate well to clean brine as required. TOH and lay down deadstring. Pick up rock bit and casing scraper and TIH with workstring. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. Circulate well to clean brine. TOH with workstring. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 25. 26. 27. 28. 29. 30. 31. 32. 33. 1 D-131 (L3) Page 3 TAB,06/01/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1 D-131 (L3) Page 4 TAB,06/01/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-131 (L3) Drillin_q Fluid Type Extended Bentonite Slurry Drillin_q Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.O ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps ! *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A 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. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-131 (L3) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1 D~131 (L3) Page 1 TAB,06/01/98,v.1 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/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.? ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,524' MD/f'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/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3939 ft)(0.46 - 0.11 psi/ft) = 1379 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. Drillinq Area Risks: Drilling risks in the West Sak 1D-131 (L3) 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-131 (L3). Well Proximity Risks: The nearest existing well to West Sak 1D-131 (L3) is WS 1D-130 (H4). As designed, the minimum distance between the two wells would be 15.0' at 100' MD. Annular Pumpin_~ Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West 1D-131 (I_3) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the ?-5/8" combination surface / production casing and prior to the drilling rig moving off of the well. 1 D-131 (L3) Page 2 TAB,06/01/98,v. 1 I V Created lay finch For: BROCKWAY Dote lalotted: 28-~oy-98 PJot Referenc~ ;s W~ tD-ISl/L3 Ve~. ~. Caord;note9 ore ~n feet reference stat ~1~{. f~e Ve~t}col Oepths o~e reference ~8 (Porke~ ~245). 3OO 300 600 900 1200 1500 i800 2100 2400 2700 5000 3300 3600 3900 4200 300 X'RCO Alaska, Inc Structure : Pod 1D Well: t31 Field : Kuporuk River Unit Locefion : North Slope, AlaskaI 213.49 AZIMUTH 4210' (TO TARGET) **,Plane of Proposal*** RKB ELEVATION: 112' K0P TVI]=250 TMD=250 DEP=0 BEGIN TURN TO TARGET TVD=333 TMD=353 OEP=2 7.84 i3.26 19.03 24.91 DLS: 6.00 deg per 100 ft 30.83 36.78 42.74 48.70 54.68 EOC TVD=1151 TMD=1567 DEP=548 MAXIMUM ANGLE 64.66 DEG 28OO 24O0 2OOO I I I I I <- West (feet) 600 1200 800 400 0 400 I I I ~ ~ I I I I ~ 400 ESTIMATED SURFACE LOCATION: 421' FNL, 600' FEL SEC. 23, T11N, RIOE TARGET LOCATION: 1348' FSL, 2357' FWL SEC. 25, T11N, RIOE TARGET TVD=3670 TMD=6022 DEP=4210 SOUTH 3511 WEST 2323 Angle Drop Sands - West Sok A3 Bose West Sok Sands - 7 5/8 Casing Pt B/ PERMAFROST TVO=1625 TMD=2475 DEP=1550 TD LOCATION: 1258' FSL, 2299' FWL SEC. 25, T11N, RIOE 40O 270 Az Begin Turn to Target OC Permafrost 80O 1200 1600 2000 2400 2800 3200 3600 4000 TARGET ANGLE 13 DEG i I I i I 0 500 600 BEGIN ANGLE DROP TVD=2551 TMD=4639 DEP=3506 T/ UGNU SNDS TVD=2930 TMD=5255 61.62 51.62 46.62 41.62 36.62 DLS: 5.00 deg per 100 ft 31.62 26.62 21.62 16.62 END ANGLE DROP TVD=3329 TMD=5672 DEP=4132 T/ W SAK SNDS TVD=3524 TMD=5872 DEP=41771 TARGET - A3 TVD-3670 TMD=6022 DEP=4210i~ B/ W SAK SNDS TVD=3939 TMD=6298 OEP=4272 ~ TD - CSG PT TVD=4134 TMD=6498 DEP=4317 ~ I I I i i I I I i I i I ii I i i i I i I i I i I I 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 5900 4200 4500 VerticalSection (feet) -> Azimuth 213.49 wHh reference 0.00 N. 0.00 E from slot ~131 RCO Alaska, In Structure : Pod 1D Well: 131 Field : Kuperuk River Unit LocoHon : North Slope, AloskoI 60 40 20 20 80 (D lO0 (- 120 -I-, 0 I v 160 180 200 22o 240 260 28O 3OO 520 <- West (feet) 240 220 200 180 160 140 120 1 O0 80 60 40 20 I I I I I I I I I I I I I I I t I I I 1 000 ~--'"'" ..--'"" 90( /'/ / O0 /,-/ 800 ./ 1000../ 300 ,' " /800 · " 900 " '/ 2800 " / / / 2900 ,' / / /900 ,/ / / / 1500 / ,,' 3 /i0°° '"' 50O / / I I I / I / lOOO ; i i i i I I I I I i 240 220 200 180 160 0 20 40 60 .- -(~-500 60 .,./'" .X1200 ..,-'~oo 5ooe~-.~ ~oo ~o ,/ 800" ." 8...00 "X%..% 9 00 /_,'/ ~ ~ ~ ~'"'--~ 1 000 ~.~.;; / 500 ~5'O~UU~ '"-%.1100 20 50~...' % 600 ~ 1500x 'x,, i200 / ,./" .,/' =~ 1600x 20 .,/,. ~'~ .... _ ........ 4o #"TOO ,' / ? / / / ,/ / / / / 1100 1100 9OO ?00 000 8OO 1200 700 ~oo ~ 8oo }0 3000 25od 2100 1600 1400 900 / 500 600 1500 1000 , / , 140 120 1 O0 80 60 4 <- West (feet) 2'0 100 0 1 000 ,-=:I,- _~E p__O_. ,7..0.? 120 ~ '"-,,. 800 "' """-.. 900 CD 140 "-.,,500 ~ 160 ",~ 600 f~'~5 0 0 ',,, 180 ',, '",~ 700 200 """, 220 , ',, 800 "~ 240 2~0 2gO 30O 32O i I i i o 2'o 4'o 6'o 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/~¢ APB 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 June 25, 1998. 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 ~' Attachments: cc: West Sak 1D-131 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 Sperry-Sun Drilling Services LIS Scan Utility Mon Sep 28 17:02:30 1998 Reel Header Service name ............. LISTPE Date ..................... 98/09/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/09/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... 'UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SAK) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER:~ OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80277 P. SMITH D. HEIM OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 1D-131 500292289100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 28-SEP-98 MWD RUN 2 AK~MM- 80277 P. SMITH D. LUTRICK 23 liN 10E 421 600 .00 112.00 70.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 6472.0 i98~'110-0 ' KUPARUK RIV U WSAK 1D-131 50- 029-22891-00 PHILLIPS ALASKAINC Roll #1: Start: Stop Roll #2: Start Stop MD 06472 TVD 04124 Completion Date: 11/18/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 8723 2-13 SPERRY GR/EWR4/CNP/SLD D 8724 b~i2 SPERRY MPT/GR/EWR4 L DGR/EWR4-MD ~' 1,2 121-6472 L DGR/EWR4-TVD o/'1,2 1214124 L USIT-REPROSCET t/FINAL BL(C) 100-6300 R SRVY RPT 6/ SPERRY 0-6472. OH 9/23/98 9/23/98 OH 9/30/98 9/30/98 OH 10/7/98 10/7/98 OH 10/7/98 10/7/98 CH 5 9/4/98 9/9/98 OH 8/19/98 8/26/98 Tuesday, January 09, 2001 Page 1 of 1 · WELL PERMIT CHECKLIST COMPANY ~ V'~ C.r.~ WELL NAME ~UL ~10 ~ Ih [(, 1 D-I,~ ~ PROGRAM: exp [] dev,~ redrll [] serv [] wellbore seg Lq ann. disposal para req [] FIELD & POOL INITCLASS ~)E,O !- C~;I GEOLAREA ~'~/C1 UNIT# )I~ 6(} ON/OFFSHORE ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE -. 12. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If 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 ~OO'O psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY A~c~ DA.rE N (~N (~)N 30. Permit can be issued w/o hydrogen sulfide meas~ Y N 31. Data presented on potential overpressur~.c.zerf~-: ...... Y N 32. Seismic analysis of shallow~qc,.~=C~s ............. Y N 33. Seabed condit~f off-shore) ............. Y N 34. C~rogress reports ....... Y N xplorarory onlyJ ANNULAR DISPOSAL 35. With proper cementing records, thiSr §plan ~n'~' (A) will contain waste in a suitablereceiving zo.. . ...... Y N (B) will not contaminate freshwat.e_~r'..or--cad':~'~'r'lr g waste... Y N to surface; (C) will not impair].r..mectri'Anical integrity of the well used for disposal; Y N (D) will n~t~age producing formation or impair recovery from a Y N ~1; and ,.--~) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N APPR DATE GEO~pGY: RPC~ ENGINEERING: UIC/An/p~ COMMISSION: DWJ RNC . , co C¢ W~.' Com m e nts/I nstructions: M:cheklist rev 05/29/98 dlf:C:\msoffice\wordian\diana\checklist 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. 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 08/26/98. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6472'MD, 4124 '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 ....... 98/09/28 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. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH STOP DEPTH 70.0 6426.0 70.0 6426.0 70.0 6426.0 70.0 6426.0 78.0 6433.0 108.0 6426.0 121.0 6471.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 4448.0 2 4448.0 6472.0 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 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 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 DEPT 70 6471.5 ROP 13.7941 645.41 GR 11.9921 137.019 RPX 1.8498 2000 RPS 1.7145 2000 RPM 1.3732 2000 RPD 1.1777 2000 FET 0.0636 11.3278 Mean Nsam 3270.75 12804 249.588 12702 68.6121 12711 64.2328 12713 68.6299 12713 81.4977 12713 100.125 12713 0.34021 12637 First Reading 70 121 78 70 70 70 70 108 Last 'Reading 6471.5 6471.5 6433 6426 6426 6426 6426 6426 First Reading For Entire File .......... 70 Last Reading For Entire File ........... 6471.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/28 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 ....... 98/09/28 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 70.0 RPD 70.0 RPM 70.0 RPS 70.0 R?X 70.0 GR 78.0 ROP 121.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 4409.5 4409.5 4409.5 4409.5 4409.5 4416.5. 4449.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. ~RESIS. 4 $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN)-: DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 10-JUL-98 ISC 5.06 CIM 5.46 MEMORY 4448.0 121.0 4448.0 .8 67.7 TOOL NUMBER P1033CRG6 'P1033CRG6 9.880 9.9 SPUD MUD 9.60 325.0 8.5 500 8.2 4.500 3.910 5.100 4.400 30.6 $ 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 1 API 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 FET ~WD 1 HOUR 4 1 68 ROP MWD 1 FT/H 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 DEPT 70 4449 2259.5 GR 11.9921 135.667 65.3491 RPX 2.3758 2000 89.3743 RPS 1.7145 2000 95.6783 RPM 1.3732 2000 114.76 RPD 1.1777 2000 141.944 FET 0.0636 1.6279 0.202319 ROP 28.816 645.41 280.148 Nsam 8759 8678 8680 8680 8680 8680 8604 8657 First Reading For Entire File .......... 70 Last Reading For Entire File ........... 4449 First Reading 70 78 70 70 70 70 108 121 Last Reading 4449 4416.5 4409.5 4409.5 4409.5 4409.5 4409.5 4449 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Nu/~ber ........... 1.0.0 Date of Generation ....... 98/09/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4410.0 6426.0 RPD 4410.0 6426.0 RPM 4410.0 6426.0 RPS 4410.0 6426.0 RPX 4410.0 6426.0 GR 4417.0 6433.0 ROP 4449.5 6426.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $o BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: -ll-JUL-98 ISC 5.06 CIM 5.46 MEMORY 6472.0 4448.0 6472.0 13.3 65.7 TOOL NUMBER P1033CRG6 P1033CRG6 9.'880 9.9 SPUD MUD 9.60 255.0 8.0 450 6.8 6.000 4.210 6.000 3.900 40.4 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 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 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 4410 6471.5 5440.75 4124 GR 25.2134 137.019 75.6332 4033 RPX 1.8498 113.017 10.1221 4033 RPS 1.9466 108.752 10.4151 4033 RPM 2.0037 115.565 9.90824 4033 RPD 2.1482 82.6272 10.1188 4033 ROP 13.7941 643.945 184.182 4045 FET 0.1393 11.3278 0.634386 4033 First Reading For Entire File .......... 4410 Last Reading For Entire File ........... 6471.5 First Reading 4410 4417 4410 4410 4410 4410 4449.5 4410 Last Reading 6471.5 6433 6426 6426 6426 6426 6471.5 6426 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/09/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Scientific Technical Services Date ..................... 98/09/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
