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183-048
Schlumt~erger Alaska Data & Consulting Services 2525 Gamball Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO.5460 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 13-35 8148-00084 INJECTION PROFILE - ~~- 2-27 17-09 OS-38 63S0-00043 BSJN-00031 AYKP-00063 GLS - Q LDL ~ ~ p PRODUCTION PROFILE - 11/10/09 01!07/10 01/11/10 1 1 1 1 1 1 P2-52 17-09 AGMOt 82NJ-00050 AYKP-00064 BBKA-00003 MEMORY XY CALIPER _ USIT - / USIT O - C 01/21/10 01!24/10 01/22/10 1 1 1 1 1 1 01-198 AWJI-00062 MCNL _ 01/18/10 1 1 H-13A 82NJ-00042 MCNL G( ~ - 12/03/09 1 i 07-26 BALL-00007 RST 11!29109 1 1 07-19A 63S0-00036 RST _ (~ 12/08/09 1 2-14/0-16 AZCM-00050 RST fo - r 12!25/09 1 1 P1-24L1 W-217 W-217 PB1 12034915 09AKA0091 09AKA0091 OH LDWG EDIT (FLEX _ Q OH MWD/LWD EDIT _ OH MWDlLWD EDIT 12/08/09 08/08/08 11/23/09 1 1 2 1 1 1 11/15/09 2 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY EACH TC)~ or ~xpiorauon tHtasl<a) Inc. Petrotechnical Data Center LR2-t 900 E. Benson Blvd. ~E~ ~ ~ 20~ lJ~/ - \`J Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 PJO. 537E Alaska Data & Consulting Services 2525 Gambell Slreet, Suite 400 Company: State of Alaska Anchorage, AK 99503-2838 Alaska Oil & GaS Cons Comm ATTN: Betty Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL c„t,,. ~., i ~ t~, ~~ ~, ~ i ,. ., J_1lUr,'' ~~* ~a C~ ~< caywiauon iHtastca~ Inc. Petrotechnical Data Center LR2-1 Alaska Data 8 Consulting Services 900 E. Benson Blvd. 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 STATE OF ALASKA 6~~ ~ ~ ~ , AL~ OIL AND GAS CONSERVATION COM~ION ~U~ `~ ~ 208 REPORT OF SUNDRY WELL OPERATION~~~ka ~'' ~ ~~~ ions Camr~i~siari 1. Operations Performed: "' ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension - 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development~ ^ Exploratory 183-048 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20931-00-00' 7. KB Elevation (ft): 57, 9. Well Name and Number: PBU 07-26 ~ 8. Property Designation: 10. Field /Pool(s): ADL 028309 ' Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11040 ~ feet true vertical 9206 ~ feet Plugs (measured) None Effective depth: measured 11000 feet Junk (measured) 11035 true vertical 9174 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2504' 13-3/8" 2504' 2504' 4930 2670 Intermediate 10062' 9-5/8" 10062' 8440' 6870 4760 Production Liner 1273' 7" 9767' - 10040' 8214' - 9206' 8160 7020 ~~N JUL ~ ~ 200$ Perforation Depth MD (ft): 10750' - 10796' Perforation Depth TVD (ft): 8974' - 9011' 5-1/2", 17# / 15.5# / 17# x 4-1/2", 12.6# 13Cr / L-80 9804' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): (2) 9'5/8" x 5-1/2" Baker'S-3' packers; 9489' & 9640'; 9-5/8" x 5-1/2" Baker'SAB' packer 9719' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and fin al pressure: Cut, pull and dress tubing stub to 9588'. Cut and pul l 9-5/8" casing from 1990'. Run 9-5/8" tieback to 1992', cement with 143 Bbls Class'G' w/ Gas Blok Yield 1.17, 803 cu ft / 686 sx . Run new Chrome tubin with overshot to 9595'. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 1,972 20,175 213 920 1,517 14. Attachments: ®Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nick Frazier, 564-5633 308-115 Printed Name T rrie Hubble Title Drilling Technologist a Prepared By Name/Number: D Signature Phone 564-4628 Date ( eyrie Hubble, 564-4628 . ~. _ ~~ T Form 10-404 Revised 0412006 SubmijO~iginal Only ORIGINAL S ~~~ ~~~i~ ~ ~ ~aQ~ (~~~ Digital Well File Page 1 of 1 ~ ~ We11:07-26 Well History Well Date Summary 07-26 4/11/2008 T/I/O=SSV/350/0. Temp=Sl. Check for cellar liner (pre-RWO). Unable to check for cellar liner because cellar was frozen. Wrapped and put a heater on cellar to thaw. 07-26 4/15/2008 T/I/O=ssv/350/0 Temp=Sl. Check cellar for liner (pre-RWO). Cellar is thawed. Dug down 6-8 in. no liner, left heater in cellar. 07-26 4/21/2008 ***WELL SHUT IN ON ARRIVAL***[pre rwo] PULLED P-PRONG & 5 1/2" PX PLUG BODY FROM X-NIP ~ 9629' MD DRIFTED TBG TO 9750' SLM W/ 3.70" CENT & S. BAILER [NO SAMPLE] ***LEFT WELL S/1, TURNED WELL VEFi TS6 * 07-26 4/22/2008 T/I/O =SSV/400/0. Temp = SI. Install cellar liner, SC leak (pre-RWO). 20" liner (#1) installed in cellar. 3" integral flange installed on OA. 07-26 4/22/2008 T/I/O = 250/360/0. Temp = SI. Tbg & IA FL's (pre E-line). No A/L. TBG FL C«? 318' (10 Bbls). IA FL ~ 132' (6 Bbls). 07-26 4/22/2008 T/I/0=250/450/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port to check void pressure, bled to 0 psi. Pumped through void until clean fluid returns achieved. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely no problems. PPPOT-IC: Stung into test port to check void pressure, bled to 0 psi. Pumped through void until clean fluid returns achieved. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely no problems. 07-26 4/24/2008 400/375/O Assist E-Line as directed. MIT Tubing @ 3500 psi.PASSED on second trv. (Rig prep). Pumped a total 19.4 bbls crude. MIT Tubing lost 20 psi on first 15 minute test, and 10 psi on the second 15 minute test for a total loss of 30 psi. Bled Tubing down to starting pressure. Bled back 19 bbls. Final WHP's 400/400/0 E-line has control of well upon departure. 07-26 4/24/2008 ***WELL SHUT-IN ON ARRIVAL*** INITIAL WHP 250/400/0 CORRELATE TO TUBING SUMMARY DATED 11/21/2002. SET BAKER QUIKDRILL MOE 9.651'. PT PLUG TO 3500 PSI, GOOD PT. JET CUT TUBING AT 9,598'. GOOD INDICATION AT SURFACE. DID 07-26 4/26/2008 T/I/0= 680/380/0 Temp= S/I Circ-Out (RWOPrep) Pumped 5 bbls. meth through hardline &casasco to F/L of 07-25 to insure open path, Pumped 10 bbls. meth and started pumping 1 %KCL down TBG taking return up IA through hardline &casasco to F/L of 07-25, ----Job In Progress---- ***WSR Continued to 04- 27-08*** 07-26 4/27/2008 T/I/0= 400/500/0. Temp SI. Monitor assist FB. (cellar). IA FL C~? surface. LRS preformed aCMIT-TxIA to 3500 psi. Monitored cellar during pumping & MIT. OAP unchanged. Liquid level in flutes did not change during pumping operations. Removed cellar liner 07-26 4/27/2008 ***WSR Continued from 04-26-08*** Temp= S/I Circ-Out, CMIT TxIA,3500 si ***PASSED**' ON 5TH TEST (RWO Prep) Pumped 250 bbls. 110* 1 %KCL starte ge ing ui up utes, it vac truck & DHD on location, resumed pumping and pumped a total of 983 bbls. 110* 1 %KCL followed with 160 bbls. 70* diesel down TBG taking returns up IA through hardline &casasco to 07-25, U-tube TxIA for 1 hr. to put F/P in place, CMIT TxIA Pumped 9.3 bbls. 30* diesel down IA to reach test pressure ~ 3500 psi T/IA lost 60/60 psi. in 1st 15 min. and 20/20 psi, in 2nd 15 min. for a total loss of 80/80 psi., Bleed WHP's, Final WHP's 0/0/0 "Annulus casing valves tagged & left open" 07-26 5/10/2008 T/I/0= 0/0/0 Set 5 1/8" Gray K BPV#601-A ~ 108" 1-2' ext.used. Installed 3" Gray V/R Plug in frontside O/A, removeTalve so ng can access well, I/A & O/A valves remain on backside. Print Date: 6/19/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 6/19/2008 :~ BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WORKOVER Start: 5/13/2008 End: ` " Rig Release: ~ V Contractor Name: ~~ e Rig Name: ~pyo,~ `~ W""' ~t~'~ Rig Number: Date From - To Hours Task ' Code's NPT ~ Phase ~ Description of Operations 5/13/2008 08:00 - 10:00 2.00 RIGD P PRE PJSM. Jack up rig and move off DS 6-22A and spot in an area to R/U for rig move. 10:00 - 16:00 6.00 RIGD P PRE Remove BOPE from cellar and secure on cradle. R/U and install rear booster wheels. Inspect draw works brakes and linkage while waiting on Roads and Pads to remove snow. Bridle up derrick and lay derrick over. Secure derrick for move. Clean up around well. 16:00 - 00:00 8.00 MOB P PRE PJSM. Move from DS 6 to DS 7. 5/14/2008 00:00 - 03:30 3.50 MOB P PRE Continue moving rig from DS 6 to DS 7. 03:30 - 04:30 1.00 MOB P PRE Move rig to far side of DS 7 and spot. Remove rear boosters. PJSM. Prep to raise Derrick. Inspect Derrick found areas that need a closer look. 04:30 - 06:00 1.50 MOB P PRE Raise Derrick and Pin in place 06:00 - 08:30 2.50 MOB P PRE Set Herculite and Place Rig Mats. Move rig down pad and spot over well. 08:30 - 12:00 3.50 MOB P PRE Level and Shim Rig. Double Vavle Annulus. Spot #2 Pump Module and Slop Tank. Zero Psi on IA and OA. 12:00 - 13:00 1.00 DHB P DECOMP P/U Lubricator and PT to 500 psi. Pull BPV, found zero si on tb D Lubricator 13:00 - 13:30 0.50 KILL P DECOMP R/U to Clrc Out Freeze Protect. PJSM with rig crew and vac truck drivers. PT Lines to 3500 psi. 13:30 - 15:00 1.50 KILL P DECOMP Pump 20 bbl High Visc Sweep and Chase with 715 bbls of 120 deg SW. Pumping at 10 bpm and 750 psi. 15:00 - 16:00 1.00 DHB P DECOMP Monitor Well. Well Dead. Set BPV with DSM Lubricator. Test BPV to 1000 psi from Below for 10 mins on chart. Good Test. Test Dart for BPV will be set when Tree is nippled down. UD Lubricator. 16:00 - 16:30 0.50 KILL P DECOMP B/D Lines and Hoses. Break Ice out of Derrick. 16:30 - 18:00 1.50 BOPSU P DECOMP PJSM. N/D tree and adapter flange. Function LDS, check hanger thread with x/o (19 turns), install test dart. Remove from tree from cellar. 18:00 - 21:00 3.00 BOPSU P DECOMP N/U BOPE. Change out variable pipe rams to 3-1/2" x 6". 21:00 - 21:30 0.50 BOPSU P DECOMP P/U test joint and R/U BOP testing equipment. 21:30 - 00:00 2.50 BOPSU P DECOMP Pressure test BOPE to 250 low ressur ressure. Each test was held for 5 charted minutes. AOGCC witness of test was waived by Jeff Jones. Test was witnessed by Doyon Toolpusher and BPX WSL. Test 1-Choke valves 1, 12, 13, 14, HCR kill, upper IBOP and annular preventer with 4" test joint. Test 2- Choke valves 9, 11, low IBOP, and manual kill Test 3- Choke valves 5, 8, 10, blind rams, and TIW valve Test 4- Choke valve 4, 6, 7, and dart valve Test 5- Choke valve 2 Test 6- Choke valve 3 Test 7- HCR choke Test 8- Manual choke 5/15/2008 00:00 - 03:00 3.00 BOPSU P DECOMP Continue testing BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 charted minutes. AOGCC witness of test was waived by Jeff Jones. Test was witnessed by Doyon tool pusher and BPX WSL. Test 9- Pipe rams with 4" test joint Test 10- Pipe rams with 5.5" test joint Accumulater Test- Starting Pressure- 3000 psi. Pressure after Printed: 6/10/2008 11:12:37 AM • ~ BP EXPLORATION Legal Well Name: 07-26 Common Well Name: 07-26 Event Name: WORKOVER Contractor Name: Rig Name: 'j~p.,,~p~ ~~ Date From - To Hours Task 5/15/2008 00:00 - 03:00 3.00 BOPSL Operations Summary Report Start: 5/13/2008 Rig Release: Rig Number: Page 2 of 10 Spud Date: 3/27/1983 End: Code NPT Phase P 03:00 - 04:00 I 1.001 DHB I P 04:00 - 04:30 I 0.501 CLEAN I P 04:30 - 05:30 1.00 CLEAN P 05:30 - 06:30 1.00 CLEAN P 06:30 - 14:00 ~ 7.50 ~ CLEAN ~ P 14:00 - 15:00 1.00 CLEAN P 15:00 - 17:00 2.00 CLEAN P 17:00 - 00:00 7.00 CLEAN P 5/16/2008 00:00 - 02:00 2.00 CLEAN P 02:00 - 03:00 I 1.00 I CLEAN I P 03:00 - 04:00 I 1.00 I CLEAN I P 04:00 - 04:30 I 0.501 CLEAN I P 04:30 - 07:30 3.00 CLEAN P 07:30 - 09:30 2.00 CLEAN P 09:30 - 10:00 0.50 CLEAN P 10:00 - 11:00 1.00 CLEAN P 11:00 - 13:30 I 2.50 I CLEAN I P Description of Operations DECOMP actuation- 1900 psi. First 200 psi recovery- 16 seconds. Full recovery- 79 seconds. 5 Nitrogen bottles at 2150 psi DECOMP UD test joint and R/D BOP testing equipment. Pull "K" plug test dart from BPV. P/U DSM lubricator extension and space out in BOPE. R/U DSM lubricator and test to 500 psi. good test. Pull and UD BPV. UD DSM lubricator, extension and tools. DECOMP P/U landing joint. M/U into tubing hanger with 5-7/8" Right Hand Acme threads. M/U into top drive. Pull tubing hanger free of tubing spool at 210.000 lbs. Pull hanger to rig floor wit DECOMP CBU at 11.5 bpm with 320 psi. Blow down circulating lines DECOMP UD Landing Joint and XO. B/O and UD Tbg Hanger. Blow Down Top Drive and M/U 5-1/2" FOX XO to FLoor Valve. DECOMP POOH and UD 5-1/2" FOX 15.5# 13C 294 Jts, 1 X Nipple, 3 GLM's and 17.76' Cut Joint. DECOMP R/D Tbg Handling Equipment and Clean and CLear Rlg FLoor. DECOMP M/U BHA 8-1/2" x 5-1/2" Dress Off Shoe, 2 Wash Pipe Extensions, Dress Off MIII, Washover Boot Basket, XO, 9-5/8" Casing Scraper, Bit Sub w/ Float, Bumper Sub, Pump Out Sub, XO, (9) 6-1/4" DC's, XO. Total Length = 321.58 ft. DECOMP RIH with Dress Off assembly (BHA #1) on 4" HT-38 drill pipe picked up from pipe shed 1x1 to 7447'. DECOMP Continue RIH with dress off assembly (BHA #1) on 4" HT-38 drill pipe picked up from pipe shed 1 xi with a total of 292 joints to 9563'. DECOMP Establish milling parameters of Up Wt- 192,000 Ibs; Down Wt- 153,000Ibs; Rotating Wt- 170,000 Ibs at 40 rpm with 6000 ft-Ibs free torque; Pump Pressure- 320 psi at 40 bpm. RIH and to tubin stub at 9587' and S/O 5000 Ibs. P/U and work dress off shoe over tubing stub at 40 rpm, torque increased to 7000 to 7500 ft-Ibs. P/U and work dress off shoe over tubing stub once more. Stop rotation and continue RIH. Tag top of tubing stub with dress off mill at 9602'. P/U and rotate at 40 rpm and 6000 ft-Ibs free torque, pump rate at 6 bpm with 650 psi. Mill off 6" of tubin stub with 9000 ft-Ibs torque and 5000 Ibs WOB, pump pressure increase to 970 psi. P/U and confirm depth. P/U off tubing stub. Final depth of tubing stub at 9588'. DECOMP Pump 20 bbl high visc sweep at 4 bpm and 320 psi. Chase sweep out of hole at 11.5 bpm and 2200 psi. Sweep did not bring back any noticeable increase of metal to surface. DECOMP Pump dry job slug. Blow down top drive. Monitor well, well stable. DECOMP POOH standing back 4" HT-38 drill pipe in derrick. DECOMP Stand Back DC's and UD Dress Off BHA DECOMP Clear and Clean Rig Floor. DECOMP PJSM with E-Line Crew. R/U E-Line Sheaves, Line and USIT Tools. DECOMP Zero USIT Tools at Rig Floor, RIH with USIT and Log from 4100' to surface in cement and corrosion mode. Found To of Cement in 9-5/8"_x 13-3/8" annulus_at_2050'. Pick Cut Depth Printed: 6/10/2008 11:12:37 AM C C: BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WORKOVER Start: 5/13/2008 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours I! Task Code NPT Phase Description of Operations 5/16/2008 11:00 - 13:30 2.50 CLEAN P DECOMP of 1990'. 13:30 - 14:30 1.00 CLEAN P DECOMP Rig Down E-Line Tools. 14:30 - 15:00 0.50 CLEAN P DECOMP P/U Single Joint of DP from Pipe Shed and M/U 9-5/8" HES RBP. 15:00 - 15:30 0.50 CLEAN P DECOMP PT Casing from Surface to 3500 psi for 30 mins -good Test. Test done due to unexplained fluid loss. CMIT Pre-Rig was passing test. Confirmed on chart. 15:30 - 16:30 1.00 DHB P TIEB1 RIH with RBP on 4" DP from Derrick. 16:30 - 17:00 0.50 DHB P TIE61 Set RBP at 2105' to of tool . POOH with 2 singles plus one full stand. Test to 1000 psi as per program for 15 mins -good test. 17:00 - 18:30 1.50 DHB P TIEB1 R/U to Dump Sand. Place 2200 Ibs of 20-40 river sand on top of plug (+/- 50'). 18:30 - 19:00 0.50 DHB P TIEB1 Chase sand out of drill pipe at 1 bpm with 50 psi. 19:00 - 20:00 1.00 DHB P TIEB1 Allow sand to settle for 15 minutes. P/U 1 stand of drill pipe and RIH. Tag top of sand 2082'. POOH 1 stand and allow sand to settle for an additional 15 minutes. RIH and re-tap top of sand at 20 1' 20:00 - 21:00 1.00 DHB P TIEBi POOH standing back 4" HT-38 drill pipe in derrick. B/O and L/D RBP running tool. 21:00 - 21:30 0.50 CASE P TIE61 _P/U Baker multi string cutter and centralizer on 1 stand of drill collars. Total length of BHA #2- 107.70 ft. 21:30 - 22:30 1.00 CASE P TIEB1 RIH with BHA #2 on 4" HT-38 drill pipe from derrick to 1914'. Establish parameters of Up and Down Wt- 75,000 Ibs. Pump rate at 3 bpm with 160 psi. 22:30 - 23:00 0.50 CASE P TIE61 P/U stand #20 and RIH. Locate upper casing collar at 1976' in hole placing the cutter and casing collar at 1973'. Continue RIH with stand #21. Locate lower collar at 2017' in on stand 21 putting the collar at 2014'. P/U 24' to put the cutter at 1990'. 23:00 - 00:00 1.00 CASE P TIEB1 PJSM with rig crew and CH2MHill vac truck support. Discuss the displacement operation and procedures. Ensure that precausions are taken to avoid any incidents. Displace well to 9.8 ppg NaCI Brine at 8 bpm with 1240 psi. 5/17/2008 00:00 - 00:30 0.50 CASE P TIE61 PJSM with rig crew, CH2MHill, and LRHOS. Discuss Arctic Pac displacement procedure, double checking lines, assure that each crew member understands his job, and stop the job if there is any questions. Pressure test LRHOS circulating lines to 3500 psi, good test. 00:30 - 01:00 0.50 CASE P TIE61 Start cuttin 9-5/8" casin t ' by rotating work string at 30 rpm with 2000 ft-Ibs torque, pump rate at 2.5 bpm with 160 psi. Bring pump rate up to 4.3 bpm with 370 psi and again to 6 bpm with 880 psi. Torque increase to 5000 to 8000 ft-Ibs, lost pump pressure to 620 psi, OA pressure came up to 250 psi. 01:00 - 02:30 1.50 CASE P TIE61 Displace drill pipe with diesel at 3 bpm with 180 psi with LRHOS. Had 5 bbls awa takin returns out the flow line when fluid was noticed comin u behind the 13-3/8" casin an into the conductor i e. Shut down LRHOS. Got rig vac system and vac truck to keep fluid level inside conductor. Continue to pump diesel with LRHOS. Pumped 20 bbls hot diesel. Shut annular preventer and lined up returns up the OA to the arctic pac tank. Pumped 55 bbls hot diesel. Lined up rig pump, pump 40 bbls SafeSurf O pill and 21 bbls hot seawater at 4 bpm with 300 psi to spot diesel and SafeSurf O in the 9-5/8" x Printed: 6/10/2008 11:12:37 AM • BP EXPLORATION Operations Summary Report Page 4 of 10 ~ Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WORKOVER Start: 5/13/2008 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task ' Code I NPT ~ Phase ! Description of Operations 5/17/2008 01:00 - 02:30 1.50 CASE P TIEB1 13-3/8". 02:30 - 04:30 2.00 CASE P TIEB1 Shut down pumping. Allow diesel and SafeSurf O pill to soak into the arctic pac in the OA. 04:30 - 05:30 1.00 CASE P TIE61 Line up and pump 20 bbl SafeSurf O pill at 4 bpm with 240 psi. Follow with 20 bbl high visc sweep and chase out of hole with 9.8 ppg brine. 05:30- 06:00 0.50 CASE P TIEB1 Monitor well. Gas breaking out of arctic pac in the 9-5/8" x 13-3/8" annulus. Break circulation and CBU at 7.5 bpm with 930 psi. 06:00 - 06:30 0.50 CASE P TIE61 Monitor well. OA- dead, IA- dead, DP- dead. 06:30 - 07:00 0.50 CASE P TIE61 P H with Baker multi strin casin cutter standing back 4" HT-38 drill pipe in derrick. UD casing cutter and stabilizer. 07:00 - 07:30 0.50 CASE P TIE81 Clear and clean rig floor, Pull wear ring. 07:30 - 09:00 1.50 CASE P TIEB1 PJSM with rig crew and Baker Fisherman. Discuss issues with spearing and fishing 9-5/8" casing. P/U 9-5/8" spear assembly (BHA #3) consisting of 8-1/4" ITCO spear and extension, stop sub, and x/o sub. Total length of BHA #3- 14.73 ft. RIH and engage 9-5/8" casing. BOLDS. Pull hanger free with 140,000. lbs. U Wt of casin strin - 125 000 lbs. 09:00 - 09:30 0.50 CASE P TIEBi CBU at 5 bpm with 90 psi. 09:30 - 10:30 1.00 CASE P TIEBi Pull casing hanger to rig floor. Install false table for 9-5/8 casing slips. Break out and UD spear and hanger. 10:30 - 14:30 4.00 CASE P TIE61 POOH and UD 9-5/8", 47#, L-80, BTC casing 1x1. Average break out torque- 40,000 ft-Ibs. 14:30 - 15:30 1.00 CASE P TIEB1 Clear and clean rig floor. 15:30 - 17:00 1.50 CASE P TIE61 P/U 9-5/8" casin dress off assembl BHA #4 consisting of dress off shoe, washpipe extension, dress off mill, drive sub, x/o sub, 13-3/8" casing scraper, bit sub with float, x/o sub, bumper sub, x/o, 3 stands of 6-1/4" drill collars from derrick, and x/o sub. Total length of BHA #4- 312.57 ft. 17:00 - 17:30 0.50 CASE P TIEB1 RIH with 4" HT-38 drill pipe from derrick to 1929' 17:30 - 18:30 1.00 CASE P TIE61 M/U to top drive and establish parameters of Up Wt- 87,000 Ibs; Down Wt- 87,000 Ibs; Rotating Wt- 87,000 Ibs at 40 rpm with 2500 ft-Ibs free torque; Pump Pressure- 100 psi at 4 bpm. Continue RIH with dress off mill and tag casing at 1990'. Dress off 6" of casin stub. Final depth of casing stub ~ 1990'. 18:30 - 20:00 1.50 CASE P TIEB1 Pump 20 bbl high visc sweep and chased with a 20 bbl SafeSurf O sweep. Pump sweeps out of the hole at 5 bpm with 140 psi. Sweep brought back a small increase of arctic pac. 20:00 - 20:30 0.50 CASE P TIEB1 Monitor well, well static. POOH standing back 4" HT-38 drill pipe in derrick. 20:30 - 21:30 1.00 CASE P TIE61 POOH with BHA #4 and stand back 3 stands of drill collars in derrick. 21:30 - 22:00 0.50 CASE P TIEB1 Clear and clean rig floor. 22:00 - 23:00 1.00 CASE P TIEB1 P HES 1 - and RIH on 4" HT-38 drill pipe from derrick to 1980'. 23:00 - 00:00 1.00 CASE P TIEB1 Establish parameters of Up Wt- 70,000 Ibs; Down Wt- 70,000 lbs. mot RTTS at 1980'. Turn 1 full turn to the right and set 20,000 Ibs down on RTTS. Line up to circulate down drill pipe. 15/18/2008 100:00 - 00:30 I 0.501 CASE I P TIEB1 Bleed pressure. R/D testing equipment and lines. Unseat RTTS. Printed: 6/10/2008 11:12:37 AM ~ • BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WORKOVER Start: 5/13/2008 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date I, Frorn - To II Hours Task Code ~, NPT Phase I, Description of Operations 5/18/2008 00:30 - 01:30 1.00 CASE P TIEB1 POOH standing back 4" HT-38 drill pipe in derrick. VD HES 01:30 - 03:00 1.50 CASE P TIEB1 R/U rig floor to run 9-5/8" casing patch. Load wiper plug in CMT head. R/U Doyon Torque Turn equipment. 03:00 - 03:30 0.50 CASE P TIEB1 PJSM with rig crew. Discuss procedures and hazards of running 9-5/8" casing. 03:30 - 07:00 3.50 CASE P TIEB1 P/U and Run 9-5/8" Casing Patch, ES Cementer, BTC x Hydril 563 XO, 51 Joints of 9-5/8", 47#, L-80, Hydril 563. Ridgid Body Centralizers Run on every joint above the ES Cementer, except Joint #51. All Hydril 563 Connection Torque Turned to 15,800 ft-Ibs as per Hydril Make Up Procedures. 07:00 - 07:30 0.50 CASE P TIEB1 C/O Bails for Cement Head. 07:30 - 08:00 0.50 CASE P TIEB1 M/U 5 ft Casing Pup Joint and M/U to String. Up Wt = 125,000 Ibs S/O Wt = 125,000 Ibs. With 5ft Pup Joint M/U to String S/O and Start Takina Wt at 1992; P/U and Patch was latched up - P/U to 10,000 Ibs over. S/O 25,000 Ibs and then P/U to 25,000 Ibs over to get good bite. S/O 70,000 Ibs and then P/U to 250,000 Ibs. S/O to 120,000 Ibs over string Wt hand hold. 08:00 - 11:00 3.00 CASE P TIEB1 M/U Cement XO and Cement Head. Pressure Test Lines and Then Begin to Pressure Up on Casing for Pressure Test . Cement Head Leakin at ACME Thread Re-Tighten and Attempt to PT again, found XO Leaking at BTC Threads. Break Off and Cement Head, Change Out Seals on Cement Head. Check XO. M/U XO and ement Haan anri Attamnt to PT again. Still Leaking. Call Out for new XO. M/U XO to String and M/U Cement Head. PT Lines again and Pressure U to 1000 si on Caisn .All Holdin Good 11:00 - 12:00 1.00 CASE P TIEB1 Pressure Test Casing to 2000 psi for 30mins. Good Test. Circulate at 3.5 bpm and 110 psi for -30 bbls. 12:00 - 12:30 0.50 CASE P TIEB1 PJSM with Rig Crew, Vac Truck Drivers, Dowell, Haliburton on Cement Job. 12:30 - 13:30 1.00 CASE P TIEB1 Circ 290 bbls of warm 9.8 ppg Brine to warm up casing and well prior to cement job. Circulate at 3.8 bpm and 150 psi. 13:30 - 14:00 0.50 CEMT P TIEB1 PT Cementers to 4250 psi. Pump 143 bbls of 15.8 ppg cement w/ Gas Block at ~4.8 bpm and 700 psi pump pressure. 14:00 - 15:30 1.50 CEMT P TIE61 Kick Out ES Cementer Closing Plug and Chase with 5 bbls from Dowell and then 140 bbls of 9.8 ppg with rig pumps. Saw Cement at surface with 120 bbls of Displacement. Wlth Cement at surface Drop Rate to 1.5 bpm and Choke Back on Return line. Hold between 200 and 500 si on choke and squeeze cement uo 13-3/8" by 20" annulus. Maintain back 2-3 bbls of cement through the flutes and -20 bbl of cement at surface into flow back tank. Cement in Place at 15:15 hrs. 15:30 - 16:30 1.00 CEMT P TIE61 Flush out BOP stack and circulating lines. Clear and clean rig floor. Suck out casing joint. 16:30 - 17:30 1.00 WHSUR P TIEB1 ND BOPE between the tubing spool and casing head. Install Gray 13-3/8 x 9-5/8 Gen 3 emergency sli sand per Cameron Tech. Slack off and set 100,000 Ibs in slips. 17:30 - 18:00 0.50 WHSUR P TIEB1 R/U Wachs cutter and cut 9-5/8" casing. 18:00 - 19:00 1.00 WHSUR P TIEB1 N/D old tubing spool from BOPE and remove from cellar. Printed: 6/10/2008 11:12:37 AM BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WORKOVER Start: 5/13/2008 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date 5/18/2008 5/19/2008 100:00 - 01:00 I 1.001 CASE I P From - To Hours Task Code NPT Phase Description of Operations TIE61 Install new Gray Gen 3 lower emergency packoff in casing head. P/U and N/U new McEvoy 13-3/8 x 13-5/8 5M tubing spool with secondary packoff to casing head. R/U and pressure test packoffs and the break between the tubing and casing head to 3800 psi. Hold test for 30 minutes, good test. Test witnessed by BPX WSL. TIEB1 N/U BOPE. R/U new Dutch System riser to BOPE. TIEB1 test BOPE. Pressure test the tubing spool/BOP stack break to 250 psi low test and 3500 psi high pressure test. Hold each test for 5 minutes charted minutes. Test witnessed by Doyon Toolpusher and BPX WSL. R/D BOP testing equipment. TIEB1 P/U and break 9-5/8" spear assembly. L/D down spear. Received word from Schlumberger that the cement had reached the 500 psi compressive strength at 00:00 hrs (10 hrs and 34 min after cement job). TIEB1 P/U drill out assembly (BHA #5) consisting of a 8-1/2" rock bit, (2) 7" boot baskets, bit sub, o/x sub, bumper sub, jars, x/o, 3 stands of 6-1/4" drill collars from derrick, and x/o sub. Total length of BHA #5- 312.54 ft. TIEB1 RIH with BHA #5 on 18 stands of 4" HT-38 drill pipe from derrick to 1929'. Establish drilling parameters of Up Wt- 80,000 Ibs; Down Wt- 85,000; Rotating Wt- 85,000 Ibs at 50 rpm with 2000 ft-Ibs free torque; Pump Pressure- 130 psi at 5 bpm. Received word from Schlumberger that the cement had reached 1000 psi compressive strength at 02:30 hrs (12 hrs and 37 min after cement job) TIE61 RIH and to to of soft cement at 1969'. P/U and control drill down to the top of ES Cementer at 1976'. Mill on ES Cementer with 10,000 Ibs WOB at 60 rpm and 3000 ft-Ibs torque. Drill through cementer at 1979'. Continue drill cement with 2000 Ibs WOB. Hard cement encountered at 1986'. Control drill through cement with 5000 to 10,000 Ibs WOB and no extra torque to 2025'. Not taking any weight from 2025 to top of sand at 2053'. Wash through sand to 2057'. TIE61 Pump 20 bbl high visc sweep at 8 bpm with 280 psi. Returns show good hard cement with metal and rubber. Bottoms up returns had softer cement and sand. Sweep brought back in increase of metal and cement. TIE61 Dry drill at 60 rpm with 3000 to 4000 ft-Ibs torque on top of sand and making hole to 2061'. P/U and wash down to 2070'. TIEB1 Pump high visc sweep at 8 bpm with 280 psi. Bottoms up brought back sand. The sweep brought back an increase in sand and cleaned up quickly. TIE61 POOH with cement track clean out assembly standing back 4" HT-38 drill pipe in derrick. TIEB1 POOH with BHA #5 standing back drill collars and L/D bit. Clean out -1 gallon cement and small amounts of metal in boot baskets TIEB1 P/U RCJB BHA #6 consisting of RCJB, (2) 7" boot baskets, bit sub, bumper sub, jars, pump out sub, and x/o. TIEB1 R/U and ressure test 9-5/8" casin to 3500 si for 30 charted minutes, ood test. Bleed pressure and R/D 19:00 - 21:00 I 2.00 I W HSUR I P 21:00 - 23:00 2.00 WHSUR P 23:00 - 00:00 1.00 WHSUR P 01:00 - 02:00 I 1.001 CASE I P 02:00 - 02:30 0.501 CASE P 02:30 - 04:30 I 2.001 DRILL I P 04:30 - 05:00 I 0.501 DRILL I P 05:00 - 05:30 I 0.501 DRILL I P 05:30 - 06:00 I 0.501 DRILL I P 06:00 - 06:30 I 0.501 DRILL I P 06:30 - 07:30 I 1.001 DRILL I P 07:30 - 08:00 0.50 ~ CASE ~ P 08:00 - 09:30 I 1.501 CASE I P Printed: 6/10/2008 11:12:37 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Event Name: WORKOVER Start: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours ' Task Code NPT Phase 5/13/2008 Page 7 of 10 ~ Spud Date: 3/27/1983 End: Description of Operations 5/19/2008 09:30 - 10:00 0.50 CASE P TIEB1 M/U RCJB (BHA #6) consisting of RCJB, (2) 7" boot baskets, bit sub, bumper sub, jars, pump out sub, x/o, 3 stands of 6-1/4" drill collars, and x/o. Total length of BHA #6- 320.49 ft. 10:00 - 11:00 1.00 CASE P TIE61 Slip and Cut 70' of drill line. 11:00 - 12:30 1.50 CASE P TIEB1 RIH with BHA #6 on 4" HT-38 drill pipe from derrick to 2014'. 12:30 - 13:00 0.50 CASE P TIE61 Establish parameters of Up Wt- 72,000 Ibs; Down Wt- 72,000 Ibs; Rotating Wt- 87,000 Ibs at 40 rpm with 2000 ft-Ibs torque; Pump Pressure- 420 psi at 5 bpm. Continue RIH and tag top of sand at 2075'. Drop ball and seat at 3 bpm with 660 psi. Wash sand to 2085'. 13:00 - 13:30 0.50 CASE P TIEB1 Pump high visc sweep at 6.6 bpm with 2950 psi. Sweep brought back sand. 13:30 - 14:30 1.00 CASE P TIE61 Monitor well, well stable. Blow down top drive and POOH standing back 4" HT-38 drill pipe in derrick. 14:30 - 15:00 0.50 CASE P TIEB1 POOH with BHA #6. Stand back 3 stands of 6-1/4" drill collars. Clean out RCJB and boot baskets. Recover several large pieces of aluminum and debris. 15:00 - 15:30 0.50 CASE P TIE61 M/U RCJB (BHA #7) consisting of RCJB, (2) 7" boot baskets, bit sub, bumper sub, jars, pump out sub, x/o, 3 stands of 6-1/4" drill collars, and x/o. Total length of BHA #6- 320.49 ft. 15:30 - 16:00 0.50 CASE P TIEB1 RIH with BHA #7 on 4" HT-38 drill pipe from derrick to 2014'. 16:00 - 16:30 0.50 CASE P TIE61 Establish parameters of Up Wt- 72,000 Ibs; Down Wt- 72,000 Ibs; Rotating Wt- 87,000 Ibs at 40 rpm with 2000 ft-Ibs torque; Pump Pressure- 420 psi at 5 bpm. Continue RIH and tag top of sand at 2085'. Drop ball and seat at 3.8 bpm with 2040 psi. 16:30 - 17:30 1.00 CASE P TIEB1 Open pump out sub. Pump 40 bbl high visc sweep and chase with 8.5 ppg seawater to displace well at 12 bpm with 810 psi. Blow down top drive. 17:30 - 18:30 1.00 CASE P TIEB1 POOH and stand back 4" HT-38 drill pipe in derrick. 18:30 - 19:00 0.50 CASE P TIE61 POOH with BHA #7. Stand back 3 stands of 6-1/4" drill collars. Clean out RCJB and boot baskets. No recovery in RCJB and only small pieces of aluminum and sand in boot baskets. 19:00 - 19:30 0.50 CASE P TIEB1 P/U HES RBP retrieving tool and RIH on 4" HT-38 drill pipe from derrick to 2040'. Establish parameters of Up Wt- 72,000 Ibs; Down Wt- 72,000 Ibs; Pump Pressure- 2040 psi at 3.8 bpm. Continue RIH and tag top of sand at 2100'. 19:30 - 20:00 0.50 CASE P TIEB1 Wash down through sand to top of HES RBP at 2105'. atch onto RBP. P/U to 82,000 Ibs to confirm engagement. S/O 15,000 Ib on RBP. 20:00 - 21:30 1.50 CASE P TIEB1 Line up and pump high visc sweep at 13 bpm 1050 psi. Sweep brought and increase in sand at the shakers. Well cleaned up, shut down pumps. Work drill pipe 1/2 turn to the right to unseat HES RBP. P/U overpull 15,000 Ibs to release RBP, P/U 10'. Ran in 10' past setting depth to 2115' to confirm release. 21:30 - 22:30 1.00 CASE P TIEB1 POOH with HES RBP standing back 4" HT-38 drill pipe in derrick. L/D RBP and retrieving tool. 22:30 - 00:00 1.50 CASE P TIEB1 Gather and M/U BHA #8 (FasDrill Plug drill out assy) consisting of 3.7"junk mill, bit sub, 8 joints of 2-7/8" PAC drill pipe, 3 x/o subs, 9-5/8" casing scraper, bit sub with float, bumper sub, jars, pump out sub, ox/ sub, 3 stands of 6-3/4" drill collars from derrick, and x/o sub. Total length of BHA #8- 570.10 ft. Printed: 6/10/2008 11:12:37 AM C7 BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WORKOVER Start: 5/13/2008 End: Contractor Name: Rig Release: Rig Name: Rig Number: i .Date From - To Hours Task ', Code ~i NPT Phase ', Description of Operations - - 5/20/2008 00:00 - 05:00 5.00 CLEAN P DECOMP RIH with BHA #8 on 4" HT-38 drill pipe from derrick to 9591'. 05:00 - 06:30 1.50 CLEAN P DECOMP Establish milling parameters of Up Wt- 207,000 Ibs; Down Wt- 145,000; Rotating Wt- 175,000 Ibs at 40 rpm with 6500 ft-Ibs free torque; Pump Pressure- 750 psi at 5 bpm. Continue RIH and tap FasDrill Plug at 9639'. Commence drilling on plug with 40 rpm and 9000 ft-Ibs torque, on bottom pump pressure up to 1120 psi at 5 bpm. Drill through FasDrill plug and lost returns. Continue pushing plug to 9655' ("X" nipple w/ ID of 3.856". Attempt to P/U and hung up at the at 9633'. Make several attempt to pull past 9633. Pump 20 bbl High Visc Sweep and brought up pump rate to 10 bpm and 3400 psi. Able work back up and ull past 9633'. 06:30 - 10:00 3.50 CLEAN P DECOMP Clrc out sweep at 10 bpm and 3400 psi. With sweep 1/2 way out of hole had as breakin out at surface still losin fluid at -2bpm while circulating, Circulate out gas and monitor well. Still losing fluid while circulating, back down rate to 5 bpm while waiting for more fluid to arrive on location. 10:00 - 11:00 1.00 CLEAN P DECOMP More fluid on location. RIH while pumping and rotating. Tag Plu a ain at -9655 feet. Mill on Plu fora roxim tel 5 feet with 5 000 Ibs wei ht on bit. Push Throu h t X ush down hole. After 9700 feet plug going down hole easily, able to push down out of tail pipe with no rotation or pumps. Push out through bottom of tail pine to 9840'. 11:00 - 12:00 1.00 CLEAN P DECOMP Circulate bottoms up at 10 bpm and 3450 psi. Loss Rate at 75 bah while circulatina. No gas seen at bottoms up. Seeing a lot of sand during circulating. Total Losses for Tour = 652 bbls. 12:00 - 14:00 2.00 CLEAN P DECOMP POOH and VD 6 joints of Drill Pipe. With Mill still in 5-1/2" Tail Pipe circulate 20 bbl high visc sweep and chase out of the hole at 10.8 bpm and 3450 psi to clean out sand in well. Loss rate at 75 b h um in and -50 b h static. Well cleaned up considerably after sweep. 14:00 - 20:30 6.50 CLEAN P DECOMP POOH and VD 4" HT-38 DP to 570' md. 20:30 - 22:00 1.50 CLEAN P DECOMP VD BHA #8 - FasDril Millin / Scra er Clean-out Assembl . 22:00 - 23:00 1.00 CLEAN P DECOMP Clean and clear Rig Floor in preparation for running 5-1/2" 17# 13cr80 Vam Top Completion. 23:00 - 23:30 0.50 CLEAN P DECOMP M/U Wear Ring pulling tool and pull Wear Ring. 23:30 - 00:00 0.50 BUNCO RUNCMP R/U equipment to run 5-1/2" 17# 13cr80 Vam Top Completion. Change out bales and elevators. R/U Single jt Compensator. R/U & Test Power Tongs. R/U Torque Turn equipment. R/U & Function Test Stabbing Board. Total Losses for Tour = 407 bbls. Total Losses for Day = 1059 bbls. 5/21/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Continue R/U to run 5-1/2" 17# 13cr80 Vam Top HC Completion. 01:00 - 02:30 1.50 BUNCO RUNCMP PJSM -Running 5-1/2" 17# 13cr80 Vam Top HC Completion with Doyon Csg Hand and Baker Completion Hand. P/U &RIH w/ Completion to 156' and (X-Nipple Assembly #2). Use Charge pump for continuous hole fill. Utilize Torque Turn Services on all connections with optimum make-up torque for Vam Top at 6580 ft-Ibs. Use Jet Lube Seal Guard thread compound. Baker-lok all connections below packer. 02:30 - 03:00 0.50 BUNCO RUNCMP Continue to run 5-1/2" 17# 13cr80 Vam Top HC Completion to 317' and (Tbg jt #5). 03:00 - 05:00 2.00 BUNCO RREP RUNCMP Power tongs jammed up and stuck on pipe. Troubleshoot and Printed: 6/10/2008 11:12:37 AM • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Event Name: WORKOVER Contractor Name: Rig Name: Spud Date: 3/27/1983 Start: 5/13/2008 End: Rig Release: Rig Number: .Date From - To Hours Task ', Code ', NPT -_ _ _ - -- 1I--~ 5/21/2008 03:00 - 05:00 2.00 RUNCOwIV RREP 05:00 - 10:00 5.00 10:00 - 11:00 1.00 11:00 - 13:30 2.50 13:30 - 14:30 1.00 14:30 - 20:00 5.50 20:00 - 21:30 1.50 21:30 - 22:00 0.50 RU 22:00 - 00:00 2.00 RU 5/22/2008 00:00 - 02:00 2.00 RU 02:00 - 04:00 2.00 RU 04:00 - 05:30 1.50 RU 05:30 - 07:30 2.00 BOPSUF~ P 07:30 - 09:00 1.50 WHSUR P Phase Description of Operations RUNCMP remove tong rams and dies to remove tongs from pipe. Change out Power tongs. RUNCMP Continue to run 5-1/2" 17# 13cr80 Vam Top HC Completion f/ 317' to 4,082' md. Continuously fill hole using charge pump. Use Torque Turn services w/optimum M/U Torque = 6,580 ft-Ibs. Use Jet Lube Seal Guard thread compound on all connections. RUNCMP Safety Stand-down with Jim Willingham, Herb Williams and Jeff Kilfoyle. Discussed recent spill from Slop Tank and entire crew viewed incident site. Crews tasked with developing plan for reducing spills. RUNCMP Continue to run 5-1/2" 17# 13cr80 Vam Top HC Completion f/ 4,082' to 4,584' md. Use charge pump to keep hole full. Use Torque Turn services w/ optimum M/U Torque = 6,580 ft-Ibs. Use Jet Lube Seal Guard thread compound on all connections. Loss rate while running tbg = -20 bph. Losses for tour = 247 bbls. RUNCMP Safety Stand-down with Jim Willingham, Herb Williams and Jeff Kilfoyle. Discussed recent spill from Slop Tank and entire crew viewed incident site. Crews tasked with developing plan for reducing spills. RUNCMP Continue to run 5-1/2" 17# 13cr80 Vam Top HC Completion. Replace Jt #211 w/ Jt #226 due to bad pin. Total of 224 Jts run with 3 - 5.5" x1.5" GLM's, 3- X Nipples, and Baker 9.625"x5.5" S-3 Packer. RUNCMP M/U Jt #225 and RIH. Observe shear pins shearing at 9,596' md. No qo on Tbg stump ~ 9,600' md. POH and L/D Jt 225. Calculate space out for completion with 21.3' RKB and 4.57' for Tbg hanger. No tbg pup jts needed. 5.4' of swallow by Unique overshot on Tbg stub w/final depth of overshot ~ 9,596' md. R/D Compensator. Change out Tbg handling equipment for landing hanger. Blow down Choke & Hole fill lines. RUNCMP M/U landing 't and hanger. Land tubin han er and RILDS._ R/U to reverse circulate heated seawater and corrosion inhibitor. RUNCMP PJSM -Circulating Corrosion Inhibitor. Pressure test all lines to 3500 psi. Line up to reverse circulate. Reverse in 230 bbls of heated seawater ~ 3 bpm / 170 psi. Losses for tour = 149 bbls. RUNCMP Reverse circulate in 430 bbls of 140 deg sea water with corrosion Inhibitor at 3 bpm with 170 psi. RUNCMP Dropped rod and 1-7/8" ball and pump down to_RHCM.__ Pressure up to 3,500 psi and set tubing for 30 charted minutes. Bled down pressure to 1,500 p: and shut in TIW. Pressured up to 3,500 psi on Annulus to 3.500 osi for 30 charted minutes. Bled off tubing pressure and sheared the DCR at 500 si differential. Circulated through DCR at 3 bpm with 140 psi the long way and 200 psi reversing. RUNCMP L/D Landing joint. Set TWC pressure test from below to 1,000 psi for 10 charted minutes, and tested from above to 3,500 psi for 10 charted minutes. R/D B/D Circulating Lines. RUNCMP N/D BOPE, Stand back BOPs on pedestal. RUNCMP N/U Adapter and Tree. Printed: 6/10/2008 11:12:37 AM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WORKOVER Start: 5/13/2008 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours ~, Task Code NPT Phase Description of Operations 5/22/2008 09:00 - 09:30 0.50 WHSUR P RUNCMP Pressure Test Hanger Void to 5,000 psi. 09:30 - 12:30 3.00 WHSUR P RUNCMP Attempt to pressure test production tree to 5,000 psi, TWC failed 2x. 12:30 - 14:00 1.50 WHSUR P RUNCMP Drain Tree and C/O TWC. 14:00 - 15:30 1.50 WHSUR P RUNCMP Refill Production Tree and test to 5,000 psi for 30 charted minutes. 15:30 - 16:00 0.50 WHSUR P RUNCMP Drain Tree and pull TWC 16:00 - 17:30 1.50 WHSUR P RUNCMP R/U LRS and pressure test lines to 3,500 psi. Pump 150 bbls of Diesel Freeze Protection, at 2 bpm with 400 psi. 17:30 - 18:30 1.00 WHSUR P RUNCMP R/U and Allow wellbore to U-Tube Diesel. 18:30 - 20:30 2.00 WHSUR P RUNCMP Blow down lines, remove secondary annulus valve, secure the wellhead. Rig release at 20:30. Printed: 6/10/2008 11:12:37 AM BP EXPLORATION Page 1 of 2 Wellbore Equipment Report Legal Well Name: 07-26 Spud Date: 3/27/1983 Common Well Name: 07-26 Report #: 2 Report Date: 5/21/2008 Event Name: WORKOVER Start: 5/13/2008 End: Assemb ly Name: TUBI NG Install D ate: 5/21/2008 Suspen ded From:SUR FACE EQUIPM ENT @ (ft) Pull Dat e: TMD C orrection: (ft) Final St ring Weight: (Ib) Landed TMD: 9,59 4.68 (ft) Landed Weight: (Ib) om. Siz Com onent p Description # Jts I 0 ~ t ~ Grade; ~~~ L th To et i~ Manufacturer Model # ',Connection'. Comments (in) (in ) ~, (i ~ (Ib/ft) ~f ~ ~ft~ 1 21.3 13.62 TUBING HANGER 1 4.89 13.51 1.2 21.3 CAMERON CONTRO TCII 7.00 X-O 1 4.89 7.07 26.0 13CR80 0.9 22.5 TCII 5.50 TUBING PUPJOINT 1 4.89 6.03 17.0 13CR80 2.2 23.5 VAM TOP 5.50 TUBING JOINTS 51 4.89 5.50 17.0 13CR80 2,134.9 25.8 VAM TOP 5.50 TUBING PUPJOINT 1 4.89 6.03 17.0 13CR80 9.9 2,160.7 VAM TOP 5.50 X-O 1 4.89 6.03 17.0 13CR80 9.9 2,170.7 VAM TOP 5.50 X NIPPLE 1 4.56 5.85 9CR 1.5 2,180.6 HALLIBURTON TCII 5.50 X-O 1 4.89 5.96 17.0 13CR80 9.8 2,182.1 TCII 5.50 TUBING JOINTS 41 4.89 5.50 17.0 13CR80 1,708.0 2,191.9 VAM TOP 5.50 X-O 1 4.89 6.03 17.0 13CR80 9.91 3,900.0 VAM TOP 5.50 GAS LIFT MANDRE 1 4.75 7.83 9CR 9.1 3,909.9 SCHLUMBERGER TCII 5.50 X-O 1 4.89 5.96 17.0 13CR80 9.8 3,919.1 TCII 5.50 TUBING JOINTS 7 4.89 5.50 17.0 13CR80 2,916.6 3,929.01 VAM TOP 5.50 X-O 1 4.89 6.03 17.0 13CR80 9.9 6,845.6 VAM TOP 5.50 GAS LIFT MANDRE 1 4.75 7.8 9CR 9.1 6,855.61 SCHLUMBERGER TCII 5.50 X-O 1 4.89 5.96 17.0 13CR80 9.6 6,864.7 TCII 5.50 TUBING JOINTS 5 4.89 5.50 17.0 13CR80 2,084.7 6,874.3 VAM TOP 5.50 X-O 1 4.89 6.03 17.0 13CR80 9.9 8,959.0 VAM TOP 5.50 GAS LIFT MANDRE 1 4.75 7.83 9CR 9.3 8,969.01 SCHLUMBERGER TCII 5.50 X-O 1 4.89 5.96 17.0 13CR80 9.8 8,978.3 TCII 5.50 TUBING JOINTS 11 4.89 5.50 17.0 13CR80 449.5 8,988.1 VAM TOP 5.50 TUBING PUPJOINT 1 4.89 6.03 17.0 13CR80 9.9 9,437.7 VAM TOP 5.50 X-O 1 4.89 6.03 17.0 13CR80 9.9 9,447.6 VAM TOP 5.50 X NIPPLE 1 4.56 5.85 9CR 1.5 9,457.6 HALLIBURTON TCII 5.50 X-O 1 4.89 5.96 17.0 13CR80 9.8 9,459.1 TCII 5.50 TUBING PUPJOINT 1 4.82 5.55 17.0 13CR80 9.9 9,468.9 VAM TOP 5.50 X-O 1 4.81 5.54 17.0 13CR80 9.8 9,478.9 VAM TOP 5.50 PACKER (PERMAN 1 4.75 8.37 9CR 4.9 9,488.7 BAKER TCII 5.50 X-O 1 4.83 5.53 17.0 13CR80 9.6 9,493.7 TCII 5.50 TUBING JOINTS 1 4.89 5.50 17.0 13CR80 41.1 9,503.3 VAM TOP 5.50 TUBING PUPJOINT 1 4.89 6.03 17.0 13CR80 9.9 9,544.4 VAM TOP 5.50 X-O 1 4.89 6.03 17.0 13CR80 9.6 9,554.3 VAM TOP 5.50 X NIPPLE 1 4.56 5.85 9CR 1.5 9,564.0 HALLIBURTON TCII Printed: 6/10/2008 11:12:24 AM Printed: 6/10/2008 11:12:24 AM Printed: 6/10/2008 11:12:30 AM TREE = GRAY J T 3 VVEt_LHEAD= rR "Y ACTUATOR = AXEL ~G' ----- BF ELEV = KOP - _ 30Q0' Max Ang~ = ~ 45 ~ 63(30' ~~ Datum MD = 1x602' ClatumlllL3= SH00 SS 9- 8 E';, ~~~ Batch 1D = 8.881" 19$$' 13-318" CSG, 72#, L-80, iD =12.347„ 2504' ST MU TV D DEV TYPE V LV LATCH 'FORT BATE. -~ - _ ~ - 16 12193/15 20 12113115 1 Q 05J22~'08 4-1/2" CAMGC~ OB-6 LANIl1Nta NIPPLE 945' S-v2" I-IESXNIF, ID=4.562° 94$9' 9-5(8" X 5-112" BKR S-3 PKR, ID = 4.750„ 5-1;2" TBG ,17#, 13CR;VamTop HC, 9585' 95 S-112°' HES X NlF; Id = 4.562" .0232 bpf, ID= 4.892" 5-ii2'" x 9-5i8" Unique Machine C3vershtit g5g5~ 9629' S-112" HES X N~', ltd = 4.562„ 964(}' 9-518" X 5-112" BKR S~3 PF4R, IL3 = 4.i 5-112" T&G, 15.5#, 13-CR, 11238 bpf, Id = 4..95 ~' 5' 5-112" X ~i-1!l" Xfl, Ia = 3.98•. X66' d-17ry" HES X N1P, MILLED ID= 3.$56" 4112" TBG, 12.6#f, 13-GFt, .0152 bpt, IQ = 3.358" 9717` X704," 5-112" BAYER PBR ASSY 9719' 9-518" X 5-112" BAKE3~ SAB I~CR 12" TBG-FC, 17#, L-80, .0232 bpf, IQ = 4.892" ~-] 9731.' IT€~~ o~ ~„ LNR l TBG-PG. 12.fi#, L-80, .0152 bpt, ID = 3.958" ~ 9$Q4" ~ 9-518'" CSG, 47#, L-80, ID = 8.681"' a' Fi*RF(?RATIC3N SUMMARY REF Lt3G: BRCS (7N 04111183 ANGLE ATTUPPERF:37 10798' Nate. Refer to Production DB for histatlcat parfi data SQE SPF INTERVAL Gpn/Sqz DATI= 3 118" 4 10718 - 10738 '' S 1112©f83 3-1/8" 4 1 X75(1- 1 Q780 Q 1112DI$3 3-318" 6 10786 - 14796 G> 06119194 fjBTQ ' 11000' 7" LNR, 29#{, L-80, .0371 bpf, 1d = 6.184" 1104()' 5731' -~ 5-112" X 41/2" xe 979'1' N4-112" CAMGfl d8-6 LANQ9NG N1P, ID = 3.812„ 9803' ~ 4-112" BAKER SNEkRQUT SUB 9$04' 4-112" TUBINGTA 9792 ELN~ TT Lf)GGEt3 06/12188 GATE _ REI/ SY CC}MAAENTS_ _ T]ATE REV BY G()PVYv1ENTS 44112183 QRIGINAL COMPLETION 111121f02 TA9NlTL RWO 45/23tU8 ois Rwo 05129108. PJC1t1A V GLV G1G {05126/0$} ~ 39" flF TEL SB SWIVEL (LdST 12127197)` ~ PRUl3HOE BAY UNET WELL: 07-26 FfRMfT No. 1830480 API No. 50_•029-20931-(l0 SEG 33, T11 N, R14E; 5234.22' EEL. & 19b3.$' FNL BP Explatatiorl {Alaska) S TES:'**4-112"TBGTAILSTUNGINTO 0 7 -2 6.~~~ Idt7T HAVESEAt.S ~~. **~~II~~E 19$$' 9-5t8" Csg cemented fo surface r78T' -` r:~X' -- - __ GAS LIF (MANDRELS 05/20/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh !t NO.4712 Company: State of Alaska tom' ~~~ ~~~ ~ ~ 2~~~ ~ Alaska Oil & Gas Cons Comm ~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i ..,. ne ...:.... MPB-04A 12021150 MEM PROD PROFILE ~y 04/17/08 1~ 1 MPG-13 12021151 MEM INJECTION PROFILE C 04/18/08 1 1 Z-26A 11978454 MEM GLS 9000 - 04/23/08 1 1 Z-29 11978453 MEM GLS - 04/22/08 1 1 Y-36 12005204 MEM GLS [,/ 02/12/08 1 1 4-14A/S-37 12031471 _ PRODUCTION PROFILE W/FSI 04/12/08 1 1 Y-07A 11966254 SCMT / 05/02/08 1 1 02-01 B 11966257 LDL - ~ (p 05/10/08 1 1 X-16A 11975771 USIT L- C 05/14/08 1 1 07-26 12061688 USIT - 05/16/08 1 1 05-34 11966251 USIT - 04/13/08 1 1 OS-23A 118966257 USIT ( 05/13/08 1 1 S-33 11962596 USIT - 04/1.5/08 1 1 V-223 12061688 CH EDIT PDC GR (USIT `~ - / ~ 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT ab - 03/03/08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT p~ --U ( ! 02/18!08 2 1 05-22B 11628800 MCNL 10/22/07 1 1 05-13B 12021140 MCNL ~ 01/31/08 1 1 Z-10 12066520 RST L 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 -~~~ ~~•~•..... ~......~ ...-v~~r ~ u ~ v~~a~.nv~a eiwv f1G1 Vfl1Vt1YV VIVG {.rVr•i cr~~.n rv: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Vii, Anchorage, Alaska 99508 Date Delivered: _ a1,t ;~ ~ c. ,i ~7f'~f1~"~ t~i . , _~ ~;' i°„ ,, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • ~\ r1 ~J ~ ~ }~ yy 7j I AQ£=-~ ~ bi 1 1~ ~ ~ ~ - COI~TSER A~TIO COI~IIIISS Old David Reem Engineer Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Prudhoe Bay, Prudhoe Bay Oil Pool, PBU 07-26 Sundry Number: 308-115 APR 1~d8 Dear Mr. Reem: ~ ~$3 ~~,5 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Piease 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, ~~ Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2008 Encl. aa ~~ STATE OF ALASKA'~~ ,pD &~ • - APR 0 be ALASKA OIL AND GAS CONSERVATION COMMISSION G Q~ APPLICATION FOR SUNDRY APPROVAL~i~ai & Gas Cans. Commission 20 AAC 25.280 ,, ~,,,,,,,,,,,,,, 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ® Alter Casing / ®Repair Well- ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 183-048 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20931-00-00~° 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 07-26 Spacing Exception Required? ^ Yes ®No ` 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028309' 57'. Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11040. 9206 11000 9174 None 11035 asin Len h Size MD TVD Burt Colla se Structural nductor 80' 20" 80' 80' 1490 470 Surface 2504' 13-3/8" 2504' 2504' 4930 2670 Intermediate 10062' 9-5/8" 10062' 8440' 6870 4760 Pro ion Liner 1273' 7" 9767' - 10040' 8214' - 9206' 816 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10750' - 10796' 8974' - 9011' S-1/2", 15.5 / 17# x 4-112", 12.6# 13Cr / L-80 9804' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'S-3' packer; Packers and SSSV MD (ft): 9640'; 9-5/8" x 5-1/2" Baker'SAB' packer 9719' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 7, 2008 (gi 0il ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Nick Frazier, 564-5633 Printed Na avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature ,,Q,iy~ Phone 564-5743 Date 327 D~ Terrie Hubble, 564-4628 ` Commission Use Onl Sundry Number: g_ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity '~.~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ ~l~Q PS ~ ~©~ "~S \ Subsequent Form Required: l.~~C.~, APPROVED BY ~ ~~ A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Rev sed 6612006 ~ t Submit In Duplicate ~. • by cr,y 07-26 Rig Workover (Surface Casing Leak) Scope of Work: Pull 5-'/z" 13Cr-80 completion, cut and pull 9-5/a" casing, tie-back w/new 9-5/8" casing (cemented to surface), replace 9 5/8" hanger with emergency slips and primary pack-off, and run 5-'/z" 13Cr80 completion. MASP: 2369 psi Well Type: Producer Estimated Start Date: June 7, 2008 Pre-Rig• S 1 Pull P-prong and PX plug body at 9,629' MD. Drift past 9,598' for 5-1/2" Power Jet cutter and 9,651' MD for 4-1/2" Fasdrill. E 2 Set 4-1/2" Fasdrill at 9651' MD (P/T to 1000 psi). if P(T passes, Power Jet cut tubing @ 9,598' (Ref: 11/21/2002 tubing summary). Jet cut desired to be in the middle of the 15t full joint above the aaker. F 3 CMIT TxIA to 3000 psi for 30 minutes. Circulate well with seawater and FP w/ diesel thru the cut. Bleed WHP's to 0 si. O 4 PPPOT-T, -IC, check all LDS. O 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE with 3-'/z" x 6" VBR's and blind rams to 250 psi low/ 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD tubing string to the cut. 3. RU wireline and run USIT from cut to surface. 4. Run 9-5/8' RBP and set at ~100'md below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Stack ~50 ft of sand on RBP. 5. Mechanically cut 9-5/8" casing in 1 s~ full joint above top of cement. Circulate out Arctic Pack. Pull casing thru stack. dress-off 9-5/8" stub in preparation of casing overshot. Note: VBR's will not be changed to 9-5/8" pipe rams as the well has two tested barriers (Fasdrill C~ -9,650' MD and RBP) to the reservoir. 6. Run back in with new 9 e/$", 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9-5/8" pack-off to 3500 psi. Cement new 9-5/8" casing to surface and squeeze cement into surface casing hole. 7. Cleanout above 9 5/8' RBP. Pull 9-5/8" RBP. 8. Mill Fasdrill C~3 9,651' MD and push it below the perforations to 10,800' MD. 9. Run 5-'/z" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 9,580' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 12. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. FF = (;RAY r~F WELLHEAD = GRAY ACTUATOR = AXELSON KFi. ELEV = 57' BF. ELEV = KOP = 3000' Max Angle = 45 @ 6300' Datum MD = 10602' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~--~ 2504' 2214' H 5-1/2" HES X NIP, 1D = 4.562" GAS LIFT MANDRELS Minimum ID = 3.812" @ 9791' 4-1 /2" CAMCO DB-6 LANDING NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3897 3818 36 FMHO DMY RK 0 11/27/04 2 6880 5984 45 FMHO DMY RK 0 11 /21 /02 1 8955 7567 35 FMHO DMY RK 0 11 /21 /02 9629' ' -~ 5-1/2" HES X NIP, ID = 4.562" 9640' 9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4.750" 1/2" TBG 5 15 5# 0238 b 13 C f D = 4 9 " ' ' " X 1 2" XO " - , . , - R, . p , I . 5 9645 9645 5-1l2 4- , ID = 3.90 1 9666' 4-1/2" HES X NIP, MILLED ID = 3.856" ' " ~1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 9717' 9704 BAKER PBR ASSY 5-112 9719' 9-5/8" X 5-1/2" BAKER SAB PKR ~5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9731' TOP OF 7" LNR 9767' ~4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9804' 9-5/8" CSG, 47#, L-80, ID = 8.681" -~Q62' PERFORATION SUMMARY REF LOG: BHCS ON 04/11/83 ANGLE AT TOP PERF: 37 @ 10718' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10718 - 10738 S 11!20/83 3-1/8" 4 10750 - 10780 O 11/20/83 3-3/8" 6 10786 - 10796 O 06/19/94 PBTD -j 11000, 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11040' 5-1/2" X 4-1/2" XO 1 9791' H4-1/2" CAMCO DB-6 LANDING NIP, ID = 3.812" 9803' 4-1/2" BAKERSHEAROUTSUB 9804' 4-1/2" TUBING TAIL 9792' ~-ELMD TT LOGGED 06/12/88 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/12/83 ORIGINALCOMPLETION 06/05!03 CMO/TLP MAX ANGLE 11!21/02 TMNITL RWO (07-26) 07/01/03 PC/KAK 5-1/2" TBG CORRECTION 12/08/02 JMltlh GLV GO 11/27/04 GJBiTLP GLV GO 12/14!02 SRB/KK CORRECTIONS 03/16/06 COM/PA WANER SAFELY NOTE (03/08/06) 01/03/03 SRB/KK MILL OUTX NIP 09/22/06 RDW/PA WANER SFTY NOTE DELETED 04/28/03 ATD/TLH WANERSAFETY NOTE ~ 39" OF TEL SB SWNEL (LOST 12127/97) ~ PRUDHOE BAY UNIT WELL: 07-26 PERMff No: 1830480 API No: 50-029-20931-00 SC-C 33, T11 N, R14E, 5234.22' FEL & 1903.8' FNL BP 6cploration (Alaska) STES: *** 4-1/2" TBG TAIL STUNG INTO O ~ ~~ ~ PB NOT HAVE SEALS *** ***CHROME TBG"** VVELLHEA D = GRAY 4'CTt1A'TOFR'- AXELSON (B. ELEV = 5T ~F. FJ:EV = KOP = 3000' IAax Angie = 45 ~ 6300' ]atum MD = 10602' Tatum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 07-26 Proposed sAoTES:"""a-1/2"TBGTaLSTUNCiNTo PB NOT HAVE SEALS "*" "*"CHROME Tpf~lefii 2214' 5-112" HES X NIP, ID = 4.562" I 2504' ~ GAS LIFT MANDRELS Minimum ID = 3.812" ~ 9791' 4-1/2" CAMCO DB-6 LANDING NIPPLE ST NID TVD DEV TYPE VLV LATCH PORT DATE 3897 3818 36 FN~-10 DMY RK 0 11127/04 2 1 6880 8955 5984 7567 45 35 FN~-10 FMHO DMY DRAY RK RK 0 0 11/21 /02 11/21 /02 ^9580 9-5/8" X 5-112" BKR S-3 PKR, ID = 4.750" 9629' 5-1/2" HES X NIP, ID = 4.562" 9640' 9-5/8" X 5-117' BKR S-3 PKR, ID = 4.750" 5-1/2" TBG, 15.5#, 13-CR, .0238 bpf, ID = 4.95" 9645' 9645' S-1/2" X 4-1/2" XO, ID = 3.90" 9666' 4-1/2" HES X NIP, MILLED ID = 3.856" 4-1/2" TBG, 12.B#, 13-CR, .0152 bpf, ID = 3.958" 9717' 9704' 5-112" BAKER PBR ASSY 9719' 9-5/8" X 5-1 /2" BAKER SA B PKR 5-1/2" TBG-Prr, 17#, L-80, .0232 bpf, ID = 4.892" 9731' 9731' S-1 /2" X 4-112" XO OF 7" LNR I-I 9767' ~4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9804' 9-518" CSG, 47#, L-80, ID = 8.681" 10062' PERFORATION SlNV11AARY REF LOG: BRCS ON 04/11/83 A NGL E AT TOP PERF: 37 ~ 10718' Note: Refer to Roduction DB for h~tor~al pert data SQE SPF INTERVAL Opn/Sqz DATE 3-118" 4 10718 - 10738 S 11/20/83 3-1 /8" 4 10750 - 10780 O 11 /20/83 3-3/8" 6 10786 - 10796 O 06/19/94 PBTD 11000' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11040' { 9791' {-~4-1l2" CA MOO DB-6 LANDING NIP, ID=3.812" 9803' 4-1/2" BAKERSHEAROUTSUB 9804' ~ 4-1/2"TUBING TAIL 9792' ELMD TT LOGGED 08/12/88 11035' I~ 39" OFTEL SB SWNEL (LOST 12/27/97) DATE REV BY CONVENTS DATE REV BY COMNIENTS 04/12/83 ORIGINAL COMPLETION 06/05/03 CMORLP MAX ANGLE 11/21!02 TMN/TLH RWO (07-26) 07/01/03 PC/KAK 5-1/2" TBG CORRECTION 12/08/02 JI1Altlh GLV C/O 11!27/04 GJB/TLP GLV C/O 12!14/02 SRB/KK CORRECT~NS 03/16/06 COMIPAG WAVER SAFETY NOTE (03/06/06) 01 /03103 SR8/KK MILL OUT X NIP 09/22/06 RDVVJPA WA V ER SFTY NOTE DELETED 04/28/03 A TDVTLH WA N ER SAFETY NOTE PRUDHOE BAY UNfT WELL: 07-26 PERNNT No: 1830480 API No: 50-029-20931-~ SEC 33, T11 N, R14E, 5234.22' FEL 8 1903.8' FNL BP Exploration (Alaska) 07-26 (PTD #1830480) Classified as TrOUble,neel waiver All, The waiver for well 07-26 has been cancelled. The waiver process relating to wells with surface casing leaks has been reviewed and the finding is that GPB will no longer waiver these types of wells. Lead Operator: Will you please ensure any waiver related signage is removed from the wellhouse. Please call with any questions. Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~.'~b.NMV;;~J; q¡;P 2 9 2005 \¡)WI'V ..'~ ~~. ~",,1 ~ . I of 1 9/25/2006 10:52 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development RKB = 57' MD [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1634' SNL, 293' WEL, SEC. 33, T11 N, R14E, UM x = 675920, Y = 5949285 07-26 At top of productive interval 9. Permit Number / Approval No. 183-048 2072' SNL, 4799' WEL, SEC. 33, T11N, R14E, UM x = 671425, Y = 5948742 10. APl Number At effective depth 50-029-20931-00 1916' SNL, 5212' WEL, SEC. 33, T11N, R14E, UM x=671008, Y= $948889 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 1907' SNL, 5234' WEL, SEC. 33, T11N, R14E, UM x= 670986, Y= 6948898 POOl 12. Present well condition summary Total depth: measured 11040 feet Plugs (measured) true vertical 9206 feet Effective depth: measured 11000 feet Junk (measured) 39" of TEL SB Swivel, lost 12/27/97 true vertical 9174 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 1910# Poleset 80' 80' Surface 2504' 13-3/8" 2130 sx Fondu, 400 sx PF 'C' 2504' 2504' Intermediate 10062' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 10062' 8440' Production Liner 1273' 7" 375 sx Class 'G' 9767' - 10040' 8214' - 9206' Perforation depth: measured 10723' - 10738', 10750'- 10780', 10786'- 10796' Sqzd: 10718'- 10723' true vertical 8952' - 8964', 8974' - 8998', 9003' - 9011' Sqzd: 8948'- 8952' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13Cr to 9645' XO to 4-1/2", 12.6#, 13Cr to 9717'; 4-1/2", 12.6#, L-80 to 9804' Packers and SSSV (type and measured depth) Baker 'SAB' packer at 9719'; Baker 'S-3' packer at 9640'; 5-1/2" HES X Nipple at 2214' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ~.~i ? N~tska Oil & Gas Cons, 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2287 72818 -0- Subsequent to operation: 2246 12413 -0- 950 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is t~ect to the best of my ~owledge Signed Terrie Hubble '~~' ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form10-404 Rev. 06/15/88 R ]0MS BFL ;~'"'* :~'" ?-' 'r,~/' ! ,JAN ~-8 2003 SubmitlnDuplicate '~ BP EXPLORATION Page I of 4 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WELL SERVICING Start: 11/14/2002 End: 11/22/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/15/2002 00.00 - 03:30 3.50 RIGU P PRE MOVE RIG F/MILNE POINT, ON LOCATION @ 03:30 HRS. 03:00 - 05'00 2.00 RIGU P PRE i LAY MATS, SPOT SUB, PITS & PIPESHED. 05:00 - 07.00 2.00 RIGU P PRE RAISE & SCOPE DERRICK. 07:00 - 08 00 1.00 RIGU P PRE SLIP & CUT SANDLINE. 08:00 - 10:00 2.00 KILL P INTERV TAKE ON 300 BBLS SEAWATER, RIG UP LINES TO iWELLHEAD. INITIAL PRESSURES, 0 PSI ON TUBING, 0 PSI ON I/A, & 0 PSI ON O/A. 10:00 - 12:30 2.50 KILL P INTERV ATTEMPT TO PULL BPV, WELLHEAD FROZEN, THAW OUT SAME & PULL BPV. 12:30 - 13:00 0.50 KILL P INTERV PJSM PRESSURE TEST HARDLINE TO 3500 PSI, OK. 13:00 - 15'00 2.00 KILL P INTERV CIRCULATE DIESEL OUT OF TUBING @ 6 BPM/800 PSI, (51 BBLS), & CIRCULATE DIESEL OUT OF I/A @ 6.5 BPM/900 PSI, (96 BBLS). MONITOR WELL. NOTE DIESEL RETURNS UP CONDUCTOR PIPE, REPORT SPILL...(PROCESS LEAK) SEE REMARKS. 15:00 - 15:30 0.50 WHSUR P INTERV SET BPV, BLOW DOWN LINES. 15.30 - 17:00 1.50 WHSUR P INTERV PJSM NIPPLE DOWN TREE. 17'00 - 21:00 4.00 WHSUR P INTERV NIPPLE UP BOPE, CIO PIPE RAMS TO 5 1/2". FUNCTION TEST BOPE, OK. 21'00 - 23:59 2.98 WHSURi P INTERV i FULL TEST ON BOPE. WITNESSING OF BOPE TEST WAIVED BY AOGCC STATE REP JOHN CRISP. 11/16/2002 00:00 - 01.00 1.00 WHSUR P INTERV COMPLETE FULL TEST ON BOPE. 01:00 - 02:00 1.00 WHSUR P INTERV R/U LUBRICATOR & PULL BPV. 02.00 - 03:30 1 50 WHSUR P INTERV MAKE UP LANDING JOINT, BACK OUT LOCK DOWN SCREWS, & PLUG CONTROL LINE PORTS ON GREY GEN III WELLHEAD. 03:30 ~ 04.30 1.00 PULL P INTERV PJSM. ATTEMPT TO UNSEAT HANGER, GRADUALLY WORKING UP TO 205K WITH NO SUCCESS. CALL FOR SPEAR & JARS. 04'30 - 06:00 1.50 PULL P INTERV WAIT ON SPEAR & JARRING ASSEMBLY. WARM UP TREE 06'00 - 07:00 1.00 PULL P INTERV MAKE UP JARRING ASSEMBLY & DOUBLE SPEAR W/(1) 6" DRILL COLLAR. PJSM 07'00 - 08:00 1.00 PULL P INTERV SPEAR 5 1/2" TUBING 12' BELOW HANGER & JAR HANGER (8) TIMES, INCREASING OVERPULL F/65K TO 125K TO SET OFF JARS. HANGER CAME FREE W/STRAIGHT PULL @ 195K AFTER FINAL JAR LICK. 08 00 - 09:00 1.00 PULL P INTERV BREAK OFF & LAY DOWN TUBING HANGER 09:00 - 13.00 4.00 PULL P INTERV POOH & LID 5 1/2" COMPLETION STRING & SPOOL UP CONTROL LINES. CONTROL LINES IN VERY BAD SHAPE. 13:00 - 14:30 1.50 PULL P INTERV CHANGE OUT CONTROL LINE SPOOLS. 14:30 - 17:00 2.50 PULL P INTERV CONTINUE TO POOH W/COMPLETION STRING & CONTROL LINES, (28) CONTROL LINE CLAMPS RETRIEVED & (2) CONTROL LINE BANDS. 17:00 - 17:30 0.50 PULL P INTERV RIG DOWN CONTROL LINE SPOOLER 17'30 - 23:59 6.48 PULL P INTERV CONTINUE TO POOH W/5 1/2" COMPLETION STRING. BOPE DRILL W/POOH 11/17/2002 00.00 - 02:30 2.50 PULL P INTERV POOH & L/D 5 1/2" COMPLETION STRING. 228 JOINTS TOTAL LAID DOWN & 29.71' OF JOINT # 229...PLACING CUT @ 9683'. 02 30 - 03:30 1.00 WHSUR P INTERV CHANGE OUT PIPE RAMS F/5 1/2" TO 2 718" x 5" VARIABLES. 03:30- 06:00 2.50 WHSUR P INTERV SET TEST PLU~JjJJJ~JlJ~" I~/L~V~T8,.~ u,~;r~J°° PSI. PULL TEST PLUG. Printed 12/6/2002 2 O0 15 PM BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WELL SERVICING Start: 11/14/2002 End: 11/22/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1 1/22/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/17/2002 06:00 - 07:00 1.00 FISH P INTERV SERVICE & LUBRICATE RIG. 07:00- 10:00 3.00 FISH P INTERV M/U FISHING BHA. 10:00 - 10:30 0.50 FISH P INTERV P/U & RIH W/3 1/2" DP. 10'30 - 12:30 2 00 WHSUR P INTERV M/U HALLIBURTON RTTS/STORM PACKER & SET @ 15' TEST TOP OF PACKER & 9 5/8" CASING & PACKOFF F/15' TO SURFACE @ 3000 PSI, OK. NO INDICATION OF COMMUNICATION TO 13 3/8" OR CONDUCTOR PIPE. 12:30 - 15:30 3.00 WHSUR P INTERV M/U RUNNING TOOL TO RETRIEVE 9 5/8" PACK OFF, ENGAGE RUNNING TOOL & PULL 28K TO RETRIEVE PACK OFF ELEMENT. M/U, RUN IN & SET NEW PACK OFF ELEMENT. L/D RUNNING TOOL. 15:30 - 16:30 1.00 WHSUR P INTERV RIH, SCREW INTO RTTS & RELEASE STORM PACKER. POOH & L/D SAME. 16:30 - 17:00 0.50 WHSUR P INTERV PRESSURE UP 9 5/8" I/A TO 3000 PSI, EFFECTIVELY TESTING 9 5/8" CASING & 9 5/8" PACK OFF. GOOD TEST & CHARTED, NO BLEED OFF & NO INDICATION OF COMMUNICATION TO 13 3/8" O/A. 17:00 - 23'59 6.98 FISH P INTERV P/U 3 1/2" DP & RIH W/FISHING ASSEMBLY. 11/18/2002 00'00 - 02:00 2.00 FISH P INTERV CONTINUE IN HOLE W/3 1/2" DP, 300 JTS 02:00 - 02 30 0.50 FISH P INTERV KELLY UP. ESTABLISH PARAMETERS. 170k UP WT, 115k DOWN, 125K ROTATING, (170 AMPS). 3 BPM @ 450 PSI. 02:30 - 03:30 1.00 FISH P INTERV TAG TOP OF TUBING STUB @ 9670 DPM, DID NOT GET OVER IT. P/U & ROTATE DOWN @ 3 BPM, SEE PRESSURE INCREASE @ 9671', SHUT DOWN PUMP & SET DOWN 20K @ 9678'. PICK UP & SEE OVERPULL, EXTEND JARS & STRAIGHT PULL TO 250K, THEN 275K, NO SHEAR ON PBR. JAR 6 TIMES @ 225K & PULL TO 275K, NO SHEAR. JAR ONCE @ 250K, SHEARED OK. 03 30 - 05'30 2.00 FISH P INTERV CBU @ 5.7 BPM/1300 PSI. NOTED FLUID RISING IN CONDUCTOR PIPE DURING CIRCULATION, SUCKED OUT SAME TO KEEP FROM FLOWING OVER. 05.30 - 06:00 0.50 FISH P INTERV POOH W/3 I/2" DP & FISHING ASSEMBLY. 06:00 - 06:30 0.50 FISH P INTERV SERVICE & LUBRICATE RIG. 06.30 - 10:30 4.00 FISH P INTERV POOH W/3 1/2" DP. 10:30 - 12:00 1.50 FISH P :INTERV L/D BHA. RETRIEVED 14 85' OF 5 1/2" TUBING, (PULLED OUT OF COLLAR). 6' PUP LEFT ON TOP OF PBR. 12'00 - 13'00 1.00 FISH P INTERV CLEAR RIG FLOOR. 13:00 - 14:30 1.50 FISH P INTERV P/U BHA #2 TO SPEAR PUP ON TOP OF PBR. 14:30 - 19.00 4.50 FISH P INTERV RIH W/3 1/2" DP. KELLY UP. 19:00 - 20:30 1 50 FISH P INTERV PJSM. ESTABLISH PARAMETERS. PUMPING 2 1/2 BPM, 300 PSI 170K UPVVT, 115K DOWN, 135K ROTATING WEIGHT. RIH TO 9686' SLIGHT INCREASE ON PRESSURE, DOWN TO 9692' W/10K SETTING DOWN, PRESSURE IS UP TO 425 PSI NOW. ENGAGE FISH, JAR UP ONCE @ 225K TO SOLIDIFY DOUBLE SPEAR ENGAGEMENT. SLACK OFF & PULL TO 180K & ROTATE TO THE RIGHT 17 TURNS, SEE WEIGHT & TORQUE DROP OFF. PICK UP. SLACK OFF, RE ENGAGE SPEAR, JAR UP @ 225K, SLACK OFF TO 200K, TURN TO THE RIGHT 10 TURNS, SEE WEIGHT & TORQUE DROP OFF. ANCHOR IS RELEASED OR SPEARS ARE DISENGAGING. 20:30 - 23:59 3.48 FISH P INTERV STAND BACK KELLY & POOH. 11/19/2002 00:00 - 01:00 1.00 FISH P INTERV CONTINUE TO POOH W/3 1/2" DP. 8CANNE i FEB 0 2_003 Printed 12/6/2002 2 00 15 PM BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WELL SERVICING Start: 11/14/2002 End: 11/22/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/19/2002 01 '00 - 02 00 1.00 FISH P INTERV STD BACK COLLARS, LID BHA, NO FISH. SPEARS IN DISENGAGED POSITION. 02:00 - 03:00 1.00 CLEAN P INTERV P/U 3 1/2" BTC, (1 JT), W/MULE SHOE ON END & M/U CLEANOUT BHA. 03:00 - 03:30 0 50 CLEAN P INTERV RIH W/15 STDS 3 1/2" DP. 03:30 - 05:00 1.50 CLEAN P INTERV SLIP & CUT 84' OF DRILLING LINE. 05:00 - 06:00 1.00 CLEAN P INTERV CONTINUE IN HOLE W/3 1/2" DP & CLEANOUT BHA. 06:00 - 06:30 0.50 CLEAN P INTERV SERVICE / LUBRICATE RIG. 06:30 - 09.30 3 00" CLEAN P INTERV CONTINUE IN HOLE W/3 1/2" DP. TAG UP @ 9685', WORK PIPE ONCE & POP INTO 5 1/2" PUP, RUN DOWN CLEAN TO 9714'. 09:30 - 11:00 1 50 CLEAN P INTERV REVERSE CIRCULATE @ 6.5 BPM / 2100 PSI. CBU, 600 BBLS TO CLEAN RETURNS..., SOME SCALE LIKE SOLIDS BACK NOTE: CONDUCTOR PIPE DID NOT FLOW DIESEL AS IN PAST CIRCULATIONS..ATTRIBUTE THOSE DIESEL FLOWS TO THERMAL EXPANSION. 11'00 - 18'30 7.50 CLEAN P INTERV PJSM. POOH & LID 3 1/2" DP. 18.30 - 19:30 1.00 CLEAN P INTERV L/D BHA. 19.30 - 20:30 1.00 CLEAN P INTERV CLEAN & CLEAR FLOOR OF HANDLING TOOLS. 20:30 - 21 '30 1.00 WHSUR P INTERV SET TEST PLUG. REMOVE 2 7/8" x 5" VARIABLE PiPE RAMS, INSTALL 5 1/2" PIPE RAMS 21:30 - 22:30 1.00 WHSUR P INTERV P/U TEST JOINT. TEST PIPE RAMS @ 250 / 3500 PSI, OK. PULL TEST PLUG. 22:30 - 23:59 1.48 RUNCOI~ 1~ INTERV RIG UP TO RUN 5 1/2" COMPLETION STRING. 11/20/2002 00:00 - 06:00 6.00 RUNCOI~ 1:> INTERV PJSM. PU MS 1 jt 4 1/2" tubing and completion jewerly as specified in Casing Equipment Report. Begin RIH with 5 1/2" 13 cr. 15 5# Fox Tubing. Torque Tbg 5200 ft/Ibs. 06'00 - 18 00 12.00 RUNCOI~!~ INTERV Crew change. PJSM. Continue RIH with 5 1/2" complebon (208 jts). 18 00 - 23 00 5.00 RUNCOI~I:' INTERV Crew change. PJSM. Continue RIH w~th 5 1/2" complebon. Stab into 5 1/2" tbg stub on jt 252...9,723-ft Driller's Depth. Bring pump on line at 3 bpm to verify circulation. 23:00-0000 1.00 RUNCOI~!~ INTERV Lay down jt # 252. Pick up space out pups. Prepare to land hanger. 11/21/2002 00:00 - 01:00 1.00 RUNCOI~!~ INTERV SPACE OUT, M/U & LAND HGR.R.I LD.S.- UP WT 140K, DN WT 110K. 01.00 - 06:00 5.00 RUNCOI~ I:' INTERV RU/REV CIRC 50 BBL VIS PILL, 200 BBLS SW, 425 BBLS INHB SW. 06:00 - 08 30 2.50 RUNCOI~ !:' INTERV COMPLETE REV CIRC WELL WITH 425 BBLS INHB SW IN 9 5/8 X 5 1/2 (IA) 08:30 - 11:30 3.00 RUNCOI~ I= INTERV DROP BAR, PRESSURE TBG TO 3500 PSI AND SET BOT S-3 PKR HOLD FOR 30 MIN. BLEED TBG TO 1500 PSI. PRESSURE IA TO 3000 PSI, HOLD FOR 30 MIN. BLEED TBG TO 0 AND SHEARED RPSV, CIRC @ .3 BPM / 200 PSI TO VERIFY RPSV OPEN. BLEED IA TO O PSI. 11.30 - 17:30 6.00 RUNCOI~ P INTERV SET AND TEST TWC TO 3000 PSI. ND BOPE / NU ADAPTER FLG AND TREE, TEST TO 5000 PSI. 17:30 - 21.00 3.50 RUNCOI~ I~1 WAIT INTERV WAIT ON WELL SUPPORT FOR INTEGRAL FLANGE FOR WING VALVE AND BPV 21:00 - 00'00 3.00 RUNCOr~ F' INTERV PJSM - PULL TWC / RU INTEGRAL TO WING VLV AND BEGIN TO FP TBG X IA TO 2500' WITH 170 BBLS DIESEL. 11/22/2002 00:00-03:30 3.50 RUNCOItP ,NTERV FREEZE PROT WELL WITH 170BBLS DIESEL. ALLOWTO U-TUBE. ~G~[{~i~E~ FEB0~:2.' O Pnnted 12/6/2002 2.00.15 PM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: 07-26 Common Well Name: 07-26 Spud Date: 3/27/1983 Event Name: WELL SERVICING Start: 11/14/2002 End: 11/22/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/22/2002 03:30 - 04.301.00 RUNCOI P INTERV !RU LUBRICATOR AND SET BPV. 04:30 - 05'301.00 RUNCOI P INTERV BLOW DOWN LINE. RD LINES. ND THRD FLANGES. NU BLIND FLANGES. 05:30 - 06:000.50 RUNCOr P INTERV RD CELAR AND SECURE WELL. RELEASE RIG. ,~ANNED FEB 0 ~ 20B3 Printed 12/6/2002 2 O0 15 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate__ Plugging_ Perforate_ Pull tubing Alter casing _ Repair well _ Other _~ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_Z 57' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1634' SNL, 293' WEL, Sec 33, T11 N, R14E, UM. 7-26 At top of productive interval: 9. Permit number/approval number: 2073' SNL, 4799' WEL, Sec 33, T11N, R14E, UM. 83-48 ,... At effective depth: 10. APl number: 50-029-20931 At total depth: 11. Field/Pool: /~:\ t ~ 1 2 199 1907' SNL, 5234' WEL, Sec 33, T11N, R14E, UM. Prudhoe Be)/Oil Pool 12. Present well condition summary Alaska 0il & Gas Cons. Co Total Depth: measured 11040 feet Plugs (measured) Sand Fill Tagged at 10739' MD (3/1/98). Anchorage true vertical 9206 feet Effective Depth: measured 10739 feet Junk (measured) true vertical 8965 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1910# Poleset 80' 80' Surface 2447' 13-3/8" 2130 Sx Fondu & 2504' 2504' 400 Sx PFC Production 10005' 9-5/8" 500 Sx G & 300 PFC 10062' 8439' Liner 1273' 7" 375 Sx G 11040' 9206' Perforation Depth measured 10735 - 10738'; 10750- 10780'; 10786 - 10796' true vertical 8962 - 8963'; 8973 - 8997'; 9002- 9010' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9731' MD; 4-1/2", 12.6#, L-80, POT @ 9804' MD / Packers and SSSV (type and measured depth) Baker SAB Packer @ 9719' MD; 5-1/2" Camco BaI-O SSSV @ 2159' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Ucf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3723 54875 0 1043 Subsequent to operation 4073 37955 124 917 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Repo~,~f Well Op)~¢ns _X Oil X Gas Suspended _ Service _ 17. I hereby c/~i~j that~egoing is true and correct to the best of my knowledge. Signed ~'~_/'/~-¢,~~/~///'/~'//~"'- "~' E//j/fO Title: Engineering Supervisor Date ~///2/~'o° Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~mission 7-26 DESCRIPTION OF WORK COMPLETED TUBING PATCH INSTALLATION 4/18/98: TIFL failed. 7/20/98: Ran a Leak Detection Log indicating a leak was present at Pup Joint just above the PBR at 9696' MD. 8/2/98: MIRU & PT equipment. POOH. RD. RIH w/Tubing Patch & set the patch across the leak (above) at 9682 - 9697' MD. 8/6/98: TIFL passed. Returned the well to production & obtained a valid welltest. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIb~'~ REPORT OF SUNDRY WELL OPERATIONS · Operations performed: Operation Shutdown_ Stimulate__ Plugging_ Pedorate_ Pull tubing _ Alter casing _ Repair well _ Other 6. Datum of elavation (DF or KB feet): 57' RKB 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1634' SNL, 293' WEL, Sec 33, T11N, R14E, UM. At top of productive interval: 2073' SNL, 4799' WEL, Sec 33, Tll N, R14E, UM. At effective depth: 5. Type of Well: Development Exploratory _ Stratagrapic _ Sen/ice _ At total depth: 907' SNL, 5234' WEL, Sec 33, T11N, R14E, UM. 12. Present well condition summary Total Depth: measured 11040 feet Plugs (measured) true vertical 9206 feet Effective Depth: measured 10739 feet Junk (measured) true vertical 8965 feet 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 7-26 9. Permit number/approval number: 83-48 10. APl number: 50-029-20931 1. Field/Pool: Prudhoe Bay Oil Pool Sand Fill Tagged at 10739' MD (3/1/98), Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1910# Poleset 80' 80' Surface 2447' 13-3/8" 2130 Sx Fondu & 2504' 2504' 400 Sx PFC Production 10005' 9-5/8" 500 Sx G & 300 PFC 10062' 8439' Liner 1273' 7" 375 Sx G 11040' 9206' Perforation Depth measured 10735 - 10738'; 10750 - 10780'; 10786- 10796' true vertical 8962 - 8963'; 8973- 8997'; 9002- 9010' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9731 MD; 4-1/2", 12.6#, L-80, PCT @ 9804' MD Packers and SSSV (~e and measured dep~) Baker SAB Packer ~ 9719' MD; 5-1/2" Camco BaI-O SSSV ~ 2159' 13. Stimulation or cement squeeze summa~ ,ntewals treated (measured) see aEached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2283 41361 28 - 1945 Subsequent to operation 3708 20613 0 - 582 15. Attachments 116. Copies of Logs and Surveys run _ Status of well classification as: Daily Report of Well Operations _X Oil _X Gas _ 17. I hereby certiflj that the foregoing is true and correct to the best of my knowledge. Signed '~"~ ~ ~ Title: Engineering Supervisor Form 10-404 Rev 06/15/88 Suspended _ Service _ Date ~ -/O - '~ ~' SUBMIT IN DUPLICATE 7-26 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 12/2/97: RIH & tagged PBTD at 10974' MD. 12/26/97: MIRU CTU & PT equipment. RIH w/CT loading the well w/Crude. Tagged bottom, then PU & pumped gelled sand slurry containing 5350 lbs of 20/40 mesh sand, to place an isolation sand plug across the lower open perforation intervals located at: 10750 - 10780' MD (Z2) Ref. Log: BHCS 4/11/83. 10786- 10796' MD (Z2) Tagged final TOS at 10726' MD. POOH w/CT. RD. 12/27/97: RIH & tagged TOS at 10726' MD. Lost tubing tail Iocator tool in well. 12/28/97: RIH w/fishing assembly & attempted to retrieve tubing tail Iocator; no retrieval. 1/14/98: RIH w/CT & jetted sand plug from the wellbore to lower the fish location to 10900' MD, then pumped gelled sand slurry containing 20/40 mesh sand to raise top of sand plug back to 10730' MD. 1/15/98: RIH & tagged TOS at 10723' MD. 1/20/98: An Acid Wash & CTU Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU & PT equipment. RIH w/CT loading the well w/1% KCI Water & Crude. Tagged TOS at 9465' MD, then PU & reciprocated an acid wash across the upper open perforation interval located at: 10718- 10738' MD (Z2) Ref. Log: BHCS 4/11/83. Pumped: a) 20 bbls of 2% NH4CI Water, followed by b) 15 bbls of 12% HCI w/10% Xylene, followed by c) 10 bbls of 6% HCI- .75% HF, followed by d) 13 bbls of 12% HCI w/10% Xylene, followed by e) 20 bbls of 2% NH4CI Water w/CitriC Acid, followed by f) 33 bbls of 1% KCI Water Flush. Swapped to pumping 31 bbls of Latex Acid Resistive Cement to squeeze off the top part of the open perforation interval exposed above the sand plug (listed above). Placed I bbl of I_ARC behind pipe & held at final squeeze pressure of 3500 psi for 50 minutes. Could not perform the planned cement cleanout due to freeze problems w/equipment. POOH w/CT. RD. 1/22/98: RIH & tagged TOC at 9907' MD. 2/22/98- 2/26/98: Performed underreaming operations to ream a 5.75" hole through the cement plug to 10735' MD, then jetted sand from the wellbore to 10860' MD to uncover the lower open perforation intervals (listed above). 3/1/98: RIH & tagged sand at 10739' MD. Returned the well to production & obtained a valid welltest. Dr$11 Site: COMMENTS: 7 Well: 26 Sun O~t 30 17:46:11 1994 K-VALVE DESIGN DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A,B,C): 860 PSIG @ 60 DEG F 950 PSIG A Redesign - Last design for well couldn't ~'be dumped. ~og,~c0 goo Lowest pressure attainable in LP was 675 psi. Redesign to dump by switching from HP to LP, but dump at 950 psi (275 psi higher for safety). CC: ENGINEERING FILE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.C. SMART /.M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) FS 3 DS Sup PRB 13 (COVER ONLY) T . D . TORCZON ATO 1555 (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: MMM Drill Site: 7 Well: 26 CK LGR FTP OIL %WTR 90 60 76 76 75 65 75 90 60 75 61 36 WELL TEST DATA GOR GLR LIQ 0 1147 4594 0.0 12768 12768 4594 0 1662 4156 0.0 11060 11060 4156 0 1093 4705 0.0 13378 13378 4705 ~/~ ~.. TEMP PRES 2577 .q~,s,.~,o 147 974 10/20/94 Y 2720 0.00 1 ~'9:~.,., 822 08 / 29 / 94 0 1066 4930 0.0 11649 11649 4930 2617 0.00 130 '803 08/20/94 0 1068 4555 0.0 11505 11505 4555 2491 0.00 130 802 08/19/94 0 1132 4589 0.0 12308 12308 4589 2624 0.00 132 874 08/05/94 0 1269 4475 0.0 12197 12197 4475 2708 0.00 127 770 07/22/94 0 1114 4719 0.0 11546 11546 4719 2585 0.00 132 853 07/16/94 0 1047 4926 0.0 10332 10332 4926 2482 0.00 147 859 07/09/94 0 1734 3969 0.0 12629 12629 3969 3082 0.00 124 826 06/20/94 0 1193 4726 0.0 10593 10593 4726 2586 0.00 140 949 06/11/94 0 1690 3600 0.0 14097 14097 3600 3005 0.00 123 834 05/26/94 0 2424 897 0.0 17927 17927 897 3408 0.00 112 721 05/21/94 ESC=EXIT; Fi=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=C~ECKLIST; Ft0=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 2159 FTP @ CLOSE (PSIG): 950 PRESS ADJUSTMENT: 148 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BM TEMP AND WELL PI WPS C= 0.308439 N= 0.625409 NEW C= 0.287560 ENTERED N= 0.625409 Drill Site: 7 Well: 26 Sun Oct 30 17:47:06 1994 K-VALVE DESIGN SSSV DEPTH (MEAS): 2159 FTP @ CLOSE (PSIG): 950 PRESS ADJUSTMENT: 148 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR .FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 90 0 1147 4594 0.0 12768 12768 4594 2577 5.24 147 0 10/20/94 Y CONDITIONS AT CLOSURE: 90 0 950 4858 0.0 12768 12768 4858 2484 5.24 147 0 W-ELL TEST @CLOSE TEMPERATURE @ SSSV: 167 167 PRESSURE @ SSSV: 1499 1352 DOME SET PRESSURE: 860 PRIOR DESIGNS: DATE: 09/02/94 SET PRESSURE: 630 FTP @ CLOSURE: 501 07/12/94 720 685 01/09/94 895 1090 TEMP: PIPROF LINEAR LINEAR ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= 0.308439 N= 0.625409 NEW C= 0.287560 ENTERED N= 0.625409 Drill Site: 7 Well: 26 K-VALVE DESIGN Mon .Aug 15 22:42:52 1994 DOME SET PRESSURE: .630 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 501 PSIG K~VALVE .CLASS (A,B,C): B COMMENTS: Previous valve design dumped 480 psi over expected. This design should dump by moving the well from HP to LP. CC: ENGINEERING~FILE / COORDINATOR PRB' 24 W. H. Smalstig ATO-1552 (WITH ATTACHMENTS) J~C. S~T / M.G. SHOEMAKE (WITHOUT ATTACHMENTS ) FS #3 DS SuperVisor PRB 13 ( cOVER O~Y) - PRB 20 WITHOUT ATTACHMENTS ) :STATEi-:OF::ALASKA ', (COVER~ ONLY cC~.:./-:.~:/~ -/_ ...... ~. ~ :~ . ~.... DESIGNED BY: KLM/MJB ~-.. STATE OF ALASKA ALASK/j ILAND GAS CONSERVATION C'--'MISSION REPORT OF SUNDRY WELL OP,-RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1634' SNL, 293' WEL, Sec. 33, T11N, R14E, UM At top of productive interval 2073' SNL, 4799' WEL, Sec. 33, T11 N, R14E, UM At effective depth At total depth 1907' SNL, 5234' WEL, Sec. 33, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 57 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-26 9. Permit number/approval number 83-48 10. APl number 50 - 029-20931 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11040 feet 9206 feet Plugs(measured) PBTD Tagged @ 10952' MD (6/16/94) Effective depth: measured true vertical 10952 feet 9134 feet Junk(measured) Casing Length Conductor 80' Surface 2447' Production 10005' Liner 1273' Size Cemented Measured depth True vertical depth 20" 1910 # Poleset 80' 80' 13-3/8" 2130 sx Fondu & 400 sx PFC 2504' 2504' 9-5/8" 500 sx CIG & 300 sx PFC 10062' 8439' 7" 375 sx CIG 11040' 9206' RECEIVED Perforation depth: measured 10718-10738'; 10750-10780'; 10786-10796' true vertical 8947-8963'; 8973-8997'; 9002-9010' AUG 12 1994 Alaska 0il & Gas Cons. Commission Anch0ra~e Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9731' MD; 4-1/2", 12.6~ L-80, PCT @ 9804' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 9719' M D; 5-1/2", Camco BaI-O SSSV @ 2159' 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 Subsequent to operation Representative Daily Average Produ~ion orlnjection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 4726 50067 0 -- 4926"f"' 50900 0 -- Tubing Pressure 1193 1047 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~C-~- ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 1 1 '70110 ~r,. 14'7 _ ItAID SUBM~ IN/DUPLICATE 7-26 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/1 6/94: RIH & tagged PBTD at 10952' MD. 6/19/94: MIRU & PT equipment. Added perforations: RIH w/perforating gun & perforated a 10' interval as follows: 10786 - 10796' MD (Z2) Ref. Log: BHCS 4/11/83. Used a 3-3/8" carrier, shot 6 spf, at 60 degree phasing. Shot at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid welltest. RECEIVED AUG 1 2 1994 Alaska Oil & Gas Cons. Commission Anchor~de ARCO Alaska, inc. Date: Subject' From/Location: Telephone: To/Location' July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Transmittal #: 94054 P.O. Box 100360, =horage, AK 99S10,~~, REcE:!,.VED · ,JUL I 7' .4~s.ka Oil & GaS.Cons. Anct~ora,~Zo C°raniSs!O,n Well · Number i 1-05ST ! 1-17 ! 2-20 2-28 3-2 RI~~ i 4-40 [ 4-43 ~ 4-44 Log Date] Tool Type i Run, (M-D-Y) . Scale 6-21-94 t Prod Prof ! 1,1"&5" 6-20-94 i / Prod Prof I 1, 5" 6-18-94 P IBP Settin9 Rec i 1, 5" 6-28-94 I/Leak Detection i 1,2" & 5" 6-22-94 ~ Leak Detection f 1,1"&5" 6-17-94 P" Patch Set Rec ! 1 5" 6-25-94 I / Per[Rec i 1 5" 5" 6-25-94 ! ,,/ Per[ Rec 6-23-94 I '" Comp Rec 6-20-94-! / PerfRec i 1 ! 1 ! 1 1! ,1 Contractor SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH "+9- ~q--- i 4-45 ()C~ ./'! 5-03A \! 5-03A \i 5-03A !5-13 (05 ! 5-33 6-8 Lo~ ! 6-12A 7-6 7-26 9-05A 9-05A 9-30ST 11-6 5'Z. ! 11-29i 6-25-94 I -/' Per[ Rec 6-9-94 !" CDN 6-9-94 i /' SlimlGR [ 1,2" &5" i 1,2" & 5" 6-9-94 i -" CDR i 1, 2" &5" 6-17-94 j/Leak Detection i 1,1" & 5" 6-15-94 I f TDTP 6-24-94 I ~' Perf Rec 6-29-94 !-' Per[ Record } I 5" 1 5" I 5" 15" 1 5" I 5" 6-28-94 !f Per[Rec i 6-19-94 i.. Per[ Rec 6-21-94 f Per[Rec 6-22-94 f Per[ Rec SCH SCH SCH , SCH , SCH SCH SCH SCH SCH SCH Dual Burst I 1 5" -/' Prod Prof [ 1, l"& 5" .-" Per[ Rec t 1, 5" 1,5" i-"'Leak Detection i 1, 5" ~' Inj Prof ] 1,5" 1,5" 6-29-94 6-22-94 6-27-94 12-02 6-28-94 -" Ini Prof ! 12-7A ! 6-27-94 12'19 ! 6-27-94 12-23 i 6-28-94 i ? IniProf 12-28 ~ 6-27-94 I / Prod Prof 13-08 I 6-30-94 i f Per[Prof 14-24 i 6-15-94 t ~' CNL I 1, 5" '::fl [:~%~ 14-39 !~ - 6-19-94 l '"Leak Detection i 1,1"&5" 14-39 i 6-19-94 i/' Leak Detection 1, 2" 2-- i 16-28 I 6-20-94 I / Per[Rec I 1, 5" SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH * DS# 04-02 The APl# is 50-029-20088-00 Number of Records: 35 ARCO Alasi(a, Inc. Is a Subsidiary o1 AUantlcRIchfleldCompany ARCO Alaska, Inc. Date' June 14, 1994 P.O. Box 100360,"~-'-"chorage, AK 99510,d~~, Transmittal#: 94045 ~ ~' Subject: From/Location' Telephone: To/Location: ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well Number Log Date i Tool Type i Run, (M-D-Y)! i. Scale ~ 511 06-02-94 i'/ USIT [ 1 RECEIV'ED ,JUI'~ 2,.. ''~ 1994 1-10A 2-33 3-18A 3-27 4-07ST 4-11A , 4-19 4-46 5-3A 6-3 6-10 A!2ska Oi! a Gas Cons. Commission 05-24-94 P'BAKER IBP REC 05-26-94 i~ PERF REC { 1, 5" 06-04-94 1 / INJ PROFILE ! 1, 5" 05-25-94 i J USIT i 1, 5" 06-04-94 kProduction Profile i 1, 1" 5" 06-02-94 j/ CCL 06-03-94 j/' PERF REC Contractor SCH 05-22-94 i f CNL i 1, 5" SCH 05-19-94 !.~ CCL i 1, 5" SCH 1, 5" SCH 1 5" 1 5" 1 5" 1 5" SCH SCH ~ SCH SCH SCH $CH SCH ~ SCH SCH SCH SCH SCH 6-16 6-22A 7-4A i 7-7A 7-18 7-28 9-13 9-44 05-22-94 I/P~atch Settin~ Rec j 06-05-94 ?~ub~i'ng Puncher i 05-22-94 i/ CNL 05-21-94 .k/ CNL 9-50 11-291 11-291 11-291 11-291 11-35 11-35 14-3 14-12 14-20 14-34 16-13 17-12 17-19 18-1 18-1 05-21-94 jvProduction Profile j 05-20-94 I / Pref Rec 05-21-94 i" CNL ' 1 5" 1 5" 1 5" 1 5" [ 1, 5" SCH 7-23 05-24-94!'/ CCL ~ 1, 1" 5" SCH 7-26 ~ 1, 5" SCH 05-21-94 Iv Prod Profile 05-26-94 i,/ Perf Rec i 1, 5" 05-25-94 i~' Bridge Plug ! 1, 5" 05-20-94 "?Production Profile ! 1, 5" 05-20-94 ~l=roduction Profile~ 1, 1" 5" 05-30-94 ! -- 05-31-94 !.~ TDT-~> 05-30-94t/ CBT 05-31-94 t/ USIT 05-31-94 ! -" CBT 05-23-94 I/ CBT i 05-31-94 t/ CNL 1 5" USIT 1 5" 1 5" 1 5" I 5" 1 5" 1 5" 06-03-94 I ~ PERF REC I 1 5" 05-:>8-94 1 ~ ~1:t I..0~ ! 15" 05-28-94 F?roduction ~rofilo~ ~ 5" 0~-0~-~4 ~' ~~[C ~ ~ 5" 0~-0~-04 i/ ¢~F~C } ~ 5" 0S-24-~4 ~ ~ Baker I~ ~ ~ 1 5" 0~-05-~4 ~/keak ~ot~ction ~ 1 ~ 2" 05-26-94 ] / PERF REC 06-04-94 ~ Pack ~ Gas L~ i 06-04-94 t/Tubing Puncher ~ 17 511 ! 5II ! 5II SCH ~ SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH ARCO Alaska, Inc. Is a Subsi~lary of A~JmltlcRIchflelclCompm'ty Dril~ s/re: 7 ~ell: 26 X-VALVE DES.I C4~ · hu Feb 04 11:31:11 1993 COMMENTS: K-valve may be tested in the HP commonline. Dome pressure is high enough to accomodate PI and changes. X-valve redesiga will be required if the recommended choke sett/ng is /ncreased stgniftcant/y. CC: ENGINEERING FILE / COORDI~ ~I~B 24 (wz~ ATmACHMEN~S ) J.C. SMART / M.G. SHQEMAKE PRB 20 J.E. FAUSE~ ./ C.W. ~Y PRB 13 ~. ( COVER OHL~) (WZ~OU~ ATZA~S ) SZ~Z OZ ALASKA (¢OVZ~ O~LY) DESI~ ~BY: A.W. ~ROOKS Drill Site: 7 Well: 26 SUn Aug 11 09:48:11 199I K-VALVE DESIGN DOME SET PRESSURE: 690 FTP @ CLOSE (PSIG): 700 K-VALVE CLASS (A,B,C): B PSIG @ 60 DEG F PSIG COMMENTS: To test in well, will need'to switch to low-pressure common-line. '~ it ~ill not dumB, then p~ll & bench CC: C.P. FARMER / W.D. COOPER~'' PRB 24 A.W. BROOKS ATO 1551 K.M. KENNEDY / L.D. LASH PRB 20 J.E. FAUSETT / C.W. SHUMWAY PRB 13 ENGINEERING WELL FILE Drill Site: 7 Well: 26 Sun Aug 11 09:45:24 1991 SENSITIVITY TABLE P.I. 4.55 7.20 4.55 %WTR 0.0 0.0 0.0 GOR 6741 6700 8000 LGR 0 0 0 · ENTER VALUES FOR P · I. , %WTR, GOR, LGR, AND FTP 1, 2, or 3. FTP 1 700 1076 1192 1111 FTP 2 PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF DATA ITEMS ENTERED. 'FTP 3 641 1038 1161 1076 ESC=EXIT; Fl=HELP F2=WELL TESTS; F3=DEsIGN;-F4=DISTRIBUTION; F10=ACCEPT; Drill Site: 7 Well: 26 Sun Aug 11 09:45:46 1991 K-VALVE DESIGN FTP @ CLOSE (PSIG): PRESS ADJUSTMENT: TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP EMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 90 0 978 6072 0.0 6741 6741 6072 2265 4.55 148 0 08/08/91 Y CONDITIONS AT CLOSURE: 90 0 '700 6674 0.0 6741 6741 6674 2133 4.55 148 0 PRIOR DESIGNS: DATE: 04/08/91 SET PRESSURE: 780 FTP @ CLOSURE: 763 04/05/91 705 673 02/24/91 765 820 TEMP: LINEAR LINEAR PIPROF ESC=EXiT; Fi=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F10=ACCEPT; SFe=RESTORE WELL TEST; CF9=CYCLE DATA; Drill Site' 7 Wel] · 2,8 K-VALVE DESIGN Mon Apr 08 13'01'51 ]991 COMMENTS' DOME SET PRESSURE' FTP @ CLOSE (PSIG)' K-VALVE CLASS (A,B,C)' 78g PSIG e 6~ DEG 763 PSIG B Based on ~kl-psi pre~_,sure-drop at K-valve before it will close. To reach FTP-763, well will have to be switched to L/P C/L to close in a test. CC' K M KENNEDY / W.S.-~ 'W_~_i,DE~ PRB 2~ J.P. WINTERS / C.W. SHUMWAY PRB 13 ENGINEERING WE[,L FILE A.W. BBOOKS ATO 155_l STATE OF ALASKA (COVER} DESIGNED BY' D.A.Bradlev _ At._l -' ~' ~ '., -'as"a U~i ,! ".'- ult~3' /,,.. 'qllc'l-~ol'a~e ~'///IlISs/O// RFC IVfo APR 79 1991 Aia~ka Oil & Gas Cons. Commission Anchorage REC~IVEb APR ]1991 Alaska 0il & Gas Cons, Commissior, Anchorage PRUDHOE BAY FIELD K-VALVE DOME-PRESSURE-SETTING DATA SHEET Drillsite-Well:I C°mments:I' 7-26 Date:I 2/5/91 Choke-setting has recently increased. Design to dump in well. Previous Settings: Dome Pres. (PSIG) Closure FTP (PSIG) Date 715 800 12/13/90 930 1100 6/1 0/90 Production Data: ROR= BOPD @ Deg choke CFR = BOPD @ Deg choke Swing Well (very high or Iow GOR): No Choke Priority Well: No Design Rates for Hydraulics Program PH2: Test Date 1/29/91 Oil Rate 6983 STBO/D Watercut 0 % Formation GOR 6351 SCF/STB Gas Lift Gas Rate 0 MSCF/D Total GLR 6351 SCF/STB :lowing Tbg. Pressure 978 PSIG ;Iow, Wellhead Temp. 1 54 Deg F Choke Setting 89H Deg Conditions at Valve: Temp. @ SSSV 1 67 Deg F Pres. @ SSSV 1323 PSIG Pres. Adjustment @ SSSV 115 PSIG Notice: This adjustment is at the valvet not surface. Calc. Dome Set Pres. 771.0 PSIG ~ 60 Deg F Actual Dome Set Pres. 770 PSIG @ 60 Deg F FTP at K-valve Closure 820 PSIG @ Surface K-valve Type A (Ar Br or C) cc: Farmer / Vacant Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Eng: A.W. Brooks D.S. Supv: Winters / Shumway Prep. by: ~~ ATO-1555 PRB-13 PRB-24 MODL LGR I ;51 ..... b. I I % ! I ! I ! I I 1 I t ! FLOH TEMP I I i I ;i = = TEMF' COF:REL' PIPROD EHTEF: 1]EPTH VALUE: I"IEA:E; TJEF'TH ITu'RE PRES:--; C:flSE PRE:SS TEMF'EF:ATUF:E I l'..IJ TiEF'TH CURREI'..IT 215'9 13~3/ 1058 LGF: 1 LGR 0 O 01 L ,6983 0 F'L4F '.2412 C~ GLF: ,'", ~ .=,, 1 C~ LGR 2 LfSR .] LGR ¢.3 Ci Ci I L :-.] 0 F'I.:.IF '?, 'C: GLR C~ C~ F ! =HI="i P..-. F3=MAh!.DF;EL CASE F'REE; I. __l TUBE F'RES ..... I i , ! :-_-~OO .... I - ~F:,.4! ..... · ...,.,......... F4.=R~TES; F-5=HL TEE: L I F T G A.'_:; I N..T E C T I 0 N F' L 0 T "-'"- T~le Feb ~ 18: MODL LGR 01L ,'-.'-'HTR GOR GLF; L i L::.! F"HF PH'-...' El 7.3'.;'.5 A. A ,'",].~ I ,E, 351 73?5 2.=',42 J I I I ! i FLOH T EI"IP '1 I I i ..... t ':...:'306 I , ! !.~'iD. " f" ~ -'-":'~ CASE F'RES '-'- ---- TUB~'F'";'I~'ES ..... :%'"{ TEi"iF' i':L=;GP DATE SE .... · . I A~.]E~ 01 ..... 2'~'.-.".7-'1 9' TEMF' CC;F:F:EL: F'IPROF ~'HT~'R,_., ,._ ]'!EF'TH ~., A~ I ~E",__. T',,'I) 2158 MEA'.=_; ]]EF'TH 21._ 9' -- b :$ F'F',E'.=;'.=; 12E18/ ~-': ~ S EF' F: E :E; :=-;i ;:'3 ?-'l T E i"i P E F: A T i_l F;~, E i ,':, I ,.~,_T .....TH '-" Ir''~'':~'r''' LGF: I ,---,-- ! '~1 ',L..I '1 I L G R !3 0 01 L 7375 0 F'HF 2342 A GLR ,_~,351 0 LGF: 2 LL~: - L G F: ~.3 E~ 01 L ;D E~ G L R 0 Fi=HELF'.:. F3=I',!Af.~.'F~REL F4=RATE:=_; ,I F._.,-6.1L TE'.-: Drill Site: 7 Well 26 Current C= .56035e-13 Trial C= .56035e-13 CHK LGR FTP OIL DEG MSCFD PSIG STBF'D Tue Feb 05 18:44:21 IPR TRIAL WELL TEST DATA N= ~ ~.5000 Entered N= 0.0000 Well N= 2.5000 Used FORM TOT WTR GOR GLR LIQ F'WF PROD CUT SCF/B SCF/B STBPD PSIG INDX Hydraulics Mode] is: PRUDHYD T E I A TEST Y D P L DATE P T R L ~ ........ 02 71 0 ~.~,9 6556 0.0 6483 6483 ~ .... 6 ~,17 ~,.98 /02/91 D 89 0 978 6983 0.0 6351 6351 6983 2531 6.45 01/29/91 R 80 0 937 6183 0.0 6326 6326 6183 2325 4.79 01/18/91 R 83 0 9~....,._,o.~, ~ 0 0.0 ~, ~9c, 5993 6390 ~ 33~ 4 . 98 0]./07/91 R 83 0 ' 967 63~3 0.0 5619 5619 6303 2319 4.86 01/01/'91 R 83 0 931 6474 0.0 5307 5307 6474 2287 4.87 12/26/90 R 83 0 899 6668 0.0 4930 4930 6668 2260 4.91 12/21/90 R 89 0 888 '7098 0 0 4846 4846 7098 o~ . ~,_,14 5.44 12/12/90 84 0 q21 718!. 0.0 4355 4355 7181 2325 5.55 12/08/90 R 53 0 1397 4930 0.0 5683 5683 4930 2600 4.83 11/01/90 R 54 0 14~o 51.=,o 0 0 6040 6040 5133 ~6.0 5 51 10/28/90 R 54 0 1580 ~o~ 0 0 6018 6018 4465 2769 5 24 10/17/90 R 61 0 1245 0 0.0 0 0 0 0 0.00 01130/91 F' Base Reservoir F'ressure: 3710 Current Declined Reservoir F'ressure: Date of Measurement: 05/3]./87 Rate of Decline: 2.2 F'rintino contents of current screen - wait for message to clear 361: Drill Site: 7 Well: 26 K.VALVE .DESIGN Thu Dec 13 19:59:57 1990 DOME SET PRESSURE: 715 PSIG ~_ 60 DEO~ F FTP ~_ CLOSE (PSIG): 800 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: K-valve redesigned to accommodate higher choke setting CC: C.P. FARMER /~'- PRB 24 K.M. KENNEDY / W.S. WILDER PRB 20 J.P. WINTERS / C.W. SHUMWAY PRB 13 ENGINEERING WELL FILE DESIGNED BY: JJ Scheidt RECEIVED O ~. C '? 7 '~990 .~,.iaska Oil ~, Gas Cons. Commission; Ar~chorage PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 7-26 Date: 8/1 3/89 Comments: New design required for changing GOR. Previous design was based on GOR of 1000 scf/stb. Valve failed State test of 8-5-89. Present GOR approx. 4000 scf/stb. Previous K-valve Settings: Production Data: ROR = 4329 CFR = 4329 Swing Well (very high or Iow GOR) ........... Design Parameters: Design parameters are based on (Mark one of these) XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. 4160 0 3821 0 3821 1651 131 BOPD BOPD No .Set Pressure, psig Date 960 12/31/88 880 7/16/88 600 3/23/88 @ 51 deg. choke @ 51 deg. choke Choke Priority Well .................. Yes Actual Well Test ..... Date of Test ..................... 8/1 0/8 9 Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program... XXX BOPD percent scf/stbo mscfpd scf/stbl psig deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustment PH2 PH3 PRUDHYD Other 150 deg. F 1 965 psig I 00 psig Calculated Dome Set Pressure = 1 226.0 psig @ 60 deg. F IActual Dome Set Press. FTP at K-valve Closure 1230 1550 psig @.60 deg. F psig @_ surface cc: Sennett/ Farmer Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Engnr. Alan Brooks D.S. Supvsr. Shumway/Winters Prepared by: M.R. Cook .~/. RECEIVED Oil & 6as Cons. 6ommi ior Anchorage ARCO ALA~"KA, INC P~ £)~ BOX ANt..HORA ~E ALACK A 995 t DATE: · 4-t 4-89 REF:'EREiNCE' ARCO HAGNEI"IC TAF'E:'($') WITH I.I,.S'I"IN(:~(S) 7'-26 3-t.r'2-89 CNL (3 F'A.?~) ..JOI.:,-S746 i t -9 .7,-9-89 PDK-t ~2~ < t ':.:',. PAS'S ) ..JU~' "~"".,-S'744 t t -23 3--t '3-89 F'DK-i 0'.") ( F'i..EA,S'E ,S'IGN AND RE'T'LtF;.'.N 'I'HE ATTACHFD ...OFY AF.; F;.:E:C.iEIPT OF' DA'i"A HAVE A NICE DAY! l~( r ~,'~~~ DISTRIBUTION · ,-'"' CENTRAL FILE,S' (CH) ~ PHII_LIP,S' CHEVRON - F'B WEi...L FILE,S' D & M R & D TAMMA~ BROWN (OH) $ BPX · ,,.'"' EXXON ~ ~I'A I"E OF ALASKA MARATHON TEXA .,O MOBIl_ ARCO ALASKA, INC. F'.O. BOX JOOJ&O ANCHORAGE, ALASKA 995~ DATE.' REFERENCE' ARCO CASED HOLE FINALS 2-tl J-J-89 COLLAR/PERF RUN 5-t J-t2-89 DUAL BURST TDT-P RUN 5-t5 3-t3-89 DUAL BURST TDT-P RUN 7-26 3-t8-89 CNL-GAMMA RUN ?-26 3-t8-89 DIFF TEMP RUN tt-9 3-9-89 PDK-tS~/GR/CCL RUN tt-t8 3-t8-89 SPINNER/TEMP RUN tl-25 3-~8-89 PDK-tO~/GR/CCL RUN 12-3t 3-9-89 PRODUCTION F'ACKER RUN ~8-t8 3-t3-89 COLLAR RUN t8-2J 3-2-89 PRODUCTION PACKER RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 APPROVED __~__ DI£TRIBUTION ATLAS $CH $CH ATLA~ ATLAS ATLAS OTIS ATLA~ ATLAS ATLA£ ATLAS CENTRAL FILE£ CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL - PHILLIPS PB WELL FILES R & D SAF'C £TATE OF ALASKA TEXACO PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite. Well: 7-26 Date: 1 2/31/88 Comments: GOR increased from 1700 to 3691 since the last k-valve design On 7/16/88. Was pulled on 12-19-88 for production logging. Should pass the state test easily if dumped into the Low Pressure system. Previous K-valve Settings: Set Pressurer psig Date 880 7/16/88 600 3/23/88 Production Data: ROR - 3 600 BOPD CFR - 360 0 BOPD Swing Well (very high or Iow GOR) ........... No Design Parameters: Design parameters are based on (Mark one of these) XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. 5183 0 3691 0 3691 1325 123 4 2 deg. choke 4 2 deg. choke Choke Priority Well ..................Yes Actual Well Test ..... Date of Test ..................... 1 1 / 2 4 / 8 8 Flowing Press. Survey ...... Date of Survey ...... ThAnr~fi,-~ Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program... percent scf/stbo mscfpd scf/stbl psig deg. F XXX PH2 PH3 PRUDHYD Other Temp. @ SSSV ............. 1 45 deg. F Pressure @ SSSV ....... 1 594 psig Pressure Adjustment 150 psig Calculated Dome Set Pressure = 959.0 psig @ 60 deg. F IActual Dome Set Press. FTP at K-valve Closure 960 1225 psig @.60 deg. F I psig ~. surface I cc: Sennett / Zibell Wilder / Kennedy (2 copies) State,of:Alaska :~~ cc: D.S. Engnr. K. Angel D;S. Supvsr. Shumway/Winters Prepared by: Krause Alasl~ 0ti & Gas Cons. Commlssk,; Anchorage ARCO ALASKA, INC· F'·O· BOX t00360 ANCHORAGE, ALASKA 995~0 DATE: t~-~8-88 REFERENCE: ARCO CASED HOLE FINALS 2-t6 t2-2t-88 COLLAR/PERF RUN ~, 5 · 7-26 t2-t6-88 PRODUCTION RUN ~, 5 · 7-27 't2-~6-88 CNL RUN ~, 5 · 7-29 ~2-~6-88 CNL RUN ~, 5' t4-37 t2-t8-88 COLLAR RUN l, t4-38 ~2-t9-88 COLLAR/PERF RUN t, 5" t4-39 t2-t9-88 CBT RUN ~4-39 t2-~-88 CET RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY__ HAVE A NICE DAY! SALLY HOFFECKER ATO-~527 TRAN$ ~88727 APPROVED ~ Oil & Gas Oon~ .......... Anchorage DISTRIBUTION ATLA3' $CH $CH $CH ATLAS ATLAS $CH $CH CENTRAL FILES ~ PHILLIPS CHEVRON PB WELL FILES D&M R&D EXTENSION EXPLORA'rlON . ~ SAF'C EXXON ~ ~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL F:'LFi¢',F:F ,.":.'!]I.~i~J ¢;h.J'F:., F.'I-;-T!iF-.:.'N. THF' ¢',T'f'¢4F.'tJ, F"T) .,-':Fir-: ,d,:-'-.? I:;:F£F-.I'F'T ('i!::' !~,¢.,'f'F.:',. I , iv,.,. . ,.. t ! ¢=,- TF)-- i .Oil & Gas Cons. Commission : Anchorage ¥) !' ."-::Tr-: T ",':: ! !T T f'! i"-J i": A i'.4 r': Fi f".' ¢2; M F: f"I (": ¢, M f": f'i F:. ¢,, M I-: Fi f": A M f': Fi f-: F,:', M f": Fi f": ¢, M C. F! r': ¢:, ,~.'i F: f"l f": ¢; M f".' Fi f": ~ H f': f"l f".','~ M E f'", f".' ¢24 M r~. F',' f": ,'% i"d f": f"~ f": (.':, M f': f": ¢.':.', M F: l'"l Fi ,.':~ H C. ARCO ALaska, Inc. F'.O. Box Anchorage, Alaska 995'i 0 DATE' June 9, ~987 REFERENCE' ARCO Pressure Datm ?~!~26!, 5-:31-87 Static Gradie~t t2-t 5-29-87 Static Gradi Otis Otis PLease sign and return the attached copy as receipt of data, · Received By HAVE A NICE DAY! Ro~anne Peek ATO-~ 529 TRAN$ $87294 .~. ApproYed DISTRIBUTION Centra L F i Chevron D & M Extension Exploration Exxoil Marathon Mob i [ '"'... Phi LLips p]~ , ...... '-- r..,~ "~- R & D ~ 5'oh i o · "'-.- St-a'l'e of Alaska ...'"Texaco ARCO Ata~ka, Inc' P.O. Box t00360 Anchorage, Ataska °°~l 0 ,. AT~ ~eep t emb er.- e,, i , ...,o REFERENCE' ARCO Cased Hote Final Epi /og(CNL o · - pass overlay) Run 2, EpJ tog (CNL 3 pass over lay) Run i, 5' Epi tog (CNL S pass over[ay) Run 4, 5' Epi tog (CNL 3 pac~_ over[ay) Run .. Epi log (CNL S pass over ray) Run Epi tog (F'DK-it~O Presentation Run ~, 5' Dress Dress Dre~s PLea_ce ~ig~ and return the attached copy as receipt Rosanne Pee ~ ,. ATO-t ~.~o_,.., TRAN$ ~ol~oo of data. DISTRIBUTION F'h i I. I. ips F'B Wetl. Fi I_es R ~ D ~: . . .-.._ -'-;~'~'~'['.mfe of Ata~ka Texaco ARCO Ala_~ka, Inc Anchorage, DATE' U~Ly 25,-~9 86 REFERENCE' ARCO Cased HoLe Final 7-26 4--3~-86 CNLog/MuL¢i-~pace/GR Run Dre~ F'Lea:~e ~ign and reCurn Che a¢¢ached copy Received By__ HAVE A NICE DAY! L inda HuLce ATO-J~o9 TRAN$ $86465 DISTRIBUTION $ Cent'raL Fi Le_s' ~ Chevron D & M '"'-,-Ex'l'en~i. on ExpLora'l:Jon ~r EX XOI] i'.ta r a t h on -.- Nob i [ · ,,- F'h i L I. ip s F'B WeI. L I:--i Les R & D $ ,.?oh Jo ~ ,S't'a'~e of A La.'..~l<a ~ Texaco U L~~ .Alaska Oil <~ Gas Corls. COlTimJssJo Anchorage ARCO Alaska, Inc. P.O. Box t00360 Anchorage, Alaska 995'i (} DATE' JuLy t 6,t986 REFERENCE' ARCO Mag;~etic Tapes w/Listing 7-26 4-30-86 CN/CN mvermge ECC2425 9-35 6-8-86 F'DK-t O0 ECC2455 Rec e ~ HAVE ~AY~ Linda H~Lce ATO-~ 529F Di- ~.£s Dress TRAN$ ~86438 DISTRIBUTION '"' CentraL Fi Les '18' Chevrm'~ I) & M Exte'nsion ExpLora'tion Ex xoi'~ 1' Mara Mob i L Phi L L ip.s F'B WeLL Fi Les $ohio ~'$ta'l'e of ALaska Texaco ARCO Alaska. Inc. Post Office Bo~[ 100360 Anchorage. Alaska 99510 Teiephone 907 276 1215 Date- July 8, 1985 Reference' ARCO Magnetic Tapes /d-17 CNL 6-10-85 #ECC 2176 ///2-18 LIS 5-12-85 ~304992 //6-24 CNL 6-10-85 #ECC 2174 /7-26 CNL 6-12-85 #ECC 2177 ../11-8 OH 6-27-85 ~ECC 2195 /~ 14-5 LIS 5-11-85 #304991 DA GO DA DA DA GO Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 200 ' , otis... . ~ Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Post Oftice Box 100360 : Anchorage. Alaska 99510 Telephone 907 276 1215 Date: June 26, 1985 Reference: ARCO CH -Finals 1-13L"~)ual Spaced Neutron 5-17-85 Run I 5" 1-1.7/Epilog 5-17-85 I 5" 3-9 ~/Epilog 5-15-85 1 5" 6-14 ~/Dual Spaced Neutron 5-10-85 I 5" 6-24/Epilog 5-18-85 '1 5" 7-26 ~Epilog 5-16-85 i 5" 9-21 '/Spinner 6-19-85 I 5" 9-25 ~Spinner 6-19-85 I 5" 14-13 ~pinner 6-10-85 1 5" 15-1J Epilog 5-16-85 I 5" 16-11/Temperature Log 6-8-85 1 5" Welex DA DA Welex DA DA Cameo Camco Camco DA Camco · : Received by . Para Lambert ATO 1429C Trans 180 receipt of data. . Alaska. Oil & O~s Cons. Commissio~ -- AncP~orage . -. '. . . D& M E. xp].¥- Ser'~-'~ces ~.. Ex=,_. Explorati-on ,' Marathon -~bL'l ' . ;. - PB Well Files R&D S't~'ic{ ' St'aC~ O~ Alaska:'. Texaco'-' ARCO Alaska, inc. Post Office Box 100360 Anchorage. Alaska 99510 Teiepnone 907 276 1215 Date: June 11, 1985 Reference: ARCO CH Finals' 1'18~. Collar Log ,- ~2-13/. Neutron GR 5-12-85 ---3-9 //~ Neutron GR 5-15-85 ~ ~4T9_~ Gamma Ray- 5-17-85 ...... 6-2 / CET 3-7-85 ~6-1'0 / Neutron GR 5-10-85 -~ 6-24/. Neutron GR 5-18-85 ~- 7-26/xNeutron GR 5-16-85 ~'~12-21/.Spinner 5-15/16-85 ~12-22/. Collar Log 5-20-85 ~12-22/ Spinner ' 5-21-85 ~12-25 /Temp. Log ' 5-22-85 ~---12-25 / Spinner - . 5-18-85 ~ 12-28 /Spinner -' 5-17/18-85 ~ 12-29 / Spinner 5-16/17-85 '-~-14-15/Neutron GR :: 5-11-85 ~14-35/~Neutron GR : 5-11-85 ~-~15-9 / CBL 11-8-84 5-20-85 Run 1 5" Camco i 5" DA 2 5" DA i 5" DA i 5" Sch i 5" DA i 5" DA I 5" DA 1 5" Camco 1 5" Camco 1 5" Camco 1 5" Camco I 5" Camco i 5" Camco : 5" Camco i 5" DA 1 5" DA I 5" Sch Please sign as reciept of data. Received by Pam Lambert ATO 1429C Trans 148 Chevron D & M " ~hi-tlips Expl.. Services PB Well Files . Ext. -Exploration R & D Exxon- Sohio Mara =hon $~a~e;- ~ f A~aska F~bil ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 1, 1984 Reference: ARCO Cased Hole Finals · ,~-~ D.S. 1-21 5-4-84 ~kJ- D.S. 4-13~c/ 4-11-84 '-~ ' ~--~- .,// 4-23-84 D.S. b-- i 4'"; TDT CH CNL TDT CN/MSN/GR CET Log TDT > TDT ~~.S. ~6~-18 L 4-28-8~ u.~. /-2i~/ 4-z-9c-84 PLS D.S. 7-26~/4-27-84 PLS D.S. 9-19~5-11-84 Collar/Perf Log D.S. 11-5 .3-29-R4 ~r/Basket Flw Mtr.. ,~ , ~~ 12-16 4-22-J4 ~~ D.S. 12-17~~0-84 Spinner ~~, ~ D.S. 12-18~4-22-84 TDT ~ ~ f--~D.S. 12-21~/ 5-2-84 ACBL/VDL/Signature/GR ~ D.S. 13-16~ 4-12-84 Spinner ~ D.S. 14-2/~ 5-3-84 CN/MSN/GR ~ D S. ~F' 5-3-n~' D.S. 16- 3~ ~~~~~ D.S. 16-8 . 5-10-84 D.8. 16-9~ 5-13-84 Collar/Perf RGI ~11¢~ 4-17-84 ~' 4-19-84 EPL 5" Sch Run 5 5" GO Run 2 5" Sch Run 2 5" DA Run 1 5" Sch Run 3 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" DA Run 1 5" DA Run 1 5" GO Run 2 5" Camco Run 2 5" Sch Run 1 5" Otis Run 2 5" Sch Run 1 5" DA Run 1 5" Camco Run 3 5" DA Run 1 5" GO Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" GO Run 1 5" Sch Run 1 2" Sch Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. #221 ~hevron D&M Have A Nice Day l DISTRIBUTION Mob ~ l anChorage Mobil E & P Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 24, 1984 Reference: ARCO Pressure Data D.S. 7-15 D.S. 6-23 D.S. 6-18 D.S. 7-25 D. S. 7-21 D.S. 7-26 D.S. 14-33 4-28-84 4-28-84 7-31-83 11-25-83 4-22-84 4-29-84 4-27-84 4-29-84 PBU Common Data Base Report Common Data Base Report Common Data Base Report Common Data Base Report Common Data Base Report Common Data Base Report PBU Otis GO Please sign and return the attached copy as receipt of data. HAVE A NICE MEMORIAL DAY WEEKEND! Kelly McFarland ATO-1429F Trans. # 219 DISTRIBUTION Chevron ~D&M Dr i 11 ing Exp. Services Ext. Exploration Exxon ~etty Marathon Mob i 1 Mobil E & P :'~" Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska, lnc.,'--'- Post Office ~ . 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S. 3-19f- D.S. 3-22/ · o 3/ D S 3-2 D.S. 4-1'~ D.S. 6-4~' D.S. 6-7/ D.S. 6-18/ D.S. 6-23~ D.S. 7-20/ D.S. 7-21/ D.S. 7-22 / D.S. 7-24 / D.S. 7-25/ D.S. 7-26' D.S. 12-7A D.S. 12-15 D.S. 12-18 D.S. 13-13/ D.S. 13-15 D.S. 13-16 D.S. 13-33 D.S. 18-7 / ~~P1 ease sign and 4-9-84 4-9-84 4-9-84 3-17-84 1-25-84 1-25-84 1-15-84 1-15-84 12-27-8 8-11-83 4-18-84 4-29-84 4-20-84 4-20-84 4-20-84 4-21-84 4-22-84 4-28-84 4-14-84 4-14-84 4-13-84 4-13-84 4-15-84 4-16-84 4-12-84 4-t3-84 4-12-84 41-5-84' 3-14-84 3-14-84 Static Static Static Static PBU Common Data Base Report PBU Common Data Base Report Horner Plots w/listing Horner Plots w/listing PBU PBU PBU Common Data Base Report PBU " Common Data Base Report PBU PBU PBU Common Data Base Report ~BU Common Data Base Report PBU Common Data Base Report Static PBU Pressure Draw-Down Static PBU Common Data Base return the attached copy Report Camco Camco Camco Camco GO GO Sch Sch Camco DA Camco Camco Camco DA Otis Camco Camco DA DA Camco DA DA as receipt of data. Kelly McFarland · ATO- 14 29F Chevron D&M Trans. % 187 Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Have A Nice Day! ~.~~,~~~~ D_ISTRIBUTION " 7, ~.. MOb i Mobil = & P '"'":""!f "''~'~, ~'~"~ ..... C~ 0/7 ' Phillips "~ '~ ' ~' ~-- Prudhoe Bay Well F~les R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc.~-'-' Prudhoe Bar ongineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 8, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 7-15 Permit No. 82-173 DS 7-16 Permit No. 82-182 DS 7-17 Permit No. 82-200 DS 7-18 Permit No. 82-209 DS 7-19 Permit No. 82-217 DS 7-20 Permit No. 83-14 DS 7-21 Permit No. 83-19 DS 7-22 Permit No. 83-39 DS 7-24 Permit No. 83-63 DS 7-25 Permit No. 83-56 DS 7-26' Permit No. 83-48 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lmi Enclosures cc: SOHIO Alaska Petroleum Co. File i00.0 ARCO Alaska, Inc. I$ a Subsidiary of AtlanllcRIchfleldCompany /" i' 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~.~ 2. Name of Operator 7. Permit Number 7 ARCO Alaska, Inc. 83-48 3. Address 8. APl Number P.O. Bo× 100360~ Anchorage~ Alaska 99510 50- 029-20931 4. Location of well at surface 9. Unit or Lease Name 1634'SNL, 293'WEL, Sec. 33, TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2073'SNL, 4799'WEL, Sec. 33, TllN, R14E, UM DS 7-26 At Total Depth 11. Field and Pool 1907'SNL,5234'WEL, Sec. 33, TllN, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 57' RKB, 27'GL I ADL 28309 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 03/27/83 04/08/83 04/18/83 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost ll040'MD, 9206'TVD ll000'MD, 9173'TVD YES [] X NO [] 2166 feet MD]1900'(Approx) 22. Type Electric or Other kogs Run DIL/SP/BHCS/GR, LDT/CNL/GR/CaZ, GR, CBL/BDL/Sign/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf. 80' 30" ' Instld w/1910# Poles~t 13-3/E" 72.0# L-80 Surf. 2504' 17~" Cmtd w/2130 sx Fondu & 400 sx PFC 9-5/8" 47.0# L-80 Surf. 10062' 12~'~ Cmtd w/500 sx Class ( & 300 sx PFC 7" 29.04A L-80 9767' 11040' 8~" Cmtd w/375 sx Class ( 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) 10718-10738'MD 8891-8907' ss 4 spf 5~" 9804' 9725' 10750-10780'MD 8917-8941' ss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A Ref: BHCS 4-11-83 27. PRODUCTION TEST Date First Production I Method of'Operation (Flowing, gas lift, etc.) 12/25/83I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4.5 TEST PERIOD I~ 1176~ 843 0 55 881 Flow Tubing Casing PressUre :. CALCULATED --~' OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. '86c~ NA - 241HOUR RATE~ 5534 4876 0 27.0 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None - : ,----- STATE OF ALASKA ALASK, )ILAND GAS CONSERVATION C }/IMISSlON /'~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '- , ! 29.. 30. ',' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10282' 8608 ' N/A GOC 10311' 8630 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". IZnrm I Cl_~f~'7 STATE OF ALASKA ALASK/-, _.ILAND GAS CONSERVATION C 4MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL E] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 1634' SNL, 293' WEL, Sec. 33, TllN, R14E, UM (Surface) 2073' 1907' SNL, 4799' WEL, Sec. SNL, 5234' WEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 33, TllN, R14E, UM (Top Prod) 33, TllN, R14E, UM (Total Depth) 7. Permit No. 83-48 8. APl Number 50- 029-20931 9. Unit or Lease Name Prudhoe Bay Un i t 10. Well Number DS 7-26 11. Field and Pool Prudhoe Bay Field I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 57' RKB, 27' GL ADL 28309 12. Check Appropriate 8ox To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations q Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state alt pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operating 11/20/83. RU perforating unit, pressure tested surface equipment. RIH with gun 91, shot 10756-10780' MD, 4 spf (24' ref: CBL 4/11/83), flow well to tank for cleanup, monitored rate and took shakeouts. POH - all shots fired. RIH with gun #2, select fire, shot 10750-10756' MD and 10718-10838' MD, 4 spf (26' ref: CBL 4/11/83), flow well to tank. POH - 20' gun misfired. RIH with gun #3, shot 10718-10738' MD, 4 spf. POH - no shots fired. RIH with gun #4, shot 10718-10738' MD, 4 spf (20' ref: CBL 4/11/83), flow well to tank. POH - all shots fired. RD. Secured well 11/20/83. 14. I hereb¥,Aertify that the,foregoing is true and correct to the best of my knowledge. Signed .... Title Regional Engineer The spac~l~elow for Commissio Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "lntentiQns" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate Rev. 7-1-80 ARCO Alaska, Inc. Prudhoe Bay ~-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 15, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 7-18 DS 7-19 DS 7-20 DS 7-21 DS 7-22 DS 7-24 DS 7-25 DS 7-26 Permit No. 82-209 Permit No. 82-217 Permit No. 83-14 Permit No. 83-19 Permit No. 83-39 Permit No. 83-63 Permit No. 83-56 Permit No. 83-48 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmi Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ,--. STATE OF ALASKA ALASKA ~_AND GAS CONSERVATION C~.'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-48 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20931 4. Location of Well 9. Unit or Lease Name 1634' SNL, 293' WEL, Sec. 33, TllN, R14E, UM (Surface) Prudhoe Bay Uni~. 10. Well Number 2073' SNL, 4799' WEL, Sec. 33, TllN, R14E, UM (Top Prod) DS 7-26 11. Field and Pool 1907' SNL, 5234' WEL, Sec. 33, TllN, R14E, UM (Total Depth) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 57' RKB, 27' GL [ ADL 28309 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each comple'~ion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations. (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operating 11/20/83. RD perforating unit, pressure tested surface equipment. RIH with gun #1, shot 10756-10780' MD, 4 spf (24' ref: CBL 4/11/83), flow well to tank for cleanup, monitored rate and took shakeouts. POH - all shots fired. RIH with gun #2, select fire, shot 10750-10756' MD and 10718-10838' MD, 4 spf (26' ref: CBL 4/11/83), flow well to tank. POH - 20' gun misfired. RIH with gun #3, shot 10718-10738' MD, 4 spf. POH - no shots fired. RIH with gun #4, shot 10718-10738' MD, 4 spf (20' ref: CBL 4/11/83), flow well to tank. POH - all shots fired. RD. Secured well 11/20/83. 14. I hereb¥,qertify that the.foregoing is true and correct to the best of my ~<nowledge. Signed .... Title Regional Engineer The spac~elow for Commission se Conditions of APproval, if any' Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "lntentiqns" in TriplIcate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ""'""~ 360 Anchorage .... .~ska 99510 Telephone 907 277 5637 December 27, 1983 Reference' ARCO Pressure Data ,,j,~. 6-17 12-9-83 ~,,,~.S. 7-16 12-4-83 ~..S. 7-17 12-5-83 i,-'15'.S. 7-19 12-9-83 ,~/~.S. 7-22 12-5-83 ,~D"~. 7-24 11-19-83 L..,~.S. 7-25 11-21-83 j,~.S. 7-26 11-21-83 i,//~.S. 13-14 12-7-83 Static Statzc Static Statzc Statzc Statzc Statzc Statzc Static Camco Camco Camco GO Camco DA DA DA DA '~~Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 702 DISTRIBUTION chevron D & M Dallas Drilling Exxon Getty Marathon Mobil North Geology Phillips Prudhoe Bay R&D Caroline Smith Sohio State of Alaska ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 31, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 7-18 DS 7-19 DS 7-20 DS 7-21 DS 7-22 DS 7-24 DS 7-25 DS 7-26 Permit No. 82-209 Permit No. 82-217 Permit No. 83-14 Permit No. 83-19 Permit No. 83-39 Permit No. 83-63 Permit No. 83-56 Permit No. 83-48 Dear Mr. Chatterton: Attached are "Intention" Sundry Notices detailing work proposed on Drill Sites 7-18, 7-19, 7-20, 7-21, 7-22, 7-24, 7-25, and 7-26. Sincerely, D. F. Scheve Regional Engineer DFS:la cc: Sohio Petroleum Co. ',- ~ ' ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchlieldCompany STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION CL ,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-48 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-20931 OTHER [] 4. Location of Well 1634' SNL, 293' WEL, Sec. 33, TllN, R14E, UM (Surface) 2073' SNL, 4799' WEL, Sec. 33, TllN, R14E, UM (Top Prod) 1907' SNL, 5234' WEL, Sec. 33, TllN, ~14E, UM (Total Depth) 5. Elevation in feet (indicate KB, DF, etc.) 57' RKB, 27' GL 6. Lease Designation and Serial No. ADL 28309 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 7-26 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Qil ?Qol 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit sand from the Prudhoe Bay unit. Upon perforating, the well will be flowed to a tank for cleanup. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and cleanup operation. Proposed perforated intervals: *10698-10718' MD (20') 10718-10738' MD (20') 10750-10780' MD (30') Ref BHCS 4-11-83 *To be added if needed for rate. RECEIVED NOV_ 011 & Gas Cons, Commission, Subsequent. I"Vor/¢ ~epo~ec] r 0,2 ?om~ No. ~ Da~cd _~l~(~l~d~~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 ORIG!~A[ SIGI~ED' BY H'~qRY W. KUGLER · ",;-:~ ro vec~ Copy ~eturr~ed COMMISSIONFR the Commission Submit "Intentions" m Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Olfic-'~"-.%ox 360 Anchora-c ~laska 99510 Telephone ¢07 277 5637 September 9, 1983 Reference: Arco Cased Hole Finals D.S. 1-26 ~- 4-11-83 D.S. 7-24-- 5-17-83 D.S. 7-25 / 4-28-83 D.S. 7-26 ~ 4-11-83 D.S. 13-28~-- 5-25-83 D.S. 13-29 5-6-83 ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACBL/VDL/Sig/GR/N ACBL/VDL Run 1 5" DA . . Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" se sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 515 D & M Dallas Drilling ~xxon Getty Marathon Mobi I DI STP~!BUTION North Geology ?hillips ~..,~o....-¢ .... ,,~ ? "...~--;.~ i ~.~,, .R & D . ~ , Caroline c,-. 4 ,-'~ ~... : ~'1 ~, ~,¢... ', { I~ ', .. ~.,," : .~. Soh&o ~'::~ .';' State of Alaska ARco Alaska, inc. ~---~. Post Office" 360 Anchorage. A~asKs 99510 Telephone 907 27T 5637 June 10, 1983 'Reference.: 'Arco Open Hole Finals D.S. 1-26 D.S. 7-26 4-8-83 CPL/CYberlook '-Run 1 4-8-83 BHCS r. Run 1 4-8-83 DIL/SFL - -Run 1 4-8-83 LDT/CNL/GR (Raw) ~ Run 1 4-8-83 LDT/CNL/GR (Pore) CRun 1 4-8-8.3 CPL/Cyberlook Run 1 4-8-83 BHCS/GR ' - Run 1 4-8-83 DIL/GR -- Run 1 4.-8-83 ' LDT/CNL/GR (Pore) Run 1 4-8-83 LDT/CNL/GR (Raw) Run 1 5" Sch 2" & 5'" 2" & 5" 5" 5" 5" Sch 2" & 5" 2" & 5" 5" 5" Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. ~ 372 DISTRIBUTION 'EXXON.. .... :,~.,~.... · " :..._._,MOBIL' - "'~"_D-'&.: M.. · .;?..STATE,,OF:; ALASKA' CAROLINE SMITH RECEIVED .j LI i 5 !9,,33 Alaska Un ~ ~-', ,-, ................ ARCO Alaska, Inc.f Post Office Bux 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 26, 1983 Reference: Arco Directional Data D.S. 7-24 5-17-83 Teleco EW D.S. 13-29 5-5-83 Teleco EW D.S. 1-26 3-27-83 Magnetic Survey Teleco D.S._ 7-26 3-29-83 Magnetic Survey Teleco D.S. 13-29 4-20-83 Magnetic Survey Teleco sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 356 NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL AI.~ : . GETTY D&M STATE OF ALAS~ DALLAS CAROLINE SMITH 1. Status of Well Classification of Service Well oILX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-48 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20931 4. Location of well at surface 9. Unit or Lease Name 1634' SNL, 293' WEL, Sec. 33, T11N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2073' SNL, 4799' WEL, Sec. 33, T11N, R14E, UM DS 7-26 At Total Depth 11. Field and Pool 1907' SNL, 5234' WEL, Sec. 33, T11N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 57' RKB, 27' GLIADL 28309 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore I16. No. of Completions 03/27/83 04/08/83 04/18/83I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MI~-TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11040'MD,9206'TVD 11000'MD,9173'TVD YES~ NO [] 2166 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, LDT/CNL/GR/Cal , GR, CBL/VDL/Sign/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Instld w/1910# Poleset 13-3/8" 72.0# L-80 Surf 2504' 17-1/2" Cmtd w/2130 sx Fondu & 40( sx PFC 9-5/8" 47.0# L-80 Surf 10062' 12-1/4" Cmtd w/500 sx Class G & 3(10 sx PFC 7" 29.0# L-80 9767' 11040' 8-1/2" Cmtd w/375 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 5-1/2" 9804' 9725 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~tlaska Oil & ~as Cons. STATE OF ALASKA ALASKA~-i;LAND GAS CONSERVATION C,, IMISSION 0 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIc MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad] erochit 10282' 8608' N/A G0C 10311 ' 8630' 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". DS 7-26 DRILLING HISTORY NU 20" annular preventer & 20" diverter system. Spudded well @ 1730 hrs, 03/27/83. Drld 17-1/2" hole to 2525'. Ran 64 jts. 13-3/8", 72#/ft, L-80, BTC csg w/FS @ 2504'. Cmtd 13-3/8" csg w/2130 sx Fondu & 400 sx Permafrost "C". ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 8' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8070'. Wash 8040'-8070'. Drlg 12-1/4" hole to 8800'. Pump pill. Hole tight 8271 '-8176'. Worked pipe, LD RWP. Unable to pull wear ring. Wash 8762'-8800'. Continued drilling 12-1/4" hole to 10,081' (4/5/83). Pull wear ring. Ran 249 its 9-5/8", 47#, L-80, BTC csg. Cmtd 9-5/8" csg w/500 sx Class "G" w/FS @ 10,062'. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,350'. Wash 10,253'-10,350'. Continued drilling 8-1/2" hole to 11,040' (4/8/83). Ran DIL/SP/BHCS/GR . fr/11,038'-10,056'; LDT/CNL/GR/Cal fr/11,038'-10,056'; GR fr/10,056 to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" an__nu~.us- W/300 sx PFC followed by 125 bbls Arctic Pack. Wash & ream 10,938'-11,040' Ran 32 jts 7" 29#/ft L-80 BTC lnr fr/9767'-11 040' · , ~ , . Cmtd 7" lnr w/375 sx Class "G" w/FS @ 11,040'. Washed 9241'-9382'. Drld cmt to 11,000'PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.8 ppg NaC1. Ran CBL/VDL/Sign/.GR fr/10~996'-9650'. Ran 5-1/2" completion assy w/tail. @ 9804' & pkr @ 9725'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Di spl aced wel 1 to diesel. Dropped ball & set pkr. Secured well & released rig @ 2230 hrs, 4/12/83. o4/18/83. Gyroscopic survey run on CSM/ltc MO5 Gas Cons ~urnmissi[m Eastman ~tl~ip~ock A PET'ROLANE COM~ REPORT of SUB-SURFACE D IREC TI ONA L SURVEY JOB NUMBER TYPE OF SURVEY DATE A-0383-026 TRT~ 26-MAR-83 SURVEY BY ~ (~IZ,SD DRIT,'r,~ ~TAN'i"S) OFFICE ALASKA ARCO ALA.C_:K..A ~ I NO; .......................................... DS 7, WELL NO: 26 TELECO (CDC) PRLIDHOE BAY, NORTH SLOPE, ALASKA ~TELECO ~ '-- 0-'10 .c.~ .c-'O- M D'r-'DFt~t-L-t::ER :--A-'C. HAPMAN ....................... SURVEY PRF~VIOEO BY CONTROLLED DRILLING CONSULTANTS - RIC'~: PARKER-176 A f"~: 'l'f:~(':)l~ANt! C(')Mf~NY REC:ORD OF .- S_IRVEY F~F~DII_I'.3 OF C:URVATURE METHOD ALASKA~ INC. .... WELL--MO :- PRUrlHOE BAY, NORTH SLi-iPE, ALASKA COMPUTATION ~'Ai}E NO. 1 '1' ! ME ,, DATE 15: 30: 2:3 13- A PR- 83 TDI I!~ · · blEflSUREn DR ! FT I]R T FT COURSE VERT ! CALVERT ! E:flL I]EPTH ANGLE D ! RECT T ON LENGTH 1]EPTH SECT l' FIN FEET ...... 1-1 ..... M ....... II---bi F EEZ---m.E EE-T- -EEET SUBSEA TVD EEST R E C T A N G U L A R C L 0 S U R E DOG L_Ei C iD iii R D I N A T E S D I:E:TANCE DIRECTION SEVER I" FEET FEET D___~DG/ 0. 0 0 0 '0 ..... 2504.- ...... 0 ..... 0 ......... 0---0 2/_-.57. 1 42 '.'3 8 0 275A_. 4 12 c-._, 64 0 ..... 2843. 6 6 S-. ~..8 .... 0 O. 0.00 O. 00 -57. O0 2:504. 2504.,.-00 0,,-00---2447..-00 .... W 153. 2656.98 O. 59 2599.9:3 W 93. 2749.85 3.73 2692.85 W ......... '~3 ........ 2842_A'Z ....... -11,-,72._--2'2:B5_- 47 . O. O0 O. O0 O. 00 0 0 O. 00 0.-00-- 0.00 O, O0 .... 0 ....O ........ O 2.25 S 0.32 W 2.27 S 8 0 W 1.11 5..97 S 3.02 W 6.69 S 26 50 W 3.81 9_~ 3&_::-L___~ !O._6A__.W !4= !7 .'_..3 { ..)S:.s__. 8 6 c-~, 68 0 W ¢~2.. . 293q. ~.76 22.70 2876.76 13.62 S 21.19 W 25.19. S 57 16 W _9.17 ........ :3026..-. 12. 0. :E;--67 ..... 0-W ........... 'Pl-. ...... 3023,34 ....... 38.01 ......... 29~6.-34 .......... 1.~-.70-S .... 35,85-W ..AO.-91~-.S.-~l-.13--W ...... _4..29.. ...... ~.- :3119. 14 1F: c; 73 0 W 93 3113 90 5F_:.62 3056.90 26 ex3 S ~ 72 W 61 "'~ o 64 12 W~.'-' 87 :3242. 17 6 S 78 0 W 123. '3. 2 ......... ~.a Y.,. ....... 20-42--.$-77. .... O-W .......... 1.53. 348:3. 2:2 54 ............. 361.1 .. .... 26.48 37:33. :30 54 :})856. 2:3 54 ..... :3946, :::7. 12 W ~,.,-P~'~.,-- .34,6._-,. 3~a~~l,~.l],~.,t~:]~ ,,.4.0... 16~.. W '178.28 '.3 72 21 W '.2.40 - ~.~.,~ ..... , ..... ,..~-- ~ ~...W ............... 3.1.2 o 75 0 W W 288 70 '~ 7:3 :::':) W :~..::::: c:~ 80 O'W W 354.45._ A~ 74 ~oo,. W 3.27 . (") 8 81 0 W W 4. ~,.-.~l ........ =.- 7., ....~-..-W ............. ~ ..~ A PEltgOLANE CC)M~?ANY 4070. 42 0 S 79 0 W 124. :3954.36 481.69 3897.36 117.90 S 470.75 W 485.29 S 75 56 W 4.00 4588. 4:3 30 8-...7~ ....... O-W ......... 51-8. .......... 4:3:34-.. 7:3 ........ 832.48 ........ 4277.73 ........... 184..-.9~--$ ............ 81.5...90.-...W ..... 8:3~...~f:~--$.---7.7--.14--.W .... ~ ~ 5,-,m o.-~ c. ~c, 22 c; 77 57 W 0:34 5014 4:3 A c. 81 0 W 426 4A45 02 11z~:.97 4~oo.02 67 1103 ::3 W 11 ~'-' 55:3:3. 42 42 8 81 0 W '519. 5025.5:2 1476.75 4968.52 290.89 S 1451.96 W 1480.81 '.3 78 40 W 0.06 · t6. ......... 4 :q..- 8A-.~-.8~-~--~ .... ~'~ =~ ~ ~-A 624.6. 45 24 '.3 84 0 662:3. 45' 1'2 '._:;.. 8D 0. 7090. 4.4 4:3 S :35 0 -' 9'-' 8 F:5 0 / 4 .~ .:.. 4:3 1 c. 7987. 4. 0 6 S 86 - 0 W 5:30. 55:37.47 1972. :36 5480.47 :354.60 S 194:3.97 W 1976.05 S 79 40 W 0.4!5 W ..... :::77.- ..... ~;802.. Z=.~ 2240..73 ~745.65 ....... 380.28...S ........... 2210, 71 · W ....... 2.24.3.,. 18 ....... $... E:O .... 14 .W .............. O. 20 W 467. 61:32.86 2570.74 6075.86 409.06 S :25:39.68 W 2572.41 S 80 51 W 0.09 W 403. 6422.51 2850.74 6365.51 433.48 S 2818.80 W 2851.94 S 81 15 W 0. :::7 W .... 494. 6791. :}0 :}178.98 ~7:34.80 459.2A 8 3146. :S&.W .... 31.7':~, 71 ........... 8~ 81.. 42..-W ............. O. 66 ,:,4._,4. 2:7 24 S 86 0 W ............ A'7A:3 '-'5 '. .... .,..._-.,, 1'2 :_~ 87 0 W 5?202. :3/=, 0 N 88 0 W 9./:,06. 3:3 48 N 82 0 W ........... 99Erl.. .... 41 . 0 N 74 0 W .. 467 .......... 7155.47 :3470 84 709::: 47 479.6.5 S 34:37 c~::: W 3471 zo c.._, ,=,'-"-'.,.- .:,'" W 0 .%° -249. ----7:3~6. 1 :} -.. :3617.. 95 ...... :7299. 1:} ............ 488.-/_-..5., ..... ;}5:,3~5.06-..W :3/_-,1:3.-2.1 ....... L~--.'.-32 ..... 14,--.W ........... O.....t-] 1., 499. 7761.87 3S~0/=,. 4:3 7704.87 491. 18 S :2:875.44 W 3'PC~/_',. 44 S 6:2 47 W 0.60 404. 8082.78 4146.24 8025.7:3 469,81 '.--; 4.11'P.75 W 4-146.45 S 8:.3 30 W 1.14 375. 8:370.45 437:3.36 831 :=:. 45 ......... 419.84 ,.$ ....... 4:::54.83.,W ...... 4:375..,(~2. ...... S-. 84.,,.30- ,.W ........... 1 ..45~ ARCO ALA:--:KA, INC:. DE', 7 WELL-' I',,IO: ,.'-_. "-TELECO '(CDC) ..................................................... ': ........... F'RUDHOE BAY., I',,IORTH SLOF'E, ALA'.::I<A · ; C:OMPUTATION F'AGE NO. :2 TI. ME -DATE- ............................ :-- .... 1._.~: :30 .' 2:3 13- A F'R- 8 :.-:: ........................ TRUE MEASLIRErl DRIFT DRIFT COI_IRSE VERTICAL VERTICAL SUBSEA R E C: T A N O U L A R C: L Em S U R E I~tOGLE DEPTH ANGLE DIRECTION LENGTH DEPTH :SECTION TVD C O O R D I N A T E .'3 DISTANCE DIRECTION '._--;~VER FEET' D M .... D ....1'1 ......... FEET- ............ FEET .......... FEET ................. FEET FEET FEET- D----M DG/-100 1A:300. 40 0 N 66 A W 31g '~/' . . .. .~,_-.1:3 02 4557 67 :3556.02 :347.04:3 4549. :35 W 4562.72 :3 E:5:37 W 1.66 ' ' i 09'.:.~0. '--' :E:6 ~0'- N "60 ..... 0-' W ....... 690 .-' ..... 9154';,-80---49t t-~-'25 .... 9097'~' 80 ...... t'55'~, ~-"$ .... 4'929'~ 7 C~ -'W ...... 4932 .," t'"7---'~"' 88--'t 2 '--W .......0 ,--74 ...... FINAL CLOSURE ...... DIRECTION: .....................S--'88 -£-~EGS'-~'- M I NS-4 7-SE6:.'3-'W DISTANCE: 4932,17 FEET · · ,4 Pb' i ROL.ANE CC)MFY~NY DRIFT CHART"S RELATED DATA FILE ARC 0 A L.A SI-::: A, I NC. .... t').'E: '"7'~ .... WELL"'-NO:--D'6'--ff'ELECC-$----i-ODO) PRUFIHOE BAY, NORTH SLOPE:, ALASKA SURVEY FILE NUMBER 1650 BOTTOM HOLE AS'.:;EMBLY VALUES USED FL]R DEPTH ARE DEPTH DE.:,L.R I PT I ON 105.00 2525.00 4131.00 8800.00 10081.00 [iR I L.L I NG DAY'.E; VALLE.:, I ISED FOR DEF'TH ARE MD DAY DEF'TH 1 1550.0(} ' '-',~'-' ~ 0 A ' ':' '":' 1' ":" ? (') 0 4 41:31.0() ':..-",~ ....................... ~.%7-0 .~0 ............................................ 6 7020.00 7 8220.00 ' 8 ....................... :B 875.. 00 ...................................... 'P '.-'.~ 9 -:: 5.0 c~ 10 10r)81.00 ............................ t4 ..................... 1 o.z..~:,O. O0 1~-'":' 1 ]. 0 4 ~').. (')0 ' WEIGHT ON BIT HEIGHT IS: Gt-V~N-~ER I{~--t:'OLIND$. VALUES I_ISED FOR DEPTH ARE MEI DEPTH WEIGHT 105. O0 65. O0 25?5. I]0 15.00 41.31.00 ................ 40-. O0 ..................... 8070. O0 61). 00 800.00 50.00 0081. O0 .......................45..00 .................... 0350.00 45.00 REVOLIJT IONS PER MINLITE VALUE::; DEF'TH R.P.M.~ ,4 t ~[: 7'ROt A NE COMf,~A NY 105.0~:~ 165.00 ......... 2525.00 ...... 135. O0 .................................................................................................................................................................................................................................................................................................................................... 4131. O0 100. O0 8070.00 140.00 ....... f' "800.00 ............................. -t.:30.,-(.-~0 ~ ,(') :l · -,.. :._'1 00 i 10.00 100.00 - i j i ; ; ~ i ii' ' : ~ · ' ' -~ -~ ' .... ~--'' ~- ,~1~ ' ~, ~ I . : : ~ ! ~ ~ J i [ [ ~ ~ ~. (i'l( .'( ;;- ........ I, :. .... . ''_. - ' ' .... . .... J' ........ ~- j.-- "- ~ - - l------J J - ..... ~ ' ' ! '. : !J .' ,:-! J'' , i i jr j~. ._ .-t~ : ::~1:: . :,i :i: .':i .:::, ; t; t ! Itlg '~;i:1 - :!i~l: : !!'~ :.!:! !ii! !i! ~llJ --I : 1,, ' "~' : ' : "'J ~o : !" "~!" :':" ':~"'~'~ '~'-~ ' .. I. ~ .~ T .-.-~- ..... ~._j~ . ,~ ~:.: : , i ~-~, ! ~iJ: , · ~ ' : ' ' ' t ...... . : : : · . ~ : ! ' - i ~ ! ! ~ ~-E= ,.' : '~' . ;' ;---i_ ; ; ~ ; . . , - ~ ; , : i : i : : : ~ i '. ! : : i : iii! ' ' : : : . , . ~ . '] lJ_J °°°~ i . ;. '-! .~!: j -' ' . ~ :I .... I' ,:ii i~ t ' ' ' ', , : ' ' ' ' : ~ : ! I , L ..~ .... . ' , - ' ~ ; : '~ ,i'l "~ ....r- .' 'i ''::1!':' _ i.i~nni'' 'i! ! .... ' ~ : ' ':''~ - , ~ ~ , :~ i:;.'i':. '---=:::'-:", ~ ~i: "!,:~. ' !" ',~ ,, ...: . :, ,..: ., '. , ,,, ~_ ~, , ~ ~ . . ::, !.~ ::'. ~. '!~ ~'I' -: ! ,~l~ iii - : : ' , ; -: - · : :' ;. .. . ; ,.J , ,~!, ~1~, -.-" ~T'::'Z.[ .... : : : £ ~I~ ~i , ~ : : : :::::::::::::::::::::::: .:_..-.l-z_--._ :.---.:Ji:-~,; : ~: ; .: :!:::~ ": :'::':' :l i~' ~Ji,~ lili ;-;:-!:=::- ;' · . ~ rtl;l ..: i!ii ,:' !i'.: .' . -.. i ......... i- ........... i ........... I - J~ ...I '. . :~ ~ i : - . ~ , . . ,i. ~ ; ' :'::--~..:: ::':~!ii':,!-:__:i-f:~i:ii: >.~ .... j . "-j.=- i , .;~. :~:-""." .... ~ ............ t -' " -~ ~ ~,,',a-- ...... ~.: !:':; ~..:!I! " _.. ' 'i:; ::'~ :jti _o~.,,.o.... .... t : L~' t . , , ..... :. .. i ~ ~ ! i, -. . ,. : ~:'.1 ,. . .1: ,,,,i !i ' "" ' ' ' '.i', ...... . ~=: :,: ; .:. ::: , . i: :: :! . !i~ ' :' , ' .-_ ........ , . .,, , .. , ..... ,!~, '- -, ' .... i ' , , ii'i! - : il ; ,. ' ::~: ':" --'-t- .... t ---- I--~ I ' t--- - l~nn' ' ! ! ! ' '1 i = ::i: ;i ' ~--~ - ~ I * _.,.._ ! :~=:~ '~- I~M '-~ I--- j '- I , ' ;l:,; 1':. :" J: ;: 8-~t",1~'1'- ! ; .... ~ : -,., , , ~, I,,I~1- yI , J , ; . , .. t ~ · TELEEO TELECO OILFIELD SERVICES INC. 61 16 NIELSON WAY. ANCHORAGE. ALASKA 99502 TEL. (907) 562-2646 May 18, 1983 ARCO ALASKA PRUDHOE BAY PAD DS-7, WELL #26 RIG: PARKER 176 JOB 257 AK Attached please find a copy'of the computer calculated survey for the above mentioned well. On behalf of Teleco, I would like to thank you for the opportunity to serve Arco. We at Teleco understand the importance of good service and are always striving to supply only the highest quality service to Arco. Please feel free to contact me if you have any questions. Sincerely, Field Service Supervisor SB/km Enclosures RECEIVED · · DI RECT I ONAL DRILLING SURVEY REPORT PAGE 1 CUSTOMER : ARCO LOCATION : PRUDHOE BAY, ALASKA WELL PAD : DS-7 WELL NO. DRILLING CO. : PARKER CUSTOMER JOb NO. : TELECO JOB NO. : 25?-AK RIO NO. 176 TELECO OILFIELD SERVICES OF ALASKA, INC. 6116 NIELSON WY., ANCHORAGE, ALASKA, 99502 TEL s (~07) 562-2646 DATA REDUCED BY RADIUS OF CURVATURE METHOD TYPE OF SURVEY : MAGNETIC MAGNETIC DECLINATION It 30.30 E START DATE It 85/29/83 FINISH DATE It 04/05/83 PLANE OF PROPOSED DIRECTION I8 It S 82.56 W REPORT PREPARED BY It DAVE REIMER MEASURED DRIFT TRUE VERTICAL DRIFT TOTAL COORDINATES C L 0 S U R ~ S DOG - LEG DEPTH ANGLE VERTICAL SECTION DIRECTION DISTANCE ANGLE SEVERITY DEG MIN DEPTH DEG MIN DD MM SS DEG/100 FT. 2504 0.00 2504.00 0.00 N 8.80 E '0.00 - 0.00 - 2657 1.42 2656.98 2.22 $ 8.80 W 0.16 S 2.26 E 2750 4.12 2749.86 1.08 S 64.18 W 4.02 S 0.56 W 2845 6.06 2842.48 9.09 S 68.06 W 7.39 S 8.20 W 2955 B. 06 2955.78 20.11 S 68.30 W 11.60 S 18.76 W 3026 12.00 3023.38 55.47 S 67.24 W 17.56 S 33.48 W 37. 311~ 14.18 3113.94 56.16 S 73.24 W 24.66 S 53.&1 W 58. 3242 17.06 3232.36 8~.21 S 78.18 W 32.79 S 85.69 W 91. 5503 19.18 5290.30 108.24 S BO.&8 W 56.25 S 104.42 W 110. 5595 20.42 3376.76 139.6~ S 77.18 W 42.22 S 155.32 W 141. 3488 22.54 3463.10 174.00 S 75.54 W 50,23 S 168.91 W 176. 3611 26.48 3574.?2 225.3~ S 75.54 W 62.82 S 219.05 W 227. 3733 50.54 3~81.57 285.78 S 75.30 W 77.36 S 276.09 W 286. 585~ 55.54 3785.43 349.46 S 80.06 W 91.29 S 340.51 W 352. 3946 57.12 3858.~5 401.75 S 80.48 W 99.97 S 3~2.11 W 604. 407~ 42.00 3954.19 480.71 S ?9.00 W 115.83 S ~6~.~3 W 483. 4588 43.50 4334.57 831.72 S 79.24 W 179.72 S 815.32 W 83~. 5014 43.00 4644.86 1123.~1 S 81.50 W 228.14 S 1103.16 W 1126. 5555 42.42 5025.36 1476.32 S 81.30 W 280.32 S 1~52.24 W 1479. 5716 43.30 5158.98 1601.3~ S 81.48 W 298.47 S 1575.~ W 1603. 6246 45.24 5557.52 1972.47 S 84..56 W 542.~2 S 19t4.50 W 1~7~. 6623 45.12 5802.50 22~0.23 S 85.00 W 3~6.71 S 2211.57 W 2241. 7090 ~4.~8 6132.72 2570.15 S 85.00 W 395.49 S 2540.33 W 2570. 7493 43.18 6~22.37 2850.07 S 85.18 W ~19.18 S 2819.55 W 2850. 7~87 40.0~ 6791~21 5178.21 S 86.00 W ~.10 S 3147.20 W 3178. 0.00 2.27 S 86 00 00 E A. 06 S 7 54 47 W 11.04 S A7 57 27 W 22.06 S 58 1~ 5~ W 81 S 62 19 37 W 83 S 65 15 19 W 75 S 69 03 30 W S 70 51 25 W 75 S 72 40 11W 22 S 73 26 22 W 88 S 73 59 50 W 72 S 74 20 ~8 W 53 S 74 5~ 31W S 75 41 &8 W 52 S 76 23 00 W 89 S 77 54 09 W 50 S 78 18 55 W 05 S 79 04 29 W 97 S 79 1S 52 W 57 S 80 35 03 W S 81 09 03 W 52 S 81 32 37 W 38 S 81 58 04 W 1.111 3.817 2. 075 2. 175 4. 291 2. 873 2.517 5.82~ 2. 002~ 2.431 3.171 3.3~ 3. 155 3. 980 0. 294 0. 558 0. ~58 ~. ~51 0.515 0. 576 ~. ~55 I) I RECT I ONi:IL D R ILL I ND PAGE JOB NUMBER : 257-AK CUSTOMER : ARCO PRD: DS-7 WELL NO. : 26 MEASURED. DRIFT TRUE VERTICAL DRIFT TOTAL COORDINATE8 C L 0 S U R E 8 DEPTH ANGLE VERTICAL SECTION DIRECTION DISTANCE ANOLE DEG MIN DEPTH DEG MIN DD MM SS 8454 57.24 7155.42 54G9.99 S 86.00 W 464.49 S 5458.80 W 5470.03 S 82 18 26 W 8703 55.12 7356.09 5617.05 "S 87.06 W 475.56 S 5585.94 W 5617.05 S 82 28 48 W 9202 36.00 7761.85 5905.46 N 88.18 W 476.41 S 5876.41 W 3905.57 8 82 59 56 W 9606 58.48 8082.77 4145.05' N 81.56 W 454.81 N 4120.83 W 4145.85 N 83 42 06 W 9981 41.00 8370.46 4371.51 N 73°54 W 405.77 N 4555.90 W 4374.57 N 84 42 14 W DOG - LEG SEVERITY DEG/100 FT. 0.578 0.921 0.560 1.222 1.hhl BOTTOM HOLE CLOSURE: 4374.57 FEET AT N 84 42 14 W PRINTED : 15 APR, 1985 · 12:02:41 PM COPYRIOHT (C) 1983 ABACUS COMPUTER SERVICE 820 W. 71st AVENUE ANCHORAGE, At(. 99502 ( 907 ) 544-0761 o. ............. ,~Rb ..~At_-A?,_ KA D'.=_; 7-, WELL i',,I0: 2/.-, SIGMA-GYRO JOR NO: A(')48:'::RO:'::4/_-,-PZ F'RUDHOE BAY-, NORTH SLOPE, ALASKA -- '---'IGMA--C.~YRO "'-I '~ "'"'"' MD ,-_., ,,.-,,.,c-v,-,c,, ,^u~,J/r'.,-,C,/,.M --D.C::~T-E--RMN:---~..8-~;: SIGMA :]-:00 GYRO NO: 774, F'ROBE NO: 72 ............ MERTtC~I..:.-S. E6-T..t.-raN-E:ALCLILA': I N F'LA - - - : ' ' ., W tpstock A I:'~[.!"TI:?O£ANE COMPANY ARC:O ALASKA, IN(::, ..... DS--7s-14ELE"'- NEt: .... 2/.:', ........... ::~ IOMA-O-YRO PRUDHOE: BAY., NORTH SLOPE, ALASKA dO:P-NO.~--A 0,483R0!~,46-P~ COMF'UTATION PAGE NO. ' 1 T-~ME Ehq-TE .................. 10: 28: 41 09-MAY-8:-": TRUE MEASI_IREfi DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G LI L A R C: L 0 S U R E £iOGLEG DEPTH ANGLE DIREF:TION LENGTH DEPTH SECTION TVD C: 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY ....... FEE] .......... D ..... M .......... D- M ...... FEE-T-- ...... F EE¥---FEE:F ............ FEET FEE-t: FEET D--.-N -DG-/-44}0F4 O. 0 0 0 0 O. O. O0 A. ilo -57. O0 O. O0 O. O0 t'[],,F'): ......... 0 .... -7-'S ....~--4-O--E~---~-(t(-k;- .... t<iO--,. 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NO: 26 SIGMA-GYRO ,_lOB NO: AO4:::3RO:-::46-F'Z F'RUDHOE BAY., NORTH SLOF'E., ALASKA - SIGHA :3¢~0 GYRO NO: 774, PROBE NF~: 7'2 ...... FORE.'.--:..I ~: H-~..----~.~.,:, A PE'I'ROLANE COM~:~NY ARCO AI_ASKA, INC. PRI_I[H-~OE BAY~ NORTH '.--~LOPE, ALASKA L-: 0 M F' I..I T A T I 0 N .TI. ME BATE ............ 1 ~'~: 3 3: 0 :--: 0'?- M A Y- ~:~ 3 F'AGE NO. --~'"~-~'-'---'M A RKER"~ .... T~(W~ ~-- ...... E:iJBE~EA .... C:ODE MEA'.E:IJRED VERTICAL MD-TVD VERTICAL R E C T A N S I_1 L A R C: L 0 S I_l R E VERTIC:AL NAME: DEPTH DEF'TH DIFF DEPTH C 0 0 R D .I N A T E S DISTANCE DIRECTION THIE:KNES:S; ................................................... -:---:'---FEET- ..... FE E-T- - ----~ EE-T-- --- F E E-T FEET FZET 'D .... Pt TOP SAG RIVER 1013'~.00 84'~:::.27~ 1640.7 8441.27~ 468.8r~ S 4418.78 W 4443.58 S :::3 57 W ..... =F 0 P -" tE: H U B L"I-~:--'A ~-t-~:'0 e---~'~:-~,'4~-~r--~ 4 7 G: ~ 6- .... ~ 6J:O ~F-G~--4 4-4 -1-'; -~ ~7~ - W ~ -4 4-6~'~ ~'--- ~-- 8' 4 .......4---W TOP SHI_IBLI K B ' 10217, 00 :::557. '~'~ 165'~. 0 8500, '~'? 452, 6':~ S 4466,32 W 4487~, 21 'S :::4 13 W TOP SHI...IBLIK C: 1023$~,00 8574,85 1664.1 8517,85 447.S~4 S 4.477~,63 W 4501.$77 S 84 ~7 W -~TOP-~-SADLEROC~HtT .............. t'-028~-'GG ...... 86G'~'~.8{ .....~-~4~~550~-8.~ ........ ~~~'-~5.6~ 4526,'?~ S 84--~6-W .... 4._ 4.,:, I]1 I"':CINTAC:T 10311.00 8/-,'-':¢J, 08 1 ,:,--,,- · .'F'/ ..... :,7..:, 08 4':-,,..'2.' 40 c-,_, '~'"~-.,.- .,...:,. 16 W ~ '" 78 c. 84 :::2 W ..... TCIP-ZC~NE":~ .............................. ~l'05:?,8-;0¢~ .......... 8805 ;-70-'~1"-7~,~-2~"C'~ ..... 8'7'48 ~-'-'70 ........... ~88~'~-(~,'~2-S--4658~-4~--W ...... 46-74-~-~x2---'.S--8~';'.'-18 · W .......... ' 'I"OP ZnNE .... ..-'-' 106.:' '-'.=, .... ¢~0 88:::1, , ~:R.._ 1753.2 8824' , ,_c.: c:.. ._ 362.66 S 4714.7'F/ W 4728.72 S ,:,._~'~ g:/:,_ W - c~,.:: o/. ~-, HO"F 1 t~7 .-. ,:. 00 ':.-~011. 21 17,_, :,, ,:, 8.~754 .21 .--.,'-"-'/... u,, 'F.~O ~-._, 4807 .25 W 48 1..,':' . ._,-:,.=,._ c.._, 86 7 W .......... c ' ' "' ~- I .-- o9-. ~-c~o-- ~4.~:;-,-~7..,~-W----4~.el.-~.~--,-47 ..... .-_ ....... o/_-,..~.,~-7--..W Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Well Nares and Number Reports and Materials to be received by: c~--/ Date Required Date Received Remarks .. Ccmpletion Report yes ., Well History Yes ~_~.~,._ .~ /--~. ~.~ . ~.~ / Core ~scription ..... ,.. Registered ~ey Plat Inclination S~ey Drill St~ Test Re~s ..,,:..~.~ . .:._,.~ ......... /~-' ~u~on T~t Re~s ~s R~. - . _~' <_.>..:~, .:/., : .... , , , ", ARCO Alaska, Inc. Post Office b,~,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 11, 1983 Mr. C. V. Chatterton Commissioner State 'of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive .Anchorage, Alaska 99501 Subject' Monthly Report of Drilling & Workover Operations Dear Sir' Enclosed find Monthly Reports of Drilling and Workover Operations for the .following: i/.~.'DS 7-26 DS 7-25 DS 7-24 -DS 1-26 DS 13-29 DS 5-11 NGI #7 S. Point State #1 Sincerely, M. A. Major Area Drilling Engineer M~B~/CS~: tw Attachments ARCO Alaska, ir)c, is a s[zbs~diary Of Atlanli :Richlie~ldCompany MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of Well at surface 1634'SNL & 293'WEL, Sec. 33, TllN, R14E, UM ~7~,e~(t~o~n ~r~ee~L(indicate KB, DF, etc.) [ 6. LeaseADLDesionation28309 and Serial No. 7. Permit No. 83-48 8. APl Number 50_029-20931 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 7-26 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of Ap ril ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded @ 1730 hfs, 03/27/83. Drld 17-1/2" hole to 2525'. Ran, cmted & tstd 13-3/8" csg. Drld 12-1/4" hole tc 10,081". Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 11,040'. Ran logs. Ran, cmtd, & tstd 7" liner. Drld cmt to 11,000'PBTD. Ran logs. Ran 5-1/2" compl assy. Secured well & released rig ~ 2230 hrs. 4/12/83. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 80'. Instld w/1910# Poleset. ,13-3/8", 72#/ft, L-80 BTC csg w/FS (~ 2504'. Cmtd w/2130 sx Fondu & 400 sx PF "C". 9-5/8", 47#/ft, L-80 BTC csg w/FS @ 10,062'. Cmtd w/500 sx Class G cmt & 300 sx PFC for AP job 7", 29#/ft, L-80 BTC csg w/FS ~ 11,040'. Cmtd w/375 sx Class G. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SP/BHCS/GR fr/11,038'-10,056' LDT/CNL/GR/Cal fr/11,038'-10,056 GR fr/10,056'-2504' CBL/VDL/Sign/GR fr/10,996'-9650' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGN[D TITLE ^rea Drilling [ngineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate DS 7-26 DRILLING HISTORY NU 20" annular preventer & 20" diverter system. Spudded well @ 1730 hrs, 03/27/83. Drld 17-1/2" hole to 2525'. Ran 64 jts. 13-3/8", 72#/ft, L-80, BTC csg w/FS @ 2504'. Cmtd 13-3/8" csg w/2130 sx Fondu & 400 sx Permafrost "C". ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 8' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8070'. Wash 8040'-8070'. Drlg 12-1/4" hole to 8800'. Pump pill. Hole tight 8271'-8176'. Worked pipe, LD RWP. Unable to pull wear ring. Wash 8762'-8800'. Continued drilling 12-1/4" hole to 10,081' (4/5/83). Pull wear ring. Ran 249 jts 9-5/8", 47#, L-80, BTC csg. Cmtd 9-5/8" csg w/500 sx Class "G" w/FS @ 10,062'. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,350'. Wash 10,253'-10,350'. Continued drilling 8-1/2" hole to 11,040' (4/8/83). Ran DIL/SP/BHCS/GR fr/11,038'-10,056'; LDT/CNL/GR/Cal fr/11,038'-10,056'; GR fr/10,056 to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 sx PFC followed by 125 bbls Arctic Pack. Wash & ream 10,938'-11,040'. Ran 32 jts 7", 29#/ft, L-80 BTC lnr fr/9767'-11,040'. Cmtd 7" lnr w/375 sx Class "G" w/FS @ 11,040'. Washed 9241'-9382'. Drld cmt to 11,000'PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to 9.8 ppg NaC1. Ran CBL/VDL/Sign/GR fr/10-996'-9650'. Ran 5-1/2" completion assy w/tail @ 9804' & pkr @ 9725'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Di spl aced wel 1 to diesel. Dropped ball & set pkr. Secured well & released rig @ 2230 hrs, 4/12/83. CSM/ltc MO5 · . ARCO Alaska, inc. Post ·Office BOX 3-60 Anchorage. Alaska 99510 Telephone 907 277 5637 May 11, 1983 Reference: Arco Magnetic Tapes and Listings ~ D.S. 7-25 ~ 4-24-83 OH tape w/List Run 1 Sch #68216 ~ ' ' ~4-24-83 RFT Pre-Edit w/List Run 1 Sch #68216· ~D.S. 2-6---- 4-14-83 ~ CH CNL w/List Run 4 Sch #68214 ~D S 5-7/ 4-14-83 CH CNL w/List Run 10 Sch #68215 ~D.S. 9-4c/ 4-17-83 CH CNL w/List Run 7 Sch #68201 D.S. 1-8// 4-18-83 CH CNL w/List Run 6 Sch #68200 · D S 7-~26 4-8-83 OH w/List Run 1 Sch #68176 ~D.S. 6-3/ 4-13-83 CH CNL w/List Run 1 Sch #68213 D.S. 7-14_,-'- 4-22-83 CN/MSN w/List DA #1689 D.S. 4-13~,' 4-23-83 CN/MSN w/List DA #1690 '[/please Sign and t c~ a receipt of data.' Kelly McFarland AFA-403 · T~ans. # 336 NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL STATE OF ALASKA ..... '"'" DALLAS '-'~'"-~:: .... :' ," ¢ . . CAROLINE SMITH-O~ ~ ARCO Alaska, Inc. ,,~-~. Post Office f ~360 Anchorage. A,dska 99510 Telephone 9,.37 27- 5637 April 21, Reference: 1983 Arco Directional Data D.S 1-26 D. S. 7-7A D.S. 7-26 3-25-83 Teleco 3-15-83 Magnetic 3-26-83 -Teleco EW Survey Teleco EW ase sign and return the attached · Kelly McFarland AFA-403 Trans. # 301 copy as receipt of data. NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION MOBIL GETTY Alaska 0il & Gas Cons. A~.r;horage D&M STATE OF ALASKA DALLAS CAROLINE SMITH ~ --. ~ f~, STATE Or: ALASKA ALASKA ~- .AND GAS CONSERVATION CO AISSION MONTHLY REPORT OF DRILLING AN__DD WO____RKOVER OPERATIONS / · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-48 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of Well 1634' SNL & 293' WEL, Sec. 33, T11N, R14E, UN at surface 5. Elevation in feet (indicate KB, DF, etc.) 57' RKB, 27' GL 6. Lease Designation and Serial No. ADL 28309 8. APl Number 029-20931 50- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 7-26 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. Ma rch ,19. 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded (~ 1730-hfs, 03/27/83. Drld 17-1/2" hole to 2525'. Run, cmtd & tstd 13-3/8" csg.. Drld 12-1/4" hole to 4213' as of 03/31/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft U-40, weld-on conductor set ~ 80' Instld w/1910# Poleset 13-3/8", 72#/ft, L-80 BTC csg w/FS ~ 2504'. Cmtd w/2130 sx Fondu & 400 sx PF "C". SEE DRILLING HISTORY 14. Coring resume and brief description N/A 15. Logs run and depth where run None 0. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Area Drilling Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by t~ ~15/t~ ~the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate DS 7-26 Drilling Hi story NU 20" annular preventer & 20" diverter system. Spudded well @ 1730 hrs, 03/27/83. Drld 17-1/2" hole to 2525'. Ran 64 jts 13-3/8" 72#/ft, L-80 BTC csg w/FS @ 2504'. Cmtd 13-3/8" csg w/2130 sx Fondu & 400 sx Permafrost "C". ND 20" diverter system. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 8' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 4213' as of 03/31/83. CSM/DHIO'llm 04/15/83 MEMORANOUM State of Alaska ~ASKA OIL AND GAS CONSERVATION COMMISSION TO: C. erton ~/ DATE: March 31, 1983 T~RU: Lonnie C. Smith/ EPHONENO: Commissioner FROM: Ben LeNorman SUBJECT: Petroleum Inspector Witness BOPE Test on Arco's DS 7-26, Sec. 33, TllN, R14E, Ugi. Prudhoe Bay Unit Monday,~ ~!ar..ch_ 28_,_. 1983: I departed my home at 3:15 p.m. for ~3:45 p.m. showup and 4:45 p.m. departure via Alaska Airlines Flight #341 for Deadhorse arriving via Fairbanks at 7:10 p.m. Weather: -7"F, Clear, light wind. Tuesday._, [.-~'.~a. rch.._29, 1983: BOPE tests began at 2:40 p.m. and were cOmpleted at- 8:30 p.m. BOPE Inspection Report is attached. ~Tednesda¥, ~arch 3_0, 1983: I departed Deadhorse at 9:45 a.m. via Alaska Airlines, Flight #66 arriving in Anchorage at ]1:25 a.m. and at my home at 12:05 p.m. In sum~ry, 1%~tnessed successful BOPE tests on Arco's DS 7-26. 02-00IA(Rev. 10/79) 4/81 /~STATE OF ALASKA ALASKA OIL _ G~S ODNSERVATION CCMMIS. SION B.O.P.E. Inspection Report _Inspector Operator Representative_ ~3 ~~~" -- ' ~Casing Set @ ~--~ ft. Location: Sec ~3 T,;~R / ~-M ~/~. ' ~" Drilling contraCtOr F--~ .~ ~.~ Rig #/~ RepreSentative ~~--7~ /~./g)//~/3 Location, Genera] Well-Sign Ceneral Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Blind Rams Choke Line Valves H.C.R. Valve- Kill Line Valves Check Valve. Test Pressure ACC/~LSATOR SYSTEM Full Charge Pressure ~Csf3f) psig ..' . Pressure After Closure /JOO psig Pump incr. clos. pres. 200 psig, FUll Charge Pressure Attained: ~ N2 /~! ,-,";-~1:),~:. Y~)~ -~o~psiq Controls: Master ~ /.-~ Remote ~A~ Blinds switch cover .Y~.~ Kelly and Floor Safety Valves · Upper Kelly Lower Kelly Ins ide BOP Choke Manifold No. valves~/_.O. No. flanges_ ~ Adjustable Chokes Test Results: Failures_ Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure Hydrauically operated chcke Test Time~ ~76. hfs .~ Repair or Replacement of failed 'equipment to be made within~ , Inspector/Ccmmission office notified. days and March 15, 1983 Mz. Mark A. Major Area DTilling Engineer ARCO Alaska, Inc. P. O. Box 360 ;m_chorage, Alaska 99510 Re~ Prudhoe Bay Unit DS 7-26 ARCO Alaska, Inc. Permit ~o. 83-48 Sur. Loc. 1634'8i~L, 293'WEL, Sec. 33, TllN, R14E, UM. BtnC~ole Loc. 2250'SML, 20'~L, Sec. 33, TllN, R14E, UM. Dear Mr. }~jor: Enclosed is the approved application for permit, to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required a~ per 20 AAC 25.050(b)(5). If available, a tape containin~ the digitized io~ information sha~ll be subr~itted on all log~ rot coping except~experimental loss, velocity surveys and dipme~ter surveys. -Many rivers in Alaska and their drainage system~ have been classified as important for the spawning or migration of anadromous fish. Operations in tbe~e areas are subject to AS 16.05.870 and the regalations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's O~ D~partment of Fish and Game. ~ fice, Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7'and the regulations promulgated thereunder (Title 18, Alaska Administrativ~ Code, Chapter 70) and by the Federal Water Pollutioz~ Control Act, am amended. Prior to commencing operation~ you may be contacted by a representative of the .Department of Enviror~emtat Conservation. To aid um in ~cheduting field work, please notify this office 24 hours prior to commencing inmtailation of the blowout Mark A. Major Prudhoe Bay Unit DS 7-26 -2- March 15, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this. office adequate advance notification so that we may have a witness present. Very trul~ -yours, C. V. Chatterton Alaska Oil and Gas Conservation Co~issi°n Enclosure cc: Department of Fish &'Game, Habitat Section w/o encl. ~Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~... J60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 10, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 7-26, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 7-26 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's posi- tion to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on March 23, 1983, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG2L26' 1 lm Enclosures RECEIVED Alaska 0il & Gas Cons. Commission An~hora~ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -'-- ALASKA O,L AND GAS CONSERVATION CO,,,MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~[~ lb. Type of well EXPLORATORY [] REDRILL [] DEVELOPMENT OIL DEEPEN [] DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. SERVICE [] STRATIGRAPHIC [] SINGLE ZONE []X MULTIPLE ZONE [] 3. Address P. O. Box 360, Anchorage, Alaska 99510 RECEIVED 4. Location of well at surface 1634' SNL & 293' WEL, .Sec. 33, T11N, R14E, UN At top of proposed producing interval 2188' SNL & 518' EWL, Sec. 33, T11N, R14E, UN At total depth 2250' SNL & 20' EWL, Sec 33, T11N, R14E, UM MAR 1 4 'i98'3 Alaska 0il & Gas Cons: Cornmissi Anchorage 5. Elevation in feet (indicate KB, DF etc.) 57' RKB 27' GL 12. Bond information (see 20 AAC 25.025) 6. Leasedesignation andserialno. ADL 28309 Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number DS 7-26 11. Field and pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 7-4 well 2,~ ~ surface feet 18. Approximate spud date ~4arch 23, 1983 13. Distance and direction from nearest town 5 mi. NW of Deadhorse miles 16. Proposed depth (MD & TVD) 10989' HD, 9185' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2600 feet. 21 14. Distance to nearest property or lease line 20' ~ TD fr/ADL 28310 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 41 o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 3411 psig@ Surface 4169 _psig@ 91R5 ft. TD (TVD) SIZE Hole Casing Weight BO" 20" 91.5# 7-1/2" 13-3/8" 72# 2-1/4" 9-5/8" 47# I 8-1/2" 7" 29# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Welded L-e0 IBu T / L-80 IBUTT / SETTING DEPTH 2520' Length MD 82' 30' I 30' I TOP TVD 30' 30' I 0043' 29' I 29' I 1217' 9772' 18268' MD BOTTOM TVD 112' 112' 2550' 12550' 10072' 18494' 10989' !9185 I I QUANTITY OF CEMENT (include stage data) 1910 # Poleset (to surf) 2300 sx Fondu + 400 sx PF 500 sx G 1st stage 300 sx PF 1, 2nd stage 400 sx Class G cement ARCO Alaska, Inc., proposes to directionally drill this well to 10989' MD (9185' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 27#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. DS 7-4 will be.2J~ away from DS 7-26 at the surface. There are no closer wellbores anywhere down hole. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~ ~ TITLE Area Drilling Engineer The space below for Commission use DATE CONDITIONS OF APPROVAL Samples required I--lYES ~NO Permit number APPROVED BY Form 10-401 r-, _.. GRU2/PD11 Mud Icg required I Directional Survey required [~]YES [~NO I I~Y E S •NO Approval date APl number 5o- o-~'~~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE lvT.~rC_t~ 1_5, 1983 by order of the Commission Submit in triplicate CHK. DATE lOB NO. i HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS CO CT, AS iO/4-/ Z _~_~'~--~ -' ~ ,~.'c....,.o.,.. %0 -k,~.-" ^ ",?r ~, 1 ¢,9 .,-.. ..,,.,, %; "'"' -'-' -- .~.-: .' :: 7/23 LAT - 70°~5'57.930'' L0~6 - 14S°34'36.537'' ¥ = 5,9~8,534.~4 x = 676,002.66 NW CORNER CELLAR BOX Et£V = 26.82 7/24 tAT = 70°15'59.079'' t0[;G = 148°34'37.272'' Y = 5,949,050.67 X = 675,~74.6~ NW CORNER CELLAR BOX ELEV = 26.42 7/15 tAT = 70°16'07.52~' LONG = 48°34'15,431'' Y = 5,9~3,926.66 X ~ 676,705.72 CORNER CELLAR ~OX ELEV = 27.29 7/16 ~AT - 70°16'06.733'' LOnG = 48°34'14.6~4TM Y ~ 5,949,810.1~ X - 676,733.05 N~/ CORNER CELLAR BOX ELEV = 27.44 7/17 LAT = 70°16'05.225TM LONG = 48°34'13.954'' Y - 5,949,654.09 x - 676,760.90 ~ CORNER CELLAR ~OX ELEV = 27,31 7/)8 LAT = 70°16'04.710'' LONG - 48°34'13.225'' Y - 5,9~9,577.q5 x ~ 676,78~.69 N"J COR~ER CELLAR BOX ELEV = 27.29 ?/i9 LAT - 70°16'02.915'' LONG = 4g°34'12.505'' Y * 5,9k9,460.46 x ~ 676,816.1~ CORNER CELLAR BOX EL~V = 27.35 7/20 LAT - 70°16'01.763" LONG - 45°34'11.7'c'',~ y - 5,~k3,344.g4 X = 676,$43.S9 N~ CORNER CELLAR Z0X ELEV - 27.30 7/25 tAT = 70°16'00.236'' 7/21 t~T - '70°!6'00.609'' LONG = 148°34'38.005'' LONG = 148°34'11.047'' Y = -5,~49,'J~7.66 Y = 5,9k9,227.26 X = 675,946.76 X - 676,$71.77 NW CORNER CELLAR EOX ELEV = 26.44 NW CORNER CELLAR EON ELEV = 27.37 7/26 tAT = 70°16'01.393'' 7/22 LAT = ?0°15'59.451'' LONG = 1h8°~4'38.712''~ t~iS = 14~°34'10.3~2''- Y = 5,a49. ,.~84,67 y = 5,9k9,110.18 X = 675,~19.74 X = 676,899.43 NW CORNER C~LLAR BOX ELEV = 26.69 ~.' Ce~NER CELLAR B~ ELEV = 27.59 P. $. "/ /I rv - ?.c, AS - L41t..T i m ARCO At'-.=.=oka, [nc. Subsid:ory of ~,tlontic Richfield Company NORTH SLOPE DRILLING-PRUOHOE BAY 13-5/8" BOP STACK DIAGRAM ANNULAR PREVENTER BLIND RAMS Accumulator Capacity ~est 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. PIP~ RAMS SPOOL PIPE RAMS 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of '3, minutes, then .test at the high pressure. $. Increase presure to 3000 psi and hold for a minimum of 3 minutes. B~eed pressure to'zero. 6o Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7o Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams o Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate 8OPE daily. Rev. 5113/81 SURFACE HOLE D ]-VERTER ARCO ALASKA SYSTEM INC. SCHEMATZC I0" HYD. OPR. BALL VALVE WELL BORE (SEE DETAIL) I0" HYD. OPR. BALL VALVE ~ ALL 90° TURNS ARE "TEE" CUSHION I t~LL QBORE RESERVE PIT AREA NOTE' FLOWLINE DRILLING RISER l 20" 2000 PSI WP ANNULAR PREVENT(DR 'Valves on diverter lines open automati- cally when the annular preventer is closed. -- DR ILL lNG SPOOL 20" CONDUCTOR PIPE I O" HYDRAULIC OPERATED BALL VALVES "DETAIL" 202..60 I( CHECK LIST FOR NEW WELL PERMITS Company Lease & Well'No. ITEM APPROVE DATE (1) Fee (2) Loc (Y thru 8) l® e 5. 6. 7. 8. (3) Admin >4/f__j (,.9/thru 11) .10. 11. (4) Casg ~-~ -~-/~-~.~ (12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. '(21 thru 24) 22. 23. 24. (6) Add: ~ ,~-fty-2~""'x.'-¢ 25. YES NO Is the permit fee attached .......................................... ,~-__ Is well to be located in a defined p°ol .............. ~ Is well located proper distance from property lin; lllllllll.l.l..lil,"~z-.~ Is well located proper distance from other wells .................... ~ Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait ....................... '... Does operator have'a bond in force ..... · ......... Is a conservation order needed .... Is administrative approval needed ~'iiiii~iiii~. . Is conductor string provided ...... ............................. Is on°ugh cement used t° circulate °n c°nduct°r and surface '[]" !ii ~ Will cement tie in surface and intermediate or production s:rings[ Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones .................. Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore , ............ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ................. . .......... Is a diverter system required ...... Are necessary diagrams of diverter Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. ~ REMARKS .NoT ~oz?/w~/"TV---/) Additional Remarks: Geology: Engi ,n .~er ing: !{WK ~ LC S <~ BEW ~ rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particulady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. P~OGRAM: LISCAN REVISION: 5.1 PART NUMBER: W5790-PE3~ Start of ex'ecution: T. hu 6 APR 89 1:28p **** RE~L HEAOER **** LIS 89/10/03 ATLAS 01 'LIS CUSTOMER FORMAT TAPE' ***4 TAPE HE~DER **** LIS 89/10/03 3746 01 ~THREr- PASS CN'/MS' FILE # 1 PASS 1.001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC WN- : O.S. 7-26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DmPTH UNIT : FT 16 CURVES : NAME CODE SAMPLE# UNiT 1 GR 68 I API 2 TTEN 68 I LB 3 TEN 68 1 LB 4 SPD 68 I F/MM 5 CCL1 68 I VOLT 6 CCL 68 I VOLT 7 CCL2 68 I VOLT BYTES 4 4 4 4 4 4 4 10 LSN 11 CLSN 12 CN 13 CNC 1/, CNRA 15 TEMP 16 DTEM 6~ 1 CT$ 68 I CTS 4 68 I PCT 4 68 I PCT 4 68 I C/C 4 68 1 DEGF 4 68 I DEGF , DATA RECORD DEPTH CCL1 LSN TEMP 10987.000 65533.00 65470.45 8.049196 10937.000 6.000000 40,05818 25.17021 10887.000 1.000000 41.37589 28.21213 10837.000 3.000000 ~4.t7871 28.19276 10787.000 3.000000 53.42331 28.15454 10737.000 1.000000 69.78239 28.22475 10687.000 5.000000 87.47562 28.16225 10637.000 3.000000 87.00249 25.2241t 10587.000 1.000000 I 69. Q901 28.21817 10537.000 (TYPE# GR CCL CLSN DTEM 150791.3 6553'3.00 16367.62 10.12700 22.63878 6.000000 9.743925 0.6999999E-01 73.44827 1.000000 9.447025 -0.181OOOO 86.74828 3.000000 7.427700 -0.4200000E-0t 25.79132 3.000000 13.06198 -0.1340000 23.65895 1.000000 15.80887 0.4999999 -0 . 1 1 4 -0. E-02 27.65761 5.000000 18.94087 .5500000 E-01 37.19209 3.000000 20.23718 3900000 E-01 9.32744 .000000 I .41345 4000000E-01 5.96120 958 BYTES * TTEN CCL2 CN 463.5542 0.4140000 15.00000 716.6675 0.4140000 38.46219 715.9131 0.4140000 29.30110 717.6372 0.4140000 42.33438 736.0217 0.4140000 ~6.89838 730.1348 0.4140000 30.53250 727.5068 0.4140000 27.41483 725.3584 0.4140000 25.96426 714.0623 0.4140000 13.24657 690.1890 TEN SSN CNC 149.4351 65307.48 19.00000 120.1148 151.3513 42.46219 21.78616 146.6278 33.30110 -13.64845 220.6058 46.33438 -8. 557390 177.6507 30.89838 -23.79214 217.6785 34.53250 -34.82613 259.3303 31.41483 -25.17197 260.1714 29.96426 -23.36604 340.9253 17.24657 -41 .73561 SPD CSSN CNRA 21.99780 65307.48 0.2506239 28.82671 157.2442 0.6196682E-01 29.04401 126.5648 0.7464182E-01 29.31230 126.8253 0.5856638E-01 29.99701 165.6610 0.7884765E-01 30.07051 220.0155 0.7185346E-01 29.99701 244.9635 0.7732117E-01 29.99701 252.0239 0.8029866E-01 29.99701 340.9561 0.1214627 29.91760 "4 ':[ A A177 t 0487. 000 79. 60030 711.6001 -22 · 56084 30 · 37340 3.000000 3.000000 0.4140000 235.0281 237. 9428 72.83240 18.67168 26.71407 30.71407 O. 78471 3CE-01 2~. 201 07 O. 7400000E-01 10437.000 24.78406 1.000000 1.000000 72.67662 15.55448 28.233t4 -0.1060000 10 387.000 58.63718 3.000000 3.000000 103.91 25 1 8. 83963 28. 22487 -0. 3300000E-01 10337.000 40.15796 1.000000 1.000000 77.Q1652 22.08273 28.20651 -0.1800000 10287.000 22.40125 3.000000 3.000000 115.9032 31.62642 28.25459 0.81000C3 10 237.000 64.78320 1.000000 1.000000 201.9798 44.53577 28.27718 0.5000000 E-01 E-01 E-01 686.8220 0.4140000 33.72935 685.4946 0.4140000 26.74309 693.5752 0.4140000 22.54472 694.9182 0.4140000 17.06586 683.1316 0.4140000 12.93320 -38.00513 226.5880 37.72935 -36.41550 294.8506 30.74309 -23.31331 239.0929 26.54472 -20.60184 287.5574 21.06586 -18.29817 385.9614 16.93320 30.31702 232.4614 0.6691706E-01 30.35941 241.0637 0.7815206E-01 30.34370 252.0541 0.8761108E-01 30.32971 302.2766 0.1046274 29.99701 363.2305 0.1226102 TOTAL DATA RECORDS STARTING TAPE DEPTH WiLE TRAILER **** : 109 = 10987.00 ENDING TAPE DEPTH = 10227.00 FILE # 2 **** FILE HEADER **** PASS 2.002 1024 FORMAT ~.ECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNiT : FT 16 CUR'VE S : NAME CODE 1 OR 68 2 TTEN 68 3 TEN 68 4 SPD 68 5 CCL1 68 6 CCL 68 SAMPLE# 1 1 1 1 1 1 UNIT API LB LB F/MM VOLT VOLT BYTES 4 4 4 4 4 4 9 CSSN 10 LSN 11 CLSN 12 CN 13 CNC 14 CNRA 15 TEMP 16 DTEM 6~ 1 CTS ~ 68 1 CTS 4 68 I CTS 4 68 I PCT 4 68 1 PCT 4 68 1 C/C 4 68 I DEGF 4 68 I DEGF 4 DATA RECORD DEPTH CCL1 LSN T;MP 10999,000 65534,00 65482.46 6.009399 I 0949.000 3,000000 41.42299 28, ~_0891 10599,000 1.000000 35,84421 28.21754 10849,000 5,000000 30.53891 28.32237 10799.000 3,000000 49.69751 28.21147 10749.000 3,000000 75,01912 28.20473 10699.000 5,000000 82.68672 28.21404 10649,000 244.0000 81,54451 28.20526 10599.000 3,000000 161 ,6736 28,23741 (TYPE# O) GR CCL CLSN DTEM 150800,6 65534.00 16370,62 11,10300 18.41455 3.000000 15.98717 -0. 2300000E-01 24.09076 1.000000 13.54925 0.6699997 E-01 76,47263 5,000000 7,024976 O, 1000000E-01 31,54211 3,000000 12,56328 0.2600000E-01 24,39598 3.000000 19,04790 -0.4300001E-01 35.55920 5,000000 19.98708 -0.6300002 E-01 36.34526 244.0000 19· 69~63~ -0,3400000 E-01 19.33250 3.000000 39.13629 -0,659999~E-01 958 BYTES * TTEN CCL2 CN 439,1560 0.4140000 15,00000 718.5667 0.4140000 24,41899 712.8254 0.4140000 28,05432 729.9885 0,4140000 43,67311 728.2964 0.4140000 28,07375 748.3213 0,4140000 25.60127 727.6848 0.4140000 23,89079 720.9009 0,4140000 26.45909 721,5923 0.4140000 13,74517 TEN SSN CNC 134.1866 65354.46 19.00000 143,0072 148,9470 28.41899 31.18840 128.2654 32,05432 -7.897367 131 ,2027 47.67311 -12.46779 170.0961 32.07375 -8,715681 240.1558 29.60127 -26.05373 250,2337 27,89079 -31,96887 250.4210 30,45909 -28.01608 328,7146 17.74516 SPD CSSN CNRA 19.99799 65354.46 0.2504897 23.99762 191.6140 O. 8343428E-01 27.86470 177.3176 0.7641232E-01 28.28209 121.6136 0.5776472E-01 27,99719 164.0981 0,7655954E-01 29.16750 235.2197 0,8097917E-01 28.68300 235.5696 0.8484572E-01 28.91180 248.3074 0.7931954E-01 29,34691 330.2502 0.1185049 25.21758 0.1060000 10499.000 37.99081 1.000000 1.000000 103.2605 31.41551 2~.27727 0.9399998 10449.000 25.14819 1.000000 1.000000 67.50731 18.67809 28.19655 0.0000000 10399.000 22.72696 5.000000 5.000000 93.06491 28.98805 28.22101 -0.6599998 10 349.000 28.62300 I . 000000 I . 000000 131.8512 33.43570 28.13493 0.1080000 10299.000 29.38120 1.000000 1.000000 123.1789 33.87392 28.22833 0.7900000 10 249.000 41.49829 1.000000 1.000000 119.3482 32.20518 28.29533 0.4999999 E-01 E-01 E-01 E-02 1G.UfOU! 833.6311 0.4140000 16.34119 832.5999 0.4140000 28.05067 833.t025 0.4140000 17.34322 840.2004 0.4140000 14.09262 842.7656 0.4140000 15.46024 840.341 3 0.4140000 25.15260 -18.83192 277.0142 20.34119 -25.88231 230.1178 32.05067 -28.54588 Z51.9254 21.34322 -23.84125 290.7922 18.09262 -21.81787 300.9280 19.46024 -18.15665 402.7371 29.15260 29.46170 291.7109 0.1076940 29.48030 244.5527 0.7637650~-01 29.25011 278.0837 0.1042421 29.18330 284.8594 0.1173761 29.64391 305.4385 0.1109026 29.47351 394.8582 0.8156139E-01 TOTAL DATA RECORDS STARTING TAPE DEPTH **** FILE TRAILER **** : 114 = 10999.00 ENDING TAPE DEPTH = 10207.00 FILE ~ 3 PASS 3.003 **** FILE HEADER **** 1024 * FORMAT ONE DEPT ECORD (TYPE# 64) H ~ER FRAME TAPE DEPTH UNIT : ~T 16 CUR,VES : NAME 1 GR 2 TTEN 3 TEN 4 SPD 5 CCL1 CODE SAMPLE# UNIT 68 1 API 68 I LB 68 I LB 68 1 F/MM 68 I VOLT BYT:S 4 4 4 4 4 8 $SN O CSSN 10 LSN 11 CLSN 12 CN 13 CNC 14 CNRA I 5 TEMP 16 DTEM 68 I CTS 4 68 1 CTS 4 68 I CTS 4 68 1 PCT 4 68 I PCT 4 68 I C/C 4 68 I DEGF 4 68 1 DEGF 4 * DATA RECORD DEPTH CCL1 LSN TEMP 10999.000 65531.00 65435.45 10.46895 10949.000 231.0000 42.98671 28.18523 10899.000 3.000000 49.03171 28.16338 10849.000 3.000000 27.02811 28.14372 10799.000 5.000000 46.3600Q 25.20770 10749.000 3.000000 74.11641 28.24608 10699.000 3.000000 84.39781 28.14658 10649.000 1.000000 85.00252 28.13222 10599.000 1.000000 144.0067 28.13698 (TYPE# 0) GR CCL CLSN OTEM 150759.1 65531.00 16358.86 8.848000 20.64958 231.0000 21.63605 0.9999999E-03 28.08159 3.000000 12.19687 -0.1600000E-01 88.88156 3.000000 10.82967 0.3800000E-01 39.42207 5.000000 10.97633 -0. 4600000E-01 23.09270 3.000000 18.54459 -0.2200000E-01 -0 30.41333 3.000000 20.30135 .3600000E-01 31.64523 I. 000000 19.11714 -0.4999999E-02 22.48250 1.000000 42.82024 0.1100000 958 BYTES * TTEN CCL2 CN 463.5542 0.4140O00 15.00000 865.4880 0.4140000 21.44156 876.9058 0.4140000 28.85876 877.0583 0.4140000 31.85284 90t.5227 0.4140000 32.04160 905.5513 0.41~0000 26.89307 888.5029 0.4140000 24.46033 896.0439 0.4140000 28.22209 880.4788 0.4140000 12.50260 TEN SSN CNC 73.19270 65184.48 19.00000 191.4458 154.8396 25.44156 41.81766 180.7062 32.85876 -3.754855 117.8959 35.85284 -6.080479 159.9928 36.04160 -17.81718 235.7488 30.89307 -33.79218 244.6165 28.46033 -~3.75525 258.9001 32.22209 -25.48611 325.7224 16.50261 SPD CSSN CNRA 1 9. 99799 65184.48 0.2509626 28.05809 236.7288 0. 9139591E-01 27.87061 162.7911 0.7492346E-01 27.87061 153.9430 0.7034862E-01 27.74980 157.1584 0.6984246E-01 27.90719 237.0960 0.7821548E-01 28.47359 241.2052 0.8416629E-01 28.19061 252.5617 0.7569295E-01 28.48170 343.0200 0. 124.$330 5.UUUUUU 6.U 164.2346 35. 28.18483 -0.21 10499.000 27. 3.000000 3.0 102.3638 35. 28. I 4035 0.31 10449.000 37. 1.000000 1.0 70.34792 19. 28.20950 0.69 10399.000 30. 3.000000 3.0 9S.04761 20. 28.08330 -0.38 10349.000 27. 5.000000 5.0 133.2562 32. 28.11382 -0.14 10299.000 32. 1.000000 1.0 128.!605 32. 2~.18637 0.00 10 249.000 54. 3.000000 3.0 158.3174 31. 28.36638 0.97 UUUUU 73233 O0000E-01 86224 00000 94606 O0000E-01 36450 00000 56732 99999E-01 95563 00000 02441 O0000E-01 59361 00000 99490 5000O 78140 00000 90372 00000 15790 00000 09195 99999E-01 U. ~1 ~uuuu 14.61501 849.5813 0.4140000 14.05960 829.0059 0.4140000 27.52837 829.3281 0.4140000 22.96381 831.5107 0.4140000 I 4.61 375 824.9702 0.4140000 15.68083 806.3003 0.4140000 28.09914 18.61501 -34.31250 260.9651 18.05960 -40.87244 230.8602 31.52837 -38.29640 269.4246 26.96381 -32.02290 298.0286 18.61375 -30.96786 304.1667 19.68083 -40.26976 387.5107 32.09914 0.1147866 28.37679 305.8806 0.1175166 28.65320 254.3508 0.7693046E-01 28.80040 228.7441 0.8754069E-01 28.95331 287.$655 0.1146192 28.42329 298.1270 0.1103681 28.96730 405.2312 0.7672644E-01 TOTAL DATA RECORDS STARTING TAPE DEPTH **** ;ILE TRAILER **** : 111 = 10999.00 ENDING TAPE DEPTH = 10223.00 **** TAPE TRAILER **** LIS 89/10/03 3746 01 TOTAL RECORDS I:N THIS LOGICAL TAPE : 347 **** REEL LIS 89/10/03 ATLAS 0'1 TRAILER **** End of e×ecUtion: Thu 6 APR 89 1:29p ~l~psed e~cution time = I minute , 24.0 seconds. SYSTEM ~ETURN CODE = 0 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska, Inc. ECC 2425 Well D.S. 7-26 Field Prudhoe Bay Date 4/30/86 Count)', State North Slo~k~,~-~,~ ,C~s~'~ ~ ~ Curve Name ~las~~ 0~.~ & 6ao. ,- ___ (Abbrev.) S~ard.:~C~rZ~me Logs Used Scale I ' ' Files 1-3 - CCL [ Casing Collar Locator CN - Multispace -~- CN I Compensated Neutron " 60 - 0 SSN I Short Space " 50 - 550 LSN i Long Space " I 0- 200 ~ , _o GR Gamma Ray File 4 CNAV I Average CN , i. 0 - 100, 100 - 200 " I 60 - 0 =CC NUMbeR 2C25.00 ^orn ^, ^S~^ -~,r D.S. 7-26 PRUDHO~ 3~¥.N.S'~ ~.~~ ~K. AVERAGE ~^SS~. , ~; SS~, co rr, - L I SSNI CN2 G~2 LSN')~. SSN2 ""'3~,. GR'z~ LSN$ $SN$ C~'''''~,, , GRO~ =~OM 10200:00 TO 11020--00 12 ....,~ PAG= I AVERAGE PASS O£PTH GAMMA RAY PASS PASS PASS FT, I 2 3 LONG SpAC[ SHORT SPACE ~ASS PASS PASS PASS PASS sAS.S I 2 3 I 2 3 COMPENS~T':D NEUTRON --"ASS PASS PASS AVERAG I 2 3 OI 10200. O. 10201. C. 10203, O, O, I UF... ~./"~. 0. 0. 10205. O. O. ~~ 0 0 I ~ i i I 10207, O, O, I02~ 0 0 1n~o O. O. 10210, O, O, 10211. O, O, 10212, O, O, 10213, O, 10214, O, O, 10215, O, O. 1021 6, 0, C, 10217. O. O. -10218, O, I0219. O. O, 10220, O. 10221 - O. O. 'I'~ O, O. O. O. O. O. O. O. O. O. O, O. O, O. O. O. O. C. O. O. O. O. O. O. O. O. O, O. O. O. O, O, O, O, O, O, O, O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O. O, O, O, O, O, .0, O, O, O, O, O. O. O. O, C. O. O. C. O. O. O. 10224, O. ~ ,,,.,~ ,,,.. ~.... -~, ii 10227. 78. 10229: 10230, 10232. 10233, 70, t iJ&j~i I ~ I i 10'36 195 10~'* 213 ~1 i 10'39 16' ~ I ' ~ m 1'3240. 1!~.. 10242, 11!, In2~-~-.- 79 ~' i I ln2F.~ 7~ u246, 67, ! 02~7. 7!. 93. O. 0'~ O· 93. O. 7 t~ I 67. 82. 51. !0~ ~ i 101, 183, t63, I°9 1 92, 200, I ~4, 169, 150. 128. 112, 107, 69. ~O 67, 63, 61, 67. Oi O. 265. 221. O. 486. 434. O. 265. 221. O. 486. 434. O. 265 ~ n z, ~/,,,/.~/. 265; 22!~ O~ 486= ~=~ 246. O. 486. 451. O. 28!. 275. 2~. 493. 471. ~72. 255 2~m 22a ~'53, ~'1~ ~'51 ~ ~= I ~ 408 4~2 4'~ ~on 191, 18~. 409. 400, ~o ~ ~o~ 405 409 413 ~ ~ ~m~ 205 41 3 200. 225. 217. ~29. /~/~9. ~35. 226. ~on 277· =~.~' ~' ~478. 481 284. 312. 306. 469. 482. 511. m~ mo5 ~m~ /,6~ /.Tn ~ ~7~ ~0/, I.~7 /,Q~ 1.07 2=6 267 258 456 '-'' 483 ~ i i 22~. 2~. ~ &$1 ~'~ ~'~ 245. 27~, 275. 4~$. 470. 476. 272. 2~9. 2~2. 6~2. 0.3 0.0 0,0 0.'3 0.0 0.0 0.0 0.0 0.0 O.O 0,0 0.0 0.0 0.0 0.0 0.0 0,0 0.0 0,0 C.O "' '" 0.0 n 0 0.0 0,0 0.0 O.O 0.0 0.0 0.0 0.0 0.0 0,0 0,0 0..0 0,0 0.0 0.0 0.0 0.0 O.O 0,0 '0.0 0,0 0.0 0.0 0.0 O,O 0.0 0.0 0,0 0.0 0.0 0.0 0.0 0.0 0,3 0,0 O,O 0,0 0.0 0.0 0,.0 0,0 0,0 0.0 0.0 ~0- -0.0 0.,.0 O.O O0 n n nm 0n w -- ,... i ,.~ ~., i ,.. ,~ ~,,- ~0 0.0 O.O O.O ~,-0- -0.0 O.O O.O 0.0 0.0 0,0 0.0 0.0 0.0 0.3 0.0 0,0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.6 15.2 0.0 4.5 3.6 15.2 O.O 4.5 3.6 !5.~ 0.0 4. 3.6 !5.2 0,0 4.5 3=6 !5=2 0=0 ~..=5 3.6 15.2 O.O ~.5 3 6 13 5 14 4 1 2.6 !! .$ !4.4 13.8 2.9 12.1 !5.3 !4.5 7,0 14.& 18,0 17.7 9.: 16 7 18 5 18.° ..., · l 9.3 17.0 17.$ 15.3 9.2 I?.4 16.3 17.2 7.6 17.3 15.~ 16.4 = '~ '~c ~. 12./. 13.3 1.3 11.3 11 0.9 10.0 1! .2 !! .! I i ~.,, 2.4 !2.! !! .7 1!.9 3.0 12.4 13.4 13.2 4.2 !2.5 !4.9 1/'=. ?. 3.3 12.1 13.0 13.0 ! ;9 !2;0 !! 12: O: I ~4GE 2 D.S. 7-26 AVERAGE PASS , ,, ~,,,,~ n , nA$S PASS PASS PASS FT. I 2 3 I 2 3 PASS PASS PASS P~SS~ P'*S~o I 2 3 I 2 PASS ~,VERAG 3 !024~ 6! 10~ ~n 10250. 58 10251 = 5.7 10252. 52 10253 50 10254~ 5! 1025r' 55 10256, 61 !0_257: 6:~ 10260. 57 !026! 56 !~262. 72 10263, 87 10265. 7~ !~256. 79 I 0267. 85 10269. T5 !~270. 63 102T2. 78 1~273. 71 I~274. 5~ 1~275. 53 10276. ~ 10277 ~5 I 0278. 79 1~279. 75 10280. 9~ I~28!. 121 !~2B4. !52 t028~ $~ !02~7. 26 t028~. ~ !0~8~= ~ 10290. ~ !029! ~ ~ !0292. ~ 102~$ $ !0~5. 2 58, 294. 323, /'~; 308 322· .-~ ,~, . . 59. 299. 30!. 56: 286; 294; 5!. 296, 308. 55~ 347, 353, 46. 338, 3!/¢. 59; 293. 267, 69: ~74= 263; 62 260. 23 9. 67. 235. 2!9. 77. 2!9. 2!9. 80. 207. 2~. 309. 48~. 5!q. 501. 11.2 !!.4 315. ~=~,-,." 5n~-,. 505. 11.5 10.6 ~oo ~,0n /.o~ /.~. ~ 5 ~n 1 k i ~ ! - ~ I ~ / N i ~ / I i i i ! i ~ i ~RO 30~- ~'e2 .... ~. ~97, 11 /' 11.5 32~. 504. 5!5. 51t. 10.2 1!.3 34!. 5!7. 539. 529. 9.2 9.8 ~n 275. 478. ~69. ~77. 1!.! 11.1 257~ 457, 470, 468. !!;5 !2,6 262. 470. 479. 478. !2.5 !3.0 233. 22!. ~23. ~53. 4~. !5.! !5.9 ~15, 415,~,,~-~ 4~2, 15,7 16,5 ~-~ ..... 2n> ~85- '201~ /,nn L~'~ : z.,~n 5,4 !7,2 ~_. ., _. .~_. ., ._: ,,_. 1 ~'~.,.o~ ,~on ~o~ /.n~, ,.~ :/_z_n--17 '~ '~; 7 101· 131. 146. 140. 341. 400. 368. 23.6 23.9 ~r2~' ~-1-~6~2-; ~' ~$2:1;i'~00':: 399 · 21.3 25.2 . 56. . . 56. . 66. · ~.¢ ',',1,' . . 61. . . 121 . !54. ~/.~ m . !88. O. 29. 8, 3!: 2. 27, ~. 30~ 5. 3 4. t. 31, /, 3:..:7;36 3:~,: :-3.62 · 2 2.6 24.0 70. 151. 185, 174. 390. 404.':'403. 23.4 25.4 70, 188, 224. 222. 430. 444. 463. 19.7 18.2 70. t93. 2!4. 20!. 6!9. 6!2. 445. !7.9 !5.4 97, 167. 173. 143. 350. 390. 36B. !7.0 !4.7 ~I: · I~~'=. "~=,~.. I~/'~=, ~07. . ~15. ..,.~'"" I~.~ I~.~ '' I~I 127 154 3"6. 3~° 383 19 3 19.2 89. 124. 100. !!7. 328. 30!. 324. 24.! 26.! t33. 103. 10~. t00. 291. 305. 307. 26.3 231. !21. 145, 11!. 317. 356, 340. 23.8 27.0 ~ , , , 377, 2~ 7 21.~ ,~u, 149, 167, 146 375 390 ,, !2~. !58. !68. 169. 381. 393. 39!. 21.3 20.2 45. 168. 169. !53. 380. 387. 389. !9.3 20.3 3~: ! 68: ! 62 = ! 55 ~ 378: '378 ~ 388, ! 9; ! ! 9: 7 30, !6!_ !5!. !57. 378. 37!, 376. 20,5 20,3 31. 144. !5!. !49. 370, 372, 368. 23.2 2!,9 34, !52. !60, !5~, 372. 361, 330. 21.7 2!;7 34. !50_ !q6~ !~0 370. 370= 374, 22;! 34. !5!. !69. !64. 366. 374. 373. 2!.5 20.8 30. 164. 169. t67. 372. 331- 3~X. !9.4 !B~5 30. !6B. 170. !6x. 378. 3~3. 390. !9.! !9.2 29. 161~ !6!~ 16!~ ~80~ 3F5, 3~1~ 20~& 19.~ !! .3 11 .2 10,5 10.8 10.8 !1.3 . !! ;6 1! .7 11.4 11,0 !0.~ 10.! !0.1 9.9 !0.1 10.8 11.0 11 .B !2.4 13.0 !3.& 13.3 13.4 14.0 ~/, n lC 5 !5.3 15.2 !6,5 !6~5 15.9 18.2 17,5 1.9,1 !7.9 20.4 i v i i 21 .5 23.2 23.3 23.2 2~.1 23.2 23.4 23.1 2! .$ 22.~ 22.9 19./~ 24.! 16.9 !9.~ 20.2 !6.9 2! .9 !8 =5 23.3 24.1 23.1 26.4 2! ,2 26.5 22.2 22.2 25.6 !9.~ 29.3 20.7 29,0 21 .5 23.3 21 .2 20,0 2! ~$ 2! ~0 20,6 2! ,7 2! ,! 2_2:7 !9:8 2! .2 20.4 20.,.4 20,5 !9.5 21.4 19.~ 21 .2 DATE: 7/11/°'~ TiME - ~RCO AL ~SK~ ',-~,,r' ,',u~ ~ 0'- D "", N, SLOPE, ~r, 3.$. 7-26 AVERAGE PASS DEPTH ~^"'~ RAY PASS P~S3 PASS FT. I 2 3 LONG SPACE S"ORT,, SPACE PASS PASS PASS PASS PASS PASS I 2 3 I 2 3 COMPENSATED N~'UTRON P~S3 PASS PASS AVERAG 1 2 3 ,n~ 2~ 25. 33. 157· 15~'~. 15~'. 3-'8.,, - ~,~".. 372. 20.5 20.3 10297, 27, 28, 34, 152, I~'~, 15~., '~, ~70, 368· 10298. 26. ~-=n 32. I=0~ . I~'7, . 156. 36~'.. =*~,,~. 376. 21.~ 21.7 10299. 23. 28. 29. 1~2. 15~. 155. 37!. 367. 376. 21.7 22.7 I'~ 27 ~ ~ 363. 369. ~o~ .... I~7 156- ~* 22-r ~I'~ JJ I I ~ f l In~01~ . 27. 34. 33. 155· 164. 163. . ~70.~ .:**~, ,. =72~ · ~. 10302. 27. 29. 32. 156. 166. 169. 376. 383. 379. 21.5 !9.7 ~n~n~ 2~ 25. 28. ~o Ir5. 16g 372. 381. 3~6. 20 3 19. 1m=04~ . 26. 27. ~.~ 15~- 148. 153. 3~. 373· 3=°, ,. ~.~n 7 22·0 10305. 27. ~8. 30. !49. 15~. 15T. 362. 3T~. 37~. 21.7 22.7 I n~06.~ 25. 30. 33.- 162. 178. 166. 372 · 3o~.~, ~,o~, ,. 19 .~° 21.6 ~"'~' 25 '~ '~' 192. 192. 186. ~ 398· ~03. 16.3 17.3 I~09 2: 27 ~ I~n ~ 186. ~nL ~01 3~4 16.7 16.7 10310. 22. 23. 24. 173. 175. ~*",,~. o~,. ~,~.'"' ~.,.'~' 19.2 18.2 10312. 18315. I-~16. i N~,..,~ t ! i I gJ I ~t I~19 10320, 10321, 10322, I~3, I 03 2~. 10325. 10327, 2~I 10329, I~ 31 10333. 28, 10334. 25. 10335. 22. 10336, 23, 10337. 10338. 31. 10339. 3t. , ~ ~ , i ~.! !0343~ 40~ 25. 29. 25. 154. 159. 157. 365. 376. 375. 27. 30. 26· 155. 174- 165. 370. 385· 382. ~. ~ 2° ~ ~?~ 177 ~ ~ 3~ ~..'"r i t..~,~, I / i i ~i 1 ~ ~I ~ I i ~ i i ~ i i ~ ~'~ ~ ~ 16~ 174 373. ~7~. 3 26- 22~ 24. !57. !57~ !64. 35~. 362~ 366 ~= ~ ~ 15~' 153 157 3~° 3~5. 361 ' '~ ~ 346. 2>. 30. 139. 1;6. 158. 3~,. ~. 31. 31. 134. 146. 1~3. 338. 341. 369. ~ ~ 133 I 3¢ I ~0. ~ ~ 3~ 3~I ~ z I Jy I I I ~ ~ J I i ~S. 2~. ~=~ 13~ 13~ 3=~ 355 =47 ~ I J t I i 27. ZS. 13=~. 1TMon. 136. =~. ~ 350. 355. Zg. ~.== 13=~. 139. 135. ~'~. 356. 3~8. ~.~ 3~. ~"~,~. I~8. I"2.. 34~... ~'~. 355. 2~. 3Z. !50. !56. 151. 351. 359. 3~!. 27 28. 152 153 15~' 35~' 355 ! i i ~ i ~ I i ~ v ~ i 28 31 153 153 I=I 3~1 357 357 . I i I i ~ I j i i i 28. 31. 15Z. 157. 150. 354. 355. 36!. 30. 3~ I~'< !~'I. ~,7. ~.o ~51 I ! 35. 33. 130. 122 13~. 332. 329. 3~. ~ 3~ !19 !21. 121 ~ 319, 33~ J~ I I I I ~N J I I 37. 42. 114. 120. 113. 322. 330. 324. -~'3.- 58. 116. 1~7.~ 117. 319. 356. ~, · 50~ 5~. !2~. !43~ !25, 324. 363~ 3~0. 19.1 19·0 19.1 19./+ 20.8 19.6 21.1 20.6 19.7 !8.5 20.! 17.9 !9.5 !9=2 20.1 19.8 22.8 21 .! 2'~ 7 ~O 6 23·3 23.3 23.5 ~ ;~ · 2 23·5 23·7 21 .I 23·2 20.4 2! .0 20.2 !9.8 19·3 20,0 20.2 20.2 2!.4 !9.5 23.0 22.3 25.0 2~.$ 26.! 2,': .! 25.2 25.3 22=8 26=0 20,-4 21,7 20,8 21 .4 21,4 21,2 21 .1 20.5 21,3 19,6 21.5 !9.3 20.6 20.5 I'= 6 -~n 6 z m 19.0 19.7 !9.8 !8.3 21 2 1~ 3 21 .I 18,2 19.7 17.$ ..- . / IS.O 18,3 !7.3 18.? 19,2 21 .I 17-5 21 .0 !~,.3 !9.6 21 .I 19.1 21 .1 19.5 19.4 !9.7 18.3 2! .1 !9.7 2! .0 19.9 !9.& 21.3 15.? 20.9 !8.8 !9.8 !9.8 I~.0 20.5 !8;5 2! :~ 19,6 22,! ~,~ o 23 5 I 7 I ~ · 21 .~ 23.8 21.7 23.5 24.1 23.1 23.7 21.5 23.5 ~0.?, 22.~ 20.3 21.0 20.5 20.3 20.8 20.9 21 ,2 2! .2 ZZ .3 "I P- '~"4 23,4 26.0 26.! 26.3 26.4 25.5 25.7 23.7 23=8 2~ =4 ,~.RCO ALASK~ !NC. PRUI];"i, OE °"¥,"' S' II, V 0:1 PAGE 4 O.S. 7-26 AVERAGE PASS DEPTH G~MM~ RAY PA~'S., ~',-, S , ASS ' WT. I 2 3 PASS'PASS I 2 3 1 2 !03~6. 5B. !0349. 2~. 10350. 31. 10351 3O. 10352. 29. !0353. 30, 103~/,. 2~. 103~. 28. !0355. 30. 10357. 26. 1 0359 . 22. 10363. 10364. 3~. 10355. 10366. 31. 10357.. 24 10368. 24. 1057~. 10~7t. ~0. 10~72. ~1. 10575= ! ~ ~ i ! ~ 10~7~. 22. 10~78. 18. ~=~ 20 10381. 2t . 10382. 22. I0385. 23. 10386. 22. 10387. 27. 105~9. 105~. ~ m 38. 40. !40. !40. !62. 34~. 35/4. 358. 21.9 23.0 32..._'~?. 134. 134. I'-I.? ~'=.~.. 346. 353. 23.2 22.9 49. 44. !28. 137. 142. 3~3. 353. 3~5. 24.5 23.~ 52 45. !40. !63 !54. 36/:. 369. 371. 23.6 37. 37 162. 164. 167. 367. 369. 377. 19.3 19.3 3! 33. 159. 161. 169. 362. 376. 378. 19.5 19.1 28. 32. 159. 1~9. 163. 365. 365. 377. 20.0 20. 25. 31- 152. 152. 163. 360. 352. 369. 20.7 19.8 27. 3!. !4~. 149. !~!. 347. 35!. 356. 2!.2 20.0 27~ 28 150. 153, 155. 350. 357. 353. 20.3 20.6 2~. 28. !~9. !53. !58. 353. 353. 362. 20.9 20.2 25. 29. !51. 15~. 151. 348. 356. 362. !9.~ 20.0. 27. 27. 150. 163. 153. 34~. 36/~. 350. 20.0 20.0 25. 25. 15~. 15~. 157. 357. 367. 364. 20.0 18.9 2~. ~.~.- 170. 162., !5=.~ ~. ~2. 37~. ~"~,~. 17.4 I~.9 21 ................ :,;~ ........ o~ ~~c/ ~c~ ~ ~ ~c:;:::.~,'--20 5 ~n 7 ~ 3 ~3/::2~:~--3 ~ .-- 23.1 25.0 36 ~7. 122. 126. 130. 327. 346. 344. 24.7 25.6 29. :---:-3:3~:~ :'- ::339::, ;:-3:53.25.6 25. 37. /:3. 120. 130- 120. 326. 336. 341, 25.0 2~./4 5!. /:9. 128. 146. 129. 330. 361. 342, 23.3 23.5 32. 3~. 170. 172- 158. 380. 383. 367. !B.8 20.5 3!= 27= !~7; !79= !~7= 3~7; 38~; 38!~ 20~0 ~$..~. ~,, ,. I~3., 175. 382. ~,~,=~. 386. I~,9 I 25 25 173 I°~ I'~ 38~ .... u~. ~. ~. 394. ,382. I$.4 18.C 23. 24. 18~. !79. !78. 38!. 392. 39!. !6.4 !~.2 21 21. !$0. 173. 187. 357. 393. 4~. 17.7 !8.2 21. 22. !62. 154. 180. 3~3. 353- 394. 2~.6 19.4 ~ ~ ~:'~ ~' ~ 1~8 362. 3'~ 380 21.~ 22.3 ~ I &~ I I JN I I ~ I ~ I - I ~ I I 2~. 2~. 1~6. 147. I~. ~1. ~9. $70. 22.2 ~$.~ ..... '~ ~ . , 3~9. 22.2 22, 24. ~. ~4/' !)U. I)O. 358 35.~ 29. 24. !44. !39. !~4. 354. 3~. 372. 21.9 20.9 ~ 25. 14* 128 */'m 3~. 334 3*/' 22.0 ~3.2 28. 24. !34. 120. t40. 338. 321. 351· 22.7 23.8 25. 22. !1~. !17. !!9. 323. 325. 337. 25.2 27. 28. 111· 114. 111. 323. 331. 33~. 27.3 25.9 25 25. !08. !!8. !!0. 322. 333. 33!. 2~.! 27.! 22. ~ 1!2 122. 11~ 3~9~ 3~3 3TM ~ ~ 2~ 32. 29. !19. !24. !2!. 325. 3/~2. 3~9. 25.4 26.2 47. 38. 117. 135. 120. 315. 349. 343. 25.1 25.3 i.. 22 3 ~2 6 21 .6 22 i 20.7 !9.4 18.7 19.2 10 ~ I° i / i ~ / I !9.5 !9.7 19.$ 20.7 2~.3 19.7 !9.2 20.2 2~.6 2! .J ~ ~ 2g. 20.! 20.1 19.5 !8.9 ~ 19,8 21 a2 ~7 23.2 2~.7 2~ .2 23.6 2~.8 23.9 2&./~ 25.9 25.7 26.7 26. 26.9 26.7 26 ./: 26.0 ~/. ~ 22.5 22.7 20.! 20.0 !9.7 !~.~,, I~ I I= n / i / 18,4 !7.5 17.2 2~.3 20.4 21 .5 21 21 . 8 m! . 9 21 .9 22.~ 2! .5 21 21 .5 2! .9 26.0 25 28.3 27.9 ~ ~ 28 27,0 27.2 26.T ~5.3 26.9 26.3 Z5=o 25,8 PAGE 5 D.S. 7-26 AVERAGE PASS DF_PTH GA,-:,-,& "~ *v, LONG PASS PASS PASS PASS FT. 1 2 3 1 SPACE SP'"'RT, v ¢"'PAC¢~ COM"ENSAT~'3~ ,- PASS PASS PASS PASS PASS PASS PASS 2 3 1 2 3 1 2 N~-"TRON PASS AV-RAG 3 ~,~ · 2° I03~3. 32. 25. 1~94 33. '~6. 10395. ~3. 42. 1~96.~ ,~,.=~ 51. 1039~ =o ~.~ ln=~8. 4m I~. 25. 25. 10~0! . $~. 29. m~/,~ ~=u2. 2~ 10&05. 1~. 22. 10404. 22.- 22. I~C06. 25. 1 040~,. 3~ . ~ ~/' ~ ~ /'2 ~/ ~ ~/. I~412 ~ ~ ~.~ I~15. 48. 42. 10414. $4. $~. 104t~ · 27, 2~, ,u . 2~. 20. 13~17. 2~. 22. "~.*~ 24 "~-"m 20. 21. 1~2~. ~ 10~ ~! . 6g. 59. I~22. ~ 1~23. 5C. 69. 1~424. 31. 36. · ~2~. 2C. 26. 1~427. 23. 21. I~2-~. 23. I~. 10450 2~. i ~i 10~$t . 25. 2t . t0~$$. ~. 45. 10~$~ ~. ~9. 1~$8. 2~. 24. !0~$9. 2! . 27. 31 11B I~4 133 32~ 340 352 25. 12t· 122. I'5. 31'~ "'"' "''"' '~' " 25 3 28. 120. 122. I~,~, ~'~2~ . 336. 337· 38. I0~. !24. !22. 319. 32~. 336. 27.8 25.4 · ,I~ 121 123 309 32° 32g 26 I 23 7 5!. 115. 124. 129. 312· 337· 325. 24,0 2~.~ 3°~. 118. 116· I'~'~. 321. '~'~':'-~.,. 33', . 25.,., 25. 10~. 1!3. 116. 315. ~. ~2~. 27.4 27.2 32. t05. 109. !19. 310. 315. 325. 27.8 26.2 3~ I¢6 108 112 311 ~ 32* 2T 5 26 25. 106. 10°~. 109. 33', . '12~ . 322. ~'~,.~ 27.1 22 101 106 ~n. 303 308 31' 28 4 27 0 ~ 9~ I06. I~/-~.. ~9'~. 302. 310. 2~.5 27.3 ~0. 102. I~ ~= ~n= 301 '~ 26.g 26.7 51. 115. 118· 120· 317. 322· 334· ~1~0~ ~?~ q ~q:¢8 ~;=<:: ~1;~$ ~ :::3: 2~0:' :::3-28 · 22. 110. 105. 1t2. 310· 324. 324. 19. 106, 108· 1t0. 311· 324. 326. I~ !06. I~6. ~ ~n? 3~? 326. .2'~ 11!· 125. 113· 3n~ ~ I ~6. !!6. !30. !!5. 31t. 331. 318. =~ 136. ~ ~ ~ ~31 356 328 70. 157. I~'~ 141 367 370 33~ 50 156 141 ~/' ~/' 31, ~ 115, 16~ ~I 323, 379 ~/' 101 134, 138, 3'~ 307, 352, 22 99 106 111 ..... ~,6. 307. 313. m~,~. 100. 102. 1~-n6. ,,~a~,. 3n9.~ 304. 20. 93. 99. I0~. 293. 304. 301. ~ a~ 103 I~ ~$a 305 21 2 - 311 28. 106. 107. 107. 294. 316. 310. ~ ~ i ~ i ! ! f ~ ! % ~ i N/VI I ~ ~ V I ~. ~n~ ~ ~0~ mo~ 50. 10~-~. 108. 110. 305. ¢~°,.. 312. 47. !13. !02. 1!7. 306. 305. 320. ~n 102. In/' In~ 205. 3n/ ~n ~o ~ i m ~a In~ 112. In~ 29o 30 2~. !09. !0~. !03. 305. 3!!. 30~. 25.4 25.1 26.8 25.2 28.1 26.6 27.1 26.~ 26.1 27·8 27.4 29.3 26.9 28.3 25.3 25.1 24.5 23,! 21 .8 23.0 2! .! 20.0 23.5 22.8 ~o ~ 27.6 27.9 27.! 29.0 28.9 2S.6 25.~ 27.7 35.3 ~7 "'" ~ m ~ ,,_ ~ . ,.,, 25.5 25.9 24.6 24.7 26.2 25.5 25.4 23.9 ~1.8 23·9 26.1 25.2 ..~ · / 27.7 27.8 27.6 2,3.3 26.4 · m 25.8 25,2 2-' 3 ,.¢' I 2~..6 2~.8 25.8 2r. a ~ m / 27.1 ~~5.5 L ! I I 27.8 26.3 25 ;0 I 7 0.~/ I 7. r Z2.9 26.6 m? 6 27.2 26.7 26.7 25.5 25.2 26.5 28 ~ ~7 7 - · l.. l.. · 27.! 28.2 27.3 28.6 25 ~0 27~9 25.r,~ 24.5 2~ 6 ~.~ , ~ 2 25,7 23.9 ~ ~5.3 26.1 27.5 25.0 27.~ / 27.~ 27.2 27.1 26.5 25.5 25.3 25.0 26·1 26.7 27.1 25.7 27.2 2T.5 -- . 2~ I Ie,7 22.~ 27.3 28.7 27.8 27.3 26.2 25.5 26.3 27.8 27.~ 27.2 mAG~ 5 D.S. 7-26 AVERAGC P~SS SPACE SdORT SP~CE COMPENSATED PASS P"SS.. r~ASS="ASS p'~ ~"~ P"~S~ · 2 3 1 2 3 I 2 N~UTR~'~,, PASS AV-RAG 3 104~2. 10443: 10445. 10448. 10449 10450. 10q52. ~n~ , ~ · ~ i 1~/, 10~55 I0X~6 10457. 10~58. 10461 !0~63. 1046~. I0465- t0~67 13¢70. I0~71. 10~72. !0673- 1~/,~/. ~n~C !0~76. 10677. !0~79. ~ ~/.~/, 10486. t0~87: 23_ 21, 23. 102. 108. 103. 299. 3!0. 311. 27.5 25.9 2/,-~. 20, t5. 100, 107, I0~, 2-~-~,,, '~3.,~ , 307, 28.1 2!. 23. 20. 97. 103. 108. 29~ ..... 310. 29 0 26 26: 22~ 26: 93~ !02 108, 293, 303. 311. 30.3 27.8 2o 2~ 2~ ~2 Inn 10= 2a7 ~n3. 311 31 3 27 9 ~ 27 2~ a~ ~n~ 1~/, ~a~ 31~ 30~ 30 5 ~o 3 23. 26. 2!. 99. !04. !07 298. 3!5. 310. 28.~ 29.2 23. 26. 26. 95. 103 105. 302. 313, 309, 30.5 25.6 P~ 28 2B o~ ~n~ ln~ '~no ~ ~no ~I 0 23~ 26~ 29~ 95, 99. !00 302. 30~. 30~. 30.$ 29.2 25. ~4. 24- 95. !03- !04. 30!. 315- 305. 30.0 29.7 2~ 30 ~5 t05 10~ ~07 ~ 323 315. ~ ~ 27. 29. 24. 106. !!0. !!6. 315 327. 323. 28-0 27.9 2!. 29. 26 103. 107. !!q. ~!1. 329. 327. 28.4 28.0 2~ 27 2~. 111 112 ~!/'. ~ ~ 32~ 331 26 5 ~ m 3 28. 28. ~ .... 118. !2!. !!2. 3t5. 331 ~ 329. 24,~ =~ =~ I~. 11~. 115. =2R 3=8 :~ 25.7 2!. 31. , ;--S ~:'--3~ 2~9 28 26. 2!. ~'2';; i'12. ¥18; 115; ~28" 343. 336 27.3 26 27. 24. q 3:,-337. 27.9 27.1 33. 39. ~¢~v~;::1~20~ :c~722 ~w;::~ ~:3 ~:~:-~: :~-4~:'~:~ 353. 26 · 1 27.1 5~ ,.,. 361. 23.5 26.7 30, 75. 52, 112, 103. 117, 303. 324. ~$40:, 25,0 28.9 88. 75. 80. 110, 117. 107. 312. 3t6. 325. 26.4 30.1 !00 ~3. ~. 1!0, !21. !08. 325. 328. 320. 27.8 26.7 96. 90. !05. 1!7. !!9. 115· 336. 338. 330. 26.9 2~.9 63, 64= 87~ !23, !23: !20, 335, 3~2: 339, 25~0 26=5 40, 52, 62. 126. 122. 119. 3/43. 34~¢. 34~. 25.0 26'.7 2°., ~6.¢ 40. 118, 122. 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'1!7. 128. 322. 337. 340. 2c.0 27.3 49, 44~ 76; !20, !!9, !2!, 330, 334, 334. 25~5 26=9 3!, 27, 54, !!4. !!9. !21 329. 33!. 337. 27,0 26,! 2~. 2~. ~t. t12. 117. 121- 32&- 329. 338. 27.! 25,6 22~ 24: ~3~ !09: !~!5~ !16~ 3!5~ 329~ 340- 26~ 26,! 22. 25. 21. 108. !!2. !!9. 313. 331. 336. 27.0 26-7 33. 28 24. !06. !!2. 112, 3t3. 324. 322. 27.6 27~ 65. 52. 31. 106, 115. 11!. 3!6. 326. 329. 27.9 27.0 ~2. 7~- 57. 11~. 133, 113. 329. 350. 326. 25.8 25.5 65. 69, $~, 132. 138. 122. 3/~3, 361. 339. 23.6 24.~ 27.0 27.1 26.5 27.2 27.1 28.3 28.4 28.8 27.1 28.6 27.5 28.2 27.7 28.5 '~o O 2° ,... / · / . v 28.4 20.1 27.9 28.7 26.9 26.g 26.1 26.5 26.9 27.7 27.~ 27.5 27.z~ 26.7 27,2 26,8 27.9 27.1 26.9 27.1 26.4 26.5 26.0 27.4 27.3 27.5 27.4 27.3 26.9 26.7 26.2 25.9 27.2 26.7 28.8 Z8 .! 27.0 26.9 27.0 2~./~ 26.5 27:3 25 .I 25.5 25 · 5 ~6 26,6 26 .O 25.6 26.! 26.7 ~5.7 25.7 24.4 25.1 25.9 25.0 25.6 25, ~ 26. ~ 26.9 27.0 26,9 26.4 26.1 27,3 27.8 2,5.2 26.2 25.9 . 25.5 24.7 25=3 23=~ DATE: 7/11-/86 TIME: PRIJDHO~ BAY,N.SLOPE~AK. P~,GE 7 D.$. 7-'26 AVERAGE PASS LF I fl FT. GA ..... RAY L mASS PASS PASS PASS I 2 3 I ¢~ACEor - StIORT SnArEr RASS PASS PASS PASS PASS 2 3 1 2 3 PASS PASS I 2 ":UTRON PASS AVERAG 3 I0/.~ 10491. I0~92. 10493. 10/~94. J0496. I0~97. ~ '~ ~i 10503. 10504. !050~. 10508. I 05 0~ . 13510. 10511. 10512. I ~J I ~ i 1051~. 10515. ~05~7. 10519. !0q20. I~21~ · I ~ I t0525. 10527. I052~ 10551- 1053~. 10535. 41. 33. 58 . 137. I/'n=~. 1TM¢~ . 3:2¢ . 360. ~I . 23 · 2 ~. ~u. 44. 14~. 136· 143. 352 342. 365 20.9 54. 47. 44. 139. 134· ~/'~,~. 342. 327. 3czar. 22·1 67. 62. 45. 115. 111 139. 322. 315. 3~7. 25.9 82. 7°~. 57. 107. 103- ~,~,- 301. 315.- 3~. 26.0 ~5 ~9 73. 111. 11~- 112 305 3~5~ 313. ~.~ 81. ~3. 83. 116. 121. 115. 310· 326. 316. 2~.4 ~ 76 ~ ~ 1~ 115. 313. 323. 326· 23.0 ~ [ I I I ~ i I [ J t I ~/' 73. 73. 110· 120. 119. ~' 317. 3TMon. 26. 8/' T3. 7~ 10° I~3', !2~. 319 330. 327. ~* /' 61. ~..~Jl * ~, .. 118. I/'~,~. 121. 338. 370...~7. ~6.7 ~ ~5 ~4 ~ ~e, ~ 361 ~0~ =' ~ =~ $1. "' 1'9 I/''~ 146. 374 37~. 353. 22.c ~i- 33 . ~= ~. 36. 14:~. 136. 160. 358. 3~7. ~76. 22.1 ~I C3. 31. ~33. I~~o. ~,~. 3~0. 3~3.~ o~9. 23.2 ~* ~3. ~, .153. 17~. !/~3. 370. 383, 345. 21 . 5 ~¢: '' 387 2 18 3 2". 20. 2~5~ ::~-~:~:. 3 M .-- 1-5 1~. !S. 22 174. 167. 202. 37T. 374. 406. 17.8 ~ ~ ~ ~ :-: 405 1 9 32. 2. ; 368. 18.8 '~ 24. 19 176 198 168 366 398 380 16 7 ~ I I I m I I I i 23. 2~. 17. 192. 188. 179. 384. 398. 383. 15.7 ! N ~ I I / I I / ~ I I I I I / / I ; ~; I ~ ~ I ~ / I I I / I ~n 2/. 20. 128. 161. 15~ 3~3 367. '~==~. 24.6 31. 25. 2~. 1~6. 1GI. I,~c~. 361. 39t. 341. 22.1 24. 22. 30. !59. 183. !34. 377. 387. 358. 18.8 25. 22. 24. ~o~,~. ~o~,~. 164. 334. 3~0. 375· 16.5 25. 25. ~3. 183. 184. 182. 3°0~ . 394. 388- . 16. 2~ ~= 26 ~ ~o= ~, ~ I ~. ~. . ,,, . ,~. ,u~. ~j. 391. 39 · 17.° ~ 24 24. 170. 178. ~o/. 2~/. 302. ~oo 29. 27. ~S 179 I°~ 18~ ~o~ 3~- ,~ 17 5 25. 25. 25. 187. !78. 181. 3~6. 393. 396. !6.5 ~= ~ ~6 17~. 153. 18g. 379. ~*q ~ 18 I ~ J I [ ~ I [ i J I ! ! j i I I I ~ Il ~" 25. 151·- 153. 170. 3=n, . . 359. ~2°6 . ,n.~. 9 ~7 ~7 2~ 150 16° 15/' 3~n lol 310. 26. ~*, . 33. 17=~ . 18=~. 155 · ~=°= · 414. ~ ~ ~ . = [ Il 13.2 22 21 35 1~9 1°0 172 /.n~ ~11 ~92 17 3 i ~ i / i ~ i ~ I i ~ i i 2~ ~4 ~:~ ~ ~ ~n~ ,~ ,4~ '"~ 17 I 25. 25. 24. 193. 195. 205. 407. ~15. 412. 17.1 .o .. Z3 I 93. 207. 201 ' ' V O" ~ O' ~ ~'l ':. 41 4. I 7 .2 2X 23 23. *09. 21 ~ ~ oo /' ! ~ /' '6 /' ! ~ 23.2 24.1 22.2 23·2 ~-, o 22 2 -_r .~ I 22.~ .----.-.'~ /' 23.5 2! .8 22.~ 2~.6 26.2 24.1 25.3 29.1 2.5.9 25.5 25./~ 25.3 24.S 24 7 26 3 2: ' · i ~,' i ~ 24.2 ~5.~ .~ .~5.5 2~+.0 24.2 25.3 2415 25.0 25.6 23.4 24.7 24.3 22.2 22.1 22.1 22 6 ,n 3 20.° . ' 1,1 Nl~ I / 23.0 20.1 21 .I 21.0 2! .6 21 .5 18.4 20.1 20.1 - 57.7 17.7 1B.1 17.9 !6.4 !7.1 1'7 1 ,~= o 16 2 I I J I 'J ' - $5.2 18.2 16.4 17.! !8.9 !8.2 18.9 19.8 !8.~ 19.0 19.2 19.8 19.9 !7.5 !9.;~ 17.9 15.7 17.-$ 15.$ I'3.3 I~.~ 17.2 !7.9 !6.1 !8.$ 2~.8 17.1 20~2 24~3 !9:6 21 .C' 2Z,.5 23.9 19.5 20.2 24.5 !7~9 !7.7 20.$ '~7 2 !7 /' I~ 0 I I I I ""r 17.7 17.7 17.1 17.6 18.5 17.4 17.2 18.7 18.3 13.~ 17.9 I 17.2 17.9 17.8 18.5 19.9 17./~ 21 .5 21 .I 19.3 20.4 20.5 Zl .1 20.0 I~. · 5 2r',., . 7 18./~ 16.6 19.! ~ o 15.8 16.° I ! · · 1713 15.~ 16.2 17.4 17.1 !6.7 !6.~ !6.9 !7.1 DATE: 7/1!/86 TIME- 12: 0:1 ARCO ALASK^ !NC. D.$. 7-26 '~"DHCE ~AY, N.SL~_, . · ~ PASS ~ ~ ~ ~K AVERAG~ P~GE 8 DEPTH FT. GAMMA DAy , n,,r ~^r: ............. SHOAT SPACE ~ ~S PAaS PA~S PASS=ASS PASS~SS =ASS I 2 3 I 2 3 1 2 3 COMP=NSAT:D. ~ N~"TRON=~ PASS PASS P~SS &VCRAG 1 2 3 10536. 21. 23, !9. 2!!. 2!5. 206. 4!9. 426. 429. 15.4 15.7 ~.0~'~'?- -~, . 22. 25. 20. 203. 2~I. '~q~.,*, · 419. ~2~. ~37. I ~n~ ~ ~4 23 ~o~, ~92 21~' /'14 ~16 42~ 17 4 17 2 10530; 24 23~ 27~ 190, 190: 209. 405. 5!3. ~26. 17.5 17.9 lng/'0 ~ ~/' 2~ ~ I~8. !°0. ~'nl ~16. 420. ' ~ ~ , , - u ~ -~ N ~ i , ~v ! i - ~ i i / 1 i ~ ~ i ~ N I i ~ i N i I 10542. 27. 29. 23. t93. 205. 193. 42q. /429. ~!~. 18./~ !8.8 ~nc~ ...... ~2 26 ~ ~u . ~n~ ~aa x~c /.~o /.2o !0564. 24. 24. 24. 2!2. 2!2. 206. 4!9. 434. '~r~B. 15.4 16.5 !0545~ 3! 25 22. 2!!. 2!0 2!0. 4!9. 435. 534. 15.S 16.2 10c/'6 30 33. ,x >0° ~ ~18 /'*~ ~'~/' ~0 ~c o 16 6 105~7. 2~'~. ~'6. 26. 213. 216. '13.~ -~'23. -~."~ -~.~'~ 15.5- 16.~ ~¢/'~.~=~. 3n~. 25. 23. 22~,. 2~, . 2!5. ~/'2*-. -/'2~- ~/'~4. I/'-.6 ~,~.*, ~ n~.o ~ 22 *~ 21e ~ 2!* ~'24. ~'~ /.~o ~' I0550. 2~ 2& 2~a. ¢12. 221. 222, 4=~ ~-=~ ' · ; 433. 15..1 15.2 0552. ?~. 27. ~n~ -~ " ~" ~ ......... ~-~. ~ -~-,-, .-- 15.5 16.0 , . ~ ~ 3 - 2 t. ~ ~. ~;~,~,,> ~'- 4~ 8 ' - 1-5 ~5 - $ 6 · 3 .... ~. ~ 3 .... ;~;:~ ~ ~ .-- 1-5 ~ 1 4 · 2 10557' 27. 21. 23. 180. 177. 212. 380~~: 38:0. 430. 17.2 16.3 I 0558. 25. 2 ~. ~I~?~<~1 ~88~ ~85;;-: 396. I 8 · 3 I 7.7 10561- 19. 20. 24. 184. 203. 185. 388. 399. 388, 17.1 16.0 10562. 21. 19. 24. 201. 212. 189. 396. 403. 394. 15.3 15.2 ~'n~3 22 ~0 2~ ~ ~ ~nl. ~ao /.n~ I ~ ~ ~ I I ~ i i I I II! I III I ~ 1~564. 17. 19. 2~. 2!3. 2~. 2~9. ~!. ~11. 4!3. !4.2 I~.4 10565. !7, 20~ !6~ 210. 215~ 2!6~ 407. 424~ 404. !5~0 !5~4 ~n:x~,~. 20. 21. I~,. ,~15. ,'~28. 218. ~/'17. ~32. ~/'11. 14.9 15.3 ~n:~ 21. 19 20 227 ~ ~ '~ '~ '~ I~ ~ 14 3 ~055°, ~. ~-~.~ 20. lg. 219..~.~. .~3~'~. 10570. lS. 23. 20. 215. 233. 221. ~14. ~36. &37. 14.7 14.7 10571. 21. ~m~. ~- 2~4~ - ~-~'~- ~, =. 4~7~ ·¢~C.~ ¢35. 14.$ 1~.0 10572. 22. 23. 24. 235. 225. 223. 429. z~26. 445. 13.5 13.1 10c73 21 ~c ~/. ~ ~ ~8 i ~-I ~ i ~ ~ i !057~. 19. 22; 2!~ 2!~. 223, 230. 4!5. 430. ~'23. !4.9 !5,~ 10575. !9. !9. !9. 220. 229. 2!9. 10576. 2/~. 19. 19. 22!. 229. 22~. q27. ~38. ~29. !4.9 14.4 ln~7 21 20 23. 23n m~ m~ /-~ ~/.. 43~. !4 4 !~ 6 1057~ 20 1~ ~1 P2~ 2t7 ~ ~'3 i i ~ i ~ i -- ! i I ~i !0579. 1~. 22. 1~. 20~. 2!~. 23~. ~2!. ~25. ~7. !5.~ !4.7 I05~0. 18. 2Z. 2~. 207. 219. 230. ~2S. ~29. ~31. !~.7 15.$ 10581. 2!. 17. 22. 217. Z2~ 22~. ~27. {30. ~29. 15.2 15.2 10582. 24. ~. 24. Z~. 2~-~.- 220. 42 10583 22: ~! 25 230~ 232= 230~ L32: 43~ ~3~: !~:1 13:3 15.9 16.4 15.7 15.7 .1~. ") .I/., n 18.6 16.6 17,$ I° ' 17.7 17.& 17.8 17.8 18.1 18.0 16.6 17.7 15.4 16.2 16.1 15.4 15,9 16,1 15.5 15.8 14.6 15.2 15.2 1¢.7 15.5 15.5 14.6 !5.3 15.6 !~.9 15.9 15.6 15.~ 15.? 16.0 15.5 17~1 15.7 18.4 17.2 !3.1 18.4 16.9 18.1 10.7 17.1 15.~ 16.$ !5.4 !5,7 !4.0 !4.~ !4;3 !4~! I~.5 14.5 1~,1 lZ,,7 !4.2 1~.1 15.5 14.3 15.5 15.2 15.7 15.2 15.0 15.3 14.0 14.5 !5,0 !4,2 14.4 15.0 13.; 14.4 !4.2 !4.2 !4.2 !4.2 14.2 !4.3 15.0 14.8 15.0 15.6 13.9 15.1 !3;~ !~-~0 12: O: I ~GE 9 D.S. 7-26 AVERAGE PASS DEPTit GAMMA "~Y~ PASS P4S$ mASS r,. I 2 3 LONG. SPACE ~"~RTo,]~ SPACZ mASS PASS PASS PASS PASS PASS I £ 3 I 2 3 COMPE"~&T[D,,~ NEUTRON PASS P~SS PASS AVERAG I 2 3 I0585. 22. ~o~ 1° ~,~. 17. I0~89. 18. IOS~I. 19, "~ 22 I05~'- I~ IOS~S. I~ ~. 17. ~. 21 . ~00. 20. In~01 22 10&02. 22. ~04. 21. 10605. 2t . ~~ 19 I~07.~ 20. I a~ 2fl I0~tt. 2~. 10~!$. 18. ~' 17 ~=18.,~ 2= 4¢'~ 20 I~n 19 I~21 20 In4~ 20 ~= 20 ~27. 2~ I~&25 10651. 25. In ~n 232 228 239 431 437 44C 13 9 14 3 ~ . ~,. N.~ I · · . . . I · I i 20. 20. 230. ~19. 233-. 416. 4:7. 447. 13.3 14.6 23. 19. 218. 222. ~.~.~.~° 41~.. ~6. 445. I~.:, 15.1 ~/' 20 ~ 2~z ~20 /'~ /'~O ................. . .... ). I 5.6 i/, .7 17. 20, 215. 223, 2'1~ '~ '~ '~ 21. "m, ~. 219. ~.~=m ~"~,. 420. 438. 435. 14.& 14,9 19. 20. 2~I~ . 232-. 223. 4~7~ · 435. 430. 14.8 I~.5 20 19 217 ~26 225 ,~: ,~ 20, 20. ~I~ ~ ~. 2~2. 224. 422, 427. 22. 21. 21~. 219' 225. 425. &26. 434. 15.5 I~.7 21. 21. 214. 221. ~.~ 426. 430. &26. I~.6 15.0 22 21 21 2 ~ ~ ~ ' ~ ' ~ !9. t9. 210. I~8. 2~6~ · 41:~. 413. 20 21 2~ 413 ~3~ 15 7 16 9 · ~ 198. ~23 s.n~ i ~ i i i 23. 20. 1~. 20~. .~07..~,L~. .~-',~.~ .~,~', 16,9 16,8 21. 22. 21 6. 209· 228. 20. t8. 209. 21 6' 228. 16. 20. 20~. 209. 223. 18.- 20.- 198. ,.~,.,.~n~2!3. !9. t7. 195. 207, 200 20. ~ ~1. 200, 200. ~1. 16. 186, 178.~u~'. 21. 20. !74. 179. 201. 2~ ~ 4~ 40~ ~u. 21. 191. 1~u. 175. 19. 25 I~ 185 173 I 7Ui I I ~ ~. 187. I~2. 187. 19. 2~ ~. ,~,. 199. 191. 22. ~,, I~3. 201, ~,. ~.~ 22. 192. 19~ .... ~3. ~ I ~. I ~ 1 9~ 2n~ 20. 2t. 182. I~!. !95. ~ 22. 178. 131. ~5- · .~,. 181. 1~ 19 20. 25. 177. 175. 185. 21 26. 173. t7S. 17~. 426. 433. 437. 419. 430. 444. 1, I~ 1,~ /,'~ /'11 /'~ 430. 4!!. 420. 433. "~'~ 41~. 418, 3~ ,2. 398. 378. 3~5. 419. 393. 411. 408. 416. 414. / ~0 / ~L "~ ~11, 414, 401, 413. ,"20, ~'I~ 421 /'!~ ~ i i i ~ ~ i ~17, ¢17, 413, ~'~" ~11, 410, 399. 408. 397, ~94. 399 ~ 39~ 380. 383. 395. 16.7 16.2 15.9 15.~ 15.9 14.6 15.3 15.0 15.4 15.5 15.7 16.6 !6.2 15.5 16.7 !6.1 !7.2 !6~0 I~.4 16.1 17.2 16.6 I$.! !8.9 17.9 I$.~ 18.2 17.8 17.8 J g I J 17.7 18.2 15,2 17,5 !6.8 !6.7 I~ 8 16 6 17.1 16.7 !7.~ !7.5 17.C 17.3 15.3 ~o ~ 18.0 I 'J I I 18.1 17.9 !7.2 !8,3 18,3 `1/ ~ 15.0 t/..,..6 tS.7 1.4.4 15.7 15.3 14.9 1:6 t4.8 15.3 t5.1 15.2 t5.0 1~.~ 15.2 '1/. ~ '1/. E--ri./ I--I' ! ~ 14.5 14.$ 14.6 14.3 15.~ 15.0 16.5 15~7 17.5 16.3 !6.7 17.3 17.0 16.6 !6.3 17.1 I.~.6 17.0 17.2 17.1 17.3 17.2 !6.0 17.'3 I~ 3 16.~ 15.1 15.9 14.$ 15.3 15.1 15.0 15.5 15.2 17.4 15.~ i I . I i J . !6.0 16,8 16.6 16.~ 17.6 16.7 !8.7 !7.7 20.1 18.8 18.9 19.2 18.4 18.5 17.~ 18.1 "~ '~ 17.2 15.9 1~.1 17.0 16,g 16.2 17,0 16.8 16.5 17.7 17.6 !6.7,. 17.3 17,~ 17,1 i .../ ~ ,,~ i i... 18.5 15.5 18,6 18.3 PAGE 10 D.S. 7-26 AV£RAG~ PA ,_ SS n~- ...... z, ....... '~¥ :,,,,'~eS P~SS PASS PASS. FT. I 2 3 I PASS PASS PASS PASS PASS 2 3 I 2 3 COHPE~S~T:D m S' ~ASS PA S 1 2 NEUTRON P~SS AVERAG 3 10632. 10633. 22. 21- ~nx~ ~ 23 !0635: 20: 10637. 17. 20. ~n~8 P2, 21 10639. 2~- !0640, 24, 23, !054a. 26. !7. !g54:5 26. 33- ~nxz.~ 34 39 10647. 36. 41. I06¢$. 30, 41 . 10649. 25. 3!, 10650. 25, 30. 10551. 29. 29. 10652. 28, 29, -q 0653 32. 32 I0554. 35. 33. 25. t72. 169. 175. 351. 384. 392. 21 16~. 165, t76. 37~ 376. · . 21. 160· 160, 176. 370. 371. 383. 23. !4.~ !44~ !74, 356~ 354, 3~0. 19. IZ~!. 134. 165. 331. 335. 376. 17. t24. 126 155. 329. 331· 371. 18. 112. 122. 14~. 3!9. 33~. 353. ~1. t16. 122, 13~ ~n ~ ~/.~ 25. 117. 125, 123. 321. 329. 337. 25: !!4~ !27~ !22~ 324. 337. 338. 23. 122. !28. 122. 332. 336. 343. 25. 125. 122. 1!~. 336. 336. 342. 26 1~1 ~6 12c ~ ~o ~. 120. !~4, !~7. ~0. ~. ~4~. 116. 121, 127. 329. 333. 335~::': 3:55 · !8.6 !8.2 19.5 19.~ 19.9 19.5 ~I ~n :~n n 20.5 22.1 26.5 23.9 25.1 24.3 24.5 25.5 25.5 24.7 25.5 25.2 25 25.5 2~.-6- 2-6,4 23.9 26 2 2-4,2 26 0 2-5 .-4 25 ,, 2 26.0 25,6 25.1 26.0 I0656. 10557. .... 4. ~-~ 33. · :352 26-2 31. 29. :? ':: 3:3-7: 26.7 334. 334. 3:35. 25. 32-8. 328. 344. 26.7 115. 118. 120. 317. 325. 341. 25.4 115. 123. 1t8. 324. 33~. 339· 26.2 !17. !!7~ !!7, 325. 333. 330, 25;6 ;'~ I I ~l ...' i if-f-ti -..'--'...~ I ...~... 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L.O. 29. 2~. 3'0. i,.~i 25~ !06~. 33. 33. 10559. 29. 33. 10660. 31. 32. 10661 29, 3! ~n~ 27. 31, ,~. 33. ~9. !066q. 26, 27. ~n~c 22 2~ i~V~il · 10666. 22, 27, 10668. 30. 10669. 41 . 37. !0671. 35. 39. !0672. 29. 33. 10673 28. 26. !0674. 28. 25. · .!0675. 26. ~6. ~n~ ~o 27 In678~ · 25. ~/' !nA~; ~7~ -25,! 25.3 24.4 25.5 25.9 25.5 25;! 26.4 25.8 24.7 26.3 26.4 25.1 27.5 25~2 23.0 22.1 24.3 25.9 2~.4 25.5 24.0 24.5 25~7 18.1 !8.4 18.1 18.4 19.3 18.9 2! ,'3 20.6 21 .3 21 .2 ~ i- i ,.~ '-- ~. i 25.3 25.0 25.7 25.~ 2~.2 25.6 27.0 26.S 2;.4 25.8 25.1 25.0 24.9 2~.0 24.6 24.7 25.5 25.5 24.8 25.4 ~..'-r i ! c..-'r I f 25.1 25,.,2 24.3 24.5 23..6 23.8 2~.~ 26.7 26.2 26.2 23.8 24.4 25.8 25.7 · 25.8 26.2 26.4 26.1 26.8 26.~. 26.1 25.9 25.! 25.5 24.6 25.1 24.7 ~5.5 25.3 2_6.0 26.0 26.1 ~'~ 4 26.a 26.5 26.3 26.0 25.9 25.4 25.2 25.6 2~7 23.1 23.1 22.3 23.5 25.1 25.£ pc, /, P~ 0 26.4 26.~ 25.7 Z5.5 25.1 24.9 24.6 24.9 26;0 25:7 ^o~'n .~L~SK.~ *,%'C. sRUDHOE 3AY,N.SLOPE,AK, 12: O: 1 PAGE 11 O.S. 7-26 AVERAGE PASS DEPTH GAMMA ~*Y L^''~ PASS PASS PASS FT. 1 2 3 1 SPACE S'~T~,~ S~ACE PASS PASS PASS P~S3 PASS 2 3 1 2 3 COMPENSATED PASS PASS I 2 NZUTRON PASS &VERAG 3 ln~on u~81 . 10~ o'~ I0~5. I F'~ Z.. 0 z I~687 I ~z o~ I~1~,. 10694. I0'~5.~ I~96. I0~7.~ ~ 10~ I~.~9 I~0. 10701. I n~n3. I 0706. 10709. 10710. 10711, 10712. 10713, 'JI 151 1~6. I~7, 10718. I 0720. 10721. 10722. !0723. 1072~. 10725. ! ~ ~ ~'~i 10727. 28. '6.-~ 25. ~, .=. 118. 127. 3~,,. 329. 342. *~;~.~. 28. 27. 24. 118. 117. 122. 324. 334. 343. 25.3 26- 26. 29. 11= I~7. 121· 324 =/- ~-O. ~. 26.1 ~ ~ 3~' ~2~' I~ 122 333 3~~ ~3 2~' 5 28. 2T._ 27. 128. 143. 123, 350. ~' ~4. ~='~. 25.2 28. 30. ~= ~=~ 150. 125. 3~. 5. 336. 27. 30. 27. I~a~=, 147. 131. ~.=~' ~.~,~' 348. 23.C 2~.. 28. 26. ~,~,. ~'~,~,. I~0. 352. 3~7~ . 367, ~3,2 ..mT. 27, 27. I=~. 14~. 146. 351. 354, 369, ~,~ 26, 26. _m~. 130. 139, I~5. 3~,~., 351, 351. ~5. ~,.~ 2~, 1=2 134. 142. 3~-~-~ 3~3, 359, 23,7 25, 28. 24. 13~.~ 134, 137, 346, 3=8.~ =~.~. 22,6 ~,- ~. 25. 131. 130, 137· 33C. 3~. ~.~ 29. 31. ~,~ I~. 127. 12~, 33=~, ~.~ 352. 23.8 26. 3~. ~.~ ~',~. 131, 130. 32~.~, 342. ~=~, 23. 24. 30. ~= .... ~ ~ ~'~ ~ ~/- ~=~ . . ~;~_~..: , ~. , ~ . ,~. ~-. ~.. ~. 31. 33. ~~ ~-?~'4,i/' J;~2~-' 32~2. 340.-- 2-3.-8 28. 33. 31. 119. 118. 123· 314· 322. 336. 24.1 37. 34, ~ ;7t~2:~-~' :~;-~ 1~.5-, ~327, ~ 328. 24.4 37. 36. 29. 119· 128. 121. 321. 330· 327. 24.9 36. 35. 37. 115. 1'21' 120· 315. 325. 327. 24.4 30. 3~ 42. !!2. 117. 124. 313. 319. 329. 25.8 , · q~- . ~..- 29. 36. 33. !08. 114. 12~ 3!1. 3!~. ~0 2 31. 34. 38. !!2. !17, !18. 311. 322, 325. 25,7 36.~ 37. 4~. 119. 121. 112. ~21. ~. v"'o~,,. 24. 3S. 42. 37. 122. 120. 12~.w ~v~8.~ 324. 317. 24.6 32. 56. qq. 128. 122. t23. 33!. 320. 3!4. 23.5 Cl 52 53 I 2~' I ~4 ~ ~ ~n =~ ~ ~" ~' ~x' ~ ~ ~7 11~ t2~ ~ 32~ 310. 318. 25,4 66. 72. 55. 119. t14. 116. 322· 308. 308, 25.0 72. 68 I 60. I~3~ · 127, 117, 323, 327, 305, ~, 49. 6!. 60. !26. 13~. 111. 334. 344. 309. 2~.2 ~ /'~ 5c 125. 133. 11~ 333 3/'5. 31~ 27. 24. 57. 125. 124. 130. 326. 327. 335. 23.0 28. 29. 27. I0~. 1~8. 1~. ~0~. ~11. ~$I. 2~.8 $!. $1. 2~. 11!. 111. 12~. ~I0. $!$. ~$I. 29. 31 32. 115. 12t. 111. 315. 333. 325. 25.1 ~.=n ~=~n. 33. 119, 1t6· 121· ~2~ .. 331. 32~, 2/.=.o, 3t. 30, 29. tt0. 96. 115. 302. 2~9. 321. 25,2 *t 'O 25.7 25 4 25.8 25.4, 25 . 3 ')6 5 24 9 25 0 ~.. · · · 2 4.5 2 4.7 2 4. 24.8 24.3 24.3 23.0 23.$ 23.7 21.8 22.7 22.~ 22.2 22.3 ~ ° ~ n 22.7 23 · 7 22.4 24.0 23.B 22.7 23.6 24.0 23.9 25.3 24.5 2&.5 25.3 23.2 25.5 2~.5 23.7 2= & 24 5 25 .,~ · · 23.~ 26.4 25.~ 23.9 2~.6 2/+.4 -- ~4 e 24.1 24.} 25.2 25.2 24. 25.1 24.8 2-5.7 25.5 24.7 25.~ 24.9 25.9 25.0 25.3 24.9 24.8 24.9 24.B 26.0 25.0 2/4.5 25,5 24.3 24.1 23.3 23.6 24.7 2/:.5 25.3 26.5 'Dr-, I 'D~. /. ")r_.. /. 25;9 24;! 23 25.~ 23.1 23.8 24.8 23.3 23.2 24.9 22.9 24.3 23.~ 24.9 24.8 23.1 24.2 23.9 ~ = 23.7 25.0 24.5 35,6 25.1 24,9 25.2 23,~ 23.4 23.6 23.9 '>'~ ': o~ v 2x 3 23.6 23.6 24.? 24.0 2~.9 26.2 26.3 26.2 26.9 26.7 27.4 2~.~ ')~ ') 24 5 P5.5 I.. ~,.~ I ~ I -- 25.5 25.9 26.2 ~,...... -.r i,..,., · ,-- .,-... ~' 26~6 27.5 28.~ DATE: 7/1!/.8~ TIM=: .~.RCO ALASKA INC. 12-' O' t 9.S. 7-26 AVERAGE PASS DmpTN 9aM~^ may LONO PASS. P~ PA~S~ PASS FT. I 2 3 I SPACE SHOST SPACE PASS~"~'SS..~ .~ASS. ?~SS~ P~SS 2 3 1 2 3 C O~.pE,N, S AT E D ,N:UTRON '~ASS PASS P~SS~"V-RAG F- l 2 10728. 37. 33. 10729..,,_~"'. 37. 10730. 30. 33- 10731 ~ 25: 10732. 25. 21 . 10733. 24. 22 10734~ 26. 24. 10735. 2..8. 26. 1073~ 30, 27, 107-z? -q~ · _- . _- ~ ~ ,; :_ . ,,~ ln?Z~ /,i 38. 10739. 7! 59. !~7~0. 69. 64. 10741 . 43. 33. ~ ~-~x '~ 30. 33. 10743. 3~. 31 . I074/' ~3, !g74~. 29. 10746. 30. 31. 10747. 31. 36. !074~. 32. 33. 10749. 3~. 10750, 41, 4t . 10751 . 3~. 35. 10752, 42. 33, 10753. 43. 29. ~ n~/. /.m 3~ 107~5. 41. 30. -! 0756. 44. 32. 10757, ~5 1075~, 43. 31 . I 07 ~n ¢ ~ 10760. q4. 31 10761 . 46. 33. 10762. 49. 34. 10754. 45. 34. 10765. 43. 10766, 42, 3! 10767. 37. 29. 10768. 36. 2~. 10769. 38. ~5. 10770, 43, ~6, 10771 . 47. 33. 10773. S~. 30. 10774, =~ 10775: 6~ 31 31. 96. 84. 118. 275. 266. 339. 34. $~, .~1, 11~ '~63 2=9 346 , ~ · ~ · ~ · · 35. 77. 77. 97. 253· 249. 300. 33~ 74, 79~ 93, 2~.9, 254, 257. 33. 82. -~0, 83. 251, 260. 264, 27. 85. 80. 77. 256. 252. 255. 23. 82, $1- 77. 262. 254. 255. 23. 83. 81, 80. 266. 2~'9. 263. 21, 85, 82. 85. 264. 252. 266, 25, 81. 7-8. 87, 260~ 251, 273. 25. 78. 68. $4. 255. 241. 272. ~6, · 74.. 70, -.-,~/'. 2/'3--~ ~-~-~/' 2~3~ · 27, 73. 76. 85, 241, 240. 256, 5~. 78, 74. 78. 249, 237. 247. 75, 73. 7~, 73, 2~5. 225, 235. 35, 95, 85, 97. 266, 256· 269, 33 94 ~4 91 ~62 253 261 . 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PRUDHGE 3AY,N.SLOPE,AK. 12' O' I ~GE 13 D.S. 7-26 AVERAGE P~SS FT. I 2 3 t *PACE *uORT SD^"~ ~ 3 I 2 3 rOMPENSAT=D ;,, E U*R 0~; PASS PASS PASS AVFRAG 1 2 3 10776. 6= ~ '~ 10778. 56. 3~. 28. ! 0779, 5 2. 37, 2~. 10780. 50. 37. 10781 . 88. 66. 2~. !07~2. !30. 130. 27. 10 ~ 17~ ~== ~- 10784. 210. !37. ~5. 10785. 150. 105. ~n~ 11~ 96 i '¢ ~ ~ ~ i ~ ~I / ~! t i ~i ~n~ 7~ 8~ I0~ I~ 37 =~ 10791. 2~. 31 . 10792. 25. 29, !07~3 . 27. 27. 10~n4 27. 10795 25 10797. 27. 2~. 10798, ~' 10800. 26. 32. 10801 · 2= ~ 24. 10802. 28. 28. 26. , ~/. 3n 33. 31. I ,~ '~ I ~ I I0~05. 3~- 29. 29. 10~06. ~ 34 ~ I I I 10807. 34. 38. 31 ~n~n~ 3o =~ 3 10~09 ~= ~= 3~ 10810. 29. 32. 39. ~,I. ~,. ~,. 35. · ~ 32 32 31 1 ~J ! ~i I i I 10814. 3t. 34. 31. 10815. 30. 32. 29. 10816. 36. 30. 35. 10817. 38. 35. 35. 10518. 3&. 33. 37. 10819 31 . 29. 32. !0~2!. 3~ ~3 ~ i ~ i - i ~:~ 35 30. 28. I ~'~I m 10823. 36. 29. 30. 77. 85. 84. 255. 251. 253. 32.7 27. '?° '"')' '" "* 2"0 2z, 8 79 81 $0 '~/.o 253 255. 29 9 2~ 3 . - · . . ~.. -r / . I · ' · 80. 82. 85. 2/:7. 248. 253. 29.3 29.5 81. 86. 83. 245. 256. 251. 28.7 28.6 81. 87 78. 258. 272. 252. 30.4 27.$ 76. 65. 80. 255. 239. 255. 33.3 30.1 6~ /'5 ~1 199 178 Z5 i . -mr . -~ . · · ~ I · i . / 51. 39. 8!. 176. 159. 266. 34.7 42.3 46. /:4. 80. !75. !59. 26!. 39.7 42.8 51. 64. 55. 182. 193. 20~. 35.6 36-6 6~' 70 42. ~ 203. ~ 25.$ 2~ 3 · '~ i - i - ~./ I ~ .~ i.,. i · · , i 69. 63. 42. 202. 200. I/-~2. 27.~ 27.2 58. 5~ : '> 2n~ ,~ oo ~I ,,~.~n 6'? 19n; I~:~. 231. 31.7 29.7 %~ · · · 168. 18g_ ~.-5 ~1.7 48. 46, 55. 165· 163· 182· 34.0 33.8 -?':~::4;6'%" ~:-' $5-.~~ ::::::t6:4:,':: ~::63;; 175. 34.4 36. I 45. 46. 43. 160, 158. 164. 36.2 35.2 43. 46. 47. 157. 158. 165· 37.6 34.1 44. 47. 48. !58. ag. 37.7 ~5. ~6. 4~. 161. 161. 160· 35.6 35.2 &x ~ ~ lC8. 161 1~7 ~7 x xq,n 41..~."= -"8. 158. 159. 159. ~./'n 9 ~0.5 41. 43, 47. 157, 16~. 160, 40,3 38,4 ~4. 47. 44. 158. 166. !61. 36.8 39.! ~-~ ~-~ 43. 16~ ~= 161 . 37.2 42. 43, ~3, 161. 152.~ ~==,~. ~n~..~. 36.7 ~3. 4~. 43. 161 I~4, ~=~ =~ 3 =9.5 /.3 ~3. /-/- 1.52. I~ ~x~ ~a ~ 3~ o, ~0 45, ~7, 158, 15* 16= /'I ! 41. 45. 42. 15q. 159. !61. 39.7 35.6 /-~ /'~ /'5 ~55. 161. 161. 37.= ~/' 9 47 ~4 =: ~58 ~67 157 ~ 3 ~/' 48. 44. 42. t51. 16~. !58. 33.3 38.0 48. 44. 44. 159. 151. 157. 32.7 39.0 47. 45. 45. !58. 157. !59. 32.9 36.9 /'~ /'~ /': I=7 I~7 163 , 48. 45. ~5. 160. 159. 150. 33.! 33.0 43. ~5. ~/~ ~'. 1.63. I,¢'2. 156. 33.7 36.1 49. 50. /,5. 168. 171. !c6. 33.8 36,6 3n 6 28 ~,~ I - 23.0 3~ ~ 23.4 29.9 3! .2 30.0 30,5 32 .~ ~o ~ ~1.6 32.0 37.9 31 .5 3~.0 ' 3 9./~ 34.1 37.3 29.$ ~ ~ 27.~ 3~.6 2~.~ ~7.0 ~o ~.o 31 .I 29.2 32.; 30.9 32.7 32,A 31 .9 32.6 32.0 32.3 35.~ 31 .0 35.2 37.6 40.6 35.5 40.2 35.5 35.0 33.9 35.7 33.7 ~ ¢ 33 3! .9 35.7 32.3 39.8 33;6 37=9 37.2 37,2 39.2 38.~ 36.7 37.4 3~.6 37.6 38.4 39.1 34.9 35.6 39.~ 37.8 3/~.7 37.7 34.3 34.0 39.4 34.0 36.7 35.7 3/, /. ~, -. i · ~'= i ~ 37.0 35.5 35.7 33.2 ~x 2 33.5 34.7 33.9 33.4 35.2 33.! 32,7 ARCO ALASKA 1¢!5. D.S. 7-26 n=g"r~ GA~,~^ oar LO'""'"' ~'P^CE SHO~T S°^CE I,M .,-! F'T. I 2 3 I 2 3 1 2 3 COMPENSATED PASS 1 ~,~U~-,~O~, PASS AVERAG 3 !0.$24. 34. 33. 30. 51. 52. 47. 17~. 181 158. t082-'~. 34. 38. 33. ~'. 53. 4~.~. 133. 1-33. 161. !0B26. 34. 35. 34. 55. 5.0. 47. 178. 173. !65. 10827 33= 34 31; ~!~ 50 4~ !70. 169~ !69. 10828. 33. 38. 34. 52. 51. 53, 170. 172· 174· 10829. 40. 38. 35. 50. 54. 53. 171. 176. 178. !0830. 39. 3~. 31. ~1. 54. 50. 177. 182. 173. ~n~ /.o x7 34 49 /'5, ~ 17~. 170. 10832. 66. 59. 38. 36. 35. 53. 143. 140. 172· 10833 73~ 88~ 38, 34. 39, 53, 135, !45. !74. !0834. 76. 87. 36. 41. 44. 53. !42. 152. 175. t~ 7~ 33 65 ~'/' ~'~ ~'3. 155. 159. 145. !0836. 77. 75. 85. 48. 58. 40. 164. 151. !33. !0837. 76. 60. 90. 65- 77- 40 200. 2!5. !44. 10~''~,,.,,,. 49. --.,L~. ?a,,. 75. 76. -,~.J'~ 220. 215· 153· -t-0 g 4 5. 8 6. 8 2. ~- ~:~::~ ~ 4-d 2-Z-.: ::: ~: 2:3:,::~ 2 21 . !0g49. 75 81. 63. 29. 29- 32. 132. 129. 1,34. 1085~. 75. $2. ~0. 28. 28, 29. 128. 126. 123. 10851. 82. ~3. 78, 29. 28. 29. 126. !2~. !23- !0~2. 81. 82. 77. 30. 26. 29. 122. 120- 132- 10853 7~, 80= 7~ ~8: 27, 29= !!7= !2! ~ n~, S~ ~2 8~ ~ 2~' 28 ~ ~/' I ~/' 10355, 8~ ~ ~ 31 37 '6 ~=~- 135, 124, 10856. t03. ~6, B3. 35. 47. 27. !43. !64. !20. 10857. !05. 94. 83. 42. ~2. 25. t63. 1~I. !29. ~n~=~ 79. 83. ~.~= 53. .65 30. 183. 1~6 126. 10~59 55, ~= ~ 66. ~ ~5 ~01 .~o 139, -~ I 10869. 54. 58. 99. 67. 65. 44. 202. 195. !51. 10861. 35 ~8 84. 54. 66. 52. !99. 102. !72. 10862, x~; xo= ~7~ A~ ~ c~ ~ lO' 10863. 35. 37. 63. 70. 58. 69. 199. 207. 2!0. 10864. 26. 31. 52. ~0. 76. 66. 204. 2!¢. 204. 10865, !o; 23= 3! 8L; 86, 67~ 20!~ 226~ !99 !0866. !7. 22. 35. 96. 93. 69. 223. 234. !98. 10867. t8. 18. 32. 10t. 89. 69. 237. 223. 208~ I~868. !8. ~ m 2~. 9~. ~.~ ~.~ 230. ,~.~. ~ 210. 10869, 20. 2!. 23. 83. 83. 96. 217. 206. 215. 108~0 ~ 2~ 20 77. ~1 In/' -n.~ 2 33 33 31 32 32 33 '~L ..~-r 36 41 , , 34 35 33 28 27 28 2~ 2-6 26 2-7 2~ 26 37 49 52 52 4~ 42 ~5 46 43 33 22 28 2,0. 3O 2~ 23 2! 20 20 2! 23 24 7 .9 33.8 ..?, 34.4 2 -z/. 1 · .~ -,r · ! .7 34 .! .0 33.'~, .7 33.1 ./4. 32.0 .0 33.3 .5 39.2 .2 39.0 .5 34.7 ,9 34,5 .9 30.! .7 35.9 ,7 · 5 28,3 .-4 - 25.5 23,9 ,8 33,5 .6 35.3 .6 ,1 ~3.5 · 3 51.0 .6 50.0 .8 50,2 _ . .g 49,9 ,3 48,4 .! 36.8 .3 .9 34.2 · 0 2~ ~ i .6 27.6 .5 28.2 ~4 2~! .2 .! 2~.6 =2 26~2 .~ 24.! ~3 22~7 .~ 22.~ .9 22.3 34.9 31 .? 35,6 34.0 31 .o 33.9 33.0 32.5 34.9 _J &. · ..~ 32.2 34.g 31.5 36.3 31.5 33.4 32.5 35.6 33.2 36.1 32.7 31.1 36.5 27.9 36.$ 30.5 30.5 28.8 2~.I 2~.4 3! ;7 27,6 28.7 27.3 29=5 2m,1 28.1 28.4 27.4 x3.6 26.7 /,7.9 29.3 48.3 3! .8 47.6 47.0 50.7 45.9 47.1 49.4 53.8 49.& 48~7 50;0 q3.6 49.3 50:7 5! 54.5 49.0 ,- ~ 45~ /: ! . 0 39.8 33.7 32.4 32,9 oo S 29.5 29.3 2~.0 26;6 27:9 28.2 27.5 22.9 22.9 !8;8 !9,6 !8.9 !9.3 2! .O 21 .5 22 .~ 23.4 24.B 25.3 ?7.3 DATE' 7/11/~o~ TIME; .~AnCO ALASKA I~'r,,,,. PRUDHOE BAY,N.SLOPE,AK. PAGE 15 D.S. 7-25 AVERAGE PASS DEPTH. ~AMM*... R~, ...... Nu~ PASS PASS PASS PASS FT. I 2 3 I SPAC~~,,c~ORT SP~C~ PASS PASS P~SS PASS PASS 2 3 I 2 3 COMP:NSATED NEUTRON PASS PASS P^~S~o AVERAG 1 2 3 lm~72. Im 10~73' 20. I 0874. 24. 19875. 25. 10376 *3 i ~ · 10877. 22. 10878. 27. 10879. ~° 108°~ 2° 10881. 26. 10~°~ 27 10°83.~ 2"" 10584. 10885. 27 10886. 27 10~87. 36 """ =' '-' '=' 57 !0~89. 74. I0~90. 75. 10892. 75. !0S93. ~ ~- 7! 108~6. 7 I O°~'~ 10901. u903 · 10904. 10905 · 22. 24. 25. 23. 31. 32. 29. 30. 28. 26. ~i ~I. ~6 f i 79. ~Ni 21. 51. 41. 92. 153. 159. 220. 30.6 20. 46. -,~'~. o°'~. I~7' . ~=~,~.. 217. 34.1 20. /,.S. -,'/"~.-- 77. 158. 157. 210. -,-,'.'~/' o, 19. 42. 39. 62. I 56. I 53. ! 80 · 37.7 2:3. 41 . 38. 49· 153 · I 53 · I ~-'9 ·38 · 9 23. 38. 41. 47. 152. 15~. 1=6. · ~I.~; 27. /'"'" '"'" /'/' 152· 155. 158. 3 27. 44. 4~. 42. 15/'-. 162. 1~$~ · 35.6 25. 46. 43. 41. 167. 170. 155. 37.0 22. 52. 51. 4t. 173. 175. 150. 32.9 21. 53. 53. 40. 175. 178. 155. 32.8 25.¢ 54. 57. 41. 179. 183. 162. 32.7 32. 53. 56. 48. 180.. 186. *,~,*~. 33.6 29. 55. 54. 54. 131. 180. 17/~. 32.4 24. 58. 52. 57. 17~. 176. 176. 29.0 5s. 80. 39. 43. 38. 152. 151. 146. 40.6 77. 77. 35. 36. 41. 74. 78. 32' 37. 52. 75. 75. '30. 31. 50. 76 ~o ~8. 30. /'~ ~'~ ~/i 82. 73. 30. 35 35. 90 75. · 75. 75. 55. 5~. 34. 36. 88. 54. 48. 28. ~1 87 ~0. ~ 46 27. 42. 45. 43. 56. ~4 ~ 44 ~'~ 57 26. z~. 44. 44. 4 ,~7. 2q., 45. 46. ,~.z'= Zl. ~ ~ 4~- 43. 27. 24. ~2 41. ~5. ?5. 30. /'~ ~4 44 ~... 28. 40. 43. 45. ~4 25 40 42 47 ~4 21 · ~ /'2 46 ~, . ~/i ~ - · 21. 25. 33. 40. 42. 24. 25. 40. 4!. 39. J m I . I · i m I g / gVI ~.~,. 'J i I ~ ~' ~'" 24 LJ 7 ',.J I · I 0909. 26. I~I0 2= 10~11 , 2~ 1~2 !~913. 26. I~914. 21 · I~m15. 10~16. 2~. l~Od~ 2~ 10919. 2~. 37.5 37.7 135. 140. 145. 40.2 142. 138. 172. 49.1 137. 123. 173. 5!.2 11°.. '~'~'~,,.,. I~3... -,/'5.4 !2!. !60. !36. 43.7 15~... 183. I/'/'-,-,'. 39.9 187. 180. 1~6. ~.6 t51. 1~7. 124. 33.0 I~' 161. 138. '~'~ ~..i v . ..~ FI. · 161. 161. 16~.. 34.9 161. 161. I~6. I 59 I =~ I 84 37 1 · ~.~ ,.~ I · · I~/ 167 16n I== 163. 163. 3 ~'~I 163. 161, 160. 34. t59. !55. 162. 157· 155. 163. 37.2 15t. 155. !55. 39.7 150. 152. 162, 39.1 150. 151. 160. 39.6 151. 152. 157. /¢2.3 !56. !52; !5!. 33.5 31 .1 31.4 41.0 32.0 33.6 37.9 36.8 37.3 33.3 39.4 39.2 41.7 39.6 39.4 42.$ 37.9 39.4 38.7 39.9 4~.! 37.8 41 .7 33.~ 35.3 33.! 35.6 3! .0 30.9 33.$ 2~.5 31 .3 32.7 32.0 33.4 30.9 34.0 33.2 32.~ 32.4 31 .6 32.6 33~7 36.3 38~~ 32.9 60.1 ~ /' _34'7 39.5 38.9 35.n 38.0 39.3 37.1 ~49.7 /40.0 ~3.6 42.7 37.5 37.6 35.6 36.8 35.2 32.2 35.2 32.5 34.1 37.~ 31.8 37.9 40./4 38.1 40.6 45.5 41.5 ~43.7 46.0 37.9 63.~ 47.8 41.3 49.0 50.7 44-0 54.3 ~! .7 52.4 42.~ 32.~ 39.9 32.3 31 33.3 31.3 34.1 34 2 34 5 ~7 I =' 2 37.5 38 6 ~ ~ 39 9 37.8 ~ 8 38 5 37 I ~ i i i 37.1 36.4 38.5 39.0 37.5 36.4 36.1 38.1 35.3 34 O 3 I 40.3 34.9 39.6 38.7 3~.2 60.0 35.1 ~! .1 38.2 35.5 37.0 41 .6 36.8 ~g.O 42.2 39=~ ARCO ALASKA ZNC. 12: O: I D.S. 7-26 ~V~RAGE PASS DEPTH FT, gAMMA RAY LONG OAS ~ P~¢¢ ~S~ ~ASS 1 2 3 I SPACE SHORT SPACE PASS PASS PASS PASS PASS 2 S 1 2 $ COMPENSATED PASS PASS 1 2 NEUTRn~' PASS AVERAG !0920. 23. 25. 10921. 22. ~6. 10922. 23. 28. ! 0923 = 25-_ 26 !092/;. 26. 25. 10926. 24, 24, 10927. 24 , 23 . ! ~928. 2~. 24 . 10929. 10930, 25. 26. 10931 23 28. 10932. 25, 27. 10933. 24. 22. 10035 , 24, ! 10937 10938. 36, 38. 10939. 30. 31 , !09%0. 3~. 29. 10941 . 27, 28, 10942. 25. 25. 10943. 29. 29. ! 0964. 31 , 34. !09&5. 27. 27. ! 09/46. 26, 28. 10947, !094~. 22. 25. 10950. 21. 28. 109~I 24 ~ I i i ~o9s2. 10953. 23. 27. 10954.. 23. 20. I095c 10956. !4. 20. 10957 t3. t6. 10958. 24. 20, 1095Q 58, 66. I 0960. 50. 52. 10961 . 3~. 4! 10962. 27. 26. 10963. 26. 30. ,no~i. 25. 28. 10965. Z4. P6, 10966. 25, 29. 10067~ 19. 40. 40. 40. !53. 151. 150. 40.5 37.9 23. 40. 41. 41. 151. 151. 147. =~_,,..,./- 39.6 20. 42. 40. 39. !54. 14~. !50. 37.9 37.5 2!= 40~ 39~ 38, 153. !49. !~!. 39.9 37.6 24. 39. 40. 37. 152. 151. 151· 41.2 40.0 25. 40. 38. 40. 151· 14~. 153· 39·5 38.5 24. 1:2. 4!. /~!. 153. !49. 153. 37.5 4!.4 25. 42. 40. 42. 152. 154. 151. 36.1 37. 26. 41. 43. 38. 153. 16'3. 153· 37.8 /:!.! 23~ 45, 46~ 37, !~4, !66. !52. 34.0 38.0 25. 48. 45. l:0. !60, 167. !49. 33.! 36.1 27, 44. 4/4. /;2. 162· 164. !5/4. 37.5 37.6 29. 45, 50, 42. 153. 173· 156. 36·7 38.0 28. 59. 61. 44. !74. !84. 162. 27.6 34.7 ';!. 61, 59. 44. 18~. !79. 166. 28.4 ~,~ 53, /'~ LL. 17:) ,~7_ --, -,:,' ,;;;, ~:~:27~:_,.5 ~, 1 ..7-. 7. _ .-- "155" 17-1.__ 29. 45. 41. 39. 165· 163· 155, 24. 39. 38. 41. 158. 153, 155. 32. 37, 37. 44, !50, !~4, !58 30. 39, 36, 4~, 150. 1~. !59. .......... -_'_- . ._ _- . - - -_ 33. 37. 38. 37. 149, 150. 153. 27. 3° ~'~ 39 I ,2 I 52 151 ~I '~P~I · · · · 'zn 41 5~' 39 154 172 26. 43. 61. 36. 167. 207. !/43. ~4. 6/' ~/' 35.- I°I, 2Z=.. I~/'5. 27. ~= 92, ~7. 228. 2~$. ~m I ~ F i 28. 97. 95. ~8. 2~!. 229. !5!. 24. 82. ~6. 45, 250, ~0. 15~, 23. 46. 38. 87. t57. IC5. 228. !9. 40. ~3. 99. !5!. !~9. 2/43. 16. 42. 42. 89. !58. 156. 230 2n 40 ~ 65 159 1~/' 5/~. 39. 39. ~. 1~4. 152. 1~. 62. 40, /~2, 40. 152· 152. 154, 39. &0, 42. /:3, !53. !56. !60. 29, 41. 45. 39. 152. !56, !57. 32:0 28:5 35 /. 31, 3-8.-3 - ~,0:2 39 ~0 4-0.-1 3-8.-6 ~8.3 40.5 36,/.`- 43.4 38.6 4.1.0 38,2 37.9 37.5 38.1 39./.· 43.0 41.8 39.4 ~ .0 ~. 3_-3 4~ $ ~'0 3 I.. · --F- · 4~ ~ 41.9 [.,. I" 39.! 4! ./4 34.! 28.2 33.4 24.1 24.5 22.3 23./=` 26.0 2! .4 3! .9 20.0 3/~.3 33.5 39.7 43.5 3~ .3 38.6 ~! .6 38.9 ~! .! 40.3 "4? O /,.'~ ..., · / -'T ~,.,, i i 39.3 36.7 37.7 37.5 37_-3 34,8 43. ~ 3 $. 4 40.~ 37·3 38.3 42.6 3A.8 42.7 43. $ ~7 . 9 44.2 37.1 3£.2 3~.3 37.3 36.~ 38.5 37.Z 38.2 37.3 35 .~ 33.4 37·5 29.6 ~/, ~ 9Q 7 3! ./: 32.6 2~.5 3;.5 .... , . . 34.2 38.~ 39:! 37,0 39,3 35.3 4! .4 38.1 41 ;8 38,0 36~5 35.0 ~3.7 37.8 /,! .7 /~ . ~ 40. ! ~0~5 43.5 ~1 .6 ~.~ 39,u 42.7 30.7 36.~ 2/~.7 28,0 22 ~/' 0 ~3 2 22.1 26.7 23.2 3! .7 26,~ 38.5 34.5 39.3 40.3 39.3 38,5 42.3 42.7 39.2 3~.9 36.2 35.9 36.3 3~,5 36,1 12-8: I P~GE 17 C-- PTH G~MMA RAY LO .~ASS PASS PASS PASS PASS PASS FT. I 2 3 1~ ~ 3 S ~ '" R T,., SP.~C~ C OM ~'E N S"~':~ ,.,, ED P;~SS PASS PASS PASS P~,SS 1 9 3 1 ~ NEUTRON PASS AVERAG 3 10a~° 28. '~'~ 31 I 0~· 30 39 3S 7~7 I I I 10~70. 32, 3~- 31 . I 0971 . 3~. 39. 37. I g / I ~I ~ i i i I0~7,. ~/, ~,~. 3/· ~~ 46 /'3 10976. 44. 43. 48. 10977. 42. 43. ~. 10975. ~2. 44. 41 . 10979. 37. 43. 44. !0981. ~3. 43. 43. 10~82, 37, ~,~'~' 43. 10983. 35. y ~ i . i !0~5. /4! ~7. I 09 S ~. 39. 4 ~. ! ~ I I ~ ~ I / ~ I ~ ~ I ~ I 10989. ~! . 68. 10~ ~ 43._ 41. 41. 155. 15~¢. 152. .,,,.~x ~ 38.3 40. 44. 42. 15~. 157.. I¢ =-~' .40.~° 37.5 ~0. 41. 43. 154. 157· 151· 39.7 36.0 42. 40. ~2. 15q. 15~. 153. 37.7 40.4 ' ' - ~ 6 41 5 ~0. ~O. 45. I~3. 154. 155. ¢=- · 43. 43. 40. 155. 156. 151. 37.3 40.8 ~3. 44. 39. 155. 158. 15/~. 36.9 36.7 C2. 47. 42. 155. 153. 15~. 37.7 35.9 4~. 49. /~3. 162. !68. 153. 37.9 34.2 49. 53. 40. !73. 180. 156. 35.6 34.2 5/4. 52. /~2. 183. 183. !5~. 33.5 33.3 55. 50. ~1. 180. 176. I¢~8. ~¢,.~, 3~¢.7 $0. 52, 39. 175. !76. !6!. 35.0 35.5 51. 50' 48. 173. 172. !68. 33.4 33.3 49. ~8. 53. 170. 172· 179. 3~.6 33.~ 40993. 41 · ~. 60. 48- 50. ~0°9/',. . -,.. 4t. -,-.../"= /,4. 50. 5~. 10995. /~! . 48. 45. 51 . 52. 10~a6. /'I . /'~ /, ,.r, /.a c2. --,-r ~ i, '-r ~,.,, · "-~/ · -r "" ~ "' ~ 41 45 48 -49. 52 · I ~/7 ~ ~ i · · · 11000. A! . 6~. 4~. 69. 52. ~,~ t,,,~ ~ i · · · · 11'~n2. O. O. 4~ n O 110"'". u'"'. O. ~5 0 · O. 11n'''/. 0 O. 47. O. 0 11005. O. O. 39. O. O. 11~*,.., ,., ,,-. O. ,., r', · 4~. 3. O. 11007. 3. O. 43. O. O. I 1 008· O. O. 43. O. O· 11009. O. O. 4t . O. O. 11nI~,., ,,.,· O. O. 44. O. O. 34.5 35.8 34.3 33.5 50. 166. 172· 171· 34.2 33.2 51. 165· 170. 174. 32·1 3~.0 5t. !65. 172. !76. 31.5 31.7 51. 166· 172. !70. 33.3 32.4 51= 166, !72~ 17!= 33~&. 32:~ 52. I~. 172. ~/-,,-,. 33./~ 32./~ 51. 166. 17'"~. ~,~. 33.4 32.4 50. !66. !72. !72. 33.4 32./4 49. 166. O. 172. 33.4 32./+ 47. O. O. 172. 0.0 47. O. O. 170. 0.0 0.0 47. O. 3. 173. 0.3 0.0 49, O. O. 171· 0,0 0.0 50 r'. 0 169 0 0 · ~ · · · · m 48. O. O. 163. O.O 0.0 4~' O C 173 0 0 3 O ~ i · · I · · ~7. O. 3. 174. 0.0 0.0 49. O. C. ~,r..~,..,,.,..0.3 0.0 36·3 3.7.9 "' ~ ~0.5 .~ m~ 40.~ ~0.1 4! .7 37 3° 6 3~ 7 3~.5 39.3 'n0 3~ 7 l,n 2 ~ i ~ / i '~ 39.S ~40.8 z~z: -0 36.1 3~.2 32.~ 33.4 33.7 32.9 34.3 33.~ 35.7 ~A X~ 7 37.1 36.9 34.2 35.9 34.3 35.3 33.~ 33.4 33.5 - 32:5 35.Z 33.1 34.3 33.8 36.0 33.9 33.7 33.2 33.1 33.2 32.2 32.5 32.7 33.0 33.2 33:2 33:7 34.2 34.3 34.1 34.4 36.0 35.7 36.7 24.& 36 . 3 ~4= . 5 37.3 24.6 35.1 22.5 33.0 22.2 , 34.3 23.2 35.9 34.5 37.8 S2,5 22,0 LIBRARY TAYE CURVE SPECIFICATIONS Company A~RCO ALASKA, INC. Well D. S. Field PRUDHOE BAY County, State NORTH SLOPE, AJ~S~ Date JUNE ~2, 1985 Curve Name "- (Ah~rev.) Standard Curve Name Logs Used Szale ~ CN1 ! Co}~ENSATED NEUTRON ! CNL I 60 - 0 ! c~3 I 100 · DATS: 7,/ F:/C. 5 TIME: 14:25.:3; " }_ . ..~..:. .¢:.....:..: 7." Y": :'~ ..:.... _->_ · .....:::..:_ .. ~ :.__ ..: .. _ :... :. -~.. -: ......... ~:'~ -..~.-. ~57.:.. ?'."y:--- '..;. '~-'~.~Z"".": ".. X'." "~ ~ ;".'.':. -- ~. -." - .'- ' Z'.' .'-' ~. 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[:-t I COMPANY NA~4~ : ARCO ALASKA INC. WELL NAFIE : D . S . 7-26 FIELD NA~IE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 500292093100 REFERENCE NO : 98026 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: **** RR~.L HEADER **** SERVICE NAME : EDIT DATE : 98/01/20 ORIGIN : FLIC RR~L NAFIE : 98026 CONTINUATION # : PREVIOUS REEL : CO~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 7-26, API# 50-029-20931-00 **** TAPE HEADER **** SERVICE NAFIE : EDIT DATE : 98/01/20 ORIGIN : FLIC TAPE NAF~E : 98026 CONTINUATION # : 1 PREVIOUS TAPE : COF~V~Ff : ARCO ALASKA INC., PRUDHOE BAY, D.S. 7-26, API# 50-029-20931-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAFIE: D.S. 7-26 API NUMBER: 500292093100 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUF~ERGER WELL SERVICES TAPE CREATION DATE: 20-JAN-98 JOB NUFIBER: 98026 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: M. BOLKOVATZ SURFACE LOCATION SECTION: 33 TOWNSHIP: 1 iN RANGE: 14E FNL : 1634 FSL : FEL : 293 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 57. O0 DERRICK FLOOR: 56. O0 GROUND LEVEL: 27. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 675 10062.0 47. O0 2~D STRING 7. 000 11040.0 29. O0 3RD STRING 5. 500 9731.0 17. O0 PRODUCTION STRING 4 . 500 9804. 0 12. 60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (FIEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 08-APR-83 LOGGING COMPANY: SCHLUmbERGER WELL SERVICES BASELINE DEPTH 88888.0 10791.0 10790.5 10787.5 10783.5 10783.0 10778.5 10773.5 10770.5 10768.5 10767.0 10765.0 10759.5 10757.0 10754.0 10751.0 10750.5 10746.5 10739.0 10735.0 10731.0 10729.0 10722.5 10722.0 10717.5 10717.0 10715.5 10714.5 10712.5 10708.5 10703.0 10702.5 10696.0 10687.5 10686.0 10685.5 10678.5 10673.0 10670.5 10667.5 10661.0 10658.5 10651.5 10651.0 10647.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.5 88889.0 10792.0 10790.0 10786.5 10783.0 10783.0 10778.5 10778.5 10773.0 10773.0 10771.0 10771.0 10768.0 10768.0 10766.0 10766.0 10765.0 10765.0 10761.0 10761.0 10756.5 10756.5 10754.0 10754.0 10748.0 10748.0 10744.5 10744.5 10739.0 10739.0 10736.5 10736.5 10732.0 10732.0 10729.0 10729.0 10721.5 10721.5 10716.5 10716.5 10715.0 10715.0 10712.0 10712.0 10706.5 10706.5 10700.5 10700.5 10694.5 10694.5 10687.0 10687.0 10685.5 10685.5 10677.5 10677.5 10672.5 10672.5 10670.5 10670.5 10667.5 10667.5 10659.0 10659.0 10656.5 10656.5 10650.5 10651.0 10647.5 10647.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing 10642.5 10641.5 10633.0 10625.5 10623.0 10620.0 10610.0 10604.5 10602.0 10600.0 10593.5 10583.0 10576.5 10572.0 10566.0 10562.5 10558.5 10558.0 10555.5 10555.0 10547.5 10543.5 10541.5 10535.0 10519.0 10516.0 10511.5 10511.0 10509.5 10509.0 10503.0 10502.5 10501.0 10496.0 10494.5 10488.5 10485.0 10484.5 10479.5 10479.0 10477.0 10476.5 10473.5 10471.0 10470.5 10461.5 10456.0 10454.0 10441.5 10441.0 10433.5 10430.0 10429.5 10425.0 10424.0 10421.5 Center 10642.0 10642.0 10640.5 10640.5 10633.0 10633.0 10622 . 5 10622 . 5 10621.0 10621.0 10617.5 10617.5 10610.0 10610.0 10604.0 10604.0 10602.0 10602.0 10599.0 10599.0 10593 . 0 10593.0 10581.5 10581.5 10577.0 10577.0 10571.0 10571.0 10565.5 10565.5 10561.5 10561.5 10558.5 10558.5 10555.5 10555.5 10548.0 10548.0 10543.5 10543.5 10539.5 10539.5 10534.0 10534.0 10519.0 10519.0 10515.5 10515.5 10510.0 10510.0 10508.0 10502.5 10500.5 10495.0 10488.0 10485.5 10480.5 10477.0 10473.0 10508.0 10502.5 10500.5 10495.5 10488.0 10485.5 10480.5 10477.0 10473.0 10470.5 10470.5 10461.0 10461.0 10456.0 10456.0 10454.5 10454.5 10441.0 10434.0 10430.5 10424.5 10422.0 10441.0 10434.0 10430.5 10424.5 10422.0 20-JAN-1998 14:22 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10418.0 10417.5 10417.5 10415.5 10415.5 10415.0 10415.5 10412.0 10413.5 10413.5 10409.5 10410.0 10410.0 10407.5 10407.5 10407.5 10405.5 10405.5 10405.5 10403.0 10404.0 10403.5 10401.0 10402.0 10400.5 10402.0 10398 . 5 10399 . 5 10396.5 10396.5 10396.0 10396.5 10391.5 10392.0 10392.0 10390.0 10390.0 10390.0 10383.5 10384.0 10384.0 10378.5 10379.5 10379.5 10374.5 10375.5 10374.0 10375.5 10372.0 10373.5 10370.5 10371.0 10370.0 10371.0 10367.0 10367.5 10366.5 10367.5 10365.0 10364.0 10364.5 10364.5 10360.0 10361 . 0 10361 . 0 10357.5 10357.5 10357.5 10353.5 10352.0 10352.0 10346.0 10347.0 10347.0 10344.0 10345.0 10345.0 10342.0 10343.0 10343.0 10337.5 10339.0 10339.0 10334.5 10335.0 10334.0 10335.0 10330.5 10331.0 10331.0 10320.0 10320.0 10320.0 10317.0 10318.0 10316.5 10318.0 10310.5 10311.0 10311.0 10305.5 10305.5 10305.5 10304 . 0 10304.0 10304 . 0 10298.5 10300.0 10300.0 10293.0 10294.0 10294.0 10290 . 0 10290 . 5 10290.5 10286.0 10287.5 10287.5 10284 . 5 10285.0 10285.0 10282.0 10281.5 10281.0 10281.5 10278.5 10278.0 10278.0 10278.0 10277.0 10276.0 10274.5 10274.0 10274 . 0 10274.0 10271.5 10271.0 10271.0 10271.5 20-JAN-1998 14:22 PAGE: 4 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 10270 . 5 10270 . 0 10268.5 10268.5 10265.0 10265.0 10265.0 10258.5 10258.0 10258.0 10255.5 10255.5 10255.5 10254.0 10254.0 10252.0 10251.0 10251.5 10251.0 100 · 0 99 · 0 99 . 5 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 7-26 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAMMA RAY, ALSO NPHI PASS #1 AND THE BCS GAMMA RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~ER : 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 1 DEPTH INCRb~4ENT: 0.5000 FILE SUF~ARY LDWG TOOL CODE START DEPTH GRCH 10792.5 CNTG 1O8O5. O $ · # STOP DEPTH .......... 10249.0 10249.5 CURVE SHIFTDATA - PASS TO PASS(FIEASUREDDEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: REFIARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 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 NUMB SAMP ELE~ CODE (HEX) DEPT FT 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNTG 1065831 O0 000 O0 0 1 1 I 4 68 0000000000 CRATCNTG 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 NCtFT CNTG CPS 1065831 O0 000 O0 0 1 1 1 4. 68 0000000000 FCNTCNTG CPS 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 CNECCNTG CPS 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 CFECCNTG CPS 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1065831 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: ** DATA ** DEPT. 10900.000 NPHI. CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG GR.BCS 108.063 DEPT. 10210.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC.CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG GR.BCS 107.188 -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRC 10792 . 5 10248.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: CNTG 10805.0 10249.5 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURE~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10802.5 10801.0 10797.0 10794.0 10791.0 10788.5 10786.5 10785.0 10783.0 10781.0 10779.0 10778.0 10777.0 10775.0 10772.0 10770.5 10770.0 10769.5 10765.5 10763.5 10757.0 10756.0 10751.0 10750.0 10744.5 10742.5 10740.0 10737.5 10735.0 10732.0 10731.0 10728.5 10726.0 10725.0 10724.0 10721.0 10720.0 10719.5 10718.0 10717.0 10713.0 10712.5 10712.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88887.5 88889.0 10790.5 10783.0 10781.0 10778.0 10776.0 10770.5 10769.0 10765.0 10761.0 10754.0 10748.0 10744.0 10739.5 10736.5 10732.0 10728.5 10725.5 10721.5 10718.5 10716.5 10712.0 10803.5 10802.5 10797.0 10795.0 10789.0 10786.0 10783.0 10778.0 10774.5 10772.0 10768.5 10756.0 10748.5 10741.5 10735.0 10733.0 10730.5 10727.5 10726.0 10724.5 10723.0 10718.0 10716.5 10712.0 10710.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 10709.0 10706.5 10708.0 10705.0 10705.5 10702.0 10702.5 10699.0 10701.0 10697.5 10699.0 10697.0 10697.0 10694.5 10696.5 10694.5 10691.5 10691.0 10690.5 10686.0 10686.5 10685.5 10684.0 10682.0 10682.5 10682.0 10678.0 10676.5 10677.0 10677.5 10676.5 10675.0 10674.5 10674.0 10673.5 10673.0 10672.0 10671.5 10671.0 10670.5 10667.5 10667.0 10667.0 10667.5 10663.5 10662.0 10663.0 10661.0 10662.0 10659.5 10658.5 10656.5 10656.5 10654.5 10652.5 10651.0 10651.5 10651.0 10649.5 10649.0 10647.5 10647.0 10647.0 10646.5 10645.0 10644.5 10641 . 5 10640.5 10636.5 10636.5 10632.5 10630 . 5 10632.0 10633. $ 10628.0 10629.5 10625.5 10623.0 10620.0 10620.5 10618.5 10616.5 10618.0 10619.0 10614.0 10612.5 10612.0 10610.0 10610.5 10608.5 10610.0 10609.0 10605.5 10604.5 10603.5 10600.5 10599.0 10599.0 10597.0 10595.0 10594.0 10593.0 10593.0 10586.0 10583.$ 10580.5 10576.5 10579.0 10578.0 10573.0 10573.0 10572.0 10569.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 10 10565.0 10563.5 10564.5 10561.5 10561 . 0 10558.5 10559.0 10558.5 10556.0 10556.0 10552.0 10551.5 10550.0 10550.5 10547.0 10547.0 10545.0 10547.5 10544.0 10543.5 10543.5 10544.0 10538.0 10536.5 10532.5 10531.5 10531.5 10531.0 10530.5 10529.0 10527.0 10527.0 10524.5 10524.5 10522.5 10522.0 10515.5 10515.5 10511.5 10510.0 10508.5 10508.0 10505.0 10504.5 10503.5 10502.5 10501.0 10500.5 10498.0 10497.0 10495.0 10495.5 10493.5 10492.5 10492.5 10492.0 10489.5 10488.0 10489.0 10489.0 10485.5 10485.5 10482.5 10483.5 10481.5 10480.5 10479.5 10480.5 10477.0 10477.0 10475.5 10473.5 10471.0 10470.0 10468.5 10468.0 10467.5 10467.0 10462.0 10461.0 10461.5 10461.0 10456.5 10456.0 10454.5 10454.5 10454.0 10454.5 10446.0 10444.0 10445.5 10445.5 10441.0 10440.5 10440.5 10441.0 10438.0 10438.0 10434.0 10434.5 10433.5 10433.5 10431.5 10432.0 10426.5 10424.5 10426.0 10425.5 10421.5 10422.5 10422.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 11 10418.5 10418.0 10415.5 10415.5 10413.0 10413.5 10410.5 10409.5 10408.0 10407.5 10403.5 10403.5 10402.0 10402.5 10399.0 10399.5 10398.5 10399.5 10396.5 10396.5 10396.5 10392.5 10392.5 10392.0 10390.5 10390.5 10387.0 10388.0 10385.0 10385.5 10382.5 10382.5 10378.5 10379.5 10374.5 10375.5 10373.5 10375.0 10370.5 10370.5 10370.0 10371.0 10367.5 10367.5 10366.5 10367.0 10365.0 10364.0 10364.5 10365.0 10360.5 10361.5 10354.0 10354.0 10352.5 10351.5 10350.5 10350.5 10346.0 10346.5 10347.0 10344.5 10345.0 10342.5 10343.0 10343.0 10340.0 10340.0 10339.0 10340.5 10334.5 10334.5 10334.0 10334.5 10328.5 10329.5 10327.5 10328.0 10326.5 10326.5 10324.0 10323.5 10320.0 10318.0 10314.5 10316.0 10310.5 10310.5 10308.5 10308.5 10304.5 10305.0 10303.0 10304.0 10300.5 .10301.5 10298.5 10299.0 10295.0 10296.0 10293.5 10294.0 10290.5 10291.0 10290.0 10290.5 10288.0 10289.5 10285.0 10284.5 10282.5 10281.5 10281.5 10282.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 12 10278.5 10278.0 10278.0 10277.0 10276.0 10276.5 10276.5 10275.0 10274.0 10274.5 10274 . 0 10270.5 10270.5 10269.0 10268.5 10265.5 10265 . 0 10264.5 10265.0 10263.0 10262.0 10258.0 10258.5 10256.0 10255.5 10254.0 10253.5 10252.5 10251.0 100.0 98.5 99.5 $ REM3~RKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATIONRECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 13 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 NRATCNTG 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 CRATCIVI~ 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNTG CPS 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 CNTCCNTG CPS 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 CNECCNTG CPS 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 CFECCNTG CPS 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1065831 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10805.000 NPHI. CNTG 21.091 ENPH. CNTG NRAT. CNTG 2.311 CRAT. CNTG 2.554 ENRA. CNTG FCNT. CNTG 871.027 CNTC. CNTG 2423.542 CFTC. CNTG CFEC. CNTG 826.690 GRCH. CNTG -999.250 TENS. CNTG DEPT. 10248.500 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 50.969 TENS. CNTG 28.954 CPHI.CNTG 4.552 NCNT. CNTG 930.407 CNEC. CNTG 3840.000 CCL.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG 20.434 2537.787 3763.355 -0.083 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 14 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10792.0 10250.0 ~ 10805.0 10250.0 $ CURVE SHIFT DATA - PASS TO PASS (F~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88887.0 88889.0 10802.5 10803.5 10797.0 10797.0 10794.0 10795.0 10790.5 10789.5 10787.5 10786.5 10785.5 10786.0 10783.5 10783.0 10783.0 10783.0 10780.0 10781.0 10778.0 10778.0 10776.5 ~0774.5 10772.0 10772.0 10770.5 10771.0 10770.0 10770.5 10769.0 10768.5 10766.5 10765.0 10764.0 10765.0 10757.0 10757.5 10755.5 10755.0 10754.0 10754.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 15 10753.5 10750.5 10749.5 10746.5 10742.0 10739.5 10737.0 10733.5 10732.0 10731.0 10728.0 10727.5 10727.0 10723.5 10722.0 10721.0 10718.0 10716.0 10715 0 10708 5 10707 5 10707 0 10704 0 10701 0 10696.0 10693.5 10688.0 10687.0 10685.5 10683.0 10681.5 10681.0 10678.5 10673.5 10671.0 10667.0 10666.5 10664.5 10662.5 10657.0 10655.5 10651.5 10650.5 10648.0 10645.5 10638.0 10637.0 10635.0 10630.5 10625.5 10624.0 10619.5 10617.5 10609.5 10605.5 10748.0 10744.5 10741.0 10739.5 10737.5 10732.0 10728.5 10725.5 10721.5 10714.5 10709.0 10706.5 10702.0 10694.0 10691.0 10688.0 10685.5 10679.5 10678.0 10673.0 10670.5 10667.5 10659.5 10651.0 10647.5 10636.5 10631.0 10624.5 10621.0 10610.0 10604.0 10752.0 10748.5 10741.5 10739.0 10736.0 10733.0 10727.5 10723.0 10720.0 10716.5 10715.0 10705.5 10699.0 10694.5 10686.0 10682.5 10679.5 10678.0 10667.5 10663.0 10661.0 10654.5 10651.0 10646.0 106~0.0 10633.5 10630.0 10622.5 10617.0 10616.0 10609.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 16 10601.5 10602.0 10599.5 10599.0 10593.0 10593.5 10590.5 10590.5 10585.0 10583.5 10581.0 10581.5 10578.5 10578.0 10575.5 10577.0 10573.0 10573.0 10568.0 10569.0 10564.0 10563.5 10560.0 10561.5 10558.0 10558.0 10558.5 10554.0 10554.5 10552.5 10551.5 10549.0 10549.5 10546.5 10546.5 10544.0 10544.0 10543.5 10545.0 10541.0 10540.5 10537.5 10536.5 10535.0 10535.0 10534.0 10534.0 10532.5 10531.0 10530.0 10529.0 10527.0 10528.0 10525.0 10525.0 10522.0 10522.5 10519.5 10519.0 10519.0 10518.5 10515.0 10515.0 10514.0 10513.0 10511.5 10510.0 10508.5 10508.0 10508.0 10508.0 10503.0 10502.5 10502.5 10502.5 10501.0 10500.5 10497.5 10496.5 10496.0 10495.5 10492.5 10492.5 10492.0 10489.5 10489.5 10488.0 10488.0 10485.0 10485.5 10481.5 10482.5 10480.0 10480.5. 10476.5 10477.0 10474.5 10476.0 10473.5 10473.5 10470.5 10470.5 10467.0 10467.0 10464.0 10463.5 10461.0 10459.5 10459.0 10458.0 10457.5 10457.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 17 10456.0 10455.0 10453.0 10452.0 10448 0 10447 5 10445 0 10444 0 10440 0 10438 0 10434 0 10433 5 10431.0 10429.0 10426.5 10424.5 10422.0 10418.5 10415.0 10412.0 10410.0 10408.0 10407.5 10405.5 10401.0 10400.5 10398.5 10396.0 10392.0 10390.0 10388.0 10386.0 10385.0 10381.0 10379.0 10376.5 10375.5 10373.0 10370.0 10369.5 10368.0 10366.5 10365.5 10364.5 10360.0 10359.5 10354.5 10351.5 10350.5 10346.0 10342.0 10337.5 10337.0 10334.5 10334.0 10456.0 10454.0 10448.5 10444.5 10438.0 10434.5 10430.5 10422.0 10417.5 10413.5 10409.5 10407.5 10405.5 10402.5 10396.5 10392.5 10388.0 10386.0 10380.0 10377.5 10371.0 10368.0 10366.5 10361.0 10349.0 10347.0 10337.5 10335.0 10455.0 10452.5 10448.0 10445.5 10440.0 10433.5 10432.0 10426.0 10424.5 10422.0 10415.5 10408.5 10405.5 10402.0 10399.5 10396.5 10392.0 10390.5 10385.5 10380.0 10378.0 10374.0 10370.5 10367. 10364.0 10361.5 10353.5 10351.5 10347.0 10343.5 10339.5 10334.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 18 10327.0 10326.5 10323.5 10318.5 10315.5 10313.0 10311.5 10307.5 10305.5 10301.5 10298.0 10295.0 10292.5 10290.0 10289.5 10287.5 10284 5 10282 0 10281 0 10278 5 10278 0 10276 0 10274 5 10274 0 10270. 0 10268 5 10264.5 10263.5 10255. $ 10255.0 10253.5 100.0 $ 10329.0 10320.0 10311.0 10305.5 10304.0 10299.5 10294.0 10290.5 10288.0 10281.5 10278.0 10276.5 10274.0 10270.5 10268.5 10265.0 10263.0 10255.5 10253.5 100.0 10328.0 10323.5 10317.5 10314.0 10308.5 10295.5 10290.5 10285.0 10281.5 10278.0 10274.0 10255.0 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1I CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 19 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 NRATCNTG 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 CRATCNTG 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 NCNTCNTG CPS 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNTG CPS 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 CNTCCNTG CPS 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 CNECCNTG CPS 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1065831 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10805.000 NPHI. CNTG 18.011 ENPH. CNTG NRAT. CNTG 2.165 CRAT. CNTG 2.351 ENRA. CNTG FCNT. CNTG 860.112 CNTC. CNTG 2239.040 CFTC. CNTG CFEC. CNTG 795.272 GRCH. CNTG -999.250 TENS. CNTG DEPT. 10250.000 NPHI. CNTG 7.258 ENPH. CNTG NRAT. CNTG 1.598 CRAT. CNTG 1.516 ENRA.CNTG FCNT. CNI~ 2746.672 CNTC. CNTG 4137.966 CFTC. CNTG CFEC. CNTG 1993.149 GRCH. CNTG 50.438 TENS. CNTG 28.303 CPHI.CNTG 4.484 NCNT. CNTG 861.004 CNEC. CNTG 3785.000 CCL.CNTG 11.720 CPHI.CNTG 2.494 NCNT. CNTG 2854.031 CNEC. CNTG 3535.000 CCL.CNTG 20.373 2400.801 3565.919 0.018 5. 462 4171. 776 4970.509 -0.101 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 2O ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUF~ER : 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREFIENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFIBERS CNTG 1, 2, 3, $ REMARKS: TTHIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT 1065831 NPHI CNAV PU-S 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 NRATCNAV 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 CRATCNAV 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 CNTCCNAV CPS 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 CNECCNAV CPS 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 CFECCNAV CPS 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1065831 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10805.000 NPHI. CNAV 18.718 NRAT. CNAV 2.247 CPHI.CNAV CRAT. CNAV 2.397 ENPH. CNAV 29.265 ENRA. CNAV 4.584 NCNT. CNAV FCNT. CNAV 889.377 CNTC. CNAV 2298.078 CFTC. CNAV 895.217 CNEC. CNAV CFEC. CNAV 804.471 GRCH. CNTG -999.250 19.902 2478.851 3687.545 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 22 DEPT. 10249.000 NPHI.CNAV -999.250 NRAT. CNAV CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA. CNAV FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV CFEC. CNAV -999.250 GRCH. CNTG 54.156 -999. 250 CPHI. CNAV -999. 250 NCNT. CNAV -999 . 250 CNEC. CNAV -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NU~I~ER : 1 DEPTH INCREM~INT: 0.5000 FILE SUM~n~RY VENDOR TOOL CODE START DEPTH ........................... CNTG 10820.0 $ - LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 10245.5 08-0CT-97 CP 42.2 849 08-0CT-97 10978.0 9836.0 10250.0 10805.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 23 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~A RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : TOOL ArU?4~ER ........... SGC-SA-27 CN C- GA- 6 3 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) '. SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TI~4PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 11040.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): PUMPED IN DEAD CRUDE 20.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): EPIT~ERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): TIED INTO BHCS DATED 4/8/83 PUMPED 400 BBLS OF DEAD CRUDE INTO TUBING PRIOR TO LOGGING. MADE 3 PASSES WHILE PUMPING AT 1 BPM. FIELD PICK GOC AT 10673'. THIS FILE CONTAINS RAW PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELEM CODE (HEX) DEPT FT 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 TNRAPS1 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 ENRAPS1 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 RCENPS1 CPS 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1065831 00 000 O0 0 5 1 1 4 68 0000000000 RCFTPS1 CPS 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1065831 00 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1065831 00 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1065831 O0 000 00 0 5 1 1 4 . 68 0000000000 TENS PS1 LB 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1065831 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 25 DEPT. 10820.000 NPHI.PS1 TNRA.PS1 2.561 RTNR.PS1 CNEC. PS1 3920.819 RCEF. PS1 RCFT. PS1 645.286 CNTC. PS1 GR.PS1 26.984 TENS.PSI DEPT. 10245.500 NPHI.PS1 TNRA.PS1 1.743 RTNR.PS1 CNEC. PS1 4437.917 RCEF. PS1 RCFT. PS1 1903.970 CNTC. PS1 GR.PS1 50.281 TENS.PSi 21.201 ENPH. PS1 2.575 ENRA.PS1 734.848 RCEN. PS1 1681.884 CFTC.PSi 3795.000 CCL.PS1 9.871 ENPH. PS1 1.595 ENRA.PS1 1608.465 RCEN. PS1 3739.595 CFTC. PSi 3615.000 CCL.PS1 33.915 TNPH. PS1 5.053 CFEC. PS1 3422.256 RCNT. PS1 663.789 NPOR.PS1 0.025 12.350 TNPH. PS1 2.578 CFEC.PS1 3803.362 RCNT. PS1 2193.299 NPOR.PS1 -0.092 19.437 775.983 1649.469 20.379 8.552 1721.187 3934.569 7.791 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREFIENT: 0.5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH ........................... (INTG 10815.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH 10240.0 08-0CT-97 CP 42.2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 26 TIFIE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 849 08-0CT-97 10978.0 9836.0 10250.0 10805.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAIV~4A RAY CNTG COMPENSATED NUETRON $ TOOL NUI~I~ER SGC-SA-27 CNC-GA-63 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11040.0 BORE~OLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TI~4PERATURE (DEGF): BOTTOM HOLE TE~IPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WE~ (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : PUMPED IN DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (F~: BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): TIED INTO BHCS DATED 4/8/83 PUMPED 400 BBLS OF DEAD CRUDE INTO TUBING PRIOR TO LOGGING. MADE 3 PASSES WHILE PUMPING AT 1 BPM. FIELD PICK GOC AT 10673'. THIS FILE CONTAINS RAW PASS #2. LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE 27 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 13 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 ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD B73MB SAMP ELEM CODE (HEX) DEPT FT 1065831 O0 000 O0 0 6 i 1 4 68 0000000000 NPHI PS2 PU 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 RTNRPS2 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1065831 O0 000 O0 0 6 I 1 4 68 0000000000 RCEF PS2 CPS . 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 RCFTPS2 CPS 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1065831 O0 000 O0 0 6 i 1 4 68 0000000000 CFTC PS2 CPS 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1065831 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 28 ** DATA ** DEPT. 10815.500 NPHI.PS2 22.361 ENPH. PS2 32.261 TNPH. PS2 TNRA.PS2 2.629 RTNR.PS2 2.712 ENRA.PS2 4.890 CFEC. PS2 C1TEC. PS2 3835.903 RCEF. PS2 736.885 RCEN. PS2 3271.605 RCNT. PS2 RCFT. PS2 594.490 CNTC. PS2 1610.552 CFTC. PS2 627.849 NPOR.PS2 GR.PS2 25.078 TENS.PS2 3820.000 CCL.PS2 -0.083 DEPT. 10240.000 NPHI.PS2 7.764 ENPH. PS2 11.137 TNPH. PS2 TNRA.PS2 1.561 RTNR.PS2 1.564 ENRA.PS2 2.415 CFEC. PS2 CNEC. PS2 4755.844 RCEF. PS2 1935.225 RCEN. PS2 4013.479 RCNT. PS2 RCFT. PS2 2428.503 CNTC. PS2 4019.676 CFTC. PS2 2554.223 NPOR.PS2 GR.PS2 94.438 TENS.PS2 3480.000 CCL.PS2 0.130 19.877 784.427 1630.789 19.877 6.947 1969.416 4198.152 6.372 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUf4BER RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREFIENT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH CITTG 10820.0 10240.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 29 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 08-0CT-97 CP 42.2 849 08-0CT-97 10978.0 9836.0 10250.0 1O8O5.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED NUETRON $ SGC - SA - 27 CNC-GA- 6 3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 11040.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TE~4PERATURE (DEGF) : BOTTOM HOLE TI~4PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): ~S: TIED INTO BHCS DATED 4/8/83 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 3O PUMPED 400 BBLS OF DEAD CRUDE INTO TUBING PRIOR TO LOGGING. MADE 3 PASSES WHILE PUMPING AT 1 BPM. FIELD PICK GOC AT 10673'. THIS FILE CONTAINS RAW PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CPiAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 TNRAPS3 1065831 00 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 ENRAPS3 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 RCFTPS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-JAN-1998 14:22 PAGE: 31 ~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELE~ CODE (HEX) CFTC PS3 CPS 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1065831 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10820.000 NPHI.PS3 20.732 ENPH. PS3 31.021 TNPH. PS3 TNRA.PS3 2.531 RTNR.PS3 2.610 ENRA.PS3 4.765 CFEC.PS3 CNEC. PS3 3565.102 RCEF. PS3 702.783 RCEN. PS3 3040.642 RCNT. PS3 RCFT. PS3 591.510 CNTC. PS3 1541.190 CFTC. PS3 624.702 NPOR.PS3 GR.PS3 29.578 TENS.PS3 3155.000 CCL.PS3 0.018 18.511 748.125 1560.556 18.511 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/20 ORIGIN : FLIC TAPE NA~E : 98026 CONTINUATION # : 1 PREVIOUS TAPE : COMFIF2FT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 7-26, API# 50-029-20931-00 **** REEL TRAILER **** SERVICE NAFIE : EDIT DATE : 98/01/20 ORIGIN : FLIC REEL NAME : 98026 CONTINUATION # : PREVIOUS REEL : COMFIENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 7-26, API# 50-029-20931-00
