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Home My WebLink About203-028 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a 03 - o;tß Well History File Identifier Organizing (done) D Two-sided 11111111I1111111111 ~can Needed RESCAN ~Olor Items: o Greyscale Items: DIGITAL DATA ~kettes, No"~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: Helen C Maria) ~--" o Other:: 7 ~ Date:<f-:J-{ OS-Is! mP , I Project Proofing Scanning Preparation ~~ x 30 = of) "I) .~ + (p = T,'JTAL PAGES ~(p (Count doe~ not in("~ude cover sheet) 11\ A n Date: 4-, (9-1 O....S-/sl vvrr I Date: 4 J.1. os 151 BY: Hel~_ Maria) BY: Helenc-MariW BY: Production Scanning Stage 1 Page Count from Scanned File: 10 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,/ YES NO Date: if 8--9, "o!; 151 VVl,D NO H el erC,--M a ria ) _ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Helen Maria Date: Is I I I '"I II Date: Isl Quality Checked III II 1111111111111I Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~chl~m6er~er Alaska Da4a & Consulting Services 2525 Gambell Street, Suite 400 Anchorage,,4K 99503-2838 L-TTM: Beth ~t ~°~d~~i~ w 1 ~~ ~ .,. .~ ~ U+1 ~,.x 1l~ell Job # ~ • / Log Description N0. 5297 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnk~n 333 West 7th Ave, Suite 100 Anchorage,AK 99501 Date BL Color CD o~iosios Z-06 AYTO-00035 GLS/PRODUCTION PROFILE OS/12/09 1 1 07-336 B4C4-00003 SCMT 05/30/09 1 1 17-14 AVY5-00049 PRODUC ION PRO ILE t~_ 05/31/09 1 1 12-01 AYTU-00039 PRODUCTION PROFILE 06/01/09 1 1 04-43 AXWS-00011 IBP/CROSS FLOW CHECK - '~. 06/02/09 1 1 D-13A B04C-00059 USIT - 06/03/09 1 1 Z-112 62WY-00011 MEM PROD PROFlLE - O6/03/09 1 1 06-OS B04C-00061 USIT O6/04/09 1 1 12-18 AV1H-00014 PRODUCTION PROFILE O6/OM09 1 1 A-35 AY3J-00026 USIT a(p ~ O6/OM09 1 1 12-22 AXWS-00013 PROD PROFlGLS 06lOS/09 1 1 12-16A AXWS-00014 PRODUCTION PROFILE 06/05/09 1 1 18-298 604C-00062 PSP XY-CALIPER LOG 06/06/09 1 1 C-12A AXWS-00015 SCMT ~- ~ 06/O6/09 1 1 B-27A AXBD-00028 MEM PROD PROFILE 06/ii/09 1 1 L2-13A AWJI-00036 MEM CNL & INJ PROFILE " ~ 06/17/09 1 1 L2-13A AWJI-00036 MEM PROD PROFILE j O6/17/09 1 1 oa-at 6146-00064 LDL ^- ( 06/20/09 1 1 17-01A AYQQ-00030 SBHP SURVEY - O6/11/09 1 1 01-25 AP3Q-00041 LDL - 06/15/09 1 1 L-202 62WY-00010 MEM PROD PROFILE ~- C/ 06/02/09 1 1 L-103 AXBD-00027 MEM INJ PROFILE O6/04/09 1 1 GfVI-03 AWJI-00034 MEM PRESS & TEMP SURVEY ~~-.- 06/15/09 1 1 G-316 AWJI-00027 MCNL _~ 04/30/09 1 1 15-296PB1 09AKA0143 OH MWD/LWD EDIT ~ ~jf ~~ 05/11/09 2 1 e.... •.vr~~mvvr~~v~a~ nca.ur ~ o~ .71VIY117V MIYU ~7C1 UI'f1V11VU1 VIYC I.VYT CAI,I'1 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~~ : _~ ~, ; -° __ __.~- r_~ ~ i .,.~ ~ ~ . ... -_._. ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • -~.. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE F:\LaserFicheiCvrPgs_InsertslMicrofilm_Marker.doc STATE OF ALASKA 1Ft J/J/o~ ALAS41L AND GAS CONSERVATION ceMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 181 Repair Well 181 Pull Tubing 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 63' 8. Property Designation: ADL 028334 11. Present well condition summary Total depth: measured 12270 true vertical 9037 Effective depth: measured 12269 true vertical 9037 Casing Length Structural Conductor 110' Surface 2682' Intermediate 6874' Production Liner 6501' Liner 3239' Perforation Depth MD (ft): Perforation Depth TVD (ft): rVEr) o ~~ ZOOS o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 203-028 6. API Number: 50-029-20476-01-00 9. Well Name and Number: PBU 17-01A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 110' 110' 1530 520 13-3/8" 2682' 2682' 4930 2670 9-5/8" 6874' 6730' 8150 5080 7" 9175' 8876' 7240 5410 4-1/2" 9030' - 12269' 8752' - 9037' 8430 7500 (\ E) Slotted Section: 9174' - 12227' 8874' - 9038' Tubing Size (size, grade, and measured depth): 4-1/2",12.6# 13Cr80 9035' 7" x 4-1/2" Baker 'S-3' Packer; Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer 8975' 8814' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Surface to 2686' RBDMS B~' . .. r ~ MA Y {).1 2006 Treatment description including volumes used and final pressure: Ran 7" Tieback to correct OA leak. Cemented to surface w/ 73.8 bbls Class 'G' Gasblok (354 sx). 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL t at the oregolng IS true and correct to the best 0 my now edge. Sundry Number or NIA if C.O. Exempt Matt Martyn, 564-4101 306-071 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl 249 375 Representative Dail Gas-Mcf 576 618 Avera e Production or Injection Data Water-Bbl Casin Pressure 2146 3180 Tubin Pressure o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 17. I Printed Name Terrie Hubble Signature Form 10-404 Revised 04/2004 Title Technical Assistant Phone Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 OR\G\NAL Well: Field: API: Perm it: e e 17-01A Prudhoe Bay Unit 50-029-20476-01-00 203-028 Accept: Spud: Release: Rig: 03/20/06 N/A 03/26/06 Nabors 7ES PRE-RIG WORK 02/21/06 SET 4-1/2" HES FASDRILL PLUG AT 8984'. PLUG PRESSURE TESTED UP TO 2000 PSI BY LRS. PLUG PASSED PT. JET CUT TUBING AT 8922' USING 3.65" POWER CUTTER. JOB COMPLETE. TURNED WELL OVER TO DSO. LEFT WELL SHUT IN. 02/26/06 CTM : T/I/0=550/560/390 TEMP=SI CIRC-OUT TXIA, FREEZE PROTECT TXIA, CMIT TXIA AT 3500 PSI. FAILED, UNABLE TO ESTABLISH LLR AMT. TOO SMALL. MIT OA AT 2000 PSI. PASSED (PRE-RWO) PUMPED 3 BBLS METH AND 40 BBLS 180°F DIESEL INTO FLOW LINE TO WARM IT UP. PUMPED 5 BBLS METH AND 603 BBLS 2% KCL WATER INTO TBG W/ RETURNS FROM IA TO FLOWLINE. PUMPED 171 BBLS 100°F DIESEL INTO IA THEN U-TUBE FOR FREEZE PROTECT. WING VALVE LEAKING-BY. CLOSED GROVE VALVE FOR CMIT TEST. FREEZE PROTECT FLOWLINE W/5 BBLS METH AND 41 BBLS 100°F DIESEL. CMIT T X IA - PUMPED 7 BBLS DIESEL TO 3500 PSI. FIRST TEST TBG AND IA LOST 360 PSI IN 15 MINUTES. SECOND TEST TBG AND IA LOST 400 PSI IN 15 MINUTES. BLED TBG AND IA PRESSURE TO 0 PSI. MIT OA - PUMPED 6.2 BBLS DIESEL TO 2000 PSI. OA LOST 50 PSI IN 1ST 15 MINUTES. OA LOST 10 PSI 2ND 15 MINUTES. FOR A TOTAL OF 60 PSI IN 30 MINUTES. BLED OA PRESSURE TO 500 PSI. FINAL WHP'S= 0/0/500. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-01 17-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 3/18/2006 3/26/2006 Spud Date: 6/10/1980 End: 3/26/2006 3/18/2006 15:00 - 00:00 9.00 MOB P PRE Rig down Top Drive and rig floor. String up bridle lines to blocks to lower derrick. Rig down pit module and disconnect from sub base. Blow down lines on Kuskokwim camp. Split camp and move to Drill Site 17-01A. 3/19/2006 00:00 - 11 :00 11.00 MOB P PRE Move satellite camp, pits, and truck shop from Pt. Mcintyre 2-18 to Drill Site 17-01. Lower mast at 03:00 hrs. Pull rig to edge of PM 2 at 04:00 hrs. to clear Nordic 1. Prepare rig to move to DS 17-01. 11 :00 - 00:00 13.00 MOB P PRE Move rig from Pt. Mcintyre 2-18 to DS-17-01. Arrive at Sag River Ice Rd at midnite. 3/20/2006 00:00 - 02:00 2.00 MOB I: PRE Continue rig move from Pt. Mcintyre 2-18 to DS 17-01. Pull rig on location at 02:00. 02:00 - 04:00 2.00 MOB PRE Place 1 layer of mats. 04:00 - 07:00 3.00 MOB P PRE Raise derrick, move in, spot and level sub base over well 17-01. Verify footprint of rig and back rig off to construct elevated mat layer to accomodate height of well head currently on well and additional flange to be installed during workover. Accept rig at 07:00. 07:00 - 11 :30 4.50 RIGU P DECOMP Build 3 additional layers of mat boards to elevate rig to match wellhead height. Place a totall of 44 mats unders substructure. 4 layers w/11 mats per layer. Place herculite. 11 :30 - 12:00 0.50 RIGU P DECOMP Hold night tour PJSM/pre-spud meeting w/WSL, toolpusher, hands, service company representatives. Discuss well plan. Discuss day plan forward. 12:00 - 14:00 2.00 RIGU P DECOMP Move rig up on elevated mat structure and re-spot over wellhead. Construct plywood cellar enclosure. 14:00 - 15:00 1.00 RIGU P DECOMP Layout single layer of mat boards to accomodate pits and move pit module in place and verify footprint of pit module. Move module out to place mat board structure to elevate pits to substructure level. Place a total of 38 mats under pit module. Place 4 layers. 11 mats in bottom layer w/9 mats per layer top three layers. 15:00 - 18:00 3.00 RIGU P DECOMP Move pit module back on elevated mat board structure and hook up pits to substructure. 18:00 - 20:00 2.00 RIGU P DECOMP RU utilities and high pressure lines to pits. 20:00 - 23:30 3.50 RIGU P DECOMP RU on tree to circulate diesel freeze protection out of well. Take on seawater and check out pits. 23:30 - 00:00 0.50 RIGU P DECOMP Hold day tour PJSM/pre-spud meeting w/WSL, toolpusher, hands, service company representatives. Discuss well plan. Discuss day plan forward. 3/21/2006 00:00 - 00:30 0.50 WHSUR P DECOMP Rig up Drill Site Maintenance lubricator. Pull back pressure valve. RD Drill Site Maintenance. 00:30 - 04:30 4.00 WHSUR P DECOMP Reverse circulate diesel freeze protection out of tubing direct to cuttings box w/120 deg. seawater. 2 bpm at 400 psi. 04:30 - 05:00 0.50 WHSUR P DECOMP Pump seawater to circulate diesel freeze protection out of annulus direct to cuttings box. Circulated 400 bbls of 120 deg. seawater until clean seawater at surface. 3 bpm at 250 psi. 03:30 - 05:00 1.50 WHSUR P DECOMP RU and have FMC install 5.5" ISA BPV and test to 1000 psi by pressuring down annulus. 05:00 - 07:00 2.00 BOPSU P DECOMP ND tree and DSA adaptor flange. Install FMC LH thread "Blanking Plug" w/ball valve to hold pressure f/above and place Printed: 3/27/2006 10:56:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-01 17-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/18/2006 Rig Release: 3/26/2006 Rig Number: Spud Date: 6/10/1980 End: 3/26/2006 DECOMP I above BPV which holds pressure from below. Note: This I arrangement required on all FMC 5.5" ISA type profiles. . Verify thread type on hanger w/FMC = 4" Acme. Threads in i good shape. 07:00 - 09:00 2.00 I BOPSU DECOMP I NU BOPs. Add length to bell nipple. Install air boot flange on 1.50 I BOPSU top of annular. 09:00 - 10:30 DECOMP ¡Install bell nipple. RU to test BOP. Fill lines w/water. 10:30 - 14:00 3.50 I BOPSU DECOMP Pressure test BOP. 250 psi low side. 3500 psi high side. Chart and put in well file. AOGCC representative John Crisp I I waived his attendance to test. Test witnessed by Jim Davidson 0.50 I BOPSU P Nabors Tool Pusher and Duncan Ferguson BP WSL. 14:00 - 14:30 DECOMP Rig down BOP test and BD lines. 14:30 - 16:00 1.50 I BOPSU P DECOMP Slip and cut 300' of drilling line. Inspect and adjust brakes. 16:00 - 16:30 0.50 BOPSU~ P DECOMP Service rig and top drive. 16:30 - 18:00 1.50 BOPSU P DECOMP RU DSM to pull Back Pressure Valve. RD DSM. 18:00 - 20:00 2.00 WHSUR P DECOMP MU landing jt. 5.5" Acme thread. Back out lock down screws. !p PU 130K and pull to RKB. LD hanger and landing it. 20:00 - 21 :00 1.00 PULL DECOMP Circulate bottoms up at 6.5 bpm/650 psi. 21 :00 - 22:00 1.00 PULL lp DECOMP Check threads and x-overs. VAM ACE. MU VAM ACE to IF XO to TIW valve and lay back on floor. 22:00 - 00:00 2.00 PULL ¡p DECOMP Pull, number, and LD 38 its. 4.5" 13 Cr. tubing. Tubing is in I good shape. 3/22/2006 00:00 - 07:00 7.00 PULL Ip DECOMP Pull, number, and lay down its. 39 to 207 4.5" 13Cr. Tubing in I i good shape. Lay down 6 gas lift mandrels and 1 X-nipple. Lay Ip down stub w/length 20.41'. 07:00 - 08:00 1.00 PULL DECOMP RD tubing handling equipment. Changeout bails. 08:00 - 12:30 4.50 CASE Ip TIEB1 MU running tool for Halliburton RBP and single in with drill pipe Ip from pipeshed. 12:30 - 13:30 1.00 CASE TIEB1 Run and set HES 7" 26# RBP w/element at 2773' and top of I fishneck at 2769'. Set back one stand in derrick. Pressure test RBP to 1000 psi. Bleed off and blow down. 13:30 - 14:30 1.00 CASE P TIEB1 Dump 700 # of 20/40 sand slowly down tubing w/water hose running down tubing. Pump drill pipe volume to clear sand f/drill pipe and POH to let sand fall on RBP. 14:30 - 16:00 1.50 CASE P TIEB1 POH w/HES bridge plug running tool and LD. Seawater in lout 8.5 ppg 16:00 - 18:00 2.00 BOPSU P TIEB1 Drain stack and pull wear bushing. MU test plug and test lower pipe rams to 250 psi low and 3500 psi high and record on chart. Reinstall wear bushing. 18:00 - 18:30 0.50 CASE P TIEB1 Service rig and topdrive. 18:30 - 19:00 0.50 CASE P TIEB1 MU Baker 7.5" OD liner top extension sleeve polishing mill w/brass cleanout depth indicators and 9-5/8" scraper. 19:00 - 21 :00 2.00 CASE P TIEB1 RIH w/polishing BHA 21 :00 - 22:00 1.00 CASE P TIEB1 Break circulation at 5 bpm, 130 psi. Continue RIH pumping at same rate and rotating polish mill 20 rpm into tieback extension sleeve. Locate in bottom of extension sleeve at 2680'. 22:00 - 23:00 1.00 CASE P TIEB1 Circulate surface to surface w/26 bbl. hi vis sweep w/3lb./bbl. Duo-Vis. Pump 435 gpm, 470 psi. Saw no sand or debris at surface. 23:00 - 00:00 1.00 CASE P TIEB1 Blow down topdrive and POH w/scraper/polish mill assembly. Seawater in lout 8.5 ppg 3/23/2006 00:00 - 01 :30 1.50 CASE P TIEB1 Continue POH w/scraper/polish mill assembly. Brass on Printed: 3/27/2006 10:56:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-01 17-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/18/2006 Rig Release: 3/26/2006 Rig Number: Spud Date: 6/10/1980 End: 3/26/2006 3/23/2006 00:00 - 01 :30 1.50 CASE P TIEB1 I cleanout assembly indicated polish mill had been to bottom of extension sleeve during cleanout. 01 :30 - 02:30 1.00 CASE P TIEB1 RU compensator and casing running equipment for TCII f premium thread casing. Makeup w/optimum torque value for 7" I TCII of 10,100 ft. Ibs. w/Jet Lube Seal Guard on connections. 02:30 - 07:00 4.50 CASE P TIEB1 RIH w/7" 26#/ft. L-80 TCII and tieback assembly consisting of 7" X 6' BTC-M Baker tieback stem, 7" BTC-M pup jt., 7" BTC-M TAM Port Collar, 7" TCII Box X 7" BTC pup jt., and 7" TCII to I surface. Stop just above liner top w/tie back stem. 07:00 - 08:00 1.00 CASE P TIEB1 RU to circulate and pump minimum pump rate while moving slowly into tie back extension sleeve. See pressure increase I and slack off 6' until tieback stem bottoms out at 2686.01' RKB. Pressure test to 1000 psi to verify sting in. 08:00 - 08:30 0.50 CASE P TIEB1 Drain BOP stack and ND. 08:30 - 10:00 1.50 CASE P TIEB1 MU emergency slip assembly and land 7" casing w/65K on 2.5<1 BOPSU~P slips. Cut casing off w/Wachs cutter. Casing stub 35.66'. 10:00 - 12:30 TIEB1 NU 13-5/8" X 13-5/8" tubing spool and 7" packoff. Test pack off to 3500 psi. NU BOP. 12:30 - 13:00 0.50 BOPSU P TIEB1 MU test equipment, install test plug and test BOP flange to 3500 psi. 13:00 - 13:30 0.50 BOPsu1 P TIEB1 Install wear bushing. 13:30 - 14:00 0.50 CASE P TIEB1 RU TAM combo port collar operating tool and MU to XO. 14:00 - 16:00 2.00 CASE P TIEB1 RIH w/port collar operating tool to 2650'. 16:00 - 16:30 0.50 CASE P TIEB1 MU TIW valves and pump in sub. Engage port collar at 2668' and actuate. Up wt. 75, SO wt 70. 16:30 - 17:00 0.50 CASE P TIEB1 Establish circulation through TAM port collar, 5 bpm, 330 psi. 17:00 - 18:00 1.00 CASE P TIEB1 RU Schlumberger. PJSM w/Schlumberger, all hands, toolpusher, WSL. Pump 5 bbls water. Pressure test lines to 4K psi. Pump 5 bbl water ahead, 74 bbls. 15.8 ppg G cement w/Gasblok. Schl pump 5 bbl water & rig displace w/19 bbls of seawater (leaving 2 bbls cement in drill pipe). Displace cement w/final pressure of 1250 psi. Close port collar by picking up 20K# and pressure test down drill pipe to collar w/2000 psi. Port collar closed. Rotate right w/slight upstrain and attempt to pull out. Did not release. Slack off slightly, test to 2000 psi OK and rotate again while picking up. Tool released. Test to 2000 psi to verify collar closed. CIP @ 18:00 hrs. Approximately 5 bbls. cement back to surface. Perform multiple flow checks to ensure Port collar closed at all times. 18:00 - 18:30 0.50 CASE P TIEB1 Pressure up on TAM port collar and blow TAM combo tool choke port open at 1900 psi. Flow check OK. CBU 5 bpm, 570 psi. Circulate 2.5 bbls. cement to surface. Flow check OK. Add retarder at flowline and send direct to cuttings box. 18:30 - 19:00 0.50 CASE P TIEB1 LD TIW valve, pups, and pump in sub. 19:00 - 00:00 5.00 CASE P TIEB1 RU Hot Oil and circulate heated brine at 120 deg. F. Temperature at 00:00 hrs. = 120 deg. F. in and 80 deg F. out of the well. Note CBU w/ rig while RU Hot Oil. No cement in seawater. Flow check OK. 3/24/2006 00:00 - 00:30 0.50 CASE P TIEB1 Circulate w/Hot Oil to keep seawater 120 deg F. going in and out of wellbore at 80 deg F. to facilitate cement curing in 7" X 9-5/8" tie back annulus. 00:30 - 02:00 1.50 CASE P TIEB1 POH wIT AM port collar combo tool. LD TAM tool and clear floor. Seawater 8.5 ppg in / out. Bottom cup inverted. Printed: 3/27/2006 10:56:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-01 17-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/18/2006 Rig Release: 3/26/2006 Rig Number: Spud Date: 6/10/1980 End: 3/26/2006 3/24/2006 02:00 - 02:30 I 0.50 CASE P TIEB1 RU and test 7" tie back casing from 7" HES RBP at 2744' to surface. Test to 3500 psi for 30 minutes and chart. 02:30 - 03:30 1.00 CASE P TIEB1 Cut and slip 300' of drilling line. Service top drive and rig. 03:30 - 05:30 2.00 DHB P TIEB1 MU HES retrievable bridge plug retrieving tool. RIH same to 2743'. Circ sand out of hole with back to back hi vis sweeps I down to RBP @ 2773'. Recover large amount of sand at I surface, suspect 100% recovery. Latch RBP & unseat same. 05:30 - 07:00 1.50 DHB P TIEB1 I POH and LD HES 3L RBP and running tool. 07:00 - 08:00 1.00 DHB P TIEB1 RU to run 2-7/8" PAC drill pipe. Clean rig floor. 08:00 - 10:00 2.00 DHB P TIEB1 PU Fasdril milling BHA. PU and RIH w/8 jts. of 2-7/8" PAC. I PU and RIH w/9 jts. of 4.75" drill collars. 10:00 - 17:00 7.00 DRILL P TIEB1 PU 4" HT-40 drill pipe and RIH to 8978'. No problems entering in tubing stub. 17:00 - 18:00 1.00 DRILL P TIEB1 Drill up Fast Drill bridge plug f/8978 to 8987'. Tq. on 5K, tq. off 3K, 215 gpm, 920 psi. Up wt. 175K, SO wt 160K, 100 rpm, 18:00 - 18:30 0.50 DRILL P TIEB1 I Rot. wt. 170K. i Wash down f/8987' to 9100'. Well taking fluid. 160 bbls in 1/2 Ihr. 18:30 - 19:00 0.50 DRILL P TIEB1 I Circulate 153 bbls, 218 gpm, 1050 psi. Losing 110 bbls./hr. 19:00 - 22:00 3.00 DRILL P TIEB1 POH f/91 00' to 560'. Brine wt. = 8.5 ppg. Function test rams when out of hole. 60 bbls/hr. static losses. 22:00 - 00:00 2.00 DRILL P TIEB1 LD BHA #1. Note: Fluid loss since milling up Fast Drill = 665 bbls. 3/25/2006 00:00 - 01 :00 1.00 RUNCO RUNCMP Phase change point in workover program from tie back to completion w/mechanical downhole barriers removed. I Conducted safety meeting and BOP drill. All hands, I tourpusher, contractors, RGL hand, WSL. Held meeting at the manifold/choke control panel. Asked well control questions. Each hand participated and instructed or questioned the I process. Goal of the meeting was to review well control and BOP functions w/all to ensure that every hand on tour understands well control process and procedures and that each is capable of shutting well in should emergency occur. 01 :00 - 03:00 2.00 RUNCO RUNCMP PU tubing stub dressing BHA # 2 consisting of: 6-1/8" OD X 4.25" ID washover superloy equipped shoe, two 5' X 5-3/4" washpipe extensions, 4-3/4" X 3-7/8" intemal dress mill for tubing stub, drive sub, boot basket, double pin sub, 4-3/4" boot basket, 7" casing scraper, bit sub, lubr. bumper sub, oil jars, nine 4-3/4" drill collars, XO to HT-40 drill pipe. 03:00 - 06:00 3.00 RUNCMP RIH to 8900' w/dress mill BHA #2. 06:00 - 07:30 1.50 RUNCMP Circulate and rotate w/tubing dress mill down over top of tubing at 8922' w/washpipe and continue down to 8934'. Pump 50 bbl. (200 vis) hi-vis sweep around and see a 3X increase in metal cuttings from tubing, scale, and some sand. 07:30 - 13:30 6.00 RUNCMP POH w/drill pipe laying down 282 singles. MW = 8.5 ppg seawater. 13:30 - 15:30 2.00 RUNCO RUNCMP LD tubing dress mill BHA #2. 15:30 - 17:30 2.00 BOPSU RUNCMP Pull wear bushing. Make dummy run w/hanger. RU compensator, torque turn equipment, and tubing tongs to run 4.5" 12.60# 13Cr VAM TOP tubing. PJSM w/all hands, service contractors, tour pusher, and WSL. 17:30 - 00:00 6.50 BOPSU P RUNCMP RIH w/4.5" 12.60# 13 Cr VAM TOP tubing f/jt 1 to jt. 90. Min. Printed: 3/27/2006 10:56:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-01 17-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES 3/26/2006 00:00 - 07:00 07:00 - 08:30 08:30 - .10:00 10:00 - 11 :30 1.50 1.50 11 :30 - 12:30 12:30 - 13:30 13:30 - 15:30 15:30 - 17:00 17:00 - 18:00 18:00 - 21 :00 1.00 WHSUR P 3.00 WHSUR P 21 :00 - 22:30 1.50 WHSUR P 22:30 - 00:00 1.50 WHSUR P Start: 3/18/2006 Rig Release: 3/26/2006 Rig Number: Spud Date: 6/10/1980 End: 3/26/2006 RUNCMP tq. = 4000 ft. Ibs, optimimum tq. 4800 ft. Ibs. I Note: Lost 1034 bbls. seawater to well in last 24 hr. period. RUNCMP RIH w/4.5" 12.60# 13 Cr VAM TOP tubing jt # to jt # 206. Min. tq. = 4000 ft. Ibs, optimimum tq. = 4400 ft. Ibs., maximum tq. = 4800 ft. Ibs. RUNCMP I Tag up on tubing stub at 8924'. Rotate string 1 turn and drop lover stub to 8928'. Saw the overshot shear pins go with 8K Ibs. Spaceout w/overshot at 8931' utillizing 3 pup jts. MU tubing hanger, land string w/140K on hanger. RUNCMP Reverse circ inhibited seawater @ 3 BPM - 500 psi. RUNCMP Drop ball and rod down tubing. Pressure up to 2800 psi to set I Baker S-3 production packer. Continue to pressure up to 3500 I psi and record 30 min. tubing test on chart. Bleed tubing from 3500 psi to 1500 psi and shut in. Pressure 4-1/2" x 7-5/8" annulus to 3500 psi and record 30 min. annulus test on chart. RUNCMP Bleed annulus pressure to 0 psi then bleed tubing pressure to 0 psi. Pressured annulus to 2600 psi and the DCK valve in GLM # 5 sheared out. Pumped 2 bbls seawater each way throuh valve to confirm shear out of DCK. RUNCMP Install TWC in tubing hanger. Test to 1000 from below. RUNCMP Nipple down BOP. RUNCMP Nipple up adaptor flange and 4 1/16" tree. Test pack-off and tree. RUNCMP Rig up Drill Site Maintainence (DSM) lubricator and pull TWC. RUNCMP Rig up lines to freeze protect. Rig up Little Red hot oil unit and test lines to 3000 psi. Pump 75 bbl 80 deg F diesel down 4 1/2" x 7" IA. Allow diesel to 'U' tube. RUNCMP Rig up DSM lubricator and install BPV. Test with Little Red unit to 1000 psi from below. Rig down hot oil unit. RUNCMP Secure well, blow down lines, empty and clean pits and prepare for move. Rig released at 00:00 hrs. Printed: 3/27/2006 10:56:40 AM AlASKA. OIL A1Q) GAS CONSERVATION COMMISSION Dave Wesley Senior Drilling Engineer SP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ) ¡~J..... 1: !f0 !-: I~ ((ù :·Vl1Ã I J J JÙ _:c1 Lh\ QÙ J~ Ir\ / / / ) (,.~,'(~, '?,. ~,. "'hÃ~~l, ¡ !,Þ ro) I"'~~ l· ,~ \-",-, '""~ ~.,. ,,' .~~:;;:~~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276·7542 'Â" ' 0 '}QJ 'DJ ~ Re: Prudhoe Bay 17-0 1A Sundry Number: 306-07!~Çt'NNEf' FEB 7¿i .f:; 200& Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed fonn. 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, hairman DATED thisfl;ay of Februmy, 2006 Encl. ¡.Jc;lt-- "¿ /2 7/ ¿o ø {, C/(I} Z~ 2-7 ,1)þ ) STATE OF ALASKA /) \IS ' -yo 7/ b R ALASKA OIL AND GAS CONSERVATION COMMISSION ECEIVED APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 FEB 2 4 2006 AI.skl Oil & Gas Cons, Commi$S;o,ß o Other AnchoragR o Re-Enter Suspended Well o Time Extension 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate o Alter Casing /181 Repair Well 0 Plug Perforations 0 Stimulate o Change Approved Program 181 Pull Tubing 0 Perforate New Pool 0 Waiver 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current W~" C)9ss: B Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 203-028 / 6. API Number: 50-029-20476-01-00 ,. 99519-6612 63' 9. Well Name and Number: PBU 17-01A ./ 8. Property Designation: ADL 028334 10. Field / Pool(s): . Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12270 ,( 9037 None MD / TVD Burst Junk (measured): None Collapse 11. Total Depth MD (ft): 12270 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 9037 Length Size Liner 110' 20" 1101 110' 1530 520 2682' 13-3/8" 2682' 2682' 4930 2670 6874' 9-5/8" 6874' 6730' 8150 5080 6501' 7" 2674' - 91751 26741 - 8876' 7240 5410 3239' 4-1/2" 9030' - 12269' 8752' - 9037' 8430 7500 Perforation Depth MD (ft): Perforation DepthTVD (ft): Slotted Section: 9174' - 12227'/ 8874' - 9038' Packers and SSSV Type: 7" x 4-1/2" Baker '5-3' packer Tubing Size: 4-1/2", 12.6# / Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 8975' ,/ Tubing MD (ft): 9035' 12. Attachm ents: B Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: /' o Exploratory B Development 0 Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name D51ve Wesley', Title Senior Drilling Engineer Signature ÆíA¿ á"¿4j 1-..... i' ~ Phone 564-5153 Date Z/z. -slot;... Úi ' Commission Use Only Marc~~)006 Da'té: 15. Well Status after proposed work: BOil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Matt Martyn, 564-4101 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance I Sundry Number: 30 c, -07 I Other: T e-s. t DO t) E f-o ;C;OO f' ~ " RBDMS 8FL FEB 2 8 2006 SUbSeQUentFormR?JJqUI' . _ - Approved By: ~ ~ Form 10-403 Revised 5 ~ COMMISSIONER APPROVED BY THE COMMISSION Date t" Z:1- ,0;' OR\G\NAL Submit In Duplicate ) ) Well Status: DS 17-01A is a horizontal sidetrack, initially completed by slotted liner in the Sag, Shublik and Z4B in March, 2003. Currently, the well has IA x OA communication and needs gas lift to operate. 17-01A has been shut-in awaiting a rig-fix to the IAxOA /' communication. Project: DS 17-01A is currently completed conventionally with 4-1/2" 13-Cr tubing inside 9-5/8" casing with a 7" tieback liner to 2674' MD. The tubing will be cut and pulled above the existing packer. A 7" premium threaded tieback string will be run to surface and a /" packer set immediately above the existing tieback liner. New tubing will be run in the hole and stacked over the existing packer with an overshot. The new 13 Cr tubing string will be pressure tested in addition to the inner annµlus. The plug will be removed from the well bore and the well will be placed on production and tested. Pre-RWO 1. Check well head seals and lock down scre? 2. Set plug in tubing tail just below pack~r. 3. Cut 4-1/2" tubing above packer. /'~ 4. Circulate well clean and freeze protect with diesel. 5. Set BPV in tubing hanger 6. Remove well houses and flow lines. Prepare pad for rig. RWO 1. MIRU work over rig. 2. Pull BPV. Circulate out diesel freeze protect. Circulate to seawater (kill weight fluid). / 3. Install TWC and test. NO tree and tubing head adapter flange. 0 4. NU BOPE and test per BP and AOGCC regulations. Test the BOPE to 250 psi low and 3~~ ....- psi high. Test the annular to 250 psi low and 3500 psi high. Pull the TWC with lubricator 5. PU landing joint or spear and make-up into the tubing hanger. Pull and lay down the tubing hanger. 6. Pull and lay down the 4-Y2", 12.6 lb/ft, 13-Cr tubing down to the cut @ -8900 ft md. /' 7. RIH wI polish-mill to dress off seal receptacle at -2,674' md. /'" 8. RIH wI 7" tie-back string and sting into tie-back receptacle at - 2674' md., ) 9. Circulate diesel freeze protect in the 7"x9-5/8" annulus to -2500' TVO. SevJMZ?P per Baker procedure. Pressure test the 9-5/8"x7" annulus. / i ,--,/ 10. NO BOPE. Pull tension and set slips per FMC procedure. /' 11. Lift stack and cut 7" with Wachs cutter. Set back BOPE 12. Install 7" packoff. NU new tbg spool. Test packoff. 13. NU & Test BOPE. / 14. Pressure test 7" casing to 3500 psi for 30 minutes. 15. RIH and dress the tubing cut (internal and external) in preparation for UMI overshot. 16. RIH with OP and drill out tubing tail plug. / 17. Run 4-Y2", 12.6 #/ft, 13 Chrome premium thread tubing and overshot. Locate new tubing onto existing tubing stub. J' 18. Set the packer. Test the tubing and IA to 3500 psi for 30 minutes. 19. NO BOPE and NU adapter flange and tree. Test to 5000 psi. FP IA to -2200'. 20. ROMO. ) ) Post-RWO 1. Pull ball and rod from RHC sleeve. 2. Set gas lift valves. 3. Pull RHC sleeve. 4. Tie-in flow lines, replace well houses, and instrumentation. TREE = 5-1/8" 5M FMC \-. WELLHEAÐ= FMC 17-01A F _~posed RWO Com.)letion ACTUA TOR = AXLESON KB. ELEV = 70' BF. ELEV = KOP = 3500' Max Angle = 101 @ 9850' Datum MD = 9156' Datum lVD = 8800' SS DA TE REV BY COMMENTS DA TE REV BY 07/17/80 ORIGINAL COM PLETION 03/16/03 JDM/KK RIG SIDETRACK (17-01A) 04/28/03 A TD/TLH WAIVER SAFETY NOTE 04/20/04 ATD/KAK WAIVER SAFETY NOTE 09/26/05 EZL/TLH WAIVER SFTY NOTE DELErED 02/16/06 MJM Proposed RWO Completion 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2682' Minimum ID = 3.725" @ 9019' 4-1/2" HES XN NIPPLE PERFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: 36 @ 9174' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SLTD 9174-9493 0 03/15/03 SL TO 9616 - 12227 0 03/15/03 TOP OF WHIPSTOCK 1-1 6874' I EZSV 1-1 6897' 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9010' 7" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" 1-1 ~-I 9924' 9932' I . I 2102' 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 I 2668' 1-1 9-5/8" X 7" BKR JM-ZXP PKR I 2670' 1-1 7" TC-1I26# L-80, 10 = 6.125" -I 2674' l-i 9-5/8" X 7" BKR ZXP LNR TOP PKR GAS LIFT MANDRELS ST MD lVD DEV TYÆ LA TCH PORT DATE 5 3250 3250 1 KBG-2 4.5x 1" BK 4 5001 5000 6 KBG-2 4.5x1" BK 3 6252 6200 26 KBG-2 4.5x 1" BK 2 7533 7350 10 KBG-2 4.5x1" BK 1 8738 8500 31 KBG-2 4.5x1" BK g ~~ ~ ~~ - . L ~!~I II It . ' ~;', " .. SAFETY NOTES: ***4-1/2" CHROMETBG*** . . MILLOUT WINDOW 6874' - 6890' ~ 6698' 1-1 9-5/8" X 7" BKR ZXP LNR TOP PKR JfR5' M) 7" X 4-1/2"BKR S-3 PKR, 10 = 3.875" 1 I ~92~' l-i Tubing Cut wI Unique Overshot 1'/ ~_..> 8954' l-i 4-1/2" HES X NIP, 10 = 3.813" 1 I 8975' 1-1 7" X 4-1/2"BKR S-3 PKR, 10 = 3.875" I 8998' 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 I 9019' 1-1 4-1/2" HES XN NIP, 10 = 3.725" 1 I 9030' 1-1 7"X5" BKR ZXP LNR TOP PKR I I 9035' 1-1 4-1/2" WLEG, 10 = 3.958" ~ ~. .. '''' '''' ~G' 12.6", 13-CR-80, -1 .0152 bpf, 10 = 3.958" 7" LNR, 26#, L-80, .0365 bpf, 10 = 6.125" 1-1 9175' , @ , 9035' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 12269' 1 COMMENTS PRUDHOE BA Y UNIT W8...L: 17 -01 A ÆRMIT No: Jr2030280 API No: 50-029-20476-01 SEC 22, T10N, R15E BP Exploration (Alaska) TREE = 5-1/8" 5M FMC WELLHEP,o = FMC A CTUA TOR = AXLESON KB. ELEV = 70' BF. ELEV := KOP= Max Angle = Datum MD = Datum lVD = ) 17-01A ~ J 3500' 101 @ 9850' 9156' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2682' ~ / SAfE"r"YTES: ***4-1/2" CHROME TBG*** 26' l-i 5-1/2" X 4-1/2" XO, ID = 3.958" 1 2102' 1-1 4-112" HES X NIP, ID = 3.813" 1 2674' 1-1 9-5/8" X 7" BKR ZXP LNR TOP PKR GA S LIFT MA NDRELS ST MD lVD DEV TY PE VLV LA TCH PORT DATE Minimum ID = 3.725" @ 9019' L 6 3004 3004 1 KBG-2 DMY BK 0 03/21/03 4-1/2" HES XN NIPPLE 5 3786 3786 1 KBG-2 DOME BK 16 03/21/03 4 5912 5886 19 KBG-2 DOME BK 16 03/21/03 3 6610 6510 33 KBG-2 DMY BK 0 03/16/03 2 7894 7708 4 KBG-2 DOME BK 16 03/21/03 1 8886 8627 29 KBG-2 SO BK 24 03/21/03 ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: 36 @ 9174' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SL TD 9174 - 9493 0 03/15/03 SLTD 9616-12227 0 03/15/03 TOP OF WHIPSTOCK l-i 6874' I EZSV 1-1 6897' 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9010' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 1-1 ~-1 9924' 9932' ~ 6698' 1-1 9-5/8" X 7" BKR ZXP LNR TOP PKR MILLOUTWINDOW 6874' - 6890' 8922' 1-1 JET CUT (02/20/06) 1 8984' 1-1 FASDRILL (02/20/06) 1 8954' l-i 4-1/2" HES X NIP, ID = 3.813" 1 I 8975' 1-1 7" X 4-1/2"BKR S-3 PKR, 10 = 3.875" 1 8998' 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 9019' l-i 4-1/2" HES XN NIP, ID = 3.725" 1 9030' l-i 7"X5" BKR ZXP LNR TOP PKR 9035' 1-1 4-1/2" WLEG, ID = 3.958" ~ ''''' ''''' DA TE REV BY COMMENTS DA TE REV BY 07/17/80 ORIGINAL COM PLETION 03/16/03 JDM/KK RIG SIDETRACK (17-01A) 04/28/03 ATDITLH WANER SAFETY NOTE 04/20/04 A TD/KAK WA N ER SA FETY NOTE 09/26/05 EZLITLH WAIVER SFTY NOTE DB...ETED 02/20/06 GLSITLH JET CUT & FASDRILL SET ~G' 12B'. 13·CR·80, -i .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, .0365 bpf, 10 = 6.125" l-i 9175' 1 9035' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" l-i 12269' 1 COMMENTS PRUDHOE SA Y UNrr WB...L: 17-01 A ÆRMrr No: '2030280 API No: 50-029-20476-01 SEC 22, T10N, R15E BP Exploration (Alaska) e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 I?JÎ1~ RE: MWD Formation Evaluation Logs 17-01A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 17-01A: LAS Data & Digital Log hnages: 50-029-20476-01 ;¡D 3 --o;)-~ 1 CD Rom c ~ 111 9-rotl00 I ~ I1.p ÁQ Û 1 DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030280 MD ---------- ---------~--- Well Name/No. PRUDHOE BAY UNIT 17-01A Operator BP EXPLORATION (ALASKA) INC TIl~~ )fVlt~~) APr No. 50-029-20476-01-00 12270'-- TVD 9037 ,......,. Completion Date 3/16/2003....-A Completion Status 1-01L REQUIRED INFORMATION Samples No Mud Log Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, PWD Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ------ I i~ I.. c:_ ---= ! trEr D ~D D kD D ~pt l~~_ Log Log Run Scale Media No Directional Survey 11819 liS Verification <D {t. I ê'-i-l'tt,~ rZcJ J4 Directional Survey Directional Survey Directional Survey LIS Verification 4 4 Well Cores/Samples Information: Name Interval Start Stop Sent Current Status 1-01L UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH -' Received 6793 12270 Open 4/17/2003 6874 12199 Open 7/24/2003 6793 12270 Open 4/17/2003 MWD 6793 12270 Open 4/17/2003 6793 12270 Open 4/17/2003 MWD 6874 12199 Open 7/24/2003 --- Sample Set Number Comments Permit to Drill 2030280 MD 12270 TVD 9037 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ,~ Analysis ~ Received? -------~ -~------ Comments: -~------ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Well Name/No. PRUDHOE BAY UNIT 17-01A Operator BP EXPLORATION (ALASKA) INC Completion Date 3/16/2003 Completion Status 1-01L Daily History Received? Formation Tops tv Current Status 1-01L &YN (y)/N Date: API No. 50-029-20476-01-00 UIC N ~- ) r- 11 ^-iCH ~- ~- MEMORANDLII~ , State 01 r\\aska Alaska Oil and Gas Conservation Commission TO: Jim Regg 0"" 1[(1"o/05 DATE: November 24, 2003 P.I. Supervisor ~ót1 SUBJECT: Mechanical Integrity Tests BPX W-209 PBU FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well W-209 Type Inj. S T.V.D. 5068 Tubing 1780 1780 1780 1780 Interval I P.T.D. 203-128 Type test P Test psi 1267 Casing 1810 2520 2600 2620 P/F f Notes: New Well Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to BPXs W Pad and witnessed the initial MIT on well W -209. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then perfonned for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1 Attachments: Number of Failures: Q Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. MIT PBU W-209 11-24-03 CS.xls 11/26/2003 \ , ) dO 3 -Dd.-'ð 1)3tq WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 17-01A, 1 LDWG formatted Disc with verification listing. API#: 50-029-20476-01 June 02, 2003 AK -MW -2302699 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 f;~ECE'VED Date: JUL 24 2003 Signed: 2ß~ Alaska Of¡ & Gas Cons. ComnùS!ion (j l~nchorage BP Exploration (Alaska) Inc. Petro- T echnicalData Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 1. Status of Well ISI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2443' NSL, 523' EWL, SEC. 22, T10N, R15E,UM At top of productive interval 1226' NSL, 1053' EWL, SEC. 22, T10N, R15E,UM X = 709353, Y = 5926593 10. Well Number At total depth 369' SNL, 2807' EWL, SEC. 27, T10N, R15E,UM X = 711153, Y = 5925048 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 63' ADL 028334 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/1/2003 3/13/2003 3/16/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12270 9037 FT 12270 9037 FT ISI Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, PWD, RES 23. CASING SIZE 20" 13-3/8" 9-518" 7" 4-1/2" WT. PER FT. 94# 72# 47# 26# 12.6# ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 7. Permit Number 203-028 8. API Number 50-029-20476-01 9. Unit or Lease Name X = 708787, Y = 5927794 Prudhoe Bay Unit 17-01A 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2102' MD 1900' (Approx.) GRADE H-40 L-80 JL-95 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 32" Surface 2682' 17-1/2" Surface 6874' 12-1/4" 2674' 9175' 8-1/2" 9030' 12269' 6-1/8" AMOUNT PULLED CEMENTING RECORD 300 sx Permafrost 2400 sx Fondu, 400 sx Permafrost 500 sx Class 'G' 168 sx Class 'G', 423 sx Class 'G' Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section Flow Tubing Casing Pressure CALCULATED Press. 241 24-HoUR RATE 28. CORE DATA kJ-f'CIVCD Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core clii~ _....,.~...~¥'~.,.~~ i, LG'CAt~z: 1 'S" 1. .. ,. .~ -SIJ~.~,~~_~ ~~~;.~.) MD 9174' - 9493' 9616' - 12227' TVD 8874' - 9059' 9064' - 9038' 27. Date First Production March 31, 2003 Date of Test Hours Tested 4/25/2003 10.1 No core samples were taken. Form 10-407 Rev. 07-01-80 25. TUSING RECORD DEPTH SET (MD) 9035' SIZE 4-1/2", 12.6#, 13Cr80 PACKER SET (MD) 8975' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 150 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD OIL-BsL 1,776 OIL-BsL GAs-McF 2,205 GAs-McF WATER-BsL 2,575 WATER-BsL CHOKE SIZE 89.08° OIL GRAVITY-API (CORR) GAS-OIL RATIO 1,241 '-~~3 ¡ ._-21:2:-.:. APR 3 0 2003 Alaska Oil & Gas Cons Comm' . . ISSIon Anchorage RBDMs 8Fl ORIGINAL MAY 1 2003 I~I~ Submit In Duplicate 29. Geologic Markers Marker Name Measured Depth Sag River 9187' Shublik / A 9220' Shublik B 9237' Shublik C 92661 Sadlerochit I 46P 9325' 45N 99631 45P 11432' 31. List of Attachments: ) ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8886' 89131 8926' 8947' 8987' 90221 90401 RECEIVED APR 3 0 2003 Alaska Oil & Gas Cons ~., '. A . lPomm,ss,on nchorage Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble 4~ _ Hl ~ Title Technical Assistant Date 04· Á 9..03 17 -01 A 203-028 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Phil Smith, 564-4897 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 (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 ORiGINAL Legal Name: Common Name: Test Date 2/27/2003 3/8/2003 LOT FIT 1 7-01 17 -01 A Test Type Test Depth (TMD) 7,082.0 (ft) 9,175.0 (ft) BPEXPLORATION Leak-Off Test Summary Test Depth (TV D) 6,910.0 (ft) 8,876.0 (ft) AMW 9.20 (ppg) 8.60 (ppg) Surface Pressure Leak OffPrèssUre (BHP) 3,992 (psi) 4,615 (psi) EMW 11.12 (ppg) 10.01 (ppg) 690 (psi) 650 (psi) "-' "'-.-- Printed: 3/17/2003 9:25:23 AM ) ) BP EXPLORATION Operations Summary Report Page 1 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/22/2003 13:30 - 19:30 6.00 MOB P PRE Turnkey rig move. RDMO C 01A to center of Pad. 19:30 - 20:00 0.50 MOB P PRE Safety meeting wI all personnel for rig move. 20:00 - 00:00 4.00 MOB P PRE MIRU Nabors 2ES on DS 17-1A. 2/23/2003 00:00 - 16:00 16.00 MOB P PRE Turn key rig move. MIRU Nabors 2ES on DS 17-1A 16:00 - 17:00 1.00 KILL P DECOMP Pre spud meeting with all personel. Review 'Prespud Check list'. Post 'Permit to Drill' in dog house. 17:00 - 17:30 0.50 KILL P DECOMP Check WH pressures @ tbg 700 psi, IA 300 psi, OA 0 psi. Bleed dn pressure on tree I tbg to Opsi. 17:30 - 20:00 2.50 WHSUR P DECOMP RU DSM lubricator pull BPV. Re check WH pressures @ tbg 300 psi, IA 300 psi. Note: Master valve leaking, Swab valve packing & ACT valve packing leaking. Utilize ACT valve wI Master valve to secure well after BPV pulled. DSM grease all valves. RD DSM. Take on 900 bbls 9.2 ppg NaCI kill wt fluid. 20:00 - 21 :30 1.50 KILL P DECOMP RU surface circ lines to tree. RU secondary annulus valve. Test same. 21 :30 - 00:00 2.50 KILL P DECOMP Circ out diesel from tbg thru choke 2 BPM 330 psi, swap lines circ out diesel from IA thru choke @ 2 BPM 450 psi. By pass choke con't displace well wI 50 bbls 'Safe Kleen' & 9.2 ppg kill wt NaCI brine @ 4.5 BPM 385 psi. Observe well static. Load pipe shed wI 4" DP, SLM same. 2/24/2003 00:00 - 01 :30 1.50 KILL P DECOMP Con't displace well wI 50 bbls 'Safe Kleen' & 9.2 ppg kill wt NaCI brine @ 4.5 BPM 385 psi. 01 :30 - 02:00 0.50 KILL P DECOMP Observe well static. Blow dn surface circ lines. Dry rod BPV. Test from below 500 psi. O-K. 02:00 - 07:00 5.00 WHSUR P DECOMP ND tree and adapter flange. LD same. Install blanking plug in tbg hanger neck above BPV. Attempt to function LD screws. No movement on any of the LD screws. Mobilize 'Luckies' to attempt to lube and loosen screws and new set of LD screws. 07:00 - 18:00 11.00 WHSUR N SFAL DECOMP RU 'Luckies' on LD screws allow to soak I lube. Attempt to remove junk ring - No success. Remove 8 LD screws wI 48" pipe wrench & chain hoist. Chase out threads, replace same. 18:00 - 00:00 6.00 WHSUR N SFAL DECOMP RU Tuboscope 'Mag Drill' equipment. Drill out & replace LDS's. 2/25/2003 00:00 - 14:30 14.50 WHSUR N SFAL DECOMP Tuboscope drill out LDS's utilizing 'Mag Drill' equipment. RD Tuboscope equipment. Necessary to drill out a total of 6 LOS's out of 14. 14:30 - 17:00 2.50 WHSUR N SFAL DECOMP Complete chasing out threads in body of tbg spool. Complete installation of new LDS's I gland packing. FMC test 9 5/8" pack off 5000 psi. O-K. 17:00 - 17:30 0.50 BOPSUR N SFAL DECOMP Clear & clean cellar. 17:30 - 20:00 2.50 BOPSUR P DECOMP NU BOPE & riser. PU 5 1/2" test jt. 20:00 - 21 :30 1.50 BOPSUR P DECOMP Pressure test BOPE to BP & AOGCC regs. 250 psi low 13500 psi high. Chuck Scheve of AOGCC wavied witness of BOPE test. Upper pipe rams failed test. 21 :30 - 22:30 1.00 BOPSURP DECOMP Change upper 3 1/2" x 6" pipe rams to 4 1/2" x 7" rams. 22:30 - 23:00 0.50 BOPSURP DECOMP Pressure test upper pipe rams to BP & AOGCC regs. 250 psi low I 3500 psi high. 23:00 - 23:30 0.50 BOPSUR P DECOMP LD 5 1/2" test jt. 23:30 - 00:00 0.50 WHSUR P DECOMP MU 'Blanking plug' retrieving sub on 1 jt 4" DP. Flush out stack I top of 'Blanking plug'. MU & retrieve 'Blanking plug' from tbg hanger neck. LD same. 2/26/2003 00:00 - 01 :00 1.00 WHSUR P DECOMP RU DSM lubricator. Pull BPV. RD DSM. 01 :00 - 02:30 1.50 PULL P DECOMP MU Baker 5 1/2" tandem spear on 1 jt of 4" DP. Engage 5 1/2" tbg 5 ft below hanger. BOLDS. Unseat tbg hanger wI 85k over Printed: 3/17/2003 9:25:33 AM ) ) BP EXPLORATION Operations Summary Report Page 2 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Description of Operations 2/26/2003 01 :00 - 02:30 1.50 PULL P DECOMP pull. Flow check showing well static. Pull hanger to rig floor. P/U Wt 135k. Calculated P/U Wt 135k. LD spear & tbg hanger. 02:30 - 03:30 1.00 PULL P DECOMP Circ btms up @ 260 GPM 360 psi. RU floor for LD 51/2" tbg. RU Camco control line spooling equip. 03:30 - 05:30 2.00 PULL P DECOMP POH LD 5 1/2" tbg. Spooling 'Dual Encapsulated' control lines. Recover 2 x Camco flow coupling, Camco SSSV. 05:30 - 06:30 1.00 PULL P DECOMP LD Flow couplings & SSSV. RD Camco control line spooling equip. 06:30 - 15:00 8.50 PULL P DECOMP Con't POH LD 51/2" tbg. LD 2 Camco GLM's, Total 165 jts of 51/2" 17#, L 80, ABM 8rd tbg. 20 ft cut off jt. 25 SS bands. Note: No pup jts on GLM's 15:00 - 16:30 1.50 PULL P DECOMP Clean & clear rig floor. LD tbg handling equip. RU DP handling equip. 16:30 - 17:00 0.50 BOPSURP DECOMP PU test jt. Test lower pipe rams to BP & AOGCC regs. 250 psi low 13500 psi high. LD test jt. 17:00 - 17:30 0.50 BOPSUR P DECOMP Install wear bushing. 17:30 - 19:30 2.00 CLEAN P DECOMP MU & RIH wi 8" - 81/2" window mill assy on 1 jt 5" HWDP, bumper sub, FS, 9 ea 61/2" steel DC's, 22 jts 5" HWDP to 1,012 ft. 19:30 - 00:00 4.50 CLEAN P DECOMP Con't RIH wi 8" - 81/2" mill assy BHA on 4" DP from pipe shed to 6,927 ft. Pipe displacement showing well static. 2/27/2003 00:00 - 00:30 0.50 CLEAN P WEXIT Con't RIH wi 8 x 8 1/2" mill assy BHA on 4" DP from pipe shed. Tag tbg stump @ 7,082 ft. Pipe displacement showing well static. 00:30 - 01 :30 1.00 CLEAN P WEXIT Circ hole clean wi 25 bbls 90 deg 'Safe Kleen' sweep followed wi 90 deg 9.2 ppg. Chunks of asphaltines at surface on btms up. Pump rate 515 GPM 600 psi. P/U Wt 170k S/O Wt 165k. 01 :30 - 02:00 0.50 CLEAN P WEXIT Perform LOT wi 9.2 ppg brine, 690 psi surface pressure. EMW 11.1 ppg @ TVD of6,910 ft. 02:00 - 04:00 2.00 CLEAN P WEXIT POH wi 8" x 81/2" mill assy to BHA @ 1,012. Hole fill showing well static. 04:00 - 05:00 1.00 CLEAN P WEXIT Rack back BHA in derrick. LD & inspect mill assy. 05:00 - 10:30 5.50 TA P WEXIT RU Schl e - line unit. MU & RIH wi 9 5/8" EZSV. Correlate & set EZSV @ 6,892 ft wireline measurement. POH setting tool. RD Schl. 10:30 - 11 :00 0.50 EVAL P WEXIT Attempt to test 9 5/8" csg wi 9.2 ppg brine. Broke over @ 690 psi surface pressure. EMW 11.1 ppg. TVD 6,747 ft 11 :00 - 12:00 1.00 EVAL P WEXIT MU & RIH wi 9 5/8" RTTS on 5" HWDP to 691 ft. 12:00 -13:00 1.00 EVAL P WEXIT Con't RIH wi 9 5/8" RTTS to 2,714 ft on 4" DP. 13:00 - 14:00 1.00 EVAL P WEXIT Set RTTS. Test 9 5/8" csg 3500 psi I 30 mins. O-K. Unseat pkr. 14:00 -15:00 1.00 EVAL P WEXIT POH wi 9 5/8" RTTS to 5" HWDP @ 691 ft. 15:00 - 16:00 1.00 EVAL P WEXIT Con't POH wi pkr, racking back 5" HWDP. LD 9 5/8" RTTS. 16:00 - 19:30 3.50 STWHIP P WEXIT PU 9 5/8" whipstock assy BHA, orient UBHO & RIH to 1,071 ft. Shallow test MWD. 19:30 - 20:00 0.50 STWHIP P WEXIT Service Top Drive. 20:00 - 23:00 3.00 STWHIP P WEXIT Con't RIH wi 9 5/8" whipstock BHA to 6,768 ft on 4" DP @ controlled running speed. 23:00 - 23:30 0.50 STWHIP P WEXIT Orient 9 5/8" whipstock to 85 degrees right of high side. P/U Wt 170k, S/O Wt 165k. Trip btm anchor wi 20k on 9 5/8" EZSV @ 6,897 ft (Drillers tally). Confirm orientation @ 85 degrees RHS. Shear off whipstock wi 45k dn wt. 23:30 - 00:00 0.50 STWHIP P WEXIT Displace well wi 50 bbl 9.6 ppg spacer & 10 ppg LSND mud. 546 GPM 1882 psi. Printed: 3/17/2003 9:25:33 AM ) ) BP EXPLORATION Page 3 of13 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES -To HoÙrs Task Code NPT Phase 2/28/2003 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 14:30 14.00 STWHIP P WEXIT 14:30 - 15:30 1.00 STWHIP P WEXIT 15:30 - 16:00 0.50 STWHIP P WEXIT 16:00 - 17:00 1.00 STWHIP P WEXIT 17:00 - 17:30 0.50 STWHIP P WEXIT 17:30 - 19:30 2.00 STWHIP P WEXIT 19:30 - 20:30 1.00 STWHIP P WEXIT 20:30 - 21 :00 0.50 STWHIP P WEXIT 21 :00 - 22:00 1.00 STWHIP P WEXIT 22:00 - 00:00 2.00 DRILL P INT1 3/1/2003 00:00 - 00:30 0.50 DRILL P INT1 00:30 - 01 :00 0.50 DRILL P INT1 01 :00 - 02:30 1.50 DRILL P INT1 02:30 - 04:00 1.50 DRILL P INT1 04:00 - 04:30 0.50 DRILL P INT1 04:30 - 05:00 0.50 DRILL P INT1 05:00 - 00:00 19.00 DRILL P INT1 3/2/2003 00:00 - 20:30 20.50 DRILL P INT1 20:30 - 21 :00 0.50 DRILL P INT1 21 :00 - 22:00 1.00 DRILL P INT1 22:00 - 23:00 1.00 DRILL P INT1 Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Description of Operations Fin displace well to 10 ppg LSND mud. 546 GPM 1882 psi. Establish baseline parameters. SPR's wI both pumps. Mill window 6,874 ft to 6,910 ft. 500 GPM 1655 psi. 90 RPM, TO 5 -10 K. P/U Wt 170k, S/O Wt 165k Rot Wt 170k WOM 2 - 30k Circ hi-vis sweep. 550 GPM 1700 psi. Work thru window. No problems. Observe well static. Pump dry job. POH wI milling assy to 6,460 ft. Slip & cut drlg line. Service Top Drive & check crown. POH wI 8" x 8 1/2" milling assy to BHA @ 1,048 ft Con't POH wI mills. Rack back 5" HWDP, LD steel DC's, MWD & mills. Check upper mill full gauge. Clear & clean rig floor. Pull wear bushing. Flush stack. Run wear bushing PU & RIH wI 8 1/2" S 88 bit on directional BHA. Shallow test same. Con't RIH wI 8 1/2" bit on 4" DP from pipe shed to 1,522 ft. Shallow pluse test MWD @ 444 GPM 900 psi Con't RIH wI 8 1/2" bit on 4" DP from pipe shed to 3,327 ft. Con't RIH wI 8 1/2" bit on 4" DP from derrick to 6,783 ft. Install blower hose on TD Orient string to 85 degrees RHS @ 6,783 ft. P/U Wt 155k S/O Wt 148k. 440 GPM 1440 psi. Slide thru window @ 6,974 ft wI pumps off. Motor ream to 6,910 ft. P/U Wt 165k, S/O Wt 145k. 436 GPM 1450 psi. Driectional drill 8 1/2" hole section to 6,910 ft to 7,485 ft. P/U Wt 165k, S/O Wt 145k, Rot Wt 158k. 534 GPM on btm 2400 psi, off btm 2200 psi. WOB 15k, 80 RPM's TO on btm 6-7k, TO off btm 4k. Slide 422 ft AvgTF130 ROP slide 40 ftlhr Rotate 153 ft ROP rotate 118 ftlhr AST= 10.6 hrs, ART= 1.3 hrs, ADT= 11.9 hrs. Directional drill 8 1/2" hole section from 7,485 ft to 8,089 ft. P/U Wt 180k, S/O Wt 165k, Rot Wt 170k. 534 GPM on btm 2650 psi, off btm 2350 psi. WOB 10k, 80 RPM's TO on btm 5-7k, TO off btm 4-5k. Slide 397 ft Avg TF 140 ROP slide 53 ft I hr Rotate 207 ft Rotate ROP 71 ft I hr ECD's Avg 10.55 ppg AST= 7.5 hr, ART= 2.9 hr, ADT= 10.4 hr Circ hole clean wI hi - vis sweep. 534 GPM 2700 psi. 80 RPM's TO 4.5k. P/U Wt 180k, S/O Wt 165k, Rot Wt 170k. POH wI 8 1/2" bit to 6,783 ft - inside of 9 5/8" csg. Flow check showing well static. Hole in good shape. Window in good shape. Service Top Drive. Printed: 3/17/2003 9:25:33 AM ) '} Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report 1 7-01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 3/2/2003 23:00 - 23:30 23:30 - 00:00 3/3/2003 00:00 - 04:00 0.50 DRILL P 0.50 DRILL P 4.00 DRILL P 04:00 - 05:00 1.00 DRILL N RREP INT1 05:00 - 16:00 11.00 DRILL N RREP INT1 16:00 - 17:00 1.00 DRILL N RREP INT1 17:00 - 00:00 7.00 DRILL P INT1 3/4/2003 00:00 - 12:00 12:00 - 00:00 12.00 DRILL P 12.00 DRILL P Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Phase INT1 Orient string. Pass thru window @ 6,874 ft with pumps off. Con't RIH to 8,089 ft. Hole & window in good shape. INT1 Directional drill 8 1/2" hole section from 8,089 ft to 8,094 ft. P/U Wt 180k, S/O Wt 165k. 534 GPM on btm 2650 psi, off btm 2350 psi. WOB 10k. Slide 5 ft Avg TF 140 Rap slide 33 ft / hr ECD's Avg 10.55 ppg AST= .15 hr, ART= 0 hr, ADT= .15 hr Directional drill 8 1/2" hole section from 8,094 ft to 8,182 ft. P/U Wt 185k, S/O Wt 168k. 529 GPM on btm 2650 psi, off btm 2350 psi. WOB 5 - 10k. Slide 76 ft Avg TF 120 Slide Rap 30 ft / hr Rotate 12 ft Rotate ROP 100 ft / hr AST= 2.5 hrs, ART= 0.1 hrs, ADT= 2.6 hrs. Wash pipe leaking on Top Drive. POH to 6,783 ft - inside 9 5/8" csg. Flow check showing well static. Hole in good shape. Change out wash pipe packing on Top Drive. Orient string. Pass thru window @ 6,874 ft with pumps off. Con't RIH to 8,182 ft. Hole & window in good shape. Directional drill 8 1/2" hole section from 8,182 ft to 8,290 ft. P/U Wt 185k, S/O Wt 168k. 529 GPM on btm 2700 psi, off btm 2400 psi. WOB 5 - 10k. Slide 107 ft Avg TF 0 Slide ROP 21 ft / hr AST= 5 hrs, ART= 0 hrs, ADT= 5 hrs. Directional drill 8 1/2" hole section from 8,290' to 8,580'. P/U Wt 190K, S/O Wt 165K, Rot Wt 175k. 80 RPM's, TO on btm 5-6K, off btm 4-5K. WOB 5 - 10K. INT1 INT1 Flow rate 512 GPM @ on btm 2850 psi, off btm 2650 psi. Slide 218 ft TF 25 L - HS Rap slide 25 ft / hr Rotate 72 ft Rotate Rap 70 ft / hr ECD's Avg 10.6 ppg INT1 AST= 7.20 hrs, ART= 1.00 hrs, ADT= 8.20 hrs Increasing MW prior to HRZ Directional drill 8 1/2" hole section from 8,580' to 9,015'. P/U Wt 195K, S/O Wt 165K, Rot Wt 180k. 80 RPM's, TO on btm 7-9K, off btm 5-7K. WOB 10 - 12K. Flow rate 512 GPM @ on btm 2850 psi, off btm 2650 psi. Printed: 3/17/2003 9:25:33 AM 1,\ ) ) Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/412003 12:00 - 00:00 12.00 DRILL P INT1 Slide 103 ft TF HS - 35 L ROP slide 25 ft I hr Rotate 292 ft Rotate ROP 70 ft I hr Avg. ECD 11.0 ppg AST= 3.80 hrs, ART= 4.90 hrs, ADT= 8.70 hrs Increasing MW Wior to Kingak 3/5/2003 00:00 - 03:00 3.00 DRILL P INT1 Directional drill 8 1/2" hole section from 9,015' to 9,172'. P/U Wt 200K, S/O Wt 165K, Rot Wt 180K. 80 RPM's, TQ on btm 7-9K, off btm 6-7K. WOB 10 - 12K. Flow rate 495 gpm, on btm 3050 psi, off btm 2750 psi. Rotate 155 ft Rotate ROP 75 ft I hr Avg ECD 11.0 ppg Slide 2 ft Slide ROP 8 ft I hr AST= 0.15 hrs, ART= 2.19 hrs, ADT= 2.34 hrs 03:00 - 03:30 0.50 DRILL P INT1 Circulate, Pump sweep, CBU. Geologist reviewed cuttings and found no evidence of Top Sag transition. Decided to drill three additional feet, to 9,175'. 03:30 - 04:30 1.00 DRILL P INT1 Circulate at 495 gpm and 2,750 psi. Monitor well. Static. Prepare to POH to window. 04:30 - 06:00 1.50 DRILL P INT1 POH from 9,175' to 6,930', just below window. P/U Wt. 210K. Hole appears in good shape. 06:00 - 08:30 2.50 DRILL P INT1 MWD I MAD pass log from 6,930' to 6,532' at -200 fph. 08:30 - 09:30 1.00 DRILL P INT1 Service top drive. 09:30 - 10:00 0.50 DRILL P INT1 RIH from 6,532' to 6,779'. Orient TF to 85 degrees RHS. 10:00 - 11 :00 1.00 DRILL P INT1 RIH from 6,779' to 8,750'. Tight spot at 8,750' ( 50K drag.) 11 :00 - 11 :30 0.50 DRILL P INT1 Wash from 8,750' to 8,770' and work pipe. Continue RIH from 8,770' to 9,175'. 11:30-12:00 0.50 DRILL P INT1 Sweep hole with Hi Vis sweep. CBU at 478 gpm and 2,750 psi. 12:00 - 14:00 2.00 DRILL P INT1 Continue circulating sweep around; spot a liner running pill. Pump a dry job and drop rabbit. 14:00 -17:30 3.50 DRILL P INT1 POH from 9,175' to 898' SLM. No correction. 17:30 - 20:30 3.00 DRILL P INT1 POH UD BHA, Download MWD data, UD motor and bit. Clear rig floor. 20:30 - 21 :30 1.00 CASE P LNR1 Pull wear bushing, test 7" RAMS to 250 psi low and 3,500 psi high. Install wear bushing. 21 :30 - 22:30 1.00 CASE P LNR1 RIU to run 7", 26#, L-80, BTC-M liner. 22:30 - 00:00 1.50 CASE P LNR1 PJSM. Run 7", 26#, L-80, BTC-M liner. M/U torque 8,200 ft-Ibs. Baker-Lok shoe joint connections. 3/6/2003 00:00 - 03:00 3.00 CASE P LNR1 Continue to run 7", 26#, L-80, BTC-M liner. Run a total of 60 joints. 03:00 - 03:30 0.50 CASE P LNR1 M/U Baker HMC liner hanger, ZXP liner top packer wi tie back Printed: 3/17/2003 9:25:33 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 3/612003 From - To Hours Task Code NPT Phase Description of Operations 03:00 - 03:30 03:30 - 04:00 04:00 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 08:30 08:30 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 23:00 23:00 - 23:30 3/7/2003 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:00 02:00 - 02:30 02:30 - 04:00 04:00 - 04:35 0.50 CASE P 0.50 CASE P 2.00 CASE P 0.50 CASE P LNR1 LNR1 LNR1 LNR1 1.50 CASE P 0.50 CASE P 1.50 CASE P LNR1 LNR1 LNR1 1.00 CEMT P LNR1 1.00 CEMT P 1.00 CEMT P 0.50 CEMT P 1.00 CEMT P 2.00 CEMT P 0.50 CEMT P 1.00 CASE P 5.00 CASE P LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 0.50 CASE P LNR1 0.50 CASE P 0.50 CASE P LNR1 LNR1 1.00 CASE P 0.50 CASE P LNR1 LNR1 0.50 CEMT P LNR1 1.50 CEMT P LNR1 0.58 CEMT P LNR1 sleeve. Liner hanging weight is 80K. Circulate liner volume at 210 gpm and 290 psi. RIH, with 7" liner on 4" drill pipe, to 6,827'. Circulate drill pipe and liner volume at 6,827' at 5 bpm and 500 psi. RIH from 6,827' to 9,175'. No problems, no fill. M/U cement rotary head, circulation lines, and valves. Stage mud pump up to 6 bpm at 1,050 psi. CBU. PJSM. Pump 5 bbl water. Test circulating lines and valves to 4,000 psi. Pump 35 bb111.6 ppg Mud Push. Pump 35 bb115.8 ppg cement. \ Shut down and wash lines to rig floor. Drop dart. Displace with 10.6 ppg LSND mud. Bump plug to 3,500 psi with 158 bbl displacement. CIP at 10:45 hours. Slack off 25K to set liner hanger. Rotate 15 turns to release. Pump to 1,000 psi, unsting from liner hanger, circulate. CBU at 6,698' at 13 bpm and 1,700 psi. Pump dry job, break down cement head, blow down lines. POOH from 6,686' to 6,218'. Cut and slip 103' drilling line. POOH from 6,218' to running tool. Make service breaks and LID running tool. R/U casing equipment. PJSM, Run 7", 26#, L-80, BTC-M tieback liner. M/U torque 7,800 ft-Ibs P/U and M/U Flex-Lock II liner hanger and ZXP liner top packer assembly. Circulate liner volume at 4 bpm and 300 psi. Continue circulating liner at 4 bpm and 300 psi. Liner weight 115K RIH with liner on drill pipe from 4,074' to 6,690'. M/U cement rotary head, circulating lines, and valves. P/U weight 156K, SIO weight 153K Break circulation. RIH from 6,690' to liner top at 6,698'. Pump at 1 bpm and 200 psi. Engage seals, continue RIH to No-Go at 6,703'. Pressure up to 1,000 psi, hold pressure. O.K. Bleed pressure, pick up from 6,703' to 6,700', circulate at 1 bpm and 200 psi. PJSM. Pump 5 bbl water and test lines to 4,500 psi. Pump 25 bb111.6 ppg Mud PUSH. Mix and Pump 103 bb113.5 ppg lead slurry, followed by 21 bbl 15.8 ppg tail slurry. Shut down and wash lines. Drop dart. Dowell displace cement with 10.6 ppg LSND mud. Slow rate to 2.5 bpm, bump plug on calculated displacement of 181 bbls. Release pressure, slack off 1 OK to No-Go on indicator, pressure against plug to 4,200 psi to set hanger. Notice shear of hydraulic setting tool at 3,000 psi. Set packer. CIP at 04:35 hours, 3/07/03. Printed: 3/17/2003 9:25:33 AM ) ) of·13 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES HöUrs Task Cöde NPT Phase 3/7/2003 04:00 - 04:35 04:35 - 05:00 0.58 CEMT P 0.42 CEMT P LNR1 LNR1 05:00 - 06:00 1.00 CEMT P LNR1 06:00 - 08:00 2.00 CEMT P LNR1 08:00 - 14:00 6.00 BOPSURP PROD1 14:00 - 14:30 0.50 EVAL P PROD1 14:30 - 16:30 2.00 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 18:30 0.50 DRILL P PROD1 18:30 - 20:30 2.00 DRILL P PROD1 20:30 - 21 :00 0.50 DRILL P PROD1 21 :00 - 22:30 1.50 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 3/8/2003 00:00 - 01 :30 1.50 DRILL P PROD1 01 :30 - 03:30 2.00 DRILL P PROD1 03:30 - 05:00 1.50 DRILL P PROD1 05:00 - 07:30 2.50 DRILL P PROD1 07:30 - 08:30 1.00 EVAL P PROD1 08:30 - 10:30 2.00 DRILL P PROD1 10:30 - 11 :00 0.50 EVAL P PROD1 11 :00 - 12:00 1.00 DRILL P PROD1 Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Description of Operations Rotate to right 15 turns, release running tool. Pressure to 1,000 psi. P/U above tie-back and circulate. CBU @ 2,673' at 8 bpm and 1,350 psi. Trace cement in returns. Slug pipe, prepare to POH. LID cement head, POH from 2,673', LID running tool. Change rams, test BOPE to 250 psi low and 3,500 psi high. BOP test witnessed by Jeff Jones of the AOGCC. Install wear bushing. Short pressure test 9 5/8" casing to LlC at 6,676'. Chart and hold 3,500 psi. Blow down surface equipment. PJSM. M/U 6 1/8" drilling BHA (#4) to 89'. Upload MWD tools. M/U BHA #4 from 89' to 206'. Shallow test MWD at 206' at 238 gpm and 1,040 psi. Blow down surface equipment. P/U 4" drill pipe singles from 206' to 3,753'. Fill pipe. Function test MWD tools @ 3,753'. RIH with 4" drill pipe from derrick to 6,676'. Install blower hose. Fill pipe. Drill on Landing Collar at 6,676' at 241 gpm and 1,750 psi. P/U weight 125K, S/O weight 120K, Rot. weight 125K Torque OnBtm 3K, Torque OffBtm 2K. Continue to drill on the scab liner LlC, circulating at 240 gpm and 1,750 psi. Rotating at 30 rpm, WOB 5 - 25K. RIH from 6,676' to tag up on LlC at 9,095'. Had to push the T/B liner LlC plug down hole. Drill shoe tract and cement from 9,095' to 9,167'. PJSM regarding mud swap to Flo-Pro. Displace well to 8.6 ppg Flo-Pro mud at 250 gpm and 1,800 psi. Pressure test the 9 5/8" X 7" casing to 3,500 psi for 30 minutes. Record test. Drill remaining shoe tract from 9,167' to 9,178', plus 20 feet of new hole from 9,178' to 9,198' at 252 gpm and 1,750 psi. Pull up into casing at 9,169'. Perform FIT to 10.0 ppg EMW (650 psi). Record test. No problems. Blow down kill line. Directional drill 6 1/8" hole section from 9,198' to 9,217'. P/U Wt 165K, S/O Wt 150K, Rot Wt 160K. Flow rate 250 gpm, on btm 1,700 psi, off btm 1,500 psi. Slide 19 ft @ TF HS 12:00 - 17:30 5.50 DRILL P AST= 1.50 hrs, ART= 0.00 hrs, ADT= 1.50 hrs PROD1 Directional drill 6 1/8" hole section from 9,217' to 9,283'. P/U Wt 165K, SIO Wt 150K, Rot Wt 160K. Flow rate 250 gpm, on btm 1,700 psi, off btm 1,500 psi. Printed 3/17/2003 9:25:33 AM ) ) ;, BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To Hours Task Code NPT Phase 3/8/2003 12:00 - 17:30 5.50 DRILL P PROD1 Slide 66 ft @ TF HS AST= 4.54 hrs, ART= 0.00 hrs, ADT= 4.54 hrs BHA not yielding sufficient DLS. Required 15/100', only getting 13 - 14/100'. PROD1 Monitor well at 9,283'. POOH with drill pipe from 9,283' to 9,175'. Drop dart to open circulating sub. CBU at 9,175' at 13 bpm and 1,800 psi. Slug pipe and blow down surface equipment. POH with drill pipe from 9,175' to BHA at 206'. LID jars, stand back NMFDC. PJSM. LID bit and motor. M/U BHA #5 to 96'. C/O kick pad on motor housing. P/U pony Flex collar and String stabilizer. P/U MWD, download, test, and upload. Continue test and download of MWD/LWD. RIH with BHA from 96' to 223'. Surface test MWD at 102 spm, 250 gpm, 650 psi. Blow down top drive. RIH with drill pipe from 223' to 9,095'. Fill pipe and check MWD at 3,021' and 6,292' at 250 gpm. Service top drive. Connect blower hose. Check brakes. 17:30 -18:30 1.00 DRILL P 18:30 - 21 :30 3.00 DRILL P PROD1 21 :30 - 22:30 1.00 DRILL P PROD1 22:30 - 23:30 1.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 3/9/2003 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01 :30 1.00 DRILL P PROD1 01 :30 - 05:00 3.50 DRILL P PROD1 05:00 - 06:00 1.00 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 12:00 5.50 DRILL P PROD1 Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Descri ptiori of Operations Increase pump rate to 325 gpm and 1,775 psi. Wash to bottom and tag fill at 9,280'. Directional drill 6 1/8" hole section from 9,283' to 9,374'. P/U Wt 165K, S/O Wt 150K, Rot Wt 160K. Torque off btm 4K Slide 91' (9,283' - 9,374') at TF HS Flow rate 320 gpm, on btm 1,780 psi, off btm 1,650 psi. WOB 0 - 10K, Avg. ROP 28 fph Begin circulating in glass bead sweep every half hour. (Sweep 25 bbl @ 15 ppb.) 12:00 - 00:00 12.00 DRILL P AST= 3.38 hrs, ART= 0.00 hrs, ADT= 3.38 hrs PROD1 Directional drill 6 1/8" hole section from 9,374' to 9,553'. P/U Wt 170K, S/O Wt 150K, Rot Wt 165K. Torque off btm 4K Slide 55' (9,374' - 9,429') at TF HS Flow rate 320 gpm, on btm 1,800 psi, off btm 1,650 psi. WOB 0 - 10K, Avg. ROP 20 fph Sliding difficult, hanging up and stacking out. NOTE: At -9,415', ABI began giving erroneous data; continuous reading of 89.9 degrees. Apparent failure. Circulate in glass bead sweep at 9,426'. (Sweep 25 bbl @ 15 ppb.) Rotate 6' (9,429' - 9,435') to help clean the hole. Flow rate 320 gpm, on btm 1,800 psi, off btm 1,650 psi. Printed: 3/17/2003 9:25:33 AM ) ') BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Cbdé NPT Phase DescriptiÒnöf Operations 3/9/2003 12:00 - 00:00 12.00 DRILL P PROD1 WOB 8K, Avg. ROP 100 fph Circulate in glass beads at 9,489' and 9,510'. Some improvement in ability to slide. Slide 118' (9,435' - 9,553') at TF HS Flow rate 340 gpm, on btm 1,950 psi, off btm 1,780 psi. WOB 0 - 10K, Avg. ROP 46 fph AST= 4.91 hrs, ART= 0.06 hrs, ADT= 4.97 hrs 3/10/2003 00:00 - 06:00 6.00 DRILL P PROD1 Directional drill 6 1/8" hole section from 9,553' to 9,590'. P/U Wt 170K, SIO Wt 150K, Rot Wt 165K. Slide 37' (9,553' - 9,590') at TF HS Flow rate 320 gpm, on btm 2,250 psi, off btm 2,000 psi. WOB 0 - 10K, Avg. ROP 25 fph Rotate 16' (9,590' - 9,606') Flow rate 325 gpm, on btm 2,250 psi, off btm 2,000 psi. Torque on btm 5,500 WOB 5K, Avg. ROP 30 fph 06:00 - 12:00 6.00 DRILL P Slide 24' (9,606' - 9,630') at TF HS Flow rate 326 gpm, on btm 2,250 psi, off btm 1,900 psi. WOB 0 - 10K, Avg. ROP 30 fph PROD1 Directional drill 6 1/8" hole section from 9,590' to 9,840'. P/U Wt 170K, SIO Wt 150K, Rot Wt 165K. Rotate 157' (9,590' - 9,747') at 30 RPM Flow rate 330 gpm, on btm 2,250 psi, off btm 1,950 psi. Torque on btm 5,000 - 7,000; Torque off btm 4,000 WOB 8 - 12K, Avg. ROP 75 fph Slide 1 Rotate 93' (9,747' - 9,840') Slide at TF -90 Flow rate 330 gpm, on btm 2,050 psi, off btm 1,850 psi. WOB 14K, Avg. ROP 20 fph Rotate at 30 RPM Flow rate 330 gpm, on btm 2,250 psi, off btm 1,950 psi. Torque on btm 5,000 - 7,000; Torque off btm 4,000 WOB 12K, Avg. ROP 60 fph 12:00 - 00:00 12.00 DRILL P AST= 4.25 hrs, ART= 2.37 hrs, ADT= 6.62 hrs PROD1 Directional drill 6 1/8" hole section from 9,840' to 10,375'. P/U Wt 170K, SIO Wt 145K, Rot Wt 160K. Slide 1 Rotate 293' (9,840' - 10,133') Slide at TF -170 Printed: 3/17/2003 9:25:33 AM ) ") OperationsS urn rnary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 From - To Hours Task Code NPT Phase Description of Operations 3/10/2003 12:00 - 00:00 12.00 DRILL P PROD1 Flow rate 330 gpm, on btm 2,050 psi, off btm 1,850 psi. WOB 8 -12K, Avg. ROP 35 fph Rotate at 60 RPM Flow rate 330 gpm, on btm 2,350 psi, off btm 1,950 psi. Torque on btm 5,000 - 7,000; Torque off btm 4,000 - 6,000 WOB 8 -12K, Avg. ROP 100 fph Rotate 176' (10,133' -10,309') at 60 RPM Flow rate 330 gpm, on btm 2,500 psi, off btm 2,150 psi. Torque on btm 5,000 - 7,000; Torque off btm 4,000 WOB 12 - 14K, Avg. ROP 175 fph Slide I Rotate 293' (10,133' - 10,375') Slide at TF -90 Flow rate 330 gpm, on btm 2,200 psi, off btm 2,000 psi. WOB 14K, Avg. ROP 30 fph Rotate at 60 RPM Flow rate 330 gpm, on btm 2,500 psi, off btm 2,150 psi. Torque on btm 5,000 - 7,000; Torque off btm 4,000 - 6,000 WOB 14K, Avg. ROP 150 fph 3/11/2003 00:00 - 01 :30 1.50 DRILL P AST= 3.70 hrs, ART= 2.82 hrs, ADT= 6.52 hrs PROD1 Directional drill 6 1/8" hole section from 1 0,375' to 1 0,402'. P/U Wt 170K, SIO Wt 145K, Rot Wt 160K. 01:30 - 02:15 0.75 DRILL P PROD1 Rotate 27' (10,375' - 10,402') at 60 RPM Flow rate 330 gpm, on btm 2,500 psi, off btm 2,150 psi. Torque on btm 6,000 Torque off btm 5,000 WOB 8 -10K, Avg. ROP 75 fph Pump sweep, CBU at 335 gpm and 2,250 psi. Nothing substantial back with sweep. Short trip to shoe at 9,175'. P/U weight at 185K. Hole in good condition. Service top drive. RIH from 9,175' to 10,402'. No problems. Directional drill 6 1/8" hole section from 10,402' to 10,636'. 02:15 - 03:00 0.75 DRILL P PROD1 03:00 - 04:00 04:00 - 04:30 04:30 - 12:00 1.00 DRILL P 0.50 DRILL P 7.50 DRILL P PROD1 PROD1 PROD1 Slide I Rotate 234' (10,402' - 10,636') Slide at TF -90 to -120 to continue lefthand turn and to access lower 46P interval Flow rate 340 gpm, on btm 2,200 psi, off btm 2,050 psi. WOB 8K, Avg. ROP 45 fph Rotate at 60 RPM Flow rate 340 gpm, on btm 2,350 psi, off btm 2,150 psi. Torque on btm 5,000 - 6,000; Torque off btm 3,000 - 5,000 WOB 8 - 10K, Avg. ROP 100 fph 12:00 - 00:00 12.00 DRILL P AST= 3.17 hrs, ART= 2.17 hrs, ADT= 5.34 hrs PROD1 Directional drill 6 1/8" hole section from 10,636' to 10,867'. Slide I Rotate 124' (10,636' -10,760') Printed: 3/17/2003 9:25:33 AM ) ') BP Operations Summary Report Legal Well Name: 1 7-01 Common Well Name: 17-01 A Spud Date: 6/10/1980 Event Name: REENTER+COMPLETE Start: 2/25/2003 End: 3/16/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/16/2003 Rig Name: NABORS 2ES Rig Number: Frbrrl....Tb HoUrs TaSk CÖdé NPT Phase Description of Operations . 3/11/2003 12:00 - 00:00 12.00 DRILL P PROD1 Slide at TF -110 to -120 to continue lefthand turn and to access lower 46P interval. Flow rate 330 gpm, on btm 2,200 psi, off btm 2,050 psi. WOB 12 - 18K, Avg. ROP 30 fph Rotate at 60 RPM Flow rate 340 gpm, on btm 2,350 psi, off btm 2,150 psi. Torque on btm 5,000 - 6,000; Torque off btm 4,000 - 5,000 WOB 8 - 10K, Avg. ROP 60 fph Slide 107' (10,760' - 10,867') Slide at TF -70 to continue lefthand turn and to build out of 45N shale. Flow rate 330 gpm, on btm 2,300 psi, off btm 2,050 psi. WOB 12K, Avg. ROP 35 fph AST= 4.80 hrs, ART= 0.65 hrs, ADT= 5.45 hrs 3/12/2003 00:00 - 12:00 12.00 DRILL P PROD1 Directional drill 6 1/8" hole section from 10,867' to 11,428'. Slide / Rotate 561' (10,867' - 11,428') Slide at TF -90 to -120 to continue lefthand turn and to break over after building up out of the 45N shale. Flow rate 330 gpm, on btm 2,300 psi, off btm 2,000 psi. WOB 12 - 15K, Avg. ROP 70 fph Pumped 25 bbl @ 15 ppb glass bead pill and a 11 % lube pill to facilitate sliding. Improved slide capability. Rotate at 60 RPM Flow rate 330 gpm, on btm 2,400 psi, off btm 2,000 psi. Torque on btm 5,000 - 6,000; Torque off btm 4,000 - 5,000 WOB 15K, Avg. ROP 120 fph AST= 4.20 hrs, ART= 1.79 hrs, ADT= 5.99 hrs 12:00 - 00:00 12.00 DRILL P PROD1 Directional drill 61/8" hole section from 11,428' to 12,110'. Slide I Rotate 682' (11,428' - 12,110') Slide at TF -20 Flow rate 330 gpm, on btm 2,300 psi, off btm 2,000 psi. WOB 12K, Avg. ROP 30 fph Pumped 25 bbl @ 15 ppb glass bead pill. Rotate at 80 RPM Flow rate 330 gpm, on btm 2,400 psi, off btm 2,000 psi. Torque on btm 5,000 - 6,000; Torque off btm 4,000 - 5,000 WOB 15K, Avg. ROP 120 fph AST= 1.82 hrs, ART= 4.87 hrs, ADT= 6.69 hrs 3/13/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Drill 61/8" hole section from 12,110' to 12,269'. Rotate at 80 RPM Flow rate 330 gpm, on btm 2,400 psi, off btm 2,000 psi. Torque on btm 5,000 - 6,000; Torque off btm 4,000 - 5,000 WOB 15K, Avg. ROP 150 fph Printed: 3/17/2003 9:25:33 AM ) ) BP EXPLORATION Page 120f 13 OperatiönsSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-01 17 -01 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2003 00:00 - 01 :30 1.50 DRILL P PROD1 TD called at 12,269' by Geologist. AST= 0.00 hrs, ART= 1.10 hrs, ADT= 1.10 hrs 01 :30 - 02:30 1.00 DRILL P PROD1 CBU at 140 spm, 340 gpm, and at 2,700 psi. Rotate and reciprocate pipe. 02:30 - 04:30 2.00 DRILL P PROD1 Short trip to 7" liner shoe at 9,175'. Good trip. Areas of 15 - 20K overpull at 11,820' - 11,800', 11,260' - 11,240', 11,100'-11,090', 9,570' - 9,550'. 04:30 - 06:30 2.00 DRILL P PROD1 Cut and slip 91' drilling line. Service top drive. 06:30 - 08:00 1.50 DRILL P PROD1 RIH from 9,094' to 12,176'. No problems. 08:00 - 10:00 2.00 DRILL P PROD1 Fill pipe, break circulation, wash down from 12,176' to 12,269'. Pump a Hi Vis sweep at 344 gpm and 2,760 psi. 10:00 - 10:30 0.50 DRILL P PROD1 Spot 120 bblliner running pill in open hole at 5.5 bpm and 1,840 psi. 10:30-12:30 2.00 DRILL P PROD1 POOH from 12,269' to 9,175' with drill pipe. No problems. Monitor well, drop rabbit. 12:30 - 13:30 1.00 DRILL P PROD1 Open circ sub at 9,175'. CBU at 550 gpm and 2,100 psi. Slug pipe. Blow down surface equipment. 13:30 - 16:30 3.00 DRILL P PROD1 POOH from 9,175' to 223' with drill pipe. 16:30 - 17:30 1.00 DRILL P PROD1 PJSM. LID BHA #5 from 223' to 96'. 17:30 - 18:00 0.50 DRILL P PROD1 Down load MWD tools. 18:00 - 19:00 1.00 DRILL P PROD1 LID BHA #5 from 96'. Clear rig floor. 19:00 - 20:00 1.00 CASE P COMP PJSM. R/U 41/2" liner equipment. 20:00 - 22:30 2.50 CASE P COMP P/U 4 1/2", 12.6#, L-80, BTC-M slotted 1 solid (7 joints) liner to 3,219'. M/U torque 4,000 ft-Ibs. 22:30 - 23:00 0.50 CASE P COMP M/U Baker HMC liner hanger. Liner hang weight 60K. RIH to 3,338'. RID liner equipment. 23:00 - 23:30 0.50 CASE P COMP Circulate through hanger at 3,338' at 4 bpm and 320 psi. Blow down surface equipment. 23:30 - 00:00 0.50 CASE P COMP RIH with liner on 4" drill pipe from 3,338' to 4,633'. 3/14/2003 00:00 - 02:00 2.00 CASE P COMP RIH with 4 1/2" liner from 4,633' to 9,130', at the 7" liner shoe. Break circulation. Circulate drill pipe volume at 3.5 bpm and 600 psi. 02:00 - 04:00 2.00 CASE P COMP Continue running 41/2" liner into open hole from 9,130' to 12,200'. P/U weight 190K S/O weight 140K. 04:00 - 04:30 0.50 CASE P COMP Connect top drive, establish flow at 35 spm. P/U at 195K and S/O at 145K. Tag bottom, no fill. P/U and S/O back to bottom. Drop 29/32" ball and begin pumping at 55 spm. Catch pressure and continue to pressure up to 2,500 psi. Hold a couple minutes. S/O 25K and confirm hanger set. Increase pressure to 3,450 psi and blow ball seat. Rotate 20 rotations to the right to release from hanger. P/U 170K. Liner top at 9,028' 04:30 - 06:30 2.00 CASE P COMP PJSM. Circulate and displace well to seawater at 10 bpm and 1,300 psi. Monitor well, clean surface equipment. Printed: 3/17/2003 9:25:33 AM ) ) BP EXPLORATION Operations Summary Report· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -01 17-01A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/25/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/10/1980 End: 3/16/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/14/2003 06:30 - 07:00 0.50 CASE P COMP LID 4" drill pipe from 9,028' to 8,406'. 07:00 - 08:00 1.00 CASE P COMP Service top drive. 08:00 - 11 :30 3.50 CASE P COMP LID 4" drill pipe from 8,406' to 3,705'. 11 :30 - 12:30 1.00 CASE P COMP RIH with stands from derrick to 6,725'. 12:30 - 17:30 5.00 CASE P COMP LID 4" drill pipe from 6,725' to 30'. Service break the running tool and LID same. Clear rig floor. 17:30 - 20:00 2.50 RUNCOI\IP COMP Pull wear bushing. RlU 4 1/2" chrome tubing equipment. 20:00 - 00:00 4.00 RUNCOI\IP COMP M/U tailpipe and Baker S-3 packer. Baker Lock connections. RIH with 41/2", 12.6#, 13Cr-80 Vam Ace completion to 2,240'. Average M/U torque 3,620 ft-Ibs. 3/15/2003 00:00 - 07:30 7.50 RUNCOI\IP COMP RIH with 41/2", 12.6#, 13Cr-80 Vam Ace completion from 2,240'. Tag up at 9,030' Average M/U torque 3,620 ft-Ibs. P/U weight 125K S/O weight 115K Ran a total of 208 joints. 07:30 - 08:30 1.00 RUNCOI\IP COMP Space out with 1 - 9.91' pup joint. 08:30 - 09:30 1.00 RUNCOI\IP COMP M/U tubing hanger and land. 09:30 - 10:00 0.50 RUNCOI\IP COMP RILDS 10:00 - 12:00 2.00 RUNCOI\IP COMP Displace wellbore to clean seawater at 3 bpm and 220 psi. 12:00 - 13:00 1.00 RUNCOI\IP COMP Reverse circulate Nalco Corrosion Inhibitor at 3 bpm and 220 psi. Lost 40 bbl total losses, 8.5 ppg Flo-Pro mud, to formation while reverse circulating seawater wi corrosion inhibitor. 13:00 - 14:30 1.50 RUNCOI\IP COMP Drop 1 7/8" Ball I Rod on 'XN' nipple at 9,018'. Set packer at 8,975' with 3,500 psi. Test tubing to 3,500 psi for 30 minutes, bleed back to 1,800 psi and test casing X tubing annulus to 3,500 psi for 30 minutes. Good test. Bleed tubing pressure to shear DCK valve at 3,003'. 14:30 -15:00 0.50 RUNCOI\IP COMP Dry rod in BPV. Test from below to 1,000 psi. Blow down surface equipment. 15:00 - 17:00 2.00 BOPSURP COMP Nipple Down BOPE. 17:00 - 20:00 3.00 BOPSUR P COMP Repair lock down screw. Nipple Up adapter flange and tree. 20:00 - 21 :00 1.00 BOPSURP COMP Pull BPV with DSM I lubricator. Install Tree Test Plug. 21 :00 - 22:00 1.00 BOPSURP COMP Test tree to 5,000 psi. Replace leaking needle valve. 22:00 - 22:30 0.50 BOPSUR P COMP Pull Tree Test Plug. RID DSM. 22:30 - 23:00 0.50 BOPSUR P COMP PJSM with Hot Oil. RlU for freeze protect. 23:00 - 00:00 1.00 WHSUR P COMP Test lines to 2,500 psi. Begin pump 150 bbl diesel freeze protect down IA at 2.5 bpm and 1,800 psi. Take returns to cuttings tank. 3/16/2003 00:00 - 01 :30 1.50 WHSUR P COMP Continue to circulate freeze protect diesel. U-tube diesel to balance at -2,200'. 01 :30 - 02:30 1.00 WHSUR P COMP Install BPV and test to 1,000 psi. 02:30 - 04:00 1.50 WHSUR P COMP N/D secondary annulus valve and secure well. RELEASE rig at 04:00, 03/16/2003. Printed: 3/17/2003 9:25:33 AM j ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 17-01A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,793.00' MD Window / Kickoff Survey: 6,874.00' MD (if applicable) Projected Survey: 12,270.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) 26-Mar -03 cYQ8 --Q,) ~ RECE\VED APR 1 -, Z003 AlasKft ~ &. Gas Coni.l~mm-n Mœoragc Sperry-Sun Drilling Services North Slope Alaska BPXA 17-01A ~/ Job No. AKZZ2302699, Surveyed: 13 March, 2003 Survey Report 26 March, 2003 Your Ref: API 500292047601 Surface Coordinates: 5927794.39 N, 708786.75 E (70012' 21.8461" N, 148018' 59.6777" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 63.00ft above Mean Sea Level "-' 5ipe"I'Y-5iul! DRILLING SERVIc:es A Halliburton Company Survey Ref: svy3998 Sperry-Sun Drilling Services Survey Report for 17-01 A Your Ref: API 500292047601 Job No. AKZZ2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6793.00 33.170 145.100 6599.38 6662.38 557.87 S 359.54 E 5927246.67 N 709161.57 E 661.97 Tie On Point AK-6 SP, IFR-AK 6874.00 32.930 146.160 6667.27 6730.27 594.33 S 384.48 E 5927210.91 N 709187.51 E 0.773 706.10 Window Point 6952.06 30.240 146.230 6733.76 6796.76 628.30 S 407.22 E 5927177.58 N 709211.19 E 3.446 746.92 6983.02 29.520 146.270 6760.60 6823.60 641. 13 S 415.79E 5927165.00 N 709220.11 E 2.326 762.32 7011.61 28.070 146.300 6785.66 6848.66 652.58 S 423.44 E 5927153.76 N 709228.06 E 5.072 776.07 7046.24 24.870 146.350 6816.65 6879.65 665.43 S 432.00 E 5927141.16 N 709236.97 E 9.241 791 .48 -> 7075.67 23.500 146.390 6843.50 6906.50 675.47 S 438.67 E 5927131.31 N 709243.93 E 4.655 803.52 7105.72 22.650 146.440 6871.15 6934.15 685.28 S 445.19 E 5927121.68 N 709250.71 E 2.829 815.28 7139.75 21.010 142.810 6902.74 6965.74 695.60 S 452.50 E 5927111.57 N 709258.30 E 6.240 827.92 7171.38 18.110 141.010 6932.54 6995.54 703.94 S 459.02 E 5927103.41 N 709265.05 E 9.363 838.50 7199.86 15.810 139.320 6959.78 7022.78 710.32 S 464.33 E 5927097.18 N 709270.54 E 8.258 846.80 7234.27 14.000 136.720 6993.03 7056.03 716.91 S 470.24 E 5927090.76 N 709276.63 E 5.606 855.61 7265.01 13.560 135.340 7022.88 7085.88 722.18 S 475.33 E 5927085.63 N 709281.86 E 1.787 862.88 7293.02 12.620 134.480 7050.17 7113.17 726.66 S 479.82 E 5927081.27 N 709286.47 E 3.427 869.16 7327.29 10.620 127.010 7083.73 7146.73 731.18 S 485.01 E 5927076.90 N 709291.79 E 7.292 875.90 7355.54 9.310 119.750 7111.56 7174.56 733.88 S 489.07 E 5927074.31 N 709295.92 E 6.416 880.50 7386.67 7.990 101.240 7142.34 7205.34 735.55 S 493.38 E 5927072.76 N 709300.28 E 9.840 884.42 7418.72 7.950 79.230 7174.09 7237.09 735.57 S 497.75 E 5927072.86 N 709304.64 E 9.465 887.06 7448.02 8.590 64.91 0 7203.09 7266.09 734.27 S 501.72 E 5927074.27 N 709308.58 E 7.339 888.40 7479.21 9.300 54.790 7233.90 7296.90 731.83 S 505.89 E 5927076.83 N 709312.67 E 5.525 888.96 7513.53 9.570 43.530 7267.76 7330.76 728.16 S 510.12 E 5927080.61 N 709316.80 E 5.427 888.57 7541.02 9.480 33.390 7294.87 7357~87 724.61 S 512.94 E 5927084.23 N 709319.52 E 6.105 887.43 7572.18 8.710 20.950 7325.64 7388.64 720.27 S 515.20 E 5927088.64 N 709321.66 E 6.761 885.31 7606.09 8.660 9.380 7359.16 7422.16 715.35 S 516.53 E 5927093.59 N 709322.86 E 5.146 882.18 - 7616.94 9.880 356.690 7389.61 7452.61 710.41 S 516.76 E 5927098.53 N 709322.95 E 7.693 878.37 7665.77 10.780 350.950 7417.98 7480.98 705.28 S 516.19 E 5927103.65 N 709322.24 E 4.739 873.93 7726.66 8.030 353.420 7478.04 7541.04 695.43 S 514.81 E 5927113.46 N 709320.58 E 4.564 865.22 7757.91 6.430 1.240 7509.04 7572.04 691.51 S 514.59 E 5927117.37 N 709320.26 E 6.000 861.96 7791.97 5.350 6.970 7542.92 7605.92 688.03 S 514.83 E 5927120.85 N 709320.40 E 3.607 859.32 7851.00 4.540 2.690 7601.73 7664.73 682.96 S 515.27 E 5927125.93 N 709320.70 E 1.507 855.54 26 March, 2003 - 14:19 Page 2 of 6 DrilfQlIest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17-01 A Your Ref: AP/500292047601 Job No. AKZZ2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7908.32 3.670 10.140 7658.91 7721.91 678.89 S 515.70 E 5927130.01 N 709321.02 E 1.777 852.54 7944.26 3.340 14.930 7694.78 7757.78 676.75 8 516.17 E 5927132.17 N 709321.43 E 1.227 851 .11 8037.53 3.460 74.010 7787.91 7850.91 673.35 8 519.58 E 5927135.66 N 709324.74 E 3.595 850.44 8130.38 3.510 140.860 7880.63 7943.63 674.788 524.07 E 5927134.35 N 709329.27 E 4.134 854.28 8223.55 7.500 175.580 7973.37 8036.37 683.06 8 526.34 E 5927126.14 N 709331.77 E 5.396 862.26 8253.08 10.510 180.120 8002.53 8065.53 687.68 8 526.48 E 5927121.53 N 709332.04 E 10.465 866.04 8288.98 14.040 185.070 8037.61 8100.61 695.29 8 526.09 E 5927113.91 N 709331.86 E 10.252 871.89 '-- 8317.72 16.860 187.560 8065.31 8128.31 702.90 8 525.23 E 5927106.28 N 709331.21 E 10.078 877.45 8351.23 20.240 187.900 8097.07 8160.07 713.468 523.80 E 5927095.68 N 709330.07 E 10.092 885.03 8382.44 21 .850 187.400 8126.20 8189.20 724.57 8 522.31 E 5927084.54 N 709328.89 E 5.191 893.02 8411.24 23.190 186.430 8152.80 8215.80 735.52 8 520.98 E 5927073.56 N 709327.86 E 4.828 900.97 8444.51 25.180 183.120 8183.15 8246.15 749.09 8 519.86 E 5927059.95 N 709327.12 E 7.236 911.16 8476.70 27.110 179.970 8212.05 8275.05 763.27 8 519.49 E 5927045.77 N 709327.14 E 7.383 922.27 8505.27 28.040 178.200 8237.37 8300.37 776.49 S 519.71 E 5927032.56 N 709327.72 E 4.338 932.96 8538.36 29.410 178.570 8266.39 8329.39 792.39 8 520.15 E 5927016.68 N 709328.61 E 4.175 945.94 8570.27 31.920 179.050 8293.83 8356.83 808.66 8 520.49 E 5927000.43 N 709329.39 E 7.903 959.15 8598.47 32.360 179.100 8317.71 8380.71 823.66 S 520.73 E 5926985.44 N 709330.05 E 1.563 971.28 8692.64 30.910 179.480 8397.89 8460.89 873.04 8 521.35 E 5926936.09 N 709332.03 E 1.554 1011.13 8786.31 31.320 181.200 8478.08 8541.08 921.44 8 521.06 E 5926887.70 N 709333.08 E 1.045 1049.65 8880.13 29.210 182.000 8559.11 8622.11 968.71 8 519.75 E 5926840.42 N 709333.08 E 2.290 1086.64 8973.54 30.020 177.840 8640.33 8703.33 1014.848 519.83 E 5926794.31 N 709334.44 E 2.365 1123.57 9066.08 31.930 175.960 8719.67 8782.67 1062.39 8 522.43 E 5926746.85 N 709338.35 E 2.313 1163.14 9124.38 30.790 176.290 8769.45 8832.45 1092.66 8 524.48 E 5926716.65 N 709341.23 E 1.977 1188.57 9197.45 33.480 175.980 8831.32 8894.32 1131 .43 S 527.10 E 5926677.96 N 709344.93 E 3.688 1 221 .14 9215.16 36.320 175.690 8845.84 8908.84 1141.548 527.84 E 5926667.88 N 709345.94 E 16.063 1229.66 -- 9229.78 38.310 176.230 8857.47 8920.47 1150.388 528.46 E 5926659.06 N 709346.81 E 13.794 1237.10 9261.20 42.860 175.330 8881 .33 8944.33 1170.768 529.97 E 5926638.73 N 709348.89 E 14.600 1254.30 9290.24 46.800 176.310 8901.92 8964.92 1191.178 531.46 E 5926618.36 N 709350.94 E 13.774 1271.51 9323.19 52. 1 50 179.090 8923.32 8986.32 1216.198 532.44 E 5926593.39 N 709352.61 E 17.455 1292.10 9353.34 56.280 181.600 8940.95 9003.95 1240.648 532.28 E 5926568.94 N 709353.12 E 15.271 1311.54 9382.38 60.000 181.930 8956.28 9019.28 1265.28 8 531.52 E 5926544.28 N 709353.04 E 12.846 1330.79 9416.47 65.760 182.090 8971.81 9034.81 1295.60 S 530.45 E 5926513.95 N 709352.82 E 16.902 1354.38 9446.57 69.770 182.670 8983.20 9046.20 1323.43 8 529.30 E 5926486.10 N 709352.43 E 13.441 1375.93 9475.26 75.050 183.050 8991.86 9054.86 1350.738 527.93 E 5926458.77 N 709351.82 E 18.447 1396.94 9503.28 78.980 185.080 8998.16 9061 .16 1377.96 S 525.99 E 5926431.50 N 709350.63 E 15.701 1417.54 26 March. 2003 - 14: 19 Page 3 of 6 DriflQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17-01A Your Ref: AP/500292047601 Job No. AKZZ2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9542.38 86.550 185.390 9003.08 9066.08 1416.56 S 522.45 E 5926392.82 N 709348.16 E 19.377 1446.26 9569.88 91.230 186.4 70 9003.61 9066.61 1443.90 S 519.61 E 5926365.41 N 709346.08 E 17.465 1466.4 1 9603.30 94. 190 186.040 9002.03 9065.03 1477.08 S 515.98 E 5926332.14 N 709343.36 E 8.950 1490.75 9620.19 96.660 105.990 8999.68 9062.68 1501.72 S 513.38 E 5926307.44 N 709341.45 E 9.926 1508.89 9661.60 96.600 185.580 8995.82 9058.82 1534.74 S 510.04 E 5926274.34 N 709339.01 E 1.232 1533.27 9697.25 96.470 185.230 8991.77 9054.77 1570.00 S 506.70 E 5926239.00 N 709336.65 E 1.041 1559.45 9728.13 96.480 185.370 8988.28 9051.28 1600.55 S 503.87 E 5926208.38 N 709334.67 E 0.452 1582.17 -' 9756.21 97.410 183.350 8984.89 9047.89 1628.34 S 501.75 E 5926180.54 N 709333.32 E 7.872 1603.11 9790.61 98.580 179.540 8980.10 9043.10 1662.39 S 500.89 E 5926146.48 N 709333.40 E 11 .483 1629.81 9821.38 100.380 176.920 8975.03 9038.03 1692.72 S 501.82 E 5926116.19 N 709335.17 E 10.235 1654.62 9849.94 100.650 175.640 8969.82 9032.82 1720.74 S 503.64 E 5926088.23 N 709337.77 E 4.507 1678.12 9884.63 99.270 173.850 8963.82 9026.82 1754.76 S 506.77 E 5926054.31 N 709341.84 E 6.454 1707.19 9943.92 95.300 171.520 8956.30 9019.30 1813.08 S 514.26 E 5925996.22 N 709350.94 E 7.748 1758.31 9978.24 90.800 170.620 8954.48 9017.48 1846.92 S 519.58 E 5925962.53 N 709357.19 E 13.371 1788.56 10009.52 86.240 168.440 8955.28 9018.28 1877.66 S 525.26 E 5925931.96 N 709363.72 E 16.156 1816.55 10038.05 85.940 168.660 8957.23 9020.23 1905.56 S 530.91 E 5925904.23 N 709370.14 E 1.303 1842.24 10072.45 86.240 168.740 8959.58 9022.58 1939.21 S 537.64 E 5925870.78 N 709377.79 E 0.902 1873.18 10103.82 86.550 168.520 8961.55 9024.55 1969.91 S 543.81 E 5925840.27 N 709384.81 E 1.211 1901.43 10131.83 87.540 167.460 8962.99 9025.99 1997.27 S 549.63 E 5925813.08 N 709391.38 E 5.174 1926.80 10165.76 87.350 166.890 8964.51 9027.51 2030.32 S 557.15 E 5925780.25 N 709399.82 E 1.769 1957.74 10196.68 87.230 166.860 8965.97 9028.97 2060.40 S 564.17 E 5925750.38 N 709407.66 E 0.400 1985.99 10224.78 87.170 166.760 8967.34 9030.34 2087.72 S 570.57 E 5925723.24 N 709414.81 E 0.415 2011.69 10259.24 87.11 0 166.600 8969.06 9032~06 2121.21 S 578.50 E 5925689.98 N 709423.67 E 0.495 2043.22 10289.71 87.170 166.030 8970.58 9033.58 2150.78 S 585.70 E 5925660.62 N 709431.68 E 1.879 2071 .1 8 10317.89 87.230 164.830 8971.96 9034.96 2178.02 S 592.78 E 5925633.59 N 709439.51 E 4.259 2097.21 -'" 10351.50 88.280 161.550 8973.27 9036.27 2210.17 S 602.49 E 5925601.72 N 709450.11 E 10.240 2128.74 10386.98 88.520 159.560 8974.26 9037.26 2243.61 S 614.30 E 5925568.62 N 709462.83 E 5.647 2162.57 10409.85 89.140 157.580 8974.73 9037.73 2264.89 S 622.65 E 5925547.58 N 709471.77 E 9.070 2184.60 10440.40 89.570 154.570 8975.07 9038.07 2292.81 S 635.04 E 5925520.01 N 709484.93 E 9.952 2214.36 10474.93 89.820 151.910 8975.26 9038.26 2323.64 S 650.59 E 5925489.62 N 709501.32 E 7.737 2248.35 10502.60 89.750 152.020 8975.36 9038.36 2348.06 S 663.59 E 5925465.57 N 709514.99 E 0.471 2275.68 10567.17 89.510 148.520 8975.78 9038.78 2404.12 S 695.61 E 5925410.41 N 709548.55 E 5.433 2339.73 10595.56 89.140 146.060 8976.11 9039.11 2428.01 S 710.95 E 5925386.96 N 709564.54 E 8.762 2368.04 10629.94 88.830 143.110 8976.72 9039.72 2456.02 S 730.86 E 5925359.51 N 709585.23 E 8.626 2402.40 10661.30 88.150 141.690 8977.55 9040.55 2480.86 S 749.99 E 5925335.21 N 709605.03 E 5.019 2433.75 26 March, 2003 - 14:19 Page 4 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17-D1A Your Ref: AP/S00292047601 Job No. AKZZ2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10689.25 87.910 139.450 8978.51 9041.51 2502.43 S 767.73 E 5925314.14 N 709623.36 E 8.055 2461.65 1072:1.04 87.290 134.490 8979.93 9042.93 2527.10 S 790.76 E 5925290.11 N 709647.06 E 14.780 2495.21 10754.01 87.420 131.580 8981 .36 9044.36 2548.21 S 813.37 E 5925269.64 N 709670.25 E 9.396 2525.67 10782AO 88.1 SO 127.040 8982.45 9045.45 2566.18 S 835.32 E 5925252.28 N 709692.68 E 16.185 2553.22 10816.77 89.940 121.890 8983.03 9046.03 2585.62 S 863.64 E 5925233.63 N 709721.53 E 15.861 2585.77 10847.83 92.030 118.740 8982.49 9045.49 2601.29 S 890.44 E 5925218.71 N 709748.76 E 12.169 2614.41 --- 10878.50 93.020 116.840 8981.14 9044.14 2615.58 S 917.55 E 5925205.18 N 709776.25 E 6.980 2642.11 10909.78 93.570 114.290 8979.34 9042.34 2629.05 S 945.71 E 5925192.48 N 709804.78 E 8.326 2669.81 10941 .25 94.560 111 .260 8977.11 9040.11 2641.20 S 974.65 E 5925181.14 N 709834.04 E 10.106 2696.91 10969.13 94.370 109.050 8974.94 9037.94 2650.78 S 1000.75 E 5925172.29 N 709860.39 E 7.932 2720.24 11002.55 93.880 104.850 8972.54 9035.54 2660.49 S 1032.62 E 5925163.46 N 709892.52 E 12.620 2747.16 11033.62 93.690 104.240 8970.49 9033.49 2668.28 S 1062.63 E 5925156.50 N 709922.74 E 2.052 2771.41 11061 .98 92.650 103.340 8968.92 9031.92 2675.03 S 1090.13 E 5925150.52 N 709950.41 E 4.846 2793.33 11107.57 90.120 100.330 8967.81 9030.81 2684.37 S 1134.73 E 5925142.41 N 709995.25 E 8.623 2827.60 11154.71 89.940 100.000 8967.79 9030.79 2692.69 S 1181.13E 5925135.37 N 710041.86 E 0.797 2862.13 11201 .45 89.820 100.180 8967.89 9030.89 2700.88 S 1227.15 E 5925128.46 N 710088.09 E 0.463 2896.32 11249.33 89.380 100.290 8968.22 9031.22 2709.39 S 1274.27 E 5925121.26 N 710135.42 E 0.947 2931 .43 11342.78 86.310 96.640 8971.74 9034.74 2723.14 S 1366.60 E 5925110.07 N 710228.11 E 5.101 2997.90 11390.94 85.750 94.090 8975.07 9038.07 2727.63 S 1414.43 E 5925106.90 N 710276.04 E 5.409 3030.23 11436.19 84.890 93.440 8978.76 9041.76 2730.59 S 1459.44 E 5925105.19 N 710321.11 E 2.379 3059.64 11530.89 88.570 94.350 8984.16 9047.16 2737.01 S 1553.75 E 5925101.37 N 710415.56 E 4.003 3121 .44 11624.79 89.140 93.870 8986.04 9049.04 2743.74 S 1647.38 E 5925097.24 N 710509.35 E 0.794 3183.08 11718.21 89.020 92.850 8987.54 9050.54 2749.21 S 1740.63 E 5925094.34 N 710602.71 E 1.099 3243.48 11811 .48 91 .050 96.040 8987.48 9050.48 2756.44 S 1833.60 E 5925089.69 N 710695.85 E 4.054 3305.12 ---' 11905.16 92.340 97.550 8984.71 9047.71 2767.52 S 1926.58 E 5925081.18 N 710789.10 E 2.119 3369.84 11998.39 92.650 97.330 8980.65 9043.65 2779.58 S 2018.94 E 5925071.68 N 710881.75 E 0.408 3434.97 12091.12 91 .230 96.590 8977.52 9040.52 2790.81 S 2110.93 E 5925063.00 N 710974.02 E 1.727 3499.22 12182.01 91. 050 97.130 8975.71 9038.71 2801.66 S 2201.15 E 5925054.64 N 711064.50 E 0.626 3562.10 12270.00 91.050 97.130 8974.09 9037.09 2812.58 S 2288.44 E 5925046.14 N 711152.07 E 0.000 3623.28 Projected Survey 26 March, 2003 - 14:19 Page 5 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17·01 A Your Ref: AP/500292047601 Job No. AKZZ2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 143.070° (True). Magnetic Declination at Surface is 26.084°(24-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12270.00ft., The Bottom Hole Displacement is 3625.96ft., in the Direction of 140.867° (True). '- Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6793.00 6874.00 12270.00 6662.38 6730.27 9037.09 557.87 S 594.33 S 2812.58 S 359.54 E 384.48 E 2288.44 E Tie On Point Window Point Projected Survey Survey tool program for 17-01A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) -" 0.00 6793.00 0.00 6662.38 6793.00 12270.00 6662.38 BP High Accuracy Gyro(17-01) 9037.09 AK-6 BP _IFR-AK(17-01A) 26 March. 2003 - 14:19 Page 6 of 6 DrillQuest 3.03.02.002 \ '\ ) ) 26-Mar-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 17-01A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,793.00' MD Window / Kickoff Survey: 6,874.00 I MD (if applicable) Projected Survey: 12,270.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 1 7 2003 Aiaaka em & Gas Cons. C<JmmiMtgn AnChorage a03-~g-- Sperry-Sun Drilling Services North Slope Alaska BPXA 17-01A MWD '-of Job No. AKMW2302699, Surveyed: 13 March, 2003 Survey Report 26 March, 2003 Your Ref: API 500292047601 Surface Coordinates: 5927794.39 N, 708786.75 E (70012' 21.8461" N, 148018' 59.6777" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 63.00ft above Mean Sea Level - 5pal1.....y-5uf1 DRILLING SERVIc:es A Halliburton Company Survey Ref: svy3999 Sperry-Sun Drilling Services Survey Report for 17-01A MWD Your Ref: AP/500292047601 Job No. AKMW2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6793.00 33.170 1 45. 1 00 6599.38 6662.38 557.87 S 359.54 E 5927246.67 N 709161.57 E 661.97 Tie On Point MWD Magnetic 6874.00 32.930 146.160 6667.27 6730.27 594.33 S 384.48 E 5927210.91 N 709187.51 E 0.773 706.10 Window Point 69!1?.06 802110 1 116.230 6733.76 6796.76 628.30 S 407.22 E 5927177.58 N 709211.19 E 3.446 746.92 mnn02 ¿~J .5¿O 1 l1~t080 G7GO.ö 1 6823.61 640.88 S 416.14 E 5927165.25 N 709220.45 E 5.57G 7G2.311 7011.61 28.070 150.860 6785.67 6848.67 652.39 S 423.65 E 5927153.96 N 709228.27 E 14.044 776.05 ~. 7046.24 24.870 135.520 6816.70 6879.70 664.72 S 432.73 E 5927141.88 N 709237.69 E 21.727 791.36 7075.67 23.500 125.340 6843.56 6906.56 672.54 S 441.86 E 5927134.32 N 709247.03 E 14.896 803.09 7105.72 22.650 146.830 6871 .25 6934.25 680.86 S 449.93 E 5927126.23 N 709255.33 E 28.028 814.59 7139.75 21.010 143.350 6902.84 6965.84 691.24 S 457.15 E 5927116.05 N 709262.84 E 6.137 827.23 7171.38 18.110 141.360 6932.65 6995.65 699.63 S 463.61 E 5927107.84 N 709269.52 E 9.406 837.82 7199.86 15.810 139.820 6959.89 7022.89 706.05 S 468.88 E 5927101.57 N 709274.97 E 8.228 846.12 7234.27 14.000 137.160 6993.14 7056.14 712.69 S 474.73 E 5927095.10 N 709281.00 E 5.622 854.94 7265.01 13.560 135.670 7022.99 7085.99 717.99 S 479.78 E 5927089.93 N 709286.19 E 1.839 862.21 7293.02 12.620 134.920 7050.27 7113.27 722.50 S 484.24 E 5927085.55 N 709290.78 E 3.410 868.50 7327.29 10.620 127.620 7083.84 7146.84 727.07 S 489.39 E 5927081.12 N 709296.06 E 7.233 875.25 7355.54 9.310 120.020 7111.67 7174.67 729.81 S 493.43 E 5927078.50 N 709300.17 E 6.561 879.86 7386.67 7.990 101.690 7142.45 7205.45 731.51 S 497.73 E 5927076.92 N 709304.52 E 9.762 883.80 7418.72 7.950 79.530 7174.20 7237.20 731.55 S 502.10 E 5927076.99 N 709308.88 E 9.529 886.46 7448.02 8.590 65.340 7203.19 7266.19 730.27 S 506.08 E 5927078.39 N 709312.82 E 7.279 887.83 7479.21 9.300 55.190 7234.01 7297.01 727.86 S 510.26 E 5927080.91 N 709316.94 E 5.539 888.42 7513.53 9.570 44.170 7267.86 7330.86 724.23 S 514.53 E 5927084.66 N 709321 . 1 0 E 5.314 888.08 7541.02 9.480 33.830 7294.98 7357~98 720.71 S 517.38 E 5927088.25 N 709323.86 E 6.225 886.98 7572.18 8.710 21 .280 7325.75 7388.75 716.38 S 519.67 E 5927092.65 N 709326.02 E 6.812 884.89 ~ 7606.09 8.660 9.540 7359.27 7422.27 711.47 S 521.02 E 5927097.59 N 709327.24 E 5.221 881.78 7636.94 9.880 356.690 7389.72 7452.72 706.54 S 521.25 E 5927102.53 N 709327.34 E 7.764 877.98 7665.77 10.780 350.810 7418.09 7481.09 701.41 S 520.68 E 5927107.64 N 709326.62 E 4.805 873.53 7726.66 8.030 353.810 7478.15 7541.15 691.56 S 519.31 E 5927117.45 N 709324.98 E 4.586 864.83 7757.91 6.430 1.300 7509.15 7572.15 687.64 S 519.12 E 5927121.37 N 709324.68 E 5.932 861 .58 7791.97 5.350 7.090 7543.03 7606.03 684.15 S 519.36 E 5927124.85 N 709324.82 E 3.615 858.94 7851.00 4.540 2.920 7601.84 7664.84 679.09 S 519.82 E 5927129.93 N 709325.14 E 1.500 855.17 26 March. 2003 - 14:28 Page 2 of6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17-01 A MWD Your Ref: API 500292047601 Job No. AKMW2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7908.32 3.670 10.700 7659.02 7722.02 675.02 S 520.27 E 5927134.01 N 709325.48 E 1.799 852.19 7944.26 3.340 15.560 7694.89 7757.89 672.88 S 520.77 E 5927136.16 N 709325.92 E 1.235 850.78 8037.53 3.460 74.500 7788.02 7851.02 669.51 S 524.21 E 5927139.63 N 709329.26 E 3.587 850.15 0130.38 3.510 141.110 7880.73 7943.73 670.98 8 528.69 E 5927138.29 N 709333.79 E 4.120 854.02 8223.55 7.500 176.310 7973.48 8036.48 679.278 530.88 E 5927130.06 N 709336.20 E 5.422 861.96 8253.08 10.510 181 .280 8002.64 8065.64 683.89 S 530.94 E 5927125.44 N 709336.39 E 10.519 865.69 8288.98 14.040 186.480 8037.72 8100.72 691.49 S 530.38 E 5927117.83 N 709336.04 E 10.294 871.43 _r 8317.72 16.860 187.910 8065.41 8128.41 699.08 S 529.41 E 5927110.21 N 709335.28 E 9.901 876.91 8351.23 20.240 188.440 8097.18 8160.18 709.63 S 527.89 E 5927099.62 N 709334.05 E 10.099 884.44 8382.44 21 .850 188.010 8126.31 8189.31 720.72 S 526.29 E 5927088.49 N 709332.76 E 5.182 892.34 8411.24 23.190 186.460 8152.91 8215.91 731.67 S 524.90 E 5927077.51 N 709331.68 E 5.089 900.25 8444.51 25. 180 183.350 8183.26 8246.26 745.24 S 523.75 E 5927063.91 N 709330.90 E 7.100 910.42 8476.70 27.11 0 180.130 8212.16 8275.16 759.42 S 523.33 E 5927049.73 N 709330.88 E 7.440 921 .49 8505.27 28.040 178.410 8237.48 8300.48 772.64 S 523.51 E 5927036.52 N 709331.41 E 4.285 932.17 8538.36 29.410 179.220 8266.50 8329.50 788.54 8 523.83 E 5927020.63 N 709332.18 E 4.304 945.07 8570.27 31.920 179.090 8293.94 8356.94 804.81 S 524.07 E 5927004.38 N 709332.87 E 7.869 958.22 8598.47 32.360 179.520 8317.82 8380.82 819.81 8 524.26 E 5926989.39 N 709333.47 E 1.759 970.32 8692.64 30.910 179.930 8398.00 8461.00 869.20 S 524.50 E 5926940.02 N 709335.07 E 1.557 1009.95 8786.31 31.320 181.470 8478.19 8541 .19 917.60 S 523.90 E 5926891.63 N 709335.82 E 0.956 1048.28 8880.13 29.210 182.370 8559.22 8622.22 964.85 8 522.33 E 5926844.34 N 709335.55 E 2.300 1085.11 8973.54 30.020 178.440 8640.43 8703.43 1010.99 S 522.02 E 5926798.22 N 709336.52 E 2.252 1121.81 9066.08 31.930 176.780 8719.78 8782.78 1058.57 S 524.03 E 5926750.71 N 709339.84 E 2.261 1161 .04 9124.38 30.790 177.670 8769.56 8832~56 1088.87 S 525.50 E 5926720.46 N 709342.15 E 2.111 1186.15 9197.45 33.480 176.490 8831 .43 8894.43 1127.68 S 527.49 E 5926681.72 N 709345.21 E 3.780 1218.37 9215.16 36.320 176.030 8845.95 8908.95 1137.79 S 528.16 E 5926671.63 N 709346.16 E 16.105 1226.85 ..~ 9229.78 38.310 175.990 8857.58 8920.58 1146.638 528.77 E 5926662.81 N 709347.02 E 13.613 1234.29 9261.20 42.860 175.190 8881.43 8944.43 1167.01 S 530.35 E 5926642.49 N 709349.16 E 14.575 1251.53 9290.24 46.800 176.380 8902.03 8965.03 1187.42 S 531.85 E 5926622.13 N 709351.22 E 13.871 1268.74 9323.19 52. 1 50 179.480 8923.43 8986.43 1212.44 S 532.73 E 5926597.14 N 709352.79 E 17.738 1289.27 9353.34 56.280 181.910 8941.06 9004.06 1236.88 8 532.42 E 5926572.70 N 709353.15 E 15.177 1308.62 9382.38 60.000 182.070 8956.39 9019.39 1261.538 531.56 E 5926548.04 N 709352.98 E 12.818 1327.81 9416.47 65.760 182.190 8971.92 9034.92 1291.84 S 530.43 E 5926517.71 N 709352.69 E 16.899 1351.36 9446.57 69.770 183.200 8983.31 9046.31 1319.668 529.12 E 5926489.86 N 709352.14 E 13.679 1372.81 9475.26 75.050 183.510 8991.97 9054.97 1346.95 S 527.52 E 5926462.53 N 709351.30 E 18.432 1393.67 9503.28 78.980 185.670 8998.27 9061.27 1374.16 S 525.33 E 5926435.27 N 709349.86 E 15.910 1414.10 26 March, 2003 - 14:28 Page 30f6 DrillQl1est 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17-01 A MWD Your Ref: AP/500292047601 Job No. AKMW2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9542.38 86.550 185.920 9003.19 9066.19 1412.72 S 521.41 E 5926396.62 N 709347.02 E 19.371 1442.58 9569.88 91.230 186.470 9003.72 9066.72 1440.05 S 518.45 E 5926369.22 N 709344.81 E 17. 1 35 1462.64 9603.30 94.190 186.230 9002.14 9065.14 1473.23 S 514.76 E 5926335.96 N 709342.03 E 8.886 1486.94 962A.19 96.660 1 A6.440 8999.79 9062.79 1497.85 S 512.02 E 5926311.27 N 709339.98 E 9.959 1504.98 9661.60 96.600 185.680 8995.93 9058.93 1530.85 S 508.52 E 5926278.18 N 709337.39 E 2.267 1529.25 9697.25 96.470 185.760 8991.87 9054.87 1566.09 S 504.99 E 5926242.85 N 709334.84 E 0.427 1555.30 9728.13 96.480 185.940 8988.39 9051 .39 1596.62 S 501.86 E 5926212.26 N 709332.55 E 0.580 1577.83 -- 9756.21 97.410 183.910 8985.00 9048.00 1624.39 S 499.47 E 5926184.43 N 709330.93 E 7.904 1598.59 9790.61 98.580 180.200 8980.21 9043.21 1658.42 S 498.24 E 5926150.37 N 709330.65 E 11.208 1625.06 9821.38 100.380 177.390 8975.14 9038.14 1688.76 S 498.88 E 5926120.06 N 709332.12 E 10.740 1649.69 9849.94 100.650 175.900 8969.93 9032.93 1716.79 S 500.52 E 5926092.09 N 709334.54 E 5.216 1673.09 9884.63 99.270 174.290 8963.93 9026.93 1750.83 S 503.45 E 5926058.14 N 709338.40 E 6.060 1702.05 9943.92 95.300 171.670 8956.41 9019.41 1809.19 S 510.64 E 5926000.01 N 709347.20 E 8.003 1753.02 9978.24 90.800 170.840 8954.59 9017.59 1843.05 S 515.85 E 5925966.30 N 709353.35 E 13.332 1783.22 10009.52 86.240 168.440 8955.39 9018.39 1873.80 S 521.47 E 5925935.72 N 709359.82 E 16.472 1811.18 10038.05 85.940 168.720 8957.34 9020.34 1901.70 S 527.10 E 5925907.99 N 709366.22 E 1 .437 1836.87 10072.45 86.240 168.830 8959.68 9022.68 1935.36 S 533.78 E 5925874.52 N 709373.83 E 0.929 1867.79 10103.82 86.550 168.490 8961.66 9024.66 1966.06 S 539.94 E 5925844.01 N 709380.83 E 1 .465 1896.03 10131.83 87.540 167.800 8963.10 9026.10 1993.43 S 545.69 E 5925816.80 N 709387.33 E 4.306 1921.36 10165.76 87.350 167.470 8964.61 9027.61 2026.54 S 552.95 E 5925783.90 N 709395.50 E 1.121 1952.19 10196.68 87.230 167.220 8966.08 9029.08 2056.68 S 559.71 E 5925753.97 N 709403.10 E 0.896 1980.35 10224.78 87.170 167.470 8967.45 9030.45 2084.06 S 565.86 E 5925726.76 N 709410.00 E 0.914 2005.93 10259.24 87.110 167.180 8969.17 9032.17 2117.64 S 573.41 E 5925693.41 N 709418.48 E 0.858 2037.31 10289.71 87.170 168.400 8970.69 9033.69 2147.39 S 579.85 E 5925663.85 N 709425.74 E 4.004 2064.95 10317.89 87.230 167.320 8972.06 9035.06 2174.90 S 585.77 E 5925636.51 N 709432.41 E 3.834 2090.50 - 10351.50 88.280 161.680 8973.38 9036.38 2207.25 S 594.74 E 5925604.42 N 709442.28 E 17.056 2121.75 10386.98 88.520 160.770 8974.37 9037.37 2240.83 S 606.15 E 5925571.17 N 709454.62 E 2.652 2155.45 10409.85 89.140 158.440 8974.84 9037.84 2262.26 S 614.12 E 5925549.97 N 709463.17 E 10.540 2177.37 10440.40 89.570 155.230 8975.18 9038.18 2290.34 S 626.14 E 5925522.23 N 709475.96 E 10.601 2207.04 10474.93 89.820 152.310 8975.37 9038.37 2321.31 S 641.40 E 5925491.69 N 709492.07 E 8.487 2240.96 10502.60 89.750 152.260 8975.47 9038.47 2345.81 S 654.27 E 5925467.56 N 709505.61 E 0.311 2268.28 10567.17 89.510 148.770 8975.89 9038.89 2402.00 S 686.04 E 5925412.27 N 709538.93 E 5.418 2332.29 10595.56 89. 140 146.400 8976.22 9039.22 2425.97 S 701.26 E 5925388.73 N 709554.80 E 8.449 2360.59 10629.94 88.830 142.640 8976.83 9039.83 2453.95 S 721.21 E 5925361.31 N 709575.51 E 10.972 2394.95 10661.30 88.150 142.190 8977.66 9040.66 2478.80 S 740.33 E 5925337.00 N 709595.31 E 2.600 2426.29 26 March. 2003 - 14:28 Page 4 of 6 DrillQlIest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17-01A MWD Your Ref: AP/500292047601 Job No. AKMW2302699, Surveyed: 13 March, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10689.25 87.910 139.780 8978.62 9041 .62 2500.50 S 757.91 E 5925315.80 N 709613.49 E 8.660 2454.21 10723.04 87.290 134.450 8980.04 9043.04 2525.23 S 780.88 E 5925291.71 N 709637.13 E 15.866 2487.77 10754.01 87.420 131.920 8981.47 9044.47 2546.40 S 803.43 E 5925271.17 N 709660.26 E 8.171 2518.25 1 0782.40 88.150 127.670 8982.56 9045.56 2564.55 S 825.22 E 5925253.63 N 709682.55 E 15.178 2545.85 10816.77 89.940 123.330 8983.14 9046.14 2584.50 S 853.19 E 5925234.46 N 709711.06 E 13.657 2578.60 10847.83 92.030 120.730 8982.60 9045.60 2600.97 S 879.52 E 5925218.73 N 709737.83 E 10.739 2607.58 - 10878.50 93.020 106.090 8981 .24 9044.24 2613.11 S 907.56 E 5925207.37 N 709766.19 E 47.796 2634.14 10909.78 93.570 105.330 8979.45 9042.45 2621.57 S 937.62 E 5925199.74 N 709796.48 E 2.996 2658.96 10941.25 94.560 107.650 8977.21 9040.21 2630.48 S 967.72 E 5925191.67 N 709826.81 E 7.998 2684.16 1 0969. 13 94.370 108.200 8975.04 9038.04 2639.03 S 994.16 E 5925183.85 N 709853.48 E 2.081 2706.89 11002.55 93.880 106.140 8972.64 9035.64 2648.87 S 1026.01 E 5925174.89 N 709885.59 E 6.320 2733.89 11033.62 93.690 106.450 8970.59 9033.59 2657.57 S 1055.77 E 5925167.02 N 709915.57 E 1.168 2758.73 11061.98 92.650 103.160 8969.02 9032.02 2664.80 S 1083.14 E 5925160.55 N 709943.14 E 12.150 2780.95 11107.57 90. 120 100.710 8967.92 9030.92 2674.23 S 1127.72 E 5925152.36 N 709987.96 E 7.724 2815.28 11154.71 89.940 100.120 8967.89 9030.89 2682.75 S 1174.09 E 5925145.12 N 710034.54 E 1.309 2849.94 11201.45 89.820 100.420 8967.99 9030.99 2691.08 S 1220.08 E 5925138.06 N 710080.75 E 0.691 2884.24 11249.33 89.380 100.910 8968.33 9031 .33 2699.94 S 1267.13 E 5925130.51 N 710128.03 E 1.375 2919.59 11342.78 86.310 96.800 8971.84 9034.84 2714.31 S 1359.37 E 5925118.69 N 710220.63 E 5.487 2986.50 11390.94 85.750 93.270 8975.18 9038.18 2718.53 S 1407.22 E 5925115.80 N 710268.58 E 7.404 3018.62 11436.19 84.890 93.210 8978.87 9041 .87 2721.08 S 1452.24 E 5925114.49 N 710313.66 E 1.905 3047.72 11530.89 89.570 95.860 8983.44 9046.44 2728.56 S 1546.50 E 5925109.62 N 710408.09 E 5.677 3110.33 11624.79 89.140 94.620 8984.50 9047.50 2737.14 S 1640.00 E 5925103.63 N 710501.79 E 1.398 3173.36 11718.21 89.020 93.840 8986.00 9049'.00 2744.03 S 1733.16 E 5925099.32 N 710595.10 E 0.845 3234.84 11811.48 91 .050 96.040 8985.94 9048.94 2752.06 S 1826.07 E 5925093.86 N 710688.19 E 3.209 3297.08 '-" 11905.16 92.340 97.390 8983.17 9046.17 2763.00 S 1919.06 E 5925085.49 N 710781.45 E 1.993 3361.71 11998.39 92.650 96.720 8979.11 9042.11 2774.44 S 2011.50 E 5925076.61 N 710874.17 E 0.791 3426.39 12091 . 12 91 .230 95.070 8975.98 9038.98 2783.96 S 2103.68 E 5925069.64 N 710966.58 E 2.347 3489.39 12182.01 91.050 95.830 8974.17 9037.17 . 2792.59 S 2194.14 E 5925063.52 N 711057.24 E 0.859 3550.64 12270.00 91.050 95.830 8972.55 9035.55 2801.53 S 2281.66 E 5925057.00 N 711144.98 E 0.000 3610.37 Projected Survey 26 March, 2003 - 14:28 Page 50f6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 17-01A MWD Your Ref: AP/500292047601 Job No. AKMW2302699~ Surveyed: 13 March, 2003 '? BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 143.070° (True). Magnetic Declination at Surface is 26.086"(22-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12270.00ft., The Bottom Hole Displacement is 3613.11ft., in the Direction of 140.839° (True). ~. Comments Measured Depth (It) Station Coordinates TVD Northings Eastings (It) (It) (It) Comment 6793.00 6874.00 12270.00 6662.38 6730.27 9035.55 557.87 S 594.33 S 2801.53 S 359.54 E 384.48 E 2281.66 E Tie On Point Window Point Projected Survey Survey tool proqram for 17-01A MWD From Measured Vertical Depth Depth (ft) (It) To Measured Vertical Depth Depth Survey Tool Description (It) (It) ---- 0.00 6793.00 0.00 6662.38 6793.00 12270.00 6662.38 BP High Accuracy Gyro(17-01) 9035.55 MWD Magnetic(17-01A MWD) 26 March, 2003 - 14:28 Page 6 of 6 Dríl10uest 3.03.02.002 ~u&\~E I~ ) 'f &\~&\~~~&\ .\ ) I ~ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COJDIISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage Alaska 99519 Re: Prudhoe Bay Unit 17-01A BP Exploration (Alaska), Inc. Permit No: 203-028 Surface Location: 2443' NSL, 523' EWL, Sec. 22, TI0N, RISE, UM Bottomhole Location: 291' SNL, 2572' EWL, Sec. 27, TI0N, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~?~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 7f2. day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section v..I 0;/t- 2-/ ffp { Ô '"$ Hole 8-1/2" 6-1/8" STATE OF ALASKA .'. ALASKA_l AND GAS CONSERVATION cOMrv~._110N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 11 Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 63' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028334 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' 17-01A 9. Approximate spud date., 02/25/03 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 /'12039' MD / 9048' TVD o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 98 Maximum surface 3075 psig, At total depth (TVD) 9009' / 3607 psig Setting Depth TaD Bottom Lenath MD TVD MD TVD 6520' 2650' 2650' 9169' 8872' 3019' 9020' 87451 12039' 9048' / 1 a. Type of work 0 Drill 11 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 708787, Y = 5927794 2443' NSL, 523' EWL, SEC. 22, T10N, R15E,UM At top of productive interval x = 709364, Y = 5926330 963' NSL, 1057' EWL, SEC. 22, T10N, R15E,UM At total depth x = 710916, Y = 5925119 291' SNL, 2572' EWL, SEC. 27, T10N, R15E,UM 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well /' ADL 028331, 291' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 6850' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade COUDlina 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 IBT Quantitv of Cement (include staae data) 168 sx Class 'G', 600 sx Class 'G' ,/ Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9932 feet Plugs (measured) true vertical 9644 feet Effective depth: measured 9006 feet Junk (measured) true vertical 8721 feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 110' 20" 2682' 13-3/8" 9010' 9-5/8" 1221' 7" 300 sx Permafrost 3400 sx Fondu, 400 sx Permafrost 110' 2682' 110' 2682' 500 sx Class 'G' 425 sx Class 'G' 9010' 8703' - 9924' 8725' 8419' - 9636' Perforation depth: measured R· E' C tW'o Ir 1& ~ . '\ JC ~' ~ \\. ",',"", tì 9166' - 9190', 9192' - 9206', 9214' - 9226', 9272' - 9300', 9318' - 9338' r' ,l~ Ii II"" true vertical 8880' - 8904', 8906' - 8920', 8928' - 8940', 8986' - 9014', 9032' - 9052' l~'~ E.: E· 0 :~. )()q,'~) c..1. \J .,.> 20. Attachments 11 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter ske~a:¡:iJ1¡~i~' !~S;~~r:~:~,:j':~;'~1\f.:~¡Of; 11 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 11 20 AA~·12~~gweqUirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Billlsaacson 1J.Jl ,Å. ~" .. Title s~ni~rD~"ingEngineer ::~i$SiOn'.Qàe:'º"IY:· " Date F;:g 5"Jlf ~6"3 1 Permit Number Lo3 - 0 ¿ (? Conditions of Approval: API Number 50- 029-20476-01 Samples Required 0 Yes [lI No Hydrogen Sulfide Measures Jg(Ves 0 No Required Working Pressure for BOPE 0 2K 0 3K Other:TÐSi-15o PE /-0 "5Ç"OO p!..ii.. ORIGINAL SIGNED BY M l. ßUI App,.fÇ>val D~ See cover letter f)( 1 Ii '1 for other requirements Mud Log Re~ui'ed 0 Ves ~ No Directional Survey Required 2g Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU Approved By Form 10-401 Rev. 12-01-85 by order of Commis.s.iooer... "\ ,.th~, Cl. mmission I ~ \1 " \. , :1 1'1 ~<~..) \~~ ~ .~..,~):J ,t .: ~I ~i.~~\~ Date ,?-\1(C'1 Submit (~ T{¡plicate )) \ Well Name: IOS17-01A Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 4 Bottom Hole Location: x = 708,787 Y = 5,927,794 24431 FSL, 523' FWL Sec. 22, T10N, R15E Umiat X = 709,364 Y = 5,926,330 TVDss 8995 963' FSL, 1057' FWL Sec. 22, T10N, R15E Umiat X = 710,916 Y = 5,925,119 TVDss 8985 2911 FNL, 2572' FWL Sec. 27, T10N, R15E Umiat I AFE Number: I P8D4P2054 I I Estimated Start Date: 102/25/03 I RiQ: I Nabors 2ES I I OperatinQ days to complete: 121.5 I MD: 112,039' I I TVD: 19,048' I I BF/MS: 134.5' I I KB: 128.5' I I KBE: 163' I Well DesiQn (conventional, slim hole, etc.): 1 Horizontal Sidetrack I Objective: I Zone 48 Formation Markers Formation Tops (wp05) MD TVD TVDss Comments WS1 CM3 6978 6820 -6757 CM2 7535 7359 -7296 THRZ 8725 8498 -8435 BHRZ 8881 8629 -8566 LCU / Top Kingak 8953 8690 -8627 TJA 9059 8779 -8716 TSGR 9168 8872 -8809 Top Shublik 9200 8898 -8835 TSAO / TZ4B 9300 8972 -8909 MHO 9468 9047 -8984 HOT 9511 9055 -8992 TAR 9531 9057 -8994 TO 12,039 9048 -8985 TD Criteria: TO when TSAO is reached on E side of fault, or if 4001 MO of productive section has been drilled E of fault and a trip is required. DS17-01A Sidetrack Page 1 ') ) Casing/Tubing Pro~.ram Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. /' ../ MDfTVD MDfTVD 8 Y2" 7" 26# L-80 BTC-M -6,520' 2650'/2650' 9,169 I 8,872' 61/8" 4 Y2" Slotted 12.6# L-80 IBT -3,019' 9020' I 8745' 12,039'19,048' Tubing 4 Y2" 12.6# 13Cr80 V AM ACE -8960' GL 9020' I 8745' Di rectional KOP: 16850' MD Maximum Hole Angle: -33.00 in 8 Y2" hole -98.4 0 in 6 1 18" horizontal section There are no close approach issues with the planned sidetrack. The closest well is DS17-04 at 1070' center-to-center in the reservoir section with an allowable deviation of 836'. MWD from kick-off to TD Close Approach Well: Survey Program: Mud Program Section Milling Mud Properties: LSND I Whip Stock Window 9 5/8" 1 Density (ppg) Viscosity PV VP tauo MBT PH API FI 10.0 50-60 14-18 50 - 60 6-8 8.0 - 9.0 NC Intermediate Mud Properties: LSND I 8 1/2" hole section I Density (P')J) 1 Q-Sec Gel PV VP tauo MBT PH API FI 10.6 40-50 12-14 30-35 6-8 8.0 - 9.0 <6 Production Mud Properties: Flo-Pro Drill-in 1 6 1/8" hole section I Density (ppg)--- LSRV PV VP LSVP MBT pH API FI 8.6- 8.7 55,000+ 7 -11 20 - 25 4-8 <6 9.0 - 9.5 4-6 Logging Program 8 %" Intermediate: Sample Catchers - from JD to casing point. Drilling: MWD Dir/GR/PWD- Real time GR/PWD throughout entire interval. Open Hole: None Cased Hole: None 6 118" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GRlRes- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: None DS17-01A Sidetrack Page 2 ') ) Cement ProQram Casing Size I 7" 26#, L-80 Intermediate Liner I Basis: Lead: None Tail: Bas e¡:n '&¿ , of 7" shoe track, 1000' of 7" x 8 V2" open hole with 40% excess Tail TOC: 1Qt MD /7990' TVD-bkb Fluid Sequence & -umes: Pre 10bbls CW 1 00 Flush Spacer Lead Tail Casing Size I 7" 26#, L-80 Tieback ./ Basis: Lead: None Tail: Based~ }1-050' of 7" x 9 5/8" casing annulus with 20% excess Tail TOC:t26§.eJ' MD / TVD-bkb Fluid Sequence &&,øfûmes: Pre 15bbls CW1 00 Flush Spacer Lead Tail 25bbls MudPUSH XL at 10.6 ppg None @ 35 bbls, 200 ft3, 6 sacks Class G @ 15.8 ppg, 1.17 ft3/sack I .- 35bbls MudPUSH XL at 10.6ppg None ,/ 125 bbls, 700 ft3'~SaCks Class G @ 15.8 ppg, 1.17 ft3/sack Casing Size 14 1/2", 12.6#, L-80 Slotted / Solid Production Liner Basis: I None. Uncemented solid/slotted liner Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8 ¥2" hole Production Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingl7" Liner Test Planned completion fluids DS17-01A Sidetrack 13-5/8", 5M, 3 MPL Gates with Annular (Hydril-13-5/8" GK) 3960 psi (8.6 ppg @ 8,854' TVD) /' 3075 psi (.10 psi/ft gas gradient to surface) 94 bbls with a 12.0 ppg LOT Rams test to 3,500 psi/250 psi. ./ Annular test to 2,500 psi/250 psi 3500 psi surface pressure FIT to 12.0 ppg after drilling 20' outside window 13-5/8", 5M, 3 MPL Gates with Annular (Hydril-13-5/8" GK) 3607 psi ( 7.7 ppg @ 9009' TVD) 2706 psi (.10 psi/ft gas gradient to surface) Infinite Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure 8.4 ppg Seawater / 7.2 ppg Diesel Page 3 ) ') Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure Summary pre-Rig Work: 1. Test the FMC 9-5/8" packoff and tubing hanger seals. 2. Rig up slickline, drift and tag. 3. RU coil tubing, liquid pack the tubing and lA, and P&A perforations with 500' of cement (20 bbls) to the production packer depth. 4. Test the integrity of the cement plug to 3000 psi for 30 minutes. 5. Chemical cut the 5%" tubing at ± 7,100' in the middle of a joint. 6. Circulate the well to seawater and shut-in. Monitor IA pressure until stable and calculate the balance brine weight with leak at 6000' MD/TVD. Circulate the well to balance brine weight + 0.2 ppg and freeze protect as required. 7. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Rig Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater andlor weighted brine. Set TWC. 3. Nipple Qown tree. Nipple up and test BOPE. 4. Pull 5%" tubing from above pre-rig cut. 5. MU window milling BHA and drift down through the BP setting depth. Set BP on E-line (set as needed to avoid cutting casing collar). 6. RIH with 9-5/8" test packer to -2700' MD and test 9-5/8" casing back to surface to verify integrity (for upcoming tie-back liner to repair Cretaceous leak). POH. 7. RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Mill window in 9 5/8" casing at ±6,850' MD plus 20' minimum open hole below the window top. Perform FIT to 12.0 ppg EMW. POH. 8. Kick-off and drill the 8%" section to the top of the Sag River at -9169' MD. 8. Run and cement a 7", 26# L-80 intermediate drilling liner, cemented -1000' above the 7" casing shoe. 9. Run and cement a 7" 26# L-80 tie-back liner to cover Cretaceous interval. Liner is planned to extend from top of newly installed drilling liner, up to -2650' MD (surface casing shoe). 10. RIH with 6-1/8" directional assembly to the landing collar in the tie-back liner. Test 9-5/8" casing and 7" liner above to 3500 psi. 11. Drill out the landing collar and RIH to drilling liner shoe. Re-test the casing to 3500 psi. Drill the shoe tract and 20' of new formation. Perform FIT with 10.6 ppg mud. Change mud over to 8.6 ppg Flo-Pro. 12. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3500 psi for 30 minutes. - 7, 13. Drill the 6-1/8" production section as per directional plan to an estimated TO of 12,039' MD. 14. Run a 4 %", 12.6# L-80 production liner consisting of a combination of solid and slotted liner. Displace well to clean seawater above liner top. POH LD DP. 15. Run 4-1/2",12.6# 13Cr-80 completion tying into the 4-1/2" liner top. 16. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure the well. 19. Rig down and move off. /' // /' DS17-01A Sidetrack Page 4 ) ) Post-RiQ Work: 1. Install wellhouse and flow lines. 2. MIRU slickline. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. Job 1: MIRU Hazards and Contingencies )-. No wells will require shut-in for the rig move onto DS17-01A. The well is on the end of a row with OS17-02 at 120' center as it's closest neighboring well. )-. D517 is an H2S site. Coordinate with the DS operator prior to moving onto the pad for special H2S considerations. An H2S contingency plan should be posted in the doghouse and reviewed with all personnel. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: / 17 -02 20ppm 17 -04AL 1 10 ppm 17-03 12ppm 17-16 24 ppm The maximum level recorded of H2S on the pad was 186 ppm on DS17-11 in 03/1997. OS 17-11 has since recorded 100 ppm in June, 2003 and most recently 22 ppm in November. Only two other wells have recorded higher than 100 ppm: 17-05 and 17-20. These wells most recently recorded at 55 ppm in June and 61 ppm in November, respectively. ~ Post Permit to Drill in camp prior to spud. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP ~_w _:~:.I.lil::mm~~·:::::_'--:'T _:__IIIII\i~«<+I!4+I-:m:T:t:T_:.I:mmr:!1o.16~UI- "11-- .1.!III.!iI!1II!Io'1! 1_ :IIIIII! .lm":::I:::!!"':II:a:--,!; _1_ _: _1_ '111_ IIIII:1Imnl:III!II,,111umll-- .I::-n:\ --.1:1:1. IIIIIrl'.llllml;I'Ilm:II1I\I'Clmllum:'-,:--II':111 Job 2: De-complete Well Hazards and Contingencies )-. The lower section of this well is isolated by 2 barriers - the cement plug over the perforations and kill weight seawater. The cretaceous leak in the 9 5/8" casing will by isolated by the tubing hanger and BPV and kill-weight fluid only. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is an FMC Gen \I and has a 5 Y2" tubing hanger with 5 3,4" LH Acme running threads. Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies )-. Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP OS17-01A Sidetrack Page 5 ) ') ~m,I.-.-¡':.:m),;;,;nm''-.,.,.-,¡'-,.-,I:,I.I'-,::,:¡'.-,__,I,:.:',I,:,.t,I',a,:,r.I,:¡,,:J.;;~¡¡.-,:;'-,:'-'-''-,._.:c"-.a!,I,I,~,:;,:"~,:,I.;'-¡,I.~I:,,,.,,,,~;,;¡:m¡,:.-,,:',).:":,;~am_lffl,I,.I.I,;,U_I,:,.I~-,_,:,.I,~,I}.I,,:,I.',:.~J«.¡:-:;~>",~,...m,.m'rl!'-I!M;,::¡,:!¡' .'. :~,_,¡:.,:;;;;;~·,:m¡mm_I¡,I)!,I,IJ,I,I.lm~.I,:,¡,I;,¡,~¡,'.I',,~::::o:o:-:¡~,,I,I'!,:.:'.I!,I",I,lm.I!,:¡',I>,I;',~,~,I',I.~.r!_!.::I,:,I:,;). Job 5: Drill 8 Y2" Intermediate Hole Hazards and Contingencies » The intermediate section will kick off in mid Colville and drill the about 160' of HRZ and 220' of Kingak before the top of Sag River. Previous 0817 wells drilled the Kingak with 9.8 to 10.2ppg mud weights. For this well direction and inclination 10.4 ppg MW should be adequate to stabilize the shales. Maintain mud weight at 10.6 ppg for safety factor. Follow all shale drilling practices to minimize potential problems. » There are no faults prognosed in the intermediate section. » KICK TOLERANCE: In the worst-case scenario of 9.8 ppg pore pressure at the Sag River depth, a fracture gradient of 12.0 ppg at the 9 5/8" casing window, and 10.6 ppg mud in the hole, the kick tolerance is 94 bbls. Reference RP .:. "Shale Drilling, Kingak and HRZ" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" I . \h., . I "" I . ,...,......:.. ~\ I' ~~ :'- :n::.:L.:.:II-'I::~I:m~I:H_*1:m g·1;~~1:~:,. ",..,.--y ':T'::I' Job 6: Install 7" Intermediate and Tieback Liners Hazards and Contingencies » Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. » Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. » The cretaceous leak at ±6000' will need to hold the hydrostatic head of 4300' of 15.8 ppg cement until the cement sets. Be prepared with LCM as required to stop losses at the cretaceous after releasing from the drilling liner hanger (prior to POH for the scab liner). Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP IUI:".LIIIIUlllwmllnll;I:--IIIIUIlIU'II: ,_ A"'II'W~'. _IUL _BI Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies » There is just one fault crossing anticipated: 20-35' of throw to the east at 11,090' MD (8995' TVDss). Uncertainty in location is ±200'. Should the faults cause losses, follow the Lost Circulation Decision Tree. » The anticipated reservoir pressure is around 3300 psi. At 8.6 ppg the Flo-Pro mud density will provide about 600 psi overbalance. The reservoir pressure may be higher due to neighboring injection well DS17-15Ai, on injection at about 5000 bpwpd. An accurate static BHP from 17-15Ai is not available, but pressure falloff data from January 2001 suggests that it is less than the DS17 -01 A Sidetrack Page 6 ) ') hydrostatic of seawater. TO of DS17-01A will be the closest point to DS17-15A horizontal section at about 1150' to the north-northeast. One other pressure anomaly exists in the area: DS17-05 measured 3672 psi BHSP in June 2002. This well is 2400' west and 2600' north (3500' away) of the heel of the planned horizontal section. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP õI:'~r\'l.-.· .'r:'~''-:'-;'-:,··'f"fm~~~'''''I,~~~~~,;¡o:;~~I(-~'.,.M.~.~~"",,,,,,,,.,,,,,,,,,,~,,,,",,.......,~'".,;"....\'o,...·~,...·,~."'¡"'I.I,'.~·,','t'·:,'...:-.~..-,"'l,Vj¡.,'""'P:'·I,.':',''''''''''~W~~w...~11M1/O 1,·~I"w#rt;.'~'''II.,''')I.',;''''W¡;·'M\J;M'-:o;·~-Þ,~n'1¡o,'''''''''''''~~~~,+""",.,,~'~~~~I:'(i!'!'>\':rr:.'iI'I'm¥~~rr Job 9: Install 4 Y2" Slotted Production Liner Hazards and Contingencies ~ The completion design includes a 4 Y2", 12.6#, L-80 slotted liner throughout the production interval. Solid liner will be placed across intervals of lower resistivity / higher water saturation, as determined by the subsurface team. ~ A relatively tortuous path through the reservoir coupled with a high differential pressure between hydrostatic and reservoir create concern for stuck pipe while running the liner. Ensure that the well is particularly clean prior to the final trip out of the hole and minimize connection time while running liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Þ- Sufficient 4 Y2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ...·-«-J+:I::Imll!~;:::..··,,>.....:__W'O':!_I_:'I:..I:_m+;+:-:-·!o'#OtI1~IIi'!:a!'IW:::I::.I!~~_tl:I::~II!II;II'<\o'!~'II~II~II_.~I_I_II'111'l'I:'-:I~I:'III~!HI:ml;IIIII:!~I\W""+tlI.::::ljl:I~!!:.'I!1:1'1:':III_I!:II'I:IIIIII:t'C::::..::::~:::~tm.".I__II_I_~"1._I:\_II__II:'::_'III::llml~llllU:n:rl:I'~I:IOIUouml':"1I11::II!II':lrl~ Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP ¡;,...<t-~¡..,¿,¡,_~"",~&,'__ "'_"6J!,.~",....,",~,Iöl_""_"'~'.""'_-~'~""'"'_",,~""'..,"'_'·. """-_...,_,,', r'..~'''_'''_'''''''''''',.'''''~';...'''''''''~_'''oIi''''''~. .,. ~,_. .-41 ._ ..-.-,,""..._,,_...._.....,..,....__ ,."',..~,..;"'''-II.,,'\. ..."',,:...-,.,,~^"_ . ...'" ,,,",' ¡~_. .,. .""~-~...-___._-.... ..,\ " .... -~._ ~-"","'-''-'''''''' Job 13: ND/NU/Release RiQ Hazards and Contingencies Þ- There are no identified hazards particular to this phase of the operation. Reference RP .:. "Freeze Protecting an Inner Annulus" RP DS17-01A Sidetrack Page 7 TREE ~ WELLHEAD= ACTUÁTÓR";' KB. ELEV = BF. ELEV = KOP= Max Angle = DaiumMO; . Datum TVD= FMC GEN 2 FMC ÃxCËsóï\J 70' ) "".,.., ".""""",,,,..,..,,, 5300' . '.~~:®~?g~: 9156' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2682' Minimum ID = 3.75" @ 8598' 4-1/2" CAMCO DB-6 NIPPLE 5-1/2" TBG-IPC, 17#, L-80, -i 8556' 0.0232 bpf, ID = 4.892" 4-1/2" TBG-IPC, 12.6#, N-80, -i 8601' 0.0152 bpf, ID = 3.958" I TOP OF 7" LNR l-i 8703' 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9010' PERFORA TION SUMrvtARY REF LOG: BHCS 07/09/80 ANGLE AT TOP PERF: 4 @ 9166' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 9166 - 9206 C 03/28/02 3-3/8" 6 9214 - 9226 C 03/28/02 3-3/8" 4 9272 - 9300 C 03/28/02 3-3/8" 4 9318 - 9338 C 03/28/02 7" LNR, 29#, N-80, 0.0371 bpf, ID = 6.184" l-i 9924' Œ£]-i 9932' DA TE REV BY COMMENTS 07/17/80 ORIGINAL COMPLETlON 11/29/00 SIS-M\NI- CONVERTED TO CANVAS 02/27/01 SIS-LG FINAL 07/13/01 RNIKAK CORRECTIONS 03/28/02 DBrvtlKK SAND DUMP 17 -01 J SAFETY NOTES W AIVERED WELL IA X ) OA COMMINUCATION TO AIL I ~ 2162' l-i 5-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" I (f) GAS LIFT MANDRELS ~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3777 3777 1 MMG RK 2 6035 6002 21 MMG RK 3 7324 7111 32 MMG RK 4 7375 7155 32 MMG RK L 5 7842 7579 20 MMG RK 6 7894 7629 20 MMG RK 7 8237 7959 13 MMG RK 8 8289 8010 13 MMG RKP I I I 8428' l-i 5-1/2" CAMCO SLIDING SLV l J-, 8529' l-i 5-1/2" BAKER PBR ASSY Z ~ I 8544' l-i 9-5/8" X 5-1/2" BAKER SAB PKR I f t II 8556' l-i 5-1/2" X 4-1/2" XO I 8598' l-i 4-1/2" DB-6 LANDING NIP (ERODED) ID = 3.75" 8600' l-i 4-1/2" BAKER SHEAROUT SUB I ~ 8601' l-i 4-1/2" TUBING TAIL LOGGED 11/28/86 I II II ~ .... 9006' l-i TOP OF SAND/SLUGGITS I n n II 1I II II II -- 9338' l-i SLM BRIDGE PLUG ELEMENT (STILL IN HOLE) 4~ 9880' l-i PBTDI DA TE REV BY COMMENTS 04/08/02 RL/tlh DUMP SLUGGITS PRUDHOE BAY UNIT WELL: 17 -01 PERMIT No: 80-055 API No: 50-029-20476-00 SEC 22, TION, R15E 4010.56 FEL 4055.18 FNL BP Exploration (Alaska) TREE: 5-1/8" - 5M FMC Carbon WELLHEAD: 13 5/8" - 5M FMC Gen 2 13-3/8", 72#/ft,L-80, BTC I 2682' I.. Window Milled from Whipstock Top of Window at +/-6850' MD Bridge Plug set at +/-6874' MD --.!: --.!: 17-01 A Proposed Completion 4-112" 'X' Landing Nipple with 3.813" seal bore. I 2200' I +/-2650' .. I BAKER 7" x 9-5/8" Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger Cellar Elevation = 34.5' Nabors 2ES RKB = 63.0' 4-112" 12.6# 13Cr-80 Vam Ace Tubing with GLM's GAS LIFT MANDRELS MD Size Valve Type 6 5 4 3 2 1 TBD TBD TBD TBD TBD 1 jt above pkr +/-6700' I BAKER 7" x 9-5/8" Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger ~,.'. ;A~~~~;;'~~' ~."~. - .".~. '-~ }~1!0Jft to- 9-5/8",47 lIft, L-80 & JL-95, BTC 19010' I . '.". . 7", 29#/ft, L-80 BTC I 9924' Sand Plug and Fill ~ ~ ~ I +/-9169' 7",26 lIft, L-80, BTC-Mod D- ~ ~ 4-112" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-112" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. +/-9020' BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger --------- ========= ========= --------- --------- ========= ------- - ========= --------- --------- ========= ========= Date 01/28/02 Rev By Comments PGS Proposed Completion - WP-07 1" 1 " 1 " 1" 1" 1" RP Shear DV DV DV DV DV --- "' ~ 4-1/2" 12.6 #IIt, L-80, IBT Combo of Solid and Slotted Liner I +/-12,039' I ---------------('1) ___________ ---- N".,'. =========== ====,~ --------------- ~:-. --------------- ::.;. ===============@ ----------- ---- :.;. PRUDHOE BAY UNIT WELL: 17-01A API NO: 50-029-20476-01 Greater Prudhoe Bay 17-01 A) Date: 111512003 Date: Date: 17-01A "'1107 (17-olfPlan Created By: Ken Allen Checked: Reviewe<l: Plan: SURVEY PROGRAM [Rp!h Fm Depth To StuwyiPlan Tool 6850.00 1203855 PIanro:\: 17-OIA "p07 VI6 MWD REFERENCE INFORMATION CO-<IfIlinat< (N<E) Refereoœ: WeU Centre: 17·01. T roo Nor1h Verti<al (lVD) Rekreœe: 63.1)(163.00 Sec,joo (VS) Refereoœ: Slot· 01 (O.OON,O.OOE) M<a>1Jred Depth Reference: 63.00 63.00 Calcutation Method; Miuimum Curvature Cakulation Mclfkxl: Minimum CUl\'3Jurc FIT'" Sr""'n: ISCWSA Scan Method: TravC)·\it>1erNorth Error Surro.,.,: EUiplUl· Casin$ W.mJin~ Mclhod: Rules ß.«ð ObP . - Size 7.000 4.500 CASING DETAILS Name MD 9169.48 12038.54 TVD 8872.00 9048.00 No. All TVD depths are ssTVD plus 63'for RKBE. 7' 4 7-01a Tlakwa .--' 7-01a T2a 7-OIa T2.5 7-01a De 17-01a T4b 7-01a T5 Targe VSec 693.06 703.95 854.31 1032.97 1249.61 1505.35 1550.98 1785.1I 1814.67 1851.93 2044.32 2044.35 2060.57 21I4.79 2699.51 2772.44 2849.65 2999.05 3045.80 3087.34 3419.45 TFaee 0.00 85.00 189.24 174.29 0.00 0.01 2.81 0.00 -179.95 -179.88 0.00 17.4 7 -71.12 0.00 -92.24 0.00 -90.17 0.00 -33.45 -78.82 0.00 DLeg 0.00 12.00 6.00 3.90 0.00 15.50 15.00 0.00 12.00 12.00 0.00 12.00 12.00 0.00 12.00 0.00 4.00 0.00 4.00 4.00 0.00 +EI-W 377.18 382.97 491.05 513.60 524.14 536.57 538.59 547.96 549.14 550.64 558.39 558.40 559.42 564.04 957.35 1055.77 1164.57 1384.76 1454.78 1519.80 2054.58 +N/-S .,.., \.50 "'_~. 77 ··"').64 ·....i.18 -11.·'1.28 -I': ¡·1.87 -I '. l'i.43 -I x: I .29 -IX .7.38 -I '''':..86 -: 117.72 -.~ 1 '7.76 -.: 1 Q.28 -~.':1.63 -~...' 7.48 -~., 7,¡. 74 -.:..!icl.55 -..' 7111.94 -~ 71 ti.79 -.:71<.1.88 -~ 7.'J.37 TVD 6710.13 6726.88 7405.76 8479.26 8888.40 9058.00 9053.94 9011.91 9008.00 9006.99 9013.00 9013.00 9013.37 9014.16 9033.92 9038.00 9042.50 9051.56 9053.00 9052.71 9048.00 Azi 145.84 150.20 5.00 177.71 177. 71 177.71 178.12 178.12 178.12 178. II 178.11 178.11 175.89 175.89 99.95 99.95 95.55 95.55 94.00 91.45 91.45 MD lne 33.00 33.28 11.00 32.76 32.76 90.00 98.36 98.36 94.00 88.54 88.54 88.54 89.30 89.30 87.66 87.66 87.65 87.65 90.00 90.50 90.50 6850.00 6870.00 7582.06 8702.44 9188.98 9558.25 9614.04 9903.13 9939.46 9984.99 10220.06 10220.09 10239.64 10304.16 10936.85 11036.85 II 146.78 11368.19 11438.47 11503.57 12038.55 See 1 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 21 Formation CM3 CM2 CMI THRZ BHRZ JKUILCU TJA TSAG TSHAfTSHU TSAD/TZ4B MHO HOT TAR 1/2' FORMATION TOP DETAILS MDPath 6977.69 7534.61 8374.43 8724.73 8880.51 8953.05 9058.89 9169.48 9200.52 9300.93 9467.84 9511.12 9531.05 TVDPath 6820.00 7359.00 8186.00 8498.00 8629.00 8690.00 8779.00 8872.00 8898.00 8972.00 9047.00 9055.00 9057.00 No. I 2 3 4 5 6 7 8 9 10 II 12 13 Start Dir 12/100': 6850' MD, 6710.\3'TVD Start Dir6/IOO': 6870' MD, 6726.88'TVD 6500- 7582.06' MD, 7405.76'TVD 87')2.44' MD, 8479.26' TVD 7000 =---= CM~...-"/ WELL DETAILS Name ·w·s .E/·W Northing Easting Latitu<k Longituœ Slot 17-01 1562.84 42436 5927794.40 708786.76 70"12'21.846N 148"18'59.678W 01 TARGET DETAILS Name WD -Nl·S ~E/-W Northing Easting Sbal" 17-010 T2a 9008.00 -185738 549.14 5925953.00 709387.00 Point 17-010 T2.5 9013.00 -2137.76 558.40 5925673.00 709404.00 Poinl 17-010 Dc 9038.00 ·2674.74 1055.71 5925150.00 709916.00 Poin' 17-010 T5 90-18.00 -273337 2054.58 5925119.00 710916.00 Point 17-010 T4b 9053.00 -2716.19 1454.78 5925119.00 710316.00 Point 17-010 no""" 9058.00 -1479.87 53657 5926330.00 709364.00 PojD( 17-01 A Poly 9058.00 -1078.æ 367.61 5926727.00 709184.00 Polygon SECTION DETAILS 7500 ~ - <:) , ~ " - '/~ ..../'I~ ".,,~ /' End Dir : 10936.85' MD, 9033.92' TVD Start Dir 4/100' : 11036.85' MD, 9038'TVD End Dir : 11146.78' MD, 9042.5' TVD Start Dir4/100': 11368.19' MD, 9051.56'TVD End Dir : 11503.57' MD, 9052.71' TVD ! 4 1/2" _____ 17-OIA ",-p07 I 3500 -4 :-" . 20-£7 o J MJ, 9()L8' -vJ 1208 55' 3000 ~\ \ StartDir2/OC': 0304.16'M'),WI4.I6'TVD \ Etw.1 Dir : 10239.64' MD, 9013.3T T'JD ..... T I1r 00·. 102:0.0& "". On37VD oc oc 00') T ola Ir.pt1 15.5/100': 9188.98' MD, 8888.4'TVD Start Dir 15/100': 9558.25' MD, 9058'TVD J End Dir : 9614.04' MD, 9053.94' TVD ~<f I StartDirI2/100':9903.13'MD,9011.91'TVD ~¿g . ! EI),d Die : 9984.99' MD, 9006.99' JVD ~*' / 0> ~ __ _~j ~ I I(~} ~HO j I f-O- T}"R 2000 2500 Vertical Section at 143.070 [500ft/in] J "'i 500 8000 -----\-\60 1000 1Î-O"1111-0~) I c"'" -- 500 c ~ o ~ .c g. 8000 Ç¡ ~ 'i: > 2 ¡-. 9000 9500 8500 Date: 1/15/200 Date: Date: Plan: 17-OIA \\1'07 (17-0 I /Plan 17-01 A) Created By: Ken Allen SURVEY PROGRAM Depth fm Deplh To SUIyey/P1an Tool 6850.00 1203855 l'iann«t 17.olA "pO? VI6 MWD REFERENCE INfORMATION Co-ooJinaIe (N'E) R<f"""",e; wen Ce"""; 17.01. True North Venkal (lVD) R<l<reoee; 63.00' 63.00 Se<tioo (VS) R<fereoee; Slot - 01 (O.OON,O.OOE) l=ured Depth R<ferenœ; 63.00' 63.00 C.kuJ.1ion M,,!bod; Minimwn CUI'","", nr A..ml--....:o Cal..-ul.alion Mcth('kt Minimum rurutun: Error Sy,t<m; ISCWSA ScaD Melhod; T ra' Cyhnder Nonh Error Surra,;~: ElIiptk.a1 - Casing Wami!!! MCIhOO: Rule< /lased d Checked: Reviewed: WELL DET AIU; Narœ ~N'-S ~FJ-W Northing Easting La,itu& Loogitude SloI 17.01 156284 42436 5921794.40 708186.76 10"1nl.846N 148"18'59.618W 01 TARGET DETAIU; Narœ lVD ~N!-S ~FJ-W Northing Easting Shape 17.01. T20 9008.00 -185738 549.14 5925953.00 109381.00 Point 17-01. T2.5 9013.00 -2131.16 558.40 592..<673.00 109404.00 Point 11.01. Dc 9038-00 -2674.14 1055.11 5925150.00 109916.00 Point 11-01. IS 9018.00 -213331 2054.58 5925119.00 110916.00 Point 11-01. T4b 9053.00 -2116.19 1454.18 5925119.00 110316.00 Point 11-01. TI. kmi 9058.00 -1419.81 53651 5926330.00 109364.00 Point 11.oIA Poly 9058.00 -1078.03 361.61 5926W.00 109184.00 Polygon SECTION DETAILS 7582.06' MD, 7405.76'TVD 00' -400 Targe 17-ola Tla kwà~ 17-ola T2a 17-01 a T2.5 17-ola Be 17-01a T4b 17-01a T5 VSee 693.06 703.95 854.31 1032.97 1249.61 1505.35 1550.98 1785.11 1814.67 1851.93 2044.32 2044.35 2060.57 2114.79 2699.51 2772.44 2849.65 2999.05 3045.80 3087.34 3419.45 TFaee 0.00 85.00 189.24 174.29 0.00 0.01 2.81 0.00 -179.95 -179.88 0.00 17.47 -71.12 0.00 -92.24 0.00 -90.17 0.00 -33.45 -78.82 0.00 DLeg 0.00 12.00 6.00 3.90 0.00 15.50 15.00 0.00 12.00 12.00 0.00 12.00 12.00 0.00 12.00 0.00 4.00 0.00 4.00 4.00 0.00 +FJ-W 377.18 382.97 491.05 513.60 524.14 536.57 538.59 547.96 549.14 550.64 558.39 558.40 559.42 564.04 957.35 1055.77 1164.57 1384.76 1454.78 1519.80 2054.58 +N/-S ~~. 1.50 "'·.'..77 ,,·.·l.64 'Wti.18 -11'/1.28 -I~ ¡".87 -I ~ '<;.43 -I x,'1.29 -lx~7.38 -I'III~,,86 -::' I '7.72 -.::' 11"/.76 -::'1'7.28 -.::::' 1.63 _::'t., 7.48 _::'h 74.74 -::'M"l.55 -.::'7111.94 -:} 1t;.79 -~ II'l.88 -::'71.1.37 TVD 6710.13 6726.88 7405.76 8479.26 8888.40 9058.00 9053.94 9011.91 9008.00 9006.99 9013.00 9013.00 9013.37 9014.16 9033.92 9038.00 9042.50 9051.56 9053.00 9052.71 9048.00 Azi 145.84 150.20 5.00 177.71 177.71 177. 71 178.12 178.12 178.12 178.11 178.11 178.11 175.89 175.89 99.95 99.95 95.55 95.55 94.00 91.45 91.45 Ine 33.00 33.28 11.00 32.76 32.76 90.00 98.36 98.36 94.00 88.54 88.54 88.54 89.30 89.30 87.66 87.66 87.65 87.65 90.00 90.50 90.50 MD 6850.00 6870.00 7582.06 8702.44 9188.98 9558.25 9614.04 9903.13 9939.46 9984.99 10220.06 10220.09 10239.64 10304.16 10936.85 II 036.85 11146.78 11368.19 11438.47 11503.57 12038.55 See ~ 2 3 ~ 5 5 7 ¿?, ~ 10 II 12 13 14 15 16 17 18 19 W 21 Size 7.000 4.500 Name 7" 4 1/2' MO 9169.48 12038.54 TVD 8872.00 9048.00 No. 1 2 9188.98' MD, 8888.4'TVD 7-01 :;ta1. t;ir 15/100': 9558.25' MD, 9058'TVD ./ 2nc bir:9614.04' MD, 9053.94' TVD - 7" ------~- - --~-_._~_._- __ L-- r~d :Jil : 8702.44' MD, 8479.26' TVD --==8WO=j_~ ~--~ 1" ~~ s~~:roo' 7-01 9.10- ) ~--- ------- ~2.-O. B. l~ k....a -800 1200 600 c ~ o o :!. '+ J5 1:: ~ J5 :í o en - c1q, c:::. 7/<q, ., " - "<q, ...yt'" , ~"' >itq, /' Start ,)ir 12/100' : 9903.13' MD, 9011.9I'TVO ./ 010 T2~~1lJL '~9984.99' MD, 9006.99' TVD /' I" - Start JiLl.2/100' : 10220.06' MD, 9013'TVD 1.0 ~ ~0239.64' MD, 9013.37' TVO \ ./ S:ar,~ir 2/100': 10304.16' MD, 9014.16'TVD ~-=\-. "" --.\ \ ~~ ----~ ~ : :~--= -~- - ----- - ~ I 3"L92--;--V~ ~ /' ~ D,,)('3f'TVD ....... All TVD depths are ssTVD plus 63'for RKBE. FORMATION TOP DETAILS No. TVOPath MOPath Formation I 6820.00 6977.69 CM3 2 7359.00 7534.61 CM2 3 8186.00 8374.43 CMI 4 8498.00 8724.73 THRZ 5 8629.00 8880.51 BHRZ 6 8690.00 8953.05 JKU/LCU 7 8779.00 9058.89 TJA 8 8872.00 9169.48 TSAG 9 8898.00 9200.52 TSHAffSHU 10 8972.00 9300.93 TSADfTZ4B 11 9047.00 9467.84 MHO 12 9055.00 9511.12 HOT 13 9057.00 9531.05 TAR CASING DETAILS -2000 146.78' MO, 9042.5' TVD Start Dir 4/100' : 11368.19' MD, 9051.56'TVD End Dir : 11503.57' MD, 9052.71' TVD 7-0la T~ 4 . /2 1-0 a -3c ) ::f 17-0" A ",")(ì7 17-0<1 TLb ~ I rooù Depl1: 12)38.55' 'vID, 9OL8' T\'D 1200 1600 2000 West(-)lEast(+) [400ft/in] End Dir 800 a T2 ~- 400 -2400 -2800 ) BP KW A Planning Report MAP ) COß1P~I1Y: · Fie.~: Site: \Veil: ./ .. . Wellpatb: BPAl'r\dCO .··en.ldQqøl3~Y 1?~'P~1T. .. 1.7-q1....',..·.. ...... ·.·....·i. Plan'1}~01,A..·· ..º~~:"i¡1!~~/~QØ~..i',.,"'~~.~,~:····.1·~¡á~:~9>.'i.·..·...i.·..., ~.ge: .'. ·,.~O~~~J~~~'¥N~),~~(~..!..~~:..·...... '.., , "w~n:'1'l~~t~~ry~ ~?~h...··..·.... .'......................., Ye~~.1 (T;yJ?)'Jt~f~~Q~:'i). .·ß~:Q()'·~~.Pi.'. ... ............../ ...... ......... .··.i .... ..... .····'..·.·.is~~~~~S~.,~~fe~~Q~'::··.·.ii<::'.......VV~11··..~þ;99N,q:09êj143·0~~i) . '. S~t:V~y(J~'ç~l~ti~IIN1~~M: 'MilJimt!m'º~ryªtur~' 1 p~: ,<.:"1,:' :', 1","'1" ",:' Oracle 1"'"(;;:::,,>: 'I'. . Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 17 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5926220.53 ft 708405.69 ft Latitude: Longitude: North Reference: Grid Convergence: 1 Alaska, Zone 4 Well Centre BGGM2002 70 12 6.476 N 148 19 11.993 W True 1.58 deg Well: 17-01 Slot Name: 01 17-01 Well Position: +N/-S 1562.84 ft Northing: 5927794.40 ft Latitude: 70 12 21.846 N +E/-W 424.36 ft Easting : 708786.76 ft Longitude: 148 18 59.678 W Position Uncertainty: 0.00 ft Wellpath: Plan 17-01A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 63.00' 10/4/2002 57548 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 63.00 ft Plan: 17-01A wp07 Date Composed: Version: Tied-to: Principal: Yes Casing Points 17-01 6850.00 ft Mean Sea Level 26.23 deg 80.80 deg Direction deg 143.07 1/14/2003 16 From: Definitive Path 9169.48 8872.00 7.000 8.500 7" 12038.54 9048.00 4.500 6.125 41/2" Formations MD TVD Dip Angle Dip Direction ft ft deg deg 0.00 WS1 0.00 0.00 6977.69 6820.00 CM3 0.00 0.00 7534.61 7359.00 CM2 0.00 0.00 8374.43 8186.00 CM1 0.00 0.00 8724.73 8498.00 THRZ 0.00 0.00 8880.51 8629.00 BHRZ 0.00 0.00 8953.05 8690.00 JKU/LCU 0.00 0.00 9058.89 8779.00 TJA 0.00 0.00 9169.48 8872.00 TSAG 0.00 0.00 9200.52 8898.00 TSHA/TSHU 0.00 0.00 9300.93 8972.00 TSADITZ4B 0.00 0.00 9467.84 9047.00 MHO 0.00 0.00 9511.12 9055.00 HOT 0.00 0.00 9531.05 9057.00 TAR 0.00 0.00 0.00 OWC 0.00 0.00 ') ') BP KW A Planning Report MAP Company: BP Arno,co Field: , Prudhoe Bay Site: PBDS'17 Well: 17-01 'Yeltpath:, Plån17-01A Targets Patt: ,.~115/~0()3,," 'Time:, 15:3:3::2Ø ..,. ...., " ,Page:' 2 Ço~rdi~at~rŒ)'Re(ere~c~:" ',Well:,17,~P1, Truø North 'Vertic.I'(J;VD)¡Referen~e:"63:()O' ~3.0 " '. , SeCtiO~(vS)'Refe~ence:"Well (b.OON,().OOE143.0?~i) Survey Calcula~~nMetlaPd: MinimumCurvature' ' , , .. Db.: Oracle 9008.00 -1857.38 549.14 5925953.00 709387.00 70 12 3.579 N 148 1843.745 W 17-01a T2.5 9013.00 -2137.76 558.40 5925673.00 709404.00 70 12 0.821 N 148 1843.477 W 17-01 a T3c 9038.00 -2674.74 1055.77 5925150.00 709916.00 70 11 55.539 N 148 1829.050 W 17-01 a T5 9048.00 -2733.37 2054.58 5925119.00 710916.00 70 11 54.961 N 148 18 0.075 W 17-01a T4b 9053.00 -2716.79 1454.78 5925119.00 710316.00 70 11 55.125 N 148 18 17.475 W 17-01a T1a kwa 9058.00 -1479.87 536.57 5926330.00 709364.00 70 12 7.291 N 148 1844.109 W 17-01A Poly 9058.00 -1078.03 367.61 5926727.00 709184.00 70 12 11.244 N 148 18 49.011 W -Polygon 1 9058.00 -1078.03 367.61 5926727.00 709184.00 70 12 11.244 N 148 18 49.011 W -Polygon 2 9058.00 -1327.53 345.70 5926477.00 709169.00 70 12 8.790 N 148 18 49.647 W -Polygon 3 9058.00 -2172.30 360.36 5925633.00 709207.00 70 12 0.481 N 148 18 49.223 W -Polygon 4 9058.00 -2637.29 533.58 5925173.00 709393.00 70 11 55.908 N 148 1844.198 W -Polygon 5 9058.00 -2822.81 802.57 5924995.00 709667.00 70 11 54.083 N 148 18 36.395 W -Polygon 6 9058.00 -2833.36 1437.55 5925002.00 710302.00 70 11 53.979 N 148 18 17.975 W -Polygon 7 9058.00 -2875.14 2260.75 5924983.00 711126.00 70 11 53.566 N 148 17 54.095 W -Polygon 8 9058.00 -2548.25 2269.79 5925310.00 711126.00 70 11 56.781 N 148 17 53.830 W -Polygon 9 9058.00 -2468.65 1055.47 5925356.00 709910.00 70 11 57.566 N 148 18 29.058 W -Polygon 10 9058.00 -2457.78 915.71 5925363.00 709770.00 70 11 57.673 N 148 18 33.112 W -Polygon 11 9058.00 -2185.34 687.14 5925629.00 709534.00 70 12 0.353 N 148 18 39.742 W -Polygon 12 9058.00 -1086.88 687.50 5926727.00 709504.00 70 12 11.156 N 148 18 39.729 W Plan Section Information MD IlIcl' , ..¡\ii.~ TVD +Nj~S 'tEl-"'., ,·'~çS,.~~Ud: .':T~rD..·. ....., TFO ,Wä..get, ft: '·,deg·' '. ~eg 'ft", 'ft ,ft de9/~oOftde9~1~(j~g/1!q9ft ,!(jeg' 6850.00 33.00 145.84 6710.13 -583.50 377.18 0.00 0.00 0.00 0.00 6870.00 33.28 150.20 6726.88 -592.77 382.97 12.00 1.43 21.80 85.00 7582.06 11.00 5.00 7405.76 -699.64 491.05 6.00 -3.13 -20.39 189.24 8702.44 32.76 177.71 8479.26 -906.18 513.60 3.90 1.94 15.41 174.29 9188.98 32.76 177.71 8888.40 -1169.28 524.14 0.00 0.00 0.00 0.00 9558.25 90.00 177.71 9058.00 -1479.87 536.57 15.50 15.50 0.00 0.01 17-01a T1a kwa 9614.04 98.36 178.12 9053.94 -1535.43 538.59 15.00 14.98 0.74 2.81 9903.13 98.36 178.12 9011.91 -1821.29 547.96 0.00 0.00 0.00 0.00 9939.46 94.00 ,178.12 9008.00 -1857.38 549.14 12.00 . -12.00 -0.01 -179.95 17-01a T2a 9984.99 88.54 178.11 9006.99 -1902.86 550.64 12.00 -12.00 -0.02 -179.88 10220.06 88.54 178.11 9013.00 -2137.72 558.39 0.00 0.00 0.00 0.00 10220.09 88.54 178.11 9013.00 -2137.76 558.40 12.00 11.45 3.60 17.47 17-01a T2.5 10239.64 89.30 175.89 9013.37 -2157.28 559.42 12.00 3.89 -11.35 -71.12 10304.16 89.30 175.89 9014.16 -2221.63 564.04 0.00 0.00 0.00 0.00 10936.85 87.66 99.95 9033.92 -2657.48 957.35 12.00 -0.26 -12.00 -92.24 11036.85 87.66 99.95 9038.00 -2674.74 1055.77 0.00 0.00 0.00 0.00 17-01a T3c 11146.78 87.65 95.55 9042.50 -2689.55 1164.57 4.00 -0.01 -4.00 -90.17 11368.19 87.65 95.55 9051.56 -2710.94 1384.76 0.00 0.00 0.00 0.00 11438.47 90.00 94.00 9053.00 -2716.79 1454.78 4.00 3.34 -2.20 -33.45 17-01 a T4b 11503.57 90.50 91.45 9052.71 -2719.88 1519.80 4.00 0.78 -3.92 -78.82 12038.55 90.50 91.45 9048.00 -2733.37 2054.58 0.00 0.00 0.00 0.00 17-01 a T5 ) BP ) KW A Planning Report MAP C~~p~.nY~ ;~~',A;rnq~ê> ,····.Ï1¡~;:,..·,.111$I?ÖØ3·...·.·." ,. TiD1~:<':r~¡3~:?Ø, '.....,:,...., 'Pa~è,: Field: Prudhoe Bay Çq-o~cIinate(~j'Refer¢ncê:· ," 'Well: 17~01"Tr\JeNorth Site: PB'DS17 ., Vertical' (TYD}~eferent:e: 63:()0' 63,0 '. , ' Well: 17.,01 Seçtion(VS)'Reference: ' W~n(Q.OON;O.OOE, 143.Q7Azi) ..' Wellpath: Plan 17-01A SurveyCalçulatio"l\1etho~: 'Minimum 'Curvature Db:, Oracle Survey 6850.00 33.00 145.84 6710.13 6647.13 5927221.57 709179.90 693.06 0.00 0.00 MWD 6870.00 33.28 150.20 6726.88 6663.88 5927212.47 709185.94 703.95 12.00 85.00 MWD 6900.00 31.51 149.65 6752.21 6689.21 5927198.79 709194.38 719.90 6.00 189.24 MWD 6950.00 28.55 148.59 6795.50 6732.50 5927177.67 709207.80 744.78 6.00 189.70 MWD 6977.69 26.92 147.91 6820.00 6757.00 5927166.91 709214.88 757.61 6.00 190.62 CM3 7000.00 25.61 147.31 6840.01 6777.01 5927158.72 709220.39 767.46 6.00 191.22 MWD 7050.00 22.68 145.72 6885.63 6822.63 5927141.97 709232.13 787.87 6.00 191.76 MWD 7100.00 19.77 143.70 6932.23 6869.23 5927127.48 709242.97 805.96 6.00 193.20 MWD 7150.00 16.89 141.01 6979.69 6916.69 5927115.29 709252.89 821.68 6.00 195.09 MWD 7200.00 14.06 137.27 7027.88 6964.88 5927105.42 709261.86 834.99 6.00 197.65 MWD 7250.00 11.32 131.72 7076.65 7013.65 5927097.91 709269.86 845.84 6.00 201.25 MWD 7300.00 8.74 122.83 7125.89 7062.89 5927092.78 709276.86 854.22 6.00 206.67 MWD 7350.00 6.53 107.36 7175.44 7112.44 5927090.03 709282.84 860.09 6.00 215.43 MWD 7400.00 5.18 80.68 7225.19 7162.19 5927089.69 709287.80 863.45 6.00 230.77 MWD 7450.00 5.38 47.71 7274.99 7211.99 5927091.74 709291.70 864.28 6.00 257.31 MWD 7500.00 7.01 23.96 7324.70 7261.70 5927096.19 709294.56 862.57 6.00 290.15 MWD 7534.61 8.57 13.85 7359.00 7296.00 5927100.66 709295.91 859.91 6.00 313.77 CM2 7550.00 9.34 10.48 7374.20 7311.20 5927103.02 709296.34 858.34 6.00 323.79 MWD 7582.06 11.00 5.00 7405.76 7342.76 5927108.64 709296.93 854.31 6.00 327.11 MWD 7600.00 10.30 5.39 7423.39 7360.39 5927111.95 709297.14 851.85 3.90 174.29 MWD 7700.00 6.44 9.08 7522.30 7459.30 5927126.44 709298.46 841.34 3.90 173.91 MWD 7800.00 2.68 23.34 7621.97 7558.97 5927134.17 709300.06 836.28 3.90 170.26 MWD 7900.00 1.81 142.59 7721.93 7658.93 5927135.11 709301.92 836.71 3.90 156.03 MWD 8000.00 5.46 167.95 7821.72 7758.72 5927129.25 709304.04 842.61 3.90 36.82 MWD 8100.00 9.32 172.75 7920.87 7857.87 5927116.62 709306.41 853.96 3.90 11.50 MWD 8200.00 13.20 174.75 8018.93 7955.93 5927097.28 709309.01 870.72 3.90 6.73 MWD 8300.00 17.09 175.86 8115.44 8052.44 5927071.32 709311.83 892.79 3.90 4.77 MWD 8374.43 19.98 176.40 8186.00 8123.00 5927047.77 709314.07 912.61 3.90 3.70 CM1 8400.00 20.98 176.56 8209.95 8146.95 5927038.86 709314.87 920.08 3.90 3.18 MWD 8500.00 24.87 177.05 8302.03 8239.03 5927000.05 709318.10 952.46 3.90 3.04 MWD 8600.00 28.77 177.41 8391.26 8328.26 5926955.07 709321.52 989.79 3.90 2.59 MWD 8702.44 32.76 177.71 8479.26 8416.26 5926902.81 709325.18 1032.97 3.90 2.26 MWD 8724.73 32.76 177.71 8498.00 8435.00 5926890.77 709326.00 1042.89 0.00 180.00 THRZ 8800.00 32.76 177.71 8561.30 8498.30 5926850.13 709328.75 1076.41 0.00 180.00 MWD 8880.51 32.76 177.71 8629.00 8566.00 5926806.66 709331.70 1112.25 0.00 180.00 BHRZ 8900.00 32.76 177.71 8645.39 8582.39 5926796.14 709332.41 1120.93 0.00 180.00 MWD 8953.05 32.76 177.71 8690.00 8627.00 5926767.50 709334.36 1144.55 0.00 180.00 JKUlLCU 9000.00 32.76 177.71 8729.48 8666.48 5926742.15 709336.08 1165.46 0.00 180.00 MWD 9058.89 32.76 177.71 8779.00 8716.00 5926710.35 709338.23 1191.68 0.00 180.00 TJA 9100.00 32.76 177.71 8813.57 8750.57 5926688.16 709339.74 1209.99 0.00 180.00 MWD 9169.48 32.76 177.71 8872.00 8809.00 5926650.64 709342.28 1240.93 0.00 180.00 TSAG 9188.98 32.76 177.71 8888.40 8825.40 5926640.12 709342.99 1249.61 0.00 180.00 MWD 9200.00 34.47 177.71 8897.57 8834.57 5926634.03 709343.40 1254.63 15.50 0.01 MWD 9200.52 34.55 177.71 8898.00 8835.00 5926633.74 709343.42 1254.87 15.50 0.00 TSHAlTSHU 9225.00 38.35 177.71 8917.69 8854.69 5926619.23 709344.41 1266.83 15.50 0.00 MWD 9250.00 42.22 177.71 8936.75 8873.75 5926603.11 709345.50 1280.13 15.50 0.00 MWD 9275.00 46.10 177.71 8954.69 8891.69 5926585.73 709346.68 1294.46 15.50 0.00 MWD 9300.00 49.97 177.71 8971.40 8908.40 5926567.19 709347.93 1309.75 15.50 0.00 MWD 9300.93 50.12 177.71 8972.00 8909.00 5926566.48 709347.98 1310.34 15.50 0.00 TSADfTZ4B 9325.00 53.85 177.71 8986.82 8923.82 5926547.57 709349.26 1325.93 15.50 0.00 MWD 9350.00 57.72 177.71 9000.88 8937.88 5926526.94 709350.66 1342.94 15.50 0.00 MWD 9375.00 61.60 177.71 9013.50 8950.50 5926505.42 709352.12 1360.69 15.50 0.00 MWD 9400.00 65.47 177.71 9024.64 8961.64 5926483.10 709353.63 1379.10 15.50 0.00 MWD ) ') BP KW A Planning Report MAP Company: BP Amoco D.~: 1/15/2003" ,. Time: 15:33:29 Page: ,4 Field: prudhoeßay Cô-ordiQate(NE) Referelice:, ' . Well: 17~01. True North Siw: P,B.DS 1,7 VerticalaVD) Refe~ence:" ' 63.00'63.0 Well: 17-01' Seçtion (VS)Reference:' W.ell (0,OON,O.00E,143.07Azi) Wellpath: 'Plan 17.;Q1A Suney Calculation Method: Minimurn Cu~ature Db: Oracle Survey 9425.00 69.35 177.71 9034.24 8971.24 5926460.08 709355.19 1398.08 15.50 0.00 MWD 9450.00 73.22 177.71 9042.26 8979.26 5926436.46 709356.79 1417.56 15.50 0.00 MWD 9467.84 75.99 177.71 9047.00 8984.00 5926419.30 709357.95 1431.71 15.50 0.00 MHO 9475.00 77.10 177.71 9048.67 8985.67 5926412.35 709358.42 1437.44 15.50 0.00 MWD 9500.00 80.97 177.71 9053.42 8990.42 5926387.87 709360.08 1457.63 15.50 0.00 MWD 9511.12 82.70 177.71 9055.00 8992.00 5926376.89 709360.83 1466.68 15.50 0.00 HOT 9525.00 84.85 177.71 9056.51 8993.51 5926363.13 709361.76 1478.03 15.50 0.00 MWD 9531.05 85.78 177.71 9057.00 8994.00 5926357.11 709362.17 1483.00 15.50 0.00 TAR 9550.00 88.72 177.71 9057.91 8994.91 5926338.23 709363.44 1498.57 15.50 0.00 MWD 9558.25 90.00 177.71 9058.00 8995.00 5926330.00 709364.00 1505.35 15.50 0.00 17-01a T1a kwa 9575.00 92.51 177.83 9057.63 8994.63 5926313.29 709365.11 1519.12 15.00 2.81 MWD 9600.00 96.26 178.02 9055.72 8992.72 5926288.42 709366.70 1539.57 15.00 2.82 MWD 9614.04 98.36 178.12 9053.94 8990.94 5926274.52 709367.56 1550.98 15.00 2.83 MWD 9700.00 98.36 178.12 9041.44 8978.44 5926189.63 709372.69 1620.60 0.00 180.00 MWD 9800.00 98.36 178.12 9026.90 8963.90 5926090.88 709378.66 1701.59 0.00 180.00 MWD 9903.13 98.36 178.12 9011.91 8948.91 5925989.04 709384.82 1785.11 0.00 180.00 MWD 9925.00 95.73 178.12 9009.23 8946.23 5925967.38 709386.13 1802.88 12.00 180.05 MWD 9939.46 94.00 178.12 9008.00 8945.00 5925953.00 709387.00 1814.67 12.00 180.05 17-01 a T2a 9950.00 92.73 178.12 9007.38 8944.38 5925942.50 709387.64 1823.29 12.00 180.12 MWD 9975.00 89.73 178.11 9006.84 8943.84 5925917.55 709389.15 1843.75 12.00 180.12 MWD 9984.99 88.54 178.11 9006.99 8943.99 5925907.58 709389.75 1851.93 12.00 180.12 MWD 10000.00 88.54 178.11 9007.38 8944.38 5925892.60 709390.66 1864.21 0.00 0.00 MWD 10100.00 88.54 178.11 9009.93 8946.93 5925792.83 709396.72 1946.06 0.00 0.00 MWD 10200.00 88.54 178.11 9012.49 8949.49 5925693.05 709402.78 2027.91 0.00 0.00 MWD 10220.06 88.54 178.11 9013.00 8950.00 5925673.04 709404.00 2044.32 0.00 0.00 MWD 10220.09 88.54 178.11 9013.00 8950.00 5925673.00 709404.00 2044.35 12.00 17.47 17-01 a T2.5 10225.00 88.73 177.55 9013.12 8950.12 5925668.10 709404.32 2048.39 12.00 288.88 MWD 10239.64 89.30 175.89 9013.37 8950.37 5925653.52 709405.56 2060.57 12.00 288.89 MWD 10304.16 89.30 175.89 9014.16 8951.16 5925589.33 709411.96 2114.79 0.00 0.00 MWD 10325.00 89.20 173.39 9014.43 8951.43 5925568.64 709414.48 2132.54 12.00 267.76 MWD 10350.00 89.09 170.39 9014.80 8951.80 5925544.01 709418.69 2154.44 12.00 267.80 MWD 10375.00 88.98 167.39 9015.22 8952.22 5925519.63 709424.18 2176.93 12.00 267.84 MWD 10400.00 88.87 164.40 9015.69 8952.69 5925495.57 709430.94 2199.97 12.00 267.89 MWD 10425.00 88.76 161.40 9016.21 8953.21 5925471.89 709438.95 2223.48 12.00 267.95 MWD 10450.00 88.66 158.40 9016.77 8953.77 5925448.67 709448.18 2247.40 12.00 268.01 MWD 10475.00 88.56 155.40 9017.38 8954.38 5925425.97 709458.62 2271.67 12.00 268.08 MWD 10500.00 88.47 152.40 9018.03 8955.03 5925403.84 709470.23 2296.21 12.00 268.15 MWD 10525.00 88.38 149.40 9018.72 8955.72 5925382.35 709482.98 2320.96 12.00 268.23 MWD 10550.00 88.29 146.40 9019.44 8956.44 5925361.56 709496.83 2345.86 12.00 268.31 MWD 10575.00 88.21 143.40 9020.21 8957.21 5925341.53 709511.76 2370.84 12.00 268.40 MWD 10600.00 88.13 140.40 9021.01 8958.01 5925322.30 709527.71 2395.81 12.00 268.49 MWD 10625.00 88.06 137.40 9021.84 8958.84 5925303.94 709544.65 2420.73 12.00 268.58 MWD 10650.00 87.99 134.40 9022.70 8959.70 5925286.49 709562.53 2445.52 12.00 268.68 MWD 10675.00 87.93 131 .40 9023.59 8960.59 5925269.99 709581.29 2470.11 12.00 268.79 MWD 10700.00 87.88 128.39 9024.50 8961.50 5925254.51 709600.89 2494.43 12.00 268.89 MWD 10725.00 87.83 125.39 9025.44 8962.44 5925240.07 709621.27 2518.42 12.00 269.00 MWD 10750.00 87.79 122.39 9026.40 8963.40 5925226.72 709642.38 2542.01 12.00 269.12 MWD 10775.00 87.75 119.39 9027.37 8964.37 5925214.50 709664.16 2565.14 12.00 269.23 MWD 10800.00 87.72 116.39 9028.36 8965.36 5925203.43 709686.56 2587.75 12.00 269.35 MWD 10825.00 87.69 113.38 9029.36 8966.36 5925193.55 709709.49 2609.76 12.00 269.47 MWD 10850.00 87.67 110.38 9030.37 8967.37 5925184.89 709732.92 2631.13 12.00 269.59 MWD 10875.00 87.66 107.38 9031.39 8968.39 5925177.46 709756.7ç 2651.79 12.00 269.71 MWD ') BP KW A Planning Report MAP ") O?.).på~Y:' Xi'i~~4:" . ..Si~:. . Well:'" \V~npat~: §PAm~9° .... Pr~d~q~,B~x: PB'PS't7·. ...... "17--9 ti ..... (, :PI~ngë()1A ; <.:~:,>, ::,:"1 I', I' ""1':::::::',",1';,:, ,. ::º.~:<"111:~12Q~~.,::;:....·'¥i¡'¡#;,!I1~:;~$;2Ø<':·....... ......... ............:., r~g¿:¡····, 5 . . .·.C~"ß~~,...~~~)~~fer~~~tr~:'> I, ¡··...'vy~II~..'..'t,i7:.P1,·.... ær4~.~.o'i1h( ........ ..,..,ii',ii .....,',.........'.............., ;····:.·y~~Ç~'@1Y~)~¢re~~~::':. ',q~;ºP'~~;Ø';I.....·..·.'···..·'...·,'.·....,.....· ........... ....'../...,'» ..............'............................... ...'........,... s.~ti~Il~~~Jlef'~n~::\. .,~~IJI~q:~q~,q.qºJ:J4-~:~~~i)) ..,', .... ...... .·,.·..i ,~~1;Y~y@~I~..1~~i9nM~~~(I:···· ' ·':Mil"llrn4m··Çll.y~ture'.....·....,. '..... .·'.'l)~:'9~ac,~ ..... Survey 1\10 i'.Jl~ti ~~~ID' Ì'VD' ~ys·1VDi:: 'iJ\t[~~ i>' M~Þ~'" 'i·Vir' '."" D~$<'i:;~J;'c?;·'····· .. "·'f~ÖV¢9mfu~nt······ ft. . dElg I deg .. . , ',ft' .. ft . ft. ' Jt . ft ." .,' "deg/10OO . . deg 10900.00 87.66 104.38 9032.41 8969.41 5925171.30 709780.97 2671.69 12.00 269.83 MWD 10925.00 87.66 101.37 9033.43 8970.43 5925166.41 709805.46 2690.76 12.00 269.95 MWD 10936.85 87.66 99.95 9033.92 8970.92 5925164.54 709817.15 2699.51 12.00 270.08 MWD 11000.00 87.66 99.95 9036.50 8973.50 5925155.36 709879.57 2745.56 0.00 0.00 MWD 11036.85 87.66 99.95 9038.00 8975.00 5925150.00 709916.00 2772.44 0.00 0.00 17-01 a T3c 11100.00 87.65 97.42 9040.58 8977 .58 5925142.20 709978.60 2817.53 4.00 269.83 MWD 11146.78 87.65 95.55 9042.50 8979.50 5925138.21 710025.17 2849.65 4.00 269.93 MWD 11200.00 87.65 95.55 9044.68 8981.68 5925134.53 710078.21 2885.56 0.00 0.00 MWD 11300.00 87.65 95.55 9048.77 8985.77 5925127.62 710177.88 2953.04 0.00 0.00 MWD 11368.19 87.65 95.55 9051.56 8988.56 5925122.91 710245.85 2999.05 0.00 0.00 MWD 11400.00 88.72 94.85 9052.57 8989.57 5925120.91 710277.58 3020.38 4.00 326.55 MWD 11438.47 90.00 94.00 9053.00 8990.00 5925119.00 710316.00 3045.80 4.00 326.57 17-01a T4b 11503.57 90.50 91.45 9052.71 8989.71 5925117.71 710381.08 3087.34 4.00 281.18 MWD 11600.00 90.50 91.45 9051.86 8988.86 5925117.94 710477.50 3147.20 0.00 0.00 MWD 11700.00 90.50 91.45 9050.98 8987.98 5925118.18 710577.49 3209.28 0.00 0.00 MWD 11800.00 90.50 91.45 9050.10 8987.10 5925118.42 710677.48 3271.36 0.00 0.00 MWD 11900.00 90.50 91.45 9049.22 8986.22 5925118.67 710777.47 3333.44 0.00 0.00 MWD 12000.00 90.50 91.45 9048.34 8985.34 5925118.91 710877 .46 3395.52 0.00 0.00 MWD 12038.55 90.50 91.45 9048.00 8985.00 5925119.00 710916.00 3419.45 0.00 0.00 17-01a T5 DATE CHECK NO. p054999 12/19/2002 P054999 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 12/19/2002 INV# CK121702H PERMIT TO DRILL FEE \-1~a\ }t tI ,~- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ . ,__. _ _,-".:.-0 '-? '.- - - - - ',,'. '-"" - -."'-' '-.- -, "';.-"- ,".' -~ - - .- .'.' .- ._','-,--_. - -,' - '.'.- .'<,- .'. . . . . -. - - -' , - - - -' - - ßP EXPI..ORAIION,·(Al.A$!AA)...··INÇ¿. PRUDHQEBAYUNIT . PO B()X196p12/{ ". .... ....., ANCHQJìA9t, AI5Ø'951~-e612 '~,c\T!OAA8cÍT\'BANJ(- ., . AshI8l1ð;Qhio' No~P 054999 CONSOLlDATEP COMMERCIAL ACCOUNT PAY: C'_ ' '. - --.. _. . _;_,_.: ..:-....... .. .".. - '.- -"'.' . . _ _ '.. _ _ _," _'." _ . . H' . . - .- .- . . - . - .... . - . - --. - ... . ,".-. . - - - --'- -'- ." ." ",.__ _ ,'_' ','. H:' _ ,- _ ,- .".'. ',' - '.,- ,'. .............-...-... ..' .. . .-,--.-....-_...'-.. - - ".- .'-.....'.... .. - -.'.-" -. . . - - ... . __. ','. . ._".' n',' ,_.'"U "'." "p." . .'C.__"',_:." "'," .... .'--..... - .. - . .' .. - . .. . .. .. - ". '." ,-. . . -.' '."..'. "-'..'. .'- '.- . -. .....--. :-".-':-.'.'. '--.. . - - ".' -- .. .' .." -' ..-" ....... ., - -'. -'. '-.' ..- .. - . . ...'. -- '.- .'.'-'.'." - '.'. ~'-. '. - - , "'.' . . - . .. . .... d . ,_'. _. __. _..-. ,., ." ." ,- ..., . ..... d'_ __ '.', .'.... . .. - ... . . .. .--- -' - ...' .... .; . . . '.. - -. ." '.-."..' ·c··· _.;....:_...... - ...... :::;,:':.:-::': ':"':'.-' ..-:.: -....,.""":"'. .. . > ::,;:::'-::":. ..:..-.:.: -.:'. :..; ....-........ "'.". . -". ;'.. --.:' ...... . .' . .. - - . . -~.' . -.. .. . .. '...- - ..... . ".. "'.' "- '... .. - ... . . .... . - - ..'. ... . - - - . ...... ". ..'. - - - --' - - . ..' -"'. ..' .'. - - ,'. '.'.- .. . . .... "- .--. ..... '..- -- ..., .... .. - . "'. .. - ". .. . '-' .-.. - .-- ..". ... -- -. . - .- "'-' .'.' .-.. .. .. - -' - -. '"-- .','. '. .....- '1IliJtli!Æ~t:~[ì;šfÎ~f... .. DATE> AMOUNT ,-., ÄLÄ~KA...~.IL~êG~S. CðNSÈR~~Tlð~\c~MMl.~SIO~·i:;F,·.······. ,.,~ 333W?"B~A.~t~,pE ......,.,;.,.);/(.. /:.> SUITE10Øi:x,,'}" .>,< ". ANQHQRÀ($g;ÄK~9501L:····.····.·····. '/;' -- -:.--' -.-; ..'.".. - .'.' - c _;.:._::.... . -_;_'.,::"'..-' . .~. Øi=$:ce,t1:~:e:t;·~::~ '9, ':;.40Q2 ***************$100.00*** '., -'.' '. _c_ .'.-'" _ . .. .-.. ... .'. ..' .' ,-... - ---. . - -. "'. - -.-. '..- ...... ... . .'-. - "". . . .-" . '-'.'-"-' .' - '.' ;C];C)N¢~1~J~f:0~J;~ff~~}~;¡:;~ji;~;\~~ ... '........... .'. .....··~.~:i:Æ:~lj~j,}~P.\:17N-. "'U' ...... ..... )';C<¡,5r~~i~~~~~~~};~:~;;¡i~~:;& . -' THE ORDER OF: 1110 5 ~ g g g III I: 0 l. ~ 20 j B ~ 5 I: 0 ~ 2 ? 8 g b 1111 ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ·l3f X WELL NAME (lAtA 17~o1A PROGRAM:Exp _ Dev.Á Redrll..:;z{. Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL 6¿¡C>/.~ð INITCLASS Dp.t/ /-CJ,j( ^ GEOLAREA ~'10 UNIT# /I~,("o ON/OFFSHORE-O..tÙ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y - N 2. Lease number appropriate. . . ~ . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . , . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. .'. . Y N 6. W ell located proper distance from other wells.. . . . . . . . . \ Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ¡;;p~ ") / ~ / 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N /Tfr' ~ô3 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . }5' Y) N (Service Well Only) 13. Well located w(in area & strata authorized by injection order#_ Y A/I If)" (Service Well Only) 14. All wells w/in % mile area of review identified. . . . . . . . ., N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . , , . . . . . [ÐN 16. Surface casing protects all known USDWs. . . . . . . . . . Y N 17. CMT vol adequate to circulate on conductor & surf csg. . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y (fiJ f . II....d 19. CMT will cover all known productive horizons. ,. . .' . . . .. . ~ì s.wtte~ 20. Casing designs adequate for C.' T, B& permafrost. . . . . . . N Ill· b N S. 'Î ~Ç. . 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . ,t:{., by /..- 22. If a re-drill, has a 10-403 fO,r abandonment been approved. .. ¥. 'In N 23. Adequate wellbore separation proposed.. .... . . . . . . " . . Sot N 24. If diverter required, does "it meet regulations. . .. . . . . .. . . "'IA- 25, Drilling fluid program schema~ic & equip list adequate. . . . . ' N JIJ1 It-.y 111 vJ I 0.· to r pc-¡ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ..' 27. BOPE press rating appropriate; testto ·~ÇOO psig. N MSI) "3f)1Ç 'Pf.t· ~8·. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N , (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N /\Ilk- GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . , . . Y @ APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . JrN A / ~ {¿()/} ~_ /' 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y 1/ L/, ~ j/~ 0/03 35. Seabed condition survey (if ,off-shore). . . . . .. ...... N ' . Explora ory Only) 36. Contact name/phone for weekly progress reports. ...... .. N Æ APPR DATE 1vlfA- 2i'lo~ ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RPc-¡FC TEM JDH JBR COT DTS WGA /' MJW MLB ..2/Yð '1 SFD Rev: 10/15/02 - G:\geology\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well PellTlitting 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 APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) Sperry-Sun Drilling Services LIS Scan Utility 2D3-Dd-.8 \ , 8 l C) $Revision: 3 $ LisLib $Revision: 4 $ Tue May 27 09:28:14 2003 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/05/27 Origin.................. .STS Reel Name................ UNK]\OWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date. .. . . . . . . . . . . . . . . . . . .03/05/27 Origi n. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Sci.entific Technical Services Physical EOF Comment Record TAPE HEADER PBU!EOA MWD/MAD LOGS 11 WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # cTOB DATA 17-01A 500292047601 BP EXPLORATION Sperry-Sun Drilling Services 27-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW2302699000 D. HAWKINS BORDES 1 VAU MWD RUN 2 MW2302699000 D. HAWKINS VAUGlIN 1 RAL MWD RUN 3 MW2302699000 D. HAWKINS RALL 1 t'¡¡ESLE clOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN -1 MW2302699000 D. HAWKINS RALL 1 ~^JESLC # SURFACE LOCATION SECTION: TOWNSHI P: RANGE: fNL: fSL: fEL: fh'L: ELf,VATTON (fT fROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: ¿.L lON 15E 2443 523 63.00 34.50 # WELL CASING RECORD 1ST STRING ?ND STkTNCì 3RD STRING PRODUCTION STRING OPSN HOLE CASlNG DRlLLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 6874.0 6.1?5 7.000 0175.0 RENARì\S: ) ) 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 17-01A WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 6874'MD!6730'TVD; THE BOTTOM WAS AT 6890'MDI 6744'TVD. i[. MWD RUN 1 COMPRISED DIRECTIONl\L WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUSE DETECTORS. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK AND MILL THE WINDOW. 5. MWD RUN 2 COMPRISED DIRECTIONAL; DGR; AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL; DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-t (E\ì-vR4); AND AT-SIT-INCLINATION (ABI). SESP DATA FOR ALL OF RUN 3, AND RUN 4 DOWN TO 11226 rMD ARE NOT PRESENTED DUE TO POOR DATA QUALITY FROM A MALFUNCTIONING TOOL. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-Ml\IL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 4/14/03. MWD DA'r.A ARE PDC. 8. MWD RUNS 1 - 4 REPRESENT WELL 17-01A WITH API#: 50-029-20476-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 12270'MD/903·j'TVD. SROP - SMOOTHED RATE OF PENETRA'l'ION í"lHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOO'I'HE:D PHASE: SI-tJ F"I'-[JE:RTVE:D RE:S.TS'T'IVI'T'-.i (SHALLOW SPACING) . SEMP C~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SHOOTHED PHJ\SE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SF'XE= SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ F'i.le Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/05/27 Maximum Physical Record..65535 F.i 1 e T yµe . . . . . . . . . . . . . . . . LO Previous File Namc.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED ~¡D Depth shitted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 ff FILE SUMMARY FEU TOOL CODE ROP GR FET RPD START Dt:~Tn STOt? DEPTH 6874.0 12269.0 12199.5 12206.5 12206.5 6874.0 9165.5 9165.5 ) ') RPM RPX RPS $ 9165.5 9165.5 11226.0 12206.5 12206.5 12206.5 # BASELINE CURVE FOR SI-II FTS; CURVE SHI FT DA'l'A (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH é y # MERGED DATA SOURCE FBU TOOL CODE MWD MWD ]\'IWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 6874.0 6910.0 9184.5 9283.0 MERGE BASE 6909.5 9184.5 9283.0 12269.5 # RE¡V¡ARKS; MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type... ..0 Logginq DiL'ection................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth unas....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1. 68 12 4 RPS HWD OI-J.¡V¡M 4 1 68 16 5 RPH MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1. 68 24 "/ FET M'"flD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6874 12269 9571. 5 10791 6874 12269 ROP MWD FT/H 0.02 388.81 86.8846 10791 6874 12269 GR MWD API 18.07 .515.11 91.3024 10652 6874 12199.5 RPX MWD OHMM 0.57 695.13 9.95563 6083 9165.5 12206.5 RPS [V!WD OHMM 4.13 18.22 10.5524 1962 11226 12206.5 RPM MWD OHMM 0.35 2000 15.0588 6083 9165.5 12206.5 RPD MWD OHMM 0.35 1594.72 14.3749 6083 9165.5 12206.5 fET MWD HOUR O. ::n 80.96 2.4~229 608::1 916~.~ 12206.~ First Reading For Entire File..........68"/4 Lå~t ReddlClÿ FOL EClLlre Flle.......... .12269 file Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.lLO Date of Gcncration.......03/05!27 Maximum Physical Record. .65535 File Type.............. ..La Next File Name...........STSLIB.002 Physical EOF ') File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date ot Generation.......03/05/27 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTII 6874.0 6874.0 STOP DEPTH 6909.5 6909.5 # LOG ¡--lEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REA.L-TIME) : TD DRILLER (FT): TOP 1JOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUN ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM.MA RAY $ jf BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: NUD CHLORIDES (22M): fLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MÞX CIRCULATING TERMPERATURE: MUD fILTRATE fJ..T MT: MUD CAKE AT MT: jf NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL S'l'ANDOFF I.i N) : EWR fREQUENCY (HZ): REMARKS: t- 'Y. # Data Form~t Specification Record Data Record Type..................O Data Specification B~ock 'I'ype.....O Logging Dirp~tinn................ . Dnwn Optical loq depth units_...._.....Fee~ 28-FEB-03 Insite 66.37 Mernory 6908.0 68'14.0 6908.0 .0 .0 TOOL NUMBER 136692 8.100 6874.0 NaCl Brine 9.20 .0 .0 o .0 .000 .000 .000 .000 .0 138.0 . I) .0 ') ) Data Reference Point..............Vndefined Frame Spacing.....................60 .lIN Max frames per reco.cd............ .Undefined Plbsent value...................... -999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOIO FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT .FT 6874 6909.5 6891.75 72 6874 6909.5 ROP MWDOIO FT/H 0.02 11.83 4.99083 '72 6874 6909.5 GR MvVD010 API 37.81 54.63 44.3687 ·12 68'14 6909.5 First Reading For Entire File..........6874 Last Reading For Entire File...........6909.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/27 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.003 Physical EOr File Heade.c Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/27 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.002 Comment Record fILE HEADER FILE NUMBER: RAW MWD Curves o.nd log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROE' GR $ 3 heo.der do.ta for eo.ch bit run in separate files. 2 .5000 START DEPTH 6910.0 6910.0 STOP DEPTH 9184.5 9141.0 # LOG HEADER. DATA Dl\TE LOGGED: SOfTWARE SURfACE SOFTWARE VERSION: OŒI\'t-!HOLE SOfTt^U\RE VERSION: DATA TYPE (MEMORY OR. REAL-TIME): TD DRILLER (fT): TOP LOG INTCRVl\L (fT): BOTTOM LOG INTERVAL (fT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG [viINHíU¡-"¡ ANGLE: !vLD..c'UMUM .I\.I\[GLE: 05-MAR-03 Insile 66.37 Memory 9185.0 6908.0 9185.0 J.J 32.¡ ") TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PP)vI): FLUID LOSS (C3): RESISTIVITY (OHMM) A'll TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD A'l' MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: )vIUD CAKE AT )vIT: # NEUTRON TOOL MATRIX: MATRIX DE:NSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RE)vIARKS: $ "ff Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................. Down Optical log depth uni.ts...........Feet Data Reference Point..............Undefined Frame Spacing...... ...............60 .1IN Max fLames per Leco.cd............. Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O ') TOOL NUMBER 136692 8.500 68·/4.0 LSND 10.60 48.0 8.9 4200 4.8 .000 .000 .000 .000 .0 156.2 .0 .0 Name Service Order Units Size Nsam Rep Code Offset. Channel DEPT FT 4 1 68 0 1 ROP MWD020 F'I'/ H 4 1. 68 4 2 GR MWD020 API 4 1. 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6910 9184.5 8047.25 4550 6910 9184.5 ROP MWD020 FT/I-! 0.22 251.9 63.2033 4.550 6910 9184.5 GR MWDU2U API 31.41 416.17 136. 68·¡ 4463 6910 9141 First Reading For Entire File..........6910 Ldst Reddln':) For ErlLlre F 11.e. . . . . . . . . . .9184.5 flle Trailer Service n~mc.............STSLIB.003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/05/27 Maximum Physical Record..65535 fi 1 e Type............ _ . . . LO Next File Name.......... .STSLI3.004 Physic¿:¡l EOr ) File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/05/27 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEFTll 9141.5 9165.5 9165.5 9165.:) 9165.5 9185.0 STOP DEE'TH 9230.5 9237.5 9237.5 9237.5 9237.5 9283.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM At\!GLE: Mp·'xIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 $ 11 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OIIMM) AT TEMP8RATUR8 (D8GF) MUD AT MEASURED TEMPERJ\TURE (MT): MUD AT ~X CIRCULATING TERMPE~~TURE: MUD FILTRATE AT MT: MUD CAKE AT NT: NEUTRON TOOL HATRIX: MJ\TRD: DENSITY: HOLE CORRECTION (IN): TOOL STl\NDOFF (IN): EWR FREQUENCY (HZ): REMJ\RKS: ·s ü8-MAR-03 Insite 66.37 ~I¡emory 9283.0 9185.0 9283.0 33.5 36.3 'TOOL NUMBER 129046 159439 6.125 917 5.0 flo-Pro 8.60 80.0 9.5 12000 6.2 . .500 .330 .480 75.0 116.0 "/5.0 75.0 .520 -) ) ff Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Unit s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 O]-MM 4 1 68 12 4 RPM IIIIWD030 OHHH 4 1 68 16 5 RPD HWD030 OHHH -1 1 68 20 6 FET MWD030 HOUR 4 1 68 24 ! First Last Name Service Unit Mj_n Max Mean Nsam Reading Reading DEPT FT 9141.~¡ 9283 9212.25 284 9141.5 9283 ROP MWD030 FT/H 0.56 52.47 17.7613 197 9185 9283 GR MWD030 API 58.29 334.42 9'} . 39·} 5 n9 9141. 5 9230.5 RPX MWD030 OHMH 1.15 695.43 19.9177 145 9165.5 9237.5 RPM MWD030 OHMH O. -19 2000 206.329 1-15 9165.5 9237.5 RPD MWD030 OHMM 1. 02 1594. "J2 125.502 145 9165.5 9237.5 FET MWD030 HOUR 2.83 80.96 14. 977 145 9165.5 9237.5 First Reading For Entire File..........9141.5 Last Reading For Entire Fi1c...........9283 Fi18 Trùiler Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......OJ/05/27 Maximum Physical Record..65535 File Type................ LO Next File Name........ ...STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number·...........1. 0.0 D3te of Gcncrotion...... .03/05/27 Maximum Physical Record..65535 File Tyµe................LO Previous file Namc.......STSLIB.004 COI!unen t Record FILE HEl\DER FILE NUMBER: RAW ¡VIWD Curvc0 ond log hcodcr doto for 80ch bit run in 0cporot8 filc0. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMHARï VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9231.0 12199.5 RPD 9238.0 12206.5 5 RPM RPX 9238.0 9238.0 12206.5 12206.5 ) FET ROP RPS $ 9238.0 9283.5 11226.0 12206.5 12269.5 12206.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWA.RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (. FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (PT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSrry (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) .AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: [VIUD FILTRATE .AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Formal Specification Record D.:ltù Record Type.................. 0 Dat.a Specitication Block Type.....U Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per recocd.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Dùtum Spccificùtion Block sub-t}~c...O ) 13-MAR-03 InsiLe 66.37 M.emory 12270.0 9283.0 12270.0 46.8 100.7 TOOL NUMBER 129046 159439 6.125 917.5.0 FLO-PRO 8.70 47.0 8.9 1100 5.6 .540 .270 .460 .590 76.4 162.0 76.4 76.4 Name Service Or.-de!:" Units Size Nsam Rep Code ottset Channel DCFT fT 4 1 68 0 1 ROP MWD040 FT/H 4 l 08 4 2 GR MWDU4U API 4 1 68 u j RPZ Mh'D040 OHr-TM 1 Go 1:2 RPS MT"-lDO·1 0 OHM1"-1 '1 1 6:3 16 .5 RPM MWDU4U OHMM 4 1 68 :2U .::- RPD Mí"lDO '1 0 OHMM 1 1 68 21 7 fET MWDU40 HOUR 4 1 68 2I::J 8 ) ') } First Last Name Service Unit Min Max Mean Nsam Reading Reading JEPT FT 9231 12269.5 10750.3 6078 9231 12269.5 ~OP MWD040 FT/H 0.03 388.81 108.185 5973 9283.5 12269.5 GR MWD040 API 18. en 515.11 5'} .5766 5938 92~n 12199.~J RPX H'VI1DO <10 OI-lHM 0.57 230.71 9.71237 5938 9238 12206.5 RPS MWD040 OI-lHM ·1.13 18.22 10.5524 1962 11226 12206.5 RPH HWD040 OI-lMM 0.35 168.98 10.3881 5938 9238 12206.5 RPD MWD040 OHMM 0.35 233.03 11. 6613 5938 9238 12206.5 FET MWD040 HOUR 0.31 18.4 2.14645 5938 9238 12206.5 First Reading For Entire Filc..........9231 Last Reading For Entire File...........12269.5 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/27 Haximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.006 Physical Eor Tape T:r:ailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/ OS/2·1 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOTrJN Continuation Number......Ol Next Tape N,,(!üe........... UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wri t.i.ng Library. Sc.i.en·t.i.fic Technical Services Reel Tra.iler Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ OS/27 Origin. . . . . . . . . . . . . . . . . . . 81'S Reel Namc................UNKNOWN Continuation Number...... 01 Next Reel Name...........UNKNOWN Comments.................S1'S LIS Wri.ting Library. Scientific Technical Services Physicùl EOF Physical EOF Erld Of LIS File