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Home My WebLink About196-023s-'-~s~EC~EIOI~~ STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMIS MAY ~ ~ ~~~g REPORT OF SUNDRY WELL OPERATIONS;giaska Oil ~ Gas Cnns. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ^Inchoraq~ _ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development i~ Exploratory i~ 196-0230 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20255-02-00 7. KB Elevation (ft): 9. Well Name and Number: 58 KB PBU 05-15B 8. Property Designation: 10. Field/Pool(s): ADLO-028326 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12550 feet Plugs (measured) None true vertical 8823.96 feet Junk (measured) None Effective Depth measured 12438 feet true vertical 8815 feet Casing Length Size MD TVD Burst Collapse Conductor 113 20" Surface - 113 Surface - 113 1530 520 Surface 2695 13-3/8" 72# I-80 Surface - 2695 Surface - 2695 4930 2670 Intermediate 8687 9-5/8" 47# s-95 Surface - 8687 Surface - 7818 6870 4760 Liner 2640 7" 29# L-80 8443 - 11083 7613 - 8800 8160 7020 Liner 2531 2-7/8" 6.5# L-80 9969 - 12500 8713 - 8819 10570 11160 Scab Liner 1255 7-5/8" 29# L-80 7194 - 8449 6579 - 7618 6890 4790 Scab Liner 4249 7" 29# L-80 2957 - 7206 2957 - 6589 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 9648' 4-1 /2" 12.6# NT80S NSCT 9654' - 10409' Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 PKR 9542' 9-5/8"X 7" BKR S-3 PKR 9679' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ?~~~~ qq ~~ „, ((~'~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 459 23739 116 1848 Subsequent to operation: 362 18805 93 1937 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas i WAG ~ GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 5/12/2009 - ; , .~ ~ MAY ~ ~ 2DD~ ~s~~1.~---~ r~~/~ 05-15B 196-023 PFRF OTTOC:HMFNT L~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 05-15B 3/30/96 PER 11,570. 11,730. 8,807.75 8,811.59 05-158 3/30/96 PER 11,790. 11,880. 8,813.3 8,815.18 05-15B 3/30/96 PER 12,000. 12,200. 8,813.26 8,809.31 05-15B 4/23/09 APF 11,340. 11,360. 8,806.21 8,806.32 05-15B 4/23/09 APF 11,360. e,/ 11,380. 8,806.32 8,806.03 05-15B 4/23/09 APF 11,320. f 11,340. 8,805.59 8,806.21 05-15B 4/24/09 APF 11,300. 11,320. 8,804.59 8,805.59 05-15B 4/25/09 APF 11,280. 11,300. 8,803.71 8,804.59 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 05-15B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/21/2009,CTU #6, Add Pert; MIRU CTU. Cont' on WSR 4/22/09 ... 4/22/2009 CTU #6, Add Perf; Cont' from WSR 4/21/09 ... Com lete RU CTU. Shut well in. Load well with 100 bbls of 1 % KCL w SafeLube. op well with 30 bbls of 50:50 methanol for freeze protect. RIH with SLB memory GR/CCL in 2.2" carrier. Logged up from 11,500' to 11.100' ~ctmd. Pipe flapped at 11350' ctmd. POOH with SLB logging tool. On 'surface recovered good data. Shutdown for BP Leadership Meeting. Corrected depth + 19' (Log referenced to Sperry-Sun MWD Natural GR Log, July 15, 1996). MU Gun #1. Cont' on WSR 4/23/09 ... 4/22/2009``Assist CTU (Add Perf) Pumped 5 bbls meth, 59 bbls crude to freeze j protect flowline. _ -- 4/23/2009 CTU #6, Add Perf; Cont' from WSR 4/22/09 ... RIH with Gun #1, S~ LB 20' - 2.0" PJ2006 HMX @ 6 spf. Perforate interval 11360' to 11380'. POOH. At surface confirm all shots fired and recover ball. MU and RIH Gun #2 (20' SLB 2.0" PJ @ 6 sp orrect to top shot at flag. Perforate interval 11340' to 11360'. POOH. At surface confirm all shots fired and recovered ball. MU and RIH Gun #3 (20' SLB 2.0" PJ @ 6 spf). Correct to top shot at flag. Perforate interval .11320' to 11340'. POOH. At surface. Cont' on WSR 4/24/09 ... 4/24/2009: CTU #6, Add Perf; Cont' from WSR 4/23!09 ... Lay down Gun #3. All shots fired. Recovered ball. Cut off 200' of pipe. Change pack- o s. nspec chains. MU new MHA. MU and RIH with SLB memory GR/CCL. Lo ed from 11,500' to 11,100'. Flagged pipe at 11300' ctmd. POOH. At surface recovered good Data. Corrected depth + !22' (Log referenced to Sperry-Sun M atural GR Log, July 15, 1996). MU and RIH with Gun #4 (20' SLB 2.0" PJ @ 6 spf). Correct to top shot at flag. Perforate interval 11300' to 11320'. POOH. Lay down Gun #4. All shots fired. Recovered ball. MU and RIH with (Gun #5 (20' SLB 2.0" PJ @ 6 spf). Cont' on WSR 4/25/09 ... SLB 2.0 PJ @ 6 spf). Correct to top shot at flag. Perforate interval 11280' to 11300'. POOH. Cap well with diesel. At surface. All shots fired. Ball recovered. RD CTU. Contact DSO to make 9 arrangements to put well on production. **" Job Complete *"" ~~ 4/25/2009CTU #6,~Add Perf; Cont' from WSR 4/24/09 ... RIH with Gun #5 (20' FLUIDS PUMPED BBLS 100 KCL W/SAFELUBE 224 50/50 METH 113 DIESEL 437 Totai o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): . STATE OF ALASKA . ~ RECEIVED ALA~OILANDGASCONSERVATIONCOM SION AUG 1 6 2007 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission Anchorage o Re-Enter Suspended Well o Other rg Repair Well rg Pull Tubing o Operation Shutdown o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver 1. Operations Performed: o Abandon o Perforate o Time Extension 4. Well Class Before Work: rg Development' 0 Exploratory o Service 0 Stratigraphic 5. Permit To Drill Number: 196-023 / 6. API Number: 50-029-20255-02-00 - 99519-6612 58' 9. Well Name and Number: P8U 05-158 ' ADL 028326 - 10. Field / Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Property Designation: 11. Present well condition summary Total depth: measured 12550 ( feet true vertical 8824 feet Plugs (measured) None Effective depth: measured 12438 feet Junk (measured) None true vertical 8815 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' 1530 520 Surface 2695' 13-3/8" 2695' 2695' 4930 2670 Intermediate 8687' 9-518" 8687' 7818' 6870 4760 Production Liner 2640' 7" 8443' - 11083' 7613' - 8800' 8160 7020 Liner 2531' 2-7/8" 9969' - 12500' 8713' - 8819' 10570 11160 Scab Liner 1255' 7-5/8" 7194' - 8449' 6579' - 7618' 6890 4790 Scab Liner 4249' 7" 2957' - 7206' 2957' - 6589' 7240 5410 Perforation Depth MD (ft): 11570' - 12200' Perforation Depth TVD (ft): 8808' - 8809' Tubing Size (size, grade, and measured depth): 4-112", 12.6# 13Cr80 I L-80 10409' 7" x 4-1/2" Baker 'S-3' Perm packer; Packers and SSSV (type and measured depth): 7" Baker 'SABL-3' packer 9542' 9679' 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED AUG 2 1 2007 Treatment description including volumes used and final pressure: Cut and pull tubing from -9650'. Run 7" Scab Liner (7",26#, L-80). Cement wI 133 Bbls Class 'G' (747 cu ft 1644 sx). Run new Chrome tubin to 9658'. Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o ExploratQry rg Development 0 Service rg Daily Report of Well Operations 16. Well Status after proposed wOrk: rg Well Schematic Diagram rg 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 Frank Roach, 564-4373 307-223 Printed Name T,errie Hubble Signature Æ Form 10-404 Revised 04/2006 Title Technical Assistant Phone 564-4628 Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only RBDMS 8FL AUG 2 1 2007 Digital Wellfile . Page 1 of 1 . Well: 05-15 Well Events for SurfaceWell - 05-15 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FSl -> 05 -> 05-15 Date Range: 25/Jun/2007 to 11/Ju1/2007 Data Source(s): AWGRS Events Source Well AWGRS 05-15B 6WGRS 05-15B 8WGgS 05-15B AWGRS 05-15B Date 07/11/2007 07/11/2007 07/10/2007 07/08/2007 A WGRS 05-15B 07/08/2007 8WGRS 05-15B 07/04/2007 AWGRS 05-15B 07/04/2007 AWGRS 05-15B 07/03/2007 AWGRS 05-15B 07/03/2007 AWGRS 05-15B 07/02/2007 AWGRS 05-15B 06/27/2007 AWGRS 05-15B 06/26/2007 A W GB.5 05-15B 06/25/2007 Description PULLED BPV , BOP TEST Cost Placeholder for Pre Rig Well house prep. Cutting of floor for removal, rig prep PULLED BPV, RIG MOVED ON THE WELL T/I/O = 300/350/500. [RWO Prep] CIRC OUT WELL BORE. Pumped 5 bbls neat, 905 bbls 9.8# brine, and 20 bbls diesel down TBG taking IA returns to the flowline. U-Tubed for 30 min. Freeze protected the flowline with 5 bbls neat and 55 bbls diesel. MIT-OA to 2000 psi. *PASSED* on the second attempt. Lost 80 psi / 1st 15 min & 30 psi / 2nd 15 min. Pumped 0.8 bbls of 60* crude to achieve test pressure. Final WHP= 0/0/0. SET 5" FMC BPV THRU TREE PRE RIG WORK API VALVE SHOP T/I/0=320/220/580 Assist Slickline (RWO Prep) Pumped 6.6 bbls crude down TBG to help SLB Lockout SSSV. FWP= 5/1/220/620 ***CONT FROM 7/3/07***(pre rwo) LOCK OUT 4.5" CAMCO TRDP-4A SSSV RAN FLAPPER CHK AND FUNCTION TESTED TO CONFIRM LOCK OUT ***WELL LEFT 5/1, NOTIFIED DSO*** ***TRAVEL FROM L2-14 TO DS5-15*** RAN 3.84" CENT TO 2089' SLM. ***IN PROGRESS, CONT. ON 7/4/07 **** JOB CONTINUED FROM THE 2ND OF JULY ***** STRING SHOT FROM 9644 - 9656' CHC 4.5" TBG AT 9653' OAL = 28', MAX OD = 3.625', MIN ID = 3.813 FINAL T/I/O = 200/200/500 PSI ***** JOB COMPLETED ***** *** WELL SHUT-IN ON ARRIVAL INITIAL T/I/O = 300/200/500 *** PUNCH TUBING FROM 9,628'- 9,630'. *** JOB CONTINUED ON THE 3RD OF JULY **** ***CONT. WSR. FROM 6/26/07***(RWO prep) R/D S/L UNIT, TRAVEL TO CT SHOP FOR MONTHLY MAINT. ***WELL LEFT 5/1, NOTIFIED DSO*** ***IN PROGRESS, CO NT. FROM 6-25-07***(RWO prep) GOOD DATA FROM CALIPER. SET 4.5" XX TIP @ 9740' SLM (8 X 1/8" EQ PORTS) DUMP 10' SLUGGITS @ 9730' SLM.- ***CONTINUED ON WSR 06-27-07*** ***WELL 5/1 ON ARRIVAL***(RWO prep) DRIFT W/ 3.80" GAUGE RING TO 9736' SLM. (TOP OF PRONG). PULLED PRONG & PX PLUG BODY FROM 9734' SLM. DRIFT TO 9800' SLM W/ 3.625" CENT-SB. RAN PDS CALIPER AS PER PROGRAM. ***IN PROGRESS, CONT. WSR ON 6- 26-07*** http://digitalwellfile.bpweb.bp .com/W ellEvents/Home/Default.aspx 8/15/2007 . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-15 05-1 5 WORKOVER DOYON DRilLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: 7/8/2007 12:00 - 00:00 12.00 RIGD N WAIT PRE ! Rig currently on 5-11 A awaiting completion of pre-rig I i operations on 5-15B. Crews cleaning rig and servicing rig i equipment. LRS on DS5-15 circulating out well with 9.8 brine and 20 bbls of diesel freeze protect. 7/9/2007 00:00 - 20:00 20.00 RIGD N WAIT PRE Clean rig and perform general rig maintenance. DSM is removing valves from tree. Well support crews removing S-pipe and flow line from DS5-15. Two cracks were found on the Pipe Skate Stinger when it was removed for replacement of the operating cable. Welding repairs were designed completed by the rig welder at 1700-hrs. Site preparation was completed at 2000-hrs. 20:00 - 00:00 4.00 MOB N PRE Lay herculite around DS5-15. Lay matting boards out. Move MP #2 module. Move Doyon 16 off of DS5-11 down pad and spot on DS5-15 7/10/2007 00:00 - 02:00 2.00 MOB P PRE Spot Doyon 16 over DS5-15. Level and shim rig. 02:00 - 04:00 2.00 RIGU P PRE Rig up floor, spot slop tank, spot and RIU #2 Mud Pump I module. 04:00 - 06:00 2.00 KILL P DECOMP ! R/U secondary annulus valve, RIU squeeze manifold and lines in cellar. Take on 9.8 ppg brine in pits. Rig accepted at 04:00 hrs. 06:00 - 06:30 0.50 KILL P DECOMP P/U DSM Lubricator and pulllSA BPV. O-psi on tubing, lA, and OA. 06:30 - 07:00 0.50 KILL P DECOMP Pressure test surface lines to 3,500-psi. 07:00 - 09:00 2.00 KILL P DECOMP ,PJSM and Pre-Spud meeting in Doghouse with crew, Veco . Vac-truck drivers, MI Engineer, Tollpusher, and WSL to discuss short scope for RWO and well circulation. Circulate out the diesel freeze protect fluid and brine with hot (120-130-F) 9.8-ppg NaCI brine, 7-BPM at 560-psi. 09:00 - 10:00 1.00 KILL P DECOMP Monitor well and ensure well is dead with no U-tubing. 110:00 - 13:00 3.00 WHSUR P DECOMP FMC Technician P/U ISA BPV and install in hanger. Test ISA BPV from below to 1,OOO-psi. Could not get pressure over 300-psi, kept bleeding off due to the Cretaceous leak. This particular FMC BPV can only be tested from the bottom. Once the Tree is removed, a crossover will be screwed into the RH Acme threads to check the integrity of the threads. It will then be removed and the ISA Blanking plug screwed into the threads to prepare for the BOPE test. 13:00 - 15:30 2.50 WHSUR P DECOMP N/D Tree and adaptor flange. Check hanger threads, threads OK. Function LDS. 15:30 - 17:00 1.50 BOPSU DECOMP N/U BOPE, NIU flow nipple and turnbuckles. 17:00 - 17:30 0.50 BOPSU DECOMP R/U BOP test assemblies and fill BOPE. 17:30 - 22:30 5.00 BOPSU DECOMP Test BOP's, choke manifold, and floor valves to 250 psi low and 3,500 psi high. Each test was held for 5 minutes. Choke HCR valve and kill line coupling failed. Test was witnessed by Lou Grimaldi with the AOGCC. 22:30 - 00:00 1.50 BOPSU RREP DECOMP 7/11/2007 00:00 - 01 :00 1.00 BOPSU RREP DECOMP Change out Choke HCR valve and Kill line seal ring. 01 :00 - 01 :30 0.50 BOPSU DECOMP Test Kill line seal ring and Choke HCR valve to 250 13,500 psi pressure. Good test. Test witnessed by Doyon TP and BP WSL. 01 :30 - 02:00 0.50 BOPSU P DECOMP RID test equipment and blow down equipment. 02:00 - 02:30 0.50 WHSUR P DECOMP FMC wellhead tech pulled FMC blanking plug. 02:30 - 03:30 1.00 WHSUR P DECOMP RIU DSM lubricator and lubricator extension. Pull FMC type Printed: 8/2/2007 1 :40: 19 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-1 5 05-1 5 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: Description 7/11/2007 02:30 - 03:30 1.00 WHSUR P DECOMP ISA BPV. 03:30 - 04:00 0.50 PULL P DECOMP R/U landing joint, pull tubing hanger, hanger came off seat at 145,000#, string came free at 165,000#. 04:00 - 05:30 1.50 PULL P DECOMP Circulate bottoms up 10 bpm with 500 psi. Took 42-Bbls to fill hole. Puts FL appx. 600'. Calculated fluid loss rate -30-BPH. 05:30 - 07:00 1.50 PULL P DECOMP UD tubing hanger. M/U single 1/4" SS Control Line to Camco Spooler. R/U Double Stack Tongs and prepare to POH and UD tubing. Check flow in annulus and see bubbles in the top of the fluid column. Circulate 70-Bbls at 3-4BPM. Stop, observe a few, small bubbles in fluid as the level drops. Break off circulating line, open TIW valve and fluid spills over top, but quickly stops and fluid level continues to drop. Decide to use double pipe displacement plus 30-BPH while POH with 4-1/2" tubing. 07:00 - 16:30 9.50 PULL P DECOMP POH and UD 4-1/2" tubing. There appears to be a tight spot that each collar drags through. The drag disappeared after 24-joints were POH. Joint #31 @ 0835-hours. Recovered 239 joints of 4 1/2" tubing, 4 GLM's, SWS Nipple, 20.08' cut joint of 4 1/2" tbg, SSSV and 46 Stainlees Steel Bands. Old talley indicated 54 stainless steel bands were ran. From about Jt #200 - 239 Scale was noticed on the outside of the tubing. Also, there were cracks and holes noticed in quite a few on pin ends of the tubing pulled. 16:30 - 17:30 1.00 PULL P DECOMP RID tubing handling equipment, Clear and clean rig floor. 17:30 - 19:00 1.50 CLEAN P DECOMP M/U BHA #1, Polish Mill. Baker Polish Mill, XO, 9518" Csg Scraper, 2 x Boot Baskets, XO, Bumper Sub, Oil Jar, XO, 9 x 4 3/4" DC's. Total BHA Lenght = 320.06' 19:00 - 00:00 5.00 CLEAN P DECOMP RIH wI BHA #1, picking up 4" HT-38 DP to 4,739' 7/12/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP RIH wI BHA #1, picking up 4" HT-38 DP from 4,739' to 7,180' 01 :30 - 03:00 1.50 CLEAN P DECOMP Establish parameters, Up weight 147,000#, Down weight 125,000#, Rotating weight 138,000#, 3,000 ftIIbs of rotary torque at 40 rpm, 370 psi at 4 bpm. Tag Top of 7 5/8" liner at 7,200'. Polish from 7,200' to 7,207' with 5,000# WOM, 15 rpm with 5,000 to 8,000 ft/lbs of rotary torque, 150 psi with 2 bpm. 03:00 - 04:00 1.00 CLEAN P DECOMP Pump 20 bbl high-vis sweep around at 12 bpm with 2,380 psi pump pressure. 04:00 - 06:00 2.00 CLEAN P DECOMP POOH standing back 4" HT-38 DP. 06:00 - 07:00 1.00 CLEAN P DECOMP Stand Back 4-3/4" DC's and UD Polish Mill. Top Brass Tattle Tail on Polish Mill showed an inside ID of -7-5/8". 07:00 - 09:00 2.00 CLEAN P DECOMP M/U BHA #2 Dress Off BHA. Rotary Shoe with 2 Extensions, Top Dressing Mill for for 4-1/2" Tbg, Boot Basket, 7" Scraper, Boot Basket, 13 stands of DP, 7-5/8" Scraper, Boot Basket, Bumper Sub, Jars, and 9 4.75" DC's. Total Length = 1573.85' 09:00 - 14:00 5.00 CLEAN P DECOMP RIH wI BHA#2 on DP from Derrick to 7200'. P/U DP from Pipe Shed and continue to RIH to 9563'. 14:00 - 15:00 1.00 CLEAN P DECOMP Tag up on fill at 9563'. M/U Top Drive and Rotate and Wash Down. Wash Down 3 Joints. 15:00 - 16:00 1.00 CLEAN P DECOMP Dress off top of 4-1/2" Tubing. Found Top of Tubing Stub at -9649'. Dress off 6" of Tbg to 9650'. Rotate over Stub Multiple Times to Clean Up and Dress Off. Worked 7" Scraper down to 9636' and 7-5/8" Scraper down to 8387'. 16:00 - 18:30 2.50 CLEAN P DECOMP Circulate Around 20 bbl High Visc Sweep at 10 bbll min and 2450 psi. Large amounts of sand seen at shakers. A good Printed: 8/2/2007 1 :40:19 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-1 5 05-1 5 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: 7/12/2007 16:00 - 18:30 2.50 CLEAN P DECOMP amount of sand still coming after sweep. Circulate around another sweep at 11.0 bbl 1 min and 3200 psi. 18:30 - 21 :30 3.00 CLEAN P DECOMP POOH standing back 4" HT-38 DP from 9,650' to 1,573'. 21 :30 - 23:30 2.00 CLEAN P DECOMP Stand back 4" HT-38 DP and 4 3/4" DC's, UD Dress-Off assembly. Recovered mainly sand and scale with several small metal shavings in junk baskets. 23:30 - 00:00 0.50 CLEAN I: DECOMP Clear and clean rig floor. 7/13/2007 00:00 - 00:30 0.50 CLEAN DECOMP M/U 7 5/8" HES Champ IV packer. 00:30 - 03:30 3.00 CLEAN DECOMP RIH with Champ packer on 4" HT-38 DP to 7,150' 03:30 - 04:00 0.50 CLEAN P DECOMP Establish parameters, Up weight 140,000#, Down weight 120,000#. Set 7 5/8" HES Champ IV packer at 7,217' 04:00 - 05:00 1.00 CLEAN P DECOMP Test casing below 7,217' to 3,500 psi for 30 minutes. Good I test. 05:00 - 05:30 0.50 CLEAN P DECOMP RID test equipment and unseat 7 5/8" HES Champ IV packer. 05:30 - 08:00 2.50 CLEAN P DECOMP POOH standing back 4" HT-38 DP. 08:00 - 08:30 0.50 CLEAN P DECOMP UD 7-5/8" Champ Packer and P/U 9-5/8" RTTS. 08:30 - 09:00 0.50 CLEAN P DECOMP Rig Service. Maintenance on Pipe Skate, Roughneck, & Draworks. 09:00 - 11 :30 2.50 CLEAN P DECOMP RIH wI 9-5/8" RTTS on DP from Derrick. 11 :30 - 12:00 0.50 CLEAN P DECOMP Set RTTS at 3140'. Rig Up Pressure Test Equipment. 12:00 - 13:30 1.50 CLEAN P DECOMP Pressure Test 9-5/8" 47# Casing from 3140' to Surface at 3500 psi for 30 mins- charted. Good Test. Rig Down Pressure Test Equipment. 13:30 - 14:30 1.00 CLEAN P DECOMP Unseat RTTS and POOH. Stand Back 4" DP in Derrick. 14:30 - 15:30 1.00 CLEAN P DECOMP UD 9-5/8" RTTS and P/U 7" HES RBP. 15:30 - 19:00 3.50 CLEAN P I DECOMP RIH wI 7" RBP on 4" DP from Derrick. 19:00 - 19:30 0.50 CLEAN P DECOMP Attempt to work 7" HES RBP into 7 5/8" liner. Stacking out at 7,206'. Pick up and turn pipe and attempt to slack off. Still stacking out at 7,206'. Work multiple times with same results. Discuss options with Well Engineer. 19:30 - 22:00 2.50 CLEAN N DPRB DECOMP POOH standing back 4" HT-38 DP. 22:00 - 22:30 0.50 CLEAN N DPRB DECOMP UD 7" HES RBP. RBP was in good operating condition with no indication of where RBP was hanging up at. 22:30 - 23:00 0.50 CLEAN N DPRB DECOMP Clear and clean rig floor. Discuss options with well engineer. 23:00 - 00:00 1.00 CLEAN N DPRB DECOMP Gather BHA #3, Clean out! Polish assembly 7/14/2007 00:00 - 00:30 0.50 CLEAN N DPRB DECOMP M/U BHA #3. Bull Nose, 6-3/4" String Mill, Polish Mill, XO, 2 x Boot Baskets, XO, Bumper Sub, Oil Jar, 9 x 4.75" DC's. Total BHA lenght = 321.65' 00:30 - 02:30 2.00 CLEAN N DPRB DECOMP RIH with BHA #3 on 4" HT-38 DP. 02:30 - 03:00 0.50 CLEAN N DPRB DECOMP Establish parameters, Up weight 155,000#, Down weight 125,000#, Rotating weight 140,000#. 30 rpm with 3,000 ft!lbs of rotary torque. 4 bpm with 300 psi. Wash down ang tag up at 7,209'. Rotate Mill thru 7,200' to 7,214'. 70 rpm with 4,000- 5,000 ft!lbs of rotary torque. 03:00 - 04:30 1.50 CLEAN N DPRB DECOMP Pump 20 bbl high-Vis sweep around at 11 bpm with 1,970 psi while rotating and reciprocating pipe. 04:30 - 05:30 1.00 CLEAN N DPRB DECOMP Slip and cut drilling line. 05:30 - 07:30 2.00 CLEAN N DPRB DECOMP POOH standing back 4" HT-38 DP. 07:30 - 08:30 1.00 CLEAN N DPRB DECOMP Stand Back 4-3/4" DC's and UD Polish Mill and Sting Mill BHA. Very slight wear was noticed on the leading edge of the String Mill. Junk Baskets showed some outside wear and had sand, several small pieces of SS Control Line Bands and half dollar size piece of aluminium in it. Printed: 8/2/2007 1:40:19 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-15 05-1 5 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: 7/14/2007 08:30 - 09:00 0.50 CLEAN N DPRB I DECOMP Clean and Clear Rig Floor. 09:00 - 13:00 4.00 CLEAN N DPRB DECOMP P/U 7" HES RBP on a joint of DP. Total Length = 45.19'. RIH on DP. Able to run through 7-5/8" Liner Top at 7200' very easily. Notice one small bobble on weigth indicator at - 7217'. Took several attempts to get into 7" Liner Top at 8443'. 13:00 - 14:30 1.50 CLEAN P DECOMP Set HES 7" RBP at 8517' (top of plug). POOH w/4 Joints of DP. Dump 1200 Ibs of 20/45 sand on top of plug. 14:30 - 15:00 0.50 CLEAN P DECOMP Circulate Drill Pipe Volume at 4.0 bpm to clear sand from DP. 15:00-17:15 2.25 CLEAN P DECOMP POOH wI 4" DP and Rack Back in Derrick. 1 17:15 - 00:00 6.75 CLEAN N HMAN DECOMP After Standing Back 64 of 90 Stands. Relief Driller came down with the blocks to P/U Stand #65 and as the blocks came down \ the Drill Pipe Elevators made contact with the Stabbing Board. There was severe damage to the stabbing board. No material I I I or equipment fell to the floor and no personnel were injuried during the event. The rig floor was quickly cleared of all persons and secured. BP and Doyon HSE as well as Supervisors were notified immediately. Stand Down till r investigation completed. 7/15/2007 00:00 - 19:00 19.00 CLEAN N HMAN DECOMP Safety Stand Down until BP/Doyon Incident Investigation is complete. 19:00 - 21 :00 2.00 CLEAN N HMAN DECOMP PJSM with all parties involved. Remove damaged stabbing board. 21 :00 - 00:00 3.00 CLEAN N HMAN DECOMP Perform derrick inspection, Top Drive inspection and Replace Top Drive Link Tilt and Float Control Switches. 7/16/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP POOH standing back 4" HT-38 DP from 2,324'. UD HES 7" RBP running tool. 01 :00 - 01 :30 0.50 CLEAN P DECOMP M/U HES 75/8" FasDrill Assembly. 01 :30 - 03:30 2.00 CLEAN P DECOMP RIH with FasDrill on 4" HT-38 DP. 03:30 - 04:30 1.00 CLEAN P DECOMP Establish parameters, Up weight 144,000#, Down weight 120,000#. Wash Area from 7,220' to 7,265' at 3 bpm with 150 psi. Set HES 7 5/8" FasDrill at 7,250'. Sheared off at 40,000# overpull. Confirmed set at 7,250' by setting down 15,000# on FasDrill plug. 04:30 - 05:00 0.50 CLEAN P DECOMP Observe well, pump dry job. Blow down Top Drive. 05:00 - 07:00 2.00 CLEAN P DECOMP POOH standing back 4" HT-38 DP. 07:00 - 07:30 0.50 CLEAN P DECOMP UD Fas Drill Running Tool. 07:30 - 08:30 1.00 CASE P TIEB1 PJSM on running 7" Liner. Rig Up Casing Running Tools, and Power Tongs. Organize Shoe Track. 08:30 - 09:30 1.00 CASE P TIEB1 P/U 7-5/8" Seal Assembly wI 7" x 7-5/8" XO and Pup Joint. Found square shoulder bottom to it. UD Seal Assembly, remove bottom connection and cut 1/2 mule shoe. 09:30 - 11 :00 1.50 CASE P TIEB1 P/U and Run 7-5/8" Seal Assembly, Float Collar Assembly, 1 Joint of 7" Casing and 1 Jt of 7" Casing wI Insert Landing Collar in Pin End. All connections below the Landing Collar were Baker Locked. Check Floats. 11 :00 - 16:30 5.50 CASE P TIEB1 P/U and Run 7" 26# L-80 BTC-M Liner. Make Up each Joint to the mark wI an average M/U Torque = 8,100 ft-Ibs. Use Best Of Life 2000 Pipe Dope on all Connections. Fill Pipe wI 9.8 ppg Brine every five Jts. 104 total Jts run including the Landing Collar Jt. 16:30 - 17:00 0.50 CASE P TIEB1 M/U Baker "Flex-Lock" Liner Hanger and Baker ZXP Liner Top Packer. 17:00 - 18:00 1.00 CASE P TIEB1 Circulate Liner Volume, 163 bbls. Printed: 8/2/2007 1 :40: 19 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-15 05-1 5 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: 7/16/2007 18:00 - 20:30 2.50 CASE P TIEB1 RIH wI 7" 26# L-80 BTC-M Liner on 4" HT38 DP from Derrick. 20:30 - 21 :30 1.00 CASE P TIEB1 P/U Baker Cementing head. Establish parameters, Up weight 183,000#, Down Weight 153,000#. Slack off to NO/GO at 7,206', Pressured up to 500 psi. Pick up to 7,202' Circulate at 3 bpm with 210 psi. 21 :30 - 22:00 0.50 CEMT P TIEB1 Circulate 80 degree 9.8 Brine at 3 bpm with 210 psi. Hold Cementing PJSM with all personnel involved. 22:00 - 00:00 2.00 CEMT P TIEB1 Pressure test lines to 4,500 psi. Pump 133 bbls of 15.8 ppg Class G Cement with 2#/bbl CemNet at 5 bpm, Kick out wiper plug with 5 bbls from Schlumberger. Observed flag, indicating plug was kicked out. Displace cement with 9.8 ppg brine. Displacement Pressure Rate 25 bbl 120 2 45 bbl 250 5 65 bbl 250 5 85 bbl 260 5 105 bbl 480 5 125 bbl 740 5 145 bbl 960 5 165 bbl 1060 4.5 Slow pump to 2 bpm. Bump plug with 1,800 psi at 184 bbls of displacement. Bleed pressure off and slack off to No/Go at 7,206'. Cement in place at 23:45 hrs. 7/17/2007 00:00 - 00:30 0.50 CASE P TIEB1 Pressure up to 2,800 psi to set hanger. Slack off to 40,000# and pressure up to 4,000 psi and set liner top packer. Bleed off pressure and check floats. Floats holding. Release from liner, Pressure up to 1,000 psi and P/U till pressure decreased. Pump 40 bbl biozan sweep around at 12 bpm with 2,010 psi. Appx 2 bbls of cement back to surface. 00:30 - 01 :30 1.00 CASE P TIEB1 Break out and UD Baker cement head. 01 :30 - 02:30 1.00 CASE P TIEB1 POOH standing back 4" HT DP. 02:30 - 03:00 0.50 CASE P TIEB1 Make service breaks and UD Baker liner running tool. 03:00 - 04:00 1.00 CASE P TIEB1 Flush out Kill and Choke lines, pull wear bushing and make up stack washing tool. Flush out BOP stack. Install wear bushing 04:00 - 05:00 1.00 DRILL P TIEB1 Gather and M/U BHA #4. 6 1/8" Bit clean out assembly. 6 1/8" Bit, 2 x Boot Baskets, XO, Bumper Sub, Oil Jar, XO, 9 x 4 3/4" DC's. Total BHA Lenght = 307.59' 05:00 - 05:30 0.50 DRILL P TIEB1 RIH with 4" HT-38 DP to 970' 05:30 - 06:00 0.50 DHB P TIEB1 M/U HES Storm packer and set one stand below rig floor. 06:00 - 09:30 3.50 WHSUR P TIEB1 PU Packoff pulling tool. Engage and pull packoffs. 30 K overpull to remove. ND BOPE, ND Tubing Spool. 09:30 - 13:30 4.00 WHSUR P TIEB1 Install new packoff and new tubing spool (VR plug installed on one side for annulus valves). Tested new packoffs and tubing spool to 5000 psi and charted for 30 minutes. 13:30 - 15:30 2.00 WHSUR P TIEB1 NU BOPE. 15:30 - 16:00 0.50 WHSUR P TIEB1 PJSM, RIU to Test BOPE. 16:00 - 20:00 4.00 WHSUR P TIEB1 Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BPWSL. Test #1- 3.5"x6" VBRs on 4" Test Joint, Upper IBOP Test #2 Annular Preventer, Lower IBOP, Kill HCR, Choke Printed: 8/2/2007 1 :40: 19 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-15 05-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: RID BOP Test Equipment, Pull Test Plug, Install Wear ring. P/U 1 std drill pipe and retieve RTTS Storm Valve, Release , RTTS and pull to rig floor lay down same. I RIH f/970' to 6,285', to clean out liner and drill out shoe track. Contiune to RIH f/6,285' tagged soft cement at 6,905', Rack back one stand. Pressure Test Casing to 3,500 psi for 30 charted minutes, RID test equipment. Obtain Parameters: up weight=150,000#, down weight=120,OOO#, rotating weight=132,OOO#, wob=5-10,OOO#,60 rpm, 4,000 ft-Ibs free torque, 7 bpm with ! 890 psi. Continue to drill cement fl 6,905 to 7,113', Tagged I wiper plug at 7,113'. CLEAN Drill wiper plug and landing collar w/5,OOO# to 15,000# wob, 60 - 100 rpm and 7 bpm w/880 psi. CLEAN Drill shoe track and cement to top of Fas-Dril @ 7250'. Drill top l' of Fas-Dril @ 60 rpm, 5-10K #'s wob, 7 bpm, 880 psi. Push Fas-Dril to top of T' 29 # liner @ 8450'. Drill another -2' with same parameters. Push Fas-Dril into liner to top of sand @ 8493'. Pump 20 Bbls Vis sweep. Get sweep around BHA, I reduce pump rate and "drill" plug to 8501 '. Top of RBP @ 8517'. POOH to 8400', pump another 20 bbl Vis sweep and swap well to SeaWater @11 BPM, 2760 psi. 8.4 #/gal SW in-out. Monitor well, pump 15 bbl "dry job" and POOH standing back DP in Derrick, keeping hole full. Break out 6 1/8" drilling BHA. Recovered 2 cups of FasDril composite shards, and slip buttons from plug. PUMU 6" OD x 4" ID mill shoe on RCJB, 2 ea boot baskets, bumper sub, jars, and DC's. OAL- 315.65, CLEAN RIH wI RCJB BHA to clean FasDril from top of sand 17" RBP@ 8476' CLEAN M/U Top Drive and RIH and Tag at 8,479'. Operational Parameter: up weight=182,000#, down weight=135,OOO#, Rotating weight=155,OOO#, 9 bpm with 3,040 psi, 50 rpm, 6.5 ft-Ibs torque. Wash and Ream to 8,505' 1-5,000# wob, 2.5 bpm and 280 psi to 8 bpm and 2230 psi, 50 rpm and 7-10,000 ft-Ibs torque. 20:00 - 21 :00 I 1.00 WHSUR P TIEB1 21 :00 - 22:00 ' 1.00 WHSUR P TIEB1 22:00 - 00:00 2.00 CLEAN P CLEAN 7/18/2007 00:00 - 00:30 0.50 CLEAN P CLEAN 00:30 - 01 :30 1.00 CLEAN P CLEAN 01 :30 - 03:30 2.00 CLEAN P CLEAN 03:30 - 06:00 2.50 CLEAN P 06:00 - 09:30 3.50 CLEAN P 09:30 - 11 :00 1.50 CLEAN P CLEAN 11 :00 - 14:00 3.00 CLEAN P CLEAN 14:00 - 15:00 1.00 CLEAN P CLEAN 15:00 - 18:30 3.50 CLEAN P 18:30 - 21 :00 2.50 CLEAN P Valves 1,12,13,14 Test #3- Manual Kill, Blinds Rams, Choke Valves 9, 11 Test #4- Choke Valves 5,8, 10, TIW Valve Test #5- Choke Valves 4,6,7, Dart Valve Test #6- Choke Valve 3. Test #7- Choke Valves 1, 2. Test #8-Choke HCR Test #9- Manual Choke Test #10- 3.5"x 6"VBRs on 4.5" Test Joint Accumulater Test- 3,000 psi Starting Pressure, 1,950 psi After Actuation, First 200 psi in 15 seconds, Full Pressure in 1 Minute 15 Seconds. 5 Nitrogen Bottles at 2,250 psi. Printed: 8/2/2007 1:40:19 PM . . Legal Well Name: 05-1 5 Common Well Name: 05-1 5 Spud Date: 7/27/1977 Event Name: WORKOVER Start: 7/7/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: 7/18/2007 CLEAN I CLEAN POOH from 8,476' to 1,835' 21 :00 - 00:00 3.00 I~ 7/19/2007 00:00 - 00:30 0.50 CLEAN CLEAN Continue to POOH f/1835' to 317', Stand back Drill Collars. 00:30 - 01 :00 0.50 CLEAN P CLEAN Clean Junk Baskets, Recovered Several Pieces of Composite slip and Rubber element. Did not recover Bull Nose. 01 :00 - 01 :30 0.50 CLEAN P CLEAN M/U RCJB #2 (Junk Basket with fingers 6" from bottom shoe), 2 boot baskets, bumper sub, jars, and DC's. RIH on 4" DP from Derrick. 01 :30 - 04:30 3.00 CLEAN P CLEAN RIH to 8,477'. 04:30 - 05:30 1.00 CLEAN P CLEAN Slip and Cut Drilling line. 05:30 - 06:00 0.50 CLEAN P CLEAN Washed Down with Reverse Circulating Basket to 8515'. (Top of RBP @ 8517'). Reduce pump rate to 1/2 BPM, no rotation, and no wob. 06:00 - 09:00 3.00 CLEAN P CLEAN Pump dry job and POOH, standing back DP in Derrick. 09:00 - 10:00 1.00 CLEAN P CLEAN Break out RCJB. No FasDril parts recovered. Break out boot baskets and recover -1 gal sand. Reconfigure RCJB to place fingers 3.2" inside wash pipe. MU boot baskets, bumper sub, jars, DC's. 10:00 - 13:30 3.50 CLEAN P CLEAN RIH wI RCJB run #3. 13:30 - 14:00 0.50 CLEAN P CLEAN RIH to 8479' MD. Establish fishing parameters of 130K PUW, 181K SOW, 3.8 BPM, 2700 psi. RIH to 8517', top of RBP, take 2K wob, work RCJB over RBP fish neck. Short trip working pump rate and wob to 10K on RBP @ 8519'. 14:00 - 17:00 3.00 CLEAN P CLEAN I Pomp 10 bbl dO' job aod POOH. 17:00 - 18:00 1.00 CLEAN P CLEAN BOLD RCJB BHA #3. Recover -1 gal of sand and no remnants of FasDril plug. PUMU HES retrieval head wI xo. OAL-3.21 ' 18:00 - 21 :00 3.00 CLEAN P CLEAN RIH to retrieve HES RBP at 8,450'. 21 :00 - 21 :30 0.50 CLEAN P CLEAN M/U TID and RIH and latch and release RBP @ 8,517', upweight=174,OOO#, down weight=127,OOO#, 5 bpm with 440 psi. 21 :30 - 23:00 1.50 CLEAN P CLEAN Pump 20 bbl Hi-Vis Sweep at 8 bpm and 1,180 psi, Pump Dry Job. 23:00 - 00:00 1.00 CLEAN P CLEAN POOH from 8,450' to 7,119'. 7/20/2007 00:00 - 01 :30 1.50 CLEAN P CLEAN Continue to POOH f/7 ,119'. 01 :30 - 02:00 0.50 CLEAN P CLEAN BIO and UD RBP and Running tool. 02:00 - 03:00 1.00 CLEAN P CLEAN M/U Washover Assembly, BHA Consist of: Shoe, Wash Over Extensions, Wash Over Junk Basket, Double Pin Sub, 2-Junk Baskets, 7" Csg Scraper, Bit Sub, Bumper Jar, Oil Jar, XO, 9-Drill Collars, BHA Length = 330.86' 03:00 - 06:30 3.50 CLEAN P CLEAN RIH with Wash Over Assembly. 06:30 - 07:00 0.50 CLEAN P CLEAN MU top drive and reciprocate 7" casing scraper 20' above and below packer setting depth of 9543', pumping 10 BPM, 2600 psi. 07:00 - 09:30 2.50 CLEAN P CLEAN PU DP and establish fishing parameters: 197K PUW I 140K SOW. Tag fill on 41/2" tubing stub @ 9649', jet @ 5 BPM, 570 psi, rotate @ 40 rpm, dress off top of stub. Clean stub and no go with 13.5' of swallow with wash pipe. PU 2', pump Vis sweep @ 10 BPM, 2600 psi I surface to surface. 09:30 - 13:00 3.50 CLEAN P CLEAN Pump 15 bbl dry job, POOH wI dress off BHA. 13:00 - 15:30 2.50 CLEAN P CLEAN BOLD 5 3/4" OD shoelwashpipe BHA. Recoverd 2 cups of scale and cement. PUMU 3 5/8" RCJB wi shear pin guide assy., on 4 jts of 2 7/8" PAC DP, bumper sub, oil jar, pump out sub, 9-4 3/4" DC's. Printed: 8/2/2007 1 :40: 19 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-1 5 05-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: 7/20/2007 15:30 - 19:30 4.00 CLEAN P CLEAN RIH w/3 5/8" RCJB- BHA. 19:30 - 20:00 0.50 CLEAN P CLEAN M/U Top Drive on std 98 and obtain parameters, Up Weight=205,OOO#, down weight=140,OOO#, rotating weight=170,000, 20 rpm, 6,000 ft-Ibs washed down from 9,649' to 9,733' at 5 bpm with 1,850 psi. 20:00 - 21 :00 1.00 CLEAN P CLEAN Pump 20 bbl Hi-Vis sweep Circ well bore clean. R/U stabbing board. 21 :00 - 00:00 3.00 CLEAN P CLEAN R/U and install stabbing board in derrick. 7/21/2007 00:00 - 03:00 3.00 CLEAN P CLEAN Continue to R/U and Install Stabbing Board, and circulating at 4 bpm with800 psi. 03:00 - 03:30 0.50 CLEAN P CLEAN Continue to wash down from 9,733' to 9,742' @ 8 bpm with 2600 psi. Unable to wash past 9,742'. 03:30 - 05:00 1.50 CLEAN P CLEAN Pump 20 bbl Hi-Vis Sweep @ 8 bpm with2600 psi. 05:00 - 05:30 0.50 CLEAN P CLEAN Monitor well pump 15 bbl dry job BID T/D. 05:30 - 13:00 7.50 CLEAN P CLEAN POOH UD drill pipe. 13:00 - 15:00 2.00 CLEAN P CLEAN BPLD DC's, 27/8" PAC DP, 35/8" RCJB BHA 15:00 - 15:30 0.50 CLEAN P CLEAN Service Top Drive and Draworks. 15:30 - 17:30 2.00 RUNCO RUNCMP C & C rig floor. Remove stabbing board platform for modifications. RU floor wI Doyon Csg to weight compensate and torque turn completion equipment. 17:30 - 19:00 1.50 RUNCMP Install stabbing board platform and test same. 19:00 - 00:00 5.00 RUNCMP PJSM P/U and M/U Completion BHA components. Unique Overshot, 1jt 4.5",12.6#, 13cr-80, Yam Top Tubing, 1-X nipple, Baker 7"x 4.5" S-3 Packer, 1-X nipple, 2 jts 4.5", 12.6#, 13cr-80, Yam Top Tubing, 1- 4.5"x 1", 9cr, KBG2-1 Dummy Valve. 7/22/2007 00:00 - 08:00 RUNCMP Continue to Run 4.5",12.6#, 13CR-80, Yam Top Completion, average M/UTorque 4,440 ft-Ibs using Jet Lube Seal Gaurd thread compound and Torque Turning all Connections. 08:00 - 08:30 RUNCMP RU circ lines to jt # 224, RIH and tag tubing stub @ 9649'. Shear pin wI 15K. No-go @ 9660'. Short trip off of stub and pump @ 1 bpm, 40 psi and repeat. No-go @ same depth wI increase in pump pressure to 120 psi. 08:30 - 10:00 1.50 RUNCMP Laydown jts #224-223, PUMU space out jts 3.84'/9.90/19.47' and tubing hanger on landing jt. 10:00 - 11 :00 1.00 RNTBH TUBHGR RIH and land tubing hanger. RILDS. Overshot spaced out with 2.41' off of no-go. 11 :00 - 13:30 2.50 RNTBH TUBHGR RU and reverse circulate 140 deg F SW, 150 bbls neat, followed by 290 bbls with corrosion inhibitor added. 13:30 - 16:00 2.50 RNTBH TUBHGR Drop ball and rod. Set packer wI 3500 psi, test tubing and chart for 30 minutes. Remove stabbing board from Derrick while charting 1 st test. Bleed tubing to 1500 psi. Pressure IA to 3500 psi and test packer and annulus, chart for 30 minutes. Bleed tubing to 900 psi, shear DCR valve, equalize tubing and IA. Bleed to 0 psi. Circulate both ways thru DCR vlv. Dry rod TWC and test to 1000 psi for 5 minutes and chart. 16:00 - 17:00 1.00 WHSUR P OTHCMP ND BOPE 17:00 - 21 :30 4.50 WHSUR P OTHCMP NU tubing head adaptor and 7 1/16" 5M FMC tree. Test tubing hanger packoff to 5000 psi for 15 min., Test tree to 5000 psi (with diesel) and chart for 10 minutes. 21 :30 - 22:00 0.50 WHSUR P OTHCMP RIU DSM lubricator, Pull TWC. 22:00 - 23:00 1.00 WHSUR P OTHCMP Pump 150 bbls of Diesel Freeze Protection at 4 bpm with 1,800 psi Printed: 8/2/2007 1 :40:19 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-15 05-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/7/2007 Rig Release: Rig Number: Spud Date: 7/27/1977 End: 7/22/2007 7/23/2007 23:00 - 00:00 00:00 - 01 :30 1.00 WHSUR P 1.50 WHSUR P OTHCMP Allow Diesel to U-Tube. OTHCMP SID Circulating Lines in Cellar, Set SPV and Test to 1,000 psi from below. OTHCMP RID Circulating Lines, RID Double Annulus Valve, Install Gauges and secure well. Rig Release 02:30,7/23/2007 01 :30 - 02:30 1.00 WHSUR P Printed: 8/2/2007 1 :40: 19 PM . TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = FMC GEN 1 FMC AXELSON 58 . 05-158 L SA. NOTES: 70° @ 9971' & 90° @ 10284' 2092' -1L1í2" HES X NiP, 10'" 3.813" 1 GAS LIFT MANDRELS ST MD TVD DEV 1YÆ VLV LA TCH PORT DATE 5 2909 2909 3 KGB2 DCK BEK 07/22/07 4 4990 4750 34 KGB2 OMY BK 0 07/22/07 3 6608 6100 34 KGB2 DMY BK 0 07/22/07 2 8020 7258 33 KGB2 DMY BK 0 07í22/07 1 9391 8406 42 KGB2 OMY BK 0 07/22/07 2957' 92 7-5/8" LNR, 29.7#, L-80, 113-3/8" CSG, 72#, L-80, 10 = 12347" -17 -5/8" BAKER SBP WEIGHT-SET PKR 8450' H 7" BA KER H TIEBA CK PKR I 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 9648' 9511' 9542' 9576' 9648' Minimum ID = 2.438" @ 9975' 3-1/2" X 2-7/8" XO 9622' 9679' 9750' 9970' TOPOF2-7/8" LNR- CT I 9975' 14-1/2" TBG, 12.6#, .01522, .0152 bpf, 10'" 3.958" I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6184" 10409' 10409' 11083' 4-1/2" PARKER SWS NIP, ID = 3.813" 7" BAKER SABL-3 PKR 4-1/2" PARKER SWS NIP, ID = 3.813" 4-1/2" WLEG (BEHIND PIPE) ÆRFORA TION SUMMA RY REF LOG: SÆRRY NGP ON 03/21/96 ANGLE AT TOP ÆRF: 88 @ 11570' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DA TE 2-1/8" 4 11570 - 11730 C 03/30/96 2-1/8" 4 11790 - 11880 C 03/30/96 2-1/8" 4 12000 - 12200 C 03/30/96 OATE 1977 03/31/96 02/04/02 04/03/02 06/07/02 06/12/03 12-7/8" LNR- CT, 6.5#, L-80, .0056 bpf, ID= 2.441" REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER SDTRK RN/TP CORRECTIONS TMN/KK SET ECLIPSE TBG PA TCH RLlTLH PULL ECLIPSE TBG PA TCH CMO/TLP KB ELEVATION CORRECTION DATE 08/18/03 09/23/05 REV BY COMMENTS CMO/TLP DATUM MD CORRECTION KSB/TLH PX TIP SET (06/07/02) JBM POST R\NO PJC GL V CORRECTIONS MILLED OUT OF 7" SHOE@ 11083' PRUDHOE SA Y UNIT WELL: 05-15B ÆRMIT No: 11"1960230 API No: 50-029-20255-02 SEC 32, T11 N, R15E, 4135.27' FEL & 1969.94' FNL BP Exploration (Alaska) . ~i~iŒ rnJ~ ~~~~~~ . A.I,A.~Ii.&. OIL AlO) GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 sCANNED JULO 6 2007 Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-15B ~ Sundry Number: 307-223 \ q ~~ 0 d- Dear Mr. Reem: Re: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~day of July, 2007 Encl. PTS 7/3/7 C141-,;-t>1 ~~ a ST~TE OF ALASKA I ;z.é>?O~ JUN 2 7 2007 ALA~ Oil AND GAS CONSERVATION COM SSION ~'11'} APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 25.280 Anchorage K I;::.l.11:: I V 1... U 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 196-023 , 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20255-02-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 05-15B Spacing Exception Required? DYes ~No <' 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): - ADL 028326 / 58' Prudhoe Bay Field / Prudhoe Bay Pool 12. .. \^JELL t;\)NUI ..... .. ,.....< ,«"... .> < . .... .... '. >, Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12550 r 8824 12438 8815 9750 None Casina Lenath Size MD TVD Burst CollaDse Structural Conductor 113' 20" 113' 113' 1530 520 Surface 2695' 13-3/8" 2695' 2695' 4930 2670 Intermediate 8687' 9-5/8" 8687' 7818' 6870 4760 Production Liner 1255' 7-5/8" 7194' - 8449' 6579' - 7618' 6890 4790 Liner 2640' 7" 8443' - 11083' 7613' - 8800' 8160 7020 Liner 2531' 2-7/8" 9969' - 12500' 8713' - 8819' 10570 11160 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11570' - 12200' 8808' - 8809' 4-112", 12.6# L-80 1 0409' Packers and SSSV Type: 7" Baker 'SABL-3' packer packers and SSSV MD (ft): 9679' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: July 1, 2007 ~Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 P,inted Namw~ Reem Title Engineering Team Leader Date 612 ~h-:7 Prepared By Name/Number: Signature L j{ {1 ð ¿ Phone 564-5743 Terrie Hubble, 564-4628 Commission Use Only , I Sundry Number: '7£)Î . :J:J ~ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~BOP Test D Mechanical Integrity Test D Location Clearance Other: ~saa~\ \S<:J\> ~c;.+- Subsequent Form Required: '{{Jm ¥,J.ðl 7 -(l :iu APPROVED BY Approved Bv: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 l./ '" , Su it In Duplicate \.....,./ RBDMS BFL JUL 0 5 1007 #7M7 ole ;, -- ,~ . . 05-158 Rig Workover Scope of Work: Pull L-80 completion, run 7-5/8" scab liner to -3000' to cover cretaceous leak, replace 9- 5/8" pack-off, and run 4-W' 13Cr80 completion. MASP: 2871 psi Well Type: Producer Estimated Start Date: July 01 2007 P R' re- Ig: S 1 Pull PX plug in nipple at 9750' MD. Drift tubing for caliper survey and tubing cut to 9800' MD. Caliper tubing from surface to 9800' MD. Set XX plug at 9750' MD. Dump 10' sluggits on top of plug. E 2 String shot and punch tubing string. Chemical cut 4-W' tubing @ 9653' MD (Ref 08/18/1993 tubing summary). Chem cut desired to be in the middle of the full joint between packer and upper SWS nipple. F 3 Circulate well with -9.8 ppg NaCL brine and cap with diesel thru the cut. MITOA to 2000 psi. Bleed WHPs to 0 psi. No CMIT required due to PC leak. 0 4 Set a BPV in the tubinq hanqer. 0 5 Remove the wellhouse & flow line. Level the pad as needed for the riq. Proposed Procedure 1. MIRU. NO tree. NU and test BOPE with to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean 9.8 ppg brine through the cut. 2. Pull and LD tubing string to the cut. 3. RU wireline and run USIT from cut to surface. 4. Run 7-5/8" RBP and set at -800'md below existing 7-5/8" scab liner top determined from USIT. PT RBP to 1000 psi to prove up barrier. Stack -50 ft of sand on RBP. 5. Run 7-5/8" scab liner on drill pipe to cover cretaceous leak Note: VBR's will not be changed to 7- O\t. l.orw1. 5/8" pipe rams as the well has two tested barriers (XX plug and RBP) to the reservoir, f;th .. \ 6. Cement new 7-5/8" scab liner to top of liner and set liner top packer and hanger. '\ "\-()\.. 7. Change out 9-5/8" packoff and pressure test to 3800 psi. 8. Run 4-W' 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -9543' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 11. Set BPV. ND BOPE. NU and test tree. RDMO. . . TREE : FMC GEN 1 WELLHEAD - FMC 05-158 SAFETY NOTES: 70° @ 9971' & 90° @ 10284' ACTUATOR: AXELSON KB. ELBI - 58' BF. ELBI : ? KOp: 3100' -14-1/2" CAMCO TRDP-4A SSSV NIP, 10: 3.813" I Max Angle: 92 @ 12090' 2106' Datum MD : NA . Datum TV 0 : 8800' SS ~ ~ GAS LIFT MANDR8...S 13-3/8" CSG, 72#, L-80, ID: 12.347" 1 2695' ST MD TVD OBI TYÆ VLV LATCH PORT DATE U 1 3201 3198 13 TE- TPD RA 1 TOP OF 7-5/8" LNR I 7194' 2 5792 5418 33 TE- TPD RA 3 8306 7498 33 OT-WBX BK-5 4 8412 7587 33 OT-WBX BK-5 Minimum ID = 2.438" @ 9975' 3-1/2" X 2-7/8" XO ITOPOF 7" LNR I 8443' J-- -17" BAKER H TIEBACK A<R I 17-5/8" LNR, 29.7#, L-80, .0459 bpf, 10: 6.875" I 8450' 8449' I 19-5/8" CSG, 47#, L-80, 10: 8.681" I 8687' 1----.4 I . ~ 9622' -14-1/2" PARKER SWS NIP, 10: 3.813" I I 9679' H 7" BAKER SABL-3 A<R 1 9750' -i4-1/2" PARKER SWS NIP, 10: 3.813" I ---- 9750' -i4-1/2" PX TIP (06/07/02) I ~ 9970' -14-1/2" G SEAL SUB I I TOP OF 2-7/8" LNR - CT I 9975' 9975' -13-1/2" X 2-7/8" XO,ID: 2.438"1 I I - 10397' H 4-1/2" PARKER SWN NIP, 10: 3.725" (BEHIND PIPE) I 14-1/2" TBG, 12.6#, .01522, .0152 bpf, ID: 3.958" I 10409' I 10409' 14-1/2" WLEG (BÐiIND PIPE) I MILLED OUT OF 7" SHOE @ 11083' 17" LNR, 29#, L-80, .0371 bpf, ID: 6.184" I 11083' ..II ~ ÆRFORA TION SUMMARY REF LOG: SÆRRY NGP ON 03/21/96 ANGLEATTOPÆRF: 88 @ 11570' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/8" 4 11570 - 11730 C 03/30/96 2-1/8" 4 11790 - 11880 C 03/30/96 / 2-1/8" 4 12000 - 12200 C 03/30/96 1 PBTO I 12438' 1 ~1 12-7/8" LNR - CT, 6.5#, L-80, .0056 bpf, 10: 2.441" I 12500' I I TO I 12550' DATE REV BY COMMENTS DATE RBI BY COMMENTS PRUDHOE BA Y UNrr 1977 ORIGINAL COM PLETION 08/18/03 CMOrrLP DATUM MD CORRECTION WELL: 05-15B 03/31/96 LAST WORKOVER SDTRK 09/23/05 KSBrrLH PX TIP SET (06/07/02) ÆRMrr No: r:¡ 960230 02/04/02 RN/TP CORRECTIONS API No: 50-029-20255-02 04/03/02 TMN/KK SET ECLIPSE TBG PA TCH SEC 32, T11 N, R15E, 4135.27' FEL & 1969.94' FNL 06/07/02 RUTLH PULL ECLIPSE TBG PA TCH 06/12/03 CMO/TLP KB RBI A TION CORRECTION BP Exploration (Alaska) TREE = W8..LHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= FMC GEN 1 FMC AXELSON 58' ? 3100' 92 @ 12090' NA 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I 7-5/8" LNR, 297#, L-80. .0459 bpf, ID = 6,875" TOP OF 7-5/8" LNR TOP OF 7" LNR 7-5/8" LNR. 29.7#, L-80, .0459 bpf, ID = 6.875" 19-5/8" CSG, 47#, L-80, ID = 8.681" I 14-1/2" TBG. 12,6#. 13Cr-80, ,0152 bpf, ID = 3.958" I Minimum ID = 2.438" @ 9975' 3-1/2" X 2-7/8" XO ¡TOP OF 2-7/8" LNR - CT I 9975' 14-1/2" TBG, 12.6#, .01522, .0152 bpf, ID = 3.958" I 17" LNR, 29#, L-80, .0371 bpf.ID=6.184" 1 0409' 11083' ÆRFORA TION SUMMARY REF LOG: SÆRRY NGP ON 03/21/96 ANGLEA T TOP PERF: 88 @ 11570' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-118" 4 11570 - 11730 C 03/30/96 2-1/8" 4 11790 - 11880 C 03/30/96 2-1/8" 4 12000 - 12200 C 03/30/96 DATE 1977 03/31/96 02/04/02 04/03/02 06/07/02 06/12/03 05-158 PROPOSED SAÆTYNOTES: 70° @ 9971' & 90° @ 10284' -14-1/2"HESXNIP, 10=3.813" I GAS LIFT MANDRELS ST MD VLV LATCH 1 4-112" 1" 2 4-1/2" 1" 3 4-1/2" 1" 4 4-112" 1" 9-5/8" X 7-5/8" BKR C-2 ZXP L TP w / FLEXLOCK LNR HGR, 10 = 6.290" 7216' -f7-5/8" BAKERSBPWSGHT-SETPKR I -f7" BAKER H TIEBACK PKR I 10409' 4-112" \M.EG (BEHIND PIPE) MILLED OUT OF 7" SHOE @ 11083' 12-7/8" LNR - CT, 6.5#, L-80, .0056 bpf, ID = 2.441" REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SDTRK RNITP CORRECTIONS TMNtKK SET ECLIPSE TBG PATCH RUTlH PULL ECLIPSE TBG PATCH CMOITLP KB B.EV A TION CORRECTION DATE 08/18/03 09/23/05 06/24/07 REV BY COflllMENTS CMOITLP DATUM MD CORRECTION KSBITLH PX TIP SET (06/07/02) FVR PROPOSED RWO PRUDHOE BA Y UNIT W8..L: 05-15B ÆRMIT No: '1960230 API No: 50-029-20255-02 SEC 32, T11N, R15E, 4135.27' FB. & 1969.94' FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ SET TaG PATCH Pull tubing _ Alter casing _ Repair well _ Other_X PATCH 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2029' FNL, 5217' FEL, Sec. 32, T11 N, R15E, UM At top of productive interval 3685' FNL, 110' FEL, Sec. 30, T11 N, R15E, UM At effective depth 2081' FNL, 4112' FEL, Sec. 29, T11N, R15E, UM At total depth 1972' FNL, 4135' FEL, Sec. 29, T11 N, R15E, UM 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service_ (asp's 697120, 5949414) (asp's 696840, 5953032) (asp's 698069, 5954669) (asp's 698043, 5954777) 6. Datum elevation (DF or KB feet) RKB 69 :":!;L~feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 05-15B 9. Permit number / approval number 196-023 10. APl number 50-029-20255-02 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical 12550 feet Plugs (measured) 8818 feet Effective depth: measured true vertical 12438 feet Junk (measured) 8815 feet Casing Length Conductor 113' Surface 2660' Intermediate 8652' Scab Liner 1255' Liner 2640' Sidetrack Liner 2531' Size Cemented Measured Depth True Vertical Depth 20" 284 sx PF 148' 148' 13-3/8" 5520 sx PF II 2695' 2695' 9-5/8" 750 sx Class 'G' 8687' 7818' 7-5/8" 146 sx Class 'G' 7194' - 8449' 6579' - 7618' 7" 425 sx Class 'G' 8443' - 11083' 7613' - 8800' 2-7/8" 30 bbls Latex Acid Resistance 9969' - 12500' 8713' - 8819' Perforation depth: measured Open Perfs 11570' - 11730', 11790' - 11880', 12000' - 12200' true vertical Open Perfs 8802' - 8806', 8807' - 8809', 8808' - 8804' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80, TBG @ 9679' MD; 4-1/2", 12.6#, L-80 Tubing Tail @ 10409'. Tubing Patch set @ 5785' (04-03-2002). 7" Baker H Tieback PKR @ 8450'. 7" x 4-1/2" Baker SABL-3 PKR @ 9679'. 4-1/2" Camco TRDP-4A SSSV @ 2106' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/20/2002 Subsequent to operation 04/15/2002 Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Well Shut-In Well Shut-In Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service the for~rect to the best of my knowledge. DeWayae R. Schnorr ~ Title: Technical Assistant Form 10-404 Rev 06/15/88 · Date April 16, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 01/1 o/2oo2 01/11/2002 01/30/2002 01/31/2002 01/31/2002 02/01/2002 02/09/2002 02/10/2002 03/03/2002 04/03/2002 01 / 10/O2 01/11/02 01/30/02 01/31/02 01/31/02 02/01/02 O2/O9/O2 02/10/02 O3/03/O2 0~0~02 05-15B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM ANN-COMM : DRIFT TUBING (PRE-TBG PATCH) : DRIFT TBG TO 6000' SLM W/20' X 3.8" DUMBELL(PRE TBG : TUBING TAIL PLUG : TUBING TAIL PLUG :FISH : TUBING TAIL PLUG : TUBING TAIL PLUG : TUBING TAIL PLUG : BRUSH/BROACH; DRIFT/TAG · AC-MONITOR; PATCH TUBING / CASING EVENT SUMMARY DRIFT W 20' X 3.80 DUMB BELL DRIFT TO 6020' SLM W/NO PROBLEMS. WELL RIG DOWN WIRELINE. WELL LEFT SHUT IN. PULL 4 1/2" PX PRONG. ATTEMPT TO PULL 4 1/2" PXX PLUG BODY. GOT BLOWN DOWN HOLE & HYDROSTATICALLY LOCKED AT CT LINER TOP. UNABLE TO SHEAR OFF. FLOWING WELL INTO BLEED TANK TO RELIEVE HYDROSTATIC HEAD (IN PROGRESS). PUMP 110 BBLS CRUDE DOWN FLOWLINE @ 180', PUMP 234 BBLS CRUDE DOWN TUBING TO ASSIST SLICKLINE. FREEZE PROTECT FLOWLINE. ATTEMPT TO FREE-UP TOOL STRING BY PUMPING DOWN TBG. DROP KINLEY CUTTER. POH W/WIRE (IN PROGRESS). DROPPED KINLEY CUTTER ON STUCK TOOL STRING & PX PLUG BODY. RECOVERED ALL WIRE. CUTTER, TOOL STRING & PLUG BODY LEFT IN HOLE. RDMO. LEFT WELL SHUT-IN RIH W/BELL GUIDE & PULLING TOOL TO FISH CUTTER BAR. FISHED KINLEY CUTTER FROM 9930'SLM. FISHED COMPLETE S/L TOOLSTRING & RECOVERED TT PLUG ALSO. PUMPED DOWN FLOWLINE 10 BBLS METH, 75 BBLS HOT CRUDE, 10 BBLS METH. FOR FREEZE PROTECT AND LEAVE WELL SHUT IN. 20'. BRUSH 5788' TO 5808' 1 HR ( PRE PATCH ). SET (TWO RUN) 4.5" ECLIPSE TUBING PATCH (2.245" ID, 23.5' OAL) @ 5785'. THIS IS ACROSS GLM #2. BOTTOM ELEMENT @ 5808' & UPPER ELEMENT @5788'. USED DOWNHOLE PUMP TO ASSIST IN GETTING UPPER SECTION Page I 05-15B DESCRIPTION OF WORK COMPLETED O4/O3/O2 (continued) INTO BOTTOM PACKER ASSEMBLY. NOTIFY PAD OPER OF STATUS - OK TO BOL. Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 2 TESTS) 2O METHANOL 419 CRUDE 2O DIESEL 461 TOTAL Page 2 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED · ON OR BEFORE JANUARY 03, 2001 E W PL ATE IA L U N D ER T C:LoRIXMFILM.DOC H ISM A R K E R PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 03/12/98 RUN RECVD 96-023 96-023 96-023 96-023 GR- MD GR-MD 7378 7379 ~/11084-12555 ~/11084-11459 PB1 FINAL 07/16/96 FINAL 07/16/96 1-4 08/12/96 1-2 08/12/96 96-023 96-023 TDTP/B 7185 10-407 ~L~ 10350-12250 · ~%CHLUM TDTP a "CO L T ON DATE / FINAL 10/02/96 1 12/06/96 DAILY WELL OPS ~' >/,%0/o./~/ TO ~/},:)/ '-:~;/ Are dry ditch samples required? yes ~ And received? ~ Was the well cored? yes ~Analysis & description received?~-~y~ es .... ~ Are well tests required? yes ~ Received? Well is in compliance Initial COMMENTS ~"~ I~ I.I. I i'11~--] ~ [:-] i~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10603 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 2/4/96 Field: Prudhoe Bay Floppy Well Job # Log Description Date 131_ RF Sepia Disk D.S. 4-49 RFT 961 I 1 6 I 1 D.S. 9-22 INJECTION PROFILE LOG 961 1 23 I 1 D.S. 9-35A PRODUCTION PROFILE LOG 961 1 22 I 1 D.S. 5-15B 96250 TDT-PBORAX "J:~'"/l~' 960824 I S I G N E D: (~__ '_~__~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 9/23/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10421 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter D.S. 1-12 PRODUCTION PROFILE 9 6 0 82 8 I 1 D.S. 1-30 PRODUCTION PROFILE 9 6 0 82 9 I 1 D.S. 3-9 CNTG 960821 I 1 D.S. 3-16 INJECTION PROFILE 9 6 0 83 0 I 1 D.S. 4-10 TDT (BORAX INJ.) 960830 I 1 D.S. 5-15B TDTP 960824 I 1 , , D.S. 9-25 INJECTION PROFILE 9 6 083 0 I 1 , , D.S. 13-24 INJECTION PROFILE 9 6 0 831 I 1 .... D.S. 15-28 CNTG 960822 I 1 D.S. 18-33 TDTP BORAX 96 0 826 I I I[4- o"~8 SIGNED: ~~ ..... DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 F:! I I--I--I IM G WELL LOG TRANSMITTAL To: State of Alaska August 12, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 05-15B & 05-15B PB 1 AK-MW-6003 5 .. The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Tan Galv~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2 LDWG formatted magnetic tapes with LIS listing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company r'l Ft I I_1_ I IM G S I::: F:t ~J I I-- I:: S WELL LOG TRANSMITTAL To: State of Alaska July 16, 1996 Alaska Oil and Gas Conservation Comm. Atm.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs DS 05-15B & 05-15B PB 1, AK-MW-60035 - The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 0~-.15B: 2" x 5" MD Gamma Ray Logs: 50-029-20255-02 1 Blueline 1 Folded Sepia DS 05-15B PBI: 2"x 5" MD Gamma Ray Logs: 50-029-20255-70 1 Blueline 1 Folded Sepia ,d iVED JUL 1 6 '1996 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALA~rtA OIL AND GAS CONSERVATION COMM,~,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS E~ SUSPENDED [-~ ABANDONED [-~ SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-23 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20255-02 4 Location of well at surface ........ . .......... ' .... 9 Unit or Lease Name ~ -r..."~,.~., ;'::':;'~;..i ~ ~_ L:,'!": !, 63'FWL, 3250'FSL, Sec32, T11N, R15E UM ! ~/~,_~.~ ; ~ PRUDHOE BAY UNIT AtTop Producing Interval I ~ ' 10 Well Number 1595'NSL, 110'WEL, Sec30, T11N, R15E UMi ',/;:~:;i~-~'i;;:U -: "_ ~ 5-15B At Total Depth i ./~_ ~__~_ ..... ~ 11 Field and Pool 3307' NSL, 4148' WEL, Sec 29, T11N, R15E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL 69' RKB ADL 28326 12 Date3/2Spudded1/96. 13 Date 3/27/9T'D' Reached6. 14 3/30/DDate ComP.6. ' Susp. or Aband. 15 WaterN/ADepth, if offshorefeet MSL 16 No. of Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 12550' MD / 8818' TVD 12460' MD / 8811' TVD YES [~ NO E]I 2106 feetMDI 1900'(approx) 22 Type Electric or Other Logs Run MWD. 23 CASING, LINER AND CEMENTING RECORD SE-II'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 # H-40 Surf 113' 32" 284 sx PF 13-3/8" 72# L-80 Surf 2695' 17-1/2" 5520 sx PF ,. 9-5,8" 47# L-8O Surf 8687' 12-1,4" 750 sx Class G /.41 7-5/8" 29.7# L-80 7194' 8449' 9-5/8" 146 SxClass G ! ~ I ~ I I ¥ ~ t 7" 29# L-80 8443' 11083' 8-1/2" 425 Sx Class G 2-7/8" 6.5# & 9.3# L-80 9969' 12500' 3-3/4" 30 bbls Latex Acid Resistive Cmt 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" Tbg to 10409' 9599' 11570 - 11730' MD; 8802- 8806' TVD; at 4 spf. 11790 - 11880' MD; 8807- 8809' TVD; at 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 12000 - 12220' MD'; 8808 - 8804' TVD; at 4 spf. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A I\ L ~., I- ~ ~ 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) M AY '{ ,~ ]9 9 6 4/5/96. F ow ng. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHO~F~J~ 0J~ ~8~)l~¢f~'l~0111rtlll~$t0rl: 4/6/96. 3.0 TEST PERIOD ¢ -~ Anchoral~ FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 454 24-HOUR RATE ¢ 5764 6832 150 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. *Note: 5-15B Coil Tubing Extension Drilling Operations Summary attached. * This 10-407 submitted per 10-401 approved on 2/16/96 (Permit # 96-23). Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _9. 30. GEOLOGIC MARKER FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9235' 8284' N/A Shublik 9277' 8318' Top Sadlerochit 9350' 8374' 31. LIST OF A'I-rACHMENTS Summary of 5-15B Coil Tubing Extension Drilling operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~~ ~"'~ · ~ Title Engineering Supervisor Date 5'- ? INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,~r~e~il~l~,fYJ['a~r In- jection, Gas Injection, Shut-in, Other-explain. item 28: It no cores taken, indicate "none". MAY 1 5 1996 Form 10-407 Ala[tk~1011 & GaS Cons. C0mrmssion Anch0r~e 5-15B DESCRIPTION OF WORK COMPLETED COIL TUBING DRILLED WELLBORE EXTENSION 3/20/96: MIRU CTU & PT equipment. Loaded wellbore w/Seawater, then MU & RIH w/3.8" milling BHA. Milled through the 3.725" SWN Nipple at 10397' MD. 3/21/96: RIH to tag float shoe at 11077' MD, then drilled out shoe to 11083' MD. Pumped 30 bbls Hi-Vis sweep, then circulated well over to FIo-Pro. POOH w/BHA. Performed tests to to 9.5 Emw. MU & RIH w/drilling BHA and drilled 3.75" extension wellbore to 11106' MD. POOH w/BHA. 3/22/96: MU & RIH w/drilling BHA. Drilled from 11106' to 11365' MD into Kavik shale. to 11450' MD, then decided to plugback. Drilled Kavik 3/23/96: Jetted OOH w/BHA. MU cementing nozzle & RIH to 11450' MD. Pumped 5.3 bbls of 17 ppg cement to plugback from 11450' to 11085' MD. RIH jetting contaminated cement to dress off cement plug to 11250' MD. POOH circulating FIo-Pro. WOC. 3/24/96: MU & RIH w/drilling BHA. Tagged cement at 11259' MD & circulated 30 bbls Hi-Vis sweep. Oriented & drilled a new 3.75" horizontal hole to 11500' MD w/periodic short trips to clean hole. Displaced well w/new FIo-Pro & continued drilling to 10590' MD. 3/25/96: Drilled to 12037' MD w/periodic short trips to wipe hole. POOH w/BHA. 3/26/96: MU & RIH w/drilling BHA. Drilled to 12379' MD. 3/27/96: Drilled to TD at 12550' MD. openhole & POOH w/BHA. Tripped to tubing tail to condition hole, then spotted Hi-Vis pill in 3/28/96: MU & RIH w/2-7/8" blank liner assembly. Worked liner to 12500' MD; couldn't get deeper. Disconnected from liner, then circulated & conditioned mud for cement job. Pumped 30 bbls Latex Acid Resistive Cement, followed by wiper plug, 20 bbls biozan, and mud displacement, to set the liner assembly from 9969' to 12500' MD. POOH w/liner setting tool. Left an estimated top of cement behind liner at 10059' MD, to plug & abandon the open perforation interval located at: 10770 - 11070' MD Ref. Log: CET 8/19/93. 3/29/96: RIH w/nozzle displacing well to Seawater. Tagged float collar at 12460' MD & POOH w/nozzle. PT liner to 2000 psi; lost 300 psi/30 mins. RIH w/perforating guns & shot initial perforations at: 11570 - 11730' MD 11790 - 11880' MD 12000 - 12220' MD Used 2-i/8" carriers & shot all perforations at 4 spf at zero degree phasing, rf guns. 3/30/96: MAY 1 5 199t~ RD CTU. NU & PTtree. Released CTU. AI~,~ l~it & Gas eons. Comnussion \ / SPF~--~'Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU/5-15B 500292025502 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/11 /96 DATE OF SURVEY: 032896 MWD SURVEY JOB NUMBER: AK-MW-60035 KELLY BUSHING ELEV. = 58.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11084.00 8794.34 8736.3 11095.24 8795.08 8737.0 11108.67 8795.94 8737.9 11120.62 8796.67 8738.6 11136.62 8797.41 8739.4 4 85 54 8 86 34 4 86 2 7 87 0 1 87 42 N 50.60 E .00 4135.10N 438 N 47.14 E 31.29 4142.48N 447 N 46.93 E 4.24 4151.61N 457 N 47.14 E 8.31 4159.74N 465 N 47.63 E 5.34 4170.56N 477 .90E .35E .15E .88E .64E 4139.52 4148.43 4159.34 4169.05 4182.00 11149.87 8797.74 8739.7 11161.97 8797.74 8739.7 11172.82 8797.57 8739.5 11193.77 8797.17 8739.1 11215.37 8796.94 8738.9 89 22 90 37 91 11 90 58 90 15 N 47.81 E 12.68 N 49.57 E 17.79 N 52.10 E 23.92 N 53.08 E 4.80 N 55.02 E 9.56 4179.47N 487 4187.46N 496 4194.31N 504 4207.03N 521 4219.71N 539 .44E .53E .94E .58E .06E 4192.69 4202.32 4210.72 4226.50 4242.42 11233.89 8797.10 8739.1 11250.37 8797.45 8739.4 11267.70 8797.76 8739.7 11276.02 8797.91 8739.9 11282.95 8798.11 8740.1 88 46 88 46 89 10 88 46 87 55 N 54.49 E 8.54 N 56.78 E 13.89 N 57.85 E 6.59 N 54.84 E 36.49 N 55.02 E 12.40 4230.40N 554 4239.69N 567 4249.05N 582 4253.66N 589 4257.64N 594 .18E .78E .36E .29E .96E 4255.90 4267.73 4279.81 4285.71 4290.74 11292.90 8798.54 8740.5 11300.75 8798.94 8740.9 11312.22 8799.54 8741.5 11322.55 8800.01 8742.0 11337.65 8800.47 8742.4 4 87 11 4 86 55 4 87 5 1 87 42 7 88 46 N 56.25 E 14.42 N 56.60 E 5.62 N 57.13 E 4.88 N 55.19 E 19.67 N 57.13 E 14.63 4263.25N 603 4267.59N 609 4273.85N 619 4279.59N 627 4288.00N 640 .16E .69E .28E .85E .39E 4297.87 4303.42 4311.47 4318.81 4329.55 11349.47 8800.64 8742.6 11360.92 8800.62 8742.6 11371.35 8800.47 8742.4 11390.67 8800.23 8742.2 11412.97 8800.01 8742.0 89 33 N 56.07 E 11.18 90 40 N 55.92 E 9.87 90 58 N 56.07 E 3.13 90 26 N 54.66 E 7.80 90 41 N 54.49 E 1.39 4294.50N 650 4300.91N 659 4306.74N 668 4317.72N 684 4330.64N 702 .25E .75E .39E .29E .46E 4337.89 4346.06 4353.50 4367.43 4383.72 11427.90 8799.81 8741.8 11446.32 8799.54 8741.5 11462.37 8799.39 8741.3 11480.87 8799.51 8741.5 11498.22 8799.86 8741.8 1 90 47 4 90 52 9 90 13 1 89 1 6 88 40 N 53.44 E 7.06 N 51.50 E 10.54 N 51.28 E 4.33 N 49.39 E 12.07 N 48.69 E 4.51 4339.42N 714 4350.64N 729 4360.66N 741 4372.46N 755 4383.83N 769 .53E .13E · 67E · 91E .01E 4394.73 4408.64 4420.96 4435.37 4449.12 11522.72 8800.57 8742.5 11542.90 8801.22 8743.2 11570.77 8802.08 8744.0 11603.32 8803.15 8745.1 11631.77 8803.93 8745.9 87 58 88 19 88 9 88 4 88 46 N 47.28 E 6.42 N 45.88 E 7.15 N 43.29 E 9.31 N 42.54 E 2.32 N 38.14 E 15.65 4400.22N 787 4414.09N 801 4433.93N 821 4457.75N 843 4479.42N 861 .20E .85E .40E .56E · 96E 4468.81 4485.32 4508.66 4536.43 4561.33 RECEIVED SPE' 'f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU/5-15B 500292025502 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/11/96 DATE OF SURVEY: 032896 MWD SURVEY JOB NUMBER: AK-MW-60035 KELLY BUSHING ELEV. = 58.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11664.10 8804.55 8746.55 89 1 N 38.32 E .98 4504.81N 881.96E 11690.40 8805.06 8747.06 88 46 N 37.09 E 4.78 4525.62N 898.04E 11720.87 8805.71 8747.71 88 46 N 34.98 E 6.92 4550.25N 915.96E 11750.55 8806.39 8748.39 88 35 N 33.92 E 3.62 4574.71N 932.75E 11779.32 8807.26 8749.26 87 58 N 31.99 E 7.03 4598.84N 948.39E 4590.21 4613.80 4641.51 4668.83 4695.60 11811.69 8808.29 8750.29 88 20 N 30.29 E 5.37 4626.53N 965.12E 11838.89 8809.04 8751.04 88 30 N 30.23 E .63 4650.01N 978.82E 11868.96 8809.51 8751.51 89 44 N 27.24 E 10.76 4676.37N 993.27E 11892.44 8809.40 8751.40 90 47 N 24.08 E 14.18 4697.54N 1003.44E 11919.51 8809.05 8751.05 90 41 N 23.90 E .74 4722.26N 1014.44E 4726.07 4751.81 4780.53 4803.29 4829.72 11949.96 8808.70 8750.70 90 37 N 22.67 E 4.05 4750.23N 1026.48E 11981.79 8808.11 8750.11 91 29 N 21.09 E 5.67 4779.76N 1038.34E 12005.44 8807.42 8749.42 91 50 N 18.10 E 12.72 4802.03N 1046.26E 12039.84 8806.82 8748.82 90 10 N 18.28 E 4.85 4834.70N 1057.00E 12065.92 8806.37 8748.37 91 46 N 16.19 E 10.09 4859.60N 1064.72E 4859.53 4890.83 4914.23 4948.39 4974.33 12089.82 8805.52 8747.52 92 16 N 13.88 E 9.88 4882.67N 1070.92E 12118.44 8804.71 8746.71 90- 58 N 10.90 E 11.37 4910.60N 1077.06E 12149.27 8804.24 8746.24 90 47 N 11.07 E .80 4940.86N 1082.93E 12171.02 8803.96 8745.96 90 41 N 8.61 E 11.32 4962.29N 1086.65E 12185.59 8803.80 8745.80 90 33 N 5.81 E 19.24 4976.74N 1088.47E 4998.17 5026.77 5057.59 5079.32 5093.85 12203.04 8803.62 8745.62 90 37 N 5.97 E 1.00 4994.10N 1090.27E 12229.24 8803.12 8745.12 91 34 N 1.93 E 15.85 5020.23N 1092.07E 12262.74 8802.06 8744.06 92 1 N 2.34 E 1.82 5053.68N 1093.32E 12285.47 8801.43 8743.43 91 8 N 1.23 E 6.26 5076.39N 1094.02E 12300.84 8801.25 8743.25 90 10 N 1.05 E 6.36 5091.76N 1094.33E 5111.22 5137.18 5170.21 5192.61 5207.72 12320.92 8801.39 8743.39 89 1 N .53 W 9.73 5111.83N 1094.42E 12360.49 8802.82 8744.82 86 50 N 2.11 W 6.82 5151.37N 1093.51E 12390.32 8804.76 8746.76 85 41 N 5.10 W 10.72 5181.07N 1091.64E 12411.45 8806.54 8748.54 84 40 N 7.46 W 12.11 5201.99N 1089.34E 12439.42 8808.97 8750.97 85 20 N 8.62 W 4.76 5229.58N 1085.44E 5227.42 5265.97 5294.70 5314.75 5341.00 12461.22 8810.54 8752.54 86 24 N 8.26 W 5.13 5251.09N 1082.25E 12479.47 8811.88 8753.88 85 9 N 10.91 W 16.00 5269.03N 1079.22E 12496.95 8813.40 8755.40 84 54 N 13.01 W 12.06 5286.07N 1075.61E 12510.02 8814.59 8756.59 84 38 N 14.59 W 12.20 5298.70N 1072.51E 12550.00 8818.32 8760.32 84 38 N 14.59 W .00 5337.23N 1062.48E 5361.44 5378.42 5394.39 5406.15 5441.90 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. R E C E IVE D HORIZONTAL DISPLACEMENT = 5441.95 FEET AT NORTH 11 DEG. 15 MIN. EAST AT MD = 1255~A¥ 15 199~ VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG TIED INTO 5-15A AT 11084' INTERPOLATED DEPTH 12550' SPE; '-SUN DRILLING SERVICES kNCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBO/5-15B 500292025502 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/11/96 DATE OF SURVEY: 032896 JOB NUMBER: AK-MW-60035 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11084.00 12084.00 12550.00 8794.34 8736.34 8805.75 8747.75 8818.32 8760.32 4135.10 N 438.90 E 2289.66 4877.02 N 1069.52 E 3278.25 988.58 5337.23 N 1062.48 E 3731.68 453.43 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE3 .'-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC. PBU/5-15B 500292025502 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/11/96 DATE OF SURVEY: 032896 JOB NUMBER: AK-MW-60035 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11084.00 8794.34 8736.34 4135.10 N 438.90 E 2289.66 12550.00 8818.32 8760.32 5337.23 N 1062.48 E 3731.68 1442.02 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED MAY I 5 199~ An¢l~ora§e SPE f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU/5-15B PB1 500292025570 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/11/96 DATE OF SURVEY: 032396 MWD SURVEY JOB NUMBER: AK-MW-60035 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 11084.00 8794.34 8736.34 85 54 N 50.60 E .00 4135 11095.24 8795.08 8737.08 86 34 N 47.14 E 31.29 4142 11108.67 8795.94 8737.94 86 2 N 46.93 E 4.24 4151 11120.62 8796.67 8738.67 87 0 N 47.14 E 8.31 4159 11136.62 8797.41 8739.41 87 42 N 47.63 E 5.34 4170 .ION 438.90E 4139.52 .48N 447.35E 4148.43 .61N 457.15E 4159.34 .74N 465.88E 4169.05 .56N 477.64E 4182.00 11149.87 8797.74 8739.74 89 22 N 47.81 E 12.68 4179 11161.97 8797.74 8739.74 90 37 N 49.57 E 17.79 4187 11172.82 8797.57 8739.57 91 11 N 52.10 E 23.92 4194 11193.77 8797.17 8739.17 90 58 N 53.08 E 4.80 4207 11215.37 8796.94 8738.94 90 15 N 55.02 E 9.56 4219 .47N 487.44E 4192.69 .46N 496.53E 4202.32 .31N 504.94E 4210.72 .03N 521.58E 4226.50 .71N 539.06E 4242.42 11233.89 8797.10 8739.10 88 46 N 54.49 E 8.54 4230 11250.37 8797.45 8739.45 88 46 N 56.78 E 13.89 4239 11276.59 8798.14 8740.14 88 14 N 57.30 E 2.83 4253 11288.84 8798.62 8740.62 87 11 N 59.76 E 21.82 4260 11310.27 8799.82 8741.82 86 24 N 58.71 E 6.13 4271 .40N 554.18E 4255.90 .69N 567.78E 4267.73 .95N 589.77E 4286.09 .34N 600.21E 4294.43 .29N 618.60E 4308.83 11335.04 8801.83 8743.83 84 17 N 58.53 E 8.55 4284 11350.59 8803.57 8745.57 82 52 N 59.59 E 11.32 4292 11368.82 8805.98 8747.98 81 54 N 56.25 E 18.92 4301 11380.67 8807.71 8749.71 81 18 N 55.19 E 10.24 4308 11400.29 8810.68 8752.68 81 18 N 54.49 E 3.53 4319 .14N 639.67E 4325.63 .09N 652.92E 4336.05 .68N 668.23E 4348.51 .28N 677.92E 4356.91 .45N 693.77E 4371.02 11430.84 8815.16 8757.16 81 49 N 53.08 E 4.88 11450.00 8817.88 8759.88 81 49 N 53.08 E .00 4337.30N 718.15E 4393.38 4348.70N 733.31E 4407.57 THE CALCULATION PROCEDURES THREE-DIMENSION MINIMUM HORIZONTAL DISPLACEMENT AT NORTH 9 DEG. 34 MIN. ARE BASED ON THE USE OF CURVATURE METHOD. = 4410.09 FEET EAST AT MD = 11450 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 11.51 DEG. TIED INTO 5-15A AT 11084' INTERPOLATED DEPTH AT 11450' RECEIVED MAY 1 5 1996 Alaska Oil & Gas Cons. Commission Anchorage SPE f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 D~RCO ALASKA INC PBU/5-15B PB1 500292025570 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/11/96 DATE OF SURVEY: 032396 JOB NUMBER: AK-MW-60035 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11084.00 8794.34 8736.34 11450.00 8817.88 8759.88 4135.10 N 438.90 E 2289.66 4348.70 N 733.31 E 2632.12 342.46 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. R£CI IVF_D t996 Anchorage SPE~ :-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC PBU/5-15B PB1 500292025570 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/11/96 DATE OF SURVEY: 032396 JOB NUMBER: AK-MW-60035 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAi~GULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11084.00 8794.34 8736.34 11450.00 8817.88 8759.88 4135.10 N 438.90 E 2289.66 4348.70 N 733.31 E 2632.12 342.46 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS - ' ...... ;' '~ "' "' .l\.!,,. ~ ~'"''; ~ 'i t', :i~-.- ~_~! ;.--' ','~i -!,: ,~-...:~ .// / ALASI~& OIL AND GAS ./ CONSERVATION COMMISSION I TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 16, 1996 Erin Dba, Engineering Supervisor ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 5-15B ARCO Alaska Inc 96-23 3250'NSL, 63'EWL, Sec. 32, T11N, R15E, UM 1928'FNL, 1178'EWL, Sec 29, T11N, R15E, UM Dear Ms. Dba: Enclosed is the approved application for permit to re-ddll the above referenced well. The permit to re-ddil does not exempt you from obtaining additional permiis required by law from other govemmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed pdor to ddiling a new hole. Notice may be given by contacting the Commission's peti-oleum field inspector on the North Slope pager at 659-3607. David W ,/~nston Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALAS, ~, OIL AND GAS CONSERVATION COMMIS~,.)N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill _ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test Development Oil Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone ~ Multiple Zone. 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 58' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28326 Prudhoe Bay/Prudhoe Bay Oil 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 3250' NSL, 63' EWL, Sec 32, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1071' NSL, 738' WEL Sec 30, T11N, R15E, UM 5-15B #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1928' FNL, 1178' EWL, Sec 29, T11N, R15E, UM February, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 12515' MD / 8834' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 11084' MD Maximum hole anc~le 90° Maximum surface 3000 psig At total depth (TVD) 3500 psic~ 18. Casing program Setting Depth size Specification To~ Bottom Quantity of cement Hole Casin$ Weight Grade Couplinc~ Length MD TVD MD TVD (include sta~le data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 2215' 10300' 8765' 12515' 8834' 20 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11085 feet Plugs (measured) true vertical 8800 feet Effective depth: measured 11082 feet Junk (measured true vedical 8799 feet Casing Length Size Cemented Measured deplh True Vertical depth Conductor 113' 2 0" 284 Sx PF 1 1 3' 1 1 3' Surface 2637' 13-3/8" 5520 Sx PF Il 2695' 2695' Production 91 1 5' 9-5/8" 750 Sx Class G 8687' 7817" Liner 1255' 7-5/8" 146 Sx Class G 8449' 7617' Tieback Liner 2640' 7" 425SxClassG 11083' 8799' FEB 02 1996 Perforation depth: measured Alaskr~ Oil & ¢~s Cons. C0mrnissi 10770 - 11070' true vedical Anchorage 8781 - 8799' 20. Attachments Filing fee ~ Property plat _ BOP Sketch _Z_ Diverter Sketch _ Drilling program _~_ Drilling fluid program __ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed ~~ '~. ~ Titlle Engineering Supervisor Date Commission Use Only Permit Number I APl number I Approvaldaj~ /_ J See cover letter for ,C:/,~_ ~ 50-(:7 2.¢- 2.0 ,2 ~-"~:::~ ~ ~--//~/~¢, other requirements Conditi6ns of approval Samples required __Y e s ~ N o Mud log r~quir~c~ ~__ Y e s ~ N o Hydrogen sulfide measures ~ Y e s __ N o Directional survey required _z~Yes__ N o Required working pressure forBOPE __2M' __ 3 M' __ 5M · __ 1 0M' __ 1 5 M IXI3500psiforCTU Other: 0ri~ir~a~ Si,.qJled ~y, 'by order of 4:~/ /? Approved by David W. J0hr~sfnn Commissioner the commission Date ~ Form 10-401 Rev. 7-24-89 Submit ~n/ triplica ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 John W. Peirce Workover/Stimulation Engineering Aide Prudhoe Bay Resource Development ATO- 1515C Phone: 265-6471 Fax: 265-1336 January 31, 1996 Mr. Blair Wonzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wonzell: Re: 5-15A Application for P&A and 5-1~B Permit T0 Drill An Application Sundry is attached for the Plug & Abandonment of well 5-15A. The 5-15B Permit to Drill recently delivered to you has inaccurate Casing information listed in box 19. The data listed reflects the original 5-15 wellbore; not the current 5-15A casing data. I revised the first page of the 5-15B Permit (attached in triplicate) to reflect the casing in the current 5-15A wellbore. Please replace the Permit pages on the previously sent 5-15B Permit with the revised pages attached. Please call me at 265-6471 if you have any questions. Sincerely, Workover / Stimulation Aide PruOhoe Bay Resource Development FEB 02 1~96 Al~ska Oil & Gas Cons. Corn.mission Anchorage ARCO Alas~ka, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany DS 5-15B CTD Sidetrack Extension Intended Procedure Objective: Directionally drill -~1000' horizontal well from 'she existing weHbore. Complete with 2-7/8" cemented liner. Intended Procedure: Mill existing 7" float collar/shoe and 10' new formation. Perform FIT. Directionally drill a 3-3/4" hole to the target sands. Drill approximately 950' of horizontal well in the Romeo sands. Obtain GR and directional information from MWD. Run 2-7/8" FL4S blank liner from TD to a minimum of 100' above the existing perforations in the 7" liner. Cement liner in place bringing top of cement up to a minimum of 100' above the existing perforations in the 7" liner. Perforate selected intervals. Return well to production. January 24, 1996 DS 5-15B Potential Drilling Hazards POST ON RIG · H2S production 2 ppm (10/94). BHP: 3520 psi @ 8800' ss (7.7 ppg EMW), BHT 190 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/ full column of gas: 2800 psi. · Deepest expected gas/oil contact is 8720' ss. A 30'-50' fault will be intersected ~-100'-200' from existing 7" shoe in 5-15A. Lost circulation may occur. Have LCM available in the event of lost circulation. January 24, 1996 Proposed CTD Extension of 5-1 SA J-I C-1 k G-1 C-2 FO @ 2301' 1 2106' 2 8450' 3 9622' FO @ 2428' 4 9679' 5 9750' 6 10397' 7 10409' J-2 4-1/2' 7" Bakl~rH~~~ 4-1/2" Pazke= 7" Baker SAS~-3 4-~/2' ~ 4-1/2' Pazkex 4-1/2' W~ ~ ~.,~, ~L~ ZD: 4-1/2" ~amkmx ~ ~ 15-3/8" 72~ L-80 9-5/8" 47f 9-5/8" ~ @ 8687' - 8737' 7-5/8" 29.7~ 7" 29f A-80 4-1/2" 9-5/8' 8687' ARCO ALASKA EXPLORATION 5- ]$ SIDE. TRACK BAY INC. 5- 1500TN , SidetDack Plan · ' Op I g Ina I le I ] bone BO00 _ 8500- tg 9000- O~l~l~L ~LLSOt~ VePtica] Section Scale ! inch: 500 ft 5000 - 4000 - ( PLANE OF VERT SEE]Tn . 11.51' (REL. TO TRUE NORTH) NoPth Rel. To True Z / )lag (,29.7G) 5-1501 SIDETRACK 6.i6A $1DETR,~'CK wELLPLAN ----jANUARY 22, IggE~ ................................................................ MD; Inc. j ~irl $$ DEPTH~L NI-Si E/-W' Ooglegi Build[ .... ~'U-rn'~ ASP Y ASP X ', Comments ........ ftl deg deg, fl~ ft ft~ deg/lOO' degtlO01 deg/100? fl: fl : ............ ~= ......................... ? ............. ............. i ..................... ; .... , ............................... I .... '"-" ~'' ' ; 11084LY.~_ ~00' 8590' 50,6~-5060 873634 41354145.20110' 43890~_| 000 000,~ 0 O0595355700~ 69745030 TI ° ......... ' ...... *- ..... ' ........... ~ ..... ~. -'--' ............................ : ............ ' ..... ' ............ - ....... _.L___ , ~ E IN POINT BUILD 10/100ABOVE8735 SS {{:i25~0. 90.00; ....... ~)0.60'I ...... §757.81 ['*'416~;~; ...... ~0.70', {~.-§-~.~._ ....... '~;'~'-~': ....... ~i~0! 5953584.00 097481.40 BOTTOM dF CUF~vE'. BUILD UP Td 91° ~-~0.6b'~-"901~[ 5--~-.60i S~/~7~§'' 4~~-' 47~.;t(~: 10140[ .... ~-~;~6 ~ "'~'~3587.00~ 697485,10' ' ~ ..... ; ; .. 111~'2d*T-*'~'~ ~ ..... ~ 60[- 873~-'f~*'"4167 so '-7~ 40'~ .......... ~*~'t ............. ~6~ ......... 0 oo 595359~ 'd6'~'"'~-9'i~-89-'6~*'Hd~D'~-~L ; · , - · · I . , ...... EUNTILLFA~LT ~ ............ - ......................................... , ..................................... . , 11160.00 ..... 91.~ 48~~'* 8737.29~ 41~3.70r 497.20~ 10.10, 0.00[ -10.10:5953607.001 697507.40 ......... ~ ......................... ~ .......... ' 1190.00 ~0''-'~';101 ...... ~7~".77 ~204.30';'*'~'~-~00~ ~0~'~ ......... d:~b; ',10 00' '~2~J '~9~ ..... ', ........................... ............... 1~220.00 9i.00[ ~2.10~ 'S73~.'24~ ~2~'1'~ 53~.'~- ..... 16;00 ~~b~o0] i i'~o.'o~*~l,eof 3~.~= dz~;~ ~E48.e6~ ...... ~s~2o~ i~ ........ 6.06~"_~o. Od" ~f~'~*~[ ~*f:.'Y6 ~ ...... ....................................~ ........... 1" [ ..................... f .................................... I ...... ~ ......................... 112d0.00 91.00 ~.10, 8735.20 4272.60' 577.50~ 10.00 0.~{ -10.00 5953698,00 697585,40 ......... { ........... ~ ..... ~ , ...... ,'; '. , ,, ~-'i~8020~ .... ~1,00~-"3~,107 ~735,19}" 4272',8b-~ ~77.7~ ........ ~ ................ ; ...... .... 0.00, 0,00~ 0,00 5953698OO '697585.5o~END~"~[D'DRO'P'io4/lo0 TO 79' ~1310.00~ '~b0, ~10 8735.45~'"'42~,~ 59~.20 '10,10~ .10.10 ...... ~]'~3~22,00097002.40~ ~'0.0~~ ~5.~ ~6~0~' ~,28 ~00~ "6'~ 10,00 -10.00 *0.~'~ 5953747.00697619.40 ""~ ...... ~'~b[' ~0~ *~6~~* '~740~8~45','~:"-~40~ 10~00 -10.00 '"b 00 ~" 5953771 O069763640' ' ........ . - ~ ............. ' ........ ' : ~ ................ ~. . 11400.00~ ~ ~-*" -'S745.~3' 4369.00~" ~7.80[ ~0.00 ...... ~O~[ 0.00[ 5953796.00697653.20 HOLD'TO 11477 MD .... ~ ........... , ..' ~ ' ............... , ~ ............... ]~ ........ ~ 1140~ 79.00. 36,10i 8745,67[ 4369.20~ 64800 0.00[ 0.00~ b~"59537~,00' 697e53.30~ ..' '~'~430.00~ ?9~d*G[-' ~b'* ' ~'~'.~[ ~2~*'66~,~ "b'.ooJ .......... ~70'b'~ ~0~ 59538200d' 697~990 '~.' ~ ~460.00~- 7--9'.00~-' ~6,'~'b~-757.0~'-'4416.~---~2.50~ 0~00~ ' 0.0~ ..... ~'.'005953~4,00697686.70' ~ '; ........ ~ .... i ~'~~' 7~00' ' ~0~ ...... ~'~9 ~~ 69~.6~'~' ' 0,~0'.'-~~~*~58.~0' 697696~40 START 18°/100 BU~Lb To FINAL ~TE~L ....... ~ ......... f ........... ~ ..... : _ - ...................... 11490,~ 80.40~ ~.30 876265 4~0.50! 699,80~ 17.80 11.10 -14.20 5953868.00' 6~7703.30 ..~... l ................ ~ ... 1152,0.00 83.70'. 30.00; 876d.-80 4465.70i 715,60~ 18,00 ¥~,0.'o_0_[-~-~.10;"---~5.d6{ '---d~g.:~l' i-'-~,~21~o ~g.5o ' -~a.oo; ... 739.80 3~58'0~; {0.~--'22.3b~' d7~;~{ 451g.50~.. 741.6'0[~ 0.00~ 11610.00[ 90.00' 22.30{ 8769.~' '= 4~7,30{ 753.00~ 0/00~ ~ ..... { " ,. 11.00 -14.30'"59-~§89'4.00" 697~/i"8140 11.30 ~ti005953921,0069~731',70 '~: il.50' ~;I-'~)-"~{~',~§~4-~i~-~ ..... ~'~-~.'~'~'~'i* START HOLD' To TD 0.00'~" 010~' '5~53~81~6'" 697743,10 ................................... 0,00~ 0.00 5953976.00. 697753.70 ....................................... : i \L.T,.~,.~ L_ I V Page 1 JAN 2 6 1996 Alaska Oil & Gas Cons. Commission 11640.00; 90.00' 22.30i 8769.84i 4575.00i 764.40! 0.00 0,00i 0.00 5954004 00] . 697764.30! -i""~o0,O~T 90.~ '-~'~0 .... ~69.~' ~'~0~6~': 7~'~'~'0'~ 0.00 0.00' ........ b;'O'o' 5954060,00~ 697785.60~ ~"~'73-0,00---' 90.Ob~ 2~;30['"~~84'[ ~58.30; 798.50~ 0,00[ '0,00 "0'~ 5954088,00~ 697~'~:~b- ....................................................... ~-~'~6'~001 ~dO~ - 22,'3~-' 87~'~'~ ~6~-~" 809.~'~' ~ 0.0~ ....0.00 5954116.00 697806.80 .......... ~ ........... ~ .... ~ ................ ~ ............. ~ .......... ~ ...... ~. ~ ............ 117~0,00'~ 90,~ 22.301 8769.84~ 4713,80 ~21,30j 0,00~ 0,001 0,00 5954144.00 697817 40 ............................. ~182~:~0~ ..... ~0.00 ..... ~2,30~ '~':~I 4741,6~'~ .... ~32.70~ 6~,~; ~.Ob'. 0.00 5954172.0~ 697828.10' 11~0.0~ 9~:'~ 2~:30 .... 8769.~'~-~'~69.301 ~:~ 0.00" o,bo ...... ~"-'~'~'O0.OO- 097838.70 '~Tg~O'; ...... ~d:'d~i 55';'3b'~ ' ~9.~,~~'~90~ ~;~0' 6';~5~ ............. 6'.b~ ...... O.oOl' ~~ ......... ~ ............... i ........................ I ........ t .............. I ................ ~ ..... ~ ................................................................... ....... ~ ...................................... l ...................... ; : ........ ~ .................... 11~0.00'~ 90.00~ 22,30~ 8769,84~ 4852,60~ 878.20~ O~ O.OOi 0.00 5954284.00; 697870~6'0' ' "'~'~eT~;~'[ ~',66't' ~30'['-~Tee.84[-~488d:40~ '~6.6o' ...... ~.oo .............. 5':'0~' d;oo~ 5~543i~.b0] Sb?~8~':~O', '~'dO0.O0'~ ..... ~0.00~ ....... 22.3bl ~;~ 49~;'~d ~~ ............. ~00 0.00~ 0J0~'-"~954340.00', 697891,80: "'~20~".00/ ~5;bd~ ....~2.3b~''~69.8~';'''''~935~d~- ..... ~J'2.40 b'~'~;O~ -'O.o0"~6~6[66'T--~b~ 'j~o.Od~ 9~b:: 2~bj-~.84~ ""~963.80~ ....... 6'23.~ 0,~ ............ -d['db-~ ......... ~';~';"'5954396 00~ 897913'10 12090.00 9000 22,30. 8769.84~ 4991.40 935,10' 0.~ 000. 000: 5954424,00. 697923 70~ 12120.00,. 90Jo~ .....2~0~ 8769,84] 5019.10:~46.50 '°.0° ............ '~'dO ......... QO07"-~6~~ ~7~-~3~~ ~2i'5~ ~Of'~OOo~---~"3-d! 8~:.' ~046,~"[ ...... ~?.9'~; E~'~ ........ -0,66 ...... ,,.~ ..... ; .........' .~. 80.00' 90.00~ 22.30 8769.~[-~b~4, .70~ .......... ~30~' 0.~ ......... ~: ~" Q00~ 59545~8.00~ 6~7955,6~; ~22~0.00~2~ ~'~.00~ ~2.30~_.~:~4t s~02.40~ ~so.zo'i0~ 0.06' ~6 ~ ~~~[ , ....... ~ .................... [ ............................... , .... 22.30~ 8769.84 5130.20 , 0,00 ' 12240.~ 90.00[ ~ 0,00 0,00; 5954564.001 097970.80 ~2270:0'0, ~:00~-" =~6~ s76[~~ s~57:~0 1003.~0 .9..~_ ....... '.~:.~.~." ~'~~:~'~ ~7~:40'. 12300.00 .... ~6f 5185.70 1014.80, 0.00 22.30! 8789.84 ":i23:~-~.0__0_~ 90.00i 2~.~6~' 8769.84 '~213.40 1026.20i ~00..;~_9~0_~' 22.30: 8769.84i'-' 5241.20~ 1037.60[ ~'hgo.o0~ 9000. 22.3d~"'876~.04~ 526900 ' :00" 0.00 i ~'.' ' ' --- -~'{~~, ~0' 22.30 '-~9.~ 52~.70 1~0,40'. 0~~ 0.00~ 12450.00l 90,O~T' 22.30; 8769.~ 5324.50 107~.~0 ..... O.~r 0.00 90,00~ ~.3d? 878~;~ 535~,~ 1083.10 124~.00 ~~' 90.00l ~.30~ 8769.84~ 5380,00~ 10~.50 6,00 0.00 0.00 0.00 5954620.00i 697998.10 0.00 0.00! 5954648001 698008.70 0.00" .... ~3100" 5954676,00 698019,30 0,00; 5954704.00 698029.90 'i ............ 0.00 5954732.00, 69B04016;0 ...... 0.00 5954760.013 698051.20 , 0.00 5954788.00 8980~1.80 0.00' 5954818.00' 698072~40 ........ "'0.00' 5954821.00 698074.10!TD ' ~ ............ Page 2 C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection ~,. Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" R~ser Otis 7' WLA Quick Connect ---'- Ii jl 2" Pump-ln~ ~ 5-1/8" ID CT BOP Stack 10,000 psi Working Pressure ~' J Cutters or Combination Cutter/Blinds Slip/Pipe rams Annular BOP (Hydril), 7-1/16" ID 5,000 psi working pressure Alignn'mnt Guide Flan Ram Type Dual Gate BOPE Manual over Hydraulic ~ 7-1/16" ID with Pipe/Slip Earns Flanged Fire Resistant Kelly Hose To Dual \ ChokeManifold \ Manual Valves Drilling spool 7-1/16", 5M by 5-1/8", 1 OM o.45s' (5.5-) Manu/Valve / Manual Master Valve ,.I ri fTubing Hanger 9-5/8" Annulus 3-3/8" Annulus X Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree JAN ~6 1~6 Alaska Oil & Gas Cons. Commission Anchorage Fuel Shop Boilers Water 60/40 I Trplx I Mud Pump Room Pipe rack Dowell Drilling Equipment Trailer Fire Ext. Preferred Major Equipment Layout for CT Drilling in DS 5-15A Ext. PERMIT CHECKLIST GEOL AREA Y- IF~'3 PROGRAM: exp [] der []. redrll ~ serv [] : t l I'o ADMINISTRATION 1. Permit fee attached ................... ~_. N 2. Lease number appropriate ................ ~ N 3. Unique well name and number ............... ~ N 4. Well located in a defined pool .............. ~ N 5. Well located proper distance from drlg unit boundary. . .~ N 6. Well located proper distance from other wells ...... ~ N 7. Sufficient acreage available in drilling unit ...... ¢ N 8. If deviated, is wellbore plat included ......... ~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N ll. Permit can be issued without conservation order ..... ~ N 12. Permit can be issued without administrative approval...~O N 13. Can permit be approved before 15-day wait ........ ~ N REMARKS ENGINEERING APPR 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg. . . Y N 18. CMT will cover all known productive horizons ...... ~ N ~ ^ ~ ' 19. ~ ~ ; ~~, ~a~ a ~; ~0~ ~a n ~ ;e;n a; Ca~i~g:designs ade~u;te~for C~;~,;B & permafrost ..... 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate ~> N 25. BOPEs adequate ..................... Y~ N 26. BOPE press rating adequate; test to ~7~> psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... .-Y----N-~j~ 28. Work will occur without operation shutdown ....... ~..~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY DA~E / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y ~ 32. Seismic analysis of shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ......... / N 34. Contact name/phone for weekly progress reports .... /Y N [explorator~ only] GEOLOGY: ENGINEERING: COMMISS ION: Comments/Instructions: '% - A:%CORMSlcheklist rev 11/95 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end Of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . ............................ * * ....... SCHLUMBERGER ....... * . ............................ * COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 5-15B FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-20255-02 REFERENCE NO : 96250 ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE ' 96/11/25 ORIGIN · FLIC REEL NAME : 96250 CONTINUATION # : PREVIOUS REEL : COR~4ENT ' ARCO ALASKA INC, D.S. 5-15Bi PRUDHOE BAY, 50-029-20255-02 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE . 96/11/25 ORIGIN · FLIC TAPE NAME : 96250 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA INC, D.S. 5-15B, PRUDHOE BAY, 50-029-20255-02 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 5-15B API NUMBER: 500292025502 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 25-NOV-96 JOB NUMBER: 96250 LOGGING ENGINEER: S. CHAPESKIE OPERATOR WITNESS: R.BURNO SURFACE LOCATION SECTION: 32 TOWNSHIP: 11 ~GE: 15 FNL: FSL: 3250 FEL: 5217 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 58.00 DERRICK FLOOR: 58.00 GROUND LEVEL: 39.00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 7.625 8449.0 29.70 7.000 11083.0 29.00 4.500 10409.0 12.60 2.875 12500.0 9.30 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUI4BER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SPERRY-SUN BASELINE DEPTH 88888.0 12199.0 12193.0 12173.5 12140.5 12138.0 12099.0 12017.5 11994.5 11988.0 11974.5 11958.5 11919.0 11836.0 11833 0 11761 5 11761 0 11751 0 11707 0 11652 5 11648 0 11640 5 11611 5 11575 5 11573 0 11567 5 11563 5 11562 0 11531 0 11504 5 11477 5 11460 0 11458 5 11438 5 11429 5 11421 0 11408 5 11334 5 11326 0 11241 0 11208.5 11199.0 11198.5 11191.5 11176.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.5 88887.0 12193.5 12144.5 12107.5 12000.0 11994.5 11980.0 11838.5 11762.0 11705.0 11646.0 11638.5 11609. 0 11564.5 11562.0 11529. 0 11501.5 11456.5 11436. 0 11426.5 11419. 0 11327.0 11243.5 11199.5 11193.5 11177.0 12198.0 12172.0 12138.0 12015.0 11955.0 11923.5 11836.0 11762.0 11753.0 11649.0 11572.5 11570.5 11562.0 11529.0 11472.0 11457.0 11436.0 11406.0 11331.5 11209.0 11199.5 11193.5 PAGE: Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 11170.5 11171.0 11169.5 11171.0 11159.5 11159.0 11147.0 11146.0 11138.0 11137.0 11132.0 11131.0 11125.0 11125.5 11125.5 100.0 100.5 100.5 $ REMARKS: This tape contains the CH LDWG edit for Arco Alaska well D.S. 5-15B TDTP. The tape contains the first edited baseline file, 2 edited borax files, the first edited flowing file and the average file. The flowing passe was numbered sequentially (passes 6 and 7) and placed at the end of the data. The depth adjustments shown above reflect cased hole GR to open hole MWD GR and cased hole SIGM to open hole GR. All other TDTP curves were carried with the SIGM shifts. The baseline GR was the Sperry-Sun MWD GR. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEAl'ER FILE~BER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NYIMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12212.0 10369.0 TDTP 12245.0 103 69.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: $ RE~ARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 SBP~N TDTP CU 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 J Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 5 NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TSCN TDTP CPS 100504/ O0 000 O0 0 1 1 1 TSCF TDTP CPS 100504/ O0 000 O0 0 1 1 1 INND TDTP CPS 100504/ O0 000 O0 0 1 1 1 INFD TDTP CPS 100504/ O0 000 O0 0 1 1 1 GRCH TDTP GAPI 100504/ O0 000 O0 0 1 1 1 TENS TDTP LB 100504/ O0 000 O0 0 1 1 1 CCL TDTP V 100504/ O0 000 O0 0 1 1 1 GR MWD GAPI 100504/ O0 000 O0 0 1 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. 12265. 000 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP - 999. 250 TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP -999. 250 TSCN. TDTP -999. 250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999. 250 CCL. TDTP -999. 250 GR .MWD 99. 050 DEPT. 10369 500 SIGM. TDTP 15. 703 TPHI. TDTP 26. 646 SBHF. TDTP 60. 907 SBHN. TDTP 69 534 SIGC. TDTP 0.485 SIBH. TDTP 184.372 TRAT. TDTP 1.819 SDSI. TDTP 0 366 BACK. TDTP 189. 425 FBAC. TDTP 32. 678 TCAN. TDTP 20905.910 TCAF. TDTP 8889 572 TCND. TDTP 16050.967 TCFD.TDTP 4847.291 TSCN. TDTP 4447.469 TSCF. TDTP 1891 144 INND. TDTP 1445. 051 INFD. TDTP 224. 842 GRCH. TDTP 16. 609 TENS. TDTP -70 000 CCL. TDTP O. 000 GR.MWD -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE . FLIC VERSION . O01CO1 DATE . 96/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE 'FLIC VERSION .O01CO1 DATE · 96/11/25 MA~REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~4MARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12220.0 10390.0 TDTP 12250.0 10390.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88899.0 88886.5 12199.5 12198.0 12173.0 12184.0 12164.0 12176.0 12140.5 12137.0 12114.0 12121.5 12087.0 12093.5 12065.5 12073.0 12032.0 12038.5 12018.5 12015.0 12012.5 12010.5 12004.5 12010.5 11992.0 11988.0 11990.0 11995.5 11978.0 11983.0 11969.5 11975.5 11959.5 11964.0 11957.5 11955.5 11926.0 11929.5 11923.5 11927.5 11895.0 11898.0 11867.5 11869.0 11835.5 11838.0 11830.5 11833.5 11819.5 11821.0 11808.0 11809.5 11786.5 11787.5 11762.5 11763.5 11760.5 11762.0 11756.0 11756.5 11751.0 11753.5 11742.0 11742.5 11725.5 11724.0 ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 11704.0 11702.5 11677.5 11675.0 11662.5 11660.5 11644.0 11644.5 11640.0 11638.5 11636.0 11635.5 11625.0 11624.0 11594.0 11592.5 11573.0 11570.5 11572.5 11569.5 11567.0 11564.5 11563.0 11562.0 11561.5 11561.5 11558.0 11557.0 11557.5 11558.5 11551.0 11551.0 11549.5 11548.0 11531.0 11530.0 11530.0 11529.0 11519.5 11518.5 11515.0 11513.5 11498.5 11495.5 11476.0 11471.5 11469.0 11467.0 11460.5 11459.0 11458.0 11453.0 11451.0 11450.5 11446.5 11445.0 11441.5 11439.0 11440.5 11438.0 11433.0 11430.5 11429.5 11426.5 11420.5 11419.0 11420.0 11418.0 11417.0 11415.5 11373.5 11370.0 11347.5 11346.0 11331.0 11328.5 11328.5 11329.0 11321.5 11323.0 11286.5 11289.0 11284.5 11283.0 11258.5 11262.5 11256.0 11258.5 11254.0 11256.0 11239.5 11241.0 11209.0 11209.5 11198.5 11199.5 11200.0 11195.0 11196.5 11191.0 11193.5 11176.5 11177.5 11174.5 11174.5 11170.5 11172.0 11169.5 11171.0 11159.0 11157.5 11158.5 11158.5 ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 11146.5 11136.5 11133.5 11132.0 11129.0 11124.5 11105.5 11099.5 11084 0 11064 0 11063 0 11049 5 11042 5 11019 5 11012 5 11007 5 10987.5 10974.0 10963.5 10949.5 10945.5 10908.5 10890.5 10888.5 10861.5 10848.0 10814.5 10786 0 10783 0 10763 5 10753 0 10744 5 10737 5 10736 0 10729 0 10726 0 10718.5 10717.0 10714.5 10707.5 10691.0 10679.0 10671.5 10661.0 10645.5 10633 5 10623 0 10614 0 10593 0 10581 5 10576 5 10564 5 10562, 0 10556.5 10554.5 11146.0 11135.5 11133.5 11129.0 11125.5 11100.5 11065.0 11043.5 11020.0 11009.5 10988.5 10963.5 10951.0 10909.5 10891.0 10862.0 10848.0 10815.5 10784.0 10745.5 10736.5 10729.5 10717.5 10706.0 10691.5 10632.0 10622.5 10594.5 10583.0 10580.0 10558.0 11146.0 11131.5 11106.5 11084.5 11064.5 11051.0 11017.0 10974.5 10945.0 10888.5 10786.0 10764.5 10753.5 10738.5 10726.5 10718.5 10715.5 10678.5 10672.5 10661.5 10646.5 10615.0 10565.5 ! 0563.0 10557.5 ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 10545 0 10527 5 10520 5 10517 0 10497 0 10492 5 10479 0 10476 5 10434.0 10430.0 10410.0 10399.0 10396.5 100.0 $ 10528.5 10520.5 10493.0 10477.5 10434.5 10410.0 10399.5 100.5 10545.5 10518.5 10497.0 10479.0 10430.5 10396.5 100.0 REMARKS: This file contains Borax Pass #1 of the TDTP. The depth adjustments shown above reflect Borax Pass #1 GRCH to Base Pass #1 GRCH and Borax Pass #1 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 10 ** SET TYPE - CHAN ** NgME SERV UNIT SERVICE API API API API FILE NUlVlB Nr.~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 INArD TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 100504/ O0 000 O0 0 2 ! 1 4 68 0000000000 TENS TDTP LB 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 100504/ O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12248. 500 SIGM. TDTP 14 . 836 TPHI. TDTP 22. 725 SBHF. TDTP SBHN. TDTP 45. 423 SIGC. TDTP O. 921 SIBH. TDTP 83 . 294 TRAT. TDTP SDSI. TDTP 0.264 BACK. TDTP 317. 363 FBAC. TDTP 96. 553 TCAN. TDTP TCAF. TDTP 23546. 441 TCND. TDTP 26332. 863 TCFD. TDTP 9681. 680 TSCN. TDTP TSCF. TDTP 4424. 436 INND. TDTP 1706. 546 INFD. TDTP 349. 946 GRCH. TDTP TENS. TDTP -70. 000 CCL. TDTP O. 000 DEPT. 10390. 000 SIGM. TDTP 14.222 TPHI. TDTP 23. 649 SBHF. TDTP SBHN. TDTP 78. 466 SIGC. TDTP O. 405 SIBH. TDTP 21 O. 661 TRAT. TDTP SDSI. TDTP O. 371 BACK. TDTP 219. 205 FBAC. TDTP 39. 885 TCAN. TDTP TCAF. TDTP 8622.236 TCND. TDTP 13212. 191 TCFD. TDTP 4251.211 TSCN. TDTP TSCF. TDTP 1823. 999 INND. TDTP 1447. 993 INFD. TDTP 212. 791 GRCH. TDTP TENS. TDTP -70. 000 CCL. TDTP O. 000 36.796 1.768 53112.938 9980.055 -999.250 62.519 1.762 18981.281 4015.412 -999.250 ** END OF DATA ** ~ Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT . 002 SERVICE · FLIC VERSION · O01CO1 DATE : 96/11/25 MJLY REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE · 96/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12220.0 10380.0 TDTP 12260.0 10380.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88890.0 88887.0 12193.0 12192.0 12173.5 12175.5 12160.5 12163.0 12156.0 12157.5 12145.0 12143.5 12143.0 12144.5 12118.0 12123.0 12113.5 12109.5 12104.0 12110.5 12087.0 12095.5 _S Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 12 12067.5 12046.0 12035.0 12031.5 12019.0 12008.5 12002.0 11992.5 11986.0 11961.0 11960.5 11944.0 11942.5 11925.5 11924.0 11914.0 11903.5 11896.0 11893.5 11882.0 11880.5 11878.0 11876.5 11859.0 11836.0 11810.5 11788.0 11782.5 11768.5 11761.0 11760.5 11752.5 11752.0 11749.0 11736.5 11729.5 11707.0 11697.0 11684.5 11677.5 11672.0 11665.5 11661.5 11656.5 11649.5 11648.0 11640 0 11635 5 11622 5 11614 5 11609 0 11595 0 11580.0 11573.0 11572.5 12053.5 12036.0 12005.0 11992.0 11963.5 11947.5 11928.0 11917.5 11907.0 11901.5 11898.0 11885.5 11883.0 11878.0 11859.5 11838.0 11811.5 11782.5 11768.5 11761.5 11751.0 11748.0 11736.5 11728.5 11704.5 11693.0 11682.0 11659.5 11649.5 11646.5 11633.0 11606.0 11592.5 11577.5 11569.5 12064.5 12032.5 12015.0 12005.0 11988.0 11956.5 11942.0 11928.0 11886.0 11789.0 11762.0 11753.0 11675.5 11669.0 11663.5 11656.0 11640.5 11621.5 11613.5 11570.5 _S Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 13 11567 0 11561 5 11559 5 11554 5 11553 0 11539 5 11534.0 11531.5 11526.0 11516.0 11495.5 11460.5 11458.5 11453.0 11441.5 11440.5 11438.0 11433.5 11430.5 11430.0 11421.5 11421.0 11409.0 11389.5 11371.0 11344.0 11326.0 11322.0 11321.5 11317.0 11301.0 11285.0 11258.5 11243.0 11219.5 11209.0 11206.5 11199.0 11198.5 11192.0 11191.5 11176.0 11170.5 11164.5 11159.5 11146.5 11145.0 11132.5 11129.5 11126.0 11123.0 11104.0 11090.5 11062.0 11061.5 11564.5 11562.0 11558.5 11552.5 11537.5 11532.0 11530.0 11524.0 11513.5 11456.5 11451.0 11438.0 11430.5 11426.5 11419.0 11406.0 11387.5 11370.0 11344.5 11327.0 11322.5 11298.0 11246.5 11221.5 11207.5 11199.5 11193.5 11177.0 11171.0 11159.0 11147.0 11133.5 11127.5 11125.5 11093.0 11063.5 11552.5 11529.0 11493.0 11457.5 11439.0 11435.5 11427.5 11418.5 11319.0 11314.5 11283.5 11258.0 11209.0 11199.5 11193.5 11166.5 11146.5 11131.0 11107.5 11065.5 _S Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 14 11054 5 11049 5 10988 0 10970 5 10970 0 10946 5 10928 5 10921 5 10917 5 10907.0 10887.0 10886.5 10838.5 10810.0 10787.0 10778.5 10773.0 10760.5 10756.5 10750.5 10734.5 10733.0 10726.0 10723.5 10713.0 10687.5 10687.0 10658.0 10646.5 10628.5 10612.0 10588.5 10581 0 10554 0 10552 5 10541 0 10530 0 10516 5 10501 5 10479 5 10468 5 10460 0 10444 5 10431 5 10428 0 10427.0 10407.0 10396.5 100.0 $ RE~ARKS ~ 11058.0 11053.5 10993.0 10975.5 10950.5 10933.5 10911.5 10891.0 10843.0 10815.5 10777.0 10761.5 10737.0 10729.5 10717.0 10691.0 10653.0 10632.0 10592.0 10558.0 10534.5 10520.0 10471.5 10464.0 10448.0 10435.0 10431.0 10410.0 103.0 10974.5 10926.0 10920.5 10890.5 10790.5 10781.5 10764.5 10753.5 10738.5 10727.0 10690.5 10661.5 10615.0 10586.5 10557.5 10545.0 10505.5 10482.0 10472.0 10430.5 10399.0 102.5 This file contains Borax Pass #2 of the TDTP. The depth adjustments shown above reflect Borax Pass #2 GRCH to Base Pass #1 GRCH and Borax Pass #2 SIGMA to Base Pass #1 SIGMA. All other TDTP curves were carried with the _S Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 15 SIGMA shifts. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT !1 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 T~TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 _S Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE 16 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) INFD TDTP CPS 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 100504/ O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12222.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999.250 CCL.TDTP -999.250 DEPT. 10382.500 SIGM. TDTP 17.085 TPHI. TDTP 23.436 SBHF. TDTP SBHN. TDTP 77. 184 SIGC. TDTP O. 680 SIBH. TDTP 213 . 971 TRAT. TDTP SDSI. TDTP O. 512 BACK. TDTP 220. 092 FBAC. TDTP 40. 431 TCAN. TDTP TCAF. TDTP 5552. 364 TCND. TDTP 12135. 414 TCFD~ TDTP 3548. 620 TSCN. TDTP TSCF. TDTP 1192.540 INND. TDTP 1512.642 INFD. TDTP 209.638 GRCH. TDTP TENS.TDTP -80.000 CCL.TDTP 0.000 -999.250 -999.250 -999.250 -999.250 43.719 61.758 1.641 12218.846 2624.371 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER AS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 17 FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCRE~IENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP $ R~KS: The arithmetic average of passes 1, 2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 ! 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 100504/ O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 100504/ O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 100504/ O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 100504/ O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 100504/ O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 100504/ O0 000 O0 0 4 1 1 4 68 0000000000 .~S Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SIBH PNAV CU 100504/ O0 000 O0 0 4 1 1 4 68 TRAT PNAV 100504/ O0 000 O0 0 4 1 1 4 68 SDSI PNAV CU 100504/ O0 000 O0 0 4 1 1 4 68 BACK TDTP CPS 100504/ O0 000 O0 0 4 1 1 4 68 FBAC TDTP CPS 100504/ O0 000 O0 0 4 1 1 4 68 TCAN PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 TCAF PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 TCND PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 TCFD PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 TSCN PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 TSCF PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 INND PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 INFD PNAV CPS 100504/ O0 000 O0 0 4 1 1 4 68 GRCH TDTP GAPI 100504/ O0 000 O0 0 4 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA DEPT. 12245.000 SIGM. PNAV -999.250 TPHI.PNAV 21.460 SBHF. PNAV 25.639 SBHN. PNAV 37.808 SIGC. PNAV 2.221 SIBH. PNAV 54.690 TRAT. PNAV 1.758 SDSI.PNAV 0.211 BACK. TDTP 57.231 FBAC. TDTP 16.759 TCAN. PNAV 61926.492 TCAF. PNAV 28274.680 TCND.PNAV 30578.281 TCFD.PNAV 11549.973 TSCN. PNAV 12142.418 TSCF. PNAV 5495.491 INND.PNAV 1796.196 INFD.PNAV 364.533 GRCH. TDTP -999.250 DEPT. 10369.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK.~DTP 189.425 FBAC. TDTP 32.678 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAD!E : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE · 96/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : kS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1996 17:26 PAGE: 19 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/11/25 ORIGIN : FLIC TAPE NAME ~ 96250 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT :ARCO ALASKA INC, D.S. 5-15B, PRUDHOE BAY, 50-029-20255-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/11/25 ORIGIN · FLIC REEL NAME · 96250 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 5-15B, PRUDHOE BAY, 50-029-20255-02 '96-N/1£-90 NO ('DNI 'k~ISk~I~ OOH~) ~DON~ D~OG GN~ (S~OIA~S DNI~I~ N/IS-XHH~S) ~HHfl~ I~ N~M~ NOI~SHHAN03 HH~ S~ 'GH~IHS ~ON SI ~¥~ ~I-~ ~qHM 'G~ ,~gEI ~ G~ O~ GHqqIH~ SI ~I-~ qqHM 'O~ ,6gEII ~ I~ ~I-g qqHM ~OH~ ~O-OHHOIH ~gI-g q~HM S¥ GHAON SI GN~f 'SHO~DH~H~ H~A~ NOI~k~IqI~NIDS 'H~OH6 kS~4~fD ~k~8/1A~N HAIM GHHI~D~ ~A~G A~fH ~D 'A%fH ~D HAIM q~NOI~DHHIG HH~ 9-I SN/1H '~-I SN/IH A~ ~HANHSHH~HH SI ~I-g qqHM 'HD - ~ 0'~EI 0gL'~ 0'~80II 000'L 0'6~98 gE9't 0'L898 gE9'6 (~) H~H~ (NI) HZIS (NI) HZIS ~I~ SHHqqIH~ DNIS~D HqOH NH~O 9GG . Z L O0 'Sg ~9 NOm~NIH,I, HOM NO,~,~NIH,~,HOM C N/1H GMt'I ~ N/1H GM{'i aaO_H/SSV , NO,L~NIH.LMOM :S~H DNIH~S NOIAD~OH~ DNIHAS DNIH~S GNE DNIH~S ~SI " 96-D~-E0 SHDIAHHS DNIqqIHG NflS-XHHH~S 'ONI '%QISk~I~ OOH%f E0~EOE6E00~ ~I-~ 'S'G aarralss a NO,~,~NIH,LHOM ~ C009-M/~-~ I NflH :SSHN~IM HOA%fHH~O :HHHNIDNH DNIDDO~ :HH~qN ~0£ SI~ -adA~ s! g aI!~qns o~ FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11060.0 $ BASELINE CURVE FOR SHIFTS: UNKNOWN CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12528.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 11084.0 11106.0 2 11106.0 11259.0 3 11259.0 12037.0 4 12037.0 12555.0 MERGED MAIN PASS. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 5-15B : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 * DATA RECORD (TYPE# 0) Total Data Records: 36 1014 BYTES * Tape File Start Depth = 12555.000000 Tape File End Dep=~ = 11060.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8974 datums Tape Subfile: 2 126 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11060.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11080.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 21-MAR-96 1.32 2.041 MEMORY 11106.0 11084.0 11106.0 0 70.0 86.0 TOOL NUMBER NGP 235 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 11083.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.3 38000 .0 .000 .000 .000 .000 .0 141.6 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 1. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 5-15B : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR * DATA RECORD · (TYPE# 0 ) Total Data Records: 2 , Tape File Start Depth Tape File End Depth 1014 BYTES * = 11110.000000 = 11060.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 304 datums 65 records... 62 bytes 1014 bytes API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11080.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ STOP DEPTH 11432.0 NATURAL GAMMA PROBE 23-MAR-96 1.32 2.041 MEMORY 11459.0 11106.0 11459.0 0 81.3 91.2 TOOL NUMBER NGP 66 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11083.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.1 36000 .0 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT DATA BELuW KICK-OFF POINT OF 11259' IS FROM THE 5-15B PB1 BOREHOLE. $ : ARCO ALASKA, INC. : D.S. 5-15B : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 10 Tape File Start Depth = 11460.000000 Tape File End Depth = 11075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11288 datums Tape Subfile: 4 75 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11250.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11950.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 26-MAR-96 1.32 2.041 MEMORY 12037.0 11259.0 12037.0 0 86.9 92.3 TOOL NUMBER NGP 66 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11083.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.1 43000 .0 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 3. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 5-15B : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) Total Data Records: 19 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 1014 BYTES * Tape File Start Depth = 12035.000000 Tape File End Depth = 11245.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5048 datums Tape Subfile: 5 82 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11940.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12528.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 28-MAR-96 1.32 2.041 MEMORY 12555.0 12037.0 12555.0 0 84.6 92.3 TOOL NUMBER NGP 235 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11083.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.1 43000 .0 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 4. CN WN FN COUN STAT GAMMA RAY INTERVAL FROM 11950' - 12034' RELOGGED ON RUN 4 DUE TO SENSOR FAILURE ON RUN 3. : ARCO ALASKA, INC. : D.S. 5-15B : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 15 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 12555.000000 Tape File End Depth = 11935.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15012 datums Tape Subfile: 6 80 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: LIS 96/ 8/ 2 01 **** REEL TRAILER **** 96/ 8/ 5 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes .End of execution: Mon 5 AUG 96 10:13a Elapsed execution time = 4.06 seconds. SYSTEM RETURN CODE = 0 0'6SEII 0SL'C 0'g80II 000'L 0'6~8 SE9'L 0'L898 gE9'6 (~M) H~dHG (NI) HZIS (NI) HZIS ~I~ saa~I~ sNIS~O auoH Naao uoi~!u~u~o9 ',~uo3 sf,~9 :~? l!O ~.selV 966[ 00'85 C9 0SE~ NO~DNIH~HOM 96-DD~-~0 SHDIAHHS DNI~qIHG NI1S-AHHH~S ' DNI ' %~HSk~I~ ODH%f 0£SSEOE6E00S I~ ~SI-S 'S'~ aanr~/ssY~ NO,T,~NIH,T,~tO~4 S gO09-M~-l~f :SHHk~HH DNIH~S NOI~D~GOH~ DNIHAS (/H~ DNIH~S ONE DNIH~S ASI SIq :acLK$ s{ E aI~3qns FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11060.0 11432.0 $ BASELINE CURVE FOR SHIFTS: UNKNOWN CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 11084.0 11106.0 2 11106.0 11459.0 MERGED MAIN PASS. CN WN FN COUN STAT : ARCO ALASKA, INC. : 5-15B PB1 : PRUDHOE BAY : NORTH SLOPE .' ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 * DATA RECORD (TYPE# 0) Total Data Records: 10 1014 BYTES * Tape File Start Depth = 11457.000000 Tape File End Depth = 11060.000000 Tape File Level Spacing = 0.500000 Tape File D~pth u.,its = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2386 datums Tape Subfile: 2 94 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11060.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11080.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): 21-MAR-96 1.32 2.041 MEMORY 11106.0 11084.0 11106.0 0 70.0 86.0 TOOL NUMBER NGP 235 3.750 11083.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.3 38000 .0 .000 .000 .000 .000 .0 141.6 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 1. CN WN FN COUN STAT ARCO ALASKA, INC. 5-15B PB1 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 2 Tape File Start Depth = 11110.000000 Tape File End Depth = 11060.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 304 datums Tape Subfile: 3 65 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type:-LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11080.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ STOP DEPTH 11432.0 NATURAL GAMMA PROBE 23-MAR-96 1.32 2.041 MEMORY 11459.0 11106.0 11459.0 0 81.3 91.2 TOOL NUMBER NGP 66 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11083.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.1 36000 .0 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT : ARCO ALASKA, INC. : 5-15B PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 810 01 1 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 10 Tape File Start Depth = 11457.000000 Tape File End Depth = 11075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4682 datums Tape Subfile: 4 73 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 = ~GO0 NHfl~NH~S~S ~90:0~ 96 ~ ~ uo~ :uo~noaxa ~o pu~ sa~Xq ~I :q~uaI p~osa~ ~n~x~ · ''spaooaa E ~ :aI~qns IO S /8 /96 ~ HHqlk~H~ qHHH ~ I0 /96 SI~ :odA$ s~ S oI~qns ode~