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Home My WebLink About190-1071500 sx CS III, 350 sx G, 100 sx CS II RECEIVED by James Brooks on 3/2/2023 at 3:23PM Abandoned 2/16/2023 JSB RBDMS JSB 051723 xGMGR03AUG2023DSR-5/18/23 3.2.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.03.02 15:19:13 -09'00' Monty M Myers ACTIVITYDATE SUMMARY 1/1/2023 ***Job cont from 12-31-22 WSR*** Pumped 101 bbls crude down Tbg for B&F. Pumped 3 bbls 60/40 followed by 202 bbls down IA for load. Pumped 116 bbls down Tbg for load. Pumped 1 bbls to psi up on Plug. Pumped 2 bbls down Tbg IA pressureing up for CMIT TxIA Job in progresss ***Job cont. to 01-02-23 WSR*** 1/1/2023 ***WSR CONTINUED FROM 12-31-22*** BRUSHED / GAUGED TBG 2.69"; DRIFTED TO 12,200' SLM (NO ISSUES). BRUSHED / GAUGED TBG 3.79" TO XO @ 6517' MD. RAN 24 ARM READ CALIPER W/ PRESSURE & CCL TO 12,200' SLM TO SURFACE (Good Data) SET 4-1/2" WHIDDON ON XO @ 6,517' MD PULLED BK-OGLV FROM ST#1 @ 6,424' MD PULLED BK-LGLV FROM ST#2 @ 3,789' MD SET BK-DGLV IN STA# 2 (3789' MD). TBIRD TO LOAD IA W/ 220 BBLS CRUDE. SET BK-DGLV IN STA# 1 (6424' MD). PULLED WHIDDON CATCHER FROM 6517' MD. LOADED TBG W/ 120 BBLS CRUDE. SET 2.81" XXN PLUG @ 6590' MD. ***WSR CONTINUED ON 1-2-23*** 1/2/2023 ***WSR CONTINUED FROM 1-1-22*** MITT 2250 PSI (PASSED). CMIT 2250 PSI (PASSED). PULLED 3-1/2" XXN FROM 6,590' MD ***WELL S/I, DSO NOTIFIED*** 1/2/2023 ***Job cont from 01-01-23 WSR*** Pumped an additonal 2 bbls 100* crude down TBG / IA for a total of 4 bbls crude in attempt to get a CMIT TxIA Target 2250 psi. Pumped a total of .5 bbls crude down Tbg for MITxT 2250 target pressure. 1st 15min= Tbg lost 50 psi // IA gained 25 psi 2nd 15min= Tbg lost 0 psi // IA lost 0 psi. Attempt another CMIT TxIA Target 2250 psi. Pumped 1 bbls crude down Tbg/IA to achieve test pressure of Target 2250 psi. 1st 15 min= Tbg lost 30 psi / IA lost 40 psi // 2nd 15min = Tbg lost 0 psi / IA lost 5 psi. Pumped .5 bbl crude to bring Tbg psi up for Sline to pull plug Pad op notified of well status and Sline incontrol of well upon departure TAGS HUNG FWHP's= 300/300/0 1/14/2023 T/I/O=SI/5/0. Pre CDR2. Bled IA to 0 psi. Monitor 0 Psi. Remove 2" Blind from CIA. Install 2" temp Vavle #04. Torque to spec. PT CIA 300 low 2500 high (pass). Remove 2" FMC VR plug. Installed tapped blind. FWPs=SI/0/0. ***RDMO*** 1/23/2023 LRS 72 Free up F/L Obstruction (HYDRATE / ICE PLUG). Pressure up on the F/L as directed by DSO. Pumped a total of 12 bbls of neat methanol. 1/24/2023 LRS 72 Free up F/L Obstruction (HYDRATE / ICE PLUG). Pressured up and bled back keeping < 500 psi DP. Plug broke free. Pumped a total of 25 bbls of neat methanol 44 bbls of 60/40 Meoh and 50 bbls of 180* F diesel into the Flowline. 1/25/2023 CTU#9 1.75" Coiled Tubig (0.156 wall) Job Scope: Pre CTD: Mill XN, Cement Plug Road Unit from J-pad to DS-9. MIRU ***Job Continued on 1/26/23*** Daily Report of Well Operations PBU 09-43 Daily Report of Well Operations PBU 09-43 1/26/2023 CTU#9 1.75" Coiled Tubig (0.156 wall) Job Scope: Pre CTD: Mill XN, Cement Plug ***Job continued from 1/25/23*** MU BOT LH Milling assembly w/ 2.8" Mill. RIH Tag XN @ 6573' CTM / 6594' Mech. Mill XN to 2.80". POOH FP CT w/ Diesel. MU 2" cement BHA and RIH ***Job Continued 1/27/23*** 1/27/2023 CTU#9 1.75" Coiled Tubig (0.156 wall) Job Scope: Pre CTD: Mill XN, Cement Plug ***Job coontinued from 1/26/23*** Continue to RIH w/ 2" cement nozzle. Stop at 12,304' did not see a tag, PUH to 12,200'. Pump Plug #1 26 bbls of 15.8 class g cement. No Pressure bump. PUH to safety and WOC. Injection 1.1 bpm @ 1458 psi. Pump Plug #2 25.5 bbls 15.8 ppg class g cement. Little Press Increase WP at end 56 psi. PUH to safety and WOC. ***Job Continued on 1/28/23 *** 1/28/2023 CTU#9 1.75" Coiled Tubig (0.156 wall) Job Scope: Pre CTD: Mill XN, Cement Plug ***Job coontinued from 1/27/23*** WOC, Attempted to pump, 1 bbl/m @ 314 psi. RIH to 12,200' down squeeze Plug #3: Pump 5 bbls FW. Pump 3 bbls neat cmt 15.8 ppg Class G. Pump 10 bbls 15.8 ppg w/ 4 #/bbl Bridge Maker. Pump 6 bbls neat cmt 15.8 ppg (Total of 19 bbls). 5 bbls FW. 15 bbls slick 1% kcl w/ SL. When Cmt hit perfs already had 200 psi bump on WHP. Got 6.5 bbls Cmt underneither (5.1 in perfs) and WHP climbed 1400 psi. Lay in 12.5 bbls Cmt to TOC 11,770'. PUH to 11,000'. 30 mins after cmt at 11,770'. Squeeze 1531 psi for 15 mins. RIH cleaning out w/ PowerVis down to 11,950' 5/8" ball on nozzle. PUH washing. POOH 80% w/ 1 % slick kcl w/ SL. At surface make drift ball catch, pop on well and pump 1-3/16" drift ball. RIH to 2750 and freeze protect well with diesel. RDMO. ***Job Complete*** 2/3/2023 ***WELL S/I ON ARRIVAL*** (CTD) DRIFT w/ TEL & 1.75" S.BLR. LOCATE TTL @ 6,596' SLM (6,612' MD), 16' C/F, TAG CEMENT @ 11,937' SLM (11,953' MD). ***WELL S/I ON DEPARTURE*** 2/5/2023 LRS CTU 2, 1.5" Blue Coil, Job Objective: Mill/Underream pilot hole Travel from L-116 to 09-43. Standby for cold temps ***Continued on 02/06/23*** 2/6/2023 LRS CTU 2, 1.5" Blue Coil, Job Objective: Mill/Underream pilot hole Standby for cold temps. Weather breaks. MIRU. RIH with nozzle BHA to freeze protect down to 5600'. Make up BOT UR BHA. Tag at 11925' ctm. Mill easy to 11957'ctm. ***Job continued on 2/7/23*** 2/7/2023 LRS CTU 2, 1.5" Blue Coil, Job Objective: Mill/Underream pilot hole MIll/UR to 11973' ctm (12001MD - corrected off of TOC tag 2/3/23). Pump gel pill off bottom and chase ooh at 80% to surface. RBIH to freeze protect well with 42bbl of diesel. Laid down UR BHA. Upper blades caliper at 4.25" and lower blades calipered at 3.4". RDMO. ***Job Complete*** Activity Date Ops Summary 2/11/2023 Move sub and pit module from 09-09A to 09-43A. Back over well and set modules down. Accept rig at 00:00. Safe out rig. R/U cellar and steam lines. Take on rig water. Continue working on MIRU checklist 2/12/2023 RU checklists. Safe out cellar. LTT swab/ master to 3500#. Nipple down tree cap. Nipple up BOPE. Nipple up MPD line. Service stack and choke manifold. Fluid pack rig. PT new MPD line to 250/5000 psi. Pass. Shell test BOP to 250/5000 psi. Pass. Begin Initial BOPE Test. Test 1: IRV, Packoff, C7, C9, C10, C11. Test 2: Blind/Shears, R2, B2, C15. M/U and Install test joint. Test 3: Annular (3700 psi). Test 4: TIW #1, B1, B4. Test 5: Upper 2" Pipe/Slips, TIW #2, B2, B3. - Test 6: Lower 2" Pipe/Slips, C5, C6, C8, TV2. Test 7: Choke A, Choke C. Drawdown Test on Accumulator. Record closing times and N2 bottle pressures. Test 8: C1, C4, TV1. Test 9: 2-3/8" Pipe/Slips, C2, C3. N/D Test Riser. N/U drilling riser. Test Rig H2S and Methane Gas Alarms - Pass. Install BHI Floats. PT PDL's to 3500 psi. Pass. Thaw frozen lines on rig. Fluid pack coil reel with 10 bbls neat methanol spear. Follow with 140 degree slick 1% KCL w/0.6% safe lube. Shut down pumping when methanol at nozzle. Open well to a closed choke and record WHP. 0 psi on well. 1 bbl to fill. Flow check well. 2/13/2023 Complete extended flow check. Well static. PJSM, Discuss open hole deployment of BHA. Make up BHA# Cement pilot hole. RIH with BHA #1 Cement pilot hole. Rate: 1.01 bpm in, 1.33 bpm out. Circ pressure: 637 psi. Mud Weight: 8.44 ppg in, 8.44 ppg out. Log down for tie-in from 10,760' to 10836.24 MD (HRZ) with -9 correction. Rih and tag at 11969' MD. PU and bring pumps up to rate. Mill down. Stalling as soon as we touch down on 11973. On third stall trying to time drill. Bit stuck. PU to max on HOT. PU to neutral and bring pumps on. PU clean. Pump 10 bbls HiVis Jet on bottom with pill. Chase out of hole. Pump 20 bbls HiVis. Rih above TD and time mill to get a pattern started. Slight motor work increase at 11973.6'. Stalled and stuck at 11974.64' Free coil. Pump sweep up hole. Send second sweep. Stage bit off bottom. Jet on bottom. POOH. Continue POOH for mill change. Rate: 2.63 bpm in, 2.38 bpm out. Circ pressure: 3030 psi. - Mud Weight: 8.31 ppg in, 8.41 ppg out. OOH - Flow Check well and confirm no flow. L/D mill and M/U new mill with side cutters. Replace leaking hydraulic hose on injector cart. M/U injector to well - PT QTS. RIH with BHA #2. Rate: .94 bpm in, 1.25 bpm out. Circ pressure: 730 psi. Mud Weight: 8.31 ppg in, 8.41 ppg out. IA = 47, OA = 0. Log Tie In from 10760' @ 5 fpm. Correct -8.5'. PUW = 48k, RIW 25k. - Rate: 1.79 bpm in, 1.87 bpm out. Circ pressure: 2122 psi. Mud Weight: 8.31 ppg in, 8.41 ppg out. Take weight at 11,976' and milled off. Continue milling 2.80" cement pilot hole from 12,000' to 12,035'. Rate: 1.79 bpm in, 1.87 bpm out. Circ pressure: 2122 psi. Mud Weight: 8.31 ppg in, 8.41 ppg out. ROP = 25 - 35 fph, WOB = 1.2 - 1.9k. Mill 2.80" cement pilot hole from 12,035' to 12,095'. PUW = 47k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.78 bpm in, 1.91 bpm out. Circ pressure: 2373 psi. Mud Weight: 8.31 ppg in, 8.41 ppg out. ROP = 25 - 40 fph, WOB = 1.2 - 1.9k. 2/14/2023 Mill 2.80" cement pilot hole from 12,095' to 12168'. PUW = 48k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2356 psi free spin. Mud Weight: 8.32 ppg in, 8.42 ppg out. ROP = 40-60 fph, WOB = 0.8- 1.2k.Stalled and took weight at 12168' MD. Mill 2.80" cement pilot hole from 12,168' to 12226'. PUW = 50k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2320 psi free spin . Mud Weight: 8.32 ppg in, 8.43 ppg out, ROP = 30-40 fph, WOB = 0.8- 1.2k. Stalled at 12182' MD. Clean PU. Mill 2.80" cement pilot hole from 12226' to 12238'.PUW = 52k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.89 bpm in, 1.83 bpm out. Circ pressure: 2418 psi free spin. Mud Weight: 8.32 ppg in, 8.43 ppg out. ROP = 30-40 fph, WOB = 0.8- 1.2k. Pump 10 bbl HiVis. Chase to surface. Open EDC and chase up to tie in depth. Log tie in with -1' correction. Rih and finish pumping bottoms up. Increase in cement returns of 20%. Sample given to Geologist. 99% cement with trace pipe scale and shavings. Close EDC. Min rate through pilot hole. Mill 2.80" cement pilot hole from 12238' to 12284'. PUW = 52k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2413 psi free spin. Mud Weight: 8.32 ppg in, 8.43 ppg out. ROP = 20-30 fph, WOB = 0.8- 1.0k. 12,242' Stalled. 12,282-84' Stalled x 4. Mill 2.80" cement pilot hole from 12284' to 12287'. PUW = 52k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2503 psi free spin. Mud Weight: 8.32 ppg in, 8.43 ppg out. ROP = 10 fph, WOB = 0.8- 1.0k. Mill 2.80" cement pilot hole from 12287' to 12292'. Rate: 1.83 bpm in, 1.89 bpm out. Circ pressure: 2368 psi free spin . Mud Weight: 8.33 ppg in, 8.42 ppg out. ROP = 10 fph, WOB = 0.8- 1.0k. Back ream 7-5/8" contact point from 12,100' to 12,060' @ 1 fpm. 45R, 45L, 180, 180. Drift pilot hole at min rate from 11,950' to TD @ 12,293'. Clean drift. Pump 23 bbl high vis sweep off bottom. Rate: 1.72 bpm in, 1.72 bpm out. Circ pressure: 3229. Mud Weight: 8.33 ppg in, 8.43 ppg out. POOH from 12,294'. Open EDC at 11,950' and POOH pumping max rate. Rate: 2.43 bpm in, 2.36 bpm out. Circ pressure: 3229. Mud Weight: 8.33 ppg in, 8.43 ppg out. Reverse jog at surface. OOH - Flow check and confirm no flow. L/D BHA #2 Mill gauged 2.80" GO, 2.79" NOGO. M/U BHA #3 w/2.75" whipstock drift and READ 24 finger caliper. Confirm caliper arms function at surface. RIH. Caliper arms programmed to open in 4.5 hrs (08:34). RIH with BHA #3 - Drift and caliper. Rate: .60 bpm in, .85 bpm out. Circ pressure: 546. Mud Weight: 8.32 ppg in, 8.43 ppg out. IA = 131, OA = 0. 2/15/2023 RIH with BHA #3 - Drift and caliper. Rate: .58 bpm in, .92 bpm out. Circ pressure: 555. Mud Weight: 8.33 ppg in, 8.44 ppg out. IA = 140, OA = 0. Wait on caliper arms to open at 12,287'. Log up from 12,287' to 10,800' at 50 fpm per READ logging specialist. Rate: .43 bpm in, .24 bpm out. Circ pressure: 413. Mud Weight: 8.33 ppg in, 8.44 ppg out. Stop coil and wait for caliper arms to collapse. POOH from 10,800'. Rate: .58 bpm in, .29 bpm out. Circ pressure: 476. Mud Weight: 8.34 ppg in, 8.43 ppg out. OOH, flow check well. Good no flow, pull & LD BHA. Verify good data, good data, call out BOT to MU and run WS while processing data for WS set. MU the WS BHA. BHA MU, RIH with open EDC. 10,790' Log tie in, correct depth -13'. RIH and drift WS to TD @ 12,293'. PUH to logging depth. Log CCL and GR from 11,900' to 12,290' @ 15 fpm. Confirm setting depth with town team. Close EDC and pressure up to 3400 psi. Set top of whipstock at 12,262'. Slack off 6.5k and confirm good set. POOH. POOH from 12,272.5'. Rate: 1.24 bpm in, .92 bpm out. Circ pressure: 1095. Mud Weight: 8.34 ppg in, 8.45 ppg out. OOH - flow check well and confirm no flow. Inspect last 30' of coil and L/D BHA #4. M/U swizzle stick and jet stack and return lines. M/U BHA #5 - Window Milling BHA. RIH with BHA #5. Rate: 1.15 bpm in, .92 bpm out. Circ pressure: 1103. Mud Weight: 8.35 ppg in, 8.44 ppg out. IA = 81, OA = 0. Log tie in from 10,850' @ 5 fpm. Correct -13'. Close EDC and RIH to begin window milling. 50-029-22078-01-00API #: Well Name: Field: County/State: PBE 09-43A Prudhoe Bay East Hilcorp Energy Company Composite Report , Alaska 2/16/2023Spud Date: 2/16/2023 Begin milling window at 12,263.0', establish a lip then apply max WOB for the first 1'. In Rate = 1.83, Out Rate = 1.80. Mud weight in = 8.35, Out = 8.45. IA = 57, OA = 0. Circ pressure = 2455 psi. 3 stalls before we were able to establish a starting point for a lip. Lip established start working up to max WOB for the first 1'. CSG appears to be soft, WOB at 1.5k no movement on TF, stop moving and WOB drills off, BOT hand wants to slow down a little to keep from popping out to soon. Milled 1' in 30 minutes, WOB is not drilling off as fast, WOB at 1.83k, start 1 FPH time milling at 12,264.0'. Milling window at 12,265.0'. In Rate = 1.80, Out Rate = 1.81. Mud weight in = 8.33, Out = 8.44. IA = 184, OA = 0. Circ pressure = 2651 psi, WOB = 2.01k. Milling window at 12,267.0'. In Rate = 1.80, Out Rate = 1.83. Mud weight in = 8.33, Out = 8.45. IA = 246, OA = 0. Circ pressure = 2542 psi, WOB = 1.65k. 12270.0' Window mill should be at the bottom of the window, continue, milling at 1 FPH to dress the bottom of the window with the string mill. In Rate = 1.81, Out Rate = 1.84. Mud weight in = 8.33, Out = 8.44. IA = 296, OA = 0. Circ pressure = 2661 psi, WOB = 0.5k. 12270.85' WOB dropped off, string mill should be out, start milling Rat Hole. In Rate = 1.82, Out Rate = 1.82. Mud weight in = 8.34, Out = 8.45. IA = 337, OA = 0. Circ pressure = 2851 psi, WOB = 0.02k. Mill to 12,280' bottom of rat hole. Begin back reaming passes. In Rate = 1.85, Out Rate = 1.88. Mud weight in = 8.34, Out = 8.45. IA = 371, OA = 0. Circ pressure = 2920 psi, WOB = 1.3k. Complete back reaming passes. Confirm 10% formation sand in bottoms up sample. Dry drift window and rat hole clean. Pump high vis sweep from TD. POOH from 12,280' pumping min rate through cement pilot hole. Open EDC at 11,938'. POOH from 11,938' pumping max rate. In Rate = 1.85, Out Rate = 1.88. Mud weight in = 8.34, Out = 8.45. OOH - Flow check well and confirm no flow. Inspect last 30' of coil. L/D BHA#5. Mill and reamer gauged 2.81" GO, 2.80" NOGO. M/U swizzle stick and jet stack and surface lines. M/U and RIH with BHA #6 - Build BHA. In Rate = .32 bpm, Out Rate = .76 bpm. Mud weight in = 8.30 ppg, Out = 8.45 ppg. IA = 91 psi, OA = 0. Log tie in from 10795' @ 5 fpm. Correct -13'. Begin displacing to new PowerPro mud system. In Rate = 1.04 bpm, Out Rate = .99 bpm. Mud weight in = 8.54 ppg, Out = 8.44 ppg. IA = 121 psi, OA = 0. Close EDC and RIH through cmt pilot hole and window. Drill build section from 12,280' to 12,285'. In Rate = 1.75 bpm, Out Rate = 1.80 bpm. Mud weight in = 8.60 ppg, Out = 8.45 ppg. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR2AC DATE:2/13/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1901070 Sundry #322-714 Operation:Drilling:Workover: X Explor.: Test:Initial: X Weekly:Bi-Weekly:Other: Rams:250 / 5000 Annular:250 / 3500 Valves:250 / 5000 MASP:2461 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2"P Trip Tank P P Annular Preventer 1 7 1/16" GK P Pit Level Indicators P P #1 Rams 1 Blind/Shears P Flow Indicator P P #2 Rams 1 2.0" Pipe/Slip P Meth Gas Detector P P #3 Rams 1 2 3/8" Pipe/Slip P H2S Gas Detector P P #4 Rams 1 2.0" Pipe/Slip P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"P System Pressure (psi)3000 P Kill Line Valves 1 2-1/16"P Pressure After Closure (psi)2200 P Check Valve 0 NA 200 psi Attained (sec)19 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)57 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1050 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):10@1940 P No. Valves 12 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 4 P #1 Rams 2 P Coiled Tubing Only:#2 Rams 3 P Inside Reel valves 1 P #3 Rams 3 P #4 Rams 2 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/12/23 06:21 Waived By Test Start Date/Time:2/12/2023 20:00 (date)(time)Witness Test Finish Date/Time:2/13/2023 0:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Re-tested #4 Ram(Lower 2" Pipe/Slip) after test hose fitting failed. N.Wheeler/ T. Henson Hilcorp North Slope LLC J.Perl/R. Burnett PBU 09-43 Test Pressure (psi): nathan.wheeler@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022)2023-0213_BOP_Nabors_CDR2AC_PBU_09-43          J. Regg; 6/12/2023 12260 x2, 12234, 12301 12.21.2022 322-714 By Anne Prysunka at 11:30 am, Dec 27, 2022 Revised 12/27/2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.12.21 13:47:03 -09'00' Monty M Myers DLB 12/29/2022 10-407X DSR-1/3/23MGR29DEC22 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) alternate plug placement approved for P&A. Brett W. Huber, Sr. GCW 01/13/23JLC 1/13/2023 1/13/23 RBDMS JSB 011723 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: December 21, 2022 Re: PBU 09-43 Sundry Request Sundry approval is requested to set a whipstock and mill the window in 09-43, as part of the pre-rig and drilling/completing of the proposed 09-43A CTD lateral. Proposed plan for 09-43A Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, caliper and MIT. E-line or service coil will mill XN nipple. See 09-43A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A 3-1/2"x7-5/8" HEW whipstock will be set with the rig. Contingency cement squeeze HEW in place (to be determined per calliper run). A 2.80" window +10’ of formation will be milled out of the 7-5/8” casing. The well will kick off drilling in the Ivishak Zone 2 and land in the Ivishak Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner and cemented in place. The well will be selectively perforated post rig (see future perf sundry). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing Ivishak perforations via the contingency whipstock cement squeeze and the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start January 2023): 1. Slickline: Dummy WS drift and Caliper Log a. Drift past whipstock setting location b. Run Caliper over whipstock setting location 2. Fullbore: CMIT-TxIA and MIT-T to 2,500 psi 3. E-line or Coil: Mill XN Nipple a. Mill nipple at 6,590’ MD to 2.80” 4. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU 09-43A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,461psi a. Give AOGCC 24hr notice prior to BOPE test 2. Set Whipstock 3. Contingency – Cement Squeeze Whipstock* 4. Mill Window 5. Drill Build and Lateral 6. Run and Cement Liner* 7. Perforate (only if not done post-rig) 8. Freeze Protect and RDMO 9. Set LTP* (if needed) and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Sundry 322-714 PTD 222-157 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 December 30, 2011 - FEB 2 2 2012 Mr. Tom Maunder � � 1 0 n Alaska Oil and Gas Conservation Commission 6 . J 333 West 7 Avenue Anchorage, Alaska 99501 o9 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, - Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09-02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09 -11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09-13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09 -15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09 -16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09 -17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09 -19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09 -22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09 -24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09 -25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09-26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09 -29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09 -31C 1960640 50029213960300 0.2 NA 0.2 NA 1.7 7 /27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09 -34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7 /27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09 -37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10 /20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 1.2 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 , 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak - 7 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/16/2010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 10.2 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 _ 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 K I:: t,,1:: I V I:: U . STATE OF ALASKA. SEP ;.~ 8 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD 2. Operator Name: 3. Address: Repair Well 0 Pull TubingD Operation ShutdownD Plu¡:¡ PerforationsD Perforate New PoolO Perforate 0 Stimulate [&:J WaiverD OtherD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ŒJ StratigraphicO 9. Well Name and Number: 09-43 ExploratoryD ServiceD 6. API Number 50-029-22078-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 51.00 8. Property Designation: ADL-028343 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth measured 12575 feet true vertical 9012.0 feet Effective Depth measured 12460 feet true vertical 8936.0 feet Plugs (measured) Junk (measured) Top of Tubing Tail Junk @ 12284 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H-40 34 144 34.0 144.0 1490 470 SURFACE 4249 10-3/445.5# J-55 33 - 4282 33.0 - 3508.0 3580 2090 PRODUCTION 12517 7-5/8" 29.7# L-80 32 - 12549 32.0 - 8995.0 6890 4790 SCAB LINER 5551 5-1/2"17# 13Cr80 6528 - 12079 4988.0 - 8674.0 7740 6280 Perforation depth: Measured depth: 12230-12235,12254-12264,12306-12325, 12333-12351, 12356-12388, 12388-12414 True vertical depth: 8781-8784,8797-8804,8833-8846,8851-8864, 8867-8888, 8888-8905 Tubin¡:¡ ( size, ¡:¡rade, and measured depth): 4-1/2" 12.6# 13CraO 3-112" 9.2# 13CraO @ 29 @ 6517 6517 6612 t"'/'" \~. \~;;:'" ,'.',5; \'¿'4'~I;~'" t\; l....~\,' [. I:}' ')N\~\ ~.t (,.;; ~t~......""" Packers & SSSV (type & measured depth): 7-5/8" Baker S-3 Packer 4-1/2" HES X Nipple @ 6513 @ 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 429 SI Representative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 1118 8204 o 0 Tubin Pressure 229 322 14. Attachments: ~ 15. Well Class after proposed work: Exploratory(] 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr A Form 10-404 Revised 4/2004 Title Petroleum Engineer Signature Phone 564-5174 Date 9/27/06 . . 09"43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/03/2006 BOPD: 252 BWPD: 2,596 MCFPD: 3,064 AL Rate: 2,000 08/03/2006 ASRC Well Test 2848 bfpd 252 bopd 90.18% W/C 1.064 mmscf/d 2.0 mm G/L 4213 GOR 113<>1' wht 176 beans 08/02/2006 CTU #5 Acid Stimulation. RIH with 2.25" JSN to 12000'. Kill well with 1% KCL. Displace CT with 3% NH4CI. Bullhead 205 bbls of NH4CI, 30 bbls SafeLube pill and 143 bbls diesel. Initial injection pressure with well loaded at 2 bpm was <50 psi. Pumped 29.5 bbls 7% HCI, 28 bbls 9:1 Mud Acid and over displaced into perforations by 10 bbls with 3% NH4CI. Due to the low BHP, no obvious breakdowns were seen when the either acid hit formation. POOH pumping CT displacement down backside with diesel. While POOH, stacked out G/L on IA. RDMO CTU and turn well over to ASRC for flowback. Notified pad operator of well status. Final T/I/O: 1037/175010 *** Job Complete *** 08/01/2006 CTU #5...MIRU..RIH with 2.25" JSN. 07/30/2006 TIIIO = 1680/600/VAC. Temp = S/I. WHPs, IA FL (post TIFL, pre Acid). TBGP and OAP unchanged overnight. lAP increased 10 psi, IA FL unchanged. FLUIDS PUMPED BBLS 15 50/50 Methanol Water 158 Diesel 430 1 % KCL Water 30 1 % KCL with 0.6% Safe Lube 290 NH4CL Acid 29 7% HCL Acid (Titration 7.2% HCL; Iron < 20 ppm 28 9:1 Mud Acid (Titration 9.2% HCL, 0.9% HF; Iron < 20 ppm) 50 Soda Ash 1030 TOTAL Page 1 TREE = WB..LHEAD = ACTUATOR = KB. B..E\! = BF. B..E\! = KOP= Max Angle = Datum MD = Datum TV D = 900' 52 @ 3200' 12334' 8800' SS FMC FMC OTIS 51' 09-43 SAFETY NOTES: ***CHROME TBG & SCAB LNR*** 110-3/4" CSG, 45.5#, J-55, ID = 9.953" I 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" I 6513' Minimum ID = 2.750" @ 6590' 3"1/2" HES XN NIPPLE 13-112" TBG, 9.2#, 13-CR-80, .0087 bpf, ID = 2.992" I 6612' 5-1/2" SCAB LNR, 17#, 13CR80 NEW V AM, .0232 bpf, ID = 4.892" PERFORA TION SUMMARY REF LOG: CNL ON 08/23/90 ANGLE AT TOP PERF: 46 @ 12230' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 12230 - 12235 0 07/12/94 2-1/8" 4 12254 - 12264 0 07/12/94 2-1/8" 2 12306 - 12325 0 02/12/92 2-1/8" 2 12333 - 12351 0 02/12/92 2-1/8" 4/8 12356 - 12388 0 07/12/94 2-5/8" 4 12388 - 12414 S 09/15/90 I PBTD I 12460' 17-5/8" CSG, 29.7#, L-80, ID = 6.875" I ~ DATE 09/02/90 04/01/00 02/09/05 02/13/05 11/14/05 REV BY COMMENTS ORIGINAL COM PLETION RWO N4ES RWO DA V /TLH GL V C/O RAClTLH DRLG DRAFT CORRECTIONS DATE REV BY 2005' -14-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRB..S DE\! TYÆ VLV LATCH 50 KBG DOME BK 48 KBG SO BK PORT DATE 16 02/13/05 20 02/13/05 ST MD TVD 2 3789 3175 1 6424 4917 6492' -14-1/2"HESXNIP,ID=3.813" -17-5/8" X 4-1/2" BKR S-3 A<R, ID = 3.875" -14-1/2" X 3-1/2" XO, ID = 2.992" I 7-5/8" X 5-1/2" BKR ZXP LNR TOP A<R & BKR HMC HNGR, ID = 4.937" -13-1/2" HES X NIP, ID = 2.813" I -13-1/2" HES XN NIPw/NO GO,ID= 2.75" 1 -13-1/2" WLEG, ID = 2.920" I H ELMD TT LOGGED 08/14/05 12284' -1 TOP OF TBG TAIL JUNK I COMMENTS PRUDHOE BA Y UNrr WELL: "09-43 PERMrr No: "1901070 API No: 50-029-22078-00 SEC 32, T10N, R15E, 77.98' FB.. & 2224.6' FNL BP Exploration (Alaska) STATE OF ALASKA, DECEIV ALASKA JL AND GAS CONSERVATION ce. .MISSION' . ED REPORT OF SUNDRY WELL OPERATIONS 04 2005 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028343 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Scab Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): AIStlk:a Oil & Gas Cons. Commission Anchoraao 0 Otñer 0 Time Extension IBI Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 52' 12575 9012 12460 8936 110' 4282' 12549 5551' 4. Current Well Class: IBI Development 0 Exploratory . 0 Stratigraphic 0 Service 5. Permit To Drill Number: 190-107 6. API Number: 50-029-22078-00-00 99519-6612 9. Well Name and Number: PBU 09-43 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) 12276 feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 10-3/4" 4282' 3508' 3580 2090 7-5/8" 12549' 8995' 6890 4790 5-1/2" 6528' - 12079' 4988' - 8674' 7740 6280 SCANNED MAR 1 0 2005 12230' - 12388' 8781' - 8888' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Printed Name Terrie Hubble Signature ./fÓMli, f!, .JW -( Form 10-404 Revised 04/2004 4-1/2", 12.6# x 3-1/2",9.2 13Cr80 6612' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'X' Nipple 6513' 2005' Treatment description including volumes used and final pressure: RBDMS BFl MAR 0 7 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure 7,202 6,340 2,385 6,062 15. Well Class after proposed work: 0 Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nick Miller, 564-4746 N/A Oil-Bbl Prior to well operation: 632 Subsequent to operation: 176 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram 13. TubinQ Pressure 1,500 300 Title Technical Assistant 0 f) ,p~..' ~ ~\' l~sk-4628 .> ~ \ ! \.j 1 Q ,J ¡- \ -L. Date 03jOl/(OS Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only ,'" Well: Field: API: Permit: ) 09-43 Rig Workover Prudhoe Bay Unit 50-029-029-22078-00-00 190-107 Accept: Spud: Release: Ri9: 02/01/05 N/A 02/09/05 Nabors 4ES PRE-RIG WORK 01/18/05 DRIFTED W/3.70 CENT & S.B. TO COLLAPSE AT 6480' SLM (NO SAMPLE). 01/22/05 CHEM CUT 4-1/2" TBG AT 6506'. 4 RUNS: GR-CCL I TBG PUNCH I STRING SHOT I CHEM CUT, ALL SHOTS FIRED, TIED INTO TUBING TALLY DATED 29-MAR-2000. Jj, " ) ) . BPEXPLQRA TION , , Operati ()ns .$u IJ1l11aryRepor,t Page 1,' of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-43 09-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Sta rt: 1/31/2005 Rig Release: 2/9/2005 Rig Number: ' Spud Date: 8/7/1990 End: 2/9/2005 Date From- To Hours Task Code NPT Phase Description of Operations 2/1/2005 00:00 - 04:00 4.00 MOB P PRE Move from DS 12 to DS 9-43. Distance 7.8 miles. 04:00 - 05:30 1.50 RIGU P PRE Lay down Herculite & matting boards. Spot rig sub over well. Spot in pits & pipe shed. Set camp. 05:30 - 06:30 1.00 RIGU P PRE Raise & scope up derrick. Pin same. Con't to R/U equip. 06:30 - 07:00 0.50 RIGU P PRE R/U lines to pits & sub. 07:00 - 09:00 2.00 RIGU P DECOMP R/U lines to tiger tank & X-mas tree. Take on 120 degree seawater. RIG ACCEPTED @ 0700 hrs. 09:00 - 11 :00 2.00 WHSUR P DECOMP P/U lubricator & pull BPV. UD lubricator & plug. 11 :00 - 11 :30 0.50 KILL P DECOMP Hold PJSM & Pre-spud meeting. Review H2S & kill requirements. Teat lines to 3500 psi, Ok. 11 :30 - 18:00 6.50 KILL P DECOMP Open well, SITP 0 psi, SICP 40 psi. Kill well, 3 BPM @ 40 psi. Pumped 481 bbls. SID observe well. 18:00 - 19:00 1.00 WHSUR P DECOMP Monitor well. well dead. Set BPV. Blow down lines. 19:00 - 20:00 1.00 WHSUR P DECOMP N/D & remove X-mas tree. Inspect hanger. Threads good, 9" LH ACME. 20:00 - 22:30 2.50 BOPSUF P DECOMP N.lU BOPE. 22:30 - 23:00 0.50 BOPSUF P DECOMP Hold PJSM & Pre-spud mtg wI all personnel. Review H2S safety. 23:00 - 00:00 1.00 BOPSUP P DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones wI AOGCC @ 1830 hrs, 2-1-2005. 2/2/2005 00:00 - 03:00 3.00 BOPSUF P DECOMP Con't to test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. 03:00 - 04:30 1.50 WHSUR P DECOMP Blow down & RID lines. Pull & UD test plug. P/U lubricator & pull blanking & BPV. LID same. 04:30 - 05:30 1.00 PULL P DECOMP M/U landing jt & XOs. BOLDS. Pull hanger to floor. P/U wt = 73K. Tubing free wI no overpull. UD landing jt & hanger. 05:30 - 13:30 8.00 PULL P DECOMP POOH & UD 41/2" completion. Chem. cut looked good, cut was right below collar on GLM. 13:30 - 15:00 1.50 PULL P DECOMP R/U to run 3-1/2" DP. Tally drill collars. M/U Overshot fishing BHA. 15:00 - 21 :30 6.50 PULL P DECOMP PJSM. RIH wI overshot to fish "K" Anchor, picking up 3 1/2" DP 1 x 1. 21 :30 - 22:00 0.50 PULL P DECOMP P/U kelly. break circulation & tag up on fish @ 6500'. Work overshot down over fish w/1 OK. P/U wI no overpull. rotate wI no torq. Set down 2nd time, went to 6502'. P/U & tag again. Blow down & set back kelly. 22:00 - 23:00 1.00 PULL P DECOMP Cut & slip 84' of drilling line. Adjust brakes. 23:00 - 00:00 1.00 PULL P DECOMP POOH & stand back DP. 2/3/2005 00:00 - 01 :30 1.50 PULL P DECOMP POOH & stand back DP. 01 :30 - 02:30 1.00 PULL P DECOMP Set back DCs. Break down Overshot & recover 8.2' of 4 1/2' tbg. Bottom jagged. Apparently have less than l' of jagged tbg looking up above the 4 1/2" x 3 1/2" X-over. 02:30 - 03:00 0.50 PULL P DECOMP Clear & clean rig floor. Redress O/S to fish X-over (BHA #2). 03:00 - 04:30 1.50 PULL P DECOMP RIH wI Drill string & BHA #2 to 6486'.. 04:30 - 05:00 0.50 PULL P DECOMP P/U kelly. break circulation. Work down over fish. Had to repreat several times kept pulling off fish. Rotate down & stack up to 24K. Grabbed fish & P/U. Bled off jars & pull, have 4-6K additional wt. P/U 94K, S/O 72K Rot 84k. Blow down & set back kelly. 05:00 - 08:00 3.00 PULL P DECOMP POOH wI drill string. 08:00 - 09:30 1.50 PULL P DECOMP PJSM. UD overshot & BHA. UD fish...recovered 41/2" x 31/2" x/o, (12) jts 3 1/2" tbg, 10' pup, & crossover to "K" Anchor. Printed: 2/14/2005 9:25: 14 AM ....:( " ) ) , BP EXPLORATION Qperation!; Summary'Report Page 2 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-43 09-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/31/2005 Rig Release: 2/9/2005 Rig Number: Spud Date: 8/7/1990 End: 2/9/2005 HQurs Task Code NPT ,Phase Description of Operations 2/3/2005 08:00 - 09:30 1.50 PULL P DECOMP Crossover extremely corroded wI multiple holes & severe thread damage. Consult town.....opt to make cleanout run to XIN nipple below packer. 09:30 - 12:30 3.00 PULL P DECOMP Order & wait on tools. 12:30 - 14:30 2.00 CLEAN P DECOMP PJSM. M/U cleanout BHA. 14:30 - 19:00 4.50 CLEAN P DECOMP PJSM. RIH wI motor & mill assembly for packer I tailpipe cleanout on 3 1/2" DP. 19:00 - 20:00 1.00 CLEAN P DECaMP Bit hung up @ top of liner@ 6532'. Attempt to work thru. no good. P/U kelly & break circulation. Attempt to rotate down thru liner. Motor stalled. P/U & motor pressured up. Attempt to unplug. No joy. Drop dart. Open circ sub. 20:00 - 23:30 3.50 CLEAN P DECOMP POOH wi drill string. 23:30 - 00:00 0.50 CLEAN P DECOMP UD BHA. Lots of scale. Bottom stand had 10-12 of scale. 2 1/16" CS Hydil pipe plugged & motor.. Intermittant plugging og 27/8" PAC pipe. 2/4/2005 00:00 - 01 :30 1.50 CLEAN P DECaMP Clean out scale in BHA. P/U new motor & BHA. 01 :30 - 04:30 3.00 CLEAN P DECaMP RIH wI BHA on 31/2" DP. RIH 10 stands. P/U circulating pin & check motor. DP pressured up. attempt 2nd time, DP plugged. POH wI wet string. 1 st stand found ice plug in 2nd connection. M/U circ pin & check motor, motor good. LID #1 stand. 04:30 - 09:00 4.50 CLEAN P DECaMP Con't RIH wI motor. Test motor every 14 stands by pumping (1) DP volume. 09:00 - 10:30 1.50 CLEAN P DECOMP Tag top of liner @ 6531' DPM, (3') in on stand #264. 80K up wt, 60K down. Stand back stand & pick up single wI headpin. Line up & pump down DP @ 3 bpm, see pressure increase indication DP full & reduce rate to 1 1/2 bpm @ 50 psi. Slack off & motor thru TOL, OK. Continue in hole to packer. M/U headpin on Jt #204. Pump down DP @ 1 1/2 bpm @ 225 psi & motor on thru packer, seeing a bit of resistance @ 6994'. Work thru OK & pick up #205. Motor on down wI no resistance to 7030', approximately 10' below XIN nipple. Pick up & ream down thru top of packer (3) times, no problem. 10:30 - 13:00 2.50 CLEAN P DECOMP PJSM. POOH wI cleanout BHA. 13:00 - 14:30 1.50 CLEAN P DECOMP PJSM. UD cleanout BHA. 14:30 - 17:00 2.50 CLEAN P DECOMP PJSM. R/U slickline & make up tools. 2.74" swedge, 5' of stem, 2.60" swedge & tubing end locator. 17:00 - 17:30 0.50 CLEAN P DECOMP RI H wI slickline, thru liner top, OK. Unable to enter packer @ 6995'. 17:30 - 18:00 0.50 CLEAN P DECOMP POOH wI slickline to rearrange tools. 18:00 - 22:00 4.00 CLEAN P DECaMP RIH wI 2.6" & then 2.5" drifts. could not get thru SABL-3 packer @ 6987 SLM. POOH & RID Slickline equip. 22:00 - 23:00 1.00 CLEAN P DECOMP UD 7" Otis extension. Pull wear Bushing. P/U & set test plug. 23:00 - 00:00 1.00 CLEAN P DECOMP Begin testing BOPE as per AOGCC/BP requirements. 2/5/2005 00:00 - 04:00 4.00 CLEAN P DECOMP Test BOPE as per regulations. LP 250 psi, HP 3500 psi. Tested Accum., Ann., rams, All valves & kelly. 1 extra stabbing valve, which had just been rebuilt, failed. All other equip tested good. Witnessing of test waived by AOGCC rep Chuck Sheve. 04:00 - 04:30 0.50 CLEAN P DECaMP RID test equip. Pull test plug. Blow down lines. Set Wear bushing. 05:00 - 06:30 1 .50 CLEAN P DECOMP M/U BHA wI 2.75" bit & motor. 06:30 - 12:00 5.50 CLEAN P DECOMP PJSM. RIH wi cleanout BHA, pumping drill pipe volume every 18 stands to flush pipe. 12:00 - 13:30 1.50 CLEAN P DECOMP Tag top of 51/2" liner @ 6532'. Stand back stand & mlu Printed: 2/14/2005 9:25: 14 AM . . ) ') BPEXPLORATION ' , , 9peratiol1sSummaryRE!Port, , Page 3 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-43 09-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/31/2005 Rig Release: 2/9/2005 Rig Number: Spud Date: 8/7/1990 End: 2/9/2005 . Date From- To Hours 'Task Code, NPT Phase , Description of Operati()ns 2/5/2005 12:00 - 13:30 1.50 CLEAN P DECOMP headpin on single & motor thru TOL, OK. Continue in hole & single in. M/U headpin on jt # 204. 97K up wt, 65K down. Tag top of packer/"K" Anchor 14' in on # 204 @ 6990' DPM. 13:30 - 19:30 6.00 CLEAN N DPRB DECOMP PJSM. Commence milling on what is most likely the corroded pin end, (looking up), of the "K" Anchor that was perhaps folded over during slickline ops. See many & frequent stalls, milling wI very little WOB, pumping @ 1 1/2 bpm @ 100-125 psi. Made approx 2", no progress in final 2 hrs. 19:30 - 22:00 2.50 CLEAN N DPRB DECOMP POOH wI motor & speed mill assy. 22:00 - 23:00 1.00 CLEAN N DPRB DECOMP Break out & LID Motor & Speed mill assy. 23:00 - 23:33 0.55 CLEAN N DPRB DECOMP Clear & clean rig floor. 23:33 - 00:00 0.45 CLEAN N DPRB DECOMP Strap & begin making up BHA #6 to mill packer. 2/6/2005 00:00 - 01 :30 1.50 CLEAN N DPRB DECOMP M/U BHA #6 to mill packer as follows: Mill, 2 Extensions, Drive Sub, PxP, 3 Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, XO, 13 * 3 1/8" DCs, 15 jts 2 7/8" PAC DP, XO. TL = 892.70'. 01 :30 - 04:30 3.00 CLEAN N DPRB DECOMP RIH wI BHA #6 on 31/2" DP. 04:30 - 06:00 1.50 CLEAN N DPRB DECOMP RIH to 6984'. P/U kelly, pump & beging milling on packer @ 6994' P/U Wt =1 02K, SIO Wt = 76K, Rot Wt = 85K. 70-80 RPMs, 3-4K WOB, 2 BPM @ 125 psi. Torq = 3.5-4.5K. 06:00 - 11 :00 5.00 CLEAN N DPRB DECOMP Continue milling on packer. See a few stalls wI 5000 f/tlbs of torque at surface. Circulating @ 1-2 bblslmin, no returns. Overpull to 140K, (40K over up weight),when coming off bottom after stall. 11 :00 - 16:00 5.00 CLEAN N DPRB DECOMP Continue milling W/5-8K WOB. WI 3' milled off, see weight drop & packer fall free. 16:00 - 17:30 1.50 CLEAN N DPRB DECOMP Push packer to 7394'. 17:30 - 20:30 3.00 CLEAN N DPRB DECOMP POOH & stand back 3 1/2" DP. 20:30 - 22:00 1.50 CLEAN N DPRB DECOMP POOH wI BHA & LID unneeded components. 22:00 - 22:30 0.50 CLEAN N DPRB DECOMP CLean out junk baskets. Only had a small amount of metal & shavings in lowest basket Clear & clean rig floor. 22:30 - 00:00 1.50 CLEAN N DPRB DECOMP M/U new BHA to push packer to bottom. P/U additional 2 7/8" PAC DP. 2/7/2005 00:00 - 00:30 0.50 CLEAN N DPRB DECOMP Con't to P/U 162 jts of 2 7/8" PAC DP to push packer to bottom. 00:30 - 03:30 3.00 CLEAN N DPRB DECOMP P/U 162 jts 2 7/8" PAC DP, 1x1 & RIH to push packer to bottom.RIH wI BHA #7 on 31/2" DP. Push packer from 7394. 03:30 - 06:00 2.50 CLEAN N DPRB DECOMP Change out tools for 3 1/2" DP & con't to RIH wI BHA #7. Tagged top of liner & had to rotate to go thru. Con't to RIH & push packer to bottom. 06:00 - 09:00 3.00 CLEAN N DPRB DECOMP PJSM. Continue in hole. Tag packer @ 11,331' & push wI 3-5K to final depth of 12,276'. Take weight, (10-15K), @ 10,276' . 09:00 - 11 :30 2.50 CLEAN N DPRB DECOMP POOH w/3 1/2" DP & cleanout BHA 11 :30 - 16:30 5.00 CLEAN N DPRB DECOMP PJSM. LID (177) jts 2 7/8" PAC & (13) 31/8" DCs & BHA 16:30 - 18:00 1.50 CLEAN P DECOMP Clear & clean rig floor. Load & tally new BHA. 18:00 - 19:00 1.00 CLEAN P DECOMP M/U BHA # 8 to scrape casing as follows: MM Mill, 2 Boot Baskets, 7 5/8" Casing Scraper, BS, Bumper Sub, Jars, 6 * 4 3/4" DCs. TL = 220.09'. 19:00 - 21 :30 2.50 CLEAN P DECOMP RIH & scrape casing to to top of liner @ 6533'. Pump 25 bbls & flush casing. P/U 100K, SIO 65K. 21 :30 - 23:30 2.00 CLEAN P DECOMP POOH WI BHA #8 & stand back DP. 23:30 - 00:00 0.50 CLEAN P DECOMP Break out & LID BHA #8. 2/8/2005 00:00 - 00:30 0.50 CLEAN P DECOMP Finish LID BHA # 8. Clear & clean rig floor. Printed: 2/14/2005 9:25: 14 AM .' ) ) BP<EXPLORATION, , , ,Qperatlons. $ummCiryREJPort Page40f4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-43 09-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Sta rt: 1 /31 /2005 Rig Release: 2/9/2005 Rig Number: Spud Date: 8/7/1990 End: 2/9/2005 Date From- To Hours' Task Code NPT Phase Description öfOperations 2/8/2005 00:30 - 04:00 3.50 CLEAN P DECOMP P/U RTTS. RIH, space out & set RTTS, @ 6523' w/24K down weight. P/U = 97K, SIO = 64K. 04:00 - 05:30 1.50 CLEAN P DECOMP Fill Hole wI 51 bbls. FL @ +1-1500'. 05:30 - 06:30 1.00 CLEAN P DECOMP Pressure test casing to 3500 psi f/30 minutes. Held solid. O/A @ 0 psi throughout test. Bleed all pressure. Open pipe rams. 06:30 - 07:00 0.50 CLEAN P DECOMP PJSM. Release RTTS. 07:00 - 12:30 5.50 CLEAN P DECOMP POOH & LID 31/2" DP. 12:30 - 13:30 1.00 CLEAN P DECOMP PJSM. Slip & cut 84' of drilling line. 13:30 - 14:30 1.00 CLEAN P DECOMP PJSM. LID drill collars & Halliburton RTTS. Pull wear bushing. 14:30 - 16:30 2.00 RUNCOMP RUNCMP PJSM. Rig up to run 41/2" chrome completion. 16:30 - 17:00 0.50 RUNCOMP RUNCMP Pre job with all involved personel regarding running of completion string & phase II conditions. 17:00 - 00:00 7.00 RUNCOMP RUNCMP M/U 3 1/2" completion jewelry, Baker Locking all connections below packer. All connections torque turned. 4 1/2" 13cr 12.6# Yam Top connections torque turned to 4440 ftllbs. Ran a total of 153 jts 41/2" 13cr 12.6# Yam Top tubing. Fluted WLEG went into 5 1/2" liner without hanging up. 77K up wt, 54K down. 2/9/2005 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Continue in hole w/4 1/2" 13cr 12.6# Yam Top completion string. 01 :00 - 02:00 1.00 RUNCOMP RUNCMP M/U tubing hanger, land tubing, RILDs. 02:00 - 02:30 0.50 RUNCOMP RUNCMP Rig down handling equipment, tongs etc. 02:30 - 06:30 4.00 RUNCOMP RUNCMP PJSM. Line up & reverse circulate heated seawater @ 3 bpm I 50 psi, no returns. 250 bbls heated seawater followed by 200 bbls heated seawater wI corrosion inhibitor. 06:30 - 10:30 4.00 RUNCOIVP RUNCMP PJSM. Drop rodlball assembly. LID landing jt. Fill tubing, (13) bbls. Allow air to escape. Close blind rams & pressure tubing via kill line to 3500 psi, set packer. Test @ 3500 psi, bled 200 psi in 20 minutes. Bleed off & fluid pack casing above packer, (60) bbls to fill. Allow air to escape. Line up on tubing & pressure to 3500 psi. Bled 150 psi in 1 st 15 minutes, 70 psi in 2nd 15 minutes. Bled tubing to 2500 psi & pressure 7 5/8" casing to top of packer @ 6513' to 3500 psi. Held solid for 30 minutes, no bleed off. Monitored tubing while testing casing & noted tubing continued to bleed off, indicating leak is below packer & most likely the ball/rod seat. All tests charted & witnessed by company man. 10:30 - 14:00 3.50 RUNCOrvP RUNCMP PJSM. Set two way check valve & N/D BOPE. 14:00 - 16:00 2.00 RUNCOrvP RUNCMP N/U tree. Test tree & void to 5000 psi, OK. 16:00 - 17:00 1.00 RUNCOrvP RUNCMP PJSM. P/U lubricator, pull two way check. 17:00 - 18:00 1.00 RUNCOrvP RUNCMP PJSM. R/U Little Red. Test lines & reverse circulate 100 bbls diesel @ 2.0 bpm. 18:00 - 19:30 1.50 RUNCOrvP RUNCMP R/U and U- Tube Freeze Protect 19:30 - 20:00 0.50 WHSUR P RUNCMP Set BPV and Test to 1000psi with Little Red 20:00 - 21 :00 1.00 RIGD P RUNCMP Secure Well and Release Rig at 2100 Printed: 2/14/2005 9:25: 14 AM TREE = FMC ""'WELLhÆ:AD = FMC ACTUA TOR ;~--- 'OTIS 'KB'~' äéi;;;""'" '" ""51" . ."" ..... '"'' BF. ELEV = ". ... ,,'-,"",. ,," KOP= ".. ........ . .. ... ./lV. '" . Max Angle = .... ... ... ......, " ,- , Datum MD = .....""."..... """...."......." Datum TVD = From L. IG- DRAFT 9-43 ) - t----I 2006' l-i 4-1/2" HES X NIP, ID ~ 3.813" I L...... - .. GAS LIFT MANDRELS ~' .------- --- ..-~... :-'T ¡".:[J "¡-I CI [",~:'\'" ¡-; rF \/L" '_...', T"~: I r,,~';-: T ~:.'. '~-f , ""'..,,',,"',',M. ,". ... . 900' "I.. . . ,.........".... \1 52 @ 3200' " .........,. .... 12334' , ...."...... ...",....... 8800' SS 110-3/4" CSG, 45.5#, J-55, ID = 9.953" 1-1 4282' ~ 14..1/2" T8G,'!2.6#, 13.CR-80, .0'152 bpf, !D'" 3.958" l-i 6502' I---- ..u._ I ,:..~, , j .[ ',! ; :' -I ..' " '; 1" ',' [ , "'. 2 3789 3175 50 4.5" xi" lGVl BK . I I '. :,..¡ I 1. ' 1 . ~,' i} ,- 20/64 02/14/05 ~ 15 1/2" 17# SCAB LNR TOP, .0232 bpf, ID = 4.892" l-i ---.----i 6492' l-i 4..1/2" HES gel' "X" NIP (3.813" ID) .----1 6513' l-i 7..5/8" x 4..1/2" 8f<RS..3 PKR, 10"" 3.875" -,.-1 6511' l-i 4..1/2" x 3..1/2" XO.. ChrOlY1e 1 -<.-~~---I 6538' l-i ::H/2." HF:.8 ~ìcr "X" NIP (2.81 :.~" ID) -- --L,,,~~~g,:\ "I-ivu3~'1/?-"~f:::?,9~~r"~\~',\\ NIP , 001-1 ' , I I 1 Minimum ID ::::: 2750u @ 6590' 3 1/2" HES XN NIPPLE , 13.1/2" T8G. ¡¡;;:2:99i:;--H.:.6!!!1:::! I 5-1/2",17# SCAB LNR, .0232 bpf,ID= 4.892" 1-1 12079t "'\' " PERFORA 110N SUMfv1A RY REF LOG: CNL ON 08/23/90 A NGlE AT TOP PERF: 46 @ 12230' Note: Refer to Production DB fot historical perf data S lZ E ' S'ÞF'oo :" 'INTERVA'L '''''''Oi:miSqz DATE ,.. 2-1/8' 4 ' 12230-t2235' 0 07112/94 2 -1/8' 4 12254 - 12264 0 07/12/94 2 -1/8' 2 12306 - 12325 0 02/12/92 2-1/8' 2 12333 - 12351 0 02/12/92 2-1/8' 4/8 12356 - 12388 0 07/12/94 2-5/8' 4 12388 - 12414 C 09/15/90 , ~C- 'J-f' nJß!~~G TA!l~" JU~¡K 'I I PBTD l-i 12460' i - 1 \7-5/8" CSG, 29.7#, L-80, ID = 6.875" l-i 12549' ~-i 12575' REV BY DA TE REV BY COMMENTS PRUDHOE SA Y UNIT WELL: 09-43 ÆRMIT No: 1901070 API No: 50-029-22078-00 SEC 32. T10N, R15E. 77.98' FEL & 2224.6' FNL DATE 09/02/90 04/01/00 10/06/01 07/27/04 02/14/05 COMMENTS ORIGINAL COMPLETION LAST WORKOV ER RNlKA K CORRECTIONS JLJ/TLP GL V C/O RMHlPJC GL V C/O BP Exploration (Alaska) 09-43 (PTD #1901070) Classified as Problem Well Subject: 09-43 (PTfHJt90'ttffÖ)'Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Tue, 17 Aug 2004 11 :41 :45 -0800 T~!~tlC, arlŠbn"¡:BHÜ11,, H?::sB,':"riãrîl'ciu;, "J""s,Q,n~D,' ',R",'""',,, "~¡"':!!,6J,' ÐØ'~'PS~r,' "" ",' II '~¡":;""':i\¡</"!;':""" ",,!;;:::- ",',.",i!;,:"",~~r;:::, ","::"""'!"'..' ,)~~;':'" i:', ,~;I~S:t~"!"!;,:,~Rq~!;þ~@Q~,i~mn~", ~~:¡l~P~:')i~ll: < ' 1l~ttåii6risSJ (:t!VÜÓr~np~cð~ ""~GPá~:We""llS;\ :YI:K' ",¡,:p" ..~'" '~ij,>""~"""""",:,, ....,,'," '~6ì)U," :",D,"" """"""~,,",,",',"'!~":""A'A,:,'~:,,;'"""""!",',O",'¡:¡¡;ì¡¡i""l)it,.,'",,.'", .... "', ~;I"",;.~~ , ~Y~~Ó!'" "~la,t ' , '$' , tlAG~:;Wr"tø;Aub~'ni~ør.J~i¡: '. ""QdØilf~ãìe.~~k¡:" ¡¡¡i:!:,:',:,',!:"""" ""'"" ,~, ,',,'~""":':":';""""!":'!"":'""""",\~,.,:"".".'~~u" '~,""<", "'""""""""""",r. úOhi ' '.Qn,:$ypervïsðr~:<' S~pe~~ör ' ,,:',,: ,!'l~Fsm$,~fi;.¡~,"~'" , :;'',\:" ":, , 'C""""C~:::~:1,,',,"':""):",,'i';,'",,' ",'W"",e":'l"~":.¡"f;.~,'e" i':" '." '".. , ,~l€'T;\t,;~~w I UR ,~,t!f~"IiI,~ ",' '~""""'" , "'11 1S"')""l~' '" ' «" "t"j'i""R'~!r\o,jlììi:!'""" ;:""" ponwd:, F";;, ~~,~~~S1:l,~Ð.r~C~~;" , All, Well 09-43 (PTD #1901070)) has been found to have sustained casing pressure on the IA. The TIO's on 08/17/04 were 2200/2250/0. The well was secured by load and kill prior to the video log which confirmed collapsed tubing. The well has since become unsecured. The plan forward for this well is as follows: 1. FB: L&K w/SW - DONE 2. EL: Video obstruction - DONE, collapsed tubing 3. FB: Secure well A wellbore schematic has been included for reference. : «09-43.pdf» The well has been classified as a Problem well. Please questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 call if you have any Content-Description: 09-43.pdf Content-Type: application/octet-stream Content-Encoding: base64 Re~ p~ tti~ Pres~s ~ o.:J:t-( ß 8L-) GM. (1-lCf) v.me.- (ßBt..) 4%~ '"1\.wø 2-7 /IøAzz 2.14/274 I 56; ~'5 U ,...lIt íû~~ 'Z7.ØO~: 6\UM- æ 1<64&S- 2:z-7¡ <113 705/ 314 I 5(u;ü/r ~I 2..11 I 'b4 Z'14 s-~ 7 Z 1..0, ~4 U zzSbr:j 310\ r: o'V I lv(zeot¡..- 30 21,091 2..<Çl 7t.:,9 Lob /5/ OA 0 f'!>: Z341?f~ l1I- , , '31 'ZCO 4- 3\ ZZ¡ 32-7 b.Jó, &"34 21 z,/o'ó<t. 1 of 1 8/24/2004 10:38 AM TREE = FMC WB.LHEAD = FMC ACTLII\ TOR = OTIS KB. ELEV = 51' BF. ELEV = KOP= 900' Max Anale = 52 @ 3200' DatumMD= 12334' DatumlVD = 8800' SS 09-43 10-3/4" COO, 45.5#, J-55, ID = 9.953" 4-1/2"lBG, 12.6#, 13-CR-80, ,0152bpf, ID=3.958" 5 1/2" 17# SeA B LtoR lOP, .0232 bpf, ID = 4.89Z' Minimum ID = 2.635" @ 7020' 3112" HES XN NIPPLE 3-1/2" TOO, 9,2#, 13-CR-80, .0087 bpf, ID = 2.992" 7042' 5-112", 17# SCAB LNR, .0232 bpf, ID = 4,892" ÆRFORA lION SLMMARY REF LOG: (}oiL ON 08/23/90 A I'l3LE AT lOP PERF: 46 @ 12230' Note: Refer to Production œ for historical perf data SIZE SA' INlERVAL OpnlSqz DATE 2-1/8" 4 12230 - 12235 0 07/12/94 2-1/8" 4 12254 - 12264 0 07/12/94 2-1/8" 2 12306 - 12325 0 02/12/92 2-1/8" 2 12333 - 12351 0 02/12/92 2-1/8" 4/8 12356 - 12388 0 07/12/94 2-518" 4 12388 - 12414 C 09/15190 12460' 12549' 12575' 2171' I SAFETYNOTES: CHROMETBG. 4-1IZ' HES X NP, ID= 3.813" GAS LIFT P,NU'I)RB.S Sf MD lVD DEV lYÆ VLV LAlCH PORT ~lE 1 3954 3291 50 TE DMY INlG 07/27/04 2 6497 4967 50 KGB2-LS DMY INlG 07/27/04 6514' 6994' 7020' 7042' 12343' ~TE REV BY COMIIIENT~ DAlE REV BY COMIlfENTS 09A12190 ORIGINAL COMPLETION 04A1HIO LAST WORKOVER 10106101 RI'¥KAK CORREr;TONS 07/27104 JUITLP GLV C/O 4-1IZ' X 3-1/2" XO,ID = 2,99Z' 5-1IZ' X 3-1/2" BKRSABL-3 A<R, ID=2,78" 3-1/2" HES XN P>.IP (2.75" ID, 2,635' NO-GO) 3-1I2"TLBII'l3 TAIL, ID= 2.99Z' TLBII'l3 TAILJl.IIIK PRlDt-OEBAY l.IIIrr I/VELL: 09-43 PffiMfI' I'Ð: 1901070 AA I'Ð: 50-029-22078-00 SEr; 32, T1 ON, R15E, 77.98' FB. & 2224.6' FI'L BP Exploration (Alaska) 09-43 (PTD t,t 190 I 070) Classitìed as Problem Wçl .-:J I Kê.í'l ~ I"? 04 Subject: 09-43 (PTD #1901070) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sat, 31 Jul 2004 12:06:04 -0800 To: "Carlson, Brian H" <Brian.Carlson@BP.com>, "GPB, Fld Ops Lead" <GPBFldOpsLead@BP.com>, "GPB, FS2 DS Ops Lead" <GPBFS2DSOpsLead@BP.com>, "FS2 DS Operators GPB (E-mail)" . <IM:CEAEX-_O=BP_DU=USAANC_cn=Recipients_cn=FS2DSOperators@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "ADGeC - Winton Aubert (E-mail)" <winton_aubert@admin.state.ak.us>, "AOGCC - Jim.Regg (E-mail)..<jim_regg@admin.state.ak.us> CC: "NSU, ADW Well Integrity Engineer'! <NSUADWWellIntegrityEngineer@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWel1OperationsSupervisor@BP.com>, "NSU, ADW WL & COll1pletion Supervisor" <NSUADWWL&ConlpletionSupervisor@BP.com>, "Rea, Jeffrey A (VECQ)" <ReaJA@BP.com>, "Mielke, Robert L." <robert.mielke@BP.com> All, Well 09-43 (PTD n1901070) has been found to have sustained casing pressure on the IA. The TIOls on 07/30/04 were 2180/2200/0. A TIFL failed and the IA pressure has equalized with the tubing pressure. The plan forward for this well is as follows: 1) D80: Pop well 2) DHD: Fluid levels on the Tubing and IA 3) SL: Check DGLV's, troubleshoot obstruction at XO 4) DHD: ReTIFL The well has been classified a problem well. Please call if you have any questions. Clark Olsen for, Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: [.~~~J.^üí~~.Je111 ~l t ec.n: it ,;'Eng 1 nee r'~'b'p... ~OIT1 1 of I 8/).'2004 9: 15 AM STATE OF ALASKA ALASI'"'~)IL AND GAS CONSERVATION COr,"~"~SSION R,--PORT OF SUNDRY WELL OPERATIL,,,,S 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. TyPe of'well: (~".' Dat'u~ Ele~ation'"(DF 0;'"KB) ........ ARCO Alaska Inc. [] Development 52' RKB [] Exploratory 7. Unit or Property Name 3~ Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1992' NSL, 62' WEL, SEC. 02, T10N, R15E, UM 09-43 9. permit Number/ Approval No. At top of productive interval 190-107 .................. 2391' SNL, 279' WEL, SEC. 36, T11N, R15E, UM 10.'",~'PI Number At effective depth 50- 029-22078-01 2338' SNL, 211' WEL, SEC. 36, T11N, R15E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 2226' SNL, 79' WEL, SEC. 36, T11N, R15E, UM Pool 12. Present well condition summary Total depth: measured 12575 feet Plugs (measured) true vertical 9013 feet Effective depth: measured 12343 feet Junk(measured) true vertical 8858 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 55 sx Arctic Set 110' 110' Surface 4230' 10-3/4" 1500 sx CS III, 350 sx 'G', Top Job 100 sx CS II 4282' 3508' Intermediate Production 12497' 7-5/8" 500 sx ARC 12549' 8995' Liner Scab Liner 5551' 5-1/2" 495 sx Class 'G' 6528' - 12079' 4988' - 8674' Perforation depth: measured 12230'- 12235', 12254' - 12264', 12306' - 12325', 12333'- 12351', 12356' - 12388' true vertical 8781' - 8784', 8798' - 8805', 8833' - 8846', 8852' - 8864', 8867' - 8889' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr80 to 6516'; 3-1/2", 9.2#, 13Cr80 6516' - 7042' Packers and SSSV (type and measured depth) 5-1/2" x 7-5/8" Baker ZXP Packer at 6528'; 5-1/2" x 3-1/2" Baker 'SABL-3' Packer at 6995'; 4-1/2" SSSV Nipple at 2172' I,~1-,'/"% I'""" I% i31 stimulation or cement squeeze summary ~I[~,,~_,,,! V Intervals treated (measured) 0RIGINAL Treatment description including volumes used and final pressure Alat~a 0il & Gas Cons. Comm~ 14. RepreSentative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: ...................... 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble .'~/'~..~ Title Technical Assistant III Date ~)~,. ' prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Du Progress Report Facility PB DS 09 Well 09-43 Page 1 Rig Nabors 7ES Date 03 April 00 Date/Time 14 Mar 00 03:30-06:00 03:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00-06:00 06:00-07:00 07:00 07:00-01:00 15 Mar 00 01:00 01:00-06:00 06:00 06:00-15:00 06:00-15:00 15:00 15:00-20:30 15:00-15:30 15:30 Duration 2-1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 9 hr 9 hr 15:30-18:30 3 hr 18:30 18:30-20:30 2 hr Activity Move rig Rigged down Fluid system Prep pits to move. Equipment work completed Rigged down Drillfloor / Derrick L/D derrick, move sub off well. Rigged down Drillfloor / Derrick 20:30 20:30-00:30 4 hr 20:30-00:30 4 hr 16 Mar 00 00:30 00:30-04:30 4 hr 5-1/2 hr 1/2 hr oo: o-o4: REC, qEiVED Prepare derrick to lay down. Moved pits, shop and camp off location. 24 hr Move rig (cont...) 1 hr Rigged down Drillfloor / Derrick (cont...) Prepare derrick to lay down. Moved pits, shop and camp off location. Equipment work completed 18 hr Rig moved 95.00 % Moved pits, shop, camp, and sub base to DS9. At well location - Cellar 5 hr Rig moved 100.00 % Lay mats and spread herculite. Spot sub over well. Lay herculite and spot pits. Set shop and camp. At well location - Cellar Move rig (cont...) Rigged up Drillfloor / Derrick Bermed under the rig. Spotted cuttings tank. Raised derrick and pinned pipe chute. Unpin bridal lines. Hooked up top drive to blocks. Hand tongs and prepare rig floor. Equipment work completed Wellhead work Held safety meeting Held pre-spud safety/environmental meeting. Reviewed pre-spud checklist, well plan, plan forward, H2S precautions. Completed operations Rig accepted 1500 hrs 3/15/2000. Rigged up High pressure lines R/U manifold to bleed gas off well head and test BPV to 500 psi. Tested BPV, OK. Equipment work completed Rigged down Xmas tree N/D tree and adapter. Installed blanking plug in tubing hanger thread on top of BPV. Equipment work completed Nipple up BOP stack Rigged up BOP stack NFU BOP w/11" x 13-5/8" DSA. Installed secondary annulus valve. Installed bell nipple, finished rigging up to circulate to cuttings tank. Equipment work completed Test well control equipment Tested BOP stack Tested pipe rams, blind rams, choke and kill line 10 2000 Alaska Oil & Gas Cons. Commission Anchorage valves, floor safety valves, hydril, choke to 250/3500 psi. Function tested accumulator. Witness of Lr~DL w o..1 v ~u. UI OlllOiLll, Progress Report Facility PB DS 09 Well 09-43 Page 2 Rig Nabors 7ES Date 03 April 00 Date~ime Duration Activity 04:30 04:30-06:00 04:30-06:00 04:30-06:00 06:00-07:00 06:00-07:00 07:00 07:00-10:30 07:00-10:30 10:30 10:30-21:00 10:30-13:00 13:00 13:00-20:00 20:00 20:00-21:00 21:00 21:00-21:30 21:00-21:30 21:30 21:30-06:00 21:30-23:00 23:00 23:00-06:00 17 Mar 00 06:00 06:00-12:00 06:00-06:30 06:30 06:30-08:00 08:00 08:00-12:00 1-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 3-1/2 hr 3-1/2 hr 10-1/2 hr 2-1/2 hr 7 hr 1 hr 1/2 hr 1/2 hr 8-1/2 hr 1-1/2 hr 7 hr 6 hr 1/2 hr 1-1/2 hr 4 hr Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Finished pull BPV with lubricator. Removed Hanger plug Pulled blanking plug. R/U DSM and pulled BPV. Wellhead work (cont...) Removed Hanger plug (cont...) Pulled blanking plug. R/U DSM and pulled BPV. Equipment work completed Fluid system Circulated at 6000.0 ft Test lines and circ out freeze protect and seawater to cuttings tank. Verify well is dead. Blow down lines. Hole displaced with Seawater - 100.00 % displaced Had 35 bbls gas cap on top of fluid column. Hole appears to be taking 10 bbls/hr to formation. Pull Gas lift completion, 4-1/2in O.D. Pulled Tubing on retrieval string to 35.0 ft P/U Baker spear and pulled hanger to floor. L/D spear, tubing hanger. Finished R/U HES spooling unit. Stopped: To change handling equipment Laid down 6000.0 ft of Tubing L/D 4-1/2", L-80, BTC tubing. Recovered 52 SS bands, 144jts tbg, SSSV, 1 GLM, 31.77' cutjt. Chemical cut fairly clean. Tubing badly corroded, pins rotten. Holes injts 124, 126, 129. 144 joints laid out Rigged down Tubing handling equipment Equipment work completed Wellhead work Installed Wear bushing Install 6.75" ID wear ring. Eqpt. work completed, running tool retrie~lt 0Il & ~ COILS. C0ffill BHA run no. 1 ,t~ll010rit~8 Made up BHA no. 1 M/U fishing BHA #1. Overshot, bumper jars, oil jars, (12) 4-3/4" DC, intensifier, xo=406.02' BHA no. 1 made up Singled in drill pipe to 6000.0 ft P/U 180 jts 4" DP. At Top of fish: 6000.0 ft BHA run no. 1 (cont...) Fished at 6030.0 ft Washed over and engaged fish. TOF @ 6030' DPM. P/U 150K, fish came free. (43K over string weight). Fish came free Circulated at 9718.0 ft CBU. Some gas cut seawater. Obtained bottoms up (100% annulus volume) Pulled out of hole to 6030.0 ft Stood back drill collars, L/D jars. RECEIVED 10 2000 Facility Datefrime 18 Mar O0 Progress Report PB DS 09 Well 09-43 Page 3 Rig Nabors 7ES Date 03 April 00 12:00 12:00-18:00 12:00-13:00 13:00 13:00-17:00 17:00 17:00-18:00 18:00 18:00-06:00 18:00-19:00 19:00 19:00-20:30 20:30 20:30-21:30 21:30 21:30-01:00 01:00 01:00-01:30 01:30 01:30-03:00 03:00 03:00-06:00 06:00-08:00 06:00-07:00 07:00 07:00-08:00 08:00 08:00-13:00 08:00-09:00 09:00 09:00-11:30 11:30 11:30-13:00 13:00 13:00-06:00 13:00-14:00 Duration 6 hr 1 hr 4 hr 1 hr 12hr 1 hr 1-1/2 hr 1 hr 3-1/2 hr 1/2 hr 1-1/2 hr 3 hr 2 hr 1 hr 1 hr 5 hr 1 hr 2-1/2 hr 1-1/2 hr 17hr 1 hr Activity Fish at surface Pull Gas lift completion, 4-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed Laid down 3688.0 ft of Tubing L/D 88 jts tubing plus 4 GLM's. Calc'd TOF @ 9718'. 88 joints laid out Rigged down Tubing handling equipment R/D tubing handling tools and clear floor. Equipment work completed BHA run no. 2 Made up BHA no. 2 Fishing BHA #2. Spear, B. jars, O. jars, (12) 4-3/4" DC, intensifier, prop out sub, xo=409.67' BHA no. 2 made up R.I.H. to 6008.0 ft Stopped: To service drilling equipment Serviced Block line Line slipped and cut Singled in drill pipe to 9718.0 ft P/U wt = 165K 120 joints picked up Fished at 9718.0 ft Engage fish at 9718'. P/U to 210K, while working pipe came free. P/U wt - 185K. Fish came free Circulated at 9718.0 ft CBU. Observe well. Obtained bottoms up (100% annulus volume) Pulled out of hole to 2700.0 ft POH w/fish at report time. BHA run no. 2 (cont...) Pulled out of hole to 409.0 ft (cont...) POH w/fish at report time. At BHA Pulled BHA Stand back drill collars. L/D jars, spear. Fish at surface RECEIVED · . ,, aoo 10 2000 Pull Gas lift completion, 4-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed AllOhOl'a~jo Laid down 2190.0 ft of Tubing Recovered 51 jts 4-1/2" tubing, 5 GLM, one tubing collar. Jet cut was incomplete, tubing parted below collar of pup jt on top of packer seal assembly. Stopped · To change handling equipment Rigged down Tubing handling equipment R/D casing equipment. Clear floor and clean work area. Equipment work completed BHA run no. 3 Made up BHA no. 3 Fishing BHA #3. Overshot, B. Jar, Oil Jar, (12) 4-3/4"-~-:" --"--~ : ..... UIIII k.,UIICII3, IIItClI3111UI, pump out sub, xo- Facility PB DS 09 Progress Report Well 09-43 Page 4 Rig Nabors 7ES Date 03 April 00 Date/Time 19 Mar O0 20 Mar O0 14:00 14:00-19:30 19:30 19:30-21:30 21:30 21:30-22:30 22:30 22:30-00:30 00:30 00:30-05:00 05:00 05:00-06:00 05:00-06:00 06:00-07:00 06:00-07:00 07:00 07:00-06:00 07:00-09:00 09:00 09:00-14:00 14:00 14:00-15:00 15:00 15:00-15:30 15:30 15:30-20:00 20:00 20:00-20:30 20:30 20:30-21:30 21:30 21:30-22:30 22:30 22:30-00:00 00:00 00:00-00:30 Duration 5-1/2 hr 2 hr 1 hr 2 hr 4-1/2 hr 1 hr 1 hr 1 hr 1 hr 23 hr 2 hr 5 hr 1 hr 1/2 hr 4-1/2 hr 1/2 hr 1 hr 1 hr 1-1/2 hr 1/2 hr Activity 408' BHA no. 3 made up R.I.H. to 9718.0 fl Stopped ' To change handling equipment Singled in drill pipe to 11964.0 ft Observed 100.00 klb resistance Fished at 11991.0 ft Tagged fish at 11,964'. Set down 100K, Pulled 225K, came free. Pushed fish to 11,991. Pmp @ 9 spm, 2000 psi, bled off. Slack off to 100K, pulled 250K, wt fell off to string wt, 195K. Fish came free Circulated at 11955.0 ft Circulate out two bbl gas bubble. Obtained clean returns - 150.00 % hole volume Pulled out of hole to 408.0 ft At BHA Pulled BHA L/D pup jt fish. 6.95' Pulled BHA Recovered pup jr, collar and 3" of 3-1/2"xo to seal assembly. Pipe is rotten. BHA run no. 3 (cont...) Pulled BHA (cont...) Recovered pup it, collar and 3" of 3-1/2"xo to seal assembly. Pipe is rotten. Fish at surface BHA run no. 4 Made up BHA no. 4 P/U and strap packer milling BHA. Make up BHA and RIH. BHA no. 4 made up R.I.H. to 11935.0 ft Stopped · To service drilling equipment Serviced Block line Line slipped and cut Washed to 11998.0 ft At Top of packer · 11998.0 ft Milled Permanent packer at 11998.0 ft Milled Baker FB-1 packer f/11,998'- 12,001' Completed dressing Permanent packer Packer came free. R.I.H. to 12071.0 ft Pushed packer to top of sand, 20K down. Bottom of packer calc'd 12,097'. Observed 20.00 klb resistance Circulated at 12071.0 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 11327.0 ft POH. Hole not taking correct fill. Observe well. Stopped · To circulate Circulated at 11438.0 ft Circulate, some gas strung out in seawater. Obtained clean returns - 150.00 % hole volume Flow check RECEIVED APR 10 NaskaO &OasCons. C Progress Report Facility PB DS 09 Well 09-43 Page 5 Rig Nabors 7ES Date 03 April 00 Date/Time 00:30 00:30-01:00 01:00 01:00-02:00 02:00 02:00-03:30 03:30 03:30-06:00 06:00-10:00 06:00-08:30 08:30 08:30-10:00 10:00 10:00-06:00 10:00-11:00 11:00 11:00-12:00 12:00 12:00-13:00 13:00 13:00-14:00 14:00 14:00-16:00 16:00 16:00-17:00 17:00 17:00-00:30 Duration 1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 4 hr 2-1/2 hr 1-1/2 hr 20 hr 1 hr 1 hr 1 hr 1 hr 2 hr lhr 7-1/2 hr Activity psi. Observed 0.500 bbl gain in annulus in 0.50 hr Held safety meeting Held PJSM on stripping. (Prep to have stripping drill) Completed operations R.I.H. to 12055.0 ft Stripped in hole, bleeding off pipe displacement. On bottom Circulated at 12055.0 ft CBU and observe well. Got some gas cut brine before bottoms up. Observe well. Obtained bottoms up (100% annulus volume) Pulled out of hole to 7000.0 ft POH w/packer milling assembly. Hole taking correct fill. BHA run no. 4 (cont...) Pulled out of hole to 423.0 ft (cont...) POH w/packer milling assembly. Hole taking correct fill. At BHA Pulled BHA Stand back collars, L/D milling tools. Clean junk baskets. (Recovered 1/2 gal metal) BHA Laid out BHA run no. 5 Made up BHA no. 5 P/U overshot fishing assembly, run drill collars from derrick. RECEI V D BHA no. 5 made up R.I.H. to 3490.0 ft RIH. Fluid returns from pipe displacement 4 bbls ~p[~ ,] 0 over calculated. Stopped · To flowcheck well Flow check ~a8118 0[1 & ~a$ Oglll8. ~ ~ Well flowing 1.0 bbls in 15 min. SI well, 15 psi on DP and CSG. Pressure rising 5 psi, 30 min. Observed 1.000 bbl gain in annulus in 0.25 hr Circulated at 3480.0 ft Circ fluid around thru choke, no gas bubble in annulus. Opened well, still flowing from annulus. Obtained bottoms up (100% annulus volume) R.I.H. to 5345.0 ft Strip in hole holding 35 psi on choke while bleeding 1.5 bbls/stand. Stopped: To circulate Circulated at 5345.0 ft Circ thru choke to fill pipe, check annulus for gas bubble. No gas bubble. (86 spm, 680 psi) SICP = 50 psi Obtained bottoms up (100% annulus volume) R.I.H. to 12040.0 ft Cont'd stripping in hole to 12,040'. Filled pipe every 10 stds. Held 70 psi back pressure. (hole taking fluid if increased safety margin) II III Facility PB DS 09 Date/Time 21 Mar 00 00:30 00:30-03:00 03:00 03:00-03:30 03:30 03:30-04:30 04:30 04:30-05:30 05:30 05:30-06:00 05:30-06:00 06:00-13:00 06:00-11:00 11:00 11:00-13:00 13:00 13:00-13:30 13:00-13:30 13:30 13:30-01:30 13:30-14:00 14:00 14:00-16:00 16:00 16:00-16:30 16:30 16:30-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-19:30 19:30 19:30-20:00 Progress Report Well 09-43 Page 6 Rig Nabors 7ES Date 03 April 00 Duration 2-1/2 hr 1/2 hr 1 hr 1 hr 1/2 hr 1/2 hr 7 hr 5 hr 2 hr 1/2 hr 1/2 hr 12hr 1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2hr Activity On bottom Circulated at 12040.0 ft Held PJSM. Circ well thru choke using kill sheet to 8.9 ppg. Hole displaced with Brine - 100.00 % displaced Small amount of gas at B/U. Flow check Observe well. Well stable. Observed well static Fluid level dropping slightly. Fished at 12081.0 ft Engaged packer fish. Worked free to 300K. Fish came free Circulated at 12070.0 ft CBU. Small amount of gas at B/U. Obtained bottoms up (100% annulus volume) Hole stable. Pulled out of hole to 11890.0 ft POH w/fish. Pulled out of hole to 11890.0 ft POH w/packer fish. BHA run no. 5 (cont...) Pulled out of hole to 411.0 ft (cont...) POH w/packer fish. At BHA Pulled BHA Stand back 4-3/4" drill collars. L/D fish and fishing tools. Recovered 26.88' packer and rotten tailpipe. BHA Laid out Wellhead work Removed Wear bushing Serivced wear ring. Visual inspection of hydril rubber, good shape. Reran wear bushing. Equipment work completed BHA run no. 6 Made up BHA no. 6 %5/8" RTTS, (12) DC, XO= 377.56' BHA no. 6 made up APR1 02000 R.I.H. to 4000.0 ft Stopped' To pressure test A]~ 0[l & ~a8 Cons. ~mi~ Tested Casing - Via annulus ,a,l~iXlt~ Tested 7-5/8" casing to 3000 psi, OK. Pressure test completed successfully - 3000.000 psi R.I.H. to 8017.0 ft Stopped: To pressure test Tested Casing - Via annulus Pressure test casing to 3000 psi, bled to 125 psi. Suspended pressure test on Casing, observed leak Pulled out of hole to 6060.0 ft Stopped: To pressure test Tested Casing - Via annulus Pressure test completed successfully - 3000.000 psi R.I.H. to 7000.0 ft RECEIVED Facility Date/Time 22 Mar O0 PB DS 09 20:00 20:00-20:30 20:30 20:30-20:45 20:45 20:45-21:00 Progress Report Well 09-4'3 Rig Nabors 7ES Page 7 Date 03 April 00 21:00 21:00-21:15 21:15 21:15-22:00 22:00 22:00-00:30 00:30 00:30-01:30 01:30 01:30-06:00 01:30-03:00 03:00 03:00-05:00 05:00 05:00-06:00 06:00 06:00-06:00 06:00-08:00 08:00 08:00-13:00 13:00 13:00-14:00 14:00 14:00-20:00 20:00 20:00-02:30 23 Mar 00 02:30 02:30-03:30 Duration 1/2 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 2-1/2 hr 1 hr 4-1/2 hr 1-1/2 hr 2 hr 1 hr 24 hr 2 hr 5 hr 1 hr 6 hr 6-1/2 hr 1 hr Activity Stopped: To pressure test Tested Casing - Via annulus Pressure test completed successfully - 3000.000 psi R.I.H. to 7554.0 ft Stopped: To pressure test Tested Casing - Via annulus Casing leaked. Suspended pressure test on Casing, observed leak Pulled out of hole to 7275.0 ft Stopped: To pressure test Tested Casing - Via annulus Pressure test casing to 3000 psi for 30 min, good test. Leak isolated between 7275' to 7554'. (Ugnu Cretaceous leak, approximately 5500' TVD)) Pressure test completed successfully - 3000.000 psi Pulled out of hole to 377.0 ft At BHA Pulled BHA L/D RTTS. BHA Stood back BHA run no. 7 Made up BHA no. 7 M/U T-dog overshot/washpipe fishing BHA. BHA no. 7 made up R.I.H. to 7044.0 ft Stopped: To service drilling equipment Serviced Block line Line slipped and cut BHA run no. 7 (cont...) R.I.H. to 11995.0 ft Observed 10.00 klb resistance Washed to 12230.0 ft Wash and ream thru parafin & asphaltene in well bore below previous packer setting depth. At Top of perforations: 12230.0 ft Washed to 12275.0 ft Continued to wash thru sand across from perfs. Lost complete returns @ 12,275'. Stopped: To circulate Circulated at 12182.0 ft Mix and pump LCM pills while pumping @ 1 bbl/min down backside. Mixed and pumped (4) 40 bbl pills, 30 ppb mixed CaCo3. No returns. Followed CaCo3 pills with 125 bbls 50 lb/bbl liq csg, OM seal, barafiber. Regained circulation. Lost 1275 bbls fluid. 285.000 bbl LCM pill spotted downhole, LCM content 50.0 lb/bbl Circulated at 12182.0 ft Circulate hole volume to balance system. Loss rate increasing to 50 bbls/hr. Mix and pump (2) 40 bbl 30 ppb CaCo3 pills and (1) 40 bbl 50 ppb LCM fiber pill. Static loss 12 bbl/hr. LCM spotted downhole Pulled out of hole to 11244.0 ft POH to 11,244' to allow pills to soak. RECEIVED APR 10 2000 QI & Coos. Com. Facility Date/Time 24 Mar 00 Progress Report PB DS 09 Well 09-43 Page 8 Rig Nabors 7ES Date 03 April 00 03:30 03:30-05:00 05:00 05:00-05:30 05:30 05:30-06:00 06:00-06:00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-10:30 10:30 10:30-02:30 02:30 02:30-03:30 03:30 03:30-06:00 06:00-11:00 06:00-08:30 08:30 08:30-11:00 11:00 11:00-14:30 11:00-11:30 11:30 11:30-13:30 13:30 13:30-14:30 14:30 14:30-06:00 14:30-15:30 Duration 1-1/2 hr 1/2 hr 1/2 hr 24 hr 1/2 hr 1/2 hr 3-1/2 hr 16hr 1 hr 2-1/2 hr 5 hr 2-1/2 hr 2-1/2 hr 3-1/2 hr 1/2 hr 2 hr 1 hr 15-1/2 hr 1 hr Activity Stopped: To service drilling equipment Serviced Block line Slip and cut 500' drilling line. (Bad spot in drilling line.) Line slipped and cut Circulated at 11244.0 ft Circ @ 150 SPM, 2000 psi. Loss rate 7 bbls/hr. Broke circulation R.I.H. to 12000.0 ft RIH to cleanout perfs at report time. BHA run no. 7 (cont...) R.I.H. to 12182.0 ft (cont...) RIH to cleanout perfs at report time. Began precautionary measures Washed to 12275.0 ft Observed 10.00 klb resistance Reamed to 12320.0 ft Cleanout hole to 12,320'. Losses to formation 10 bph. At Top of fish: 12320.0 ft Forward progress slowed to 1.5 '/hr. Excess torque. Washed over string at 12343.0 ft Milled over fish. Excessive torque. Added lubricants. Slow progress, mill quit. ROP dropped from 1.5 fl/hr to 0.0 fl/hr - Mill quit Circulated at 12343.0 ft RECEIVED Obtained bottoms up (100% annulus volum Pulled out of hole to 7000.0 ft POH @ report time. BHA run no. 7 (cont...) Pulled out of hole to 511.0 ft At BHA Pulled BHA APR 1 0 2000 Aia a Oil & Gas Co s. Commi Stand back drill collars, L/D BHA. Mill 100% worn. L/D 26' tailpipe fish. (16' rotted off on low side, 10' twisted). BHA Laid out Test well control equipment Retrieved Wear bushing Pulled wear bushing and installed test plug. Equipment work completed Tested Well control Tested pipe rams, blind rams, choke and kill line valves, floor safety valves, choke, hydril to 250/3500 psi. Tested accumulator. Witness of test waived by J. Spaulding AOGCC. Pressure test completed successfully - 3500.000 psi Installed Wear bushing Pulled test plug and installed wear bushing. Eqpt. work completed, running tool retrieved BHA run no. 8 Made up BHA no. 8 Milling BHA. Facility PB DS 09 Date/Time Duration 15:30 15:30-19:30 4 hr 19:30 19:30-06:00 10-1/2 hr 19:30-06:00 10-1/2 hr 25 Mar 00 06:00-19:00 13 hr 06:00-08:00 2 hr 08:00 08:00-09:30 1-1/2 hr 09:30 09:30-10:00 1/2 hr 10:00 10:00-14:00 4 hr 14:00 14:00-17:00 3 hr 17:00 17:00-19:00 2 hr 19:00 19:00-03:00 8 hr 19:00-20:00 1 hr 20:00 20:00-03:00 7 hr 26 Mar 00 03:00 03:00-06:00 3 hr 03:00-05:00 2 hr 05:00 05:00-06:00 06:00 06:00-22:00 06:00-10:30 10:30 1 hr 16hr 4-1/2 hr 10:30-11:30 1 hr 11:30 Progress Report Well 09-43 Page 9 Rig Nabors 7ES Date 03 April 00 Activity BHA no. 8 made up R.I.H. to 12336.0 ft Tagged top tailpipe fish at 12,336'. At Top of fish: 12336.0 ft Milled Tubing at 12343.0 ft Mill quit. No progress last two hours. Torque dropped from 11K to 7K. Fish possibly spinning. Milled Tubing at 12343.0 ft Milled tubing stub f/12, 336' to 12, 343'. Two feet of progress since midnight. (Spinning on junk?) BHA run no. 8 (cont...) Milled Tubing at 12343.0 ft (cont...) Milled tubing stub f/12, 336' to 12, 343'. Two feet of progress since midnight. (Spinning on junk?) ROP dropped from 1.0 ft/hr to 0.0 ft/hr - Spun on downhole equipmel Circulated at 12343.0 ft Pumped hi visc sweep and spotted 20 bbl LCM pill on bottom. 20.000 bbl LCM pill spotted downhole, LCM content 50.0 lb/bbl Pulled out of hole to 11800.0 ft Stopped: To change handling equipment Laid down 5300.0 ft of 4in OD drill pipe POH and L/D 171 jts 4" drill pipe. 171 joints laid out Pulled out of hole to 424.0 ft At BHA Pulled BHA L/D drill collars and milling BHA. Circular wear pattern on bottom of mill, mill not completely worn. BHA Laid out Electric wireline work Rigged up Logging/braided cable equipment R/U Schlumberger. P/U GR/CCL and fiberglass EZSV. Equipment work completed Conducted electric cable operations RIH to 1906'. Set down. POH and looked at tools. P/U 6.13" gauge ring/JB and RIH to 12,200'. POH. P/U GR/CCL EZSV and RIH. RIH to 12,219 for tie in. Could not come up, went down to get movement. Stuck @ 12,240'. Set EZSV. POH. R/D. Completed misrun with Cement retainer to 12240.0 ft 4in. Drillpipe workstring run Ran Drillpipe in stands to 6626.0 ft RIH w/drill pipe to set sand plug. Stopped · To change handling equipment Serviced Top drive Equipment work completed 4in. Drillpipe workstring run (cont...) Singled in drill pipe to 12252.0 ft At Top of packer: 12252.0 ft Tagged EZSV w/25K. Rigged up High pressure lines R/U Dowell to pump sand plug. Equipment work completed RECEIVED APR 10 2000 Facility PB DS 09 Progress Report Well 09-43 Page 10 Rig Nabors 7ES Date 03 April 00 Date/Time 27 Mar 00 11:30-12:00 12:00 12:00-13:00 13:00 13:00-13:30 13:30 13:30-14:30 14:30 i4:30-15:30 15:30 15:30-19:30 19:30 19:30-22:00 22:00 22:00-06:00 22:00-00:30 00:30 00:30-01:00 01':00 01:00-06:00 O1:00-06:00 06:00-17:00 06:00-11:00 11:00 11:00-11:30 11:30 11:30-12:30 12:30 12:30-16:30 16:30 16:30-17:00 17:00 17:00-21:00 Duration 1/2 hr 1 hr 1/2 hr 1 hr 1 hr 4 hr 2-1/2 hr 8 hr 2-1/2 hr 1/2 hr 5 hr 5 hr llhr 5 hr 1/2 hr 1 hr 4 hr 1/2 hr 4 hr Activity Held safety meeting Completed operations Batch mixed slurry - 19.000 bbl Pumped 5 bbls seawater. Tested lines to 3500 psi. Mixed and pumped (19 bbls) 4200g sand slurry and displaced with 103 bbls seawater. Batch slurry mixed Slurry mixed and pumped. Pumped out of hole to 11760.0 ft POH 5 stands. At top of check trip interval Circulated at 11768.0 ft Pumped 5 bbls seawater to ensure drill pipe not plugged. Wait on sand to fall. Broke circulation Ran Drillpipe in stands to 12150.0 ft RIH and tagged top of sand at 12,150'. At Top of fill: 12150.0 ft Laid down 5550.0 ft of 4in OD drill pipe 180 joints laid out Pulled Drillpipe in stands to 0.0 ft APR 10 000 L/D muleshoe. Stopped' To change handling equipment ~0[l& ~ C0115. C0ffif Run Tubing, 5-1/2in O.D. Rigged up Casing handling equipment ~[/l~0fa~0 RECEIVED R/U to run chrome 5-1/2" liner. Equipment work completed Held safety meeting Completed operations Ran Liner to 2870.0 ft (5-1/2in OD) Running 5-1/2", 17#, CR-80, NEW VAM liner at report time. Ran Liner to 2870.0 ft (5-1/2in OD) Finished run 5-1/2' CR80 liner. PFU liner hanger and packer. Run Tubing, 5-1/2in O.D. (cont...) Ran Liner to 5552.0 ft (5-1/2in OD) (cont...) Finished run 5-1/2' CR80 liner. P/U liner hanger and packer. Stopped: To change handling equipment Rigged up Drillfloor / Derrick MFU lower kelly on top drive. Equipment work completed Circulated at 5552.0 ft Circulate volume of liner. Broke circulation Ran Drillpipe in stands to 12079.0 ft RIH w/liner on drill pipe. Tagged top of sand at 12,079'. Observed 25.00 klb resistance Held safety meeting Held PJSM. Completed operations Cement: Liner cement Facility Date/Time 28 Mar 00 PB DS 09 17:00-17:30 17:30 17:30-19:15 19:15 19:15-19:45 19:45 19:45-20:30 20:30 20:30-21:00 21:00 21:00-23:30 21:00-23:30 23:30 23:30-06:00 23:30-01:00 01:00 01:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00-06:00 06:00-08:30 08:30 08:30-09:00 09:00 09:00-10:00 10:00 10:00-10:30 10:30 10:30-11:30 Progress Report Well 09-43 Page 11 Rig Nabors 7ES Date 03 April 00 Duration 1/2 hr 1-3/4 hr 1/2 hr 3/4 hr 1/2 hr 2-1/2 hr 2-1/2 hr 6-1/2 hr 1-1/2 hr 3 hr 2 hr 2 hr 24 hr 2-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr Activity Rigged up High pressure lines Finish R/U Dowell. Equipment work completed Mixed and pumped slurry - 103.000 bbl Pump 5 bbls H20 and tested lines to 4500 psi. Mixed and pumped 103 bbls (495 sx) Class G cmt @ 15.8 ppg. Washed lines and dropped plug. Displaced cement with 193.5 bbls seawater. Reciprocated with full returns, bumped plug at calculated strokes. Cement pumped CIP 1915 hrs, 3/27/00. Functioned Liner hanger Set down 25K on sand. Pressured to 2800 psi and set liner hanger. Pressured to 4500 and set packer. Rotate to release setting tool. Equipment work completed Circulated at 6528.0 ft Pressure up and released from liner. Pump out excess cement at 210 spm, 630 gpm. Recovered 5 bbls excess cement off top of liner. Obtained clean returns - 125.00 % hole volume Rigged down High pressure lines L/D cementing head. R/D hoses. Equipment work completed Pull Drillpipe, 4in O.D. Pulled Drillpipe in stands to 0.0 ft POH and L/D liner running tool. At Surface · 0.0 ft BHA run no. 9 APR 10 Rigged up Drillstring handling equipment R/U to run 3-1/8" DC and 2-3/8" Dp~i~0~&C-~$.C~IIIIII~ Equipment work completed /lilll~10~ Made up BHA no. 9 4-3/4" Economill, XO, 3-1/8" SS Mud Motor, XO, B. Sub, Oil Jars, XO, (18) 3-1/8"DC, XO, (168) jts 2-3/8" DP, XO = 5879.22' BHA no. 9 made up Singled in drill pipe to 1470.0 ft Finish PU 2 3/8" DP. Singled in drill pipe to 1470.0 ft P/U 2-3/8" drill pipe at report time. BHA run no. 9 (cont...) Singled in drill pipe to 5880.0 ft (cont...) P/U 2-3/8" drill pipe at report time. 168 joints picked up Rigged up Drillstring handling equipment Change out tongs & elevators for 4" DP. Work completed - Drillstring handling equipment in position Serviced Block line Slip & cut 120'. Line slipped and cut R.I.H. to 6540.0 ft Began precautionary measures Reamed to 6626.0 ft RECEIVED Facility PB DS 09 Date/Time 11:30 11:30-14:00 14:00 14:00-15:00 15:00 15:00-16:00 16:00 16:00-21:30 21:30 2i :30-02:30 29 Mar 00 02:30 02:30-06:00 06:00-14:00 06:00-08:00 08:00 08:00-08:30 08:30 08:30-12:30 12:30 12:30-14:00 14:00 14:00-05:30 14:00-15:00 15:00 15:00-16:30 16:30 16:30-17:00 17:00 17:00-04:30 30 Mar 00 04:30 04:30-05:30 Progress Report Well 09-43 Page 12 Rig Nabors 7ES Date 03 April 00 Duration Activity 2-1/2 hr 1 hr 1 hr 5-1/2 hr 5 hr 3-1/2 hr 8 hr 2 hr 1/2 hr 4 hr 1-1/2 hr 15-1/2 hr 1 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1 hr Completed precautionary measures R.I.H. to 11885.0 ft D1 Drill-OS-45 secs. At Top of cement: 11885.0 ft Drilled cement to 11995.0 ft Drill cement to insert landing collar. Tagged Landing collar Tested Liner - Via string Tested scab liner f/30 min-OK. Pressure test completed successfully - 3000.000 psi Drilled installed equipment - Float shoe Drilled float equipment, cement, sand plug, & bridge plug to 12,343'. D2 Drill-OS-l:15 min. Completed operations Circulated at 12343.0 ft Circ Hi-Vis sweep. Clean pits & mix spacer. Pump Hi-Vis spacer. Displace to clean seawater. Hole displaced with Seawater - 120.00 % displaced Laid down 3743.0 ft of 4in OD drill pipe Monitor well-OK. No losses. Pump dry job. Blow down. Start LDDP. BHA run no. 9 (cont...) Laid down 6463.0 ft of 4in OD drill pipe (cont...) Monitor well-OK. No losses. Pump dry job. Blow down. Start LDDP. Stopped: To change handling equipment Rigged up Drillstring handling equipment Change tongs & elevators f/2 3/8". Work completed - Handling equipment in position Laid down 5757.0 ft of 2-3/8in OD drill pipe D 1 Drill-OS- 1:15 min. At BHA Pulled BHA BHA Laid out Run Gas lift completion, 4-1/2in O.D. Removed Wear bushing Pull wear ring & clear floor. RECEIVED APR 10 2000 ~O~&Gas Ce~s. Commiss~ Equipment work completed Rigged up Completion string handling equipment ,Allohota~o RU to run chrome tubing. Work completed - Completion string handling equipment in position Held safety meeting PJSM w/all personnel. Completed operations Ran Tubing to 7042.0 ft (4-1/2in OD) Ran chrome completion. 12 Jts 3.5", 9.2# FOX and 153 jts 4.5", 12.6# New VAM. MU & land hanger. RILDS. Fire Drill-OS- 1:10 min. Hanger landed Tested Tubing hanger Tested hanger seals from above to 3000 psi-OK. Tested from below to 500 psi-OK. Slight bleed off to perfs. Blow down lines. Facility Date/Time PB DS 09 05:30 05:30-06:00 05:30-06:00 05:30-06:00 06:00-08:30 06:00-08:30 08:30 08:30-13:00 08:30-10:00 10:00 10:00-10:30 10:30 10:30-11:30 11:30 11:30-12:00 12:00 12:00-13:00 13:00 13:00-14:30 13:00-14:30 14:30 t4:30-17:00 14:30-15:15 15:15 15:15-16:00 16:00 16:00-17:00 17:00 17:00-18:45 17:00-18:45 18:45 18:45-19:00 18:45-19:00 19:00 19:00-06:00 19:00-22:00 22:00 Progress Report Well 09-43 Page 13 Rig Nabors 7ES Date 03 April 00 Duration 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2-1/2hr 4-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 3/4 hr 3/4 hr 1 hr 1-3/4 hr 1-3/4 hr 1/4 hr 1/4 hr llhr 3 hr Activity Pressure test completed successfully - 3000.000 psi Nipple down BOP stack Rigged down BOP stack ND BOPE. Rigged down BOP stack ND BOPE & adapter flange. RECEIVED Nipple down BOP stack (cont...) Rigged down BOP stack (cont...) ND BOPE & adapter flange. APR Equipment work completed Wellhead work ~ 0~ & ~8 COILS. C0ffi~ Installed Xmas tree NU 4 1/16" 5000k tree & tbg hd adapter. Equipment work completed Tested Tubing bonnet Test tbg hd adapter. Pressure test completed successfully - 5000.000 psi Installed Hanger plug Pull BPV w/lubricator. Set TTP. Eqpt. work completed, running tool retrieved Tested Xmas tree Pressure test completed successfully - 5000.000 psi Removed Hanger plug Pull TTP w/lubricator. LD same. Equipment work completed Fluid system Reverse circulated at 7042.0 ft Reverse inhibited seawater to annulus. Hole displaced with Inhibited brine - 100.00 % displaced Run Gas lift completion, 4-1/2in O.D. Set packer at 6995.0 ft with 4500.0 psi Drop rod/ball & set packer. Packer set at 6995.0 ft Tested Tubing Pressure test completed successfully - 4500.000 psi Tested Permanent packer Bled tbg to 1500 psi. Test annulus & packer to 3000 psi-OK. Bled tbg to shear RP valve. Bleed off. Pressure test completed successfully - 3000.000 psi Fluid system Freeze protect well - 100.000 bbl of Diesel RU HB&R and reverse diesel. U-Tube. Completed operations Wellhead work Installed Hanger plug Set BPV. Eqpt. work completed, running tool retrieved Fluid system Cleared Sand traps Finish cleaning pits. Equipment work completed Rig released @ 2200 hrs on 3/30/00. To: B lair Wondzell - AOGCC From: Dan Stone- Shared Services Drilling .=..~q '"- ~-~ O~ Subject: 9-43 Rig Workover (no t0-403; workover of producing well) Date: 3/23/00 Blair, attached is diagram of well in question. It is a workover for corroded tubing. Situation is thus: 1. Hole in 7-518" casing. Cretaceous external corrosion of 7-5/8". ~x'tr}-ated depth with use of RTFS between 7275' and 7500'. 2. Will be running scab liner from just above perfs to top Cretaceous interval to isolate leak. Liner fully cemented with liner top packer, 3. Well was originally complete with 4-1/2" tubing all the way, was 8000 BFPD producer, 1500 BOPD 4. If we run 3-1/2" tubing inside 5-1/2" liner with a 5-1/2" x 3-112" packer, the flowrate will be cut in half according to hydraulic calculations. 5. Asset would like to explore possibility of using the scab liner as production tubing basically. Will then put a production packer above the liner (7-5/8" x 4-1/2" packer) and run tubing above there (Chrome 4-1/2" tubing). The tubing tail will be just inside the liner top. They can then keep the high rate producer that this well was before So the question to you is, would it be acceptable to have the production packer this high above the perfs in this situation? I will call you this afternoon to discuss. Thanks Dan Stone RECEIVED MAR 2 $ 2000 0~1 ~ ~a~ Gon$. ~mmi:~jon Ifil} r~ NOI,I,VHO;IAY,~q ttH P..[i[g 17.q~ L0~i }(V,q §~: 0 [ O01$:Z/$:0 J ................. Rllllflllllll 11 I DS 09-43 Proposed Completion TREE: ~ ~ ~! Cel]ar Elevation = WELLHEAD: ! ~ Orig RKB = 51' t0-3/4", 45.5 #~, J-55, BTC ~ GAS LIFT MANDRELS / # MD Size Valve Type -- 4-1/2" 12.6# 13CR, Tubing ~ i 5 From sudaca to H ~ ~ 7-5/8" x 4-1/2" Baker Packer at 6500'. liJ-~--- 5-1/2" 17# 13CR STL scab prod liner from +I-6600' to 12050' Cretaceous exlernal '; co~msion. Top of scab liner I1!1 Fully Cemented with liner top packer, liner hanger @6800'. cretaceousdesigned ,o be above lop Ofzones at 6600' !J Scab liner may be 4-1/2' chrome dependirlg on pipe availabilily. Perfslrom 12230'to 12388'~...~.: I RECEIVED ~ N1AR 25 2000 7-b? ~'F~j~ I 'zo~Aj~ska u, ~ u~ c0n~. commission ~ . Date Rev By Comments Arco Alaska, Inc 12/2/99 JES Proposed Completion WELL: 09-43 APl NO: 50-029-22078 ,,, ..... Shared Services Drilling "' II GAS LIFT MANDRELS # MD Size Valve Type 4 ~ , 7nn F/~ kTfll,i,¥Nflq,t¥5t riff [26 [g lzge~ LO6 'X'V~[ 9c~: 0 [ 00/~,/~20 ,__. STATE OF ALASKA ~... ALASKA AND GAS CONSERVATION CC AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X ,,, Pull tubing , Alter casing ,,, Repair well,,, Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1992' FSL, 62' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2391 FNL, 279' FEL, Sec. 36, T11N, R15E, UM At effective depth At total depth 2226' FNL, 84' FEL, Sec. 36, T11 N, R15E, UM 5. Type of Well Development X , Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-43 9. Permit number/approval number 90-107 10. APl number 50 - 029-22078 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Sudace 4230' Production 12497' 12575' feet 9012' feet Plugs(measured) Fill @ 12389' MD (7/12/94) 12389 feet 8890 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 55 sx AS 110' 110' 1500 sx CS III & 350 sx CE G, Top Job w/100 4282' 3508' 10-3/4" sx cs ~ 7-5/8" 500 sx ARC 12549' 8995' Perforation depth: measured 12230-12235'; 12254-12264'; 12306-12325'; 12333-12351'; 12356-12388' true vertical 8781-8784'; 8797-8804'; 8834-8847'; 8852-8864'; 8867-8889' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, PCT @ 12000' MD; 3-1/2", 9.3#, L-80, PCT tail @ 12101' MD Packers and SSSV (type and measured depth) Baker FB-1 pkr @ 12000' MD, 4-1/2", Otis HRQ SSSV @ 2188' MD 13. Stimulation or cement squeeze summary 14. RECEIVED Intervals treated(measured) See attached. Treatment description including volumes used and final pressure ~.epresentative Daily Averaqe Production or Inje'~JB~ta Oil-Bbl Gas-Md Water-Bbl Oasing Pressur~ Tubing Pressure Prior to well operation 1147 10506 4956 -- 513 Subsequent to operation 1328 11932 5053 -- 500 15. Attachments Copies of Logs and Surveys run.. Daily Report of Well Operations .. 16. Status of well classification as: Oil x Gas , Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'t/~,,~Q~{,)b ~ Title Form 10-404 '!!~ev 06/15)-88" 1192/13 cc: KZ, JWP Engineering Supervisor Date ~t~'o/~ ~ ~-~, SUBMIT IN DUPLICATE ~ 9-43 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/23/94: RIH & tagged PBTD at 12338' MD. 7/1 0/94: RIH w/CT & jetted a fill cleanout using biozan, down to 12390' MD. 7/1 2/94: MIRU & PT equipment. RIH w/perforating gun #1 & tagged PBTD at 12389' MD, then PU & shot 47' of perforations as follows: Added perforations: 12230 - 12235' MD (Z2) 12254 - 12264' MD (Z2) 12356 - 12357' MD (Z1B) 12372 - 12378' MD (ZlB) Ref. Log: CNL 8/23/90. Reperforated: 12357 - 12372' MD (Z1B) 12378 - 12388' MD (Z1B) Ref. Log: CNL 8/23/90. Used 2-1/8" carriers, & shot 4 spf (except 12368 - 12372' MD : shot 8 spf), at 0 degree phasing, at underbalanced pressures. POOH w/perf guns. Rigged down. Returned the well to production & obtained a valid welltest. ARCO Alaska, Inc. Date: Subject: Fro m/Lo cat ion: Telephone: To/Location: August 3, 1994 ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 265-6547 Distribution P.O. Box 100360, ArmChorage, AK Transmittal #: 94069 99510,~ ~b' Well Log Date Tool Type Run Contractor Number (M-D-Y) 16-24 7-11-94 Prod Prof 1 SCH 14-07 7-12-94 Leak Det 1 SCH 12-32 7-10-94 Perf Record 1 SCH 09-43 7-12-94 Pef Record 1 SCH ,., 09-06 7-11-94 Leak Det 1 SCH 07-03 7-10-94 Dual Burst TDT-P 1 SCH ., 01-18 7-9-94 Perf Record 1 SCH Number of Records: 7 Karla Zuspan Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil Please ackn,c~ledge rec,e~J/by signing and r~_~g a cot~,Z>f~transmittal. ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfleldCompany STATE OF ALASKA REPORT SUNDRY WELL OPF_.HATIONS 1. Operations performed: Operation shutdown . Stimulate., X,, Plugging Pull tubing Alter casing Repair well , 2. Name of Operator ARCO Alaska, Inc. 6. Datum of elevation(DF or KB) ( 52' RKB feet 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1992' FSL, 62' FEL, sec. 2, T10N, R15E, UM At top of productive interval 2391' FNL, 279' FEL, Sec. 36, T11N, R15E, UM At effective depth At total depth 2226' FNL, 84' FEL, Sec. 36, T11 N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 4230' Production 12497' Perforation depth: 5. Type of Well Development X Exploratory Stratigraphic ,,, Service 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-43 9. Permit number/approval number 90-107 10. APl number 50 - 029-22078 11. Field/Pool Prudhoe Bay Oil Pool 12575' feet 9012' feet Plugs(measured) Fill @ 12390' MD (3/17/93) 12390' feet 8891' feet Junk(measured) Size Cemented 20" 55 SX AS 10-3/4" 1500 sx CS III & 350 sx CL G Top Job w/100 sx CS II 7-5/8" 500 sx ARC Measured depth True ve~icaldepth 110' 110' 4282' 35O8' 12549' 8995' measured 12306-12325'; 12333-12351 '; 12364-12366'; 12384-12386' true vertical 8834-8847'; 8852-8864'; 8872-8874'; 8886-8888' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, PCT @ 12000' MD; 3-1/2", 9.3#, L-80, PCT Tail @ 12101' MD Packers and SSSV (type and measured depth) Baker FB-1 pkr @ 12000' MD, 4-1/2" Otis HRQ SSSV @ 2188' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached. 2 4 199;5 Treatment description including volumes used and final pressure Alaska 0ii & Gas CORS. C01-flt'ftiSsi0rt ,Representative Daily Average Production or Injection Data ,-,,,,,h0rag0 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 659 590 2730 -- 321 Subsequent to operation 1181 4268 2987 -- 686 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas__. Suspended,,.._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 994/2 JCA cc:SW, JWP 9-43 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF ZONE I 3/10/93: RIH & tagged bottom at 12381' MD. 3/11193: MIRU CTU & PT equipment. Loaded the wellbore w/Seawater & Crude, then RIH w/CT & pumped gelled sand slurry containing 2300 lbs of sand, to isolate the lower perforation intervals located at: 12333 - 12351' MD (Zl) 12364 - 12366' MD (Zl) 12384 - 12386' MD (Zl) Ref. Log: CNL 8/23/90. Made final top of sand plug tag at 12339' MD. POOH w/CT. Rigged down. 3/12/93: RIH & tagged top of sand plug at 12328' 3/15/93: MIRU & PT to 9600 psi. Pumped a Data Frac & Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforations located above the sand plug at: 12306 - 12325' MD (Z1) Ref. Log: CNL 8/23/90. Pumped Data Frac: a) 270 bbls Pre Pad @ 35 bpm, followed by b) Shutdown. Resumed pumping Data Frac: c) 400 bbls Pad @ 35 bpm, followed by d) Shutdown. ISlP @ 1680. Resumed pumping Fracture Treatment: e) 500 bbls 40# Crosslinked Pad @ 42 bpm, followed by f) 900 bbls Slurry, w/proppant stages @ I - 10 ppg, followed by g) 180 bbis Flush, followed by h) Shutdown. Placed a total of 153,000 lbs of proppant in the formation. Rigged down. 3/16/93: Performed a CT proppant/sand plug fill cleanout to 12390' MD. 3/17/93: RIH & tagged bottom fill at 12390' MD. Placed well on production & obtained a valid welltest. ,~iask~ Oil & Gas Cons. Anchorage /7 ARCO Alaska, Inc. P.O.Box 100360 AnChorage, Alaska 99510 DATE: 6-19-92 REFERENCE: 7-9 X~- 11-5 J/~ ARCO CASED HOLE FINALS 5-12-92 Jewelry Run 1, 5" 5-21-92 GR-Collar Run 1, 5" 5-15-92 Prod Profile Run 1, ii" 5-12-92 Prod Profile Run 1, 5" 5-12-92 Jewelry Run 1, 5" 5-17-92 Prod Profile Run 1, ~'Sd~' 5-1 1-92 Prod Profile Run 1, 5" 5-16-92 PITS Run 1, 5" 5-15-92 PITS/Flowmeter Run 1, 5" 5-24-92 Prod Profile Run 1, 5" 5-16-92 Prod Profile Run 1, 5" 5.15-92 Prod Profile Run 1, 5" 5-14-92 Prod Profile Run 1, 5" 5-14-92 Prod Profile Run 1, 5" 5-18-92 Gas Lift Run 1, 5-25-92 InJ Profile Run 1, 5" 5-14-92 InJ Profile Run 1, 5" 5-14-92 InJ Profile Run 1, 5" 5-19-92 CCL/GR/Junk Basket ~ 3, 5" · Clunco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco C~mco C~mco Camco Please sign and return the attached copy as receipt of data. RECEIVED BY .~~ ATrP PansRf~fll~ ~1~- Have A Nice Day! Sonya Wallace ATO- 1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF AI2~KA TEXACO RECEIVED * The correct APl# for 9-30ST is 50-029-21411-00. AU(; ] 0 1992 Alaska Oil & ~as Cons. Commissbn Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOI~- FINALS 3-8 2-25-92 Collar R~m 1, 5" ?/-~ 3-35 2-21-92 CCLfPerf Run 1, 5" ?/-~' i 4-3 2-9-92 Perf Record Run 1, 5" 4-3 3-2-92 Perf Record R~_m 1, 5" ?J'- ?~ 4-7ST 3-2-92 Perf Record Run 1, 5" ??-~ ~ 5-14 2-11-92 Perf Record R~_m 1, 5" ~Z~z ? 6-21 2-22-92 CCL/Pe~f R._n 1, 5" ~°~/~? 9-43 2-12-92 Perf R~_~_n 1, 5" ?/_~-z~, 11-3A 2-23-92 CCL/Perf Run 1, 5" ~! z~--- 14-32 2-28-92 Perf Record Run 1, 5" 2-28-92 Perf Record ~+/-,.~/~17-11 R~_m 1, 5" Please sign and return the attached copy as receipt of data.~ ~ C ~ ~] ~ O RECEIVED BY Have A Nice Day! Sonya Wallace ATO- 1529 G~s Cons. Comm'tssion ~laska 0~ ~ APPROVED84~// ~s~ 920 it CENTRAL FH.ES it CHEVRON D&M it EXTENSION EXPLORATION it EXXON MARATHON it MOBIL it PHILLIPS PB WELL ~ R&D it BPX it STATE OF ALASKA TEXACO * The correct APl# for 11-3A is 50-029-20666-01. STATE OF ALASKA ALASKA~' AND GAS CONSERVATION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1992' FSL, 62' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2391' FNL, 279' FEL, Sec. 36, T11N, R15E, UM At effective depth At total depth 2226' FNL, 84' FEL, Sec. 36, T11 N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED 6. Datum of elevation(DF or KB) 52' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-43 9. Permit number/approval number 90-107 10. APl number 50 - 029-22078 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12575' feet Plugs(measured) 9012' feet Effective depth: measured 12460' feet true vertical 8936' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 55 sx AS 110' 110' Sudace 4230' 10-3/4" ~s0o sx CS III & 350 sx CL 'G' Top Job w/100 4282' 3508' sx CS II Production 12497' 7-5/8" 500 sx ARC' 12549' 8995' Perforation depth: measured 12306-12325';12333-12351';12364-12366';12384-12386' true vertical 8834-8847' ;8852-8864' ;8872-8874' ;8886-8888' Tubing (size, grade, and measured depth) 4-1/2",12.6#,L-80,PCT @ 12000' MD;3-1/2",9.3#,L-80,PCT tail @ 12101'MD Packers and SSSV (type and measured depth) Baker FB-1 pkr @ 12000' MD,4-1/2" Otis HRQ SSSV @ 2188' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 525 420 11 3900r~'~' 2000 404 Tubing Pressure 310 398 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: OilX__ Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title FS-2 Regional Operations Engineer Date ,~/.-5~/'~ ~- SUBMIT/IN DUPLICATE .... ~ILY REPORT OF WELL OPER~ IONS DS 9-43 Perforating Operations: ARCO Alaska, Inc. perforated DS 9-43 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 2/12/92. The intervals perforated were the following: 12306'-12325'; 12333'-12351' MD (Reference Log: SWS-GR/CCL dated 8/30/90). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 2/12/92. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. S.I. well, RIH and perforated 12330'-12348' MD at 2 SPF, POOH, Tool Misfired. RIH and perforated 12330'-12348' MD at 2 SPF, POOH, and confirmed all shots fired. RIH and perforated 12306'-12325' MD at 2 SPF, POOH, and confirmed all shots fired. (ref: SWS-GR/CCL of 8/30/90). Rigged down and secured well. RDC: 4/16/92 ARCO Alaska, Inc. Post Office Bo× Anchorage, Alaska 99510-.0360 Telephone 907 276 12!5 October 11, 1991 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commissioner 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 9-43 Permit No, 90-107 API No. 50-029-22078 Fi~$ SR SR ~NG ASS Dear Mr. Johnston: ARCO Alaska, Inc. requests a waiver on DS 9-43 to Conservation Order 165, Rule 11A, which pertains to the requirement of obtaining initial production profiles on new wells. PBU 9-43 is a new well that was perforated and fractured in Zone i to encourage production from this interval. The frac is still being evaluated, after which additional Zone i perforations will be shot. ARCO Alaska, Inc. rquests a waiver of Conservation Order 165, Rule 1 lA for this well until these perforations are performed. If you have any questions pertaining to this waiver request, please contact Greg S. Sanders at (907) 265-6856. Sincerely, Daniel J. Regional Engineer Prudhoe Bay Operations Engineering RECEIV 'D CC' James Bennett, BP Exploration, Anchorage OCT Oil & Gas Cons, Anchorag{l ARCO Alaska, Inc. is a Subsidiary of At ~ t cR ; '.4 e L;o p~ V STATE OF ALASKA ALASKA''~-~' AND GAS CONSERVATION C¢'~"AISSION~ ~-~'''''~ REPORT SUNDRY WELL OPERATIONS Stimulate X 1. Operations performed: Operation shutdown Pull tubing Alter casing Plugging Repair well Perforate X Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1992' FSL, 62' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2391' FNL, 279' FEL, Sec. 36, T11N, R15E, UM At effective depth At total depth 2226' FNL, 84' FEL, Sec. 36, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9 ~43 9. Permit number/approval number 90-107 10. APl number 50 - 029-22078 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12575 feet true vertical 9012 feet Effective depth: measured 12460 feet true vertical 8936 feet Casing Length Size Conductor 110' 20" Surface 4230' 10-3/4" Plugs(measured) Junk(measured) Cemented 55 sx AS 1500 sx CS III, 350 sx 'G' & 100 sx CS II Measured depth True verticaldepth 110' 110' 4282' 3508' Production 12497' 7-5/8" 500 sx ARC 12549' 8995' Perforation depth: measured 12364-12366'; 12384-12386' true vertical 8872-8874'; 8886-8888' Tubing (size, grade, and measured depth) 4-1/2", 12.64¢, L-80, PCT @ 12000' MD; 3-1/2", 9.3#, L-80, PCT tail @ 12101' MD Packers and SSSV (type and measured depth) Baker FB-1 packer @ 12000' MD; 4-1/2" Otis HRQ SSSV @ 2188' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure SEP 0 4 1991 Alaska 0il & Gas Cons. C0m~ss!~ 14. Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl 312 --J 981 36 Casing Pressure Tubing Pressure 274 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . 16. Status of well classification as: Oil X Gas__. Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 746JCA c: SW, JWP DS 9-43 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENTS OF ZONE I & PRE-FRAC CTU CEMENT SQUEEZE 10/27/90: MIRU & PT equipment to 7500 psi, then performed a Perforation Breakdown Treatment & Hydraulic Fracture Treatment to initiate flow through the initial perforations (shot 9/15/90), at: 12378 - 12414' MD (Zl) Ref. Log: CNL 8/23/90. Pumped Perforation Breakdown: a) 315 bbls Seawater Gel, w/180 ball sealers, @ 15 bpm / 4400 psi, followed by b) Shutdown. ISIP @ 2400. Surged well twice to unseat balls & resumed pumping c) 80 bbls Seawater Flush, @ 20 bpm, followed by d) Shutdown. ISIP @ 2400. Surged well, then proceeded with Fracture Treatment. Pumped Fracture Treatment: e) 375 bbls 40# Crosslinked Gelled Pad, @ 25 - 30 bpm, followed by f) 125 bbls Crosslinked Slurry w/proppant concentrations of 2 - 9 ppg, @ 25 bpm, followed by g) 104 bbls Flush, followed by h) Shutdown. Placed a total of 2,200 lbs of proppant into the formation. Rigged down. 10/29/91 - 11/5/91: Performed proppant fill cleanouts to 12435' MD. 1/13/91: Reperforated : 12378 - 12404' MD (Zl) Ref. Log: CNL 8/23/90. 3/3/9 I: MIRU & PT equipment to 5000 psi, then pumped a Perforation Breakdown Treatment through perforations: 12378 - 12404' MD (Z1) Ref. Log: CNL 8/23/90. 12404 - 12414' MD (Z1) Pumped: a) 15 bbls A-Sol P-38 (alcohol solvent), followed by b) 267 bbls Gelled Seawater, @ 11- 22 bpm / 4600 psi, followed by c) Shutdown. ISIP @ 2730. Resumed pumping d) 100 bbls Gelled Seawater, @ 20 bpm, followed by e) Shutdown. ISIP @ 2400. 3/6/9 I: MIRU & PT equipment to 8500 psi, then performed a Hydraulic Fracture Treatment to initiate flow through the perforations (listed above). Pumped: a) 200 bbls 40# Pre Pad, @ 25 bpm / 4800 psi, followed by b) Shutdown. ISIP @ 2400. Resumed pumping c) 350 bbls 40# Crosslinked Gelled Pad, @ 25 bpm / 6000 psi, followed by d) 125 bbls Crosslinked Slurry w/proppant concentrations of 1 - 11 ppg, @ 25 bpm, followed by e) 118 bbls 40# Flush, @ 25 bpm, followed by f) Shutdown. Placed a total of 23,500 lbs of proppant into the formation. 3/1 0/9 I: Performed a proppant fill cleanout to 12404' MD. 4/21/91: Added perforations: 12357 - 12372' MD (Z1) Ref. Log: CNL Rigged down. 8/23/90. RECEIVED $ E P 0 1991 Alaska Oil & Gas Cons. C0mm.isS|~ DS 9-43 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENTS OF ZONE I & PRE-FRAC CTU CEMENT SQUEEZE 5/23/9 1: MIRU & PT equipment to 9500 psi, then pumped a Hydraulic Fracture Treatment through the perforations: 12357 - 12372' MD (Z1) Ref. Log: CNL 8/23/90. 12378 - 12414' MD (Z1) Pumped: a) 200 bbls Pre Pad, @ 25 bpm, followed by b) Shutdown. ISIP @ 2600. Resumed pumping c) 228 bbls 40# Pad, @ 35 bpm / 5000 psi, followed by d) 207 bbls Crosslinked Slurry w/proppant concentrations of 1 - 12 ppg, @ 35 bpm, followed by e) 32 bbls Flush, followed by f) Shutdown. Placed a total of 4,000 lbs of proppant into the formation. Rigged down. 5/25/91 - 5/31/91: Performed proppant fill cleanouts to 12436' MD. 7/2/9 I: MIRU CTU & PT equipment to 4500 psi. Loaded wellbore w/Seawater, then RIH w/CT & pumped 35 bbls "junk" plug, (contains XCD gel, 100 mesh sand, silica flour, & barite), squeezing the perforations (listed above). Placed all 35 bbls of "junk" plug behind pipe at 2100 psi max squeeze pressure, held for 20 minutes. Jetted out fill from wellbore. POOH. Rigged down. 7/9/91: A CTU Cement Squeeze was performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/Seawater, then RIH w/CT & pumped 25 bbls of PVA cement, followed by 26.5 bbls of PVA cement w/20# bbl Perfect Seal, squeezing the perforations (listed above). Placed 30 bbls of cement behind pipe at 3500 psi maximum squeeze pressure, held for 20 minutes. Contaminated cement & jetted out contaminated cement from wellbore. 7/15/91: Reperforated: 12364 - 12366' MD (Z1) 12384 - 12386' MD (Z1) Ref. Log: CNL 8/23/90. 7/17/91: POOH. Rigged down. RECEIVED S E P 0 4 199t Alaska 0il & 6as Cons. C0mt~tss[0tl MIRU & PT equipment to 9500 psi, then performed a Perforation Breakdown Treatment~Cl~l~ic Fracture Treatment to initiate flow through the initial perforations (listed above). Pumped Perforation Breakdown: a) 537 bbls Seawater Gel, @ 25 - 35 bpm / 5000 avg psi, followed by b) Shutdown. ISIP @ 2500. Proceeded with Fracture Treatment. Pumped Fracture Treatment: c) 329 bbls Pre Pad, @ 36 bpm, followed by d) Shutdown. ISIP @ 2826. Resumed pumping e) 250 bbls Pad, followed by f) 790 bbls Crosslinked Slurry w/proppant concentrations of 0.5 - 10 ppg, @ 35 bpm, followed by g) 90 bbls Flush, followed by h) Shutdown. Placed Placed a total of 48,000 lbs of proppant into the formation. Rigged down. well on initial fulltime production w/gas lift & obtained a valid production test. ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 995 .~DATE: 8-2-9t REFERENCE' ARCO CASED HOLE FINALS i-4 · 3-t 6-9i 2-3. 5-22-9t 3-2 - 4-22-9t 3-2 · 5-26-9t 3-22 · 7-t 3-9i 3-27' 3-i 5-9i ~:~ .._/~ 3-27 ' 7-i 3-9i 5-t 9' 7-t 4-9i '?-4' 6-22-9t 7-23- 3-30-9i 7-28- 5-25-9i 9-4- 5-t 6-9i 9-8- 5-t -9i -35 7-~ 4-9t -43. 7-i 5-9t 9-46- 5-6-9i C~O-J ~3~ 9-46- 5-t '?-9~ ** t 1-25- 7-t 4-9t *** ~i 6-9A · 6-3-9t F'ERF RECORD PERF RECORD CCL F'ERF RECORD F'DK- ~ O0/GR/CCL PERF RECORD PDK-~OO/GR/CCL CNL COLLAR LOG PERF RECORD COLLAR LOG TUBING PATCH PERF RECORD PERF RECORD PDK-~/GR/CCL-BORAX CCL-PERF RECORD JEWELRY-COMPLETION RECORD PERF-UEWELRY RECORD CNL PERF RECORD RUN t, 5" RUN t, 5' RUN t, 5" RUN ~, 5' RUN t, 5" RUN t, 5" RUN t, 5" RUN t, 5" RUN t, 5' RUN ~, 5' RUN RUN RUN t, 5' RUN t, 5" RUN J, 5' RUN t, 5' RUN t, 5' RUN t, 5' RUN ~, 5' RUN PLEASE SIGN AND RETURN I'HE ATTACHED COPY AS RECEIPT.OF DATA. RECEIVED BY ~__________________~ HAVE A NICE DAY! SONYA WALLACE AT0-t529 AF, F, ROVED~~-~ TRANS~ 9 HLS HL$ HLS HLS ATLAS HLS ATLAS SCH HLS HL$ HLS HLS HLS HLS ATLAS ATLAS HLS HLS SCH HLS DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL FILES R & D p B X STATE OF ALASKA TEXACO * THE CORRECTED LOG INTERVAL FOR 9-46 IS t4408'-i5160', ** THE CORRECTED AP l~ r-'OR ~'t-25: I$ 50-029-20488-.0t. *** THE CORRECI"ED AF'I~ FOR t6-9A IS 50-029-20558-01, STATE OF ALASKA ALASK/~ '. AND GAS CONSERVATION REPORT uF SUNDRY WELL OPi::HATIONS 1. Operations performed: Operation shutdown., Stimulate Plugging , Perforate X Pull tubing Alter casing Repair well ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface 1992' FSL, 62' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2450' FNL, 0' FEL, Sec. 36, T11N, R15E, UM (APPROX) At effective depth 2200' FSL, 200' FWL, Sec. 36, T11N, R15E, UM (APPROX) At total depth 2365' FSL, 74' FWL, Sec. 31, T11N, R15E, UM (APPROX) X 6. Datum of elevation(DF or KB) RKB 52 7. Unit or Property Prudhoe Bay Unit 8. Well number /. 9-43 ~' 9. Permit number/approval number 90-107 10. APl number 50 - 029-22078 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12575 feet Plugs(measured) 9012 feet Effective depth: measured 12460 feet true vertical 8936 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 1775# Poleset Sudace 4197' 10-3/4" 1500 sx CS III & 350 sx Class G Production Liner 12549' 7-5/8" 500 SX ARC Measured depth 110' 4230' 12549' True vertical depth 110' 3500' 8995' Perforation depth: measured 12357-12372', 12378-12404', 12404-12414' true vertical 8868-8878', 8882-8899', 8899-8905' Tubing (size, grade, and measured depth) 4-1/2', L-80, 12000 Packers and SSSV (type and measured depth) Baker FB-1 packer, 12000 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure jUN ! ? 199 Alaska 0il & Gas Cons. commisslop Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae PrQduction or~ Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 160,x/'' 150 0 Tubing Pressure 0 300 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: OilX Gas__ Suspended..._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed dJ~?~ , ,.,.~[j~'~ Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUN/nb Date ~/t~/~1 SUBMIT IN DUPLICATE DS 9-43 PERFORATING SUMMARY OF OPERATIONS ARCO Alaska, Inc. perforated DS 9-43 in the Ivishak Sand of the Prudhoe Bay Unit on 1/13/91 (12378-12404' MD) and on 4/21/91 (12357-12372' MD), ref. log DIL 8/23/90. Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/lubricator tested to 1.2 times the maximum expected surface pressure. A summary of the work is below: Rig up perforating unit on 1/13/91 and pressure tested equipment to 3000 psi. open up well and produce with drawdown. SI Well. shot 12388-12404' MD, 4 spf. open up well and produce with drawdown. SI Well. shot 12378-12388' MD, 4 spf. Secured well. RD. Propped fracture well. Returned well back to production. 1.5 MMscf gas lift gas for 1.5 MMscf gas lift gas for No production. Rig up perforating unit on 4/21/91 and pressure tested equipment to 3000 psi. open up well and produce with 1.0 MMscf gas lift gas for drawdown. shot 12357-12372' MD, 4 spf in preparation for re-fracture. - ~' ~ .... . ..... . ..... ~ ~'.-.-' ', '.. -...'-.. ·., ."~ . '-..~' .'- .~ '~ . . ~' ~'.'~ · ,'.~-" ~?~ .-~ "'~ ."' . "'~-y-.:~'~%~.m~'~ ~-~.'~ '.~ ' '" ' . ~ ~. 0. - ~OX .. t ~~ ~..-,~ · ~.? ..~ ~?.~,.~,~='~.'~..~'~.~:~.~.~ ~'.~. '.~.'~ .' ...... -'" ;'=> ~' ~.~'"-' ..'~% ~'~'~.-" :. ' ": ', =;~=~'~ ~?..-~,~ :- ~-." ANCHORAGE-:."'ALAXKA' 995 t 0 :'~:?.~:~,{?:{;: t,:,qX;/~'T:'::.' ' ... .... ::; ...:'.~¢~>:<:;,.L~"~.-j.'.,:~}~:. ~.~~:,~ ~...~.:-~.. . ~ _~,_.-_-~ - -: ~-~~ ....... :- - . ~---,-.-. ....... =~.-- -~ --~ ....... ,.. ..- · .- ~ .- .,'-'~ ~ r?.,~¥, . · · ~ ~.....~-~'-~ ~.~'" '~. ~" ~ · - . -','-~ .... -. · .... ~ ..... ~- ~ .~. ~'. ~,.~?~=-..~:::/~t..-.' .... .-.. ..... ~". - .' -' ..% ': ~- ~-., ~-~..' -:- .':~.'.. .... .'-,.x~ 4..~'~ - ,~'~q:'--. ':- '. . . .' ~ .' '.i 7$ ." - "'., ' ' ~ .. " ~.. ':'~, ..S ..'C~%:~:',~'~SX~'~,'_~.,~..~ .' ,,...:,S .~' ,'. ......... ': .~':," .-. Z~ ~.~L'-',~-~:.~.,~:,~;.,-'-~' ,,'~C.'~~ ~:r~.4~ ;.., ' ......... ,', :,~ :.~.' r:.c.''. ,-=:~ .-. · - ~. 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'~-..~.::~.vv~!c~'.-%.~ ? -..~.~ ~.'~.- ........ : ....... ........=.=..~:~.e~S~.~..., :. · ~c=.:s-":..~? REFERENC~: ' 'ARCO CA~E~ ~HOLE 'flNAL~..'.~'.' -' ' :."':."~=,..:')?Xq '.- ' -" ' '~.~=:'...~.'~V'.."-.= .'.~.',~ ~--~'.. ~ ~.','.~, ~.~. .~ ~ -:-",~-~ -% .~ ~T~' ~'~,~!'~.~.. '~ .~-?~'"' "Z:~%~'"? '..~:'; .~m~ ~m~".~' '~ ~'-.-..':2~.~: ~-~'.~:;" .... ~--~ · ~ 1~ ~1 .... .. ~'~<~U~ ..................... . ........ ... .......... ~,,.,..., ...... __ . . . _ · ... , . - .. .... - . , · ~- ~..: ~.. ~ ' . · .= ~ .-... ~ ~.-' ~,. ~, ~,~- ...... .... . ..... ~ ... ....... ., . ..... , -., .... ~ .... .. ,.~=, .,. ., ,.,~,.~., -.:~ .e, ,.~- ~,.. ,,. ...... , .... . ......... ~-.~ ...... ~ * ....... · ~..-.. :~..~ .. ..... , ~;;.-:.., ..-,... ,.~.. -... .~ .. ;-..q..,~. . - ?--... ,,.~.*,..,.. ~ ,-., n*. --..- . ..~.- ...., . .-..,e~ ' m '- ' -' .~ .:~;.'~-~r' - ' "-?' ~s. 4 'n ' · "-"::a-t q-gt ",'-'..'*;y~NJECTION '";.'-.~".'?'"; ..... '" .. ' .. ,;. RUN .-.i., . ~ .... ...:.c,:....:***.CA~CO , , ~ .- ~ .."' ::..' * ~ .... ~ .< ' .*",,~ .... ~ .; .... , ~'",-;'L~'.,'~;~. ~., ;, C~.s ........... ,-..~ ...... ~.-;' -;' . m *.' '~'~ -' ' ~-- .......... ~ ~ .". ...... ~ ~o 'o,-?...; ...... ~.~c.*i"~"-~'.*~:.~.,~:'~.',:::'~* .... .-:.:.:.:' .. .'. '."..- ....... *..~' RUN ?t',-.:.. 5 ......... ,..,...:;:;....HL~ · · - . · ,. · . .- , .~, . ..- , ,. ,.; .. ,~. -* . ,~. , .,...~; ~ . ~:.-~'~,*~',,.~ ... .. :~ '; ;.. . .;; . . .... i* . .~;-. ~ · .,%,...~.F..'.. ~ ' . - ~ .-~ ··' -~~/ ' *. ''.,'~,~ ~',;':'., -'.'e? '"~".'X"'~ ..... - ::'~' ' · " '" ' *" ........... . · .:' ".~-~ '.'- 4~4 ~-9t '.*':.'.,:~.;.'~-,,=..-~-~ '~'..;;?" . .: ;.. .'.' '." · -" '. ..... .:.- .' .'~ .... - ' ........ '"'~'?"~ "'"' ~-' '" ..... "'~G .......................................... RUNt'*t7' S' ........... . "'CAHCO "" ...... 6-6 -~-4 ~-9t 'GAMMA ;.~A~/CCE..T . .. · · . ...... - .. '-;,.:,.-, '". " ' "' ' '~' '"' .... ' ..... ~"' ' '* ' ' ...... m · ' ~ .....'"'" '"" RUN 4, 5 .;.,~..:....~ 9-3~ 5-5-9~ . ,.'..~DT.;:.;~ · ' ' .. ' .... ~ o~ ;~.~--ET~ ...... ,,-~: ..... - . '": .... ~' ' s7.E.~UN'i l:;"; ~~-- .~:._.:~ '~*~,.'-:' -'--&, ~a-~-"~. ........... ~ :' ~:~,~.-.::;: ...... . ............. ,,..-...~.~,~. ~.,,:~:~,,~;.-..,..,; .~-..._ ... :.~.. --' · ...... ~p[~ .~-40 ...' 3mt9-91 ,:~.GAMNA..~C~.: OE:; JEWELRY FERF 5 '.". (T-~9=~-~ .... , ....... ~'~'- "r ~ ~ ;-.. ' I "~-'~'~" ' .' :h ..... ' " '~ECO~J.~ ,.'~ "~ ~:~ RUN ...~. ..~ ' ~. '~ . .. - 'r -. ,."[ - · t.- .~: ,. ·: .... ; . ~..'~.... -~ ,~. .... ~ ~;'. ,.': ~ ~:, ....... .-.._.:~ ~ .... . PLEASE ~$IGN'"AND 'RETURN *COPY" AS RECEIPT ". .. .~ ~. ~. _.. ~ ~.:'~j.~. '~ __~___ _ -: .~ ', . ~ -~ ~ -'~ ; ~..~-~i · ~;~.~ . . -~. ,. ,..:.,~: ~,::~;, .. "' HAVE "A' ~I CE"D'AY ~'~.. ,--::': -'t':..-.' "' . ' ' ':; '~-' ~ .... ;-~ ... '-.~. -. · .. . -' ' " ~ O--A~-~ ...."'-:"" .... " "~ :~"::'~"':'-';; ' AF · -.. m ..... ~IL~ON -' ..,' ..~ ~.. ; ._ .. ,: :,~_ :.- ....;~ .... . ATO-~ 529 '-'..--,......:.-- ' . TRANS':~ 9 ~ 49 - .'- :. o.,..?~. ... -,~ - ~ ..,-';'~' ...... r~:'- ' . . "~; ..... .................... ~ -.,~--~..~.~ .... . :.,.j .~ -- ?, ~. . . .' ~. · ~.~ -~,?~..~..'. . . -- . ,-, ,~. _ ..~ . ;,, . . .., :- '. ::.'. ,,: ~' ;::.L"?~;~;>. · . . . -. ~.. ,:,.~ - ... ~.:... .... ~- . .... ..... .._ :, ..... ,,.,.... - .... .?~.~ '.,~-.,~:~:~-~_~,~..~,-~:~, '::;.~.~., -~ ~:;~. ~:.~:~_~-:,-.~.~ ,-.. , ' , ~..."~;~'; ~~ .... . - ..- . '- ~ .. . -~..-.." ... . ,~, ...... ,~'.-- . - - . ~, -.. - .-..~. - _ -.. ~ - . ,- . .,~-~: ~,,.; · ~,.:~ · . ~ ' .. .:':' .'.~ CENTRAL~ FILES ;.~:.:-;:.';,~.."- ,' ~ ~HILLIP$ '~; ..~ . . .:.,. -~. .. :...:;'~-..~ ~ ;/.'; -.,~' - ~.~:.,;~;- .~.-.;'-~.' ,- .. :.. ~ . ,- ....... . ..... . ....... ~ ......,,. ......... -... 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'.. · ~ ~1 --: ~ ..... ~i' iii ~I ~ Ii~ i I ~ II i _ · ~ .,.. ,~-- ... . . . ~ ....... . .. -.. ~ ~ .... A R C 0 A Lo A,'.f K A, I N (]:~ P~O~ BOX ~ ¢)C.~S6~) · ANCHORAGE~ AL. ASKA 995i0 R E F' E: F< Ii; N C E ' A R C 0 C A,S' E D I"I 0 L !!.". F i N A L. S ",~ n ':.~. 4-"- 9 i 'T' E H F' E R A 'T' U R E 2 .... i6 4 .... iS..-.9i L. EAK DETFZC. TION 3 .... t 7 4 - i 3 -. 9 i L. Iii: A K D Ii..". 'i" E C '1" I C! N ,,q, 4 .... i ,,:.:, 4 .... 6.-9i ! N,J Ii/.C T I 0 N I "~/',,,'q "'J"',: .... 2 (') 4 .... 22 - 9 i C B i- 6 .... t 5: 4 -8 "" 9 t F' F: 0 D U C '!" I 0 N 6 '"' '2 ';:..~ 4 "" 6 - 91 P R 0 D LJ C': T I 0 N 9 "" 4 4 .... t 3 '"' 9 i L. Iii] A K ][:' E T lie C "1" I 0 N ':":' .... '::." 4 .... '.""::- 9 'i I... Iii] h 1< D lii]'i" E C"I" I 0 N qO - Io'-1 ,.",.--"::, t, ... ..... :?.',, C:OLL. AF.:,"F'ERF o11-o q,.-, ,-, . · ; ...... ~ 6 4 .... 4.-.. 9 i [; A H H A /C C I... / J Iii: Wiii:l... R Y i i .... i 4. '"- · -' ,:. --, i I... Ii.;. A K D Iii: T li'] C'I" I 0 N ii .... 3 4 .... 2-9i L.!ii:AK DEI"fi:C:IZON t t .... 4 4 .... 3-'--9 t F:' I l' S / I Iq J E C'¥ I 0 N i '" © -' .4 .... 6- 9 i N IF r: l' I C) N ,..:. - ,:. ,:~ I ....... t 2 .... '25 4 - t 4 - 9 t I N,.J Ii:' C i" I 0 N · x- t 4 "- '23 3 - 3 - 9 i F' R 0 D U C 1' I 0 N t 4-.3'-':'. .~ .'.'.'.~. -3---o, t C:O L LAR t ",-" '"- t .4 --- 3- 9 i F' R OD LJ C T I 0 N PL. EA.S'E SI(.';N AND F;:ETLiF('N THE ATTACHED COPY HAVE A NICIF DAY! ,:.~ I..t~'.;~RL~r.~: WIL..;.?OH ATO-' i 529 D I S T R I B LJ l" I 0 N RLJN t, .,"~:" CAHCO RUN t, .5" CAMCO RI..JNt , t" C A i"lC 0 '-'~" CAMCO F;,'UN.i , ..:. F;-'. U N i , 5:" S C I"1 RUN t, 5" CAMC;O F;:UN t , 5' CAMCC.I I;,'UIH t, 5" ' CAM. CO f:: tJ N i , ,,..."~" & 5:" C A N C C:' F;:I..JN t , .~' ATLAS RUN i, 5:" CAHCO RUN t, 5" CAMCO '~'" C A M C O RUN i , .., · RUN i, 5" CAMCO ~:" C A t"i C 0 RUfl t,., F,:UN t, 5" CAMCO RUN t, 5" C;ANCO RUN t , 5" CAMCO F: U N. t , ..,.':~" C A M C 0 RUN t, .~'"" CAMCO ,:. R.E C E I F:' T O F:' I) A T A, A F:' F' R. 0 V E I~~'~ 'i'I;.'.AN,S':~ 9 t i 38 :II: CIE N T t-'< A I... F I L. E $ :~ F' H I L L I !:' S' .,,- CI-IEVF;:Oi'4 FB WEL. L. FILE£' D & H F: & D :,": EXTE:i"-.!.':.? I Oi'".~ ['i. XF'I...CJRAT I [.IN ~: BPX ~.' EXXON :~ S-I"A'I"E OF ALASKA i"iARA T HOi"I i"EXACO ~ i"iOBI L ..-I 'l" : ' * THIS I,~ A DUPLIC:ATE ~"i_F: THE L. O6 YOU AL. READY RECEI?I::D, E. XCE. PT THE thF:'I-,." :[S COt',.:I',,'I:..;Tii~.D I:'L_IEA,~IE THROW THE F'F;:EVIOLJ:'.,' COF'Y WII'H THE WRON(;- AF'I:L': AWAY f"-~ STATE OF ALASKA AI~o~A OIL AND GAS CONSERVATION CO I~Nl ~ I N ,~. [ ~ WELL COMPLETION OR RECOMPLETION,REPORT AND LOG 'F' 1 Status of Well Classification of Service Well OIL ~'~ GAS r~ SUSPENDED [~] ABANDONED r-~ SERVICE r~ 2 Name of OperatOr 7 Permit Number ARCO Alaska, Inc 90-107 3 Address 8 APl Number P.O. Box 100360, An. chorage, AK 99510-0360 -- 50-029-22078 4 Location of well at surface " COMP! ~ ~ '"~~ r- 9 unit or Lease Name 1992' FSL, 62' FEL, SEC 2, T10N, R15E UM~ ~',';.~yD'^'i *~. I ,.(3CATIONS PRUDHOE BA Y UNIT At Top ProSucing Ir~va, ~/~.~_,~ ~ 10 Well Number 2391' FNL, 279' FEL, SEC 36, TllN, R15E UM 9-43 At Total Depth 11 Field and Pool 2226'FNL, 84'FEL, SEC 36, T11N? R15E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 5'1' ADL 28343 12 Date Spudded .... ~13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Deplh, if offshore 116 No. of Completions 08108/90. 08/22/90. 09/15/90'I N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 'Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 12575' MD/9012' TVD 12460' MD/8936'TVD YES [~ NO r-~ 2188, feet MD 1900' (approx) 22 Type Elec~c or Other Logs'Run ' CHTfTEMP/GR/CN/ZDEN/DIFL, GR/CBT/CET, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 SURF 110' 30" i55 SX AS CMT 10-3/4" 45.5# . J-55 SURF 4282' 17-1/2" !1500 SX CS III & '350 SX CLASS G iTOP JOB W/100 SX CS II r, , 7-5/8" 29.7# L-80 SURF 12549' 12-1/4" ~500 SX ARC , ,, 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) 4-1/2" 12101' 12000' 12376'-12412'MD/8881'-8837'TVD W/4 SPF, 1800 PHASING 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A ,, 27 N/A PRODUCTION TEST Date First Production IMethed of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,~ , 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONER'ECEIVED IVOV 1 s I990 *NOTE: DRILLED & TUBING RUN 9/2/90. PERFORATED WELL 9/15/90. chOra ;orm 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , ,, 29. \ 30. _.j GEOLOGIC MN:IKERS FORMATION TESTS NNVlE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 12230' 8781' BASE SADLEROCHIT 12417' 8908' NONE 31. LIST OF ATI'ACHMENTS WELL HISTORY (DRILL AND COMPLETE), WELL HISTORY ADDENDUM (SIGNED 10/19/90), GYROSCOPIC SURVEY (2 COPIES) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ (~/-/~/)-~,_.~ Title DRILLING ANALYST Date //- ?-C)0 /1 - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil ana Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field ARCO ALASKA INC. ICounty. parish or borough NORTH. SLOPE ILease or Unit ADL: 28343 Title DRILL & COMPLETE JState AK PRUDHOE BAY Auth. or W.O. no. AS3790 API: 50-029-22078 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/08/90 ( TD: 496'( SUPV:DBJ 08/09/90 ( TD: 1586'( SUPV:RB 08/10/90 ( TD: 2666'( SUPV:RB 08/11/90 ( TD: 4290'( SUPV:RB 08/12/90 ( TD: 4290'( SUPV:RB JDate 08/08/90 JHour Complete record for each day reoorted NABORS 28E 1) 496) 02:00 IARCO w,, 21. 7000 Prior status if a W,O. DRLG TO KOP MW: 8.6 VIS:300 MOVE RIG, OPPOSITE SIDE OF PAD, PREP PITS FOR WATER & R/U COMPLEXES, RIG FLOOR LEVEL MOTOR COMPLEX, HOOK UP STEAM AND WATER. ACCEPT RIG @ 1800 HRS, 8/7/90. N/U HYDRILL AND DIVERTER, BELL NIPPLE, DIVERTER LINES, FLOWLINES, SPOT FUEL TANK, MIX SPUD MUD - STRAP & P/U BHA, CHANGE OUT STAB SLEEVES: 17-1/2 - 13-1/2" FUNCTION TEST DIVERTER SYSTEM. SPUD WELL @ 0200 HRS, 8/8/90. DRILL F/O 'MD TO 496'MD - ADT=2.5 HRS. DAILY:S117,575 CUM:$117,575 ETD:S118,000 EFC:$2,479,575 ) 9O) DRILLING W/ DYNA DRILL MW: 8.9 VIS:300 DROP SURVEY,CBU, POOH ,L/D BIT AND MONEL COLLAR, P/U BIT F#2, ORIENT MOTOR, RIH HAD 35' OF FILL- DRLD W/ DYNA DRILL (DD) F/496'-1586'MD DAILY:S76,058 CUM:$193,633 ETD:S118,000 EFC:$2,555,633 3) 080) DRILLING SURF. HOLE MW: 9.0 VIS:300 DRLD. W/ DD F/1586'-2534',SURV W/TELECO, CBU ,DROP SURV, SLUG PIPE,POOH W/ BIT #2,RETRV. SURV, C/O MOTOR SLEEVE,M/U BHA #3 ,ORIENT AND TEST SAME, RIH REAM F/ 2402'MD TO 2536'MD , DRLD W/ 1 DEG. PDM F/2534'MD - 2666'MD. DAILY:S93,254 CUM:$286,887 ETD:S118,000 EFC:$2,648,887 4) 624) REAMING @ 3096'MD MW: 9.5 VIS:250 DRLD W/1DEG. BH PDM, F/2666-4290'MD LET MUD WT. INCREASE F/9.1 - 9.5 PPG WHILE DRLG. DUE TO PACKING OFF AND FILL ON CONNECTIONS. PUMP HI VIS SWEEP ,CIRC AND CONDITION MUD ,SLUG PIPE - SHORT TRIP TO HWDP, TIGHT HOLE F/2927'MD TO 2401'MD - RIH , TAG UP @ 2332'MD - WASH AND REAM F/2307'MD TO 2603'MD , RIH TAG UP @ 2814'MD ,REAM F/2814'MD TO 3096'MD. DAILY:S54,457 CUM:$341,344 ETD:S160,000 EFC:$2,661,344 The above is correct OTTOM For form preparation and distribution see Procedures Manuel, Section 10, ' \ Drilling, Pages 86 and 87. ) PUMPING 10-3/4 CMNT.JOB 10-3/4"@ 4282' MW:10.1 VIS:220 0) MOUSE HOLE BREAKS ,L/D 10 STDS F/ DERRICK-FIN.REAMING TO BTTM. F/3096'MD TO 42 90'MD - NO FILL ,TIGHT HOLE. INCREASING MUD WEIGHT F/9.5 TO 9.8 PPG.,P/U 165K SO.WT 65 K - CIRC HOLE CLEAN- W/9.8 PPG IN AND OUT.- SLUG PIPE ,POOH W/13 STDS @ 3034'MD ,HOLE TIGHT, P/U KELLY- PUMP OUT OF HOLE TO 2877'MD (W/OUT PUMPS P/U WT = 300K#)- WORKED PIPE BACK IN HOLE TO 2908'MD ,TIGHT NO-GO,WASHED F/2908 TO 2971'MD - RIH TO 4290'MD ,NO FILL ON BTTM.-PUMP 20 BBLS COARSE NUT PLUG "IG'! ~z~.eWE~ ~T ,I~ F/G...8~.TO~I. 0..1 PPG, CIRC AROUND,- SHORT TRIP TO HWT.,NO TIGHT SPOTS; RIH ,WORK THROUGH TIGHT SPOTS 2 2623'2685' & 3409'-3502' - FIN. RIH TO 4290'MD - NO FILL. CIRC. BTTMS.UP,DROP SURVEY, SLUG .PIPE, POOH ,STAND BHA #3 IN DERRICK- NO PROBLEMS W/ HOLE-- R/U TORQUE TURN CSG. CREW , ~Date ~Title PLUG-.IX ~ PUm~ %EAD C~T. 1500 SXS CSIII,513 BBLS / / AR3B-459-1-D INumber all daily well history forms consecutivety as they are prepared for each well. IPage ha. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filred out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish ARCO ALASKA INC. NORTH SLOPE I Lease or Unit PRUDHOE BAY DS9-43 Complet ...... df .... c~z~oW[:~eL~J~d'~i~in'"'g .....k .... in prog .... 08/13/90 ( TD: 4300' ( SUPV: RB 08/14/90 ( TD: 6310'( SUPV:RB 08/15/90 ( TD: 7570'( SUPV:RB 08/16/90 ( TD: 7925'( SUPV:ZR 6) 10) 7) 2010) 8) 1260) ~l~e ab'0~e is correct i For for~ preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 State AK - IWell no. BPM 1150 PSI- RECIPROCATING CSG. 15-20'.TEST CMNT LINES TO 3000 PSI.-TEST PASSED, PUMP 100 BBL OF F.W SPAC ER- DROP SLURRY 12.2 PPG W/1.92 YIELD @ 8.5 BPM 1000-800 PSI. DROP MIDDLE PLUG. DAILY:S165,377 CUM:$506,721 ETD:S500,000 EFC:$2,486,721 9) 355) CBU'S 10-3/4"@ 4282' MW: 9.0 VIS: 35 CONT'D W/CMNT JOB- PUMP TAIL SLURRY OF 350 SX CLASS G, BUMPED PLUG - FLOATS HELD ,CSG RECIPROCATED THROUGH OUT CMNT. JOB, CIP@ 0700 HRS. CLEARED FLOOR OF CMNT EQUIP,R/U AND RUN 80' OF 3/4" TUBING FOR TOP JOB, PUMP 100 SXS OF CSII,GOOD CMNT. RETURNS- N/D FLOWLINE ,BELL NIPPLE ,ANNULAR PREVENTER, N/U FMC TBG. SPOOL, DSA, BOP,FLOWLINE CHOKE AND KILL LINES,TEST BOP'S, CHOKE MANIFOLD,VALVES,TIW,- INSTALL WEAR RN G.- L/D BHA #3 ,STRAP & P/U 9-7/8" BHA #4 (C/O 5 STAB. BLADES) ORIENT AND TEST TELECO MWD. - TEST PASSED. RIH,TAGGED FLOAT COLLAR @ 4196'MD- CIRC 8.9 PPG MUD IN & OUT,TEST CSG. TO 2500 PSI. F/30 MIN. PASSED TEST. DRLD. FLOAT COLLAR + HARD CMNT.TO 4274'MD. CBU'S, TEST CSG.TO 2500 PSI.,10 MIN. -TEST PASS ED DRLD. CMNT. + FLOAT SHOE + 10' OF NEW HOLE TO'4300'MD, CBU'S. DAILY:S147,541 CUM:$654,262 ETD:S700,000 EFC:$2,434,262 DRLG. INTERMEDIATE HOLE. 10-3/4"@ 4282' MW: 9.0 VIS: 41 FIN. CBU'S W/8.8 IN AND OUT & PERFORM LEAK OFF TEST W/ 8.8 PPG MUD = 13.3 PPG EMW. DRLD W/3/4DEG. BH PDM F/4300-4454'MD ,ART 3/4 HRS. ,TELECO MWD FAILDED ( UNABLE TO TRANSMIT SURVEY) ,POOH- C/O TELECO TOOL, ORIENT TELECO RIH W/BHA#5 ,TEST TELECO-OK, FIN RIH,WASH 43' TO BTTM.- NO FILL, DRLD W/1-3/4 DEG BH.PDM F/ 4454'-6310'MD . DAILY:S54,413 CUM:$708,675 ETD:S800,000 EFC:$2,388,675 DRILLING INTER. HOLE 10-3/4"@ 4282' MW: 9.5 VIS: 43 DRLD W/3/4 DEG. BHPDM. F/6310-6626 ,CBU'S ,DROP SURVEY, SLUG PIPE- POOH W/BIT RR4 (F/5780~4282' HOLE WAS TIGHT,SWABBING, FILLED PIPE EVERY STAND- C/O PACKING SWIVEL ON KELLY ,RIH (SURF TEST TELECO AND MOTOR) -WORK THROUGH TIGHT SPOTS WASH AND REAM F/4756' TO 6626'-DRLD W/3/4 BHPDM F/6626-7570. DAILY:S60,056 CUM:$768,731 ETD:S850,000 EFC:$2,398,731 DRILLING INTR. HOLE 10-3/4"@ 4282' MW:10.0 VIS: 47 DRLD F/7570'-7658'MD , REPLACE FAILED ROTARY CHAIN, DRLD F/7658-7677,CBU, DROP SURVEY ,PUMP PILL, POOH ,SWABING F/7302'MD -7210'MD ,CIH TO COND. MUD- CIRC & CONDITION MUD W/ DURANEX - PUMPED PILL, POOH TO 7300'MD - WELL SWABBING AND DRAGING 145K SWAB 10 BBLS IN 90' - RIH . CIRC. AND WT. UP F/9.5 TO 9.8 PPG POOH TO 7020'MD .WELL SWABBING - RIH- CIRCULATED LOW VIS SWEEP . WT UP F/9.8 -10.0 PPG- POOH, TIGHT PnT.~ F/ 683? ~ ~4"~'''~ ~W'?O'"C p'";TF% -.,'?o~n,~ -~n00n ~ I D~.~~(j~ ITitle ~ Ofit~ing Supt. AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each welt. IPage no. ARCO Oil ana Gas Company '~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lllterim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. ICounty or Parish NORTH SLOPE Lease or Unit DS9-43 District ARCO ALASKA INC. State AK Field PRUDHOE BAY jWell no. Date and depth as of 8:00 a.m, 08/17/90 ( TD: 9290'( SUPV:ZR 08/18/90 ( TD:10362' ( SUPV:ZR 08/19/90 ( TD:l1580' ( SUPV:ZR 08/20/90 ( TD:l1920' ( SUPV:ZR 08/21/90 ( TD:12160' ( SUPV:ZR Complet ...... d f .... ~,~zl~)v~e el~i~g ..... k ....in prog .... o) 1365) 11) 1072) 12) 1218) 13) 340) 14) 240) OVER P/U WT. SWABING ANYWHERE F/4/8 BBLS PER 90' STAND, CONT'D TO POOH WHILE FILLING HOLE THRU DRILL PIPE. NOTE : SWEEP INDICATED HOLE VERY CLEAN.- CHANGED OUT MOTOR & BIT - RIH W/BIT # 6- TEST TELECO & MOTOR-CUT 104' OF DRILL LINE - CONT'D TO RIH W/BIT #6 , TIGHT SPOT@ 6757'MD .WORKED THRU WITHOUT KELLYING UP-HAD NO PROBLEMS GETTING TO BOTTOM- DRILLED F/7672'MD -7925 'MD. DAILY:S84,522 CUM:$853,253 ETD:S875,000 EFC:$2,458,253 POOH F/ PDC BIT 10-3/4"@ 4282' MW: 9.8 VIS: 44 DRLD F/ 7925-8694,CBU,MADE 10 STANDS SHORT TRIP-SWABBED 4 BBLS ON FIRST 4 STANDS. PULLED 90K# OVER NORMAL P/U WT. NEXT SIX STANDS OFF BOTTOM - NO PROBLEM. RIH TO BOTTOM NO PROBLEM. DRLD. F/8694'MD TO 9290'MD ,CBU, DROP SS SURVEY PULLED OUT OF HOLE W/BIT #6 DUE TO INCREASE IN TORQUE.PULLED VERY TIGHT FIRST 3 STANDS UP TO 350000#. ALSO SWABBED 3 BBLS. PULLED NOT AS TIGHT NEXT 7 STANDS NORMAL P/U WT SEEN AFTER 10 STANDS OFF BOTTOM. DAILY:S88,635 CUM:$941,888 ETD:S875,000 EFC:$2,546,888 DRILLING AT 10362 10-3/4"@ 4282' MW: 9.8 VIS: 45 POH. REPLACED WEAR BUSHING. SERVICED RIG. P/U BIT #7 AND TIH TO 9290'. DRILLED TO 10362'. DAILY:S56,773 CUM:$998,661 ETD:S1,050,000 EFC:$2,428,661 DRILLING AT 11580 10-3/4"@ 4282' MW: 9.8 VIS: 49 DRILLED TO 10584'. CBU. SHORT TRIP TO 9380'. DRILLED TO 10580'. DAILY:S61,875 CUM:$1,060,536 ETD:S1,150,000 EFC:$2,390,536 TRIP FOR BIT & BHA 10-3/4"@ 4282' MW: 9.8 VIS: 44 DRILLED TO 11593'. CBU. TRIP FOR BHA. L/D MOTOR. WIH W/ ROTARY ASSY. DRILLED TO 11920'. CBU. TRIP FOR BHA. DAILY:S58,945 CUM:$1,119,481 ETD:S1,150,000 EFC:$2,449,481 RIH (SHORT TRIP) 10-3/4"@ 4282' MW: 9.8 VIS: 46 CONT'D TO POOH W BIT #8- PULLED WEAR RING, TESTED BOP'S, M/U BHA #8 & BIT #9 AND RIH- DRLD F~ l1920'MD TO 12156'MD -CBU, PUMPED PILL - POOH TO SHOE, FIRST 2 STANDS PULLED FINE, STANDS 3-5 PULLED W/ 50-75K# OVER NORMAL P/U. - AFTER ST AND #5 - NO PROBLEMS ENCOUNTERED IN HOLE DURING SHORT TRIP. DAILY:S62,552 CUM:$1,182,033 ETD:S1,200,000 EFC:$2,462,033 The above is correct For form~l~repara~on and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Drilling Supt. '~;]:~i;F~*' [ ' ' ' [~umber ail-;;ily well history ........... lively ~ ~choragaJas they are prepared f ..... hweH. IPage no. ARCO Oil an,., Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a;I drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. ARCO ALASKA INC. NORTH SLOPE Field ~Lease or Unit PRUDHOE 3AY I DS9-43 Complete record for each day while drilling or workover in progress NABORS 28E Date and depth as of 8:00 a.m. AK IWell no. 08/22/90 (15) DRILLING AT 12547 10-3/4"@ 4282' MW: 9.8 VIS: 51 TD:12547' ( 387) WIH TO 12160' CIRC. SHORT TRIP. DRILLED TO 12547' SUPV:ZR DAILY:S55,658 CUM:$1,237,691 ETD:S1,300,000 EFC:$2,417,691 08/23/90 (16) TIH TO COND FOR CSG 10-3/4"@ 4282' MW: 9.9 VIS: 52 TD:12575' ( 28) DRILLED F/ 12547-12575'. SHORT TRIP. CIRC. POH. L/D BHA. R/U SUPV:ZR ATLAS WL. RAN CHT/TEMP/GR/CN/ZDEN/DIFL. R/D WL. SIH TO COND FOR CSG. DAILY:S55,507 CUM:$1,293,198 ETD:S1,300,000 EFC:$2,473,198 08/24/90 (17) CIRCULATING FOR CMT JOB 7-5/8"@12549' MW: 9.8 WBM TD:12575 WIH TO 12575'. NO FILL. C &C MUD. POH. L/D BHA. CHANGED TOP PB: 0 RAMS TO 7-5/8". RAN 7-5/8" CASING TO 12570'.CIRCULATE AND SUPV:ZR COND MUD FOR CEMENTING. DAILY:S54,219 CUM:$1,347,417 ETD:SO EFC:$3,827,417 08/25/90 (18) RUNNING COMPLETION 7-5/8"@12549' MW: 9.8 WBM TD:12575 CIRC. AND COND. MUD FOR CMNT. JOB= - TEST CMNT LINES TO 3000 PB:12467 PSI,PUMPED 50 BBLS ARCO SPACER,~3~XS OF ARC CEMENT + SUPV:ZR ADDITIVES AS PER WELL PLAN- CIP L/D LANDING JOINT- INSTALLED PACK-OFF TESTED TO 5000 PSI- L/D 5" DRILL PIPE OUT OF DERRICK- NIPPLE DOWN RISER WASHOUT MUD OUT OF FLOWLINE-CHANGE TOP SET OF RAMS TO 4"X7" VARIABLE-TEST TOP SET OF RAMS TO 5000 PSI- TEST PASSED-CLEAN AND STRAP 4.5" TUBING. DAILY:S700,465 CUM:$2,047,882 ETD:SO EFC:$3,827,417 08/26/90 (19) M/U SPREAR ASSY. 7-5/8"@12549' MW: 8.6 FSW TD:12575 R/U TO TEST 7-5/8" CSG.TESTED TO 3000 PSI FOR 30 MIN.WAIT ON PB:12467 SLIM HOLE GLM. RIH W/ TBG TAIL, PKR ASSY,ONE JT 4-1/2" SUPV:ZR TBG.CONT'D COMPLETION RUN.SET PACKER. PRESSURE UP BACK SIDE, TRY REVERSE OUT W/O LUCK.UNABLE TO WORK PKR FREE OR CIRC AROUND IT.DROP BALL.PRESSURED UP TBG TO 2500 PSI TO SET PACKER, NO USUAL "SHEARING ACTION".SHEARED SEAL ASSY.POOH L/D 4-1/2" TBG.R/U TO P/U 3-1/2" DP. CHANGED KELLIES AND RAMS.TEST TOP SET OF RAMS TO 5000 PSI.M/U PBR AND RETRIEVING TOOL.M/U TSA PKR MILL AND FTA #2.RIH.TAG PKR @ 2449'.MILL PKR.PUMP SWEEP.POOH SLOW'GRAPPLE BROKE OFF.L/D TSA PKR MILL. DAILY:S49,800' CUM:$2,097,682 ETD:S0 EFC:$3,877,217 08/27/90 (20) DISPLACE SW WITH NEW SW 7-5/8"@12549' MW: 8.6 FSW TD:12575 CONT'D L/D PKR MILL.BASKETS FULL OF MILL CUTTINGS.M/U FTA PB:12467 #3.RIH TO SPEAR PKR. P/U 3-1/2" DP.BRK CIRC @ 8111' 3 BPM @ SUPV:ZR 750 PSI.WASH DOWN TO FISH.TAG FISH @ 12354'.ENGUAGE FISH.POOH SLOW.FISH HANGING ON COLLARS.L/D FISH AND TSA .................... _~ ,~ ...... ~- 4_,',~. ~- ~p The;~eiscormct ~-.''.,.,o ~.~v~ ~ ~/~ ~u~,~ ~ -- L, ~ , ., s,gna~'% %, % ~L~,~-f~¢ sos.~/~ ~,i~;~ .~.c~ o~-,~~ ~L~ ~'~ ~ \ CYLINDER~IRON ROUGH NECK tCONT'D ~W~A_~,~? BTM LAST 3 ~r fo~ pre~r~on~n~ ~istribution (~k %\ \ (~ ~ D' I,111,~ --'r" see Procedures Manual Section 10, ~\ \ ~ \ ~ ~ ' Drilling, Pages 86 and 87 \~' ' ~ ~ AR3B-459-2-B INumber all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO Oil an(] ~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion, Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and forlowing setting of oil string until completion. District County or Parish ARCO ALASKA INC. Field Lease or Unit PRUDHOE BAY DS9-43 Date and depth Complete record for each day while drilling or workover in progress aa of 8:00 a.m. NABORS-28E I Stale NORTH SLOPE AK Well no. 08/28/90 ( TD:12575 PB:12460 SUPV:ZR 08/29/90 ( TD:12575 PB:12460 SUPV:ZR 08/30/90 ( TD:12575 PB:12460 SUPV:ZR SINGLES.TAKEN WEIGHT @ 12461' (PBTD). DAILY:S65,426 CUM:$2,163,108 ETD:SO EFC:$3,942,643 21) ATTEMPTING TO SET PACKER 7-5/8"@12549' MW: 8.6 FSW MILL ON JUNK .WORKED BOOTH BASKETS @ 12460'MF .R/U TO REVERSE OUT,REVERSED OUT 8.5 SW INHIBITED W/C-193 AT 6-8 BPM AT 2200PSI,TEST CSG.TO 3000 PSI FOR 15 MIN TO ENSURE INTEGRITY- POOH L/D 3-1/2 DP,CUT 104' OF DRILLING LINE AND BROKE KELLY ,L/D HEVI WATE AND 4-3/4 "DRILL COLLARS,CHANGED OUT TOP PIPE Pu%MS TO 4"-7" VARIABLES + ALSO CHANGED OUT KELLIES,R/U TO RUN 4-1/2 COMPLETION RIH W/ 4-1/2 COMPLETION + 7-5/8 SAB BAKER PACKER W/4-1/2 X 1" SLIM HOLE GLM PRE SET PACKER AT 231 JTS IN HOLE F(9760' MD) ATTEMPTED TO R/O ,1/2 BPM AT 460 PSI BUT UNABLE TO MOVE PACKER ,DROP BALL - ATTEMPTING TO SET PACKER-PBR SHEARED AT 21OO PSI,NOT SURE YET IF PACKER IS FULLY SET. DAILY:S49,800 CUM:$2,212,908 ETD:S2,232,208 EFC:$1,710,435 22) POOH W/ PBR ASSEMBLY 7-5/8"@12549' MW: 8.5 FSW PRESS UP TO SET PACKER- PBR SHEARED AT 2100 PSI. - CONT'D TO PRESSURE UP TO 2500 PSI + 16000 PULL. - POOH W/ 4-1/2" TUBING AND LAID IT DOWN. CHANGED ELEVATORS + KELLY & CHANGED RAMS.- INSTALLED WEAR BUSHING- M/U BAKER PBR RETRIEVING TOOL, RIH ON 3-1/2" DP- TAGGED TOP OF PBR @ 9668'MD - LATCH UP AND RELEASE PBR / K ANCHOR- POOH W/ FISH DAILY:S49,300 CUM:$2,262,208 ETD:S2,281,508 EFC:$1,710,435 23) POOH 7-5/8"@12549' MW: 8.5 FSW FIN POOH ,L/D SEAL ASSY.-STRAP & P/U FISH,ASSY, (PRT.PKRMILL, 3 BOOT BSKT. X-0) RIH, TAGGED@ 9674'MD, MILL ON PKR @ 9674-9677'MD ,POOH SLOW, L/D MILL ASS¥, NO FISH, SERV BOOT BASKET, RECOVERED 1-1/2 GAL OF MILLED CUTTINGS AND RUBBER ,TEST BOP'S ,SERV WEAR RING, M/U SPEAR W/4.01 OD GRAPPLE + 3- BOOT BASKET, RIH W/FISH ASSY.ON 3-1/2 DP.TO 12350'MD ,P/U WT. 250K#,ENGAGED FISH @ 12359'MD- PUMP PRESSURE INCREASED TO 2400 PSI, SHUT DOWN PUMPS ; P/U NO DRAG, S/O SEVERAL TIMES 15-20 K, P/U 30' OFF BOTTOM , 51 STKS 2150 PSI.,POOH DAILY:S49,300 CUM:$2,311,508 ETD:SO EFC:$4,041,243 08/31/90 (24) TIH W/ FB-1 PKR ON DP 7-5/8"@12549' MW: 8.5 FSW TD:12575 FIN. POOH .RECOVERED FISH ,L/D SAME + FISHING TOOLS-CLEARED PB:12460 FLOOR, R/U LOGGERS LUBRICATOR, RAN CCL, 6.75 OD GAUGE RING/JUNK SUPV:ZR BASKET TO 2140'MD ,UNABLE TO GO DEEPER, POOH ,C/O GAUGE RING TO 6.62 OD.,TIH TO 12449'MD - TIGHT SPOTS AT 3412 &4365'MD -POOH SAW BOBBLE AT 3412'MD ,CLEANED JUNK F/ BASKET ' The above is correct ~ ~ ................................... Sign~ure%~ .~ ~ ~ >~ ~ ~ ~, ~o~/, ~ss. s,o~ ~c~so~>-~sc~o For form p~eparation and distribution ~ ~ ' ~v ~V ~1 Ill~ ~ ~--~" see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well, IPage no. ARCO Oil an(., Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish NORTH SLOPE 1State AK Lease or Unit DS9-43 [Well no. Field ARCO ALASKA INC. PRUDHOE BAY Date and depth as of 8:0~] a.m. 09/01/90 (25) TD: 12575 PB:12460 SUPV: ZR The ab0've is'borre~t ' For form p"~,e~ra~'ion and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Complet ...... df .... ~j,~ j~[~,Yo'~ ~ e..c~ i ~ i~g ..... k .... in prog .... DIFFERENCE TO RIG DIRECTIONAL SURVERYS. R/U ,RIH W/ BAKER SOS + PUP JT. + XN NIPPLE+ 2 JTS OF 3-1/2",9.3 ,EUE, TBG + 7-5/8" FB-1 BAKER PACKER ON DP. DAILY:S52,400 CUM:$2,363,908 ETD:SO EFC:$4,093,643 RUNNING 4-1/2" COMPLETION 7-5/8"@12549' MW: 8.5 FSW RIH W/FB-1 PKR ON D/P TO 12000'MD ,P/U WT. 220K# ,S/O WT. 125K# BFLK. CIRC. @ 3BPM ,750 PSI,DROP 1-7/16" BALL, STAGE SET PKR W/1500# & 2000 PSI - RELEASED PRESSURE, REPRESSURED UP TO 2000 PSI,PULLED 225K# SHEARED SETTING TOOL F/FB-1 PKR.- POOH ,L/D 3-1/2" DP + BAKER SETTING TOOL + BRK. KELLY ,7-1/2 HRS CUT AND SLIP 104' OF DRILL LINE.- PULL WEAR RING ,C/O RAMS TO 3-1/2" X 6", VARIABLE-TEST TO 5000 PSI- RU TORQUE TURN, RUNNING 4-12/" ,12.6#,L-80 MOD BTC IPC PRODUCTION TBG. (OTIS SSSV @ 2188', BAKER 'FB-i' PKR @ 12,000', & TT @ 12,101') DAILY:S81,500 CUM:$2,445,408 ETD:S2,409,308 EFC:$1,765,835 Drilling Supt. AR3B-459-2-B Number all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after arlowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. r Accounting cost center code District /State ARCO ALASKA INC. AK I County or Parish~oRT[.{ SLOPE Field ILease or Unit Well no. ?RUDHOE BAY I ADL: 28343 DS9-43 Auth. or W.O. no. ITitle AS3790 I DRILL & COMPLETE I API: 50-029-22078 Operator A.R,Co. W.I, ARCO 21.7000 Spudded or W.O. begun Date SPUD 08/08/90 Date and depth as of 8:00 a.m. 09/02/90 ( TD:12575 PB:12460 SUPV:RB Complete record for each day reported NABORS-28E I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our l Prior status if a W.O. 02:00 ~6) FRZ.PROT. 7-5/8"X4-1/2" 7-5/8"@12549' MW: 8.5 FSW P/U & RAN 4-1/2" TUBING & ACCESSORIES,TAGGED FB-1 PKR & STUNG IN SAME @ 12000 ,P/U & SPACED OUT FMC TBG.HANGER & CONTROL LINES ,TESTING TO 5000 PSI. OK- FRZ. PROTECT + 2200'MD OF TBG. & 7 5/8"X 4-1/2" ANNULUS.PUMPED 100 BBLS OF DIESEL W/C-120 C.I. DN. TBG -U-TUBED TO ANNULUS. LANDED FMC TUBING HANGER-RILD S - TEST DOWN TUBING TO 3000 PSI. FOR 30 MIN. ,L/D LA/~DING JT.-SET BPV N/D FLOWLINE ,BOP ,X-O SPOOL, SET BOP'S BACK, N/U TREE, SET TEST PLUG, TEST TREE AND 1/4" CONTROL LINE TO 5000 PSI. TEST OK. R/U ON 7-5/8"X 4-1/2" ANNULUS PRESSURE UP TO 650 PSI,TRAPPED SAME ,PRESSURE UP DN.TBG.SHEARED OUT SOLID NOSE SHEAR OUT SUB @ 12100'MD,W/3500 PSI. ,TEST TBG. & CSG. BELOW PKR. FOR 30 MIN @ 3350 PSI. TEST OK. FREEZE PROTECT DS 9-43 @ 3 BPM ,700 PSI/ 80 BBLS OF 50/50 + 20 BBLS DIESEL. L/D 3-1/2" KELLY ,SECURED WELL, RELEASE RIG @ 06:00 HRS 9-2-90. DAILY:S372,100 CUM:$2,817,508 ETD:SO EFC:$4,547,243 Old TD Released rig Classifications (oil, gas, etc.) Producing method INew TD Date PB Depth I K nd of rig Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Wetl no. Date Reservoir Producing Interval Oil or gasTest time IProductio.n Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sig~.ture~% ~ ~ X ~%~ ~.~. ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively as they are prepared for each well. iPage no. Division of AtlsnflcRIchfleldCompany WELL HISTORY ADDENDUM WELL WORK LOG Well # 9-43 Date: 9/1 5/90 Work performed: INITIAL PERFORATIONS AFE: AS3790 9/15/90 RU Atlas Wireline. Perforate well w/ 2-5/8", Jumbo jet, 11 grm charge. Perforated well w/ 4 spf, 180° phasing f/ 12376'-12392' and 12392'-12412°. All shots fired. Perforated: 1 2376'- 1 241 2' DRILLING SUPERINTENDENT I I Teleco Oilfietd/""~ ices Inc. TELECO J ~~ 99518~nch°ra§e AK (907) 5~2-2~4~ September 18, 1990 JOB #773 ARCO ALASKA, INC. WELL: DS-9-43 PRUDHOE BAY RIG: NABORS 28E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan G. Mapes Field Operations Supervisor JGM/el Enclosures A S(~IAT COMPANY Company: Well: Location: Rig: Arco Alaska Inc. DS9-43 Prudhoe Bay Nabors 28E TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 08/24/90 TELECO Job # Grid Correction: Magnetic Declination: Total grid correction: Proposed Direction: 773tak 30.8° 0.0° 30.8° 41.1° MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100° ******************************************************************************************************* Tie In Coordinates 109 0 0.0 0.0 109.00 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 TELECO In With Motor 515 406 0.8 58.9 514.99 2.74 1.51N 2.44E 2.87 N 58.23E 0.20 687 172 5.6 32.9 686.67 12. 19 9. 18N 8.03E 12. 19 N 41. 16E 2.85 869 182 10.2 30.1 866.90 36.82 30.59N 20.94E 37.07 N 34.39E 2.54 1058 189 15.1 32.9 1051.25 77.63 GS.76N 42.72E 78.42 N 33.01E 2.61 t'~AG E ] _Company: Arco Alaska Inc., Well: DS9-43, Location: Prudhoe Bay, Riq: Nabors 28E __ Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 1245 187 18.1 34.3 1230.44 130.60 110.22N ~.~2 . 187 19.9 37.5 1407.25 191..21 159.47N 1620 188 23.6 36.8 1581.84 260.70 215.00N 72.32E 131.83 N 33.27E 1.62 108.07E 192.64 . N 34.13E 1.11 150.11E 262.22 N 34.92E 1.97 1810 190 27.1 37.1 1753.52 341.82 280.00N 199.01E 343.51 N 35.40E 1.84 2000 190 29.1 38.2 1921.11 431.14 350.83N 253.69E 432.94 N 35.87E 1.09 2190 190 33.7 38.9 2083.24 530.01 428.20N 315.40E 531.82 N 36.37E 2.43 2410 220 38.9 35.4 2260.51 659.84 532.09N 393.80E 661.96 N 36.51E 2 54 2634 224 42.6 37.8 2430.18 805.56 649.37N 481.04E 808.13 N 36.53E 1.79 2856 222 50.1 38.9 2583.31 965.90 775.19N 580.71E 968.57 N 36.84E 3.40 ~ 5 309 51.2 41.7 2779.25 1204.77 957.36N 735.26E 1207.12 N 37.52E 0.79 3511 346 49.4 39.9 3000.27 1470.95 1158.82N 909.23E 1472.94 N 38.12E 0.66 3914 403 49.1 42.4 3263.36 1776.20 1388.68N ll10.09E 1777.84 N 38.64E 0.48 4225 311 48 5 42.4 3468.21 2010.14 1561.48N 1267.87E 2011.40 N 39.08E 0.19 4546 321 46.8 42.8 3684.44 2247.29 1736.11N 1428.44E 2248.22 N 39.45E 0.54 PAGE 2 Company: Arco Alaska Inc., Well: DS9-43.~ .Location: Prudhoe Bay, .Riq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 4860 314 50.1 39.2 3892.72 2482.17 1913.50N 1582.39E 2483.03 N 39.59E 1.36 5xt4 314 49.9 39.6 4094.. 56 2722.60 ~ 2099.37N ~ 1735.07E 2723.57 N 39.57E 0.12 5519 345 49.8 39.2 4317.01 2986.19 2303.15N 1902.45E 2987.27 N 39.56E 0.09 5834 315 49.2 43.1 4521.63 3225.63 2483.47N 2059.98E 3226.63 N 39.67E 0.96 6150 316 48.3 41.3 4729.99 3463.15 2659.43N 2219.58E 3463.97 N 39.85E 0.51 6426 276 47.7 42.4 4914.67 3668.23 2812.22N 2356.41E 3668.96 N 39.96E 0.37 6745 319 47.8 43.1 5129.16 3904.26 2985.61N 2516.69E 3904.82 N 40.13E 0.17 7061 316 49.4 42.1 5338.13 4141.20 3160.10N 2677.11E 4141.63 N 40.27E 0.56 7373 312 48.8 45.9 5542.45 4376.64 3329.71N 2840.84E 4376.91 N 40.47E 0.94 7 3 313 49.2 41.3 5747.86 4612.53 , 3500.71N _ 3003.65E 4612.68 N 40.63E 1.12 8001 315 49.7 42.1 5952.65 4851.86 3679.41N 3162.87E 4851.99 N 40.68E 0.25 8316 315 49.0 41.3 6157.85 5090.83 3857o84N 3321.86E 5090.94 N 40.73E 0.29 8629 313 48.7 38.9 6363.83 5326.45 4038.09N 3473.66E 5326.58 N 40.70E 0.59 PAGE 3 ..Company: Arco Alaska Inc., Well: DS9-43, Location: Prudhoe Bay, Riq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 8945 316 48.7 37.5 6572.40 5563.54 4224.64N 3620.46E 5563.75 N 40.60E 0.33 ( ~5 280 47.1 . 38.5 6760.11 5770.97 4388.36N 3748.34E 5771.28 N 40.50E .0.63 9544 319 48.3 36.8 6974.81 6006.46 4575.17N 3892.42E 6006.92 N 40.39E 0.54 9861 317 48.7 39.6 7184.88 6243.53 4761.70N 4039.23E 6244.13 N 40.31E 0.67 10171 310 48.9 39.3 7389.08 6476.69 4941.81N 4187.44E 6477.36 N 40.28E 0.10 10519 348 48.6 40.3 7618.53 6738.25 5142.82N 4354.91E 6738.98 N 40.26E 0.23 10806 287 49.7 42.1 7806.26 6955.33 5306.13N 4497.91E 6956.03 N 40.29E 0.61 11056 250 49.4 11373 317 48.9 11( ~ 309 47.2 42.8 7968.46 7145.51 5446.51N 4626.31E 7146.13 N 40.34E 0.24 39.9 8175.83 7385.25 5626.46N 4784.72E 7385.83 N 40.38E 0.71 43.8 8382.42 7614.95 5797.65N 4937.90E 7615.48 N 40.42E 1.09 12028 346 44.3 46.3 8623.85 7862.15 5972.79N 5113.17E 7862.49 N 40.57E 0.98 12276 248 46.1 50.8 8798.64 8036.52 6089.14N 5245.06E 8036.68 N 40.74E 1.48 12505 229 50.1 51.5 8951.54 8204.31 6196.01N 5377.80E 8204.34 N 40.96E 1.76 -- PAGE 4 TELECO 0 ~ 1 f ~ e icl PLAN VIE~ Services Arco Alaska Inc. DS9-43 Prudhoe Bay Nabors 28E dOB# 773tak/O0 SCALE: 1 inch = 1600 + +/ 125o5 ' +/ 12028 ' / 1_1~73 ' 4225 ' feet 12800 11200 9600 8000 Z 5400 4800 3200 1600 0 '1600 3200 4800 6400 8000 9500 EAST (ft) TF~'ECO Oi 1 f ie ld Serv ~c~- VERTICAL PROJECTION 0 2000 4000 6000 8000 I0000 12000 2boo 4000 %6OOO Ld o8000 r_) . >10000 515 ' .8 deg ' 15.1 deg 1620' 23.8 deg APCO Alaska Inc. DS9-43 2~9o ' 23.7 aeg Prudhoe Bay 2B56 ' 50. 1 deg Nab o r s 28E ~511 ' 49.4 dec JOB# 773tak/O0 ~225 ' 48.5 dec SCALE: 8eo ' 5o.~ ~eg 1 inch = 2000 feet . ::~ 19 ' 49.8 dec 50 ' 4B. 3 dec 061 ' 49.4 dec ~%,~606 ' 49.2 dec 3~6 ' 49 dec 945 ' 48.7 dec ~544 ' 48.3 dec ~%~0 & 71 · 48.9 dec 06 ' 49.7 dec deg 12000 14000 16000 18000 VERTICAL SECTION (ft) .{5? SUB - S URFA CE DIRECTIONAL SURVEY r~-i UIDANCE ~10NTINUOUS F~ OOL Company ARCO ALASKA, INC. Well Name D.S. 9-43 (199Z' FSL, 6Z' FEL, SEC Z, T10N, R15E, UN) Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 74062 Loclcjed By: SARBER Date 30-AUG-90 Computed By: KOHRING * SCHLUMBERGER * GCT gIRECTIONAL SURVEY CUSTOME,q LISTING ARCO ALASKA INC. D.S. 9-~3 ~RUDHOE BAY NORTH SLOPEr ALASKA SURVEY DATE: 30-AUG-lOg0 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOL~TION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 41 DEG 7 MIN ~AST COMPUTATION D~TE: 23-0CT-90 PAGE 1 ARCO ALASKA INC. D.S. 9-43 PRUDHOE BAY NORTH SLOPE, ALASKA INTERPOLATED VALUES FOR TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA COURSE VERTICAL DEVIATION AZIMUTH DEPTH DEG MIN DEG O.O0 0.00 100.00 99.99 200.00 199.99 300.00 299.99 400.00 399.99 500. O0 499.99 600.00 599.94 700.00 699-55 800.00 798.69 900.00 897.21 lDO°LDO 994.89 1100.00 1091.69 lz00.00 1187.74 13oo.oo 12s2.92 14oo.oo 1377.53 lSOO.OO 1471.41 1600.00 1563.99 1700.00 1684.84 18oo.oo 1744.23 1900.00 1833.24 2000.00 1921.41 2100.00 2007.70 2200.00 2091.93 2300.00 2174.21 2400.00 2254.01 2500.00 2331.62 2600.00 Z408.07 2700.00 2480.49 2800.00 7_549.61 2900.00 2614.44 3000.00 2678.06 3100.00 2741.13 3200.00 2803.56 3300.00 2866.36 3400.00 2931.16 3500.00 2996.17 3500.00 3060.91 3700.00 3125.57 3800.00 3190.10 3900.00 3255.22 -51.00 0 0 48.99 0 13 148.99 0 14 248.99 0 16 348.99 0 12 448.99 0 31 548.94 3 26 648.55 6 10 747.69 8 52 ~46o21 10 53 943.89 13 39 1040.69 15 20 1136.74 16 59 1231.92 18 31 1326.53 19 19 1¢Z0.41 21 12 1512.99 23 16 1603.84 26 2 1693.23 26 58 178Z.24 27 21 1870.41 29 13 1956.70 31 2'7 2040.93 33 42 2123.21 35 41 2203.01 38 22 2280.62 39 24 2357.07 41 35 2429.49 45 9 2498.61 47 53 2563.44 50 24 2627.06 50 36 2690.13 51 11 2752.56 51 32 2815.36 50 15 2880.16 49 23 2945.17 49 32 3009.91 49 43 3074.57 49 48 3139.10 49 39 3204.22 49 13 N 0 0 E S 25 41 W N 88 55 E N 3 37 E S 51 N 70 20 E N 36 7 E N 29 38 E N 26 42 E N 30 5'9 E N 32 17 E N 33 2 E N 33 41 E N 35 23 5 N ;36 17 5 N 35 32 c N 36 Z ~ N 37 58 E N 37 59 E N 37 29 E N 37 32 E N 37 6 E N 37 25 E N 35 54 E N 34 36 E N 35 31 E N 37 11 6 N 36 58 E N 37 13 E N 38 41 E N 39 24 E N 40 9 E N 40 47 E N 38 23 E N 37 56 E N 38 48 E N 39 37 E N ~0 19 E N 40 56 E N 41 11 ~ EVEN lOO FEET VERTICAL DOGL SECTION SEVE FE ET OE G/ D~T~ OF SURVEY: KELLY BUSHING ELEVATION= ENGINEEr: OF ME4SURED OEPTH EG RECTANGULAR RITY NORTH/SOUTH 100 FEET O.O0 0.00 0.00 N 0.11 0.85 0.24 S 0.07 0.29 0.47 S 0.44 0.43 0.23 S 0.40 0.59 0.04 S 0.47 1.27 0.18 S 3.34 3.90 1.93 N 11.84 2.22 9.22 N 24.51 2.03 20.84 N 41.27 2.97 35.76 N 62.33 2.15 53.86 N 87.15 1.43 75.02 N 114.69 2.49 98.23 N 145.14 1.11 123.50 N 177.42 0.95 149.7~ N Z11oTZ 2.51 177.57 N 249.31 2.79 208.35 N 290.98 2.15 241.64 N 335.73 0.84 276.84 N 381.23 0.98 313.01 N 2.60 350.36 N 2.52 390.58 N 2.00 433.42 N 2.94 478.90 N 2.47 528.22 N 1.70 579.97 N 4.58 631.69 N 1.90 686.71 N 5.03 744.39 N 0.61 804.30 N 478.70 532.48 589.14 649.05 711.74 775.97 844.73 916.80 992.82 1069.92 1147.50 1225.61 1303.41 1379.45 1455.34 1531.52 1607.78 168~.17 1760.06 0.73 864.22 0.74 923.86 0.22 983.26 3.46 1043.02 0.55 1103.12 0.79 1162.71 0.58 1221.75 0.71 1280.20 0.55 1338.15 0.49 1395.40 30-~UG-1990 51.00 FT SARBER COORDINATES HORIZ. OEP EAST/WEST DIST. AZI FEET FE~T DE~ 0.00 E 0.00 N 0 0.4~. : 0.50 S 61 0.6z, 2. 0.79 S 53 0.89 E 0.92 S 7'7 0.64 E 0.6-4 S 86 0.92 : 0.93 S 79 2.90 ~ 3.4.7 N 56 7.44 E 11.85 N 38 13.40 E 24.78 N 32 21.79 E 41.87 N 31 33.07 E 63.21 N 31 46.58 E 88.31 N 31 61.88 E 116.09 N 32 79.23 E 146.73 N 32 98.25 E 179.10 N 33 118.53 E 213.49 N 33 140.43 E 251.26 N 3.3 165.66 E 292.97 N 34 193.38 E 337.70 N 34 221.13 E 383.24 N 35 249.93 E 430.37 N 35 280.49 F_-_ 4,'30.86 N 35 313.19 E 534.74 N 35 347.25 E 591.55 N 35 381.86 E 651.79 N 35 417.90 E 714.84 N 35 456.32 E 779.27 N 35 497.85 E 848.19 N 35 541.37 E 920.43 N 3,5 588.33 E '996.51 N 36 N 636.92 E 1073.57 N 3-5 N 686.57 E 1151.0,4 N 36 N 737.32 E 1228.99 N 36 N 797.15 5 1306.71 N 3'7 N 833.93 E 1382.86 N 37 N 881.08 E 1458.83 N 37 N 929..2~ 5 1535.00 N 37 N 978.29 E 1611.20 N 37 N 1028.06 E 16~7.47 N 37 N 1077.88 E 1763.23 N 37 A2TUR:= MUTH MIN 0 E 17 38 E 16 E 53 E 6 E ,41 E 5~ E ~5 E 22 E 33 E ~0 E 12 E ~1 E I6 E ~3 E 59 E 26 E 56 E 14 E )0 E 41 E 51 E i? E ~52 E ~6 E 56 E Z E ll E 23 E 37 E 52 E 2 E 5 E ~ E 15 E 23 E ~2 E ~1 E COMPUTATI3N DATE: 23-007-90 PAGE 2 ARCO ALASKA INC. D.S. 9-43 PRUDHOE BAY NORTH SLOPE, ALASKA OATE OF SURVEY: 30&AUG-1990 KELLY ~USHING ELEVATION: 51.00 FT ENGINEER: SARB~R INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUREO DEPTH TRUE SUB-SEA COURS5 MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOU'TH E~ST/WEST OI$T. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG 4000.00 3320.91 3269.91 48 36 4100-00 3387.10 3336.10 48 33 4200.00 3453.24 3402.24 48 33 4300.00 3519.86 3468.86 47 35 4400.00 3587.72 3536.72 47 10 4500.00 3655.8g 3604.89 46 51 4600.00 3724.31 3673.31 47 5 4700.00 3791.14 3740.14 49 4 4800.00 3856.10 3805.10 49 45 4900.00 3920.56 3869.56 49 51 N 41 4~ E 1935.46 N 42 3 E 1910.41 N 40 50 E 1985.41 N 41 26 E 2059.~9 N 41 4'~ E 2133.43 N 42 11 E 2206.58 N 42 15 E 2279.50 N 39 32 E 2353.87 N 38 43 E 2429.83 N 38 34 iE 2506.22 0.67 0.99 0.22 1.53 0.31 0.45 1.36 2.84 0.9,2 0.53 1451.83 N 1127.83 E 1838.46 N 37 50 E 1507.53 N 1178.05 E 1913.2.3 N 38 0 E 1563.94 N 1227.47 E 1988.11 N 38 8 E 1620.10 N 1276.54 E Z062.59 N 35 14 E 1675.01 N 1325.32 E 2135.92 N 38 21 E 1729.40 N 13'74.26 E 2208.94 N 38 28 E ! 1783.37 N 1423.32 E 2281.72 N 3~ 36 E 1839.40 N 1472.21 E 2356.01 N 38 40 E 1898.62 N 1519.83 E 2432.04 N 38 41 E 1958.26 N 1567.71 E 2508.49 N 38 41 E 5000.00 3984.88 3933.88 50 9 5100.00 4049.11 3998.11 50 3 5200.00 4113.45 4062.45 49 46 5300.00 4178.28 4127.28 49 30 5400.00 4243.19 4192.19 49 35 5500.00 4307.95 4256.95 49 40 5600.00 4372.97 4321.97 49 18 5700.00 4437.91 4386.91 49 25 5800.00 4503.40 4452.40 49 5 5900.00 ~569.07 4518.07 48 39 N 38 34 E 2582.71 N 38 45 E 2~$59.29 N 37 55 E 2735.75 N 38 0 E 2~11.77 N 38 Z~ E 2887.74 N 98 48 E 2963.86 N 39 35 E 3039.79 N 40 3 E 3116.82 N 40 2T E 3191.38 N 40 4 E 3266.79 0.41 0.22 0.70 0.23 0.43 0.62 0.79 I .11 0.38 1.39 Z018.16 N 1615.41 E 2585.06 N 3~3 ~.1 ~ Z078.01 N 1653.30 E 26,61.71 N 38 40 ~ 2138.04 N 1710.80 E 27,38.26 N 38 ½0 E 2198.11 N 17~7.58 E 2814.38 N 38 39 E 3257.91 N 1804.60 E 2890.45 N 38 38 E 2317.47 N 1852.12 E 2966.65 N 38 38 E 2376-37 N 1900.10 E 30~,2.62 N 38 39 E 2434.79 N 19~8.80 E 3118.65 N 38 40 E 2492.46 N 1997.64 E 3194.20 N 38 43 E 2549.86 N 2046.55 E 3269.58 N 38 45 E 6000.00 4635.09 4584.09 48 47 6100.00 4701.06 4650.06 48 30 6200.00 4767.51 4716.51 48 15 6300.00 4834.22 4?83.22 48 4 6400.00 4901.45 4~50.45 47 32 6500.00 4968.77 4917.77 48 1 6600.00 5035.2~ 4984.28 48 35 6700.00 5101.74 5050.74 48 2 6800.00 5168.81 5117.81 47 49 6900.00 5235.20 5184.20 49 1 N 38 40 E 3341.86 N 39 6 E 3416.94 N 39 36 E 3491.64 N 40 14 E 356~.12 N 40 47 ~ 3640.14 N 40 52 E 3714.08 N 41 9 E 3788.76 N 41 41 E 3863.48 N 42 8 E 3937.64 N 41 34 E 4012.42 0.44 0.6 i' 0.59 0.76 0.34 0.80 0.71 0.86 0.98 1.18 2608.06 N 2094.02 E 3344.68 N 38 ~,6 E 2666.62 N 2141.I1 E 3419.83 N 33 46 E 2724.39 N 21~38.52 E 34'94.56 N 38 47 E 2781.54 N 2236.31 E 3569.0~ N 3~3 4~ E 2837.7~ N 22~34.45 E 3643.03 N 3~ 50 E ) 2893.73 N 2332.79 E 3716.93 N 38 52 E 2950.10 N 2381.75 E 3791.56 N 38 55 E 3006.17 N 2431.16 E 3866.21 N 38 58 E 30,61.35 N 2480.73 E 3940.2~ N 3) i E 3116.94 N 2530.74 E 4014.97 N 39 4 ~ 7000.00 5300.60 5249.60 49 11 7100.00 5365.97 5314.97 49 10 7ZO0.O0 5431.49 5380.49 49 3 7300.00 5497.04 5446.04 49 1 7400.00 5562.80 5511.80 48 33 7500.00 5629.04 5578.04 48 45 7600.00 5694.87 5643.87 49 1 7700.00 5760.34 5709.34 49 ll 7800.00 5825.69 5774.69 49 7900.00 5891.15 5840.15 49 9 N 41 37 E 4088.06 N 42 11 E 4163.73 N 41 58 E 4239.27 N 42 41 E 4314.77 N 43 19 E 4390.06 N 42 39 E 4464.93 N 40 16 E 4540.20 N 40 2.8 E 4615.78 N 40 56 E 4691.47 N 41 33 E 4767.06 0.52 0.3.3 0.71 0.37 1.34 1.23 1.06 0.34 0.70 0.66 3173.64 N 2580.81 E 4090.55 N 39 7 E 3229.94 N 2631.40 E 4166.14 N 39 10 E 3286.11 N 2681.90 E 4241.60 N 39 13 E 3341.91 N 2732.79 E 4317.00 N 39 16 E 3397.00 N 2784.18 E 4392.1~ N 39 ZO E 3451.68 N 2835.39 E ~466.94 N 39 24 5 3508.0~ N 2885.22 E 4542.15 N 39 26 E 3565.75 N 2934.10 E 4617.74 N 3'9 27 E 3623.18 N 2983.41 E 46')3.42 N 39 23 E 3680.03 N 3033.23 E 4768.97 N 39 30 E COMPUTATION D~TE: 23-gCT-90 PAGE 3 ARCO ALASKA INC. D.S. 9-43 PRUDHOE BAY NORTH SLO'PEm ALASKA D~TE OF SURVEY: 30-AUG-1990 KELLY 8USHIN$ ELEV4TION: 51.00 FT :NGINCER' SARBCR INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED OEP'TH TRUE SUI3-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HgRIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH FEET DEG/IO0 ~EET =EET FEET OEG MIN 8000.00 5956.2t 5905.21 49 43 8100.00 50Z0.91 5969.91 49 24 8200.00 6096.49 6035.49 48 47 8300.00 6152.38 6101.38 48 54 8400.00 6218.00 6167.00 49 2 8500.00 5283.32 6232.32 49 8 8600.00 6349.11 6298.11 48 46 8700.00 6415.16 6364.16 48 33 8800.00 6481.35 6~30.35 48 35 8900.00 6547.49 6496.49 48 34 N 42 12 E 4343.00 N 42 21 E 4919.23 N 40 25 E 4994.71 N 40 3 E 5069.94 N 39 39 E 5145.37 N 38 20 ~ 5221.05 N 37 4 E 5296.20 N 37 6 E 5371.10 N 36 39 E 5445.86 N 36 26 E 5520.62 0.73 1.77 0.49 0.68 0.4~ 3.48 0.00 0.25 0.44 0.64 3736.54 N 3083.96 E 4844.85 N 39 32 E 3792.76 N 3135.4'7 E 4921.00 N 39 35 E 3849.613 N 3185.11 E 4996.45 N 39 36 E 390'7.02 N 3233.75 E 5071.68 N 3'9 37 E 3964.97 N 3282.07 E 51~7.13 N 39 37 E ~ 4023.52 N 3330.08 E 5222.85 N 39 137 E 4083.34 N 3375.84 E 5298.11 N 3::3 35 E 4143.21 N 3421.14 E 5373.1Z N 39 33 E 4203.16 N 3466.14 E 5448.00 N 39 31 E 4263.44 N 3510.77 E 5522.90 N 39 28 E 9000.00 6613.65 6562.65 48 28 9100o00 6680.51 6629.51 47 49 9200.00 6748.12 6697.12 46 58 9300.00 6816.85 6765.85 46 26 9~00.00 6885.52 6834.52 47 17 9500.00 6952.50 6901.50 48 20 9600.00 7019.10 6968.10 48 11 9703.00 7085.50 7034.50 48 31 9800.00 7151.75 7100.75 48 42 9900.00 7217.85 7166.95 48 24 N 36 3 E 5595.33 N 36 3 E 5669.40 N 36 9 E 5742.80 N 36 25 E 5815.18 N 35 43 E 5887.60 N 35 I E 5961.49 N 34 45 E 6035.62 N 36 8 E 6110.01 N 36 47 E 6184.67 N 37 Z E 6259.52 0.74 0.32 1.29 0.49 1.BB 0.81 0.62 0.97 0.97 0.54 4323.96 N 3555.05 ir. 5597.77 N 39 26 E 4384.05 N 3598.85 E 5672.00 N 39 23 E 4443.5~ N .36%2.29 E 5745.56 N 39 ZO E 4502.13 N 3685.25 E 5818.10 N 3'9 18 E 4560.77 N 3728.20 E 5890.68 N 39 16 E 4621.34 N 3771.17 E $964.77 N 39 13 E 4632.62 N 3813.69 E 6039.14 N 39 ~0 E 4743.57 N 3,857.00 E 6113.74 N 39 7 E 4803.85 N 3901.43 E 6188.57 N 39 5 E 4863.70 N 3946.73 E 6263.57 N 39 3 E 100~8.00 7284.55 ~33.55 47 56 101 .00 7351.91 00.91 47 41 10200.00 7418.34 7367.34 48 51 10300.00 7484.43 7433.43 48 22 10400.00 7551.01 7500.01 48 8 10500.00 7617.81 7566.81 48 12 10600.00 76~4.24 7633.24 48 31 10700.00 7750.05 7699.05 49 14 10800.00 7815.08 7764.08 49 30 -10900.00 7879.52 7828.52 50 5 N 36 30 E 63313.81 N 36 29 E 6407.47 N 36 53 E 6482.00 N 36 53 E 6556.85 N 37 58 E 6631.29 N 38 29 E 670'5.60 N 38 31 E 6780.28 N 39 0 E 6855.50 N 39 49 E 6931.43 N 41 7 E 7007.90 0.83 1.13 0.03 0.~O 0.99 1.14 0.46 1.1'9 0.53 0.87 492.3.39 N 39gl.32 E 63138.01 N 3) Z E 4982.87 N 4035.13 E 5411.84 N 39 0 E 5042.77 N 4079.89 E 6486.53 N 3~ 58 5102.74 N 4125.02 E 6561.53 N 3~ 57 5152.13 N 4170.17 E 6636.11 N 38 56 E 5220.69 N 4216.10 E 5710.52 N 38 ~,5 E 5279.11 N 4262.72 E 5785.25 N 38 55 E 5337.97 N 4309.6,~ E 6860.5~ N 3~ 55 E 5396.54 N 4358.06 E ~936.52 N 3~ 55 E 5454.70 N 4407.71 E 7012.96 N 3H 56 E 11000.00 7943.92 7892.92 49 50 11100.00 8008.81 7957.81 49 19 llZO0.O0 8073.98 8022.98 49 18 11300.00 8139.05 8088.06 49 22 11400.00 8204.75 8153.75 48 26 11500.00 8271.31 8220.31 47 58 11600.00 8338.96 8287.96 47 13 11700.00 8406.74 8355.74 47 28 11800.00 8475.48 8424.48 45 40 11900.00 8546.04 8495.04 44 23 N 40 55 6 7084.40 N 40 2~_ E 7160.49 N 40 10 E 7236.32 N 39 54 E 7312.24 N 39 20 E 7387.60 N 39 13 E 7462.19 N 38 47 E 7535.79 N 42 15 E 7509.29 N 43 40 E 7681.87 N 43 57 E 7752.66 0.54 0.57 0.64 0.21 0.56 1.37 1.10 1.35 1.45 1.73 5512.35 N .4457.98 E 7039.41 N 38 5~ E 5570.11 N 4507.52 E 7165.47 N 3~ 59 E 5628.03 N 4556.49 5 7241.29 N 39 0 E 5686.14 N 4605.36 E 7317.21 N 39 0 E 5744.20 N 4653.46 E 7392.60 N 3~) 1 E 5801.97 N 4700.6'9 E 7467.22 N 39 I E 5859.26 N 4766.97 E 7540.97 N 39 1 E 5915.06 N 4794.83 E 7614.35 N 39 Z E 5968.19 N 4844.33 E 7686.80 N 39 4 E 6019.36 N 4893.35 E 7757.~2 N 39 7 E COMPUTATION D~TE: 23-DCT-90 PAGE aRCO ALASKA INC. DATE OF SURVEY: 30-AUG-1990 D.S. 9-43 KELLY ~USHING ELEVATION: 51.00 FT PRUDHOE BAY NORTH SLOPEr ALASKA ENGINEER: INTERPOLATED VALUES FOR EVEN 100 FEET O~F MEASURED DEPTH TRUE SUB-SEA COURSE VERTZC&L DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH E,~ST/WEST OISTo AZIMUTH DEPTH DEPTH DEPTH OEG MIN 12000.OO 8617.66 8566.66 44 23 12100.00 8689.10 8638.10 44 34 12ZOO.O0 8759.86 8708.86 45 27 12300.00 8879.26 8778.26 46 57 12400.00 8896.51 8845.51 48 30 12500.00 89E, 2.77 8911.77 48 30 12575.00 9012.46 8961.46 48 30 DEG MIN FEET OEG/100 FEET FEET FEET DEG MIN N 46 1 E 7872,,29 47 43 E 7891.90 N 50 8 E 8033.12 N 49 38 E 8106.26 N 49 38 E 8180.32 N 49 3~ ~ 823S.88 1.7~ 1.35 1.50 1.98 4.77 0.00 0.00 6068.85 N 49~2.55 E 7826.86 N 39 10 E 6116.60 N 4993.69 E 7896.18 N 39 14 E 6163.41 N 5046.61 E 7965.93 N 39 19 E 6209.7'7 N 5101.70 E 8036.70 N 3<7 24 E 6257.47 N 5158.28 E 8109.48 N 39 )0 E ) 6305.98 N 5215.33 E 8183.22 N 39 36 E 6342.37 N 5258.13 5 ~238.54 N 39 40 E COMPUTATIgN D~TE: 23-0CT-90 PAGE 5 ARCO ALASKA INC. D.S. 9-4.3 PRUDHOE 8AY NORTH SLOPEr ALASKA DATE 3F SURVEY: 30-AUG-lO90 KELLY ~USHING :ELEVATION: 51.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET O~ MEASURED OEPTH TRUE SUB-SEA COURS;E MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -51.00 0 0 1000.00 994.89 943.99 13 39 2000.00 1921.41 1870.41 29 13 3000.00 ~678.06 2627.06 50 36 4000.00 3320.91 3269.91 48 36 5000.00 3984.88 3933.B8 50 9 6000.00 4635.09 4~84.09 48 47 TO00. O0 5300.60 5249.60 49 11 8000.00 5956.21 5905.21 49 4.3 9000.00 6613.65 6562.65 48 28 ENGINEER: SARBER 10000.00 7284.55 7233.55 47 56 11000.00 7943.9Z 7892.92 49 50 12000.00 8617.66 8566.66 44 Z3 12575.00 9012.46 8961.46 48 30 VERTICAL DOGLEG REC'TANGUL~R COORDINATES HgPIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. ~&ZIMUTH FEET DEG/IO0 FEET =E~T FE~T DEG MIN N 0 0 E 0.00 N 32 17 ~ 62.33 N 37 32 E 428.30 N 39 24 E 106'9.92 N 41 48 E 1835.46 N 38 34 !E 2582.71 N 38 40 E 3341.86 N 41 37 E 4088.06 N 42 1Z E 4843.00 N 36 3 5 5595.33 N 36 30 E 6333.81 N AO 56 E 7084.40 N 46 I E 782Z.29 N 49 38 E 8235..B8 0.00 2.15 2.60 0.73 0.67 0.41 0.44 0.52 0.73 0.74 0.00 N 0.00 '= 0.09 N 0 0 E 53.86 N 33.07 ~ 53.21 N 31 33 E 350.)6 N 249.93 E 430..37 N 35 30 E 8,64.22 N 636.92 E 1073.57 N 3,6 23 E 14'51.88 N 11Z7.83 i 1838.4~ N 37 50 E } 201.8.16 N 1615.41 E Z585.06 N 39 41 E 260.8.06 N 2094.02 E 33~4.6~ N 38 46 E 3173.64 N 25~0.81 ~ 4090.55 N 39 '7 E 3736.54 N 30,~3.96 ~ .~+844.85 N 39 32 E 4323.96 N 3555.05 E 5597.77 N 39 26 E 0.83 0.54 1.74 O.OD 4923.39 N 3991.32 E 6338.01 N 39 2 E 5512.36 N 4457.98 E 7089.41 N 38 58 E 60~B.85 N 49~2.55 E 7826.86 N 39 10 E 6342.37 N 5258.13 E 8238.54 N 39 40 E COMPUTATIgN OATE: 23-0CT-90 PAGE 6 ARCO ALASKA D.S. 9-43 PRUOHOE BAY NORTH SLOPEr INC. ALASKA INTERPOLATED VALUES F3R EVEN 100 FEET MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH COURSE VERTICAL DOGL DEVIATION AZIMUTH SECTION SEVE DEG MIN DEG MIN FEET DEG/ . 51. 151. 251. 351. 551. 651. 751. 853. O0 O1 O1 01 O1 O1 02 21 81 03 0.00 51.00 151.00 251.00 351.00 451.00 551.00 651.00 751.00 851.00 -51.00 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 0 0 N 0 0 E 0.00 0 0 20 S I 47 E 0.28 4 0 13 S 41 $ E 0.01 0 0 14 N 44 7 E 0.24 0 0 13 N 61 58 W 0.51 0 0 13 S 50 25 E 0.30 0 I 29 N 45 56 E 1.26 3 5 6 N 31 52 E 7.14 2 7 34 N 26 37 r. 17.82 3 9 54 N 29 38 E 32.97 2 95 '4~. 1057. 1161. 1266. 1371. 1478. 1585. 1695. 1807. 1920. 93 88 65 36 91 14 89 75 60 01 951.00 1051.00 1151.00 1251.00 1351.00 1451.00 1551.00 1651.00 1751.00 1851.00 900.00 12 31 1000.00'14 40 1100.00 16 21 1200.00 18 9 1300.00 19 4 1400.00 20 41 1500.00 22 55 1600.00 25 56 1700.00 26 59 t80O.O0 27 32 N 32 5 E 52.24 3 N 32 36 E 76.36 1 N 33 27 E 103.81 1 N 34 42 E 134.60 1 N 36 10 E 168.22 0 N 35 56 E 203.90 2 N 35 43 E 243.82 2 N 37 55 E 289.14 2 N 37 52 E 339.17 0 N 37 41 E 390.,41 I 2034. 2151. 2271. 2396. 2525. 2658. 2802. 2957. 3115. 3275. 04 09 55 15. 10 58 11 41 74 81 1951.00 2051.00 2151.00 2251.00 2351.00 2451.00 2551.00 2651.00 2751.00 2851.00 1900.00 30 1 2000.00 32 41 2100.00 35 2200.00 38 17 2300.00 39 30 2400.00 44 4 2500.00 48 3 2600.00 50 29 2700.00 51 15 2800.00 50 47 N 37 17 E .445.09 2 N 37 26 E 505.77 2 N 36 33 E 572.75 Z N 34 36 E 546.67 2 N 26 11 ~ 727.62 2 N 37 0 5 815.72 3 N 37 20 E 918.38 4 N 39 $ ~= 1037.05 0 N 40 15 E 1159.77 0 N 39 8 E 1284.74 3 3430. 3584. 3739. 3893. 4045. 4196. 4345. 4492. 4639. 479Z. 68 44 54 47 61 99 84 45 11 2951.0D 3051.00 3151.00 3251.0D 3351.00 3451.00 3551.00 3651.0D 3751.00 3851.00 2900.00 49 24 3000.00 49 43 3100.00 49 53 3200.00 49 14 3300.00 48 33 3400.00 48 33 3500.00 47 11 3600.00 46 52 3700.00 47 48 3800.00 49 43 N 38 11 E 1402.55 N 39 30 E 1519.84 N 40 36 E 1.537.93 N 41 9 E 1755.17 N 42 7 E 1869.55 N 40 49 E 1982.87 N 41 36 E 2093.83 N 42 9 E 2201.36 N 41 35 E 2308.55 N 38 41 E 2423.83 D,~T5 OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: OF SUE-SEA DEPTH 30-AUG-lg90 51.00 FT SARBER 0.72 1121.34 N 8~8.19 E 1406.00 N 37 6 E 0.59 1212.74 N 921.83 6 1523.32 N 37 14 E 0.72 1303.13 N 997.85 E 1641.30 N 37 27 E 0.43 1391.72 N 1074.66 E 1758.34 N 37 $0 E 0.50 1477.23 N 1150.63 E 1872.47 N 37 55 E 0.13 1562.02 N 1225.81 ~ 1935.5H N 38 7 E 0.35 1645.44 N 129H.97 E 2096.38 N 3H 17 E 0.44 1725.52 N 1370.75 E 2203.72 N 38 28 E 3.15 1804.97 N 1442.73 E 2310.72 N 3~ 38 E 0.76 18'93.92 N 1516.13 E 2426.02 N 38 41 E .00 0.00 N 0.00 E 0.00 N O 0 E .53 0.12 S 0.56 E 0.58 S 77 54 E .36 0.40 S 0.47 :_ 0.62 S 49 32 E .27 0.39 S 0.81 ; 0.90 S 64 12 E 44 0 03 S 0 81 E 0 81 S 89 0 = . . . . ~., .60 0.17 S 0.65 E 0.67 S 75 19 E .42 0.30 N 1.57 E 1.60 N 79 5 E .85 5.11 N 5.00 E 7.15 N 44 25 E .28 14.64 N 10.33 E 17.92 N 35 I3 E .12 28.47 N 17.53 E 33.43 N 31 37 E .31 ,%5.22 N Z7.62 ': 52.99 N 31 25 E .60 65.86 N 40.67 ~ 77.41 N 31 42 E .73 89.08 N 55.81 E 105.12 N' 32 4 E .41 11~+.83 N 7~.13 E 1'36.1,4 N 32 29 E .76 142.29 N 92.79 E 159.88 N 33 7 E .38 171.19 N 113.95 E 205.65 N 33 39 E .55 Z03.88 N 137.21 E 245.75 N 33 56 E .21 24.0.18 N 164.53 E 291.13 N 34 25 E .79 279.57 N 195.49 E 341.14 N 34 58 E .32 320.31 M 2~6.74 E 392.4% N 35 18 E .20 363.72 N 260.15 ; 4,~7.13 N 35 34 E .213 412.17 N 296.91 E 507.98 N 35 46 E .50 465.63 N 337.53 r- 575.10 N 35 56 E .56 526.25 N 380.50 E 649.40 N 3'5 52 E .04 592.90 ,'4 427.23 E 730.79 N 33 47 E .38 663.47 N 480.35 E 819.10 N 35 54 E .95 745.64 N 542.33 E 922.01 N 36 2 E .59 838.76 N 616.11 E 1040.73 N 36 18 E .78 933.24 N 694.49 ;' 1163.29 N 36 39 E .32 1028.47 N 775.43 E 1288.04 N 37 1 E EG RECTANGULAR COORDIN4TES HORIZ. DEPARTURE RI'TY NORTH/SOUTH EAST/WEST DIST. AZIMUTH lO0 FEET FEET KE~T DEG MIN COMPUTATION DATE: 23-0CT-90 PAGE 7 ARCO ALASKA INC. D.S. 9-43 PRUDHOE BAY NORTH SLOPE, ALASKA DaTE OF SURVEY: 30=AUG-1990 KELLY BUSHING ELEVATION: 51.00 FT , ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH 9EPTH DEG NIN DEG M[N VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST gIST. AZIMUTH FEET gEG/IOO FEET ~EET mEET DEG MIN 4947.22 3951.00 3900.00 49 55 5102.95 4051.00 4000.00 50 3 5257.98 4151.00 4100.00 49 31 5412.05 4251.00 4200.00 49 36 5566.30 4351.00 4300.00 49 19 5720.07 4451.00 4400.00 49 13 5872.59 4551.00 4500.00 48 49 6024.16 4651.00 4600.00 48 51 6175.19 4751.00 4700.00 48 20 6325.07 4851.00 4800.~0 47 55 N 38 31 E 2542.28 N 38 45 E 2661.55 N 37 54 E 2779.86 N 38 26 E 2896.91 N 39 1T E 301,~.25 N 40 9 E 3131.04 N 40 25 E 3246.19 N 38 39 E 3360.03 N 39 30 E 3473.13 N 40 26 E 3584.75 0.67 0.20 0.15 0.48 0.92 1.16 1.49 0.12 0.33 1.00 1986.51 N 1590.20 E 2544.59 N 38 41 E 2079.78 N 1664.71 E 2663.97 N 38 40 E 2172.91 N 1737.92 E 3782.43 N 38 39 E 2265.10 N 1810.30 E 2899.63 N 38 38 E , 2356.64 N 1883.87 E 3017.07 N 38 38 E ~ 2446.43 N 1958.60 E 3133.87 N 38 ~,I E · 2534.14 N 20313.23 E 3248.98 N 38 44 E 2622.27 N !105.38 E 33,52.87 N 38 46 E 2710.12 N 2176.73 E 3476.0,% N 38 -%6 E 2795.74 N 2248.37 E 3587.65 N 38 48 E 6473.50 ¢951.00 4900.00 47 46 6623.75 5051.00 5000.00 48 34 6773.48 5151.00 5100.00 47 49 6924.12 5251.00 5200.00 49 9 7077.11 5351.00 5300.00 49 12 7229.77 5451.00 5400.00 49 3 7382.14 5551.00 5500.00 48 45 7533.33 5651.00 5600.00 48 48 7685.72 5751.00 5700.00 49 10 7838.67 5851.00 5800.00 49 3 N 40 51 ~ 3694.43 N 41 14 E 3806.57 N 42 3 E 3917.99 N 41 23 E 4030.64 N 42 7 E 4146.41 N 42 14 E 4261.76 N 43 15 E 4376.66 N 41 58 E 4490.00 N 40 24 E 4504.98 N 41 10 E 4720.71 1.02 0.67 0.92 0.66 0.22 0.79 1.04 2.24 0.53 0.49 2878.87 N 2319.93 5 3697.29 N 38 52 E 2963.50 N .23-~3.49 E 3809.35 N 38 56 E 3046.76 N 24-57.55 E 3920.65 N 39 0 E 3130.60 N 2542.8,2 E 4033.13 N 3'9 5 E 3217.09 N' 2619.77 E 4148.8~ N 39 9 E 3302.80 N 2696.9~ E 4264.06 N 3'9 14 E 3357.24 N 2774.9,3 E 4378.80 N 39 20 E 3470.21 N 2852.2~ E 4491.98 N 39 25 E 3557.52 N 2927.09 E 4606.93 N 39 27 E 3645.23 N 3002.61 5 4722.65 N 39 29 E 7991.94 5951.00 5900.00 49 41 8146.03 6051.00 6000.00 48 59 8297.91 6151.00 6100.90 48 54 ~450.46 6251.00 6200.00 49 19 8602.87 6351.00 6300.00 48 46 8754.14 6451.00 6400.00 48 34 8905.31 6551.00 6500.00 48 33 9055.99 6651.00 6600.00 47 55 9204.22 6751.00 6?00.00 46 54 9349.52 6851.00 6~00.00 46 27 N 42 9 E 4~36.85 N 41 2 E 4954.06 N 40 4 E 5068.36 N 39 34 E 5183.54 N 37 ~ E 5Z98.35 N 36 52 E 5411.$7 N 36 24 E 552~.59 N 36 5 ~ 5635.88 N 36 9 E 5745.87 N 36 lB E 5850.92 0. 2.14 0.72 0.65 0.00 0.45 0.62 0.11 I .35 1.44 3731.99 N 3079.83 E 4838.71 N 39 32 E 3818.79 N 3158.63 c 4955.81 N 39 36 E 3905.81 N 3232.74 ~ 5070.10 N 39 37 E 3994.38 N 3306.42 E 5185.32 N 39 37 E 4085.06 N 3377.14 E 5300.25 N 39 35 E 4175.61 N 3445.56 E 5413.66 N 39 32 E ) 4266.64 N 3513.13 E 5526.88 N 39 28 E 4357.67 N 3579.61 E 5639.41 N 39 24 E 4446.05 N 3644.11 ~ 5'748.64 N 3'9 20 E 4531.00 N 3706.53 E 5~53.92 N 39 17 E 9497.75 6951.00 6900.00 48 20 9647.93 7051.00 7000.00 48 24 9798.87 7151.00 7100.00 48 42 9949.81 7251.00 7200.00 48 9 10098.64 7351.00 7300.00 47 40 10249.54 7451.00 7400.00 48 38 10399.98 7551.00 7500.00 48 8 10549.89 7651.00 7600.00 48 23 10701.46 7751.00 7700.00 49 14 10855.53 7851.00 7800.00 50 2 N 35 2 E 5959.91 N 35 20 E 6071.18 N 36 46 E 618.3.83 N 36 46 E 6296.60 N 36 29 E 6406.47 N 37 Z E 6519.15 N 37 58 F 6631.27 N 38 42 E 6742.82 N 39 i E 6856.60 N 40 35 E 6973.77 0.81 1.79 0.98 0.67 1.06 0.55 0.99 0.40 1.21 2.26 4619.96 N 3770.20 E 5963.09 N 39 13 E 4711.92 N 3834.21 E .5074.81 N 39 8 E 4803.17 N 3900.97 ~ 6187.7~ N 39 5 E 4893.43 N 3969.05 E 6300.72 N 39 3 E 49~2.07 N 4034.59 5 6410.8~, N 39 0 E 5072.54 N 4102.29 E 6523.75 N 38 58 E 5162.12 N 4170.17 E 6636.10 N 38 56 E 5249.82 N 4239.32 E ,5747.77 N 3~3 55 E 5338.83 N 4310.37 E 6861.66 N 38 55 E 5428.91 N 4385.36 E 5978.86 N 3~ 56 E COMPUTATION DATE: 23-0CT-90 PAG-E ARCO ALASKA INC. D.S. 9-43 PRUDHOE BAY NORTH SLOPE, ALASKA DaTE OF SURVEY: 30-AUG-1990 KELLY ~USHINS ~LEVATION: 51.00 FT ENGINEEr: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET O~ :SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERT.IC.~L DOGLEG RECTANGULAR C,]ORDINATES HSRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 ~EET .~EET FEET OEG MIN 11010.98 7951.00 7900.00 49 48 11164.77 8051.00 8000.00 49 16 11318.33 8151.00 8100.00 49 18 11469.58 8251.00 8200.00 48 14 11617.73 8351.00 8300.00 47 12 11764.76 8451.00 8400.00 46 16 11906.94 85,51.00 8500.00 44 18 12046.63 8651.00 8600.00 44 21 12187.39 8751.00 8700.00 45 16 1233Z.02 8851.00 8800.00 47 30 N ¢0 53 E 7092.79 N 4.0 6 E 7209.63 N 39 52 E 7326.14 N 39 16 E 7439.56 N 39 20 E 7548.79 N 43 13 E 7656.55 N 44 Z E 775 7.50 N 46 5B E 7854.75 N 49 10 E 7953.09 N 50 I E 805,6.34 0.68 0.82 0.72 0.43 2.80 2.30 1 1.09 1.64 1.57 5518.70 N 4453.47 .:..7097.79 N 33 `58 E 5607.62 N 4539.28 E 7214.60 N 38 59 E 56'96.81 N :4614.28 E 7331.11 N 3'9 0 E 5784.43 N 4636.37 E 7444.58 N 39 1 E ,5569.35 N 4755.19 E 75`53.88 N 39 1 E 59,~9.79 N ~B26.91 E 7661.53 N 39 3 E 5022.84 N 4996.TZ E 7762.25 N 39 T E 6091.27 N 4966.2! E 7859.19 N 39 11 E 6157.57 N 5039.a~ E 7957.09 N 39 18 E 6224.86 N 5119.73 E 8059.80 N 39 26 E 12482.24 8951.00 8900.00 48 30 12575.00 9012.46 8961.46 48 30 N ~9 38 E 8167.16 N 49 38 E 8235.88 0.00 0.00 6297.35 N 5205.Z0 E 8170.12 N 3g 35 E 6342.37 N 5258.13 E 8238.54 N 39 4,0 E COMPUTATION DATE: 23-0CT-90 PAGE 9 aRCO ALASKA INC. D.S. 9-~3 PRUDHOE BAY NORTH SLOPE,, ALASKA MARKER TOP SADLEROCHIT ZONE 2 ZONE lB GCT LAST READING BASE SADLEROCHIT PBTD TD O.ATE OF SURVEY: )O-AUG-1990 KELLY 5USMIN9 ELEVATION: 51,00 FT · ENGINEER: SARB~R INTERPOLATED VALU=S FOR CHOSEN HORIZONS SURFACE LDC~TION = 1992' FSL, & 62' FEL, SECO2 TiON R15E MEASURED DEPTH BELOW KB 'TV D FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 12230,00 12230,00 12320,00 12400,00 12417,00 12460.00 12575.00 8780.88 8729.88 8780.88 8729.88 8~47.. 87 8791.87 8896.51 8845.51 890'7.78 B856.7 B 8936°27 8885,27 9012.46 8961.46 6177, 28 N 6117'7, 28 N 6219.17 N 6257,47 N 6265,71 N 6286' 57 N 634Z.37 N 5062.92 5062.92 5112.94 5158.28 5167.97 5192.51 5258.13 COMPUTATION DATE: 23-OCT-g0 PAGE 10 ARCO ALASKA INC. D.S. 9-43 PRUDHOE BAY NORTH SLOPE~ ALASKA MARKER TOP SADLEROCHIT ZONE 2 ZONE lB BASE SAOLEROCHIT PBTD TD ************ STRATIGRAPHIC SURFACE MEASUREg gEPTH BELOW KB 12230.00 12230.00 12320.00 12417.00 12460.00 12575°00 KELLY LOCATION = lcJgz' =SL, & 6Z' TVD FROM KB SUB-SEA 8780.88 8729.88 8780.88 8729.88 8862.87 8791.87 890T.78 8856.78 893,6.27 8885.27 9012.~6 8961.46 DATE OF SURVEY: ~USHING EL EV.,~TION: ENGINEER: 30-AUG-lOgO 51.00 FT SARBER ~EL, SECOZ TION R15~E R ECTANGUL.~R COO NORTH/SOUTH E 6177.28 N 5 6177.28 N 5 6219.17 N 5 6265.71N 5 6286.57 N 5 634Z.37 N 5 RDINATES AST/WEST 06Z.g2 E 062.92 E 112.94 E 167.g? E 19Z.51 E 258.13 E FIN~.L WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12575.00 9012.46 B961.46 HORIZONTAL DEPARTURE 9IST*NCE AZIMUTH mEET DEG MIN 8238.54 N 39 40 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. 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LLLL~,..L4...LLJ...LLLL · -t.t.-+-? :::: ~+ k}'+'~-++H'~"H"+'+'t'H''++--'~-~ · ~.- ~-~.~ · ~.~ ~ ~-4 4..4.-.L~ .~..~...~._~...Lu.~..~..~ ....... ~...~..~...~._...~...~..~...~_.~...~1...:...~...,4_~..~...~...~... ........... ~---,'----?,'-?-~ ...... ?-4--+-?-'-~---~--T--, .............. *--+-'~ ........ ~ ........ l .............................. ,..+4 ........ ~--4.-+.-*.-4.-.~--+-.,..-? · .~-~.4.4..-~..~-&.4.-. "'~'~"T'~"ff'~-~-~"~ '-Y-~"T"-?'T"~"~"T"'~ .... ~ ............. ~ .... , . t { : i : I : 12000 41.. m ii ID z PROJECTION ON VERTICAL PLRNE 41, - 221, SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT A~GC~ GEOLOGICAL MATERi~LS ~NYFNTORY UST COMPLET!O~ D~TE ~ I / ~ ~'~) CO, CO~TACT check off or list data as it is received.*list received date for 407, if not reauired list as NFl drillina history survey well tests core dcscri cored i core analysis ditch intervals ital data , " , .,,. ~-..r,=" ' ~U~ ..... ,.~.=r,,,..~ " SCALE L..~lllt~l I i FL 11111 I NO. [to thc nearest footI .... [inchll §0'] , ..... ,,. ...... .//~ ,~/ ! .............. I I Illl ....... I .... ~ ...... AR(](] AL. A3~KA, :[NC.~ F:' 0 B u,. i ,.:,, (-) o o ANCI-.IORAt]E, ALA,SKA 99fJ~I O .: D A ]" E · 9 .... 25 - 90 R E F-" Iii] R E N C E · A R C 0 D I R E C; T I 0 N A L. D A T' A '::;, ..... .a, ..¥ F~ ....... .... 7 4 .... 9 ;'.),. i'"'i t;.I.. ]() ,..'0 .~.'r .f:(: i::', ........ f']: 'i" ]J ,"] i"-i A i... ,.,':':' i.....iF:.'' ;,i iiiJ Y ...J {.} J(i': :ii: 7 ?' 3 F:'I...iEA,';~;~:; ;}:?!C:.N ANn F::ETUF:.:N 'i"i"llii] AT'T'ACHED COF:'Y A;L'..~ :"i::',"i::'"pT r"~i::' 'r',Af'A ,,.. .. ..... . ~. ..... ; · ~..l ..... .... .'. R Iii] L. r..:. ~. v iii] D B Y i..I A V E A N I C; [.; D A "',."' ! D t 5: T i:;,' ! B U 'T' i; 0 N C Iii: N T F;.: A L. F"' ;[ t... i!."; ;S C i"i E V R 0 N D & M :~I: iii: X T !ii: N ;S: ]: 0 N iii; X F:' I... 0 R A 'T' i 0 N -,:-'"' Ii:.' X X 0 N. i"'t A R A T t"t O N H 0 B :[ 1... RECFIVED OCT O ! 1990 Alaska Oil & Gas Cons. Comml~lon Anchorage ARCO Alaska, Inc. ~' '~, Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 September 21, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 · SUBJECT: DS 9-39, 40, 42, 43, 44, 45 Dear Mr. Chatterton: Enclosed are copies of the subject As-buiits for your information. If you have any questions, please call me at 263-4618. Danielle Warner Engineering Aide · DW cc: File W1-1 RECEIVED SEP 2 7 ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO ALAS'KA: ?i'd,C, F' f'i B f'i W '~,-,,-,~ ....... 6,':', .. ..... · ..... , .... :: . ;qN. CHOF;~A(;E, ALA£KA RECEIVED ._ DATE · °-2,:3-g'0,. _ . REFERENCE' ARCO CASED HOLE F' :E HAl_"": 'Gas gons. gommiss~on Anchorage F'!._I!-.'.A;~CE ::~IE-N AND RETURN TiiE ATTACHED COF'Y AS F;..'FZCE:[PT OF DATA~ RE i"::`iil ]:VED BY _...~~..~ HA;,,"i-Z A NICE DAY! D l $ T IF;..' :[ B t.J T ]: 0 N -"' r'tFNTRAL FILEZ ,,- CHEVRON '~ EXTEN$.T_ ON EXF'LORAT ]:CIN .~ EXXON MARATHON · '" F' H.'[ Li',_ t F' ,., *'' 'F'.'f-:.,' WEt_L F]:LEZ i:;' , · ':N '"' 9 F'X "' :"-..~TATE OF At..A:~;'t<A T E X ¢.4 C 0 ARCO ALA&"KA, ZNC., F'., O, BOX ANt'HE, RAGE ALA~'KA ~, o,.'.' ,i OA'I'E · 9-i 7-9(:_) R!:--FERENCE' ARCO CASED HOLE FINAL.,:.7 i - 9 i --24 2'-? ,'"-, - ! ~::~ 9--4.3 .9-43 i 2.-29 i...:.'='- i ,:5 i 6-24 i 8- 9 F'WDW i .-2A 9-6-9¢ F:' W D W i -- 2 A 9 -- 6 - 9 F'WDW t -"~A.- 9-'7-,~ ;:;, ,, o ._. ,:.q _ c;, ,..---, ,"" i'.-i L - F; :- ,~ : ...- ,...... . . 9 '- 9 .... 9 ,:D F' O K - i ,:ii:, E:: /ii. i:;.: /Iii C L 9 -- '.? -- 9 (.} 'T' }]',' ij C U T T E i:;,: ,=,_".",; ,:;,;:., ~-'-',c~,¢ Ri=~"'O!:;:D c,_ 3,':~- '=." ;:" [J i::..: I i'-J F: A ~i; ]: N ... : ..., 8 - :3 ,:-} - 9 ,:::, C: B T :.,~::' - S (:; .. '- '=.", ;:~._. C: IF- T 9 - S - 9 ;) A C B L / ¥ D i /' ~; :[ C; 9- 7--- 9 (.:;,F'D K - i ,:i),.';:, /' (]- F;.: /C C i_ / B 0 R A X 9 - 6 '- 9 (-) C 0 L L A i.;..' / F' E F.: F-' 9-i E:,'.-'-'..:-",::2 F'DK-i ,."::, ,:b .," g R/CCL CBT C': E:: T F' K R $ F T T' I N (-:- F:ii: C' C..: R D F:'L[:-AF'/E .'~IGN AND F;.'.ETLIRi'J, THE ATTACHE:D COPY AS' REC.'.EZF'T OF:' DATA., ED HAVE: A NICE DAY! SALLY HOF"FECi( ER ATO- i 529 SEP 19 1990 , Alaslm Oil & Gas Co.s. Commissi~!~'F."?! r=!i~E D :~ t KAI'~3':.' '..--' (:)/..5 6 .5 Anchorage DI~TRIBUTiON "- Ci:NTRAL 1:: I LE:'~ -'~ F'H ZLL 'r F'::";' ~~ CHEVRON t""B WELL F']:I_E3 D & M R & D ~- EXTENSION "', r",'-- ExF LuR~-~ I I Oi'~ BF'X " EXXON :~ ,"~"t"A~"E OF AI_A31'.:A MARATHON 'TEXACO " MOBIL. ir · :'~ "['FIE CORRECTED AF'I~ FOR F:'WDWi-2A ]:";'.' "'".;:;-;:~29-n"~':.:.:"='4-'~')t · I.., .~ ,,,z '..' ,~. -' .. ~'. ~. ARCO ALA2KA, INC.~ A N C H Ill)R A C;. E, A 1... A ,?-,' K A 9 9 5 'i (') R iii: F iii: R E N C: E ' A R C: O M A G N Ii!: T ]: C: T A F:' Iii: ( ,~? ) W :I: 'i" H I... ]: .? T ]: N C;- ( S ) J::' !... iii: A 5; E ,}? I C;. N A N D R E 'i" U R N 'T' t..t iii: A'T' T A C H iii: D C: 0 F:' Y A ;!'? R E C E t t::' T O F:' 0 A "F A ~ ~:', i::' ": '::' :. , ..~ ....~. ,,.,...L,L I ';/iii:):) i:.:'.,,' .............._ ......_ ~.._ _..... _ HAViii: A NIC:tii: DAY! 2 A i... L. Y H 0 F' F:' EEC K lie R A'T' [] .... 'i '::'"':' ~::' .... .:' :;....' D t 2 'i" R I B U T ]: O N "" E N'T' R A L F:' 'r t... ii-" $ ,' r': H ', L.: ,~. : .. : CHEVRON i} & M "i'Ai"~kiA,~.;! E-,'F;~'OWix! ( OH ) E: X X 0 N i'"'i A R A "~' H 0 N ....... i. ~.... A R f": 0 A L A v K A I N C !":" 0 B 0 X 'i '3 '3 Z ;. 3 t. ~ I'tt'! ANC:HOF;,'ACSEJ, ALASKA 995:::t ,;'} R Iii] F E R E i',! C E ' A R C 0 0 P E N H 0 I... E F:' ]] N A L. ;i{,' ~":"..:-": ..... 4 2 :iii: .... 3 .... 9 0 ;!it i"1R D ~ 9 .... 4 2. iii .... '.3 .... 9 0 0 i P J"i E 'i" E tR A D V i ;ii.: 0 R '9 ..... 8 .... '2','::!: .... 90 ,.? ,S; 'i" V i} 9 .--- 4 L','.¢ 8 .---23 --.-9 (-)D J'. 1.....-. (] F;..' · ~/r 9 ..... ':~ S 8 -',.:.:'..]".", .... 90 C N i..."" ":, R F:' L.. !iii A ;!;! E ;!;: I ('.; N A N D R E T U R N '1' H lie A 'i"'1" A C i.'i E ii.') C ill)P Y A ;:'.'; R E C: E i P i" (Si j::' D A T A., RECEIVED R iii] C: E ]] V iii] D B Y .................................... ...... HA Viii: A :,..! :!: :::::!i::. :()A":"' ! Alaska Oil & Gas Cons, com~tssW~ A TO .... i '::~";"': ....,£.7 A F:' F:' F;,' O V tED · r ~:;.: A ?.!,!i: :~ 9 D I :};' 'T' i:~'. 1 i('3 U "i" ]] C)bi :i~ ii:; iii] N 'i" F..: A i... F:' i !... li'] $ ~I: C: l"I iii; V R fi N :~ D & H · 41:E X 'i" E N 2 i 0 N E X F' I... O R A T I O N ,iL .... · .. t::. X X 0 N · ,. iq A J:;..' f'-",. 'i" I.-i 0 N · "' H ~'"~ B i L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator _ Suspend _ Alter casing ~ Repair well Change approved program ~ ARCO Alaska, Inc. ' 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown_ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other_ 6. Datum elevation (DF or KB) 4. Location of well at surface 1992' FSL, 62' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 2450' FNL, 0' FEL, Sec. 36, T11N, R15E, UM (APPROX) At effective depth 2200' FSL, 200' FWL, Sec. 36, T11N, R15E, UM (APPROX) At total depth 2365' FSL, 74' FWL, Sec. 31, T11N, R15E, UM (APPROX) 12. Present well condition summary Total Depth: measured true vertical feet feet Effective depth: measured feet true vertical feet Casing Length Size Conductor 8 0' 2 0" Surface 41 97' 1 0-3/4" Production Liner Perforation depth' Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) RKB 52' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 9-43 9. Permit number 90-107 10. APl number 50-029-22078 Plugs (measured) feet 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool RE¢ IV D None E Junk (measured) Cemented 1775# Poleset 1500 sx CS III & 350 sx Class G None AtJ G ~ I~ '~°~90 Alaska Oil & Gas Cons. l;0~tt~,ot~'-"~ Anchorage Measured depth /rue vertical depth 110' 110' 4230' 3500' This report was previously submitted with the incorrect permit measured number of 90-82. AOGCC changed the well number to DS 9-42 on the assumption our error was the well number. ARCO Alaska true vertical Inc., was not notified of this change before it was made, so was unaware of any problem with having approval for DS 9~43 until we received it in the mail on 8/27/90, after the work was completed. The AOGCC was notified of the altered casing procedure on 8/14/90, a week prior to the proposed change and the previously submitted report was approved 8/15/90. Description summary of proposal X Detailed operation program _ BOP sketch _ 13. A~achments 15. Status of well classification as: Oil X Gas __ Suspended 14. Estimated date for commencing operation . August 22, 1990 16. If proposal was verbally approved Name of approver Date approved Service Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~)~~ ~X~ Title Drilling] Analyst _ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApp..r..oval No. Plug integrity __ BOP Test _ Location clearance __ ! ~'~,) --' ~"~,_~,,~ Mechanical Integrity Test_ Subsequent form require 10- ,/'¢'/-: &' 7, Conditions of approval' Replaces Sundry originally approved 08/15/90. ~j:)proved by the order of the Commission Commissioner Date ~J _"~l 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy ~c] J:ieturned . / SUBMIT I~ TRIPLICATE Form PBU DS 9-43 REVISED OPERATIONS SUMMARY . , 1. MIRU ddlling dg. NU diverter and function test same. 2. Ddll vertical 13-1/2" hole to KOP @500' TVD/MD. Build angle at 2deg/100 to end of curve at 2959'md. Drill to surface csg. point at 4230'MD/3500' TVD. 3. Set 10-3/4" casing and cement same. Nipple up BOPE and test to 5000 psi. 4. Pick up 9-7/8" BHA and GIH. Test casing to 2500 psi for 30 minutes. Ddl110' of new hole and perform leakoff test. 5. Ddll 9-7/8" hole to 8707'TVD/12199'MD maintaining the hole angle and direction. (SEE NOTE ) Set 7-5/8" casing and cement same. 7. Pick up 6-3/4" BHA and GIH. Test casing to 3500 psi. 8. Ddll 10' of new hole and perform EMW test. 9.Drill 6-3/4" hole to 12525'MD/8919'TVDmaintaining the hole angle and direction. 10. Run wireline logs as programmed. 11. Set 5-1/2" liner and cement same. 12. Clean out the liner and test liner to 3500 psi for 30 minutes. Circulate well to brine. 13. Run cased hole logs. 14. Run 3-1/2 tubing and packer assembly with GLMs. Test tubing and casing to 3500 psi. Freeze protect with diesel. 15. N/U tree and test to 5000 psi. Release ddlling dg. 16. Rig up wireline unit and perforate. NOTE: In the event that the mud weight requirement is less than or equal to 10 ppg at the intermediate csg. point (12199'MD / 8707' TVD ) the option to proceed with the intermediate hole will be evaluated. Recall that DS 9-41 and DS 9-42 required a 9.8 ppg mud weight to drill the K5 shale interval. · Antcipated BHP: 3650 psi (8.0 ppg EMW) @ 8800' TVD · Maximum Anticipated Surface Pressure: 2750 psi Planned Completion Fluid: 8.6 ppg Seawater NOTE; PBU DS 9-43 REVISED OPERATIONS SUMMARY CONT. a. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non-freezing fluid during any extended pedod. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Wells within 200 ft. of the proposed well is: DS 9-07 60.67' @ 0 TVD/0MD DS9-36 119.45 @ 500q'VD/500'MD DS 9-08 183'@ 500'MD/500"I'VD c. The ddlling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. f. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). g. Based on previous logs on DS 9, no potential productive zones am antidpated above 3500' TVD. h. No potential hazardous levels of H2S am antidpated in this well. AUG ~ 1 1990 A.[aska Oij & Gas Cons. Commission Anchorage DS 9-43 MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) GELS GELS CC/30MIN (%) (%) MUD TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 to to to to to 10-3/4 9.2 100 4O 6 csg pt. SET 10-3/4" CASING GEL-BENEX SPUD MUD DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 10-3/4" 8.7 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to TREATED 5000 9.0 15 16 4 10 10 9 POLYMER 5000 9.0 15 16 4 10 10 0 9 UGHTLY to to to to to to to to TREATED 7-5/8" 10.0 20 25 6 12 6 11 POLYMER csg pt. SET 7-5/8" CASING DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD ('I'VD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 7-5/8" 8.7 10 6 2 1 8 0 4 LIGHTLY to to to to to to to to TREATED TD 9.4 15 10 4 10 6 6 POLYMER SET 5-1/2" LINER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. R '¢EiVED A U G 3 1 1990 ltlasP, a.Oil & Gas Cons. Commission Anchorage ~2 el~ 013 o14 o15 NOTES , i i BOX IN NO. ~OS. COORO$; POSITION £L£V. 5,943,434.54 N 2439.87 70'14'55.258' 1999' 59 717,276.98 E 655.08 148'1¢'40.293' 20.6 1085' F.£.L S.2 5,94~,874.37 N 1619.96 70-14'47.417° 1405' F.S.L 40 718,441.97 Ir 1652.70 148'14'08.901' 19.6 62' F.W.L S.1 5,945,376.56 N 2379.68 '70'14'52.679' 1940' F,~L. 4~' 717,291.21 E $53.09 148'14'39.929' 20.0 1073' F.E.L 5.2 5,943,457.35 N 2219.87 70'14'55'189~' 19.4 1992' 4..~ 718.500.56 E 1653.04 148'14'10.520' 62' F.F..L $.2 , 5,943,1~.27 N 1859.69 70'14'49.725' 1639' F.S.L 44 718,585.17 E 1652.54 148'14'08.35~' 20.2 13' F.W.L $.1 5,942,991.22 N 1740.17 "70-1'4'48.$74' i522' F.S.L 45 718,415.74 E 16§2.88 148'14'07.623' 20.0 58' F.W.L LOCATED WITHIN PROTRACTED SECTIONS 1,2.11,12, TION, R15E, U.M.. ALASKA. DE't/ I~1/'~ I r~ ^ TC' ISSUED FOR INFORMATION ~ I:"Vl C::l ~l,,J C~ 12 ..'ts. VICINITY MAP SURVEYOR'S CERTIFICATE [ HEREBY CERTIFY THAT I AM PRO- PERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT TI-IlS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMEN- SIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 28, 1990. 1. BASIS OF LO~ATION IS D.$. MONUMEN~ 9A ANO 2. COORDS. ARE ALASKA STATE PLANE. ZONE 4. k-.9999§39. 3. BASIS OF ELEVATION IS ARCI3~)ATUM LEGEND · EXISTING M[].LS /' ! F. ROBERT BELL-'" XSSOC. ARCO Alaska Inc. CONDUCTOR AS-BUILT DS 9 WELLS 39,40,42,43,44,45 .... I I 7-28-90 I JMF ! HITCH I t N.T.S. I - I A53684 I PA2004AAJ n~'AWNICH£CK I NSDPI 00001 CEA-2700-048 I2°~ Au~lst 2, 1990 Telecopy~ (907)276-7542 J. D. Gillesple Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box i00360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 9-43 AJP. CO Alaska, Inc. Permit No. 90-107 Sur. Loc. 1992'FSL, Btmhole Loc. 2365' FSL, 62'FEL, Sec. 2, T10N, R15E UM. 74'F~, Sec. 31, TllN, R16E UM. Dear Mr. Gillespie: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The C~ission will advise you of those BOPE tests that it wishes to witness. Ve~ truly yours, Commt~ ~iouer o~ Alaska Oil aud Gas Cou~e~a~iou Co~t~stou BY O~ER OF THE COM~!ISSION dlf EncloSure Department of Fish & Game, Habitat Section w/o encl. Department of ~vironmental Conservation w/o encl. STATE OF ALASKA -, ALASKA L AND GAS CONSERVATION C'~'"IMISSION ! Re-Entry- Deepen r-I PERMIT TO DRILL 20 AAC 25.0O5 lb. Type of welt. Exploratory ,~ Stratigraphic Test ~ Development Oil Service _- Developement Gas ~_ Single Zone :-; Multiple Zone 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 10036,0, Anchorage, AK 99510-0360 4. Location of well at surface - 1992'FSL, 62'FEL, Sec. 2, T10N, R15E, OM At top of productive interval 2450'FNL, 0'FEL, Sec.36, TllN, Ri5E, UM At total depth 2365'FSL, 74'FWL, Sec.31, TllN, R16E, UM 12. Distance to nearest 13. Distance to nearest well property line DS 9-07 O' feet 6Q' at surfac~ feet 16. To be completed for deviated wells 49012' Kickoff depth 500' feet Maximum hole angle 0 18. Casing program size Hole Casing " 2 0" -1/2" 10-3/4" 7/8" 7-5/8" 5. Datum Elevation (DF or KB) RKB 52 ' feet 6. Property Designation ADL: 2~43 7. Unitorproperty Name Prudhoe Bay Unit 8. Wellnumber PBU DS 9-43 9. Ap~oximate spud date 08/~'~90 14. Number of acres in property 10. Field and Pool )rudhoe Bay Field Prudhoe Bay Oil Pool 11. ~pe Bond(see20AAC25.025) Statewide Number No. U-630610 Amount $200,000 2560 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2 8 0 0 psig At total depth ('TVD) 8 8 0 0 Setting Depth 15. Proposed depth(MDandTVDi 12525'MD feet 8919'TVD psig MD Specifications Weight ! Grade [Coupling I Length 94#[H-40 ],eld [ 80' 29.7~ [7~ 1~-8o /smc / ~=~' 30 35' 13 33' 9- 31' 9-7/8" 7-5/8" 6-3/4" 5-1/2" 11906 ' 19. TO be completed for Redrill, Re-entry. and DeePen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Top Bottom I 31' 15760'!. 4500' , I ~511' 11=5=5'1 s9~9' Quantity of cement (include stage data) 280 sx CS I'T 2000 sx CS III/350 sx C 500 ~x ¢1 ~ ,, 200 sx Cl G Effective depth: measured feet Junk (measured) true vertical feet (~asing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth 20. Attachments Filing fee [] Property plat [] BOP Sketch I-: Diverter Sketch Q Drilling program Q Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the beSt of my knowledgej~_.. Signed Title p,=~,~ ~,,,~ ~ n.-~ ~ ~ ~.,. ~-~ .... Date i Comm,s,,on se n,, ' Permit Nu umber ~ Approval date~ See cover letter ~o- ~ 7 50--o~- ~~ ~F J 08/02/90 _J for other requirements ConSitions of approval Samples required ~ Yes ~ No Mud log required ~ Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional. su~ey required ~ Yes ~ No Required working' pressure for BOPE ~2M; g 3M; ~5M; g 10M; ~ 15M Other: " .~~ // . by order of Date ~.~-¢e Approved by .... ~.~__ Commissioner the commission Form 10-401 Rev 12-1-8~'~/~~ (~ Submit in triplicate . , PBU DS 943 OPERATIONS SUMMARY MIRU ddlling fig. NU diverter and function test same. ~D~lJ~ver~i~l :t~ 1t2~ h01e to .~,~,~- 'TVD~D. 10. 11. 12. 13. 14. 15. 16. 17. 3. ¥~S~ 1.0~3/4' ~!ngand cemem same, N~pp e up BOPE and test to 5000 psi. 4. Pick up 9-7/8" BHA and GIH. Test casing to 2500 psi for 30 minutes. Drill 10' of new hole and perform leakoff test. 5. Kick off and build angle at 2.5 degrees/100 ft. to 49deg 12' in the N 41deg 7' E direction. End of build is to be at 2688q'VD/2959'MD. 6. Drill 9-7/8" hole to 8707'TVD/12199'MD maintaining the hole angle and direction. 7. Set 7-5/8" casing and cement same. 8. Pick up 6-3/4" BHA and GIH. Test casing to 3500 psi. 9. Drill 10' of new hole and perform EMW test. Drill 6-3/4" hole to 12525'MD/8919'TVDmaintaining the hole angle and direction. Run wireline logs as programmed. Set 5-1/2" liner and cement same. Clean out the liner and test liner to 3500 psi for 30 minutes. Circulate well to brine. Run cased hole logs. Run 3-1/2 tubing and packer assembly with GLMs. Test tubing and casing to 3500 psi. Freeze protect with diesel. N/U tree and test to 5000 psi. Release drilling rig. Rig up wireline unit and perforate. · Antcipated BHP: 3900 psi (8.5 ppg EMVV) @ 8800' TVD · Maximum Anticipated Surface Pressure' 3020 psi · Planned Completion Fluid: 8.6 ppg Seawater R[C IV[D NOTE; PBU DS 9-43 OPERATIONS SUMMARY CONT. a. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non-freezing fluid dudng any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Wells within 200 ft. of the proposed well is: DS 9-07 DS9-36 DS 9-08 60.67' @ 0 TVD/0MD 119.45 @ 500'TVD/500'MD 183'@ 500'MD/500'TVD c. The drilling fluid program and sudace system will conform to the regulations set forth in 20AAC25.033. f. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). g. Based on previous logs on DS 9, no potential productive zones are anticipated above 3500' TVD. h. No potential hazardous levels of H2S are anticipated in this well. DS 943 MUD PROGRAM DEPTH DENSITY ViS YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) GELS GELS CC/30MIN (%) (%) MUD TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 to to to to to 10-3/4 9.2 100 40 6 csg pt. SET 10-3/4" CASING GEL-BENEX SPUD MUD DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 10-3/4" 8.7 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to TREATED 5000 9.0 15 16 4 10 10 9 POLYMER 5000 9.0 15 16 4 10 10 0 9 LIGHTLY to to to to to to to to TREATED 7-5/8" 10.0 20 25 6 12 6 11 POLYMER csg pt. SET 7-5/8" CASING DEPTH DENSITY PV YP INT 10min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 7-5/8" 8.7 10 6 2 1 8 0 4 LIGHTLY to to to to to to to to TREATED TD 9.1 15 10 4 10 6 6 POLYMER SET 5-1/2" LINER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. 13-5/8" 5000 psi BOP STACK DIAGRAM B IPE RAMS~ IND DRILLING c~SING SPOOL ACCUMULATOR CAPACrFY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 13-5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN 17. AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TE,.ST DALLY. NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP LINE RISER FLOWUNE I 20" 2000 PSI DIVERTER I 1t:7' BALL VALVE 1(7' BALL VALVE I NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. RESERVE PIT 1(7' VENT LINE 10" VENT UNE DIVERTER LINES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEES. R E C E IV E D 0 1000 2000 3~ 4000 5000 6000 '/~ [ I I I I I I I I I I I I I i I I I [ [ I [ I I I I I I I I I I I I I I ...... I I I I I I I I I I I I I I I ...... RT~ 1:1 EL~-'~rATTON 20" Casing TVD=I 10 TMD=I 1~. .~EP=0 ~O~ ~:~00 AR¢~O ALg S KA, II'~[C. 2.0 DS9-.43D ~ ~4.o SHL: U 1 ~)N 15E 2 1992' FSI 62' FEL ~16.0 }~ ~8.o THL: U 11N 15E 36~24~0' Fl IL 0' FEL ~2~.Oxo BHL: U 1 1N 16E 31 2365' F~ ~L 74' FWL 1~2~O.o $41 7'£ ~.o :~.0 ~ 10-3/4' C~g ~=35~ ~230 D~=1953 ~~5~ ffi D~=3111 A~GE t ~GLE = 49 12' K-10 ~7892 T~=10950 DEP=7~) 8222 ~:11456 D g~7423 7-5/8" C~g ~=8707 ~121~ Dt~=7986 ~ 1~ ~=8717 ~=12214 DEP=7~8 - ~p Sadl~hit ~ ~=8717 T~=12214 )~=7998 TARGET ~::8822 ~12375 DE ~:8119 ~ ~=89:.9 T~=I~ D~=8233 ................................................................ lOOO 2000 3000 4000 6OOO 7O00 8000 10000 7000 8000 9000 10000 11000 12000 13000 14000 VERTICAL SECTION ARCO ALASKA, INC. DS9-43D N417'E 0 0 09 -07 E - W COORDINATES - 1000 0 1000 2000 3000 4000 5000 6000 7000 {2,i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ~ i i i ........................ ~ ......... ° 0 09-~ ,5 ._ [86 21'689 \UY-.30 5680 ~086`8753 ~ '' __._, ....... _ ............................................. 1000 0 -1000 -1000 -1000 0 1000 2000 3000 4000 5000 6000 7000 0 Ch 100 ¢~ ¢~, 200 1000 2000 3000 4000 5000 , ~ '~/fTNI = RO f; 7' '~t3:~0 MY'~=O , , , ~ ............................................. INC. 2000 2000 3000 ~ 3000 40~ ~ 4~0 5000 ~ 5000 6000 ' ' 6~0 7000 7000 8000 8000 9000 .... 90~ 10000 10000 11 ~0 11000 12000 12000 0 100 200 1000 2000 3000 4000 5000 PRO~MITY CHECK LIST FOR NEW WELL PERMITS IT_~M APPROVE DATE (8) '(9 / (10 ~d 13) 12.' 13. (14 thru 22) ,,, (23 thru 28) Company _/~..~~ Lease & Well No..~,~- YES NO Is the perm_it fee attached .......................................... ~ -- 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is wei! located proper distance from other wei!s ........ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is we!! =o be deviated and is weilbore piat included. ............... 7 Is operator the oniy affected party ......... i ....................... /_ 8 Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 2.5. 26. 27. 28. Does operator have a bond Lu force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is =he lease number appropriate ..................................... Does the well have a unique name and number !s cdnductor string provided ........................................ Will surface casing pro=act all zones reasonably expected to serve as am umderground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... ,-~ Will cement tie in surface and intermediate or production strings ... ,~. ...... Will cement cover all ~o~ productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an ez. isting wellbore ............. , , Is old wellbore abandonment procedure included on 10-403 ............ Is d q lib parati pr po d ' a e uate we ore se on o se ..................... ...... , ...... Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~d)OO psig .. Does the choke manifold comply w/AP1 RP-53 (~ay 84) .................. Is the presence of H2S gas probable ............................. ~... (29 thru 31) ~ Eng$~n ~eeEing: DWJ~ LCS~: ~' ~ BEW / rev: 01/30/89 6.011. For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed condi=ions presented Additional requirements ............................................. INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SNORE , 90/S Zge% /- ,'/ FYo // Yo o /d Addi:ional Remarks:' Well Histo.ry File APPENDIX .Information of detailed nature that is not particulady 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 APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. PR~OGRAM: LIS REVISION: 4.1 ~RT N~BE~: ~5550-MTC~O Start of execution: Tue 28 AUG 90 2:52pm WELL DATA FILE: C:\CLIFF\W04553.WDF ECC: 4553.00 COMPANY NAME: ARCO ALASKA INCORPORATED WELL NAME: D. S. 9 - 43 FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 4100.000 4270.000 0.500 NUMBER OF CURVES: 21 DEPTH CAL CHT CNC GR PE RFOC RILD RILM SFT2 SSD SSN TTEN ZCOR ZDEN HRD1 HRD2 LSN SHR SP SPD COMPANY:ARCO ALASKA INCORPORATED WELL:D. S. 9 - 43 FIELD:PRUDHOE BAY COUNTY:NORTH SLOPE STATE:ALASKA TAPE INFORMATION FILE: MAIN .001 FILE INTERVAL: START= 4270.000 END= 4100.000 DEPT CAL SP GR RFOC CHT HRD1 HRD2 TTEN ZCOR ZDEN CNC PE 4270.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 -999 -999 .250 .250 .250 4245.000 6.000 -80.000 0.000 908.407 0.000 0.000 -0.250 2.000 0.000 2 2629 0 .390 .462 .000 4220.000 6.000 143.339 0.000 932.104 0.000 0.000 -0.250 2.000 0.000 2 2590 0 .401 .600 .000 4195.000 10.143 137.294 46.946 957.687 663.061 982.876 -0.631 2.011 68.706 2 2577 13 .400 .081 .757 4170. 000 10.247 124.406 34.338 965.056 611.099 915.213 -0.792 1.884 69.805 2 2569 14 .394 .575 .974 4145.000 10.169 -80.000 35.283 500.000 750.192 1072.048 -0.696 1.900 62.268 0 4000 12 .200 .000 .994 4120. 000 6.000 -80.000 33.721 500.000 0.000 0.000 -0.250 2.000 0.000 0 4000 0 .200 .000 .000 4100.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 WELL DATA FILE: C:\CLIFF\W04554.WDF ECC: 4554.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INCORPORATED D. S. 9 - 43 Top of Well: Bottom of Well: Level Spacing: 12030.000 12540.000 0.500 RILM SFT2 -999.250 -999.250 1.861 0.000 1.855 0.000 1.853 376.124 1.848 335. 126 0.200 422.398 0.200 0.000 -999.250 -999.250 RILD SSN -999.250 -999.250 0.200 0.000 1.848 0.000 1.847 109.518 1.845 116.989 0.200 113.818 0.200 0.000 -999.250 -999.250 SPD LSN -999.250 -999.250 25.997 0.000 24.997 0.000 24.997 33.066 24.997 35.065 0.000 35.997 0.000 0.000 -999.250 -999.250 NUMBER OF CURVES: 21 DEPTH CAL CHT CNC GR PE RFOC RILD RILM SFT2 SSD SSN TTEN ZCOR ZDEN HRD1 SHR HRD2 SP LSN SPD FILE:PASS 2.002 FILE INTERVAL: START= 12540.000 END= 12030.000 DEPT 12540.000 12515.000 12490.000 12465.000 12440.000 12415.000 12390.000 12365.000 12340.000 12315.000 12290.000 12265.000 CAL SP GR RFOC CHT HRD1 HRD2 TTEN ZCOR ZDEN CNC PE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6.000 1134.125 -0.250 5.869 1588.606 0.137 6.184 1084.137 0.135 -80.000 0.000 4.231 0.000 0.000 7174.426 2.000 0.000 0.000 61.801 0.000 8.629 8712.086 11897.801 8145.180 1.585 0.000 3.155 65.436 108.089 5.088 8605.473 11795.734 7041.262 1.588 41.185 3.123 6.281 68.459 117.197 5.821 1027.697 9186.621 12646.125 6931.320 0.110 1.528 42.254 3.201 6.509 70.901 59.431 20.425 946.913 4004.121 5059.305 6664.324 0.173 2.028 27.772 2.801 7.003 -20.222 50.317 23.015 944.461 4402.812 5612.004 6664.852 0.170 1.977 29.105 2.423 7.139 -13.713 46.463 22.858 978.265 4561.898 5707.164 6701.824 0.170 1.964 30.535 2.261 7.208 25.752 37.917 29.061 1013.640 4024.869 5058.758 6785.848 0.152 2.005 32.180 2.295 7.355 38.357 41.348 29.952 1293.133 4117.785 5145.699 7304.516 0.141 1.985 32.886 2.361 7.061 71.836 113.307 6.276 1115.698 4501.387 5776.820 6957.273 0.197 1.992 36.503 2.708 6.956 -7.676 37.553 19.242 1107.222 3509.243 4395.766 6919.914 0.119 2.039 27.450 2.604 RILM SFT2 -999.250 -999.250 6.008 0.000 8.677 7378.516 4.855 7328.164 5.087 7703.129 12.363 3387.337 16.412 3782. 142 23.648 3970.572 20. 141 3496.296 24.047 3552.478 15.555 3837.619 5.216 2977.463 RILD SSN -999.250 -999.250 0.200 0.000 8.984 0.000 4.867 156.164 5.059 152.601 15.349 201.333 22.851 183.650 29.780 175.121 33.213 171.577 39.038 163.449 13.626 148.083 7.796 203.650 SPD LSN -999.250 -999.250 26.997 0.000 26.233 0.000 26.997 61.486 26.888 59.208 26.997 99.855 26.888 88.538 26.997 82.029 26.997 77.899 26.997 73.263 26.997 62.459 26.997 101.722 12'240.000 7.288 -50.329 32.625 36.725 1343.395 5060.758 6442.016 7243.527 0.132 1.871 27.824 2.335 15.087 4390.172 16.867 179.403 26.997 88.879 12215.000 7.136 20.627 152 1355.436 3702.999 4570 0.186 2.085 54 .045 .754 .112 725 5.437 4.258 2.695 5.637 3187.158 5.397 127.313 26.997 43.187 12190.000 6.892 61.896 182 1343.535 4087.497 5204 0.181 2.025 57 .402 .527 .088 722 7.547 6.539 2.625 6.403 3472.279 6.879 137.799 26.997 45.488 12165.000 7.004 25.033 218 1349.791 4859.461 6228 0.184 1.943 55 .836 .621 .002 5.928 7193.941 2.687 5.246 4148.883 5.302 139.253 26.997 46.843 D. S. 9-43 DEPT CAL SP GR RFOC CHT HRD1 HRD2 TTEN ZCOR ZDEN CNC PE RILM SFT2 RILD SSN SPD LSN 12140.000 7.063 11.659 297 1261.298 4871.375 6402 0.184 1.935 54 .623 .840 .458 8 7000 3 .033 .625 .231 6.647 3994.629 7.099 165.708 26.997 56.027 12115.000 7.907 47.769 179 1203.117 4727.602 6048 0.196 1.969 57 .216 .977 .310 689 4.693 1.898 2.852 3.859 3940.543 3.809 126.580 26.997 41.702 12090.000 7.292 57.566 293 500.000 5383.551 7093 0.147 1.849 57 .904 .715 .374 500 0.200 0.000 3.332 0.200 4433.523 0.200 123.433 0.000 40.643 12065.000 6.000 -80.000 155 500.000 4602.340 6095 -0.250 2.000 42 .329 .855 .916 0 5000 0 .200 .000 .000 0.200 3777.347 0.200 144.024 0.000 55.389 12040.000 6.000 -80.000 0.000 500.000 0.000 0.000 -0.250 2.000 0.000 0 5000 0 .200 .000 .000 0.200 0.000 0.200 0.000 0.000 0.000 12030.000 -999.250 -999.250 -999 -999.250 -999.250 -999 -999.250 -999.250 -999 .250 .250 .250 -999 -999 -999 .250 .250 .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 WELL DATA FILE: C:\CLIFF\W04555.WDF ECC: 4555.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INCORPORATED D. S. 9 - 43 Top of Well: Bottom of Well: Level Spacing: 11830.000 12530.000 0.500 NUMBER OF CURVES: 21 DEPTH CAL CHT CNC GR PE RFOC RILD RILM SFT2 SSD SSN TTEN ZCOR ZDEN HRD1 HRD2 LSN SHR SP SPD FILE:PASS 3.002 FILE INTERVAL: START= 12530.000 END= 11830.000 DEPT 12530.000 12505. 000 12480.000 12455.000 12430.000 12405.000 12380.000 12355.000 12330.000 12305.000 CAL CHT ZCOR -999.250 -999.250 -999.250 6.000 1206.517 -0.250 6.900 1189.492 0.204 7.003 1061.925 0.188 6.806 912.259 0.232 7.166 1026.918 0.203 7.106 963.624 0.176 7.313 990.218 0. 190 7.209 1096.199 0. 183 7.209 1247. 113 0.138 SP HRD1 ZDEN -999.250 -999.250 -999.250 41.159 0.000 2.000 66.905 2826.555 2.227 63.284 3114.997 2.171 47.473 3144.690 2.214 18.040 2831.484 2.230 -35.284 3100.980 2.166 -15.735 3315.669 2.145 -10.932 2749.432 2.233 -26.678 2145.975 2.291 GR HRD2 CNC -999.250 -999.250 -999.250 0.000 0.000 0.000 0.000 3512.684 0.000 114.472 3785.672 38.285 128.408 3792.359 33.394 89.775 3469.397 25.310 51.016 3711.223 29.617 83.675 4024.407 38.070 34.947 3253.552 30.218 32.936 2663.232 30.598 RFOC TTEN PE -999.250 -999.250 -999.250 4.933 7132.871 0.000 7.689 7157.797 2.556 5.187 6870.117 2.162 8.081 6588.926 2.361 13.828 6793.754 2.538 16.972 6621.602 2.493 14. 975 6783.027 2.075 37.156 6874.656 3.113 35.847 7152.988 2.883 RILM SFT2 -999.250 -999.250 4.716 0.000 8. 142 2427.177 5.162 2669.104 6.502 2690.405 12.648 2443.026 16.184 2689.198 14.749 2868.284 21.040 2293.862 22.995 1764.212 RILD SSN -999.250 -999.250 0.200 0.000 8.060 0.000 5.169 171.512 6.891 173.521 14.706 182.331 20.344 183.267 14.938 176.089 31.066 202.788 36.255 172.251 SPD LSN -999.250 -999.250 28.997 0.000 28.997 0.000 28.997 70.395 28.997 77.079 28.997 95.653 28.997 87.430 28.997 72.506 28.997 95.584 28.997 80.585 · 12280.000 115 7.758 4.725 116.042 8.730 2.388 2085.306 2560.773 6905.930 0.157 2.326 29.238 2.726 7.226 8.513 28.997 1729.641 177.855 85.510 12255.000 132 6.899 6.861 0.201 -30.406 47.132 3450.673 4117.133 2.142 27.642 18.654 7132.301 2.502 16.688 15.897 28.997 2885.859 184.058 91.548 12230.000 7.458 1252.998 0.169 -15.581 103.800 3500.492 4346.492 2.092 37.922 12.895 17.280 13.203 28.997 7057.441 3069.416 160.754 66.338 2.435 12205.000 7.106 1267.650 0.204 35.730 172.200 7.551 4940.355 6447.516 7096.797 1.949 54.297 2.796 6.618 6.871 28.997 4317.434 131.827 44.640 12180.000 7 1235 0 .106 .785 ·208 45.782 217.159 4989.855 6399.344 1.953 54.694 7 6924 2 .251 · 086 .707 6.019 6.372 28.997 4192.672 133.400 45.004 12155.000 7 1294 0 .218 .409 .206 53.466 216.335 4391.020 5759.473 2.008 51.682 4 7064 3 .789 .051 .033 3.840 3.733 28.997 3667.841 133.250 46.294 D. S. 9-43 DEPT CAL SP GR RFOC CHT HRD1 HRD2 TTEN ZCOR ZDEN CNC PE RILM RILD SPD SFT2 SSN LSN 12130.000 7.408 113.098 190.029 4 1193.137 4971.750 6350.539 6836 0.208 1.956 43.434 2 .223 .918 .707 3.481 3.449 28.997 4277.301 128.681 49.153 12105.000 7.384 64.202 224.918 6 1205.341 6683.949 8963.066 6786 0.160 1.749 44.444 3 .728 .293 .110 5.258 5.258 28.997 5634.578 128.266 48.365 12080.000 7.338 15.972 243.889 1195.495 4857.922 6528.516 0.200 1.946 45.855 8 6761 3 .066 .895 .361 5.626 5.877 28.997 4109. 176 132. 294 49. 025 12055.000 124 7.391 11.894 223.197 10 3.513 4915.684 6339.113 6837 0.179 1.931 51.346 3 .439 .332 .118 8.081 8.441 28.997 4121. 645 127. 281 44. 373 12030. 000 128 7.416 47.983 156.657 10 2.'742 3738.998 4668.277 6849 0.182 2.073 33.791 2 · 144 .578 .845 10.235 10.142 28.997 3144.259 171.304 75.568 12005.000 7.519 63.345 231.651 4 1273.543 4876.992 6379.277 6836 0.207 1.959 52.879 3 .787 .980 · 177 4.474 4.696 28.997 4000.992 126.784 43.523 11980.000 7.623 48.798 303.454 4 1366.866 4786.129 6180.168 7009 0.191 1.955 49.753 3 .891 .602 .105 4.104 4.335 29.997 3939. 099 122. 580 43. 455 11955.000 7.929 14.742 195.318 5.347 4.818 4.878 29.997 1416.751 3631. 0.201 2. 11930.000 802 4508.488 7050.371 108 43.734 2.990 11905.000 7.905 37.667 223.302 1297. 568 4690. 551 6069. 012 0.200 1.974 44.841 11880.000 8.472 46.896 138.032 1257.829 3674.110 4819.301 0.203 2.089 49.462 11855.000 10.733 -80.000 136.107 500.000 2518.082 3159.680 0.267 2.343 40.901 11830.000 6.000 -80.000 99.639 500.000 0.000 0.000 -0.250 2.000 31.700 11830.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 End of execution: Tue 2 Elapsed execution time = 1 SYSTEM RETURN CODE = 0 8 AUG 90 2:52pm 4.72 seconds. 4.878 6802.676 3.072 8.152 6653.094 3.173 0.200 5000.000 3.396 0.200 5000.000 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3058.488 4.066 3936.928 4.326 3111.677 0.200 2045.957 0.200 0.000 -999.250 -999.250 -999.250 -999.250 131.970 4.044 125.081 4.563 128.631 0.200 144.263 0.200 172. 147 -999.250 -999.250 -999.250 -999.250 50.214 29.997 46.931 29.997 45.743 0.000 57.027 0.000 78.856 -999.250 -999.250 -999.250 -999.250