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Home My WebLink About202-207Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251016 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 2-36 50029220140000 190024 9/17/2025 BAKER SPN T40994 END 2-74 50029237850000 224024 9/22/2025 HALLIBURTON PATCH T40995 KU 12-17 50133205770000 208089 9/23/2025 YELLOWJACKET TEMP-CALIPER T40996 KU 24-7RD 50133203520100 205099 9/24/2025 YELLOWJACKET TEMP-CALIPER T40997 M-25 50733203910000 187086 8/31/2025 YELLOWJACKET CALIPER T40998 MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey T40999 MPF-61 50029225820000 195117 9/27/2025 READ CaliperSurvey T41000 MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG T41001 NIK SI17-SE2 50629235120000 214041 9/23/2025 HALLIBURTON IPROF T41002 NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG T41003 NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG T41003 ODSN-26 50703206420000 211121 10/7/2025 HALLIBURTON MFC24 T41004 PBU 01-25A 50029208740100 225056 9/13/2025 BAKER MRPM T41005 PBU 01-25A 50029208740100 225056 9/13/2025 HALLIBURTON RBT-COILFLAG T41005 PBU 01-31A 50029216260100 225070 9/22/2025 BAKER MRPM T41006 PBU 01-31A 50029216260100 225070 9/23/2025 HALLIBURTON RBT-COILFLAG T41006 PBU 05-09A 50029202540100 199014 9/18/2025 READ ArcherVIVID T41007 PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT T41008 PBU 07-23C 50029216350300 225043 7/4/2025 BAKER MRPM T41009 PBU 13-24B 50029207390200 224087 9/18/2025 HALLIBURTON RBT T41010 PBU 15-11C 50029206530300 210163 9/6/2025 HALLIBURTON RBT T41011 PBU 15-49C 50029226510300 215129 9/10/2025 HALLIBURTON RBT T41012 PBU H-07B 50029202420200 225064 9/30/2025 HALLIBURTON RBT-COILFLAG T41013 PBU P19 L1 50029220946000 212056 10/3/2025 HALLIBURTON RBT T41014 PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT T41015 PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D T41016 Please include current contact information if different from above. T41003NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.20 13:17:06 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,063 feet NA feet true vertical 11,135 feet NA feet Effective Depth measured 14,058 feet 11,584, 13,270 feet true vertical 11,133 feet 9,340, 10,658 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6#, 13Cr-80 13,319' 10,697' 940' MD, Packers and SSSV (type, measured and true vertical depth) See Above 938' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 7,500psi 4,930psi 6,870psi 7,240psi 8,430psi 4,760psi11,753' 9,467' 3,405' 11,144' 13,480' 14,080' 10,823' NA 2,270psi 5,410psi 3,202' Burst NA Collapse Intermediate Plugs Junk measured measured 20" 9-5/8" 201' 3,361' 11,710' TVDSize 201' NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799, ADL0312808, ADL0312809 NORTHSTAR UNIT NS-19 NORTHSTAR / NORTHSTAR OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-207 50-029-23122-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 51 Gas-Mcf 1436 173 140040818 65 191926 1099 72320 Length Production 1,896' 752'4-1/2" Casing 13-3/8" Conductor Surface Liner 7" measured true vertical Packer MD 201' Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 9-5/8"x7" BKR LTP, 7"x-41/2" LTP 4-1/2" TRM-4E SSSV Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Aras Worthington aras.worthington@hilcorp.com 907-564-4763 325-007 and 325-438 N/A Representative Daily Average Production or Injection Data Casing Pressure Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:39 am, Oct 15, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.10.14 14:18:57 -08'00' Justus Hinks (3691) RBDMS JSB 101625 J.Lau 11/10/25 ACTIVITY DATE SUMMARY 4/12/2025 ***WELL S/I ON DEPARTURE*** FUNCTION TEST WLV ***PASS*** DRIFTED W/ 3.25"CENT,8' x 1.875"3.45" CENT,1.75" S.BAILER TO 13,929' SLM, RECOVERED TRACES OF SAND RAN SPARTEK SBHPTS PER PROGRAM (see log) RAN 10'x2.5" P.BAILER (ms-fb) TO 13,926' SLM, RECOVERED .5gal SAND LRS LOADED TBG W/ 222 BBLS CRUDE. LOGGED (CBL) FROM 13,998'-12,994' MD ***CONT WSR ON 4/13/25*** 4/12/2025 T/I/O = 3840/710/105 (WELLWORK) **Assist SL** Pump 223 bbls Crude down TBG for load. Area authorities notified upon completion. SL in control of well upon departure. FWHPs = 1215/606/31 4/13/2025 ***CONT WSR FROM 4/12/25*** LOGGED (cbl) FROM 13,996'-12,994' MD RAN MULT BAILER TO 13,992' MD BRUSHED FROM 13,850'-13,950' SLM W/ 4-1/2" BLB & 3.50" G-RING SET 4-1/2" MONOPAK PACKER W/ 2.313" X-NIPPLE & WLEG @ 13,670' MD (lih: 152", od: 3.68", ser#NS 450-368 ) W/ 2-7/8" XX-PLUG (see log) EQUALIZED 2-7/8" XX-PLUG @ 13,670' MD ***CONT WSR ON 4/14/25*** 4/13/2025 Transfer 305 bbls Crude to open top tank. Secure unit & Equiptment for departure. 4/14/2025 ***CONT WSR FROM 4/13/25*** EQ & PULL 2-7/8" XX PLUG FROM MONOPACKER @ 13,670' MD SET & TEST 2-7/8" XX-PLUG W/ FILL EXT IN MONOPACKER @ 13,670' MD (lih: 40", od: 2.30", 2 x 1/4" eq-ports) ***WELL LEFT S/I ON DEPARTURE. NOTIFY PAD-OP OF WELL STATUS*** 4/27/2025 ***WELL SHUT IN ON ARRIVAL*** SAFETY MEETING IN CONTROL ROOM RIG UP AK E-LINE (PERFORATE) PT 250 L 2500 H RIH WITH RS, GR/CCL, 10' PERF GUN. OAL= 19' MAX OD= 3 3/8 PERFORATE (13579-13589) 10' 3 3/8 GUN, 6 SPF, 60 DEGREE PHASE, 22.7 GRAM CHARGES CCL STOP DEPTH=13571.8 (CCL-TS=7.2') PERFORATE (13541-13551) 10' 3 3/8 GUN, 6 SPF, 60 DEGREE PHASE, 22.7 GRAM CHARGES LOGS CORRELATED TO HES MEMORY CBL DATE 12-APR-25 JOB COMPLETE SECURE WELL AND RIG DOWN. ***WELL SHUT IN ON DEPARTURE*** 5/4/2025 ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV=PASS RUN 2-7/8" EQ PRONG. SD @ 13,350' MD (+362' high) NO MARKS MADE MULTIPLE ATTEMPTS TO PULL 4-1/2" NS MONOPAK PACKER (unsuccessful) ***CONT WSR ON 5/5/25*** Daily Report of Well Operations Northstar NS19 Daily Report of Well Operations Northstar NS19 5/5/2025 ***CONT WSR FROM 05/04/25*** HES 767 STAND BY FOR WEATHER (high winds) ***CONT WSR ON 05/06/25*** 5/6/2025 ***CONT WSR FROM 5/5/25*** R/D MOVE TO NS33 ***WELL LEFT S/I. NOTIFY PAD-OP OF WELL STATUS*** 5/10/2025 ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV=PASS RUN MULTIPLE BAILERS (recovered 3/4 cup solids) PULL 2-7/8" XX PLUG FROM NS MONOPAK PACKER @ 13,347' MD ***CONT WSR ON 5/11/25*** 5/11/2025 ***CONT WSR FROM 5/10/25*** FUNCTION TEST WLV=PASS JAR ON N.S.MONOPAK PACKER @ 13,308' MD (4 hrs 5 min) PULL 4-1/2" N.S. MONOPAK PACKER @ 13,294' MD ***CONT WSR ON 5/12/25*** 5/12/2025 ***CONT WSR FROM 5/11/25*** FUNCTION TEST WLV=PASS RECOVERED NS 4-1/2" NS MONOPAK PACKER ***MISSING ELEMENT*** RUN 4-1/2" BRUSH,3-PRONG WIRE GRAB TO FISH ELEMENT (unsuccessful) DRIFT FOR EVO TREIVE PUSH ELEMENT TO 13,825' MD SET 4-1/2" EVO TREIVE W/ 2.7" DPU @ 13,755' MD ***WELL LEFT S/I ON DEPARTURE. NOTIFY PAD-OP OF WELL STATUS*** **********4-1/2" NS MONOPAK PACKER ELEMENT LEFT IN HOLE. PUSHED TO 13,825'MD*********** 6/27/2025 ***WELL S/I ON ARRIVAL*** R/U ALASKE E-LINE PT PCE 250LP-4500HP(good) CORRELATE TO SLB GR/CCL 03-MAY-03, GEO REQUEST +3 SHIFT TO TIE INTO OH GAMMA RAY LOG IN TOWN. TAG TOP OF EVO PLUG WITH 3-1/8" GUN GAMMA RAY @ 13768' MD LAY DOWN EQUIPMENT FOR THE NIGHT. ***JOB CONTINUED ON 6/28/2025*** 6/28/2025 ***CONTINUED FROM 6-27-2025 WSR*** RIG UP ALASKA E-LINE SHOOT 2" STIM TUBE FROM 13548.5' MD - 13551.5' MD CCL OFFESET=4 FT, CCL STOP DEPTH=13546' MD, LOG CORRELATED TO SLB PERF RECORD 3-MAY-2003 TURN WELL OVER TO PRODUCTION TO POP, PLANT UPSET DELAYED FLOW TEST. ***JOB CONTINUED ON 6/29/2025 WSR*** 6/29/2025 ****CONTINUED FROM 6/28/2025 WSR*** RIG DOWN ALASKA E-LINE, TRAVEL BACK TO PRUDHOE JOB READY FOR SLICKLINE TO TROUBLESHOOT EVO ****WELL S/I ON DEPARTURE*** Daily Report of Well Operations Northstar NS19 7/4/2025 ***WELL LEFT S/I ON ARRIVAL*** WITNESS WLV FUNCTION TEST AND INSPECT SEALS- WELL CONTROL DRILL (ATP) DRIFTED W/ 3.84" NO-GO CENT TO TRSV @ 940' MD RAN FLAPPER CHECKER TO TRSV FUNCTION TESTED VLV @ 940' MD (pins unsheared-funtions normal)- ops reported some ctrl line pressure issues RAN 3.65" CENT & 2.25" PUMP BAILER S/D @ 1905' MD (light metal marks on bailer btm- no return) ATTEMPTED TO LATCH 4-1/2 EVO W/ 2-3/8 GR BARBELLED & STRAIGHT UNABLE- PUSH FISH 1,948SLM-1970'SLM ***CONT WSR ON 7/5/25*** 7/5/2025 ***CONT WSR FROM 7/4/25*** RAN 4-1/2" BLB, 3-1/2" WIRE GRAB TO 1,970' SLM (potential element in the way) RAN 10' x 2.25" P. BAILER TO 1972' SLM, PUSH EVO TO 2,007' SLM, ATTEMPT TO LATCH 4-1/2" EVO @ 2,007' SLM W/ BARBELLED 2-7/8" GR (aux- fishneck), PUSH EVO TO 2,014' SLM RAN BARBELLED 2.50" LIB TO 4-1/2" EVO @ 2,014' SLM, (smooth impression of element) RAN 4-1/2" BLB, 3-1/2" WIRE GRAB TO EVO @ 2,014' SLM (no recovery) RAN CENTRALIZED 3.80" LIB TO EVO @ 2,014', (smooth impression of element) RAN BARBELLED DBL 4-1/2" BRUSH W/ 1" SHARP POCKET POKER(w/brush) TO EVO @ 2,014' SLM, PUSH EVO TO 2,018' SLM ATTEMPT TO LATCH EVO @ 2,018' SLM W/ BARBELLED 2-3/8" GR W/STINGER (handspanging feels spongy) RAN 3.5" P- BAILER WITH SHARP 3.60 WICKER BASKET BTM TO EVO @ 2,018' SLM, PUSH EVO TO 2,033' SLM (no recovery) RAN CENTRALIZED 2.92" GAUGE RING TO EVO @ 2,033' SLM, GOT POPPED BY EVO FISH- LOST TS @ ~1,953' SLM (note: EVO Throat is 2.90" Blown up ~80) RAN 3.30" BLIND BOX TO TOP OF TS @ 1,922' SLM (clear markings of rope socket hole) JARRED ON TS @ 1,922' SLM W/ 3.60" B. GUIDE, 2-1/2" JU (sheared- no lower TS action) ***~25-30' of .125"SS LIH*** *** T.S.= 1-3/4" RS, QC,QC,5' x 2-5/8" STEM, QC,QC,5' x 2-5/8" STEM,QC,QC,1- 3/4" OJ,QC,QC,KJLSS,QC, BHA, 1-3/4" QCs, OAL= 32'*** ***CONT WSR ON 7/6/25*** 7/6/2025 ***CONT WSR FROM 7/5/25*** RAN BAITED WIRE GRABS FROM 1,710'-1,917' SLM (6 runs, multiple configurations, no wire recovered) RAN CENTRALIZED 3.00" LIB TO 1,898' SLM (no impression) ATTEMPTED TO LATCH TS W/ BAITED 2-1/2" JDC, S/D HIGH & UNABLE TO PASS 1,898' SLM RAN SLICK 2.50" LIB TO 1,922' SLM (clear rope socket impression) PLANTED 2-1/2" JD (gutted) ON TS @ 1,922' SLM w/ 3-1/2 G-BAITSUB OAL= 109"( lower TS jars active, EVO plug appears to be attached oal=72") MONITOR & MANIPULATE TBG PSI TO KEEP FISH BALANCED W/ GAS ***CONT WSR ON 7/7/25*** Daily Report of Well Operations Northstar NS19 7/7/2025 ***CONT WSR FROM 7/6/25*** JARRED ON LOST TS ATTACHED TO EVO @ 1,912' SLM FOR ~4.5hrs toolstring spangs and oj's continue to function) JARRED DWN ON LOST TS ATTACHED TO EVO @ 1,912' SLM FOR~1hr (flagged 8" travel) JARRED ON LOST TS ATTACHED TO EVO @ 1,912' SLM FOR 1hr ( toolstring spangs and oj's continue to function) RECOVERED BAITED & GUTTED 2-1/2" JD (oal: 109") FROM 1,912' SLM, SKIRT BROKEN PLANTED 2-1/2" JD (gutted) ON TS @ 1,921' SLM w/ 3-1/2 G-BAITSUB (oal= 72") JARRED ON LOST TS ATTACHED TO EVO @ 1,912' SLM FOR 1hr ( toolstring spangs and oj's continue to function/ ~6.5 total hrs) ***MAINTAIN 3,600psi ON TUBING, TO PREVENT BEING UNDERBALANCED*** ***EVO / SL TS / BAIT = 44' *** Tree Cap to Master= 7'*** ~25' .125SS WIRE FISH *** ***CONT WSR ON 7/8/25*** 7/8/2025 ***CONT WSR FROM 7/7/25*** JARRED ON TS @ 1,916' SLM FOR 45min HES 767 R/D TRAVEL FROM NS TO HES SHOP ***WELL S/I ON DEPARTURE*** 7/9/2025 ***CONT'D FROM 7/8/25*** CONT'D DEMOB EQUIPMENT FROM NORTHSTAR ***WELL S/I ON DEPARTURE*** 9/3/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, FCO, Perf, Stim Tube, Set CIBP RU P-sub, RU CTU, Function test BOP, MU BOT 3-1/8" Fishing BHA ***Continue on 9-4-25 WSR*** 9/4/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, FCO, Perf, Stim Tube, Set CIBP PT PCE 331/4600psi, RIH w/ BOT 3-1/8" fishing bha w/ 3" GS-spear, latch baited slickline toolstring at 1953', Hit 1 jar lick at 21k overpull and baitsub pulled free, POOH, lay down 3" baitsub x 2.5" JD overshot OAL 72". Fishing toolstring came back loose at the CTC, cut off CTC, re-head. RIH with baited bowen overshot (1.75" grapple) on 4" GS, and could not latch. Jarred down multiple times and could at most get at 5K overpull before slipping off. RIH with Hydraulic JDC. Tagged at similar depths and continued to slip off at 5K over. POOH for smaller grapple. RIH with Baited overshot with 1.66" grapple. Tagged at similar depth. First latch attempt slipped off at 9k overpull, unable to repeat latch, POOH for larger grapple. RIH w/ baited overshot with 1.87" grapple. Set down on fish at 1943¿ctmd, drew down WHP to 1800psi, hit 3 jar licks down to set overshot, hit 16 licks up and SL toolstring came free, worked fish up hole, pumped off fish leaving top of fish at 904¿. POOH and shorten fishing tools. ***Continue on 9/5/25 WSR*** 9/4/2025 LRS 58 Assist CTU #2 (PERFORATING). Heat seawater as needed. Job continues on 9/5/2025. Daily Report of Well Operations Northstar NS19 9/5/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, FCO, Perf, Stim Tube, Set CIBP RIH w/ short 4" GS retrieval BHA, tag baited SL toolstring at 900', latch fish and POOH. Recovered 4" baitsub x 3.70" Bowen overshot w/ 1.875" grapples 2.63' length and All slickline tools left in hole from 1.75" rope socket to 2.92" Gauge Ring. RIH w/ 3-1/8" Venturi and 3.66" mule shoe, tag at 931', attempt to work past and unable, L/K tubing w/ 50bbls 50/50, 82bbls Seawater and WHP locked up. Pump 50/50 down CT, venturi at fish/SSSV, work past SSSV depth, circulate 50/50 to surface. Drift clean down/up thru SSSV. Push evo down to the XN at 13306 MD. Continue working evo down to 13778 CTMD. Reciprocate on top of evo trieve plug and circualte well to KCL. POOH. Recover 1' of wire, small rocks, and a few pieces of rubber. Make up 2.300" x 8" snorkel to venturi. RIH and tag evotrieve plug at 13772', reciprocate on top of plug w/ KCL. POOH, Venturi basket empty. RIH w/ 3-1/8" fishing bha w/ 3"GS. ***Continue on 9-6-25 WSR*** ***Well control drill with day crew - Leak below the BOPs*** ***Well control drill with night crew -Pinholed pipe and parted pipe*** 9/5/2025 LRS 58 Assist CTU #2 (PERFORATING). Pumped 600 bbls of 120*F seawater into vac trucks. Pumped 158 bbls of returns into NS32. Job continues on 9/6/2025. 9/6/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, FCO, Perf, Stim Tube, Set CIBP Cont RIH w/ 3-1/8" fishing bha w/ 3" GS-spear. Set down on fish at 13771' make multiple attempts to latch dry and pumping, pump pipe displacement while POOH. Plug was not recovered. RIH w/ 2-1/2" GS-Spear. Tagged at 13772. Jarred 16 hits and broke free. Set back down 10' higher. POOH. OOH and have broken 4 dogs off the GS. Make up and RIH with 2.5" slick catch spear (1.81" catch). Tag evo at 13763 and get a latch. Hit 14 jar licks and slipped out of fish, relatched, hit 41 total jar licks, slipped out of fish and unable to relatch. POOH, spear came back w/ 8 missing slickcatch collets: (5) 0.5"Wx1.2"L, (2) 0.5"W x 2.2"L, (1) 0.5"W x1.5". ***Continue 9-7-25 WSR*** 9/6/2025 Job Continues from 9/5/2025 LRS 58 Assist CTU #2 (PERFORATING) Heat and transfer fluids as instructed. Job continues on 9/7/2025 9/7/2025 Job continued from 9/6/2025 LRS 58 Assist CTU #2. (PERFORATING) Filled vac truck with 300 bbls of 120*F seawater. Job continues on 9/8/2025 9/7/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, FCO, Perf, Stim Tube, Set CIBP RIH w/ 3-1/8" venturi w/ 2.30" snorkel. Pump 1.7bpm, venturi on plug at 13764' for 60bbls. POOH. Recovered 2 slick catch collets. Make up and RIH with 1.69" venturi. Recip pipe at tag 13772 CTM. Work venturi 29bbls. POOH. Venturi was empty w/ indication on the mule shoe we are tagging the lower FN. RIH w/ 2-1/8" fishing assem and 2" GS-spear, tagged Evo plug at 13768'CTM, latched and overpull 5k and 7k and appear to come free, pushed plug 20' past previous stuck depth. POOH and overpull through XN and X nipples. POOH. Recover 4-1/2" Evotrieve plug w/ all slips, and element. Recovered 5 slick catch collets, 1 GS-spear collet, and ~2' .125"SS wire. B/D fishing tools, MU 3-18" milling tools and 3.68" VBS. ***Continue on 9-8-25 WSR*** Daily Report of Well Operations Northstar NS19 9/8/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, Perf, Stim, Set CIBP RIH w/ BOT 3-1/8" milling bha w/ 3.68" VBS, tagged at 13320', mill at 1.5bpm from 13300' to 13780', PUH to 13300' and dry drift to tag at 13958', Begin milling and stall at 13952', work for 1hr to make 4' to 13956', hard milling: 4 stalls and bit stuck each time. POOH, swap VBS for a mill. Recover 1 collet from GS, 7.25" of wire, and a Venturi barrel full of formation sand. Make up and RIH with 3.700" 5-blade junk mill. Dry Tag Fill at 13967' ctm. Cleanout w/ gel sweeps to PBTD at 14053'. Pump final gel sweep & chase ooh. Break down tools & reconfigure lubricator for logging & perforating. Make up & RIH w/ HES 2.20" Logging Carrier & 3.60" DJN. Tag PBTD 14059'CTMD, Log interval 14059' - 12700', paint WHITE depth correlation flag at 13428.68. POOH. ***Continue on 9-9-25 WSR*** 9/8/2025 Job Continued6 from 9/7/2025 LRS 58 Assist CTU #2 (PERFORATING). Pumped 1065 bbls of returns into NS32. Transferred 880 bbls of 120*F seawater into the vac truck. Job continues on 9/9/2025 9/9/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, Perf, Stim, Set CIBP POOH w/ gamma/ccl log w/ 3.60 DJN. Confirm +8.5' Correction. Conduct Weekly BOP Test 300/4500psi. Function Test BOP's on well. Pressure Test PCE 300psi Low, 4500psi High. Make up & RIH w/ HES 2-7/8" MaxForce Perf Gun (28' loaded). Correct depth at flag. Perforate Interval: 13483' - 13511'. Pooh. All shots fired, ball recovered. MU and RIH w/ HES MaxFire Tools to 13,497' MD. POOH. ***Continue on WSR 9/10/25*** 9/9/2025 Assist CTU#2 ( PERFORTING ) *** Job Continued 9-10-25 *** 9/10/2025 *** Job Continued from 9-9-25 *** ( PERFORATING ) Assist CTU Pumped 40 bbls returns down NS32 TBG. *** Job Continued 9-11-25 *** 9/10/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, Perf, Stim, Set CIBP POOH w/ HES MaxFire Tools. Break down MaxFire Tools and verify good data (BHP = 5084 psi / BHT = 231 deg). Halliburton Programmed MaxFire Tool. Make up & RIH w/ HES MaxFire & Alaska EL Stim Tube (3' of stim tube) BHA. Correct depth at Flag. Fire center of Stim Gun at 13,500'. Good indication of firing (was fluid packed when stim gun went off). Pooh. At surface, verified Stim Gun fired. All Tools Intact. Pump methanol cap down Tbg. Turn over to Operations to depress fluid level to gas before setting CIBP. Make up & RIH w/ Baker 4-1/2" CIBP and RIH. Set @ 13,700' MD mid element. POOH. Perform Well Control Drill w/ Day Crew. Scenario - Pin hole Coil Leak. ***Continue on WSR 9/11/25*** 9/11/2025 *** Job Continued from 9-10-25 New AFE *** ( CEMEMT SQUEEZE ) Assist CTU # 2. heated 915 bbls Sea water to 120*F to a vac truck. *** Job Continued 9-11-25 *** Daily Report of Well Operations Northstar NS19 9/11/2025 CTU#2 1.75" CT. Job Scope: Mill CIBP, Cmt Sqz, Log, Adperf Well unable to flow from Sag Perforations. Take control of NS19 back from Operations. Function Test BOP's. Pressure Test PCE 300psi Low / 4700psi High. Test DHCV's. Good Surface Tests. Make up & RIH w/ Baker 2-7/8" Milling BHA & 3.70" Junk Mill. Circ out the 50/50 out CT & gas out well thru Facility test Separator. Pumped btms up until started getting fluid at test Sep. RIH tag CIBP @ 13,693.28' E (corr +5.76') top of CIBP 13,699.04' and corr depth and painted yellow flag. Start milling taking returns to OTT. Milled 1 hour & pushed plug down. Hung up @ 13,866, 13,909', and 13,953'. ***Continue on WSR 9/12/25*** 9/11/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Fish SL TS and Evotrieve, Perf, Stim, Set CIBP POOH w/ BOT setting tool BHA. BD BOT setting tool (1/2" ball recovered). Install night cap on BOPs and Test. Hand well over to Operations to flow test well. Well is not flowing thru the Sag Perfs. Decision made to mill plug, cement sqz, log & adperf. ***Well Control Drill - Stripper failed high WHP w/ gas*** ***End AWGRS / Start new AWGRS with different AFE*** 9/11/2025 *** Job Continued from 9-10-25 *** ( PERFORATING ) Job ending at noon for different AFE # . ***Job Continued 9-11-25 at Noon *** 9/12/2025 *** Job Continued from 9-11-25 *** ( CEMENT SQUEEZE ) Assist CTU # 2. Pumped 785 bbls 120*F Seawater into Vac Truck. Pumped 796 bbls Returns into NS32 TBG. *** Job Continiued 9-13-25 *** 9/12/2025 CTU#2 1.75" CT. Job Scope: Mill CIBP, Cmt Sqz, Log, Adperf Milling 4-1/2" CIBP down to13,953'. Hit with multiple jar licks down and stalls. Pulled heavy multiple times, POOH pumping pipe displacement. Break down BOT 3.70" mill, minimal wear. Small piece of slickline wire in center of mill. Make up & RIH w/ 2- 7/8" Milling BHA w/ 3.68" Venturi/burnshoe. Correct depth at Yellow Flag. Tag Plug at 13952' milled to 13,959,2' avg 1.1 fph (milled w/ multiple stalls) working thru btm set of perfs. ***Continue on WSR 9/13/25*** 9/13/2025 CTU#2 1.75" CT. Job Scope: Mill CIBP, Cmt Sqz, Log, Adperf Milled down to 13,959,2'. Reload Fluids & Empty OT-tanks. RIH Tag @ 13,959' and resume milling. At ~ 6am ROP increased and was able to start pushing the plug. Mill/Push CIBP to PBTD at 14053' ctm / 14044' m. Chase ooh. Had to work through tight spot/trouble area at 13950' ctm. Work through, pump gel sweep & chase ooh 80%. Break down Baker Tools. Mill face looks untouched. Outer edges are worn. 3.70" G-Ring that did not Go prior to milling run now Go's. Restriction at ~ 13950' ctm = ~ 3.69" ID. Cut off Baker Tools. Stack down & change packoffs. Stack back up. Trim 100' of pipe. Make up Cement BHA. PT PCE 250psi Low / 4500psi High. RIH w/ 2.50" Cement Nozzle. Well Control Drill / Leak btwn BOPs & Wellhead (night crew). Well Control Drill / Pin hole in CT (day crew) ***Continue on WSR 9/14/25*** Daily Report of Well Operations Northstar NS19 9/13/2025 *** Job Continued from 9-11-25 *** ( CEMENT SQUEEZE ) Assist CTU #2. Pumped 1573 bbls Returns into NS32 TBG. Pumped 1500 Seawater into Vac Trucks & heating @ 120*F. *** Job Continued 9-14-25 *** 9/14/2025 *** Job Continued from 9-13-25 *** ( CEMENT SQUEEZE ) Assist CTU # 2. Pumped 1091 bbls Returns to NS32 TBG. Pumped 900 bbls 120*F Seawater into Vac Truck. *** Job Continued 9-15-25 *** 9/14/2025 CTU#2 1.75" CT. Job Scope: Mill CIBP, Cmt Sqz, Log, Adperf Cement in Place over Top Perfs. Perform hesitation squeeze up to 2500 psi. Hold 50 mins. Good Squeeze. Bleed down squeeze pressure. Pump 30 bbls PowerVis and begin to contaminating jetting into Cement. Tag hard cement at 13811' ctm. Able to jet thru to a hard Tag at 13835'. Unable to Jet thru. Cement flashed off early. Drop 3/4" ball & still unable to jet thru cement. Chase OOH 80%. Reciprocate across all jewelry. Reciprocate across TRSSSV making 4ea up/down passes jetting at 2.5bpm across the valve. Continue chasing ooh. Jet BOP's. Recover 3/4" ball. Also had Cement rocks in the nozzle. Pumped & recovered 1.25" drift ball. Re- configure hardline. Make up & RIH w/ Baker 2-7/8" Milling BHA w/ 3.70" PDC Bit. Tag @ 13,543' milled right off, tag @ 13,757, & 13,803'. Keep on milling 1 bbl fill bites w/ 5 bbl sweep. ***Continue on WSR 9/15/25*** 9/15/2025 CTU#2 1.75" CT. Job Scope: Mill CIBP, Cmt Sqz, Log, Adperf Continue milling Cement @ 13,905' CTM down to 14000'. Stop milling until we have more milling fluids & tank space. Pressure Test Squeeze to ~ 800psi (500psi over Static Whp with Column of Seawater) for 5 mins. Whp bleeding back to ~ 350psi. Discuss w/ OE. No additional Sqz required. Continue Milling Cement to a Stall at 14042' e / 14055'. Looks like PBTD. Pump final gel sweep & chase ooh. Break down Milling Tools. Make up & RIH w/ HES 2.20" Logging Carrier & 3.25" JSN. Tag PBTD @ 14,0599.66' CTM. Log up 50 fpm Blue Flag @ 13,899.66' CTM. ***Continue on WSR 9/16/25*** 9/15/2025 *** Job Continued from 9-14-25 *** ( CEMENT SQUEEZE ) Assist CTU # 2. Pumped 1600 bbls Returns down NS32 TBG. Pumped 1200 bbls 120*F Seawater into Vac Truck. *** Job Continued 9-16-25 *** 9/16/2025 CTU#2 1.75" CT. Job Scope: Mill CIBP, Cmt Sqz, Log, Adperf Log up 50 fpm from13,899.92' CTM. Top stop 13,100' CTM. POOH pumping pipe displacement. BD HES Mem GR/CCL(+6.5' Correction / Corrected PBTD = 14,065..58'. PT MHA & MU HES 43' of 2-7/8" MaxForce Perf Guns (6 spf & 60 deg phasing) & RIH to Blue Flag & Corr Depth. Perforate 13,963' - 14,006'. POOH. BD HES spent perfs guns & Firing Head. PT MHA & MU HES 11' of 2-7/8" MaxForce Perf Gun (6 spf & 60 deg phasing) & RIH to Blue Flag & Corr Depth. Perforate 13,952' - 13,963'. POOH. BD HES Spent Perf Guns & Firing Head. Rig down CTU and prepare to demob. ***In Progress*** 9/16/2025 *** Job Continued from 9-15-25 *** ( CEMENT SQUEEZE ) Assist CTU #2. pUMPED 1364 bbls returns down NS32 TBG. *** Job Continued 9-17-25 *** Daily Report of Well Operations Northstar NS19 9/17/2025 LRS CTU #2 1.75" CT. Job Scope: Mill CIBP, Cmt Sqz Log Adperf Continue rigging down CTU, Barge unit for NS to Westdock and road unit back to LRS yard for planned maint. ***Job Complete*** 9/17/2025 *** Job Continued from 9-16-25 *** ( CEMENT SQUEEZE ) Assist CTU # 2. Rig Down and travel to Lrs Yard. Secure well. FWHP=750/0/0 Valve position upon departure SV=C WV,SSV,MV=O IA,OA=OTG 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: NORTHSTAR 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,063 NA Casing Collapse Structural Conductor NA Surface 2,270psi Intermediate 4,760psi Liner 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Aras Worthington Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799, ADL0312808, ADL0312809 202-207 CO 739 NORTHSTAR UNIT NS-19 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23122-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 11,135 14,058 11,133 3,946 NORTHSTAR OIL NORTHSTAR OIL 12.6# TVD Burst 13,319 7,240psi MD 6,870psi NA 4,930psi 201 3,202 9,467 201 3,405 10,8237" 20" 13-3/8" 201 9-5/8"11,710 3,361 907-564-4763 aras.worthington@hilcorp.com Operations Manager September 1, 2025 14,080752 4-1/2" 11,144 Perforation Depth MD (ft): See Schematic 9-5/8" x 7" BKR LTP, 7" x 4-1/2" BKR LNR Top PKR, and 4-1/2" TRM-4E SSSV 11,584' MD/9,340' TVD, 13,270' MD/10,658' TVD and 940' MD/938' TVD NA 13,480 11,753 1,896 4-1/2" See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:17 am, Jul 25, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.07.25 08:41:07 -08'00' Justus Hinks (3691) 325-438 DSR-8/14/25 10-404 A.Dewhurst 19AUG25JJL 8/18/25JLC 8/19/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.19 14:45:20 -08'00'08/19/25 RBDM JSB 082025 Page 1 of 6 Perforate Sag Well: NS19 PTD: 202-207 Well Name:NS19 API Number:50-029-23122-00 Current Status:Shut In Producer PTD #202-207 Estimated Start Date:9/01/2025 Rig:SL, EL, CT Reg.Approval Req’std?Yes Estimated Duration:7 days Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure (Ivishak):5,093 psi @ 11,000’ TVD (SBHPS 4/12/2024) 9.0 ppge Current Bottom Hole Temperature (Ivishak):255 deg F @ 11,000’ TVD (SBHPS 4/12/2024) Max. Anticipated Surface Pressure (Ivishak):3,993 psi Gas Column Gradient (0.1 psi/ft) History NS19 was drilled and completed as an Ivishak producer in 2003. The well became uncompetitive in 2018 on a GOR basis. The well has been put online as recently as 9/9/2023 and produced at a GOR of 900,000 – 1,000,000 scf/bbl, nearly double the marginal GOR at Northstar. In 2025 a plug was set over the Ivishak and the Sag was perforated. Objective If the Sag cannot be produced economically, squeeze the Sag and Ivishak and perforate the Ivishak deeper to return the well to a competitive producer. Page 2 of 6 Perforate Sag Well: NS19 PTD: 202-207 Slickline 1. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 2. Pull the Evotrieve plug set over the Ivishak perforations. 3. Fish the LIH packer element that was last pushed down to ~13,825’ MD on 5/12/2025. Alternatively, push the element down to PBTD; minimum depth is 13,975’ MD (bottom of Ivishak perforations). 4. Set a DSSSV over the TRSV. Coiled Tubing 5. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 6. Drift to PBTD with ~2.5” cementing nozzle (WSS discretion). Tag PBTD, pick up 10’ and flag pipe for depth control. 7. Liquid pack well with seawater or 1% KCL by pumping down the coil tubing and up the backside or bullhead (WSS discretion). ¾Tubing volume: 202 bbls ¾Liner volume: 10 bbls ¾Total WBV:212 bbls 8. Perform pre-cement injectivity test. 9. Lay up to 25 bbls 15.8 ppg Class G cement @ 1:1 from flag depth. a. Minimum thickening time = 10 hours. i. 1 hour mixing at surface. ii. 0.5 hours pump down coil assuming 1 bbl / minute iii. 1 hour cement placement assuming 0.5 bbl / minute iv. 2 hour squeeze time v. 2 hour contingency b. Expected bottom hole temperature 255 degF 10. Hesitation squeeze for ~2 hours targeting 2500 psi squeeze in 250 psi increments. Hold each pressure for 5-15 minutes. c. Hold max squeeze pressure for target of 45-60 minutes. 11. If hesitation squeeze is successful cleanout cement with frequent gel sweeps down to PBTD. Thoroughly jet and cleanout to PBTD. a. First contamination pass should be no later than 2/3 of thickening time. b. PBTD was tagged @ 13,983’ MD on 4/12/2025 with traces of sand recovered in the bailer. Jet and FCO sand as deep as possible; the desired adperfs are just above the liner wiper plug (14,055’ MD) in the 4-1/2” shoe tract. Page 3 of 6 Perforate Sag Well: NS19 PTD: 202-207 12.Contingent If unable to build squeeze pressure, over displace cement by 2-3 bbls and prepare to repeat squeeze attempt once cement has reached compressive strength. Or consider leaving cement to set up and milling cement. 13. After cement has reached 1000 psi compressive strength perform PT to 500 psi for five minutes. 14. Pull DSSSV. 15.MU logging tools and flag pipe for milling/perforating.Tie-in to SLB Jewelry Log / GR-CCL dated 3- MAY-2003 16. MU 3.7” Mill and motor BHA. 17. Mill to PBTD. PBTD was initially tagged with EL on 5/3/2003 @ 14,040’ MD but it is unknown it this tag was cement or fill above the liner wiper plug or if it is the liner wiper plug. Perforations are desired as deep as possible so if milling is progressing through cement and the liner wiper plug then mill to 14,058’ MD (~3’ past the top of the liner wiper plug). (Sundry Required): 18. Perforate with CT or alternatively with E-line as detailed below. Slickline 19. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 20. Drift w/ 2-7/8” Dummy Guns. E-line (Sundry Required) 21. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 22. Tie-in to SLB Jewelry Log / GR-CCL dated 3-MAY-2003 23. Perforate 14,028’ – 14,058’ (PBTD) using 2-7/8” 6 spf, 60 phased Millenium (or similar). Page 4 of 6 Perforate Sag Well: NS19 PTD: 202-207 Tie In Log Page 5 of 6 Perforate Sag Well: NS19 PTD: 202-207 ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƟĐ Page 6 of 6 Perforate Sag Well: NS19 PTD: 202-207 WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƟĐ All Ivishak & Sag perfs squeezed Perforate ± 14,028’–14,058’ MD Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40753NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250515 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-23 50283201910000 223061 4/24/2025 AK E-LINE Plug/Perf T40412 END 2-72 50029237810000 224016 4/4/2025 READ CoilFlag T40413 IRU 241-01 50283201840000 221076 4/30/2025 AK E-LINE Perf T40414 IRU 241-01 50283201840000 221076 4/23/2025 AK E-LINE Plug/Perf T40414 KU 33-08 50133207180000 224008 4/22/2025 AK E-LINE PPROF T40415 MRU D-16RD 50733201830100 180110 4/21/2025 AK E-LINE Cement/Perf T40416 NSU NS-06 50029230880000 202101 4/21/2025 AK E-LINE PPROF T40417 NSU NS-19 50029231220000 202207 4/27/2025 AK E-LINE Perf T40418 NSU NS-20 50029231180000 202188 4/24/2025 AK E-LINE Perf T40419 NSU NS-23 50029231460000 203050 4/23/2024 AK E-LINE Packer T40420 PBU 02-10B 50029201630200 200064 3/21/2025 BAKER SPN T40421 PBU 06-19B 50029207910200 224095 3/1/2025 BAKER MRPM Borax T40422 PBU S-100A 50029229620100 224083 2/28/2025 BAKER MRPM Borax T40423 PBU Z-235 (Revised)50029237600000 223055 4/1/2025 READ InectionProfile T40424 SRU 231-33 50133101630100 223008 5/1/2025 AK E-LINE Plug/Perf T40425 Revision Explanation: Processing report added Please include current contact information if different from above. T40418NSU NS-19 50029231220000 202207 4/27/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.16 08:15:21 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: NORTHSTAR 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,063 NA Casing Collapse Structural Conductor NA Surface 2,270psi Intermediate 4,760psi Liner 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Aras Worthington Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312809 202-207 CO 739 NORTHSTAR UNIT NS-19 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23122-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 11,135 14,058 11,133 3,946 NORTHSTAR OIL NORTHSTAR OIL 12.6# TVD Burst 13,319 7,240psi MD 6,870psi NA 4,930psi 201 3,202 9,467 201 3,405 10,8237" 20" 13-3/8" 201 9-5/8"11,710 3,361 907-564-4763 aras.worthington@hilcorp.com Operations Manager February 15, 2025 14,080752 4-1/2" 11,144 Perforation Depth MD (ft): See Schematic 9-5/8" x 7" BKR LTP, 7" x 4-1/2" BKR LNR Top PKR, and 4-1/2" TRM-4E SSSV 11,584' MD/9,340' TVD, 13,270' MD/10,658' TVD and 940' MD/938' TVD NA 13,480 11,753 1,896 4-1/2" See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:37 am, Jan 10, 2025 325-007 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.01.09 15:46:24 -09'00' Justus Hinks (3691) 10-404 ADL0312808, ADL0312799 SFD JJL 1/21/25 DSR-1/16/25SFD 1/21/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.27 10:00:22 -09'00'01/27/25 RBDMS JSB 012925 Page 1 of 10 Perforate Sag Well: NS19 PTD: 202-207 Well Name:NS19 API Number:50-029-23122-00 Current Status:Shut In Producer PTD #202-207 Estimated Start Date:2/15/2025 Rig:SL Reg.Approval Req’std?Yes Estimated Duration:3 days Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure (Ivishak):5,066 psi @ 11,100’ TVD (SBHPS 7/20/2023) Current Bottom Hole Temperature (Ivishak):252 deg F @ 11,100’ TVD (SBHPS 7/20/2023) Maximum Expected BHP (Ivishak):5,066 psi @ 11,100’ TVD (est.) 8.8ppg EMW Max. Anticipated Surface Pressure (Ivishak):3,946 psi Gas Column Gradient (0.1 psi/ft) Sag pressures are expected to be normally pressured and equal to or less than Ivishak pressures listed above. History NS19 was drilled and completed as an Ivishak producer in 2003. The well became uncompetitive in 2018 on a GOR basis. The well has been put online as recently as 9/9/2023 and produced at a GOR of 900,000 – 1,000,000 scf/bbl, nearly double the marginal GOR at Northstar. NS19 is an under-utilized wellbore and a good candidate for flow testing the Sag. Objective Set a plug between the Ivishak and the Sag. Perforate and flow test the Sag for economic evaluation. Page 2 of 10 Perforate Sag Well: NS19 PTD: 202-207 Procedure (Page 1 of 3) Slickline or Eline 1. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 2. Drift to PBTD to ensure no obstructions. 3. Perform SBHPS with the following stops. This will be to capture the pressure of the Ivishak prior to setting plug. a. 15 minute @ 13,902’ MD (11,000’ TVDss) b. 15 minute @ 13,524’ MD (10,800’ TVDss) c. 15 minute @ 13,268’ MD (10,600’ TVDss) d. 15 minute @ 13,021’ MD (10,400’ TVDss) 4. Record data in AWGRs well service report. Send data to the following distribution. a. Aras Worthington, OE, aras.worthington@hilcorp.com b. Gavin Dittman, RE, gavin.dittman@hilcorp.com c. Ryan Thompson, Well Integrity Engineer, ryan.thompson@hilcorp.com 5. Run tie in log GR/CLL/CBL from PBTD to 13,000’ MD. Flag wire ±13,500’ for depth control. a. Use SLB Jewelry Log / GR-CCL dated 3-MAY-2003 as tie in log. b. CBL will provide liner information for future well interventions. c. Send pdf and .las files to OE and Geo for final tie in. i. Aras Worthington, OE, aras.worthington@hilcorp.com ii. Brock Rust, Geo, brust@hilcorp.com 6. Set EVO-Trieve plug at ± 13,775’ MD. a. Plug will isolate all Ivishak perforations prior to perforating the Sag. 7. Make up Halliburton MAXFIRE tool with perf guns. a. Guns should utilize large hole diameter charges / frac charges. i. If Sag is productive, it may become desirable to frac this well in the future. 8. Perforate per the following perf intervals. a. ± 13,579 – 13,589’ MD (10’) b. ± 13,541 – 13,551’ MD (10’) Operations 9. Place well online. Get well test of unstimulated perforations. Collect fluid samples to determine oil quality. Page 3 of 10 Perforate Sag Well: NS19 PTD: 202-207 Procedure (Page 2 of 3) Slickline or Eline 10. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 11. Drift to top of EVO plug to ensure no new debris or obstructions from well test has entered wellbore. 12. Run tie in log GR/CLL from EVO plug at ± 13,775’ to 13,000’ MD. Flag wire ±13,500’ for depth control. a. Use SLB Jewelry Log / GR-CCL dated 3-MAY-2003 as tie in log. b. Send pdf and .las files to OE and Geo for final tie in. i. Aras Worthington, OE, aras.worthington@hilcorp.com ii. Brock Rust, Geo, brust@hilcorp.com 13. Observe for fluid level depth prior to running Stim Tube. a. Ensure fluid level is at least 1,500’ TVD above Stim Gun prior to firing to ensure >500psi hydrostatic pressure at stimulation depth. b. Ensure tubing fluid level is depressed at least 100’ from surface to provide an air gap between the wireline valves to the top of wellbore fluid. c. If necessary, pump fluids into well to bring up liquid level. Seawater preferred, but can use diesel or crude if available. 14. Stimulate perforations with Stim Tube per vendor recommendation. a. Basic design suggests 60% of perforation interval by length, not to exceed 15’ per stim gun. b. Oversized connections are required. Use thread lock on all connections. c. Run in hole per vendor recommended speed. Reduce running speed at fluid contacts. Operations 15. Place well online. Get well test of unstimulated perforations. Collect fluid samples to determine oil quality. Page 4 of 10 Perforate Sag Well: NS19 PTD: 202-207 Procedure (Page 3 of 3) Slickline or Eline (CONTINGENT) 16. MIRU. Pressure test PCE 250psi low, 4,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 17. Drift to top of EVO plug to ensure no new debris or obstructions from well test has entered wellbore. 18. Run tie in log GR/CLL from EVO plug at ± 13,775’ to 13,000’ MD. Flag wire ±13,500’ for depth control. a. Use SLB Jewelry Log / GR-CCL dated 3-MAY-2003 as tie in log. b. Send pdf and .las files to OE and Geo for final tie in. i. Aras Worthington, OE, aras.worthington @hilcorp.com ii. Brock Rust, Geo, brust@hilcorp.com 19. Contingent perforations will be considered based on performance of primary targets. a. ± 13,564 –13,579’ MD (15’)(CONTINGENT) b. ± 13,515 – 13,541’ MD (26’)(CONTINGENT) c. ± 13,595 – 13,615’ MD (20’)(CONTINGENT) d. ± 13,483 – 13,511’ MD (28’)(CONTINGENT) Page 5 of 10 Perforate Sag Well: NS19 PTD: 202-207 Figure 1: Tie In Log Page 6 of 10 Perforate Sag Well: NS19 PTD: 202-207 Figure 2: EVO-Trieve Data Sheet Page 7 of 10 Perforate Sag Well: NS19 PTD: 202-207 Figure 3: Laboratory Comparison of Perf Charge vs StimTube Propellant Normal Perforation Charge StimTube Propellant Page 8 of 10 Perforate Sag Well: NS19 PTD: 202-207 Figure 4: Fracture Length Modelling Page 9 of 10 Perforate Sag Well: NS19 PTD: 202-207 ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƟĐ Page 10 of 10 Perforate Sag Well: NS19 PTD: 202-207 WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƟĐ Plug set ± 13,775’ MD ± 13,579 – 13,589’ MD (10’) ± 13,541 – 13,551’ MD (10’) ± 13,564 – 13,579’ MD (15’) (CONTINGENT) ± 13,515 – 13,541’ MD (26’) (CONTINGENT) ± 13,595 – 13,615’ MD (20’) (CONTINGENT) ± 13,483 – 13,511’ MD (28’) (CONTINGENT) 4-1/2” Liner: -Set in 6-1/8” OH with top/bottom @ 13,309’ MD/14,062’ MDrespectively.-Cemented with 34 bbls (~170% excess) of 15.9 ppg Class G - Circulated ~15 bbls of cement to surface after setting the LTP. *Fully cemented to LTP. 7” Casing: -Set in 9” OH with top/bottom @ 11,584’ MD/13,480’ MD respectively. -Cemented with 102 bbls (~70% excess) of 15.9 ppg - Full returns during the cement job and circulated ~20 bbls of cement to surface after setting the LTP. *Fully cemented to LTP. U BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, ~~ t ~~ . ~rc~~v~r? ~~~,~r`l ao~- ~°7 Ns~ ~`1 Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Northstar n i~nioni n Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NSO6 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30!2009 NS08 20 0210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5!2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 .5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 " na " na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233otOt00 0 na 0 na 2.2 5/3/2009 "Not measured due to rig proximity. STATE OF ALASKA ALAS AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~EC~IVED APR 2 6 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate0 Other Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time 2~E d5ti0t1S.~1m13310f Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ~n~~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 202-2070 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-312809 ~- NS19 10. Field/Pool(s): NORTHSTAR FIELD / NORTHSTAR OIL POOL 11. Present Well Condition Summary: Total Depth measured 14063 feet Plugs (measured) None feet true vertical 11135.18 feet Junk (measured) None feet Effective Depth measured 14058 feet Packer (measured) 941 11584 13270 true vertical 11132.72 feet (true vertical) 941 9339 10658 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3361 13-3/8" 68# L-80 44 - 3405 44 - 3202 4930 2270 Intermediate 11710 9-5/8" 47# L-80 43 - 11753 43 - 9467 6870 4760 Production Liner 1896 7"26# L-80 11584 - 13480 9339 - 10823 7240 5410 Liner 752 4-1/2" 12.6# L-80 13328 - 14080 10704 - 11144 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ - True Vertical depth: _ _ _ - - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 41 - 13317 41 - 13317 Packers and SSSV (type, measured and true vertical depth) 4-1/2" TRM-4E SSV 941 941 7" Liner Toa Packer 11584 9339 7"13Cr80 Packer 13270 10658 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1292 40251 1839 792 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development 0 Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-042 Contact Gary Preble Printed Name Gary Pre I Title Data Management Engineer Signature Phone 564-4944 Date 4/23/2010 Form 10-404 Revised 7/2009 ~~~~5 Afi~ 2 ~ ~~ ~= ~/. Z7•GD Submit Original Only NS19 202-207 PERF ATTOC_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15/06 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 7/8/07 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 NS19 4/19/09 APF 13,809. 13,826. 11,011.33 11,019.53 NS19 1/26/10 APF 13,835. 13,885. 11,023.88 11,048.09 NS19 1/27/10 APF 13,805. 13,835. 11,009.4 11,023.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/12/2010 CTU #5 MIRU had to move all equipment and hardline from NS-06. """`"""` Continued on 4/13/10 4/13/2010 CTU #5 Log/Acid treatment ****' Continued from 4/12/10 **"'`* Finish RU `perform BOP test. MU PDS carrier w/ GR/CCL. Kill well w/ NH4CL w/ safelube. I RIH. Tagged at 13932' PUH to 13900' paint flag. Start logging from 13900' to 13000' at 30 fpm. POOH****** Job Continued on 4/14/10 *""*" I _ _ _ __ 4/14/2010~CTU #5 ***** Continued from 4/13/10""**** BD logging tools check for good data. MU 3.38" Inflatable Packer RIH set packer @ 13900' corr.dept~. Launch 11/2" ball and set packer, Launch 5/8" ball and open upper circ sub, establish °injectivity 1 BPM @ 2628 psi. Start pumping NHCL **job continued on WSR 04- ~ 15-10. 4/15/2010 CTU #5 **"Continued from 4-14-10""*. continue pumping pre-flush/cooling NH4CL, and 30 bbls of NH4CL w/ U67. Pumped 36 bbl's of pre-flush acid (10% HCL. Surface in-line ck valve developed drip into containment. flush line w/ freshwater and change-out valve. Pump remainder of acid pre-flush. Swap to ~ 6:1 mud acid. lump remaining treatment as planned. Pull 41.5k and treatment 1 packer released, pooh.Recoverd all elements on packer. freeze protect well with ' 39 bbls diesel. RD (notify control room to flow well back to test seperator) "'job complete*' 4/16/2010~T/I/0=250/0/187. (Acid treatment flowback) Spear into FL w/ 2 bbls neat meth ;followed by 239 bbls Mag-Ox to neutralize acid during flowback to plant. Freeze !protect surface lines w/ 3 bbls neat meth. FWHP=560/0/190 FLUIDS PUMPED BBLS 60 METH/WATER 292 NH4CL W/0.6% SAFELUBE 239 MAG-OX 140 DIESEL 30 NH4CL W/U67 761 Total TREE _ ABB-VGI5-1/8" 5KSI WEIpLHEAD= ABB-V GI 13-518" MULTBOWL SKSI ACTUATOR = BAK KB. Elf = 56.3' BF. ELEV = 40.1' (CB 16.2') KOP = 100' Max Angle = 62° @ 13713' Datum MD = 13145' Datum TVD = 10500' SS 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 3405' Minimum ID = 3.725" @ 13306' 4-1 /2" XN NIPPLE TOP OF 7" LNR 1 11584 ~ 9-5/8" CSG, 47#, L-80 BTGM, ~ = 8.681" ~ N~-S-1~9 S ES: ***4-1 /2" CHROME TBG 8~ LNR*** 940' 4-1/2" TRNF4E SSSV, fD = 3.812" w / X PROFLE GAS LEI' MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 5067 6469 4428 5474 44 41 SMOR SMOR DMY DMY BK BK 0 0 03!31103 03/31/03 11584' I-I 9-5/8" X 7" BKR LTP w /LNR HGR, ~ _ ? 13{ 229' I--I4-112" F~ER OPTIC TRANSDUCER, ~ = 3.945" (TOP OF4-1/2" LNR 4-1/2" TBG, 12.6#, 13CR-80 VAM-ACE, .0152bpf, ID = 3.958" 7" LNR, 26#, L-80 HYDRA. 521, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: JEWELRY LOG / GR CCL ON 05/03/03 ANGLE AT TOP PERF: 61 ° @ 13805' Note: Refer to Production DB for historical pert data INII7AL PERF-CHARGE 2906 POWERJET, HMX, PENETRATION: 27", HOLE 0.36", PHASE 60 DEG. SIZE SPF NYfERVAL (MD) Opn/Sqz DATE 2-718" 6 13805- 13885 O 01/27/10 2-7/8" 6 13809 - 13826 O 04/19/09 2-1/2" 6 13860 - 13905 O 09/27/05 2-7/8" 6 13860 - 13920 O 05/05/03 2-7/8" 6 13895 - 13920 O 05/15/06 2-7I8" 6 13935 - 13975 O 05/15/06 2-7/8" 6 13935-13975 O 07/08/07 U- 4-1/2" LNR, 12.6#, 13CRVAM-ACE, 14062' .0152 bpf, ID = 3.958" (13228' ELMD) 13248' 4-1/2" HES X NIP, ID = 3.813" 13270' 7" X 4-1/2" BKR LNR TOP PKR, ID = 3.875" 13294 4-1/2" HES X NIP, ID = 3.813" 13306' 4-112" HES XN NIP, ID = 3.725" (13312' ELM D) 13309' - I 7" X 5" BKR ZXP LTP, ID = ? 13319' 4-112" WLEG, ID = 3.85" 13326' ELMD TT LOGGED 05103/03 13331' 7" X 5" BKR LNR HGR ID = ? 13340' 1 5" X 4-112" XO, ID = ?~ DATE REV BY COMMENTS DATE REV BY COMMENTS 11115!02 FH INITIAL DWLL 06!28/08 WRRlPJC DRAWING CORRECT~NS 03/31/03 JAS ORIGINAL COMPLETION 06/02/09 WWR/TL ADPERF (04/19/09} 10/07!05 (fLH NEW FORMAT & TVD CORRECT. 02/03/10 RRD/PJC PERFS (01/27/10) 05!15!06 WRR/PJC PERFS J ELN~ CORRECT~N 07/22/07 RMH/PJC ADPERFS (07108107) 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIONS NORTHSTAR WELL: NS19 PB~Mff No: x2022070 API No: 50-029-23122-00 SEC 11, T13N, R13E, 1229' FSL & 646' FEL BP Exploration (Alaska) u Mr. Jack Lau Well Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 19 ao~'a°7 Sundry Number: 310-042 ~ ~~ ~ , ~ ~ ~ ~ Dear Mr. Lau: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this < ~ day of February, 2010 Encl. :Y t 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Re-enter Suspende~r~ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate Q Other ^ Specify: Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 202-2070 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 _ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^~ ^ NS19 - Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-312809 , NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14063. 11135.18 14058 - 11132.72 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface .3361 13-3/8" 68# L-80 44 3405 44 3202 4930. 2270 Intermediate 11710 9-5/8" 47# L-80 43 11753 43 9467 6870 4760 Liner 1896 7" 26# L-80 11584 13480 9339 10823 7240 5410 Liner 752 4-1/2" 12.6# L-80 13328 14080 10704 11144 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13Cr80 41 - 13317 Packers and SSSV Tvoe: 4-1/2" TRM-4E SSV Packers and SSSV MD and TVD (ft): 941 940 7" LINER TOP PKR 11584 9339 7" 13CR80 PKR 13270 1065 4-1/2" LINER TOP PKR 13328 10704 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q ° Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/21/2010 Oil Q' ~ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Lau Printed Name Jack Lau Title Well Engineer Signature Phone Date 564-5102 2/11/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Sund Numb t ti it f l N tif i i th t i C //, er: 3<v `D~~ ry a represen ve may w ness tions o approva : y omm ss on so a a Cond o Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ ~ • ` O / Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: z-1?•!~ ~oMS FES i s 20~o f R I G l~ A L ~ ,~ ~/~~a Form 10-403 Revised 07/2009 Submit in Duplicate STATE OF ALASKA (,~1~C p ~~ -" ~~~~ .~d'~ ALASK~ AND GAS CONSERVATION COMMISSI~" ~~~ ~~ APPLICATION FOR SUNDRY APPROVALS ~ ~'~~,,~~~~ ~ ~ 2Q10 20 AAC 2s.2so 'ion NS19 206-141 PFRF ~TT~rHMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15/06 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 7/8107 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 NS19 4/19/09 APF 13,809. 13,826. 11,011.33 11,019.53 NS19 1/26/10 APF 13,835. 13,885. 11,023.88 11,048.09 NS19 1/27/10 APF 13,805. 13,835. 11,009.4 11,023.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVE SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ by To: Jerry Bixby/Clark Olsen Well Operations Supervisors Date: February 1St, 2010 From: Jack Lau, Wells Engineer Mark Sauve, Northstar PE Subject: NS19 Mud Acid & SIT (w: 564-5102 c: 227-2760) (w: 564-4660 c: 748-2865) Please perform the requested well work on NS19 per the below procedure. 1 C Mud Acid & SIT w/ Stim Pkr Well Detail Current Status: Operable Online Producer Last Test: 05/07/09: 1311 BOPD, 1699 BWPD, & 45 MMSCFD Max Inclination: 62° at 13,713'; ~61 ° at Top Perf Max Dog Leg: 15.1 at 13,554' MD Minimum ID: 3.725" at the 4'/i" XN Nip C~3 13,306' MD Last TD tag: 01/21/10: Tagged 13,928' SLM w/ 2-7/8" DMY Gun & S-Bailer (no Sample recovered, sticky bottom) Last Downhole Op: 01/27/10: Adperf, Reperf Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP/BHT: 09/11/09: 5097 psia / 247°F @ 11,000 ft ss Objective The objectives of this well intervention design are to: 1) Isolate lower high water perforated intervals with inflatable stimulation packer. 2) Stimulate the upper interval with a mud acid & scale inhibitor treatment. Well History NS19 experienced a severe decline in 2004. Two consecutive Acid/Scale Inhibition treatments were performed in 2005 in an attempt to mitigate the extreme decline. The second Acid/SI treatment performed on 5/1/2005 increased the rate by 2,000 BOPD, but the increase lasted less than a month. Due to the short lived results of the Acid/SI treatments, re-perforating the top 45' of perforations using Schlumberger's PURE technique was recommended. Only the upper 45' of the original 60' section were re- perforated due to water concerns. Severe scaling required multiple drift/broach runs to ensure the perforation guns would be able to reach the targeted perforation interval While the September 2005 re-perforations did increase NS19's production, the severe scaling encountered in the drift runs indicated the bullhead Acid/SI treatments are inadequate. Therefore, a coil tubing conveyed acid job was proposed in order to insure efficient delivery of the acid to all perforations. The CTU acid job was completed 03/28/06 resulting in no change in the well's performance and no increase in produced water. Due to the poor results of the March Coil Acid Job and based on favorable results from re-perforating NS19 in September 2005, reperfs were proposed. In addition to the reperfs, adperfs were recommended to access additional reservoir below the existing perforation interval in an attempt to increase oil rate. The initial perforation interval was 92' above the oil water contact and the proposed adperf interval was 65' above the oil water contact. Despite the 92' of standoff from the oil water contact, NS19 produced X500 bbls of water. Therefore, in the event the Adperfs resulted in excessive water production a 15' gap between the perf intervals was left to set an IBP for water shut-off if required. Due to scale in the liner above the perforations, a liner acid wash was required in order to be able to access the perforation interval. The acid wash and adperf/reperf resulted in an IOR of over 4000 BOPD and the highest oil rate to date for NS19. A bullhead acid/scale inhibition treatment was completed in August 2006 to inhibit the new perforations that were shot in May 2006. The treatment resulted in 100 BOPD initial rate increase. NS19 was scheduled for a Coil Acid/Scale Inhibition Treatment during the 2007 barge season; however, the treatment was expedited to the 2007 ice road season. The Coil Acid Treatment conducted 04/03/07 resulting in a 950 BOPD increase. Following the Coil Acid Treatment, a production log was run 04/24/07. The Production Log indicated minimal production coming from the lower perforation interval. Therefore, the lower 40' of perforations were re-shot 07/08/07 resulting in a 400 BOPD rate increase. A second coil acid treatment was completed in 2007 as an attempt to remove any scale that may have formed in NS19 since its last treatment and acidize the July re-perf interval. The CT Acid treatment 08/14/07 resulted in 100 BOPD increase. Another coil HCI treatment was performed on 04/18/08 which resulted in minimal impact to production. 30' of the bottom perf interval and the bottom 20' of top pert interval were subsequently reperforated on 06/30/08 resulting in a production increase of 235 BOPD. Based on the historical rate benefits of treating NS19, an additional CTU HCUScale inhibition treatment was performed on 03/19/09 utilizing benzoic acid flakes for diversion. A small IOR benefit was observed, but short lived. Based on the declining benefit of pumping HCI treatments in NS19 and success of the 2009 NS05 mud acid treatment, the below mud acid/scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. An inflatable stimulation packer will be set to isolate the lower high water interval and a combination mud acid/scale inhibition treatment will be performed to stimulate the upper perforation intervals. Acid compatible scale inhibitor L066 will be included in the acid treatment to provide ~6 months of protection from scale build up. Operational Phases Coil tubing • Drift run -Memory CCVGR log. • Set inflatable isolation packer at 13,900'ELMD • Mud Acid & SIT • Flowback & Sampling Program Risk Discussion A risk review was held between the Wells Group and the North Star teams on 2/17/09 to discuss the risks associated with pumping aggressive HCL treatments and evaluate the feasibility of a HF treatment at Northstar. Risks were identified and mitigation plans have been developed. It is quite evident from the previous experience where using just HCI for stimulation, that main formation damage is calcium carbonate scale. This calcium carbonate poses an additional challenge for any sandstone acidizing treatment containing HF, as precipitation of Calcium Fluoride is irreversible once it happens and we must do whatever we can to avoid it. Using a regular 10 to 15%HCI treatment before the sandstone acidizing to remove most, if not all carbonate material, will greatly reduce the possibility of Calcium Fluoride precipitation. Historical Tbg/IA/OA data illustrates a large differential pressure between the tbg, ~ IA, and OA which collaborates with all available data indicating the tubing has integrity and there is no risk of pushing acid into the IA. Acid returns will be neutralized during flow back by pumping MagOx slurry through the tree cap to mitigate the risk of flowing live acid through the facility and down the disposal well. This procedure proved successful during the March-09 NS16 and NS19 HCI jobs. It is critical to have twice the volume of MagOx necessary onsite to neutralize the treatment volume of acid. Action Items from 2/17/09 risk review. • Pump and other process components were verified to be resistant to HCI. • Soft PSV components can be susceptible to HCI. Risk is minimal as operations will mitigate high pressures by establishing an open flow path from the treated well to the disposal well • Using a test separator to bypass the facility was evaluated, however this option is not recommended due to additional risk added by rerouting flow and limited space on NS. • Low/settling points in system will be inspected before and after HC1 treatments. • CIC inspection of water injection header before and after HCl treatments. • Portable acid shower/wash on site. An additional eye wash station is located in NS shop. • Contingency patch/sleeve in case of water injection header failure -North Star Ops will evaluate the need for a contingency repair • Schlumberger will provide Slicker Suits and associated acid resistant PPE for Northstar Ops • A pre-task risk assessment will be performed before sampling returns at the test separator. Use appropriate PPE and acid resistant sample containers. North Star ops have taken on the role of sampling Flowback at the test separator. • SimOps with Drilling to ensure the treatments are scheduled to avoid rig interruptions • Corrosion inhibitor package injected at wellhead during acid during Flowback was deemed not necessary due to the neutralization of the HCL at the wellhead. • HF Neutralization - Mag Oxide slurry Injection at Wellhead The proposed IBP setting depth is heavily shot, at roughly 18 spf, posing potential risk of puncturing IBP during inflate. 3D caliper log indicates ~24% wall loss in addition to perfs at the proposed setting depth. If the initial attempt fails the plan is to redress the inflatable and make a second attempt to set 10' further up hole. Scale inhibitor L066 is acid compatible and requires ~4 hour residence time prior to flow back. That being said there is risk associated with leaving HF shut in prior to flow back which can result in the loss of permeability due to damage caused by precipitate formation. To avoid this damage in the near wellbore area, the over flush has been designed to push all HF and byproducts into the formation to roughly 8 radial feet (12.5% porosity). Please review the following sections of the PE manual. <htt~://alaska.b~web.b~.com/sst drilling wells ~emanual/> Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash Section: Acid Safety & General Rig Up Section: Acid Flow Back Coil Tubing Set Inflatable Treating Packer • Previous Tag - 01/21/10: SL tagged 13,928' SLM w/ 2-7/8" DMY Gun & S- Bailer (no Sample recovered, sticky bottom). • On 05/02/06 slickline broached 1367-13700' SLM. No problems drifting or tagging TD since. • CT HCL treatment performed on 04/2/07. • A slickline drift pre-CT is not necessary as the well was last drifted on 01 /21 /10 with no problems. • 4'h" 13-Chrome tubing and liner. 1. Obtain NS19 oil sample and deliver to Schlumberger Well Services lab for pre-job emulsion/sludge testing at least 5 days prior to acid stim. 2. Contact SLB and order Mud Acid Design. Have sufficient neutralizer available to handle volume of acid. Due to the high BHT order Geovis XT for viscous sweep system. 3. SI Well. MIRU CTU. a) Note: if coil is new and has not been pickled, follow pickling procedure below. b) Ensure RU is in accordance with MMS regulations and CATII for SIWHP greater than 3500 psi. c) NS Ops has verified acid returns, including MagOX, can be flowed back through test separator to well clean up tank and down disposal well NS32. Ensure well is diverted to disposal well NS32 for FCO and Acid Stim flow back. d) Load out an additional 5 bbls HCI from volume on pump schedule. e) RU acidizing equipment. PT CT & lines. f) Line up to pump acid down CT with coil at surface & take returns to disposal well 4. MU GR/CCL memory tool. Pumping down the backside (CTxTbg annulus) knock down WHP and sweep gas from wellbore with a minimum of 1.2 wellbore volumes of 1 % KCI + 0.2% surfactant F103 (1.2 wellbore volumes = 250 bbls). Pump 30 bbls of diesel for FP. 5. With well SI, RIH TD for drift/memory log run. Log up flagging coil at +/-13900'. This flag will be used to correct coil depth to ELMD to provide good depth control for the inflatable stimulation packer. 6. POOH. Pump diesel at min rate to keep wellbore gas free. Download data and tie in to the Reference Log: Jewelry Log/GR-CCL dated 03-May-2003. 7. MU BHA to include inflatable treating packer with concentric ID circulation sub above treating packer. Stab lubricator on well. PT as per standard procedures. 8. RIH to flag, pumping diesel down CT at min rate (backside SI) and change CT depth to the corrected ELMD depth at flag from previous logging run. 9. Set Inflatable packer at 13900'ELMD per Baker rep recommendations. • If the initial attempt fails, POOH and inspect inflatable packer. If the packer was ruptured or damaged by being set in the heavily perforated interval then PU another inflatable packer and set at center of element at 13,890'ELMD, 10' up hole from the initial attempt. The caliper log indicates no perforations or metal loss from 13,889-13,891'ELMD. 10. Establish injection rate at 1 BPM or 3500 psi maximum. SD pumping. Drop 5/8" ball and circulate to seat on concentric circ sub. Open Circ sub at 3500PS1. 11. Perform infectivity test by pumping 20 bbls of 3% NH4C1 + Surfactant F103 down CT at max rate. Monitor rate, CT pressure and backside pressure in an attempt to verify inflatable packer has isolated lower perfs. Mud Acid & SIT w/ Inflatable Treating Packer Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. • Please do not filter fluids that contain L066. All filtering should be performed before the addition of the L066 scale inhibitor to insure the inhibitor does not plate out in the filters. • Please do not add friction reducer to water that will contact the formation due to formation plugging issues. • Please avoid contacting L066 with methanol or seawater -these fluids will cause premature precipitation of the L66 scale inhibitor and jeopardize the objectives of this procedure. • Please review: Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash • Filter all fluids that will enter the perforations to 3 microns absolute. Filter all NH4C1 on site using Northstar's filter pots. • The maximum recommended WHP during treatment is 3500psi. • Well is equipped with 13-CR 4~/2" tubing and liner. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. HCI should be within ±1.5% and HF should be within ±0.5% • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Pump acid within 24 hours of mixing to ensure mixture homogeneity. • In general, pump job at maximum allowable or achievable rate/pressure. Scheduled rates are estimates only. • L066 Scale Inhibitor requires a 4-hr shut in period prior to flowing back Open Perforations Zone MDT MDB H TZE 1.3,805 13,835. 30 TZE/TZD 13,835 13,860 25 TZD 13,860 13,900 40 Acid Design Details Total Footage 95' (lower 60' will be isolated with inflatable pkr) # of Perforations 1122 Wellbore Volume 209.9 bbl (to top of perfs - 13,805'ELMD) Acid Design 10% HCI Pre-Flush - 100 gal/ft 6:1 Mud Acid - 100 gal/ft Over flush - 100 al/ft Acid Volume 10% HCI Pre-Flush - 225 bbls 6:1 Mud Acid - 225 bbls Diversion Design 6#/ft at 1.5 ppg in 30# HEC Gel Diversion Volume 570#'s total Wax Beads in 30#HEC Gel Reservoir Pressure 5,097 psia / 247°F @ 11,000 ft ss 12.Hold PJSM. • Possible hazards on this job include bringing partially spent acid back to surface. • Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 13.Preheat filtered 3% NH4C1 and diesel to 100°F (Absolute minimum temperature of 80°F). • Do not heat the acid or acid mixture 14.RU Acidizing equipment. PT lines. Line up to pump fluids down the coil per the following schedule. 15.Mix/Circulate acid to ensure homogenous solution at pump time 16.Reduce wellbore temperature and condition formation rock by pumping 200 bbls of filtered 3%NH4C1 + Surfactant F103 preheated to 85-90°F at max rate. The objective is to cool the wellbore to help prevent the wax beads from prematurely melting and to displace all gas from the wellbore. The melting point of the wax beads is 190°F. Note: It is crucial that the water temperature does not exceed the melting temperature of the wax beads of 190°F. 85-90°F water should be used to reduce the wellbore temperature of 256°F to below the 190°F melting point. Ensure there is no shut down time after pumping the cool down, as the formation will quickly warm back up quickly. This volume was calculated based on actual volumes to cool NS-13 during the Aug-03 acid job. NH4C1 will be the only aqueous solution to contact HF; this prevents precipitation of alkaline fluorides. 17.Pump four stage mud acid treatment with wax bead diversion down the tubing per the treatment schedule below. Pump at max rate to corresponding with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/frac gradient). Maintain pump rate as high as feasible below frac gradient after the wax beads are in the liner. It is critical to keep the pumping pressure high after diversion break over is observed. Record pump rates, tubing, IA and OA .pressures throughout the job. Note: If the diversion. locks up causing loss of infectivity, incrementally increase pump pressure to 3500 psi (max pump pressure while liquid packed) and hold for leak off. If no leak off occurs bleed surface pressure to 0 psi and incrementally increase pressure to 3500 psi looking for leak off. Repeat pressure cycles as needed. If this does not work, as a final contingency flow back 1-2 bbls and continue with pump schedule. Note: When diverter stages contact the formation a pressure increase should be observed. If no pressure change is occurs, the wax bead concentration. is too low. If time allows and diverter concentrations can be swapped on the fly increase diversion stage concentration by 30%. Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. Mud Acid Treatment Design Schedule Stage Fluid # Stage Fluid Vol Descri tion T e bbl 1 Wellbore Coolin 3% NH4CI no U67 200 r 2 Conditioning 3% NH4C1 30 ~ rn 3 Acid Pre-Flush 10% HCI 55 `~ 4 Acid 6:1 Mud Acid 55 5 Over Flush 3% NH4CI + L066 110 6 Diversion 2001bs Wax Beads + 30#HEC 10.0 7 Spacer 3% NH4C1 5 ~ 8 Acid Pre-Flush 10% HCI 55 ~ c~ 9 Acid 6:1 Mud Acid 55 in 10 Over Flush 3% NH4C1 + L066 110 11 Diversion 2001bs Wax Beads + 30#HEC 10.0 12 Spacer 3% NH4C1 5 ~'' 13 Acid Pre-Flush 10% HCI 55 m ~ c~ 14 Acid 6:1 Mud Acid 55 i~ 15 Over Flush + L066 110 16 Diversion 2001bs Wax Beads + 30#HEC 10.0 ~ 17 Spacer 3% NH4CI 5 ~ 18 Acid Pre-Flush 10%HCI 55 ~ 19 Acid 6:1 Mud Acid 55 20 Over Flush 3% NH4CI + L066 110 18.Release IBP and begin POOH. FP and leave under balanced by pumping 30 bbls of diesel while POOH. 19.S1 in for 4 hours. Prepare to flow back acid at exactly 4 hours. Prepare to neutralize acid flow back by slip streaming MagOx. 20. Line-up the well to flow into the test separator and well cleanup tank for flowback 21. RU LRS and begin Mag OX slurry injection to neutralize flowback.. 22. Start sampling returns for analysis at Prudhoe Bay lab when the tubing volume has been brou ht back to surface. Grab 1 liter sam le in a clean nal ene bottle once per hour until the fowback is complete and the well is returned to production. Sample should be taken from the test separator. Flowback Sampling Schedule: • Initial sample after 300 bbls returned (flowline + tubing volume + 10 bbls) • Sample once per hour until 603 bbls returned • Sample at the hours 2 and 5 of both 6-hour well tests • Obtain produced fluid samples once per day for 1 week after the treatment Label bottles as: • Well: NS19 • Date/Time: • Bbls Produced: • Tests: pH, solids quantification and identification, common cations by ICP, presence of emulsions • Contact: Craig Graff 564-5185 Note: Appropriate PPE to be used during acid sampling Note: There are two separate flow back sampling programs occurring; the first is to determine the pH for Mag Ox calculations, the second is for analysis at Prudhoe Bay lab. 23.Post Flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree post acid treatment. 24.Obtain produced fluid samples once per day for 1 week after the treatment. Obtain produced fluid samples once per month for ~2 years post treatment, or until scale inhibitor returns diminish to the point the well needs to be inhibited again. These samples should be analyzed for P,Ca, Fe, B, CL, sulfates. Add well to GPB lab sampling request list. 25.Perform complete water analysis on the sample taken 1 week after treatment. Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) with any questions, comments, or concerns. i ` TREE= A~-VGI5-1 t8^ 5K61 YJELW.EAD= AB&VG113-518'MIILTBOWL5KSI ~_..o - ., _b R,~.a.~- -, AC ~ U4101t= BAKE:F2 -- -- - K8. ELEV = _. 56.3` 8F. ELEV = _ 4o.~`(C6 16,71 KOP = 1 CO" Max Angie = 62` :(~ 13713' [?aturn 1.~ = 13145` C?atuanTLfl = 1;150? SS 13-318' CSG, $8#. L-80 f3TC. ~f = 12.415' Minimum tD = 3.725" tL`y' 73306' 4-1f2"XN NEPPIE 19-5f8" GSG. 47#. L-80 BTC-M, A =8.$81` 737AS- H4-i2° ME:iX MP, ~=3.8t3' r] _ ~ 13270' i--i7°X4-ir2'BKRIhRTOPPKF2,m=3,8]5' 13294' 4-1 P2° WES X N~, b = 3.813' 13306' 4-117 HESXN NP, D =3:725' (133t2' B.I 4-i12' TBG,12.$i4, 13CR-80 VAM-ACE, 13318 .0152bpt, fl7 = 3.956" 13309' 7'X5'BKRZSCPLTP.t?=? 7' WR, 28fd, t-80 HYDfi~ 521. 13+180 13319' 4-1J2"4VLE1;, D=3.85' .0383 bp}. A = $.278' 13326' ELMD TT I:OGGE405103t03 PERFOF2ATKNJ SlN4AM,RY REF LOG'. JEWELRY LOG ! GRfi.Ct nN 05r03r'03 13331' 7" X 5' BKR LNR MGR. ~ = ANGLEATTOPPQiF: $1`13860' 13340' 5'X4-112'XO,~=? Nuie: Referto ProrLeticm DB fa trsturca! pert data NITIAL PERF - CHARGE: 2906 POLYEfLlET. HMX. PEMETR4TION 27', Ii71E 0.3$", PH4SE: $0 DEG.. SIZE SPF INTERVAL (Mr>) OpntSgz DATE 2-ir2" $ 13860- 13905 O 09t`27105 2.7x8" 6 138$0- 13920 O 05r05r03 2-Pt8" $ 13895- 1 3920 O 05115'0$ 2-114" $ 13900- 13920 O 0$f301Y78 2-1~4' $ 13935- 13955 O 0$Y30/08 2-716" $ 13935- 13975 O 05t15J0$ 2-718' $ 13935.13975 O 07106107 2-ti4" $ 13943- 139$3 O 06r30f08 SAFEf1f MATES: "'4-112" CHROME T8G b UdR`"" 9A0` 4-12"TfMAAESSSV, R=3.817 w r x PROFi.E GAS Lli°1' NDREf-S ST Mfl 'tVfl DEV TYPE VLV LA'IC;H PORT D4TE 2 1 50$67 $4~ 4428 5474 44 41 SMOR SMOR DMt' BK BK 0 0 03?31103 03?31r03 11584' 8-5.6' X 7' BKR L-iP w I wR F1GR ID = 2 4.112'wR, 12.6#, t3CRYAM .41521rpi, ~1=3.958' -` r TREE= A88-Yfi15-f,~8" SKEi ELLHEAU = ,~.BfiEt--Rte 13-G.~S" f.IULTIBOt4~L 5KS1 ACTUATCiR = &AKER KS. ELEY = 5~E2T ~~F. EtEti~ _ -- _ __- A~J.f' {'CB i5.~ KtiP _ .~. ....~..,..°.~ , ...p.. Max Anr~ _ .. u.,. ,,,_,„ ST' ,~ 330' Da>Lrn NU = i~if?n SS 138' ~ 68#. L~B7 BTC, ~7 ~ 12.415° 4443' Minimum ID = 3.725" @ '15729` 4-112" HES XN NIPPLE ToFOF 7" ~ 14369 ! X Ff~C3FIL~ ~~ 3.8f2" I ~eSSLFT MA 5 ~ a~ x r Kra FLE7C L(?CJC LT7? ~ ~ 7' I ~ ~5ra- 53.5#., L7 a~r~t-c. ~ ~ ~.- la-a~r x rte; u ~ se~s° I 4-if2' F2QPf~ T ffi'i ~ 3.958" 7" X 4 ft2"' BKft S-3 F1€R, ~5 ~ 3.8'75°' lS/7tF' H$-7tz' sx rte; u a 3as73° FERK7RA 7 iON S1M~AA fiY R~ LC;'Ci: G~-{7CL~1 f}4I15~?6 ANGLEAT TUPPERE: 24' ~ 16112` "lv;a: Referb Rroduttxsn Tl~fat traYxcalperf d~ SeE SPF WTFS{HAL {FM7) Qprv'S~z DATE 2-;,13" 6 i6f12-16132 © t?4115![76 2-7.~ 6 f61f2 - 16137 O G$Jc"tiJ1998 2-7.~" 6 161.33 - f6t52 (7 44d151'fa6 2-7~" 6 16f37 - 16162 C7 44134tf16 2-7:tY 6 16153-16172 d 44lf5Jt]6 2-718°' 6 161&4 - i6f94 G tSdf 141@76 2-7,~" 6 164 - 16224 Q 04/141136 i2.Q9R. 13GR YAkA-Tbf+, 16395' 3.956" 7" INR, , L~it7 NVf .13383 bpt. ~ ~ 6.184' 157'19' 4-11'2" } XN Nom, d ~ 3.Y%5" {15112' ELlNB {t514fi) 15729" 11.77 lftRTRCdC, t7 ~ ?" 15739' T' X 5 BKR 7.}GPLTP, D ~+'i° FK}tiFMS'tAR WELL' NS30 Nu: ~14$2rJ70 APINac 5~-0'c -2333-£~ S9C 11, T13N, it13~ iZ33 ESL 8 64~ FEL ~' 157+03' ~--IA-11'x°' SELF ALAN W~ECf, ~1 a 3,84" 1,575Q' 7"X5" f3KR FLEX LIX~f FIGR. fl ~ 7" 1575{1` 5' x ' X4, D ~ fi DP.TE REII BY S f14TE REV BY fX}tJYJ~N[S U41Q6106 N33E ACTil4LCgNPLfTd~l i2If5Jd77 W~1'PJC SAFETYNOTE{MM,5WEM1~ 04/1a~~J£+ JLJ1TtH CsLYG13 f#5J11146 JL.UTLH f?E1~5( 8) f}41t4:ia JLJ1TLfi M1fY4L i'ERFS Q71071f7d; T~.UIrD P10PEi~S{€36128K36) Ek'ittU'!36 JLJ1Tt#i {i~..GORAF"T K7NS 11t27~0T WlJG WELLi~7VL~:ATC3N q}+IS i2ft5dt77 #~Ttf~JC TRSV 6cpbtatbn (Aiaskaj STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS (RECEIVED 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver Tir~,>~,~gg ~~, COf-MI'tiSSion Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-e er Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ~ Exploratory ^ 202-2070 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 8. Property Designation (Lease N tuber) : 9. Well Name and Number \ ADLO-312809 NS19 10. Field/Pool(s): NORTHSTAR FIELD / NORTHSTAR OIL POOL 11. Present Well Condition Summary: Total Depth measured 14063 feet Plugs (measured) None feet true vertical 11135.18 feet Junk (measured) None feet Effective Depth measured 14058 feet Packer (measured) 941 11584 13270 true vertical 11132.72 feet (true vertical) 941 9339 10658 Casing Length Size MD TVD Burst Collapse Structural Conductor Surtace 3361 13-3/8"68# L-80 44 - 3405 44 - 3202 4930 2270 Intermediate 11710 9-5/8" 47# L-80 43 - 11753 43 - 9467 6870 4760 Production Liner 1896 7"26# L-80 11584 - 13480 9339 - 10823 7240 5410 Liner 752 4-1/2" 12.6# L-80 13328 - 14080 10704 - 11144 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 41 - 13317 41 - 13317 Packers and SSSV (type, measured and true vertical depth) 4-1/2" TRM-4E SSV 941 941 7" Liner Too Packer 11584 9339 7"13Cr80 Packer 13270 10658 4-1/2" Liner Too Packer 13328 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): sr ~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1468 40138 1603 798 Subsequent to operation: 1663 45120 1737 815 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas W DSPL G OR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-413 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 2/9/2010 Form 10-404 R ised 7/2009 110 ~ ~ ,Z • J~'. /v Submit Original Only ~ ~~.~io NS19 202-207 PERF OTTO[:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Mean Depth Base Tvd Depth Top Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15/06 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 7/8/07 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 NS19 4/19/09 APF 13,809. 13,826. 11,011.33 11,019.53 NS19 1/26/10 APF {/ 13,835. 13,885. 11,023.88 11,048.09 NS19 1/27/10 APF 13,805. 13,835. 11,009.4 11,023.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE r~ U ~J • NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/26/2010 "*WELL FLOWING ON ARRIVAL""" E-LINE(PERFORATION) INITIAL SHUT IN T/I/0=3500/0/400 PERFORATE 13835'-13885' WITH 2.875" PJ HSD GUN RUN #1 PERFORATED FRQI~I 13.865'-13.885' WITH 2.875" O.D. PJ HMX. ~ °GUN RUN #2 PERFORATED FROM 13,835'-13,865' WITH 2.875" O.D. PJ 'HMX. l ~RIH WITH GUN RUN #3. '"**JOB IN PROGRESS AND CONTINUED ON 27-JAN-10 WSR*** 1/27/2010"**JOB IN PROGRESS CONTINUED FROM 26-JAN-10**"(E-LINE PERFORATING) wFINAL SHUT IN T/I/0=3500/0/400 RI WITH GUN RUN #3 AND PERFORATE FROM 13,805'-13,835' WITH f X2.88" O.D. PJ HSD GOOD SURFACE INDICATION, POOH, INSPECT SHOT GUN AND RIG DOWN RETURN WELL CONTROL BACK TO OPERATOR '"**JOB COMPLETE*"* FLUIDS PUMPED BBLS 1 DIESEL 1 METH 2 Total TREE _ ABB-VGI5-1/8" 5K51 WELLHEAD= ABB-VGI 13-5/8" MULTIBOWL 5KSI ACTUATOR = BAKER KB. ELEV = 56.3' BF. ELEV = 40.1' (CB 16.2') KOP = 100' Max Angle = 62° @ 13713' Datum MD = 13145' Datum TV D = 10500' SS NS19 ~ 13-318" CSC, 68#, L-80 BTC, ID = 12.415" 3405' Minimum ID = 3.725" @ 13306' 4-1 /2" XN NIPPLE TOP OF 7" LNR 11584 ~ 9-518" CSC, 47#, L-80 BTGM, ID = 8.681" S TES: ***4-112" CHROME TBG &LNR*"* 940' ~ 4-112" TRM-4E SSSV, ID = 3.812" w / X PROFILE CAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 5067 6469 4428 5474 44 41 SMOR SMOR DMY DMY BK BK 0 0 03/31/03 03(31103 115$4' 9-5/8" X 7" BKR LTP w /LNR HGR, ID = ? 13229' I~4-1/2" FIBER OPTICTRANSDUCER, ID = 3.945" (13228' ELMD) 13248' 4-112" HES X NIP, ID = 3.813" 13270' -~ 7" X 4-112" BKR LNR TOP PKR, ID = 3.875" 13294' ~ 4-1/2" HES X NIP, ID = 3.813" ~4-112" HES XN NIP, ID = 3.725" (13312' ELMD} ~ TOP OF 4-112" LNR I-112" TBG, 12.6#, 13GR-80 VAM-ACE, .0152bpf, ID = 3.958" 7" LNR, 26#, L-80 HYDRIL 521, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: JEWELRY LOG / GR-CCL ON 05/03/03 A NGLE AT TOP PERF: 61 ° @ 13809' Note: Refer to Production DB for historical perf data INITIAL PERF-CHARGE: 2906 POWERJET, HMX, PENETRATION: 27", HOLE: 0.36", PHASE: 60 DEG. SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7t8" 6 13809 - 13826 O 04/19/09 2-1/2" 6 13860 - 13905 O 09/27/05 2-7/8" 6 13860 - 13920 O 05105103 2-718" 6 13895 - 13920 O 05!15106 2-7/8" 6 13935 - 13975 O 05/15/06 2-7/8" 6 13935 - 13975 O 07!08/07 PBTD 4-1/2" LNR, 12.6#, 13CRVAM-ACE, .0152 bpf, ID = 3.958" 13309' -~7" X 5" BKR ZXP LTP, ID = ? 13319' 4-112" WLEG, ID = 3.85" 13326' ELMD TT LOGGED 05/03103 13331' 7" X 5" BKR LNR HGR, ID = ? 1~ $~ 5" X 4-112" XO, ID = ? DATE REV BY COMMENTS DATE REV BY COMMENTS 11/15/02 FH INITIAL DRILL 06/28108 WRR/PJC DRAWING CORRECTIONS 03/31/03 JAS ORIGINAL COMPLETION 06(02(09 WWR/11 ADPERF (04119109) 10107(05 /TLH NEW FORMAT & TV D CORRECT. 05!15/06 WRR/PJC PERFS / ELMD CORRECTION 07/22/07 RMH/PJC ADPERFS (07/08107) 11/27/07 WRR/PJC WELLHD/ LOCAl1ON CORRECTIONS NORTHSTA R WELL: NS19 PERMIT No: 2022070 API No: 50-029-23122-00 SEC 11, T13N, R13E, 1229' FSL & 646' FEL BP Exploration (Alaska) r `~ Date: 02-02-2010 Transmittal Number: 93126 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastufka at (9071564-4091 Delive Contents Bottom SW Name Date Contracto Run To De th De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS19 01-21-2010 PDS 1 0 13934 SUMMARY Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center ~ ; BPXA AOGCC DNR Murphy Exploration MMS a~~ ~-~ ~~~~ David Fair Christine Mahnken Corazon Manaois Ignacio Herrera Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • • Memory Multi-Finger Caliper 5 Log Results Summary ~,;. Company: BP Exploration (Alaska), Inc. Well: NS-19 Log Date: January 21, 2010 Field: Northstar Log No.: 10611 State: Alaska Run No.: 1 API No.: 50-029-23122-00 Pipet Desc.: 4.5" 12.6 Ib. 13CR-80 VAM-ACE Top Log Intvl1.: Surface Pipet Use: Tubing and Liner Bot. Log Intvl1.: 13,934 Ft. MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the 4.5" HES XN Nipple @ 13,392' (FEND). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage, and to evaluate the extent of any restrictions that might exist. The caliper recordings indicate the 4.5" tubing and liner logged is in good condition, with no significant wall penetrations, areas of cross- sectional wall loss or I.D. restrictions recorded. The body region analysis and joint tabulation data for the 4.5" tubing and liner logged are combined. A 3-D tog plot of the caliper recordings across the pertoration intervals in the 4.5" liner logged is included in this report. 4.5" TUBING ~ LINER -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 13%} are recorded throughout the tubing and liner logged. 4.5" TUBING & LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded outside of the perforation intervals throughout the tubing and liner logged. 4.5" TUBING & LINER -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.Q. restrictions are recorded throughout the tubing and liner logged. Field Engineer: G. Etherton Analyst: HY. Yang Witness: B. Roshin & D. Doshier PrnActive diagnostic Services, Inc. ~ P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax.: (281.) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 2 oa -ao~' ~~i3aa • • PDS Multifinger Caliper 3D Log Plot ~,: ~~. Company : BP Exploration (Alaska), Inc. Field : Northstar Well : NS-19 Date : January 21, 2010 Description : Detail of Caliper Recordings Across Perforation Intervals Recorded in 4.5" Liner Logged • , Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (-36.9' - 13906.0') Well: NS-19 Field: Northstar Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: January 21, 2010 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 -33 50 2067 100 4169 GLM 2 ~ GLM 1 6294 ~ v ;_ ~ .~ Z c 200 8413 Q ~ , v o p 250 T 10527 300 r /l l 12633 329 ti 13906 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 329 • • PDS Report Overview ~. ~,, Body Region Analysis Well: NS-19 Survey Date: January 21, 2010 Field: Northstar Tool Type: UW MFC 40 No. 218451 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper {en. Lower len. 4.5 ins 12.6 f 13CR-80 VAM-ACE 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body -, metal loss body 400 300 200 100 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 345 pene. 0 339 2 0 1 3 loss 205 137 1 2 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting contusion corrosion corrosion iblehole Number of'oints dama ed total = 1 1 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n GLM 2 GI_M 1 Bottom of Survey = 329 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft) I'e~n. Ul~s~°I {Ins.) Pen. Body (Ins.) Pc~n. % Metal I oss °'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -37 O 0.01 4 I 3.98 PUP 1 -33 O 0.01 5 1 3.97 1.1 9 U 0.02 h 1 3.97 PUP 2 13 O 0.01 (i I 3.97 3 56 U 0.01 5 ' 3.95 4 98 t) 0.01 6 i 3.96 5 140 O 0.01 (~ I 3.97 6 183 t ~ 0.01 5 I 3.98 7 225 0 0.02 (~ _' 3.97 8 267 0 0.01 5 1 3.95 9 310 0 0.02 6 I 3.95 ~~ 10 352 l) 0.01 S 1 3.94 '~ 11 394 O 0.01 5 3 3.95 12 437 t( 0.01 5 ? 3.94 13 479 !) 0.01 5 ~ 3.94 14 521 t) 0.01 ~ 1 3.94 15 564 U 0.02 6 3.93 16 606 O 0.01 ~ i 3.94 ~ 17 648 (1 0.01 .5 ~ 3.94 18 691 t) 0.01 (, 1 3.95 19 733 U 0.02 (~ _' 3.95 20 775 U 0.01 i _' 3.94 21 817 U 0.01 5 1 3.94 21.1 859 0 0.01 5 U 3.98 PUP 21.2 869 U 0 0 U 3.81 4.5" lRM-4E SSSV 21.3 874 () 0.01 4 1 3.96 PUP 22 885 t) 0.01 4 ~ 3.95 23 927 U 0.02 6 3.96 24 969 (~ 0.01 4 .' 3.95 25 1011 U 0.01 5 ' 3.96 26 1053 U 0.01 S 3.95 27 1095 U 0.01 5 3.95 28 1137 U 0.01 5 1 3.95 29 1179 U 0.02 b 3.96 30 1222 U 0.01 6 I 3.95 31 1264 U 0.02 6 ~' 3.96 a2 1306 U 0.01 ~' ~ 3.95 a 33 1348 t? 0.01 `i _' 3.96 34 1391 ;? 0.01 3.96 35 1433 U 0.02 i ? 3.96 `~ 36 1475 t) 0.01 5 ! 3.95 37 1518 O 0.01 5 3.96 38 1560 O 0.01 4 ! 3.94 39 1602 a 0.01 5 4 3.94 40 1644 O 0.01 5 1 3.94 41 1687 t) 0.01 5 1 3.95 42 1729 U 0.01 6 1 3.95 43 1771 U 0.01 5 2 3.95 44 1814 U 0.01 b I 3.94 - 45 1856 !? 0.01 5 4 3.93 - Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft.) I'e~n. t 1t~set Ibis.) Pen. Body (Ins.) Pen. % ~~1e),~I Loss "~<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1898 U 0.01 5 3 3.95 47 1940 t) 0.01 5 3 3.94 48 1983 U 0.01 5 I 3.95 49 2025 l) 0.01 5 -1 3.94 50 2067 ~> 0.01 5 s 3.95 51 2109 t) 0.01 5 I 3.93 52 2152 ~) 0.01 ~ I 3.93 53 2194 O Q02 6 I 3.93 54 2236 U 0.01 5 1 393 55 2278 O 0.02 6 1 3.93 56 2321 i) 0.02 7 1 3.92 57 2363 U 0.01 G I 392 58 2405 t) 0.02 E~ I 3.94 59 2447 a 0.01 f~ 1 3.95 60 2489 i) 0.01 2 I 3.95 ' 61 2532 t) 0.02 6 1 3.94 62 2574 U 0.01 f~ 1 3.94 63 2616 ~ ? 0.02 7 I 3.95 64 2659 ~) 0.02 6 I 393 65 2701 U 0.02 6 I 3.93 66 2743 U 0.02 6 I 3.92 67 2783 0 0.01 ~ 1 3.R4 68 2825 U 0.01 5 1 3.94 69 2866 U 0.02 Ei 1 3.94 70 2908 U 0.01 ~ ~ 3. 4 " 71 2 950 i) 0.02 (, • 3.94 72 2992 ~? 0.01 5 I 3.92 ~ 73 3034 O 0.01 _' 3.92 74 3076 U 0.01 5 _' 3.94 75 3118 t) 0.01 5 1 3.92 76 3160 U 0.01 6 3.92 77 3202 0 0.02 G I 3.93 78 3244 l) 0.01 S I 3.92 79 3286 l) 0.01 -{" 1 3.92 80 3326 U 0.01 ~ I 3.92 81 3369 t) 0.01 6 I 3.92 82 341 1 O 0.01 4 1 3.92 83 3453 O 0.01 -l I 3.93 84 3495 l) 0.01 ~ 1 3.92 85 3537 U 0.01 4 1 3.92 86 3579 O 0.01 2 1 3.91 87 3620 U 0.01 4 1 3.92 88 3662 U 0.01 6 1 3.92 89 3704 U 0.01 4 1 3.92 90 3746 U 0.01 4 1 3.92 ' 91 3789 U 0.01 4 1 3.91 ~ 92 3831 t) 0.01 6 1 3.92 ~ 93 3873 U 0.01 4 I 3.93 94 3915 t) 0.01 (> I 3.93 95 3957 O 0.01 d i 3.93 ~~ _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wail: 0.271 in Eield: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft) Pen. U(>set (Ins.) Pen. Body (Ins.) Pen. % ~~letal I c,~ss "~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 96 4000 U 0.01 4 1 3.93 97 4042 i) 0.01 Z 1 3.91 °' 98 4084 n 0.01 4 i 3.93 99 4127 t~ 0.01 =l i 3.92 100 4169 O 0.01 4 1 3.92 101 4211 U 0.01 4 I .92 102 4253 t) 0.01 4 I 3.92 103 4296 U 0.01 4 1 3.93 104 4338 0 0.01 6 1 3.92 105 4380 O 0.01 4 I 3.93 106 4422 O 0.01 4 1 3.92 107 4465 (1 0.01 4 1 3.90 108 4507 U 0.01 6 1 3.90 109 4549 i) 0.01 ~ 1 3.91 110 4591 i) 0.01 6 1 3.91 111 4634 l) 0.01 .~ 1 3.90 112 4676 U 0.01 4 I 3.90 ~ 113 4718 l) 0.01 4 :' 3.91 114 4760 O 0.01 4 ? 3.91 115 4803 O 0.01 4 3.92 116 4845 t) 0.01 4 3.91 117 4887 U 0.01 4 i 3.91 118 492 9 O 0.01 4 ) 3.92 119 4968 O 0.01 4 1 3.92 119.1 5010 U 0.01 4 1 3.92 PUN 119.2 501 7 t) 0 t) t) N A GLM 2 Latch @ 7:00 119.3 5029 t) 0.01 <1 I 3.92 PUP 120 5037 U 0.01 4 1 3.90 121 5079 O 0.01 4 _' 3.91 122 5118 (1 0.01 4 4 3.90 123 5160 U 0.01 4 ~' 3.89 ' 124 5202 0 0.01 4 3 3.91 125 5244 O 0.01 2 1 3. 2 t 126 5287 (1 0.02 6 I 3.91 127 5329 U 0.01 4 1 3.90 t 128 5371 U 0.01 4 2 3.90 ~ 129 5413 U 0.01 4 3 3.91 130 5456 0 0.01 4 ? 3.91 131 5498 U 0.01 4 i 3.92 132 5540 O 0.01 4 i 3.90 ~ 133 5582 ~) 0.01 ~ 3.91 134 5624 U 0.01 4 3.89 ~ 135 5667 U 0.01 4 ~ 3.91 136 5709 O 0.01 4 3.91 137 5751 t) 0.01 4 ~ 3.92 138 5793 (~ 0.01 4 1 3.89 139 5835 U 0.01 4 1 3.90 140 5877 i ~ 0.01 4 1 3.90 141 5919 U 0.01 4 I 3.91 142 5961 t) 0.01 4 I 3.90 _ Penetration Body Metal Loss Body Page 3 a • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LU.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft.) Porn. Ut~se~l (Ins.) Pen. Body (Ins.) Pen. % ~~Icial Loss "<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 143 6002 U 0.01 4 1 3.90 144 6044 U 0.01 4 2 3.90 145 6086 U 0.01 -1 a 3.89 146 6129 t) 0.01 ~ 3 3.89 147 6171 t) 0.01 4 1 3.89 148 6213 t) 0.01 4 3.90 149 6255 +~ 0.01 4 ) 3.90 150 6294 ~ i 0.01 a ~' 3.90 151 6336 tJ 0.01 4 ~ 3.90 152 6379 i r 0.01 4 3.90 152.1 6420 t) 0.01 4 t) 3.91 PUP 152.2 6426 O 0 0 U N A GLM 1 Latch C~3 9:00 152.3 6441 t) 0.01 4 I 3.98 PUP 153 6449 U 0.01 Z ? 3.93 154 6491 l) 0.01 4 ~' 3.96 155 6533 U 0.01 4 3.94 156 6575 a 0.01 4 ! 3.97 157 6617 0 0.01 2 i 3.95 158 6638 (~ 0.01 2 I 3.96 159 6680 t) 0.01 4 3.94 160 6722 i1 0.01 4 I 3.95 161 6764 O 0.01 4 s 396 162 6806 U 0.01 2 I 3.95 163 6849 t } 0.01 -1 ~' 3.96 164 6891 t) 0.01 2 Z 3.94 165 6933 U 0.01 4 I 3.95 166 6976 t) 0.01 4 I 3.95 167 7018 t~ 0.01 4 I 3.95 168 7060 t) 0.01 ~ ~ 3.94 169 7103 c) 0.01 4 ~ 3.94 170 7145 i) 0.01 4 1 3.95 171 7187 t) 0.01 4 3 3.93 172 7230 O 0.01 4 2 3.95 173 7272 t? 0.01 4 ? 3.95 174 7314 t) 0.01 4 ~ 3.95 ~ 175 7356 U 0.01 4 ~ 3.94 176 7399 t) 0.01 2 I 3.95 177 7441 t) 0.01 4 _' 3.95 178 7483 U 0.01 ? 3.95 179 7525 O 0.01 =1 395 180 7568 ! ? 0.01 -1 3.94 181 7610 t ~ 0.01 4 3.95 182 7652 O 0.01 ? 3.95 183 7694 U 0.01 2 I 394 184 7737 t) 0.01 2 I 3.95 ` 185 7779 t? 0.01 4 3.94 186 7II22 t) 0.01 4 -t 3.95 187 7864 t) 0.01 2 1 3.95 188 7906 t) 0.01 4 3.95 189 7948 t r 0.01 ~ 1 3.93 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft.) I'~~n. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss `%, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 190 7991 U 0.01 4 1 3.93 191 8033 i) 0.01 2 2 3.94 192 8075 U 0.01 4 ? 3.93 193 8117 l) 0.01 4 1 3.94 ~ 194 8160 1) 0.01 4 _' 3.94 19 8202 a 0.01 4 3.94 196 8244 ~) 0.01 3.95 197 8286 l) 0.01 4 1 3.93 198 8329 t) 0.01 -1 I 3.92 199 8371 t~ 0.01 4 I 3.93 200 8413 ~ I 0.01 4 I 3.92 201 8455 ~) 0.01 ~ I 3.94 202 8498 t) 0.01 l I 3.93 203 8540 O 0.01 4 I 3.93 204 8582 U 0.01 =t 1 3.94 205 8624 t) 0.01 4 _' 3.94 ~~ 206 8667 U 0.01 4 1 3.93 ~ 207 8709 U 0.01 ~' ~ 3.93 208 8751 t) 0.01 4 1 3.95 209 8793 t I 0.01 ~ I 3.94 210 8835 t~ 0.01 4 I 3.94 211 8878 U 0.01 4 I 3.94 212 8920 O 0.01 2 ~ 3.94 213 8962 l) 0.01 4 1 3.92 214 9005 U 0.01 4 ? 3.94 215 9047 U 0.01 4 1 "3.92 216 9089 l) 0.01 2 1 3.94 r 217 9131 0 0.01 4 1 3.94 218 9174 U 0.01 4 1 3.93 ~ 219 9216 !) 0.01 4 I 3.93 220 9258 0 0.01 4 1 3.94 ~ 221 9301 t) 0.01 4 ~ 393 222 9343 t I 0.01 '1 1 395 223 9385 t) 0.01 4 ,? 3.93 224 9428 t) 0.01 4 I 3.94 225 9470 t) 0.01 2 I 3.92 226 9512 l) 0.01 4 1 3.92 227 9554 U 0.01 4 I 3.95 228 9597 U 0.01 ~' 1 3.94 ` 229 9639 n 0.01 2 1 3.93 230 9681 t) 0.01 -1 ? 3.94 231 9724 U 0.01 4 s 3.93 232 9766 U 0.01 ? I 3.94 233 9808 U 0.01 4 1 3.93 234 9850 0 0.01 2 ~ 3.93 235 9893 t) 0.01 a I 3.94 236 9935 U 0.01 ~ 1 394 ° 237 9978 t) 0.01 4 1 3.93 238 10020 tl 0.01 4 3.93 ~ 239 10062 t) 0.01 4 ~' 3.94 _ Penetration Body Mctal Loss Body Page 5 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft) P~~n. UI>sc~l (Ins.l Pen. Body (Ins.) Pen. % ~V1et,~l Ic>ss "r~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 240 10104 0 0.01 4 1 3.93 241 10147 (? 0.01 4 3 3.92 242 10189 (? 0.01 4 2 3.93 243 10231 (? 0.01 4 1 3.93 244 10273 U 0.01 2 ~' 3.91 245 10316 U 0.01 _' _' 3.93 246 10358 (? 0.01 ~1 1 3.92 ~ 247 10400 n 0.01 4 2 3.93 248 10442 l) 0.01 4 3.92 249 10485 O 0.01 ? 3.93 250 10527 l~ 0.01 4 ~ 3.93 251 10568 O 0.01 2 1 3.92 252 10610 U 0.01 4 1 3.92 253 10653 (? 0.01 4 y 3.93 254 10695 (? 0.01 4 1 3.93 255 107 8 (? 0.01 ~i 2 3.93 256 10780 a 0.01 L 1 3.92 257 10822 0 0.01 4 1 3.92 258 10862 O 0.01 :' 1 3.93 259 10905 (? 0.01 Z 1 3.93 260 10947 a 0.01 4 1 3.93 261 10989 U 0.01 ! 3.92 262 11032 U 0.01 -1 1 3.92 263 11074 0 0.01 4 i 3.92 ~ 264 11116 O 0.01 4 ~ 3.92 265 11159 O 0.01 ~' 3.91 ' 266 11200 O 0.01 ~t I 3.91 267 1124 0 0.01 4 1 3.92 268 11285 U 0.01 Fi I 3.93 269 11325 U 0.01 4 ~ 3.93 270 113 7 t? 0.01 ~ 1 3.91 ~' 271 11409 c? 0.01 ~t 3.92 ~ 272 11451 i? 0.01 4 I 3.93 273 11494 ;? 0.01 4 3.93 274 11536 t? 0.01 4 ~ 3.92 275 11579 U 0.01 4 3 3.92 276 11621 (? 0.01 4 ~' 3.91 277 11661 0 0.01 ~ i 3.92 278 11702 a 0.01 4 3.91 279 11744 (l 0.01 2 4 3.91 280 11787 (7 0.01 1 1 3.92 281 11829 tJ 0.01 ~' 1 3.93 282 11871 U 0.01 d 1 3.93 283 11914 i) 0.01 4 1 3.92 284 11956 ll 0.01 4 I 3.92 285 11998 U 0.01 4 1 3.91 286 12041 ~? 0.01 4 I 3.92 287 12083 l? 0.02 i I 3.91 288 12125 (~ 0.01 4 I 3.92 ° 289 12168 U 0.01 ? I 3.93 _ Penetration Body Metal Loss Body Page 6 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft.) i'~•n. Upx~i (Ins.) Pen. Body (Ins.) Pen. % ~ic~t,,l Ic~ss °4> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 290 12210 ~) 0.01 4 ! 3.91 291 12252 U 0.01 2 1 3.92 292 12295 l) 0.01 4 I 3.91 293 12337 U 0.01 4 I 3.92 294 12379 ~) 0.01 -d 1 3.92 295 12422 ~) 0.01 ~ I 3.92 296 12464 n 0.01 4 I 3.91 297 12506 ! ~ 0.01 3 1 3.92 298 12548 I) 0.01 4 I 3.93 299 12591 a 0.01 4 1 3.92 300 12633 )~ 0.01 4 ~ 3.92 ~ 301 12675 U 0.01 2 ~' 3.91 302 12717 ~) 0.01 4 I 3.92 303 12759 )) 0.01 ~1 1 3.90 304 12802 U 0.01 4 3.92 305 12844 U 0.01 4 3 3.91 306 12886 0 0.01 4 1 3.92 307 12929 0 0.01 4 I 3.91 308 12971 O 0.01 2 -1 3.92 309 13013 U 0.01 4 ~ 3.91 310 13055 U 0.01 4 ? 3.93 311 13097 U 0.01 4 I 391 312 13140 0 0.01 4 1 3.92 313 13182 U 0.01 2 1 3.92 313.1 13225 ~) 0.01 _' 1 3.94 PUP 313.2 13235 ~) 0 t) li 3.95 4.5"FiberO tic Transducer 313.3 13243 !) 0.01 4 I 3.94 PUP 313.4 13250 i) 0 )1 U 3.81 4.5" HES X Ni le 313.5 13257 li 0.03 11 I 3.93 PUP 313.6 13266 0 0.01 4 I 3.94 PUP 313.7 13276 t) 0 0 U 3.88 7" X 4.5" Baker Liner To Packer 313.8 13281 U 0.01 4 I 3.93 PUP 313.9 13291 O 0.02 8 1 3.92 PUP 314.1 13300 t) 0 U U 3.81 4.5" HES X Ni le 314.2 13302 U 0.03 1 U 1 3.94 PUP 314.3 13312 U 0 U ~) 3.73 4.5" HES XN Ni le 314.4 13314 U 0.04 13 I 3.92 PUP Shallow ittin . 314.5 13323 U 0 c) i~ 3.85 4.5"Tubin -Tail WLEG 314.6 13325 O 0 U U N A 7" X 5" Baker ZXP LTP 314.7 13338 O 0 0 O N A 7" X 5" Baker Liner Han er 314.8 13349 U 0 l) U N A 5" X 4.5" Cross-over 314.9 13350 t) 0.03 1 t) 1 3.94 PUP 315 13354 l) 0.01 4 1 3.91 316 13397 U 0.01 4 3 391 W 317 13439 t) 0.01 2 ? 3.92 318 13482 t) 0.01 4 3.91 319 13524 ~) 0.01 4 1 3.91 320 13567 t) 0.01 4 I 3.92 321 13610 )? 0.01 ~ ! 3.91 322 13653 U 0.01 ~ 3.91 ' _ Penetration Body ~titetal Loss Body Page 7 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-19 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: January 21, 2010 Joint No. Jt. Depth (Ft.) I'E•n. t!pset (Ins.) Pen. Body (Ins.) Pen. °4, Metal toss "4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 323 13Fi96 ~) 0.01 4 3.90 324 13739 U 0.02 ti Z 3.90 325 13781 t~ 0.01 ~ I 3.92 326 13800 ~~ 0.25 X32 ~~ 3.83 Perforatio s. 327 13 21 l?.It, 0.23 t~~ I! 3.90 Perforations. 328 13864 ~) 0.27 100 L5 3.83 Perforations. 329 13906 i1.1C~ 0.27 100 Z' 3.85 Perforations. _ Penetration Body Metal Loss Body Page 8 WELLHEAD = ABB-VGI 13-5 ACTUATOR = BAKER KB. ELEV. _ 56.3' BF. ELEV = 40.1' (CB 16.2') KOP _ 100 Maz Angle = 62° @ 13713' Datum MD = _ 13145' Datum ND = 10500' SS 13-3/8" CSG, 68#, L-80 BTC, iD =12.415" Minimum ID = 3.725" @ 13306' 4-1/2" XN NIPPLE TOP OF 7" LNR 19-5/8" CSG, 47#, L-80 BTC-M, D = 8.681" 1 NS19 SAFETY~ES: ***4-1 /2" CHROME TBG 8~ LNR"'*" 4-1/2" TRNt-4E SSSV, ID = 3.812" w / X PROFILE GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 5067 6469 4428 5474 44 41 SMOR SMOR DMY DMY BK BK 0 0 03!31!03 03131/03 9-5/8" X 7" BKR LTP w /LNR HGR, D = ? 13229' H4-1/2" F~ER OPTIC TRANSDUCER, ID = 3.945" 41/2" HES X NIP. ID = 3.813" 13274, I-{7" X 4-1/2" BKR LNR TOP PKR, ID = 3.875" 13294' 4-1 /2" HES X Nom, D = 3.813" 14-1/2" HES XN NI'. ID = 3.725" (13312' ELM D1 1 TOP OF 4-112" LNR 4-1/2" TBG, 12.6#, 13GR-80 VAM-AGE, .0152bpf, D = 3.958" 7" LNR, 26#, L-$0 HYDRA 521, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: JEWELRY LOG / GR-CCL ON 05/03/03 ANGLE AT TOP PERF: 61 ° @ 13809' Note: Refer to Production DB for historical pert data INff1AL PERF -CHARGE: 2906 POWERJET, HNDC, PENETRATION: 27", HOLE 0.36", PHASE 60 DEG. SIZE SPF INTERVAL (W~) Opn/Sqz DATE 2-7/8" 6 13809 - 13826 O 04!19109 2-1/2" 6 13860 - 13905 O 09/27/05 2-7/8" 6 13860 - 13920 O 05/05/03 2-718' 6 13895 - 13920 O 05/15/06 2-7/8" 6 13935 - 13975 O 05/15/06 2-7/8" 6 13935 - 13975 O 07/08/07 4-112" LNR, 12.6#, 13CR VAM-ACE, .0152 bpf, ID = 3.958" 1~~ 13319' 13326' 13331' 1334x• DATE REV BY COMMENTS DATE REV BY CONWBVTS 11/15/02 FH INITIAL DRILL 06/28/D8 WRRlPJC DRAWING CORRECTIONS 03/31/03 JAS ORIGINAL COMPLETION 06/02/09 WWR/TL ADPERF(04/19(09) 10!07/05 /TLH NEW FORMAT & TVD CORRECT. 05/15/06 WRR/PJC PERFS / ELIVID CORRECTION 07/22/07 RMH/PJC ADPERFS (07/08/07) 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIONS ABB-VGI5-1/8" 5KS1 /8" MULTIBOWL 5KSI -~ 7" X 5" BKR ZXP LTP, ID = ? 4-1/2" WLEG, D = 3.85" E]_Iu1D TT LOGG®05/03103 7" X 5" BKR LNR HGR, D = ? NORTHSTAR WElL: NS19 PERMff No: 2022070 RPI No: 50-029-23122-00 SEC 11, T13N, R13E, 1229' FSL &646' FH- BP Exploration (Alaska) SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mark Sauve Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 309-413 Lu Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, N rman Commissioner DATED this / 9 day of December, 2009 Encl. STATE OF ALASKA (/�' j' ECE1VE® � • ► ALASAIL AND GAS CONSERVATION COMMISSION DEC 0 9 2009 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 41oska Oil & Gas Cons. Commission 1. Type of Request: Abandon Suspend Operational shutdown Perforate � Re -enter Sus e Yp q ❑ P ❑ P ❑ ❑ p 'Mge❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑ Specify: Change approved program ❑ Pull Tubing ❑ Perforate New Pool E] Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -2070 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23122 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No F1 NS19 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO - 312809 NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14063 ' 11135.18 14058 11132.72 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3361 13 -3/8" 68# L -80 44 3405 44 3202 4930 2270 Intermediate 11710 9 -5/8" 47# L -80 43 11753 1 43 9467 6870 4760 Liner 1896 7" 26# L -80 11584 13480 9339 10823 7240 5410 Liner 752 4 -1/2" 12.6# L -80 13328 14080 10704 11144 8430 7500 Perforation Depth MD (ft): 1 77 th ep TVD (ft): Tubing Size: T bing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13Cr80 41-13317 Packers and SSSV TVDe: 4 -1/2" TRM -4E SSV Packers and SSSV MD and TVD (ft): 941 940 7" LINER TOP PKR 11584 9339 7" 13CR80 PKR 13270 1065 4 -1/2" LINER TOP PKR 13328 10704 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑✓ - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/23/2009 Oil 0- Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve Title Production Engineer Signature Phone Date 564 -4660 12/9/2009 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY �/J�J Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2 / " 413 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: I Subsequent Form Required: / D - L/® APPROVED BY Approved by: C MMISS ER THE COMMISSION Date: 14 ' OkfGINAL Form 10 -403 Revised 07/2009 Submit in Duplicate I NS19 202 -207 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15/06 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 7/8/07 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 NS19 4/19/09 APF 13,809. 13,826. 11,011.33 11,019.53 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • by To: Jerry Bixby /Clark Olsen Date: December 8, 2009 Well Operations Supervisors From: Mark Sauve, Northstar PE (w: 564 -4660 c: 748 -2865 h: 336 -6128) Subject: NS19 Perfs AFE: NSFLDWL19 -C Cost: $100M IOR: 200 Please perform the requested well work on NS19 per the below procedure. H 2 1 S D &T w/ 2 -7/8" DMY Gun Obtain Sample, Need 13,885' E Perf 80' Btm shot at 13,885' Well Detail Current Status: Producer Last Test: 12/6/09: 1192 BOPD, 1591 BWPD, 38.8 MMSCFPD Max Inclination: 62 at 13,713' md; 60 at Perfs Max Dog Leg: 15.1 deg /100' at 13,554 and Minimum ID: 3.725" @ 13,306` md, 4.5" XN Nipple Last TD tag: 4/17/09: 2 -7/8" dummy gun tagged TD @ 13,945' WLMD (corr) . Last Downhole Op: 9/28/09: SBHP Survey Latest 1-12S value: None anticipated BHP: 5,097 psi @ 11,100 ft ss, 9/28/09 Obiective The objective of this well intervention is to increase oil production by perforating some virgin interval and re- perforating part of the existing producing interval. Well History NS19 has one of the longest stimulation records of any Northstar well. No less than 10 separate acid stimulations have been pumped into NS19 and six separate perforation programs have been executed. The results of these stimulations have been mixed but the most recent attempts have done little to boost oil rate. A recent production log has indicated which zones appear to be underperforming and it is hope that a combination of re -perfs and add -perfs will significantly boost the oil rate from NS19. 1. SI Well. MIRU SL. 2. Drift and Tag TD w/ XN locator and 2 -7/8" Dummy Gun; include S.Bailer in BHA. Locate XN profile, correct depth and tag TD. Bottom proposed pert is 13,885'MD. Obtain sample if obstruction /fill encountered (scale possible). If unable to reach target depth with 2 -7/8" dummy gun attempt smaller ID drift (- 2.50 "). • Last TD Tag - 4/17/09: Tagged 13,945' MD w/ 2 -7/8" Perf gun • Last Downhole Op - 9/28/09: Memory SBHP survey • Note corrected Tag depths in WSR • 4Y2" Chrome Tubing and Liner 3. RDMO SL. :.: r' nEZ,.'. :','::r - "r✓m" ::n'. . L.. ,.> .�:�'. ±. :.ir �=, -.std: a; "g, <= 'p' •. ............. .. z ;� < : :'`:- --W.' s ,-.art. • 1. MIRU EL. 2. Shoot 80' of Perfs per the attached perforating procedure with 2 -7/8" HSD Power Jet 2906 HMX (6 spf). Proposed Add Perfs • 13,805- 13,885' MD Reference Log Schlum GR/CCL dated 3- May -2003 3. RDMO E -Line and return NS19 to production. Obtain well test. Please contact Mark Sauve 564 -4660 (w); 748 -2865 (c); 336 -6128 (h) with any questions, comments, or concerns. 2 of 3 TRH . AB&VGI&lCSM ACTL MCLL _ MAD�-_A�VGI 1 I&r HXTBDWL 90 SAFM NOTEW �*4-1*'CWME ffi KIM� NSI 9 & Q1 ' " CBISII ---- ----- -- I w L-!ff—jl 4W2"TI*A4ESM,O- Ace An 6 13_n 3, jw I X F44CFLE Oekm 60= 2. ;a �� 131 (OSS 16�0�y " GAS LFT KV&VFBS I ST I W I rM I M I TYPE I WV ILARMI POW I �M 1 Min ID 3.725"@ 13306 1 2 1 MMI 144M 1 44 1 ZSFAUHIUM I UK I U jUaF3lMj 4-1/2"XNNIPPLE 1 IMOD 5474 •1 SMOR DW Bt 0 (IN31003 ITogo i r LmR I =I 9-QrX*FBKRLIPWIH 1044 csc, 47Ak L4OBTc4k D •aiAssi. 753 132W "�VTFZERa'ICT%kNSMKMRK)-3.Q4T 4-142"HESX NP. D iTcPcw&lr Imm' 13" rx5- RZ 4-la 1=319' 1331V 4-'a'wLEG.K)-'fiw BIOTTLOMMOM3103 F LNPL W CIS mmm 621, 13 7. FEFWCFATUN SUMMMW FEFLOM JEM3" LOG iGRCM CNOW3003 ANGLE A T 7CP FEW 8 1- @ 119909' wm� Refer so Rod De foe timatim) Pf*f dba HIIAL PUIW� CWJGE 2W6 FIDWIRIET. MW PO40MTM 27 HOLE 0.W, PHkSE 90 Mr- SIZE SP WIMAL (MD) CP DATE Vgq2 2-7/r 8 i3m - 19!28 0 0419M 2-VT 8 13BSO -19905 0 09mm 2-71r 6 13M -1 3!920 0 09050M 2.71T 0 i3m-t3am 0 O&ISM kTE ,r M -- X — PL W TP, — JD S*BMLNRHGPU ? 141 fit 2-7flr 0 13935 -13975 0 05' 15008 MI 2-71C 6 19996 - 19975 0 C17M WO7 H 1405r - NRlZe#,13CJtvAmmM H I x -17 0 fZ: l52pf.D-"W' _ I _ZTE P" BY CCMAENTS CMTf m BY COMAMTS NORIMIAR 11MM2 M UTIAL OWL OMMS Wlavw EMWWGCDRFtECTIDKS WELL- NS19 4313I83 ,#A3 ONONALCOMPLEnM OBM2d09 "WMU ADPUFM4MWOD) MWNcr 2022970 I0087006 MH NEWFOWAT&TVDCCFJl=. ARM& 60.0 122,M 05n6ft wmvnfc FEWS I OACCOFam7m SEC 11, TI M. Rl 3E, 1229 FIL A SM' FEL 0742207 MWX AUPERFS(0710BM7) 11127107 WINVW WEILM LDrA7lDNM%VC7V3!8 SP Expkirati" jAhm ka) 3 of 3 PERFORATING PROCEDURE v.4e06/04/01 Rom ..�....�.. Well: NS19 API #: 50- 029 - 23122 -00 Date: 12f8f09 Prod Engr Mark Sauve Office Ph: 564.4660 H2S Level: Home Ph: 1. 336-6128 _ 0 ppm _ Cell: 748 -2865 .......................I ....."......................11. CC or AFC: NSFLDWL19 Detail Code: .. ........................................................................................ ............................... Description: Drift to TD with Dummy Gun, Perforate ....................... ............................... WBL Entries IOR Type Work Description 200 S Drift to TD with 2 -7/8" Dummy Gun 200 1 E Perforate 13,805'- 13,885' MD Well Obiectives and Louaina Notes: For the a detailed NS well history, please see NS19 Pert program currently on the WBL. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale and ensure the guns and patch can make it to target depth. The proposed perforations are an attempt to increase production by stimulating pats of the reservoir that we believe to be under performing. Please contact Mark Sauve with any questions, comments, or concerns - 564 -4660 (w); 748 -2865 (c); 336 -6128 (h). Attachment: Reference Log Tie in Log feet ................... Log: GR -CCL GR -CCL tie -in log to be on Date: 5/3/2003 5/3!2003 depth with the reference log. Company: Schiumber. Sc lumber ...... . ....................... 1111.......................... Depths (from -to) Depths (from - to) Feet SPF Orient. Phasing Zone Ad /Re /lperf 13,805' - 1 13,805' - » 13,885' 80' 6 » Random - 60 0 Ivishak Reperf & Add -perf .............I.. ..................... ......................... ............... .............1111............. ....................... ................: ..................... .......................... ................ ... ........................................................ - .......................... 0 . .............1111.............. ........................... .............................. 111.1................ ...... ........I...... .......................... ...1...1...11.1 .... 0 1-- .................. .................. .. ............................... GasJetting Expected -. ........... .............................. .......Np At what Depth ........... .................. ......................... ........... ...... NIA ........................................ ............................... .............................. ...................... Requested Gun Size: 2.875" HSD Charge: Power Jet 2906 ............................... Desired Penetration: 25, 3" Entry Hole Diam: 0 Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary ............. ................. .,............. ............................... Describe below how to achieve drawdown (check w.rPad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas. Gas Lift, Flow Well. Back Now Through Drain or Hardline) . . . . . . . . . .......... . . . . . . ................ . ............... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tie in to Jewelry @ MD Tie in using: ...................................... ............................... Minimum ID: 3725 in Min ID Type: 4 -1/2" XN Nipple @ 13,306 'MD Tail Depth: 13 317 R MD Casing Size: in 4 5 12.6# 13 -CR Liner ........................ Est Res. Pres. @ MD - 11100' SS -5100 psi Last Tag: 13,945 ft ELMD on 4/17/2009 1 . ......................1... Well: NS19 Perforation Summary Date: API #: 50- 029 - 23122 -00 On -Site Prod Engr: PBTD ........ ............................... . 1111................. General Comments: « .................................................................................................................. ............................... ........................................................................................................................ ............................... • ........................... ............................... Depths Balance Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf O /B /U - O O /B /U - O O /B /Ll O O /B /Ll O .................... ............................... .......................... ................. 1,11,1...» »1111... O /B /U - O • ~~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf vnn have anv nuestinnc_ nlease cnntact Joe Lastufka at (9071564-4091 Date: 10-08-2009 Transmittal Number: 93102 Delive Contents Bottom SW Name Date Contracto Run To De th De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS17 10-02-2009 PDS 1 0 17582 SUMMARY CD-ROM - MEMORY MULTI- FINGER CALIPER LOG NS17 10-02-2009 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS29 10-02-2009 PDS 1 0 13276 SUMMARY CD-ROM - MEMORY MULTI- FINGER CALIPER LOG NS29 10-02-2009 PDS RESULTS SUMMARY STATIC TEMPERATURE/ S19 09-28-2009 PDS 1 PRESSURE SURVEY CD-ROM - STATIC EMPERATURE/PRESSURE NS19 09-28-2009 PDS SURVEY STATIC TEMPERATURE/ NS16A 09-18-2009 PDS 1 PRESSURE SURVEY CD-ROM - STATIC TEMPERATURE/PRESSURE NS16A 09-18-2009 PDS SURVEY Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center ,~, ~4~,`; ~ ` ~3~~~ ~~ ~ BPXA AOGCC DNR Murphy Exploration MMS . ~~ ~~~~ ~rT ~ ;; 2009 ~it~is~ ~1 ~ Cons. ~t ~~ David Fair Christine Mahnken Corazon Manaois Ignacio Herrera Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Static Temperature/ Pressure Survey B. P. Exp/oration (AlaskaJ. /nc. NS - 99 Noit,fi Star Na~l-i Slope ~., ~,~~~{~~ n~p'~ ~ 4 2009 .~~:. Surface - Before R/H Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 42.71 3657.17 0.5 42.69 3657.22 1.0 42.67 3657.25 1.5 42.64 3657.30 2.0 42.62 3657.34 2.5 42.60 3657.38 3.0 42.58 3657.42 3.5 42.56 3657.45 4.0 42.54 3657.48 4.5 42.52 3657.52 5.0 42.50 3657.55 5.5 42.48 3657.59 6.0 42.46 3657.61 6.5 42.44 3657.63 7.0 42.42 3657.66 7.5 42.40 3657.69 8.0 42.39 3657.71 8.5 42.37 3657.73 9.0 42.35 3657.75 9.5 42.33 3657.77 10.0 42.31 3657.79 AVERAGE 42.50 3657.52 Current Wellhead Read in s Wellhead Pressure (psig) : 3,650 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 0 Outer Annulus Pressure (psiyj : 160 Date: September 28, 2009 ob`~M We(( sA~ a ~~• _ ~M ~ ~ P~oAcrivr Di~yMOSTic SE~vicEs Start time: 00:51:00 Temperature Data 110 ~ o0 90 8O _ -- ----- - LL ~o ---------- --- - ~ 60 -- --- - 50 - --- -- - - ao 30 - _ _ 0 1 2 3 4 5 6 7 8 9 10 Minutes 3720 3710 3700 g ssso N a 3680 ss~o 3660 3650 Pressure Data 0 1 2 3 4 Minutes 6 ~ 8 9 10 ~J ~ Page 1 ~Oa - `~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Static Temperature/ Pressu~e Survey B. P. Explorvtron (A/askaJ. lnc. NS - 79 No~tti Ste~ Noith Slope 9 9,005' TVDss M.O. = 93,992' Elapsed Time (Minutes) Temperature (Deg. ~ Pressure (psia) 0.0 251.10 5086.61 1.0 251.12 5086.61 2.0 251.14 5086.61 3.0 251.17 5086.60 4.0 251.19 5086.60 5.0 251.21 5086.60 6.0 251.23 5086.60 7.0 251.26 5086.60 8.0 251.28 5086.60 9.0 251.30 5086.60 10.0 251.32 5086.60 11.0 251.35 5086.60 12.0 251.37 5086.60 13.0 251.39 5086.61 14.0 251.41 5086.60 15.0 251.43 5086.60 16,0 251.45 5086.60 17.0 251.48 5086.60 18.0 251.50 5086.60 19.0 251.52 5086.61 20.0 251.54 5086.60 21.0 251.56 5086.60 22.0 251.58 5086.60 23.0 251.60 5086.61 24.0 251.62 5086.61 25.0 251.64 5086.61 26.0 251.66 5086.60 27.0 251.68 5086.61 28.0 251.70 5086.61 29.0 251.72 5086.61 30.0 251.73 5086.61 AVERAGE 251.43 5086.60 Date: September 28, 2009 ~,E,~- WE(( S.o Qao R~,~' s ~ F- .. ~ P~oAcrivE D4Gwosric S~wvic[s Start time; 03:10:00 Temperature Data 255 253 --------- - LL 251 ~ 249 ----- --- 2a~ 245 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes 5oso 5085 5oso ----- a N a 5075 so~o --- 5065 0 2 Pressure Data Page 2 4 6 8 10 12 ~nutes 18 20 22 24 26 28 30 ~J ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Static Temperature/ P~essure Survey B. P. Exp/oraG'on (AlaskaJ. lnc. lVS - 79 Norit~ Star Nor~h Slope ~0,955' TVDss M.O. = 93,B09' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 253.70 5075.20 0.5 253.70 5075.21 1.0 253.69 5075.21 1.5 253.68 5075.22 2.0 253.68 5075.22 2.5 253.67 5075.22 3.0 253.66 5075.23 3.5 253.65 5075.23 4.0 253.65 5075.23 4.5 253.64 5075.24 5.0 253.63 507524 5.5 253.62 5075.25 6.0 253.61 5075.25 6.5 253.61 5075.26 7.0 253.60 5075.26 7.5 253.59 5075.26 8.0 253.58 5075.27 8.5 253.57 5075.27 9.0 253.57 5075.27 9.5 253.56 5075.28 10.0 253.55 5075.28 10.5 253.54 5075.29 11.0 253.53 5075.29 11.5 253.52 507529 12.0 253.51 5075.29 12.5 253.51 5075.29 13.0 253.50 5075.29 13.5 253.49 5075.30 14.0 253.48 5075.30 14.5 253.47 5075.30 15.0 253.46 5075.31 AVERAGE 253.59 5075.26 Date: September 28, 2009 ob`EM WE(( SA~ a ~~• _ ~s ~ ~ M P~oAcrivF Di~ywostic S~wvicFs Start fime: 04:45:00 Temperature Data 255 253 251 --..._..---- - -------- ------ {y -'-------- -----...... ~ 249 - --- ------ ---..... 247 245 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data soso 5085 - soso - g y a 5075 50~0 --- - - -- 5065 0 1 2 3 4 5 6 ~j~nutes 9 10 11 12 13 14 15 • Page 3 Static Temperature/ Pressu~e Su~vey B. P. Exploraaon (Alaska). lnc. NS - 99 NarY,t~ Sta~ Norrh S/ope ~ 9,005' TVDss M.D. = 93,992' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 247.10 5086.56 0.5 247.11 5086.54 1.0 247.12 5086.53 1.5 247.13 5086.52 2.0 247.14 5086.51 2.5 247.15 5086.51 3.0 247.16 5086.50 3.5 247.17 5086.49 4.0 247.18 5086.48 4.5 247.19 5086.47 5.0 247.20 5086.46 5.5 247.21 5086.46 6.0 247.22 5086.45 6.5 247.23 5086.44 7.0 247.24 5086.44 7.5 247.26 5086.43 8.0 247.27 5086.43 8.5 247.28 5086.42 9.0 247.29 5086.42 9.5 247.31 5086.41 10.0 247.32 5086.41 10.5 247.33 5086.40 11.0 247.34 5086.40 11.5 247.36 5086.40 12.0 247.37 5086.39 12.5 247.38 5086.39 13.0 247.40 5086.39 13.5 247.41 5086.38 14.0 247.42 5086.38 14.5 247.44 5086.38 15.0 247.45 5086.38 AVERAGE 247.26 5086.44 Date: September 28, 2009 Temperature Data ~~~ 253 LL 251 ~ 249 za~ 245 ob~EM WE[[ sA~ 4° c~~ i M ~ M P~oAcrivE Di~ywo~ric S~~victs Start time: 04:53:00 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 5090 5085 5oso S N a 5075 so~o - 5065 0 1 2 3 4 5 6 ~j~nutes 9 10 11 12 13 14 15 Page 4 ~ ,~ ^~ ~ ~ ~ ^~ ~ ~ ~ ~ ~ ~ r r~ ~ ~ ~ ~ Static Temperatu~e/ P~essure Survey B. P. Exp/oration (AlaskaJ. lnc. NS-99 Norf,t~ Sta~ North Slope 90,905' TI/Uss M.Q = 93,704' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 254.46 5080.62 0.5 254.46 5080.63 1.0 254.46 5080.63 1.5 254.46 5080.63 2.0 254.46 5080.63 2.5 254.46 5080.64 3.0 254.46 5080.64 3.5 254.46 5080.64 4.0 254.46 5080.64 4.5 254.46 5080.65 5.0 254.46 5080.65 5.5 254.46 5080.65 6.0 254.46 5080.65 6.5 254.46 5080.65 7.0 254.45 5080.65 7.5 254.45 5080.66 8.0 254.45 5080.65 8.5 254.45 5080.65 9.0 254.45 5080.66 9.5 254.45 5080.66 10.0 254.45 5080.66 10.5 254.45 5080.66 11.0 254.45 5080.66 11.5 254.44 5080.67 12.0 254.44 5080.67 12.5 254.44 5080.67 13.0 254.44 5080.67 13.5 254.44 5080.67 14.0 254.44 5080.67 14.5 254.44 5080.67 15.0 254.44 5080.67 AVERAGE 254.45 5080.65 Date: September 28, 2009 ob~M WE[[ sp~ Qa ~'~ i ~ ~ M PwoAc~ivE Di~ywosric Suvic[s Start time: 04:03:00 Temperature Data 255 253 LL 25~ -- - -! ~ 249 -~ 247 ~ ~ 245 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 5090 5085 - ------ -- ----------------- 5oao - - g N a 5075 -- -- so~o 5os5 0 1 2 3 4 5 6 ~j~nutes 9 ~0 11 12 13 14 15 Page 5 • B.P. F~ploreh'on (A/askaJ. lnc. NS-99 North Star North Slope 90,856'TVDss M.D. = 93,690' Static Temperatu~e / P~essure Survey Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 250.50 5069.90 0.5 250.50 5069.90 1.0 250.49 5069.90 1.5 250.48 5069.90 2.0 250.48 5069.91 2.5 250.47 5069.91 3.0 250.46 5069.91 3.5 250.46 5069.90 4.0 250.45 5069.91 4.5 250.44 5069.91 5.0 250.44 5069.91 5.5 250.43 5069.91 6.0 250.42 5069.91 6.5 250.41 5069.91 7.0 250.41 5069.91 7.5 250.40 5069.91 8.0 250.39 5069.91 8.5 250.39 5069.91 9.0 250.38 5069.91 9.5 250.37 5069.91 10.0 250.37 5069.91 10.5 250.36 5069.91 11.0 250.35 5069.91 11.5 250.35 5069.91 12.0 250.34 5069.91 12.5 250.33 5069.91 13.0 250.32 5069.91 13.5 250.32 5069.91 14.0 250.31 5069.91 14.5 250.30 5069.91 15,0 250.30 5069.91 AVERAGE 250.40 5069.91 Date: September 28, 2009 O`0`EM WE~~ s'Of a ~~• ; ~~' ~ M PaoAcrivr DiwyNO*iic Sr~vic[s Start time: 04:23:00 Temperature Data 255 253 251 -- LL -- ~ 249 247 245 ' - 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5090 5085 soao 5 H a 5075 50~0 Pressure Data 5065 I i+ E i i i I I i I F-ri ~Ti i i F-TTi t i E~-+~ 0 1 2 3 4 5 6 ~inutes 9 ~0 11 12 13 14 15 .J Page 6 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Static Tempe~ature/ Pressu~e Survey B. P. F~plorvd'on (A/askaJ. lnc. NS-99 Nortl~i Star Nort~ S/ope Surface -Aher PDOH Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia} 0.0 107.93 3659.43 0.5 107.81 3659.47 1.0 107.70 3659.49 1.5 107.58 3659.52 2.0 107.46 3659.55 2.5 107.34 3659.58 3.0 107.22 3659.61 3.5 107.10 3659.63 4.0 106.98 3659.66 4.5 106.85 3659.68 5.0 106.73 3659.71 5.5 106.61 3659.74 6.0 106.48 3659.76 6.5 106.36 3659.79 7.0 106.23 3659.82 7.5 106.10 3659.85 8.0 105.98 3659.87 8.5 105.85 3659.90 9.0 105.72 3659.92 9.5 105.59 3659.95 10.0 105.46 3659.98 AVERAGE 106.72 3659.71 Current Weilhead Read in s Welthead Pressure (psig) : 3,650 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 0 Outer Annulus Pressure (psig) : 160 Date: September 28, 2009 ob`~M WE[( SA~ Q°, c'~ i ~ M~ M PMOAfTIVf Di~yMOSric Siwiccs Start time: 07:10:00 Temperature Data 110 ~oo .....----- 90 ----- - - so -- - -- ----- ~ ~o ' ---- ~ so - - 50 ------.._ ao -. 30 - 0 1 2 3 4 5 6 7 8 9 10 Minutes 3720 3710 3700 g ssso ~ a 3680 ss7o 3660 3650 Pressure Data 0 Page 7 1 2 3 4 Minutes s ~ $ 9 10 C~ Static Tempe~atu~e / Pressure Su~vey B.P. Exploration (A/askaJ. lnc. NS - 79 North Star North S/ope Dvwnha/e Temp/Press Date: September 28, 2009 Start time: 00:51:00 End Time: 07:20:00 Ob`EM WEI( sA~ a ~~• 4 +~ W !~ F'~' M PROACTIVF DIAC~MOSTIC SERYICH Temperature Data 255 253 - LL 251 -- ~ 249 ~ 247 245 , -200 0 200 400 600 800 1000 1200 1400 1600 Minutes ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Pressure Data 5090 5085 --- --- - 5080 N a' S075 - - 5070 5065 -200 0 200 400 600 Minutes 8~ 1000 1200 1400 1600 ~ ~, ~J Page 8 • • by BP Exploration (Alaska) Inc. _ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 .; Anchorage, Alaska 99519-6612 _.~ :.~ ~~~ ~~~i~ May 26, 2009 I~~~~ L~ia ~~:~~ i`~~~~i~sion ~)9~~~ Mr. Tom Maunder J Alaska Oil and Gas Conservation Commission ~~x~ - ~~ 333 West 7t" Avenue Anchorage, Alaska 99501 ~ ~®~ Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact.,me or my alternate, Anna Dube, at 659-5102. Sincerely, l Andrea Hughes BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ "-~\ O~ Date Northstar 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS14 A 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5!2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 na na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 na na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. . ~ JUN 0 1 2009 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS gJ~~ r ~~~~~~~~~ .~ . ~ 1 ~~~~y 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Oth~r~ ~ ~~ a c.a~i#~, ~;Op;it~s Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension ~ ~:;; ;,;;; .:C~6 Change Approved Program ~ Operat. Shutdown ~ Perforate ~ - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 202-2070 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 56.3 KB . NS19- 8. Property Designation: 10. Field/Pool(s): ADLO-312809 - NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14063 - feet Plugs (measured) None true vertical 11135.18 feet Junk (measured) None Effective Depth measured 14058 - feet true vertical 11132.72 feet Casing Length Size MD TVD Burst Collapse Surface 3361 13-3/8" 68# L-80 44 - 3405 34 - 3202 4930 2270 Intermediate 11710 9-5/8" 47# L-80 43 - 11753 43 - 9467 6870 4760 Liner 1896 7" 26# L-80 11584 - 13480 9339 - 10823 7240 5410 Liner 752 4-1/2" 12.6# 13CR80 13328 - 14080 10704 - 11144 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 - 13317 0 0 - Packers and SSSV (type and measured depth) 4-1 /2" TRM-4E SSV 941 7" Liner Top Packer • • ~ 41584 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~~-~~ . r~ 200 ~~~~~~ :, , Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1824 36607 1816 789 Subsequent to operation: 2000 41879 1723 814 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ' ~ $erviCe Daily Report of Well Operations X 16. Well Status after proposed work: Oil ° Gas WAG ~ GINJ WINJ WDSPL ~" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-114 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ Phone 564-4944 Date 5/7/2009 Form 10-404 Revised 04/2006 _ `~~ ~" ~~~ ~ tf LUU~ I~1"I ~ Submit Original Only ,- ,~ ~ ~ 5i0t`i NS19 202-207 PERF ATTACHMENT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15/06 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 7/8/07 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 NS19 4/19/09 APF 13,809. 13,826. 11,011.33 11,019.53 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE ~ SUMMARY 4/18/2009 i "**"`WELL FLOWING ON ARRIVAL*""" (PPROF W/DEFT&GHOST, ADD PERF) RIG UP E-LINE **""LOG CONTINUED ON 19-APR-2009****JOB IN PROGRESS***** 4/19/2009 *'""*LOG CONTINUED FROM 18-APR-2009**** LOG PRODUCTION PROFILE WITH DEFT AND GHOST FROM 13930'- ~ 13700' 40/80/120 FPM UP-DOWN, STOP COUNTS 13700' AND 13928'. PRODUCTION SPLITS 94% 13860'-13920', 6% 13935'-13963'. IPRODUCTION DATA: 9.5 MMSCFD, 0 FLUIDS, CHOKE 30, FWHT 141, PERFORATE 13809'-13826' WITH 2 7/8" 2906 PJ 6 SPF, 0.36" EH, 27" PENE, CORRELATED TO SWS JEWELRY LOG DATED 3-MAY-2003. ***'WELL LEFT FLOWING. FINAL T/I/O = 3600/13/201 PSI**** ***Job Complete"** FLUIDS PUMPED BBLS 1 DIESEL 1 MEOH 2 Total _f ,; :~; ~~~~ ~~~. ~~~A ~~~~~~~~ ~ ~~. Enclosed are the materials listed below. ~~`3b ~~~3 1 a ~~~A ~ ,r~~~a 1`~1 ~~~~~ 1 if v~u have anv questions. nlease contact Joe Lastufka at (907)564-4091 date: 0~' -2e_? ~;c Transmittal i~T3lmber: 9306c Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion ULTRASONIC CEMENT/ NS33 04-14-2009 SCH 1 200 14100 CORROSION EVALUATION CD-ROM -ULTRASONIC CEMENT/ CORROSION NS33 04-14-2009 SCH EVALUATION 19 04-19-2009 SCH 1 13650 13830 PERFORATING RECORD CD-ROM -PERFORATING N 19 04-19-2009 SCH RECORD PRODUCTION PROFILE W/ S19 04-19-2009 SCH 1 13700 13930 DEFT & GHOST CD-ROM -PRODUCTION NS19 04-19-2009 SCH PROFILE W/DEFT & GHOST PRODUCTION PROFILE W/ NS16A 04-20-2009 SCH 1 14200 14365 DEFT & GHOST CD-ROM -PRODUCTION NS16A 04-20-2009 SCH PROFILE W/ DEFT & GHOST "Y ~ J Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka , - Petrotechnical Data Center . ~~ ~ AOGCC Christine Mahnken Murphy Exploration Ignacio Herrera MMS Doug Chromanski DNR Kristin Dirks BPXA David Fair ~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • • 'l'cr~~ ' i,fi ~''~I ~ ~,: AI,A58-A OIL ArTD GA.S CO1~T5ERQATIOI~T COl•'II~i1551O1~T Jack Lau Well Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~ ~c~-~a7 Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 309-114 Dear Mr. Lau: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after ~~vritten 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 u~-iless rehearing has been requested. 4in rPrPly- S~ DATED this / day of April, 2009 Encl. Daniel T. Se ;.mount, Jr, Chair 3l, o~ __ ~~~~®,G~ ,y~~' ~~ STATE OF ALASKA ~'~ ~.~ ~ ~~AR 2 '~ 7109 ,._ ' ~,~ ~ ° ALASKA OIL AND GAS CONSERVATION COMMISSION ;~laska Oil ~t Gas Cons. Commission APPLICATION FOR SUNDRY APPROVAL Anchorage 20 AAC 25280 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ - Waiver Othe After casing ^ Repair well ^ Plug Pertorations^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Class: 5. Pennit to Drill Number: BP Exploration (Alaska), Inc. DevelopmenlQ' - Exploratory ^ 202-2070 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS19 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312809 ~ 56.3 KB - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14063 - 11135.18 14058 ~ 11132.72 NONE NONE Casing Length Size MD ND Burst Collapse Surface 3361' 13-3/8" 68# L-80 44' 3405' 44' 3202' 4930 2270 Intermediate 11710' 9-5/8" 47# L-80 43' 11753' 43' 9467' 6870 4760 Liner 1896' 7" 26# L-80 11584' 13480' 9339' 10823 7240 5410 Liner 752' 4-1/2" 12.6# 13CR80 13328' 14080' 10704' 11144 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 4-1/2" 12.6# 13Cr80 41 -13317 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development [~ - Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/9/2009 OIL ~_ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Lau Printed Name Ja au Title Well Engineer Signature ~ Phone 564-5102 Date 3/26/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ Plug Integrity ^ BOP Test ^ Mechanigl Integrity Test ^ Location Clearance ^ cc Other: ~C~..~~C~°s~"~D~~v ~e~MCc,~~~Y'~GC~SJd~ ~ld~~l~-~a-~~~'~ l Subsequent Form Required: ~~ APPROVED BY ~ Approved by COMMISSIONER THE COMMISSION Date: ~- Form 10-403 Revised 06/26 ~ /"'{ ~ ~~ ~ ~; , . ~ r, :1! ~~ Submit in Duplicate NS19 202-207 PFRF ATTAf:HMFNT Sw Name Operation Date Perf O eration Code Meas Depth To Meas Depth Base Tvd Depth Top Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15/06 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 7/8/07 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • by To: Jerry Bixby/Clark Olsen Date: March 25, 2009 Well Operations Supervisors From: Jack Lau, Wells Engineer (w: 564-5102 c: 227-2760) Robert Younger, Northstar PE (w: 564-5972, c: 244-0529) Mark Sauve, Northstar PE (w: 564-4660 c: 748-2865) Subject: NS19 PPROF w/ DEFT & GHOST, Add/Re-Perf Pending PPROF AFE: NSFLDWLI9-C Cost: $120M IOR: 200 Please perform the requested well work on NS19 per the below procedure. 1 S D&T w/ 2-7/8" DMY Gun Obtain Sam le, Need 13,963' 2 E PPROF w/ DEFT & GHOST. Add/RePerf 13,786'-13,920',13,935-13,963' Well Detail Current Status: Producer Last Test: 12/08/08: 1,567 BOPD, 1,736 BWPD, & 33,136 MSCFD Max Inclination: 62° at 13,713'; ~61 ° at Top Perf Max Dog Leg: 15.1 at 13,554' MD Minimum ID: 3.725" at the 4'/i" XN Nip @ 13,306' MD Last TD tag: 05/04/08: Tagged 13,941'SLM w/ 2.50" Cent. Last Downhole Op: 08/30/08: RePerf Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP/BHT: 05/04/08: 5,065 psia / 252°F @ 11,000 ft ss Objective The objective of this well intervention is to: 1. Perform a production profile to better understand production characteristics post HCI treatment. The production profile will be utilized to determine fluid entry contributions across the perforation interval and help influence the subsequent re-pert design. 2. Increase production by adding perforations to the upper sands above the existing perforated interval. 3. Subsequent to production logging, perforations will be added with the intent of increasing production in the low-contribution intervals. Well History i NS19 experienced a severe decline in 2004. Two consecutive Acid/Scale Inhibition treatments were performed in 2005 in an attempt to mitigate the extreme decline. The second Acid/SI treatment performed on 5/1 /2005 increased the rate by 2,000 BOPD, but the increase lasted less than a month. Due to the short lived results of the Acid/SI treatments, re-perforating the top 45' of perforations using Schlumberger's PURE technique was recommended. Only the upper 45' of the original 60' section were re- perforated due to water concerns. Severe scaling required multiple drift/broach runs to ensure the perforation guns would be able to reach the targeted perforation interval While the September 2005 re-perforations did increase NS19's production, the severe scaling encountered in the drift runs indicated the bullhead Acid/SI treatments are inadequate. Therefore, a coil tubing conveyed acid job was proposed in order to insure efficient delivery of the acid to all perforations. The CTU acid job was completed 03/28/06 resulting in no change in the well's performance and no increase in produced water. . Due to the poor results of the March Coil Acid Job and based on favorable results from re-perforating NS19 in September 2005, reperfs were proposed. In addition to the reperfs, adperfs were recommended to access additional reservoir below the existing perforation interval in an attempt to increase oil rate. The initial perforation. interval was 92' above the oil water contact and the proposed adperf interval was 65' above the oil water contact. Despite the 92' of standoff from the oil water contact, NS19 produced 500 bbls of water. Therefore, in the event the Adperfs resulted in excessive water production a 15' gap between the pert intervals was left to set an fBP for water shut-off if required. Due to scale in the liner above the perforations, a liner acid wash was required in order to be able to access the perforation interval. The acid wash and adperf/reperf resulted in an IOR of over 4000 BOPD and the highest oil rate to date for NS19. A bullhead acid/scale inhibition treatment was completed in August 2006 to inhibit the new perforations that were shot in May 2006. The treatment resulted in 100 BOPD initial rate increase. NS19 was scheduled for a Coil Acid/Scale Inhibition Treatment during the 2007 barge season; however, the treatment was expedited to the 2007 ice road season. The Coil Acid Treatment conducted 04/03/07 resulting in a 950 BOPD increase. Following the Coil Acid Treatment, a production log was run 04/24/07. The Production Log indicated minimal production coming from the lower perforation interval. Therefore, the lower 40' of perforations were re-shot 07/08/07 resulting in a 400 BOPD rate increase. A second coil acid treatment was completed in 2007 as an attempt to remove any scale that may have formed in NS19 since its last treatment and acidize the July re-pert interval. The CT Acid treatment 08/14/07 resulted in 100 BOPD increase. The most recent coil acid treatment was performed 04/18/08 which resulted in minimal impact to production. 30' of the bottom pert interval and the bottom 20' of top pert 2of11 • i interval were subsequently reperforated on 06/30/08 resulting in a production increase of 235 BOPD. A bullhead acid and scale inhibition treatment with three stages of BAF diversion was performed on 3/13/09. During the treatment all three diversion stages were observed by a pressure spike upon hitting the perfs indicating successful diversion. Initial production tests indicated increase water rates with a reduction of oil. Subsequent tests have shown an increased in oil rate indicating the BAF diversion is cleaning up. The most recent test indicates 100 bopd benefit. A production profile is proposed to understand the effect of the recent acid treatment and obtain a production snap shot. 1. SI Well. MIRU SL. 2. RIH with 3.85" gauge ring and tag X-profile in 4~/2"TRM-SSSV. Use this depth to make subsequent depth correction. POOH. 3. Drift and Tag TD w/ 2-7/8" Dummy Gun; include S.Bailer & TEL in BHA. Target depth is 13,963'MD. Obtain sample if obstruction/fill encountered (scale possible). If unable to reach target depth with 2-7/8" dummy gun attempt smaller ID drift (2.50"). • Last TD Tag - 5/04/08: Tagged 13,941'SLM w/ 2.50" Cent. • 6/30/08: Perforated 13,935'-13955' and 13,900'-13920' w/ 2.25" PJ • Note corrected Tag depths in WSR 4. Drift 4~/z" Baker 45 KB DMY Patch to 13,860'MD. OD of the Baker 45KB is 3.70". The goal is of this drift is to ensure a patch can be set over the proposed add pert interval above 13,860' if high gas rates are observed. • Top pert is located at 13,860'MD. 5. RDMO SL. -Line PPROF 3 of 11 1. Prior to starting a-line-.job, ensure the following: NS19 has been producing for at least 24 hours. • Place NS19 in, test and produce for a minimum of 4 hrs (or until stable prior to logging :with well choked back to a max .:gas rate of 10 M'MSCFD to enable safe a-lime logging operations. • -Well is lined up through the test separator during logging • :.Due to NS19's current gas rates of ~34 mmscfd, gas jetting is a risk; please .take. all proper precautions. • Be prepared to upload live data into Interact toallow live viewing. This wilt allow the production team to decide actual interval to perforate based on real-time PPROF data. Once rigged up and prepared to upload to Interact contact Mark Sauve 564-4660 (w); 748-2865. (c); 336-6128 (h) or Jack Lau 564-5102 (w); 22~-2760 (c). Total Form Fluid. Water Gas Well Rate Oil Rate Hate Rate IOR Bore Run Date Hrs b d b d b d mscfd bo d NS19 3/16/2009 4 3,236 1,419 1,818. 33,497 501 NS19 3/15/2009 4 3,241 1,329 '1,911 31,913 456 NS19 ' 3/15/2009 4 3,252 1,301.. 1,951 3.1.,495 439 NS19 3/14/2009 6 3,308 1,1.91 2,117 28,857 401 NS19 3/14/2009 6 3,406 1,127 2,279- 26,897 390 NS19 .3/4/2009 4 3,180 1,502 1,678 34,296 568 2. MIRU EL. 3. MU BHA w/ Wtbars/ GR/ CCU Pressure/ Temperature/ Gradio/ GHOST/ DEFT/ Spinners. Utilize heat sock. SI with wing valve and RLH 4. RIH to below the SSSV. Open the wing valve slowly and continue to RIH. 5. Slowly bring well on production to acceptable .logging rates (<10 mmscfd). Ensure well is lined-up through the test separator. Monitor well and. wait for stabilized flow before proceeding with logging passes. Ensure well rates are acceptable for the tool components.. Tie into SWS Jewelry/GR/CCL dated 3- May-2003. RIH. slowly while monitoring spins and tension o ensure-tool is falling.. • If unable to RIH against requested flow rate, the well can be choked back to an acceptable RIH rate, but be sure to open choke back up for logging passes. • Please note choke settings and flow rates for dynamic passes in WSR and field logs. 4 of 11 6. Run 40, 80, and 120 FPM up & down passes from TD to 150' above the top perfs located at 13,860'MD. Record a stop count at the top of the logging interval prior to making each dynamic pass. All logging passes should be made below the max gas rate of 10 MMSCFD. • NS19 currently makes ~34 MMSCFD, rates above 10MMSCFD are anticipated. • Document changes in choke setting and flow rates in WSR and field logs. 7. Perform stop counts at the following locations: a) Above and below the following perforated intervals • 13,860-13,920'MD • 13,935-13,963'MD b) Above and below any anomalies Note: Ensure that sufficient time is spent at each designated stop to achieve a reasonably constant rotation count PPROF Lo in Summa Pass Direction S eed f m De th ft, and Notes PPROF w/ GHOST & DEFT Flowin Pass DowNU 40 13,700 - 13,970' Well Flowin Flowin Pass DowNU 40 13,700 - 13,970' Well Flowin Flowin Pass DowNU 80 13,700 - 13,970' Well Flowin Flowin Pass DowNU 120 13,700 - 13,970' Well Flowin 8. Ensure good data. SI well after logging to POOH. • Note: Minimize freeze-up due to Hydrate Formation by `trickling' McOH into lubricator stack while POOH, utilize Triplex pump per established SOP. Hydrate formation is a potential at Northstaryear-round. At a FWHP of 2,500 psi, the hydrate formation temperature is approximately 75 deg F. POOH. 9. While rigged up evaluate PPROF data to determine contributing intervals. Contact Mark Sauve or Jack Lau to discuss intervals to re-perf. • Contact Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) or Jack Lau 564-5102 (w); 227-2760 (c) Sofll ~ ~ 10.Add/Re-Pert per the attached. perforating procedure with 2-7/8" HSD Power Jet 2906 HMX. Contact Mark Sauve or Jack:Lau prior to perforating to discuss actual re-perf interval based on PPROF results: Proposed Add Perfs • 13,786-13,860'MD Proposed Re-Perfs • '13,860=13,920'MD • 1.:3,935-13,963'MD Reference: Log: SWS Jewelry/GR/CCL dated 3-May-2003 11. RDMO E-Line and return NS19 to production. Obtain well test. PPROF Log Presentation 1. Job Comments • Operating steps. in-sequence • Changes in choke setting and production noted at test separator • Volumes pumped • Logging passes executed • Field data interpretation 2. In the .header for each pass, include a summary of the production conditions such as choke setting, pressure, and phase specific rates. 3. Flowing STP up.pass overlay -:.spinner and temperature data from 40, 40, 80, and 120 fpm dynamic. up passes with constant choke.. 4. Flowing. STP up/down pass overlay -spinner and temperature data from best up/down pass. 5. Static/Flowing pass overlay-temperature from best static and.#lowing passes 6. Stop Counts. Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) with any questions, comments, or concerns. Results from Previous PPROF: 6 of 11 ~ ~ Table 1 Internretprl I)nwnhnle and Surtare Results th Oil Water Ws From Ft To Ft Oownhole BPD Surface STBPD 96 Downhole BPO Surface STBPD 9L Downhole BPD Surface MscUD °/. 13860 13920 2524.4 1911.6 98°k 314.2 300.0 78°/, 5914.8 8604.1 99°h 13935 13975__ -- u~'~Y~ 46.2 2% 88.6 84.6 22% 54.2 94.9 1% Total 2588.1 1959.8 3.1. Interpretation Results: 402.9 384.6 5969.0 8699.0 PFC2 GR S h ~ 10000 Sp i,u,er - ownPass 2 o (~~ do DEFT -Holdup •.~ 0.2 Fw-d oensny (grom3~ -- - -1,2 -i ~ 4600 Pressure (~) 4650 Tempewlute , 250 (cfPaF ] 28d `'_ ~ - s -*--- -- 1 ~;i d ~•, 1 = --._~ ~: 1 -- 3 i ~~ -- ; ~ , ;; ---- - - - -- = i - :i i 7 of 1 1 • JEI~W"~.RY L ! CR-L PERFORA~ F~EOORD 1271'8 HST ~~ 2~' ~ ~ ~ F ~-MA1l--.'# 1229' PSt. B. FED ~iT$UI1F~ PBilll~lallt~tlrtl; ~ ~v._ IC.~. 6B~ n ilk 1~59~ Q.F. ! ~~: ~~ •- ~ ~ _. ~ Ma~rpNnrd Flan: f#1~ 6~~ A ~boti~s ##irm. ~ ~ ~ ~' ~ Dti~g Messured F~oms RMOE~ 11P1 SBrW Fla. $~lon ,~St22~00 1 i T~r~Aup _ i~N i~E d,dOb 8of11 9 of 11 • • • vii 19100 • 10 of 11 Ttz~A Ass-vc~si>~ s~csa wEt~s~AO ~ ass-vc~a i~-sm~ ~iTisov~ s~csa ACTWxT(1i2~+ ~~----~__~ ~.__ N S 19 sA~rvrioTES:^•4;-irrc~tanrFrscs DATE RED/ 8Y QOAR~(fS GATE fi£i/ $Y ©OAAI.1slf5 NC~THSTAR 11115402 F!! It~NTIAIOfmLI 07172107 i~Ai~PJC AOPCiiFS(O7AB~7j V-~3.L: NSi9 03431103 JAS Ot6CiINAICCHAPIETIW4 11!27/07 WRRtPJC WaLi~VLOGATgN fFR1uQTt4o:~02207t1 OSdOTA53 AOS OSJ28J06 1N(~IPJC O~AWNG ~ APIt4a SO-029.7312E-00 09J77R95 ~ pig 47/08K1B Y~l2W?JC REJ~S {06AOKl9y S`£C i 1, 7t3N, tt13E, 1729' ESL 8646' ff1 10J071D5 RH NQWKN~AATBNOOORf~GT. O5t'1aC16 Wd~JC FEF2~S / Ettslti WfC?N 9i+ExPbta~oa (Alaska- 11 of 11 • PERFORATING PROCEDURE ~W rrror~uu~u Well: NS19 API #: 50-029-23122-00 Date: 03/16/09 Prod Engr Jack Lau Office Ph: 564.5102 Home Ph: Cell: 227.276 .......................................... CC or AFC: NSFLDWLI9-C Detail Code: Description:.Drift to TD with Dummx.Gun, PPROF.w/ DEFT & GHOST, Re-Perforate WBL Entries #REFI tie-in log to be on depth with the reference log. 1 S D&T w! 2-7/8" DMY Gun (Obtain Sample, Need 13,963') 2 E PPROF w/ DEFT & GHOST. Re- Pert (13,860-13,920',13,935-13,963') Well Objectives and Loaaina Notes: For the a detailed NS19 well history, please see NS19 PPROF, Re-Pert program currently on the WBL. Please plan to contact Bob Younger or Jack Lau with the results of the PPROF prior to perforating. The proposed re-pert interval will likely be revised based on the PPROF results. A recent HCI treatment produced minimal IOR indicating a possible nonexistence of calcium carbonate scale. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale and ensure the guns will make it to target deoth. The proposed perforations are an attempt to increase production by re-perforating the low contribution intervals. Please note that the perforations will be dependent on the PPROF data. Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Bob Younger 564-5392 (w); 830-4920 (c); 677-2599 (h) with any questions, comments, or concerns. Attachment: Reference Log with annotated perforations. Log: GR-CCL .............................. Date: 5/3/2003 ............................. .............................. Company: _Schlumber. .............. .............................. Depths (from-to) Depths (from-to) Feet SPF 13,860' - 13,920' 13,860' 13,920' 60' 6 .......13,935'...... 13,963' ....13,935'..... .....13,963'..... ....28~ .... .........6......... Gas Jetting Expected? .No At what Depth Requested Gun Size: 2;875" HSD Charge: .................. Power Jet 2906 Desired Penetration : ...............25.3".._,,.......... Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown ~cheCk w~ Pad Operator !e see it necessary piping is installed) ie.g- N2 Litt. Hardline Lifi Gas. Gas Lift. Fiow V. el: Fsackflow Through Drain or Hardlln el Tie in to Jewelry @ ..............................MD Tie in using: Minimum ID: in 3:725 Min ID Type: Tail Depth: .,....... ....... . „ 13,319 tt MD ........... ~~ Casing Size: Est Res. Pres. ~ Last Tag: ..,13,941 ft SLMD on .5/4/2008 Ver 4.0 O6/OM01 H2S Level: .........................o .PP~....................... Orient. Phasing Zone Ad/ReAperf 0 Random 6Q~ Ivisnak .............. Reperf....................... ..... ..... Random .....60~..... 0 . ........... .Ivisnak ........... ...............Reperf....................... 0 ... .......... .............................. ......................................................... 0 .......................... ..... . ................... . . ....... .............................. ......................................................... 0 ........... .. . ... ? NIA Entry Hole Diam: ...0.38:: Unnecessary ............................................................................ _....,..,..4.:1/2".XN,Nipple..,....,,.. C~3 13[306 'M[ ................ 4:5 in 12.6# 13-CR Liner MD -11100' SS -5100 psi Zone Aperf/Reperf O/B/U - 0 STATE OF ALASKA ~A~ 2 ~ ~p~~~~ ~~ 9 ALA OIL AND GAS CONSERVATION COM~I~~k ®i~ ~ Gas Cons. Ca REPORT OF SUNDRY WELL OPERATION mmisslan e,,,,ti..____ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ . Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory ~~ 202-2070 3. Address: P.O. Box 196612 StratigraphlC ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.3 KB - NS19 , 8. Property Designation: 10. Field/Pool(s): ADLO-312809 ~ NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14063 - feet Plugs (measured) None true vertical 11135.18 feet Junk (measured) None Effective Depth measured 14058 feet true vertical 11132.72 - feet Casing Length Size MD TVD Burst Collapse Surface 3361' 13-3/8" 68# L-80 44' - 3405' 44' - 3202' 4930 2270 Intermediate 11710' 9-5/8" 47# L-80 43' - 11753' 43' - 9467' 6870 4760 Liner 1896' 7" 26# L-80 11584' - 13480' 9339' - 10823' 7240 5410 Liner 752' 4-1/2" 12.6# 13CR80 13328' - 14080' 10704' - 11144' 8430 7500 Perforation depth: Measured depth: see attached _ True Vertical depth: _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 - 13317 0 0 - Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1784 33821 1732 789 Subsequent to operation: 1709 33379 1820 799 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ - Gas WAG GINJ r WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-464 Contact Robert Younger Printed Name Robert Younger Title Production Engineer Signature Phone 564-5392 Date 3/23/2009 Form 10-404 Revised 04N2006 ~~ ~ t~ t r ~ 1 /s, , Submit Original Only (~~ NS19 202-207 PERF ATTOC_I-IMFNT LJ Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top- Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15/06 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 7/8/07 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/12/2009`7/1/0 = 3400/0/475 Acid Treatment. Pumped into the Tbg with 100 bbls of 85" Sea Water and 68 bbls of 100" diesel, following the acid pill. Well tender to flow well ~ """WSR continued to 03-13-09*"" 3/12/2009Acid treatment. Pumoed 35 bbls of 12% HCI for ig ckle portion of rogram. Standby for LRS to pump remaining pickle and well flow back. ***cont. on 3/13/2009*"* 3/13/2009***WSR continued from 03-12-09*''* Acid Treatment. Pumped into the Tbg with 129 bbls of 85" Sea Water followed by 80 bbls of 85* diesel. Let acid soak in formation for 4 hrs before flowina well. Well tender to POP @ 17:04. After 250 Ibbls flowed back start to Slip Stream Magnesium Oxide into well while flowing. ~"**WSR continued to 03-14-09"** 3/13/2009Contfrom 3/12/2009. pickle flow back. Pun Acid stimulation treatment w/scale inhibitor. Completed >ed Acid/SIT per program. All three diversion staaes were ;rfs. No pressure changes associated with acid stages were seen. Pumped 254 bbls 2% KCI w/F103 for displacement. Pumped 133 bbls of 12% HCI w/L66 scale inhibitor in four stages. Pumped 36 bbls of benzoic acid flakes (BAF) in HEC gel as a diverter between acid stages. Pumped 182 bbls of 2% KCL w/F103 & L66 as spacer and flush. (LRS pumped remaining program fluids). ""'Job complete""" FLUIDS PUMPED BBLS 50 MAGNESIUM OXIDE 190 2% KCL W/F103 & L66 4 METH 80 DIESEL 35 12% HCI 254 2% KCL W/F103 133 12% HCL W/L66 36 BENZOIC ACID 782 Totat Revisions: NS Acid Treatments - NS05,11,16, 19 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 7:11 PM To: Lau, John, Jack Cc: Younger, Robert O Subject: RE: Revisions: NS Acid Treatments - NS05,11,16, 19 Jack and Bob, No issues with the diverter. Tom Maunder, PE ;~c;~{„a~'?: ~=~ ~ :~ ~ ~J+j AOGCC From: Lau, John, Jack [mailto:Jack.Lau@bp.com] Sent: Mon 2/9/2009 4:56 PM To: Maunder, Thomas E (DOA) Cc: Younger, Robert 0 Subject: Revisions: NS Acid Treatments - NS05,11,16, 19 Tom, aoa-~~~ As you are aware we are planning divererted acid treatments on NS05, NS11, NS16, and NS19 during ice road season. Originally we planned to use wax beads to divert between stages, however we have revised the programs to use benzoic acid flakes (BAF) in place of wax beads. We see no negative effects of using BAF, as BAF is extremely soluble in hydrocarbons and slightly soluble in water which should facilitate cleanup. Let me know if you have any questions, concerns, or requests. Thanks! .~CXC~C ~~Citt V4'cl]s L,ngnecr BP Exploration (_Alaska) lnc. Office: 907.561.5102 Cell: 907.227 27Ci() 2/10/2009 41 ~ 5 ',"°. l ~ ~ ~ ~ ~ r ~ ~-~~ ' -, SARAH PAL./N, GOVERNOR t1.1.~t~~7i>•L1. OIL Al~i1 ~S // 333 W. 7th AVENUE, SUITE 100 COI~TSERQATI01'IT COMI-IISSIOrIT J ANCHORAGE, ALASKA 99501-3539 / PHONE (907) 279-1433 Jose Solo FAX (907) 276-7542 PE BP Exploration Alaska Inc. ~ , ;,; . ~~ ~ { ~r , ~; ~ ~ . , PO Box 196612 °'``'J~'u~'~"~' `'~ '~ ~~~"` Anchorage, AK 99519-6612 ~~~ Re: Northstar Feld, Northstar Oil Pool, NS 19 ~~ ~'1 Sundry Number: 308-464 ~ Dear Mr. Solo: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Corrunission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair h DATED this day of December, 2008 Encl. 'V~ ~~ ,~^1 ~N ~v • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~ ~~~~ 20 AAC 25280 ~-~~ .._.vn ~~~,~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well ^ Plug Perforations^ Stimulate Q ~ Time Extension ^ ~/7~1 Acid Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ Treatment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development - Exploratory ^ 202-2070 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS19 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312809 ~ 56.3 KB ~ NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14063 ~ 11135.18 14058 - 11132.72 NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3361' 13-3/8" 68# L-80 44' 3405' 44' 3202' 4930 2270 Intermediate 11710' 9-5/8" 47# L-80 43' 11753' 43' 9467' 6870 4760 Liner 1896' 7" 26# L-80 11584' 13480' 9339' 10823 7240 5410 Liner 752' 4-1/2" 12.6# 13CR80 13328' 14080' 10704' 11144 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached 4-1/2" 12.6# 13Cr80 41 - 13317 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 941 7" Liner Top Packer 11584 7"13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/1/2009 OIL Q , GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true an correct to the best of my knowledge. Contact Jose Solo Printed Name ~-J se olo Title Production Engineer Signature ' Phone 564-5972 Date 12/18/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ "~~'~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~~ APPROVED BY ~ ~~ ~ ~ Approved by: COMMI THE COMMISSION Date: t ~ ~~ ~ ~ ~' (~~` k~ ~ ~~~~ Submit in Du Form 10-403 Revised 06/2006 - "~; ? f°`~ ~ ~ ~ ~ ~ ~~~'~"`-- plicate NS19 202-207 PERF ATTOC_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS19 5/3/03 PER 13,900. 13,920. 11,055.37 11,065.1 NS19 5/5/03 PER 13,860. 13,900. 11,035.98 11,055.37 NS19 9/27/05 APF 13,860. 13,905. 11,035.98 11,057.8 NS19 5/15106 APF 13,955. 13,975. 11,082.17 11,091.95 NS19 5/16/06 APF 13,895. 13,920. 11,052.94 11,065.1 NS19 5/16/06 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 7/8/07 APF 13,935. 13,975. 11,072.4 11,091.95 NS19 6/29/08 APF 13,943. 13,963. 11,076.31 11,086.08 NS19 6/30/08 APF 13,900. 13,920. 11,055.37 11,065.1 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE No portion of the Belo ork should be performed w/out fi~taking time to ensure ~~ No Accidento harm to People, and No damag the Environment To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Robert Younger, Northstar PE Subject: NS19 Bullhead Acid SIT Treatment AFE: NSFLDWLI9 Date: December 18th, 2008 (w: 564-5102 c: 227-2760) (w: 564-5972, c: 244-0529) Cost: $100M IOR: 200 Please perform a bullhead acid treatment on NS19 per the below procedure. 1 F Bullhead Acid Treatment w/ Diversion Current Status: Producer Last Test: 12/08/08: 1,567 BOPD, 1,736 BWPD, & 33,136 MSCFD Max Inclination: 62° at 13,713'; ~61 ° at Top Perf Max Dog Leg: 15.1 at 13,554' MD Minimum ID: 3.725" at the 4'/s" XN Nip @ 13,306' MD Last TD tag: 05/04/08: E-line tagged 13,941'SLM w/ 2.50" Cent. Last Downhole Op: 08/30/08: RePerf Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP/BHT: 05/04/08: 5,065 psia / 252°F @ 11,000 ft ss Objective Based on the historical scale issues at Northstar, the below acid/scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. A multi stage diversion treatment will be performed in an attempt to open the middle and lower perforation intervals while stimulating the contributing interval. Well History NS19 experienced a severe decline in 2004. Two consecutive Acid/Scale Inhibition treatments were performed in 2005 in an attempt to mitigate the extreme decline. The second Acid/SI treatment performed on 5/1/2005 increased the rate by 2,000 BOPD, but the increase lasted less than a month. Due to the short lived results of the Acid/SI treatments, re-perforating the top 45' of perforations using Schlumberger's PURE technique was recommended. Only the upper 45' of the original 60' section were re- perforated due to water concerns. Severe scaling required multiple drift/broach runs to ensure the perforation guns would be able to reach the targeted perforation in#erval. While the September 2005 re-perforations did increase NS19's production, the severe scaling encountered in the drift runs indicated the bullhead Acid/SI treatments are inadequate. Therefore, a coil tubing conveyed acid job was proposed in order to insure efficient delivery of the acid to all perforations. The CTU acid job was completed No portion of the belo ork should be performed w/out fir taking time to ensure No Accidents~o harm to People, and No damag~ the Environment 03/28/06 resulting in no change in the well's performance and no increase in produced water. Due to the poor results of the March Coil Acid Job and based on favorable results from re-perforating NS19 in September 2005, reperfs were proposed. In addition to the reperfs, adperfs were recommended to access additional reservoir below the existing perforation interval in an attempt to increase oil rate. The initial perforation interval was 92' above the oil water contact and the proposed adperf interval was 65' above the oil water contact. Despite the 92' of standoff from the oil water contact, NS19 produced 500 bbls of water. Therefore, in the event the Adperfs resulted in excessive water production a 15' gap between the pert intervals was left to set an IBP for water shut-off if required. Due to scale in the liner above the perforations, a liner acid wash was required in order to be able to access the perforation interval. The acid wash and adperf/reperf resulted in an IOR of over 4000 BOPD and the highest oil rate to date for NS19. A bullhead acid/scale inhibition treatment was completed in August 2006 to inhibit the new perforations that were shot in May 2006. The treatment resulted in 100 BOPD initial rate increase. NS19 was scheduled for a Coil Acid/Scale Inhibition Treatment during the 2007 barge season; however, the treatment was expedited to the 2007 ice road season. The Coil Acid Treatment conducted 04/03/07 resulting in a 950 BOPD increase. Following the Coil Acid Treatment, a production log was run 04/24/07. The Production Log indicated minimal production coming from the lower perforation interval. Therefore, the lower 40' of perforations were re-shot 07/08/07 resulting in a 400 BOPD rate increase. A second coil acid treatment was completed in 2007 as an attempt to remove any scale that may have formed in NS19 since its last treatment and acidize the July re-perf interval. The CT Acid treatment 08/14/07 resulted in 100 BOPD increase. The most recent coil acid treatment was performed 04/18/08 which resulted in minimal impact to production. 30' of the bottom perf interval and the bottom 20' of top pert interval were subsequently reperforated on 06/30/08 resulting in a production increase of 235 BOPD. Based on the historical rate benefits of treating NS19, the below CTU acid/scale inhibition treatment is proposed. A summary of well work activity is outlined below. No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidents~o harm to People, and No damag the Environment Operational Highlights [,4dd P~lea'~a] [Uie~~ Recent] Date Comments 06/3012008 --> X235 BOPD Increase - Reperf 30' of btm pert interval & btm 20' of top perf interval. Edit Delete 04!18/2008 AcidISIT: --? minimal impact Edit Delete 08/1412007 CT Acid (No L066} --> w100 BOPD Increase Edit Delete 0 710 812 0 0 7 Reperf Btm 40' --> X400 B4PD Increase Edlt Delete 04/D312007 CT Acid (No L066) --> rv950 BOPD Increase Edit Delete 0 713 112 0 0 6 AcidISIT: --> 100 bbls ail inc. Edit Delete 05/1612006 Reperf 25': 13895'-13920'. Adperf 40': 13935'-13975'. --~ 3700 bbls oil inc. Edit Delete 08/0712006 Liner Acid Wash: Pumped 15 bbl Acid Pill to 40' above Perfs --> 1200 bbls oil inc. Edit Delete 05/02/2006 1.99" Broach 13627'-13700' SLM. 1.875" Bailer to 13735' SLM. Edit Delete 0510112006 2.5" Broach 13627'-13681' SLM. 2" DMY Gun to 13628' SLM. Edit Delete 04/3012006 Drift: w1 2-718" DMY Gun to 13742' SLM. Edit Delete 0312812006 Coil Tbg Acid Treatment --> No change in well perFormance. Edit Delete 0912712005 RPF: 13,860' - 13,905' --? ~190D bbls oil inc. Edit Delete 4813D/2005 Attempt to reperforate. Sat down at 13880' MD. Edit Delete 0511712005 PPRdF -drift with 2-118" GR 1st. 76% of flow from top 19' of perFs. Edit Delete 0 510 112 0 0 5 Acidize with 43 Bbls of acid with L66. Edit Delete 0411712005 Acid - 29 Bbls w L066. Well treatedvery tight, will re-treat Edit Delete 1012412DD4 Scale Inhibitor Treatment -Pump 4.6 bbls VX7377 Access scale inhibitor Edit Delete 0812312003 AcidISIT w. 10°la ECb085A: --> X700 bbls oil inc. Edit GPlete 05/02/2003 Initial SlicklinelPerfs: 13,860' - 13,92D' (60') Edit Galata Basic Program Phases • Tubing Pickle • Immediate Pickle Flowback • 1St Stage HCI Acid Treatment • Wax Bead Diverter • 2"d Stage HCI Acid Treatment • Soak - 4 hour Residence Time • Flowback Spent Acid Please contact Bob Younger with any questions, comments, or concerns - 564- 5392 (w); 830-4920 (c); 677-2599 (h). Or Jack Lau 564-5102 (w); 227-2760 (c). No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidentso harm to People, and No damag the Environment Open Perforations Zone .MDT MDB Status TZD 13860 13900 O en TZD 13900 13920 O en TZC3 13935 13955 O en TZC3 13955 13975 O en Design Details Total Footage 100' # of Perforations 2040 Wellbore Volume 210.8 bbl (to top perf) Acid Design 60 gpf for perfs Acid Volume 145 bbls total Diversion Design 6#/ ft at 0.5-1 ppg in 30# HEC gel Diversion Volume 10 bbls total wax beads Reservoir Pressure 5,065 psia / 252°F @ 11,100 ft ss GLV's All GL Mandrels are Dummied Pre-Acid Stimulation Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. • Please do not filter fluids that contain L66. All filtering should be performed before the addition of the L66 scale inhibitor to insure the inhibitor does not plate out in the filters. • Please do not add friction reducer to water that will contact the formation due to formation plugging issues. • Please avoid contacting L66 with methanol or seawater -these fluids will cause premature precipitation of the L66 scale inhibitor and jeopardize the objectives of this procedure. • Please review: Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash: No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidento harm to People, and No damag the Environment 1. Obtain NS19 oil sample and deliver to Schlumberger Well Services lab for pre- job emulsion/sludge testing at least 5 days prior to acid stim. 2. Arrange DHD to shoot IA FL. If the IA FL is deeper than 500' top off IA. 3. Mobilize pumps, tanks, and acid transport to Northstar. 4. Order out necessary volume of seawater, 2% KCL and diesel to flush both the pickle and the acid treatment. See attached Volumes table. 5. Ensure that the well is ready to be flowed to the test separator after the tubing pickle and scale inhibitor absorption. Bullhead Acid and Scale inhibition Treatment. • Filter all fluids that will enter the perforations to 3 microns absolute. • The maximum recommended WHP during treatment is 3500psi. • NS05 is equipped with 13-CR 4'h" tubing and liner. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Send an electronic copy of the treatment report including digital, ASCII or an EXCEL copy of pumping rates and pressures to Robert.Younger@bp.com and IauiiO@bp.com. 6. MIRU. 7. Hold PJSM. • Possible hazards on this job include bringing partially spent acid back to surface.. • Ensure that current MSDS sheets are onsite and .that safe handling rocedures are followed. 8. Review IA fluid level (step 2). Ensure IA FL is within 500' of surface. No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidentso harm to People, and No damag the Environment 9. Preheat filtered 2% KCI and diesel to 100°F. (Absolute minimum temperature of 80°F). • Do not heat the acid or acid mixture 10. PT Dowell surface lines. to 5000 psi. Tubing Pickle Treatment 11. Pickle the tubing by pumping the following acid design at 2 bpm. Do not exceed 3500 psi max pumping pressure. Do not pump more than 209 total bbls during pickle treatment. It is critical that the acid not reach perfs. Wellbore volume to top perf is 209.8 bbls. 12% Acid Mixture Design: 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer 12. Produce pickle back to test separator and well clean up .tank. Total pickle volume to flowback is 315 Bbls, ~1.5 times wellbore volume. HCI Perf Wash / StT Treatment 13. Reduce wellbore temperature by pumping 240 bbls of filtered 2% KCI + Surfactant F103 preheated to 100°F at 4-6bpm. The objective is to cool the wellbore to help prevent the wax beads from prematurely melting and to displace all gas from the wellbore. The melting point of the wax beads is 168°F. Note: It is crucial that the water temperature does not exceed the melting temperature of the wax beads of 168°F. 100°F water should be used to reduce the wellbore temperature of 256°F to below the 168°F melting point. Ensure there is no shut down time after pumping the cool down, as the formation will quickly warm back up quickly. Stage Fluid Type Vol,. bbls Acid -Tubing Pickle (~100ga1/1000') 12% acid 33 Filtered Seawater Filtered 2% KCI 107 Diesel cap Diesel 70 No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidento harm to People, and No damag the Environment 14. Bullhead acid treatment down the tubing per the treatment schedule below. Pump at 3-5 bpm if possible while loading tubing and displacing. gas from wellbore. After tubing is displaced with treating fluids, reduce rate. to correspond with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/frac gradient). Maintain pump rate as high as feasible below frac gradient after the wax beads are in the tubing. Record pump rates, tubing, IA and OA pressures throughout the job. Note: If the diversion locks up causing loss of infectivity, incrementally increase pump pressure to 3500 psi (max) and hold for leak off. If no leak off occurs contact Bob Younger or Jack Lau to discuss plan forward. HCI Treatment Desi n Schedule Stage Fluid Type Vol (bbls) 1 Liquid pack -cool wellbore 2% KCI +F103 240 2 Acid 12% HCI +8.2% L066 70 4 Over Flush 2% KCI +L066+F103 75 5 1.5 PPA Wax Beads +30# HEC Wax Beads 10 6 Spacer 2% KCI + L066+F103 5 7 Acid 12% HCI +8.2% L066 75 8 Over Flush 2% KCI +L066+F103 80 10 Displacement 2% KCI 140 11 Displacement/Freeze Protect Diesel 70 8.2% L66 Scale Inhibitor 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer Note: Acid strength to be verified and documented via titration before leaving Sch/umberger. Please note the acid titrations on the WSR and have results available on location. 15. Shut well in for 4 hours to allow scale inhibitor to precipitate No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidento harm to People, and No damag the Environment Acrd Ffowback 16.After the 4 hour shut-in, line-up the well to flow into the test. separator and well cleanup tank for flowback. Produce clean-up volume of 600 bbls (Tubing 210.8 bbl + Treatment 315 bbl + Flowline). After clean-up, divert back to the lant and et 2 6-hour tests. 17. Start sampling when the tubing volume has been brought back to surface. Grab 1 liter sample in a clean nalgene bottle once per hour until the flowback is complete and the well is returned to production. Sample should be taken from the test separator. Label bottles as: • Well: NS11 • Date/Time: • Bbls Produced: • Tests: pH, solids quantification and identification, common cations by ICP, presence of emulsions • Contact: Craig Graff 564-5185 Note: Appropriate PPE to be used during acid sampling 18. Post Flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree ost acid treatment. 19.Obtain produced fluid samples once per day for 1 week after the treatment. Obtain produced fluid samples once per month for ~2 years post treatment, or until scale inhibitor returns diminish to the point the well needs to be inhibited again. These samples should be analyzed for P,Ca, Fe, B, CL, sulfates. Add well to GPB lab sampling request list. 20. Perform complete water analysis on the sample taken 1 week after treatment. Procedure Contacts: Robert Younger Jack Lau WK: 564-5392 WK: 564-5102 H M: 677-2599 Cell: 227-2760 Cel I: 830-4920 TREE= ABB-VGI5-118" 5 WELLHEAD = ABB-VGI 13-5/8" MULTIBOWL 5K , ACTUATOR = BAKER KB. ELEV = 56.3' BF. ELEV = 40.1' (CB 16.2') KOP = 100' Max Angle = 62° @ 13713' Datum MD = 13145' Datum TVD = 10500' SS 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 3405' Minimum ID = 3.725" @ 13306' 4-1i2" XN NIPPLE TOP OF 7" LNR 11584 ~ 9-5/8" CSG, 47#, L-80 BTC-M, ID = 8.681" ( N S 19 S NOTES: ***4-112" CHROME TBG &LNR*** 940' 4-1/2" TRM-4E SSSV, ID= 3.812" w / X PROFILE GA S I IFT MA NDRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 5067 6469 4428 5474 44 41 SMOR SMOR DMY DMY BK BK 0 0 03/31/03 03/31/03 11584' I--i 9-5/8" X 7" BKR LTP w /LNR HGR, ID = ? 13229' (-~4-1/2" FIBER OPl'IC TRANSDUCER, ID = 3.945" 1 (13228' ELMD) 13248' 13270' 13294 4-1/2" HES X NIP, ID = 3.813"~ 7" X 4-112" BKR LNR TOP PKR, fD = 3.875" 4-112" HES X NIP. ID = 3.813" ITOPOF4-1/2" LNR 4-1/2" TBG, 12.6#, 13CR-80 VAM-ACE, .0152bpf, ID = 3.958" 7" LNR, 26#, L-80 HYDRIL 521, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: JEWELRY LOG! GR-CCL ON 05/03/03 ANGLE AT TOP PERF: 61 ° @ 13860' Note: Refer to Production DB for historical perf data INITIAL PERF -CHARGE: 2906 POWERJET, HMX, PENETRATION: 27", HOLE 0.36", PHASE 60 DEG. SIZE SPF INTERVAL (MD) OpnlSgz DATE 2-1/2" 6 13860 - 13905 O 09/27/05 2-718" 6 13860 - 13920 O 05/05/03 2-718" 6 13895 - 13920 O 05/15/06 2-1/4" 6 13900 - 13920 0 06/30/08 2-1/4" 6 13935 - 13955 O 06/30/08 2-7/8" 6 13935 - 13975 O 05/15/06 2-7/8" 6 13935 - 13975 O 07/08/07 2-1/4" 6 13943 - 13963 O 06/30/08 PBTD 4-1/2" LNR, 12.6#, 13CRVAM-ACE, .0152 bpf, ID = 3.958" 13306' ~4-1/2" HES XN NIP, ID = 3.725" (13312' ELM 13309' 7" X 5" BKR ZXP LTP, ID = ?~ 13319' ~ 4-1/2" WLEG, ID = 3.85" 13326' ELMD TT LOGGED 05/03/03 13331' 7" X 5" BKR LNR HGR, ID = ?, 1~~--{ b" X 4-1 i2" XO, ID = ?1 DATE REV BY COMMENTS DATE REV BY COMMENTS 11115!02 FH INITIAL DRILL 07122/07 RMH/PJC ADPERFS (07108/07) 03!31/03 JAS ORIGINAL COMPLETION 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTK 05!07!03 EMF ADPERFS 06/28/08 WRR/PJC DRAWING CORRECTIONS 09127105 WRR/TLH PERFS 07/08/08 WRR/PJC PERFS (06/30/08) 10/07/05 /TLH NEW FORMAT & TV D CORRECT. 05/15/06 WRR/PJC PERFS / ELMD CORRECTION NORTHSTAR WELL: NS19 PERMTf No: ~L022070 API No: 50-029-23122-00 SEC 11, T13N, R13E, 1229' FSL & 646' FEL BP Exploration (Alaska) Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent; Monday, December 22, 2008 3:54 PM To: 'Preble, Gary B (SAIC)' Subject: RE: NS19 (202-207) OK, I will make the hand change on the 403. From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Monday, December 22, 2008 3:52 PM To: Maunder, Thomas E (DOA) Subject: RE: NS19 (202-207) Bullhead is correct From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 22, 2008 3:35 PM To: Preble, Gary B (SAIC) Subject: NS19 (202-207} Gary, I am reviewing the sundry submitted to treat this well. It is stated that a CTU acid treatment is planned, however the procedure provided is for a bullhead treatment. How is it planned to treat this well. If a new procedure is needed, please send via email. Tom Maunder, PE AOGCC 12/22/2008 ~~~ ~~~~~~ • Date 07-23-2008 Transmittal Number:92988 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastufka at (907)564-4091 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS10 07-10-2008 PDS 8 0 8022 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS10 07-10-2008 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS32 07-09-2008 PDS 5 0 8116 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS32 07-09-2008 PDS RESULTS SUMMARY NS16A 07-04-2008 SCH 1 14100 14376 PERFORATING RECORD CD-ROM -PERFORATING NS16A 07-04-2008 SCH RECORD NS19 06-30-2008 SCH 1 13550 13940 PERFORATING RECORD CD-ROM -PERFORATING NS19 06-30-2008 SCH RECORD NS30 06-28-2008 SCH 1 15890 16197 PERFORATING RECORD CD-ROM -PERFORATING NS30 06-28-2008 SCH RECORD e~ ~ ~~.~ECi~~~~ AUG a 6 2Q~t3 Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka ac~~~yr `~l~to5~- Petrotechnical Data Center a6~ ap'1 /(~~ ~' L____.a ~ o~ l lo~~ BPXA uT Cam-nr2 / lolo~ l AOGCC Murphy Exploration DNR MMS v~ ~a3 - ts~ ~(v(vG~ David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 by • • BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions, please contact Joe Lastufka at (9071564-4091 Date OS-14-2008 Transmittal Number:92968 Deliver Contents SW Name Date Contractor Run To De th Bottom De th Descri tion STATIC TEMPERATURE / NS-19 05-04-2008 PDS 1 0 13904 PRESSURE SURVEY NS-19 05-04-2008 PDS 1 13010 13972 CORRELATION LOG CD-ROM STATIC TEMPERATURE/ PRESSURE SURVEY AND NS-19 04-04-2008 PDS CORRELATION LOG STATIC TEMPERATURE / NS-20 05-03-2008 PDS 1 0 18475 PRESSURE SURVEY NS-20 05-04-2008 PDS 1 17825 18514 CORRELATION LOG CD-ROM STATIC TEMPERATURE/ PRESSURE SURVEY AND NS-20 04-04-2008 PDS CORRELATION LOG Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC Murphy Exploration DNR MMS ~ a2-a~~ ~ ~ a ~ ~~ANNE~ MAY ~ ~ 200$ ..w . a ~._ 1 David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LRZ- [ 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 B.P. Exploration (A/askaJ. loc. Static Temperature/Pressure Survey WEl[ NS - 79 e~b`Eµ s'O~ci North Star ¢ v s North S/ope ~O~ a~~ ;~~~.9~,(~~~~~ ~~,~~ ~ ~i ~~~~ '~ ~' F„ ~ Surface -Before R/H Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psis) 0.0 36.5 3529.11 0.5 36.3 3549.69 1.0 35.8 3561.98 1.5 35.5 3568.00 2.0 35.2 3570.54 2.5 34.9 3571.71 3.0 34.6 3572.34 3.5 34.4 3572.71 4.0 34.2 3572.94 4.5 34.1 3573.07 5.0 33.9 3573.16 5.5 33.8 3573.21 6.0 33.6 3573.24 6.5 33.4 3573.26 7.0 33.4 3573.27 7.5 33.3 3573.27 8.0 33.1 3573.27 8.5 33.0 3573.27 9.0 33.0 3573.25 9.5 32.9 3573.23 10.0 32.8 3573.22 AVERAGE 34.2 3568.94 Current Wellhead Read ings Wellhead Pressure (psig) : 3,500 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : N/A Outer Annulus Pressure ( sig) : 250 PROACTIVF DI~QNO7TIC SERVICES Date: May 4, 2008 Start time: 9:18:00 Temperature Data 40 35 ........................................... ................ ................................................ ~ ......................................................... LL ~i 30 .......................................... .................................................................... ............................................ D 25 .......................................................................................................................................................................................................................... ........ 20 0 1 2 3 4 5 6 7 8 9 10 Minutes 3600 3575 3550 3525 a rn 3500 a 3475 3450 3425 3400 Pressure Data 0 1 2 3 4 5 6 7 8 9 10 Minutes Page 1 B.P. Exploration ~A/askaJ. lnc. Stat~C TER7PB/'c~tU/'E~ P/'BSSU/'E SU/'VBj/ NS - 99 North Star North Slope 7 7,009' Tl/Dss M.D. = 93,904' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 252.9 5,062.27 1.0 252.7 5,062.45 2.0 252.6 5,062.74 3.0 252.5 5,063.07 4.0 252.4 5,063.40 5.0 252.4 5,063.71 6.0 252.4 5,064.00 7.0 252.3 5,064.25 8.0 252.4 5,064.48 9.0 252.2 5,064.70 10.0 252.3 5,064.89 11.0 252.3 5,065.07 12.0 252.2 5,065.24 13.0 252.3 5,065.40 14.0 252.3 5,065.55 15.0 252.3 5,065.69 16.0 252.4 5,065.83 17.0 252.3 5,065.95 18.0 252.4 5,066.07 19.0 252.4 5,066.19 20.0 252.4 5,066.29 21.0 252.4 5,066.40 22.0 252.4 5,066.49 23.0 252.4 5,066.58 24.0 252.4 5,066.67 25.0 252.4 5,066.75 26.0 252.4 5,066.83 27.0 252.4 5,066.90 28.0 252.4 5,066.97 29.0 252.4 5,067.03 30.0 252.4 5,067.07 AVERAGE 252.40 5.065.32 Date: May 4, 2008 Temperature Data 254 252 IL 250 ~' c 248 246 244 0 5070 5065 5060 a a 5055 5050 so45 so4o Ob`E~,4 WE((SAF a, c,. Q v~ ~. PROACTIVE D14C~NOSTIC SElVICES Start time: 11:11:00 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes Pressure Data 0 2 Page 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes B.P. Exploration (A/askaJ. lnc. Static Temperature/ Pressure Survey NS - 79 North Star North S/ope 90,959' Tl/Dss M.D. = 93,809' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 249.5 5,061.23 0.5 249.5 5,061.33 1.0 249.5 5,061.42 1.5 249.4 5,061.49 2.0 249.4 5,061.56 2.5 249.4 5,061.61 3.0 249.4 5,061.66 3.5 249.3 5,061.69 4.0 249.3 5,061.72 4.5 249.3 5,061.75 5.0 249.3 5,061.76 5.5 249.3 5,061.77 6.0 249.3 5,061.79 6.5 249.2 5,061.80 7.0 249.2 5,061.80 7.5 249.2 5,061.80 8.0 249.2 5,061.81 8.5 249.2 5,061.81 9.0 249.2 5,061.81 9.5 249.2 5,061.81 10.0 249.2 5,061.81 10.5 249.1 5,061.81 11.0 249.1 5,061.81 11,5 249.1 5,061.81 12.0 249.1 5,061.81 12.5 249.1 5, 061.81 13.0 249.1 5,061.81 13.5 249.1 5, 061.81 14.0 249.1 5,061.80 14.5 249.1 5,061.80 15.0 249.1 5,061.80 AVERAGE 249.2 5,061.72 Date: May 4, 2008 Temperature Data L.7~1 252 aL 250 ~' ~ 248 246 244 ?Db`EM WEl[ spec'. Q 9~ f- PROAcrive DisyMOSric S~evices Start time: 11:43:00 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data so~o 5065 ......___ ................._........................._....................._................................................................_............................................ __ _ ~ I 5060 ..................................................................................................................................................................................................................................... tg 5055 ..._._._ ............................................._._............_........................._.._.........................................._.._._..................-.__.................................................... a 5050 ......................................................................................................................................................................................................................................... 5045 ................................................................................................. ................................................................................................................................. 5040 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 3 e.P ~po~at/o~ ~Alaska~ 1~~. Static Temperature/ Pressure Survey NS - 99 North Star North Slope 9 9,009' TI/Dss M.D. = 93,904' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 252.2 5,067.81 0.5 252.2 5,067.73 1.0 252.3 5,067.65 1.5 252.3 5,067.59 2.0 252.3 5,067.55 2.5 252.3 5,067.52 3.0 252.4 5,067.49 3.5 252.3 5,067.48 4.0 252.4 5,067.48 4.5 252.4 5,067.48 5.0 252.3 5,067.49 5.5 252.3 5,067.50 6.0 252.4 5,067.50 6.5 252.4 5,067.52 7.0 252.4 5,067.53 7.5 252.4 5,067.55 8.0 252.4 5,067.56 8.5 252.4 5,067.58 9.0 252.4 5,067.59 9.5 252.4 5,067.60 10.0 252.4 5,067.62 10.5 252.4 5,067.63 11.0 252.4 5,067.64 11.5 252.4 5,067.65 12.0 252.4 5,067.67 12.5 252.4 5,067.68 13.0 252.4 5,067.69 13.5 252.4 5,067.70 14.0 252.4 5,067.71 14.5 252.5 5,067.72 15.0 252.5 5,067.73 AVERAGE 252.4 5.067.60 Date: May 4, 2008 Temperature Data obtEM We[[ sAF 4~ °'v s M PROACTIVE DIAGROSTIC SERVICES Start time: 12:01:00 Pressure Data 5070 5065 ........................................................................................................................................................................................................................................ 5060 ...................................................................................................................................................................................................................................... a a 5055 .................. ........................................ ....................................................................................... ~ ... -............................-......................... so5o -..._ ........................................_.... -.-.--__--._....._................................_............._........._......... _._...-............._..................................... 5045 ........................ _....................................._.-_.-..................... -....... --...-- _.......................................... _- ....................................._.......-..... so4o 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 4 B.P. Exploration (AlaskaJ. lnc. Static T@n7~7@!'c'1tU/'B~ P/'BSSU!'@ SU/'VBj/ NS - 99 North Star North Slope 90,909' TI/Uss M.D. = 73,696' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 246.5 5,055.70 0.5 246.5 5,055.87 1.0 246.5 5,056.01 1.5 246.5 5,056.12 2.0 246.4 5,056.19 2.5 246.4 5,056.25 3.0 246.4 5,056.28 3.5 246.4 5,056.29 4.0 246.4 5,056.29 4.5 246.3 5,056.28 5.0 246.3 5,056.27 5.5 246.3 5,056.25 6.0 246.3 5,056.23 6.5 246.3 5,056.20 7.0 246.2 5,056.18 7.5 246.2 5,056.15 8.0 246.2 5,056.12 8.5 246.2 5,056.10 9.0 246.2 5,056.07 9.5 246.2 5,056.05 10.0 246.2 5,056.03 10.5 246.2 5,056.01 11.0 246.2 5,055.99 11.5 246.2 5,055.96 12.0 246.1 5,055.95 12.5 246.1 5,055.92 13.0 246.1 5,055.91 13.5 246.1 5,055.89 14.0 246.1 5,055.88 14.5 246.1 5,055.86 15.0 246.1 5,055.84 AVERAGE 246.3 5.056.07 Date: May 4, 2008 Temperature Data 254 252 LL 250 ~' c 248 246 244 0 5070 5065 5060 a vs 5055 a 5050 5045 5040 1 2 3 4 5 6 7 8 Minutes Pressure Data Ob`F,M WE((SAf 4~ c~v s ~"~ N PROACTIVE DIATjNOSTIC SERVICEf Start time: 12:19:00 9 10 11 12 13 14 15 0 Page 5 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes B.P. Exploration (A/askaJ. lnc. NS - 99 North Star North Slope 90,859' TUDss M.D. = 93,602' Static Temperature/ Pressure Survey Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 245.8 5,049.39 0.5 245.8 5,049.39 1.0 245.8 5,049.39 1.5 245.8 5,049.39 2.0 245.8 5,049.38 2.5 245.8 5,049.38 3.0 245.8 5,049.37 3.5 245.8 5,049.36 4.0 245.8 5,049.35 4.5 245.8 5,049.34 5.0 245.8 5,049.33 5.5 245.8 5,049.32 6.0 245.8 5,049.31 6.5 245.8 5,049.30 7.0 245.8 5,049.28 7.5 245.8 5,049.27 8.0 245.8 5,049.26 8.5 245.8 5,049.25 9.0 245.8 5,049.24 9.5 245.8 5,049.23 10.0 245.8 5,049.22 10.5 245.8 5,049.22 11.0 245.8 5,049.21 11.5 245.8 5,049.20 12.0 245.8 5,049.19 12.5 245.8 5,049.18 13.0 245.8 5,049.18 13.5 245.8 5,049.17 14.0 245.8 5,049.17 14.5 245.8 5,049.16 15.0 245.8 5,049.15 AVERAGE 245.8 5,049.28 Date: May 4, 2008 Temperature Data ob`EM We[[ SAF QQ. c'v W V' PROACTIVE DiayROSTic Scavien Start time: 12:36:00 254 252 .......................................................................................................................................................................................................................................... a 250 ................................................................................................................................................................................................................................ ~' c 248 .......................................................................... ................................................................................................................ ....... 246 .... .... .... ........ .... .... .. .. ~ .......... .... .... . 244 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 5070 5065 ......................................................................................................................................................................................................................................... 5060 ............................................................................................................................................................ a rn 5055 ..... _ ............................................ _................_..............................................................._..._............................................... - ............... - ............... a 5050 ... .... .... ..................................................................................................................................................................... 5045 .................................................................................................................................................................... ................ ............... 5040 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 6 B.P. Exploration (Alaska) lnc. Sti~tiC TB/T)~7@/'c~t'U/'B~ P/'BSSU/'B SU/'VBJ/ NS - 79 North Star North Slope Surface -After POOH Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 37.8 3,571.88 0.5 37.4 3, 572.11 1.0 37.3 3,572.36 1.5 36.9 3,572.60 2.0 36.8 3,572.83 2.5 36.6 3,573.04 3.0 36.5 3,573.24 3.5 36.4 3,573.42 4.0 36.2 3,573.57 4.5 36.1 3,573.71 5.0 36.0 3,573.83 5.5 35.9 3,573.93 6.0 35.8 3,574.01 6.5 35.7 3,574.07 7.0 35.7 3,574.12 7.5 35.6 3,574.15 8.0 35.5 3,574.17 8.5 35.5 3,574.19 9.0 35.5 3,574.19 9.5 35.4 3,574.18 10.0 35.4 3,574.16 AVERAGE 36.2 3,573.51 Current Wellhead Read ings Wellhead Pressure (psig) : 3,500 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : N/A Outer Annulus Pressure (sig) : 250 Date: May 4, 2008 40 35 LL ~+ 30 0 25 20 Temperature Data Ob`EM We[[ SAF 4~ C'v s ~ ProActivF Di~ynosric $EavICES Start time: 14:36:00 0 3600 3575 3550 3525 ugj 3500 a 3475 3450 3425 3400 1 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 0 Page 7 1 2 3 4 5 6 7 8 9 10 Minutes B.P. Exp/oration (A/askaJ. lnc. Static Temperature/ Pressure Survey /Vis' 79 Q~Ob`EM WE~~SA~C'9 North Star = North Slope ~- Downho% Temp/Press PROACTIVE UIRfjNOSTIC SERVICEf Date: May 4, 2008 Start time: 9:18:00 End time: 14:46:00 254 252 u. 250 00 v ~ 248 246 244 Temperature Data r -200 0 200 400 600 800 1000 1200 1400 1600 Minutes Page 8 • STATE OF ALASKA S~ ~ -"~~~ `~ ~® AL OIL AND GAS CONSERVATION COt~SION ~ .MAY U REP~T OF SUNDRY WELL OPERATIONS S 1 2008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q - 8S l,Ot1S. Commj S5 Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ .~ Waiver Time Extension ~1l7C~lOf~ e Change Approved Program ~ Operat. Shutdown ~ Perforate ~ ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: ~ 5. Permit to Drill Number: Name: Development Exploratory f`~` 202-2070 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.3 KB NS19 - 8. Property Designation: 10. Field/Pool(s): _ ADLO-312809 ~ NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14063 ~ feet Plugs (measured) None true vertical 11135.18 feet Junk (measured) None Effective Depth measured 14058 feet ~~,~~ ~~~' '~ ZOO true vertical 11132.72 feet Casing Length Size MD TVD Burst Collapse Surface 3361' 13-3/8" 68# L-80 44' - 3405' 44' - 3202' 4930 2270 Intermediate 11710' 9-5/8" 47# L-80 43' - 11753' 43' - 9467' 6870 4760 Liner 1896' 7" 26# L-80 11584' - 13480' 9339' - 10823' 7240 5410 Liner 752' 4-1/2" 12.6# 13CR80 13328' - 14080' 10704' - 11144' 8430 7500 Perforation depth: Measured depth: 13860 - 13900 13900 - 13920 13905 - 13920 13395 - 13975 True Vertical depth: 11035.98 - 11055.37 11055.37 - 11065.1 11057.8 - 11065.1 10757 - 11092 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 - 13317 0 0 - Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: S E~~~. ~~~f ~Q~B 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2460 27299 1737 790 Subsequent to operation: 2471 31819 1939 796 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~` Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Robert Younger P ~ik.ya.~,~ ~Qr~pc ~~ ~ ~~ ~ ~' '-1 Printed Name Robert Younger Title Production Engineer Q~ ~( ~c~~ Signature Phone 564-5392 Date 4/28/2008 Form 10-404 Revised /2006 ~ ~ ~ ~ ~ `~ ~ Submit Original Only on S . , • 4/17/2008 CTU #5 Job Scope: CT Acid Stimulation «InterAct not publishing» RIH w/ 2.5" JSN with well flowing tag bottom at 13952' CTM corrected depth to ELMD of ;13969' (+1 T correction) PUH above perfs to 13825' Once acid at nozzle conducted four passes across perforations from 13860'-13959' (flag 10' off !bottom) pum~pm 6_0 bbls of 12% HCL w/ 10% L66 Parked above perforations ' ';and proceed d ush 132b s of 2% KCL w. 10% L66 made one down up pass >>. across perforations flushing away any remaining acid in wellbore using 2% KCL "°' "w. 10% L66 Pumped space of 2% KCL and freeze protected CT w. 60/40 meth. `POOH pumping 40 bbls of 80 deg. F diesel at CT displacement. ...Continue Job on 4/18/2008... r . _ . __, ..._~,, ....._ ,.. .,..._ _...., __...._ a.__...__. ,_., 4/18/2008 T/I/O= 400/3/200. Assist CTU with Acid Stimulation. Pump 40 bbls of 80" diesel "into the TBG. Final WHP= 450/3/193. 4/18/2008!: Continue job from 4/17/2008 CTU #5 Job Scope: CT Acid Stimulation «InterAct not publishing» POOH pumping CT displacement w. 80 deg. F diesel `down backside. Turn well over to DSO and production control for acid flow back ' **"Job Complete"** FLUIDS PUMPED BBLS 132 2% KCL W/10% L66 40 DIESEL 172 Total NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY 4/16/2008 CTU #5 Job Scope: Acid Stimulation w. CT MIRU ...Continue job on 4/17/2008... ___ ~ ___~_. w.., _._ ~.~_ ...__.. _ _n._ ___. .___.. n__a~.~~ ~__ ...._- 4/17/2008!Assist CTU with Acid Stimulation. MIRU. Preheat diesel to 80"~F. • • OIL ~ ~ 333 W. 7th AVENUE SUITE 100 COI~TSERQATIOi~T COMDII55I01~ , ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 ,~1~N~~ FEB 2 0 2008 Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 308-054 ~b ~, -~ ~•~ Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this .~ day of February, 2008 Encl. ~ ~~~ RECEIVED STATE OF ALASKA ` ~-~9'-rJ8 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ ~~~~ APPLICATION FOR SUNDRY APPRO~ p~~ & Gas Cons. C Ini ' 20 AAC 25.280 . __~,......... 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ ° ~ • aiver Othe Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ CTU Acid Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ Treatment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory ^ 202-2070 ~ 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ~ NS19 . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312809 - 56.3 KB - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14063 ~ 11135.18 14058 - 11132.72 NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3361' 13-3/8" 68# L-80 44' 3405' 44' 3202' 4930 2270 Intermediate 11710' 9-5/8" 47# L-80 43' 11753' 43' 9467' 6870 4760 Liner 1896' 7" 26# L-80 11584' 13480' 9339' 10823' 7240 5410 Liner 752' 4-1/2" 12.6# 13CR80 13328' 14080' 10704' 11144' 8430 7500 Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13860 - 13900 11035.98 - 11055.37 4-1/2" 12.6# 13Cr80 41 - 13317 13900 - 13920 11055.37 - 11065.1 - 13905 - 13920 11057.8 - 11065.1 - 13935 - 13975 11072 - 11092 - Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/28/2008 OIL 0 GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Robe unger Title Production Engineer Signature Phone 564-5392 Date 2/14/2008 COMMISSION USE ONLY C;~ Conditions of a roval: Notif Commission so that a re resentative ma witness Sund Number: ~ U U~~' pp y p y ry Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~'~Sc M~~ti~ ~ ~,e3 'd~~4~_~~'~ ~ -~~ ~~ I`I: ~ ~ ~ ~~~~ Subsequent Form Required: APPROVED BY ~ ~ ~ ~~ A d b pprove y: COMMISSIONER THE COMMISSION Date: Form 10-40 R~vised 06/2006 / ~ n I ~ ~ {~ ~ /~ ~ Submit in Duplicate • PERFORATING PROCEDURE ADW .~~...~ Well: NS19 API #: 50-029-23122-00 Date: 02/14/08 Prod Engr Robert Younger Office Ph: Home Ph: ............ Cell: ............ CC or AFC: NSFLDWLI9 Detail Code: Description: Drift,to.TD with Dummy Gun, Perforate ......................................................................................................... WBL Entries 564-5392 ...................... 677-2599 830-4920 ~a,<.oa~,e~,o, H2S Level: ................................................................ 0 ppm IOR T e Work Descri lion 300 S Drift to TD with Dummy Gun -Coordinate w/ per-coil drift currently on the WBL. 300 E Perforate 13,905' - 13920' MD & 13,935' - 13965' MD Well Objectives and Logging Notes: For the a detailed NS19 well history, please see Coil Acid Treatment currently on the WBL. If possible, please incorporate the dummy gun run drift into the pre-coil drift. Please plan to perforate the proposed RePerfs prior to the planned coil tubing acid treatment, which will likely be mid-March. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by re-perforating a total of 45' of the existing perforations. Please note that the perforations will be dependent on the drift information. Please contact Bob Younger with any questions, comments, or concerns - 564-5392 (w); 830-4920 (c); 677-2599 (h). Attachment: Reference Log with annotated perforations. Reference Log Tie in Loq ##### Log: GR-CCL . Date: 5/3/2003 .............................. ............................. Company: Schlumber. ............................. .............................. .............................. Depths (from-to) Depths (from-to) Feet SPF 13,905' - 13,920' 15' 6 13,935' 13,965' 30' 6 Gas Jetting Expected? .No At what Depth Requested Gun Size: 2.875" HSD Charge: Power Jet 2906 Desired Penetration: 25.3" Is Drawdown Necessary/Desired/Unnecessary During Perforating Desrribe below how to achieve drawdown (check w{ Pad Operator to see i/necessary piping is installed) (e.g. N2 Lilt, Hardline Lilt Gas, Gas Lilt, Flow Well, Backllow Through Drain or Hardline) Tie in to Jewelry ~ MD Tie in using: Minimum ID: ........................... 3.725 in Min ID Type: . Tail Depth: .... ......................... 13.317 ft MD Casing Size: Est Res. Pres. ~ .................... #REF! tie-in log to be on depth with the reference log. Orient. Phasing Zone Ad/Re/Iperf .Random .....60°..... 0 .Ivishak ........... ...............Reperf....................... Random .60° 0 Ivisnak ........... ...............Reperf .......................... ................... 0 .............................. ......................................................... .......................... ................... 0 .............................. ......................................................... . . ..... 0 ............. ...... ......................................................... :......................... ~ .. ..... .... . N/A ...................... Entry Hole Diam: .0.38" UnnecessarX ........................................................... ............. .................................... ......................................................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-1/2,:.XN.Nipple C~ 13,306.,'MD 4.5 in 12.6# 13-CR Liner .......................... .......................... MD :11100'.. SS .5100............... psi Last Tag: 13,979 ft ELMD on 7/8/2007 Well: NS79 Perforation Summary Date: API #: 50-029-23122-00 On-Site Prod Engr: - - -- General Comments: PBTD O/B/U - O • • Grade 13Cr _ ._. ..._ a .__ _~. _ From _ _,_ 0 ~ __.. ._._.__ ........`._...._.__~. - ~_ To ._._.~.._ _ 14077 ft .___.,,__..~ .~.__.~ _ Maximum Recorded Temperatures ._...__-_ __.__ ~.._.... ___ Logc~err Oo Boitnm~ .,=Time Un+tNumber Lacation _._ _ _ _ .._ 3-Ma~-2003 _..___ 1s 15 410t ~ PRUDHOE BAY _ _.._.._ ._.._ ~__ _ _ _ . _ ______ __ _~-~~~~~~~ __„ ~ ,.. _...w.. _ Recorded BY-____. F1RAS AL-TAJAR _ _ m ... ____. --- Witnessed B FiOC3 t.1DOt~..OW • • 13200 13300 13400 t~S ~~ ~~•" C,CI~ ~„~c 5 (O 3 ~ a-C~C73 ~~..`.~.,~~ ~ '~~..C~C~V1 13700 ,~ Schlumberger NS 19 GR-CCL 05/03/2003 Initial Perforations 05/05/03 13860'-13920' MD RePerforations 09/27/05 ^13860'-13905' MD RePerforations 05/15/06 13895' - 13920' MD Propose RePerfs 13905' - 13920' M 'MD 13935' - 13975' MD ~ Initially shot 05/15/06 Re-shot 07/08/07 Please melntaln a 15' gap between the exlstlnp end proposed Reperf interval. In the event of excessive water productlon, an IBP will be set to isolate the ~dpartinterval. 04/24/07 Tag TD „~ 13975' 1s ~' 7vo abw,e me 011 Water ~nta~t. 13977 MD F ALASS-A OIL A1~TD GAS CO1~T5ERQA~`IOl~T COMI~IISSIOI~T Robert Younger Production Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Northstar Field, Northstar Oil Pool, NS 19 O~ Sundry Number: 308-041 ~` ~ ~ FED ~ ~ 2~4~~F Dear Mr. Younger: ~4 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~day of February, 2008 Encl. Sincerelv, ZSTATE OF ALASKA ~y y JAN ~ ~ 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION K7 ~~ APPLICATION FOR SUNDRY APPROVAL ~iaska Oi18~ Cap C~)~. ~~~n~i~s~r~~~~ 20 AAC 25.280 Cnrhnratrt~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing^ Repair well ^ Plug Perforations Stimulate Q Time Extension ^ CTU Acid Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ Treatment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory ^ 202-2070' 3. Address: P.O. Box i 96612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS19 ' Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): , ADLO-312809 ~ 56.3 KB ~ NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14063 ~ 11135.18 14058 / 11132.72 NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3361' 13-3/8" 68# L-80 44' 3405' 44' 3202' 4930 2270 Intermediate 11710' 9-5/8" 47# L-80 43' 11753' 43' 9467' 6870 4760 Liner 1896' 7" 26# L-80 11584' 13480' 9339' 10823 7240 5410 Liner 752' 4-1/2" 12.6# 13CR80 13328' 14080' 10704' 11144' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13860 - 13900 11035.98 - 11055.37 4-1/2" 12.6# 13Cr80 41 - 13317 13900 - 13920 11055.37 - 11065.1 - 13905 - 13920 11057.8 - 11065.1 - Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 4-1l2" Liner Top Packer 13328 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/12/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Ro Younger Title Production Engineer Signature Phone 564-5392 Date 1/29/2008 COMMISSION USE ONLY mberLJo V ~ ~ 7 / nditio r v l tif nd C f N C i i th t t ti it S N : y o ns o app o a o omm on so a represen ve may w ness u ry u ss a a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ''\\ Other: ~~ V QS~1 ~Q ~ ~C~. ~~t- Subsequent Form Required: ~~y APPROVED BY ~'D SION D Approved by: ISSIONER THE COMMIS ate: Form 10-403 Revised 06/2006 ® /~ ~ v ~~~' ~ t ~ ~¢' f~ ~' 1~~~ Submit in Duplicate No portion of the bel~ork should be performed w/out fi~taking time to ensure ~~ No Accidents, o harm to People, and No damag the Environment To: Jerry Bixby/Clark Olsen -Well Operations Supervisor January 28, 2008 From: Robert Younger - Northstar Production Engineer subject: NS19 CTU Acid Treatment AFE NSFLDWLI9 Est. Cost: $150 M Est. IOR: 750 BOPD Please perform a coil tubing acid treatment on NS19 per the below procedure. Type IOR PR N DSWL AFE Job Description S 1000 NS19 NSFLDWL19 Drift to TD -Slope Discretion C 750 NS19 NSFLDWL19 Pump Acid Treatment Current Status: Last Test: Max Inclination: Max Dog Leg: Perforations: Minimum ID: Last TD tag: Last Downhole Op: Latest H2S value BHP: Well History Producer 01/21/08: BOPD: 2,270, BWPD: 1,859; MMCFPD: 30.6 62° at 13,713' md; 61 ° at Perfs 15.1 deg/100' at 13,554 and 13,860'-13920' md; 13,935' -13,975' and 3.725" @ 13,306' md, 4.5" XN Nipple 07/08/07: Tagged TD 13,979' ELM 07/01/07: ran 2 7/8" x 10' dummy gun, 1 td @ 13,941' slm, solid bottom 04/24/07: Tagged TD 13,977' ELM 07/08/07: RePerf 13935'-13975' MD 04/24/07: Production Log Field Produced Gas 4 ppm -Taken from 5,086 psi @ 11,100 ft ss, 5/17/05 1/2" sample bailer tagged HP Separator 06/11/07 NS19 experienced a severe decline in 2004. Two consecutive Acid/Scale Inhibition treatments were performed in 2005 in an attempt to mitigate the extreme decline. The second Acid/SI treatment performed on 5/1/2005 increased the rate by 2,000 BOPD, but the increase lasted less than a month. Due to the short lived results of the Acid/SI treatments, re-perforating the top 45' of perforations using Schlumberger's PURE technique was recommended. Only the upper 45' of the original 60' section were re- perforated due to water concerns. Severe scaling required multiple drift/broach runs to ensure the perforation guns would be able to reach the targeted perforation interval. While the September 2005 re-perforations did increase NS19's production, the severe scaling encountered in the drift runs indicated the bullhead Acid/SI treatments are inadequate. Therefore, a coil tubing conveyed acid job was proposed in order to insure efficient delivery of the acid to all perforations. The CTU acid job was completed 03/28/06 resulting in no change in the well's performance and no increase in produced water. No portion of the belo~ork should be performed w/out f~taking time to ensure No Accidents, o harm to People, and No damag the Environment Due to the poor results of the March Coil Acid Job and based on favorable results from re-perforating NS19 in September 2005, reperfs were proposed. In addition to the reperfs, adperfs were recommended to access additional reservoir below the existing perforation interval in an attempt to increase oil rate. The initial perforation interval was 92' above the oil water contact and the proposed adperf interval was 65' above the oil water contact. Despite the 92' of standoff from the oil water contact, NS19 produced 500 bbls of water. Therefore, in the event the Adperfs resulted in excessive water production a 15' gap between the pert intervals was left to set an IBP for water shut-off if required. Due to scale in the liner above the perforations, a liner acid wash was required in order to be able to access the perforation interval. The acid wash and adperf/reperf resulted in an IOR of over 4000 BOPD and the highest oil rate to date for NS19. A bullhead acid/scale inhibition treatment was completed in August 2006 to inhibit the new perforations that were shot in May 2006. The treatment resulted in 100 BOPD initial rate increase. NS19 was scheduled for a Coil Acid/Scale Inhibition Treatment during the 2007 barge season; however, the treatment was expedited to the 2007 ice road season. The Coil Acid Treatment conducted 04/03/07 resulting in a 950 BOPD increase. Following the Coil Acid Treatment, a production log was run 04/24/07. The Production Log indicated minimal production coming from the lower perforation interval. Therefore, the lower 40' of perforations were re-shot 07/08/07 resulting in a 400 BOPD rate increase. A second coil acid treatment was completed in 2009 as an attempt to remove any scale that may have formed in NS19 since its last treatment and acidize the July re-pert interval. The CT Acid treatment 08/14/07 resulted in 100 BOPD increase. Based on the historical rate benefits of treating NS19, the below CTU acid/scale inhibition treatment is proposed. Procedure Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. Please do not filter fluids that contain L66. All filtering should be performed before the addition of the L66 scale inhibitor to insure the inhibitor does not plate out in the filters. Please do not add friction reducer to water that will contact the formation due to formation plugging issues. Please avoid contacting L66 with methanol or seawater -these fluids will cause premature precipitation of the L66 scale inhibitor and jeopardize the objectives of this procedure. No portion of the bel~ork should be performed w/out f~taking time to ensure No Accidents, o harm to People, and No damag the Environment Prep Work: 1. Mobilize coil unit, pumps, tanks and acid transport to Northstar. Order out necessary volume of seawater, 2% KCL, acid, and diesel. Please review: Alaska Wells Group Rigless Operations Manual: Coiled Tubing Operations Section: CTU Operations at Northstar Island DRIFT WITH SLICKLINE: Slope discretion 07/08/07: Tagged TD 13,979' ELM 2. RU slickline. 3. RIH with slickline to TD. Note if scale is encountered. COIL TUBING ACID TREATMENT: 4. MIRU. 5. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 6. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 7. PT Dowell surface lines to 5000 psi. 8. Bullhead kill with filtered 2% KCI (volume to top pert is 210 bbls). Please leave a 50 bbls diesel cap for an under-balanced flowback. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. 9. RIH with jetted nozzle (min ID = 3.725"). Drift to below perforations to insure no obstructions exist. 10. Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 60 bbls Acid w/ 10% L66 b) 130 bbls 2% KCI w/ 10% L66 (112 bbls provides 5' radial displacement, but 130 bbls required to meet scale inhibitor meet L66 ) Please do not POOH until the total over-flush volume has been pumped in order to reduce the chance of stirring-up solids that could plug the perforations. Ensure well has a 50 bbls diesel cap for an under-balanced flowback. No portion of the bel~ork should be performed w/out f~taking time to ensure No Accidents, o harm to People, and No damag the Environment Coil Treatment of 12% HCL Acid to contain: 10% L66 Scale Inhibitor 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results avai la bl e on lo cati on. : - I iti l P f ti 05!05/03 n a er ora ons 13860'-13920' MD - RePerforations 09/27/05 13860' 1 905' - 3 MD t RePerforations 05/15/06 - 13895' - 13920' MD - R ?l i i t5' th i b t d , ~ ease ma nta e exist ng an n a gap e ween proposed Adpert interval In ~e event the proposed . Adperis result in excessive water productbn, an IBP will be Set to Isolate the Adperf interval. 13975 C t t on ac Shot 117/118/117 P d R P f ropose e er s _ - ~ 13935' 1397' MD =' -- - - Initially shot OS/ 15106 - _ Pl d i i ease ensure a equate rec procat on ` across the lower perf interval to ensure 04/ 24/07 Ta TD g acid contacts this lower interval The . 13977 MD 04/24/07 roduction lo indicates minimal p g t ib ti f thi i t l i di ti con r u on rom s n erva n ca ng ' possible damage -see log below. 11. Shut well in for 4 hours after injection to allow scale inhibitor to precipitate. 12. RD Schlumberger. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures) to Robert.Younger@ bp.com. No portion of the bel~ork should be performed w/out taking time to ensure No Accident , o harm to People, and No dama the Environment Flowback Procedure: 13. After 4 hour shut-in, line-up the well to flow into the test separator and well cleanup tank for flowback. Produce clean-up volume of 468 bbls (Tubing 210 bbl + Treatment 190 bbl + Flowline 68 bbl). After clean-up, divert back to the plant and get 2 6-hour tests. 14. Post Flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree post acid treatment. Procedure Contacts: Robert Younger W K: 564-5392 HM: 677-2599 Cel I: 830-4920 No portion of the bel~ork should be performed w/out f~taking time to ensure No Accidents, o harm to People, and No damag the Environment 04/24/07 PRODUCTION LOG RESULTS: Table 1 Interpreted Downhole and Surface Results Ds Oil Water Gas From Ft To FL Downhde BPD Surfaco STBPD °l. Downhole BPD Surface STBPD 9i. Downhole BPD Surtace 141scf/D 96 13860 13920 2524.4 19S 1.6 $$°.~ ! 31.s ~ __ _ . 300.0 7E'~ 59.4.8 RfC4.t 99:ro 13935 13975 q.7 48.2 _ ' 2°~ - L.....a.l ''.___ _. `` r _ c : t^_ Total 2b88.1 1959.8 402.9 384.6 5969.0 8699.0 PFC2 it Flow in}S PFC1 Water Flew '~in c~Ft s M~ (~~ ft (bbl/d) 10000 Spinner - DwnPass2 0 (c/s) ~ DEFT -Holdup 0.1 ( ~ t.l te-oa6 m Fluid Density 0.2 (9Icm3)----1.2 Pressure 4800 (Ps+) 4650 Temperature -- -~ 250 (degF ~ - x i ~~ ;: --r- •, .- -; ` ~ ~ ~ :t ; I 11.- 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: . tt::~ RECEIVED STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COM ION AUG 2 2 2007 REPORT OF SUNDRY WELL OPERATIONS . D D D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic r Stimulate D Waiver D Time Exte_ Re-enter Suspended Well D 5. Permit to Drill Number: 202-2070 / k P.O. Box 196612 Anchorage, AK 99519·6612 7. KB Elevation (ft): Exploratory Service 6. API Number: 50-029-23122-00-00 ,/ 3. Address: 9. Well Name and Number: 56.3 KB - NS19 ADLO-312809/ 11. Present Well Condition Summary: 10. Field/Pool(s): NORTHSTAR Field/ NORTHSTAR OIL Pool 8. Property Designation: Total Depth measured true vertical 14063 ( 11135.18 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 14058 ' feet SCANNED AUG 2' 8 2007 true vertical 11132.72 feet Casing Length Size MD TVD Bu rst Collapse Surface 3361 13-3/8" 68# L-80 44 - 3405 44 - 3201.89 4930 2270 Intermediate 11710 9-5/8" 47# L-80 43 - 11753 43 - 9467.45 6870 4760 Liner 1896 7" 26# L-80 11584 - 13480 93íi9.35 . 1 Qi23.2e.... ...... 7240 5410 Production 752 4-1/2" 12.6# 13Cr80 13328 - 14080 10704.48 - 11143.53 8430 7500 Perforation depth: 13895 - 13900 11053 - 11055 13900 - 13905 11055 - 11058 13905 - 13920 11058 - 11065 13935 - 13955 11072 - 11082 Measured depth: .f3860 - 13895 True Vertical depth: 11036 - 11053 Measured depth: 13955 - 13975 True Vertical depth: 11082 -11092 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 - 13317 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 941 11584 13270 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): R8DMS 8FL AUG 2 7 2007 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 3177 5206 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 26041 2018 0 44077 2908 0 15. Well Class after Droposed work: Exploratory r Development P 16. Well Status after proposed work: Oil P Gas r WAG r Tubing pressure 770 778 13. Service r x WINJ r WDSPl r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-234 Contact Robert Younger Printed Name Robert Younger n~ Title Production Engineer Signature Phone 564-5392 Date 8/14/2007 . . NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/12/2007 CTU #5. Acid Stimulation. MIRU CTU. During rig up, discovered needle bearing in the injector head sump. Discovered 55+ broken chain bearings which required replacement. Work on repairing injector head. *** Job continued on WSR 08/13/2007 *** 8/12/2007 Stand by for CTU #5 (Acid Treatment) - Stand by for CTU #5 repairs ***Continued to next Days WSR*** _~ -n_" 'r'~ .." ,om r'r-r-n-"~" '",'" '_'-_w' '."""" ,_ W_'···'__··"N_','_'-'._.-uw.__'h_,'^,·_',w -'··W.·.'._.·-'.·.__·.___C_·,·oW_'·hW=·r'~=" 'wN" '~'~.W~"~,·,·,W·'~"W,'m-,m-'.·__m'-',w__mu~-,_, ""'''~~'~~''='''__-u'''' 8/13/2007 CTU #5. Acid Stimulation *** Continued from WSR 08/12/2007 *** Continue replacing broken injector chain bearings. Perform BOPE test (pass) MU BHA w/3.0" side jet nozzle. Load well with 5 bbls meth, 165 bbls of 2% KCI, 90 bbls of 2% KCI w/0.6% Safelube and 8 bbls meth. RIH with BHA #1. *** Job continued on WSR 08/14/2007 *** 8/13/2007 :-Assist CTU (Acid Treatment) - Spot up equipment, stand by for coil to kill well & RIH ***Continued to next days WSR*** m.......vm....w.>"'..·. 'm"....'.~....... ~ "·..·'w',...··,,.., 8/14/2007; CTU #5. Acid Stimulation *** Continued from WSR 08/13/2007 *** InterACT . broadcasting. RIH with 3.0" Side Jet Nozzle to 13953' ctm. PUH above perforations and pump 60 bbls of 12% HCI. Initial injection rate at 1.5 bpm at 616 i psi with 2% KCI. Overdisplace with 112 bbls of KCI into formation. ¡ *** Job in progress *** ""-.~m...-mm..".,',·",',',',',"· n'."."'m.,'.-......,','.',',-.'.'~·.,-.'.....wm..,'mm 8/14/2007i***Continued from Previous Days WSR*** . Assist CTU (Acid Treatment) - Pump as directed down coil w/60 bbls 12% hcl acid while coil jets perfs. Pumped 47 bbls diesel down back side of coil to fill voidage as coil POOH. *** Job Complete*** FLUIDS PUMPED BBLS 112 2%KCI 60 12% HCI (titration 12.1% HCI, IRON <20PPM) 47 DIESEL 219 TOTAL e e Date 08-14-2007 Transmittal Number:92897 ...... 'J 'ìPQ'lC LU ! Oil'?, BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ;) Log Top SW Name Date Contractor Run Depth Bottom Depth Log Type u:s:c.. -/1Ja NS10 07 -21-2007 SCH 1 4800 7975 WATERFLOW INJECTION :te. o"3-,,,,<k NS32 07 -20-2007 SCH 1 3760 8075 WATERFLOW INJECTION e- dò"'?- NS19 07 -08-2007 SCH 1 1 3650 13955 PERFORATION RECORD -ö3C.. NS11 07 -06-2007 SCH 1 14450 14625 PERFORATION RECORD ll- ()'X(_ NS13 07-14-2007 SCH 1 11534 11790 MEMORY PPROF - (~ NS24 07 -15-2007 SCH 1 11774 12476 STATIC BOTTOM HOLE , ~ -9J3 NS22 07 -09-2007 SCH 1 12600 12850 PERFORATION RECORD - -ö81 NS08 12-23-2005 PDS 1 9006 11406 CORRELATION LOG ö;) ..-a~ NS21 07 -02-2005 PDS 1 21590 22249 DEPTH DETERMINATION ~~ -/~<9 NS10 01-01-2006 PDS 1 4497 5497 CORRELATION LOG 8öo Ú g ~ '}o(o Jë ~ ~o }od- () 7uo (!^f~ Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer 2007 Petrotechnical Data Center 5'~NED AUG 1 '7 Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . ~TI~TIŒ (ID~ ~~~~[K\~ AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 307 -234 5CANNED JUL 1 8 2007 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this /1:day of July, 2007 Enc!. c9ùd-dör Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 1. Type of Request: 3. Address: Abandon A~AOllAND~:~~g~!;?f,~~~~Ma~ RECEIVED APPLICATION FOR SUNDRY APPROVAL (".~ JUL 1 2 2007 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Developm ent ~ m¡~!;íOH Suspend Repair well D Pull Tubing D 5. Permit to Drill Number: Stratigraphic 0 Exploratory 0 Service 0 6. API Number: 50-029-23122-00-00 - 202-2070 ~ Anchorage, AK 99519-6612 8. Well Name and Number: 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer Descriptive Sum m ary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 11. Total Depth MD (ft): 14063 Casing Surface Intermediate Liner Production Perforation Depth MD (ft): 13860 - 13975 Packers and SSSV Type: 12. Attachments: Commencing Operations: 16. Verbal Approval: Commission Representative: NS19 D No ADLO-312809 / 10. KB Elevation (ft): 11. Field/Pools(s): 56.3 KB ' NORTHSTAR Field / NORTH STAR OIL Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11135 14058 - 11133 None None Length Size TVD Burst Collapse 3361 13-3/8" 68# L-80 44 3405 44 3202 4930 2270 11710 9-518" 47# L-80 43 1175343 9467 6870 4760 1896 7" 26# L-80 11584 13480 9339.35 10823 7240 5410 752 4-1/2" 12.6# 13Cr80 13328 14080 10704.48 11144 8430 7500 Perforation Depth TVD (ft): 11036 - 11092 Tubing Size: 4-1/2" 12.6# Tubing Grade: 13Cr80 Tubing MD (ft): 41 -13317 Packers and SSSV MD (ft): 941 11584 13270 13328 13. Well Class after proposed work: Exploratory 0 Developm ent ~ Service 0 7/20/2007 Date: 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by \.:Iäry ....rt:Jule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Robert Younger Title Contact Robert Younger Production Engineer 6/29/2007 Signature Date Phone 564-5392 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: '"'\ooa ~\ "",\,,,\ ~~"" c.., ~O\> ~}<\- Subsequent Form Required: I.-\() '-\ Approved by: APPROVED BY THE COMMISSION Date: OMMISSIONER Form 10-403 Revised 06/2006 . RBDMS BFl JUL 1 8 Z007 4- N A ~ ~ M~mn;o D'pllœ" · No portion of the belo!Ork should be performed w/out Ii.akins time to ensure Õ No Accld_, 0 harm to Pooplo, and No damag the Environment To: Jerry Bixby/Clark Olsen - Well Operations Supervisor July 11, 2007 From: Robert Younger - Northstar Production Engineer Subject: NS19 CTU Acid Treatment AFE NSFLDWL 19 Est. Cost: $150 M Est. lOR: 1200 BOPD Please perform a coil tubing acid treatment on NS19 per the below procedure. Current Status: Last Test: Max Inclination: Max Dog Leg: Perforations: Minimum ID: Last TO tag: Producer 06/07/07: BOPD: 3,199, BWPD: 1,385; MMCFPD: 26.88 62° at 13,713' md; 61° at Perfs 15.1 deg/100' at 13,554 md 13,860'-13920' md; 13,935' -13,975' md 3.725" @ 13,306' md, 4.5" XN Nipple 0708107: Tagged TD 13,979' ELM 07/01/07: ran 2 7/8" x 101 dummy gun, 1 1/211 sample bailer tagged td @ 13,9411 slm, solid bottom 04/24/07: Tagged TD 13,977' ELM Last Downhole Op: 07/08107: RePerf 13935'-13975' MD 04124/07: Production Log Latest H2S value: Field Produced Gas 4 ppm - Taken from HP Separator 06/11/07 BHP: 5,086 psi @ 11,100 ft ss, 5/17/05 Well History NS19 experienced a severe decline in 2004. Two consecutive Acid/Scale Inhibition treatments were performed in 2005 in an attempt to mitigate the extreme decline. The second Acid/SI treatment performed on 5/1/2005 increased the rate by 2,000 SOPD, but the increase lasted less than a month. Due to the short lived results of the Acid/SI treatments, re-perforating the top 451 of perforations using Schlumberger1s PURE technique was recommended. Only the upper 45' of the original 60' section were re- perforated due to water concerns. As outlined in the tag history, severe scaling required multiple driftlbroach runs to ensure the perforation guns would be able to reach the targeted perforation interval. While the September 2005 re-perforations did increase NS19's production, the severe scaling encountered in the drift runs indicated the bullhead Acid/SI treatments are inadequate. Therefore, a coil tubing conveyed acid job was proposed in order to insure efficient delivery of the acid to all perforations. The CTU acid job was completed 03/28/06 resulting in no change in the well's performance and no increase in produced water. Due to the poor results of the March Coil Acid Job and based on favorable results from re-perforating NS19 in September 2005, reperfs were proposed. No portion of the bel.Ork should be performed w/out tAtaklns time to ensure No Acclden 0 harm to People, and No damas~ the Environment In addition to the reperfs, adperfs were recommended to access additional reservoir below the existing perforation interval in an attempt to increase oil rate. The initial perforation interval was 92' above the oil water contact and the proposed adperf interval was 65' above the oil water contact. Despite the 92' of standoff from the oil water contact, NS19 produced -500 bbls of water. Therefore, in the event the Adperfs resulted in excessive water production a 15' gap between the perf intervals was left to set an ISP for water shut-off if required. Due to scale in the liner above the peñorations, a liner acid wash was required in order to be able to access the peñoration interval. The acid wash and adperf/reperf resulted in an lOR of over 4000 SOPO and the highest oil rate to date for NS19. A bullhead acid/scale inhibition treatment was completed in August 2006 to inhibit the new perforations that were shot in May 2006. The treatment resulted in -100 SOPO initial rate increase. NS19 was scheduled for a Coil Acid/Scale Inhibition Treatment during the 2007 barge season; however, the treatment was expedited to the 2007 ice road season. The Coil Acid Treatment conducted 04/03/07 resulting in a -950 SOPO increase. Following the Coil Acid Treatment, a production log was run 04/24/07. The Production Log indicated minimal production coming from the lower perforation interval. Therefore, the lower 40' of perforations were re-shot 07/08/07 resulting in a -400 SOPO rate increase. The next step for NS19 is the below proposed coil acid treatment is an attempt to remove any scale that may have formed in NS19 since its last treatment and acidize the July re-perf interval. Procedure Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. Prep Work: 1. Mobilize coil unit, pumps, tanks and acid transport to Northstar. Order out necessary volume of seawater, 2% KCL, acid, and diesel. COIL TUBING ACID TREATMENT: 2. MIRU. 3. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. 4. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 5. PT Dowell surface lines to 5000 psi. No portion of the bel.Ork should be performed w/out Ii_taking time to ensure No Accidents, No harm to People, and No damag the Environment 6. Bullhead kill with filtered 2% KCI (volume to top perf is 210 bbls). Please leave a 49 bbls diesel cap for an under-balanced flowback. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. 7. RIH with jetted nozzle (min 10 = 3.725"). Drift to below perforations to insure no obstructions exist. 8. Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 60 bbls Acid b) 112 bbls 2% filtered KCI (Overflush for 5' radial displacement) Please do not POOH until the total over-flush volume has been pumped in order to reduce the chance of stirring-up solids that could plug the perforations. 12% Acid to contain: 25.0 ppt A 153 4.0 ppt A179 0.6 % A261 0.2 % F103 20.0 ppt L058 0.5 % W054 0.5 % W060 Inhibitor Aid Inhibitor Aid Inhibitor Surfactant, EZEFLO Iron Stabilizer Non-Emulsifying Agent Sludge and Emulsion Preventer Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. w/out and No damage 1 Robert Younger WK: 564~5392 HM: 677-2599 Cell: 83(}..4920 No portion of the No rk should be performed w/out No harm to People, and No dam taking time to ensure the Environment 04/24/07 PRODUCTION lOG RESULTS: Tot~1 19S0,8 402,9 384.6 5969.0 1699.0 . r=e TREE:; , ~ ABB-VGI5-118" 5K W8.UEAO - ABB-VGI13-5I8" UA.TBOWl5KS NS19 SAFETY NOTES: ***4-112" CHROMET8G& LNR*** ACTUA TOR:; KR ElÐl :: 56.3' BF. ElÐl - 4O.1'(CB 16.2') KOP- . 941' 4-112" TRM-4ESSSV, D= 3.812" I -- Max Angle = @ Datum M) = Datum TVO :: 10500' SS 13-3..'8' CSG, 68#, L-BO BTe, D = 12.415" 3405' -µ t... GAS lFT MAf'oIJRElS Sl M) lVO DEV TYÆ VlV LA TO- PORT DAlE Minimum ID = 3.725" @ 13306' L 2 5067 4428 1 6469 5474 4-112" XN NIPPLE I TOP OF 7" LIIR 13328' 2S ~\.. 9-518" CSG,47#. l-80 BTC-M, D = 8.681" 11753' ~ 13229' 4-112" FBffi. OPTIC TRANSDUCER, D - 3.945" I I 113328" aM H4-112" FBffi. OPTIC TRANSDUCER. D = 3.945" I · I 13249' 4-112" x NP, D= 3.813"' ¡:g ð 13270- 7" x 4-112" PKR. D = 1111 1 · I 13294' 4-1I2"XNP,D=3.813" I · 18 13306" 4-1I2"XNNP, D::3.725"-' I TOP OF 4-112" LIIR 13328' 25í 4-1f2"TBG.12.6#,13CRVAM-ACE 13317' 1331T 4-112" WlEG, D :; 3.85"1 .0152bpf, D:: 3.958" I HElM) TT LOGGID 05103103 I 13326' 17" LfIR 26#,:-80 HY"DRL 521. 13480' ~ II... .0383 bpf, D - 6.276 ÆRFORA TON StANARY REF LOG: JEWElRY LOG I GR-CCl ON 05103103 ANGlE AT TOP PERF: 11@ 13860' Note: Refer to R"oduction œ for historical perf data NlTlAL PERF - ŒlARGE: 2906 POWERJET, tNX, PENETRA T1ON: 27", 1-KJlE: 0.36", PHASE: 60 DEG. ] SIZE SPF MERV Al (MJ) OpnISqz DAlE 2-112 6 13860 - 13905 0 09/27105 2-718 6 13860 - 13920 0 05105103 2-718 6 13895 - 13920 0 05/15106 2-718 6 13935 - 13975 0 05/15106 I] ~ 14077' I 14'112" LNR. 1~.6#, 1~RVAM-ACE 14080' I .0152 bpf, D - 3.958 DAlE REV BY e<:>M'ÆNTS ClUE REV BY e<:>M'ÆNTS NORlHSTAR 11/15/02 FH INTIAL DRILL WEll: 1'519 03131103 JAS ORIGINAL COMPLErION PERMT No: ~22070 05.'07103 EM" AOÆRFS API No: 50-029-23122-00 09!27105 WRRITLH PERFS SEe TNRE 10107105 fTl.H tEN FORMAT & lVO CORRECT. 05.'15106 WRRlPJC PERFS I ElM) CORRECllON BP Exploration (Alaska) .".,.-" ~ I STATE OF ALASKA I ;¡¿.7.5""t?? ALAS A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS <14 I»~c J(/., ~/ t-"" ;r~~ ·Ž" ~ l'() 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D Other IT/I d: ,( ¡ ') i Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D 8~.!' /' (' (;;'77 Change Approved Program D Operat. Shutdown D Perforate 0( Re-enter Suspended Well D i?C'A, ~'D;~~;,' " 2. Operator BP Exploratión (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number:' "¿?~)i "i?;';{): Name: Development Exploratory 202-2070 ~ I,. 3, Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-0Q./ 7, KB Elevation (It): 9. Well Name and Number: 56.3 KB - NS19 '" 8. Property Designation: 10. Field/Pool(s): ADLO-312809 I NORTHSTAR Field/ NORTHSTAR OIL Pool - 11. Present Well Condition Summary: Total Depth measured 14063 / feet Plugs (measured) None true vertical 11135.18 ' feet Junk (measured) None Effective Depth measured 14058 I feet SCANNE.D JUL 1 8 2007 true vertical 11132.72 feet Casing Length Size MD TVD Burst Collapse Surface 3361 13-3/8" 68# L-80 44 - 3405 44 - 3201.89 4930 2270 Intermediate 11710 9-518" 47# L-80 43 - 11753 43 - 9467.45 6870 4760 Liner 1896 7" 26# L -80 11584 - 13480 9339.35 - 10823.22 7240 5410 Production 752 4-1/2" 12.6# 13Cr80 13328 - 14080 10704.48 - 11143.53 8430 7500 Perforation depth: Measured depth: 13860 - 13900 13900 - 13920 13905 - 13920 13935 - 11072 True Vertical depth: 11035.98 - 11055.37 11055.37 - 11065.1 11057.8 -11065.1 13975 - 11092 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 -13317 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): R8DMS BFL JUL 1 7 2007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3891 28772 1740 0 779 Subsequent to operation: 4388 33231 2120 0 813 14. Attachments: 15. Well Class after Droposed work: Copies of Logs and Surveys Run Exploratory Development P Service Daily Report of Well Operations X 16. Well Status alter proposed work: Oil P Gas r WAG GINJ r WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Isundry Number or N/A if C.O. Exempt: 307-201 Contact Robert Younger P,;ol'" Name RObe~ _"" Title Production Engineer Phone 907-564-5392 Date 7/11/2007 Signature Form 10-404 Revised 04/2006 0 R , G \ N A L 4-. ( \." # ;rÎ6;&;it Original Only . . ... NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/8/2007 RE-PERFORATED 13935'-13975' WITH 2.88" HSD PJ2906 TIED INTO SLB JEWELRY / PERF LOG DATED 3-MAY-03. CORRELATED WITH GAMMA RAY AND COLLARS. ALL SHOTS FIRED. TAGGED TD AT 13979'. DSO POPPED WELL AFTER SLB RD. Job complete FLUIDS PUMPED BBLS I 1 DI ESEL 1 TOTAL · . ~1f~1fŒ ffiJ~ ~~~~æ~ / I AI4~"1iA. OILA5D GAS / CONSERVATION COMMISSION / SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Product Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 307-201 " ~ 'J-,O 1 :;}t.:Þ Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisd day of June, 2007 Encl. (j)T~'//Õ /7 I~Ø .. I ~TATE OF'1;lA~A6 -Ð1 A Oil AND GAS CONSERVATION COM_ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: . .. .tf 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 Suspend Repair well 0 Pull Tubing 0 Development ~ Stratigraphic 0 3. Address: Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: ~ 6-/.5-07 'Yf2j. ~16 JU, . CS/!/Þ-D "';llIs/(. IV . , Waiver ~ Q. Stimulate 0 Time Extension 04. :ø3 C(J/i fJcl¡ III. /'I Re-enter Suspended Well 0 Qflll. . f.,,0t}z 5. Permit to Drill Number: Exploratory 0 202-2070 / 6. API Number: Service 0 50-029-23122-00-00 , 8. Well Name and Number: NS19 ( No 0 10. KB Elevation (ft): 11. Field/Pools(s): 56.3 KB ¡ NORTHSTAR Field / NORTHSTAR OIL Pool / ADLO-312809 I 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14063 11135 14058 11133 NONE NONE Casing Length Size TVD Burst Collapse Surface 3361 13-3/8" 68# L-80 44 3405 44 3202 4930 2270 Intermediate 11710 9-5/8" 47# L-80 43 11753 43 9467 6870 4760 Liner 1896 7" 26# L -80 11584 13480 9339.35 10823 7240 5410 Production 752 4-1/2" 12.6# 13Cr80 13328 14080 10704.48 11144 8430 7500 Packers and SSSV MD (ft): Perforation Depth MD (ft): 13860 - 13900 13900 - 13920 13905 - 13920 Packers and SSSV Type: Perforation Depth TVD (ft): 11035.98 - 11055.37 11055.37 - 11065.1 11057.8 - 11065.1 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer DescriDtive Sum mary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Tubing Size: 4-1/2" 12.6# Tubing Grade: 13Cr80 Tubing MD (ft): 41 - 13317 941 11584 13270 13328 12. Attachments: 13. Well Class after proposed work: Exploratory 0 Developm ent ~ Service 0 Commencing Operations: 16. Verbal Approval: 6/22/2007 Date: 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by \.:Ié1ry r-r~ule 564-4944 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Robert Younger Title Signature Phone 564-5392 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Contact Date Sundry Number: -1- 80 J Location Clearance 0 Other: ~~\\ ~C"\t"O\ (c'\,~\~,,^,<t:.>(-~ \>~C d-a~~<-d-S'<ð~ì. Approved by: Subsequent Form Required: L\(),-\ Form 10-403 Revised 06/2006 APPROVED BY THE COMMISSION RBDMS 8Ft JUN I 9 2007 Submit in Duplicate No portion of the bel_ork should be performed w/out f. taking time to ensure o No Accident 0 harm to People, and No damag 0 the Environment To: Jerry Bixby/Clark Olsen - Well Operations Supervisor June 7,20077 From: Robert Younger - Northstar Production Engineer Subject: NS19 RePerf AFE NSFLDWL 19 Est. Cost: $80 M Est. lOR: Est 500 SOPD lOR 500 T e S Work Descri tion Drift to TD w dumm un 500 E Perforate 40' of Ivishak 13,935' - 13975' MD Please Note: Ad-Perfs interval 13,935' -13975' MD may need to be shortened if tag is high Current Status: Producer Last Test: 5/17/07: BOPO: 3,531, BWPO: 1,372; MMCFPO: 27.8 Max Inclination: 62° at 13,713' md; 60° at Perfs Max Oog Leg: 15.1 deg/100' at 13,554 md Minimum 10: 3.725" @ 13,306' md, 4.5" XN Nipple Last TO tag: 04/24/07: Tagged TO @ 13,977' ELM. Last Oownhole Op: 04/24/07: Production Log Latest H2S value: None anticipated Well Historv NS19 experienced a severe decline in 2004. Two consecutive Acid/Scale Inhibition treatments were performed in 2005 in an attempt to mitigate the extreme decline. The second Acid/SI treatment performed on 5/1/2005 increased the rate by 2,000 BOPO, but the increase lasted less than a month. Oue to the short lived results of the Acid/SI treatments, re-perforating the top 45' of perforations using Schlumberger's PURE technique was recommended. Only the upper 45' of the original 60' section were re- perforated due to water concerns. As outlined in the tag history, severe scaling required multiple drift/broach runs to ensure the perforation guns would be able to reach the targeted perforation interval. While the September 2005 re-perforations did increase NS 19's production, the severe scaling encountered in the drift runs indicated the bullhead Acid/SI treatments are inadequate. Therefore, a coil tubing conveyed acid job was proposed in order to insure efficient delivery of the acid to all perforations. The CTU acid job was completed 03/28/06 resulting in no change in the well's performance and no increase in produced water. Oue to the poor results of the March Coil Acid Job and based on favorable results from re-perforating NS19 in September 2005, reperfs were proposed. No portion of the bel.ork should be performed w/out . taking time to ensure ~ No Acciden 0 harm to People, and No damag 0 the Environment In addition to the reperfs, adperfs were recommended to access additional reservoir below the existing perforation interval in an attempt to increase oil rate. The initial perforation interval was 92' above the oil water contact and the proposed adperf interval was 65' above the oil water contact. Despite the 92' of standoff from the oil water contact, NS19 produced -500 bbls of water. Therefore, in the event the Adperfs resulted in excessive water production a 15' gap between the perf intervals was left to set an IBP for water shut-off if required. Due to scale in the liner above the perforations, a liner acid wash was required in order to be able to access the perforation interval. The acid wash and adperf/reperf resulted in an lOR of over 4000 BOPO and the highest oil rate to date for NS19. A bullhead acid/scale inhibition treatment was completed in August 2006 to inhibit the new perforations that were shot in May 2006. The treatment resulted in -100 BOPO initial rate increase. NS19 was scheduled for a Coil Acid/Scale Inhibition Treatment during the 2007 barge season; however, the treatment was expedited to the 2007 ice road season. The Coil Acid Treatment conducted 04/03/07 resulting in a -950 BOPO increase. Following the Coil Acid Treatment, a production log was run 04/24/07. The Production Log indicated minimal production coming from the lower perforation interval. Therefore, the proposed reperfs are an attempt to ensure the lower interval is adequately accessing the reservoir. Please call with any questions, comments, or concerns. Procedure Please see attached Wireline Request. Procedure Contacts: Robert Younger WK: 564-5392 HM: 677-2599 Cell: 830-4920 · . -. RDIII .--..... PERFORATING PROCEDURE Well: Date: NS19 ............................................................... 06/07/07 API #: 50-029-23122-00 ................................................. Prod Engr ..~9.~~~..y.9.~~~.~.~........... ............................................................... Office Ph: Home Ph: Cell: 564-5392 ........................................................ 677-2599 ........................................................ 830-4920 WBL Entries CC or AFC: NSFLDWL 19 Detail Code: Description::~:~fi:~~:::::::::::::::::::::::::::::::::::::::::::::::......................................::::::::::::::::::::::.::::::,............................................................................................ ........................................................ Ver 4.0 06/04/01 ~......·.....·..·..·~·~:-p~~~·~:··..........·..·..·I) lOR Type Work Description 500 S Drift to TD w dummv qun Perforate 40' of Ivishak 13,935' -13975' MD Please Note: Ad-Perfs interval 13,935' -13975' 500 E MD may need to be shortened if tag is high Well Objectives and LOQQinQ Notes: Please see attached detailed history. The 04/24/07 Production Log indicated minimal production coming from the lower perforation interval. Therefore, the proposed reperfs are an attempt to ensure the lower interval is adequately accessing the reservoir. Please note that the adperf interval is dependent on the tag depth. In the event that the drift is unable to access the entire proposed perforation interval, the proposed ad perf interval may have to be shortened. For questions or comments please call Bob Younger at 564-5392 (w), 677-2599 (h), or 830-4920 (cell). Attachment: Tie-in Log Reference Log Tie in Log GR-CCL ....·i5ï3ï¿o03..·.. .............................. Schlumber. .............................. Depths (from-to) .....F~!.~:??.:..... ....J:?!~.??.:..... Feet 40' SPF 6 Log: Date: ............................. Company: ............................. Depths (from-to) ............................. ,................................ ............................. -................................ ............................. ................................ ............................. .............................. .............................., ................................. ............................. .............................. ............................... '................................ ............................. .............................. .............................., Gas Jetting Expected? No At what Depth? ............................... Requested Gun Size:.?:.ê.??..:..t!.§p... Charge: Power Jet 2906, HMX Desired Penetration: 25.3" ............................................ Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to acNeve drawdown (check wI Pad Operator to see if necessary piping is installed) (e.g. N2 Lift. Hardline Lift Gas. Gas Lift. Flow Well. Backflow Through Drain or Hardline) Tie in to Jewelry @ Minimum ID: Tail Depth: MD Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ .............................. 3.725 in .............................. .......1.~...9..1.!........ ft MD Last Tag: .......1}!~!.!........ ft MD on 4/24/2007 ............................... Well: Date: Perforation Summary API #: 50-029-23122-00 NS19 -------...-------. .........................,.... .........................................................., General Comments: ##### #REF! tie-in log"iëïï,e on depth with the reference log. Orient. Random .......................... Phasing 60° 0 o o o o feet Zone AdlRe/lperf ...1.Y.i.~.~~.~..........................A.~f?.~rf........................ ......................................................................................, ....................................................................................... ....................................................................................... ....................................................................................... N/A 0.38" Entry Hole Diam: .Y.D.!!.~.y.~~.~.~.~......................................................................................................................................... ............................... .,....................................................................................................................................................................... :::::::::::+:E?:::x~::~)p.p.)~:::::::::::.............@....:::r~:;~9.~::·;Mï)...........·.......·................··..·............... 4.5 in 12.6# 13-CR Liner :::jI~:i:$.::::: MD is ..:?.!.9.9................ psi On-Site Prod Engr: pem .n.·...'...,...···..........··...........·····"........·..· .............n....'.........,."..,....... Phasing ............."..,........ 00 00 o .......................... ........"................ .......................... .......................... ....................'"................................."......".",.....................,..,.........".......................,............"...........................".,.........."",.........""."'...n."".,......······ Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Feet SPF Orient. .,..............................,.........."."........,........,.,...,...,.,...,......,.,..,.........,...........,...........,.............,..........................................,................,.......,..............................................,..........,............,.".',................, Zone Aperf/Reperf ..............,............... ..,.......,...,.,....".""... ,...........,.....",."...... .."",.".,.....,.",....",. ,......",....."..,.......,.. .""".....""............... .........,.................... .....,.............".,..."." ...........,....",...,....... .............................. .............................. .....................,......... .............................. .........,........,............ .n............................ .......................... .......................... .......................... .......................... ....................................................................................... ....................................................................................... ....................................................................................... ........................................,.............................................. ....................................................................................... TREE = ABB-VGI5-118· W!iiLHEAD '" ABB-VGI13-5I8· W- TBOWL. SKS NS19 SAFErYNOT8S:***4-112" CHROME TBG & LNR*** AC11.IA TOR = KB. aEV - 56.3' BE aEV - 4{).1' (æ 16.2') KOP- . 941' 4-112"TRM4ESSSV, 1)=3.812" Max Angle - @ Datum MJ - Datum TVD = 10500' SS 13-318· CSG, 68#, L-80 BTC, 1)-12.415· 3405' -µ II.. GAS LFT MAf\IJREl.S ST MJ TVD DEV TYÆ VLV LA TŒI rom DATE Minimum ID = 3,725" @ 13306' l 2 5067 4428 1 6469 5474 4-112" XN NIPPLE TOP OF.,.. LfIR 13328' ~\. 9-518· CSG, 47#, L-80 BTC-M, I) = 8.681· 11753' ~ I 13229' 4-1/2· FBER OPTIC TRANSDlJCER, I) 3.945· I I 113328' B.MH4-1/2· FBEROPTIC TRANSDlJCER,1)- 3.945· I I I 13249' 4-1/2· x NP, I) 3.813· I g I 13270' .,.. x 4-112" PKR, I) - ???? Ið I I 13294' 4-112" x NP, I) = 3.813· . I I 13306' 4-1I2"XNNP,I)=3.725· I TOP OF 4-112" LfIR 13328' I ~ .~ 4-1/2- TBG. 12.6#, 13CRVAM-ACE 13317' I I 1331T 4-112" WlEG, I) = 3.85· I .0152bpf, I) = 3.958· I H aMJ TT LOGGED 05/03103 I 13326' I"" LfIR, 26#, L-80 HYDRL 521, 13480' ~ II.. .0383 bpf, I) = 6.276- PERFORA TON StJl.NARY REF LOG: JEWI3..RY LOG / GR-CCl ON 05103103 ANGLE AT TOP PERF: ?? @ 13860' Note: Refer to A-oduction DB for historical perf data NTlAL PERF - ŒlARGE: 2906 FOWERJET, tNX., PENETRA TDN:: 2.,.., HOLE: 0.36·, PHASE: 60 DEG. ~ SIZE SPF MER\( AL (MJ) Opn/Sqz DATE 2-1/2 6 13860 - 13905 0 09/27105 2-7/8' 6 13860 - 13920 0 05105103 2-7/8' 6 13895 - 13920 0 05115106 ~ 2-7/8 6 13935-13975 0 05115106 ~ 14077' I 4-1/2" LIIR 12.6#, 13CRVAM-ACE 14080' .0152 bpf, 1)= 3.958" DATE REV BY <:otJM:NTS DATE REV BY <:otJM:NTS NORniSTAR 11/15102 FH INTlAl DRIll WaL: NS19 03131103 JAS ORIGINAL COMPLETION PERMT No: !r¿022070 05107/03 eE ADPERFS API No: 50-029-23122-00 09/27105 WRRITLH PERFS SEe TNRE 10/07/05 fTLH tEN FORMAT & TVD cx:>RRECT. 05115106 WRR/PJC PERFS / aMJ CORRECTK>N BP Exploration (Alaska) Date 05-24-2007 Transmittal Number:92891 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. a 0.2.- ;R07 N & -'t Cf ( Log Top SW Name Date Contractor Run Depth Bottom Depth Log Type NS13 03-31-2007 SCH MEMORY COIL FLAG PERFORATION RECORD NS13 04-16-2007 SCH WITH GAMMA RAY JEWELRY LOG GAMMA RAY NS16 04-30-2007 SCH COLLARS PERFORATION RECORD NS12 04-17 -2007 SCH WITH GAMMA RAY NS19 04-24-2007 SCH PRODUCTION PROFILE ! 0 \ - 0'6'=' \ OO-¡fY:¡' - 08-1/6 - Õ0 d -dot- Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petro technical Data Center RECEiVED 2 9 Z007 Attn: Cheryl Ploegstra Doug Chromanski Ignacio Herrera Kristin Dirks Christine Mahnken sCANNED MAY 3 1 2007 p,laska Oil & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 NS12 and NS19 Bob and Carolyn, We have received the 404 Report of Sundry Operations for the subject wells. The 403 authorization numbers listed on both reports is incorrect. For NS12, stimulation was authorized by sundry 306-418 issued 1/5/07. For NS19, stimulation was authorized by sundry 306-410 also issued 1/5/07. I will make the corrections on our copy and you may wish to do the same on yours. We would appreciate that the correct sundry authorization number is listed on the operations reports. It makes the recording tasks at the Commission flow more smoothly. Call or message with any questions. Tom Maunder, PE AOGCC &~ MAY 0 3 2007 1 of 1 5/2/20073:47 PM RECEIVED ~ . STATE OF ALASKA _ ..¡/.-:r¿J-t:)7 ALAS~ OIL AND GAS CONSERVATION COM~<1tfR 2 6 7007 REPORT OF SUNDRY WELL OPERATIONS -.... . -;. - ..... ~ n 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimu,o,c ~ Ol \.JO,} l.I'-t!1ther U Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 ~~rtiUlon 0 Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: ............,,~'" 5. Permit to Drill Number: Name: Development R Exploratory ~r" 202-2070 /' 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 " 7. KB Elevation (ft): 9. Well Name and Number: 56.3 KB I NS19. .-- 8. Property Designation: 10. Field/Pool(s): ADLO-312809 . NORTHSTAR Field/ NORTHSTAR OIL Pool . 11. Present Well Condition Summary: Total Depth measured 14063 ( feet Plugs (measured) None true vertical 11135.18 , feet Junk (measured) None Effective Depth measured 14058 . feet true vertical 11132.72 feet Casing Length Size MD TVD Burst Collapse Surface 3361 13-3/8" 68# L-80 44 - 3405 44 - 3201.89 4930 2270 Intermediate 11710 9-5/8" 47# L-80 43 - 11753 43 - 9467.45 6870 4760 Liner 1896 7" 26# L-80 11584 - 13480 9339.35 - 10823.22 7240 5410 Production 752 4-1/2" 12.6# 13Cr80 13328 - 14080 10704.48 - 11143.53 8430 7500 Perforation depth: Measured depth: 13860 - 13900 13900 - 13920 13905 - 13920 True Vertical depth: 11035.98 - 11055.37 11055.37 -11065.1 11057.8 - 11065.1 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 - 13317 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3662 19569 1154 0 764 Subsequent to operation: 4682 24966 1508 0 800 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development R Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil P Gas r WAG GINJ r WINJ r W DS PL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ìSUndry Number or N/A if C.O. Exempt: .~07~ Contact Carolyn Kirchner ~Co-\.\ lÙ~?Vl5(;> Printed Name Carolyn Kirchner Title Production Engineer Signature CL^,VZ/LL/~~k/l ¡l..----- Phone 564-4862 Date 4/25/2007 Form 10-404 Revised 04/2006 RBDMS BFL MAYO 51 2007 k5b Submit Original Only . . NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/3/2007 CTU #6***Continued from 4-2-07 WSR***MIRU. Perform 5000 psi BOP test per Sundry requirements. Bullhead kill tubing with 10 bbls of 60/40 meth, 290 bbls of 2% KCI and 25 bbls of 60/40 methanol. RIH. Pump 60 bbls 12% HCL with KCL overdisplacement across perf interval(13850' to 13985') *** Job Continued on 4-4-07 4/3/2007 Assist #6 w/Acid Treatment - Pumped down coil tbg w/10 bbls 90*F filtered 2% kcl spear, 61 bbls 70*F 12% HCL acid (See CTU WSR for acid data). 103 bbls 1 OO*F filtered 2% kcl. Pumping In Progress. *** Job Continued to next days WSR*** 4/4/2007 CTU #6*** Job Continued from overdisplacing acid. Re-install tree cap and pressure test to 5000psi. RDMO. Notify well tender and control room of status. JOB COMPLETE 4/4/2007 ***Continued from Previous Days Assist CTU #6 w/Acid Treatment - (Job In Progress) pumped 11 bbls 100*F filtered 2% kcl (Total of 114 bbls) & 46 bbls 90*F diesel *** Job Complete*** FLUIDS PUMPED BBLS 46 60/40 METH 290 KCL w/0.6% Safe Lube 95 KCL 430 TOTAL . . SARAH PALIN, GOVERNOR A...A.~&A OILAlQ) GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 306-410 SrANNED JAN 0 8 2007 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, //~ , /~) / . \.... . '1. ../ ..... ~. ..... . ( J, ¡ / ~/;/ /: \ " ¿/y ...... / .' . d) yr o ,p(, ;..//11,;//// \"'~ )/ Y / Dan {' Seamount Commissioner 'j . )¡ DATED th~ day of January, 2007 Enc!. ~Dd-d61 . STATE OF ALASKA <If- k 3...ø.1 øfqj, ~13 ALA OIL AND GAS CONSERVATION COMMI 1;.~qlKl C~/I/~ APPLICATION FOR SUNDRY APPROVAL ~I \.l7Dtc cD 20 AAC 25.280 "'/8slr.. .2 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver G. 8S C. Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension D.4/1Ch O/1S. C. Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 0'80e o,.,,/1¡/ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ø >- Exploratory 0 202-2070 3. Address: P.O. Box 196612 0 SelVl'ce 0 6. API Number: Stratigraphic Anchorage, AK 99519-6612 7. KB Elevation (It): 50-029-23122-00-00 9. Well Name and Number: 56.3 KB NS19 8. Property Designation: 10. Field/Pools(s): ADL-312809 Northstar Field / Northstar Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (It): Total Depth TVD (It): Effective Depth MD (It): Effective Depth TVD (It): Plugs (measured): Junk (measured): 14080 11143.53 14077 11142.06 None None Casing Length Size TVD Burst Collapse Surface 3361 13-3/8" 68# L-80 44 3405 44 3202 4930 2270 Production 11710 9-5/8" 47# L-80 43 11753 43 9467 6870 4760 Liner 1896 7" 26# L -80 11584 13480 9339.35 10823 7240 5410 Liner 752 4-1/2" 12.6# 13Cr80 13328 14080 10704.48 11144 8430 7500 Perforation Depth MD (It): 13860 - 13920 13935 - 13975 Perforation Depth TVD (It): 11035.98 - 11065.1 11072.4 - 11091.95 Tubing Size: 4-1/2" 12.6# Tubing Grade: 13Cr80 Tubing MD (It): 41 - 13317 Packers and SSSV Type: 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 12. Attachments: DescriDtive Summaryof Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Packers and SSSV MD (It): 941 11584 13270 13328 13. Well Class alter proposed work: Exploratory 0 Developm ent ø Service 0 Date: 15. Well Status alter proposed work: Oil ø Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Prepared by Gary Preble 564-4944 Contact Robert Younger Abandoned 0 Commencing Operations: 16. Verbal Approval: Commission Representative: 1/5/2007 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Phone 564-5392 COMMISSION USE ONLY Production Engineer Date 12/22/2006 Signature Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: 8000 ,,~\ <:.\V ~\7 ~,-=;À-' Approved COMMISSIONER Form 10-403 Revised 7/20°sf'1 R SUbmit in Duplicate N'o portion of the belo.rk should be performed w/out fir~aking time to ensure No Accidents, harm to People, and No damag~he Environment To: Jerry Bixby/Clark Olsen - Well Operations Supervisor December 15, 2006 From: Robert Younger/Carolyn Kirchner - Northstar Production Engineer Subject: NS19 CTU Acid Treatment AFE NSFLDWL 19 Est. Cost: $100 M Est. lOR: 1200 BOPD Please perform an acid stimulation on NS19 per the below procedure including a coil tubing acid/scale inhibition treatment: Type lOR PR N DSWL AFE Job Description S 1200 NS19 NSFLDWL 19 Drift to TD F 1200 NS19 NSFLDWL 19 Pump Acid for Liner Pickle Contingent on Drift Results CT 1200 NS19 NSFLDWL 19 Pump Acid Treatment & Scale Inhibition Treatment (SIT) Current Status: Producer Last Test: 12/01/06: BOPD: 4,004, BWPD: 1,213; MMCFPD: 21.04 Max Inclination: 620 at 13,808' md; 610 at Perfs Max Dog Leg: 4.6 deg/100' at 2,154' md Perforations: 13,860' -13,975' md Minimum 10: 3.725" @ 13,306' md, 4.5" XN Nipple Last TO tag: 05/15/06: Tagged TO 13,977 ELM Last Downhole Op: 05/16/06: Perforated from 13,935'-13,975' and 13,895'-13,920' md w/2 7/8" PJ2906 HMX gun, 6 SPF. Latest H2S value: None anticipated BHP: 5,086 psi @ 11,100 ft ss, 5/17/05 NS19 experienced a severe decline in 2004. Two consecutive Acid/Scale Inhibition treatments were performed in 2005 in an attempt to mitigate the extreme decline. The second Acid/SI treatment performed on 5/1/2005 increased the rate by 2,000 BOPD, but the increase lasted less than a month. Due to the short lived results of the Acid/SI treatments, re-perforating the top 45' of perforations using Schlumberger's PURE technique was recommended. Only the upper 45' of the original 60' section were re- perforated due to water concerns. As outlined in the tag history, severe scaling required multiple drift/broach runs to ensure the perforation guns would be able to reach the targeted perforation interval. While the September 2005 re-perforations did increase NS19's production, the severe scaling encountered in the drift runs indicated the bullhead Acid/SI treatments are inadequate. Therefore, a coil tubing conveyed acid job was proposed in order to insure efficient delivery of the acid to all perforations. The CTU acid job was completed 03/28/06 resulting in no change in the well's performance and no increase in produced water. Due to the poor results of the March Coil Acid Job and based on favorable results from re-perforating NS19 in September 2005, reperfs were proposed. No portion of the belo.ork should be performed w/out firJl.taking time to ensure No Accidents, 0 harm to People, and No damag~he Environment In addition to the reperfs, adperfs were recommended to access additional reservoir below the current perforation interval in an attempt to increase oil rate. The initial perforation interval was 92' above the oil water contact and the adperfs were 65' above the oil water contact. Despite the current 92' of standoff from the oil water contact, NS 19 produced -500 bbls of water. Post adperfs 5/16/06 the well produced around 1500 bwpd (same water cut as pre-ad perfs). In the event the Adperfs result in excessive water production an IBP will be set in the 15' gap that exists between the current and proposed adperf interval. The proposed acid treatment is an attempt to remoe any scale that may have formed in NS 19 since its last treatment. Procedure Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. Prep Work: 1. Pull SSSV. Drift to TO. 2. Mobilize coil unit, pumps, tanks and acid transport to Northstar. DRIFT WITH SLlCKLlNE: 3. RU slickline. 4. RIH with slickline to TO. Note if scale is encountered. FULLBORE LINER PICKLE CONTINGENT ON DRIFT RESULTS: **If scale is encountered during the slickline drift, please pickle liner** 5. Order out volume of seawater, acid, L66 and diesel for both the pickle and acid/SIT treatment. See attached volumes table. 6. RU pumping equipment. 7. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. 8. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 9. PT Dowell surface lines to 5000 psi. , No portion of the belo.ork should be perfOrmed, w/out fi~aking time to ensure No Accident 0 harm to People, and No damag.the Environment 10. Pump the following fluids to wash the production liner at 3 bpm, 3500 psi max pressure. a) 15 Bbls DAD acid per below recipe b) 146 Bbls seawater c) 49 Bbls diesel 90:10 DAD Acid (12% HCL) to contain: 0.6% A261 Corrosion Inhibitor 4 ppt A 179 Corrosion Inhibitor 8 ppt A 153 Corrosion Inhibitor 0.5% W54 Non-Emulsifier 0.2% F103 Surfactant 20 ppt L58 Iron Control 0.5% W60 Anti-sludge Flowback Procedure: 11 . Produce liner wash fluid to test separator and well clean up tank. The volume of flowback is 210 Bbls. 12. RD slickline. COIL TUBING ACID TREATMENT: 13.MIRU. 14. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. 15. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 16. PT Dowell surface lines to 5000 psi. 17. Bullhead kill with filtered 2% KC!. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. 18. RIH with jetted nozzle (min ID = 3.725"). Drift to below perforations to insure no obstructions exist. 19. Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 60 bbls Acid b) 112 bbls 2% filtered KCI (Overflush for 5' radial displacement) c) 49 bbls Diesel (for displacement and under-balance) Please do not POOH until the total over-flush volume has been pumped in order to reduce the chance of stirring-up solids that could plug the perforations. , , Ño portion of the belo.ork should be peñormed w/out fir~aking time to ensure No Accidents, 0 harm to People, and No damag~he Environment 12% Acid to contain: 0.5% A261 Corrosion Inhibitor 4 ppt A 179 Corrosion Inhibitor 8 ppt A 153 Corrosion Inhibitor 0.5% W060 Anti-Sludge 0.5% W54 Non-Emulsifier 0.2% F103 Surfactant 20 ppt L58 Iron Control Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. 20. RD Schlumberger. Flowback Procedure: 21. After the 4 hour shut-in, line-up the well to flow into the test separator and well cleanup tank for flowback. Produce clean-up volume of 221 bbls. After clean- up, divert back to the plant and get 2 6-hour tests. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures) to Robert.Y ounger@ bp.com. Procedure Contacts: Robert Younger WK: 564-5392 HM: 677-2599 Cell: 830-4920 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION . !1fc 7!v-¡/OG RECEIVED SEP 1 4 2006 , REPORT OF SUNDRY WELL OPERA 1'aºn~ Gas Cons. Commission 1. Operations Performed: Stimulate ŒJ AnchorðU.'rD Abandon 0 Repair Well 0 PluQ PerforationsD Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate IKI Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD 202-2070 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-23122-00-00 7. KB Elevation eft): 9. Well Name and Number: 56.30 NS19 8. Property Designation: 10. Field/Pool{s): ADL-312809 Northstar Filed 1 Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 14063 feet true vertical 11135.2 feet Plugs (measured) None Effective Depth measured 14058 feet Junk (measured) None true vertical 11132.7 feet Casing Length Size MD TVD Burst Collapse SURFACE 3361 13-3/8" 68# L-80 44 - 3405 44.0 - 3201.9 4930 2270 PRODUCTION 11710 9-5/8" 47# L-80 43 - 11753 43.0 - 9467.5 6870 4760 LINER 1864 7" 26# L-80 11616 - 13480 9363.1 - 10823.2 7240 5410 LINER 735 4-1/2" 12.6# 13Cr80 13328 - 14063 10704.5 - 11135.2 8430 7500 Perforation depth: :~(;ANNED! SEP 2 0 2001 Measured depth: 13860-13900,13900-13920,13935-13975 True vertical depth: 11036-11055,11055-11065,11072-11092 TubinQ ( size, Qrade, and measured depth): 4-1/2" 12.6# 13CrSO @ 41 - 13319 Packers & SSSV (type & measured depth): 7" Top Packer @ 11584 4-1/2" Baker SAB Perm PKR @ 13270 4-1/2" Top Packer @ 13309 4-1/2" TRM-4E SSV @ 940 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: 4,632 10,550 595 --- 742 Subsequent to operation: 6,548 19,914 1,337 .-- 761 14. Attachments: 15. Well Class after proposed work: Exploratory(] DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ! OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr 306-154/306-235 Printed Name DeWayne R. Schnorr ^ Title Petroleum Engineer Signature L1f..d A?'_ ~ /I Phone 564-5174 Date 9/13/06 f/ Form 10-404 Revised 4/2004 0 RIG I N Þ., RBDMS 8Fl SEP 1 8 2006 . . NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/30/2006 Acid treatment/Scale inhibition. Pumped 15bbls DAD acid, 127bbls seawater, 68bbls diesel for pickle. Wait 1 hour, flow back 21 Obbls to clean-up tank. Pumped 60bbls Acid wI L66, 135bbls 2%KCL wI L66, 112bbls 2%KCL, 143bbls seawater, 68bbls diesel, for AcidlSIT treatment. 4 hour shut in. Bring well on. FWHP's = 600/vac/151 07129/2006 Heat Seawater for Scale Inhibition treatment. 05/16/2006 PERFORATE WITH 2 718" PJ2906 HMX, 6 SPF. EHD=0.38" - TTP=27.7" TIE INTO JEWELRY LOG OF 3-MAY-03. PERFORATE FROM 13935 -13955' ELMD. PERFORATE FROM 13895 -13920' ELMD. RD. WHP=2800 PSI. POP WELL. HAVE WELL PUT INTO TEST. LEAVE ISLAND. *****JOB COMPLETE***** 05/15/2006 PERFORATE WITH 2.875" HSD, POWER JET 2906 HMX, 6 SPF, 60 DEG PHASING, 27.7" TTP, 0.38" EHD. CORRELATE TO JEWELRY LOGI GR-CCL DATED 3-MAY-2006. SHOT 13955'·13975'. TAGGED TD @ 13977' ELMD. WHP=2800 PSI. 05/14/2006 WELL FLOWING UPON ARRIVAL DRIFT WITH 2 718" x 10' DUMMY GUN FOR UPCOMING PERF JOB. SAT DOWN @ 4100' SLM. PUMP NEAT METHANOL WITH SMALL TRI-PLEX . TAG TD AT 13930' SLM. SLIGHTLY STICKY COMING OFF BOTTOM. PICK UP WEIGHT OFF BOTTOM 950#. RD.POP WELL. LEAVE ISLAND. PROPOSED BOTTOM PERF 13975' ELMD. FLUIDS PUMPED BBLS PT Surface Equipment 5 Methanol 10 Diesel 336 Crude 351 TOTAL Page 1 , ~NOTES: ***4-1/2" CHROME TBG & LNR*** TREE = ABB-VGIS-1/8" 5KS WELLHEAD = ABB-VGI13-5/8" MUL TIBOWL 5KSI NS19 ACTUATOR = KB. ELEV = S6.3' BF. ELEV = 40.1' (CB 16.2') 1-14-1/2" TRM-4E SSSV, ID = 3.812" I KOP= . 941' Max Angle = @ Datum MD = Datum ND = 1 OSOO' SS 113-3/8" CSG, 68#, L-80 BTC, ID= 12.415" 1 3405' 1--4 .. GAS LIFT MANDRELS ST MD ND DEV TYÆ VLV LATCH PORT DATE l 2 S067 4428 Minimum ID = 3.725" @ 13306' 1 6469 5474 4-1/2" XN NIPPLE I TOP OF 7" LNR I 13328' ö 8 19-s/8" CSG, 47#, L-80 BTG-M, ID - 8.681" I 11753' ~ .. I 13229' -14-1/2" FIBER OPTIC TRANSDUCER, ID = 3.94S" I 113328' ELM H 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.94S" I I I 13249' -14-1/2" x NIP, ID = 3.813"1 ~ 2S I 13270' H 7" x 4-1/2" PKR, ID = ???? I I I I 13294' H4-1/2" x NIP, ID = 3.813" I I TOP OF 4-1/2" LNR I I .~ 13306' -14-1/2" XN NIP, ID = 3.725" I 13328' I P1 ...... 4-1/2" TBG, 12.6#, 13CR VAM-ACE, 13317' I , 13317' -14-1/2" WLEG, ID = 3.8S" , .01S2bpf, ID = 3.9S8" I H ELMD TT LOGGED 05/03/03 I 13326' 17" LNR, 26#, L-80 HYDRIL 521, 13480' 1---.4 III. .0383 bpf, ID = 6.276" PERFORA TION SUMMA RY REF LOG: JEWELRY LOG / GR-CCL ON OS/03/03 ANGLE AT TOP PERF: ??@ 13860' Note: Refer to Production DB tor historical perf data INITIAL PERF - CHARGE 2906 POWERJET, HMX, PENETRA TION: 27", HOLE 0.36", PHASE 60 DEG. ] SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-1/2" 6 13860 - 1390S 0 09/27/0S 2-7/8" 6 13860 - 13920 0 OS/OS/03 2-7/8" 6 1389S - 13920 0 OS/15/06 2-7/8" 6 13935 - 13975 0 05/15/06 ] IPBmH 14077' I 4-112" LNR, 12.6#,13CRVAM-ACE, 14080' I .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 11/15/02 FH INITIAL DRILL WELL: NS19 03/31/03 JAS ORIGINAL COMPLETION PERMIT No: '2022070 05/07/03 EIVIF ADPERFS API No: SO-029-23122-00 09/27/05 WRRlTLH PERFS SEC T N R E 10/07/0S /TLH NEW FORMA T & ND CORRECT. 05/15/06 WRRlPJC PERFS / ELMD CORRECTION BP Exploration (Alaska) I 1iP¿ 1/J~/ð~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM+N REPORT OF SUNDRY WELL OPERATIONS o o o ~ ~..< -:;.. 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ,p Stratigraphie P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 56.3 KB 8. Property Designation: ADLO-312809 11. Present Well Condition Summary: Total Depth measured 14063 feet true vertical 11135.18 feet Effective Depth measured 14058 feet true vertical 11132.72 feet Casing Length Size MD Surface 3361 13-3/8" 68# L-80 44 - 3405 Intermediate 11710 9-5/8" 47# L-80 43 - 11753 Liner 1896 7" 26# L -80 11584 13480 Production 752 4-1/2" 12.6# 13Cr80 13328 - 14080 Perforation depth: Measured depth: 13860 - 13900 13900 - 13920 True Vertical depth: 11035.98 - 11055.37 11055.37 - 11065.1 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVED SEP 1 3 2006 Stimulate [2] Waiver 0 Time Extension DAncnorage Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2070 Exploratory Service 6. API Number: 50-029-23122-00-00 9. Well Name and Number: NS19 10. Field/Pool(s): NORTHSTAR Field/ NORTHSTAR OIL Pool Plugs (measured) None Junk (measured) None TVD 44 - 3201.89 43 - 9467.45 9339.35 - 10823.22 10704.48 - 11143.53 Burst 4930 6870 7240 8430 Collapse 2270 4760 5410 7500 13905 - 13920 11057.8 - 11065.1 13Cr80 41 - 13317 941 11584 13270 13328 « (ì I)f'.nt:; SCANNED SEP 1 J ¡:.uuw Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 7223 493 0 11180 582 0 15. Well Class after oroposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 3208 4805 x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Tubing pressure 747 747 Service WINJ WDSPL Title Data Mgmt Engr Signature Phone 564-4944 Form 10-404 Revi ed 04/2004 0 RIG ¡ N A J Date 8/31/2006 Submit Original Only . . NS19 DESCRIPTION OF WORK COMPLETED NWRO OPERATIONS EVENT SUMMARY 5/6/2006 Pre-Perf tubing acid wash. Spot hot oil unit and 600 bbl up right tank. Heat 128 bbls seawater for upcoming acid job. ***** Job In Progress***** 5/7/2006 T/I/O= 2800/31/166 Attend Island safety meeting. ATP. Perform Tubing - Liner acid wash, Pre-Perforating. Pumped 16bbls 12% DAD acid, displace with 126bbls warm seawater, 68bbls warm diesel down tubing. 1 hour soak. Flowed back 210bbls to clean up tank. FWHP's = 1000/vac/143 ***** Acid Job Complete***** FLUIDS PUMPED BBLS 16 12% DAD ACID 126 SEAWATER 142 TOTAL . . Date: 08-22-2006 Transmittal N umber:92819 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~f1'kÂ~ì SW Name Date Contractor Loq Run Tap Depth Bottom Depth Log Type NS08 03-28-2006 SCH PERF RECORD NS08 06-01-2006 SCH PERF RECORD NS14A 01-20-2006 SCH DEPTH CONTROL NS16 05-05-2006 SCH PRODUCTION PROFILE PERF RECORD WITH NS31 06-05-2005 SCH GAMMA RAY NS30 04-15-2006 SCH JEWELRY LOG NS30 04-02-2006 SCH JEWELRY LOG PERF RECORD WITH NS30 04-14-2006 SCH GAMMA RAY NS19 05-15-2006 SCH PERF RECORD oJL} Plea e ign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center ð: ,+.; Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Ignacio Herrera Doug Chromanski SCANNED AUG 3 1 2005 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box [96612 Anchorage. AK 99519-6612 i'fù ~l' .. ¡~ 9 Œ· .j~\,.\_ .. i../..Üi. ~,I . .... 1111 ~:! ¡n, '. L '& L uu . e ilill1ì)n, .¡~ .'Ã' U. ." ".' ..... '.Þ. ../.,11,.\' ~ ~ ¡ û ~ . 'u """, ;, U U e 17! 1'.,' 'iJ\ frÜ FRANK H. MURKOWSKI, GOVERNOR AI~SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Robert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 306-235 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 1/ day of July, 2006 Encl. gDd -;}O1- ·fIIiIo> e /.p¿ 7J)b/Ó~1f 1\ tjQl, RECEIVED JUL 0 6 2006 ~t& ..,.~. BP Exploration (Alaska) Inc. ,~... 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp June 28, 2006 Alaska Oil & Gas Cons. Commission Anchorage Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS19 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS19 well. The formation of CaC03 scale is suspected as a contributing factor to the well's steep decline following the May 2006 adperfs. The procedure includes the following major steps: · Pickle tubing · Bullhead HCL based acid treatment including scale inhibitor · Flowback Sincerely, ~~ Robert Younger Production Engineer BPXA, ACT, Northstar f J/ (',(11,,11 ",D " STATE OF ALASKA a A. OIL AND GAS CONSERVATION COMM~N APPLICATION FOR SUNDRY APPROVAL \út)~ \.f'fil¥ W'~ JUL 0 6 2006 Alaska Oil & Gas Cons. Coovnission 20 AAC 25.280 . . 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waiver U "'Other U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension D Change approved program 0 Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development e pcploratory D 202-2070 ---- 3. Address: P.O. Box 196612 Stratigraphic 0/ Sel'llice D 6. API Number: / Anchorage, AK 99519-6612 50-029-23122-??-oo 7. KB Elevation (ft): 9. Well Name and Number: 56.3 KB NS19 /' 8. Property Designation: 10. FieldlPools(s): ADL·312809 Northstar Field 1 Northstar Oil Pool 11. PRESENT WELL CONDmON SUMMARY Total Depth MD (ft): rotal Depth TVD (ft): Effective Depth MD (ft): ¡Effective Depth TVD (ft): rlUgS (measured): runk (measured): 14080 11143.53 14077 11142.06 None None Casing Length Size MD TVD Burst Collapse Surface 3361 13-318" 68# L-80 44 3405 44 3202 4930 2270 Production 11710 9-518" 47# L·80 43 11753 43 9467 6870 4760 Liner 1896 7" 26# L-80 11584 13480 9339.35 10823 7240 5410 Liner 752 4·1/2" 12.6# 13CrBO 13328 14080 10704.48 11144 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13860 . 13920 11035.98 - 11065.1 4·1/2" 12.6# 13CrBO 41 - 13317 13935·13975 11072.4 -11091.95 . - Packers and SSSV Type: 4·1/2" TRM-4E SSV Packers and SSSV MD (ft): 941 7" Liner Top Packer 11584 7" 13CrBO Packer 13270 4-1/2" Liner Top Packer 13328 12. Attachments: DescriDtive Summary of Proposal e 13. Well Class after proposed work: / Detailed Operations Program D BOP Sketch D E>cploratory D Development iI Service D 14. Estimated Date for ¡::~~ 15. Well Status after proposed work: Commencing Operations: Oil iI Gas D Plugged 0 Abandoned D 16. Verbal Approval: V Date: WÞGD GINJ D WINJD WDSPL D Commission Representative: Prepared by Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Contact Robert Younger Printed Name Ro~ert Younger Title Production Engineer Signature ~ ~ Phone 564-5392 Date 6/28/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: 3 i) 'lo ... ól35 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RBDMS 8Ft JUt 122006 \0 aYfl Subsequent Form Required: APPROVED BY ~/t>6 Approved by: '~rø COMMISSIONER THE COMMISSION Date: V I'G1NAL , , Form 10-403 Revised 7/2005 Submit in Duplicate OR e e r? p .!F. ~ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 d., 0):" d.Þ 7 Re: Northstar Field, Northstar Oil Pool, NS19 Sundry Number: 306-163st~.~!\jNc:r!\~ E\V 0. " 2nnQ .:;;;:J'\;: J "\.. ,-; ~~;r.J t\~~ ~ (,I,.) if '~''''' j Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this Gday of May, 2006 Encl. bp e p,e:.. J/5/oG 7·/ö1o" -t··... -è~~~. ~.tr ø"f.... BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 5, 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS19 to acid wash the liner BP Exploration Alaska, Inc. proposes to spot acid across NS19's liner in an attempt to mitigate what is believed to be scale that is inhibiting access to re- /' perforation and add perforation intervals. The procedure includes the following major steps: Work Descri tion o erations Pum Acid for Liner Wash ~ Comments Please let me know if there are any questions, comments, or concerns. Robert You ger Production Engineer 907 -564-5392 work 907 -830-4920 cell BPXA, ACT, Northstar 1. Type of Request: Abandon U Suspend 0 Operational shutdown U Perforate U Waiver U Anc_iU Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Dellelopment iii /xploratory [J 202-2070 ,,/ 3. Address: P.O. Box 196612 Stratigraphic [J Service [J 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 ,/ 7. KB Elevation (ft): 9. Well Name and Number: 56.3 KB NS19 / 8. Property Designation: 10. FieldlPools(s): ADL-312809 Northstar Field / Northstar Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): rotal Depth TVD (ft): IEffective Depth MD (ft): Effective Depth TVD (ft): rlUgS (measured): runk (measured): 14080 11143.53 14077 11142.06 None None ./ Casing Length Size MD / TVD Burst COllapse Surface 3361 13-318" 68# L-80 44 3405 44 3202 4930 2270 Production 11710 9-518" 47# L-80 43 11753 43 9467 6870 4760 Liner 1896 7" 26# L-80 11584 13480 9339.35 10823 7240 5410 Liner 752 4-1/2" 12.6# 13Cr80 13328 14080 10704.48 11144 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13860: 13920 / 11035.98 - 11065.1 4-1/2" 12.6# 13CrBO 41 - 13317 - - - Packers and SSSV Type: 4-1/2' TRM-4E SSV Packers and SSSV MD (ft): 941 7" Liner Top Packer 11584 7" 13Cr80 Packer 13270 / 4-1/2" Liner Top Packer 13328 12. Attachments: DescriDtille Summary of Proposal iii 13. Well Class after proposed work: Detailed Operations Program [J BOP Sketch 0 Exploratory [J Dellelopment iii Service [J 14. Estimated Date for ~1006 15. Well Status after proposed wo~: Commencing Operations: Oil iii Gas [J / Plugged 0 Abandoned [J 16. Verbal Approval: Date: WAG [J GlNJ [J WINJ [J WDSPL [J Commission Representative: Prepared by Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Ro~rt Younger Title Production Engineer Signature (V¡ _____ Phone 564-5392 Date 4/27/2006 (J COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: ",--?£j 0 - I (Q, ~ Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RBDMS 8Ft MAY (I g 2006 Subsequent Form Required: ûJfi APPROVED BY Date: 5-5"',.06 Approved by: t.J. ~ COMMISSIONER THE COMMISSION , I ,,"" 10-403 R.-o7f'Q05 V' 0 ~ I f\fA L Submit in Duplicate A' WGA- ~ / ~Ð4fc, STATE OF ALASKA ~(" I "v,'!" &"'N ALAeOIL AND GAS CONSERVATION COMMIS_ 'Y"S/" I) APPLICATION FOR SUNDRY APPROVAL ~~" 20 AAC 25.280 ft,t¡"K~, -- TREE ;: ABB-VGI5-1/S" 5K ~1I<mS'-4-112. atROMETBG& ........ I WElU-EAD - ABB-VGI13-5I8" MJ..TBOWL 5K NS19 ACTUATOR - KB. ElEV - 56.3' BF. ElEV ;: 40.1'(æ 16.2') 4-112"TRM-4ESSSV, D-3.S12" I KOP= . 941' Max Angle ;: @ Datum MD - Datum TVD = 10500' SS 113-318" CSG, 68#, L-80 BTe, D= 12.415" 3405' µ ~ GAS LFT MA~S ST MD TVD DEV TYÆ VLV LATCH PORT DATE U 2 5067 4428 Minimum ID = 3.725" @ 13306' 1 6469 5474 4-112" XN NIPPLE ¡,J4k' r IIS-tf I TOP OF 7" LNR .s.as28'- I ~ 19-5/8" CSG, 47#, L-80 BTG-M. D;: 8.681" 11753' 1----011 13229' 4-112" FBER OPTIC TRANSDUCER, D 3.945" I 113328' ELM H4-112" FBEROPTICTRANSDUCER, D-3_945" I · I 13249' 4-112" x NP, D - 3.S13"1 8 ~ 13270' 7" x 4-112" A<R. D - nn I · I 13294' 4-112" x NP, D= 3.813" I · . 13306' 4-112" XN NP, D - 3..725" I I TOP OF 4-112" LNR 13328' ~ ~ 14-1/2" TBG, 1~.6#, 1~RVAM-ACE 13317' I . 13317' 4-1/2" WLEG, D - 3.85" I _0152bpf, D - 3_958 I HELMD TT NOT LOGGED? I 17" LNR, 26#, ~-80 HY"DRL 521, 13480' ~ .. .0383 bpf, D - 6.276 PERFORA TION SUÞJMARY REF LOG: JEWElRY LOG 1 GR-CCL ON 05103103 ANGLE AT TOP PERF: ?? @ 13860' Note: Refer to A"oduction DB for historical perf data IIIITlAL PERF - a-lARGE: 2906 POWERJET, ~ ÆNETRA TION: 27", HOlE: 0.36", F+tASE: 60 DEG. ~ SIZE SPF Mm\fAL (MD) OpnlSqz DATE 2-112 6 13860 - 13905 0 09127105 2-7/8 6 13860 - 13920 0 05105103 II ~ 14077' 14-112" LNR, 1:_6#, 1~CRVAM-ACE, 14080' .0152bpf, D-3.958 DATE REV BY COÞJMNTS DATE REV BY COÞJMNTS NORTHSTAR 11/15102 FH INTIAL DRILL WB...L: NS19 03131/03 JAS ORIGINAL COMPLETION PERMT No: !J¿022070 05/07/03 EMF ADPERFS AF1 No: 50-029-23122-00 09127/05 WRRfTLH PERFS see TNRE 10/07/05 ITLH t>Ø2N FORMAT & TVD CORRECT. BP Exploration (Alaska) 'JfIJ dilO& rÞ/C.. ,.2) O~ STATE OF ALASKA 1'4 ALAe OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS o o o "~2- S}Mh P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development M Stratigraphic D Stimulate 0 r,r 9me~ Waiver 0 Tirti~ ExtehSio~ Re-enter Suspended 5. Permit to Drill Number: 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: 202-2070 6. API Number: 50-029-23122-00-00 9. Well Name and Number: Exploratory Service 56.3 KB NS19 ADLO-312809 11. Present Well Condition Summary: 10. Field/Pool(s): NORTHSTAR Field/ NORTHSTAR OIL Pool 8. Property Designation: Total Depth measured 14063 true vertical 11135.18 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 14058 true vertical 11132.72 feet feet Surface Intermediate Liner Production Length Size MD TVD Burst Collapse 3361 13-3/8" 68# L-80 44 - 3405 44 - 3201.89 4930 2270 11710 9-5/8" 47# L-80 43 - 11753 43 - 9467.45 6870 4760 1896 7" 26# L-80 11584 - 13480 9339.35 - 10823.22 7240 5410 752 4-1/2" 12.6# 13Cr80 13328 - 14080 10704.48 - 11143.53 8430 7500 Casing Perforation depth: Measured depth: 13860 - 13905 True Vertical depth: 11035.98 - 11057.8 13860 - 13920 11035.98 - 11065.1 n (;'1 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 - 13317 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 941 11584 13270 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft {I .1t 7006 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 7455 546 0 7015 569 0 15. Well Class after proposed work: Exploratory Development fii'1 16. Well Status after proposed work: Oil fii'1 Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 3375 3136 Tubing pressure 745 775 13. Service x Contact Sharmaine Vestal WDSPL D Sundry Number or N/A if C.O. Exempt: 306-060 Signatu~~ I I / 'a;;t;ß Title Data Mgmt Engr Printed Name Sharmaine Vestal Phone 564-4424 Date 4/26/2006 Form 10-404 Revised 04/2004 Submit Original Only ... , .. e e NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMMARY 3/26/2006 CTU #5, Acid Stim; Standby for SL to finish work on NS-28. SL finished; waiting for VECO to finish rig up and fluids to arrive. ... Job in Progress - Can't on WSR 03/27/2006... 3/27/2006 CTU #5, Acid Stim; ... Cant' from WSR 03/26/06... MIRU CTU #5. Wait on fluids. Alternator failed on deck engine. Jumper to pickup to maintain hydraulics. Start well kill. C-pump failed. Discontinue well kill. SLB mechanic on location. Decide to use Dowell pumpers for well kill. Kill well with 285 bbls of filtered 2% KCL. RIH while pumping 0.5 bpm. ... Job in Progress - Cant' on WSR 03/28/06... 3/28/2006 CTU #5, Acid Stim; ... Cant' from WSR 03/27/06... Continue RIH down to 13950' ctmd (did not tag TD). Established initial injectivity of 1.4 bbls at 2200 psi. Jet 50 bbls of 12% HCL with 10% L66 scale inhibitor across perfs (perf interval is 11860-13920). Jet 16 bbls of 2% KCL with 10% L66. Flush acid and inhibitor with 67 bbls of filtered 2% KCL. Saw immeadiate drop in WHP as acid went in to the formation. Injectivity increased to 1.6 bpm at 1500 psi. Saw a slight 200 psi increase in WHP as 2% KCL with 10% L66 went into the formation. POOH while pumping 70 bbls of diesel down the backside. Control room notified to keep well shut in for 4 hours. *** Job Complete *** (see fluid summary for acid properties) FLUIDS PUMPED BBLS 51 12% HCL 16 2% KCL w/1 0% L66 scale inhib 50 60/40 meth 67 Filtered 2% KCL 70 Diesel 254 TOTAL e e ,. 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA. OIL AND GAS CONSERVATION COMMISSION Ro bert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 (,) ~s.; Re: Northstar Field, Northstar Oil Pool, NS 19 Sundry Number: 306-154 Óv0d.-"' ~Ol Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thiSz! day of April, 2006 Encl. bp e e .A~ ~ -,. .I"~ , BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 28, 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS19 to re-perforate and add perforations (Ivishak) BP Exploration Alaska, Inc. proposes to re-perforate and add perforations in .--' well NS19. Based on favorable results from re-perforating NS19 in September 2005, the below re-perforation interval is proposed. The proposed adperf interval is recommended to access additional reservoir below the current perforation interval in an attept to increase oil rate. Please note that the add perf interval is dependent on the slickline tag depth. In the event that the drift is unable to access the entire proposed perforatioin interval, the proposed add perforation interval may have to be shortened. ~ The procedure includes the following major steps: Comments ,/ Please note perforation interval 13,935'- Electric Re-Perforate 25' of Ivishak 13,895' - 13,920' MD 13975' is dependent on the slickline tag and Line Perforate 40' of Ivishak 13,935' - 13975' MD./ a have to be shortened. Please let me know if there are any questions, comments, or concerns. Sincerely, g~ , Robe Younger Production Engineer BPXA, ACT, Northstar ~ I) ~ 4-~. .,/ / O(J}- 1'..-$1)6 I b STATE OF ALASKA A~ OIL AND GAS CONSERVATION COM.ON APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 wGA- 4I1...J{2.00(p 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate l.:j . "" '..5 ;;:~ t'E,'; 9t~~r,~ <." Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension [: f?'U Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well L 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ø Exploratory 0 202-2070 ' 3. Address: P.O. Box 196612 Stratigraphic 0 Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-23122-00-00 /' 7. KB Elevation (ft): 9. Well Name and Number: 56.3 KB NS19 , .,/ 8. Property Designation: 10. Field/Pools(s): ./ .. ADL-312809 Northstar Field 1 Northstar Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): I Plugs (measured): IJUnk (measured): 14080 11143.53 14077 11142.06 None None Casing Length Size MD ./ TVD Burst Collapse Surface 3361 13-3/8" 68# L -80 44 3405 44 3202 4930 2270 Production 11710 9-518" 47# L-80 43 11753 43 9467 6870 4760 Liner 1896 T' 26# L-80 11584 13480 9339.35 10823 7240 5410 Liner 752 4-1/2" 12.6# 13Cr80 13328 14080 10704.48 11144 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13860 - 13920 / 11035.98 -11065.1 4-1/2" 12.6# 13Cr80 41 - 13317 - - - - Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 941 7" Liner Top Packer 11584 / 7" 13Cr80 Packer 13270 4-1/2" Liner Top Packer 13328 12. Attachments: Descriptive SummaryofProposal ø 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development ø Service 0 14. Estimated Date for ~~6 15. Well Status after proposed work: Commencing Operations: Oil ø J Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: .::,,¿ Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Prepared by Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Robert Younger Title Production Engineer Signature £tr';r Phone 564-5392 Date 4/27/2006 , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: f?Dt;.-/S-Y D D D D - Plug Integrity BOP Test Mechanical Integrity Test Location Clearance - Other: RBDMS 8FL MAY () 1 1006 Subsequent Form Required: to APPROVED BY Date: 4-,g/OÞ Approved by: THE COMMISSION L/"~ ...... - Þ. 4'/~6¡é, (TRIG Form 10-403 Revised 7/2005 Submit in Du licate lNAL p .4 ý. 2.8' 0(. ~()^ w~1 . . Date: 03-15-2006 Transmittal Number:92763 ,~} BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Loq Run Top Depth Bottom Depth Loq Type VISION SERVICE LWD MD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE VISION SERVICE LWD TVD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE NS14 01-07 -2006 SCH 1 9900 10300 BRIDGE PLUG SET RECORD NS24 03-26-2005 SCH 1 12150 12478 MEM PSP PPROF NS10 12-26-2005 SCH 1 4800 8025 CHEMICAL CUTTER RECORD NS14 12-22-2005 SCH 1 11 500 11867 CHEMICAL CUTTER RECORD NS08 10-26-2005 SCH 1 111 30 11915 CHEMICAL CUTTER RECORD NS19 09-26-2005 SCH 1 13700 13990 PERFORATION RECORD NS27 06-06-2005 SCH 1 10950 11 300 PERFORATION RECORD NS31 06-05-2005 SCH 1 10950 11320 PERFORATION RECORD NS24 09-22-2005 SCH 1 11 800 12470 PERFORATION RECORD NS25 10-03-2005 SCH 1 18750 19200 PERFORATION RECORD NS21 07 -31-2005 SCH 1 22050 22225 PERFORATION RECORD NS08 12-16-2005 SCH 1 9500 11244 PERFORATION RECORD NS05 09-19-2005 SCH 1 13210 14002 PERFORATION RECORD NS06 09-17 -2005 SCH 1 13040 13825 PERFORATION RECORD NS18 12-08-2005 SCH 1 16200 16834 PERFORATION RECORD NS17 07 -29-2005 SCH 1 17850 18200 PERFORATION RECORD Petrotechnical Data Center LR2-l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~ DÅ - ')...07 r: [""- . . Date: 03-15-2006 Transmittal Number:92763 BPXA WELL DATA TRANSMITTAL I I I I I Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Doug chromanski Ignacio Herrera Petrotechnical Data Center LR2- 1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 ctú&</dJJ7 Re: Northstar Field, NS 19 Sundry Number: 306-060 \' I (.~ k Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. . orm Chairman DATED thisJi day of February, 2006 Encl. bp e e BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 15, 2006 RECEIVED FEB 1 7 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage Dear Winton: Re: Sundry Notice for NS19 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS19 well. This well has exhibited a high rate of decline and historical analysis of formation water indicates the formation of CaC03 scale is likely. Due to indications of severe // scaling, a coil tubing conveyed acid job is proposed in order to insure efficient delivery of the acid to all perforations. The procedure includes the following major steps: . Coil Tubing conveyed acid treatment . Flowback Sincerely, Robert Younger Production Engineer BPXA, ACT, Northstar IGI~IAL C/tJ ¿-?,I--ot, . STATE OF ALASKA _ ALÄ OIL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Development ~ /Exploratory 0 1. Type of Request: Suspend Repair well D Pull Tubing D Abandon Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Stratigraphic 0 9. Well Name and Number: NS19 / 10. Field/Pools(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 14077 11142.06 None Anchorage, AK 99519-6612 7. KB Elevation (ft): 56.3 KB 8. Property Designation: ADL-312809 11. Total Depth MD (ft): 14080 Total Depth TVD (ft): 11143.53 Casing Surface Production Liner Liner WúA- 1.-/2./ (2-00 4- RECE'~ff:.D bT~ ~l~' ~ FEB 7 ZOUt) Perforate Alaska o1Y~Y! Cons. CornRißeJi Stimulate 0 Time Extensio~ orage Re-enter Suspended Well 5. Permit to Drill Number: 202-2070 /' Service 0 6. API Number: 50-029-23122-00-00 ,r-/ Junk (measured): None Collapse 2270 4760 5410 7500 Length Size MD / TVD Burst 3361 13-3/8" 68# L -80 44 3405 44 3202 4930 11710 9-5/8" 47# L -80 43 11753 43 9467 6870 1896 7" 26# L-80 11584 13480 9339.35 10823 7240 752 4-1/2" 12.6# 13Cr80 13328 14080 10704.48 11144 8430 Perforation Depth MD (ft): 13860 - 13920 - / Perforation Depth TVD (ft): 11035.98 -11065.1 Tubing Size: 4-1/2" 12.6# Packers and SSSV Type: 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 12. Attachments: Descriptive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for / Tubing Grade: 13Cr80 Tubing MD (ft): 41 - 13317 Packers and SSSV MD (ft): 941 11584 13270 / 13328 13. Well Class after proposed work: Exploratory 0 Development ~ /' Service 0 2/24/2006 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Abandoned 0 WDSPL 0 Commencing Operations: 16. Verbal Approval: Commission Representative: Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Contact Prepared by Sharmaine Vestal 564-4424 Robert Younger Signature Phone 564-5392 COMMISSION USE ONLY Production Engineer Date 2/10/2006 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Other: Subsequent Form Required: Approved by: Sundry Number: .3ofe,-oCcO Location Clearance D RBDMS BFl .2 7006 APPROVED BY THE COMMISSION Date: Form 10-403 Revised 7/2005 ¡ ('I. ~dA' L ILJII\1 Submit in Duplicate ABB-VGI5-1/8" 5K ABB-VGI13-5/8" MUL TIBOWL 5KSI NS19 113-3/8" CSG, 68#, L -80 BTC, 10 = 12.415" Minimum ID = 3.725" @ 13306' 4-1/2" XN NIPPLE II~)~' I TOP OF 7" LNR 19-5/8" CSG, 47#, L-80 BTC-M, 10 = 8.681" I TOP OF 4-1/2" LNR I 13328' 4-1/2" TBG, 12.6#, 13CR VAM-ACE, ,0152bpf, 10 = 3958" ÆRFORA TION SUMMARY REF LOG JEWELRY LOG / GR-CCL ON 05/03/03 ANGLEAT TOP PERF: ?? @ 13860' Note: Refer to Production DB for historical perf data INITIAL PERF - CHARGE 2906 POWERJET, HMX, PENETRA TION: 27", HOLE 0.36", PHASE: 60 DEG, INTERVAL (MD) Opn/Sqz DATE 13860 - 13905 0 09/27/05 13860 13920 0 05/05/03 2-1/2 2-7/8" 6 I PBTD H 14077' 14080' DATE 11/15/02 03/31/03 05/07/03 09/27/05 10/07/05 REV BY REV BY COMMENTS FH INITIAL DRILL JAS ORIGINAL COM PLETION EMF A DPERFS WRRlTLH PERFS /TLH NEW FORMAT & TVD CORRECT DATE . / NOTES: ***4-1/2" CHROME TBG & LNR*** 941' GAS LIFT MANDRELS PE VLV LA TCH PORT DA TE COMMENTS 13229' -j 4-1 /2" FIBER OPTIC TRANSDUCER, ID 3.945" I 113328' ELM H4-1/2" FIBER OPTIC TRANSDUCER, ID=3.945" 13249' -14-1/2" X NIP, 10 = 3.813" I 13270' H7"X4-1/2"PKR,ID=???? 13294' H4-1/2" X NIP, ID = 3.813" I 13306' 13317' -i 4-1/2" WLEG. ID = 3.85" I H EJ.MD n rJOT iJJCGED? I NORTHSTAR WELL NS19 No: "2022070 API No 50-029-23122-00 SEC T N R E BP Exploration (Alaska) 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: a STATE OF ALASKA e Al~ Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D D o RECEIVED OCT 1 9 2005 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P" Stratigraphic D Stimulate D WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): D 6. API Number: 50-029-23122-00-00 9. Well Name and Number: Exploratory Service t#i>; 56.3 KB NS19 8. Property Designation: ADL-312809 10. Field/Pool(s): NORTH STAR Field/ NORTH STAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14063 true vertical 11135.18 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 14058 true vertical 11132.72 feet feet Casing Surface Intermediate Liner Production Length Size MD TVD Burst Collapse 3361 13-3/8" 68# L-80 44 - 3405 44 - 3201.89 4930 2270 11710 9-5/8" 47# L-80 43 - 11753 43 - 9467.45 6870 4760 1896 7" 26# L-80 11584 - 13480 9339.35 - 10823.22 7240 5410 752 4-1/2" 12.6# 13Cr80 13328 - 14080 10704.48 -11143.53 8430 7500 Perforation depth: Measured depth: 13860 - 13920 True Vertical depth: 11035.98 - 11065.1 - - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 41 - 13317 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 941 11584 13270 13328 12. Stimulation or cement squeeze summary: Intervals treated (measured): "" c..·~ 2 OO\~ 5CANNEU NO I U QJ' . v Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 937 2546 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 1644 199 475 4460 535 0 15. Well Class after Droposed work: Exploratory D Development P' 16. Well Status after proposed work: Oil P' Gas D WAG Tubing pressure 2523 2600 Service x Contact Sharmaine Vestal WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signatu~~ 7~ Title Data Mgmt Engr Printed Name Sharmaine Vestal Phone 564-4424 Date 10/18/2005 Form 10-404 Revised 04/2004 LJ , 0 C1 2 0 2005bmit Original Only I I..... .. e e ;# NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 9/26/2005 *****Continue from WSR 9/25/05***** Well flowing. Prep to perforate. Perforate 13860' - 13890' elmd using 2506 PJ Omega HMX guns 2.50" 6 SPF "PURE" technology. (Ref. SWS GR-CCL 5/23/03). Lay down for nig~.t,.\l\flILs~~got gun #3 in the AM. 9/27/2005 *****Continue from WSR 9/26/05 ***** Well flowing. Prep to perforate final gun run (# 3) 13890' - 13905' elmd. Winds 22 - 24 mph. Shut in well. Tie into SWS GR/CCL 5/23/05. SIWHP=2595 psi. Perforate top shot 13890' - btm shot 13905' elmd. POOH. Cap well. POP well. RD. Leave island. FLUIDS PUMPED I BBLS I : TOTAL ) ) bp Date: 07-20-2005 Transmittal Number: #91588NS 10,08,32 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohilsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type rNS19 05-16-2005 PDS 1 13700 14080 PRESSURE BUILDUP; )..-10'7 NS19 05-16-2005 PDS 1 13700 14080 PRODUCTION PROFILE ..... NS10 05-12-2005 PDS 5 0 8007 MEMORY MULTI-FINGER CALIPER ,~-\8).. NS-08 05-12-2005 PDS 1 0 11374 MEMORY MULTI-FINGER CALIPER , '-\.:;À l ,.,I,'... :::, --I ~-g NS- 05-14-2005 PDS 2 0 8105 MEMORY MULTI-FINGER CALIPER :2/WD-02 '1 I r .f ,l'/, ! .Ie .:::\..> /1 ,t./ / ../ / /,.1/\ i U./ . I 1/ lit..... A--''' _..1'> ,./' /I£~ ,1 { / ,/~,' VV IIV-v\. l -", ,/~ ~ '. " Pl'ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center SCA~,\t~~Er SF P (J 6 (~OO~:; Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) ~ ~ Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 /' ~ Ð:::1-'~~!" f=.r ( ~. 3 J VN'- N)--~~1 DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2022070 Well Name/No. NORTHSTAR UNIT NS-19 Operator BP EXPLORATION (ALASKA) INC MD 14063'/ NO 11153 /" Completion Date 5/3/2003 / Completion Status 1-01L REQUIRED INFORMATION MUdS Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, DIR, RES, DEN, NEU Well Log Information: Logl Data Digital Type Med/Frmt iE~ I ~og ~Og Electr Dataset Number Name Directional Survey Gamma Ray Casing collar locator Log Log Run Scale Media No 1 2 Blu 2 Blu ! i Rpt Directional Survey i ¡~ Report: Final Well R í I lJ..ðQ See Notes 2 Col ~ C Lis 12058 LiS V"I ¡neat/on J "i- fu~ 1-5 i - C Pds 12058 I nd uction/Resistivity 25 1-5 , ; iÀ.Or~ I I 'Er:J"' C Pds 1~ Induction/Resistivity 25 1-5 ¡ ! ! Lpg-'- -1?1)58 -Induction/Resistivity 25 Blu 1-5 lA::óg ..EQ.5.8 I nd uetion/Resistivity 25 Blu 1-5 i ! !~ C Pds 12058 Neutron 25 5 ~ C Pds 12058 Neutron 25 5 í It ~ Neutron 25 Blu 5 1~-Neutron 25 Blu 5 I bQg.--- Perforation 5 Blu 2 , Current Status 1-01L 5 u.¿ 21lJt ~ À At:: No. 50-029-23122-00-00 UIC N - --- --- - Directional s~_. -_.~cc _ (data taken from Logs Portion of Master Well Data Maint) Interval OH 1 Start Stop CH Received o 13500 Open 12/2/2002 40 13400 Case 1/3/2003 40 13400 Case 1/3/2003 o 201 13500 Open 12/2/2002 13500 Open 5/9/2003 201 265 265 13500 Open 5/9/2003 14065 Open 7/29/2003 14065 Open 7/29/2003 265 14065 Open 7/29/2003 265 14065 Open 7/29/2003 265 14065 Open 7/29/2003 265 14065 Open 7/29/2003 265 14065 Open 7/29/2003 265 14065 Open 7/29/2003 265 14065 Open 7/29/2003 13140 14000 Case 5/28/2003 -~- Comments ------------~- - -- End of ~ell ,Repo~ _ \p.,.J ~ ~ Jt}. t{,. V' Rig Monitoring , (i ~ ( / ~~NI (. b AI rt.. ~ G K [ Vision Resistivity, Borehole Corrected - MD : , Vision Resistivity, Borehole I Corrected - NO ! i Vision Resistivity, Borehole ; Corrected - NO I Vision Resistivity, Borehole Corrected - MD Density Neutron - MD Density Neutron - NO Density Neutron - NO Density Neutron - MD Perforating Record 27/8 HSD, 6SPF, 2606PJ --. -_.------- DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2022070 Well Name/No. NORTHSTAR UNIT NS-19 MD 14063 NO 11153 Completion Date 5/3/2003 I Log - Casing collar locator ~- Directional Survey 'f<Pt Directional Survey iÉÔ 0 Directional Survey ~D 0 Directional Survey ~pt Report: Final Well R ~ See Notes ¡ Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Y / N Analysis Received? ~- Comments: Compliance Reviewed By: ¿~ Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23122-00-00 Completion Status 1-01L Current Status 1-01L UIC N 5 Blu 14012 12550 Case 5/28/2003 Jewelry Log / GR-CCL - Perforating Record / 27/8 HSD 6SPF 20' 0 13998 Open 4/15/2003 0 14063 Open 4/15/2003 Geodetic 0 14063 Open 4/15/2003 Geodetic 0 13998 Open 4/15/2003 ~=-"'-o_ 10/21/2003 Col 201 14063 Case 10/21/2003 Rig Monitoring - in Well History File w/End of Well Report - -------- - Sent Sample Set Number Comments Received Daily History Received? [PN ~/N Formation Tops -" ------- ----~ Date: ~ j".~ ~ )~ ~:ifù, '¡ ïr 1M, ír Œ' :_ ' ,~ ! II / JJ~' ::1 I \ 11:1 Jj,l . ¡ ,I i¡: '_ ; ... U i ;'ìl ì, U ~ ¡ ( (mr' ! i, ~ [' : :j ¡¡ 11 ,¡-oJ ~ ! :! ~ :I ~ ~u (' '~q .1-', '~'1 0"-" ¡i'tJh \\' 1::1 f;\ \ ,:, (U 1 Y /, J :i\ \ ,¡ _", j ,; ;\ 'I, -\, \, j '\ '\ i fI ), , ' I , ,-.,¡ '\ ,,\ ",.w "~'I ' '1.1 ....', I 'o' ;-¡ , -I L.. ~ ,:-,,\ \ i-:1 I) , ,[ :" ':ï1" J..J ~~ ~ ~I LJ \..::::.. U \.~ L' 'w ~O:2 -;<() 7 FRANK H. MURKOWSK/, GOVERNOR AI¡ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar #19 Sundry Number: 305-162 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours 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 ecis' nl to Superior Court unless rehearing has been requested. ,.....- L' .' l~l~C ~ DATED thisiL day of July, 2005 Encl. bp ( It ,\t6t,. ..~~ ~~. --.- -.-. .......~ ~...~ .'J'_'- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 29, 2005 ~ Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS 19 to Reperforate (Ivishak) BP Exploration Alaska, Inc. proposes to reperforate the NS19 well. This well has exhibited a high rate of decline and an acid job provided only a temporary ,- rate increase. Reperforating to attempt to bypass near wellbore damage is /~- recommended. The procedure includes the following major steps: Type Slickline Electric Line Work Description Drift/taQ wI dummy Qun Perforate 451 of Ivishak 13,860' - 13,905' MDrkb /~ Sincerely, ~~~' Michael J. Fr , .E. Senior Petro urn Engineer BPXA, ACT, Northstar RECEIVED JUN 3 0 2005 ß\laska Oil & Gas Cons. Commission ß"m;hor~~e ORIGINAL V-IL1Â- 1/1/ ¿C'or;; ('. STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Suspend 0 Repair Well D Pull Tubing D Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: 4. Current Well Class: Operation Shutdown D Plug Perforations D Perforate New Pool D /. Development Œ1 Exploratory D Perforate[i] / WaiverD Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 202-2070/, Other 0 BP Exploration (Alaska), Inc. 56.30 KB StratigraphicD Service 0 9. Well Name and Number: NS19 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11086.0 14077 11085.0 Size MD TVD 6. API Number /"' 50-029-23122-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 8. Property Designation: ADL-312809 11. Present Total Depth MD (ft): 14080 Casing SURFACE INTERMEDIATE LINER PRODUCTION top bottom top 3361 13-3/8" 68# L-80 44 3405 44.0 11710 9-5/8" 47# L-80 43 11753 43.0 1896 7" 26# L-80 11584 13480 9339.4 752 4-1/2" 12.6# 13Cr80 13328 14080 10704.5 Plugs (md): Junk (md): None None Burst Collapse bottom 3201.9 4930 2270 9467.5 6870 4760 10823.2 7240 5410 11143.5 8430 7500 Length Perforation Depth MD (ft): 13860 - 13900 13900 - 13920 Perforation Depth TVDss (ft): 10980 - 10999 10999 -11009 Tubing Size: 4-1/2 " Tubing Grade: Tubing MD (ft): 12.6 # 13Cr80 41 13334 Packers and SSSV Type: 7" Liner Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 4-1/2" TRM-4E SSV 12. Attachments: Packers and SSSV MD (ft): 11584 13270 13328 941 Description Summary of Proposal [! Detailed Operations ProQram D BOP Sketch D 14. Estimated Date for Commencing Operation: 13. Well Class after proposed work: / July 13, 2005 Exploratory D DevelopmentŒ) 15. Well Status after proposed work: Oil [!] GasD PluggedD Service 0 Abandoned D 16. Verbal Approval: Date: WAG D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. GINJO WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Contact Michael Francis Printed Name Signature Michael Francis ~iJL!fi-U~ (J.p¡. r Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Title Phone Petroleum Engineer 564-4240 6/29/05 Subse 4ol\-. Sun~ NumbeZ ;J05 -/02- Mechanciallnt. egrity Test .:J IJ ... Location Clearance 0 R:)EC· ~ErvED '..- {,1 == ~ ::" RBDMS BFl ,JUt ~i1 7005 JUN 3 0 2005 . BX"PRDER OF ~/ h /' Alaska Oil & Ga~ CO~:~ Commls¥ll~ COMMISSION Date: II¡ t)) RBDMS BFl JUl ~'t~J n P I h ¡ I "i' I!\, I: ''', ...! $UBMIT IN DUPLICATE BOP TestO Other: Form 10-403 Revised 11/2004 \.. , TR5E: ABB-VGI 5 1/8" 5ksi ( WELLHEAD: ABB-VGI 13-5/8" Multibowl5ksi 13 3/8", 68#/ft, L-80, BTC @ 3405' MD 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.958" CAPACITY: 0.0152 BBLlFT 9-5/8" 47# L-80 BTC-M @ 11753' MD 4.5" X NIPPLE, @ 13249' MD w/3.813" 10 4.5" X NIPPLE, @ 13294' MD w/3.813" 10 4.5" XN NIPPLE, @ 13306' MD w/3.725" 10 4.5" WLEG, @ 13317' MD- w/3.850" 10 7", 26#/ft L-80, Hydril 521 @ 13480' MD PERFORATION SUMMARY REF LOG: Jewelry Log 1 GR-CCL (5/3/2003) ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data Initial Perf" Charge: 2906 Pow erJet, HMX; Penetration: 27"; Hole: 0,36"; Phase: 60 deg SIZE SPF INTERVAL MDrkb INTERVAL TV Drkt Opn/Sqz DATE 2,875 6 13860'-13920' 11054'· 11083' Opn 5/5/2003 PBTD @ 14077' MD TO @ 14080' MD DATE 9/24/02 11/25/02 3/18/03 04/10/03 5/ (/03 REV. BY BMH FH JAS MJF ~M- COMMENTS ~s1è proposed NS19 Proposed Revision #1 NS19 Proposed Revision #2 ~S19 Proposed Perforations BP Exploration (Alaska) Add perfs 0 ~ I G h\ ~A I ~<I J!~\! - ~_ NS19 f RIGINAL KB. ELEV = 56.3' r<B-BF. ELEV = 40.1' CB. ELEV = 16.2' 4 1/2" TRM-4E SSSV @ 941' MD W/4 1/2 "X" PROFILE= 3.812" 10 ..4 ... 4 1/2" GLM @ 5067' MD (4364' TVD) w/3.833" 10 4 1/2" GLM @ 6469' MD (5339TVD) w/3.833" 10 ~ H Jj- ~ - 7" LINER TOP @ 13328' MD V I 4.5" Fiber Optic Transducer @ 13229' MD w/3.945" 10 Elm 13327.5' MD, 10665' TVDss B -;:¡ _ 7" PACKER,13 Cr @ 13270' MD 'E: 1 E. 4.5" LINER TOP @ 13328' MD .II .. j ~ 4.5",12.6#, Solid Cemented 13Cr Vam Ace Northstar WFI I : NS19 API NO: 50-029-23122-00 ( ,," IF'''' "' ,rt r('" \1 "\ l ç: 0 STATE OF ALASKA ,¡ '¡,,,,J;, t:.\, ¡: : "', \',' :i!.."-,, ",,,. t ~ W(" h . \,J ALASKA OIL AND GAS CONSERVATION COMMISSION'" , ,,\ ;_, '0 '7005 _ REPORT OF SUNDRY WELL OPERATlëN~ ~ ~ '~J[lF'Ù~'iOr, 1. Operations Performed: r<" '., ..:~ G~;:;; ~"u!o-1'· Abandon 0 Repair Well 0 Pluç PerforationsD Stimuràtê'"Œ] ~~nt.hOfage OtherD Alter Casing 0 Pull Tubing 0 Perforate New Pool D WaiverD Time Extension 0 Change Approved ProgramD Operation ShutdownD Perforate D Re-enter Suspended Well 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] Exploratory 0 5. Permit to Drill Number: 202-2070 6. API ~lì1ber 50-029-23122-00-00 P.o. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.30 8. Property Designation: ADL-312809 11. Present Well Condition Summary: Stratigraphic D Service 0 9. Well Name and Number: NS19 10. Field/Pool(s): Northstar Field / Northstar Oil Pool Total Depth measured 14063 feet true vertical 11135.2 feet Effective Depth measured 14058 feet true vertical 11132.7 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse LINER 1864 7" 26# L-80 11616 - 13480 9363.1 - 10823.2 7240 5410 Liner 735 4-1/2" 12.6# 13Cr80 13328 - 14063 10704.5 - 11135.2 8430 7500 Production 11710 9-5/8" 47# L-80 43 - 11753 43.0 - 9467.5 6870 4760 SURFACE 3361 13-3/8" 68# L-80 44 - 3405 44.0 - 3201.9 4930 2270 Perforation depth: Measured depth: 13860 -13900, 13900 -13920 True vertical depth: 11035.98 - 11055.37, 11055.37 - 11065.1 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 41 13319 Packers & SSSV (type & measured depth): 4-1/2" Baker SAB Perm Packer 4-1/2" TRM-4E SSV 7" Top Packer 4-1/2" Top Packer @ 13270 @ 940 @ 11584 @ 13309 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13860' -13920' Treatment descriptions including volumes used and final pressure: 43 Bbls 12% HCLlSI @ 3511 psig Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 2.6 326 0 2.7 331 0 RBDMS 8FL JUN 0 ?' 2005 13 Prior to well operation: Subsequent to operation: Oil-Bbl 1481 1440 Tubing Pressure 731 721 Copies of Logs and Surveys run _ Daily Report of Well Operations_ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD Development ŒJ Service D 14. Attachments: Signature Garry Catron Garry Catron Jj /~, WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 305-035 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Ctct<:~ Phone 564-4657 Date 6/3/05 Form 10-404 Revised 4/2004 C) R, '1' \ (:; ~I .....',. \. ,~, I ( ~' NS19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/17/05 ACID TREATMENT / SCALE INHIBITION: PUMPED TBG PICKLE...12 BBLS OF 12% HCL, 124 BBLS SW, 68 BBLS DIESEL. PRODUCE PICKLE BACK TO WELL CLEANUP TANK. PUMP MAIN TREATMENT...29 BBLS 12% HCL W/ L66, 241 BBLS 2% KCL W/ L66, 15 BBLS DIESEL, 194 BBLS SW, 68 BBLS DIESEL (ALL FLUIDS HEATED TO +90 DEG F). *** NOTICED IMPROVED INJECTIVITY WHEN ACID HIT THE PERFS THEN DECREASING INJECTIVITY AS 2% KCL W/ L66 HIT THE PERFS ***. LET TREATMENT SOAK 4 HOURS AND POP TO WELL CLEANUP TANK. LDFN. FLUIDS PUMPED BBLS 43 12% HCUSI 142 SeaWater 68 Diesel 78 2% KCL 10 Foam (NH4CL + N2) 107 2% KCUSI 4 Neat Methanal 452 TOTAL Page 1 (. TREE: ABB-VGI 5 1/8" 5ksi ( WELLHEAO: ABB-VGI 13-5/8" Multibowl 5ksi NS19 1 3 3/8", 68#/ft, L-80, BTC @ 3405' MO ~ 41/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.958" ~ CAPACITY: 0.0152 BBLlFT 9-5/8" 47# L-80 BTC-M @ 11753' MD 6 4.5" X NIPPLE, @ 13249' MD w/3.813" 10 J ~ I '")IGINAL KB. ELEV = 56.3' -BF. ELEV = 40.1' CB. ELEV = 16.2' "1 1/2" TRM-4E SSSV @ 941' MD W/4 1/2 "X" PROFILE= 3.812" 10 t' ~ 4 1/2" GLM @ 5067' MD (4364' TVD) w/3.833" 10 4 1/2" GLM @ 6469' MD (5339TVD) w/3.833" 10 !\. - 7" LINER TOP @ 13328' MD 4.5" Fiber Optic Transducer @ 13229' MD w/3.945" 10 Elm 13327.5' MD, 10665' TVDss 4.5" X NIPPLE, @ 13294' MD w/3.813" 10 4.5" XN NIPPLE, @ 13306' MD w/3.725" 10 );" _ 7" PACKER, 13 Cr @ 13270' MD I 'E: 4.5" WLEG, @ 13317' MD- w/3.850" 10 7", 26#/ft L-80, Hydril 521 @ 13480' MO B if PERFORATION SUMMARY REF LOG: Jewelry Log 1 GR-CCL (5/3/2003) ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2906 Pow erJet, HMX; Penetration: 27": Hole: 0,36'; Phase: 60 deg SIZE SPF INTERVAL MDrkb INTERVAL TVDrkt Opn/Sqz DATE 2,875 6 13860' - 13920' 11054' - 11083' Opn 5/5/2003 PBTO @ 14077' MO TO @ 14080' MO L DATE 9/24/02 11/25/02 3/18/03 04/10/03 b/'t /03 REV. BY BMH FH JAS MJF I::MI- COMMENTS ~S19 ~roposed NS19 Proposed Revision #1 NS19 Proposed Revision #2 ~ . S 19 Pro[;>osed Perforations Add ~erfs ~ 4.5" LINER TOP @ 13328' MO ~ 4.5", 12.6#, Solid Cemented 13Cr Vam Ace Northstar WF~ ~ : NS19 API NO: 50-029-23122-00 BP Exploration (Alaska) .~ ( ,,-\ fÇ, :LU'I,n, j : b. , ~u ; J ~ " ,) u ji'}' \ r.¡ ~.\ /M (f\\ù r.v7 ¡r;1¡, \. 1J111 jU, \ \~\ l{j~\ ~ \ ~ j . 'I to, , , .. . Liù L=1 Ùu & U \~ U-~ j{()2 - 201 :(~ 1 !.FjJ\\ IÜ·... rF ' " i) ,I 1J \ ;1. i ;-)- M ," _ ¡! ~ I~) . ~ ,¡ ~\ ." ;!L- '&UWUi.~ FRANK H. MURKOWSK/, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. T" AVENUE, SUITE 1 00 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS 19 Sundry Number: 305-035 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours 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 sho"WTI., 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 h . y or weekend. A person may not appeal a Commission decision to Superior Urt less rehearing has been requested. DATED this~day of February, 2005 Encl. . bp ( ~ .,. .",.,", ......,~ ~..~ ~.- --:...-- ~~ F.... ·'1'''1\'' ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 16, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS19 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS19 well. This well has exhibited a high rate of decline and analysis of formation water indicates the ,/' formation of CaC03 scale is likely. Offset wells have responded very well to similar treatments in the past. The procedure includes the following major steps: . Bullhead HCI based acid treatment (which includes scale inhibitor) . Flowback /,., ", Sincerely, ~~ 4 £-()/Y1 ~ Mictìael J. 6fancis, P .E. Senior Petroleum Engineer BPXA, ACT, Northstar ORIG\NAL '\ VJ 411- Oz:s ') STATE OF ALASKA ) 2../..2.« ALASKA OIL AND GAS CONSERVATION COMMISSION S APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 2./ ¿ 2/t.{)O S FEB 1 8 2.005 PerforateD // waiverD StimulateŒ] Time Extension D Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2070 ~' Œì ,& 1. Type of Request: Suspend D Repair Well D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development Œ] // Exploratory D Abandon D D o Alter Casing Change Approved Program 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Other D P.O. Box 196612 Anchorage, Ak 99519-6612 6. API Number ~ 50-029-23122-00-00 13. Well Class after proposed work: ~ Wc,1f- Exploratory D Development[Y Servic~""'" 15. Well Stat~er proposed work: Oil L.!I GasD PluggedD AbandonedD ~c,A- WAG D GINJO WIN~ WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Sundry Number: 3O:;:()~ - Location Clearance D RBDMS 8Ft MI1R {).1 ïD05 ~ ~~~~~~~~~ION Date: iJ,r 7. KB Elevation (ft): StratigraphicD Service D 9. Well Name and Number: NS19 /' 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14058 11094.4 Size MD TVD Plugs (md): None Burst 56.30 KB 8. Property Designation: ADL-312809 11. Present Total Depth MD (ft): 14063 Casing Total Depth TVD (ft): 11153.2 Length top bottom top bottom LINER 1864 7" 26# L-80 11616 13480 9377.3 10840.9 4930 Liner 735 4-1/2" 12.6# 13Cr80 13328 14063 10721.9 11153.2 6870 Production 11710 9-5/8" 47# L-80 43 11753 43.0 9481.9 7240 SURFACE 3361 13-3/8" 68# L-80 44 3405 44.0 3201.9 8430 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13860 - 13900 11054 - 11073.4 4-1/2 " , 12.6 # 13Cr80 41 13900 - 13920 11073 - 11083.1 Packers and SSSV Type: 4-1/2" Baker SAB Perm Packer 4-1/2" TRM-4E SSV 7" Top Packer 4-1/2" Top Packer 12. Attachments: Packers and SSSV MD (ft): 13270 940 11584 13309 Description Summary of Proposal ŒI Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: March 25,2005 Date: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael Francis ~>hL1. (f~, PI~ ( Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Petroleum Engineer 564-4240 Printed Name Signature Title Phone Mechanciallntegrity Test D BOP TestO Other: Subsequ \ Form 10-403 Revised 11/2004 RIGINAL SUBMIT IN DUPLICATE Junk (md): None Collapse 2270 4760 5410 7500 13319 2/8/05 TREE: ABB-VGI 5 1/8" 5ksi ') WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8", 68#/ft, L-80, BTC @ 3405' MD NS19 ~ .4 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.958" . CAPACITY: 0.0152 BBLlFT 9-5/8" 47# L-80 BTC-M @ 11753' MD 4.5" X NIPPLE, @ 13249' MD w/3.813" 10 4.5" X NIPPLE, @ 13294' MD w/3.813" 10 4.5" XN NIPPLE, @ 13306' MD w/3.725" ID 4.5" WLEG, @ 13317' MD- w/3.850" ID 7", 26#/ft L-80, Hydril 521 @ 13480' MD ÆRFORA TION SUMMARY REF LOG: Jewelry Log 1 GR-CCL (5/3/2003) ANGLE AT TOP PERF: Nole: Refer 10 Production DB for historical perf data Initial Perf - Charge: 2906 PowerJel, HMX; Penetration: 27·; Hole: 0.36·; Phase: 60 deg SIZE SPF INTERVAL MDrkb INTERV AL TVDrkt Opn/Sqz DA TE 2,875 6 13860'-13920' 11054'-11083' Opn 5/5/2003 PBTD @ 14077' MD TD @ 14080' MD DATE 9/24/02 11/25/02 3118103 04/10103 bIt /03 REV. BY BMH FH JAS MJF t::Mt- COMMENTS ""NS19 Proposed NS19 Proposed Revision #1 NS19 Proposed Revision #2 ~. S 19 Proposed Perforations Add Perfs 4.5" Fiber Optic Transducer @ 13229' MD w/3.945" ID Elm 13327.5' MD, 10665' TVDss -;;- _ 7" PACKER,13 Cr @ 13270' MD ,~ ¿. J V I B if J ~ )RIGINAL KB. ELEV = 56.3' KB-BF. ELEV = 40.1' CB. ELEV = 16.2' '1 1/2" TRM-4E @ 939' TVD 3.812" ID 941' MD 6.8PPG DIESEL FREEZE PROTECTION AT +/- 3792' TVD (4452'MD) ... 4 1/2" GLM @ 4364' TVD (5067' MD) w/3.833" ID' 4 1/2" GLM @ 5338' TVD (6469'MD) w/3.833"ID I\.. - 7" LINER TOP @ 13328' MD 4.5" LINER TOP @ 13328' MD ... 4.5", 12.6#, Solid Cemented 13Cr Vam Ace Northstar WFI I : N~19 API NO: 50-0?9-?3122-00 BP Exploration (Alaska) : ) ) Date: 10-20-2003 Transmittal Number:92626 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsoih@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type ¿ø-//Ò NS12 06-07 -2002 SPERRY 1 201 3647 MUD LOG; END OF WELL REPORT; 7- NS16 06-28-2002 SPERRY 1-4 201 12424 MUD LOG; END OF WELL REPORT; &Q9-)d ~a?1-)01 NS17 08-24-2002 SPERRY 1-6 201 18396 MUD LOG; END OF WELL REPORT; 10-29-2002 SPERRY MUD LOG; END OF WELL REPORT; ~Œl-àð1 NS19 1-4 201 14063 ~_)~ NS20 09-26-2002 SPERRY 1-5 201 18531 MUD LOG; END OF WELL REPORT; ()ò NS23 03-31-2003 SPERRY 1-5 201 13981 MUD LOG; END OF WELL REPORT; 903-0- ._.,;~~\~ ~~ LQ Cb ~~~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVEI) OCT 2 '1 200:5 AiasRaÖí'; é~ Ga~ C'~lnG. Cí.m~:Tt!8~tQn ¡\n~Qrnti8 Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~~~\\\~ .) STATE OF ALASKA' .\) ALASr,A OIL AND GAS CONSERVATION COMh ,,,,SION REPORT OF SUNDRY WELL OPERATIONS 1. Ooerations Performed: Abandon 0 Alter CasingD Change Approved Program D Suspend I=:=J Repair WellD Pull Tubingc=J Operation ShutdownD Plug perforationsD Perforate New PoolD PerforateD VarianceD Stimulate!] Time ExtensionD Re-enter Suspended WellD Annular Disposal D OtherD 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development 00 ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 StratigraphicD ServiceD 9. Well Name and Number: NS-19 10. Field/Pool(s): Northstar 5. Permit to Drill Number: 202-2070 6. API Number 50-029-23122-00-00 7. KB Elevation (ft): 56.3 8. Property Designation: ADL-2809 11. Present Well Condition Summary: / Northstar Total Depth measured 14063 feet true vertical 11153 feet Plugs (measured) Effective Depth measured 14077 feet true vertical 11047 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 3361 11710 735 1864 13-3/8" 68# L-80 9-5/8" 47# L-80 4-1/2" 12.6# 13Cr80 7" 26# L-80 44 43 13328 - 11616 - 3405 11753 14063 13480 44 43 10721.89 - 9377.31 - 3201.9 9481.85 11153.2 10840.9 4930 6870 8430 7240 2270 4760 7500 5410 Perforation depth: Measured depth: 13860' - 13900', 13900' - 13920' True vertical depth: : 11053.99' - 11073.38' , 11073.38' - 11083.1' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 @ 41' -133191 MD i''':'''''~ '.,,'.: 'I. ,,,.. r Packers & SSSV (type & measured depth) 7" Liner Top Packer @ 11584' MD /4-1/2" Baker SAB Perm Packer @ 13270' MD 4-1/2" Liner Top Packer @ 13309' MD /4-1/2" TRM-4E SSV @ 940' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: (See Attachment) Prior to well operation: Subsequent to operation: 14. Attachments: Representative Daily AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 4,257 8,000 0 5,872 11,600 10 Tubing Pressure 780 1047 13 15. Well Class after proposed work: ExploratoryD Development[&] Service D Contact Printed Name Michael J. Francis, P.E. Michael J. Francis 16. Well Status after proposed work: Operational Shutdown D Oiloo GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or NIA if C.O. Exempt: 303-245 Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature ~AJ/~I ,? r. Title Senior Petroleum Engineer Phone 564-4240 Date 9/26/03 o RIG r ~'_' A f~)~)\),~~;~> ',. :_~ .'li ~>~J' .0 L' .) Form 10-404 Revised 4/2003 ) ) NS-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/23/03 Acid Treatment, well shut in on arrival with 2470 psi whp, Pump pickle per procedure, 12 bbls 12% DAD acid, 124 bbls SW, 68 bbls Diesel, flowback pickle to production. ***Continued on 08-24-03 WSR*** 08/24/03 ***Continued from 08-23-03 WSR*** Acid Treatment, Pickle pumped and flown back, continue with main DAD Acid treatment per procedure, 14 bbls 12% DAD Acid, 210 bbls SW, shut down for 30 minute soak, 55 bbls SW, 68 bbls Diesel, leave well shut in for 4 hour FLUIDS PUMPED BBLS Methanal 26 120/0 DAD Acid 389 Sea Water 136 Diesel 551 TOTAL Page 1 bp ) ') ... ,\If.'I1. -......,~ ~...- ~40.:- ~..-- ~.~ ~.... ·'I'·~I\· ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 15, 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS19 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS19 well. This well has exhibited a high rate of decline and analysis of formation water indicates the / formation of CaC03 scale is likely. Additionally, CaC03 scale was recovered from the offset NS 13 wellbore using slickline. The procedure includes the following major steps: · Pickle the tubing · Bullhead HCI based acid treatment (which includes scale inhibitor) · Flowback Sincerely, t &7 tJ1:-·1~h~. ~~~ MicHael J. F ncis, P.E. Senior Petro eum Engineer BPXA, ACT, Northstar ORIGIN.AL ') v.-JGI\- 1'1 i /l-flC) ~ ~~ /A,{ lD ') STATE OF ALASKA ') "IS l v ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: D D D Perforate D VarianceD Annuar Disposal D Abandon Suspend Operation Shutdown Alter Casinq 0 Repair Well 0 Pluq Perforations 0 Stimulate [XI Time Extension 0 OtherD Chanqe Approved Proqram 0 Pull Tubinq 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): RKB 56.30 8. Property Designation: ADL-312809 11. Total Depth MD (ft): 14063 Casing Conductor Surface Intermediate Liner Production Liner 5. Permit to Drill Number: 202-2070 /' 6. API Number /' 50-029-23122-00-00 4. Current Well Class: Development 00 ExploratoryD StratigraphicD ServiceD 9. Well Name and N~er: NS19 10. Field/Pool(s): Northstar / Northstar PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11153.19 0 -56.3 Length Size MD TVD 3361 13.375" 68# L-80 11710 9.625" 47# L-80 1896 7" 26# L-80 753 4.5" 12.6# 13CR80 Perforation Depth TVD (ft): 11 054' - 11 083.1' Plugs (measured): Junk (measured): Burst top bottom top bottom 44 - 3405 44 - 3201.9 5020 43 - 11753 43 - 9481.9 6870 11584 - 13480 9353.5 -10840.9 7240 13309 - 14062 10650.4 - 11096.4 8440 Collapse 2270 4760 5410 7500 Tubing MD (ft): 40.8' - 133161 Tubing Grade: 12.6# 13CR80 Packers and SSSV MD (ft): 15584',13270',13308' 941' 13. Well Class after proposed work: ExploratoryD DevelopmentOO ServiceD 15. Well Status after proposed work: Oil ~ Gas D Plugged D Abandoned D WAGD GINJD WINJD WDSPLD Prepared by S. Copeland 564-4424 Perforation Depth MD (ft): 13860' - 13920' '/ Packers and SSSV Type: 7" HYD 521 Liner Top Pkr, 7" 13CR Pkr, 4.5" VAM ACE Pkr 4.5" TRM-4E SSSV 12. Attachments: Description Summary of Proposal 00 Detailed Operations Program D BOP Sketch D 14. Estimated Date for 8/20/2003 Commencing Operation: 16. Verbal Approval: Date: Commission Representative: Tubing Size: 4.5" Contact Mike Francis Printed Name 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title - Production Engineer 564-4240 Date 8/15/03 Signature (':;t~el VFranCiS . , ,t.:hl'C:' ~ t...,....."1..-¡{.V] Phone _ Commission Use Only Plug Integrity D Conditions of approval: Notify Commission so that a representative may witness Location ClearanceD Other: BOP TestD Mechanciallntegrity TestD Subsequent Form Required: I 0 - ,/-0 'f Approved by: Form 10-403 Revised 2/2003 BY ORDER OF COMMISIONER THE COMMISSION OR\G\NAL Sundry Number: 30"3-7.. L.jS- Date: SUBMIT IN DUPLICATE 1\ bp ... ,\1'.'11, ..'~ ~~.. .~~ ¡:~. ·"'t~\\~ ". ) ') .l To: Gary McBride/John Smart - Well Operations Supervisor August 8, 2003 From: Mike Francis and Patty Hill - Northstar Subject: NS19 DAD Acid/51 Treatments AFE NSZ832018 Est. Cost: $60 M lOR: Est 250 BOPD Please perform an acid stimulation/SIT with 12% DAD acid on the NS19: Type lOR PR N DSWL AFE Job Description Priority Com ments/Other o 250 NS19 NSZ832018 Pump Acid and SIT NS 19 has suffered significant decline since start-up. The water chemistry indicates CaC03 scale formation is likely and the presence of scale has been confirmed in the offset NS13 well. This treatment will dissolve the scale and place scale inhibitor in the formation. The treatments are being combined to simplify logistics. Procedure 1. Mobilize pumps, tanks and acid transport to Northstar. 2. Order out volume of seawater and diesel to flush both the pickle and the acid job. See attached Volumes table. 3. RU pumping equipment. 4. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface when the pickle is produced back. 5. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 6. PT Dowell surface lines to 5000 psi 7. Pump the following fluids to pickle the production tubing at 3 bpm, 3500 psi max pressure. / a) 12 Bbls 12% DAD acid b) 124 Bbls seawater c) 68 Bbls diesel 8. Produce pickle back to test separator and well clean up tank. The pickle volume to flowback is 203 Bbls. ) ') . -'\1. .. 9. Pump the following treatment at;:naximum rate or 3500 psi max pressure. a) 14 bbls 120/0 DAD Acid / b) 210 bbls Seawater (To displace acid to perfs) c) Shut down for 30 minutes and allow acid to soak d) 55 bbls Seawater (for over flush and displacement) e) 68 bbls Diesel (for displacement and under-balance) 10. Shut well in for 4 hours to allow scale inhibitor to precipitate. 11. RD Schlumberger. 12. Flow back Procedure: For flow back, line up into the test separator and well cleanup tank. Produce clean-up volume of 347 bbls. After clean-up, divert back to the plant and get 2 6-hour tests. Fluid descriptions: 120/0 DAD Acid to contain: 100/0 Nalco Scale Inhibitor + 0.6% A261 + 4 ppt A 179 + 8 ppt A 153 + 0.2% F103 + 20 ppt L58 + 1.5% U74 + 10% Xylene Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Results will be available on location. Procedure Contacts: Mike Francis WK: 564-4240 HM: 644-0534 Cell: 529-8678 Patty Hill WK: 564-4346 HM: 248-6262 Cell: 350-0742 TREE: ABB-VGI 5 1/S" 5ksi WELLHEAD: ABB-VGI 13-5/8" 1V1ultibowl 5ksi ) 1 3 3/S", 68#/ft, L-SO, BTC @ 3405' MD 41/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.95S" CAPACITY: 0.0152 BBLlFT 9-5/8" 47# L-80 BTC-M @ 11753' MD 4.5" X NIPPLE, @ 13249' MD w/3.S13" ID 4.5" X NIPPLE, @ 13294' MD w/3.S13" ID 4.5" XN NIPPLE, @ 13306' MD w/3.725" I D 4.5" WLEG, @ 13317' MD- w/3.S50" ID 7", 26#/ft L-SO, Hydril 521 @ 134S0' MD PERFORA TION SUMMARY REF LOG: Jaw airy Log 1 GR-CCL (5/3/2003) ANGLE AT TOP PERF: Note: Refor to Production DB for historical perf data Initial Perf - Charge: 2906 Pow crJet, HMX; Penetration: 27·; Hole: 0,36"; Phase: 60 deg SIZE SPF INTERVAL MDrkb INTERVAL TYDrkt Opn/Sqz DATE 2,875 6 13860'-13920' 11054'-11083' Opn 5/5/2003 PBTD @ 14077' MD TD @ 140S0' MD DATE 9/24/02 11/25/02 3/18/03 04/10/03 b/ {/03 REV,BY BMH FH JAS MJF eM- COMMENTS ~ S 19 proposed NS19 Proposed Revision #1 NS19 Proposed Revision #2 ~ . S 19 Proposed Perforations Add Perfs 4.5" Fiber Optic Transducer @ 13229' MD w/3.945" ID Elm 13327.5' MD, 10665' TVDss -;;- _ 7" PACKER, 13 Cr @ 13270' MD ': NS19 .. .a4 . H Jj- ~ I BL 81 ~ ~ '- ):IGINAL KB. ELE~ = 56.3' ,j.B-BF. ELEV = 40.1 CB. ELEV = 16.2' '1 1/2" TRM-4E @ 939' TVD 3.S12" ID 941' MD 6.SPPG DIESEL FREEZE PROTECTION AT +1- 3792' TVD (4452'MD) ... 4 1/2" GLM @ 4364' TVD (5067' MD) w/3.S33" ID 4 1/2" GLM @ 533S' TVD (6469'MD) w/3.S33" ID l\. - 7" LINER TOP @ 13328' MD 4.5" LINER TOP @ 1332S' MD ... 4.5", 12.6#, Solid Cemented 13Cr Vam Ace Northstar WFI I : N~19 API NO: 50-029-23122-00 BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 08/04/03 Correct Perf. Intervals ) ) 1. Status of Well 181 Oil D 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 1229' NSL, 646' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 7' NSL, 2574' WEL, SEC. 13, T13N, R13E, UM X = 663324, Y = 6024574 10. Well Number At total depth 5123' NSL, 2384' WEL, SEC. 24, T13N, R13E, UM X = 663517, Y = 6024415 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Northstar Unit RKB = 56.3' ADL 312809 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 10-29-2002 3-25-2003 5-3-2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14063 11153 FT 14058 11151 FT 0 Yes 181 No 22. Type Electric or Other Logs Run MWD, GR, DIR, RES, DEN, NEU Classification of Service Well X = 659829, Y = 6031001 7. Permit Number 202-207 8. API Number 50- 029-23122-00 9. Unit or Lease Name Northstar Unit NS19 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1545' (Approx.) 23. , CASING SIZE 20" 13-3/8" 9-5/8" WT. PER FT. 169# 68# 47# 26# 12.6# GRADE X-56 L-80 L-80 L-80 13Cr CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 201' 20" Surface 3405' 16" Surface 11753' 12-1/4" 11584' 13480' 8-1/2" 13309' 14062' 6-1/8" CEMENTING RECORD Driven 525 sx PF 'L', 475 sx Class 'G' 700sx Econolite, 600 sx Class 'G' 380 sx Class 'G' 126 sx Class 'G' AMOUNT PULLED 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 SPF MD TVD MD TVD SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 13320' PACKER SET (MD) 13270' 25. 13860' - 13920' 11054' - 11083' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4000' Freeze Protected with 306 Bbls of Diesel. 27. PRODUCTION TEST r)ate First Production Method of Operation (Flowing, gas lift, etc.) May 9, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL 5-30-2003 4 TEST PERIOD 6187 10.44 5.85 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL Press. 24-HoUR RATE CHOKE SIZE GAS-OIL RATIO 160 1 .69 OIL GRAVITY-API (CORR) o ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit tore chips.' : No core samples were taken. I ..II} ... :- ¡'j l Form 10-407 Rev. 07-01-80 OK\G\NAL ~V Submit In DuPlicate~ ) 29. Geologic Markers Marker Name Measured Depth Top of Kuparuk 10996' Kuparuk 'C' 11250' Top of Miluveach 11742' Top of Kingak 12343' Top of Sag River 13478' Top of Shublik 13628' Top of Ivishak 13775' 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. 8938' 9115' 9474' 9948' 10839' 10948' 11013' , . 32. I hereby certify that the fore oing is true and correct to the best of my knowledge Signed SO~ Stewman Title Technical Assistant NS19 Well Number Date Db - ()L~ -0 ') 202-207 Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Allen Sherritt, 564-5204 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: Ifthis 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 OR1G1~jAL ib¡p ) ) Date: 07-29-2003 Transmittal Number:92658 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type ..NS17 08-25-2002 SCH 1-8 326 18360 VISION DENSITY NEUTRON - C' TVD )09~)l9 08-25-2002 SCH 1-8 326 18360 VISION DENSITY NEUT~ON - MD 08-25-2002 SCH 1-8 326 18360 VISION RESISTIVITY - MD 08-25-2002 SCH 1-8 326 18360 VISION RESISTIVITY - TVD 10-29-2002 SCH 1-5 265 14032 VISION DENSITY NEUTRON - TVD NS19 10-29-2002 SCH 1-5 265 14032 VISION DENSITY NEUTRON - MD 10-29-2002 SCH 1-5 265 14032 VISION RESISTIVITY - MD 10-29-2002 SCH 1-5 265 14032 VISION RESISTIVITY - TVD [NS12 05-17 -2003 SCH 1 11 800 13539 CH EDIT OF RST-SIGMA ON ~09-\ \ CD ROM; NS17 02-22-2003 SCH 1-8 395 18396 LDWG, LWD; CDR; DEN; NEU; CD ROM; NS19 03-25-2003 SCH 1 LDWG EDIT DATA; LWD DATA; ARCfN E UfD E NfC D R/RTG R; ON CD ROM; _NS16 12-02-2002 SCH 1 26 10985 LDWG CASED HOLE EDIT ~dJ ¡j-- OF PRIMARY DEPTH CONTROL LOG; ON CD ROM; NS12 05-17 -2003 SCH 1 11800 13539 RESERVOIR SATURATION TOOL; ~S16 12-02-2002 SCH 1 40 10985 PRIMARY DEPTH LOG; dOJ) RECEIVED ~"- \. ....../,,~~, ~....~~C'- ·v"- JUL 2 9 2003 Petrotechnical Data Center LR2-] Alaska o¡-¡ & Gas Cons. Gomrnieeion 900 E. Benson Blvd. PO Box ]966]2 And1crage Anchorage, AK 995] 9-66] 2 bjp BPXA WELL DATA TRANSMITTAL Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn: Kristin Dirks MMS Attn: Doug Choromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) Date: 07-29-2003 Transmittal Number:92658 : ,; ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 1m 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 1229' NSL, 646' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 7' NSL, 2574' WEL, SEC. 13, T13N, R13E, UM X = 663324, Y = 6024574 10. Well Number At total depth 5123' NSL, 2384' WEL, SEC. 24, T13N, R13E, UM X = 663517, Y = 6024415 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Northstar Unit RKB = 56.3' ADL 312809 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 10-29-2002 3-25-2003 5-3-2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14063 11153 FT 14058 11151 FT 1m Yes 0 No 22. Type Electric or Other Logs Run MWD, GR , DIR , RES, DEN, NEU Classification of Service Well 7. Permit Number 202-207 X = 659829, Y = 6031001 8. API Number 50- 029-23122-00 9. Unit or Lease Name Northstar Unit NS19 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1545' (Approx.) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 169# X-56 Surface 201' 20" Driven 13-3/8 " 68# L-80 Surface 3405' 16" 525 sx PF 'L', 475 sx Class 'G' 9-5/8" 47# L-80 Surface 11753' 12-1/4" 700sx Econolite, 600 sx Class 'G' 7" 26# L-80 11584' 13480' 8-1/2" 380 sx Class 'G' 4-1/2" 12.6# 13Cr 13309' 14062' 6-1/8" 126 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 SPF MD TVD 25. SIZE 4-1/2", 12.6#, 13Cr80 TUSING RECORD DEPTH SET (MD) 13320' PACKER SET (MD) 13270' MD TVD 13860' - 13880' 11054' - 11064' 13895' -13915' 11071'-11081' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4000' Freeze Protected with 306 Bbls of Diesel. 27. Date First Production May 9, 2003 Date of Test Hours Tested 5-30-2003 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BsL GAs-McF TEST PERIOD 6187 10.44 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BsL GAs-McF WATER-BsL 5.85 WATER-BsL CHOKE SIZE 160 OIL GRAVITY-API (CORR) o GAS-OIL RATIO 1.69 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ~s. , ~ECEIVED No core samples were taken. ~ r"" j__ > --, · .,~/ 5/..:::.;:. .-: : ·.,f:"':'..'':''~'I'I::·,_ .. ·6~',·~ . :~._'-" "~""': '... ~.' ",~".\ -"I ~,C~~ MDtMS BFl. ./ ~J- JUN 3 2003 JUN 0 2 2003 Form 10-407 Rev. 07-01-80 ORIG\NAL Alaska Oil & Gas Cons. Commission Anchorage Submit In Duplicate ), ) 29. Geologic Markers Marker Name Measured Depth Top of Kuparuk 10996' Kuparuk 'C' 11250' Top of Miluveach 11742' Top of Kingak 12343' Top of Sag River 13478' Top of Shublik 136281 Top of Ivishak 13775' ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8938' 9115' 94741 9948' 10839' 10948' 11013' RECE~\lED JUN 0 2 2003 Alaska Oil & Gas Cons. Commission Anchorage Summary of Daily Drilling Reports, Surveys, Post Rig Work Summary and a Leak-Off Integrity Test Summary. 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed sO~'v(~.f:_Á..'^-- Title Technical Assistant Date 0 CD .' LJ 1: 0'3 NS19 202-207 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Allen Sherritt, 564-5204 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 é:!jachments. 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 nRI~I'NAI ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From- To Hours Task Code NPT Phase Description of Operations 1 0/28/2002 19:00 - 20:00 1.00 MOB P PRE PJSM. Obtain permit to move rig. Move rig from NS-20 to NS-19. 20:00 - 21 :00 1.00 MOB P PRE Level the rig. 21 :00 - 21 :30 0.50 MOB P PRE Rig up. Complete Pre-Rig Inspection checklist. 21 :30 - 00:00 2.50 MOB P PRE NU riser Adapter. PT. -NU Riser. Accept Rig @ 2130 hrs. 10/29/2002 00:00 - 02:00 2.00 RIGU P PRE Install mousehole, P/U gyro & wireline tools, & BHA. 02:00 - 03:30 1.50 RIGU P PRE PJSM - slip & cut drilling line. 03:30 - 04:00 0.50 RIGU P PRE Service drawworks & adjust brakes. 04:00 - 05:00 1.00 RIGU P PRE Finish pre-spud checklist. 05:00 - 07:00 2.00 RIGU P PRE PIU BHA #1 & tag ice @ 62'. 07:00 - 08:00 1.00 RIGU P PRE PJSM - R/U wireline for gyro. 08:00 - 09:00 1.00 RIGU P PRE Pre - spud meeting wi all drilling personnel. 09:00 - 11 :00 2.00 DRILL P SURF Clean conductor (ice) & drill to 330'. 11 :00 - 11 :30 0.50 DRILL P SURF Run gyro & circulate. 11 :30 - 12:00 0.50 DRILL P SURF POH for BHA # 2. 12:00 - 13:00 1.00 DRILL P SURF LID BHA # 1. 13:00 - 13:30 0.50 DRILL P SURF Clean rig floor - PJSM for M/U BHA # 2. 13:30 - 14:30 1.00 DRILL P SURF M/U BHA # 2. 14:30 - 15:00 0.50 DRILL P SURF Wash down to 330'. 15:00 - 00:00 9.00 DRILL P SURF Drill, slide, & run gyros from 330' to 1095' md. 10/30/2002 00:00 - 08:00 8.00 DRILL P SURF Drill directional from 1095' to 1564' pumping sweeps before running gyros. Note: 1) Information correlated between MWD & gyro survey on 2 seperate surveys as follows: 1210' gyro 7.97 incl, 95.63 az 1210' MWD 8.14 incl, 96.18 az 1465' gyro 9.22 incl, 101.8 az 1465' MWD 9.25 incl, 103.61 az. 08:00 - 08:30 0.50 DRILL P SURF PJSM - LID gyro & RID wireliners while circulating @ reduced rate. 08:30 - 11 :00 2.50 DRILL P SURF Drill directional in 16" hole from 1564' to 1860' increasing flow rates up to 1100 GPM. 11:00-11:30 0.50 DRILL N FLUD SURF Clean up 15 gallon mud spill in cellar due to drip pan overflow. 11 :30 - 00:00 12.50 DRILL P SURF Drill directional in 16" hole from 1860' to 3264', pumping sweeps every 300'. Note: 1) In good shape directionally - latest survey @ 3190' 37.51 incl & 159.66 az 2) Flow rate following spill 850 GPM. 10/31/2002 00:00 - 03:00 3.00 DRILL P SURF Drill 16" directional hole from 3264-3426' md. Notes: 1. Pumped sweep just prior to reaching casing point. 2. Surface TO reached with good directional position. Survey at 3354' md - 38.46 deg - 160.4 azim. 03:00 - 05:00 2.00 CASE P SURF Circulate 2.5 X bottoms up. Pumped high vis. weighted sweep. Hole clean. 05:00 - 08:00 3.00 CASE P SURF Monitor well. POH to BHA. Monitor well. Note: 1) TOH was good wi no excessive drag. Avg. drag 5 - 10 K with Printed: 4/8/2003 9:02:07 AM f ) ') BP EXPLORATION Operations Summary Report Page 20f 17 Leg al Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/31/2002 05:00 - 08:00 3.00 CASE P SURF occasional drag to 20K on a few jts. 08:00 - 11 :00 3.00 CASE P SURF PJSM. Lay down BHA. 11 :00 - 12:00 1.00 CASE P SURF Clean up drill floor. 12:00 - 12:30 0.50 CASE P SURF PJSM - Rigging up Frank's tool and casing equipment held at pre tour meeting. Rig up Frank's Tool. 12:30 - 14:30 2.00 CASE P SURF Rig up to run casing. Loaded plugs in cement head. 14:30 - 20:00 5.50 CASE P SURF PJSM - Ran 81 jts. of 13 3/8" 68# L-80 casing with no losses. Casing went in slick with the exception of jts 53 & 76 @ 2220' & 3175' respectively. SIO weights down to 95K on each jt. Worked down without problems or washing. 20:00 - 20:30 0.50 CASE P SURF R/U landing jt. & hangar & land hangar. 20:30 - 21 :00 0.50 CASE P SURF LID Frank's fill up tool & M/U HOWCO cementing head. 21 :00 - 23:00 2.00 CASE P SURF Establish circulation by staging up pumps from .5 to 10 BPM. Initial circulating pressure @ .5 BPM was 270 psi, final circulaing pressure @ 10 BPM was 410 psi. Held PJSM for cement job while circulating. 23:00 - 00:00 1.00 CEMT P SURF Pump 5 bbls water & test cement lines to 3500 psi. Pump 75 bbls. 10.5 ppg spacer. 11/1/2002 00:00 - 02:30 2.50 CEMT P SURF Pump 388 bbls 10.7 ppg Type "L" lead cement followed by 96 bbls 15.9 ppg class G tail cement @ 6 - 8 BPM. Drop bottom plug & chase wI 25 bbls. wash water from Halliburton pumping unit. Displace cement wI 472 bbls. wI rig pump. ( Last 20 bbls pumped was sea water) Bumped plug @ 96% pump efficiency. Held 1700 psi. on casing for 5 minutes. Bled off pressure & checked floats. OK 02:30 - 04:30 2.00 CEMT P SURF LID cement head, BIO & LID landing jt, flush out flow line & riser, BID lines, & remove casing handling tools from rig floor. 04:30 - 05:30 1.00 WHSUR P SURF RID surface riser & adaptor. 05:30 - 06:30 1.00 WHSUR P SURF N/U Vetco Gray multi-bowl ass'y & test to 2000 psi. 06:30 - 11 :00 4.50 BOPSURP SURF N/U BOP's - skid rig floor to line up riser. 11:00-13:00 2.00 BOPSURP SURF P/U test jt, install test plug & prepare to test BOP's. 13:00 - 14:00 1.00 BOPSURP SURF Test BOP's to 4800 1250 psi for 5/5 min. 14:00 - 14:30 0.50 BOPSURP SURF PJSM - Testing BOP's. Crew change out day. 14:30 - 18:30 4.00 BOPSUR P SURF Test BOP's to 4800 I 250 psi for 5/5 min. Test annular to 3500 psi. 18:30 - 19:30 1.00 BOPSURP SURF RID from BOP test. LID test plug & test jt. BID lines. 19:30 - 20:00 0.50 BOPSUR P SURF Install wear bushing. 20:00 - 00:00 4.00 CASE N RREP SURF PJSM - 1) Modify possum belly to accomodate more fluid from flow line discharge. 2) Spray foam insulation & silicone drip pan underneath drawworks. 3) Repair leak on top drive pipe handler by replacing cylinder. 11/2/2002 00:00 - 01 :30 1.50 CASE N RREP SURF 1) Complete possum belly modification to accomodate more fluid from flow line discharge. 2) Complete cleaning & sealing drip pan underneath drawworks. 01 :30 - 04:00 2.50 CASE N RREP SURF Replace cylinder in top drive pipe handler. 04:00 - 04:30 0.50 CASE P SURF Service top drive. 04:30 - 06:30 2.00 CASE P SURF PJSM - M/U BHA #3 - shallow test RSS - BID top drive 06:30 - 07:30 1.00 CASE P SURF Finish PIU BHA. I Printed: 4/8/2003 9:02:07 AM ) ) EXPLORATION Operations Sum maryReport Page 3 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/2/2002 07:30 - 09:00 1.50 CASE P SURF RIH to 3319' washing down the last stand & tag plugs on top of FC. 10' of cement on top of plugs. 09:00 - 10:00 1.00 CASE P SURF Circulate cement until equivalent MW in = MW out. 9.0 ppg 10:00 - 11 :00 1.00 CASE P SURF Test 13 3/8" casing to 3550 psi & hold for 30 minutes. Notes: 1) Reviewed 01 02, & 05 drills with crew during test. 2) Discussed drilling hazards associated wI intermediate hole section. 11 :00 - 15:00 4.00 CASE P SURF Drill plugs, cement & 20' of new hole to 3446'. Started displacement of old mud with new 8.6 ppg after drilling float shoe. 15:00 - 15:30 0.50 CASE P SURF Finish mud swap & circulate until MW in = MW out @ 8.6 ppg. 15:30 - 16:00 0.50 CASE P SURF Perform FIT to 12.5 EMW wI 8.6 ppg. (650 psi) 16:00 - 16:30 0.50 DRILL P INT1 Establish clean hole ECD baselines. 16:30 - 00:00 7.50 DRILL P INT1 Drill 12 1/4" directional wI RSS from 3446' to 4478'. Notes: 1) Pumping hi-vis barofibre sweeps every 400' wI 5% to 10% excess seen @ shakers. 2) RSS responding to down links. 3) ECD's are good - 9.3 to 9.4 wI 8.7 to 8.8 ppg MW. 11/3/2002 00:00 - 00:00 24.00 DRILL P INT1 Drill 12 1/4" hole wI RSS from 4478' to 7035' md. Notes: 1) Adjust RPM and or WOB to address drill string harmonics. Some stick slip occurring regardless of adjustments being made, especially on hard streaks. 2) Mud system contains 2 - 2.5% lubricants for torque reduction w/lubetex, torque trim, & BDF 263. Condet & Clayseal to prevent bit balling & screen blinding. 3) Pumping hi-vis barofibre sweeps every 400'. 4) ECD's in 9.5 to 9.6 range wI 8.9 - 9.0 ppg MW's. 11/4/2002 00:00 - 16:00 16.00 DRILL P INT1 Drill ahead in 12 1/4" hole wI RSS from 7035' to 8138' md. 16:00 - 16:30 0.50 DRILL P INT1 Service top drive. 16:30 - 00:00 7.50 DRILL P INT1 Drill ahead in 12 1/4" hole wI RSS from 8138' to 8995" md. Notes: 1) Pumping hi-vis barofibre sweeps every 400' wI 0 - 10% additional cuttings. 2) Maintaining 2.5 - 3% lubricants. 3) ECD's 9.7 - 9.85 range wI 9.1 - 9.2 ppg MW's. No ECD spikes. 4) RSS responding to downlinks. 11/5/2002 00:00 - 12:00 12.00 DRILL P INT1 Drill directional wI RSS from 8995' - 10393' md. Notes: 1) Adjust RPM & WOB to address drill string harmonics as needed. 2) Maintaining 3% lubricants. 3) Pumping hi-vis barofibre sweeps every 400'. 12:00 - 13:00 1.00 DRILL P INT1 Condition & circulate mud. Add 12.7 ppg spike fluid to get 10.1 ppg MW. 13:00 - 17:00 4.00 DRILL P INT1 Drill from 10393' to 10770' md. 17:00 - 17:30 0.50 DRILL P INT1 Lubricate blocks & service top drive. I Printed: 4/8/2003 9:02:07 AM ') ') BP EXPLORATION OperátionsSummary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From -To Hours Task Code NPT Phase Description of Operations 11/5/2002 17:30 - 00:00 6.50 DRILL P INT1 Drill from 10770' to 11227'. Top of HRZ 8606'ND -10546' md. Top of Kuparuk 8939' TVD - 10998' md. 11/6/2002 00:00 - 01 :30 1.50 DRILL P INT1 Drill 12 1/4" hole wI RSS from 11227' to 11260' 01 :30 - 03:00 1.50 DRILL N RREP INT1 Repair wash out on #2 mud pump discharge manifold. 03:00 - 11 :30 8.50 DRILL P INT1 Drill 12 1/4" hole wI RSS from 11260' to 11778'. 11 :30 - 14:00 2.50 DRILL P INT1 Pump 50 bbl. hi-vis weighted sweep (13.2 ppg) @ TO. Condition & circulate mud for easing. 14:00 - 14:30 0.50 DRILL P INT1 Monitor well - pull 5 stands - pump dry job & BID top drive. 14:30 - 16:30 2.00 DRILL P INT1 POH to 8400'. A few tight spots In the Kuparuk & HRZ wI 40K Ibs drag. Wiped through tight spots once & excess drag was gone. 16:30 - 17:30 1.00 DRILL P INT1 Spot 150 bbl. 20 ppb steel seal pill across Schrader Bluff - pump dry job - BID lines. 17:30 - 20:30 3.00 DRILL P INT1 Continue POH to shoe. Remainder of trip was good wI no excessive drag or swab. 20:30 - 21 :00 0.50 DRILL P INT1 Circulate 1 BIU @ shoe wI minimal returned cuttings. 845 gpm 21 :00 - 21 :30 0.50 DRILL P INT1 POH to 3350' - circulate @ 4 BPM while holding PJSM for slip & cut. 21 :30 - 22:30 1.00 DRILL P INT1 Slip & cut 102' of drilling line. 22:30 - 00:00 1.50 DRILL P INT1 Continue POH. LID porcupine reamer & dart sub. Note: Porcupine reamer not missing any inserts as in past. 1 insert hanging loosely. 11/7/2002 00:00 - 03:30 3.50 DRILL P INT1 Continue to Lay down BHA. BHA not balled up- clean. Bias unit had one washed out seal. Bit in good shape- 1-0-ln gage. Good Drilling Practices evident by bit! BHA condition. 03:30 - 04:30 1.00 DRILL P INT1 Clear rigfloor. Pull Wear Ring and Install Test Plug. 04:30 - 06:30 2.00 CASE P INT1 PJSM. Change out top rams to 9.5/8" and test doors to 3500- psi. Pull Test PLug. While working on Rams remove Stabilisers from rigfloor and bring up casing equipment. 06:30 - 08:00 1.50 CASE P INT1 PJSM. RIU to run 9.5/8" casing installing Franks Tool and long bails. 08:00 - 09:30 1.50 CASE P INT1 M/U 9.5/8" Shoetrack and check floats- OK. 09:30 - 13:30 4.00 CASE P INT1 Run 9.5/8" Casing to the 13.3/8" Shoe @ 3400 ft. No losses. 13:30 - 14:00 0.50 CASE P INT1 Circulate Casing contents @ 10 BPMI 800 psi. No Losses. 14:00 - 22:30 8.50 CASE P INT1 Run 9.5/8" Casing to 10,663 ft. Taking a little weight ( 80 klbs). Just above the HRZ at base of Colville. All joints Making up @ 9,900 ftlbs. Each Joint checked for Triangle. 22:30 - 23:00 0.50 CASE P INT1 Circulate joint above HRZ- Precautionary. 3 BPMI 1020 psi. Full Returns. All Parameters steady. 275 kbs down 470 klbs Up. 23:00 - 00:00 1.00 CASE P INT1 Continue to run 9.5/8" Casing. No problems at Top of Kuparuk. Total Losses for casing runing Operation Approx 55 bbls. Total Joints run of 47 11ft, L-80, BTC-M = 286. 11/8/2002 00:00 - 00:30 0.50 CASE P INT1 Run the last 5 jts. of 9 5/8" 471b. L-80 mod. buttress casing & PIU landing jt. Printed 4/8/2003 9:0207 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From·- To Hours Task Code NPT Phase Description of Operations 11/8/2002 00:00 - 00:30 0.50 CASE P INT1 Ran a total of 286 jts. casing. 00:30 - 04:00 3.50 CASE P INT1 Wash down landing jt @ 3 BPM - 1160 psi. Kept hangar 5' above load shoulder while staging up pumps. Stage pumps from 3 BPM to 9 BPM - initial circulating pressure 1160 psi, final pressure 1300 psi. Land hangar 45 minutes into circulation. Hangar weight in slips 315,000 Ibs with top drive & blocks included, 245,000 Ibs. without. Held PJSM for cement job while circulating. 04:00 - 08:30 4.50 CEMT P INT1 PJSM - RID Frank's tool, install cement head & x-over, & test lines to 4,000 psi. Pump 50 bbls. 11.0 ppg weighted spacer & drop bottom plug. Pump 402 bbls. 11.2 ppg lead slurry followed by 124 bbls. 15.2 ppg tail slurry. Drop bottom plug & chase with 25 bbls. of water from HOWCO & turn over to rig pump. Displace cement wI 829 bbls. mud. Bumped plug @ 900 psi. wI 94.1 % pump efficiency. Test casing to 1400 psi & held for -8 minutes. Pressure held. Bleed off pressure & checked floats - OK. 08:30 - 09:30 1.00 CEMT P INT1 RID cement head, casing equip't , & LID landing jt. 09:30 - 10:30 1.00 WHSUR P INT1 Install elevators, P/U stand, drain & flush BOP, install packoff & test to 5000 psi for 10 min. 10:30 -13:30 3.00 CEMT P INT1 RlU to pump down 13 3/8" x 9 5/8" annulus. Pump 210 bbls 10.5 ppg mud down annulus. Broke down @ 900 psi - final pressure was 590 psi. LID packoff running tool, stand back stand DP, take off long bails, drain stack, & change out 9 5/8" rams for 7" x 4 1/2" variables while pumping down annulus. 13:30 - 14:00 0.50 CEMT P INT1 PJSM - Install bails & elevators. 14:00 - 15:00 1.00 CEMT N RREP INT1 PJSM - Write procedure for removing stabbing board. 15:00 - 16:30 1.50 CEMT N RREP INT1 Remove stabbing board & set in pipeshed. 16:30 - 18:00 1.50 BOPSURP INT1 PJSM - drain stack & prep for BOP test. 18:00 - 23:00 5.00 BOPSUR P INT1 Test BOP's to 250 14800 psi for 5 I 5 min. Drip @ unibolt on choke hose - CIO ring & retest. 23:00 - 23:30 0.50 BOPSURP INT1 BID all lines. 23:30 - 00:00 0.50 BOPSUR N RREP INT1 Unable to pull test plug - drain stack & see annular preventer element protruding on the inside of riser. Land test plug, back out test jt. & LID. 11/9/2002 00:00 - 02:00 2.00 BOPSUR N RREP INT1 Clean rotary table drip pan & NID risers. 02:00 - 06:00 4.00 BOPSUR N RREP INT1 CIO annular preventer element. 06:00 - 07:30 1.50 BOPSURN RREP INT1 NIU riser. 07:30 - 08:30 1.00 BOPSURN RREP INT1 RlU & test annular to 3500 psi. RID test equip't. 08:30 - 09:00 0.50 WHSUR P INT1 Pull test plug & install wear ring. 09:00 - 09:30 0.50 DRILL P INT1 Clean cellar & rig floor. 09:30 - 10:00 0.50 DRILL P INT1 PJSM for M/U BHA # 4. Printed: 4/8/2003 9:02:07 AM ) ) Legal Well Name: NS19 Common Well Name: NS19 Spud Date: 10/29/2002 Event Name: DRILL +COMPLETE Start: 10/28/2002 End: 3/31/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/31/2003 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 11/9/2002 10:00 - 11 :30 1.50 DRILL P INT1 M/U BHA # 4. 11 :30 - 12:00 0.50 DRILL P INT1 Shallow test MWD & Rotary steerable power drive @ 400 GPM - 500 psi. 12:00 - 13:30 1.50 DRILL P INT1 Continue M/U BHA # 4. 13:30 - 16:30 3.00 DRILL P INT1 RI H to 8900'. 16:30 - 18:30 2.00 DRILL N RREP INT1 PJSM - Install stabbing board. 18:30 - 19:30 1.00 DRILL P INT1 Continue RIH from 8900' to 11545' 19:30 - 20:00 0.50 DRILL P INT1 Wash down from 11545' & tag cement @ 11644'. 20:00 - 20:30 0.50 DRILL P INT1 Circulate MW in = MW out @ 10.5 ppg. 20:30 - 21 :30 1.00 CASE P INT1 Pressure test 9 5/8" casing to 3900 psi & hold for 30 min. 11.4 bbl pumpl return. Discuss well control & drilling hazards associated wI 8 1/2" hole section while testing casing. Review 01, 02, & 05 drills. Perform 08 - muster drill. 21 :30 - 22:30 1.00 DRILL N RREP INT1 Replace suction valve in pit 1 D. 22:30 - 23:00 0.50 DRILL P INT1 Drill cement on top of plugs from 11644' to 11667' Tag plugs @ 11667'. 23:00 - 00:00 1.00 DRILL N RREP INT1 Lost power on rig. 13/8 highline breaker closed along wI gas valve on piperack due to gas/low pressure. No gas detected inside rig. Safety did not detect any gas venting at piperack. Trying to establish why ESD activated. 11/10/2002 00:00 - 00:30 0.50 DRILL N RREP INT1 Restore hi-line power to rig. 00:30 - 03:00 2.50 DRILL P INT1 Drill out FIC plugs & shoe track. Started adding spike fluid for 12.8 ppg MW @ 01 :50 hrs. 03:00 - 06:15 3.25 DRILL P INT1 Drill 9" hole wI RSS from 11778' to 11798 md. Pumped 2 walnut I sapp sweeps for bit balling wI limited success. Knocked ball off bit by bouncing off bottom. Dressing out mud to 12.8 ppg MW while drilling 20' of new hole. Took 2 full circulations. 06:15 - 07:00 0.75 DRILL P INT1 Perform FIT to 14.5 EMW wI 12.7 ppg MW @ 890 psi. 07:00 - 07:30 0.50 DRILL P INT1 Establish ECD baselines as follows: 11798' 600 GPM, 0 RPM - ECD 13.67 11798' 600 GPM, 60 RPM - ECD 13.66 11798' 600 GPM 120 RPM - ECD 13.71 07:30 - 18:00 10.50 DRILL P INT1 Drill 9" hole wI RSS from 11798' to 12114' md. Pumping walnut I sapp sweeps for bit balling. Adding barite to maintain 12.8 - 12.9 ppg MW. 18:00 - 18:30 0.50 DRILL P INT1 Service top drive & blocks. 18:30 - 00:00 5.50 DRILL P INT1 Drill ahead from 12114' to 12290'. P-rates 15-50 fthr. Drilling parameters indicating bit balling tendencies. Printed: 4/8/2003 9:02:07 AM ) ) IBP.··IE'><Pl2(J)fRAmIGN Operâflons····SLlmI11ary·· ·Rêpon Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 From - To Hours Task Code NPT Phase Description of Operations 11/10/2002 18:30 - 00:00 5.50 DRILL P INT1 11/11/2002 00:00 - 12:00 12.00 DRILL P INT2 Drill ahead in 9" hole wI RSS from 12290' to 12473'. Hit Kingak @ 12,390 ft. P-rates still low. Torque response indicated that bit was digging but slowly. 15-25 ftIhr. Slow ROP due to frequent bit balling. Nut plug I sapp sweeps non-productive. 12:00 -13:00 1.00 DRILL N DFAL INT2 Condition & circulate mud @ 630 GPM for TOH. 13:00 - 13:30 0.50 DRILL N DFAL INT2 Monitor well - POH wI 8 stands to 9 5/8" shoe. 13:30 - 14:00 0.50 DRILL N DFAL INT2 Monitor well @ shoe - pump dry job - BID lines. 14:00 - 17:15 3.25 DRILL N DFAL INT2 Continue POH to HWDP - monitor well for 15 min. 17:15 - 18:30 1.25 DRILL N DFAL INT2 Handle BHA # 4. Bit in good shape. Rest of BHA in good shape. 18:30 - 18:45 0.25 DRILL N DFAL INT2 Clear & clean rig floor. 18:45 - 19:30 0.75 DRILL N DFAL INT2 Download COR & test bias unit. 19:30 - 20:00 0.50 DRILL N DFAL INT2 Mlu BHA # 5. 20:00 - 22:30 2.50 DRILL N DFAL INT2 RIH to 6930'. 22:30 - 00:00 1.50 DRILL N SFAL INT2 Air boots on riser leaking. Attempts to air back up & repair with fix-a-flat were unsuccessful. PJSM - pull riser and replace air boots. No mud found its way to secondary containment- about 0.5 gallon on top of annular. Good Spot by the Shaker Hand- prevented potential spill. 11/12/2002 00:00 - 01 :30 1.50 DRILL N SFAL LNR1 Repace air boots on riser. 01 :30 - 04:00 2.50 DRILL N DFAL LNR1 RiH to 11356' md. 04:00 - 06:30 2.50 DRILL N DFAL LNR1 PJSM. Slip and cut drilling line. Adjust brakes. Service Top Drive. 06:30 - 07:00 0.50 DRILL N DFAL LNR1 RIH to 12403' md. Hole in Good shape- no problems. 07:00 - 08:00 1.00 DRILL N DFAL LNR1 Wash from 12403' to 12473' md. Stage up pumps. Some high pressures early on - 500 GPMI 4100 psi. 08:00 - 00:00 16.00 DRILL P LNR1 Drill ahead 9" hole from 12473' md to 13260' md. No Drag, No losses. ECD steady @ 14.0 ppg. RPM @ 160 and Flowrate running @ 625 GPM/3900 psi. Pump Back 90 ft on each stand. Assembly with DS-70 tending to build. Set RSS @ 20%/36 degs. Sperry Keeping a close Eye on cuttings- no obvious splinters. - ROP from 50- 100 fph. Top Sag @ 13,470 ft MD, 10,835'ND 11/13/2002 00:00 - 03:30 3.50 DRILL P LNR1 Drlg f/13262' - 13500' md. Note: Top of Sag @ 13470' md. 03:30 - 05:30 2.00 DRILL P LNR1 Pump Sweep and CBUx2. Note: Spot new 13.0 ppg pill across open hole interval. 05:30 - 07:00 1.50 DRILL P LNR1 Montor Well and POOH to 11700' md (inside 9-5/8" csg shoe). Printed: 4/8/2003 9:0207 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Descri ptionof· Operations 11/13/2002 05:30 - 07:00 1.50 DRILL P LNR1 Note: 250-350K Ibs max, Max Drag 50K & Avg Drag 15K. 07:00 - 07:30 0.50 DRILL LNR1 Monitor Well, Pump Dry Job and BID Top Drive. 07:30 - 11 :00 3.50 DRILL P LNR1 POOH to 1007' md @ BHA. 11 :00 - 13:30 2.50 DRILL P LNR1 POOH while LD 26 jts of HWDP. LD BHA#5. Notes: 1. Bit was in great shape -- one plugged nozzle. 2. Near bit reamer was missing the cutters on all 3 blades. 3. BHA was clean with no sign of balling or clay build up. 13:30 - 14:00 0.50 DRILL P LNR1 Clear and Clean rig floor. 14:00 - 14:30 0.50 CASE P LNR1 PJSM -- RU 7" liner running equipment. 14:30 - 18:00 3.50 CASE P LNR1 PJSM -- Run 46 Jts of 7" 26# Hydril 521 liner. 18:00 - 18:30 0.50 CASE P LNR1 PU Hanger Assembly. 18:30 - 19:00 0.50 CASE P LNR1 Mix and pour PAL-MIX inside 7" liner top. Allow 30 mins for mix to set up. 19:00 - 00:00 5.00 CASE P LNR1 RIH wi 7" liner on 5" DP filling every 10 stands. 11/14/2002 00:00 - 03:00 3.00 CASE P LNR1 RIH wi 7" drilling liner fl 7264' md to 11680' md (inside 9-5/8" casing shoe). - Running speed 1 minute per stand. - Fill DP per 10 stands. 03:00 - 04:00 1.00 CASE P LNR1 Circulate DP + liner volume (241 bbls) @ 5.5 bpm wi 925 psig. Take Parameters: - UWT= 285 K, DWT= 215 K, and RWT= 250 K Ibs - 35 rpm wi 11 K-Ibs torque. 04:00 - 06:45 2.75 CASE P LNR1 RIH into open hole wi 7" drilling liner to 13362' md. - Encounter minor tight spots @ 12436', 12473' and 12675' md. - Encounter more trouble through fault. Necessary to work pipe numerous times -- loosing ground. At 13082' md, got though by rotating at 40 rpml 11 K torque wlo pump. 06:45 - 09:30 2.75 CASE P LNR1 Wash from 13362' md to 13411' md -- pump 1 to 2.5 bpm with no rotary. * Packed off at 13393' and 13411' md. * Unable to advance past 13,411 -- packing off and losing ground. Established rotation @ 30 rpm while pumping 2.5 bpm -- wash and ream from 13411 to 13485' md (set liner 10' into top of Sag @ 13480' md. Did not attempt to wash liner into bottom 15' of rathole). * Packing off occured frequently. Finally able to eliminate packoff by reducing pump rate to 1 bpm and rotating 25 rpm. - Last 60' washed and reamed with no apparent problems. Did not take weight or shows signs of packing off. No trouble getting into Sag. 09:30 - 10:15 0.75 CEMT P LNR1 RU cement head. - Change out leaking valve on cement manifold. 10:15-11:30 1.25 CEMT P LNR1 Establish circulation and stage up rate in 112 bpm increments to 3 bpm and 1 bpm increments to 5 bpm. Increase rate to final clean up rate of 5.5 bpm wi 1070 psig. - Off bottom parameters: ROT 265 K wi 20 rpm and 14 K-Ibs torq. - UWT= 350 K & DWT= 235 K Ibs. 11 :30 - 12:30 1.00 CEMT P LNR1 Drop and pump ball @ 5.5 bpm. 12:30-13:00 0.50 CEMT P LNR1 1. Place ball on seat and pressure up to 2000 psi and set hanger. Printed: 4/8/2003 9:02:07 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION Operations Summary Rep.ort NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E 11/14/2002 12:30 -13:00 From - To Hours Task Code NPT Phase 13:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:15 15:15 - 16:15 16:15 - 16:30 16:30-17:15 17:15-18:00 18:00 - 21 :45 0.50 CEMT P LNR1 0.50 CEMT P 0.50 CEMT P 0.50 CEMT P 0.75 CEMT P LNR1 LNR1 LNR1 LNR1 1.00 CEMT P LNR1 0.25 CEMT P LNR1 0.75 CEMT P LNR1 0.75 CEMT P 3.75 TA P LNR1 SURE Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Description of Operations 2. Pressure up to 3200 psi and release running tool. 3. Picked up 3' past neutral point - unable to determine whether free of liner. PU an addtional 2' to make determination -- still not able to determine of off liner. 4. Blowout ball seat @ 4150 psi. Had driller shut off pumps immediately due to losses occurring on past 2 wells. - Pressure bled off immediately to 2600 psi and trapped -- signs of packoff down hole around liner shoe. - Monitored pressure for 5 minutes as slowly bled down to 300 psi. Well flowing with mud back at shaker. - 300 psi trapped -- re-establish circulation by bringing pumps on @ 1 bpm increments up to 5 bpm -- packed off. - Shut down pumps and bled off pressure to 100 psi. - Re-established circulation at 0.5 bpm and increased to 1 bpm. Patiently increased pumped rate in 1 bpm increments to 5.5 bpm over 1.5x open hole volume. Note: The total circulation time from time liner was on bottom to time to cement was increased by an extra hour to account for rig crew tour change and Halco crew change via chopper. Circulate. Halco crew change. PJSM for cement job -- no circulation. PT cement lines to 4000 psig wI 13.0 ppg ALPHA Spacer. Pump 35 bbls Alpha spacer total. Mix and pump 102 bbls (379 sxs) of 15.9 ppg tail cement at 5 bpm as per plan. -TT= 5 hrs:2mins. - Did not rotate liner during cement job. Drop plug and switch to rig pumps. Displace cement with 12.8 ppg Mud.@ 5.5 bpm wI full returns. - Slow rate and latch up @ 94% efficiency. Increase rate and bump plug to 1900 psig wI 96% efficiency. HOWCO meter 275 bbls (96% efficiency). Hold pressure for 1 min. - check floats. - No problem latching dart or bumping plug as has been the case for last 2 wells. Note: Cement in place at 16: 15 hrs. Slack Off wlo rotation and set ZXP liner top packer wi 80 K Ibs- see shear and set. PU to neutral and rotate down on liner top wI 50 K Ibs - verify ZXP set. Pressure up to 800 psig and circulate at max rate after seeing pressure loss while PU. - CBU. Estimated 20 bbls cement returned. Spacer and cement carrying quite a bit of shale - 30% spintered and 70% tabular. - Did not experience problems releasing running tool from liner as has been the case on past wells. Lay down cement head and 2 Jts of DP. PJSM for SW Displacement. - Displace well over to SW. Pump 200 bbls Sea Water. Follow wI 70 bbls Hi vis sweep and displace wI 820 bbls of sea water. Final NTU 380. Printed: 4/8/2003 9:02:07 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 1 0/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2002 21 :45 - 22:15 0.50 TA P SURE Negitive flow test well. 22: 15 - 22:45 0.50 TA P SURE POH w/12 stds. 22:45 - 23:30 0.75 TA P SURE PJSM. Monitor well. Change out drilling sweep to production sweep on upper annulus. 23:30 - 23:45 0.25 TA P SURE Fill hole and monitor well. 23:45 - 00:00 0.25 TA P SURE POOH w/ HRD running tool. 11/15/2002 00:00 - 03:45 3.75 TA P SURE Continue out of hole wI HRD liner running tool. - Tool in good shape and sheared properly. 03:45 - 04:45 1.00 TA P SURE LD Liner running tool. PU, break-out, and LD cement head. 04:45 - 06:00 1.25 T A P SURE HALCO pressure test Well bore to 4800 psig and record on chart (15 bbls to pressure up/15 bbls bled back). - Blowdown lines. 06:00 - 07:45 1.75 TA P SURE PU HWDP and RIH Open Ended for FP. 07:45 - 09:30 1.75 TA P SURE Reverse circulate 125 bbls diesel while taking returns to Trip Tank for volume verification. 09:30 - 10:30 1.00 T A P SURE U-tube diesel. 10:30 - 12:15 1.75 TA P SURE Bleed off 120 psig after U-tube completed. POOH w/ HWDP. 12:15 - 13:15 1.00 BOPSUR P SURE Pull wear bushing. Fill well with SW 13:15 - 14:15 1.00 BOPSUR P SURE MU tubing hanger wI TWC installed. - RIH on Std of HWDP. Land & Test seals to 5000 psig. 14:15 - 16:00 1.75 BOPSURP SURE Pressure Test TWC from below to 4200 psi for 5 mins. Bleed off pressure. Blow down lines. 16:00 - 19:00 3.00 BOPSUR P SURE NO BOP stack. 19:00 - 19:30 0.50 BOPSUR P SURE Island Muster Drill. Account for everyone on rig. Load personnel into ARKTOS. 19:30 - 21 :00 1.50 BOPSURP SURE Continue NO BOP's. 21 :00 - 00:00 3.00 WHSUR P SURE NU dry- hole tree. Pressure test bonnet & tree to 5000 psig. - Prep for rig move. - At Pre-tour conduct PJSM for rig move to NS-21. - Obtain permit to move from OPS at midnight. - Complete post-job inspection wI Night Operator for NS-19. - Complete pre-job inspection for well NS-21. RELEASE RIG AT MIDNIGHT. 3/22/2003 00:00 - 03:30 3.50 MOB P PRE Move rig from NS16 to NS19. 03:30 - 06:00 2.50 MOB P PRE Center rig over hole, level, and shim. 06:00 - 08:00 2.00 MOB P PRE Prepare rig for drilling as per Pre-Spud Checklist. Rig Accepted at 0800 hrs 03/22/03 08:00 - 08:30 0.50 RIGU P PRE PJSM -- NO tree 08:30 - 09:30 1.00 RIGU P PRE Pull BPV. NO dry hole tree. Install drilling sweeps. 09:30 - 10:00 0.50 BOPSUB P PRE PJSM -- NU BOP's 10:00 - 13:30 3.50 BOPSUB P PRE Nipple up BOP, turnbuckles, Koomey lines, and choke line. 13:30 - 17:00 3.50 BOPSUB P PRE PJSM -- Nipple up risers. 17:00 - 17:30 0.50 BOPSUR P PRE Pull Hanger. 17:30 - 18:00 0.50 BOPSU~P PRE PJSM -- Rig up test joint and plug for BOP test. 18:00 - 23:00 5.00 BOPSU P PRE Test BOP to 250 psi low and 4800 psi high. 5 minutes each. 23:00 - 23:30 0.50 BOPSU P PRE Pull test plug and install wear ring. 23:30 - 00:00 0.50 BOPSUR P PRE Blow down all lines and clear rig floor. I Printed: 4/8/2003 9:02:07 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/23/2003 00:00 - 01 :30 1.50 MOB P PRE Trip in hole with 5" OEDP to 2200' MD. 01 :30 - 02:00 0.50 MOB P PRE PJSM for diesel transfer to G&I. NOTE: ACS, Operations, G&I, and rig personnel present. 02:00 - 04:30 2.50 MOB P PRE Displace freeze protection fluid from well at 1.5 bpm through the trip tank to G&I NOTE: Trip tank covered with mats. Benzene monitoring - 0.2 ppm maximum reading. 04:30 - 05:00 0.50 MOB P PRE Monitor well for 30 minutes. 05:00 - 06:00 1.00 MOB P PRE Trip out of hole. 06:00 - 06:30 0.50 CEMT P LNR1 PJSM with Halliburton for casing test. 06:30 - 07:30 1.00 CEMT P LNR1 Test casing to 4800 psi with Halliburton for 30 minutes. 07:30 - 08:00 0.50 CEMT P LNR1 Pre-spud meeting with Company Rep. NOTE: 1. Discussed goals and high points of the program. 2. Discussed Loss Circulation Decision Tree (Pay-zone drilling) and well control contingency. 08:00 - 11 :30 3.50 CEMT P LNR1 PJSM -- Picked up BHA and shallow hole test MWD. 11 :30 - 12:45 1.25 CEMT P LNR1 RIH with 4" drillpipe (24 stands) 12:45 - 13:00 0.25 CEMT P LNR1 PJSM -- Change out tools to 5". RIH with one stand. 13:00 -14:15 1.25 CEMT P LNR1 PJSM -- Cut and slip drilling line (102 feet). 14:15 -15:00 0.75 CEMT P LNR1 Service top drive and crown. 15:00 - 19:00 4.00 CEMT P LNR1 Run in hole with 5" drillpipe to 11,491' MD Uust above 7" liner top at 11,585' MD). 19:00 - 20:00 1.00 CEMT P LNR1 Fill pipe with viscosified brine. Blow down. 20:00 - 21 :00 1.00 CEMT P LNR1 Continue to run in hole with 5" (114 stands) to 13,392' MD. Tag landing collar on stand 115. 21 :00 - 23:00 2.00 CEMT P LNR1 Drill up landing collar. NOTE: 1. Swap out to 9.2 ppg mud. 23:00 - 00:00 1.00 CEMT P LNR1 Drill shoe track from 13,400' to 13,486' MD. 3/24/2003 00:00 - 03:30 3.50 CEMT P LNR1 Drill shoe at 13,496' MD. Control drill rat hole to 13,500' MD. Slide 20' of new formation to 13,520' MD. NOTE: Obtained LWD GR data - no MAD pass required. 03:30 - 04:00 0.50 CEMT P LNR1 Perform FIT to 11.5 ppg EMW. NOTE: 1. 1300 psi on drillpipe (42 strokes). 2. Took 3.5 bbls of fluid to pressure up. 04:00 - 00:00 20.00 DRILL P PROD1 Drill I slide ahead from 13,520' - 13,869' MD. No drag, No losses. Built angle to 60 degs. NOTE: PU - 360K SO - 225K RT - 360K Printed: 4/8/2003 9:0207 AM " ) ) BP EXPLORATION Operations Summary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/24/2003 04:00 - 00:00 20.00 DRILL P PROD1 Torque -14.0 -17.5K 1. Top Ivishak at 11 ,016'ND 113,782' MD 2. Motor set at 1.50 bend yielded 14.5/100' with 100% slide over 30' coarse length. No problems sliding. 3. Bha dropping 0.3/100 rotating. 3/25/2003 00:00 - 06:30 6.50 DRILL P PROD1 Drill from 13869' - 14063' MD. 06:30 - 07:00 0.50 DRILL P PROD1 Circulate 4 open hole volumes (100 bbls). 07:00 - 11 :30 4.50 DRILL P PROD1 MAD pass from TO to 7" shoe at 180 ft/hr. NOTE: Pump and rotate out. 11 :30 - 12:00 0.50 DRILL P PROD1 Drop ball to open PBL. 12:00 - 13:45 1.75 DRILL P PROD1 Condition mud and circulate with PBL open at 15 bpm/2200 psi. Appreciable amount of cuttings came back with sweep ( 50 bbl LCM pill) 13:45 - 14:30 0.75 DRILL P PROD1 Drop locking ball for PBL. 14:30 - 15:00 0.50 DRILL P PROD1 Monitor well for 30 minutes. 15:00 - 15:30 0.50 DRILL P PROD1 Pump dry job (2 ppg over mud weight). Blow down line. 15:30 - 16:30 1.00 DRILL P PROD1 POH to 11550' MD (top of 7" liner). 16:30 - 16:45 0.25 DRILL P PROD1 Monitor well for 15 minutes. 16:45 -18:15 1.50 DRILL P PROD1 Continue to POOH (wet) to 9230' MD,. Monitor well for 15 minutes. Hole taking correct fill. 18:15 - 18:30 0.25 DRILL P PROD1 Work on iron rough neck. Clear floor. 18:30 - 19:45 1.25 DRILL P PROD1 Continue to POOH (wet). 19:45 - 20:00 0.25 DRILL P PROD1 Pump another dry job (2.5 ppg over mud weight). No good. Blow down lines. 20:00 - 22:15 2.25 DRILL P PROD1 Continue to POOH (wet). 22:15 - 22:30 0.25 DRILL P PROD1 PJSM -- change out tools to 4". 22:30 - 23:30 1.00 DRILL P PROD1 POOH with 4" drillpipe. 23:30 - 23:45 0.25 DRILL P PROD1 Monitor well at hevi-wate (15 minutes). 23:45 - 00:00 0.25 DRILL P PROD1 POOH with HWDP. 3/26/2003 00:00 - 03:00 3.00 DRILL P PROD1 Flush BHA with Fresh Water and LD BHA. 03:00 - 03:30 0.50 CASE P COMP PJSM for running 4-1/2" liner. 03:30 - 05:00 1.50 CASE P COMP Clear Floor and RU to run 4-1/2" liner. 05:00 - 07:30 2.50 CASE P COMP MU FS, FC and LC (Bakerlock with no float track joints) and run 16 joints and two 20' marker joints of 4-1/2" 12.6# 13CR80 Vam Ace liner. 07:30 - 11 :30 4.00 CASE P COMP RU and RIH with 2-7/8" 7.7# L80 Fox inner string. Note: Fill liner with viscosified brine. 11 :30 - 12:00 0.50 CASE P COMP MU Liner HangerlPacker. Note: Mix and install PAL mix. 12:00 - 12:30 0.50 CASE P COMP Clear Floor while waiting for PAL mix to set up. Notes: - Inner string tagged up 3 feet high. - This is not a problem since the locking tabs were removed from the wiper plug. Simply confirms space out of inner string. - This is 3rd well in a row this has occured. - Removed 8' pup and spaced out with wiper dart 5 feet above the landing collar. Printed: 4/8/2003 9:0207 AM ,. ) ') ~PE*F>L@R~ml(])N ··Opérätiö 1i55 ul11l11äryRépÒrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/26/2003 12:00 - 12:30 0.50 CASE P COMP - Confirmed talley on excess 4-1/2" and 2-7/8" joints in pipe shed; checked talley tapes and confirmed the pipe talley sheet and space out -- unable to determine source of error. 12:30 - 13:00 0.50 CASE P COMP Change over to 4" handling equip, MU XO and RIH 1 std 4" dp. 13:00 - 13:15 0.25 CASE P COMP Circulate one liner volume. 13:15 - 15:45 2.50 CASE P COMP RIH with 23 addtional stands of 4" dp. Note: Fill dp per 10 stands. 15:45 - 16:00 0.25 CASE P COMP Change over to 5" handling equip. 16:00 - 22:00 6.00 CASE P COMP RIH with 5" dp to 7" casing shoe at 13480' md. Note: Fill dp per 10 stands. 22:00 - 23:00 1.00 CASE P COMP Conditon Mud and Circulate at Shoe. Record parameters: 315K PUW; 230K SOW and 6 bpm with 840 psi. 23:00 - 23:30 0.50 CASE P COMP RIH with liner to 14046' md. 23:30 - 23:45 0.25 CASE P COMP MU Cement Head and circulating hose with Tee and drain hose. 23:45 - 00:00 0.25 CASE P COMP Establish Circulation at 1/2 bpm and Tag TO with liner -- PU one foot off bottom and set brake for cement job. - Perform rig crew tour change. - Gradually increase circulation rate as per pressure schedule. 3/27/2003 00:00 - 01 :00 1.00 CEMT P COMP Increase circ rate while circ one drill string and liner volume. - final rate 6 bpm @ 990 psi. - Held PJSM for cement job out of critical path. - Clean suction and discharge screens in #1 pump. - Prime HES cement unit and flush feed water line from G&I. 01 :00 - 02:00 1.00 CEMT P COMP Cement 4-1/2" liner as per procedure: 1) Line up HES & Pump 5 bbls of Alpha Spacer @ 10.3 ppg. 2) Test lines to 5000 psi. 3) Finish pumping 20 bbls of Alpha Spacer. 4) Pump 34 bbs (124sx) 15.9 ppg Class G Cement +additives. 5) Flush cement out of lines thru tee at cement head. 6) Line up rig pumps and flush mud out of lines with 9.3 ppg viscosified brine. 02:00 - 02:45 0.75 CEMT P COMP Drop wiper dart, displace and bump while increasing pressure to 2800 psi to set hanger. Increase pressure to 4200 psi, bleed pressure and check floats. Notes: - Displace with 9.3 ppg drilling fluid @ 6 bpm. - Slow rate to 4 bpm and bump with 2700 strokes. * Rig pump efficiency @ 92%. * HES meter was not zeroed -- efficiency unknown. 02:45 - 03:00 0.25 CEMT P COMP Set Liner Top Packer as per Baker Procedure. Notes: - PU 16 feet and clear RSS profile with packoff. - Correlated Depths: * TO of Well is 14063' md. * TO of 4-1/2" liner shoe @ 14062' md. * Top of Landing Collar @ 14057.6' md. * Top of Liner Wiper Plug @ 14055.4' md. * Inner string tail set @ 14036.6' md for circulating cement. 03:00 - 04:30 1.50 CEMT P COMP Circulate cement off top of liner. Notes: - Estimated 15 bbls of cement back to surface. Printed: 41812003 9:02:07 AM ,ý ) ) BP EXPLORATION Operations Summary Report Page 14 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2003 03:00 - 04:30 1.50 CEMT P COMP - Dumped 110 bbls of cement and contaminated mud. - Returns cleaned up after 2x BU. 04:30 - 05:00 0.50 CASE P COMP Lay Down Cement Head, 15' pup, 5' pup and one single. - Inner string tail pipe @ 14015' md -- established as NoGo mark for reciprocation during displacement to prevent damage to liner tie back assembly. 05:00 - 05:30 0.50 CASE P COMP Close bag and pressure test well to 1500 psi for 5 minutes. 05:30 - 10:00 4.50 CASE P COMP PJSM -- Wash Casing and Displace well to Sea Water. - Final NTU reading 48 NTU @ 1.75% hole volume circulated. 10:00 - 10:30 0.50 CASE P COMP Observe well for 30 minutes to confirm static and achieve negative pressure test on 4-1/2" and 7" liner tops with Sea Water fluid in wellbore. 10:30 - 15:00 4.50 CASE P COMP POOH with 5" dp. 15:00-15:15 0.25 CASE P COMP PJSM -- Change over to 4" handling equipment. 15:15-16:45 1.50 CASE P COMP POOH while Laying Down 72 joints of 4" dp. 16:45 - 17:45 1.00 CASE P COMP PJSM -- LD liner setting tool. 17:45 - 19:30 1.75 CASE P COMP PJSM -- LD 2-7/8" inner string. 19:30 - 20:15 0.75 CASE P COMP PU Cement Head out of Pipe Shed, Make Service Breaks and Break off 5" dp pups and LD in Pipe Shed via pipe skate. 20: 15 - 20:45 0.50 CASE P COMP Clear and Clean Rig Floor. 20:45 - 21 :30 0.75 RUNCOIVP COMP RIH with 15 stands of 5" DP from ODS. - Making additional room on rig floor for fiber optic and pressure testing operation. 21 :30 - 00:00 2.50 RUNCOIVP COMP PJSM -- Service Rig. - Slip and Cut Drill Line. - Adjust Brakes. - Service Top Drive, Crown and Drawworks. 3/28/2003 00:00 - 00:30 0.50 RUNCOIVP COMP Finish servicing top drive. 00:30 - 01 :00 0.50 RUNCOIVP COMP Trip out of hole. 01 :00 - 02:30 1.50 RUNCOIVP COMP Pressure test casing to 4350 psi for 30 minutes. Blow down lines. 02:30 - 04:00 1.50 RUNCOIVP COMP Pull wear bushing. RIH with wellhead junk catcher sub. Flush stack. 04:00 - 07:00 3.00 RUNCOIVP COMP Bring Gator Hawk tools to the floor. Rig up to run tubing. 07:00 - 08:30 1.50 RUNCOIVN WAIT COMP Wait on production to move heater and bleed tank to make room to spot the fiber optic spooling unit and splice shack. 08:30 - 09:30 1.00 RUNCOIVP COMP Spot fiber optic spooling unit and splice shack. Rig up fiber optic on rig floor. 09:30 - 10:00 0.50 RUNCOIVP COMP PJSM -- RU to run 4-1/2" 12.6# 13CR80 Vam Ace tubing. NOTE: Busy rig floor-- Fiber Optics cable Gator Hawk pressure test connections Nabors Casing torque turn analysis VAM PTS QAlAC connections Halliburton I SSSV to be rigged up at 1000' tvd. 10:00 - 12:00 2.00 RUNCOIVP COMP PJSM - Run in hole with completion string. MU the self anligning mule shoe, packer, x nipple assy and fiber optic PresslTemp mandrel. 12:00 - 13:00 1.00 RUNCOIVP COMP Function test fiber optic pressure temperature mandrell. 13:00 - 00:00 11.00 RUNCOIVP COMP Continue RIH with completion string (95 of 315 total joints) Printed: 4/8/2003 9:02:07 AM .' ) ) BP EXPLORATION Operations Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From~ To Hours Task COde NPT Phase DescriptiOn of Operations 3/29/2003 00:00 - 00:30 0.50 RUNCOIVP COMP PJSM -- Test fiber optic line. NOTE: A component on the Fiber Optic control cabin was damaged which has severed the ability for continuous monitoring. Thus, frequent function tests are performed to ensure the fiber optic cable has not been damaged. 00:30 - 06:30 6.00 RUNCOIVP COMP Continue to run tubing string from joint #102 to #158. NOTE: 1. Running fiber optic line (clamping at every eonnection. 2. Externally pressure testing each connection to 5,000 psi. 3. Replace collar on joint #155. Gator Hawk testing showed a leak on the factory connection (mill end). The subsequent connection test was successful. 06:30 - 09: 15 2.75 RUNCOIVP COMP Added 20' pup to re-orient the fiber optic control line relative to collar. NOTE: 1. Splice located on the at the collar on jt 157, could not clamp due to the standoff of the cable. 2. Lay down joints #157 and #158, pick up a 20 foot joint so splice will be located in the middle of a joint (#157). 3. Gator Hawk test on 20' pup connection failed on factory connection (mill end) and the rig make-up end. Changed out the collar for a successful test. 4. VAM PTS took both collars back to Houston to their Research and Development Lab. 4. PU #157 and #158. 09: 15 - 09:45 0.50 RUNCOIVP COMP Run joint #159 - #162. NOTE: GLM located after joint #160 09:45 -10:15 0.50 RUNCOIVP COMP Test fiber optic control line. NOTE: Bring SSSV control line spool to the rig floor. 10:15 - 23:30 13.25 RUNCOIVP COMP Run in hole with 4-1/2" 12.6# 13CR80 Vam Ace tubing from #162 to #291. NOTE: 1. Fiber Optics cable 2. Gator Hawk pressure test connections 3. Nabors Casing torque turn analysis 4. VAM PTS QAlAC connections 5. Halliburton / SSSV to be rigged up at 1000' tvd. 23:30 - 00:00 0.50 RUNCOIVP COMP PJSM -- Rig up control line for SSSV. 3/30/2003 00:00 - 01:15 1.25 RUNCOIVP COMP Rig up control line and test to 6000 psi for 15 minutes. Clamp. NOTE: Given the orientation of the SSSV control line, the line was moved to the "front" side of the pipe and clamped in line with the fiber optic line. Printed: 4/8/2003 9:02:07 AM .¡ ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/30/2003 01:15 - 04:30 3.25 RUNCOMP COMP Continue RIH with completion string (#292 - 314). 04:30 - 05:15 0.75 RUNCOMP COMP Tag inside liner tieback extension. Spaceout. NOTE: 1. Tagged up at 13.5' on joint #314 with 10k down weight. This was 13 feet higher than expected. 2. Confirm tag a second time. Same spot. Small bobble seen to indicate entry into extension. 3. PU - 220k; SO - 165k 4. After subtracting 2' for the spiders and 5' for off bottom depth, a 4 foot pup was required for spaceout. 5. POOH with joint #312, #313, and #314. Layout #313 and #314. MU a 4.19' pup below #312 and RIH. 05:15 - 05:30 0.25 RUNCOMP COMP Make up hanger and landing joint. 05:30 - 07:00 1.50 RUNCOMP COMP Terminate control line and splice fiber optic line. 07:00 - 08:30 1.50 RUNCOMP COMP Band all lines and Open SSSV. Land hanger and RILDS. Test seals to 5000 psi. Change out sweep. 08:30 - 13:00 4.50 RUNCOMP COMP Pressure test tubing, annulus, and SSSV. NOTE: 1. Held a PJSM 2. Drop ball and rod, set packer. Pressure up to 4200 psi. 3. Find and fix surface leak. 4. Pressure test tubing to 4200 psi for 30 minutes. Bleed pressure. 5. Pressure test annulus to 4200 psi for 30 minutes (maintaining 1200 psi differential). 6. Bleed tubing and annulus pressures to 0 psi. 7. Shear RP valve with 2650 psi by pressuring up on annulus. 8. Confirm shear by pumping 2BPM for 5 minutes. 9. Test SSSV from below to 4200 psi for 30 minutes. 13:00 - 13:30 0.50 RUNCOMP COMP PJSM - Prepare for Freeze Protection. 13:30 - 16:00 2.50 RUNCOMP COMP Reverse circulate in corrosion inhibitor and seawater. 16:00 - 21 :00 5.00 RUNCOMP COMP Reverse circulate in 306 bbls of diesel at 1 bpm, followed by 10 bbls of seawater. NOTE: Added Diesel corrosion inhibitor into pump suction while pumping diesel. 21 :00 - 22:00 1.00 RUNCOMP COMP U-tube diesel freeze protection to 4000'1VD. 22:00 - 22:30 0.50 RUNCOMP COMP Rig down cement hose and head pin. Lay down landing joint. 22:30 - 00:00 1.50 RUNCOrvP COMP Install (dry rod) TWC valve. Test to 4200 psi. NOTE: 1. Initial pressure test began to bleed off, shut in at stand pipe manifold and isolated mud pump. RUNCO~ 2. Two additional tests -- last test bled 70 psi in 30 minutes <2% overall. 3/31/2003 00:00 - 01 :30 1.50 COMP Continue to test the TWC to 4200 psi. 01 :30 - 02:00 0.50 RUNCONP COMP Blow down and rig down lines. Change bails and elevators. 02:00 - 03:00 1.00 RUNCOrvP COMP Pull mousehole. Clean cement from riser. Lay down same. Printed: 4/8/2003 9:02:07 AM '. ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS19 NS19 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 10/28/2002 Rig Release: 3/31/2003 Rig Number: 33E Spud Date: 10/29/2002 End: 3/31/2003 Date From- To Hours Task Code NPT Phase Descri ption· of Operations 3/31/2003 03:00 - 05:30 2.50 RIGD P COMP Remove turnbuckles, Koomey lines, choke flange, and short section of riser. Nipple down the BOP's and secure on stand. NOTE: Gave operations 30 minutes notice to shut in NS18 05:30 - 06:00 0.50 RIGD P COMP Clean top of tubing hanger and cellar. 06:00 - 10:00 4.00 RIGD P COMP Wrap control line and fiber optic line. Splice fiber optic line. Skid rig floor to the east. Bring the BHA to the rig floor. Loading pipeshed. 10:00 - 11 :30 1.50 N SFAL COMP Trouble with control line splice at junction box. Note: 1. Cellar environment is cold and dirty with wind drafts affecting QA/QC for making splice. 2. Weatherford technician called Houston to discuss situation with engineer. 11 :30 - 12:30 1.00 RIGD N WAIT COMP Safety Stand Down -- Both rig crews and all service representatives attended AL T Safety Induction Meeting. 12:30 - 13:45 1.25 RIGD N SFAL COMP Continue working of fiber optic line. Notes: 1. Weatherford decided to make temporary splice and post pone the permanent splice until later date after well house and heat are installed and work is not being done in critical path of rig. 2. Operations LL -- In future simply make field splice to confirm downhole fiber optic installation and 13:45 - 14:30 0.75 RIGD P COMP Install dry hole tree and nipple up. 14:30 - 15:00 0.50 RIGD P COMP Test tubing head adapter. Found a leak in the fiber optic port. 15:00 - 16:00 1.00 RIGD N SFAL COMP Fix leak and retest to 5000 psi for 15 minutes. 16:00 - 17:30 1.50 RIGD P COMP Prepare for rig move. 17:30 - 18:00 0.50 RIGD N WAIT COMP Evacuation muster drill. False alarm in facility. 18:00 - 19:00 1.00 RIGD P COMP Prepare for rig move. 19:00 - 19:30 0.50 RIGD P COMP PJSM on rig move to NS23. RIG RELEASE from NS19 at 19:30 hrs 03/31/03 MIRU on NS23 injector. Printed: 4/8/2003 9:02:07 AM l Well: Field: API: Permit: Date ) ') 10-28-02 1 0-29-02 11-05-02 Nabors 33E 05/02103 PULL BALL AND ROD, SET DUMMY GLV IN STA#1, PULL RHC AND DRIFT WITH 2 7/811 DUMMY GUN TO TD AT 13,9901 SLM (BTM SHOT @ 13,915) 05/03/03 RIH WITH 2 7/811 HSD, 6 SPF, 20', 2906PJ HMX, 60 DEG PHASING, PERFORATE INTERVAL 13895' - 139151 . DEPTH CORRELATED TO SWS PDC LOG DATED 1-DEC-2002 NS19 Northstar Field 50-029-23122-00 202-207 Accept: Spud: Release: Rig: POST-RIG WORK 05/05/03 RIH 27/8 HSD, 6SPF, 601 PHASING, RANDOM ORIENTATION, 2906 PJ HMX FINISH PERFORATING INTERVAL 139001-12860' Legal Name: Common Name: Test Date 11/2/2002 11/10/2002 3/24/2003 NS19 NS19 Test Type FIT FIT FIT Test Depth (TMD) 3,446.0 (ft) 11,753.0 (ft) 13,520.0 (ft) BPEXPLORATION Leak~OffT~stSllrnmary TestDepth(TVD) 3,201.0 (ft) 9,482.0 (ft) 10,871.0 (ft) AMW 8.60 (ppg) 12.70 (ppg) 9.20 (ppg) SurfacèPrèssure 650 (psi) 900 (psi) 1,300 (psi) LeäKOffptessur~ (BHP) 2,080 (psi) 7,156 (psi) 6,495 (psi) EMW 12.51 (ppg) 14.53 (ppg) 11.50 (ppg) .~ .~ Printed: 4/8/2003 9:01 :58 AM ANADRILL SCHLUMBERGER Survey Report Client....... ............: BP Exploration (Alaska) Inc Field....... .............: Northstar Well. . . . . . . . . . . . . . . . . . . . .: NS19 API number............. ..: 50-029-23122-00 Engineer.................: Leafstedt/Rathert Ag:.....................: Nabors 33E :lte: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions. ....: Minimum curvature Method for DLS..... ......: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.. ........: Mean Sea Level Depth reference.... ......: Drill Floor/Drillers Tally GL above permanent. ......: 15.90 ft KB above permanent.. .....: N/A ft DF above permanent.......: 56.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)... .....: 0.00 ft ~---- Platform reference point--------------- .dtitude (+N/S-)...... ...: -999.25 ft Departure (+E/W-) ... .....: -999.25 ft Azimuth from rotary table to target: 149.63 degrees [(c)2003 Anadrill IDEAL ID6_1C_l0J ..."",,~, ~, ..~ ~~ \1\/\ ~ 7--.. 25-Mar-2003 08:07:56 Spu d da t e. . . . . . . . . . . . . . . . : Last survey date.. .......: Total accepted surveys...: MD of first survey. ... ...: MD of last survey........: E;Oéì- - r¿)c57- Page 1 of 7 29-0ct-2002 25-Mar-2003 163 0.00 ft 14063.00 ft ----- Geomagnetic data ---------------------- Magnetic model... ...... ..: BGGM version 2002 Magnetic date............: 22-Mar-2003 Magnetic field strength..: 1151.06 HCNT Magnetic dec (+E/W-).....: 26.02 degrees Magnetic dip... .... ......: 80.95 degrees ----- MWD survey Reference Reference G. ........... ..: Reference H....... .......: Reference Dip...... ......: Tolerance of G.... .......: Tolerance of H... ........: Tolerance of Dip.........: Criteria --------- 1002.69 mGal 1151.06 HCNT 80.95 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.02 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.02 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N). .......: No degree: 0.00 RECEIVED APt!'") 1 r.~ f)(¡(";J~' I \ v Lv,l AJaske Of; & Ge;;: ~~:\:¡; ;C. ;~:0¡ï¡m!\f~~1 !J!.:~lcr,~/j IFR IFR IFR IFR IFR GYR GYR IFR IFR IFR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR TIP GYR GYR GYR GYR ------ ------ Tool qual type Srvy tool type ------ ------ 1.82 1.06 1.57 3.25 4.62 0.68 1.06 3.31 3.01 1.64 0.86 2.06 0.93 3.09 0.39 0.67 1.01 0.80 0.57 0.36 1.25 0.74 0.53 0.63 0.18 0.00 1.30 0.84 2.41 1.43 DLS (deg/ 100f) 2 of 7 97.81 98.50 99.43 100.90 103.26 93.47 94.12 94.46 96.04 97.18 91.30 91.89 92.19 92.31 92.80 81.79 85.41 88.08 89.79 90.67 65.10 67.74 69.95 74.21 77.36 0.00 52.60 53.44 59.66 62.53 186.75 211.91 238.95 265.95 294.87 109.39 119.66 124.28 142.61 163.61 56.69 68.55 78.41 82.34 95.65 19.35 24.72 31.42 39.13 47.46 4.36 6.13 7.49 10.78 14.15 0.00 0.28 1.03 2.44 3.19 185.02 209.58 235.72 261.15 287.01 109.19 119.35 123.91 141.82 162.33 56.67 68.51 78.36 82.27 95.53 19.15 24.64 31.40 39.13 47.46 3.95 5.67 7.04 10.37 13.80 0.00 0.23 0.83 2.11 2.83 -25.39 -31.33 -39.16 -50.28 -67.64 -6.62 -8.59 -9.67 -15.00 -20.45 -1.29 -2.27 -2.99 -3.33 -4.68 2.76 1.98 1.05 0.15 -0.55 1.83 2.32 2.57 2.93 3.10 0.00 0.17 0.62 1.23 1.47 115.45 132.99 152.96 175.42 203.46 60.92 67.76 70.99 84.64 99.71 29.77 36.59 42.20 44.47 52.34 7.30 10.75 14.97 19.66 24.47 0.42 0.87 1.34 2.71 4.31 0.00 -0.03 -0.11 0.00 0.16 1761.45 1852.25 1944.70 2033.51 2123.02 1392.24 1458.44 1486.05 1578.82 1670.15 1018.98 1113.23 1179.50 1206.21 1299.26 569.61 659.44 749.18 838.84 928.45 199.93 249.90 289.88 379.82 459.74 0.00 50.00 99.99 149.97 168.96 [(c)2003 Anadrill IDEAL ID6_1C_10] 94.21 94.25 96.39 93.06 94.80 94.00 67.00 28.01 94.64 93.77 91.00 95.00 67.00 27.00 94.00 110.00 90.00 90.00 90.00 90.00 31.00 50.00 40.00 90.00 80.00 0.00 50.00 50.00 50.00 19.00 102.66 104.49 108.72 118.27 128.78 100.08 101.80 104.71 108.05 101.86 95.40 94.20 94.22 95.63 96.03 98.00 98.18 97.46 96.01 93.63 68.98 79.21 80.40 86.37 88.18 0.00 52.60 54.47 68.85 74.71 15.12 15.99 16.92 17.91 20.60 8.56 9.22 10.01 12.78 13.42 6.21 8.16 8.78 7.97 8.33 3.08 3.99 4.71 5.21 5.45 2.03 2.09 1.88 2.40 2.52 0.00 0.65 1.07 2.21 2.35 1775.63 1869.88 1966.27 2059.33 2154.13 1398.00 1465.00 1493.01 1587.65 1681.42 1021.00 1116.00 1183.00 1210.00 1304.00 570.00 660.00 750.00 840.00 930.00 200.00 250.00 290.00 380.00 460.00 0.00 50.00 100.00 150.00 169.00 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- At Azim (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) Azimuth angle (deg) Incl angle (deg) 26 27 28 29 30 ~ 21 22 23 24 25 16 17 18 19 20 11 12 13 14 15 ,- 6 7 8 9 10 1 2 3 4 5 Seq Measured # depth (ft) Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 25-Mar-2003 08:07:56 ANADRILL SCHLUMBERGER Survey Report IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR ------ ------ Tool qual type Srvy tool type ------ ------ 1.40 1.09 0.28 0.76 1.45 0.59 0.84 1.40 0.98 1.12 1.15 2.05 1.43 0.85 0.67 2.30 2.27 1.58 1.50 0.47 0.96 1.59 1.82 2.35 2.24 4.03 3.12 2.51 2.56 2.38 DLS (deg/ 100f) 3 of 7 149.90 150.51 151.08 151.62 152.15 146.83 147.46 148.08 148.69 149.29 142.64 143.73 144.62 145.40 146.14 135.06 136.85 138.11 140.01 141.40 123.14 125.95 128.53 130.93 133.10 106.30 109.69 113.19 116.63 120.05 1581.42 1646.22 1711.49 1777.39 1842.94 1268.59 1329.55 1392.07 1454.57 1517.71 975.04 1031.04 1089.00 1148.15 1207.89 706.88 760.21 801.63 868.89 921.94 486.45 524.31 565.00 608.91 656.37 324.71 355.03 386.01 417.37 451.50 793.07 810.42 827.73 844.90 860.82 694.01 715.20 736.10 755.93 775.14 591.61 609.89 630.58 652.02 672.98 499.34 519.91 535.21 558.34 575.18 407.33 424.45 441.98 460.07 479.29 311.65 334.28 354.82 373.09 390.80 -1368.19 -1432.92 -1498.02 -1563.73 -1629.55 -1061.92 -1120.80 -1181.53 -1242.71 -1304.84 -775.05 -831.31 -887.86 -945.05 -1003.04 -500.35 -554.64 -596.80 -665.75 -720.51 -265.93 -307.80 -351.96 -398.88 -448.45 -91.16 -119.61 -151.99 -187.09 -226.10 1581.40 1646.03 1710.95 1776.32 1841.16 1267.08 1328.59 1391.56 1454.37 1517.68 967.80 1025.59 1084.84 1145.02 1205.65 684.14 741.38 785.50 856.68 912.44 435.37 480.16 527.12 576.75 629.23 236.22 272.20 310.52 350.05 392.66 4103.68 4169.32 4233.86 4299.32 4366.20 3762.95 3831.92 3901.48 3969.69 4037.04 3404.63 3477.80 3549.86 3621.50 3692.42 3033.91 3106.91 3162.33 3255.90 3331.21 2637.24 2719.19 2800.41 2880.47 2958.46 2210.32 2296.40 2383.87 2470.13 2555.74 [(c)2003 Anadrill IDEAL ID6_1C_10] 93.68 93.81 93.29 94.33 95.18 94.25 93.13 94.68 93.75 93.62 92.92 94.10 93.91 94.14 93.98 93.75 93.28 71.30 118.51 94.63 92.20 93.61 94.10 94.55 94.39 93.73 93.45 95.51 94.91 95.74 164.89 165.11 165.11 165.60 167.22 160.36 160.05 161.96 162.13 163.49 163.19 160.84 158.98 159.91 160.34 158.75 159.73 160.39 162.54 163.28 158.16 157.37 159.28 158.59 159.01 138.21 144.61 150.58 154.31 156.76 45.09 46.10 46.36 45.74 44.98 41.84 42.59 42.86 43.77 44.22 38.34 39.58 40.19 40.72 41.28 37.48 39.51 38.46 37.26 37.27 28.18 29.62 31.04 33.23 35.33 22.17 23.68 23.72 25.59 27.59 4599.95 4693.76 4787.05 4881.38 4976.56 4131.09 4224.22 4318.90 4412.65 4506.27 3660.71 3754.81 3848.72 3942.86 4036.84 3190.07 3283.35 3354.65 3473.16 3567.79 2719.67 2813.28 2907.38 3001.93 3096.32 2247.86 2341.31 2436.82 2531.73 2627.47 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- At Az im (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) Azimuth angle (deg) Incl angle (deg) 56 57 58 59 60 - 51 52 53 54 55 46 47 48 49 50 41 42 43 44 45 ,...-36 37 38 39 40 31 32 33 34 35 Seq Measured # depth (ft) Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 25-Mar-2003 08:07:56 ANADRILL SCHLUMBERGER Survey Report IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR ------ ------ Tool qual type Srvy tool type ------ ------ 0.27 0.32 0.56 0.42 0.86 0.24 0.64 0.24 0.24 0.08 0.62 0.52 0.63 0.47 0.75 0.25 0.35 0.67 0.46 0.42 0.19 0.58 1.01 0.51 0.81 1.79 0.43 1.55 1.20 0.95 DLS (deg/ 100f) 4 of 7 158.45 158.50 158.56 158.62 158.69 158.16 158.22 158.28 158.34 158.40 157.68 157.82 157.94 158.03 158.10 156.71 156.95 157.16 157.36 157.53 155.14 155.53 155.87 156.18 156.46 152.69 153.22 153.74 154.25 154.72 3425.01 3487.65 3549.84 3613.02 3675.81 3120.09 3180.90 3240.60 3302.25 3363.29 2818.08 2878.48 2939.18 3000.27 3059.88 2509.50 2572.53 2633.71 2695.69 2756.99 2206.83 2265.78 2325.50 2385.99 2447.82 1905.40 1967.66 2028.97 2089.51 2148.42 1257.88 1278.03 1297.83 1317.39 1336.00 1160.63 1180.28 1199.32 1218.92 1238.25 1070.04 1086.68 1104.08 1122.38 1141.08 992.05 1007.10 1022.16 1037.83 1053.69 927.79 938.60 950.58 963.56 977.54 874.26 886.52 897.64 907.65 917.53 3384.48 -3185.66 3445.91 -3245.05 3506.86 -3304.09 3568.68 -3364.28 3629.97 -3424.42 3085.56 -2896.18 3145.22 -2953.82 3203.75 -3010.50 3264.17 -3069.05 3323.99 -3127.06 2790.28 -2607.03 2849.12 -2665.48 2908.35 -2723.93 2968.07 -2782.42 3026.47 -2839.15 2490.34 -2305.08 2551.54 -2367.20 2610.98 -2427.26 2671.21 -2487.90 2730.82 -2547.69 2196.64 -2002.32 2253.79 -2062.23 2311.71 -2122.34 2370.41 -2182.77 2430.44 -2244.16 1902.69 -1692.99 1963.80 -1756.64 2023.75 -1819.61 2082.71 -1882.08 2139.96 -1942.64 6198.90 6269.83 6339.50 6409.62 6478.72 5846.18 5917.79 5987.21 6058.34 6128.42 5487.42 5558.84 5630.99 5703.53 5774.50 5134.59 5205.49 5274.49 5345.38 5416.16 4781.31 4852.24 4923.01 4993.55 5064.55 4432.46 4500.38 4569.05 4639.69 4710.45 [(c)2003 Anadrill IDEAL ID6_1C_10J 93.74 94.68 93.45 94.45 93.48 93.67 94.00 91.62 94.19 93.00 94.16 93.77 94.48 94.96 92.76 93.95 95.46 92.71 94.59 94.01 93.21 93.47 93.62 93.79 94.90 92.71 93.89 93.83 94.83 93.67 161.37 161.16 161.75 162.25 163.35 160.92 161.42 161.45 161.54 161.59 164.31 163.89 162.97 162.28 161.23 166.57 166.21 165.63 165.39 164.89 170.12 169.43 168.03 167.72 166.63 168.88 169.31 170.68 171.11 170.36 41.35 41.62 41.96 42.18 42.49 40.12 40.63 40.85 41.07 41.14 40.60 40.19 40.22 40.17 40.01 41.92 42.15 41.66 41.26 41.04 40.48 40.79 41.01 41.44 41.69 43.80 43.52 42.40 41.30 40.56 7415.55 7510.23 7603.68 7698.13 7791.61 6949.00 7043.00 7134.62 7228.81 7321.81 6479.36 6573.13 6667.61 6762.57 6855.33 6008.43 6103.89 6196.60 6291.19 6385.20 5538.70 5632.17 5725.79 5819.58 5914.48 5069.27 5163.16 5256.99 5351.82 5445.49 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- At Azim (deg) Total displ (ft) Displ +E/W- (ft) Displ +N/S- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) Azimuth angle (deg) Incl angle (deg) 86 87 88 89 90 - 81 82 83 84 85 76 77 78 79 80 71 72 73 74 75 ~..66 67 68 69 70 61 62 63 64 65 Seq Measured # depth (ft) Page ======== ====== ======= ====== ======== ======== ================ =============== 25-Mar-2003 08:07:56 ANADRILL SCHLUMBERGER Survey Report ANADRILL SCHLUMBERGER Survey Report _96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 -111 112 113 114 115 116 117 118 119 120 25-Mar-2003 08:07:56 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Page Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 7885.86 7980.62 8074.92 8170.10 8264.15 42.73 42.80 42.29 41.63 41.35 40.86 40.35 39.75 39.07 38.53 38.08 37.58 37.08 36.72 36.84 36.75 37.04 37.27 37.56 38.12 38.76 39.61 40.03 40.20 40.24 40.06 39.67 39.96 40.50 41.21 164.54 164.87 165.36 165.89 165.93 165.98 165.62 165.31 164.88 164.95 164.87 165.28 165.13 165.47 165.74 165.65 164.26 163.13 162.03 162.39 163.44 163.56 164.95 166.02 166.28 166.14 163.87 161.63 160.76 159.28 94.25 94.76 94.30 95.18 94.05 92.59 94.33 94.91 93.76 93.87 93.90 93.99 94.24 91.92 93.23 93.85 93.73 94.19 94.16 93.74 96.03 92.05 93.49 93.94 94.62 94.86 92.00 96.43 94.52 94.58 [(c)2003 Anadrill IDEAL ID6_1C_10] 8356.74 8451.07 8545.98 8639.74 8733.61 8827.51 8921.50 9015.74 9107.66 9200.89 9294.74 9388.47 9482.66 9576.82 9670.56 9766.59 9858.64 9952.13 10046.07 10140.69 10235.55 10327.55 10423.98 10518.50 10613.08 6548.09 6617.65 6687.13 6757.91 6828.36 6898.12 6969.74 7042.39 7114.83 7187.99 7261.67 7335.91 7410.84 7484.35 7559.02 7634.18 7709.14 7784.21 7859.00 7933.02 8008.24 8079.59 8151.40 8223.24 8295.49 8367.99 8438.61 8512.69 8584.85 8656.39 3691.80 -3485.74 3753.92 -3547.80 3815.37 -3609.42 3876.55 -3671.06 3936.36 -3731.50 3994.77 -3790.55 4053.74 -3850.07 4112.49 -3909.18 4169.86 -3966.70 4226.60 -4023.50 4282.74 -4079.69 4338.31 -4135.39 4393.36 -4190.65 4446.50 -4244.03 4500.16 -4298.10 4554.18 -4352.57 4608.44 -4406.91 4663.63 -4461.50 4719.38 -4516.09 4775.50 -4570.84 4833.60 -4627.91 4890.07 -4683.67 4947.99 -4741.29 5006.22 -4799.89 5064.79 -4859.21 5123.41 -4918.61 5180.26 -4975.57 5240.39 -5034.53 5300.19 -5092.31 5361.05 -5150.45 1353.65 1370.62 1387.00 1402.80 1417.97 1432.74 1447.80 1463.13 1478.44 1493.74 1508.90 1523.75 1538.34 1552.34 1566.22 1580.11 1594.72 1610.69 1627.82 1645.39 1662.92 1679.44 1695.68 1710.85 1725.48 1740.06 1755.31 1773.62 1793.30 1814.44 3739.35 3803.35 3866.74 3929.96 3991.83 4052.29 4113.29 4174.02 4233.26 4291.83 4349.79 4407.19 4464.08 4519.02 4574.57 4630.51 4686.57 4743.35 4800.50 4857.97 4917.61 4975.67 5035.40 5095.68 5156.47 5217.33 5276.11 5337.81 5398.85 5460.71 158.78 158.88 158.98 159.09 159.19 159.29 159.39 159.48 159.56 159.63 159.70 159.77 159.84 159.91 159.98 160.05 160.11 160.15 160.18 160.20 160.24 160.27 160.32 160.38 160.45 160.52 160.57 160.59 160.60 160.59 5 of 7 DLS (deg/ 100f) 0.89 0.25 0.64 0.79 0.30 0.53 0.59 0.67 0.78 0.58 0.48 0.60 0.54 0.45 0.22 0.11 0.94 0.76 0.77 0.64 0.95 0.93 1.05 0.76 0.18 0.21 1.64 1.52 0.82 1.27 ------ ------ Srvy tool type Tool qual type ------ ------ IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR ANADRILL SCHLUMBERGER Survey Report ~126 27 128 129 130 /-141 .142 143 144 145 146 147 148 149 150 25-Mar-2003 08:07:56 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Page Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Az im (de g) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 121 122 123 124 125 10706.75 10803.10 10898.83 10993.63 11089.78 41.72 42.44 43.87 44.61 45.89 46.01 45.24 45.41 44.31 42.54 40.69 39.65 37.93 37.14 37.08 37.46 38.30 38.33 38.96 39.15 40.33 41.66 40.20 38.54 37.73 36.56 35.88 35.75 35.82 37.80 158.08 155.77 153.06 149.73 145.83 140.54 136.10 132.07 129.33 129.17 129.19 129.83 128.80 126.63 124.72 121.85 121.28 120.15 119.42 119.87 120.76 121.87 122.42 124.11 124.29 123.95 123.77 123.97 124.12 126.04 93.67 96.35 95.73 94.80 96.15 94.01 95.81 96.37 92.69 95.54 96.31 53.90 130.72 93.54 96.86 94.99 96.76 94.31 70.70 26.10 93.47 96.08 95.14 95.70 95.23 95.64 95.46 95.15 95.57 95.26 [(c)2003 Anadrill IDEAL ID6_1C_10] 11183.79 11279.60 11375.97 11468.66 11564.20 131 132 133 134 135 11660.51 11714.41 11845.13 11938.67 12035.53 136 137 138 139 140 12130.52 12227.28 12321.59 12392.29 12418.39 12511.86 12607.94 12703.08 12798.78 12894.01 12989.65 13085.11 13180.26 13275.83 13371.09 8726.58 8798.10 8867.94 8935.86 9003.56 9068.95 9135.97 9203.74 9269.45 9338.84 9410.84 9452.02 9553.91 9628.09 9705.33 9780.93 9857.31 9931.30 9986.52 10006.79 10078.66 10151.18 10223.06 10297.04 10371.94 10448.18 10525.19 10602.35 10679.88 10756.14 5422.30 -5208.23 5486.34 -5267.62 5551.57 -5326.65 5617.66 -5384.70 5685.88 -5442.43 5752.98 -5496.48 5820.10 -5547.62 5886.09 -5595.27 5947.93 -5637.91 6009.49 -5679.46 6069.42 -5719.87 6102.06 -5741.99 6178.86 -5793.88 6231.73 -5828.74 6285.13 -5862.82 6336.66 -5894.38 6389.09 -5925.47 6440.27 -5955.34 6478.56 -5977.27 6492.80 -5985.40 6544.91 -6015.57 6600.40 -6048.33 6655.69 -6081.49 6710.06 -6114.77 6763.17 -6147.82 6815.29 -6180.22 6866.09 -6211.65 6916.23 -6242.68 6966.64 -6273.96 7018.56 -6306.78 1836.99 1862.31 1890.59 1922.26 1958.68 1999.14 2044.64 2093.85 2143.40 2194.25 2243.83 2270.66 2334.00 2379.07 2426.54 2474.62 2525.24 2575.51 2613.82 2628.12 2679.70 2733.54 2786.31 2837.07 2885.71 2933.52 2980.36 3026.59 3072.89 3119.58 5522.70 5587.13 5652.22 5717.52 5784.15 5848.75 5912.41 5974.22 6031.60 6088.60 6144.24 6174.65 6246.33 6295.57 6345.14 6392.76 6441.12 6488.40 6523.79 6536.97 6585.43 6637.36 6689.40 6740.87 6791.40 6841.10 6889.63 6937.67 6986.08 7036.14 160.57 160.53 160.46 160.35 160.21 160.01 159.77 159.48 159.18 158.88 158.58 158.42 158.06 157.80 157.52 157.23 156.92 156.61 156.38 156.29 155.99 155.68 155.38 155.11 154.86 154.61 154.37 154.13 153.91 153.68 6 of 7 DLS (deg/ 100f) 1.01 1.77 2.45 2.57 3.17 4.05 3.41 2.98 2.40 1.86 1.92 2.08 1.41 1.65 1.19 1.87 0.94 0.74 1.10 1.31 1.40 1.58 1.58 2.06 0.86 1.24 0.72 0.18 0.12 2.40 ------ ------ Srvy tool type Tool qual type ------ ------ IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR ANADRILL SCHLUMBERGER Survey Report ~156 57 158 159 160 25-Mar-2003 08:07:56 Page 7 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) -------- ------ -------- ------ 151 152 153 154 155 13419.91 13494.38 13521.01 13553.87 13587.50 13615.81 13652.60 13684.92 13712.77 13807.97 161 13903.35 162 13998.70 38.74 40.55 43.44 48.25 51.28 55.27 59.10 60.50 61.53 61.16 Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) ------- ------ -------- -------- ---------------- ------- ------ -------- -------- ---------------- 126.97 128.45 128.98 130.66 131.04 131.80 131.43 131.55 130.12 129.87 60.94 130.03 60.57 130.51 48.82 74.47 26.63 32.86 33.63 28.31 36.79 32.32 27.85 95.20 10794.47 10851.81 10871.60 10894.49 10916.21 10933.13 10953.07 10969.32 10982.82 11028.47 95.38 11074.64 95.35 11121.22 Survey Projected to Total Depth: 163 14063.00 60.57 130.51 64.30 11152.82 [(c)2003 Anadrill IDEAL ID6_1C_10J -- 7046.37 -6324.77 7090.44 -6353.84 7107.09 -6364.98 7129.26 -6380.08 7153.57 -6396.88 7175.12 -6411.89 7204.52 -6432.42 7231.06 -6450.92 7254.12 -6466.85 7332.80 -6520.54 3143.88 3181.46 3195.36 3213.45 3232.87 3249.88 3272.99 3293.91 3312.35 3376.35 At Azim (deg) --------------- --------------- 7063.05 7105.84 7122.03 7143.65 7167.39 7188.46 7217.23 7243.22 7265.79 7342.83 153.57 153.40 153.34 153.27 153.19 153.12 153.03 152.95 152.88 152.62 7411.39 -6574.13 3440.33 7419.91 152.38 7489.88 -6627.91 3503.81 7497.06 152.14 7542.79 -6664.29 3546.39 7549.15 151.98 DLS (deg/ 100f) 2.26 2.74 10.93 15.09 9.05 14.26 10.44 4.34 5.82 0.45 0.27 0.59 0.00 ------ ------ Srvy tool type Tool qual type ------ ------ IFR Interp Az Interp Az G_Mag G_Mag G_Mag G_Mag G_Mag G_Mag G_Mag G_Mag G_Mag Proj Report Date: 25-Mar-03 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 151.980° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Northstar PF / ~S19 TVD Reference Datum: KB Well: NS19 TVD Reference Elevation: 56.300 ft relative to MSL Borehole: NS19 Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL UWUAPI#: 500292312200 Magnetic Declination: +26.159° j~- Survey Name I Date: NS 19 I March :;5, 2002 Total Field Strength: 57547.184 nT Tort I AHD I DDII ERD ratio: 185.990° /7962.80 ft /6.271 /0.714 Magnetic Dip: 80.948° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: November 07,2002 Location LatlLong: N 70.4912410E, W 148.69330705 Magnetic Declination Model: BGGM 2002 Location Grid N/E YfX: N 6031001.38C ftUS, E 659828.230 ftUS North Reference: True North Grid Convergence Angle: + 1.23170016° Total Corr Mag North -> True North: +26.159° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec Nt-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) ". (") (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6031001.38 659828.23 N 70.49124105 W 148.69330705 50.00 0.65 52.60 50.00 -0.05 0.17 0.23 1.30 6031001.56 659828.45 N 70.49124152 W 148.69330521 100.00 1.07 54.47 99.99 -0.15 0.62 0.133 0.84 6031002.01 659829.05 N 70.49124273 W 148.69330026 150.00 2.21 68.85 149.97 -0.10 1.23 2.11 2.41 6031002.66 659830.31 N 70.49124443 W 148.69328980 169.00 2.35 74.71 168.96 0.03 1.47 2.83 1.43 6031002.91 659831.02 N 70.49124507 W 148.69328394 200.00 2.03 68.98 199.93 0.24 1.83 3.95 1.25 6031003.30 659832.14 N 70.49124606 W 148.69327474 i 250.00 2.09 79.21 249.90 0.62 2.32 5.67 0.74 6031003.82 659833.85 N 70.49124740 W 148.69326066 , ,:---- 290.00 1.88 80.40 289.88 1.04 2.57 7.04 0.53 6031004.10 659835.21 N 70.49124807 W 148.69324952 380.00 2.40 86.37 379.82 2.28 2.93 10.37 0.63 6031004.54 659838.54 N 70.49124907 W 148.69322224 460.00 2.52 88.18 459.74 3.75 3.10 13.80 0.18 6031004.77 659841.96 N 70.49124951 W 148.69319421 570.00 3.08 98.00 569.61 6.56 2.76 19.15 0.67 6031004.55 659847.31 N 70.49124860 W 148.69315053 660.00 3.99 98.18 659.44 9.83 1.98 24.64 1.01 6031003.89 659852.82 N 70.49124646 W 148.69310562 750.00 4.71 97.46 749.18 13.82 1.05 31.40 0.80 6031003.11 659859.60 N 70.49124393 W 148.69305034 840.00 5.21 96.01 838.84 18.25 0.15 39.13 0.57 6031002.37 659867.35 N 70.49124145 W 148.69298717 930.00 5.45 93.63 928.45 22.78 -0.55 47.46 0.36 6031001.85 659875.69 N 70.49123954 W 148.69291909 1021.00 6.21 95.40 1018.98 27.76 -1.29 56.67 0.86 6031001.31 659884.91 N 70.49123753 W 148.69284378 1116.00 8.16 94.20 1113.23 34.19 -2.27 68.51 2.06 6031000.59 659896.77 N 70.49123486 W 148.69274699 1183.00 8.78 94.22 1179.50 39.45 -2.99 78.36 0.93 6031RECEtVED0.49123288 W 148.69266654 J ~ p f. :-! 1 ~ "~n ~ f ~1 ~-i 11 ~J !:' I ~ f)Œ-QC)7 NS19 Survey Report - Geodetic Schlumb8rU8r NS19 ASP Final Survey.xls ~~~ ^^ ~ SchlumbergerPrivate : Page 1016 APR 1 5 2003 Ala8ka œ & Gas ConE. CQrnmileioo 4/2/2003·4:09 PM A _ .....L...-....._ Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S Ej-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1210.00 7.97 95.63 1206.21 41.59 -3.33 82.27 3.09 6030999.82 659910.55 N 70.49123197 W 148.69263452 1304.00 8.33 96.03 1299.26 49.01 -4.68 95.53 0.39 6030998.75 659923.83 N 70.49122826 W 148.69252615 1398.00 8.56 100.08 1392.24 57.14 -6.62 1 09.19 0.68 6030997.11 659937.53 N 70.49122296 W 148.69241450 í 1465.00 9.22 101.80 1458.44 63.65 -8.59 119.35 1.06 6030995.36 659947.73 N 70.49121758 W 148.69233142 ! 1493.01 10.01 104.71 1486.05 66.74 -9.67 123.91 3.31 6030994.38 659952.31 N 70.49121464 W 148.69229422 I 1587.65 12.78 108.05 1578.82 79.87 -15.00 141.82 3.01 6030989.43 659970.33 N 70.49120007 W 148.69214780 ~I 1681.42 13.42 101.86 1670.15 94.31 -20.45 162.33 1.64 6030984.42 659990.95 N 70.49118518 W 148.69198014 ~I ;! -g¡ 1775.63 15.12 102.66 1761.45 109.33 -25.39 185.02 1.82 6030979.97 660013.74 N 70.49117168 W 148.69179468 1;: ~~ /~- 1869.88 15.99 104.49 1852.25 126.12 -31.33 209.58 1.06 6030974.56 660038.42 N 70.49115545 W 148.69159390 1966.27 16.92 108.72 1944.70 145.30 -39.16 235.72 1.57 6030967.30 660064.72 N 70.49113407 W 148.69138023 2059.33 17.91 118.27 2033.51 167.07 -50.28 261.15 3.25 6030956.73 660090.39 N 70.49110367 W 148.69117233 2154.13 20.60 128.78 2123.02 194.54 -67.64 287.01 4.62 6030939.93 660116.60 N 70.49105625 W 148.69096103 2247.86 22.17 138.21 2210.32 226.89 -91.16 311.65 4.03 6030916.94 660141.75 N 70.49099199 W 148.69075955 2341.31 23.68 144.61 2296.40 262.63 -119.61 334.28 3.12 6030888.99 660164.98 N 70.49091426 W 148.69057464 2436.82 23.72 150.58 2383.87 300.86 -151.99 354.82 2.51 6030857.07 660186.21 N 70.49082582 W 148.69040670 2531.73 25.59 154.31 2470.13 340.43 -187.09 373.09 2.56 6030822.36 660205.23 N 70.49072992 W 148.69025741 2627.47 27.59 156.76 2555.74 383.19 -226.10 .390.80 2.38 6030783.75 660223.77 N 70.49062335 W 148.69011264 2719.67 28.18 158.16 2637.24 426.11 -265.93 407:33 0.96 6030744.29 660241.15 N 70.49051454 W 148.68997759 2813.28 29.62 157.37 2719.19 471.12 -307.80 424.45 1.59 6030702.80 660259.17 N 70.49040015 W 148.68983763 2907.38 31.04 159.28 2800.41 518.34 -351.96 441.98 1.82 6030659.03 660277.64 N 70.49027951 W 148.68969435 3001.93 33.23 158.59 2880.47 568.26 -398.88 460.07 2.35 6030612.51 660296.73 N 70.49015132 W 148.68954655 3096.32 35.33 159.01 2958.46 621.04 -448.45 479.29 2.24 6030563.37 660317.01 N 70.49001591 W 148.68938949 3190.07 37.48 158.75 3033.91 676.28 -500.35 499.34 2.30 6030511 .92 660338.17 N 70.48987413 W 148.68922563 ,--, 3283.35 39.51 159.73 3106.91 733.87 -554.64 519.91 2.27 6030458.09 660359.90 N 70.48972581 W 148.68905754 ~ 3354.65 38.46 160.39 3162.33 778.28 -596.80 535.21 1.58 6030416.26 660376.10 N 70.48961062 W 148.68893251 i 3473.16 37.26 162.54 3255.90 850.01 -665.75 558.34 1.50 6030347.84 660400.71 N 70.48942226 W 148.68874346 ~ fl 3567.79 37.27 163.28 3331.21 906.27 -720.51 575.18 0.47 6030293.45 660418.72 N 70.48927264 W 148.68860587 3660.71 38.34 163.19 3404.63 962.13 -775.05 591.61 1.15 6030239.28 660436.32 N 70.48912366 W 148.68847162 II 3754.81 39.58 160.84 3477.80 1020.38 -831.31 609.89 2.05 6030183.43 660455.80 N 70.48896995 W 148.68832223 "i 3848.72 40.19 158.98 3549.86 1080.02 -887.86 630.58 1.43 6030127.34 660477.70 N 70.48881547 W 148.68815318 ~I 3942.86 40.72 159.91 3621.50 1140.58 -945.05 652.02 0.85 6030070.63 660500.37 N 70.48865922 W 148.68797795 i 4036.84 41.28 160.34 3692.42 1201.62 -1003.04 672.98 0.67 6030013.11 660522.57 N 70.48850081 W 148.68780669 ; ; 4131.09 41.84 160.36 3762.95 1263.48 -1061.92 694.01 0.59 6029954.70 660544.85 N 70.48833994 W 148.68763489 4224.22 42.59 160.05 3831.92 1325.41 -1120.80 715.20 0.84 6029896.29 660567.30 N 70.48817909 W 148.68746173 4318.90 42.86 161.96 3901.48 1388.85 -1181.53 736.10 1.40 6029836.03 660589.51 N 70.48801316 W 148.68729093 Schlumberger Private NS19 ASP Final Survey.xls Page 2 of 6 4/2/2003-4:09 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) "'~ 4412.65 43.77 162.13 3969.69 1452.17 -1242.71 755.93 0.98 6029775.29 660610.64 N 70.48784602 W 148.68712895 ~i k' 4506.27 44.22 163.49 4037.04 1516.03 -1304.84 775.14 1.12 6029713.60 660631.18 N 70.48767631 W 148.68697197 .' ~i ; 4599.95 45.09 164.89 4103.68 1580.38 -1368.19 793.07 1.40 6029650.66 660650.47 N 70.48750324 W 148.68682547 4693.76 46.10 165.11 4169.32 1645.68 -1432.92 810.42 1.09 6029586.32 660669.20 N 70.48732639 W 148.68668378 4787.05 46.36 165.11 4233.86 1711.28 -1498.02 827.73 0.28 6029521.60 660687.91 N 70.48714853 W 148.68654236 4881.38 45.74 165.60 4299.32 1777.35 -1563.73 844.90 0.76 6029456.29 660706.49 N 70.48696903 W 148.68640209 4976.56 44.98 167.22 4366.20 1842.94 -1629.55 860.82 1.45 6029390.83 660723.81 N 70.48678920 W 148.68627206 ~. 5069.27 43.80 168.88 4432.46 1905.25 -1692.99 874.26 1.79 6029327.69 660738.61 N 70.48661589 W 148.68616230 5163.16 43.52 169.31 4500.38 1967.20 -1756.64 886.52 0.43 6029264.33 660752.24 N 70.48644200 W 148.68606215 5256.99 42.40 170.68 4569.05 2028.01 -1819.61 897.64 1.55 6029201.62 660764.70 N 70.48626999 W 148.68597136 5351.82 41.30 171.11 4639.69 2087.86 -1882.08 907.65 1.20 6029139.38 660776.06 N 70.48609932 W 148.68588958 5445.49 40.56 170.36 4710.45 2145.97 -1942.64 917.53 0.95 6029079.05 660787.23 N 70.48593386 W 148.68580893 5538.70 40.48 170.12 4781.31 2203.48 -2002.33 927.79 0.19 6029019.61 660798.78 N 70.48577081 W 148.68572509 5632.17 40.79 169.43 4852.24 2261.44 -2062.23 938.60 0.58 6028959.95 660810.87 N 70.48560716 W 148.68563685 5725.79 41.01 168.03 4923.01 2320.13 -2122.34 950.58 1.01 6028900.12 660824.14 N 70.48544294 W 148.68553900 5819.58 41.44 167.72 4993.55 2379.58 -2182.77 963.56 0.51 6028839.98 660838.42 N 70.48527785 W 148.68543297 5914.48 41.69 166.63 5064.55 2440.34 -2244.16 977.54 0.81 6028778.91 660853.71 N 70.48511014 W 148.68531882 ; ~ 6008.43 41.92 166.57 5134.59 2500.94 -2305.08 992.05 0.25 6028718.32 660869.53 N 70.48494370 W 148.68520028 i! 6103.89 42.15 166.21 5205.49 2562.84 -2367.20 1007.10 0.35 6028656.54 660885.90 N 70,48477398 W 148.68507744 ~¡ J 6196.60 41.66 165.63 5274.49 2622.94 -2427.27 1022.16 0.67 6028596.82 660902.25 N 70.48460990 W 148.68495442 .n 6291.19 41.26 165.39 5345.38 2683.83 -2487.90 1037.83 0.46 6028536.54 660919.22 N 70.48444425 W 148.68482644 ~¡ 6385.20 41.04 164.89 5416.16 2744.06 -2547.69 1053.69 0.42 6028477.11 660936.36 N 70.48428090 W 148.68469688 ;1 6479.36 40.60 164.31 5487.42 2804.13 -2607.03 1070.04 0.62 6028418.14 660953.98 N 70.48411878 W 148.68456340 ~ /:--.-" 6573.13 40.19 163.89 5558.84 2863.54 -2665.48 1 086.68 0.52 6028360.07 660971.87 N 70.48395911 W 148.68442744 6667.61 40.22 162.97 5630.99 2923.31 -2723.93 1104.08 0.63 6028302.01 660990.52 N 70.48379942 W 148.68428539 6762.57 40.17 162.28 5703.53 2983.55 -2782.42 1122.38 0.47 6028243.93 661010.07 N 70.48363962 W 148.68413591 6855.33 40.01 161.23 5774.50 3042.41 -2839.15 1141.08 0.75 6028187.62 661029.99 N 70.48348463 W 148.68398318 6949.00 40.12 160.92 5846.18 3101.95 -2896.18 1160.63 0.24 6028131.02 661050.76 N 70.48332882 W 148.68382347 7043.00 40.63 161 .42 5917.79 3162.06 -2953.82 1180.28 0.64 6028073.83 661071.64 N 70.48317137 W 148.68366296 7134.62 40.85 1 61 .45 5987.21 3221.04 -3010.50 1199.32 0.24 6028017.57 661091.89 N 70.48301651 W 148.68350749 7228.81 41.07 161.54 6058.34 3281.93 -3069.05 1218.92 0.24 6027959.46 661112.74 N 70.48285655 W 148.68334744 7321.81 41.14 161.59 6128.42 3342.22 -3127.06 1238.25 0.08 6027901.89 661133.32 N 70.48269808 W 148.68318954 7415.55 41.35 161.37 6198.90 3403.17 -3185.66 1257.88 0.27 6027843.73 661154.20 N 70.48253798 W 148.68302922 7510.23 41.62 161.16 6269.83 3465.07 -3245.05 1278.03 0.32 6027784.79 661175.62 N 70.48237571 W 148.68286471 7603.68 41.96 161.75 6339.50 3526.49 -3304.09 1297.83 0.56 6027726.19 661196.69 N 70.48221441 W 148.68270297 Schlumberger Private NS19 ASP Final Survey.xls Page 3 of 6 4/2/2003-4:09 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/·W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7698.13 42.18 162.25 6409.62 3588.81 -3364.28 1317.39 0.42 6027666.44 661217.53 N 70.48204998 W 148.68254327 7791.61 42.49 163.35 6478.72 3650.65 -3424.42 1336.00 0.86 6027606.72 661237.43 N 70.48188568 W 148.68239127 7885.86 42.73 164.54 6548.09 3713.07 -3485.74 1353.65 0.89 6027545.80 661256.39 N 70.48171816 W 148.68224720 7980.62 42.80 164.87 6617.65 3775.83 -3547.80 1370.62 0.25 6027484.12 661274.69 N 70.48154860 W 148.68210862 8074.92 42.29 165.36 6687.13 3837.92 -3609.42 1387.00 0.64 6027422.87 661292.39 N 70.48138025 W 148.68197488 8170.10 41.63 165.89 6757.91 3899.76 -3671.06 1402.80 0.79 6027361.58 661309.51 N 70.48121184 W 148.68184588 8264.15 41.35 165.93 6828.36 3960.24 -3731.50 1417.97 0.30 6027301.49 661325.97 N 70.48104674 W 148.68172204 , 8356.74 40.86 165.98 6898.12 4019.31 -3790.55 1432.74 0.53 6027242.78 661342.01 N 70.48088541 W 148.68160144 g !~ 8451.07 40.35 165.62 6969.74 4078.92 -3850.07 1447.80 0.59 6027183.60 661358.35 N 70.48072280 W 148.68147850 l 8545.98 39.75 165.31 7042.39 4138.31 -3909.18 1463.13 0.67 6027124.83 661374.94 N 70.48056130 W 148.68135338 8639.74 39.07 164.88 7114.83 4196.28 -3966.71 1478.44 0.78 6027067.66 661391.48 N 70.48040415 W 148.68122840 8733.61 38.53 164.95 7187.99 4253.61 -4023.50 1493.74 0.58 6027011.21 661408.00 N 70.48024899 W 148.68110343 ~ i ,! 8827.51 38.08 164.87 7261.67 4310.34 -4079.69 1508.90 0.48 6026955.36 661424.36 N 70.48009546 W 148.68097973 tl 8921.50 37.58 165.28 7335.91 4366.48 -4135.39 1523.75 0.60 6026899.99 661440.40 N 70.47994329 W 148.68085852 il ,j 9015.74 37.08 165.13 7410.85 4422.12 -4190.65 1538.34 0.54 6026845.07 661456.17 N 70.47979234 W 148.68073939 ~¡ 11 9107.66 36.72 165.47 7484.35 4475.82 -4244.03 1552.34 0.45 6026792.01 661471.32 N 70.47964649 W 148.68062506 9200.89 36.84 165.74 7559.02 4530.07 -4298.10 1566.22 0.22 6026738.25 661486.36 N 70.47949878 W 148.68051178 9294.74 36.75 165.65 7634.18 4584.68 -4352.57 1580.11 0.11 6026684.10 661501.41 N 70.47934997 W 148.68039841 9388.47 37.04 164.26 7709.14 4639.51 -4406.91 1594.72 0.94 6026630.09 661517.18 N 70.47920151 W 148.68027917 9482.66 37.27 163.13 7784.21 4695.21 -4461.50 1610.69 0.76 6026575.85 661534.33 N 70.47905235 W 148.68014878 9576.82 37.56 162.03 7859.00 4751.44 -4516.09 1627.82 0.77 6026521.65 661552.62 N 70.47890322 W 148.68000895 9670.56 38.12 162.39 7933.03 4808.04 -4570.84 1645.39 0.64 6026467.29 661571.36 N 70.47875363 W 148.67986553 j 9766.59 38.76 163.44 8008.24 4866.65 -4627.91 1662.92 0.95 6026410.62 661590.12 N 70.47859772 W 148.67972238 h ¡ ¡ 9858.64 39.61 163.56 8079.59 4923.64 -4683.67 1679.44 0.93 6026355.23 661607.83 N 70.47844537 W 148.67958755 1"- 9952.13 40.03 164.95 8151.40 4982.13 -4741.29 1695.68 1.05 6026297.97 661625.31 N 70.47828795 W 148.67945497 10046.07 40.20 166.02 8223.24 5040.99 -4799.89 1710.85 0.76 6026239.72 661641.73 N 70.47812787 W 148.67933117 10140.69 40.24 166.28 8295.49 5100.23 -4859.21 1725.48 0.18 6026180.73 661657.63 N 70.47796580 W 148.67921180 10235.55 40.06 166.14 8368.00 5159.51 -4918.61 1740.06 0.21 6026121.66 661673.48 N 70.47780351 W 148.67909282 10327.55 39.67 163.87 8438.62 5216.96 -4975.57 1755.31 1.64 6026065.05 661689.95 N 70.47764791 W 148.67896835 10423.98 39.96 161.63 8512.69 5277.61 -5034.53 1773.62 1.52 6026006.51 661709.52 N 70.47748683 W 148.67881888 10518.50 40.50 160.76 8584.85 5337.86 -5092.31 1793.30 0.82 6025949.16 661730.44 N 70.47732896 W 148.67865823 10613.08 41.21 159.28 8656.39 5399.12 -5150.45 1814.44 1.27 6025891 .49 661752.82 N 70.47717011 W 148.67848563 { 10706.75 41.72 158.08 8726.58 5460.72 -5208.23 1836.99 1.01 6025834.22 661776.61 N 70.47701226 W 148.67830152 10803.10 42.44 155.77 8798.10 5525.04 -5267.62 1862.31 1.77 6025775.39 661803.19 N 70.47684999 W 148.67809488 10898.83 43.87 153.06 8867.94 5590.45 -5326.65 1890.60 2.45 6025716.98 661832.74 N 70.47668870 W 148.67786393 ~! f Schlumberger Private NS19 ASP Final Survey.xls Page 4 of 6 4/2/2003-4:09 PM Grid Coordinates Geographic Coordinates I! Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10993.63 44.61 149.73 8935.86 5656.56 -5384.70 1922.26 2.57 6025659.64 661865.65 N 70.47653011 W 148.67760538 i 11089.78 45.89 145.83 9003.57 5724.63 -5442.43 1958.68 3.17 6025602.71 661903.29 N 70.47637237 W 148.67730806 11183.79 46.01 140.54 9068.95 5791.36 -5496.48 1999.14 4.05 6025549.54 661944.90 N 70.47622467 W 148.67697767 11279.60 45.24 136.10 9135.98 5857.88 -5547.62 2044.64 3.41 6025499.40 661991.49 N 70.47608495 W 148.67660610 11375.97 45.41 132.07 9203.75 5923.06 -5595.27 2093.85 2.98 6025452.81 662041.71 N 70.47595472 W 148.67620428 11468.66 44.31 129.33 9269.45 5983.98 -5637.91 2143.40 2.40 6025411 .25 662092.16 N 70.47583820 W 148.67579967 11564.20 42.54 129.17 9338.84 6044.55 -5679.46 2194.25 1.86 6025370.81 662143.89 N 70.47572465 W 148.67538438 11660.51 40.69 129.19 9410.84 6103.51 -5719.87 2243.83 1.92 6025331 .48 662194.32 N 70.47561422 W 148.67497952 11714.41 39.65 129.83 9452.03 6135.64 -5741.99 2270.66 2.08 6025309.95 662221.61 N 70.47555378 W 148.67476047 11845.13 37.93 128.80 9553.91 6211.21 -5793.88 2334.00 1.41 6025259.43 662286.06 N 70.47541196 W 148.67424321 11938.67 37.14 126.63 9628.09 6263.16 -5828.74 2379.07 1.65 6025225.54 662331.86 N 70.47531668 W 148.67387518 12035.53 37.08 124.72 9705.34 6315.54 -5862.82 2426.54 1.19 6025192.50 662380.05 N 70.47522354 W 148.67348756 12130.52 37.46 121.85 9780.93 6365.99 -5894.38 2474.62 1.87 6025161.98 662428.79 N 70.47513729 W 148.67309495 t 12227.28 38.30 121.28 9857.31 6417.22 -5925.48 2525.24 0.94 6025131.98 662480.06 N 70.47505229 W 148.67268157 t 12321.59 38.33 120.15 9931.30 6467.20 -5955.34 2575.51 0.74 6025103.21 662530.96 N 70.47497066 W 148.67227109 12392.29 38.96 119.42 9986.52 6504.56 -5977.27 2613.83 1.10 6025082.11 662569.74 N 70.47491071 W 148.67195818 J~ 12418.39 39.15 119.87 10006.79 6518.45 -5985.40 2628.12 1.31 6025074.29 662584.20 N 70.47488848 W 148.67184147 12511.86 40.33 120.76 10078.67 6569.31 -6015.57 2679.70 1.40 6025045.24 662636.41 N 70.47480602 W 148.67142027 12607.94 41.66 121.87 10151.18 6623.53 -6048.33 2733.54 1.58 6025013.64 662690.94 N 70.47471646 W 148.67098063 12703.08 40.20 122.42 10223.06 6677.59 -6081.49 2786.31 1.58 6024981.63 662744.41 N 70.47462582 W 148.67054968 I 12798.78 38.54 124.11 10297.04 6730.82 -6114.77 2837.07 2.06 6024949.45 662795.87 N 70.47453485 W 148.67013520 r 12894.01 37.73 124.29 10371.95 6782.85 -6147.82 2885.71 0.86 6024917.45 662845.20 N 70.47444450 W 148.66973806 i ~ 12989.65 36.56 123.95 1 0448.18 6833.90 -6180.22 2933.52 1.24 6024886.09 662893.69 N 70.47435595 W 148.66934769 i 13085.11 35.88 123.77 10525.19 6883.65 -6211.65 2980.36 0.72 6024855.68 662941.19 N 70.47427005 W 148.66896524 -~ ;1 13180.26 35.75 123.97 10602.35 6932.76 -6242.68 3026.59 0.18 6024825.65 662988.08 N 70.47418523 W 148.66858776 ¡, 13275.83 35.82 124.12 10679.88 6982.14 -6273.96 3072.89 0.12 6024795.37 663035.04 N 70.47409970 W 148.66820967 i i 13371.09 37.80 126.04 10756.14 7033.04 -6306.78 3119.58 2.40 6024763.57 663082.42 N 70.47401000 W 148.66782847 £;, 13419.91 38.74 126.97 10794.47 7060.34 -6324.77 3143.1313 2.26 6024746.11 663107.10 N 70.47396083 W 148.66763004 13494.38 40.55 128.45 10851.81 7103.65 -6353.84 3181 .46 2.74 6024717.86 663145.29 N 70.47388137 W 148.66732323 13521.01 43.44 128.98 10871.60 7120.02 -6364.98 3195.36 10.93 6024707.01 663159.43 N 70.47385091 W 148.66720975 13553.87 48.25 130.66 10894.49 7141.85 -6380.08 3213.45 15.09 6024692.30 663177.84 N 70.47380963 W 148.66706204 13587.50 51.28 131.04 10916.21 7165.79 -6396.88 3232.87 9.05 6024675.94 663197.61 N 70.47376374 W 148.66690353 13615.81 55.27 131.80 10933.13 7187.04 -6411.89 3249.88 14.26 6024661.29 663214.94 N 70.47372271 W 148.66676466 13652.60 59.10 131.43 10953.07 7216.02 -6432.42 3272.99 10.44 6024641.27 663238.48 N 70.47366660 W 148.66657597 13684.92 60.50 131.55 10969.33 7242.18 -6450.92 3293.91 4.34 6024623.22 663259.80 N 70.47361602 W 148.66640515 NS19 ASP Final Survey.xls Schlumberger Private Page 5 of 6 4/2/2003-4:09 PM , ~ ¥ ;- i -i 11 ~I ~ i- , . Station ID Grid Coordinates Geographic Coordinates MD Incl I Azim TVD VSec N/-S EJ-W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 13712.77 61.53 130.12 10982.82 7264.90 -6466.85 3312.35 5.82 6024607.69 663278.57 N 70.47357249 W 148.66625467 13807.97 61.16 129.87 11028.47 7342.37 -6520.54 3376.35 0.45 6024555.39 663343.70 N 70.47342573 W 148.66573218 13903.35 60.94 130.03 11074.64 7419.73 -6574.13 3440.33 0.27 6024503.19 663408.82 N 70.47327924 W 148.66520983 13998.70 60.57 130.51 11121.22 7497.03 -6627.91 3503.81 0.59 6024450.79 663473.43 N 70.47313225 W 148.66469160 14063.00 60.57 130.51 11152.82 7549.15 -6664.29 3546.39 0.00 6024415.34 663516.78 N 70.47303281 W 148.66434401 ~. . .¡ 1 [¡ ii ,~ ç ~ 1 ; NS19 ASP Final SUNey.xls Schlumberger Private Page 6 of 6 4/2/2003-4:09 PM ) ') Date: 05-27-2003 Transmittal #92651 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS23 05-09-2003 SCH 1 0 13981 MWD SURVEY R~QRT/HARD.~OPYI DISKETTE f\.~) \"'> ~;l ~ ~~ itb>-¿;r)7 NS19 05-03-2003 SCH 1 14012 12550 JEWELRY LOG; ........ ,~~/ NS10 03-25-2003 SCH 4850 8015 RST WFL-UP FLOW MODE; ~.- NS19 05-05-2003 SCH 13140 14000 PERFORATING RECORD; NS06 04-09-2003 SCH 13000 13788 PERFORATING RECORD; ~S23 05-01-2003 SCH 11 040 13333 PERFORATING RECORD; 13" NS23 04-29-2003 SCH 1 13340 13212 DEPTH DETERMINATION SAMPLE BAILER;_'"" r,1é) .. \ C \ NS06 04-11-2003 SCH 13025 13746 BAKER IBP SET RECORD; ~,..., \0 NS18 07-17-2002 SPERRY END OF WELL REPORT/MUDLOG: 1.oél~(;l:13 NS22 01-22-2003 SPERRY END OF WELL REPORT/MUDLOG: lCb2-'-jlP'-I NS24 12-27 -2002 SPERRY END OF WELL REPORT/MUDLOG: ~rS - ~ ~~ \', ,,\L,~\...~V'\.... \_~ l Cj L '~-'v""_ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECE\VED MAY 2.8 200J Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Ala!ks Cf~ &. Uti;:. C(~~L C~,~ Ancf¡cm'~~ ) BPXA WELL DATA TRANSMITTAL BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Lisa Weepie Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn: Tim Ryherd MMS Attn: Doug Choromanski Attn: Kristin Dirks (DNR) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) Date: 05-27-2003 Transmittal #92651 ) ) Date: 05-09-2003 Transmittal Number:92648 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS19 10-28-2002 SPERRY 1 50 13500 MUDLOGS (END OF WELL aa~ ri)-'} REPORT) NS06 05-18-2002 SPERRY 1 50 13900 MUDLOGS (END OF WELL ~m-JDI REPORT) NS20 09-26-2002 SPERRY 1 50 18050 MUDLOGS (END OF WELL ~,~ Ic:¿?: REPORT) ~.(~o~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Howard Okland L j 51/,,) l,UeF¡tJIY Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn: Tim Ryherd R· .., E~, (' þ~, ·.~..t:\.¡E'- ~ f) . ' ~v ~ ~ .~. "'!"~' ~""',. W\t\Y 09 MMS Attn: Doug Choromanski _" ,'", r·o"" i"·;;'.'Ff.~n . <, ~!iI\ '¡jì\ & ''';';~~~ \,\,)I..~J.., ,.,O\,~,~,-i"', ' p},.\ô\,~.,...,· ,Anct1~"~ Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp ) ') Date: 04-15-2003 Transmittal Number:92639 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com SW Name Date Contractor NS16 03-19-2003 :B~ )~~NS16 03-19-2003 NS16 03-19-2003 Top Log Run Depth Bottom Depth Log Type SURVEY REPORT - GEODETIC FINAL SURVEY REPORT FINAL SURVEY - DISKETTE ~ NS19 :J9- ~'9-7 NS19 \NS19 03-25-2003 SURVEY REPORT - GEODETIC 03-25-2003 FINAL SURVEY REPORT 03-25-2003 FINAL SURVEY - DISKETTE ~~_Q ~~\.o ~'-'>~ d'-JV"\ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Howard Okland (AOGCC) X 2 reports Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) r::)ECE~\ 'E'·.....~'''~) r'-' "'.~\} Øl!t) ¡"PH 1 [) 2003 A]a~a Or; 5. G~,~ C,,~n¡:. i'.:t'mm1:!~':)n AnctJvr~it) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RE: Northstar Completion Delays ) ,) Subject: RE: Northstar Completion Delays Date: Mon, 17 Mar 2003 12:50:49 -0600 From: "Hernandez, Floyd" <HemanF1@BP.com> To: "'Winton Aubert'" <Winton_Aubert@admin.state.ak.us> Winton, The wells that could potentially have deferred completions will be NS16, NS19, NS23, NS20, & NS21. 2.02..- k>7 Just to let you know, I'm planning on suspending these wells with seawater and a diesel cap (1700'). This puts us in an under balance situations, except that before the well is switch over to seawater, a positive pressure test to 4370 psi will be conducted. After the switching to seawater, a negative test or inflow test will be performed for 30 minutes. A tubing hanger and BPV will also be installed and tested to 4200 psi. Any issues with how we suspend these wells? They are basically the same as what we have been doing on the previous Top Sag suspensions. Thanks, Floyd Hernandez Senior Drilling Engineer Northstar Development (907) 564-5960 work (907) 240-8056 cell hernanf1@bp.com -----Original Message----- From: Winton Aubert [mailto:Winton Aubert@admin.state.ak.us] Sent: Friday, March 14, 2003 6:50 AM To: Hernandez, Floyd Subject: Re: Northstar Completion Delays Floyd, No Sundries are necessary. Let me know by E-mail which wells are involved so I can update our files. Thanks, Winton "Hernandez, Floyd" wrote: > Winton, > > To be able to drill and case off as many wells thru the reservoir section > prior to the beginning of the Seasonal Drilling Restriction which begin on > June 1st, we have decided to delay running the tubing completions on wells > until after June 1st. Do you need a Sundry Notice or can we still utilize > the Original Drilling Permit which discussed "Operation Shutdown" of the > wells after top setting the Sag River. > > Thanks, > Floyd Hernandez > Senior Drilling Engineer > Northstar Development > (907) 564-5960 work > (907) 240-8056 cell > hernanf1@bp.com \ 'i ) ~1f!Æ~1 [J} !Æ~~~~~~ / ALASKA OIL AND GAS I CONSERVATION COMMISSION . Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Northstar NS-19 BP Exploration (Alaska), Inc. Permit No: 202-207 Surface Location: 1229' NSL, 646' WEL, Sec. 11, TI3N, R13E, UM Bottomhole Location: 8' NSL, 2555' WEL, Sec. 13, TI3N, RI3E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill 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). ~. i,nCerelY, . '.~ .. F~¡( Randy Ruedrich / ~ C Commissioner BY ORDER 91;.:tJIE COMMISSION DATED thisLZ.'dãy of March, 2003. cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ",,(71\- 3/ ¡t//Z-C-"()'3 Hole 6-1/8" , STATE OF ALASKA ALASKA ",1 AND GAS CONSERVATION COMM, .110N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 56.31 Northstar Unit 6. Property Designation ADL 312809 7. Unit or Property Name Northstar Unit 8. Well Number /' NS19 9. Approximate spud date 03/26/03/ Amount $200,000.00 14. Number of acres in property 15. P~osed depth (MD and TVD) 5301.38 138841 MD 1 11156' TVD o 17. Anticipated pressure {s~20 AAC 25.035 (e) (2)} 38.74 Maximum surface 3843 psig, At total depth (TVD) 11100' 1 5175 psig Setting Depth Top Bottom Quantity of Cement Lenath MD TVD MD /' TVD (include staQe data) 554' 13330' 10724' 138841 11156' 90 sx Class IGI /" Revised 03/11/03 Change BHL 1 a. Type of work III Drill 0 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 = 659829, Y = 6031001 12291 NSL, 6461 WEL, SEC. 11, T13N, R13E, UM At top of productive interval x = 663202. Y = 6024675 110' NSL, 2693' WEL, SEC. 13, T13N, R13E, UM At total depth x = 663342, Y = 6024576 8' NSL, 2555' WEL, SEC. 13, T13N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ./ ADL 312808, Approx. 2724' No Close Approach ( 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casino WeiQht Grade Couolina 4-1/2" 12.6# 13Cr Vam Ace 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13500 feet Plugs (measured) true vertical 10857 feet Effective depth: measured NIA feet Junk (measured) true vertical NIA feet Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner ~. :¡] ""\' -y .., --,,' ,:(¡,:'::::lli.] ¿¡;~~~C~;;t;12.',;\©~D 201' 20" Driven 201' 2011 3405' 13-3/8" 525 sx PF ILl, 475 sx Class 'G' 34051 3203' 11753' 9-5/8" 700 sx Econolite, 600 sx Class 'G' 117531 9483' 1896' 7" 380 sx Class IG' 11584' - 13480' 9354' - 10842' Perforation depth: measured NIA true vertical 20. Attachments III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherritt, 564-5204 Prepared By NamelNumber: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd HernanEk- '"> (X Title Senior Drilling Engineer Date 3((¿/o:3 , . ",,:~>;"i\è>,:t':i.:··.·:.··,:ì;'::i\,:C6mJiù_$~ë)ri:U.j:,Qa1IJ:(,:\;;;,:, Permit Number / API Number .... ' --"p~ r?~~1 D91E See cover letter ;:¿ 0 2. - 2- 0 / 50- 0.2 9' - ..2 -.:;; / 2. .:.2.- II 'J L \' 0) for other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log RaqUTed I8J Yes 0 No Hydrogen Sulfide Measures 0 Yes 181 No Directional Survey Required JE Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: le,S1- 'loPE fc "KeD lS l. · by order of \ ~~ 0 '? Approved By ~-"",,"", ~--t."______ ~ Commissioner the commission Date /) ') ~-. ::> Form 10-401 Rev. 12-01-85 Submit In -riplicate ',",." ðP ,71Í7 /fj ~ bp ) ') ... ,"'.'11, .-.....~ ~~~ ~~- ~..- 4..~ F...... 611'·".'_ ". BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: March 11, 2003 From: Allen Sherritt Northstar Operations Drilling Engineer Subject: NS19 Application for Drilling Permit - Resubmission for change of BHL Original Permit #202-207 API #50-029-23122-00 Mr. Aubert, NS19 was originally permitted as a horizontal completion in the Northstar Ivishak formation. After further review of reservoir modeling, the decision has been made to complete NS19 as a conventional S-shaped /' well with a solid/cemented 4 112" liner. This resulted in a greater than 500' change to the permitted original bottom hole location. Nabors 33E is currently on schedule to re-enter NS19 on March 26th, 2003. ~. Please find attached the NS19 Well Plan Summary, directional plan (P7) and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5204. Sincerely, ~n Sherrill BP Northstar Operations Drilling Engineer 564-5204 ) ') NS19 SUMMARY DRILLING OPERATIONS Pre-RiQ Summary: NS19 was drilled/cased to the top of Sag River formation. The 7" liner is currently set at 13,4801 ~D into the top of the Sag at 38.7° Inc. at a 126.9° azimuth. The top of the liner is set at 11,585' MD. Several problems packing off prior getting the 7" liner to bottom and while establishing circulation, however, the cement job was pumped and the liner was released without problem. The well was left with a 12.8 ppg- /' KCI Polymer mud in the liner with seawater in the 9 5/8" casing with a 125 bbl (-1700') diesel cap. The well was tested to 4800 psi prior to displacement of freeze protection. The 6 1/8" production hole will be drilled to a final TD of -13,8841 MD 11,156' TVD, (subject to variations in tops.) The final hole angle is tangent at a proposed inclination of 38.7°, however, the angle will be allowed /' to drop dependent on BHA tendencies. NS19 is no longer a planned horizontal well. During the planning session for this well, lost circulation in the pay-zone was discussed. There is a small probability of encountering sub-seismic faults in the production interval, see fault discussion in the SOR. NS19 is a planned producer well to be completed with a 4 Y2" 13Cr-80 solid liner and a 4 Y2" 12.6# Cr-80 tubing string. A proposed schematic is attached. RiQ Operations: · Prior to moving the rig off of NS16, review the attached NS19 Risk Assessment for moving over NS15 (wells with annular communication). 1 . Prepare to re-enter well BPst IISeasonal Drilling Restriction." 2. MIRU Nabors 33E. /' 3. Verify there is no pressure on the tree. ND tree. a. The well was left with a TWC, tested to 4200 psi from below. /' 4. NU BOPE, pull the tubing hanger and run the test plug. Open annulus valve and test to 250/4800 pSI. Test annular to 3500 psi. 5. Pull the test plug. Install the wear bushing. 6. RIH with 4" drillpipe to 2000' MD, circulating/displacing out diesel to the trip tank. Change over to seawater. a. Have G&I and rig crew line up Trip Tank#1 sump to G&I disposal pump suction. b. Coordinate with G&I and circulate one surface-to-surface volume of seawater, monitoring the volume in Trip Tank #1. c. When the Mud Engineer is satisfied with the water quality, the hole can be lined up elsewhere on the rig. d. POOH · See Baroid Mud Program: Well Clean-out/Displacement Procedure. 7. Test 9 5/8" x 7" liner to 4800 psi for 30 minutes. / 8. MU 6 1/8" drilling assembly and run in the hole. 9. A MAD pass for real-time Gamma Ray will be run from 12630' - 12730' MDrkb. All depths are Gamma Ray tool depths. Running speed through specified intervals should be 50 - 60 fpm (equivalent to 2 samples per foot). At depths between these intervals, resume normal running speed. When just above the landing collar, CBU with seawater and high viscosity sweeps. 10. Clean out 7" liner to the landing collar while displacing to re-conditoned Drill-N fluid system. · See Baroid Mud Program: Review possibility of using re-conditioned BaraDril-n fluid from NS16 · See Baroid Mud Program: Review lubrication strategy outlined in attached Mud Program. 11. Drill out remaining cement. Drill 201 of new formation below 7" shoe. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). / NS19 Permit to Drill- Chan.. )n BHL ., 12. Drill 6-1/8" production interval to proposed TD at 13,884' MD (11156' TVD). Increase mud weight to,/' 9.3 ppg prior to POOH. ~ · Production interval is a proposed tangent hole angle of 38.7°. · While POOH, perform MAD Pass with LWD tools from TD to Top of Ivishak. 13. POOH to the top of the 7" liner. Open circulation sub and circulate at maximum flowrate (630 to 750 GPM) for at least 1 bottoms up or until wellbore is clean. POOH. · No openhole logs required 14. Run and cement the 4-1/2" 12.6# 13Cr liner with an 2 7/8" inner string. Set the liner hanger and liner / top packer. Circulate a minimum of one bottoms-up to remove excess ~ement with a 9.3 ppg- viscosified brine. Ensure proper RAMS are run in the BOP for Well Control. Drill pipe elevators and a TIW crossover from 4 1/2" to DP will be on the rig floor at all times. · When pumping cement, "pump till you bump". If you do not bump the plug, circulate out the cement in preparation for another cement job. Discuss with Anchorage team. 15. Once a successful cement job is obtained, pressure test liner lap to 1500 psi with 9.3 ppg mud to confirm pressure integrity. 16. Change well over to clean seawater thru the inner string (less than 80 NTU's) and by using spacers as per Baroid recommendation. 17. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). 18. POOH. Close the blind rams and pressure-test the liner lap to 4350 psi with 8.65 ppg seawater in the well for 30 minutes. Prepare to run the 4 Y2" completion. Note: Assume 15.5 ppg LOT at 10,732' TVD liner lap. Test to 500 psi over LOT with seawater. 19. Run the 4 %", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will / be run from packer setting depth to surface. Ensure proper RAMS are run in the BOP for Well Control. Drill pipe elevators and a TIW crossover from 4 1/2" to DP will be on the rig floor at all times. · Gator Hawk may be used to confirm connection integrity while running the 4 Y2" completion. Review Gator Hawk running procedures, verify rig floor setup requirements and coordinate with Nabors Casing crew. Gator Hawk representatives will be on location to run equipment. Note: Consider running a gauge ring inside the 4-1/2" liner if prior to running completion string if there are any indications that cement may have been left inside the liner during the cement job and change over to seawater. 20. The SCSSSV control line will be run from the Camco TRM 4E tubing retrievable SSSV at +/- 1000' TVD to surface. a. Attach control line to TRM-4E; apply 6000 psi and monitor for 5 minutes. b. Run in well with 6000 psi on line and SCSSV and clamp on to tubing. c. A representative will be on-site while running/testing the TRSSSV. ,21. RIH to packer setting depth. Record pick up and slack off weights. Tag up on the 4-1/2" ZXP liner top packer with 5-10k. Regain full string weight and PU an additional 5' to confirm spaceout. This should leave the WLEG spaced out in the tie back extension +/- 5'. Space out pups should be placed 1 full joint below the tubing hanger. 22. Run space out pups and terminate the 0.25" control line and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function- test the fiber optic line. Land tubing with 6000 psi on control line. 23. Drop ball and rod to set packer. Increase control line pressure to 6000 psi and maintain during packer setting operation and subsequent tubing tests. 24. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. /i 25. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on 2 NS19 Permit to Drill- Cha.....)n BHL ') chart. Maintain at least 6000 psi on control line during this operation. Email or fax chart to Drilling Engineer. 26. Bleed down the annulus to 0 psi. Bleed down the tubing to 0 psi. 27. Pressure up on the annulus to shear the RP in the lower most GLM. As we have been having difficulty with the RP shear valve, it is essential this pressure sequence be followed. Pressure up the casing to 2500 psi. Maintain at least 6000 psi on control line during this operation. 28. Release pressure on the casing and the SSSV control line (closing the SSSV). Pressure up on the backside to 1000 psi to test the SSSV from below (through the RP). If o~, bleed pressure to 0 psi. 29. Open the SSSV by pressuring up on the control line. 30. Pump corrosion inhibitor and heated diesel down the 4 Y2" x 9 5/8" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (approximately 4457' MD). RU the U-tubing piping. Maintain at least 6000 psi on control line during this operation. 31. Allow fluids to U-tube from the annulus into the tubing through the lower GLM. Maintain at least 6000 psi on control line during this operation. 32. Set and test the TWC. Close SSSV. ND BOP's. NU Tree. Test the tubing head adapter and tree to 6000 psi. Attach manifold to control line port on tree, test to 5000 psi, and hold for 10 minutes. If ai/I . ok, bleed to 0 psi. 33. Pull the TWC. Leave the SSSV closed. Ensure all valves are closed. RD and move off well. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod / RHC profile from 'XN' nipple below the new production packer. 2. Perforate -140' Ivishak formation between the Top Ivishak and OWC. PERFORATE INTERVAL BASED ON PE RECOMMENDATION. 3 NS19 Permit to Drill- Chan_ }n BHL ') NS19 WELL PLAN SUMMARY I Type of Well (producer or injector): NS19 1228' FSL, 646' FEL, Sec. 11,T13N,R13E,UM X = 659828 Y = 6031001 110' FSL, 2693' FEL, Sec. 13, T13N, R13E, UM X = 663202 Y = 6024675 10,877' TVDrkb 8' FSL,2555' FEL,Sec. 13,T13N, R13E,UM X = 663342 Y = 6024576 11 ,156' TVDrkb I AFE Number: 1831331 I Rig: I Nabors 33E I I Est. Re-Entry Date: I 3-26-03 I Operating days to complete: 112.5 I I MD: 113,884 I I TVDrkb: 111,156' I I RKB/Surface Elevation: (a.m.s.l.) 156.0' / 15.9' I I Well Design (conventional, slim hole, etc.): 1 Modified Big Bore 1 I Objective: I Ivishak Producer with fiber optic surveillance control line I Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 13884' MD / 11156' TVD Interval Density (ppg) / PV YP Initial/Final 9.1 - 9.3 I 8 - 12 20 - 25 Northstar Slot: Surface Location: Target (top of SAG): 300' Radius Bottom Hole Location: Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: MUD PROGRAM: DISPOSAL: 1 Producer .,/ / NS19 50-029-23122-00 Producer 5175 psi @ 11,100' TVDss 8.96 ppg 254 of @ 11,100' TVDss Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 2011 MDrkb of 20", 169#, X-56 (pre-driven) 6-1/8" Hole Section Tauo API FL 4-7 3-5 pH 8.5 - 9.5 Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS1 0 Class I Waste Disposal Well. 4 NS19 Permit to Drill - Char... )n BHL ) DIRECTIONAL:(P7) KOP: Maximum Hole Angle: Close Approach Well: Survey Program: Tangent through production interval hold at 38.70 ±46.4 0 No close approach issues. Well is in reservoir. Gyros from surface to 1465' MD. Standard MWD surveys from 1465' MD to 13884' MD. SURFACE AND ANTI-COLLISION ISSUES: There are no close approach wells in the vicinity of NS19 production interval. Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. LOGGING PROGRAM: 6-1/8" Section: Drilling: GR/Directional, Resistivity/Density/Neutron (recorded) Place Resistivity tool above the Density and Neutron MADD Pass is required from TD to the Top of the Ivishak (....13,727' MD) Mud Logging - Gas analysisldetection, show kit with indexed sample bottles, lithology description Open Hole: None Cased Hole: None Intearitv TestinQ: Test Point Depth Shoe Test EMW Casing/Liner Test Type FIT 12.5 ppg EMW 3550 psi wi 8.8 ppg FIT 14.5 ppg EMW 3900 psi wi 11.4 ppg FIT 11.5 ppg EMW Target 4800 psi wi 8.65 ppg ../ 4350 psi wi 8.65 ppg ACTUAL 133/8" Surface 20' min from 12 1/4" shoe 9 5/8" Intermediate 20' min from 9 5/8" shoe PROPOSED 7" Drilling Liner 20' min from 7" shoe 4 Y2" Production Liner CASINGlTUBING PROGRAM: Hole Size Casingl WtlFt Grade Conn. Casing Casing Top Hole Btm Tbg O.D. Length M DITVDrkb MDITVDrkb PROPOSED / ('" 6-1/8" 4-1 12" 12.6# 13Cr Vam Ace 514' 13330'/10724' 13884'/11156' Tubing 4-1 12" 12.6# 13Cr Vam Ace 13330' Su rface 13330'/10724' 5 NS19 Permit to Drill- Char.... ')n BHL ) FORMATION MARKERS: NS19 - Spud 10/29/02 Prognosed Tops Actual Depths Delta Formation TVDss I TVDrkb I MDrkb TVDss I TVDrkb I MDrkb TVD Top Permafrost 1,149 1206 1210 1149 1206 1210 0 Base Permafrost 1,519 1576 1586 1519 1576 1586 0 SV6 - top confining zone 2,988 3045 3194 3008 3065 3230 -20 Surface casing point 3,150 3207 3399 3161 3218 3426 -11 SV5 - base confining zone 3268 3325 3555.62 3286 3343 3582 -18 SV4 3,578 3635 3968 3595 3652 3983 -17 SV2 . top upper injection zone 3,988 4045 4514 4002 4059 4537 -14 SVl - top major shale barrier 4,381 4438 5038 4395 4452 5096 -14 TMBK - top lower injection zone· Top Ugnu 4,783 4840 5573 4750 4807 5573 33 WSl . top Schrader Bluff· Base Ugnu 5,795 5852 6921 5795 5852 6921 CM3· Base lower injection zone (top Colville) 6,896 6953 8387 6881 6938 8410 15 THRZ - Top HRZ 8,838 8895 10960 8698 8755 10735 140 BHRZ - Base HRZ 8,908 8965 11050 8813 8870 10901 95 Top Kuparuk 8,917 8974 11061 8881 8938 10996 36 Kuparuk C 9,123 9180 11326 9103 9160 11250 20 Top Miluveach 9,347 9404 11617 9408 9465 11742 -61 Intermediate casing point 9,387 9444 11669 9444 9501 11778 -57 Intermediate logging point 9,387 9444 11669 Decided not to run Top Kingak 9,925 9982 12371 9895 9952 12343 30 Fault 15 . throw = 200' 10200 10257 12731.1 10258 10315 12816 -58 Top Sag River 10,822 10879 13542 10778 10835 13478 44 Geol target #1 10,822 10879 13542 10822 10879 0 Current Depth 10800 10857 13500 Intermediate casing point 10,852 10909 13581 10800 10857 13500 Top Shublik· 90 10,888 10945 13628 10888 10945 13628 Top Ivishak 10,978 11035 13727 10978 11035 13727 Total Depth 11,100 11156 13884 11100 11156 13884 Oil . Water contact 11,100 11156 111 00 11156 0 6 NS19 Permit to Drill- Chan,- ')n BHL REQUIRED MATERIALS: 13Cr Liner: 514' 2-20' 1 - 4-1/2" 1 - 4-1/2" 30 - 4-1/2" x 5-3/4" 15 - 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 -4-1/2" 13Cr Completion: 13330' 1 1 1 1 1 1 1 1 1 2 1 CEMENT CALCULATIONS: ) 4-1/2", 12.6# 13Cr-80 Vam Ace (for liner lap) 4 1/2" Pup joints - Marker joints HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 4-1/2",12.6# 13Cr-80 Vam Ace 4 Y2" ABB-VGI tubing hanger 4 Y2" ABB-VGI adapter flange 4 Y2" ABB-VGI 5-1/8" 5K Swab Valve w/ tree cap CIDRA mandrel and 0.25" fiber optic cable (w/4 Y2" cable clamps). 4 Y2" TRSV and 0.25" control line 4 Y2" x 1" GLM with dummy valve installed 4 Y2" X 1" GLM with RP Shear valve installed 7" x 4 Y2" Baker 13 Cr packer S-3. 4 Y2" Halliburton Self Aligning Mule Shoe 4 Y2" 13 Cr X nipples 4 Y2" 13 Cr XN nipple The following cement calculations are based upon the planned production interval for a single stage job. Values will need to be re-calculated for actual conditions. Casing 14-1/2" Prod Liner I Basis: Stage 1: Slurry: Based on 404'~f- 1/8" open hole x 4 Y2" csg with 100% excess + 150' 7" csg x 4 Y2" csg liner lap- 200' 7" csg x 4" dril!,µ1pe bove TaL + 4' shoe joint. Slurry TOC: At -)'33: MD (10724' TVD) , Stage 1: Total Cement l;SpaÇer Spacer 20 bbl Alpha Spacer weighted to 1.0 ppg over mud MW ~. Slurry 24 bbl / 90 sk /135 fe of 15.9 ppg Premium 'G'. / 1.50 cf/sk, BHST 2500 / BHCT 1500, TT = 4.0 hrs 7 NS19 Permit to Drill - Chan... }n BHL ) WELL CONTROL: ~ Equipment to be Installed and capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) ~ 5000 psi working pressure pipe rams (2) ~ Blind/shear rams ~ Annular preventer ~ Based upon the calculations below, BOP equipment will be tested to 4800 psi. Production Section: · Maximum anticipated BHP: 5175 psi @ 11100' TVDss - Total Depth · Maximum surface pressure: 3843 psi @ surface /" (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) · Planned BOP test pressure: 4800 psi (annular to 3500 psi) · Planned completion fluid: 8.65 ppg Seawater / 6.8 ppg Diesel DRILLING HAZARDS/CONTINGENCIES: HYDROGEN SULFIDE - H2S: ./' Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. ./' No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A- 03 exploration/appraisal wells. ./' No H2S was detected while drilling the NS10 waste disposal well, or any subsequent Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. PRODUCTION SECTION: · dlogg s will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will e cir åted out as required. · e drilling liner shoe was suspended with 12.8 ppg mud. This mud will be displaced with seawater prior to swapping over to the 9.1 ppg drill-in fluid. The mud weight will be increased tq/" 9.3 ppg prior to tripping out of the hole. · Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. · Losses are not expected but calcium carbonate (CaC03) will be maintained in the system. Severe lost circulation was encountered on the NS29. · The Ivishak is a conglomerate section. Directional control will be maintained, with MWD surveys to minimize doglegs. · Ensure that the proper procedures and personnel are in place prior to pulling out of the hole and while POOH for the production liner. · The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open hole) assuming an influx from the proposed TO. This scenario is based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 11.5 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. 8 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ) 13 3/8", 68#/ft, L-80, STC @ 3405' MD 9-5/8" 47# L-80 BTM-C @ 11753' MD 7", 26#/ft L-80, Hydril 521 @ 13480' MD DATE 9/24/02 11/20/02 12/20/02 REV. BY BMH EMF EMF NS19 Operation /' Shutdown: .. ~ ~ -' H A"" ') RKB. ELEV = 56.3' KB-BF. ELEV = 40.4' CB. ELEV = 15.9' 6.8PPG DIESEL FREEZE PROTECTION AT 1695' TVD (1707'MD) .. 8.65 ppg Seawater from 1707' MD I 1695' TVD to 11584' MD I 9354' TVD I\. - 7" LINER TOP @ 11584' MDI 9354' TVD ~ 12.8 ppg drilling mud ~ ... COMMENTS ~S19 Operation Shutdown Update TVD / MD Depths Update KB Information PBTD 13393' MD I 10773' TVD Northstar WF' . : NS19 API NO: 5007931.7700 BP Exploration (Alaska) TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ) NS19 - Proposed 13 3/8" TAM Port Collar at +1-1 OOO'MD .. 13 3/8", 68#/ft, L-80, BTC @ 3426' MD ~ 4 1/2", 12.6#/ft, 13-Cr, Yam-Ace TUBING ID: 3.833" .. CAPACITY: 0.0152 BBLlFT ORIGINAL KB. ELEV = 56' /" )-BF. ELEV = 40.1' CB. ELEV = 15.9' 41/2" TRSSSV @ 1000' TVD 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' TVD (4457'MD) ~ 4 1/2" GLM @ 4500' TVD (5123' MD) 4 1/2" GLM @ 5534' TVD (6500'MD) 9-5/8" 47# L-80 BTM-C @ 11753' MD .6 ~ - 7" LINER TOP @ 11585' MD -;¡ _ 7" PACKER,13 Cr @ 13290' MD ~: 4.5" X NIPPLE, @ 13270' MD ~ I 4.5" X NIPPLE, @ 13400' MD B_ 4.5" XN NIPPLE, @ 13310' MD 4.5" WLEG, @ 13320' MD B 7", 26#/ft L-80, Hydril 521 @ 13480' MD ~ PBTD @ 13880' MD TD @ 13884' MD ~ DATE 9/24/02 11/25/02 3/11/03 COMMENTS '}JS19 proposed NS19 Proposed Revision #1 NS19 Proposed Revision #2 REV. BY BMH FH JAS ~ .. 4.5" Fiber Optic Transducer @ -12250' MD 4.5" LINER TOP @ 13330' MD 4.5",12.6#, Solid Cemented 13Cr Yam Ace Northstar WFI ~ : NS19 API NO: 50-0.?9-?31 ??-OO BP Exploration (Alaska) õ Report Date: Client: Field: Structure / Slot: Well: Borehole: UWI/API#: Survey Name / Date: Tort / AHD / DDI/ ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NÆ Y/X: Grid Convergence Angle: Grid Scale Factor: NS19 Proposed Well Profile - Geodetic Report January 14, 2003 Survey / DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Northstar 11 O·l03 Vertical Section Origin: Northstar PF / NS19 ed 3 I' TVD Reference Datum: NS19 APpro¥ TVD Reference Elevation: NS 19 Sea Bed / Ground Level Elevation: 500292312200 Magnetic Declination: NS19 (P7) final slant / January 14,2002 Total Field Strength: 160.882° /7726.44 ft /6.189/ 0.69~ Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.49124105, W 148.6933070E Magnetic Declination Model: N 6031001.380 ftUS, E 659828.230 ftUS North Reference: +1.23170016° Total Corr Mag North -> True North: 0.99992902 Local Coordinates Referenced To: SeIIlu_. Minimum Curvature / Lubinski 153.390° N 0.000 ft, E 0.000 ft KB 56.3 ft relative to MSL 15.670 ft relative to MSL 26.018° 575512.83 nT 80.953° 22-Mar -03 BGGM 2002 True North +26.018° Well Head -- Grid Coordinates Geographic Coordinates I Station ID MD Incl I Azim TVD VSec NI-S EI-W DLS Northing I Easting Latitude I Longitude (ft) (, (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 7"Csg 13480.00 38.74 126.97 10841.34 7096.69 -6347.38 3173.93 0.00 6024724.15 663137.63 N 70.47389903 W 148.66738472 Top Shublik 13612.00 38.74 126.97 10944.30 7170.67 -6397.06 3239.92 0.00 6024675.90 663204.66 N 70.47376323 W 148.66684594 Top Ivishak 13727.38 38.74 126.97 11034.30 7235.33 -6440.49 3297.61 /~O.OO 6024633.73 663263.27 N 70.47364451 W 148.66637493 owe 13883.78 38.74 126.97 11156.29 7322.98 -6499.35 3375.81 0.00 6024576.57 663342.71 N 70.47348362 W 148.66573648 TO 14-1/2" Lnr Pt 13883.79 38.74 126.97 11156.30 7322.99 -6499.35 3375.81 0.00 6024576.57 663342.71 N 70.47348362 W 148.66573648 Leaal Description: NS19 (P7).xls Northina (Y) rftUSl 6031001.38 6024724.15 6024576.57 Eastina (X) rftUSl 659828.23 663137.62 663342.71 Surface: 1228 FSL 646 FEL S11 T13N R13E UM Tie-In: 160 FSL 2757 FEL S13 T13N R13E UM BHL: 8 FSL 2555 FEL S13 T13N R13E UM Schlumberger Private Page 1 of 1 ~' 3/10/2003-4:09 PM ) VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: NS19 (P?) Field: Northstar Structure: Northstar PF Section At: 153.39 deg Date: January 14, 2003 ') ScblulDbøPllP ...- ã5::::J ..æcn o~ o Q) 'r" > II 0 .~ ~ 'r"~ '-"0 ..s:::('f) ë.<ó Q)LO Om CQ~ o.¡..: t CJ.) Q)a:: > > Q) Q) 2m I- 10600 -.".., 1 0700 .,,,,''''....-,,.-.''',,'......,...-..'''.,............,-..,,,'''.-.....----".....-..-.".,-,..........-."-.....,,.-... 1 0800 -......,.,....,.,."."""...,.-"., / r'c.g 13480MD 10841 TVD 38,74' 126,97' az 7097 departure 10900 -........."..--..,.,.,....,...,... --------------r---- Top Shublik 13ò12 MD 10944 TVD ---------------- 11000 -,.""..,.""..""'. ,,,.,,.,,...,...,.,, ,,,,,,,,.,..,.,.. "",."",,,.,.,,.,.,.,,.,.,,,,,..,,,.,,,,,,,,.,,,,,,.,,.,..,,,,. ,,,'" ...,,,.,,,,.' ,,,.,,,,,,,,,.,, ",.",.,.",.".'.'."'.'. """" Top Ivishak 13727 MD 11034 TVD ------------------------------------ 111 00 -....".".,......"'" .."'""'",,,...',,,,.,,,,,.,,,,.,--,.."',,,"'.,.,.,. -" ,.",-,-.,,"'..-..,-,..,-, ----,..".-..,..".".,-,--,-,,","..'-.-.,.."..."""---'",."" ,-",,,,,,,.,,,. "'--" --",'. " TD 14..112" Ln' Pt "·"'''i"3à84MÖ··'11156 TvC 38,74' 126.97· az 7323 deperture I - - - owe 13ã84 MO 11156 NO - t - - - - - - - - - - - - - - - I ! I I ---..,'- 1"-'- I I ¡ I ~ 7200 11200 11300 6900 I 7100 7000 - - -- Vertical Section Departure at 153.39 deg from (0.0, 0.0). (1 in = 100 feet) 7300 I 7400 ö 2900 , -6200 --'---' -6300 PLAN VIEW Client: BP Exploration Alaska Well: NS19 (P7) Field: Northstar Structure: Northstar PF Scale: 1 in = 100 ft Date: 14-Jan-2003 3100 I 3200 3300 I 3400 , 3500 ^ ^ ^ I ..... 0::: o Z -6400--·-~J.-,--- ¡ T'Csg ~ 13480MD 10841 tvo 38.74· 126,97" az\ 6347 S 3174 E ' -6500 _------i---- I ..... ::> o (/) V V V -6600 _ ,_u.~ -6700 I 2900 ¡ I 3000 I 3100 «< WEST True Horth Mag Dee ( E 26.02° ) i i NS19 crrrent ¡ ! I I=~=~~ ~ ~ ~¿ '()' !~~ ~~ {:>e ·.9'>0 TO /4-112" Lnr Pt 13884 MD 11156 TVD 38.74' 126,97' az 6499 S 3376 E ¡ ¡ i t 3200 I 3300 EAST »> 3400 3500 SchlußlbørUlr 3600 -6200 ~ -6300 -6400 -6500 --" --6600 -6700 3600 ')) BP Exploration Alaska Anticollision Report 'çQlJ)p~ny:> ......, "·;;';åPÄ~b&j':: Fiêldf", : .,cNdrt~.$tåf/.( , J,te £e re,n ~e Si ~e :h":"¡I\4~~6~ry:PF' ·j~;t:i~,;:::¡~:':;ri~t~~1·~·.·.;;,;:···(··i·;· " ,'" ',., ','., :,':,:',' ..::,.,:,;:.,.·.',·...,·,'".D.:,'.,:~t,Ç(F~#ÔI¿dQ~;,·' ·,Ti:.µe,'::·..·..1.::.~.::1.~:..~.·,.'~'. ,.......' ,'. ,;~ì>4g~;'; 1; ;'.{\: "».<' . ' . . , . ,. ., ;,<,:.,\,,:.,;'';ÇCJ~~t~il1~t~(~*f,,~~~~~~c'e('fVè:lliN'§+~,T~J~Nd~~::,:' :,.. ¡, ,,'::"'<c:::,: . ; ,:'/ ' ".' ': v,-erfic::a:1':(;r,,~~'fle;f~"ence;:" NS19'56,.3'" ' ": " ,'.:.' "..:,:......,. ".,b""';~. "","',',S··. ·y···...'b'.:,.a'.:.'.'s·,..·,e·.'..... (.:'-;::,:'.';':<'.';,.:."¡' :,'/:, "'."; ..j:.... ", . ':.:".\<,' ;".:"/.':",,.;: (i;"'.;·' ",",-,:' " ,". ..."....,.:'.',':;:.. .(>.:.~: V . NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation MethodsllD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.40 to 13883.78 ft Scan Method: Trav Cylinder North Maximum RadiusßOOO.OO ft Error Surface: Ellipse + Casing ,,":,. .:.\;; \" ;:: . !.":'::,." I.;.",.: ',:' '" >;'''.:::.::,' ~>'-::I ' Survey Program for Definitive Wellpath Date: 1/14/2003 Validated: No Planned From To Survey ft ft 50.00 1465.00 1493.01 13419.91 13419.91 13883.79 Version: 14 Toolcode Tool Name Survey #1 Survey #2 Planned: Plan #7 V1 GYD-GC-SS MWD+IFR+MS MWD Gyrodata gyro single shots MWD + I FR + Multi Station MWD - Standard Casing Points 3426.00 3218.49 13.375 16.000 13 3/8" 11778.00 9501.28 9.625 12.250 95/8" 13480.00 10841.34 7.000 8.500 7" 13883.79 11156.30 4.500 6.125 51/2" Summary Northstar PF NS06 NS06 V34 800.89 800.00 135.11 13.88 121.23 Pass: Major Risk Northstar PF NS07 NS07 V33 49.45 50.00 119.87 1.39 118.48 Pass: Major Risk Northstar PF NS08 NS08 V18 1048.56 1050.00 118.11 18.02 100.10 Pass: Major Risk Northstar PF NS09 NS09 V14 1097.51 1100.00 107.27 18.08 89.21 Pass: Major Risk Northstar PF NS10 NS10 V17 700.07 700.00 80.73 10.51 70.33 Pass: Major Risk Northstar PF NS12 NS12 V25 Plan: Plan #1 1246.63 1250.00 44.23 25.89 18.71 Pass: Major Risk Northstar PF NS13 NS13 V12 699.70 700.00 67.79 11.30 56.50 Pass: Major Risk Northstar PF NS14 NS14 V11 999.64 1000.00 48.69 17.22 31.52 Pass: Major Risk Northstar PF NS15 NS15 V19 149.76 150.00 41.54 3.22 38.33 Pass: Major Risk Northstar PF NS16 NS16 V34 149.28 150.00 30.77 3.82 26.97 Pass: Major Risk Northstar PF NS17 NS17 V12 49.80 50.00 19.94 1.39 18.55 Pass: Major Risk Northstar PF NS18 NS18 V12 1 00.42 100.00 10.29 1.78 8.51 Pass: Minor 1/200 Northstar PF NS20 NS20 V10 201.04 200.00 9.38 1.97 7.42 Pass: Minor 1/200 Northstar PF NS21 NS21 V46 200.12 200.00 19.74 4.07 15.71 Pass: Major Risk Northstar PF NS22 NS22 V13 349.35 350.00 20.60 6.16 14.45 Pass: Major Risk Northstar PF NS23 Plan NS23 V26 Plan: PI 350.43 350.00 39.02 6.46 32.57 Pass: Major Risk Northstar PF NS24 NS24 V15 698.74 700.00 53.45 11.70 41.76 Pass: Major Risk Northstar PF NS25 Plan NS25 V6 Plan: Pia 1494.49 1500.00 37.52 27.00 10.90 Pass: Major Risk Northstar PF NS26 NS26 V22 500.33 500.00 67.39 8.44 58.95 Pass: Major Risk Northstar PF NS27 NS27 V29 997.80 1000.00 82.60 17.82 64.81 Pass: Major Risk Northstar PF NS29 NS29 V22 350.11 350.00 98.31 6.16 92.15 Pass: Major Risk Northstar PF NS31 NS31 V14 1046.33 1050.00 126.24 18.52 107.73 Pass: Major Risk Northstar PF NS32 Plan NS32 V2 Plan: Pia 598.95 600.00 129.95 10.98 118.97 Pass: Major Risk NorthstarPF NS35 Plan NS35 V1 Plan: Pia 351.17 350.00 158.25 12.61 145.64 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 996.27 1000.00 325.33 19.05 306.28 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 204.53 200.00 302.00 5.55 296.46 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 204.56 200.00 302.41 5.79 296.63 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 13675.29 14050.00 356.90 329.18 122.16 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 804.50 800.00 344.92 14.61 330.32 Pass: Major Risk '055009 DATE 2/19/2002 INV# CK121702R INVOICE I CREDIT MEMO -r¡ð J 9 DESCRIPTION PERMIT TO DRILL FEE -IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHQRAGE, AK99519-6612 PAY: TO THE ORDER OF: GROSS DATE CHECK NO. } 12/19/2002 P055009 VENDOR DISCOUNT NET ~ ~ì,'~.·:' ¡'~""" \:~ \¡ M t í) "1 ",,; (')'\íY;} nr\r\ ! ....' L",\kh" '¡I;;;~~~Ri¡ ,~~,:f.,",. 56-389 412 No. P 055008 NATIONAL CITY BANK Ashland, Ohio CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT :.,.'. : ,':,', .":"",: ::::,"';,:;:", :".':','. ., ,'. '.,' :', ,":"i .' ".:,.....'....:.... ..'........... ..,.:....... .....:..:............ ..':"",. .,. . '.:-:,'.:':.. ." . . '.'. ",;.: ,';;,;::'; ';':" ,',',.,', ':', .:" ."" " .. '.':. ALASKA OIL &GAS CONSER\!ÅTION COMMISSION' ... 333 W 7TH AVENUE SUITE 100 ANCHORAGE,AK 99501 DATE Decembef19,2Q02·. **~***~~.,.t*****$1 00.00*** ':,':',: : ,..; NOT7~t:~~:¡7:~~~·:~:;~~~:.~t·,..:,~ ·;S::~~~~:~.;}~{~~\ . ..~A~. oiIi' t ,.~., .,..,,~.,.-. ...... ...... "h' '.\'.:':': ~w ~f~::~~',:;~;j" :;',,\';\0 ::'.. :~-' ::·..~...1 ...~,.. " ~,~~ r J;j'1:P' 'I,J,_'J''''~'''>'''''''''' _.~ -~~.;~ i~:: ::"::~::..:: : :;:;:.: ::': ::::. ~~~:£~i~fii,~ ~};:';;~~tt;:?~:(··~~::; ~~':li) III 0 5 5 DOg III ': 0 ~ ¡. 2 0 j 8 g 5 I: 0 ~ 2 7 8 tU; III WELL PERMIT CHECKLIST COMPANY N)¿ WELL NAME AJ. ~ /9- FIELD & POOL ,..o)'7~/rJr~ INIT CLASS t)e.-V }-o/ I ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ (Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE ¿~ APPR DATE \¡jC7A- 7> i 1'-/ I () ~ (Service Well Only) GEOLOGY APPR DATE ¡fff: 3J1Ä3 (Exploratory Only) 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . .. . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . ... . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . ,.. d . . . . . . . . 27. BOPE press rating appropriate; test to L/ 1f 00 psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... PROGRAM: Exp _ Dev.x Redrll _ Re-Enter _ Serv _ We II bore seg _ -^GEOLAREA ?~~ UNIT# /I.ç~ ON'OFFSHORE~"\ ~ N Á ~.if ../5"' -.. ...<;"""~;J/~ -c.n-l ~ ~. '----- n-/"' Y ~ LÆ.-,w Þ~A':~ oMr /S"..P/~-/.-'~ Y N 7 Y N Y N Y N Y N Y N Y N Y N .:JjN }{ /v, ¡q /Ý\N \y)N -¥-N,· f'Î/1t- ~ ~A1"'b..-s n r= .y N ,¡JIlt- i=.' ~ ~ /I1W C¡.3 PP1 ' ~ N rvz S,/ J~ c.¡.? PÇ;(. - N N YeW ¥ N NIl\-- ~N Y N Y N Y N Y N ( ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMM~~ Commentsllnstructions: RP&' TM JH JR SP~· ~ RR ð ~ '/f/-<J.) / MW DS a 3/lljOJ SFD_ WA Rev: 2/25/03 \welLpermiC checklist Perforation intervals for Northstar wells ) ) Subject: Perforation intervals for Northstar wells Date: Fri, 17 Jan 2003 11 :44:09 -0600 From: "Sherritt, Allen" <SherriJA@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Francis, Michael J" <Michae1.Francis@BP.com>, "Hernandez, Floyd" <HernanFl@BP.com> Winton, As per our conversation, the following Northstar wells do not have a reference to perforation intervals included in the drilling permits. NS18 NS22 NS06 NS20 NS16 NS21 NS19 1\ r.; They all will be perforated within the Ivishak interval: "Perforate -140' Ivishak formation between the Top Ivishak and OWC." "Perforation interval will be based on PE recommendation after completion of well." The actual perforation depths will be provided in the final well completion reports. If you need any further information, give me a shout. Thanks, Allen Sherritt BP Northstar Operations Drilling Engineer * (907) 564-5204 (Direct) * (907) 240-8070 (Mobile) * sherrija@bp.com * (907) 564-5200 (Fax) * MB 3-6 / 383B J, Date: 12-02-2002 Transmittal #92568 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Bottom SW Name Date Contractor Log Run Top Depth Depth Log Type NS21 11-18-2002 ANA 1 0 4621 MWD SURVEY REPORT; (HARDCOPY ~rB~al~ MWD SURVEY REPORT; (DISKETTE) SURVEY REPORT GEODETIC; N819 11-13-2002 ANA 1 0 13500 MWD SURVEY REPORT; (HARDCOPY ac8.al)1 MWD SURVEY REPORT; (DISKETTE) SURVEY REPORT GEODETIC; ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center ~~~~ ~~~~ ~~·Ü ~ c% Attn: Lisa Weepie (AOGCC) Attn: Doug Choromanski (MMS) Attn: Tim Ryherd (DNR) RECEIVED DEC 0 ,) 2002 (... Alaska o;~ & Gas Cons. Ccmmi88ion Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ) Date: 0] -02- 2003 Transmittal Number:92451 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS-15 10-11-2002 SCH 2 14420 15100 PERFORATING RECORD; .. ëXB-{)5'-/ NS-15 10-04-2002 SCH 1 15006 15093 PERFORATING RECORD; aaa-os'-l j, NS-20 10-22-2002 SCH ~_ ,);;}'7 ... NS~I b I !l-ð~-2t"ð9. 5 ( !--I /J.-15 -IB 1~--t)I-;).DOQ. S Ci--/ ... 1Afr;-1 7 Ij _O!··')tvf). 5 C /1 ~ tJJo¥~ ~ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center 1 100 15770 ULTRASONIC IMAGER; ~/êrl PI( I,^A.A I!. Y l> 1:"/'7")-/ L tfÆ / d. 0 ~-I g" f' fJ/2 mAl! Y DEl'r¡.¡ L.ð(;,; a Od-.-ILf I jJrlJI1"1I4t2V ¡)l?fìN L l'(;J' aoa -dOÎ J ) J 40 o It!' f & s- I ~ß85- / "5 t( ~ t:' iff) Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED JAN 0 3 2003 Alaska Q, & Gé$ Wfj~. ~mmieeirm Anchorage . -.,. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-66] 2 Northstar - SSSV Setting Depths ) ) Subject: Northstar - SSSV Setting Depths Date: Fri, 22 Nov 2002 13:35:25 -0600 From: "Francis, Michael J" <Michael.Francis@BP .com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Holt, Barbara M" <HoltBM@BP.com>, "Sherritt, Allen" <SherriJA@BP.com>, "Hernandez, Floyd" <HernanF1@BP.com>, "Schultz, Mikel" <Mikel.Schultz@BP.com>, "Garing, John D" <GaringJD@BP.com> Winton, Pursuant to our conversation, this note is to inform you that BP will be changing the SSSV setting depths in the following already permitted producer wells: NS24 NS18 NS16 NS20 NS19 2'01.. - 2.,01 As allowed by Conservation Order No. 458A, these setting depths will be changed to 1000' TVD. Please call if you have any questions or comments, Mike Michael J. Francis, P.E. BP Exploration Alaska, Inc. Senior Petroleum Engineer Phone: (907) 564 -424 0 Cell: (907) 529-8678 Fax: ( 907) 564 - 5200 e-mail: Michael.Francis@bp.com P.O. Box 196612 Anchorage, AK 99519-6612 Surface Hole Drilling NS 19 ') ) Subject: Surface Hole Drilling NS19 Zo l - LiJ 7 Date: Mon, 28 Oct 2002 13 :49:07 -0600 From: "Holt, Barbara M" <HoltBM@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Sherritt, Allen" <SherriJA@BP.com>, "NSU, ADW Drlg Rig 33E" <NSUADWDrlgRig33E@BP.com>, "Hernandez, Floyd" <HernanFl@BP.com>, "Schultz, Mikel" <Mikel.Schultz@BP.com> Winton, During this time of year, Northstar Island is limited to 94 occupants to ensure sufficient emergency evacuation procedures can be executed. This limitation has become especially taxing in drilling the surface hole interval where additional personnel are required for anti-collision gyro surveying purposes. To allow these personnel to be on location, three people will have to be displaced. It is requested that the mud loggers are among these personnel. This would eliminate mud logging in the NS19 surface hole only; they would return to work for the remainder of the well and subsequent wells. We are scheduled to spud around noon tomorrow. Sperry-sun will need approximately 12 hours to set up in the event they are required for the surface hole. Do you see any problem forgoing mud logging on NS19 surface hole? We have drilled 18 surface holes with no indication of shallow gas hazards. Additionally, the rig is equipped with a tested and calibrated gas monitoring system (5 sensors for combustible gas detection). Thanks Winton! Barbara M. Holt Northstar Drilling Engineer Office: (907) 564-5791 Cell: (907) 240-8044 ______ _____ ____ _____...________________._ - _______. _....._____ ..L____ ___________.......____.____...____ ____....__ __..__________.___. I Name: Blank Bkgrd.gif , , 01 Blank Bkgrd.gif Type: GIF Image (image/gif) ~~"_.""'w.~<-",-""_--'.~_~_M ~~,~o~~,l!.g: "b~.~~~~~e.~'~~..^'~,,~'''''''~,_.<wd /' "I -:1- .-L- /J J,t /.-' /)",- I i'----- p"" '"L.J,,--.' _J c- ,~' /.. i~-~ 1 .:::::;r:¿;·""é; /:>.~_;~ ,,:' /,t) , ~J I .,'--,0> -' '-,/ f ---I _..t-- . .~,___ /"t:J c) (;: ,.5- ,., -.....----' //~ ........,-/.....:.:::..y e í\ I ---t / ¿ <- -' <'Í" - ,-' i--¡-';r ,:z/,j' c_ J'E.-,.... ':::A/ (-- ~~_ __l""-'" '- ~ _/ --- .:::- - .....:":'1 '-."," l / c~/ ~ c::.d ~ '-~ .~.~ J.J è. ,,<' 0..::... .o",/~i-~" ¿/J@rc:. </0,-· r/CrJ ~ ifc (~f?nïJ.c¿J i 0 12~ {o ~ ::~y~~ ,; ,- ~"-:,, --"-; -- j// ~G+- '\ ) ~ tïr/Æ9 ,.........¡ . II ~ :1 ,~ J J ò ~ rç ® ~ Œ\ \~rv( fE\ U¿í U L~ 6 fF0J æ) U\~\ Lr\J TONY KNOWLES, GOVERNOR ALASKA. OIL AND GAS CONSERVAnONCO~SSION Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Northstar 19 BP Exploration (Alaska), Inc. Permit No: 202-207 Surface Location: 1229 NSL, 646' WEL, Sec. 11, TI3N, RI3E, UM Bottomhole Location: 510' SNL, 3461' EWL, Sec. 24, TI3N, RI3E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill 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). Ai~ ~. --- Wf~~ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DA TED thisQ/day of October, 2002 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. µGA- I t,!2-! 02.- , STATE OF ALASKA- ~ t6(?(~ ALASKA-_-Ì AND GAS CONSERVATION COMM._ ,ÅION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work II Drill 0 Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil ORe-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 56' Northstar Unit ./ 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312809 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1229' NSL, 646' WEL, SEC. 11, T13N, R13E, UM Northstar Unit At top of productive interval 8. Well Number 5169' SNL, 2586' EWL, SEC. 13, T13N, R13E, UM NS19/ Number 2S100302630-277 At total depth 9. Approximate spud date 510' SNL, 3461' EWL, SEC. 24, T13N, R13E, UM 10/10/02 /' Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well / 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 312808, Approx. 2000' No Close Approach 5301.38 ,/ 14684' MD / 11075' TVD 16. To be completed for deviated wells 0 17. Anticipated pres,ure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 41.33 Maximum surface 3832 psig, At total depth (TVD) 11020' / 5154 psig 18. Casin~ Program Specifications Setting Depth Size Top Bottom Quantitv of Cement Hole Casina Weiaht Grade Couplina Lenath MD TVD MD TVD (include staae data) 20" 20" 169# X-56 Weld 201' Surface Surface 201' 201' Driven 16" 13-3/8" 68# L-80 BTC 3399' Surface Surface 3399' 3205' 527 sx PF 'L', 466 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 BTC-M 11669' Surface Surface 11669' 9442' 697 sx Econolite, 598 sx Class 'G' 8-1/2" 7" 26# L-80 Hydril521 2062' 11519' 9328' 13581' 10907' 317sxClass'G' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 1253' 13431' 10792' 14684' 11075' Uncemented Slotted Liner / 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner RI€fiIVED OCT 0 1 2002 11_01& Gas Oon5. Commission Anchorage Perforation depth: measured true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Barbara Holt, 564-5791 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 Roy<! Hernandez . ~ ~. .. . . . ... !itle. ... S~~i~r Drilling ~ngineer . .... ...... '. . '.. '. ,,·.,:çom~~~i~;\~:Q"~¥:I:.:.:./":,i'::J:I¡: :'"'.' Date 9/J fo L ..'~ .' 'I".."" Permit Number API Number APP/r9~~J..QrJry_ See cover letter 202- - .2..0"/ 50- 02- 9' ~ 2. :3 )..2 2-- U ,:-/J V' for other reauirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Requir d ~ Yes 0 No Hydrogen Sulfide Measures 0 Yes 181 No Directional Survey Required EI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K O?K 0 10K 0 15K, 0 3.~K psi tor qTU Gthß~if~t~¡ij~rký/foo pS~~. Pé1-t l.vAAc l..ç',O~S(t..}{ltd¿V2-ltf''Ý .,eÕ·UffW\.i1Á.(- W~~ð. I 1 .~\Ilor Seamount by order of ~~ ' Approved By C~mmissioner the commission Date / l J ( j~Y)- Form 10-401 Rev. 12-01-85 ' I ,Ii 1 Sub t I Triplicate l \ [ l l ') ) bp .,. ...\If.'II, ......~ ~~. .~i i~. ·tl,.~\\~ ". BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: October 10, 2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS19 Application for Drilling Permit Mr. Aubert, NS19 is currently scheduled for Nabors 33E op October 10th, 2002. / A Diverter waiver is also requested on NS19. To date, no development well drilled through the Northstar upper strata-graphic intervals has experienced any difficulty with shallow gas. ~I surface holes have been drilled and cemented to a common depth of approximately 3,170' TVDss depth, (-150' TVD below the top of the SV6), with the exception of one well, which extends into the SV5 -3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. .,,/ NS19 will perform an "Operation Shutdown" during the 2002 Seasonal Drilling Restriction period. A Sundry .,-/ for the Operation Shutdown will not be submitted, as the operations are covered in the ADP procedure. Please find attached the NS19 Well Plan Summary, directional plan, and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5791. .. j Sí:cerelY, . . ^ 1t- ?/i¿~Þ-c 7?1 jÞ1ß ! --- -.' Barbara M. Holt BP Northstar Operations Drilling Engineer 564-5791 ') ') NS19 SUMMARY DRilliNG OPERATIONS Pre-RiQ Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) Ria Operations: / 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if required. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. A D7 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-150' TVD below the /' top of the SV6 marker at approximately 3194' MD. Surface casing point has been picked at 3399' MD. POOH. / 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 1 stag/' A TAM port collar will be run at +/- 1000' MD. In the event the cement does not circulate to surface, this port collar will be utilized to ensure a successful cement job is performed. 5. ND diverter / riser system and NU casing / multi-bowl wellhead. NU BOPE and test to ~0/4800 psi. / 6. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to a 12.5 ppg EMW. (FIT/LOT procedure on file with AOGCC). /' 8. Drill 12-1/4" intermediate hole to 9-5/8" casing point (approximately 11,669' MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.0 ppg at the top of Kuparuk. POOH. (N<;,Jogs will be run, unless the Kuparuk is oil bearing.) ../ 9. Run 9-5/8", 47# intermediate casing. Cement the casing to the top of the SV2 sand in a single stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus with 1 annular volume of mud upon installing and testing the packoff. Down-squeeze diesel to 2000' TVD for freeze ./' protection after WOC. /' 10. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4100 psi with 10.0 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. 11. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a FIT to a 13.5 ppg EMW, (FIT/LOT procedur~on file with AOGCC). 12. Weight up to minimum 12.5 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sag at approximately 13,542' MD.)1termediate casing point has been picked at 13,581' MD. POOH. 13. Run and cement a 7" 26# drilling liner. Displace cement with 10.0 ppg viscosified brine followed by 12.5 ppg (minimum weight) mud. This allows for a cleaner wellbore for future wireline entry. Set the liner hanger and liner top packer. Circulate excess cement from well bore. 14. Circulate to clean 8.65 ppg seawater-using spacers as per Baroid recommendation. 15. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). ./ 16. POOH and lay down liner running tools. Test 9 5/8" x 7" liner to 4800'psi for 30 mins, (MMS -70% of burst), will need to wait 8 hrs for cement to build 500 psi compressive strength. RIH to 100' below the base of permafrost and circulate 6.8 ppg diesel to freeze protect the well to surface. POOH. 17. Prepare for "Operations Shutdown. (June 1st Seasonal Drilling Restriction)" / 18. Install 4 Y2" tubing hanger and test to 4200 psi. 19. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 20. Install (dry rod in) BPV and test. Ensure all valves are closed. RD and move off well. 21. Prepare to re-enter well post "Seasonal Drilling Restriction." NS19 Permit to Drill ') ) 22. MIRU Nabors 33E. / 23. Pull BPV. Install TWC. NO dry hole tree. NU BOPE and test to 250/4800 psi. 24. RIH w/ 6-1/8" directional assembly to 2000' MD. Displace diesel with seawater, (see diesel handling procedure). Test 9 5/8" x 7" liner to 4800 psi for 30 mins. RIH to 7" liner top. Displace seawater to 9.3 ppg mud. Clean out 7' liner to the landing collar. ,,/ 25. Drill out remaining cement. Drill 20' of new formation below 7" shoe with 9.1 ppg mud. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). 26. Drill 6-1/8" production interval to the proposed TO at 14,684' MD. Increase mud weight to 9.3 ppg prior to POOH. 27. Make a clean out run, if required, and condition the hole for a liner. POOH. / 28. Run the 4-1/2" 12.6# 13Cr slotted liner. Set the liner hanger and liner top packer. 29. Pressure-test the liner top packer as per Baker recommendation prior to pulling seals. 30. Circulate the well above the 4 ¥2" liner top to weighted completion fluid. 31. POOH. / 32. Run the 3 Y2", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. Dual SSSV control lines will be run from the SVLN at +/- 2000' TVD to surface. 33. Run space out pups and terminate the 2 - 0.25" control lines and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function test the fiber optic line. 34. Drop ball and rod to set packer. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. / 35. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart to Drilling Engineer. 36. Bleed annulus and tubing pressure to 0 psi. 37. Set and test a BPV. This allows for two barriers (BPV and kill weight fluid). 38. NO BOP and NU tree. 39. Pull PBV. Set and test a TWC. Test the tree to 4800 psi. 40. Pull the TWC. 41. Pressure up the annulus to 3000 psi or until the RP valve shears. The RP valve will be set to shear at / 2500 psi differential pressure. 42. Bleed off the annulus and tubing pressure to 0 psi. 43. Pump corrosion inhibitor and heated diesel down the 3 Y2" x 9 5/a" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (4457' MD). RU the U-tubing manifold. Allow fluids to U-tube from the annulus into the tubing through the lower GLM, MD. 44. Install and test (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Estimated Spud Date: qv?-7?f{t~' ~ ~arbara M. Holt Operations Drilling Engineer 564-5791 October 10th, 2002 2 NS19 Permit to Drill ) ) NS19 WELL PLAN SUMMARY I Type of Well (producer or injector): Northstar Slot: Surface Location: Target (top of SAG): 300' Radius Bottom Hole Location: I Producer NS19 1228' FSL,646' FEL, Sec. 11,T13N, R13E, UM X = 659828 Y = 6031001 110' FSL,2693' FEL, Sec. 13,T13N, R13E,UM X = 663202 Y = 6024675 10,877' TVDrkb 4769' FSL, 1819'FEL,Sec.24,T13N,R13E,UM X = 664090 Y = 6024074 11,075' TVDrkb / I AFE Number: 1831331 1 Rig: 1 Nabors 33E I 1 Estimated Start Date: 110/10/02 / 1 Operating days to complete: I 35.5 / I 1 MD: 114,684 1 1 TVDrkb: 111,075 I 1 RKB/Surface Elevation: (a.m.s.l.) 156.0' / 15.9' I I Well Design (conventional, slimhole, etc.): 1 Modified Big Bore I 1 Objective: I Ivishak Producer with fiber optic surveillance control line 1 Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: NS19 Producer 5175 psi @ 11,100' TVDss 8.96 ppg 254 of @ 11,100' TVDss Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 2011 MDrkb of 20",169#, X-56 (pre-driven) / 3 NS19 Permit to Drill ) ) MUD PROGRAM: Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3399' MD /3205' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel APIFL pH (ppg) (seconds) 10 sec Initial 8.8- 9.0 1 00 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5 100 - 200 30 - 45 >6 15 - 25 6-10 8.5 - 9.5 SV6 @ Interval TD *9.5 ./ 75 - 100 20 - 35 >6 1 0 - 25 6-10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Seawater Polymer From Surface Casing Shoe to 11,669' MD / 9442' TVD. Interval Density (ppg) PV Initial 8.7 - 9.3 10 -16 Top HRZ 10.3 / 10 - 16 Top Kuparuk to Miluveach 10.3 10 - 18 12-1/4" Hole Section YP 20 - 30 20 - 25 20 - 28 Tauo API/ HTTP FL 4-7 6-10 4 - 7 4-6 / <12 4 - 7 4-6 / <12 pH 8.5 - 9.5 8.5- 9.5 8.5- 9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 13,581' MD /10,907' TVD (top of Sag) Interval Density (ppg) PV YP Tauo API FL pH Miluveach & Kingak to top of Sag 12.5 - 13.0 / 25 - 30 20 - 30 4 - 8 4-6 / <10 8.5 - 9.5 Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 14,684' MD /11,075' TVD Interval Density (ppg) PV YP Initial/Final 9.1 - 9.3 8 - 12 20 - 25 6-1/8" Hole Section Tauo API FL 4-7 3-5 pH 8.5 - 9.5 DIRECTIONAL:(P6) KOP: Maximum Hole Angle: Close Approach Wells: Survey Program: ±300· MO Cantenary curve 1.50°/100' build ±41.33° All wells pass major risk rule. Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1000'. Standard MWO surveys from +/-1000' to TO. SURFACE AND ANTI-COLLISION ISSUES: j' All wells pass the major risk rule except NS18 (suspended at Top Sag), NS20 plan (will be drilled to Top Sag at NS19 spud), and Seal A-03 (plugged and abandoned in 1985 by Shell). Gyros will be run from surface to -1000' MD or until reliable MWD surveys can be taken. 4 NS19 Permit to Drill ) LOGGING PROGRAM: ') 16" Section: Drilling: GR/Directional - Gyro as needed to ....1000' MD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Resistivity (real-time), PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: PEX and RFT's - Contingent on oil being present in the Kuparuk. Cased Hole: None 8-1/2" Section: Drilling: GR/Directional, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: GR/Directional Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None Inte~lritv Testina: Test Point Depth 12 14" Surface 9 5/8" Intermediate 7" Drilling Liner 4 Y2" Production Liner 20' min from 12 1/4" shoe 20' min from 9 5/8" shoe 20' min from 7" shoe CASINGITUBING PROGRAM: / Hole Size Casing/ WtlFt Grade Tbg O.D. 20" 20" 169# X-56 16" 13 3/8" 68# L-80 12 14" 9 5/8" 47# L-80 8 Y2" 7" 26# L-80 6-1/8" 4-1/2" 12.6# 13Cr Slotted Tubing 3-1/2" 9.3# 13Cr Shoe Test Type FIT FIT FIT EMW Estimated Casing/Liner Test 3500 psi w/ 9.3 ppg 4100 psi w/ 10.0 ppg 4800 psi w/ 12.5/8.65 3750 psi w/ 8.65 ppg 12.5 ppg EMW Target 13.5 ppg EMW Target 11.5 ppg EMW Target / Conn. Casing Casing Top Hole Btm Length M DITVDrkb MDITVDrkb WELD 201' Surface 201 '/201 ' BTC 3399' Surface 3399'/3205' BTC-Mod 11669' Surface 11669'/9442' Hydril 521 2062' 11519'/9328' 13581 '/1 0907' Vam Ace 1253' 13431 '/1 0792' 14684'/11075' Vam Ace 13431 ' Surface 13431 '/1 0792' 5 ) " ) NS19 Permit to Drill FORMATION MARKERS: Top (TVDss) MDrkb Pore Press. Comments Formation estimated (Psi) I (ppg EII/IW) I Top Permafrost 1,149 1210 542 8.65 Base Permafrost 1,519 1586 708 8.65 SV6 - top confining zone 2,988 3194 1379 8.65 Surface casing point 3,150 3399 SV5 - base confining zone 3,268 3556 1499 8.65 SV4 3,578 3968 1638 8.65 SV2 - top upper injection zone 3,988 4514 1823 8.65 SV1 - top major shale barrier 4,381 5038 1995 8.65 TMBK - top lower injection zone - Top Ugnu 4,783 5573 2176 8.65 WS1 - top Schrader Bluff - Base Ugnu 5,795 6921 2631 8.65 CM3 - Base lower injection zone (top Colville) 6,896 8387 3120 8.65 THRZ - Top HRZ 8,838 10960 3975 8.65 BHRZ - Base HRZ 8,908 11050 4006 8.65 Top Kuparuk 8,917 11061 4265 9.20 Kuparuk C 9,123 11326 4428 9.33 Top Miluveach 9,347 11617 Intermediate casing point 9,387 11669 Intermediate logging point 9,387 11669 Top Kingak 9,925 12371 Fault 15 - throw = 2001 10,200 12731 r' !},. ':. Top Sag River 10,822 13542 5072 8.95 \ ., Geol target #1 10,822 13542 5015 8.91 Geologic Target #1 300 I radius Intermediate casing point 10,852 13581 Top Shublik - 90 10,888 13628 5094 8.95 Top Ivishak 10,978 13775 5136 8.95 Depth - Horizontal (BHS) 11,020 13775 N/A N/A Depth - Horizontal (EHS) 11,020 14684 Total Depth 11,020 14684 5154 8.95 OWC estimated from Seal A-1 , /' Oil - Water contact 11,100 5176 8.95 A-2, A-3, NS #1, NS27, NS31 Total Depth 11,020 14684 5180 8.99 Top Kavìk 0 8.95 Top Lisburne 6 NS19 Permit to Drill REQUIRED MATERIALS: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: 13Cr Liner: 13Cr Completion: ') 3399' 1 - 13 3/8" 1 - 13 3/8" 1 - 13 3/8" 17 -133/8" x 153/4" 1 - 20" x 13 3/8" 1 - 13 5/8" 11669' 1 -95/8" 1 -95/8" 1 - set 1 - 13 5/8" x 9 5/8" 175 - 9 5/8" x 12" 2062' 1 - 8 Y2" 1 -7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1-7" 1-7" 1253' 82' 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 - 4-1/2" 13431 ' 1 1 1 1 1 1 1 1 1 1 2 1 ) 133/8",68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) TAM Port Collar SV Rigid Centralizers ABB-VGI Fluted hanger - BTC down, 11 3,4" external ACME landing thread ABB-VGI Casing HeadfTbg head 95/8",47# L-80 BTC-MOD HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers 7",26# L-80 Hydril 521 BBL reamer shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger- Rotating hanger. Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-1/2",12.6# 13Cr-80 slotted Vam Ace 4-1/2",12.6# 13Cr-80 Vam Ace Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 3-1/2",9.3# 13Cr-80 Vam Ace 3 Y2" x 4 Y2" crossover landing joint 4 Y2" ABB-VGI tubing hanger 4 Y2" ABB- VG I adapter flange 4 Y2" ABB-VGI 5-1/8" 5K Swab Valve wi tree cap CIDRA mandrel and 0.25" fiber optic cable (wi 3 Y2" cable clamps). 3 Y2" SVLN and 2 - 0.25" control lines 3 Y2" x 1 Y2" GLM with dummy valve installed 3 Y2" x 1 Y2" GLM with RP Shear valve installed 7" x 3 Y2" Baker 13 Cr packer S-3. 3 Y2" WLEG (w/o holes) 3 Y2" 13 Cr X nipples 3 Y2" 13 Cr XN nipple 7 NS19 Permit to Drill ') ) PERMAFROST: The 13-3/8" surface casing will be run approximately 1600' TVD below the permafrost to -3399' MD I 3205' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and a Permafrost 'L' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. / CEMENT CALCULATIONS: The following cement calculations are based upon a single stage job. Casing 113-3/8" Surface 1 Basis: Stage 1: Lead: Based on 200' cased hole capacity from surface to 200' MD, 2449' of Open Hole + 125% excess from the permafrost to surface + 50% excess to 750'MD above the shoe. Lead TOC: Surface Tail: Based on 750' of 16" open hole x 133/8" casing with 50% excess + 80' shoe joint. Tail TOC: -2649' MD I Total Cement / Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Aæp, acer weighted to 1.0 ppg over mud weight 389 bbl . '52 sk I 2183 ft of 10.7 ppg Permafrost 'L' Cement. 4.15 cfl ,"; ST 50° I BHCT 50°, TT = 6.0 hrs 96 bbll~6~/~k I 536 fe of 15.8 ppg Premium 'G' wI 2% CaCI2. 1.16 t:tLsK-;~BHST 50° I BHCT 50°, TT = 4.0 hrs Tail Casing 19-5/8" Intermediate Basis: Stage 1: Lead: Based on 5547' of 12 1/4" open hole x 9 5/8" csg with 30% excess Lead TOC: At -4514' MD (4043' TV D) Tail: Based on 1607' of 12 1,4" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. Tail TOC: At -10062' MD (8209' TVD) IStage 1: Total Cement / Spacer Preflush 20 bbls sea water Spacer 50 bbl A;P. .h.9,,'. pacer wei~hted to 1.0 ppg over mud MW Lead 402 bbl I 00 sk I 2258 ft of 11.2 ppg Econolite. 3.24 cf/s~t T 210° I BHCT 130°, TT = 4.0 hrs Tail 122 bbl9, k I 688 ft;:! of 15.9 ppg Premium 'G'. 1.15 cf/s ;,. HST 210° I BHCT 130°, TT = 4.0 hrs Casing tr" Drilling Liner Basis: Stage 1: Slurry: Based on 1913' of 8 Y2" open hole x 7" csg with 50% excess + 150' 9 5/8" csg x 7" csg liner lap + 200' 9-5/8" csg x 5" drillpipe above TaL + 80' shoe joint. Slurry TOC: At -11669' MD (9442' TVD) Stage 1: Total Cement / Spacer Spacer 50 bbl A~spacer ~eighted to 1.0 ppg over mud MW Slurry 86 bbl I 1 sk I 476 ft;:! of 15.9 ppg Premium 'G'. 1.50 cf/s ,BHST 250° I BHCT 150°, TT = 4.0 hrs Casing Basis: \4-1/2" Prod Liner INo Cement - Slotted Liner 8 NS19 Permit to Drill ) ) WELL CONTROL: / ~ A Diverter waiver is also requested on NS19. To date, no development well drilled through the Northstar upper strata-graphic intervals has experienced any difficulty with shallow gas. All surface holes have been drilled and cemented to a common depth of approximately 3,170' TVDss depth, (-150' TVD below the top of the SV6), with the exception of one well, which extends into the SV5 -3280' TVDss, Well mud logs and seismic data do not indicate the presence of a shallow gas hazard ~ Equipment to be Installed and capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) ~ 5000 psi working pressure pipe rams (2)./ ~ Blind/shear rams ~ Annular preventer . / ~ Based upon the calculations below, BOP equipment will be tested to 4800 psi. Surface Section: · Maximum anticipated BHP: 1379 psi @ 2988' TVDss - SV6 · Maximum surface pressure: 1020 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Intermediate Section: · Maximum anticipated BHP: 4428 psi @ 9123' TVDss - Kuparuk 'c' · Maximum surface pressure: 3334 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Drilling Liner Section: · Maximum anticipated BHP: 5072 psi @ 10822' TVDss - Sag River · Maximum surface pressure: 3728 psi @ surface (Based on BHP and a full column of gas from TD @ 0.12 psi/ft) Production Section: · Max~mum anticipated BHP: .§.l~-~~.-4.. ... s~ @11 020' TV~ss - Total Depth · Maximum surface pressure: 138~sl @ surface ../" (Based on BHP and a full column ~-from TD @ 0.12 psi/ft) . · Planned BOP test pressure: 4800 psi (annular to 3500 psi) / · Planned completion fluid: 8.5 ppg Seawater /6.8 ppg Diesel DRILLING HAZARDS/CONTINGENCIES: Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A-03 exploration/appraisal wells. No H2S was detected while drilling the NS10 waste disposal well, or any subsequent Northstar development wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS10 Class I Waste Disposal Well. 9 NS19 Permit to Drill ) ) SURFACE HOLE SECTION: · Mudloggers will be rigged up throughout the entire section. · No significant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. · Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. · Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud. · Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. · Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS19 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. INTERMEDIATE SECTION: · Mudloggers will be rigged up throughout the entire section. · Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the 2000-2002 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. · The shallow intervals beneath Northstar are, by interpretation, not faulted. To be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the rig. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. · Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. · Oil is not expected in the Kuparuk, however, if oil is found be prepared to run wireline logs to evaluate. · The kick tolerance for the 12 1/4" open hole section would be 92.9 bbls assuming an influx from the Kuparuk interval at -9168 TVD. This is the worst-case scenario based on a 9.84 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (FIT) of 12.5 ppg at the 13-3/8" shoe, and 10.3 ppg mud in the hole. 10 NS19 Permit to Drill ') ) DRILLING LINER SECTION: · Mudloggers will be rigged up throughout the entire section. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Gas in the Sag is possible. Circulate as required. According to Geology, the top of the Sag is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. · Penetration of a single seismic-scale fault (Fault 15) is expected in the lowest most Minluveach or upper half of the Kingak shales. Penetration is expected at 10,200'TVDss +/- 250'TVDss within the upper portion of the Kingak formation. Displacement should be approximately 200 feet. This fault was penetrated in Seal A3 at approximately the same stratigraphic level. Tight hole conditions were experienced throughout the Miluveach and Kingak intervals. These drilling problems are interpreted to be related to the mud weight used, not the fault. · Kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval. This is the worst-case scenario based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 13.5 ppg at the 9-5/8" shoe, and 12.8 ppg mud in the hole. PRODUCTION SECTION: · Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. · The drilling liner shoe will be drilled out with the 9.3 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. · Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. · The well is planned as a horizontal well 25' TVD above the OWC. The Kavik will not be penetrated. The project Geologist will be in charge of picking TD above the OWC and sufficient rathole will be drilled. · The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open hole) assuming an influx from the proposed TD. This scenario is based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 11.5 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. · The production portion of the hole is targeting a narrow horst block that is 1000 feet wide. The azimuth of the wellbore follows the length of this narrow fault block. The 500-foot horizontal section runs parallel to the faults that bound this horst. There is no direct seismic evidence (reflection discontinuity) for faults being present in the Shublik/Ivishak interval within the targeted, narrow fault block. However, direct seismic evidence for faulting (the bounding faults) is within 150' of the target ellipsoid cylinder. Consequently, there is concern that we may encounter lost circulation associated with sub seismic fracture zones that parallel the nearby seismic-scale bounding faults. Probability of lost circulation in the production hole is 25%. Potential losses will be treated with the "Pay-zone" loss circulation decision tree. 11 NS19 Permit to Drill ) '> NS19 RiQ-site Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE ...¡ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS19 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. ...¡ Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods; tighten fluid loss properties of mud. ...¡ Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in any previously drilled Northstar wells. Mudloggers will be used continuously on NS19 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. ...¡ Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 Y2" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. To be prepared for any potential lost circulation, the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. ...¡ Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick- up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. ...¡ Bit balling has been experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. ...¡ The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. ...¡ Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. ...¡ Northstar is not a designated H2S pad. ~ CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 12 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ) NS19 Operation ./ Shutdown ') ORIGINAL KB. ELEV = 56' KB-BF. ELEV = 40.1' CB. ELEV = 15.9' 13 3/8" TAM Port Collar at +1-1 OOO'MD . 6.8PPG DIESEL FREEZE PROTECTION AT +1- 1600' TVD (1600'MD) 13 3/8", 68#/ft, L-80, BTC @ 3399' MD ~ .. ~ 8.64 ppg Seawater from 1600' MD I 1600' TVD to 11500' MD 19313' TVD 9-5/8" 47# L-80 BTM-C @ 11669' MD ... H k ~ - 7" LINER TOP @ 11519' MD f,·,,····'·'ï' ('~ 0.2/ppg viscosified brine '~rÓm 13581' MD 110907' TVD to 11500' MD 19313' TVD ~ 7", 26#/ft L-80, Hydril 521 @ 13581' MD j, .. DATE 9/24/02 REV. BY COMMENTS BMH ~S19 Operation Shutdown Northstar WFI I : NS19 API NO: 50-079- BP Exploration (Alaska) TREE: ABB-VGI S 1/8" Sksi WELLHEAD: ABB-VGI 13-S/8" Multibowl Sksi ) NS19 - Proposed 13 3/8" TAM Port Collar at +1-1000'MD 13 3/8", 68#/ft, L-80, BTC @ 3399' MD 3 1/2", 9.3#/ft, 13-Cr, Vam-Ace TUBING 10: 2.992" CAPACITY: 0.00870 BBLlFT 9-5/8" 47# l-80 BTM-C @ 11669' MD 3.5" X NIPPLE, @ 13380' MD 3.5" X NIPPLE, @ 13400' MD 3.5" XN NIPPLE, @ 13410' MD 3.5" WLEG, @ 13420' MD 7", 26#/ft L-80, Hydril 521 @ 13581' MD TO @ 14684' MD ~ . M 6 B_ 81 ~ J DATE 9/24/02 REV. BY COMMENTS BMH ""NS19 proposed ~ o~, IGINAL KB. ELEV = 56' }-BF. ELEV = 40.1' CB. ELEV = 15.9' 3 1/2" SSSV @ 2000' TVD wI HXO SVLN nipple 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' TVD (4457'MD) .. 3 1/2" GLM @ 4500' TVD (5123' MD) 3 1/2" GLM @ 5534' TVD (6500'MD) ~ - 7" LINER TOP @ 11519' MD ~ I 3.5" Fiber Optic Transducer -;;- _ 7" PACKER, 13 Cr @ 13390' MD r F 4.5" LINER TOP @ 13431' MD / ... ~ 4.5", 12.6#, Slotted 13Cr Vam Ace Northstar WFI I : NS19 API NO: 50-079- BP Exploration (Alaska) õ NS19 Proposed Well Profile - Geodetic Report Schlumbørgør Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: September 25, 2002 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Northstar t dy Vertical Section Origin: Northstar PF / NS19 b -II-~ S U TVD Reference Datum: NS19 f 51- I .~ TVD Reference Elevation: NS19 ea Sea Bed I Ground Level Elevation: 50-029- Magnetic Declination: NS19 (P6) S26W I September 25,2002 Total Field Strength: 125.794° /8612.01 ft /6.157/ 0.77E Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.49124105, W 148.69330705 Magnetic Declination Model: N 6031001.380 ftUS, E 659828.230 ftUS North Reference: +1.23170016° Total Corr Mag North -> True North: 0.99992902 Local Coordinates Referenced To: Minimum Curvature / Lubinski 149.630° N 0.000 ft, E 0.000 ft KB 55.3 ft relative to MSL 15.670 ft relative to MSL 26.152° 57547.477 nT 80.948° November 14,2002 BGGM 2002 True North +26.152° Well Head ..-" I KBE KOP Bid 1/100 Crv 1.5/100 Station ID End Crv Top Permafrost Crv 1.75/100 Base Permafrost End Crv Crv 21100 NS19 (P6) report.xls Grid Coordinates Geographic Coordinates MD I Incl I Azlm I TVD I VSec N/-S I EI-W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 90.00 0.00 0.00 0.00 0.00 0.00 6031001.38 659828.23 N 70.49124105 W 148.69330705 300.00 0.00 90.00 300.00 0.00 0.00 0.00 0.00 6031001.38 659828.23 N 70.49124105 W 148.69330705 400.00 1.00 90.00 399.99 0.44 0.00 0.87 1.00 6031001.40 659829.10 N 70.49124105 W 148.69329994 500.00 2.50 90.00 499.95 1.99 0.00 3.93 1.50 6031001.46 659832.16 N 70.49124105 W 148.69327492 600.00 4.00 90.00 599.78 4.85 0.00 9.60 1.50 6031001.59 659837.83 N 70.49124105 W 148.69322858 700.00 5.50 90.00 699.44 9.04 0.00 17.88 1.50 6031001.76 659846.10 N 70.49124105 W 148.69316089 800.00 7.00 90.00 798.84 14.54 0.00 28.76 1.50 6031002.00 659856.98 N 70.49124105 W 148.69307196 900.00 8.50 90.00 897.92 21.36 0.00 42.25 1.50 6031002.29 659870.47 N 70.49124105 W 148.69296169 1209.78 8.50 90.00 1204.30 44.51 0.00 88.04 0.00 6031003.27 659916.24 N 70.49124105 W 148.69258739 1305.84 8.50 90.00 1299.30 51.69 0.00 102.23 0.00 6031003.58 659930.43 N 70.49124105 W 148.69247140 ---- 1400.00 9.78 96.52 1392.27 60.01 -0.91 117.14 1.75 6031002.99 659945.35 N 70.49123856 W 148.69234952 1500.00 11.25 101.77 1490.59 71.66 -3.86 135.14 1.75 6031000.43 659963.41 N 70.49123050 W 148.69220238 1585.55 12.56 ,~05.27 1574.30 83.91 -8.02 152.28 1.75 6030996.64 659980.64 N 70.49121914 W 148.69206228 1600.00 12.79 105.79 1588.39 86.18 -8.86 155.34 1.75 6030995.86 659983.71 N 70.49121684 W 148.69203727 1700.00 14.37 108.95 1685.60 103.58 -15.91 177.73 1.75 6030989.29 660006.25 N 70.49119758 W 148.69185425 1738.90 15.00 110.00 1723.23 111.12 -19.20 187.03 1.75 6030986.21 660015.62 N 70.49118859 W 148.69177823 1758.90 15.00 110.00 1742.55 115.11 -20.97 191.89 /0.00 6030984.54 660020.51 N 70.49118376 W 148.69173850 1800.00 15.27 112.97 1782.22 123.54 -24.90 201.87 2.00 6030980.83 660030.57 N 70.49117302 W 148.69165692 Page 1 of 3 9/25/2002-5:24 PM Grid Coordinates Geographic Coordinates Station ID MD I Incl Azim TVD I VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1900.00 16.10 119.72 1878.50 146.13 -36.91 226.04 2.00 6030969.34 660054.99 N 70.49114021 W 148.69145936 2000.00 17.11 125.76 1974.34 . 171.60 -52.38 250.02 2.00 6030954.39 660079.30 N 70.49109795 W 148.69126334 2100.00 18.28 131.11 2069.62 199.92 -71.29 273.77 2.00 6030936.00 660103.45 N 70.49104628 W 148.69106921 2200.00 19.58 135.79 2164.21 231.06 -93.61 297.27 2.00 6030914.19 660127.42 N 70.49098531 W 148.69087713 2300.00 20.98 139.90 2258.02 264.98 -119.32 320.49 2.00 6030888.98 660151.19 N 70.49091507 W 148.69068733 2400.00 22.48 143.49 2350.91 301.63 -148.38 343.40 2.00 6030860.43 660174.71 N 70.49083568 W 148.69050008 2500.00 24.04 146.65 2442.78 340.99 -180.77 365.97 2.00 6030828.53 660197.97 N 70.49074719 W 148.69031560 2600.00 25.66 149.44 2533.52 382.99 -216.43 388.18 2.00 6030793.36 660220.94 N 70.49064977 W 148.69013407 2700.00 27.33 151.92 2623.02 427.58 -255.34 409.99 2.00 6030754.93 660243.58 N 70.49054347 W 148.68995581 2800.00 29.04 154.13 2711.16 474.72 -297.43 431.39 2.00 6030713.31 660265.88 N 70.49042848 W 148.68978091 2900.00 30.78 156.11 2797.85 524.34 -342.66 452.35 2.00 6030668.55 660287.81 N 70.49030491 W 148.68960961 ,-' 3000.00 32.54 157.90 2882.96 576.38 -390.98 472.83 2.00 6030620.68 660309.32 N 70.49017291 W 148.68944223 3100.00 34.33 159.52 2966.41 630.78 -442.32 492.82 2.00 6030569.79 660330.41 N 70.49003265 W 148.68927887 SV6 3194.08 36.03 160.91 3043.30 684.06 -493.32 511.15 2.00 6030519.20 660349.83 N 70.48989332 W 148.68912907 3200.00 36.14 161.00 3048.09 687.48 -496.62 512.29 2.00 6030515.92 660351.04 N 70.48988431 W 148.68911976 3300.00 37.97 162.35 3127.89 746.40 -553.82 531.22 2.00 6030459.15 660371.19 N 70.48972804 W 148.68896506 13-3/8" Csg pt 3399.44 39.80 163.60 3205.30 807.13 -613.50 549.48 2.00 6030399.88 660390.73 N 70.48956500 W 148.68881585 3400.00 39.81 163.60 3205.73 807.47 -613.85 549.58 2.00 6030399.53 660390.84 N 70.48956404 W 148.68881503 End Crv 3482.27 41.33 164.56 3268.22 859.28 -665.30 564.25 2.00 6030348.41 660406.61 N 70.48942348 W 148.68869516 SV5 3555.62 41.33 164.56 3323.30 906.08 -711.99 577.14 0.00 6030302.01 660420.50 N 70.48929593 W 148.68858983 SV4 3968.44 41.33 164.56 3633.30 1169.50 -974.77 649.72 0.00 6030040.87 660498.70 N 70.48857804 W 148.68799679 SV2 4514.43 41.33 164.56 4043.30 1517.88 -1322.32 745.71 0.00 6029695.49 660602.14 N 70.48762855 W 148.68721253 SV1 5037.78 41.33 164.56 4436.30 1851.83 -1655.46 837.72 0.00 6029364.43 660701.28 N 70.48671843 W 148.68646086 TMBK 5573.11 41.33 164.56 4838.30 2193.42 -1996.22 931.84 0.00 6029025.80 660802.69 N 70.48578749 W 148.68569202 WS1 6920.78 41.33 164.56 5850.30 3053.34 -2854.08 1168.77 0.00 6028173.29 661057.99 N 70.48344384 W 148.68375692 CM3 8386.96 41.33 164.56 6951.30 3988.90 -3787.38 1426.53 0.00 6027245.81 661335.73 N 70.48089407 W 148.68165219 Crv 2/100 10336.66 41.33 164.56 8415.39 5232.98 -5028.46 1769.31 0.00 6026012.48 661705.08 N 70.47750340 W 148.67885405 -'. 10400.00 40.95 162.72 8463.09 5273.40 -5068.44 1781.04 2.00 6025972.76 661717.67 N 70.47739418 W 148.67875831 10500.00 40.42 159.77 8538.93 5337.24 -5130.16 1801.99 2.00 6025911.51 661739.94 N 70.47722555 W 148.67858730 10600.00 39.96 156.75 8615.33 5401.03 -5190.08 1825.88 2.00 6025852.12 661765.11 N 70.47706184 W 148.67839227 10700.00 39.58 153.68 8692.20 5464.68 -5248.15 1852.69 2.00 6025794.65 661793.16 N 70.47690319 W 148.67817339 10800.00 39.29 150.56 8769.44 5528.12 -5304.29 1882.38 2.00 6025739.16 661824.05 N 70.47674980 W 148.67793099 10900.00 39.08 147.42 8846.96 5591.28 -5358.42 1914.92 2.00 6025685.75 661857.74 N 70.47660190 W 148.67766530 Top HRZ 10959.66 38.99 145.53 8893.30 5628.79 -5389.74 1935.67 2.00 6025654.88 661879.16 N 70.47651632 W 148.67749587 11000.00 38.95 144.24 8924.67 5654.07 -5410.49 1950.26 2.00 6025634.45 661894.19 N 70.47645963 W 148.67737674 NS19 (P6) report. xis Page 2 of 3 9/25/2002-5:24 PM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVO I VSec I N/-S EI·W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Base HRZ 11049.66 38.92 142.66 8963.30 5685.10 -5435.56 1968.84 2.00 6025609.79 661913.30 N 70.47639113 W 148.67722503 Top Kuparuk 11061.23 38.92 142.30 8972.30 5692.31 -5441.33 1973.27 2.00 6025604.12 661917.86 N 70.47637536 W 148.67718886 11100.00 38.91 141.06 9002.4 7 5716.43 -5460.43 1988.37 2.00 6025585.35 661933.36 N 70.47632317 W 148.67706556 11200.00 38.96 137.88 9080.26 5778.27 -5508.18 2029.20 2.00 6025538.49 661975.21 N 70.47619269 W 148.67673215 11300.00 39.09 134.71 9157.96 5839.51 -5553.68 2072.69 2.00 6025493.94 662019.66 N 70.47606836 W 148.67637702 KupC 11326.21 39.14 133.88 9178.30 5855.46 -5565.23 2084.52 2.00 6025482.65 662031.74 N 70.47603680 W 148.67628042 11400.00 39.31 131.56 9235.47 5900.09 -5596.88 2118.80 2.00 6025451.74 662066.69 N 70.47595031 W 148.67600049 11500.00 39.61 128.45 9312.68 5959.94 -5637.72 2167.46 2.00 6025411.96 662116.21 N 70.47583870 W 148.67560313 11600.00 39.99 125.39 9389.52 6018.96 -5676.16 2218.63 2.00 6025374.63 662168.19 N 70.47573365 W 148.67518526 End Crv 11602.16 40.00 125.32 9391.17 6020.23 -5676.96 2219.76 2.00 6025373.86 662169.34 N 70.47573146 W 148.67517604 TMLV 11616.68 40.00 125.32 9402.30 6028.74 -5682.36 2227.38 0.00 6025368.62 662177.07 N 70.47571670 W 148.67511381 ..~ 9-5/8" Csg pt 11668.90 40.00 125.32 9442.30 6059.32 -5701.76 2254.76 0.00 6025349.82 662204.86 N 70.47566368 W 148.67489022 Top Kingak 12371.21 40.00 125.32 9980.30 6470.73 -5962.75 2623.11 0.00 6025096.82 662578.71 N 70.47495037 W 148.67188230 Fault 15 Crossing 12730.19 40.00 125.32 10255.30 6681.02 -6096.16 2811.38 0.00 6024967.50 662769.79 N 70.47458572 W 148.67034498 S26W Sag Tgt 13542.16 40.00 125.32 10877.30 7156.67 -6397.91 3237.24 0.00 6024675.00 663202.00 N 70.47376091 W 148.66686783 Top Sag River 13542.17 40.00 125.32 10877.31 7156.67 -6397.91 3237.24 0.00 6024675.00 663202.00 N 70.47376091 W 148.66686783 7" Lnr pt 13581.32 40.00 125.32 10907.30 7179.61 -6412.46 3257.78 0.00 6024660.89 663222.85 N 70.47372114 W 148.66670013 Bid 15.25/100 13624.40 40.00 125.32 10940.30 7204.84 -6428.47 3280.37 0.00 6024645.37 663245.78 N 70.47367737 W 148.66651569 Top Shublik 13628.33 40.60 125.32 10943.30 7207.16 -6429.94 3282.45 ----f5.25 6024643.95 663247.89 N 70.47367335 W 148.66649871 13700.00 51.53 125.32 10992.95 7254.12 -6459.73 3324.49 15.25 6024615.07 663290.55 N 70.47359192 W 148.66615547 Top Ivishak 13774.65 62.91 125.32 11033.30 7311.23 -6495.96 3375.62 15.25 6024579.95 663342.45 N 70.47349288 W 148.66573802 13800.00 66.78 125.32 11044.07 7332.13 -6509.22 3394.34 15.25 6024567.10 663361.45 N 70.47345664 W 148.66558518 13900.00 82.03 125.32 11070.88 7419.66 -6564.75 3472.69 15.25 6024513.27 663440.97 N 70.47330484 W 148.66494550 End Bid 13951.86 89.94 125.32 11074.51 7466.76 -6594.63 3514.87 15.25 6024484.30 663483.78 N 70.47322315 W 148.66460113 TO /4-1/2" Lnr pt 14683.93 89.94 125.32 11075.30 8133.94 -7017.90 4112.18 0.00 6024074.00 664090.00 N 70.47206601 W 148.65972482 -'- Leaal Description: NorthinQ eV) fftUS1 EastinQ eX) fftUS1 Surface : 1228 FSL 646 FEL S11 T13N R13E UM 6031001.38 659828.23 S26W Sag Tgt: 110 FSL 2693 FEL S13 T13N R13E UM 6024675.00 663202.00 TD / BHL: 4769 FSL 1819 FEL S24 T13N R13E UM 6024074.00 664090.00 NS19 (P6) report. xis Page 3 of3 9/25/2002-5:24 PM Vertical Section Departure at 149.63 deg from (0.0, 0.0). (1 in = 2000 feet) / TO/4-112"LnrPt """'"'\I 14684 MD 11075 TVD 89,94· 125.32· az BId 15.251100 /' End Bid 8134 departure 13624 MD 10940 TVD 13952 MD 11075 TVp 4000· 125,32· az --"89':94;-:'25:'32; i,i-- -,-~-" 7205 departu'e 7467 departure ----- I 8000 I 6000 I 4000 I 2000 I o .~--~_.__.- 12000 ---."-,,.--------,,-,--- - 1- r Lnr Pt 13581 MD 10907 TVD ._~~fj~~:_~~_:''"'-". ~ :: ~~R~r ~~o::oe::~ ~~blæ:13Š2e,m ~mã::TO~Vi~k~7~M~11~~:: Hold Angle 40.00° 10000 -'" '=--'''~-'-=TciP,(jn¡¡¡;K''ï237ï'MO~99ŠõìŸÕ''-=·,-=--=-·,='' "'="-=""'=--'-=,-=-=~-=,-=--=,-=~=-,,- =1~~~ar~~iffl,~ ~9ffi'2~DBãse=RRZ=i 105õ MiT ~,w = - t<UpCï13~M!)9mTVD - - - - - TMLv116i7MD94"õ2TV5 - - - - - - - - - _..~-,.-._-..__..""."'-.-"~_..'"_..._..,_...,,._...-....... --..---..-......-.-----..----,-."....-.---.-.---.--...,-.'".~,.~'"'...._-,--".. 1 Cry 2/100 10337 MD 8415TVD 41,33· 164,56· az 5233 departure End Cry 11602 MD ,9391 TVD 40,00· 125,32' az 8020 departure '-'"'''''·''·'--''''·''''''''''-+'''''''·'--7''·''''''' ",-.".-'. ""'-...-"'-"'---""','''''"..."."'',.,,,.,-..,.,.,'''''-.,, 9-&'8" Cag Pt 11669 MD 9442 TVD ~40'00" 125,~2· az 6059 departure Fault 15 Crosslng12730 MD 10255 TVD i 40,00· 125,32· az 6681 departure - - ------ --- ------ 526 Sag BIt 13542 MD 10877 TVD - - 40,000125,32- az 7157departure SchluIDbBPgBP I KOP Bid 1/1003~0 MD 300 TVD 0,00' 90,00· az: 0 departure ~ Crv1.5I1004QOMD 400TVD 1,00· 90,OO·!az 0 departure '.~,.!¿.-- -~,,~1~~';~~~~;~~~D !. ~7"'7 8,5~· 90,oo'az 52 departure ! 1 End Cry 1739 MD 1723 TVD i : 15,00' 110,00' az 111 departure 1 ! i Cry 2/100 1759 MD 1743 lVD _¡' ~ ~oo='~oo~ :'':E" = 2000 -.""'.-. . ... ""...l~"".,-.......".....,,,....-............,.,,...,,.:....,....,.......1.~~~.:.:..~"'!II..~.~~~~_~.º,,J~.~º~.:rY..º...."... ..... P·.,. 39,80· 183,60' az 807 dr, parture ! End Cry 3482 MD ~268 TVD ~, 41,33' 164,56· az '.59departure '\~ - _'- - - - - - -:- _1- _~ _ _ _ _1_ _ ----- - CM3 8387 MD 6951'fVD- - - -- -1- I .=.~1.,t3"F2.~MºJ5.'~§º-IYº= - rMBK5573MD4838TVD 1 - 1- - sV'ï 5õ38 Mõ 4436 ND - - 1- -SVEn194MCJ3043'TVIJ i -SVs-3558"MCJ3~ZT\ID" -SV096!Th1IJ"3E!33'T\ID" - - - - - - 1- _ _ _ _ Top Permafrost 1f10 MD 1204 TVD - - - - 1- - - - - Base Permafrost 1586 MD 1574 TVD "."""...".._,,,,.,,,,-,.,,-,,..1.,,,.,, ",,,,,,,,..,__,,,,,___,.,,,,,,....,,.,,.,,,,,,,,,,,,,, 1 Structure: Northstar PF Section At: 149.63 deg Date: September 25, 2002 BP Exploration Alaska NS19 (P6) Northstar Client: Well: Field: VERTICAL SECTION VIEW ') 8000 ----- 6000 ...:.... 4000 _ I -1- 0-", ..- ...... (1)..- (1)...J ~C/) 8:! o Q) C\J > II ~ c: CO :;:¢:: _0 ..c:~ ......1.0 Q.I.O (1)- om ñi~ o.¡..: .- Q) "äja:: > > (1) Q) :JW fo... I- 9 !118": Cag PI \ / ~~~~M~5~~TVD .-/ '"'' "'" ,...,,~": "'" .". .-/ """ '" ". o. ., .", "'" ..... "'" R :~ ".-". R "t .,." '"'' 5028 S 1769 E ~~ )<Ió-~. ':;.'":'':'....'"'''-- -6000 ,,,,,. .,,,"'" --þ 7"'0J<._~r- '-~'O~"'f2~az "." MO . ___~_ ___ _ rr 7, ."" " .... "'" R _ ~ , -.-, ~. I 3000 EAST »> I 2000 I 1000 «< WEST I o ---'- - -7000 r Lnr PI 13581 MD 10907 TVD 40,00· 125,32" 8Z ~' 6412 S 3258 E End Bid 13952 MO 11075 TVD - ,,'..... -,...-.- --89:94·-1:i5~3T8z--'---' .--., 6595 S 3515 E -- ~. .~, - .'- --'- ,~_.- -7000 --,., / n_._".......'_____' _"'_"'_0_'_ _.___"__,. .'. -6000 ---.. " ,....... - -5000 '_W'_'._' ___.' _"..__"".,,_..,'_'.. __.,._._._ _.....".._.~...-.,,~._-_..-.,..._.... .._-.--_.-._-~"'._.""_..._,,--".-..'_.-."....._.~.. :r: I- ::> o Cf) V V V -5000 -.",. - -4000 -4000 -,..-,,-,... --3000 i -".,_.,-.._.~-_._., -1' õ. ' ~. % ~ ..> I O'! .þ¡ ·01..... ..,.~ ... i ^ ^ ^ :r: I- et: o Z -3000 _.....,. --2000 -2000 _...,......................._.~.._.,-., --1000 _____ End Cry 900 M9 898 TVD 8, 50·_,9~~~~,~_~.~,~~,:_.___..._.._"._,_._..__.,"+_._,,__,__._...,_...__.,...._..._... '''...-[-....-.'..''..............''...'....---.--'.-..1......._....'....... ... Crv1.75/1OO1306MD 1299TVD I 8,50· 90,OQ· az 0 N 102 E End criv 1739 MD 1n3 TVD 15.00· ! 110,00· az 19 S 187 E 300 MD 300 TVD C ~11oo 1759 MD 1743 TVD 0,00" 90 00· ~ \ \ 1;'00. 11000. 8Z 21 S 192 E ON OE f) t> Cry 1,5/100 ~-~ 13-318"Cag PI 400 MD 400 TVD 3399 MD 3205 TVD 1,00· 9000· az I 3980· 16360· az -1000 _......O.N, !. ~ ,.. ___ _ .__.. .,. __,_~14.~, ~9. ~ ..__;,....,.,...... End Cry 3482 MD 3268 TVD 41.33· 164,56· az 665 S 564 E ~- i True North Mag Dee ( E 26.15° -0 SchlumbBPUBP ) PLAN VIEW Client: BP Exploration Alaska Well: NS19 (P6) Field: Northstar Structure: Northstar PF Scale: 1 in = 1000 ft Date: 25-Sep-2002 I 0 1000 2000 3000 4000 I I I I I ) Schlumberger Anticollision Report ') NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 39.40 to 14683.93 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/23/2002 Validated: No Planned From To Survey ft ft 39.40 1000.00 Planned: Plan #6 V1 1000.00 14683.93 Planned: Plan #6 V1 Version: 8 Toolcode Tool Name GYD-GC-SS MWD+IFR+MS Gyrodata gyro single shots MWD + IFR + Multi Station Casing Points 3399.44 3205.30 13.375 16.000 13 3/8" 11681.95 9452.30 9.625 12.250 95/8" 13581.32 1 0907.30 7.000 8.500 7" 14544.13 11075.15 4.500 6.125 41/2" Summary ----: OtTsetWellp~th· Offset' . ' , Refe.rente 'Ctr~Ctr.·. .'. :No:-Gø Allowable Warning' Well '<MD, ,MD···· ,Distance"..Are~ D~v'atio'" , 1'1', ' ft ,fti ' : 't,' ft . ,', "1,,1,' ",' Northstar PF NS05 Plan NS05 V10 Plan: PI 797.72 800.00 141.81 15.88 125.93 Pass: Major Risk Northstar PF NS06 NS06 V32 749.21 750.00 132.86 12.61 120.25 Pass: Major Risk Northstar PF NS07 NS07 V33 149.17 150.00 121.17 3.12 118.05 Pass: Major Risk Northstar PF NS08 NS08 V18 847.95 850.00 114.86 14.14 100.72 Pass: Major Risk Northstar PF NS09 NS09 V14 797.80 800.00 102.54 12.33 90.22 Pass: Major Risk Northstar PF NS10 NS10 V17 698.59 700.00 77.09 10.19 67.06 Pass: Major Risk Northstar PF NS12 NS12 V23 1295.32 1300.00 45.41 26.10 19.78 Pass: Major Risk Northstar PF NS13 NS13 V12 648.71 650.00 63.04 10.20 52.84 Pass: Major Risk Northstar PF NS14 NS14 V11 799.44 800.00 44.22 13.29 30.94 Pass: Major Risk Northstar PF NS15 NS15 V19 548.80 550.00 42.48 9.31 33.19 Pass: Major Risk Northstar PF NS16 NS16 V34 399.04 400.00 31.14 8.19 22.95 Pass: Major Risk Northstar PF NS17 NS17 V10 549.78 550.00 22.51 8.40 14.12 Pass: Major Risk Northstar PF NS18 NS18 V11 349.49 350.00 8.40 3.54 4.86 Pass: Minor 1/200 Northstar PF NS20 Plan NS20 V7 Plan: Pia 449.95 450.00 10.29 3.71 6.58 Pass: Minor 1/200 Northstar PF NS21 Plan NS21 V42 Plan: PI 349.50 350.00 21.02 6.57 14.45 Pass: Major Risk Northstar PF NS22 Plan NS22 V8 Plan: Pia 499.51 500.00 30.89 8.65 22.24 Pass: Major Risk Northstar PF NS23 Plan NS23 V26 Plan: PI 399.49 400.00 40.96 7.45 33.51 Pass: Major Risk Northstar PF NS24 NS24 V14 797.90 800.00 52.74 12.92 39.83 Pass: Major Risk Northstar PF NS26 NS26 V22 549.63 550.00 69.04 8.95 60.10 Pass: Major Risk Northstar PF NS27 NS27 V29 997.35 1000.00 82.26 17.47 64.83 Pass: Major Risk Northstar PF NS29 NS29 V22 399.02 400.00 100.92 7.05 93.87 Pass: Major Risk Northstar PF NS31 NS31 V14 996.39 1000.00 125.06 17.25 107.83 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 997.81 1000.00 324.38 18.73 305.65 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 994.85 1000.00 316.83 19.42 297.41 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 149.88 150.00 302.48 4.38 298.09 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 14000.25 14300.00 210.50 68.40 157.53 Pass: Minor 1/200 Seal Island SEAL-A-04 SEAL-A-04 V4 1055.94 1050.00 348.16 18.39 329.77 Pass: Major Risk {~ur";!L~ (' J\-rC i ¡ ¡,;, ~I j, ___f I, j t,·" t L, i ~:\ c.. Target: S26W Sag Site: Northstar PF } Drilling Target Conf: 99% " Description: Map Northing: 6024675.00 ft Map Easting : 663202.00 ft Latitude: 70028'25.539N Shape: Circle \11: NS19 led on: Planned Program Vertical Depth: 10822.00 ft below Mean Sea Level Local +N/-S: -6397.89 ft Local +E/-W: 3237.23 ft Longitude: 148°40'00.724W Radius: 300 ft ,,-.-."-. -"" ~._.,_..-_.'... -,-.--...- ,,---~--- ... ,"- ._, --,..,--._-"._-,-,.._. ."._~-,- _.~., ,-"'_.. --_.._---~.. ." -'-'-" ,-...---. ....~.,- "'._._~.._- ....... ---'-'-' - "-~---"-'--' ..._--,-,. --" ."---..----."--.-.----. -,,,_..,,-----..,----- ,,_.,-._- "'-.-._.--_."_..~--.--_._.' -. ~.._,.._,",-~", ~"----'~-'--'- -,.".-'-".--.----,-......----. .... ~ ~ ~ ~ ~ / 11 ~ / ~ V ~ / / -5900 -5000 -5100 -5200 N -5300 ^ -54-00 -5500 -5500 -5l00 -5800 -5900 C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) C) a- C) N (ì) ..3- Ln LD r- CD N (ì) (ì) (ì) (ì) (ì) (ì) (ì) (ì) (ì) ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /f./S / 7' PTD# Zo¿-¿CJ7 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "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). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate 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. H 207120 DATE INVOICE I CREDIT MEMO ,,-., 9/20/02 INV# CK091602N '-V'1:" ¡ ,) ( ,r. '\ i ~__ ¡ j !~....... ..-:r ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ,- BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ B 10 tj,ii 'f""' ~;¡j;h¡ . .. '" .,t U, " ~1!~lJ1 TO THE ORDER OF ALASKA OIL & GAS CONSERVATION COMMISSION 333 Wp 7th AVE, STE 100 ANCHORAGE, AK 99501 GROSS DATE 9/20/02 CHECK NO. H207120 VENDOR DISCOUNT NET H RECEIVED oc'" 0 1.2002 AlaSKa 01' €uGons. comm\sstOI\ lJtcItorage No. H 207120 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 41'2 .'''11 fUll nlll1 DATE CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT SEPT. 20, 2002 ****$100.00**** III 20 ? ~ 2 0 III I: 0 ~ ~ 20 318 9 5 I: 0 0 a ~ ~ ~ g /I- r:V~ In !FTfFi 1;20. DAYS t~}\,;:>t.'1~f~.;/ I:: ..... . ..... . . '.. t··.·,::'.' ::'.' ':',.~___' , WELL PERMIT CHECKLIST COMPANY ISf)<.. WELL NAME ¡V£' /7 PROGRAM: Exp _ Dev:;¿{ Redrll _ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL .)i~¿::'ð INITCLASS /Jr./l/ /-o~ï GEOLAREA ~ 7(') UNIT# //5~~ ON/OFFSHOREdr ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 0 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. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N M.I /-./,/? 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ 1!2f-#.O,- 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.. . . . . W N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_ ~.Y /1.J, /9, (Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . '. ~~ ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ 16. Surface casing protects all known USDWs. . . . . . . N t 17. CMT vol ádequate to circulate on conductor & surf csg. . . . . N A-¡;/~ ~ ·f e4CRt:;f. 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . Y @ -0 19. CMT will cover all known productive horizons. . . . . . . . j N 20. Casing designs adequate for C, T, B & permafrost. . .. . N _ I 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ,\.("",h (JIyS r š é . 22. If a re-drill, has a 10-403 for abandonment been approved. . . ¥-N-l'iflr 23. Adequate wellbore separation proposed.. . . . . . . . . . . . &J N 24. If diverter required, does it meet regulations. . . . . . . . . . ~ 1J.1a..-lI/-2ý ré'õu...l'\.f-ed . 25. Drilling fluid program schematic & equip list adequate. . . . . ) N rl/l A4 m{IJ l'~ P'7 . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ,A A t' 27. BOPE press rating a.ppropriate; test to II ~oo psig. ~N rZ1 Sf? s!~¿ pf c' ,. ¡VltU,L C~7 ys 4joo p e-/ . II 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N WGft- 10 .~ 0 z... 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable. ... . . . . . . . . . . . . . . Y (bJ) (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N-Allk- GEOLOGY ~N APPR DATE :ñ #)~ /ð~~~ .y NN /J, A.. (Exploratory Only) APPR DATE APPR DATE 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/lnstructions: RP~ TEM JDH ~;¡: " JBR COT DTS WGA v/ MJW /f( l-ð /o/~/¿> , Rev: 07/12/02 SFD_ G:\geology\perm its\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitling Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding infonnation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronolog¡cally organize this category of infonnation. NORTHSTAR NS19 aoa- aOt I I I I I I I I I I I I I I I I I END OF WELL REPORT REPORT FROM SPUD TO TOP SAG RIVER BP EXPLORATION ALASKA sper'r'\{-sun C R I L..L I N G 5 E R V I c: E 5 ( I I I T ABLE OF CONTENTS I I 1. General Information I 2. Daily Summary 3. Daily Operations I 4. Show Reports I 5. Morning Reports 6. BHA's I 7. Bit Record I 8. Mud Reports 9. Survey Record I 10. Formation Tops I 11. Formation Evaluation Logs I I I spe.....r'v- sun I 1:1 RI '-'-I N 13 se Fi\J i c: e 5 I I I GENERAL WELL INFORMATION ( Company: BP Exploration Alaska Rig: Nabors Alaska Drilling No. 33-E I Well : Northstar NS19 Field: Northstar Borough: North Slope I State: Alaska Country: United States API Number: 50-029-23122-00 I Sperry-Sun Job Number: AK-AM-22173 Job Start Date: Oct 29,2002 Job End Date: Nov 13, 2002 I North Referénce: True Declination: 26.296 deg Dip Angle: 80.939 deg ( Total Field Strength: 57523.701 nT Date Of Magnetic Data: Oct 28, 2002 Wellhead Coordinates N: North 70 deg 29 min 28.468 see I Wellhead Coordinates W: East 148 deg 41 min 35.905 see Vertical Section Azimuth: 149.630 deg I SDL Engineers: Doug Wilson Reg Wilson Mark Lindloff Tom Mansfield I Company Representatives: Gavin Kidd Joe Polya Bob Clump Mike Dinger I Company Geologist: Ken Lemley I Lease Name: Northstar SSDS Unit Number: 107 State: Alaska Borough: North Slope sper'l....v-sun 1:1 RI '-'-I N (5 5 lEi R\J 1 c: E S ~,I" ~ I I I I I I I I I I I I I I I I I BP Exploration - Northstar NS19 Daily Summary 10/28/02 Move rig from NS20 Preparing to spud. 10/29/02 Run in with BHA #1 (Bit #1 16" MX-C1, TFA= 1.031). Spud and drill 16' hole to 330' MD, gyroing every 50 feet. Trip out and pickup BHA # 2 with MWD. Rerun Bit # 1. Drill to 1130' , gyroing every stand. 10/30/02 Drill 1030' to 3260' MD. Good correlation on gamma ray with NS06 well. Run gyro until 1465' MD. Top of Permafrost at 1195' MD, 1190' TVD. Base of Permafrost at 1586' MD, 1577' TVD. Top of SV6 marker at 3230' MD, 3065' TVD. First indication of methane gas at 1195' MD. 10/31/02 Drill 16" hole to 3426' MD, 3218' TVD for section Total depth for running 13 3/8" casing. Maximum gas 62 units at 3189' MD. Maximum Rap 1014 ftJhr at 2011' MD. Pull out of hole and run 13 3/8" casing. !3 3/8" casing set at 3205' MD. Start cementing casing. > Bit # 1 statistics= 3426 feet, 19.6 hours and 140K revolutions. 11/01/02. Cement 13 3/8" Casing. Clean pits, nipple up BOP's, test BOP's 11/02/02. Run in BHA #3, Bit #2 12 ~"RSX238HF, TF A= 1.090, Test casing, Drill out 12 ~" shoe and 20 foot of new formation, Perform L.O.T. to 12.5 ppg. Drill 12 ~"ho1e with Rotary Steerable Tool to 4478' MD. Top SV5 3582' MD, 3343' TVD, Top SV4 3983' MD, 3632' TVD, Top ofSV2 4537' MD, 4059' TVD. Maximum gas 191 units at 4674' MD with 8.8 ppg mud. 11/03/02 Drill 12 'i4" hole with RSS from 4478' to 7035' MD. Top ofSV1 marker 5096' MD, 4452' TVD. Top ofUgnu 5573' MD, 4807' TVD. Maximum gas 664 units at 6600' MD with 9.0 ppg mud weight. 11/04/02 Drill from 7056' to 9023' MD with no problems. Top of Schrader Bluff formation 7669' MD, 6388' TVD. Top of Colville formation 8227' MD, 6800' TVD. Maximum gas 439 units at 8400' MD with 9.2 ppg mud weight 11/05/02 Drill from 9023'to 11227'MD. Top ofHRZ at 10546' MD, 8606' TVD, Base ofHRZ at 10987'MD, Top of Kuparuk at 10998' MD, 8939' TVD. Maximum gas ¡ 721 units at 9437' MD with 10.2 ppg mud weight 11/06/02 Drill from 11227' to 11778' MD. Top of Kuparuk C at 11313' MD, 9160' TVD. Top of Miluveach at 11734' MD, 9465' TVD. Circulate and condition hole. Pull Out of Hole. Maximum gas 1016 units at 11317' MD with 10.25 ppg mud weight. > Bit # 2 statistics= 8352 feet, 65.4 hours and 602K revolutions. 11/07/02 Continue to pull out of hole. Run 9 5/8" casing. 11/08/02 Finish running 9 5/8" casing. Circulate bottoms up maximum gas 188 units. Landed casing @ 11753' MD, 9482' TVD. Cement casing. 11/09/02 Pressure test annulus to 3500 psi. Test casing to 3900 psi 11.4 bbl pumped. Run in hole. Drill cement from 11644' to 11667' MD. Tag plugs. I I I I I I I I I I I I I I I I I I BP Exploration - Northstar NS19 Daily Summary 11/10/02 Drill out plugs and shoe track. Drill from 11788' to 11798' MD. Increase MW to 12.8 ppg while drilling to 11798' MD over 2 full circulations. Perform FIT to 14.5 EMW. Drill 8~" hole ahead from 11798' to 12290' MD New Bit #3 an 8 ~"RS161HGSW with a TFA of 0.7420. 11/11/02 Drill from 12290' to 12473' MD. Pullout of hole for new bit. Repair seals on riser. Top of Kingak 12390' MD, 9985' TVD, Bit #3 statistics= 694 feet, 28.0 hours and 329K revolutions. New Bit #4 an 8 ~"DS70FNPV, with at TFA of 0.7420. 11/12/02 Slip and cut drill line, Trip in hole to Bottom and begin drilling at 12474' MD to 13261' MD. Maximum Trip Gas was 138 units. 11/13/02 Drill 8 ~"hole from 13261' MD to 13500' MD, 10856' TVD, 8 Y2" TD. CBU, Trip out. Maximum gas was 242 units at 13499' MD. Top of the Sag River formation at 13470' MD, 10833' TVD. Bit #4 statistics= 1026 feet, 15.9 hours, 214K revolutions. 11/14/02 Run in hole with 7" drilling liner to 13480' MD. Cement same. 0.50 PJSM - LID gyro & RID wireliners while circulating @ reduced rate. 2.50 Drill directional in 16" hole from 1564' to 1860' increasing flow rates up to 1100 GPM. 0.50 Clean up 15 gallon mud spill in cellar due to drip pan overflow. 12.50 Drill directional in 16" hole from 1860' to 3264', pumping sweeps every 300'. Note: 1) In good shape directionally - latest survey @ 3190' 8.00 Drill directional from 1095' to 1564' pumping sweeps before runnIng gyros. Note:lnformation correlated between MWD & gyro survey on 2 s separate surveys as follows: 1) 1210' gyro 7.97 inc1, 95.63 az 1210' MWD 8.14 inc1, 96.18 az 1465' gyro 9.22 inc1, 101.8 az 1465' MWD 9.25 incl, 103.61 az. 2.00 Install mousehole, PIU gyro & wire line tools, & BHA. 1.50 PJSM - slip & cut drilling line. 0.50 Service drawworks & adjust brakes~ 1.00 Finish pre-spud checklist. 2.00 PIU BHA #1 & tag ice @ 62'. 1.00 PJSM - RIU wireline for gyro. 1.00 Pre - spud meeting wI all drilling personnel. 2.00 Clean conductor (ice) & drill to 330'. 0.50 Run gyro & circulate. 0.50 paR for BHA # 2. 1.00 LID BRA # 1. 0.50 Clean rig floor - PJSM for MIU BRA # 2. 1.00 MIU BRA # 2. 0.50 Wash down to 330'. 9.00 Drill, slide, & run gyros from 330' to 1095' md. 1.00 PJSM. Obtain permit to move rig. Move rig from NS-20 to NS-19. 1.00 Level the rig. 0.50 Rig up. Complete Pre-Rig Inspection checklist. 2.50 NU riser Adapter. PT. -NU Riser. Accept Rig @ 2130 hrs. Elapsed Operations Breakdown Time BP Exploration - Northstar NS19 Daily Operations (I.A.D.C.) 11 :00-11 :30 11 :30-00:00 I I I I 'I 08:00-08:30 08:30-11 :00 " 10/30/02 00:00-08:00 I ! I I '~I I I I I I I I I 10/29/02 00:00-02:00 02:00-03:30 03:30-04:00 04:00-05:00 05:00-07:00 07:00-08:00 08:00-09:00 09:00-11 :00 11 :00-11 :30 11 :30-12:00 12:00-13:00 13 :00-13 :30 13 :30-14:30 14:30-15:00 15:00-00:00 21 :30-00:00 20:00-21 :00 21 :00-21 :30 10/28/02 19:00-20:00 Time (hrs) I BP Exploration - Northstar NS19 Daily Operations (I.A.D.C.) '! 37.51 incl & 159.66 az 2) Flow rate following spill 850 GPM. I 10/31/02 00:00-03:00 3.00 Drill 16" directional hole from 3264-3426' md. I Notes: 1. Pumped sweep just prior to reaching casing point. 2. Surface TD reached with good directional position. I Survey at 3354' md - 38.46 deg - 160.4 azim. 03:00-05:00 2.00 Circulate 2.5 X bottoms up. Pumped high vis. weighted sweep. Hole clean. I 05:00-08:00 3.00 Monitor well. POH to BHA. Monitor well. Note: 1) TOH was good wi no excessive drag. Avg. drag 5 - 10 K with :1 occasional drag to 20K on a few jts. 08 :00-11 :00 3.00 PJSM. Lay down BHA. 11 :00-12:00 1.00 Clean up drill floor. I 12:00-12:30 0.50 P JSM - Rigging up Frank's tool and casing equipment held at pre tour meeting. Rig up Frank's Tool. 12:30-14:30 2.00 Rig up to run casing. Loaded plugs in cement head. I 14:30-20:00 5.50 PJSM - Ran 81 jts. of 13 3/8" 68# L-80 casing with no losses. Casing went in slick with the exception ofjts 53 & 76 @ 2220' & 3175' respectively. S/O weights down to 95K on each jt. Worked down without problems or 1 washing. 20:00-20:30 0.50 R/U landingjt. & hangar & land hangar. 20:30-21 :00 0.50 LID Frank's fill up tool & M/U HOWCO cementing head. 21 :00-23:00 2.00 Establish circulation by staging up pumps from .5 to 10 BPM. Initial circulating pressure @ .5 BPM was 270 psi, final circulaing I pressure @ 10 BPM was 410 psi.Held PJSM for cement job while circulating. 23 :00-00:00 1.00 Pump 5 bbls water & test cement lines to 3500 psi. I Pump 75 bbls. 10.5 ppg spacer. 11/01/02 00:00-02:30 2.50 Pump 388 bb1s 10.7 ppg Type "L" lead cement followed by 96 bbls 15.9 I ppg class G tail cement @ 6 - 8 BPM. Drop bottom plug & chase wi 25 bbls. wash water from Halliburton pumping unit. Displace cement wi 472 I bbls. wi rig pump. ( Last 20 bbls pumped was sea water) Bumped plug @ 96% pump efficiency. Held 1700 psi. on casing for 5 minutes. Bled off pressure & checked floats. OK I 02:30-04:30 2.00 LID cement head, BIO & LID landing jt, flush out flow line & riser, BID lines, & remove casing handling tools from rig floor. I 04:30-05:30 1.00 RID surface riser & adaptor. 05:30-06:30 1.00 N/U Vetco Gray multi-bowl ass'y & test to 2000 psi. 06:30-11 :00 4.50 N/U BOP's - skid rig floor to line up riser. I 11 :00-13:00 2.00 P/U testjt, install test plug & prepare to test BOP's. 13:00-14:00 1.00 Test BOP's to 4800 / 250 psi for 5/5 min. I I I 'I I I I I I I I I I I I I I I I I 14:00-14:30 14:30-18:30 18:30-19:30 19:30-20:00 20:00-00:00 11/02/02 00:00-01 :30 BP Exploration - Northstar NS19 Daily Operations (I.A.D.C.) 0.50 PJSM - Testing BOP's. Crew change out day. 4.00 Test BOP's to 4800 I 250 psi for 5/5 min. Test annular to 3500 psi. 1.00 RID from BOP test. LID test plug & test jt. BID lines. 0.50 Install wear bushing. 4.00 PJSM - 1) Modify possum belly to accomodate more fluid from flow line discharge. 2) Spray foam insulation & silicone drip pan underneath drawworks. 3) Repair leak on top drive pipe handler by replacing cylinder. 1.50 1) Complete possum belly modification to accomodate more fluid from flow line discharge. 2) Complete cleaning & sealing drip pan underneath drawworks. Replace cylinder in top drive pipe handler. Service top drive. PJSM - M/U BRA #3 - shallow test RSS - BID top drive Finish P/U BHA. RIH to 3319' washing down the last stand & tag plugs on top ofFC. 10' of cement on top of plugs. Circulate cement until equivalent MW in = MW out. 9.0 ppg Test 13 3/8" casing to 3550 psi & hold for 30 minutes. Notes: 1) Reviewed D 1, D2, & D5 drills with crew during test. 2) Discussed drilling hazards associated wi intermediate hole section. Drill plugs, cement & 20' of new hole to 3446'. Started displacement of old mud with new 8.6 ppg after drilling float shoe. Finish mud swap & circulate until MW in = MW out @ 8.6 ppg. Perform FIT to 12.5 EMW wi 8.6 ppg. (650 psi) Establish clean hole ECD baselines. Drill 12 1/4" directional wi RSS from 3446' to 4478'. Notes: 1) Pumping hi-vis barofibre sweeps every 400' wi 5% to 10% excess seen @ shakers. 2) RSS responding to down links. 3) ECD's are good - 9.3 to 9.4 wi 8.7 to 8.8 ppg MW. 01:30-04:00 2.50 04:00-04:30 0.50 04:30-06:30 2.00 06:30-07:30 1.00 07:30-09:00 1.50 09:00-10:00 1.00 10:00-11:00 1.00 11 : 00-15: 00 4.00 15:00-15:30 0.50 15 :30-16:00 0.50 16:00-16:30 0.50 16:30-00:00 7.50 11/03/02 00:00-00:00 24.00 Drill 12 1/4" hole wi RSS from 4478' to 7035' md. Notes: 1) Adjust RPM and or WOB to address drill string harmonics. Some stick slip occurring regardless of adjustments being made, especially on hard streaks. 2) Mud system contains 2 - 2.5% lubricants for torque reduction wi lubetex, torque trim, & BDF 263. Condet & Clayseal to prevent bit balling & screen blinding. 3) Pumping hi-vis barofibre sweeps every 400'. 4) ECD's in 9.5 to 9.6 range wi 8.9 - 9.0 ppg MW's. Drill 12 1/4" hole wi RSS from 11227' to 11260' Repair wash out on #2 mud pump discharge manifold. Drill 12 1/4" hole wi RSS from 11260' to 11778'. Pump 50 bbl. hi-vis weighted sweep (13.2 ppg) @ TD. Condition & circulate mud for casing. POH, Monitor well - pull 5 stands - pump dry job & BID top drive. POH to 8400'. A few tight spots In the Kuparuk & HRZ wi 40K lbs drag. Wiped through tight spots once & excess drag was gone. Spot 150 bbl. 20 ppb steel seal pill across Schrader Bluff - pump dry job - BID lines. Continue paR to shoe. Remainder of trip was good wi no excessive drag or swab. Circulate 1 B/U @ shoe wi minimal returned cuttings. 845 gpm POH to 3350' - circulate @ 4 BPM while holding PJSM for slip & cut. Slip & cut 102' of drilling line. Continue POH. LID porcupine reamer & dart sub. Note: Porcupine reamer not missing any inserts as in past. 1 insert hanging loosely. Drill directional wi RSS from 8995' - 10393' md. Notes: 1) Adjust RPM & WOB to address drill string harmonics as needed. 2) Maintaining 3% lubricants. 3) Pumping hi-vis barofibre sweeps every 400'. Condition & circulate mud. Add 12.7 ppg spike fluid to get 10.1 ppg MW. Drill from 10393' to 10770' md. Lubricate blocks & service top drive. Drill from 10770' to 11227'. Top of HRZ 8606' TVD - 10546' md. Top of Kuparuk 8939' TVD - 10998' md. Drill ahead in 12 1/4" hole wi RSS from 7035' to 8138' md. Service top drive. Drill ahead in 12 1/4" hole wi RSS from 8138' to 8995" md. Notes: 1) Pumping hi-vis barofibre sweeps every 400' wi 0 - 10% additional cuttings. 2) Maintaining 2.5 - 3% lubricants. 3) ECD's 9.7 - 9.85 range wi 9.1 - 9.2 ppg MW's. No ECD spikes. 4) RSS responding to downlinks. BP Exploration - Northstar NS19 Daily Operations (I.A.D.C.) 11/06/02 00:00-01 :30 1.50 01 :30-03:00 1.50 03 :00-11 :30 8.50 11:30-14:00 2.50 14:00-14:30 0.50 14:30-16:30 2.00 16:30-17:30 1.00 17:30-20:30 3.00 20:30-21 :00 0.50 21:00-21:3 Q.50 21 :30-22:30 1.00 22:30-00:00 1.50 I \ ( I I I I I I I 1.00 4.00 0.50 6.50 12:00-13:00 13:00-17:00 17:00-17:30 17:30-00:00 I I 11/04/02 I 00:00-16:00 16.00 16:00-16:30 0.50 16:30-00:00 7.50 I I ( 11/05/02 00:00-12:00 12.00 I I BP Exploration - Northstar NS19 : Daily Operations (I.A.D.C.) I 11/07/02 I 00:00-03 :30 3.50 Continue to Lay down BHA. BHA not balled up- clean. Bias unit had one washed out seal. Bit in good shape- 1-0- In gage. Good Drilling Practices evident by bit! BHA condition. I 03 :30-04:30 1.00 Clear rigfloor. Pull Wear Ring and Install Test Plug. 04:30-06:30 2.00 PJSM. Change out top rams to 9.5/8" and test doors to 3500- psi. Pull Test I Plug. While working on Rams remove Stabilisers from rigfloor and bring up casing equipment. 06:30-08:00 1.50 PJSM. R/U to run 9.5/8" casing installing Franks Tool and long bails. I 08:00-09:30 1.50 M/U 9.5/8" Shoetrack and check floats- OK. 09:30-13:30 4.00 Run 9.5/8" Casing to the 13.3/8" Shoe @ 3400 ft. No losses. 13:30-14:00 0.50 Circulate Casing contents @ 10 BPMI 800 psi. No Losses. I 14:00-22:30 8.50 Run 9.5/8" Casing to 10,663 ft. Taking a little weight ( 80 klbs). Just above the HRZ at base of Colville. All joints Making up @ 9,900 ftlbs. Each Joint checked for Triangle. I 22:30-23:00 0.50 Circulate joint above HRZ- Precautionary. 3 BPMI 1020 psi. Full Returns. All Parameters steady. 275 kbs down 470 klbs Up. 23:00-00:00 1.00 Continue to run 9.5/8" Casing. No problems at Top ofKuparuk. I Total Losses for casing runing Operation Approx 55 bbls. Total Joints run of 47 11ft, L-80, BTC-M = 286. I 11/08/02 00:00-00:30 0.50 Run the last 5 jts. of9 5/8" 471b. L-80 mod. buttress casing & P/U landing joint. Ran a total of 286 jts. casing. I 00:30-04:00 3.50 Wash down landingjt @ 3 BPM - 1160 psi. Kept hangar 5' above load shoulder while staging up pumps. Stage pumps from 3 BPM to 9 BPM - initial circulating pressure 1160 psi, final pressure 1300 psi. Land hangar I 45 minutes into circulation. Hangar weight in slips 315,000 Ibs with top drive & blocks included, I 245,000 Ibs. without. Held PJSM for cement job while circulating. 04:00-08:30 4.50 PJSM - RID Frank's tool, install cement head & x-over, & test lines to 4,000 psi. I Pump 50 bbls. 11.0 ppg weighted spacer & drop bottom plug. Pump 402 bbls. 11.2 ppg lead slurry followed by 124 bbls. 15.2 ppg tail slurry. Drop bottom plug & chase with 25 bbls. of water from HOWCO & I turn over to rig pump. Displace cement w/ 829 bbls. mud. Bumped plug @ 900 psi. wi 94.1 % pump efficiency. Test casing to 1400 psi & held for ......8 minutes. Pressure held. Bleed off pressure & checked I floats - OK. 08:30-09:30 1.00 RID cement head, casing equip't , & LID landing jt. 09:30-10:30 1.00 Install elevators, P/U stand, drain & flush BOP, install packoff & test to I 5000 psi for 10 min. 10:30-13:30 3.00 R/U to pump down 13 3/8" x 9 5/8" annulus. Pump 210 bbls 10.5 ppg mud down annulus. Broke down @ 900 psi - final pressure was 590 psi. I LID packoff running tool, stand back stand DP, take off long bails, drain stack, & change out 95/8" rams for 7" x 4 1/2" variables while pumping down annulus. I I BP Exploration - Northstar NS19 Daily Operations (I.A.D.C.) I 13 :30-14:00 0.50 P JSM - Install bails & elevators. I 14:00-15:00 1.00 PJ8M - Write procedure for removing stabbing board. 15 :00-16:30 1.50 Remove stabbing board & set in pipeshed. I 16:30-18:00 1.50 PJSM - drain stack & prep for BOP test. 18:00-23:00 5.00 Test BOP's to 250 I 4800 psi for 5 I 5 min. Drip @ unibolt on choke hose - cia ring & retest. I 23 :00-23 :30 0.50 BID all lines. 23:30-00:00 0.50 Unable to pull test plug - drain stack & see annular preventer element protruding on the inside of riser. Land test plug, back out I test jt. & LID. I 11/09/02 02:00-06:00 4.00 cia annular preventer element. 06:00-07:30 1.50 NID riser. I 07:30-08:30 1.00 RID & test annular to 3500 psi. RID test equip't. 08:30-09:00 0.50 Pull test plug & install wear ring. 09:00-09:30 0.50 Clean cellar & rig floor. I 09:30-10:00 0.50 PJSM for M/U BHA # 4. 10:00-11 :30 1.50 M/U BHA # 4. 11 :30-12:00 0.50 Shallow test MWD & Rotary steerable power drive ~ @ 400 GPM - 500 psi. 12:00-13:30 1.50 Continue MID BHA # 4. 13:30-16:30 3.00 RIH to 8900'. I 16:30-18:30 2.00 P J8M - Install stabbing board. 18:30-19:30 1.00 RIH P Continue RIH from 8900' to 11545' 19:30-20:00 0.50 Wash down from 11545' & tag cement @ 11644'. I 20:00-20:30 0.50 Circulate MW in = MW out @ 10.5 ppg. 20:30-21 :30 1.00 Pressure test 9 5/8" casing to 3900 psi & hold for 30 min. 11.4 bbl I pump/return. 20:30-21 :30 1.00 Discuss well control & drilling hazards associated wi 8 1/2" hole section while testing casing. Review D 1, D2, & D5 drills. Perform D8 - muster drill. I 21 :30-22:30 1.00 Replace suction valve in pit 1D. 22:30-23 :00 0.50 Drill cement on top of plugs from 11644' to 11667' Tag plugs @ 11667'. I 23 :00-00:00 1.00 Lost power on rig. 13/8 highline breaker closed along wi gas valve I on pipe rack due to gasl low pressure. No gas detected inside rig. Safety did not detect any gas venting at pipe rack. Trying to establish why ESD activated. 'I 11/10/02 00:00-00:30 0.50 Restore hi-line power to rig. 00:30-03:00 2.50 Drill out FIC plugs & shoe track. Started adding spike fluid for 12.8 I ppg MW @ 01 :50 hrs. 03:00-06:15 3.25 Drill 9" hole wi RSS from 11778' to 11798 md. Pumped 2 walnut I sapp sweeps for bit balling wi limited success. I I BP Exploration - Northstar NS19 Daily Operations (I.A.D.C.) I Knocked ball off bit by bouncing off bottom. Dressing out mud to 12.8 ppg MW while drilling 20' of new hole. I Took 2 full circulations. 06: 15-07 :00 0.75 Perform FIT to 14.5 EMW wi 12.7 ppg MW @ 890 psi. 07:00-07:30 0.50 Establish ECD baselines as follows: I 11798' 600 GPM, 0 RPM - ECD 13.67 11798' 600 GPM, 60 RPM - ECD 13.66 11798' 600 GPM 120 RPM - ECD 13.71 I 07 :30-18 :00 10.50 Drill 9" hole wi RSS from 11798' to 12114' md. Pumping walnut I sapp sweeps for bit balling. I Adding barite to maintain 12.8 - 12.9 ppg MW. 18:00-18:30 0.50 Service top drive & blocks. 18:30-00:00 5.50 Drill ahead from 12114' to 12290'. [ Rap rates 15-50 ftJhr. Drilling parameters indicating bit balling tendencies. I 11/11/02 00:00-12:00 12.00 Drill ahead in 9" hole wi RSS from 12290' to 12473'. Hit Kingak @ 12,390 ft. P-rates still low. Torque response indicated that bit was I digging but slowly. 15-25 filhr. Slow Rap due to frequent bit balling. Nut plug I sapp sweeps non-productive. 12:00-13:00 1.00 Condition & circulate mud @ 630 GPM for TOH. \ 13 :00-13 :30 0.50 Monitor well - POH wi 8 stands to 9 5/8" shoe. I I 13 :30-14:00 0.50 Monitor well @ shoe - pump dry job - BID lines. 14: 00-1 7: 15 3.25 Continue POH to HWDP - monitor well for 15 min. I 17:15-18:30 1.25 Handle BHA # 4. Bit in good shape. Rest ofBHA in good shape. 18:30-18:45 0.25 Clear & clean rig floor. 18:45-19:30 0.75 Download CDR & test bias unit. I 19:30-20:00 0.50 M/u BHA # 5. 20:00-22:30 2.50 RIH to 6930'. 22:30-00:00 1.50 Air boots on riser leaking. Attempts to air back up & repair with I fix -a- flat were unsuccessful. P JSM - pull riser and replace air boots. No mud found its way to secondary containment- about 0.5 I gallon on top of annular. Good Spot by the Shaker Hand- prevented potential spill. 11/12/02 I 00:00-01 :30 1.50 Replace air boots on riser. 01 :30-04:00 2.50 RIH to 11356' md. I 04:00-06:30 2.50 PJSM. Slip and cut drilling line. Adjust brakes. Service Top Drive. 06:30-07:00 0.50 RIH to 12403' md. Hole in Good shape- no problems. 07:00-08:00 1.00 Wash from 12403' to 12473' md. Stage up pumps. Some high I pressures early on - 500 GPMI 4100 psi. 08 :00-00:00 16.00 Drill ahead 9" hole from 12473' md to 13260' md. No Drag, No I losses. ECD steady @ 14.0 ppg. RPM @ 160 and Flowrate running @ 625 GPMI 3900 psi. Pump Back 90 ft on each stand. I RIH wi 7" drilling liner fl 7264' md to 11680' md (inside 9-5/8" casing shoe). - Running speed 1 minute per stand. - Fill DP per 10 stands. Circulate DP + liner volume (241 bbls) @ 5.5 bpm wi 925 psig. Take Parameters: - UWT= 285 K, DWT= 215 K, and RWT= 250 K Ibs - 35 rpm wi 11K-lbs torque. RIH into open hole wi 7" drilling liner to 13362' md. - Encounter minor tight spots @ 12436', 12473' and 12675' md. - Encounter more trouble through fault. Necessary to work pipe numerous times -- loosing ground. At 13082' md, got though by rotating at 40 rpm/11K torque wlo pump. Wash from 13362' md to 13411' md -- pump 1 to 2.5 bpm with no rotary . Drlg fj 13262' - 13500' md. Note: Top of Sag @ 13470' md. Pump Sweep and CBUx2. Note: Spot new 13.0 ppg pill across openhole interval. Monitor Well and POOH to 11700' md (inside 9-5/8" csg shoe). Note: 250-350K Ibs max, Max Drag 50K & Avg Drag 15K. Monitor Well, Pump Dry Job and BID Top Drive. POOH to 1007' md @ BHA. POOH while LD 26 jts of HWDP. LD BHA#5. Notes: 1. Bit was in great shape -- one plugged nozzle. 2. Near bit reamer was missing the cutters on all 3 blades. 3. BHA was clean with no sign of balling or clay build up. Clear and Clean rig floor. PJSM -- RU 7" liner running equipment. PJSM -- Run 46 Jts of7" 26# Hydril521 liner. PU Hanger Assembly. Mix and pour PAL-MIX inside 7" liner top. Allow 30 mins for mix to set up. RIH wi 7" liner on 5" DP filling every 10 stands. Continue RIH wi 7" liner assembly. At shoe circulate DP volume + liner volume. Run liner into OH. Encounter Tight Spots @ 12436' to 12473'md, 12675' md, and 12850'md to current depth of 13087' md.. Assembly with DS-70 tending to build. Set RSS @ 20%/36 degs. Sperry Keeping a close Eye on cuttings- no obvious splinters. .. Rap from 50- 100 fph Top Sag @ 13,470 ft MD, 10,835' TVD BP Exploration - NorthstarNS19 Daily Operations (I.A.D.C.) I I I I 11/13/02 00:00-03:30 3.50 I 03:30-05:30 2.00 I 05:30-07:00 1.50 07:00-07:30 0.50 f 07:30-11 :00 3.50 11 :00-13:30 2.50 I I I 13 :30-14:00 0.50 14:00-14:30 0.50 14:30-18:00 3.50 I 18:00-18:30 0.50 18:30-19:00 0.50 I 19:00-00:00 5.00 I I 11/14/02 00:00-03 :00 3.00 I I 03:00-04:00 1.00 I 04:00-06:45 2.75 I I 06:45-09:30 2.75 I ;;~ ;~ I ~ I I I I 09:30-10: 15 10:15-11:30 I I I I I I I I I I I I 11 :30-12:30 12:30-13 :00 13:00-13:30 13:30-14:00 14:00-14:30 14:30-15: 15 15:15-16:15 BP Exploration - NorthstarNS19 Daily Operations (I.A.D.C.) * Packed off at 13393' and 13411' md. * Unable to advance past 13,411 -- packing off and losing ground. Established rotation @ 30 rpm and while pumping 2.5 bpm @ 13411' md and wash and ream from 13411 to 13485' md (set liner 10' into top of Sag @ 13480' md. Did not attempt to wash liner into bottom 20' of rathole). * Packing off occured frequently. Finally able to eliminate packoff by reducing pump rate to 1 bpm and rotating 25 rpm. - Last 60' washed and reamed with no apparent problems. Did not take weight or shows signs of packing off. No trouble getting into Sag. 0.75 RU cement head. - Change out leaking valve on cement manifold. 1.25 Establish circulation and stage up rate in 112 bpm increments to a final clean up rate of 5.5 bpm wi 1070 psig. 1.00 0.50 - Off bottom parameters: ROT 265 K wi 20 rpm and 14 K-lbs torq. - UWT= 350 K & DWT= 235 K Ibs. Drop and pump ball @ 5.5 bpm. Place ball on seat and pressure up to 2000 psi and set hanger. 2. Pressure up to 3200 psi and release running tool. 3. Picked up 3' past neutral point - unable to determine whether free of liner. PU an addtional 2' to make determination -- still not able to determine of off liner. 4. Blowout ball seat @ 4150 psi. Had driller shut off pumps immediately due to losses occurring on past 2 wells. - Pressure bled off immediately to 2600 psi and trapped -- signs of packoff down hole around liner shoe. - Monitored pressure for 5 minutes as slowly bled down to 300 psi. Well flowing with mud back at shaker. - 300 psi trapped -- re-establish circulation by bringing pumps on @ 1 bpm increments up to 5 bpm -- packed off. - Shut down pumps and bled off pressure to 100 psi. - Re-established circulation at 0.5 bpm and increased to 1 bpm. Patiently increased pumped rate in, 1 bpm increments to 5.5 bpm over 1.5x openhole volume. Circulate. Halco crew change. P JSM for cement job -- no circulation. PT cement lines to 4000 psig wi 13.0 ppg ALPHA Spacer. Pump 35 bbls Alpha spacer total. Mix and pump 102 bbls (379 sxs) of 15.9 ppg tail cement at 5 bpm as per plan. - TT= 5 hrs:2mins. - Did not rotate liner during cement job. Drop plug and switch to rig pumps. Displace cement with 12.8 ppg Mud.@ 5.5 bpmwl full returns. - Slow rate and latch up @ 94% efficiency. Increase rate and bump plug 0.50 0.50 0.50 0.75 1.00 15:15-16: 15 1.00 I I I I r I 16:15-16:30 0.25 16:30-17: 15 0.75 17:15-18:00 18:00-21 :45 0.75 3.75 21 :45-22: 15 0.50 22: 15-22:45 0.50 22:45-23:30 0.75 23:30-23:45 0.25 23 :45-00:00 0.25 I I I I I I I I I I BP Exploration - Northstar NS19 Daily Operations (I.A.D.C.) P to 1900 psig wi 96% efficiency. HOWCO meter 275 bbls (96% efficiency). Hold pressure for 1 min. - check floats. Note: Cement in place at 16: 15 hrs. Slack Offw/o rotation and set ZXP liner top packer wi 80 K Ibs- see shear and set. PU to neutral and rotate down on liner top wi 50 K Ibs - verify ZXP set. Pressure up to 800 psig and circulate at max rate after seeing pressure loss while PU. - CBU. Estimated 20 bbls cement returned. Spacer and cement carrying quite a bit of shale - not splintered (more laminated). Lay down cement head and 2 Jts ofDP. PJSM for SW Displacement. - Displace well over to SW. Pump 200 bbls Sea Water. Follow wI 70 bbls Hi vis sweep and displace wi 820 bbls of sea water. Final NTU 380. Negative flow test well. POH wi 12 stds. P JSM. Monitor well. Change out drilling sweep to production sweep on upper annulus. Fill hole and monitor well. POOH wi HRD running tool. Continue POH wi 7" HRD running tool. Inspect HRD on surface - good condo Make service breaks- LD. I [ I I I sperry-sun Well Name: NORTHST AR NS 19 Depth (MD) 11313 to 11346 ft Location: NORTHST AR AREA (TVD) 9160 to 9183 ft DRILLING SERVICES Operator: BP EXPLORATION ALASKA Show Report No. 1 Show Report Report Prepared By: TOM MANSFIELD Date/Time: 11/6/02 Report Delivered To: KEN LEMLEY Interpretation: Steam still analysis indicates this portion of the Kuparuk "C" would produce gas. Dñlling Mud contained 3% lubñcants. Samples had 50% dull to moderately bñght yellow fluorescence however, no cut fluorescence was observed. No visible oil sheen was observed in mud samples used in steam still analysis. % Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 Depth 11315 ft Gas x Units 1016 Mud Chloñdes (ppm) = 17500 ---Frõ\Ñirñ¡-------§üëtiõñ------~-tiõy¡----------------------------------=----------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 56.3 2.81 = 53.49 - -- C2 5.10 0.81 = 5.02 - -- C3 4.13 0.98 3.15 - - C4 2.91 1.01 = 1.90 - -- C5 1.95 0.75 = 1.20 --Prõaüëtìõ-ñ------===-------=---------------------------------------------- Analysis IXlGas nOil nWater nNon-Producible Hydrocarbons 2 % Depth 11330 ft Gas x Units 750 Mud Chlorides (ppm) = 17500 --'1rõ\Ñlfñ¡-------§üët1õñ-----=-à"hõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 41.70 2.81 = 38.89 - -- C2 4.79 0.81 = 3.98 - -- C3 3.43 0.98 = 2.45 - -- C4 2.59 1.01 = 1.58 - -- C5 1.80 0.75 = 1.05 --Prõaûctiõ-ñ-------------------=---------------------------------------------- Analysis rtGas lOil nWater nNon-Producible Hydrocarbons 3 % Depth _ ft Gas Units Mud Chlorides (ppm) = --'j!rõWirñ¡-------§üëtiõñ-----=-~tiõy¡----...------------------------------------------ ppm ppm ppm (Steam Stili PPM's In 1000's) C1 C2 Hydrocarbon Ratios C1/C2 10.7 C1/C3 17.0 ClIC4 28.2 C1/C5 44.6 1000.0 - ..,------_. '----------,,'.'-.-._--- -----"-..._--~~-,---- __. ____ n___.__~ _________________ - ---_._._--_._._--~-- NPH 100.0 --- -- :;---=:;..--=~:~~ ~~=-~=º:;~~.:.~=-=-~:.:=~::~::~:_=:~ Gas .' "",-," .~,,-_...- ----.,- - 10.0 ~~.____.__ Hydrocarbon Ratios C1/C2 9.8 C1/C3 = 15.9 C1/C4 24.6 C1/C5 37.0 ---_._----_._._,----_..----~ ,--~_._._-_._..._...,'".._---- ---_.,.._._~..- --- - _.__.-.~--~----._---,- _._~~_._----_._-,----_._--_._- ,,-....-. -- -,-,.~-_._._..._._----_.__.,--_...._- ...--.-----..---...-. .~-- _._----_..'-~._-,-- Oil .----,--.-.-------..----,-. -------...-.-..-...-- -----...--- .,--,_.-.__._-_.~...,_.,,"- ...---,--.-..-.-. NPH 1.0 _. _ _ "'_'_____.,..._.._.._ h'~ - '" . -.. . - ----.-,..--.--.-."---. -.. Hydrocarbon Ratios C1 C1 - - C3 C4 ~ -"' -. -...-...-..-.----".."-... C1 C2 C1 C5 - --_._,,-_.,,-,..,-,...~.._"-,-_._----,.__._,_.,",._---"'--"--._'--~--_._.."._---_."...."---_._._-_.,_._-,-,.._".",.,."-."--.-.-- = Hydrocarbon Ratios C1/C2 =##### ClIC3 =##### C1/C4 =##### ClIC5 =##### NPH 1000.0 . -.'"".--- .__...-,--~-,.---,_.~,...._-,._- ...- "' - --.-.--.---.....--..--..-..-"-- ..,,----..--.-----..-.--.--..--..-----....-- -----..-..---.---..-- --- C1 C2 C3 C4 = C5 = -Prõaüëiío-ñ------===-------=---------------------------------------------- Analysis nGas nOil nwater nNon-Producible Hydrocarbons 4 % Depth ft Gas Units Mud Chloñdes (ppm) = --'j!rõ\Ñlïñ¡-------§üëtiõñ-----::-§l1õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) _...__.._..._-.._----~-_._-".._. .-.......,.,,-.--,...-----.- ..-.-..-----.-----.--....... ---...--,-.-..-.---,---.-----.... "., ..--.-..-.---.-..-..,,-.--'-'--..-.-..-- = ---.. .----...-.-..-.---...--,-.......-..----.. .-.--.--......-....-.-..--,--....-...--.-.--.- ----...".--.-.-'''-..-.--.---.---- . _.._..____.__n'__..________,___ ..----.----- 100.0 --- .~..-,~ -- =-;:~~::.~~~~-- _....._._._.._~,---_...__.._._----- --.-.-..-.---- -------._- ...----.. ---~'"--_.__._...".._,---_..._- ._-_._~,_._..- .__.._.._..._~---_.- _...~..,...-._-,,_..._...__......_,._._..- Gas -.-..-.-.-----,--,---- ------.......-.-.-------.--- --..-.-.-----..---.---....--- ._.. .._._.u______.._._;,. ___.;;-.._"-.....----~--- _..._~_._.~....~_.,_..."..__. .._ ...-...- C1 C2 C3 C4 C5 - - --Prõaüëiío-ñ------------------ Analysis Gas Oil Hydrocarbon Ratios C1/C2 =##### ClIC3 =##### ClIC4 =##### ClIC5 =##### .----..-,,----....- ""'------.---...---.-.- ---..-..,--.- 10.0 ~ ....._-,,--- ...---.-..-..-...-.-....-- ., -.... .. -_.,,,- -. .._._..~_..._". ..-.-...--"..- = _. - ..... ..__._.._.__ ___.___. __._.__..~.. _._ _. ,,_.__.___._ .__..__.__.,._ - ___... _._...____.u._... ..____..._ -..-...----..-"-..-.-.--.-.-........-..----- -_._~--_._-_._.._.--...-- ._._-_._.....~..__.-.._,_._._._..._. ,-.. Oil = -.-...-.-..--...----------...-....-'-,-,-..---. ....__..~..,_.,--_... . ..,. . .... ..._ ·_.._,_..'__..._d~._.·._..·~·._.__~·_~ __..________.... ___.__.___. = . - -....-.--..--. ---.- .. '--."--.'.-.-'''---. -"-'- --.--.-- = = NPH 1.0 ----------------------...----------------------- to ~:: to ~.' ~ ----i\~ ~' to ,r ---- · 1 t:, .....:î;I!. o~JUI'*~~:it.'4·~~~I1t.,IAM.:.';;P'<!~"'.Û"i\'!~~,'!l~$' "'~',1~.~!tI!I~~1I:t>:':;t,·v¡"c!!.¡;iI¡.~~'Fr:I::~'S:¡m·'I~!"P.~W"'~'~ ;-1,)'~r";'¡'!!$i'!llltl..t.J:·,·~.,;,:¡;.::-.'>.:;¡~".,\.·t·:fls~:f~"'I;:¥!,. ;{~Uj:;"" :'~" ~ ",0 . u~:.... ~' ~~:'I~~..·~(.ll~ .~~lot"-~1~~' ~:;~~~ø;',~ ~~~.1~:)11.~! ~.~~.fi1~\ ~1.~~~~r .!~rn~~:}¡·~7~~'-~' ': ~~. . :~~. ~~ ... ,.~~".~~~,:' ~ 'F;~~~ r--;1;, ~/~~'..~:~m~.~ :~~\~:~~~~.~~~,~}. ,,~;'. rl.:~~'.~;\~~":'· t.·. / . ~,. . r~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. " : Description of fillings: . , ,- !¡",~;-, ~:~~""';>.I:W"'~~¡ 1',u~ì'¡¡i!~j.~ :'~~"'''1('~''''J'<~ ·!4.ì:'1,¡F ':. ""~1¡;,.~~r~:t'¡fY¡<;~~~~.~f..r~)1,:'!1:¡~H~..~~.t~~~',",1~m~~~fî'l'.d~~~':~'¡' >.!!t,f:~t;~*.'¡ ~;:~I-'l:~~~¡,·,·:.:t~fJ:~~,:J($,.·,t.' ;.;; , ~1¡~f 24 hr Åe'~~'''' ' F·i~¡'~'¡'· "'Àig' u; on 'NŠÙ~ ': PiCk'upï3'HA#1 ,(:~Iea~' ~~t"~'~~d~~t~r ~nd' ~irilí' to 33Ò", POOH' , ".,.",,' .,..,.... . 'I pick up BHA #2, RIH, Continue drilling from 337' to 1130'. Gyro surveying every 2 stands. t* I :1 i }¥;" Logging Engineer: Reg Wilson/Mark Lindloff * 10000 units = 100% Gas In Air ·m % Lithology Sst Sltst Sh after Gas during before after Drill Rate during Depth before Drilling Breaks ft ft ft Connection Gas and Mud Cut ft units ppg ft _ units _ ppg ft _ units ppg ft _ units _ ppg ft _ units ppg ft _ units _ ppg ·-I·-'--'ìji]llínr~T-··~~fi[ ~~r'Kr··llT-n1T'I:~iIUß··I;¡'·;~':;';¡i--":¡-nllr- ppg ppg ppg units units units I I I , :~ ..' . :~:,. ~ '-:...' ~ ~';i ;~-: ~::;''''\·~''-::''/'1·.'~.:. \--: :';,,':~~~. ~(Þr7.~' ":.. '..~' :"'::'-..¡... =%~,~.?~~1:i'é.~~·.:::.~.;'·~~:~::~..:.::~...~~~:£'.,~.'~7~'I,...~~::·~~:-:·;::;·Ú·.:~::;::_·':'·I""",~ ";~..";;:::,:~~'" :·:w:t:~.:.?:':-':\'!~,,~~\;"'....:."íf~ :'~~ ~".::,~~-~ rw-I~: ~ P;~.~;~.~~:~i··,,~:. ~.~ ~,~~:·,,::~~~·t~~I~,:.:{t':-'.~;:;::;J".~,.:,~ ~;~:. ':fr';, \~'~f~.~: 7~·;- .':0,_ -1"~¡f ~ Bit No.: 1 Type: Hughes MX-C1 Bit Size: 16" Jets: ~ X ~ ~ X ~ _ _ TFA: 1.0310 ~ Ii:!. ~n.~': ;-~~'<:~'::~;.""'~'~"'1ó"~:':~~~'::<'.~~'~;'.;;;';;.:o:;~:~'~,~~~:~",,"j;"~"~"'<~~o,~::: ::<~!';~~.H:.11~~;~".J I~'> ~ f"o! :f¡ Trip Depth: ft Trip Gas: Mud Cut: _ ppg CI: 18000 ppm ~ ~ Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm J ;;~ Tight Spots: to to to Feet of Fill on Bottom: ft I ~;~"":'.,Yh <;¡~~"?~~~"~p~*ij¡_~",~~'¢r~.J!'.:~~~.~~~1!í~~~.\~~*"",1;'f\'"'A~)·~~'""~'~""~!"~~"!-"~""'"'' =410 . ~ { Current Lithology: _ % SL TST _ % SST % SH ~,~ %LCM _ ,ff ~~~.~ ,.oI,r..... t' .\1 '..'. ',' .1 ,,' }}Iì'- I·.~ ' I . _~., .,"', "'....,,. ,~. ".." . '. '} }"}.;'~{' ~'.I.·~.. ~ "..(,;¡ '",~\f' .~ ._.._, !t- ,,,,~,'" 1'. ,-#.~t1'~~~~h,~~. ~.f~.t:.~t.~~ ¡~.JU~117t'.~!¡:""~~~_~~+;¡;~~_~'~Ü r".~c>~'U! .,fu(n$!..m,....,~,' ",~~ ,iI;ì ~i~ % i~ Visc ~ secs API filt ~ ml HTHP 0.0 Mud Wt at Max Gas ~ ppg PV 23 cP YI 52 Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8.5 Sd 2 Mud Wt In Mud Wt Out ppg ppg 9.00 9.00 '.= . .: . I . .' . . ~ ~ ': ,¡.: - . :"'.',: I '.. . ~ -1, .:'" , :"!( J . :" ~. .,W:.; :.-1 . r'" ... .. . ::.,-:-'~~~.:..;.'..:-t¡,;..::....~~': ......... ,'~ .......~ .:-: gpm ~ gpm,-:; fpm J: fpm ~" 740 58 9J Pump and Flow Data 88 spm DH flow 87 spm Total flow spm A V @ DP 1500 psi AV ..@ DC Pump 1 Pump 2 Pump 3 Pump Pres 1 10/29/02 1,130 1,130 Drilling Birkbeck/Dinger 24 hr Max 887 ft/hr @ 257 10 units @ 520 52 deg F @ 620 24 hr Avg 255 ft/hr ( 2 unit~ ( ( ft/hr units Deg F Current 122 1 52 R.O.P. Gas" Temp Out Mudlogger's Morning Report Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Customer: Well: Area: Lease: Rig: Job No.: spe....,....,v- sun DR I LL IN G seA v I c::: e s I I I I ¡i .~~.~'.. :~~ '6& I Logging Engineer: Reg Wilson/Mark Lindloff * 10000 units = 100% Gas In Air t~ . < ':':[":~f:!R~: r~~~: :::':! ~~'-'~;: ·:è(;-";:~:,~ ,', ::- ::\;;~:::,?;~t' i::¡~;~¡~0!: ?-~;;f:i·g~~~tí:t: :¡;;~;~¡';'~;:::.i¡'ï;I: ~;: \'i~~:/ ~~:,t:~A~:;::,i::~1f€f?f.¡!~mi~{~i~k.~gf~R;~~~~~r,¡~~~I~1~1.£¡~~;~~~~g~j'~~~::~:t :l~ '~, ': ',,~' :;::;!;.f~ 24 hr Recé Drill ahead from 1130' MD to 3260' MD. Tops: Top Permafrost @ 1195' MD, 1190' TVD, Base Permafrost @ 1586' MD, 1577' TVD, Top SV6 @3230' MD 3065' TVD. ,.., /. ~:'. :.~,·~':-'f~~-t~~.:~.í:~~ït'~.l~~¡~~$;~:.~~?Jtt,~~t:~~~~¥~~!~Æ';'~~'~~~2~~~~.i:~~:~?~:.~·~~~~~!t~~',~..~~~~{:~,~;r.:.~~t~f :·~~~~~~~\,~§~1~~~f~~t~~.~~~!~~~f1!~ir~\~·~!1~;,8*,~!:~~~;;~l~,~;'~f2~k~'~~~~t~~~·~;··,: '. ';'~ ' : : . '. 7:~ Connection Gas and Mud Cut units ppg ft_units _ppg units ppg ft _ units _ ppg units ppg ft_units _ppg ":::=~:I~Ql.T.....m1;¡;~'V1~;n;,;J. Drilling Breaks Mud Wt In 9.30 ppg Visc 75 secs API filt 9.8 ml HTHP 0.0 Mud Wt at Max Gas 9.3 ppg . > - - - -I, Mud Wt Out 9.30 ppg PV 19 cP YI 35 Ibs/100ft2 Gel:: 20 / 30 / 33 Ibs/100ft2 pH 8.9 Sd 1.25 % i; ~ -" -"0;.' '''' ". '"",.; '";;",_",_."~"""..."" ' _;,,,;,,,,~~;",,,,,",,,,,,,,,,,,,,,,,.·,.,,,,,.,,i* """""""''''''''!"''''''"'~''<''''''''''''''''=_''''' "'C'. """,.""", """""~"..,,"",,~",,, ,_.=.~ ~~~ Bit No.: 1 Type: Hughes MX-C1 Bit Size: 16" Jets: ~ X ~ ~X ~ _ _ TFA: 1.0310 I", ~E Wt On Bit: 20 RPM: 60 Hrs. On Bit: 16.3 Total Revs on Bit: 125 Footage for Bit Run 3,260 ~~l,..,,,,:,_...,,.;,,,'.'.:-'t: ~!' ". , -'," .... '~L'+. "'._J.... ~ ~., "I . _ .., .., ' _.' ,_~ .~. f w" . ~ ..,. '~,~.." ..... ,. "," f"':~^:;:----"7~=----::::~-:::::~'~ I Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm F¡ t~\ Tight Spots: to to to Feet of Fill on Bottom: ft ;n ';~I,~;;!';\?i"~~~~!~~~~~~~W~~~~~,*~~~~~,'~~_ !: Current Lithology: % SL TST % SST % SH % %LCM ..~~, - - " :Y1~~~,~~~~,~;~~i"-"""""~"""-"- oz. o " % Lithology Sst Sltst Sh Gas during after _~.äJÐ¡"R~._._." ft units ft units ft units ,~ K Hi ~: gpm ~ .~. gpm ;~ >::; fpm 1t fpm ~ ~ :,.,:!Ë 't ~~~~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: to to to to before after Drill Rate during Depth before I ft ft ft I I I Pump and Flow Data 100 spm DH flow 102 spm Total flow spm AV @ DP 2171 psi AV @ DC -rr-- Pump 1 Pump 2 Pump 3 Pump Pres 846 91 108 ~~~ ~~ ~: ~ -«: ~; t ~~ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 2 1 0/30/02 3,260 2,130 Drilling Bi rkbeck/Dinger 2011 3189 2961 24 hr Max 1014 ft/hr @ 62 units @ 72 deg F @ Current 109 6 72 24 hr Avg 281 ft/hr ( 13 unit~ ( ( ft/hr units Deg F R.O.P. Gas* Temp Out .1 ~"1.0. BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: spe....,...,y- sun CJ A I LL IN G_!§i_I§_R V I c:: E S ~" :1 , * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield / Reg Wilson to to to to Drill ahead from 3260' MD to 3426' MD. Circ sweeps and clean hole. POOH. Rig up and run 133/8" 24 hr Recé casing. ..'~.;, :,:::.~~"rµ~i:~i~':':::'i*'i:t;;Bi~2';t;';.~~~h;,i:~~iÌ~.'+;?,:'::·;::'~ '10fî~'~;f::1~::,,;'¡'?;~;f.~.iEt~~~;·:~:7:t:'E~;¡~~7t~~ffi;:~:.¡;t~~¡¡.(iè~¥if.ìn$~:,'~::~'I¡~'i'li!~~è;:t'1H~~,~~~!î:r:~!f¡~-m:~~;dì'~····:,~· :;:~:~': ~~i oz. o 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: % Lithology Sst Sltst Sh Gas during before after after Drill Rate during before Depth ft units ppg - ¡ ft units ppg i.. - ¡.. ft units ppg I~ - ;., 1Th1 ¡ ]:nll~~j!J~.I.t~:'~~ J1 Connection Gas and Mud Cut ft_units ppg ft units _ppg ft units ppg ft units _ ppg ft _ units ppg ft units _ ppg "'~:Jr~m:r1Ø_1("!JIì;~~~~mr'~·=u&:'J"¡~r"1."1.aw:!al.tr"··'""";;-~" Drilling Breaks I .; Current Lithology: % % ~'ó % %LCM i6:~-::h'f~'Ì$Zj~f1;¡'~'Ii.~~~~~4ffi~i'.Ò!:.~:f~t~~~r~·~~~'~~'t:f...W't:~~~~¡.~~-";,,It~:!I$":---':~~,.î,,"~;'~¡··í,t¡";':.t',.'t'-r-l":~~~ . Trip Depth: 3426 ft Trip Gas: Mud Cut: _ ppg CI: 17500 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm ,:~ Tight Spots: to to to Feet of Fill on Bottom: ft ! ~I~-' ~ \·:,~.'~~'fiI~tn'(&~~W~;,.:¡~~t¡'i""~~~~J~~m~;¿~~I;,;'¡.."i:,......*~~)iL~~~_l'~~~ic:¡'~~;:0I~1:?";i":"-.~j"iu¡:;·,.:1JIffi4_. ~~ ~11:~! r..'.:·', ."', " .,',"-':,: :' :¡¡: :, .: \\~ I 19.6 ~.,. .' :jr·,I~~¡"i>r..- :;,~,-t~~:I~~~ti:f,:~.¡*i~;~·~¡¡·::j.·i,· "_;:~L~¡ ~':.;-i:!J:~",,1:~~:'~#'~}it..:,,:~·;¡.!,.¡.,ry:t,,·t11"!~'j;I-i"'-:':: j,¡,,[m~ij~~~~~~!·}-~·::·'!'¡';'¿ ~'1':"!":'.\;~.,~ ."'.', '."~;:, A~' .~ ~i gpm,:~.:. 846 gpm iF - ~ ~ fpm ~ 92 fpmt~ - . '>tj ···,1·,··.····· . '. ,.l%1 Mud Wt In 9.30 ppg Visc 48 secs API tilt 9.7 ml HTHP Mud Wt at Max Gas 9.3 ppg .~ Mud Wt Out 9.30 ppg PV. 14 cP YI~ Ibs/1 00ft2 Gel,~ I 24 I _ Ibs/1 00112 pH ~ Sd . 0.5 % I ".-: _';, ': ,'.1": ':.."~.:' . '~':;'. ,1',."" '<;"' t'1,.'" '.~ .;- ,'.- .~';f'':':$.~,'' . .' .~' _,.~":-:\" .'\1, ::"-~ ~..~~., ". ..." ~. :,.'.'~:;I" ·~~.!',:~v ¡ , 'M.;,.", ..,: . ,!:''''.',~ . '$ ·:.:'<f!o:~<'.:'<:,;~"':~·.·,~:·~~~-'-I'.;·~I ,'~' :~.': . ." ,..,.... , - O':':¡i~ Jets: ~x~ ---2-X~ _ _ TFA: 1.0310 I Total Revs on Bit: 140000 Footage for Bit Run 3.426 J! Pump and Flow Data 101 spm DH flow 101 spm Total flow spm AV @ DP 2350 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 3318 3258 24 hr Max ftJhr @ units @ deg F @ '. ....J.:... .:--.... " ~I. '. ,~\:' tî; ;'i~ -m .~ '!<f{. ~n ~~ .'* .~ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 3 10/31/02 3,426 166 Run CSG & CMT BirkbeckJDinger BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 ~:~ ?±~,;~ ~ ~:i ;~' 16" Hughes MX-C1 Bit Size: 60 Hrs. On Bit: 1 34 Bit No.: , Wt On Bit: Type: RPM: 159 15 24 hr Avg 100 ft/hr ( 7 unit~ ( ( ft/hr units Deg F Current Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sper'r""V- sun D A I LL I N G S e A_V I c:: e s J j 24 hour acc!Jmulation of Steel Filings from Possum Belly Magnets: 0 oz. I Description of fillings: t .:;. ~. . ,;~,:r¡1,,~~''''~W'>¡;''~µ'''''''¡'~~1_'a-.r~·~,,*\''J!~)~~'''''''~~1:'''':'>,~:,...·~'~.:t,:.~"'\""'$Ji.~M;I>-Ktl;:!,l; '''''~;;:"'Z",;^, N¡:I"1"~,::':- ,~'·f.b;..,::N::>;-:;;'~·-\i"''''''~·II::I'1;$!\,-"."..,·,::,:,,~,-~Q~~,&·k ~..~1'þ,:t,~. ~ .\' ~. ~':'l';':;;1' ; . r . ,..""" ~¿~~;....~~ .~;'-;.f... '~'f.,!l ....~,;¡ ~ . ..~.?~:':~~' ",')';1\,. H' ~ '. ., .. .;,:;-~." I ....., ...)~ ..,,~ . .. ,~.......... .r".... . v,,~ ¡.. ,.... .... . '" ."Nn::Ç";'. 1·.".....A~M."~~·~~,'~ :r~":~.~ ..~..,. l(::~.~ ~ -...". ~ ," ... . ~ ~ . ..... 24 hr Recé Ran casing and cemented. 75 bbls excess cement returns. Clean pits. Mix new mud. ' ~ ~" I~ Ii, '"'~ '~~ Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units = 100% Gas In Air I to to to to I % Lithology Sst Sltst Sh after Gas during before after Drill Rate during before Depth Drilling Breaks .rlO" ., :-!:: m Bit No.: 2 Hycalog Type: RSX238HF+GS Bit Size: 12.25" Jets: ~X~ ~X~ _ _ TFA: 1.0900 I . Wt On Bit: na RPM: na Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 ~: 1i! il\vi~" '.,..... >,: :i\.:,;'<~\;!'.',':(¡~;;-,~h~.: ~..~'.¡:¡~.;.;.&,,(.-¡, ":'~~f'" ....:"!··,.iti~,J'!:,·",.. '::f': ",-",,>,:,.t:'·, ~'~'!1~¡-,.; ,~"o.:¡i':~(/+~i'.il~\:"...: :..<::,:~ ,.1¡;';·I"~I>'i/ .>'fl.nlt!'!" ~¡!t:",,)o~~,!:,",i",f.,~~i'\:d'!~d,,¡'·r:'jÚ;.. ~~:-.:.' ~.~""""~: f ~1'" .,'. ~" J Trip Depth: 3426 ft Trip Gas: Mud Cut: _ ppg CI: 17500 ppm '; , Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm : ~! Tight Spots: to to to Feet of Fill on Bottom: ft ~: ··1J~~."_,,"":""""'4~o..h,.....;,~¡'-;'''''''';¡ ~"""""'..:.-..-.:¡,~.-.," ·--~:I'~;,;¥¡t<1;f.·", '.' ~_.Y..-¡;'K,>r--"-.2"~IIO~" ,,,,~~,~~t:..""""".\: .,~.......: '-'MI;r~_....._.*-,- -"".~_.......~:.';:..; ".¡' ,,'<'<1>}.!O ~;':¡"''''';'''L1"~ ", . ~::~:::;:~'--'~~,...- . .... '''''·'''':~~"'""'·''·~-''-~~o''~·'·'·~'~~~~~=· '.' '~:~M' - . '. -'J;}."" "'" "m'" . ' " '" , -::-:- ""- ............ ,", ," ~ .... ' ...' ..". ,... . " '," -----:.". ..1 . .,~~~n~,,,.:~,"_~~.,, ;r-...IR].x;,;;a,,]l".UJ~Q.\'.~~~,.ø,.¡ ! Connection Gas and Mud Cut I 1 units ppg ft units _ ppg ft units _ ppg ¡ - units ppg ft units _ ppg ft units _ ppg units ppg ft units _ ppg ft units ppg "w¡t'T'r1ii!L~Ir:~~~~~t;r-·"'''-=m;;":;;,~,::.~~DIII~:n::&UJ'::·NÎI'''''''''''M ft ft ft ..; ~'~.::,¡;':~j:'...'.'.:' ~'..:~:~....", ,,' :a.~_.....:' ..~.~~:_".. ~~..·":.J1\I..·.";,:'·.1~'· ;·:-'"..¡,·.·..~i.:···'2·.'t·_ . __ 'þ..... I.·~_':.~~.·;".:.· ~. .ø,... ..-;1 . ... ~.: . ::\' J t ~~-':.'I": '.: ..: _..¡o t. ..... . .. ... ... ~ ~ ~ . .ff;"::'" :.'" : ~. .... . I" "__ '.. ppg o Mud Wt at Max Gas Ibs/100ft2 pH 9.0 Sd --- '. () o HTHP 6 / 8 / 8.5 ml Gel~ 55 secs API filt 13 cP VI 16 Ibs/100ft2 Visc PV ppg ppg 8.60 8.60 Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data ftJhr ftJhr ( ftJhr @ ) Pump 1 spm DH flow gpm - units unit~ ( units @ ) Pump 2 spm Total flow gpm - Deg F ( deg F @ ) Pump 3 spm A V @ DP - fpm Pump Pres psi A V @ DC fpm : ;'./ ; }.~ : ;,:j"" ..~:~~';~~ :::~I~~;' ~,;~,*~"':'¡:'1 :}~~~'~',~~ ';";""~;':'f ,,~~,~,:;,~.~ ,~'\';; . ¡ , " :"~.: ~:'~ ,~,::.;.~:'~"<)~, ~·,...';¥~~:R~~~1-;:J\~'~~'i.Y ,~~,~'!:;':,,~'':' :-::.. ~L~': ',:,: ~,. <ii;.~ j~~.~" ~,.; ~. ' . 4 11/1/02 3,426 o Test BOPs BirkbeckJDinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report --- - t:! A! L...L...! N G 5 e A v I c:: e 5 spe""'r'v-sun :r!~j1;ifi$~~~~~\~~~~b~~~~_~~r~~."~ffi'~ft%~~~ l' 24 hour accumulation of Steel Filings from Possum Belly Magnets:' . .. 0 . oz. I Description of fillings: '~~ :::.: . '';¡:;':'¡.: h~p~.;&:::it\~~.~~·'~?'$':~~~:;·l£<'~~A¡~·,"'~!i\h:,):',:,,,::~~~A~;;'::.N~!~.y~~~~.;ft~·,g~J~~iit~1:f~*¡0;{:&.1i.:'i;·;;,~~·~;: !:;:~;·~:':·~(\i~~'¡::~;%G1:'jj'~~·~'~·;';~'::¡¿'~:;~~kØ?ì)l.;:·!.r-:;f:-{g~·¡;~0;·~i;!~~:;:ï;'¿~~;·,;::;,¡:':·<n~,;~~,: ;'~;: . ": -:-:: ~,~ 24 hr Recé Teste'd BOPs. Ran in hole. T~~ted casing. Drilied cement, shoe, and 20' new formation. Swapped ,I out mud system. Ran FIT to 12.5 ppg. Dnlllng ahead @ 4476'. '¿~ 'w t~ Tops: SV5 @ 3582' MD, 3343' TVD; SV4 3983' MD, 3652' TVD; SV2 4537' MD, 4059' TVD I I Logging Engineer: Tom Mansfield I Reg Wilson * 10000 units = 100% Gas In Air ¡~ . ": .,'. ,":. ~ ::t",. .: ''''''. .... ~-: -:-' 1.·· .. ~ ' . . -: 7..1 .,: . I '~. , . .... ~...: ø . '. . '. '"'~""~:. 'C ~t.: ,';":.. -',1 l' . J.~ . ~ '. I ~'''''' ..~. ~ '. '".~ ~ ':-'. . ~ !.; . \ :' -. :. .', ......: "., - ~: .' ~ . .. . : ." '. . ," Bit No,: 2 Hycalog Type: RSX238HF-IGS Bit Size: 12,25" Jets: _~_..x ~ ~ X ~ _ _ TF A: 1 ,0900 I " Wt On Bit: 12 RPM: 120 Hrs. On Bit: 4.8 Total Revs on Bit: 64100 Footage for Bit Run 1.050 ~. ,. .', '., . ',' ,.' ;";''''~!;.:;¡!>;:+s:r4>:~,.,''':~'':''~;.t',:.,'¡',.~.._,; "': ,'-i··"..--.··'!d~,.~:.O;;,:":·,,~.~;..,:,~.:r:', :;'';'~<ÍijI.it1'''~:..¡·,..,~.~1'':'I'''''~i";1t!7>'·:':·''~,;': ".:"',·.,··",',::'·_,.:i·,:;~,~¥,,\·,·'Pi:i,:,.,· ..;.~;.",,;. 0', :', '.',...~..: '~', -.,." "". ; ,:;n'J:.ij,"',. Trip Depth: ft Trip Gas: Mud Cut: ppg CI: ppm " Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm i'·; Tight Spots: to to to Feet of Fill on Bottom: ft ..' ::.(~,:,:. .' ·¡;~.'.:<ii~i\Ÿ;¡'\lt~~~~~1tt!¡~~~'~;~:";I~r;l..;.~~j;., ¡'~·'~'·f\'¥,~.:~~'~?o.(..~t~J~';~"ïf-~··>;'~;('t¡;:'~¡i:.~~;;,~:':';~;~-:';Ht;j_~~'1i,"":)~:";:~\: ''.',':7; ~'>~', ;".,' ¡.i-"\~' ;},"':;~';::";'" · :"~'(1iI',: 1'1 Ii' ~.~ Current Lithology: ~/O ~o ~,'o o~ %LCM ~; !',: - - -~ ,,,,:!:~\,",,,,ftlM{H·~,~~~~~~~~~~~í~~~~·:;'~~~~:h,~~¡::':,~>iiI.i2';'¿'Ø.t-~~·~~...,j¡':'¡r'!M :···.,;.;.;.1L·.,'!t~i'~.:·t. .t·j.h:,.·.-··;·~i¿ q Connection Gas and Mud Cut ç 1 ft units ppg ft _ units _ ppg ft _ units _ ppg ~ ~ ft units ppg ft _ units _ ppg ft _ units _ ppg b ì ~~~4n~==~JIJ¡UIIIUIII]~~~~~~ ì ¡ Drilling Breaks ~.., Gas during % Lithology Sst Sltst Sh before after after ~~. ! ! o Q Mud Wt at Max Gas Ibs. 100tt2 pH 9.0 Sd --- to to to to Drill Rate during before Depth I I Visc PV ppg ppg Mud Wt In Mud Wi Out ppg o HTHP 6 I 8 I 8.5 ml Gel~ 44 secs API filt 13 cP YI 16 Ibs/100ft2 ":"1.. '.' gpm gpm fpm fpm Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 123 spm DH flow 123 spm Total flow spm AV @ DP 2075 psi AV @ DC 4778 4674 24 hr Max ft/hr @ units @ deg F @ 1040 :. .", .:.. .~: .' .::ot ," .. 5 11/2/02 4,4 76 1,050 Drilling Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 8.80 8.80 572 191 24 hr Avg 219 ft/hr ( 52 unit~ ( ( ft/hr units Deg F Current 177 58 R.O.P. Gas* Temp Out Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report ----.-----.---- spe....,....,v- sun DRI L L I N G 5 e A v I c:: e 5 :":i'~5:\~~"~:ê~~~r1t').~f.~. .~~~¡'ií81&;~t:.?:,,!-;;~:'",:·::i,!'1~;;.;~m:f,¡~~~~~~!ii.f..W~,¡,\!tM~,m;~~·~~~;;;~~'~;~i:i~'~·~f;:1¡~1Ft.6\!;¡;;~~,:'2~~jm:~·,4:~~~~~,<'i'.'ê1·f~'::!;:{~~'i; ~,t;'~,:¡:¡;::;~;J, .?7~i;;1 ~ ;~·-:":·':3t'I·'¡"'~':.'. 24 hr Rec, Drilled ahead from 4476' md to 7056' md.· <. Note: No gas readings from 6845'-7200' MD. As per company man. 4: Tops: SV1 @ 5096' MD, 4452' TVD; UGNU 5573' MD, 4807' TVD .~ .~ * ~r Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units == 100% Gas In Air ~~ . ,,'~: . ::~}itW~;:':~i:};'~:~l~t¡:i¡::;~~~':~2:¡' :;;i2i';::;7':'~~~: ;~:,~~.:i.)~:.: ;~;:,:.~~~~:: >:~Y~:0:~:'¡:':~~¡:~~¡~!¡lif~~§:(i'-:,~~~:~;::: ;,i;,; i;¡z;~ :~~:~·;F,;;r~~~i-ffl1~,~~~::~g:';,f~~~E~;"f ;:~·~\~~~f4l;Y~~::::; :¡~, '.: ; - oz. o 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: -' ::: )':::.! ":~'f,;,~'~~:~~Fl~~~~~*::"'~J;~;1,:~~~ft¡*~r:~jl/;';;~W~:!ii~.:~~_i{_~~~~t~t!l,i>:~I.~~¡,{~;:;{~~¡~:~:hi;:~~,-,!j:~ ./j; ;~U:~'~~~.~b7:qit~it~1~: :,:~í:~~~)i;f~;;~t· :..;t4(::i;.:;éj.~ Connection Gas and Mud Cut ft units ppg ft _ units _ ppg ft _ units ppg '.., ~ ft units ppg . ft units _ ppg ft _ units PP~i ~ ft units ppg ft units ppg ft units . ppg ¡ -~:=~«:J:r~1~'.·aI"î'~~n:,:.wÐW[:BDJ'~¡;;J:ij::J~',&=....,,-;,a;~;__l&1~Hff:¡j':1111~lj~µjw);Ì[,,~'" ~. ! 1 ~ Drilling Breaks ·1 ;! Drill Rate Gas % Lithology ,~ before during after before during after Sst Sltst Sh ~¡~ "11i. ;¡jìì\ Trip Depth: ~~~~ \1 Short Trip Depth /' I ïight Spots: ~~t~~....J'·;''',4:.~.~~~~~~~1'!i~*'~';'~~P-!'~~~I,f~~''~'~'":O<~}:~'~:'~1'\?1~~I~I~,~,1Jlt.\;!t1~;¡~;'~: """"¡,,,;~,,,~;,.<~,~,,,,,;¡,;.:.:.f'~'¡ '",-_1I'i, h Current Lithology: % _ ~ Ó % % %LCM _ ,\·.·~'~'·'r!f,··,,'~r.':'~~~_¡;¡~..!f""~¡I',Ht~::,~),\~,;~~~~~~;'~,,~~~~,:¥ì';~.~<·~>¡~.¡~\.(:~~~~'~::~i.i'~!'~· :~?'·,~io~!¡!~,. ppm ppm ft ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: Depth ·r, ~~ -'. to .., to to .;,' to Mud Cut: Mud Cut: to to to Trip Gas: Short Trip Gas: ft ft '. .:.~':. "I!~~ ~,~1~.:;;:r·-cik,,-à~·"~~t'~.~.~"'~:i~..--=- : .,.j.: :-:. .~ i:-,I,' ~..:.:;,. \~: _/.(;..~::~ ·:<~it-·.~;.....~~~:'~~4~''~'K~3~·''~.r~-:it.:~··\~''·101·/·''~~ ..:;:.~ ø" ·~~-·~~1~· ....:'~) 'f:,~~h::"~ri~' ~s <.... . .~..I ~·.·~~·~1·~f~.....~.~ .~-4:~. .J4-'~~.; .~.~~ ~,I:. . :., ...~. .~.~~ I . '..c.:'.' . '0. '''.',,' ;'''c:.\,;;:;o':·,:.r1'-7~,-;'"-: ;":;';,.' ,,',:, :,:H~" ~.~ :.:: þ,,~i~,': ',<,,:.'~i;;' ,'~: "". ;:,>;1'::' :¡ ':',. ',: ;.:' ,,':, I':",; ·~·"I.1Û:n:"";:"':':;'1~: e:'<::k':::1',..~~ri{.",,~,)~,~¡;.~~'1~'¡,", ;:,;,:~:,"; ~i::" ; .¡",..~,.;~,¡-.:.:;,~,:' :-~:,~::"",.';~"'.' :':',,'" I,. :. ¡;: . ',"'" '. ':,i¿i Bit No.: 2 Hyealog Type: RSX238HF+GS Bit Size: 12.25" Jets: ~ X ~ ~ X ~ _ _ TFA: 1.0900 J Wt On Bit: 22 RPM: 77 Hrs. On Bit: 25.3 Total Revs on Bit: 24500 Footage for Bit Run 3.651 ~ :ij ~.~ ¡!~ ~~ Jf ~: ::~ ;~: ,:::~ ~~ gp~ }¥ gpr:1 .;t fpm~ fpm i .. ppg 0.5 % 4.9 ml HTHP Mud Wt at Max Gas - - Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8.3 Sd Vise - ,..... ....... 1056 Pump and Flow Data 126 spm DH flow 124 spm Total flow spm AV @ DP 2551 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 54 sees API filt 14 cP YI 29 Ibs/100ft2 ppg ppg 9.00 9.00 Mud Wt In Mud Wt Out PV .. - 24 hr Max fVhr @ 4778 units @ 6600 deg F @ 24 hr Avg 107 fVhr ( 93 unit~ ( ( fVhr units Deg F Current 22 Gas" 73 Temp Out 595 664 Mudlogger's Morning Report 6 11/3/02 7,056 2,580 Drilling Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Customer: Well: Area: Lease: Rig: Job No.: sper'r'v-sun -- -- -D A I LL IN G 5 e A v I c:: e 5 :~ ,'; :~, ~'~:.J';: !;(~!¡f'~~~}J~,~~<~"i~~~~:~Jt~t~~~~~~ i~¡:"..;;;:';~';~~:}\j¡Y:~f~~~;~'~rf~( i' ~~~~.¡:~ff~~'!r~:~ ¡;~:;~~f¡,~::~~r:::~ >7:,t~~s~~~'i_~~~~i~'..r:·7; ;:~;ß~?': ~.~ !;:. :~:; r;~:i:' i: 1':' :: ~.;;-:::'i~ 24 hour accum~lation 0; ~teel ~iIi'ngS from Possum Belly Mag~ets: ' '0' oz. I Description of fillings: ,~ ~~ " '..'. :'.:f:";~;j:~,'~ :: ",~< ;:',. ;;¡''I''¡'~$~;:~-'; ';;(!'\';o'\N1:4Sif:;¡~~~~V~::;~o¿~ô;~~~'.:~'~,' ~:¡':':~~~~'~;5~:'"H:~~::''':~::~:''~E!'~::, ì~:'::¡'\'!<;',:~·!\;~ø;.:]~':'0~.i\¡~~¡~~·":~':~ ''':~'''~~M.:':~f':Í'::k: '.: li:::t ',~~,~:,:;:.:..,~:~, >,:.::: :,::~ >":':¡'":;:.;:: ';~:':'~.').' 24 hr Recí Drilled ahead from 7056' MD to 9023' MD. ~I: '~<¿¡, ~¡ ··ti Tops: SCHRADER BLUFF @ 7669' MD, 6388' TVD; COLVILLE @ 8227' MD. 6800' TVD .~ i;:. '~~ ~~" Logging Engineer: Tom Mansfield / Reg Wilson * 1 0000 units = 1 00% Gas In Air .~ '., : .::. ','- :>:;',:,<: :k::.t;:;~:¡;;~A:,:::·,~::>k¡~C;~~; ;;:.:::;::'··~:i;:::;;,·':';i~~:.:?:.~;;:r.~~:'.~:;~~~\;:;;:{:Ji:::~;::"Y:' g:~: :i.~,::!·' ::;<,:~,\:.;;·~!(~:gt·~~~~~f<~~~~;·&~~i:::;:;:~::.; ;i~~;E';':: . ~':,: ';:,.' .,. ~~~ % Lithology Sst Sltst Sh Gas during after before after to to to to Drill Rate during before Depth Drilling Breaks Connection Gas and Mud Cut ft units ppg ft units -ppg ft units -ppg - tI ft units ppg ft units -ppg ft units -ppg - ft units ppg tt units -ppg ft units ppg '.;' Current Lithology: ~l~ _ % % ~,,~ ~~LCM _ ~ J¿:\:. !"~" ·~,"rI-i'~'~:oi'.II~~.:~~~~:~~,!,rrt~~,!'ih:·-?·'-:!¡~',~·'.'-~~í:>;h ~:",ít'\~·"'4W:'''rif.;tì~i~.ffi~'~~~t.-:':<:~~~iJl~~'¡:¡'¡~~~~,~...~~r..¡.~,,",,'!!:'~:.' '.' ··'~,fr,·:'¡,·· ~r'i·\ ""~'ø¡¡' ppm ppm ft Mud Cut: _ ppg CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ....~:Jt:;:(::.. ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: I .. .. .:~ .:;'''''''~...~''~ "~.1·1."~"i~,,:~:"~~.~:~,\~:"~_: ~~ ···.~~~.::,.I~·_· ~:---:"....:"'~:.':__ .:...;~ ~'~' ,'":.'''l'' ~:':"'.",,:' t. ·,:fiv"':.':':~.~.·~'I~·-:~",,;)!~:1;~:::··~~··~\~:-:;~~·.···.:~;:.!...;"~~,,~; ,: ~ ·'·~,:.···~h'~~~·~~'~~"'·¡)'JI~~..H..:.t;~~....s .', .~~. ~.~ ."l :",,¡ .' 1 .0900 5.618 Jets: 4 X 12 5 X 13 TFA: ------ Total Revs on Bit: 557500 Footage for Bit Run 12.25" 40.2 RSX238HF+GS Bit Size: 155 Hrs. On Bit: Bit No.: 2 Hycalog Type: Wt On BIt: 18 RPM: . .' .' ~; . "> 'i., ' ,.'.~'. '.:' ~':·'~'.~;0.\"'~,·~ ~~: :~.; ~~~ ~....'" ,*,;':-~~'.;':- ~~:.:~ 'A :.::, ~~-tY'.:'..· ; ~ ':':, :....."~ .¡~'..; ',~~' ~';'..I '~:;~: ;: :. '""':_,r...¡: ~.~ ~~ ... jl-," :":"'~~ ,~;,~:.~;: '-~,' .P~It.. ~:";:~:.';.¡';'~~"'~ ~,,:; ;:~ .-.:~::"..;:;;, ~ ~~,~.. . ::..;.;~:;;::. . ..:~;1:·:~~'¡,~':"'~::~;' .(....;.~. ~...~: ...~;:-,,'", ~'~~ ....;":', ~. ,.. '~' .; " " . r .. .... '.... ppg 0.5 % 6.0 ml HTHP Mud Wt at Max Gas Gel~-2- / ~ / ~ Ibs/1 00ft2 pH 8.3 Sd Visc 52 secs API filt PV 13 cP YI 24 Ibs/100ft2 ppg ppg Mud Wt In Mud Wt Out 9.20 9.20 gpm gpm fpm fpm Pump and Flow Data 123 spm DH flow 123 spm Total flow spm A V @ DP 3200 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 1040 163 265 7 11/4/02 9,023 1,967 Drilling Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 8356 8400 24 hr Max ft/hr @ units @ deg F @ 350 439 24 hr Avg 132 ft/hr ( 175 unit~ ( ( ft/hr units Deg F R.O.P. BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 , Gas* Temp Out Current 204 194 I Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report ----------.-..--- spe....,r'V- sun DRILLING seRVIc:es , ..~ ",p, I .,~~ :~ ';1 ~~ ~t * 10000 units = 100% Gas In Airt~ ~;F Connection Gas and Mud Cut Þi ft units _ ppg ft units _ ppg ~ ft units _ ppg ft units _ ppg ~ ft units ppg ft units ppg i ~ ·~__~I'In.YllIJ11õa1~¡~~ Drilling Breaks j.t Drill Rate Gas % Lithology ~ during after before during after Sst Sits! Sh I t w : '.,;,:.:,:'::: ,;,~-;,;~t~,;~i:i't:,~f/~jJl~:~~r,~~~j~1J~~R{:f:ª\;:,¡~tr;:!'¡¡~·èt~~~;~~TI:'fZ:!i:~;~~:~·; :~:·:':;~f:.:~':::¿ :i:~l:1~'~¡;, å~~:' ;FWã~¡:~~~_!.$Jf~F~{~~:P¡\f~·: :";S;:~~. ;~'(,': ::.' f'::;:':' ~:{t 24 h~ur a~~um~latio~ ~f ~~~'el ~il;ng~' fr~m possu~' Belly ~agn~ts: ,. . . 0' . - , . '-"'o~. " , I. Description of fillings: . Logging Engineer: Tom Mansfield / Reg Wilson Tops: COLVILLE @ 8227' MD, 6800' TVD; HRZ @ 10546' MD, 8606' TVD; BASE HRZ @ 10987' MD, 8931' TVD; KUPARUK @ 10998' MD, 8939' TVD Drilled ahead from 9023' MD to 11227' MD. Drilling hard spot. 24 hr Rec¿ .. ,.' . ":.;. ;:~: :~,.. ~';':'''''>~~''./'.'~;:":': 1 ",.... . .""'.~.. ;" '~~ ~,~;:I" :.: >.. í"oJ·,'r'.~.· ,::.,0:: .J..·,;'rr"'··.;.:. ·:,.·.;"f..:~~~:-~·:'4·A:/,~:'_....:; .:............ .:.~~ ",'; .;:,~r:,': :~;: ',t ':,. to to to to before Depth ppg ppg ppg units units units ft ft ft ~,';.....",~~~,!,-!,.~·.~~t~?J1.t~'j1;¡~'~.'¡I:.~~~i,~.~.~,':t'"rit-.~>i·,.."~iti'.~-.$,,~'_rJo1ill~>;-:!':f.-'.~,.¡¡~~:rt¡,¡.w}~ç;,~\;.'-,., '¡'¡;!·:"'~~,~::e'f,~t·: .Ii~'·{ :": (:':," ':," ....·}'i:'t1~.,..,' I O~LCM Current Lithology: 01 .0 O. ,'0 01 /0 ~/~ .:..;~ ;';¡¡,:i:'~.,~·.:.. {.;., ~~Ii;';;\~~~~~~¡.tr.~~~,T~~:-',~~~,:-¡.t~.. o;,t~I':M 1,~~~~I.....\~:;·t,:.~}I!~'~:'~~,*~~ ~"~1j~;1.~::'''1'/.'~\''1,~~t.;~~~I[IJl.~;~1~.:?ì,:-I'.+'~~¡\o;<~·¡: "'~ ~;,1;';' .;' \ ¡'4t.1c. , i':j", '_. Bit No.: 2 Hycalog Type: RSX238HF+GS Bit Size: 12.25" Jets: ~ X ~ ~ X ~ _ _ TFA: 1.0900 Wt On BIt: 10 RPM: 80 Hrs. On Bit: 57.7 Total Revs on Bit: 82A.Krevs Footage for Bit Run 7.822 :. :1' :.,. ' '. .:. ...,' ...: ..:,... I,if: ~~,,:-,.'.~~..~.."."~~ jj.!e·.:~' ~~.: ....·'=-.,.~~;,~1.;¡if~i7~i'·~.: ~ .':' :-:".:: ........~:....:....'. .' .. .P.~~.~~ :.'¿'~.;:~..:. '. '~~,'~.:".::. ::('.!~T::: ."\II'·~./~:~:' ~..,,::~;:L...: .~. !~~"'''~f'~:-';-'~''~'~~~'~'~':~''~f .: ,..~ ':.. ,,~~-~.' : >-.' ": ~:'... .: ~ '/' ..~:. J1ï'¡, ppm ,,'. ppm ,,: ft ~: ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: Trip Depth: Short Trip Depth Tight Spots: Mud Cut: Mud Cut: to to to Trip Gas: Short Trip Gas: ft ft --- -ppg Sd 0.5 % 6.0 ml HTHP Mud Wt at Max Gas Gel~ 7 / 12 / 15 Ibs/100ft2 pH 8.3 Mud Wt In Mud Wt Out 10.20 ppg 10.20 ppg Visc 52 secs API filt PV 13 cP YI 24 Ibs/1 00ft2 :: , ~<::,;-.I;,·~"';,_:._·~: ~_..,_..'.~. :.~..;~.:' : ~., 1r. ' ~ . .. . . I . 1040 163 265 Pump and Flow Data 123 spm DH flow 123 spm Total flow spm A V @ DP 3200 psi AV @ DC Current 1 286 Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ftIh r @ units @ deg F @ 24 hr Avg 126 ftIhr ( 388 unit~ ( ( ftIhr units Deg F R.O.P. Gas* Temp Out 10135 9437 374 1721 8 11/5/02 11 ,227 2,204 Drilling Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: spe.....,r"V- sun D A I LL IN G 5 e A v I c:: e 5 Mudlogger's Morning Report BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Customer: Well: Area: Lease: Rig: Job No.: Connection Gas and Mud Cut . \'11 ppg ft _ units _ ppg ft _ units _ ppg ~ ppg ft _ units _ ppg ft _ units ppg ~ ppg ft _ units _ ppg ft _ units _ ppg . 1 -h1 'tm~i.R~t~;ì"<·Y ]m¡~"J~'Jl·"-ft¡r·'·Ifr'"·""--""'"·H')fJì:;~!rI·ArIII·Wf·"W1~11~¡ llli·I!ft~~JI!l!!.ümlllm~ "E_tli~ll~~ t ~ Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh 11313' to 11456 150 280 55 400 1016 350 50 30 20 --- ~ ~ : ====1 ..' . ,·~:t\"tO'·' '=":'<'-""1'11.2 11:0:' .¡..~; " . ,. ..¡...¡¡¡,.:\'...."../... "-'::1':,' ')~lo!k':::J1~-'"'" '·:1:.,~···r-·· ~.', . '.u: ,,,....,,'%:.,,.,.~~\.....~nr:l;.;.:."~..... ~ .~.. ·~:Jt.,t·" . -- :'r~. ··~.L~ttf. ':;~~;··~;'fl~;¡'t.~?~1':J4~~~f~"·:? I: ~_ f \'t$' .!~~..i~ ¥~~ r: ï;:;~~'-;=:-\;.{'¡¡ ~')'~~t;.:~.\, ~r./{~:r~:~ I' "."n~·.!(~~,·:;:' 1..·./~;1: '.~:~ ~.t¡'~I~;ff~.r~~~'~~\5-S:~:!~·'¡,I~~; r~~:,1~..1.~ :~:':~~" .,~' :-- '",' :".: ~': . ,,;:-. .. . ;,")",: . 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. ~ ì Description of fillings: : : . :';<" ' .. ,; . ').~, w~ \.,: .;:;.,:. ;i';:1;.~~i:?':::·:; ,¡;': ':""~'?: t,-t:>,:. ~;.~;;: ,;,,~.'~ ,.': : ,.:.¿, :'!",~~ ~í.·; ;).~'?-;;~?:~~:; ;i:¡~.1F"~~;·S ;.\~, :.' '~1:;\:~ :y,,7~~iii':':;C,~::rj~;~,:~k>'¡'''fW.*¡~~~<;~~6'W! /:fÎfÞ¡'ii"'B-i~ë¢';;';~¡~ ¡:): :,,-: ': ~:~;: .~ :.:-:~,; :~ :-:;:';:. :,' ' : ~, . ',; . "".. . ,.:. ;~~ 24 hr Recé Drilled ahead from 11227' MD to 11778' MD, T.D. for 9 5/8" casing. ' '_ ,ii, J ~i ~.' Tops: KUPARUK @ 10998' MD, 8939' TVD; KUPARUK C @ 11313' MD, 9160' TVD ,t~ ~r. ~~ Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units = 100% Gas In Air ~¡ units units units ft ft ft [ % SLTST ;~:::,; ..ri!~'·~¡~.q~~~~:J~i:" :·,'·~~~~¿·~i'.;'¡~¡.~~~ii~d4~~'1-I:'¡~·:·!t·~;,,;,},,'H~~I#~iM~'~¡;iÌ;\".:I"~"'~¡?;ì1;'¢1¡;",~""'wii'* ,.:', .,;:;!.~'¡"...~ 20 % CLYST 70 ~!~ O'~LCM 01 .-0 10 SH Current Lithology: "':~':", ~.rmH,:~~i?~I~i~~.~;~·i'f~~¡~'~1"";~·';'; '~'" :~:{;¡,,! .,. ~;:¡}¡i:~~I;,;¡,p;.I__.,:';,;~:i~~~1~¡"~9~4:i'i·¡·:' :;'1"¡ r:. ':i'\i .¡·r:t.Q>'<'I!'r~~NI~,~~···:!d:'r _'II'f; ,;",\~~ ,·;;,:<j-:'II1~.;:'~:t, ,;....¡.. ':: . ';';"~: ppm ppm ft ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to Trip Depth: Short Trip Depth Tight Spots: to to Trip Gas: Short Trip Gas: 11 778 ft ft , . '. .' : - I' .:>¡.....~..at.....~~, 'r~:~ .":"".' ". ~,.. j!¥.II~':. '.. ~ 'I' ~~,...:.~~ tt"'~' ~..; ~ S :' .":'S*·~~~~.t~··";I.; ~ ,... ~.( - ,~. ~''':~~~~.: :".~:' ·~:",!~:$}~J'~~.~Ii.:H~,:~~: ~;". ~'.;~ . t:~.·· ~::. '.:: ~... ':. :;."...:.. .;- ¡'~. '.' .- ;·~~'.:I·.·;r·?·~~~~·".t-"",":,~~,~'n'."'go~-'" ;~)I.~.... I , '::. .~:., .:.; ;~; ~.. .~ .'".':":;';", .', : .'; :"',,,;;, ::. ,"~,,:r ': t:"f'..;-:~"·!"':.: ,; ;'.;',,' .:;..'~'~>~~~~ ,1~:.,. :~;.1":;: ;:::,'''{~~;¡-;;';;\;~: ~~,.~:,:,:\::J-:~"~'1;:'t;,',~, ',; ,;;'~." n~,:,;:',', ::.:,,' :; :'.", ,,: '," "',:,, ,"': ;~'.:::,',;¡.' ,. .,:~ RSX238HF+GS Bit Size: 12.25" Jets: ~ X ~ ~ X ~ _ _ TFA: 1.09001 140 Hrs. On Bit: 65.3 Total Revs on Bit: 928KREVS Footage for Bit Run 8.373 * Bit No.: 2 Hycalog Type: Wt On Bit: 25 RPM: . :' - ..'".~:..:"~~., ~.~':~:-)iY.~~~:t:~:' ':;~,~~;"".-~' r 4.5_ml HTHP 10.0 Mud Wt at Max Gas ~ppg Gels~ / ~ / ~ Ibs/1 00ft2 pH 8.8 Sd 0.25 % .là1 gpm ¡~ gpmt~ fpm .~ fpm ~1 ~ :.~) .. ~ "I . '-;;':'1 w .. ~ . .: . r·: ~. r. . Pump and Flow Data 112 spm DH flow 112 spm Total flow spm AV @ DP 2950 psi AV @ DC ........--- Pump 1 Pump 2 Pump 3 Pump Pres 947 148 241 . 'ii ,~;~.~ :....,: ... .~. - ~~._'':' -.,' - .;.:,. '~',f .:~:....~. .~,"':",..'.":.~ \. i:l ~. Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: '4i ... ~,~! ;'~,1 9 11 /6/02 11,778 551 Drilling Polya / Dinger 44 secs API filt 12 cP YI 25 Ibs/100ft2 10,30 ppg 10.30 ppg Visc PV Mud Wt In Mud Wt Out 11380 11318 11 778 24 hr Max ft'hr @ units @ deg F @ 315 1016 115 ft/hr units Deg F 24 hr Avg 73 ft/hr ( 350 unit~ ( ( R.O.P. Gas* Temp Out Current NA NA 115 BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: ----.-..---.--, 5pe....,....,v- sun D A I LL IN G 5 E A V I c: E 5 1" :.~~~" ~ .:~. ;."~ "··.:;S,:';·,~':)~!i~~:// m :,:::.,: ··.·:;:1 ;+·~j.¡'l.<s:~~::.f¡~t;J~;t'Îff!;Ï:!!;&~~{~J~:~f;·):~~t,:}~W:~'!~;?~~ :r:{~; :qn~~5~::'~'~O~"~~~r~:{~'.~·~~¡ ??¡~f~:~j)f:;~~'i'.~~~~~!tf.'~~1;§¥f~~~e;) ::(~,~;~~f.:;)~~\P;,7:~·i';: ¡ :~'¡;~lì:;f...:..,' :,;.:. 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz.:1 Description of fillings: ~. - ' ".. ',,' ::......'.;..~ :.~; :';;:,:<.l'::!'I:_ ~,':,;~X~~~,~' ~':~;':'::,~~~".h::i:';~~~~,,~ ~~,',:<:;,,~;~~.,~~~,j,~~;',:~~,;,~,~~~ ~~~ ~":¡~r#'.;~: ',\,: ~».~&,··;ti¡~~~~~~~ ~~ ~;~"~-i-n'~·~~· ~'; (,.~':·I ~I;t:~'tt~.~',~~.~?~~~:.;:~,j?:;~~~,~~,:,,;'~ 1i\f:,",~~~j:fr,(T~V: t';,::',1'';;t;_~,.,~,~.~,~,', "..;.~~~~~t~,;~~~.,:~4~~t~.t:';:~.J, ~......~.< ,'. ~~..,,~ ::~ ~"~'~~$" 24 hr 'R~Cí'" POOH' ~~'~t ~ell,'~ith"'n~ ~ig'ht ~p~t~: 'ë<u~~~'~tl~' r~'nni'~g'9 '5/~; '~-;'~i~~'~" . .. m ..v·..T...··'·,'.. .' ..'.., '" ,,,, """ ". " .' .~ ~l ~~~ w ~i .~ *'!I'iÞ~ * 10000 units = 100% Gas In Air Ìt '~", % Lithology Sst Sltst Sh Logging Engineer: Tom Mansfield 1 Reg Wilson to to to to atter Gas during Depth Drill Rate during after before before '" Drilling Breaks ppg ppg ppg units units units tt tt tt Connection Gas and Mud Cut tt units ppg tt _ units _ ppg tt units ppg tt _ units _ ppg tt units ppg tt _ units _ ppg "]:t:m;:::"flf~;JJ~;·;;n"::DJ:J~~~MII~m.\.l\1m~~;J: I f1o/. :'," .I-:··'·".-t~f·",~IO!,.~:;';:;~'~;·£III'þ~',,~ ,:,:r,'o;;.."C'" .:¡ ':. ';': ",..:\,;' ·'';!'~~!i:X:·.!-'¡;'' :,~;¡'¡;,~¡:..~, .J.f7f:t¡:~~~JJ~t;~h'·';:;::i·,~;A·f·:;;; '~"'~'·::;I;.:.·..,~;:;:..";.;:~o;,~,~~",;;~',~"",, " ;.' .:;:;;.'r:;~:~;~¡:·';;:::¡~·1"··;""''''·::;:·;~':~ .. . ¡ ;:l: Current Lithology: % % % % %LCM f '3' - -} ~~}<.·,,¿f¡~M~~~~"HSl~~t~f~~Mi1.~:"1:>:r·t.,\~~'Bi.~~*-~~~_! I Bit No.: 2 Hycalog Type: RSX238HF+GS Bit Size: 12.25" Jets: ~ X ~ ~ X ~ _ _ TFA: 1.0900 ::." Wt On Bit: 25 RPM: 140 Hrs. On Bit: 65.3 Total Revs on Bit: 928KREVS Footage for Bit Run 8,373 ;~~:,.~;".,~¿..:, ,,:·~··):*.·...~~Y,j:;*JI*}~~<~~¥~*~'~(-fffi~~~.'iifi!*:;;:j;(~i~'~:t,'1;~'!i~:;:,{.m:~:i~·~~~;.~.~~h~~~~;~*:~.~·&'~'~i!i!·f:"~if~'~~~·:1:,~~~\r;.~!!':":~' iii!ì Trip Depth: 11778 tt Trip Gas: Mud Cut: ppg CI: ~I' Short Trip Depth tt Short Trip Gas: Mud Cut: ppg Short Trip CI: Tight Spots: to to to Feet of Fill on Bottom: I ~ ;: '... .': ~ '.;:; "~~"'i'~.)'~ :,.:.~, ~!,~.!!;:t ~::~',,::-:'~; '.~ :,. ~,~ . J',',:.~,,:. ~'~ ;'-~~:~~'~ ~~, ,~~·:..t:~'~·'.i;,'·:.: ":,~,::~. " \'..".¡~(,: -':~ :':~-.'\..;..:-:~'",;, I : ::..-~ .~~, 1 !.;:-.:tr,,""~. ~-' : -: ~ ~ ...;--' ':, ~:~..:-o/.jrr,~~,~; :'.':"~. ~ ~..--: ·It"-;·;,:'~"~ ,~~it: ': r~.,~:~~ ~~'.:':-~~'~:';)'.' ~:,~.!, ~ . ... ~-: ~.' ~". ho"'~: :Y:~':':~':"~ ~.:;~ ~--:~.: .:- ,·7~~."'; ~~... I:': . ~ :",- :: 49 secs API filt 14 cP YI 28 Ibs/1 00ft2 10.50 ppg 10.50 ppg 4.6_ml HTHP ~ Mud Wtat Max Gas _ppg Gel~~ 1 ~I ~lbs/100ft2 pH 8.0 Sd 0.25 ~'o Visc PV Mud Wt In Mud Wt Out Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC 10 11/7/02 11,778 o Run 9 5/8" CSG Kidd / Dinger Pump 1 Pump 2 Pump 3 Pump Pres ftIhr units Deg F 24 hr Max ftIhr @ units @ deg F @ 24 hr Avg ftIhr ( unit~ ( ( R.O.P. Gas* Temp Out I Current Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Customer: Well: Area: Lease: Rig: Job No.: ----- spe.........,v- sun Õ-ÃILLI N G SEAVlc:es ..~ .", ," "'Y'-~~M.."w·;i!l!al'?'~~"i!I""IM.~ß'¡,~\'1I~!&ìI1L"kmW.1Jí~~t~<¡"f~··'··"·":J :1.·~:~~1:>iiç'~AA'I:I~~~~¡YJj~~'·'~'"J".;'r·I1;~~"·i1:"·~'·t.'i.~~~~r~.·~"-¡¡>··':fl':;¡'~·'··"·"·:·· ". ·'i·'I"·. ~i¡i::' ,"~-·:,:'ø;';~~~~~~#\;~~'¡;~~1.IA.~~~3~!,:;,:t;,~·#:'!!Ff<~¡i~%? ..:§< ~~~'~~"1v::;;~;\~,,:ì:~~~~~'f;~%f';l~~'.W~~fff.t'~iit?"·fi!.;¡,~;:~r}~'i:¡~¡:~;: ~:~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. ,r~ ;fi Description of fillings: ·1 ,', iir;¡ . ". '.' :;.' .";~~~..:~!:~'Gf:;:' '·;·~~$:~~~t¡i;;~;,~~m.::~rt¡':h"''i¡;::~;;.:n .:~~'~,b~~~~'~:':,: i ;~;.:;.{r.;.':! .~~~;~ fi':'*,;;~>i;~~i'~·~':::~~·~~*~t>:':· ;i;.:~ '~~¡~;~;~:;'Wi~fj~'t~~~ :~~{kJii!_)ti~_!~K~~!~·,:.'~ :~it¥~:~~'1;;: ',: :t :;: .-:;.:~;¡:,.".ji4ii 24 hr Recé Ran 9 5/8" casing and landed@11753'.Circulate11/4casingvolumewithmaxgas of 186 units.l.i......'.~ Pumped cement and displaced with rig pumps. Bumped plug. Nipple up and test BOPs at report time. í .·1.'·.'" ó ~ ,~ .~ ~4 ~ Logging Engineer: Tom Mansfield 1 Reg Wilson * 10000 units = 100% Gas In Air :,~i .~:~;;:;~' ,.::,:::.\.; ,;~g01I19~U~fp,:.~~~i~~·~:;:; ~.¡::;i':: ::~:::~¡:._. ',::. J:::::õ):¿;':' :; i·;?¡:;;:f:·~::;:~'.;':'~;~:'.~ :"'i?:::;~f~: :::. :'>'::.:,.' ·~·~::Y·:,~;;¡¡;:~i··}:': :i;¡f~f~m¡'~;tlio$.:~~~.:~gT~::i·;¿:_:::: ::;f:>~:::: _ :;':':'. : '.:' -.,}: Trip Depth: 11778 ft Trip Gas: Mud Cut: _ ppg CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm :~I Tight Spots: to to to - Feet of Fill on Bottom: ft ': ~¡ '~:.,:.-:~" :.' ':~.;:-:,::<~.,,;. ''''<''~:"1~¡¡¢:'Fj¡a,;;~pj'.~.'", ,Î";-¡~":<':~~'V";:. .'.:,1:"',"'¡";~<i'¡;-:''';;~,~''. ~:':',";:oi;.t;:;:~:,'''r,~~'''fJ.t~U~}~;~J'.t;"::,,.,:"i;"!\'.:'f-Æ!:¡;;~4,¡r~r.::~.,"., .,QI, ¡ ~'~~':"';':"';rJ.',"i:';";::,' IF: .:.:.:,;,'>.,.... . "-. "....:,);'... % % %LCM . - - mr~II)~~t~.~Bi!!~ßTl.\j~nt~_U~lfl.~~;,:I~,::.~..~~D.ìt&i1\'\'i~__:,' \ Connection Gas and Mud Cut ~ ppg ft units _ ppg ft units _ ppg t1 ppg ft units _ ppg ft units _ ppg ~;: ppg ft units ppg ft units ppg I - - iiiiI! ~~'~:I1]::JRmI:c;r"""C~:mr'"'ÀÎJg).~il.~ .t1211~M\ìì\r-."·""·WX"^~~~:U,U % Lithology Sst Sltst Sh Gas during before after after Drilling Breaks to to to to Drill Rate during before Depth units units units ft ft ft RS161HGSW Bit Size: NA Hrs. On Bit: Type: RPM: I ?~ 0.7420 2 X 14 TFA: ---- a Footage for Bit Run 8 1/2" 0.0 Jets: 4 X 12 -- Total Revs on Bit: 3 NA Bit No.: Wt On Bit: ~; ppg ilf 0.25 % ?~' --- . '.'-' ~ ......... .~..... ...~.::.~ ~.""'·:-.":r'," t: :;"..-'. :¡,.~.'. ~.~';':.-:.~.::.: ........... ... ":.' .~. ;'".\'.~ .. -.', \.; .....:r·~;·.·;; :.~..;....-.. ....j.. .".'~~¡,.'.:,.~-.. 'OJ' .... ...~:.....~':" .",,:.- . I: 01'1 .~. Visc 49 secs API filt PV 14 cP YI 27 Ibs/100ft2 4.8 ml HTHP 10.0 Mud Wt at Max Gas Gel~ 10 1 15 1 20 Ibs/100ft2 pH 8.0 Sd .:' .... '......... .... gpm gpm fpm fpm Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi A V @ DC Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max fVhr @ units @ deg F @ . ~',~~~,;. ..:-~ '·'~~':¡;.;~"'~';'t";·~>;:~~"",.'''~' ~',:~:~'7·..:,:;. ':', '.:~:, ..,-;,.;:,:;~,,;~. " Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 11 11 /8/02 11 778 o Test BOPs Kidd / Dinger BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 10.50 ppg 10.50 ppg Mud Wt In Mud Wt Out ."'10..... 186 24 hr Avg ft/hr ( unit~ ( ( Current fVhr units Deg F R.O.P. Gas* Temp Out I Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe.....,.......y- sun DRILLI N'G- SERVIc::es '~ ~1:; :: . :~ ;;y;::m,'¡~~ ji:~~r~~'~ X~11'~~\~#~W¡Š!y;{1!~;i~:;,; ~;¡:.,.::: .~~! :~m;:~'~;,: :1~,}~;:';";:~;~';~~~~~; ;.:!~;. .:" ~t;¡;:'A ~~\ii~?f..~t~f.~·~;'~~); ;'~·~~f;~h~!~}·:~:;'~F.i.~:~{! (:~~~I~;·: (;0 :!{!/: r ;'~':':' ::,) ::~1..:i~I·... '.~.'.'".. 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. ': ~i Description of fillings: ;~t~ ,- ..", ;;: ' : ,.~;,~~,Í·!f~~·ð;,' ':- :.'.~ij;,t~~.&'+J'!~1i'i¡.¡;~~r¡;~~1'î1.-~~t',~~z:~:;:!~~>H.~~Þ:4~~';·~~-<l:f<\f';,.-:: :~};,,~ ¡U:;-~;::¡~*F';¡¡,' ;n,:.~r.':\?~~'¡;::'~ilf, \~;~:!~" ~i"';;'À:~::: ~.;;'~~,~~;~:~?P7~~t~'11æ1~Mi~pl\;'~!¡!t'j\:f.. ':\\:1: ' . ::. ':h1~ 24 hr Recí Change bag on BOP. Nipple up riser and re-test bag. P/U 8.5" new bit 3, BHA, and trip in to shoe. ..~ Test casing to 3900 psi wi 10.6 ppg mud. Top cement @ 11644'. Lost rig power. Prepare to bleed in spike fluid. ,~~ ;'~f i,ì.~ .~" f .~~; ,~ ~ '\, ,~~:; Logging Engineer: Tom Mansfield 1 Reg Wilson * 10000 units = 100% Gas In Air~~;; . ,,::: .:- '-::~~;¡ª;~~i:~~::~:gW~g~?Tf!;~~.:~:'1~.~ ·';~~WE;,zi::3ÿ;~'~.;;¡;T~;::·~:;¡k..::;¡;i',~;~ :.'. ::. -',', :'?()'::!i(:: :W;!::,)::.~~);.-::" :::<~/!~: ~~¡>:~:: i;: : ;': ", i:;Ui'~"Y.¡\;f~:j~~~~H~~l'.i'~}~fìi:;':(-k~~, }:~:~: ;::',':' .... :::~) % Lithology Sst Sltst Sh " '''''1 ...., ~¡ .... ¡ ,! I after Gas during before after to to to to Drill Rate during before Depth Drilling Breaks units _ ppg units _ ppg units _ ppg ft ft ft Connection Gas and Mud Cut ft_units _ppg ft_units _ppg ft units _ ppg ppg ppg ppg units units units ft ft ft .. . ·~·..,1;t ,'. :.·...:·Y· ~.' :':'~:J!~~~"~'¡""':';~::" :.r: ~~:ti:"'4t~~~:~~)~:~(~',: :~.t."!t~..~~~: ~.." rj :-·..i:f~,r~::,~.~.fíf·~~:'i5~Þ·~~) ~..' ··:'~·~::;;:'~f!';jf-!1~~~·~f~~.~.-:~!·.1~·.·~··,,·,,~,~.¡::~~.:~~¡;~~'~~~.(~':'~~~J-;';':':¿ ~;!~~"::--;t.=?·¡" ",: ~1'" ...., ,. ~",(",;"."~,\,':,\,~,;"';.!~I:,,¡,«'i!'!-,-.,Jí;!,i{';'1¡~-'),,,.,¡<:I~,,~,J.\t~¡': .';;:é'·:'/,',·~'''''~''¡:;· "¡¡1,~...;.::..i.~~"~ '.:." """"''-;'¡,,~R:~'"'' ....>'k ,:,:;"':<':'''''';:''~': !#";'.: ,,;,;'.: ,I:: ". :;:,;"~ ~':.~ft:~i~":'~íiê~;,. ,:,"....;:,.!. ,'...:r' . I Trip Depth: 11778 ft Trip Gas: Mud Cut: ppg CI: ppm "W1 - _ Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm t~~ Tight Spots: to to to Feet of Fill on Bottom: ft ¡.,;.,:..<~¡¡.t;~?(;'ìf~~~~~~~_~ø~~,!.;j~;:~~~r~~~~~~4J:~~t,,¡;~~:~~,*~"~,~l''''~.~*~W~riY~1.\l(~~~-~~f.'';g:..<""*,,, Current Lithology: ~'o ~o ~'o % ~ oLCM 0.7420 Jets: 4 X 12 2 X 14 TFA: ------ Total Revs on Bit: 0 Footage for Bit Run 81/2" 0.0 : . "," . ".":'f,~,~ ,',' 7','~~,' ¡ ~ .i:.¡-:' '''~ '~:l; :,... .:r~ :',,,:,~~~~;.'~:'~ ',. ~.<'1.'. ,':~'~. ~ "..~ ~~ !~'~:.:.-: :'. ~ . :.}I::;:~t~: ':f.:.'~:· ~: ~",::;;.' " ~.:.. ; ~~:'...: .~ '.~,~~ :~,~~,: ,~""r' .:-1t.,:....1. =J~ :; ~ ,,: ~ _;.:~t:It'..OJ,:,p.h'. .'.' '~"7',.'. :;,; ~ ~ ':;' ..,; . :.~ " :..~-'; ':'" ",.~; >t ._..... : ',:\ ,~ . ~.:--.t:..:.f':' :.~.~ ~.;.:~~ ,'-: ¡.:,~~:;, ~.~'. ": '. :~~ :~ RS161HGSW Bit Size: NA Hrs. On Bit: 3 Type: NA RPM: Bit No.: Wt On Bit: I Visc 49 secs API tilt 4.8 ml HTHP 10.0 Mud Wt at Max Gas - - - PV 14 cP VI 27 Ibs/1 00ft2 Gel~~ 1 ~ 1 ~ Ibs/1 00ft2 pH 8.0 Sd 10.50 ppg 10.50 ppg Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data I R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow Gas" units unit~ ( 186 units @ ) Pump 2 spm Total flow Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi A V @ DC 12 11/9/02 11 ,778 o Drill Cement Kidd / Dinger " Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe......f'""'y- sun DR I LLI N G_~~RVI c::e 5 .-" ~,.: ~ . . . _ : :~~,,:~·~è~ l~{~;' ~ ~,; ~.~':;:~~~~~:i:,~~~~ ;J; " r.! {~~~~,t'r :~~ ~r.~J,~;;!.hf:~,~~ ,~·,~'~\~~t~~:~~·i~;~~~,~~~l~~)~~;~'~~#;~'~I~'::::'~~~~:~~~ ..~ :{ ~~':;~'~f.~~~~:;:~~~~n~':~ts'r;~;~;~!.~it~~X::~~:¡i~~1: ;~~,:~~~~;i<-=-¿*H ~ ~~:~'t~1 :·~'::.if:¿~~'¡~;:~~·~, !:: \\:':~'~,~~~'-; . 24 hr Recé Regained rig power. Bled in spike fluid to 12.9 ppg. Drill 20' new formation. Perform FIT. Drill ahead. Logging Engineer: Tom Mansfield 1 Reg Wilson * 10000 units = 100% Gas In Air ", :1</ It:i~:~::i'i~~J~~-ï;~.~~~~~~~~~~.~~¡¥~\~~~~~~~~~.~~~~~~--~~&;i.~~~¡:::.¡'~;·'~~ ;.~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 35 TOTAL oz. '~ '~.~ .';M ~f Description of fillings: predominately small slivers, some small chunks, some curley as Î ;~~~'}<~}h~~~i~'¡H.;~ q¡ Connection Gas and Mud Cut i i ft units ppg ft units ppg' i ft = units ppg ft units ppg ~\ ft _ units ppg ft units ppg! ~ :nr1rr'Il~J.~I'I#).~~ÜiÆ~.L~lrl~"'D.JtRr:~'( ~z;~) [ , Trip Depth: ft Trip Gas: Mud Cut: _ ppg CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm '1( Tight Spots: to to to Feet of Fill on Bottom: ft l~~"';~'~;:~~~~~~,~~~~",~~~%~iþ~~'!:!Ff~i~~~f¡~~~~;~:¡'{;;;~~iW'>Rr~'~~¡.;;:.<,. 1Æt t~~ Current Lithology: 90 % SH 10 % SL TST :t~~~~~w.~~~~~~,tt_~"'~~~~~~W'Ji % Lithology Sst Sltst Sh Gas during after to to to to before after Drill Rate during Depth before Drilling Breaks ppg ppg ppg units units units ft ft ft %LCM % % I ".~,,:,:~,:' ;-::~~.,~~ :.:;:., ~",,' ~'. ~,;·~,~:;~~J;,,:;·:H;"~:.>1j:,'~,:",,;~;.;, :'.'/~''''¡'':::. ':':'¡~<:; ~'"t '!~;,,~:":' ~ ;.,;.;k;'7'>!'':';:~:~'''''''':'''':,"''~!'-'I:~~~~~'::¡;\'l~'~f:.::~, :~; :·H::~~:¡·;:¡:',i::· ".:::\.:,>",\~,,~~~!'''':.' ~.,;,~-.:~;,,:,~,.:,:..,,: :,':',;' :. ::" ';i": Bit No.: 3 Type: RS161HGSW Bit Size: 81/2" Jets: --±.... X~ ~ X ~ _ _ TFA: 0.7420 ~ Wt On Bit: 10-15 RPM: 145 Hrs. On Bit: 17.6 Total Revs on Bit: 209K Footage for Bit Run 515 ~~ , , ,...: . .:I-r,~·i. ';:.~:~.,--l:. ,,;.·:d,:~'''·M~''''~ . ..'~' ..........~.. ~.1-~ '~;-":;'''¡' _~~'p!<j."\, ;··ï:'" ~.:·r'~:)..,,· ~r' 'I" ~-r~~,:.:... 1I:·&tti·;N;~·t~'f#;"": {t"~;~í:"" :....;..~':.:.:. .,>: ·:h: '~'.: ..'} '::;~,~..< ".:' ;,1"..1 ~J~'~r- r;~~'~ n~.) ..::....~-;" :~: ¡,j' ";, .~':"~' 'i.. ~~·~'~;.·o" ."Y"': ,(-. . ;",.; :'''/'' '..f~"rI;"'i . ,. - ,+. ;¡; ~:J I Visc 54 secs API filt PV 26 cP YI 31 Ibs/100ft2 12.90 ppg 12.90 ppg 3.4_ml HTHP ~ MudWtatMaxGas ~ppg Gel~~ 1 ~ 1 ~ Ibs/1 00ft2 pH 8.3 Sd 0.25 % Mud Wt In Mud Wt Out ..... .. ~.-.., ~ .~: .- ., . .. ~ .. 0" '..' . .. A 1" ., .. .." :j'"- ~,,,, .1 ¡:... . .~. . . -..,... ", . " ~ . 'n' .' .' . gpm";' gpm :;; fpm}~ fpm ':, Pump and Flow Data 79 spm DH flow 78 spm Total flow spm A V @ DP ~ psiAV@DC Pump 1 Pump 2 Pump 3 Pump Pres 558 87 386 ~ , '" " _ ~:.~;.' ;':; ~,.,~;~..~~.y.:",,;~_~,-,;:~~.. Mudlogger's Morning Report )~ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: .~ 13 11/1 0/02 12,293 515 Drilling Kidd 1 Dinger ":¡:: !l: . :",., Current 24 hr Avg 24 hr Max R.O.P. 45 ft/hr 29.3 ft/hr ( 178 ft/hr @ 12022 Gas" 80 units 100 unit~ ( 181 units @ 12017 Temp Out 105 Deg F ( 105 deg F @ 12232 BP Alaska NorthStar NS 1 9 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Customer: Well: Area: Lease: Rig: Job No.: sper'r"'y-sun DAILL.ING SEAVIc:es Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 ~:,::,;~"r·:,,·: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: SPSJ'"'"''''''v- sun o A I LL IN G 5 E A V I c:: E 5 14 11/11/02 12,472 179 Bit Trip Kidd I Dinger I~~ . :t ~1:f :Ì~ £~f ~~ ..; ~r· I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ftJhr 24.8 ftJhr ( 72 ftJhr @ 12340 Pump 1 spm DH flow Gas" units 85 unit~ ( 97 units @ 12472 Pump 2 spm Total flow Temp Out Deg F ( 105 deg F @ 12425 Pump 3 spm AV @ DP Pump Pres psi AV @ DC ,', ,:¡, ~: I gpm jf~ gpm?,; fpm ·it~ ..d-, fpm m . -.. .,. '.' . , .' . .-.;.; -. . ·.~I·~_~ .:;.~:." :r ~ ...;~ . '" '.' . ',' ':. r ',;", .. .~. . " ", I . ~:: '::~I:' - ."..:¡,;...I::. " . . "0:,".:.",,$ .';... '.. Mud Wt In Mud Wt Out 12.80 ppg 12.80 ppg Visc 59 secs API filt PV 23 cP YI 39 Ibs/100ft2 3.8 ml HTHP 8.6 Mud Wt at Max Gas 12.8 ppg Gel~ 18 / ~ / ~ Ibs, 1 00ft2 pH ~ Sd 0.25 % I Bit No.: 3 Type: RS161HGSW Bit Size: 81/2" Jets: 4 X 12 2 X 14 TFA: 0.7420 \~1 Wt On Bit: 10-15 RPM: 145 Hrs. On Bit: 28.0 Total Revs on Bit: 329K - Footage for Bit Run 694 \\f1. . .,....:.: ','. .;·:::-!~:"\~;¡~;¢~1<;'*ï.æ.:~';~f~f'~';"':~~':..'~M~~~~".~;<¡'~'!i~~.'~~'tif*~~"1i~_?>i;~r:~~#'1i:,!:t'~iM~V,·.,:,~~4rt!~';,«'Ij'S~~~.'t!'.:~~·Y~~·~~:;;::¿::·~ti:~:~~Þ)!:·;iS~:~'¿ '. . I ;~i Trip Depth: ft Trip Gas: Mud Cut: _ ppg CI: 52000 ppm :~~, Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ~, Tight Spots: to to to Feet of Fill on Bottom: ft' ~ î~~':~':;:'>'~.;~'"f~'¡~~"/I'})~~~r~~~¡~~'ì~~~~~~~'b~Æ"~"J[(J",b;;.\__h;;¡;~':~}'!~~~~I!~Ui"11'i;W}¥S';:¡'t¡.~ i Current Lithology: ~ % SL TST 10 % SH % % %LCM _ ~ '~~~\ ':,:, . ··"~~:~~:~~~~~f~i.iW,d·:··~~'~:?5f~*~;;:-:t~,~~~,.~~I't'JO;;Lt~~.A~':¡,*"..W,...if;:¡.~~t,~,:çl:ril~~~:~:è!"~;::':)':e'~:~~::" "'¡'I"~'\"Oif:.,J; ~ Connection Gas and Mud Cut ~ ft units ppg ft units _ppg ft units ppg ~ ft units ppg ft units _ ppg ft _ units _ ppg \ ~ ft units ppg ft units -ppg """ ~J':;~;:~l,~n" .~~:~::~_n~g.. ~¡¡ ~~ Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to .;.:' " )~-i;~¿~'!~!~· \l1~t{~~:r.Æ:~~~,~:t~ ~n.~ >iG:~~~r'~~gt~~¡j&;~:j~~i:; i;~~ij{(J~~:.{t~~;;¡:·r;: ~:':~;~ :;': ;;:ÚtTH,;':;J~K~)i\~~m;_~t~¥.'*~¡!}?:' \;:~,;;/:iW{!t':::: ; '.' :,;. ';';: 2~ hour accumulation of Steel Filings from Possum Belly Magnets: 11 TOTAL oz. Description of fillings: predominately small slivers, some small chunks, some curley as ~ , ' ;. ': ~ .~~ .,:.' :~:~~~ ';~,;I':. q~:;~·:':~·;~t~;J;; ~¡?E;~'~.gfZ:~~:~·!,~:·~,~!~·~l·:,£.~:~,.:,~,»t~'~~-t~~~!(t.~'~:,· !.:'t:'~~~:f~1ä~J~{~~:,~~':~~'f:;.~ ~).h'1~~...;'~~~~~·~~~":t;~~ì~ ':~,~:':~~:~~.'{',;:::~:n:f;~~~~,;~:~~::~·tr:~~i~~.¿(~:~1~:@?~~~~,;~~~l~~'~;~:~?f~¡:<~_~';' ~)/; :;~: ~'~~~ ~: ~:,: 24 hr Rece Drilled to 12472', POOH for bit trip due to slow ROPs. P/U Hycalog DS70FNPV wi 4X12, 2X14 jets. TFA=.742. RIH to 7024'. Change riser boot seals at report time. Logging Engineer: Tom Mansfield / Reg Wilson ,. 10000 units = 100% Gas In Air . ~'. ::;.:~~.;:.~,~:':~';~:,::~~~¿~~~~r~":'::·;.: ! !~~~.::'~ :;~;~~';'~~;;~"~1~': :.~:~,':~: \~~t,~¥~: ~ ~':',~~::1~~t~I;~~~;'~~Y~~~~ ,'~':':~: :~;.:i~~h~r:·~ '1:',}.: '~~~.~~7'~.:'~'i'~~?,!~~g;'~::$~,~~~~~~~i~~~~'::'~:~; ;~I~~~'¿~ ~:.~,:(,?~;~4~~~'~~: ;,,~~;~ ~r"~r :,' ~ -. I, to to ~ ===-' ~ I . .----f , , . ". ~"~'~:~:':'~:¡!~¥~~::< :'¡~¡~''),~;¡i::~t~ry:~:;Î~.;~~~t,v;~T·;:<::if;(.:r~ J,r:~í;--::f ~·:;~,"~:~·ii,1:'~~:f3=, :;;,:: ~'~::\~~;~{~{'4}Þ~:i:!!,;;~:~Il¡~;·:~i':(? ',¡·:~~:;'.i;m1~,*.f#~~~~/f'i;)Tf.~:?'~;'~i':~·{~ ~;';:::';í;"::'; ':~:. ~,...' ';,.:" ~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 25 TOTAL oz. I Description of fillings: predominately small slivers, some small chunks. some curley Os ~~ !'" , >:,. :.. :;;,é>?H~'·.~·T.",,·, ':.;i ~,·¡:!<:t3Wi;'?':'¡ì~:'f~?¿~ll!~\'r~;~>;,~~;~~~~~:~':t\~~\¡;~¡:-;,~~~~?;ß~~)'~ ~~i\~:::::N:i\-;;';i i~M~~")'t;fi;,~¡~}::&~:'þ';:,;,;~,,:1$J::~..~iE¡:¡N'·'9tf,~t;~,~t~~tili~~~r~1f~'*~~Jt~¡·~ttf~1;;:+K;~õ~· t '<: ,;. ' :¡ .:;,,:'~ 24 hr Rec! Change riser boot seals. RIH from 7024' to shoe. Slip and cut drill line, service top drive, crown and ~. draw works. RIH to bottom and drill ahead. Trip gas was 138 units ;1 I Kingak @ 12390' MD, 9985' TVD ì f. '~ Logging Engineer: Tom Mansfield 1 Reg Wilson * 10000 units = 100% Gas In Air~¡ f.1l" ,: ,', ~. : :;;~~; ¡';. ,:~':',' ~~¥~\::n:;:~¡;;:';I: :>?}~jJ¡~f;;~;:~~~:~;~.:~::·I;.;:~:~:':'::~; ',. ::;~¡r~Œ~:::~~;:::i;·~~~i~~;;:·~~:,~;~~t¡,~U~.;::;<'~~~~;:·i·Üg~f~Th~$:t..~~~~4·;·~,;~~:::;·:~.~nT!u~:]~~:. ~ :;" ~·:dt after Gas during % Lithology Sst Sltst Sh before after ... Drill Rate during \ ' Drilling Breaks before ,: Depth ,ï'·'." " "' , ~:..¡.:.'.'~:':~ I:'."':;i:' ::,.,! ,~~+'"I ....~ .,-:" i; "..' ,'!.~~~"':".: '-(' ',,~, " .:." .':.:¡,.; ,":',.:' "". ..,,~t:';"·~; ~: ,,!.:.~,.; :t1i"4+r'~!\'!-'-::<;· :.~"r.'" ,.j'" ': ':'.~" :~I/.""·,:.)¡Ó:!:Iitr~'~r;t;":,:~·":·i~"·,,...i~lt· ....~..! ,'·'·<j·'Ù!:"'";·':'- ..:. '. ; :. ~'-,~, I Trip Depth: 12472 ft Trip Gas: 138 Mud Cut: ppg CI: 51000 ppm Î: Short Trip Depth ft Short Trip Gas: Mud Cut: = ppg Short Trip CI: ppm :;:~ Tight Spots: to to to Feet of Fill on Bottom: ft iø' , ., ·:·.J;"""'~:'1"".r'~L~""~.F;;,-",¡r,·,,",'. :+"';;_'I'~~.(.~~~~,1:t.V:<''':';" ·:9~ï~}i,':.:.':.;,;.c;,:.: ,.L';1·P¡Þ*''¡-;;¡~~~¥:i''·~;¡;:¡-':~~~·.-'~'~:'''}.,~,-:¡~~:i·~·:'~;''~~P~~~'; ~·,~,¡~/~;;;"~,.',:r;~;-;-,,,",:'- . ~ ~( Current Lithology: 90 % SH 10 00 SL TST % % %LCM ~: ' ;}L .,:_ ' ,.~,.I¡;"\,,,,,,",",.......~~v.~,......it~ ........... ''''''"'''''"'~''''~(;-:P',''I''':'''':....a1t'",,,,,,,,,..,;..",,,,,,,:'l. "'''--':'><'''''>-,. ".Jit/.,.¡o.II,,~."'t.. '~;''''l.''''~''''''ì*v",o;;{~''~~''~IôJ¡I"-·''J~11IJou;·'}:'f'''P;~~~ ~., . ,....;,.....>.:.: "",e"",, ~ ~ . ,'J. .~.l,7f,;.,~..~ .,:r..~ .\:,~.~;.~~~~~,?~..~,,:-:'!l., "I,.,-,.~.-.::';~'C ",".~~.l,!$.~~~~~~'5."" . "~.~~~;¡o~r";\ ..' . 'Io~\ ¡Ç)~:~~~~~'m~ ...... JJI!~.D"'t,."T? ,tOIQII Wi. ;-."":"f,;';"~ . . ~' ~ ø;:~V?""'~i'"~~::o.-.¡¡¡o_,~·,.n:t~r.~ .. " . - .. f ..... I ~.. t f',.'f;". I ~1 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ~ ft _ units ppg ft units = ppg ft units = ppg ~~ ft units ppg ft units ppg . ft units . ppg = ~ililmK:.,w'U"~;~D1I!RìP~ï'~~lnl:IID.Dl...Jl~. ~ m ;~ JI~ :¡ "':'7:';~ 'ï 0.7420 ~. ,~ 789 ih: ~~..:. TFA: Jets: 4 X 12 2 X 14 ------ Total Revs on Bit: 179K Footage for Bit Run 81/2" 12.2 I Bit Size: Hrs. On Bit DS70FNPV 158 Bit No.: Wt On Bit Type: RPM: 4 Hyca 20 _.~ ':'~.:. .~~~ "\: :.~~ ~·.;~,:::...tiJ':.~\;':'~~::~~ ;-;~:~t~~.oc:,'~,.: ~~~~."!'"~:~..:¡;~~~-;~d1i,~~:i-J.~,:~:¢".~~~~~~~ :',: !~!~,-;-~ :':~~" ~:'\;~:;':.";~"~~"~I ~··'·.:::..!:rl'~·'1 :-:'~~_~':.¥-:~I~~~~'~,:':· ,·;-.J·~·.foð'e~,~~~,~,~~;:8;'":~: J_{'~~.'C}t: ;-,~..~ ~!,t.~~~'~~,·,,~',;:~~,:.:~.t:f:1~:;'~1;;N'!~~;=,..·~.r:~ ;-:-., .~~.~~~. :.~,~.:, --- 4.4_ml HTHP ~ Mud Wt at Max Gas ~ppg Gelt: 15 / 50 / 64 Ibs/100ft2 pH 8.4 3d 0.25 % ~..h"~.~.";.:::~ :':.:'.'_',~":,. '. ,,,~:_.. Pump and Flow Data 87 spm DH flow 86 spm Total flow spm A V @ DP 3925 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 615 96 425 .. ,', ,,,~~':-:. :. ,~"~,('~..,',;,"~¡;J\':::' '~~~'~~':-. '":'h-'~ ':"~".' ~~''':':';:t~'i:,,;:;~~·~"~,'H~;';;:~~i\""B~~~~~~::.'.:~"$:'~ :J",~,,~ ;-7~: ;\~':';::"~" '-,~~ ,".,,"';" - , 15 11/12/02 13,261 789 Drilling Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 12.80 ppg 12.80 ppg Mud Wt In Mud Wt Out Visc 51 secs API filt PV 24 cP YI 34 Ibs/1 00ft2 ,".. 12881 12988 13200 24 hr Max ftJhr @ units @ deg F @ .... " ,,'I=f" ", ·,1·, .. , 241 275 110 24 hr Avg 65 ftJhr ( 150 unit~ ( ( ft/hr units Deg F Current 42 170 110 R.O.P. Gas· Temp Out BP Alaska NorthStar NS 1 9 North Slope NorthStar NS 1 9 Nabors 33E AK AM 22173 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: spe....,....,v- sun o A I LL IN G 5 E A V I c:: e 5 ¡I- I: ! * 10000 units = 100% Gas In Air : -.::.":;. ,,:" ; ;~--:~·;!;~~!t\~"~~?f~<;i~'=::'¡;; !~ë ::~:'!;~: ,.'.:;:: :~, '!¡:¡::;:'<:~g; :~:;; ;~:: ;:;Hi¡~::~~~:;r~¡~-¡.~~!;'· :i¡';$j~;:i¡;~::; '¡:if:: ';:~~~~~~s~~~~~i~~fij~~~;:~;;~ª~iiê~;;' '~'..-,:.:. ,.,:: Logging Engineer: Tom Mansfield / Doug Wilson Sag River @ 13470' M 0, 10833' TVO Drill from 13261' MO to 13500' MD, 10856' TVO , 8 1/2" Hole TO, Circ Bottoms Up, Trip out. ~t· ··r"~'.: ,~.~~...... . .~~ ~ 0"";" ·....:,:.';!'·'7~:.~~.;.·, ..':..:.:;:.~; ;:;~~:~.!.J --0·':' .·.L·ri::~~*"~';~"'~~·i,,:,,:~,t..~':':·t.;~;:.~~!::.;·\:,;t..;.' (9~' 24 hr Recé .' ;'"!":i......r.;=-:.;.:.'-: ;~";:~~~;'~I·I·. "'-.Þ ..... - .. to ----¡; ~ ----I ~ ----Ii to , ~ ---- . ,. -;·_:~:¡'~·\;rif~P~~,:~/ì.!~:;;¡::.;~'~"~if.~~~:~~~t!{?~r~~~U;· ~: .::' '~:;tj::~'~::h:~~¿~f~)l;~f:'t7~!':f::'~~f~~¥Jg·::!;W::T:.;."¡~\: ":"~~.' " 'f.'~!~:~~~~~;~~:.':·~~!;ve·< ::: :. '.... :", ''-''~1'1' .~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 5 TOTAL oz. » . Description of fillings: predominately small slivers. some small chunks. some curley Os % % Lithology Sst Sltst Sh Gas during after before after Drill Rate during Depth before Drilling Breaks I Connection Gas and Mud Cut ¡ j ft units ppg ft units ppg! "¡ ft units = ppg ft units = ppg ~ ft units ppg ft units _ ppg ¡, Trip Depth: 13500 ft Trip Gas: NA Mud Cut: -ppg CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Filion Bottom: ft Current Lithology: 70 01 SH 20 0: SLTST 10 01 SS 01. %LCM ,0 ,0 ,0 ,0 ppg ppg ppg units units units ft ft ft I I I I . ,....- :~... "r.~·".'."i..:~:_:~~..r· "·'1 ~~""'~ .": .. ... . "' ".': .,1 "; -......... ......:. .:.::,r:_~~ ,', " ·.....-~~.·:...R1'··~:-:.·....·~í···· .~'..~.'I., "." '.~.'!.~ ~~'...'_": ._:~::..;.~:~.. .:...:..: I~.:.";·~··.· . .', P,":. ._...;'~ . . . Bit No.: 4 Hyca Type: DS70FNPV Bit Size: 81/2" Jets: ~ X ~ ~X --.!i.. _ _ TFA: 0.7420_ Wt On Bit: 22 RPM: 158 Hrs. On Bit: 15.9 Total Revs on Bit: 214K Footage for Bit Run 1.026 ~" ." ',',j; ·,'''itiC:;·~·· '<':;":~::"'~~;"':"~~:.r;J"'.¡-.~~,.¡'..~,~;,-;~"" :',::, ''''',.-.'', -t~;~':}': ';" "":'"i01:':¡¡~~6 ,'-.~":."I,'~.,...:...:,:~~.~~;.~::~:.~-,~:"".:.> t;- ;- '·':1'~.~jH!t:~·;.;~~r(~·~~,;.0.<','!·',:;"~;'··:-: .:~:,':i,'~: ;-:.. ;,f" ,"~:t~ 12.80 ppg 12.80 ppg I --- ..;¡~ .~ Vise 21-sees APlfilt ~ml HTHP ~ MudWtatMaxGas ~ppg ~ PV 24 cP YI 34 Ibsi1 00ft2 Gel~ 15 / 50 / 64 Ibs, 1 00ft2 pH 8.4 Sd 0.25 00 .' -:.: .~. ~-';:...:....':; ~..":..;~~:..''''-.. :'~,; "-~: ~l: ::\ ~ ~~ l~ i· 'I gpm !~ ,,~, gpm.·~ fPm~j fpm .. Pump and Flow Data 87 spm DH flow 87 spm Total flow spm A V @ DP 3965 psi AV @ DC -rr--- Pump 1 Pump 2 Pump 3 Pump Pres 623 100 430 . : .:,'"' ~ "'~ ::: :.;:~~~.: .;o,~, <.:...;" ':"~1\; ~~:~I~~f~"!~"\~ ':i~~~.~;.;:';f.;:~ ,:\~",~:,:. :- '.þ,\:"~::' ;;! ,~~ ".~,7',.: . 16 11/13/02 13,500 239 Trip Out Polya / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mud Wt In Mud Wt Out I .' :.r :""~..' ',;. -.....~,." '~..'.~ ..~ ,'~ ~:..~.< \: - Current 24 hr Avg 24 hr Max R.O.P. 88 ftlhr 64 ftlhr ( 131 ftJhr @ 13436 Gas" 240 units 115 unit~ ( 242 units @ 13499 Temp Out 110 Deg F ( 110 deg F @ 13500 I BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: spe....,......v-sun DRIL.LI N ci-'SËAV I c:: e 5 I ~, I \/.~r :10...12 Schlumberger BHA# 1 Job II 40008135 Date In 29-0ct-02 Date Out 29-0ct-02 Hole Size 16 Customer BP AOW Time In 6:00 Time Out 12:05 Hole Sect Surface Well NS19 Depth In 201 Depth Out 330 Bha Type Steerable Field Northstar TVD In 201 TVD Out 339 Hrs BRT 6.08 Rig Nabors 33E Drlg Hrs 0.6 Drlg Ft 129 Avg ROP 215.00 AFE II NSO-831331 Slide Hrs 0.1 Slide Ft 30 Slide ROP 300.00 DD's Tunnell/Levad Rot Hrs 0.5 Rot Ft 99 Rot ROP 198.CO Co. Men Polya 1 Clump Pump Hrs 1.8 Rotate % 77 Slide % 23 I PDM Run II 1 R/S 5/6 PDM Jet Blk Inclln Azln Bit>Srvy 40.00 PDM Serll 962-1126 Stages 4.0 Bearing Mud InclOut 2.03 Az Out 68.98 T/F Corr PDM Size 9 9/16 Rev/Gal 0.113 Rubber RM1000 Avg Dls 1.2 Max Ds 2.4 Plan Dls Mud Type Sea H20 Spud Mud Wt 8.7 Sand % 1 RPM 50 GPM 650 SPP On 750 I BHT F Mud Vis 150 Solids % 3 Dig TQ 2.0 WOB 5 SPP Off 780 Description Vendor SIN OD Stab OD F.N. Bottom Conn Length Cum Length Item In] Oüt . Top Conn ' Bit#1 MX-C1 Hughes 6004905 16 3x20 1x12 1.35 1.35 TFA=1.031 Jets 75/8 Reg P 2 9 5/8 Std POM 1.83° Ana 962-1126 9 9/16 Tool 15 7/8 1.06 7 5/8 Reg B 26.03 27.38 Float 65/8 H-90 B I 3 Orienting Sub Ana GLOO-105 8 2 3/4 65/8 H-90 P 1.46 28.84 6 5/8 H-90 B 4 MONEL STAB Ana HA-O 16 8 2 7/8 15 7/8 2.35 6 5/8 H-90 P 5.60 34.44 I, 6 5/8 H-90 B 5 MONEL LC Ana 10-HA-013 8 1/8 2 13/1 6 6 5/8 H-90 P 9.96 44.40 6 5/8 H-90 B 6 MONEL LC Ana 10-HA-011 8 2 13/1 6 6 5/8 H·90 P 9.69 54.09 I 6 5/8 H-90 B 7 MONEL STAB Ana HA-012 8 2 7/8 15 7/8 2.12 6 5/8 H-90 P 5.25 59.34 6 5/8 H-90 B 8 X-OVER Ana ANA614 7x8 2 7/8 1.20 6 5/8 H-90 P 3.09 62.43 4 1/2 IF B I I I BHA and Run Objective rBHA and Run Results Why POOH / Comments ~._-_.._._----_.-..._-_.._,...._----_._--_. BHA Weight Dry Wt 10,934 Buoyed Wt 9,485 Inel Angle 1 Buoy+lnel Wt 9,484 Bit Data IA DC # 11 5 Footage 129 Hrs 0.6 k Revs 4 k Grade Comment Tool Motor Jars Bit #1 Hrs. In 0.0 0.0 26.2 Hrs. Out 1.8 0.6 26.8 1.8 ..-.. -.....--..-.-----..---..-.... -.-...-----...-....,--..-.,..-..----.-,.--..------- I Bit To I Vur 9-02 Schlumberger BHA# 2 Job # 40008135 Date In 29-0ct-02 Date Out 31·0ct·02 Hole Size 16 Customer BP AOW Time In 13:00 Time Out 10:00 Hole Sect Surface Well NS19 Depth In 330 Depth Out 3,426 Bha Type Steerable Field Northstar TVD In 330 TVD Out 3,218 Hrs BRT 45.00 Rig Nabors 33E Drlg Hrs 19.3 Drlg Ft 3,096 Avg ROP 160.41 AFE # NSO-831331 Slide Hrs 7.5 Slide Ft 1,082 Slide ROP 144.27 DD's Tunnell / Starr Rot Hrs 11.8 Rot Ft 2,014 Rot ROP 170.ô8 Co. Men Polya / Birkbeck Pump Hrs 32.5 Rotate % 65 Slide % 35 PDM Run # 2 R/S 5/6 PDM Jet Blk Inclln 2.03 Az In 68.98 Bit>Srvy 67.00 PDM Ser# 962-1126 Stages 4.0 Bearing Mud Incl Out 38.46 Az Out 160.39 T/F Corr 355.0 PDM Size 9 9/16 Rev/Gal 0.113 Rubber RM1000 Avg Dls 2.0 Max Ds 4.6 Plan DIs 2.5 I Mud Type Sea H20 Spud Mud Wt 9.3 Sand % 1.25 RPM 50 GPM 850 SPP On 2260 BHT F Mud Vis 75 Solids % 6.1 Dig TQ 14.0 WOB 10 SPP Off 2150 . Description., Vendor Stab.OD Bot;t()mÇ()n./J Length Cum L~ngth Item ÎnlotJt Top Conn· I Bit#1 MX-C1 Hughes 6004905 16 3x20 1x12 1.35 1.35 TFA=1.031 Jets 7 5/8 Reg P 2 9 5/8 Std POM 1.830 Ana 962-1126 9 9/16 Tool 15 7/8 1.06 75/8 Reg B 26.03 27.38 *Float 6 5/8 H-90 B I 3 MONELLC Ana 10-HA-013 8 1/8 2 13/16 6 5/8 H-90 P 9.96 37.34 6 5/8 H-90 B 4 MONELLC Ana 10-HA-011 8 2 13/16 6 5/8 H-90 P 9.69 47.03 I 6 5/8 H-90 B 5 MONEL STAB Ana HA-012 8 2 7/8 15 7/8 2.12 6 5/8 H·90 P 5.25 52.28 6 5/8 H-90 B I 6 MWO Ana 173 8 1/4 3 1/4 1.40 6 5/8 H90 P 28.63 80.91 6 5/8 H90 B MONEL X·OVER Ana LWO 5B-120 8 1/2 2 13/16 6 5/8 H90 P 1.41 82.32 7 6 5/8 FH B 8 DH Filter Sub Ana JB-15250-2 8 3 1/4 6 5/8 FH P 2.29 84.61 6 5/8 H90 B 9 Orienting Sub Ana GLDD-105 8 2 3/4 6 5/8 H-90 P 1.46 86.07 ( *Mule Shoe 6 5/8 H-90 B 10 MONEL STAB Ana HA-016 8 2 7/8 15 7/8 2.35 65/8 H-90 P 5.60 91.67 6 5/8 H-90 B 11 MONEL DC Ana NMDC-HA-022 8 2 7/8 9 5/8 H-90 P 30.83 122.50 9 5/8 H-90 B 12 MONEL DC Ana NMDC-HA-02C 7 15/16 2 13/16 6 5/8 H-90 P 30.91 153.41 6 5/8 H-90 B 13 MONEL STAB Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 P 5.49 158.90 6 5/8 H-90 B 14 MONEL DC Ana NMDC-HA-01ï 7 1 5/1 6 2 13/16 6 5/8 H-90 P 30.83 189.73 65/8 H-90 B 15 HYDJARS DAILEY 1417·1044 7 3/4 3 1.19 7 5/8 H90 P 30.83 220.56 5 1/2 IF B 16 26 Jts. HWDP 5" NAD 26 HWDP 5 3 4 1/2 IF P 781.39 1001.95 4 1/2 IF B 17 DP 5" to Surface NAD DP 5 4 1/4 4 1/2 IF P 1001.95 4 1/2 IF B BHA and Run Objective Build 8:~~.~_~~~.~i~~?tion~_~.~_._ Why POOH / Comments 1~~aChed 1.~_~!~~~~i~oint BHA Weight Dry Wt 70,386 Buoyed Wt 60,415 Incl Angle 38 Buoy+lncl Wt 47,608 Bit Data IADC # 115 Footage 3,096 Hrs 19.3 k Revs 147 k Grade 3-2-WT -A-E-I-RG- TO Comment Tool Motor Jars Bit #2 Hrs. In 1.8 Hrs. Out 34.3 19.3 46.1 32.5 BHA and Run Results I~~-.!.~~ned____________._.___._______._. 26.8 -------_. ,Bit To GR=65.01'.. D&I=67.00',Gyro=96' Vm 9-02 Schlumberger BHA# 3 Job # 40008135 Date In 02-Nov-02 Date Out 07-Nov-02 Hole Size 12 1/4 I Customer BP ADW Time In 4:00 Time Out 3:00 Hole Sect Intennediate Well NS19 Depth In 3.426 Depth Out 11,778 Bha Type RSS Field Northstar TVD In 3.218 TVD Out 9,501 Hrs BRT 119.00 I Rig Nabors 33E Drlg Hrs 64.5 Drlg Ft 8,352 Avg ROP 129A.9 AFE # NSD-831331 Slide Hrs Slide Ft Slide ROP #DIV'-O! DD's Rinke I Starr Rot Hrs 64.5 Rot Ft 8,352 Rot ROP 129.49 Co. Men Birkbeck IDinger Pump Hrs 92.6 Rotate % 100 Slide % I PDM Run # R/S PDM Jet Inclln 38.46 Az In 160.39 Bit>Srvy 58.91 PDM Ser# Stages Bearing InclOut 39.65 Az Out 129.83 T/F Corr N/A PDM Size Rev/Gal Rubber A vg Dls Max Ds Plan Dls I Mud Type Polymer Mud Wt 10.2 Sand % .5 RPM 160 GPM 970 SPP On 3800 BHT F Mud Vis 44 Solids % 5.5 Dig TQ 21.0 WOB 25 spp Off 3800 Description . Vendor Stab.OD Bottom Conn Length Cum Length Item <ill/but' Top Conn 3it#3 RSX238HF+G~ Hycalog 203404 12 1/4 4x12 5x13 1.00 1.00 TFA=1.090 Jets 6 5/8 Reg P 2 PO Bias Unit Ana BU-90080 9 1/4 Tool 11 13/16 1.35 6 5/8 Reg B 3.20 4.20 I 7 5/8 Reg B 3 PO Extention Sub 90163 9 1/4 Tool 7 5/8 Reg P 1.29 5.49 75/8 Reg P 4 PO Control Collar Ana 90031 9 3/16 Tool 2.32 7 5/8 Reg B 10.07 15.56 I "CU 301 6 5/8 Reg B 5 XO FLOAT SUB Ana GLDD-118 8 2 7/8 65/8 Reg P 1.51 17.07 "Float 6 5/8 H90 B I 6 MONEL STAB Ana HA-013-SB 8 2 7/8 12 1/8 2.45 6 5/8 H·90 P 5.44 22.51 6 5/8 H-90 B CDR (PWD) Ana 8143 8 7/16 3 1/4 15.21 6 5/8 H90 P 22.83 45.34 7 6 5/8 FH B I 8 MWD Ana 196 8 3/8 3 1/4 1.74 6 5/8 FH P 27.79 73.13 "filter 6 5/8 H90 B 9 MONEL STAB Ana HA'002-SB 8 2 7/8 11 7/8 2.40 6 5/8 H-90 P 5.55 78.68 I 6 5/8 H-90 B 10 MONEL DC Ana NMDC·HA-02~ 8 2 7/8 9 5/8 H-90 P 30.83 109.51 9 5/8 H-90 B 11 MONEL DC Ana NMDC-HA·02C 7 15/16 2 13/16 6 5/8 H·90 P 30.91 140.42 6 5/8 H-90 B 12 MONEL STAB Ana HA-017-SB 8 2 7/8 12 3/16 2.40 6 5/8 H-90 P 5.49 145.91 6 5/8 H-90 B 13 MONEL DC Ana NMDC-HA-01 ï 7 15/1 6 2 13/16 6 518 H-90 P 30.83 176.74 6 5/8 H-90 B 14 HYDJARS DAILEY 1417-1 044 7 3/4 3 1.19 7 5/8 H90 P 30.83 207.57 5.1/2 IF B 15 26 Jts. HWDP 5" NAD 26 HWDP 5 3 4 1/2 IF P 781 .39 988.96 4 1/2 IF B 16 17 Stds. DP 5" NAD DP (17Std) 5 4 1/4 4 112 IF P 1603.62 2592.58 4 112 IF B 17 Porcupine Reamer STC A01821 7 1/2 3 12 1/4 1.25 4 112 IF P 5.08 2597.66 4 112 IF B 18 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 112 IF P 2.37 2600.03 4 112 IF B 19 DP 5" to Surface NAD DP 5 4 1/4 4 112 IF P 2600.03 4 112 IF B SHA and Run Objective Drill to TO and complete 2/100 curve. BHA Weight Bit Data Tool Hrs. In Hrs. Out --_.,--_.,._-_._----~---- Dry Wt 67,823 IADC # Motor 92.6 SHA and Run Results Buoyed Wt 57,285 Footage 8,352 Jars 19.3 83.8 ---.-.-----.,.--,...,., ._-~_...,-_._-""_.-_.._...,-_..__._- Incl Angle 38 Hrs 64.5 Bit #3 64.5 Why POOH / Comments Jr.D Buoy+lncl Wt 45,141 k Revs 619 k RSS 92.6 -, '.._-"_._,,,..,'_..~. ~-_.__._.._.._---_.__._-_._--- Grade 1-0-WT-C-X-I-CT-TD Sit To GR=39.651', D&I=5S.91',Res=28.65', Pres=30.40 Comment ';~f ,:)-\)2 Schlumberger Job # 40008135 Customer BP AOW Well NS19 Field Northstar Rig Nabors 33E AFE # NSO-831331 DD's Rinke I Levad Co. Men Kidd I Dinger PDM Run # nla PDM Ser# PDM Size Mud Type Polymer BHT F 168 Descr~pt¡()n I I I I I Item 2 Bit#4 RS161 HGSW TFA=.742 PO Bias Unit Extention sub PO Control Collar *CU 252 X-OVER *Float NM STABILIZER Date In 09-Nov-02 Time In 10:00 Depth In 11,778 TVD In 9.501 Drlg Hrs 28.4 Slide Hrs 0.0 Rot Hrs 28.4 Pump Hrs 37.3 PDM Jet Bearing Rubber Sand % 0.3 Solids % 17.0 OD R/S Stages Rev/Gal Mud Wt 12.8 Mud Vis 58 Vendor SIN Hycalog 203463 8 1/2" 4x122x14 Jets Tool 4 7/16 2 3/4 2 13/1 6 2 3/4 2 3/4 2 7/8 2 3/4 Tool Tool 2 13/16 Ana 675-31-018-FC 6 3/4x 5 Ana MMFL-FA 025 6 5/8x5 1/16 2 13/16 2 13/1 6 Ana MMFL-FA 024) 11 /16x5 1/1 2 13/16 16 X-OVER Ana 3TXOS-FE 104: 6 3/4 *corrosion ring 3 Jts. HWOP 5" NAD 3 HWDP 5 BHA# 4 3 4 5 6 NM FLEX LC Ana 631-BU-60154 2476 Ana 631-CC-6001C 6 3/4 2 3/4 3 2 3/4 3 3 1/8x4 1/2 Date Out 11-Nov-02 Time Out 18:00 Depth Out 12,473 TVD Out 10,050 Drlg Ft 695 Slide Ft 0 Rot Ft 695 Rotate % 100 Inc//n 39.65 Az In 129.83 InclOut 38.94 Az Out 118.76 Avg Dls 1.3 Max Ds 1.8 RPM 160 GPM 630 Dig TQ 17K WOB 20 .~fab()D Bottom'Conn,,' :In/out . Top Con,," Hole Size 8 1.2 Hole Sect Intermediate Bha Type RSS Hrs BRT 56.00 Avg ROP 24.47 Slide ROP 0.00 Rot ROP 24.4ï Slide % 0 Bit>Srvy 75.90 TIF Carr n/a Plan Dls 0.0 Spp On 3450 spp Off 3450 . 'Le'1g~/'ì Cum Length 7 XO 6 7/8 Ana AFS301 6 1/2 1.00 1.00 8 5/16 4112 Reg P 2.10 41/2 Reg B 3.36 4.36 4 1/2 IF B 41/2 IF B 9.70 14.06 4 1/2 IF B 41/21FP 1.35 15.41 4 112 XH B 2.45 41/2 XH P 5.62 21.03 41/2XHB 4112 XH P 11.40 32.43 4 112 XH B 41/2XHP 2.18 34.61 41/2 IF B 1.30 4 1/2 IF P 3.87 38.48 41/2 IF B 4 1/2 IF P 1.38 39.86 4 1/2 XH B 4 1/2 XH P 22.33 62.19 5 1/2 FH B 2.51 51/2 FH P 28.64 90.83 4 1/2 XH B 2.42 41/2 XH P 5.70 96.53 41/2XHB 2.50 41/2 XH P 30.98 127.51 4 1/2 XH B 2.50 41/2 XH P 31.01 158.52 41/2 XH B 2.53 41/2 XH P 30.96 189.48 41/2 XH B 41/2 XH P 1.98 191.46 4 1/2 IF B 4 1/2 IF P 90.40 281.86 4 1/2 IF B 1.70 4112 IF P 32.62 314.48 4 1/2 IF B 4 1/2 IF P 690.99 1005.4 7 4 112 IF B 4 1/2 IF P 2.37 1007.84 4 112 IF B Bit Data Tool Hrs. In Hrs. Out IADC # POC Motor 37.3 Footage 695 Jars 88.7 117.1 Hrs 28.4 Bit #4 0.0 28.4 k Revs 273 k RSS 0.0 37.3 Grade 1-1-WT-A-X-I-NO-PR. No balling at surface Comment NBR: O-O-NO-X-I-NO-PR. New condition. Ana JMSZSS-FA 01 6 3/4 Ana 575-31·004-FL< 6 15/16 Ana STXOS-FE086 6 9/16 8 9" NBR Security 910732103 6 3/4 shear @ 590 psi XO Ana STLFS-HH-30C 6 3/8 8 1/2 8 1/2 BHA and Run Objective Orill di.~~tiC'.nal plan to 7:'_~~y~__ BHA Weight Dry Wi 58,089 BHA and Run Results 10id not drill to_.~~~~l'n~~~~.?_~I~~___._,_ Buoyed Wi 46,763 ROP. RSS Bha generated 1.5/100 DLS at 40% setting. Incl Angle 38 Why POOH / Comments I P<?OH l~~_~_i~~~~~~._R~~~_~~_~_~~.~~~'2-g~_ Buoy+lncl Wi 36,850 RSS performed excellent, no shock. ECO steady 13.9 throughout run. P/U OS- 70 bit. Bit To Re$=45.66', GR=56.66', PWD=47.41', 0&1=75.90' 9 10 COR (PWO) 11 MWO *filter NM STABILIZER 12 13 NM FLEX 14 NM FLEX 15 NM FLEX 17 Ana 7125 6 3/4 Ana 860 6 3/4 Ana JMSZSS-FA-OC 6 3/4 18 HYO JARS DAILEY 1416-1562 6 1/2 23 Jts. HWOP 5" NAD 23 HWOP 5 19 Oart Valve Sub BPX CM7996 6 3/4 20 V~'!r J-¡)2 Schlumberger BHA# 5 Job H 40008135 Date In 11-Nov-02 Date Out 13-Nov-02 Hole Size 8 1/2 Customer BP ADW Time In 18:00 Time Out 13:00 Hole Sect Intermediate Well NS19 Depth In 12,473 Depth Out 13.500 Bha Type RSS Field Northstar TVD In 10,050 TVD Out 10,856 Hrs BRT 43.00 Rig Nabors 33E Drlg Hrs 15.5 Drlg Ft 1,027 Avg ROP 66.26 AFE H NSD-831331 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0.00 DD's Rinke / Levad Rot Hrs 15.5 Rot Ft 1,027 Rot ROP 66.26 Co. Men Kidd / Dinger / Clump Pump Hrs 22.2 Rotate % 100 Slide % 0 PDM Run H n/a R/S PDM Jet Inclln 38.94 Az In 118.76 Bit>Srvy 75.90 PDM SerH Stages Bearing Incl Out 38.75 Az Out 126.33 T/F Carr n/o PDM Size Rev/Gal Rubber Avg Dls 1.0 Max Ds 2.4 Plan Dls 0.0 Mud Type Polymer Mud Wt 12.8 Sand % .3 RPM 160 GPM 620 SPP On 4100 BHT F 188 Mud Vis 56 Solids % 17.3 DIg TQ 22.0 WOB 22 SPP Oft 4100 Item Description Vendor . 00 StabOD F.N. Bottom Conn. . Leng~~." Cum Length In I Out TopCann Bit#5DS70FNPV Hycalog 201573 8 1/2 4x122x14 1.00 1.00 TFA=.742 Jets 4 1/2 Reg P 2 PO Bias Unit Ana 631-BU-60154 6 3/4 Tool 8 5/16 2.10 4 1/2 Reg B 3.36 4.36 Extention sub 2476 4 1/2 IF B I 3 PO Control Collar Ana 631-CC-600 1 C 6 7/8 4 7/16 4 1/2 IF B 9.70 14.06 *CU 252 4 1/2 IF B 4 X·OVER Ana AFS301 6 1/2 2 3/4 4 1/2 IF P 1.35 15.41 I *Float 4 1/2 XH B 5 NM STABILIZER Ana JMSZSS-FA 01 6 3/4 2 13/16 8 1/2 2.45 41/2XH P 5.62 21.03 41/2XHB 6 NM FLEX LC Ana 375-31-004-FL< 6 15/16 2 3/4 41/2XHP 11 .40 32.43 I 41/2XHB 7 XO Ana STXOS-FE08E 6 9/16 2 3/4 4 1/2 XH P 2.18 34.61 41/2 IF B I 8 9" NBR Security 910732103 6 3/4 2 7/8 1.30 4 1/2 IF P 3.87 38.48 shear @ 590 psi 4 1/2 IF B 9 XO Ana STLFS-HH-30C 6 3/8 2 3/4 41/2 IF P 1.38 39.86 4 1/2 XH B I 10 COR (PWD) Ana 7125 6 3/4 Tool 4 1/2 XH P 22.33 62.19 5 1/2 FH B 11 MWD Ana 860 6 3/4 Tool 2.51 5 1/2 FH P 28.64 90.83 I *filter 41/2XHB 12 NM STABILIZER Ana IMSZSS-FA-OC 6 3/4 2 13/16 8 1/2 2.42 41/2XHP 5.70 96.53 4 1/2 XH B 13 NM FLEX Ana 675-31-018-FC 6 3/4x 5 2 13/16 2.50 4 1/2 XH P 30.98 127.51 4 1/2 XH B 14 NM FLEX Ana MMFL-FA 025 6 5/8x5 1/16 2 13/16 2.50 4 1/2 XH P 31.01 158.52 41/2XH B 15 NM FLEX Ana MMFL-FA 024) 11 /16x5 1/1 2 13/16 2.53 41/2XH P 30.96 189.48 4 1/2 XH B 16 X-OVER Ana STXOS-FE 104: 6 3/4 2 3/4 4 1/2 XH P 1.98 1 91 .46 ·corrosion ring 4 1/2 IF B 17 3 Jts. HWDP 5" NAD 3 HWDP 5 3 4 1/2 IF P 90.40 281.86 4 1/2 IF B 18 HYD JARS DAILEY 1416-1562 6 1/2 2 3/4 1.70 4 1/2 IF P 32.62 314.48 4 1/2 IF B 19 23 Jts. HWDP 5" NAD 23 HWOP 5 3 4 1/2 IF P 690.99 1005.47 4 1/2 IF B 20 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF P 2.37 1007.84 4 1/2 IF B BHA and Run Objective Drill directional plan to 7" csg pnt. BHA Weight Bit Data Tool Hrs. In Hrs. Out ___.'_.____~__k_.____.._,,___.,,_..~',.,______..____.._,___.___...__ Used bit. Dry Wt 58.114 IADC # PDC Motor 22.2 BHA and Run Results I Reached pl~.l1..n_~~_~g:"___'___'_h___'______'_' Buoyed Wt 46.783 Footage 1,027 Jars 117.1 132.6 þ RSS Bha yielded 1.5/100 OLS at 40% setting. Incl Angle 40 Hrs 15.5 Bit #5 15.5 Why POOH / Comments I POOH for TO. Good run. Buoy+lncl Wt 35,838 k Revs 149 k RSS 37.3 59.5 ---..--'~--~_._-"..~_.~~-~...~-~-.---.--.. OS-70 bit gave same OLS as RSS-specific bits. Grade 1-0-WT-C-X-I-PJ-TD Bit To IRe~=45.66', GR=56.66'. PWO=47.41', 0&1=75.90' Comment NBR:8-8-8 Gunk) BHA #: 1 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Depth In: 201.00 Inclination In: 2.09 Azimuth In: 79.21 Depth Out: 330.00 Inclination Out: 1.88 Azimuth Out: 80.40 I Total ROP: 209.2 Comments: I I Md From I (ft) 201.00 237.00 269.00 Md To I Rot/Slid I Duration I Course I (It) (A/S) (hr:min) (ft) 237.00 A 0:12 36.00 269.00 S 0:05 32.00 330.00 A 0:20 61.00 I I NS 19_ Shas.xls Slide Sheet Well: NS-19 Borehole: NS 19 UWUAPI#: Tot Distance: 129.00 Dist Steering: 32.00 Dist Rotating: 97.00 % Steer: 24.8 % Rot: 75.2 Steering ROP: 384.0 TF (0) I Flow ISPP On BISPP Off BI WOB I (gal/min) (psi) (psi) I (1000 Ibf) 650 700 680 5.0 650 710 680 10.0 685 780 750 10.0 M 110 Page 1 of 1 Directional Driller: James Tunnell Directional Driller: Keith Starr Job #: Total Time: 0.6 Time Steering: 0.1 Time Rotating: 0.5 Rotating ROP: 181.9 RPM Torq on, Svy Md I (c/min) I (ft) 50 2 o 0 250.00 50 3 % Steer: 13.5 % Rot: 86.5 Incl I Azmth I DLS I (0) (0) (°/100 ft) 2.09 79.21 0.74 12/9/02-3:39 PM 12/9/02-3:39 PM Page 1 of 2 NS 19_ Shas.xls BHA #: 2 Slide Sheet Client: BP Exploration Alaska Well: NS-19 Directional Driller: James Tunnell Field: Northstar Borehole: NS19 Directional Driller: Keith Starr Structure: Northstar PF UWVAPI#: Job #: r Depth In: 330.00 Depth Out: 3426.00 Tot Distance: 3096.00 Total Time: 19.3 Inclination In: 2.40 Inclination Out: 38.46 Dist Steering: 1082.00 % Steer: 34.9 Time Steering: 7.5 % Steer: 39.1 Azimuth In: 86.37 Azimuth Out: 160.39 Dist Rotating: 2014.00 % Rot: 65.1 Time Rotating: 11.7 % Rot: 60.9 Total ROP: 160.8 Steering ROP: 143.6 Rotating ROP: 171.9 Comments: I I Md From I Md To I Rot/Slid I Duration I Course I TF I Flow ISPP On BISPP Off' WOB I RPM forq on, Svy Md I Incl I Azmth I DLS I (It) (It) (RIS) (hr:min) (ft) (0) (gal/min) (psi) (psi) (1000Ibf) (c/min) (ft) n (0) (0 I 100 ft) 330.00 369.00 R 0:11 39.00 --- 685 1050 1000 10.0 50 3 369.00 399.00 S 0:03 30.00 M 120 695 1080 1050 10.0 0 0 380.00 2.40 86.37 0.63 I 399.00 460.00 R 0:12 61.00 --- 695 1080 1050 10.0 50 3 460.00 2.52 88.18 0.18 460.00 550.00 R 0:37 90.00 _u 700 1100 1080 10.0 50 3 550.00 580.00 S 0:10 30.00 M 115 700 1280 1200 15.0 0 0 570.00 3.08 98.00 0.67 580.00 640.00 R 0:17 60.00 --- 700 1280 1200 15.0 50 3 640.00 670.00 S 0:05 30.00 M90 700 1320 1300 15.0 0 0 660.00 3.99 98.18 1.01 670.00 730.00 R 0:30 60.00 --- 700 1320 1280 15.0 50 3 730.00 760.00 S 0:15 30.00 G -4 700 1330 1310 15.0 0 0 750.00 4.71 97.46 0.80 760.00 820.00 R 0:26 60.00 --- 700 1340 1300 15.0 50 3 I 820.00 850.00 S 0:09 30.00 G ·22 700 1410 1370 15.0 0 0 840.00 5.21 96.01 0.57 850.00 910.00 R 0:19 60.00 --- 700 1440 1340 15.0 50 4 910.00 950.00 S 0:14 40.00 GO 700 1450 1410 15.0 0 0 930.00 5.45 93.63 0.36 950.00 1000.00 R 0:15 50.00 --- 700 1460 1410 15.0 50 5 1000.00 1045.00 S 0:09 45.00 GO 700 1440 1360 15.0 0 0 1021.00 6.21 95.40 0.86 1045.00 1092.00 , R 0:15 47.00 _u 700 1470 1360 15.0 50 5 1092.00 1137.00 S 0:23 45.00 G -10 700 1450 1440 15.0 0 0 1116.00 8.16 94.20 2.06 I 1137.00 1187.00 R 0:36 50.00 --- 700 1470 1440 15.0 50 6 1183.00 8.78 94.22 0.93 1187.00 1281.00 R 0:52 94.00 --- 700 1460 1410 15.0 50 6 1210.00 7.97 95.63 3.09 1281.00 1326.00 S 0:36 45.00 G 14 700 1460 1410 15.0 0 0 1304.00 8.33 96.03 0.39 1326.00 1374.00 R 0:28 48.00 _u 700 1460 1410 15.0 50 6 1374.00 1416.00 S 0:44 42.00 G26 700 1430 1420 20.0 0 0 1398.00 8.56 100.08 0.68 1416.00 1469.00 R 0:34 53.00 ... 700 1450 1420 20.0 50 7 1465.00 9.22 101.80 1.06 1469.00 1529.00 S 0:30 60.00 G 20 700 1590 1420 35.0 0 0 1493.01 10.01 104.71 3.31 1529.00 1564.00 R 0:11 35.00 .-. 700 1590 1420 30.0 50 6 1564.00 1604.00 S 0:09 40.00 G ·20 910 2170 2070 25.0 0 0 1587.65 12.78 108.05 3.01 1604.00 1658.00 R 0:12 54.00 .-. 910 2170 2070 15.0 50 6 1658.00 1698.00 S 0:09 40.00 G -30 900 2130 2080 15.0 0 0 1681.42 13.42 101.86 1.64 1698.00 1752.00 R 0:12 54.00 --- 900 2150 2050 15.0 50 6 1752.00 1792.00 S 0:07 40.00 GO 1000 2400 2350 20.0 0 0 1775.63 15.12 102.66 1.82 1792.00 1847.00 R 0:08 55.00 .n 1100 1820 2780 10.0 50 6 1847.00 1887.00 S 0:08 40.00 GO 1000 2720 2500 25.0 0 0 1869.88 15.99 104.49 1.06 1887.00 1917.00 R 0:12 30.00 n_ 1100 3000 2950 20.0 50 6 1917.00 1941.00 R 0:04 24.00 n_ 850 2050 1900 20.0 50 6 1941.00 1986.00 S 0:06 45.00 G 25 850 2050 1900 25.0 0 0 1966.27 16.92 108.72 1.57 1986.00 2035.00 R 0:13 49.00 --- 850 2000 1900 20.0 50 7 2035.00 2065.00 S 0:07 30.00 G 40 850 2000 1900 30.0 0 0 2059.33 17.91 118.27 3.25 2065.00 2095.00 R 0:05 30.00 _n 850 2050 1900 20.0 50 8 2095.00 2125.00 S 0:05 30.00 G 50 850 2000 1900 25.0 0 0 2125.00 2131.00 R 0:01 6.00 n. 850 2000 1900 25.0 50 8 2131.00 2161.00 S 0:04 30.00 G 50 850 2050 1900 25.0 0 0 2154.13 20.60 128.78 4.62 2161.00 2191.00 R 0:04 30.00 n. aso 2000 1900 25.0 50 8 12/9/02-3:39 PM Page 2 of 2 NS 19_ Bhas.xls I 2191.00 2211.00 S 0:05 20.00 G 45 850 2050 1900 25.0 0 0 2211.00 2225.00 R 0:06 14.00 n. 850 2000 1920 25.0 50 8 2225.00 2265.00 S 0:12 40.00 G 70 850 2180 1970 25.0 0 0 2247.86 22.17 138.21 4.03 2265.00 2319.00 R 0:07 54.00 n_ 850 2030 1970 20.0 50 8 2319.00 2349.00 S 0:06 30.00 G 45 850 2150 2000 25.0 0 0 2341.31 23.68 144.61 3.12 2349.00 2412.00 R 0:19 63.00 .-- 850 2150 2000 25.0 50 7 I 2412.00 2442.00 S 0:14 30.00 G45 850 2150 2000 25.0 0 0 2436.82 23.72 150.58 2.51 2442.00 2507.00 R 0:17 65.00 _n 850 2150 2000 30.0 50 8 2507.00 2537.00 S 0:13 30.00 GO 850 2140 2070 40.0 0 0 2531.73 25.59 154.31 2.56 I 2537.00 2602.00 R 0:20 65.00 --- 850 2150 2070 30.0 50 10 2602.00 2632.00 S 0:15 30.00 GO 850 2220 2100 45.0 0 0 2627.47 27.59 156.76 2.38 2632.00 2697.00 R 0:13 65.00 _n 850 2250 2100 40.0 50 12 2697.00 2791.00 R 0:35 94.00 _n 850 2250 2080 40.0 50 12 2719.67 28.18 158.16 0.96 2791.00 2821.00 S 0:15 30.00 G -20 850 2340 2320 40.0 0 0 2813.28 29.62 157.37 1.59 2821.00 2885.00 R 0:25 64.00 n_ 850 2330 2210 40.0 50 12 2885.00 2915.00 S 0:12 30.00 GO 850 2180 2100 25.0 0 0 2907.38 31.04 159.28 1.82 2915.00 2979.00 R 0:11 64.00 --- 850 2240 2120 30.0 50 12 I 2979.00 3009.00 S 0:14 30.00 G -30 750 1840 1770 20.0 0 0 3001.93 33.23 158.59 2.35 3009.00 3073.00 R 0:16 64.00 _n 850 2230 2120 35.0 50 12 3073.00 3103.00 S 0:19 30.00 G -10 850 2220 2130 20.0 0 0 3096.32 35.33 159.01 2.24 3103.00 3167.00 R 0:13 64.00 --- 850 2240 2120 35.0 50 12 3167.00 3197.00 S 0:35 30.00 G -15 850 2250 2140 25.0 0 0 3190.07 37.48 158.75 2.30 3197.00 3260.00 R 0:26 63.00 -.. 850 2260 2140 25.0 50 14 3260.00 3290.00 S 0:39 30.00 G8 850 2260 2140 35.0 0 0 3283.35 39.51 159.73 2.27 I 3290.00 3354.00 R 0:37 64.00 .-- 850 2260 2150 35.0 50 14 3354.65 38.46 160.39 1.58 3354.00 3426.00 R 0:44 72.00 n_ 850 2260 2150 35.0 50 14 3426.00 38.46 160.39 0.00 12/9/02-3:39 PM Page 1 of 2 NS19_ Bhas.xls BHA #: 3 Slide Sheet Schlumberger Client: BP Exploration Alaska Well: NS-19 Directional Driller: Rinke Field: Northstar Borehole: NS19 Directional Driller: Starr Structure: Northstar PF UWI/API#: 50-029-23122-00 Job #: Depth In: 3426.00 Depth Out: 11778.00 Tot Distance: 8352.00 Total Time: 64.5 Inclination In: 37.26 Inclination Out: 39.65 Dist Steering: 0.00 % Steer: 0.0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 162.54 Azimuth Out: 129.83 Dist Rotating: 8352.00 % Rot: 100.0 Time Rotating: 64.5 % Rot: 100.0 Total Rap: 129.6 Steering Rap: 0.0 Rotating Rap: 129.6 Comments: 1 Duration 1 Md From 1 Md To I Avg Rap I Rot/Slid I RSS 1 TF 1 WOB 1 RPM forq on, Flow ISPP On BI Svy Md I Incl 1 Azmth I DLS I (hr:min) (ft) (ft) (ft/h) (RlS) SETTING (0) (1000Ibf) (cJmin) K ft/Is (qal/min) (ft) (0) (0) (0 / 1 00 ft) 0:24 3426.00 3446.00 50.0 R 0/0% --- 10.0 60 7 800 1800 0:48 3446.00 3536.00 112.5 R --- 10.0 100 7 1000 1700 3473.16 37.26 162.54 1.50 0:20 3536.00 3630.00 282.0 R _n 10.0 100 7 1060 1800 3567.79 37.27 163.28 0.47 I 0:11 3630.00 3724.00 512.7 R 326/ 20% _n 10.0 100 8 1060 1800 3660.71 38.34 163.19 1.15 0:16 3724.00 3818.00 352.5 R _u 10.0 100 9 1060 1800 3754.81 39.58 160.84 2.05 0:21 3818.00 3911.00 265.7 R --- 10.0 100 10 1060 1820 3848.72 40.19 158.98 1.43 0:22 3911.00 4006.00 259.1 R 36/20% --- 10.0 120 10 1060 1840 3942.86 40.72 159.91 0.85 0:17 4006.00 4100.00 331.8 R n_ 10.0 140 12 1060 1860 4036.84 41.28 160.34 0.67 0:25 4100.00 4194.00 225.6 R _n 10.0 140 12 1060 1910 4131.09 41.84 160.36 0.59 0:18 4194.00 4287.00 310.0 R _a. 10.0 140 12 1060 1980 4224.22 42.59 160.05 0.84 I 0:14 4287.00 4382.00 407.1 R --- 10.0 120 12 1060 2000 4318.90 42.86 161.96 1.40 0:27 4382.00 4475.00 206.7 R --- 10.0 120 12 1060 2020 4412.65 43.77 162.13 0.98 0:18 4475.00 4569.00 313.3 R 67/40% --- 10.0 120 12 1060 2090 4506.27 44.22 163.49 1.12 0:21 4569.00 4663.00 268.6 R ..- 10.0 120 12 1060 2080 4599.95 45.09 164.89 1.40 0:13 4663.00 4756.00 429.2 R 108/20% --- 10.0 120 12 1060 2090 4693.76 46.10 165.11 1.09 0:15 4756.00 4850.00 376.0 R 135/40% --- 10.0 120 12 1060 2090 4787.05 46.36 165.11 0.28 0:16 4850.00 4945.00 356.3 R --- 10.0 120 12 1060 2090 4881.38 45.74 165.60 0.76 I 0:17 4945.00 5039.00 331.8 R --- 10.0 120 12 1060 2120 4976.56 44.98 167.22 1.45 0:20 5039.00 5132.00 279.0 R --- 10.0 120 12 1060 2230 5069.27 43.80 168.88 1.79 0:17 5132.00 5227.00 335.3 R --. 10.0 125 12 1060 2220 5163.16 43.52 169.31 0.43 0:30 5227.00 5320.00 186.0 R n_ 10.0 125 12 1060 2180 5256.99 42.40 17Q.68 1.55 0:37 5320.00 5414.00 152.4 R 202/ 40% --- 10.0 140 12 1060 2200 5351.82 41.30 171.11 1.20 0:35 5414.00 5508.00 161.1 R -.- 10.0 140 12 1060 2200 5445.49 40.56 170.36 0.95 0:32 5508.00 5603.00 178.1 R 254/20% --- 10.0 140 12 1060 2250 5538.70 40.48 170.12 0.19 0:28 5603.00 5696.00 199.3 R _n 10.0 140 12 1050 2250 5632.17 40.79 169.43 0.58 0:18 5696.00 5789.00 310.0 R --- 10.0 140 12 1050 2250 5725.79 41.01 168.03 1.01 0:21 5789.00 5884.00 271.4 R --- 10.0 140 12 1050 2300 5819.58 41.44 167.72 0.51 0:21 5884.00 5978.00 268.6 R .-- 10.0 140 12 1050 2300 5914.48 41.69 166.63 0.81 0:20 5978.00 6072.00 282.0 R --- 10.0 140 12 1050 2350 6008.43 41.92 166.57 0.25 0:29 6072.00 6166.00 194.5 R 217 / 20% ..- 10.0 140 12 1050 2350 6103.89 42.15 166.21 0.35 0:30 6166.00 6260.00 188.0 R --- 10.0 140 12 1050 2400 6196.60 41.66 165.63 0.67 1:12 6260.00 6354.00 78.3 R n_ 10.0 140 12 1050 2400 6291.19 41.26 165.39 0.46 0:42 6354.00 6448.00 134.3 R _a. 10.0 140 12 1050 2400 6385.20 41.04 164.89 0.42 0:43 6448.00 6542.00 131.2 R --- 10.0 140 12 1050 2400 6479.36 40.60 164.31 0.62 0:55 6542.00 6636.00 102.5 R --- 10.0 140 12 1050 2400 6573.13 40.19 163.89 0.52 1 :44 6636.00 6730.00 54.2 R --- 10.0 140 12 1050 2400 6667.61 40.22 162.97 0.63 0:26 6730.00 6825.00 219.2 R --- 10.0 140 12 1050 2400 6762.57 40.17 162.28 0.47 0:48 6825.00 6918.00 116.3 R 0/0% __a 10.0 140 13 1050 2450 6855.33 40.01 161.23 0.75 1:00 6918.00 7012.00 94.0 R .n 10.0 140 13 1050 2450 6949.00 40.12 160.92 0.24 2:14 7012.00 7105.00 41.6 R --. 10.0 140 13 1050 2500 7043.00 40.63 161.42 0.64 2:12 ¡105.00 7199.00 42.7 R n_ 10.0 140 14 1050 2500 7134.ô2 40.85 161.45 0.24 0:51 7199.00 7292.00 109.4 R --- 10.0 140 14 1050 2500 7228.81 41.07 161.54 0.24 1:11 7292.00 7386.00 79.4 R _n 10.0 140 14 1050 2600 7321.81 41.14 161.59 0.08 12/9/02-3:39 PM Page 2 of 2 NS 19 _ Bhas.xls ! f ( 0:55 7386.00 7479.00 101.5 R n_ 10.0 140 14 1050 2600 7415.55 41.35 161.37 0.27 1:01 7479.00 7573.00 92.5 R 71/20% n_ 10.0 125 14 1050 2780 7510.23 41.62 161.16 0.32 I 1:34 7573.00 7667.00 60.0 R on 10.0 120 14 1050 2800 7603.68 41.96 161.75 0.56 2:25 7667.00 7761.00 38.9 R on 15.0 120 14 1050 2850 7698.13 42.18 162.25 0.42 0:37 7761.00 7854.00 150.8 R n' 15.0 140 14 1050 2900 7791.61 42.49 163.35 0.86 0:36 7854.00 7948.00 156.7 R --. 15.0 140 15 1050 2900 7885.86 42.73 164.54 0.89 0:40 7948.00 8043.00 142.5 R 143 / 20% --. 15.0 140 15 1050 2900 7980.62 42.80 164.87 0.25 0:42 8043.00 8138.00 135.7 R n_ 15.0 140 15 1050 2900 8074.92 42.29 165.36 0.64 0:36 8138.00 8233.00 158.3 R --. 15.0 140 15 1050 2900 8170.10 41.63 165.89 0.79 0:51 8233.00 8327.00 110.6 R 180 / 20% -.- 15.0 140 15 1050 2900 8264.15 41.35 165.93 0.30 I 0:32 8327.00 8420.00 174.4 R ... 15.0 140 15 1050 2900 8356.74 40.86 165.98 0.53 0:29 8420.00 8515.00 196.6 R ..- 15.0 140 15 1050 2900 8451.07 40.35 165.62 0.59 0:46 8515.00 8608.00 121.3 R --. 15.0 140 15 1050 3020 8545.98 39.75 165.31 0.67 0:35 8608.00 8702.00 161.1 A .-- 20.0 140 15 1050 3200 8639.74 39.07 164.88 0.78 0:37 8702.00 8796.00 152.4 R 0/0% --- 20.0 160 17 1050 3220 8733.61 38.53 164.95 0.58 0:35 8796.00 8889.00 159.4 R ... 20.0 160 17 1050 3230 8827.51 38.08 164.87 0.48 0:30 8889.00 8984.00 190.0 A -.- 20.0 160 17 1050 3250 8921.50 37.58 165.28 0.60 I 0:14 8984.00 9033.00 210.0 A ... 20.0 160 17 1050 3230 9015.74 37.08 165.13 0.54 0:17 9033.00 9077.00 155.3 R ... 20.0 160 17 1050 3230 0:35 9077.00 9171.00 161.1 R 326/20% .-. 20.0 160 18 1050 3300 9107.66 36.72 165.47 0.45 0:35 9171.00 9265.00 161.1 R --. 20.0 160 18 1050 3330 9200.89 36.84 165.74 0.22 0:44 9265.00 9358.00 126.8 R 315/40% ... 20.0 160 18 1050 3250 9294.74 36.75 165.65 0.11 0:25 9358.00 9452.00 225.6 R n' 20.0 160 18 1050 3240 9388.47 37.04 164.26 0.94 0:34 9452.00 9547.00 167.6 R n' 20.0 160 18 1050 3330 9482.66 37.27 163.13 0.76 I 0:58 9547.00 9640.00 96.2 R 0/40% ... 20.0 160 18 1050 3350 9576.82 37.56 162.03 0.77 0:32 9640.00 9734.00 176.2 R ... 20.0 160 18 1050 3350 9670.56 38.12 162.39 0.64 0:35 9734.00 9827.00 159.4 A ... 20.0 160 18 1050 3450 9766.59 38.76 163.44 0.95 0:34 9827.00 9921.00 165.9 R ... 20.0 160 18 1050 3450 9858.64 39.61 163.56 0.93 0:26 9921.00 10015.00 216.9 R .n 25.0 160 20 1050 3500 9952.13 40.03 164.95 1.05 0:28 10015.00 10110.00 203.6 R --. 30.0 160 23 1050 3500 10046.07 40.20 166.02 0.76 0:26 10110.00 10203.00 214.6 R .-. 30.0 160 23 1050 3500 10140.69 40.24 166.28 0.18 0:38 10203.00 10297.00 148.4 R 292/60% .n 30.0 160 23 1050 3200 10235.55 40.06 166.14 0.21 0:40 10297.00 10391.00 141.0 R ... 25.0 160 20 1050 3200 10327.55 39.67 163.87 1.64 1:24 10391.00 10486.00 67.9 A 315/60% .-- 15.0 160 15 900 2800 10423.98 39.96 161.63 1.52 0:30 10486.00 10580.00 188.0 A ... 25.0 160 21 1020 3800 10518.50 40.50 160.76 0.82 0:34 10580.00 10675.00 167.6 A n. 25.0 160 21 1020 3800 10613.08 41.21 159.28 1.27 0:39 10675.00 10770.00 146.2 R 299 / 80% ... 25.0 160 22 1010 3800 10706.75 41. 72 158.08 1.01 0:40 10770.00 10866.00 144.0 R .n 25.0 160 19 1010 3800 10803.10 42.44 155.77 1.77 0:38 10866.00 10961.00 150.0 A ... 25.0 160 19 1010 3800 10898.83 43.87 153.06 2.45 0:40 10961.00 11056.00 142.5 A 270/1 00% ... 25.0 160 19 1010 3800 10993.63 44.61 149.73 2.57 0:39 11056.00 11152.00 147.7 R -.. 25.0 160 19 1010 3800 11089.78 45.89 145.83 3.17 2:47 11152.00 11227.00 26.9 R 233/100% ... 15.0 80 14 1010 3800 11183.79 46.01 140.54 4.05 0:56 11227.00 11248.00 22.5 R .n 15.0 80 14 1010 3800 0:39 11248.00 11342.00 144.6 A 240/80% n. 25.0 160 19 1010 3800 11279.60 45.24 136.10 3.41 1 :32 11342.00 11435.00 60.7 A .-. 25.0 160 19 975 3800 11375.97 45.41 132.07 2.98 2:06 11435.00 11531.00 45.7 R --- 15.0 160 21 975 3800 11468.66 44.31 129.33 2.40 1:00 11531.00 11626.00 95.0 A _n 15.0 160 21 975 3800 11564.20 42.54 129.17 1.86 11660.51 40.69 129.19 1.92 0:59 11626.00 11722.00 97.6 A -.. 20.0 120 21 950 3800 11714.41 39.65 129.83 2.M 0:24 11722.00 11778.00 140.0 A --. 20.0 120 21 950 3800 12/9/02-3: 39 PM Page 1 of 1 NS19_ Shas.xls I I 38.31 119.04 38.94 118.76 18 12321.59 18 12392.29 18 17 17 150 150 150 160 160 0/60% R 12115.00 12210.00 95.00 3:06 30.6 R 12210.00 12294.00 84.00 1:59 42.4 R 12294.00 12305.00 11.00 0:26 25.4 R 12305.00 12400.00 95.00 6:50 13.9 R 12400.00 12473.00 73.00 4:04 18.0 I 0.78 0.92 14.0 15.0 15.0 15.0 20.0 3450 2950 2950 3450 3450 630 560 560 630 630 337/60% 1 Rot/Slid 1 Md From I Md To I Course I Duration 1 Avg ROP 1 TF 1 User 1 1 Flow ISPP On BI WOB 1 RPM rorq on, Svy Md I Incl 1 Azmth I DLS I (RIS) (ft) (ft) (ft) (hr:min) (ft/h) (0) (gal/min) (psi) (1000Ibf) (A) (ft) (0) (0) (0 / 100 It) R 11778.00 11798.00 20.00 2:48 7.1 n_ 293140% 520 2700 10.0 100 13 11845.13 37.92 127.97 1.60 R 11798.00 11829.00 31.00 0:58 32.1 _n 600 3350 30.0 120 17 11938.67 37.14 126.12 1.47 R 11829.00 11924.00 95.00 2:23 39.9 _n 600 3200 30.0 160 17 12035.53 37.06 123.93 1.37 R 11924.00 12019.00 95.00 1:44 54.8 _n 315/60% 615 3450 35.0 150 18 12130.52 37.45 121.12 1.84 R 12019.00 12115.00 96.00 4:06 23.4 -.. 625 3450 15.0 160 17 12227.28 38.30 120.23 1.04 I I Comments: I Rotating ROP: 24.5 Steering ROP: 0.0 Total ROP: 24.5 % Steer: 0.0 % Rot: 100.0 Total Time: 28.4 Time Steering: 0.0 Time Rotating: 28.4 % Steer: 0.0 % Rot: 100.0 Tot Distance: 695.00 Dist Steering: 0.00 Dist Rotating: 695.00 Depth Out: 12473.00 Inclination Out: 38.94 Azimuth Out: 118.76 Depth In: 11778.00 Inclination In: 37.92 Azimuth In: 127.97 Directional Driller: Rinke Directional Driller: Levad Job #: Well: NS-19 Borehole: NS19 UWI/API#: 50-029-23122-00 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Schlumbergefl Slide Sheet BHA #: 4 \1 12/9/02-3:39 PM Page 1 of 1 NS19_ Bhas.xls II BHA #: 5 Slide Sheet Schlumberger Client: BP Exploration Alaska Well: NS-19 Directional Driller: Rinke Field: Northstar Borehole: NS 19 Directional Driller: Levad Structure: Northstar PF UWI/API#: 50-029-23122-00 Job #: Depth In: 12473.00 Depth Out: 13500.00 Tot Distance: 1027.00 Total Time: 15.5 Inclination In: 40.33 Inclination Out: 38.74 Dist Steering: 0.00 % Steer: 0.0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 120.76 Azimuth Out: 126.97 Dist Rotating: 1027.00 % Rot: 100.0 Time Rotating: 15.5 % Rot: 100.0 Total ROP: 66.3 Steering ROP: 0.0 Rotating ROP: 66.3 Comments: 1 Rot/Slid 1 Md From I Md To I Course I Duration I Avg ROP 1 ·TF I RSS I Flow ISPP On BI WOB I RPM forq on, Svy Md I Incl 1 Azmth 1 DLS I (RlS) (ft) (ft) (ft) (hr:min) (ft/h) ¡oj Setting (gal/min) (psi) (1000 IbO K ftlbs (ft) (0) (0) (0 /100 ft) R 12473.00 12496.00 23.00 0:48 28.7 -.. o / 60% 615 4200 10.0 130 18 R 12496.00 12592.00 96.00 1:36 60.0 --- 0/ 40% 615 4150 15.0 160 22 12511.86 40.33 120.76 1.40 R 12592.00 12687.00 95.00 1:27 65.5 --- 71 / 20% 615 3800 20.0 160 22 12607.94 41.66 121.87 1.58 I R 12687.00 12783.00 96.00 0:40 144.0 -.. 615 3800 20.0 160 22 12703.08 40.20 122.42 1.58 R 12783.00 12877.00 94.00 2:03 45.9 ... 361 20% 615 3800 20.0 160 22 12798.78 38.54 124.11 2.06 R 12877.00 12974.00 97.00 1:10 83.1 --. 326 / 20% 615 3800 20.0 160 22 12894.01 37.73 124.29 0.86 R 12974.00 13069.00 95.00 1:23 68.7 ... 620 3650 22.0 160 22 12989.65 36.56 123.95 1.24 R 13069.00 13165.00 96.00 1:53 51.0 ... 0/40% 620 3900 22.0 160 21 13085.11 35.88 123.77 0.72 R 13165.00 13260.00 95.00 1:49 52.3 -.. 620 3950 20.0 160 21 13180.26 35.75 123.97 0.18 R 13260.00 13356.00 96.00 1:00 96.0 --. 0/80% 620 4000 22.0 160 20 13275.83 35.82 124.12 0.12 ( 13371.09 37.80 126.04 2.40 R 13356.00 13451.00 95.00 1:00 95.0 .-. 620 4050 22.0 160 20 13419.91 38.74 126.97 2.26 R 13451.00 13500.00 49.00 0:41 71.7 u. 620 4100 22.0 160 22 ( - --- .- - ..---. ~ -- ,- ~ ~ ---- --. -:;...: -- -- Customer: BP EXPLORATION ALASKA Casing Program 20 inch at 201 ft sperry-sun Well: NS19 13 3/8" inch at 3405 ft Area: BEAUFORT SEA,ALASKA 9 5/8" inch at 11753 ft Lease: NORTHST AR 1" inch at 13480 ft DRILLING SERVICES Rig: NABORS DRLG RIG 33E inch at ft Mud Company: BAROID inch at ft Bit Record Job No.: AK-AM 22173 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number In Out ftlhr % GRADE 1 1 MX-C1 6004905 16 1.031 201 330 129 0.6 215 50 4k 0 USE NEXT BHA 2 RR1 MX-C1 6004905 16 1.031 330 3426 3096 19.3 160 50 147k 35 3-2-WT-A-E-I-RG- TO 3 2 RSX238HF+GS 203404 12.25 1.090 3426 11778 8352 64.5 129 160 619k RSS 1-0-WT -C-X-I-CT - TO 4 3 RS161HGSW 203463 8.5 .742 11778 12473 695 28.4 24.5 160 273K RSS 1-1-WT-A-X-I-NO-PR 5 4 OS70FNPV 201573 8.5 .742 12473 13500 1027 15.5 66.3 160 149K RSS 1-0-WT -C-X-I-P J- TO - - -- ...-.. - - ~ .......- - - --.. ---, ~ - ~- - -~' Customer: BP ALASKA Casing Program 20" inch at 201 ft S perry-s un Well: NORTHSTAR NS19 13.375" inch at 3405 ft Area: BEAUFORT SEA, ALASKA 9.625" inch at 11753 ft lease: NORTHST AR 7" inch at 13480 ft DRILLING SERVICES Rig: NABORS DRilLING RIG 33E 4.5" inch at ft Mud Company: BAROID DRilLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22173 Depth MW Vis PV YP Gels Fltr HTHP Cake Sol Oil Water Sd CEC pH Pm I Pf / Mf Chlorides Calcium Comments Date ft Ib/gal sec LB/100 10S/10M mll30 ml@deg F 32's % % % % m¡¡efhg ppm ppm 1U/~9/U~ 1U:iU 9.U 1~1 2~ ~~ ~:i/~:i/~ I 1~.U ~ ~.ö U.U 9:i.~ ~.U 1.U ö.:i U.UU U.U:i/U.3U 1/UUU Ö4U \.mlll ng 1U/~U/U~ ~9ö1 9.~ 7:i 19 ~() ~U/3U/33 9.ö ~ I.U U.:i 9~.:i 1.~:i 7.U ö.9 U.2U U.1:i/U.ðO 17UUU ö40 ùrllllng 1U/31/U~ 342ö 9.3 4ö 14 ~ö 13/~ 9.1 ~ I.U 1.U 92.U O.:iU I.U ö.4 U.1U U.Uð/U.ðU 1 I:iUU ö4U 'kun 13 3/tS"" 11/U1/U~ 34~ö ö.ö :i:i 13 1ö ö/ö IS.~ 1 2.U U.O 9ö.U U.UU U.U 9.U U.2U U.1U/U.4O 1/ÖUU 140 I est t5UI"S 11/UZlU~ 4öOU IS.IS :i2 1~ ~U ö/lS/9 :i.U 1 3.4 1.U 9:i.ö 0.1U 1.U 9.U U.1U U.UðlU.3U 17:iUU ISUU ùrllllng 1 1/U3/U~ 7U~ð 9.U :i4 14 ~9 ö/1~/1ö 4.9 1 4.ö 1.:i 93.9 U.:iU 4.ö 1S.3 u.uu U.UU/U.ÖU 1/ÖUU IISU ùrlllmg 11/04IU~ 9U77 9.~ ö~ 13 ~4 1/1Z11ö Ö.U 1 ö.4 1.ð 9~.1 U.~U 7.U 1S.3 U.UU U.U:i/U.ÖU 1/:iUU 79U ùrllllng 1 1/Uð/U~ u.uu U.UUIU.tiU 1/ÖUU 18U ùrlllmg · 112tiU 1U.2 41 1:i 2ti 1/14/1 I 3.ö lS.ti 1 1U.U ~.:i 1S7.:i O.:iU 9.~ IS.~ 11/Uti/U~ 11/71S 1U.3 44 1~ ~ö 1S11:i/19 4.~ 1U.U 1 1U.U Z.ð IS I .:i U.~:i 9.ö lS.ö U.1U U.Uð/U.7U 1/:iUU 7UO I rlppmg 11/Uf1U~ 11/71S 1U.Ö 49 14 ~ts 9/1 :ir¿u 4.ö 1U.U 1 11.:i ~.~ ISti.U U.~:i 9.:i IS.U U.UU U.OU/U./U 11SUUU ltiU 'kun 1:1 ð/ö" 11/UIS/U~ 11771S 1U.Ö 49 14 U 1U/1:i/2U 4.1S 1U.U 1 11.:i ~.ð ISti.U U.~~ 9.U IS.U u.uu U.UU/U./U 11S0UU 71SU I est t5UI"S 11/U9/U~ 11 HIS 1U.Ö 49 14 ~ö 1U/1Ö/~U 4.1S 1U.U 1 11.5 ~.:i lSö.U U.~:i 9.U 8.U U.UU U.UUIU.70 11SUUU IISU ùrlll \;ement 11/1U/U~ 12~:iU 12.9 M ~ti 31 13/441ölS 3.4 IS.U 1 ~U.9 ~.5 lö.ti U.~:i 1S.3 1S.3 U.1U Ó.UUI1.UU ~~ouu IStiU ùrllllng 11/11/U2 124n 1~.1S :i9 ~3 39 1 1S/43/:iU 3.1S lS.ö ~ 19.9 2.ð 77.ti U.2ö I.U 1S.4 U.1:i U.1U/1.1U :i2UUU lSöU I rIppIng 11/1Z1U~ 13~UU 1~.1S :i1 ~4 34 1:i/50/ö4 4.4 1U.U 2 20.:i 3.U lö.:i U.2:i 8.U 8.4 U.U:i U.U5/1.2U :i1UUU ö40 ùrng 11/13/U2 13:iUU 12.1S :iö ~:i 32 13/4ö/öti 4.5 1U.U 2 1/.1 2.5 II.U U.~5 8.U Ö.U U.UU U.UUI1.5U 5UUUU 8~U I U 8 1/2" nOle · · - "Projections and Interpolations in Italics" 12/9/02-3:40 PM Page 1 of 3 NS 19_ Bhas.xls I " I Final Survey Client: BP Exploration Alaska Survey Computation Method: Minimum Curvature Fjeld: Northstar DLS Computation Method: Lubinski Structure: Northstar PF Vertical Section Azimuth: 1~.630' Well: N5-19 Vertical Section Origin: N 0.000 II. E 0.000 It Borehole: NS 19 TVD Reference: BoI"ehole: KB I UWVAP: 50-029-23122-00 55.3 It above MSL Date: October 31. 2002 Magnetic Declination: 26.296' Grid Convergence: 1.23170016· Total Fjeld Strength: 57523.701 nT Scale Factor: 0.99992902 Dip: 80.939· Declination Date: October 26. 2002 I Location: N 70 29 28.468, W 1484135.905 Magnetic Declination Model: BGGM 2001 N 6031001.380 IIUS, E 659828.230 nus North Reference: True North Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Coordinate Reference To: Wellhead (True) I Comment MD Incl Azlm TVD VSec NS EW Closure CIAzlm TF DLS (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0\ (0) (0/100ft) Tie-In 0.00 0.00 90.00 0.00 0.00 0.00 0.00 0.00 0.00 52.6 M Gyro 50.00 0.65 52.60 50.00 -0.03 0.17 0.23 0.28 52.60 54.5 M 1.30 I Gyro 100.00 1.07 54.47 99.99 -0.11 0.62 0.83 1.03 53.44 68.9 M 0.84 Gyro 150.00 2.21 68.85 149.97 0.00 1.23 2.11 2.44 59.66 74.7 M 2.41 Gyro ' 169.00 2.35 74.71 168.96 0.16 1.47 2.83 3.19 62.53 69.0M 1.43 Gyro 200.00 2.03 68.98 199.93 0.42 1.83 3.95 4.36 65.10 79.2 M 1.25 ( Gyro 250.00 2.09 79.21 249.90 0.87 2.32 5.67 6.13 67.74 80.4 M 0.74 Gyro 290.00 1.88 80.40 289.88 1.34 2.57 7.04 7.49 69.95 86.4 M 0.53 Gyro 380.00 2.40 86.37 379.82 2.71 2.93 10.37 10.78 74.21 88.2 M 0.63 Gyro 460.00 2.52 88.18 459.74 4.31 3.10 13.80 14.15 77.36 98.0M 0.18 I Gyro 570.00 3.08 98.00 569.61 7.30 2.76 19.15 19.35 81.79 98.2 M 0.67 Gyro 660.00 3.99 98.18 659.44 10.75 1.98 24.64 24.72 85.41 97.5 M 1.01 Gyro 750.00 4.71 97.46 749.18 14.97 1.05 31.40 31.42 88.08 96.0 M 0.80 Gyro 840.00 5.21 96.01 838.84 19.66 0.15 39.13 39.13 89.79 -43.8 G 0.57 Gyro 930.00 5.45 93.63 928.45 24.47 -0.55 47.46 47.46 90.67 14.2 G 0.36 Gyro 1021.00 6.21 95.40 1018.98 29.77 -1.29 56.67 56.69 91.30 -5.0 G 0.86 Gyro 1116.00 8.16 94.20 1113.23 36.59 -2.27 68.51 68.55 91.89 O.OG 2.06 Gyro 1183.00 8.78 94.22 1179.50 42.20 -2.99 78.36 78.41 92.19 166.5 G 0.93 ( Gyro 1210.00 7.97 95.63 1206.21 44.47 -3.33 82.27 82.34 92.31 9.1 G 3.09 Gyro 1304.00 8.33 96.03 1299.26 52.34 -4.68 95.53 95.65 92.80 70.9G 0.39 Gyro 1398.00 8.56 100.08 1392.24 60.92 -6.62 109.19 109.39 93.47 22.8G 0.68 Gyro 1465.00 9.22 101.80 1458.44 67.76 -8.59 119.35 119.66 94.12 33.0G 1.06 MWD Corrected Surveys 1493.01 10.01 104.71 1486.05 70.99 -9.67 123.91 124.28 94.46 15.0G 3.31 MWD Corrected Surveys 1587.65 12.78 108.05 1578.82 84.64 -15.00 141.82 142.61 96.04 -68.5 G 3.01 MWD Corrected Surveys 1681.42 13.42 101 .86 1670.15 99.71 -20.45 162.33 163.61 97.18 7.0G 1.64 MWD Corrected Surveys 1775.63 15.12 102.66 1761.45 115.45 -25.39 185.02 186.75 97.81 30.3G 1.82 MWD Corrected Surveys 1869.88 15.99 104.49 1852.25 132.99 -31.33 209.58 211.91 98.50 54.2G 1.06 MWD Corrected Surveys 1966.27 16.92 108.72 1944.70 152.96 -39.16 235.72 238.95 99.43 75.5 G 1.57 MWD Corrected Surveys 2059.33 17.91 118.27 2033.51 175.42 -50.28 261.15 265.95 100.90 57.2 G 3.25 MWD Corrected Surveys 2154.13 20.60 128.78 2123.02 203.46 -67.64 287.01 294.87 103.26 69.9 G 4.62 MWD Corrected Surveys 2247.86 22.17 138.21 2210.32 236.22 -91.16 311.65 324.71 106.30 61.8 G 4.03 MWD Corrected Surveys 2341.31 23.68 144.61 2296.40 272.20 -119.61 334.28 355.03 109.69 91.8 G 3.12 MWD Corrected Surveys 2436.82 23.72 150.58 2383.87 310.52 -151.99 354.82 386.00 113.19 41.5 G 2.51 MWD Corrected Surveys 2531.73 25.59 154.31 2470.13 350.05 -187.09 373.09 417.37 116.63 29.8 G 2.56 MWD Corrected Surveys 2627.47 27.59 156.76 2555.74 392.66 -226.10 390.80 451.50 120.05 48.6 G 2.38 MWD Corrected Surveys 2719.67 28.18 158.16 2637.24 435.37 -265.93 407.33 486.45 123.14 -15.2 G 0.96 MWD Corrected Surveys 2813.28 29.62 157.37 2719.19 480.16 -307.80 424.45 524.31 125.95 35.0 G 1.59 MWD Corrected Surveys 2907.38 31.04 159.28 2800.41 527.12 -351.96 441.98 565.00 128.53 -9.8 G 1.82 MWD Corrected Surveys 3001.93 33.23 158.59 2880.47 576.75 -398.88 460.07 608.91 130.93 6.6 G 2.3.5 MWD Corrected Surveys 3096.32 35.33 159.01 2958.46 629.23 -448.45 479.29 656.37 133.10 -4.2 G 2.24 MWD Corrected Surveys 3190.07 37.48 158.75 3033.91 684.14 -500.35 499.34 706.88 135.06 17.1 G 2.30 MWD Corrected Surveys 3283.35 39.51 159.73 3106.91 741.38 -554.64 519.91 760.21 136.85 158.7 G 2.27 MWD Corrected Surveys 3354.65 38.46 , 60.39 3162.33 785.50 -596.80 535.21 801.63 138.11 133.1 G 1.58 MWD Corrected Surveys 3473.16 37.26 162.54 3255.90 856.68 -665.75 558.34 868.89 140.01 89.0 G 1.50 MWD Corrected Surveys 3567.79 37.27 163.28 3331.21 912.44 -720,51 575.18 921.94 141.40 -3.0 G 0.47 "Projections and Interpolations in Italics" 12/9/02-3:40 PM Page 2 of 3 NS 19_ Shas.xls Comment MD Incl Azlm TVD VSec NS EW Closure CIAzim TF DLS (ft) (0\ (0\ (In (ft) (ft) (11) (It) (') (0) (0/100m I MWD Corrected Surveys 3660.71 38.34 163.19 3404.63 967.80 -775.05 591.61 975.04 142.64 -50.9 G 1.15 MWD Corrected Surveys 3754.81 39.58 160.84 3477.80 1025.59 -831.31 609.89 1031.04 143.73 -63.6 G 2.05 MWD Corrected Surveys 3848.72 40.19 158.98 3549.86 1084.84 -887.86 630.58 1089.00 144.62 49.1 G 1.43 MWD Corrected Surveys 3942.86 40.72 159.91 3621.50 1145.02 -945.05 652.02 1148.15 145.40 26.9 G 0.85 MWD Corrected Surveys 4036.84 41.28 160.34 3692.42 1205.65 -1003.04 672.98 1207.89 146.14 1.4 G 0.67 f MWD Corrected Surveys 4131.09 41.84 160.36 3762.95 1267.08 -1061.92 694.01 1268.59 146.83 -15.6G 0.59 MWD Corrected Surveys 4224.22 42.59 160.05 3831.92 1328.59 -1120.80 715.20 1329.55 147.46 78.9 G 0.84 MWD Corrected Surveys 4318.90 42.86 161.96 3901.48 1391.56 -1181.53 736.10 1392.07 148.08 7.4 G 1.40 MWD Corrected Surveys 4412.65 43.77 162.13 3969.69 1454.37 -1242.72 755.93 1454.57 148.69 65.0 G 0.98 MWD Corrected Surveys 4506.27 44.22 163.49 4037.04 1517.68 -1304.84 775.14 1517.71 149.29 49.0 G 1.12 MWD Corrected Surveys 4599.95 45.09 164.89 4103.68 1581.40 -1368.19 793.07 1581.42 149.90 8.9G 1.40 MWD Corrected Surveys 4693.76 46.10 165.11 4169.32 1646.03 -1432.92 810.42 1646.22 150.51 0.0 G 1.09 MWD Corrected Surveys 4787.05 46.36 165.11 4233.86 1710.95 -1498.02 827.73 1711 .49 151.08 150.5 G 0.28 MWD Corrected Surveys 4881.38 45.74 165.60 4299.32 1776.32 -1563.73 844.90 1777 .39 151.62 124.0 G 0.76 MWD Corrected Surveys 4976.56 44.98 167.22 4366.20 1841.16 -1629.55 860.82 1842.94 152.15 136.0 G 1.4.5 MWD Corrected Surveys 5069.27 43.80 168.88 4432.46 1902.69 -1692.99 874.26 1905.40 152.69 133.5 G 1.79 MWD Corrected Surveys 5163.16 43.52 169.31 4500.38 1963.80 -1756.64 886.52 1967.66 153.22 140.7 G 0.43 I MWD Corrected Surveys 5256.99 42.40 170.68 4569.05 2023.75 -1819.61 897.64 2028.97 153.74 165.5 G 1.55 MWD Corrected Surveys 5351.82 41.30 171.11 4639.69 2082.71 -1882.08 907.65 2089.51 154.25 -146.7 G 1.20 MWD Corrected Surveys 5445.49 40.56 170.36 4710.45 2139.96 -1942.64 917.53 2148.42 154.72 -117.3 G 0.95 MWD Corrected Surveys 5538.70 40.48 170.12 4781.31 2196.64 -2002.33 927.79 2206.83 155.14 -55.7 G 0.19 MWD Corrected Surveys 5632.17 40.79 169.43 4852.24 2253.79 -2062.23 938.60 2265.78 155.53 -77.0 G 0.58 MWD Corrected Surveys 5725.79 41.01 168.03 4923.01 2311.71 -2122.34 950.58 2325.50 155.87 -25.5 G 1.01 MWD Corrected Surveys 5819.58 41 .44 167.72 4993.55 2370.41 -2182.77 963.56 2385.99 156.18 -71 .3 G 0.51 MWD Corrected Surveys 5914.48 41.69 166.63 5064.55 2430.44 -2244.16 977.54 2447.82 156.46 -9.9 G 0.81 I MWD Corrected Surveys 6008.43 41.92 166.57 5134.59 2490.34 -2305.08 992.05 2509.50 156.71 -46.5 G 0.25 MWD Corrected Surveys 6103.89 42.15 166.21 5205.49 2551.54 -2367.20 1007.10 2572.53 156.95 -141.9G 0.35 MWD Corrected Surveys 6196.60 41.66 165.63 5274.49 2610.98 -2427.26 1022.16 2633.71 157.16 -158.4 G 0.67 MWD Corrected Surveys 6291.19 41.26 165.39 5345.38 2671.21 -2487.90 1037.83 2695.69 157.36 -124.0 G 0.46 MWD Corrected Surveys 6385.20 41.04 164.89 5416.16 2730.82 -2547.69 1053.69 2756.99 157.53 -139.5 G 0.42 MWD Corrected Surveys 6479.36 40.60 164.31 5487.42 2790.28 -2607.03 1070.04 2818.08 157.68 -146.6 G 0.62 MWD Corrected Surveys 6573.13 40.19 163.89 5558.84 2849.12 -2665.48 1086.68 2878.48 157.82 -87.5 G 0.52 MWD Corrected Surveys 6667.61 40.22 162.97 5630.99 2908.35 -2723.93 1104.08 2939.18 157.94 -96.7 G 0.63 MWD Corrected Surveys 6762.57 40.17 162.28 5703.53 2968.07 -2782.42 1122.38 3000.27 158.03 -103.7 G 0.47 I MWD Corrected Surveys 6855.33 40.01 161.23 5774.50 3026.47 -2839.15 1141.08 3059.88 158.10 -61.3 G 0.75 MWD Corrected Surveys 6949.00 40.12 160.92 5846.18 3085.56 -2896.18 1160.63 3120.09 158.16 32.6G 0.24 MWD Corrected Surveys 7043.00 40.63 161.42 5917.79 3145.22 -2953.82 1180.28 3180.90 158.22 5.1 G 0.64 MWD Corrected Surveys 7134.62 40.85 161.45 5987.21 3203.75 -3010.50 1199.32 3240.60 158.28 15.0G 0.24 , MWD Corrected Surveys 7228.81 41.07 161.54 6058.34 3264.18 -3069.05 1218.92 3302.25 158.34 25.2 G 0.24 MWD Corrected Surveys 7321.81 41.14 161.59 6128.42 3324.00 -3127.06 1238.25 3363.29 158.40 -34.7 G 0.08 MWD Corrected Surveys 7415.55 41.35 161.37 6198.90 3384.48 -3185.66 1257.88 3425.01 158.45 -27.3 G 0.27 MWD Corrected Surveys 7510.23 41.62 161.16 6269.83 3445.91 -3245.05 1278.03 3487.65 158.50 49.4 .G 0.32 MWD Corrected Surveys 7603.68 41.96 161.75 6339.50 3506.86 -3304.09 1297.83 3549.84 158.56 56.9 G 0.56 MWD Corrected Surveys 7698.13 42.18 162.25 6409.62 3568.68 -3364.28 1317.39 3613.02 158.62 67.7 G 0.42 MWD Corrected Surveys 7791.61 42.49 163.35 6478.72 3629.97 -3424.42 1336.00 3675.81 158.69 73.8 G 0.86 MWD Corrected Surveys 7885.86 42.73 164.54 6548.09 3691.80 -3485.74 1353.65 3739.35 158.78 72.8 G 0.89 MWD Corrected Surveys 7980.62 42.80 164.87 6617.65 3753.92 -3547.80 1370.62 3803.35 158.88 147.2 G 0.25 MWD Corrected Surveys 8074.92 42.29 165.36 6687.13 3815.37 -3609.42 1387.00 3866.74 158.98 152.0 G 0.64 MWD Corrected Surveys 8170.10 41.63 165.89 6757.91 3876.55 -3671.07 1402.80 3929.96 159.09 174.6 G 0.79 MWD Corrected Surveys 8264.15 41.35 165.93 6828.36 3936.36 -3731.50 1417.97 3991.83 159.19 176.2 G 0.30 "Projections and Interpolations in Italics·· 12/9/02-3:40 PM Page 3 of 3 NS 19_ Shas.xls 11 Comment MD Incl Azim TVD VSec NS EW Closure CIAzim TF DLS (It) (0) ('j (It) (It) (ft) (It) (It) (0\ (0) (0¡10Oft) MWD Corrected Surveys 8356.74 40.86 165.98 6898.12 3994.77 -3790.55 1432.74 .1052.29 159.29 -155.5 G 0.53 MWD Corrected Surveys 8451.07 40.35 165.62 6969.74 4053.74 -3850.07 1447.80 .1113.29 159.39 -161.7 G 0.59 MWD Corrected Surveys 8545.98 39.75 165.31 7042.39 4112.49 -3909.18 1463.13 4174.02 159.48 -158.3G 0.67 MWD Corrected Surveys 8639.74 39.07 164.88 7114.83 4169.86 -3966.71 1478.44 4233.26 159.56 175.4 G 0.78 MWD Corrected Surveys 8733.61 38.53 164.95 7187.99 4226.60 -4023.50 1493.74 4291.83 159.63 -173.7 G 0.58 f MWD Corrected Surveys 8827.51 38.08 164.87 7261.67 4282.74 -4079.69 1508.90 4349.79 159.70 153.5 G 0.48 MWD Corrected Surveys 8921.50 37.58 165.28 7335.91 4338.31 -4135.39 1523.75 4407.19 159.77 -169.7 G 0.60 MWD Corrected Surveys 9015.74 37.08 165.13 7410.85 4393.36 -4190.65 1538.34 4464.08 159.84 150.6 G 0.54 MWD Corrected Surveys 9107.66 36.72 165.47 7484.35 4446.50 -4244.03 1552.34 4519.02 159.91 53.5 G 0.45 I MWD Corrected Surveys 9200.89 36.84 165.74 7559.02 4500.16 -4298.10 1566.22 4574.57 159.98 -149.1 G 0.22 MWD Corrected Surveys 9294.74 36.75 165.65 7634.18 4554.18 -4352.57 1580.11 4630.51 160.05 -71 .4 G 0.11 MWD Corrected Surveys 9388.47 37.04 164.26 7709.14 4608.45 -4406.91 1594.72 4686.57 160.11 -71 .8 G 0.94 MWD Corrected Surveys 9482.66 37.27 163.13 7784.21 4663.63 -4461.50 1610.69 4743.35 160.15 -67.0 G 0.76 MWD Corrected Surveys 9576.82 37.56 162.03 7859.00 4719.38 -4516.09 1627.82 4800.50 160.18 21.7 G 0.77 MWD Corrected Surveys 9670.56 38.12 162.39 7933.03 4775.50 -4570.84 1645.39 4857.97 160.20 46.0G 0.64 MWD Corrected Surveys 9766.59 38.76 163.44 8008.24 4833.60 -4627.91 1662.92 4917.61 160.24 5.1 G 0.95 MWD Corrected Surveys 9858.64 39.61 163.56 8079.59 4890.07 -4683.67 1679.44 4975.67 160.27 65.3 G 0.93 I MWD Corrected Surveys 9952.13 40.03 164.95 8151.40 4947.99 -4741.29 1695.68 5035.40 160.32 76.6G 1.05 MWD Corrected Surveys 10046.07 40.20 166.02 8223.24 5006.22 -4799.89 1710.85 5095.68 160.38 76.7 G 0.76 MWD Corrected Surveys 10140.69 40.24 166.28 8295.49 5064.79 -4859.21 1725.48 5156.47 160.45 -153.4 G 0.18 MWD Corrected Surveys 10235.55 40.06 166.14 8368.00 5123.41 -4918.61 1740.06 5217.33 160.52 -105.9 G 0.21 I MWD Corrected Surveys 10327.55 39.67 163.87 8438.62 5180.26 -4975.57 1755.31 5276.11 160.57 -79.4 G 1.64 MWD Corrected Surveys 10423.98 39.96 161.63 8512.69 5240.39 -5034.53 1773.62 5337.81 160.59 -46.5 G 1.52 MWD Corrected Surveys 10518.50 40.50 160.76 8584.85 5300.20 -5092.31 1793.30 5398.85 160.60 -54.3 G 0.82 MWD Corrected Surveys 10613.08 41.21 159.28 8656.39 5361.05 -5150.45 1814.44 5460.71 160.59 -57.8 G 1.27 I MWD Corrected Surveys 10706.75 41.72 158.08 8726.58 5422.30 -5208.23 1836.99 5522.70 160.57 -65.9 G 1.01 MWD Corrected Surveys 10803.10 42.44 155.77 8798.10 5486.34 -5267.62 1862.31 5587.13 160.53 -53.3 G 1.77 MWD Corrected Surveys 10898.83 43.87 153.06 8867.94 5551 .57 -5326.65 1890.59 5652.22 160.46 -73.5 G 2.45 MWD Corrected Surveys 10993.63 44.61 149.73 8935.86 5617.66 -5384.70 1922.26 5717.52 160.35 -66.6 G 2.57 MWD Corrected Surveys 11089.78 45.89 145.83 9003.57 5685.88 -5442.43 1958.68 5784.15 160.21 -90.0 G 3.17 MWD Corrected Surveys 11183.79 46.01 140.54 9068.95 5752.98 -5496.48 1999.14 5848.75 160.01 -105.2 G 4.05 MWD Corrected Surveys 11279.60 45.24 136.1 0 9135.98 5820.10 -5547.62 2044.64 5912.41 159.77 -88.0 G 3.41 MWD Corrected Surveys 11375.97 45.41 132.07 9203.75 5886.09 -5595.27 2093.85 5974.22 159.48 -120.6 G 2.98 MWD Corrected Surveys 11468.66 44.31 129.33 9269.45 5947.93 -5637.91 2143.40 6031.60 159.18 -176.5 G 2.40 I MWD Corrected Surveys 11564.20 42.54 129.17 9338.84 6009.49 -5679.46 2194.25 6088.60 158.88 179.6 G 1.86 MWD Corrected Surveys 11660.51 40.69 129.19 9410.84 6069.42 -5719.87 2243.83 6144.24 158.58 158.6 G 1.92 MWD Corrected Surveys 11714.41 39.65 129.83 9452.03 6102.07 -5741.99 2270.66 6174.65 158.42 -159.8 G 2.08 MWD Corrected Surveys 11845.13 37.93 128.80 9553.91 6178.86 -5793.88 2334.00 6246.33 158.06 -121.7G 1.41 I' MWD Corrected Surveys 11938.67 37.14 126.63 9628.09 6231.73 -5828.74 2379.07 6295.57 157.80 -93.7 G 1.65 MWD Corrected Surveys 12035.53 37.08 124.72 9705.34 6285.13 -5862.82 2426.54 6345.14 157.52 -78.8 G 1.19 MWD Corrected Surveys 12130.52 37.46 121.85 9780.94 6336.66 -5894.38 2474.62 6392.76 157.23 -22.8 G 1.87 MWD Corrected Surveys 12227.28 38.30 121.28 9857.31 6389.09 -5925.48 2525.24 6441.12 156.92 -88.0 G 0.94 MWD Corrected Surveys 12321.59 38.33 120.15 9931.31 6440.27 -5955.34 2575.51 6488.40 156.61 -36.2 G 0.74 MWD Corrected Surveys 12392.29 38.96 119.42 9986.52 6478.56 -5977.27 2613.83 6523.79 156.38 56.3G 1.10 MWD Corrected Surveys 12418.39 39.15 119.87 10006.79 6492.81 -5985.40 2628.12 6536.98 156.29 26.1 G 1.31 MWD Corrected Surveys 12511.86 40.33 120.76 10078.67 6544.91 -6015.57 2679.70 6585.43 155.99 29.1 G 1.40 MWD Corrected Surveys 12607.94 41.66 121.87 10151.18 6600.40 -6048.33 2733.54 6637.36 155.68 166.3 G 1.58 MWD Corrected Surveys 12703.08 40.20 122.42 10223.06 6655.69 -6081.49 2786.31 6689.40 155.38 147.8 G 1.58 MWD Corrected Surveys 12798.78 38.54 124.11 10297.04 6710.07 -6114.77 2837.07 6740.88 155.11 172.3 G 2.06 MWD Corrected Surveys 12894.01 37.73 124.29 10371.95 6763.17 -6147.82 2885.71 6791 .40 154.86 -170.2 G 0.86 MWD Corrected Surveys 12989.65 36.56 123.95 10448.18 6815.29 -6180.22 2933.52 6841.10 154.61 -171.2G 1.24 MWD Corrected Surveys 13085.11 35.88 123.77 10525.19 6866.09 -6211.65 2980.36 6889.64 154.37 138.1 G 0.72 MWD Corrected Surveys 13180.26 35.75 123.97 10602.35 6916.24 -6242.68 3026.59 6937,67 154.13 51.5 G 0.18 MWD Corrected Surveys 13275.83 35.82 124.12 10679.88 6966.64 -6273.96 3072.89 6986.08 153.91 30.9 G 0.12 MWD Corrected Surveys 13371.09 37.80 126.04 10756.14 7018.56 -6306.78 3119.58 7036.14 153.68 31.9 G 2.40 MWD Corrected Surveys 13419.91 38.74 126.97 10794.47 7046.37 -6324.77 3143.88 7063.05 153.57 0.0 G 2.26 Project 8-1/2 Hole TD 13500.00 38.74 126.97 10856.94 7092.62 -6354.91 3183.93 7107.90 153.39 --- 0.00 NS19 - Spud 10/29/02 Formation Top Permafrost Base Permafrost SV6 - top confining zone Surface casing point SV5 - base confming zone SV4 SV2 - top upper injection zone SVl - top major shale barrier TMBK - top lower injection zone - Top Ugnu WSl - top Schrader Bluff - Base U~nu CM3 - Base lower injection zone (top Colville) THRZ - Top HRZ BHRZ - Base HRZ Top Kuparuk Kuparuk C Top Miluveach Intermediate casing point Intermediate logging point Top Kingak Fault 15 - throw = 200' Top Sag River Geol target #1 Current Depth Intermediate casing point Top Shublik - 90 Top Ivishak Depth - Horizontal (BHS) Depth - Horizontal (EHS) Total Depth Oil- Water contact ----.--- Prognosed Tops TVDss I TVDrkb I MDrkb 1,149 1206 1210 1,519 1576 1586 2,988 3045 3194 3,150 3207 3399 3268 3325 3555.62 - 3,578 3635 3968 3,988 4045 4514 4,381 4438 5038 4,783 4840 5573 5,795 5852 6921 6,896 6953 8387 8,838 8895 10960 8,908 8965 11050 8,917 8974 11061 9,123 9180 11326 9,347 9404 11617 9,387 9444 11669 9,387 9444 11669 9,925 9982 12371 10200 10257 12731.1 10,822 10879 13542 10,822 10879 13542 10,852 10,888 10,978 11,020 11,020 11,020 11 , 100 10909 10945 11035 11077 11077 11077 11157 13581 13628 13775 13775 14684 14684 Actual Depths TVDss I TVDrkb I MDrkb 1149 1206 1210 1519 1576 1586 3008 3065 3230 3161 3218 3426 3286 3343 3582 3595 3652 3983 4002 4059 4537 4395 4452 5096 4750 4807 5573 5795 5852 6921 6881 6938 8410 8698 8755 10735 8813 8870 10901 8881 8938 10996 9103 9160 11250 9408 9465 11742 9444 9501 11778 Decided not to run 9895 9952 12343 10258 10315 12816 10778 10835 13478 10822 10879 10800 10857 10800 10857 10888 10945 10978 11035 11 020 11 077 11020 11077 11 020 11 077 11100 11157 13500 13500 13628 13775 13775 14684 14684 o - - -=-- ;:'¡ NORTHSTAR NS19 I I f I I I I I I I I I I I I I I I I #\~a~~a O~¡ ~i;¡, Ccm~L Commission ß\m:hOTtJ1ge 0('1' 2 1 r'I¡f')C-" .... _ £:\.., j~) 1\"I~f,) \1;::::': If'~ 'r¡:: ~., 4' t:;; D'r>:;~ '~~ ~., b'~1";r..,~ ~~~Jt '1¡mt~ m \\l! i~ I END OF WELL REPORT BP EXPLORATION ALASKA spe"I'V-5Un [J RILL I N G 5 E Ff V I c:: E 5 ~CÐ- acT- I I I I T ABLE OF CONTENTS I I 1. General Information I 2. Daily Summary 3. Daily Operations I 4. Show Reports I 5. Morning Reports 6. BHA's I 7. Bit Record I 8. Mud Reports 9. Survey Record I 10. Formation Tops I 11. Formation Evaluation Logs I I I Sperl"'V-5Un I 1:1 Ft........ N G 5e R\I. c: e Si I I I I I I I I I I I ( I ( I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well : Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS 19 Northstar North Slope Alaska United States 50-029-23122 -00 AK-AM-22173/ AK-AM-2355584 October 29,2002 November 13, 2002 I March 25, 2003 True 26.296 deg 80.939 deg 57523.701 nT October 28,2002 North 70 deg 29 min 28.468 sec East 148 deg 41 min 35.905 sec 149.630 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Barb Holt Joe Polya Mike Dinger Ken Lemley I Rick Matson Northstar 107 Alaska North Slope spe..........v- sun J:JRIL.L.I IV Ci seFi\Ju::es I r I I I I I I I I I I I I I I I I I BP Exploration - Northstar NS19 Daily Summary 10/28/02 Move rig from NS20 Preparing to spud. 10/29/02 Run in with BRA #1 (Bit #1 16" MX-Cl, TFA= 1.031). Spud and 001116' hole to 330' MD, gyroing every 50 feet. Trip out and pickup BRA # 2 with MWD. Rerun Bit # 1. Drill to 1130' , gyroing every stand. 10/30/02 Drill 1030' to 3260' MD. Good correlation on gamma ray with NS06 well. Run gyro until 1465' MD. Top of Permafrost at 1195' MD, 1190' TVD. Base of Permafrost at 1586' MD, 1577' TVD. Top of SV6 marker at 3230' MD, 3065' TVD. First indication of methane gas at 1195' MD. 10/31/02 Drill 16" hole to 3426' MD, 3218' TVD for section Total depth for running 13 3/8" casing. Maximum gas 62 units at 3189' MD. Maximum Rap 1014 ft/hr at 2011' MD. Pull out of hole and run 13 3/8" casing. !3 3/8" casing set at 3205' MD. Start cementing casing. > Bit # 1 statistics= 3426 feet, 19.6 hours and 140K revolutions. 11/01/02. Cement 13 3/8" Casing. Clean pits, nipple up BOP's, test BOP's 11/02/02. Run in BRA #3, Bit #2 12 ~"RSX238RF, TFA= 1.090, Test casing, Drill out 12 ~"shoe and 20 foot of new formation, Perform L.O.T. to 12.5 ppg. Drill 12 ~"hole with Rotary Steerable Tool to 4478' MD. Top SV5 3582' MD, 3343' TVD, Top SV4 3983' MD, 3632' TVD, Top ofSV2 4537' MD, 4059' TVD. Maximum gas 191 units at 4674' MD with 8.8 ppg mud. 11/03/02 Drill 12 ~"hole with RSS from 4478' to 7035' MD. Top ofSVl marker 5096' MD, 4452' TVD. Top ofUgnu 5573' MD, 4807' TVD. Maximum gas 664 units at 6600' MD with 9.0 ppg mud weight. 11/04/02 Drill from 7056' to 9023' MD with no problems. Top of Schrader Bluff formation 7669' MD, 6388' TVD. Top of Colville formation 8227' MD, 6800' TVD. Maximum gas 439 units at 8400' MD with 9.2 ppg mud weight 11/05/02 Drill from 9023'to 11227'MD. Top ofRRZ at 10546' MD, 8606' TVD, Base ofHRZ at 10987'MD, Top of Kuparuk at 10998' MD, 8939' TVD. Maximum gas 1721 units at 9437' MD with 10.2 ppg mud weight 11/06/02 Drill from 11227' to 11778' MD. Top of Kuparuk Cat 11313' MD, 9160' TVD. Top of Miluveach at 11734' MD, 9465' TVD. Circulate and condition hole. Pull Out of Hole. Maximum gas 1016 units at 11317' MD with 10.25 ppg mud weight. > Bit # 2 statistics= 8352 feet, 65.4 hours and 602K revolutions. 11/07/02 Continue to pull out of hole. Run 9 5/8" casing. 11/08/02 Finish running 9 5/8" casing. Circulate bottoms up maximum gas 188 units. Landed casing @ 11753' MD, 9482' TVD. Cement casing. I ~ J I" I I I [ I I I I I I I I I I I I BP Exploration - Northstar NS19 Daily Summary 11/09/02 Pressure test annulus to 3500 psi. Test casing to 3900 psi 11.4 bbl pumped. Run in hole. Drill cement from 11644' to 11667' MD. Tag plugs. 11/10/02 Drill out plugs and shoe track. Drill from 11788' to 11798' MD. Increase MW to 12.8 ppg while drilling to 11798' MD over 2 full circulations. Perform FIT to 14.5 EMW. Drill 8~" hole ahead from 11798' to 12290' MD New Bit #3 an 8 ~"RSI61HGSW with a TFA of 0.7420. 11/11/02 Drill from 12290' to 12473' MD. Pull out of hole for new bit. Repair seals on riser. Top of Kingak 12390' MD, 9985' TVD, Bit #3 statistics= 694 feet, 28.0 hours and 329K revolutions. New Bit #4 an 8 ~" DS70FNPV, with at TFA of 0.7420. 11/12/02 Slip and cut drill line, Trip in hole to Bottom and begin drilling at 12474' MD to 13261' MD. Maximum Trip Gas was 138 units. 11/13/02 Drill 8 ~"hole from 13261' MD to 13500' MD, 10856' TVD, 8~" TD. CBU, Trip out. Maximum gas was 242 units at 13499' MD. Top of the Sag River formation at 13470' MD, 10833' TVD. Bit #4 statistics= 1026 feet, 15.9 hours, 214K revolutions. 11/14/02 Run in hole with 7" drilling liner to 13480' MD. Cement same. 03/23/03 Run in hole to 100' and displace out diesel freeze protect. Trip out of hole. Make up drilling BHA #6 (Bit #66 1/8" STX-30CD, TFA = .518 , with mud motor (1.5 degree bend)) and Run in hole to top ofT' drilling liner. Pump 100 bbls ofviscosified seawater. Run in hole to float collar. Displace well to 9.3 ppg mud while drilling float equipment. 03/24/03 Drill float equipment and 20' of new 6 1/8" hole to 13520' MD. Perform Formation Integrity Test to 11.5 ppg EMW-OK. Drill from 13520 to 13855' MD. Maximum gas was 510 units at 13566' MD. Top of the Shublik formation 13612' MD, 10928' TVD. Top of the Ivishak at 13782' MD, 11016' TVD. 03/25/03 Drill 6 1/8" hole from 13855' to Total Depth of 14063' MD, 11153' TVD. Maximum gas in this interval was 248 units at 13980' MD. Bit #6 statistics= 563 feet, 24.4 hours and 246 K revolutions. Perform Monitor After Drilling ( MAD) pass up to 7" drilling liner shoe for MWD information. Pump ball to open PBL sub and pump high viscosity 50 bbl sweep bottoms up. Circulate hole clean. 03/26/03 Trip out of hole to run 4 ~" production liner. Rig up and run 4 ~" production liner on 5" drill pipe to 7" drilling liner shoe. Circulate 2800 strokes-Maximum gas 18 units. Continue run to bottom. Rig up to cement. I BP Exploration - Northstar NS 19 ,[ Daily Operations (I.A.D.C) I Time Elapsed Operations Breakdown (hrs) Time I 10/28/02 19:00-20:00 1.00 PJSM. Obtain permit to move rig. I Move rig from NS-20 to NS-19. 20:00-21 :00 1.00 Level the rig. 21 :00-21 :30 0.50 Rig up. I Complete Pre-Rig Inspection checklist. 21 :30-00:00 2.50 NU riser Adapter. PT. -NU Riser. Accept Rig @ 2130 hrs. r 10/29/02 00:00-02:00 2.00 Install mousehole, P IV gyro & wireline tools, & BHA. I 02:00-03 :30 1.50 PJSM - slip & cut drilling line. 03:30-04:00 0.50 Service drawworks & adjust brakes. 04:00-05:00 1.00 Finish pre-spud checklist. I 05 :00-07 :00 2.00 PIV BHA #1 & tag ice @ 62'. 07 :00-08 :00 1.00 P JSM - R/U wire line for gyro. 08:00-09:00 1.00 Pre - spud meeting wi all drilling personnel. I 09:00-11 :00 2.00 Clean conductor (ice) & drill to 330'. 11 :00-11 :30 0.50 Run gyro & circulate. 11:30-12:00 0.50 POH for BHA # 2. r 12:00-13:00 1.00 LID BHA # 1. 13:00-13:30 0.50 Clean rig floor - P JSM for MIV BHA # 2. 13:30-14:30 1.00 MIU BHA # 2. I 14:30-15:00 0.50 Wash down to 330'. 15:00-00:00 9.00 Drill, slide, & run gyros from 330' to 1095' md. I 10/30/02 00:00-08:00 8.00 Drill directional from 1095' to 1564' pumping sweeps before running gyros. I Note: 1) Information correlated between MWD & gyro survey on 2 seperate surveys as follows: I 1210' gyro 7.97 incl, 95.63 az 1210' MWD 8.14 incl, 96.18 az 1465' gyro 9.22 incl, 101.8 az I 1465' MWD 9.25 incl, 103.61 az. 08:00-08:30 0.50 PJSM - LID gyro & RID wire liners while circulating @ reduced rate. 08:30-11 :00 2.50 Drill directional in 16" hole from 1564' to 1860' increasing flow rates up to I 1100 GPM. 11 :00-11 :30 0.50 Clean up 15 gallon mud spill in cellar due to drip pan overflow. 11 :30-00:00 12.50 Drill directional in 16" hole from 1860' to 3264', pumping sweeps every I 300'. Note: 1) In good shape directionally - latest survey @ 3190' I I 37.51 incl & 159.66 az Ie 2) Flow rate follo'vving spill 850 GPrvL 10/31/02 I 00:00-03 :00 3.00 Drill 16" directional hole from 3264-3426' md. Notes: 1. Pumped sweep just prior to reaching casing point. I 2. Surface TD reached with good directional position. Survey at 3354' md - 38.46 deg - 160.4 azim. 03 :00-05 :00 2.00 Circulate 2.5 X bottoms up. Pumped high vis. weighted sweep. Hole I clean. 05:00-08:00 3.00 Monitor \vell. paR to BRA. Monitor \-vell. Note: I 1) TOR was good wi no excessive drag. A vg. drag 5 - 10 K with occasional drag to 20K on a few jts. 08:00-11 :00 3.00 PJSM. Lay down BRA. I 11 :00-12:00 1.00 Clean up drill floor. 12:00-12:30 0.50 PJSM - Rigging up Frank's tool and casing equipment held at pre tour meeting. I Rig up Frank's Tool. 12:30-14:30 2.00 Rig up to run casing. Loaded plugs in cement head. 14:30-20:00 5.50 PJSM - Ran 81 jts. of 13 3/8" 68# L-80 casing with no losses. Casing I went in slick with the exception of jts 53 & 76 @ 2220' & 3175' respectively. S/Oweights down to 95K on each jt. Worked down without I problems or washing. 20:00-20:30 0.50 R/U landingjt. & hangar & land hangar. 20:30-21 :00 0.50 LID Frank's fill up tool & M/U HOWCO cementing head. 21 :00-23:00 2.00 Establish circulation by staging up pumps from. 5 to 10 BPM. I Initial circulating pressure @ .5 BPM was 270 psi, final circulaing pressure @ 10 BPM was 410 psi. I Held PJSM for cement job while circulating. 23 :00-00:00 1.00 Pump 5 bbls water & test cement lines to 3500 psi. Pump 75 bbls. 10.5 ppg spacer. I 11/01/02 00: 00-02: 3 0 2.50 Pump 388 bbls 10.7 ppg Type "L" lead cement followed by 96 bbls 15.9 I ppg class G tail cement @ 6 - 8 BPM. Drop bottom plug & chase wi 25 bbls. wash water from Halliburton pumping unit. Displace cement wi 472 bbls. wi rig pump. I ( Last 20 bbls pumped was sea water) Bumped plug @ 96% pump efficiency. ReId 1700 psi. on casing for 5 minutes. Bled off pressure & checked floats. OK I 02:30-04:30 2.00 LID cement head, BIO & LID landing jt, flush out flow line & riser, BID lines, & remove casing handling tools from rig floor. 04:30-05 :30 1.00 RID surface riser & adaptor. I 05:30-06:30 1.00 NIU Vetco Gray multi-bowl ass'y & test to 2000 psi. 06:30-11 :00 4.50 NIU BOP's - skid rig floor to line up riser. 11 : 00- 13 : 00 2.00 PIU test jt, install test plug & prepare to test BOP's. I 13:00-14:00 1.00 Test BOP's to 4800 I 250 psi for 5/5 min. 14:00-14:30 0.50 P JS:tvl - Testing BOP's. Crew change out day. 14:30-18:30 4.00 Test BOP's to 4800 I 250 psi for 5/5 min. Test annular to 3500 psi. I 18:30-19:30 1.00 RJD from BOP test. LID test plug & test jt. BID lines. I 19:30-20:00 0.50 Install wear bushing. r 20:00-00:00 4.00 PJSM - 1) Modify possum belly to accomodate more fluid from flow line discharge. r 2) Spray foam insulation & silicone drip pan underneath drawworks. 3) Repair leak on top drive pipe handler by replacing cylinder. I 11/02/02 00:00-01 :30 1.50 1) Complete possum belly modification to accomodate more fluid from flow line discharge. I 2) Complete cleaning & sealing drip pan underneath drawworks. 01:30-04:00 2.50 Replace cylinder in top drive pipe handler. 04:00-04:30 0.50 Service top drive. I 04:30-06:30 2.00 PJSM - MID BRA #3 - shallow test RSS - BID top drive 06:30-07:30 1.00 Finish P /U BRA. 07 :30-09:00 1.50 Rill to 3319' washing down the last stand & tag plugs on top ofFC. 10' of 1 cement on top of plugs. 09:00-10:00 1.00 Circulate cement until equivalent MW in = MW out. 9.0 ppg 10:00-11 :00 1.00 Test 13 3/8" casing to 3550 psi & hold for 30 minutes. I Notes: 1) Reviewed D 1, D2, & D5 drills with crew during test. 2) Discussed drilling hazards associated wi intermediate hole section. 1 11:00-15:00 4.00 Drill plugs, cement & 20' of new hole to 3446'. Started displacement of old mud with new 8.6 ppg after drilling float shoe. 15:00-15:30 0.50 Finish mud swap & circulate until MW in = MW out @ 8.6 ppg. I' 15:30-16:00 0.50 Perform FIT to 12.5 EMW wi 8.6 ppg. (650 psi) 16: 00-16: 3 0 0.50 Establish clean hole ECD baselines. 16:30-00:00 7.50 Drill 12 1/4" directional wi RSS from 3446' to 4478'. I Notes: 1) Pumping hi-vis barofibre sweeps every 400' wi 50/0 to 10% excess I seen @ shakers. 2) RSS responding to down links. 3) ECD's are good - 9.3 to 9.4 wi 8.7 to 8.8 ppg MW. I 11/03/02 00:00-00:00 24.00 Drill 12 1/4" hole wi RSS from 4478' to 7035' md. I Notes: 1) Adjust RPM and or WOB to address drill string harmonics. Some stick slip occurring regardless of adjustments being made, especially on hard I streaks. 2) Mud system contains 2 - 2.50/0 lubricants for torque reduction wi lubetex, torque trim, & BDF 263. Condet & Clayseal to prevent bit balling I & screen blinding. 3) Pumping hi-vis barofibre sweeps every 400'. 4) ECD's in 9.5 to 9.6 range wi 8.9 - 9.0 ppg MW's. I 11/04/02 00:00-16:00 16.00 Drill ahead in 12 1/4" hole wi RSS from 7035' to 8138' md. I 16:00-16:30 0.50 Service top drive. 16:30-00:00 7.50 Drill ahead in 12 1/4" hole wi RSS from 8138' to 8995" md. Notes: I I 1) Pumping hi-vis barofibre sweeps every 400' vvi 0 - 10% additional I cuttings. 2) Maintaining 2.5 - 30/0 lubricants. 3) ECD's 9.7 - 9.85 range wi 9.1 - 9.2 ppg NI\V's. No ECD spikes. I 4) RSS responding to downlinks. 11/05/02 I 00:00-12:00 12.00 Drill directional w/ RSS frOln 8995' - 10393' md. Notes: 1) Adjust RPM & WOB to address drill string harmonics as needed. I 2) Maintaining 3% lubricants. 3) Pumping hi-vis barofibre sweeps every 400'. 12:00-13 :00 1.00 Condition & circulate mud. Add 12.7 ppg spike fluid to get 10.1 ppg ~I\V. I 13 :00-17:00 4.00 Drill from 10393' to 10770' md. 17:00-17:30 0.50 Lubricate blocks & service top drive. 17 :30-00:00 6.50 Drill from 10770' to 11227'. I Top ofHRZ 8606' TVD - 10546' md. Top of Kuparuk 8939' TVD - 10998' md. I 11/06/02 00:00-01 :30 1.50 Drill 12 1/4" hole wi RSS from 11227' to 11260' 01 :30-03:00 1.50 Repair wash out on #2 mud pump discharge manifold. I 03 :00-11 :30 8.50 Drill 12 1/4" hole wi RSS from 11260' to 11778'. 11 :30-14:00 2.50 Pump 50 bbl. hi-vis weighted sweep (13.2 ppg) @ TD. Condition & I circulate mud for casing. 14:00-14:30 0.50 paR, Monitor well - pull 5 stands - pump dry job & BID top drive. 14:30-16:30 2.00 paR to 8400'. A few tight spots In the Kuparuk & HR.Z wi 40K lbs drag. I Wiped through tight spots once & excess drag was gone. 16:30-17:30 1.00 Spot 150 bbl. 20 ppb steel seal pill across Schrader Bluff - pump dry job - BID lines. I 17:30-20:30 3.00 Continue POR to shoe. Remainder of trip was good wI no excessive drag or swab. 20:30-21 :00 0.50 Circulate 1 B/U @ shoe wi minimal returned cuttings. I 845 gpm 21:00-21:3 0.50 POR to 3350' - circulate @ 4 BPM while holding PJSM for slip & cut. 21 :30-22:30 1.00 Slip & cut 102' of drilling line. I 22:30-00:00 1.50 Continue paR. LID porcupine reamer & dart sub. Note: Porcupine reamer not missing any inserts as in past. I 1 insert hanging loosely. 11/07/02 I 00:00-03 :30 3.50 Continue to Lay down BRA. BRA not balled up- clean. Bias unit had one washed out seal. Bit in good shape- 1-0- In gage. Good Drilling Practices evident by bit! BRA condition. I 03:30-04:30 1.00 Clear rigfloor. Pull Wear Ring and Install Test Plug. 04:30-06:30 2.00 PJSM. Change out top rams to 9.5/8" and test doors to 3500- psi. Pull Test PLug. While working on Rams remove Stabilisers from rigfloor and I bring up casing equipment. 06:30-08:00 1.50 PJSM. R!U to run 9.5/8" casing installing Franks Tool and long bails. 08:00-09:30 1.50 MID 9.5/8" Shoetrack and check floats- OK. I 09:30-13 :30 4.00 Run 9.5/8" Casing to the 13.3/8" Shoe @ 3400 ft. No losses. I I I I I I I I I I I I I I I I I I I 13 :30-14:00 0.50 14:00-22:30 8.50 Circulate Casing contents @ 10 BPJ\¡1/ 800 psi. No Losses. Run 9.5/8" Casing to 10,663 ft. Taking a little weight ( 80 klbs). lust above the HRZ at base of Colville. All joints ~faking up @ 9,900 ftlbs. Each Joint checked for Triangle. Circulate joint above HRZ- Precautionary. 3 BPM/ 1020 psi. Full Returns. All Parameters steady. 275 kbs down 470 klbs Up. Continue to run 9.5/8" Casing. No problems at Top of Kuparuk. Total Losses for casing runing Operation Approx 55 bbls. Total Joints run of 47 11ft, L-80, BTC-tvf = 286. 22:30-23:00 0.50 23 :00-00:00 1.00 11/08/02 00:00-00:30 0.50 Run the last 5 jts. of9 5/8" 471b. L-80 mod. buttress casing & PIU landing j 1. Ran a total of 286 jts. casing. Wash down landingjt @ 3 BPM - 1160 psi. Kept hangar 5' above load shoulder while staging up pumps. Stage pumps from 3 BPM to 9 BPM - initial circulating pressure 1160 psi, final pressure 1300 psi. Land hangar 45 minutes into circulation. Hangar weight in slips 315,000 lbs with top drive & blocks included, 245,000 lbs. without. Held PJSM for cement job while circulating. PJSM - RID Frank's tool, install cement head & x-over, & test lines to 4,000 psi. Pump 50 bbls. 11.0 ppg weighted spacer & drop bottom plug. Pump 402 bbls. 11.2 ppg lead slU1T)' followed by 124 bbls. 15.2 ppg tail slurry. Drop bottom plug & chase with 25 bbls. of water from HOWCO & turn over to rig pump. Displace cement wi 829 bbls. mud. Bumped plug @ 900 psi. wi 94.1 % pump efficiency. Test casing to 1400 psi & held for """8 minutes. Pressure held. Bleed off pressure & checked floats - OK. RID cement head, casing equip't , & LID landing jt. Install elevators, PIU stand, drain & flush BOP, install packoff & test to 5000 psi for 10 min. RIU to pump down 13 3/8" x 9 5/8" annulus. Pump 210 bbls 10.5 ppg mud down annulus. Broke down @ 900 psi - final pressure was 590 psi. LID packoff running tool, stand back stand DP, take off long bails, drain stack, & change out 9 5/8" rams for 7" x 4 1/2" variables while pumping down annulus. P JSM - Install bails & elevators. PJSM - Write procedure for removing stabbing board. Remove stabbing board & set in pipeshed. PJSM - drain stack & prep for BOP test. Test BOP's to 250 / 4800 psi for 5 / 5 min. Drip @ unibolt on choke hose - C/O ring & retest. BID all lines. Unable to pull test plug - drain stack & see annular preventer element protruding on the inside of riser. Land test plug, back out test jt. & L/D. 00:30-04:00 3.50 04:00-08:30 4.50 08:30-09:30 1.00 09:30-10:30 1.00 10:30-13:30 3.00 13 :30-14:00 0.50 14:00-15 :00 1.00 15 :00-16:30 1.50 16:30-18:00 1.50 18:00-23:00 5.00 23 :00-23 :30 0.50 23:30-00:00 0.50 11/09/02 02:00-06:00 4.00 06:00-07:30 1.50 C/O annular preventer element. NIU riser. I 07:30-08:30 1.00 R/U & test annular to 3500 psi. R/D test equip't. I 08:30-09:00 0.50 Pull test plug & install wear ring. 09:00-09:30 0.50 Clean cellar & rig floor. 09:30-10:00 0.50 P JStvI for MIU BHA # 4. I 10:00-11 :30 1.50 MIU BHA # 4. 11:30-12:00 0.50 Shallow test MWD & Rotary steerable power drive @ 400 GPM - 500 psi. I 12:00-13 :30 1.50 Continue MlU BHA # 4. 13 : 3 0-16: 3 0 3.00 Rill to 8900'. 16:30-18:30 2.00 P JSM - Install stabbing board. I 18:30-19:30 1.00 Rill P Continue RIH from 8900' to 11545' 19:30-20:00 0.50 Wash down from 11545' & tag cement @ 11644'. 20:00-20:30 0.50 Circulate MW in = MW out @ 10.5 ppg. I 20:30-21 :30 1.00 Pressure test 9 5/8" casing to 3900 psi & hold for 30 min. 11.4 bbl pumpl return. 20:30-21 :30 1.00 Discuss well control & drilling hazards associated wi 8 1/2" hole section I while testing casing. Review D 1, D2, & D5 drills. Perform D8 - muster drill. 21 :30-22:30 1.00 Replace suction valve in pit 1D. I 22:30-23:00 0.50 Drill cement on top of plugs from 11644' to 11667' Tag plugs @ 11667'. 23:00-00:00 1.00 Lost power on rig. 13/8 highline breaker closed along wi gas valve on pipe rack due to gasl low pressure. I No gas detected inside rig. Safety did not detect any gas venting at pipe rack. I Trying to establish why ESD activated. 11/10/02 00:00-00:30 0.50 Restore hi-line power to rig. I 00:30-03 :00 2.50 Drill out F IC plugs & shoe track. Started adding spike fluid for 12.8 ppg MW @ 01 :50 hrs. 03 :00-06: 15 3.25 Drill 9" hole wI RSS from 11778' to 11798 md. I Pumped 2 walnut I sapp sweeps for bit balling wI limited success. Knocked ball offbit by bouncing offbottom. I Dressing out mud to 12.8 ppg MW while drilling 20' of new hole. Took 2 full circulations. 06:15-07:00 0.75 Perform FIT to 14.5 EMW wi 12.7 ppg MW @ 890 psi. I 07:00-07:30 0.50 Establish ECD baselines as follows: 11798' 600 GPM, 0 RPM - ECD 13.67 11798' 600 GPM, 60 RPM - ECD 13.66 I 11798' 600 GPM 120 RPM - ECD 13.71 07:30-18:00 10.50 Drill 9" hole wi RSS from 11798' to 12114' md. Pumping walnut I sapp sweeps for bit balling. I Adding barite to maintain 12.8 - 12.9 ppg MW. 18:00-18:30 0.50 Service top drive & blocks. 18 :30-00:00 5.50 Drill ahead from 12114' to 12290'. I ROP rates 15-50 ftlhr. Drilling parameters indicating bit balling tendencies. I 11/11/02 00:00-12:00 12.00 Drill ahead in 9" hole w/ RSS from 12290' to 12473'. Hit Kingak @ 12,390 ft. P-rates still low. Torque response indicated that bit was digging I but slowly. 15-25 filhr. I Slow ROP due to frequent bit balling. Nut plug / sapp sweeps r non-productive. 12:00-13 :00 1.00 Condition & circulate mud @ 630 GPìvl for TOH. 13 :00-13 :30 0.50 Monitor well - POH w/ 8 stands to 9 5/8" shoe. I 13:30-14:00 0.50 Monitor well @ shoe - pump dry job - BID lines. 14:00-17: 15 3.25 Continue POH to HWDP - monitor well for 15 min. 17:15-18:30 1.25 Handle BHA # 4. Bit in good shape. Rest of BHA in good shape. I 18:30-18:45 0.25 Clear & clean rig t100r. 18 :45-19:30 0.75 Download CDR & test bias unit. 19:30-20:00 0.50 ìv1/u BHA # 5. I 20:00-22:30 2.50 Rill to 6930'. 22:30-00:00 1.50 Air boots on riser leaking. Attempts to air back up & repair with fix-a-flat were unsuccessful. PJSM - pull riser and replace air boots. No mud I found its way to secondary containment- about 0.5 gallon on top of annular. Good Spot by the Shaker Rand- prevented potential spill. I 11/12/02 00:00-01 :30 1.50 Replace air boots on riser. I 01 :30-04:00 2.50 Rill to 11356' md. 04:00-06:30 2.50 PJSM. Slip and cut drilling line. Adjust brakes. I Service Top Drive. 06:30-07:00 0.50 Rill to 12403' md. Hole in Good shape- no problems. 07:00-08:00 1.00 Wash from 12403' to 12473' md. Stage up pumps. Some high pressures I early on - 500 GPM! 4100 psi. 08:00-00:00 16.00 Drill ahead 9" hole from 12473' md to 13260' md. No Drag, No losses. I ECD steady @ 14.0 ppg. RPM @ 160 and Flowrate running @ 625 GPM! 3900 psi. Pump Back 90 ft on each stand. Assembly with DS-70 tending to build. Set RSS @ 20%/36 degs. I Sperry Keeping a close Eye on cuttings- no obvious splinters. - ROP from 50- 100 fph Top Sag @ 13,470 ft MD, 10,835' TVD I 11/13/02 00:00-03:30 3.50 Drlg fJ 13262' - 13500' md. I Note: Top of Sag @ 13470' md. 03:30-05:30 2.00 Pump Sweep and CBUx2. Note: Spot new 13.0 ppg pill across openhole interval. I 05:30-07:00 1.50 Monitor Well and POOH to 11700' md (inside 9-5/8" csg shoe). Note: 250-350K lbs max, Max Drag 50K & A vg Drag 15K. 07:00-07:30 0.50 Monitor Well, Pump Dry Job and BID Top Drive. I 07:30-11 :00 3.50 POOH to 1007' md @ BHA. 11:00-13:30 2.50 POOH while LD 26 jts ofHWDP. LD BHA#5. Notes: I 1. Bit was in great shape -- one plugged nozzle. 2. Near bit reamer was missing the cutters on all 3 blades. 3. BRA was clean with no sign of balling or clay build up. I 13:30-14:00 0.50 Clear and Clean rig floor. 14:00-14:30 0.50 P JSM -- RU 7" liner running equipment. 14:30-18:00 3.50 PJSM -- Run 46 Jts of 7" 26# Hydril 521 liner. I 18:00-18:30 0.50 PU Hanger Assembly. I 18:30-19:00 0.50 I 19:00-00:00 5.00 I I 11/14/02 00:00-03:00 3.00 I I 03 :00-04:00 1.00 I 04:00-06:45 2.75 I I 06:45-09:30 2.75 I I I 09:30-10: 15 0.75 I 10:15-11:30 1.25 I 11 :30-12:30 1.00 I 12:30-13:00 0.50 I I I I Mix and pour PAL-MIX inside 7" liner top. Allow 30 mins for n1ix to set up. Rill wi 7" liner on 5" DP tilling every 10 stands. Continue Rill w/ 7" liner assembly. At shoe circulate DP volume + liner volume. Run liner into OH. Encounter Tight Spots @: 12436' to 12473'md, 12675' md, and 12850'md to current depth of 13087' md.. Rill wi 7" drilling liner fl 7264' md to 11680' md (inside 9-5/8" casing shoe) . - Running speed 1 minute per stand. - Fill DP per 10 stands. Circulate DP + liner volume (241 bbls) @ 5.5 bpm wi 925 psig. Take Parameters: - UWT= 285 K, DWT= 215 K, and RWT= 250 K lbs - 35 rpm wi l1K-lbs torque. Rill into open hole wi 7" drilling liner to 13362' md. - Encounter minor tight spots @ 12436', 12473' and 12675' md. - Encounter more trouble through fault. Necessary to work pipe numerous times -- loosing ground. At 13082' md, got though by rotating at 40 rpm/llK torque wlo pump. Wash from 13362' md to 13411' md -- pump 1 to 2.5 bpm with no rotary. * Packed off at 13393' and 13411'md. * Unable to advance past 13,411 -- packing off and losing ground. Established rotation @ 30 rpm and while pumping 2.5 bpm @ 13411' md and wash and ream from 13411 to 13485' md (set liner 10' into top of Sag @ 13480' md. Did not attempt to wash liner into bottom 20' of rat hole). * Packing off occured frequently. Finally able to eliminate packoffby reducing pump rate to 1 bpm and rotating 25 rpm. - Last 60' washed and reamed with no apparent problems. Did not take weight or shows signs of packing off. No trouble getting into Sag. RU cement head. - Change out leaking valve on cement manifold. Establish circulation and stage up rate in 1/2 bpm increments to a final clean up rate of 5.5 bpm wi 1070 psig. - Offbottom parameters: ROT 265 K wi 20 rpm and 14 K-Ibs torq. - UWT= 350 K & DWT= 235 K lbs. Drop and pump ball @ 5.5 bpm. Place ball on seat and pressure up to 2000 psi and set hanger. 2. Pressure up to 3200 psi and release running tool. 3. Picked up 3' past neutral point - unable to determine whether free of liner. PU an addtional 2' to make determination -- still not able to determine of off liner. 4. Blowout ball seat @ 4150 psi. Had driller shut off pumps immediately due to losses occurring on past 2 wells. - Pressure bled off immediately to 2600 psi and trapped -- signs of pack off down hole around liner shoe. - Monitored pressure for 5 minutes as slowly bled down to 300 psi. Well t10wing with mud back at shaker. - 300 psi trapped -- re-establish circulation by bringing pumps on @ 1 bpm increments up to 5 bpm -- packed off. - Shut down pumps and bled off pressure to 100 psi. I I 13:00-13 :30 0.50 I 13:30-14:00 0.50 14:00-14:30 0.50 14: 3 0- 15 : 15 0.75 I I 15:15-16:15 1.00 I 15:15-16:15 1.00 I' 16:15-16:30 0.25 I 16:30-17:15 0.75 I I 17: 15-18:00 0.75 18:00-21 :45 3.75 I 21:45-22:15 0.50 1 22:15-22:45 0.50 22:45-23:30 0.75 [ 23:30-23:45 0.25 23 :45-00:00 0.25 I 03/22/03 I 00:00-03 :30 3.50 03:30-06:00 2.50 06:00-08:00 2.00 I 08:00-08:30 0.50 08:30-09:30 1.00 I 09:30-10:00 0.50 10:00-13 :30 3.50 13: 3 0-1 7: 00 3.50 I 17:00-17:30 0.50 17:30-18:00 0.50 18:00-23:00 5.00 I 23 :00-23 :30 0.50 - Re-established circulation at 0.5 bpm and increased to 1 bpm. Patiently increased pumped rate in 1 bpm increments to 5.5 bpm over 1.5x openhole volume. Circulate. Halco crew change. PJSM for cement job -- no circulation. PT cement lines to 4000 psig wi 13.0 ppg ALPHA Spacer. Pump 35 bbls Alpha spacer total. Mix and pump 102 bbls (379 sxs) of 15.9 ppg tail cement at 5 bpm as per plan. - TT= 5 hrs:2mins. - Did not rotate liner during cement job. Drop plug and switch to rig pumps. Displace cement with 12.8 ppg Mud.@ 5.5 bpm wi full returns. - Slow rate and latch up @ 94% efficiency. Increase rate and bump plug P to 1900 psig wi 96% efficiency. HOWCO meter 275 bb1s (96% efficiency). Hold pressure for 1 min. - check floats. Note: Cement in place at 16:15 hrs. Slack Offwlo rotation and set ZXP liner top packer wi 80 K lbs- see shear and set. PU to neutral and rotate down on liner top wi 50 K lbs - verify ZXP set. Pressure up to 800 psig and circulate at max rate after seeing pressure loss while PU. - CBU. Estimated 20 bbls cement returned. Spacer and cement carrying quite a bit of shale - not splintered (more laminated). Lay down cement head and 2 Jts ofDP. PJSM for SW Displacement. - Displace well over to SW. Pump 200 bbls Sea Water. Follow wi 70 bbls Hi. vis sweep and displace wI 820 bbls of sea water. Final NTU 380. Negative flow test well. POH wi 12 stds. PJSM. Monitor well. Change out drilling sweep to production sweep on upper annulus. Fill hole and monitor well. POOR wi HRD running tool. Continue POR wi 7" HRD running tool. Inspect HRD on surface - good condo Make service breaks- LD. Move rig from NS16 to NS19. Center rig over hole, level, and shim. Prepare rig for drilling as per Pre-Spud Checklist. Rig Accepted at 0800 hrs 03/22/03 P JSM -- ND tree Pull BPV. ND dry hole tree. Install drilling sweeps. PJSM -- NU BOP's Nipple up BOP, turnbuckles, Koomey lines, and choke line. PJSM -- Nipple up risers. Pull Hanger. PJSM -- Rig up test joint and plug for BOP test. Test BOP to 250 psi low and 4800 psi high. 5 minutes each. Pull test plug and install wear ring. Blow down all lines and clear rig floor. I 23:30-00:00 0.50 I 03/23/03 00:00-01 :30 1.50 I 01:30-02:00 0.50 I 02:00-04:30 2.50 I 04:30-05:00 0.50 I 05 :00-06:00 1.00 06:00-06:30 0.50 06:30-07:30 1.00 I 07:30-08:00 0.50 I control contingency. 08:00-11:30 3.50 ( 11 :30-12:45 1.25 12:45-13:00 0.25 13:00-14: 15 1.25 I 14:15-15:00 0.75 15 :00"-19:00 4.00 I 19:00-20:00 1.00 20:00-21 :00 1.00 I 21 :00-23 :00 2.00 I 23 :00-00:00 1.00 I 03/24/03 00:00-03 :30 3.50 I 03 :30-04:00 0.50 I I 04: 00-00: 00 20.00 I I Drill shoe at 13,496' MD. Control drill rat hole to 13,500' MD. Slide 20' of new fonnation to 13,520' MD. NOTE: Obtained L WD GR data - no MAD pass required. Perfonn FIT to 11.5 ppg EMW. NOTE: 1. 1300 psi on drillpipe (42 strokes). 2. Took 3.5 bbls of fluid to pressure up. Drill / slide ahead from 13,520' - 13,869' MD. No drag, No losses. Built angle to 60 degs. NOTE: PU - 360K SO - 225K RT - 360K Torque - 14.0 - 17.5K PJSM -- Picked up BHA and shallow hole test MWD. Rlli with 4" drillpipe (24 stands) PJSM -- Change out tools to 5". Rlli with one stand. PJSM -- Cut and slip drilling line (102 feet). Service top drive and crown. RW1 in hole with 5" drillpipe to 11,491' MD Gust above 7" liner top at 11,585' MD). Fill pipe with viscosified brine. Blow down. Continue to run in hole with 5" (114 stands) to 13,392' MD. Tag landing collar on stand 115. Drill up landing collar. NOTE: 1. Swap out to 9.2 ppg mud. Drill shoe track from 13,400' to 13,486' MD. Trip in hole with 5" OEDP to 2200'MD. PJSM for diesel transfer to 0&1. NOTE: ACS, Operations, 0&1, and rig personnel present. Displace freeze protection fluid from well at 1.5 bpm through the trip tank to 0&1 NOTE: Trip tank covered with mats. Benzene monitoring - 0.2 ppm maximum reading. Monitor well for 30 minutes. Trip out of hole. PJSM with Halliburton for casing test. Test casing to 4800 psi with Halliburton for 30 minutes. Pre-spud meeting with Company Rep. NOTE: 1. Discussed goals and high points of the program. 2. Discussed Loss Circulation Decision Tree (Pay-zone drilling) and well I I I I I I I I I I I I 1. Top Ivishak at 11,016' TVD;' 13,782' NID 2. Motor set at 1.50 bend yielded 14.5/1 00' with 1000,/0 slide over 30' coarse length. No problems sliding. 3. Bha dropping 0.3/100 rotating. I I I I I l I sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS 19 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: TOM MANSFIELD Report Delivered To: KEN LEMLEY I 11 31 3 to 11346 ft 9160 to 9183 ft Show Report No. 1 Dateffime: 11/6/2002 Depth (MD) (TVD) I Interpretation: Steam still analysis indicates this portion of the Kuparuk "C" would produce gas. Drilling Mud contained 3% lubricants. Samples had 50% dull to moderately bright yellow fluorescence however, no cut fluorescence was observed. No visible oil sheen was observed in mud samples used in steam still analysis. I % Depth 11315 ft Gas x Units 1016 Mud Chlorides (ppm) = 17500 ---¡?iõWirñë-------§üëïlõn------sli'õy¡----------------------------------=----------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 56,3 2.81 53.49 - -- C2 5.10 0.81 = 5.02 - -- C3 4.13 0.98 = 3.15 - - C4 2.91 1.01 = 1.90 - -- C5 1.95 0.75 = 1.20 --Prõaüëtiõ-ñ------=------=---------------------------------------------- Analysis JXlGas nOil nwater nNon-Producible Hydrocarbons 2 % I Hydrocarbon Ratios C1IC2 10.7 C1IC3 17.0 C1IC4 28,2 C1/C5 44.6 I I Depth 11330 ft Gas x Units 750 Mud Chlorides (ppm) = 17500 ---¡:ïõwliñë-------šüët1õn-----=-Šhõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 41.70 2.81 = 38.89 - -- C2 4.79 0.81 = 3.98 - -- C3 3.43 0.98 = 2.45 - -- C4 2.59 1.01 = 1.58 - -- C5 1.80 0.75 = 1.05 --Prõaüëtío-ñ------=------=---------------------------------------------- Analysis nGas nOil nwater nNon-Producible Hydrocarbons 3 % I Hydrocarbon Ratios C1IC2 9.8 C1IC3 15.9 C1/C4 24.6 C1IC5 37.0 I [ I Depth ft Gas Units Mud Chlorides (ppm) = ---Fïõwlrñë-------š"üëtlõn-----=-Šhõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1IC2 C1/C3 C1/C4 C1IC5 C1 = C2 = C3 = C4 = C5 = - -- --Prõaüët¡õ-ñ------------------------------------------------------------------------- Analysis nGas nOil nwater nNon-Producible Hydrocarbons 4 % Depth ft Gas Units Mud Chlorides (ppm) = ---¡:ïõWiTñë-------šüëtlõñ-----=-šli'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 = C2 = C3 = C4 = C5 = --PrõaüCiíoil------=----- Analysis Gas Oil Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1IC5 ---------------------------------------------- 1000.0 NPH 100.0 Gas 10.0 NPH 1.0 . C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -., ---,.__._,._.~----_.--.._-_._._-._-~ ---".---,- .-..-...- -.-., -, -..-.-.-."'.---.-.--"- ---- ..-. --.-.--------- --~..__..... -_.~-_.,,-_..__.__.__._--~--~._--_.__.- --..'..'-- ..--_. .-.--,,--.-.-..- ...--. ..----.-- -~--'-----'----~ - -. -- -- ..- -~~~~~~..=:_=:~-~~--=~ -==- .--.---.-.--.... --- --.--.--.-..-..----.--. --.-"..,.--.--,-..-..-....,--. .. _..___._______~_._n._ ._._.__M."'_._._..._~_._,.___,___ _ --'--.-.-' -.----..--.- - ~_._~._----------_.-.- ._-,-_.._.-._-~----_.._--_._,-- -'--"--.._._~--- .-.--..-...--....."---,.----.- Oil ----.-----.---.-- ..._" _ø_._____....._. ....__.._ ..,.._,_..__ ,__.._._~._.._...__...____"....._ _.._ .-----.----.--,-- ----,--~_..._..... .__.---_._~_.._._.-.---_...._._- -----------------,....---.--....--.--.---- . ........".,.--..----....-.....-.-,... --,-.. .--..----...--.--.....-..---.-..--- ----.-.-......---- 1000.0 NPH 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 .-". - -'-' ---........--.-..--.-. --.-....--.,,--..-.-. --.---.......... ... "----- .. .......-....--...-...-.....--. .-_.-.._-..---.--.--_.._------- ,~-..~.._".._.__........._.._~..-_. .---- -..----.-----.--.--- .__._---------,.._._,.._~ ---- --' -- . .~,.~.~_....._._, _. ..... _..._.____, .__.. _.....nø..._. ."..~._......,__.........__.._.._.. ...._..___.... ·___·___..·___·__.._.ø.___·..····_·_...~ ..______._.._._ ..__~. __.._.___~.,..__.._......_ .~_.".".~_ ..___..__~.._____.ø..._._ ---.-,--..----------- .._--_._._~._-- -------.--- _ ... ....-1ØII-........~ ---- .. --' -.--.--- .._.___.__~_ø_·__ ---.--.-.----..,--,.--., ._---_.._--~- .-.,----- __.___..__ø..._~.__..__.__ ______.________ ._._.....______.____ ---~..-......-.._---------------.----,-- ~."-_._---.-- . -..--.---- ---_....._._---,.,_.._.._.._..._.~.- .,~.. - ...-- -...-.-.....--..,,--.--......--.- I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS19 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY 13500 to 13612 ft 10855 to 10929 ft Show Report No. 2 DatefTime: 3/25/2003 Depth (MD) (ND) I Interpretation: Steam still analysis indicates the lower portion of the Sag River would produce oil but samples showed little porosity. Drilling Mud contained 1.0 % lubricants. No oil odor/sheen visually present in steam still samples. Samples ( 13500-13580' ) had a trace to 5% of a dull yel fluorescence no cut. Overall sample quality poor due to abundant cement in samples % I Depth 13540 ft Gas x Units 325 Mud Chlorides (ppm) = 21 K ---Ffõwliñ¡-------§ücflõ"ñ------§l1õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 5.4 0,15 5.2 - -- C2 0.98 0.05 = 0.93 - -- C3 0.84 0.07 = 0.76 - - C4 0.76 0.09 = 0.67 - -- C5 0.55 0.12 = 0.43 --PrõaüëTioñ------=------=---------------------------------------------- Analysis fXJGas fXJOil nwater nNon-Producible Hydrocarbons 2 % Depth # ft Gas x Units # Mud Chlorides (ppm) = ---FiõWiiñ¡-------šücflõ"ñ-----=-sl1õW'=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 --PrõaüëTío-ñ------=------=---------------------------------------------- Analysis fXJGas fXJOil nwater nNon-Producible Hydrocarbons 3 % Depth ft Gas Units Mud Chlorides (ppm) = --FfõWiiñ¡-------§ücflõ-ñ-----=-sl1õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 - -- --PrõaüëTíõ-ñ------------------------------------------------------------------------- Analysis nGas nail nwater nNon-Producible Hydrocarbons 4 % I Hydrocarbon Ratios ClIC2 5.6 C1/C3 6.8 ClIC4 7,7 C1/C5 12,2 I I Hydrocarbon Ratios C1/C2 1.0 C1/C3 1.0 C1/C4 1.0 C1/C5 1.0 I I Hydrocarbon Ratios C1/C2 1.0 ClIC3 1.0 C1/C4 1.0 C1/C5 1.0 I Depth ft Gas Units Mud Chlorides (ppm) = --Ffõwliñ¡-------šüëilõ"ñ-----=-sl1õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 1.0 0.00 = 1.0 - -- 1.0 0.00 = 1.00 - -- 1.0 0.00 = 1.00 - -- 1.0 0.00 = 1.00 - -- C5 1.0 0.00 = 1.00 - - --Prõaüëfío-ñ------------------ Analysis Gas Oil C1 C2 C3 C4 Hydrocarbon Ratios ClIC2 1.0 C1/C3 1.0 C1/C4 1.0 C1/C5 1.0 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 . - --.-----. -..._- ---.-------.--- 1 000.0 -.~~----~=:-=:::_..:::::.-.::...::.:..:.:.: .·__h.____··____. ._,.___..._._._ _.__.__.__~_ _ _ - ~. - -- .----... - ---.. ,-.-....-- -._...~-. ....-- -..-.-'''- .--,.-------.-.----.-..,,--...-.--- ._~----"--- - ---.---.--".--. ~---_. _._---~----_.- --- "---'-' .--.---- _.__._--~._---~._-_.~_."'._-_. NPH .-..---.---.--.----.- -----.-.-...---.-- -..---.-.- 100.0 .. - -' --- -.;;...;..;.=;;,-,:;;,~"",,~ ._....~.:::..._._-- ..-.- -_._~_.~-- . _ __ _. .n_. ._..~.. _..___.._.._.__.._ Gas --,...-- ~--.__.__..__.. ~----_...- __m_____.______._.._______. _.___._._~.___._~__.__ ._____.__.,_._.___ ---- ----- ...-..- 10.0 ----- ._---_.._..~..~ ".._..._._~......_.-. _._.'_"__"__"~ .,------..-.._--~._--_. . . .,-.-..-...-. _._._---_..._-_._.~~.-._.__.~,.. ------_...,......-...--"..---_.--- ___.._..__.,..._,_.__...~.....__N ..._,__...___.., h .. n_ ... ~._~,,_._.~_._.._._.._.._.__.~~ -. ~.._._. ~'-'-'-'~"-"--'--- - -. --. .--.-.... .-. -.--. . - '-_.~,-,-----~, -._"..-."_-- Oil .,.,-.... -.....-"..-.---...-...,.. ....-....-.--.----..-.-..--..--.---.-.-.-...--......-. . -_....._...._...__.._..._--_._..~.- NPH 1.0. . . . .----.----..-..-,-.--. --~-----_._._--- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -_._.__._-~._~-----~----_.._-_.._-~-_..._~_._._.._----,.-,-,-_.,-,.__...._-_._-,...,_._...__._-_....__.~.._....._-,- .__..._~_.__.- 1000.0 _.__._.._.~---_.._...__._-------_.._- .._--~----_._._------ ..-..--...-,. .._~.h.._.___.__________ .......-....--.....-.....-".-.- .. ._"'"...._...". .._"~.~.. "~h._h"__·__··_" _..~_ ~'___·_R__..___..._____"'_ _._._____._.____.._______,,__._ .--... -_._..-_......_,..,_._-_._-_._..._~._.._. ..--.----..-.---..-.--......-.-.--- .--..---.--.-.----.---.---.--.-- ..--...,,----...,."--.-.-.-.-.---,--.-- _._-----~.__._-.._------~-_. -.--..---------.,.----..-... . .___h_"_..._~__..."__,_._______._.,_. ___.___..._.._....._..,_~__,._.,_,_... ._....._.,_._.._.__...........___.._ NPH .._ .,,_.,~_____ ___.___n_._...... _.._____ ._. ___ ..__.__._n_.__..._...._._..__...__._____._ _.___..~._...._.. __._,__.._.. _._.__ ...._.___,_.,_...__._,_. ~_..____..,.,... '._"___._'R'U__"_'_'_' ,.,~___...._ 100.0 --' --- --._,~.::.~._.._.__.._...._----, --.--,..-....--.,.."..----..-.-....--..-...'"- ~:~~~~~~~~~~~~ ~===~~~::::.==~~~:~~~~~~~~=~~~~ ::~=~.~~::.~~~:~=~~~==:~~~-~:._..~~ ..-- "--.--.-...-...-..----. .-'..-_.~..-'--'.~.-......"" ..-.- ._~._-- _........~-_........._.~.--,...... ----......-....- ~ ._~----_._----,._~---_..- -.--.-.-.---.-,--...-..-,.-.--.. ----~.._.-,'_..._._.._.---_..- Gas __.._.,____..__·__..·...M_._____·___~.___....·__._·____.._..__. .__.__._._.._____ ...__1 ----- ---...-- 10.0 ...---.--.------ - -_._..~_.--_._,._--,---_.- Oil ---- NPH 1.0. . . . sperry-sun DRilliNG SERVICES Show Report Well Name: NORTHSTAR NS19 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY Depth (MD) (TVD) 13782 to 13880 ft 11016 to 11062 ft Show Report No. 3A DatefTime: 3/25/2003 Interpretation: Steam still analysis indicates this upper portion of the Ivishak would produce oil. Drilling Mud contained 1.0 % lubricants. No oil odor/sheen visually present in steam still samples. Samples ( 13820-13860' ) showed 20% of a dull to moderately bright yet fluorescence with a milky yellow white cut fluorescence. % Depth 13802 ft Gas x Units 276 Mud Chlorides (ppm) = 21 k ---FrõWiiñã-------šuciiõñ------š-lÏõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 29.8 0.41 = 29.4 C2 4.72 0.03 = 4,69 - - C3 3.45 0.06 = 3,39 - - C4 2.41 0,12 = 2,29 - - C5 1.49 0.17 = 1.32 --Prõdlictíõ-ñ------------------------------------------------------------------------- Analysis rxJGas rxJOil nwater nNon-producible Hydrocarbons 2 % Depth 13822 ft Gas x Units # 218 Mud Chlorides (ppm) = 21K --"FrÕWlfñã-------šuciiõñ-----=-šlÏÕW'.=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 40.9 0.41 = 40.5 - - C2 5.84 0.03 = 5.81 - - C3 4.46 0.06 = 4.40 - -- C4 3.05 0.12 = 2.93 - -- C5 1.85 0.17 = 1.68 -Prõdlictiõ-ñ------=-----=---------------------------------------------- Analysis ("qGas fXIOil nWater nNon-Producible Hydrocarbons 3 % Depth 13845 ft Gas x Units 190 Mud Chlorides (ppm) = 21 K --"j!rõWifñã-------šuciiõñ-----~1iõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 33.5 0.41 = 33.1 - -- C2 4.54 0.03 = 4.51 - - C3 3.37 0.06 = 3.31 - -- C4 2.30 0.12 = 2.18 - -- C5 1.45 0.17 = 1.28 - - --Prõdjjctiõ-ñ------------------------------------------------------------------------- Analysis nGas ['qOil nWater nNon-Producible Hydrocarbons 4 % Depth 13880 ft Gas x Units 141 Mud Chlorides (ppm) = 21K ---Frõ,¡¡,lfñã-------šuciiõñ-----=-š1iõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 17.1 0.41 = 16.7 - -- 2.5 0.03 = 2.44 - -- 1.8 0.06 1.70 - - 1.3 0.12 = 1.20 - -- C5 2.1 0.17 = 1.93 - - --Prõdjjctiõñ------------------ Analysis Hydrocarbon Ratios C1/C2 6.3 ClIC3 8.7 ClIC4 12.8 C1/C5 22.3 Hydrocarbon Ratios ClIC2 7.0 ClIC3 9.2 C1/C4 13.8 C1/C5 24.1 Hydrocarbon Ratios C1/C2 7.3 C1/C3 10.0 C1/C4 15.2 ClIC5 25.9 C1 C2 C3 C4 Hydrocarbon Ratios ClIC2 6.8 C1/C3 9.8 C1/C4 13.9 ClIC5 8.6 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ._----~-,-_._-,---_.._-_..,,_._-_..- 1000.0 __.__. n.._...._... ..__ _ n_ __......_ "._ __._ ---~--- -------_._----~..----- --'--'--'--' ---.-.-------.----...-- --- - -. --_. -.---.- -'--'--- -..-.--- ----------.-...--.-.- ,---_._----~-_._._- NPH -_._-.-._-._--- ------.-------.-.---.- --- 100.0 - ............................. ....dd__~~-: =~;;~-=~=~ =~----,::=.=.=:.==:= ~-=~~=:==~~=~~~==:= ______._.__'"_____...h___.. .. ,__. ..-."' _...._._-----_._.._.,~-,...... -,..,..,,".-'" ,..--...-.....-..-.".----....-.-.- '.-.--.-...--...----..---...,,--. .._- ,-, ----,-'._--.---.------ .- "-,.,,.. ----" --'~---"-'- -----..----"-.....-,---,.-- Gas------·--------·· 10'O~~ --..---.-.-..-------- --_.-.-,,----- --~_._-_._-- Oil ..-.."-....-"".--...-.....-......-,,..----..-...,--... ...- NPH 1 .0 -..---... ... .-.....--.- -----.----.---.... ....-.---.--.-----..-.- --......-- - . -----.-.--...-,.-..---.-.-.-- -_..._-,_.__.~---~--_.---..~_._._.__..__...~..._--- .....___.___.W···_·__"·M.'_...·_.~.~_____·_·_._· C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ._~,____._,_··___·_.__.__w..__..__._·_,_··_.__~_____~_.._._..._._.,_~,___.._~..__"..._..__~..~________....___ 1000.0 --...-...-.-.-.-.-------- --- ____._.w___.__._,.__ -.---.., -_..._.~.._-_.--"..'__"'- _.,--~..._",...-_.,,---_..~_.~.._._-_._. -_.._.,,--~....--_.~--_.... ,._.,....,,_.~..- ._._._---~~..._---_.~.~....__..._...... _ ·___._.w___,_...._._~~.·__,..,__ ~..-..-._--,-_._-"... ---".,~.._..._._-,..,",.~- ---......-.,,---------- ..---------.--..--.- .-..-.----. -- NPH ._...._._"..._..,_._....~--_.._--_._-_.- .._-.~.._.~.~,~.----_..~.-..-._.....-_....~. ,-,,-~,- .- -~,"" - ---.-,-...-.. . .....w". _'_'__~___'" .__'._,._..._..___._...__.___n".__~__~ .__.___._.~__ ,~.._.... 100.0 .... ... ... ' ..".~..-~ _._-.--"--~-_._-~-,-'- -------_..__._--.--..- ----,,--.--.------.--...-...- ...~.~. ....._~..._~-~.._.._----,,-- -- .....--.....--,,-..-----.-,,- Gas 10.0 ---_._-_._---------~ --.--------------.. -...-.-,,-.....---- .-....-..-..----.--.".- Oil -...-..-.-- --...---.-.--- ~.._..,,------- ----....-..,..- -'--'-'~'----.' ..,- -_..._'''-_._----_...._..~ --'.._---,-_._--,--~_._.__. -_..._._-_._-_._--~. -,-......-.---..------- ----~--.__._---- -'-"-'--"---"--...-.--- NPH 1.0 --~-,,_._.__.~..--_.--_._._--- --._-_.~.-._.'~.-_._..---.-.." .~~.. I I I I I I I I I BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 24 hr Max ft/hr @ units @ deg F @ 257 520 620 spe..........,y- sun c:J A! LL IN G 5 e A v I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: "":/"., . " ." "..:" '" ,"".. -. "'" .", ' "';' r .'-;:''''.''JI~..~~.~1'''\.i'. ~,,""~"'tl r . ~. ~ ,.~.', Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report . ... ,"';, ':.'. '\. .'..'~'l',"'~~~,"~ '~--:'>',,)i,: :I"'~ ',,~:~~r ,¡':'~,\~~ 'i' t;:,~',>:- :'~~~: '. :l ';,~~'_". 1;~~':~r,~~'t~~':~'~1 ~·{';,,;,~~~~Ä+~~\;~·~~:"':·,;'t\~t~~:;~t.~¿~~:~~t~~:¡~,:<,:·\:..:".!i:~.~::".'l:·' ,;-,,;..(~~.~~;*¡,·:-~',:,;~~:':~:(~:~t.~·:.::;~~:;,\:s.:~,: ' ,," 1 1 0/29/2002 1.130 1,130 Drilling BirkbeckJDinger Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 88 spm DH flow 87 spm Total flow spm A V @ DP 1500 psi AV @ DC . ,'ø.. ". ,I ..Of ~.' . ..... .. . . I - ',: '··~·.I:··~· '-....;~;-...I...~.':..~, ." ',,',:' ..:-, . .. : ~.' '.'I?·""" ......:...;."..a··...."..':It¡;~I..,..,,"7~~..{?....:-:....~ ":.';. ~ .' --- '~.I;i~.....¡..·.:·.. - ......:.,'.¡ .....;":-,:...,.¡',~ , Bit No.: Wt On Bit: 4 Type: RPM: Hugnes MX-C 1 Bit Size: 60 Hrs. On Bit: Current R.O,P, 122 Gas* 1 , Temp Out 52 24 hr Avg 255 ft/hr ( 2 unit~ ( ( ft/hr units Deg F 887 10 52 16" 5.5 . ., . . Jets: 3 X 20 -- Total Revs on Bit: 1 X 12 41 TFA: Footage for Bit Run . . '.......""J'. ..~.~. , to % Drilling Breaks after before Mud Wt In Mud Wt Out 740 58 94 gpm :} gpm¡~ fpm <. ~k fpm ,¿' iU '" "",,~7-!I~[ " . - T' 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: .' 9.00 ppg 9.00 ppg Visc 121 secs API filt 13.0 ml HTHP 0,0 Mud Wt at Max Gas ~ppg PV 23 cP YI 52 Ibs/100ft2 Gele 25 / 35 / 37 Ibs/100ft2 pH 8.5 Sd 2 0/0 \:- ~~t Trip Depth: Short Trip Depth Tight Spots: to .~~J;~a;;'Î;¡~i~~:Iß~~ ft ft Trip Gas: Short Trip Gas: Mud Cut: ppg CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: IU ,..JKX.~::t,{iffV~I',_,J! I T lEI ~ l~ ~.'::n:.a:v:' " SST % SH % I "m~L'"Œ: rIM. ij"1111 _ "-::I ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg 18000 %LCM ft ft ft units units units . ~'.... 1.0310 1,130 - ... ~ Current Lithology: % SL TST ;......_~.Lr_ .... Gas during after % Lithology Sst 81tst Sh oz. ppm ppm ft ppg ppg ppg '"\ '-tr~~~ ., ".', . , ; ~"' ,I·~,:,:',~"~"·" :' , ~" .~ ~ \ ,;~ t \i ~: Logging Engineer: Reg Wilson/Mark Lindloff * 10000 units = 100% Gas In Air ~ I . h "I~~·\";P?:~,\~~~:f'\~t~~;,~~~~~*-:';~~~~~~~~~~~4~;~~~~~Æ'~~~~_Þ~~f't~ units units units Depth Drill Rate during o .¿".,. ",..:..;:·:",,£¡~·M'~.;}~i''&.'{,~\i;¿~(&}iI~~ r,,~.:~-:,y':"."~:¡,~fi/f...\~~~};~·'¡¡'.:¡;#i;;;r;kt!fi:_~>·:\t"~~~J:ti\'.\m.$~r;;f.Jr~;'~"£~;~'~<,,:":i~,,~~~·~~..~;jrl~.r·;;- 'i., 24 hr Rec. Finish Rig up on NS 19 , Pick up BHA#1. Clean out conductor and drill to 330', POOH ';¡ pick up BHA #2, RIH, Continue drilling from 337' to 1130'. Gyro surveying every 2 stands. before to to to to I I I '. -....r..,.,...~ .;.. sper'r'y-sun DRILLING SERVIL:ES Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 2 10/30/2002 3,260 2,130 Drilling Birkbeck/Dinger Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 100 spm DH flow 102 spm Total flow spm AV @ DP 2171 psi AV @ DC 846 91 108 gpm gpm fpm fpm .~ '. . . ..t..~·.~·~~~¡;~~:C"~.f:':-=-'''''·~':~I'''''':"1 ·i'"rl .. I ,. ..~,.(". ~ :. :,,".·I.":1'~IIII·" .,~,.~~... ......' '. " ,~...",,'~~ . ....,...... ~ I· I". '~~~,...if."....,....; 1 .: ~"."-. ..,:!,;' ....:, -- 9.30 ppg 9.30 ppg Vise 75 sees API filt PV 19 cP YI 35 Ibs/100ft2 9.8 ml HTHP 0.0 Mud Wt at Max Gas ~ ppg Gel~ 20 / 30 / 33 Ibs/100ft2 pH 8.9 Sd 1,25 % % SL TST JiIIWIII: rmnum lII.:I::.:ll(:':1[-· % SST Mudlogger's Morning Report '~', :;0.:. ..~~~i;~'~~~~~~,:, '-,:,j;, \~.'I;:<Y';":!-,~~, ~',~~~" ,~,!,4:~~·\~~~.':!<t~.",~~~;;,;'(~I'.~ti~"1~'~~ìt;..,,~'; :.{<, :~?~.~;, ,- '" ''';~I .:.;, r , Bit No.. Type: Hugnes MX-CI Bit Size: 16" Jets:.2..... X ~ -2- X ~ _ _ TFA: Wt On Bit: 20 RPM: 60 Hrs, On Bit: 16.3 Total Revs on Bit: 125 Footage for Bit Run ~1!IIf_:lti.~~¡ørl.~C~;;;~~'1;;;LXtJ"..,.. ""..U]l::a......m~,I.ïD.^' 11 f.. ¡ ~,~~ . 1,0310 3,260 -, ,~ r I I R.O.P, Current 109 6 72 24 hr Avg 281 ft/hr ( 13 unit~ ( ( 24 hr Max 1014 ft/hr @ 62 units @ 72 deg F @ 2011 3189 2961 % SH % Trip Depth: ft Trip Gas: Mud Cut: ppg CI: 18000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Ilf~:'·~~K ···¡ø...·1iJ ·i1(·l,~C]iU£,CJW~W,f' . [ n.;;T:J,;.:Jf]':.r::Uw:~:rL[·t;;u:*U::t ! ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units _ ppg %LCM ft ft ft units units units ppg ppg ppg ft/hr units Deg F Mud Wt In Mud Wt Out units units units Drilling Breaks Depth Drill Rate during before Gas during after % Lithology Sst Sltst Sh ·Äü¡.·4·.~)'1>.;~~~~~.~~~~~.~,*~~~":;:~~i.~::r&'~~~~_~"i(,:~~.J\;!~. ;,i 24 hr Reci Drill ahead from 1130' MD to 3260' MD. . ;}~¡ Tops: Top Permafrost @1195' MD, 1190' TVD, Base Permafrost @ 1586' MD, 1577' TVD, Top SV6 @3230' MD 1¡ 3065' TVD. I I 1:~ Logging Engineer: Reg Wilson/Mark Lindloff ¡;1.\;:·'~~~~~f:,·, ." ,..'" ,,~ '~.,,,,.'. before after to to to to .., " .., ,., ~)J;l~A] ilM_lll~r":'~E: ::.~''" 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. Description of fillings: - ' * 1 0000 units = 1 00% Gas In AirJ. : ,:' .;: ,\,':. ~~.' ,~,.,,,~ , ~ '; . " ' ", ' . '_....t' "'"' , '>II::,' -,". ".. ',,' -- ~-; - I', " ...~c..~~~ .... J' 24 hour accumulation of Steel Filings from Possum Belly Magnets: i' Description of fillings: ·r:.'.........·...~~m 3260'MDt;34~6;MD.···Cir~s~eepsand Cle~=n~<"~ ~¡; casing. .~ 1. ;I~, ~ ~ ~f ~ \~. J j '. L09gm,;) En';;¡lneer' T,:)m Uansil€ld R€g vVdson . 1000ù units = , OIJ'~ " Ga:; In ~Ir : ¡' :II:~ _.~: ~4. !. ~·~'l ?~~ ·~~I~r~,.~' ·':~I, /,~ .~.\ ~~ .,' ,,r,~...J:~:~. L~~ ,~ 1·~'r,~:~"I~~-,:.;~~~~..'~:1 -..~ ~~~~~_~;~1~~*~~~~. ~·'~I'~;~~~~~I~::~'f.~~~· ;:.~" :~:, i,.1 " ,~'-?~I,.:·t~:~:"~~~~~~r~!.~~f::".',. .;.,~.," ',I'~".~'·~; .:'~¥~f),.I~,:.i~ "~I.~ T I" - . .. r:L,I~~f'~W.'":'~'J'~...~ o,¡¡L"~ % Lithology Sst Sltst Sh oz. o I I iJ I r J ""'"' ¡ I '.._~:. ~~. ~ -t.1~»ftD'~_ ., ..~n"DiJII\I·ìl·:: ~_,-,-,A,,~,.~:nr~~ 1"'¡"'i!IIoV-"O..><..I" - I units _ppg units _ ppg units ppg to to to to after Gas during Depth Drill Rate during after before before Drilling Breaks ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg units ppg units ppg units ppg ft ft ft WD1IMtJ::: % ._._._~ Current Lithology: .... ~ %LCM % '.' . _ ". . :....:.... .'.'......;.," :. I,' .::~'"" . ........ ~k,. J~.~....,...,~;.,;"...I.'i":!:: "2,~' : ~~/.~-.f' .......~,"'.~.'t..." ~.~ '0' !.':~' ~,,~. ....Sf'Ir'l;...." ~«-w..~ . ... ;"]'1: '0" .". . .: . . ~..:: ~..:.'¡\." ~ ",or 1 ~ . ;- " -... : , . ' .. . I __ 4··r"¡:'1,,' ~it No.: 1 Type:' Hughes MX.C1 Bit Size: 16" Jets: -2- X 2Q... ~ X.23... _ _ TF A: 1.0310 I , Wt On BII 3.1 RPM. 60 Hrs On Bit" 196 Total Revs on Bit 1.10000 Footage lùr Bll Run 3.426 .,~ ;..;."" . .." .....".,..,..,.---~--~...",.,.,,,."""'-"""~...," '.' ":',.<:."," .... .,.,-~ Trip Depth: 3426 ft Trip Gas: Mud Cut: ppg CI: 17500 ppm 1 i Short Trip Depth ft Short Trip Gas: Mud Cut: = ppg Short Trip CI: ppm I·· Tight Spots: to to to Feet of Fill on Bottom: ft '-'-Alæ·~~::~~~:r__:1-l'mn! nrr ! ~--':-~~·l~ ¡If ~ lß JWlII. II fr.IJCI~ìr~'_f[JI):..,. "I ijlfI % % --- ppg PPg Mud Wt In Mud Wt Out :i¡ ,:ø: Mud Wt at Max Gas ~ ppg Ibs, 100ft2 pH 8.J Sd 0 5 'J Ij Visc PV 9.30 9.30 9.7 ml HTHP Gel~ 13 I 24 / 48 secs APlfi~ 14 cP YI 26 Ibs/l00ft2 I I I I I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P, ftlhr 100 ftlhr ( 159 ftJhr @ 3318 ) Pump 1 101 spm DH flow Gas* units 7 unit~ ( 15 units @ 3258 ) Pump 2 101 spm Total flow 846 Temp Out Deg F ( deg F @ ) Pump 3 spm A V @ DP 66 Pump Pres 2350 psi A V @ DC 92 .. ... 'r'0, ",",'" .....:.~a:...~... ~.... ...1'=.'.. '.~.:. ;",,"'¡',~~.~'.,' :,.:.~'I' t,··......:~:·~..r.~~.!..."OJ,t·." .~- 'r·'I·.:.,,~..- ~. .......~....' .::...;.~ . "C"....."..,..... 'r' .... \ .~.:~.~:-,: ~ <i:.'i\. :~~'; :~:'~.~::y..;,i~~{¡...ib...k,)~~'t':'.'~~~~f..~'(: ~',~ ,; '~,',~: "'; t~Þ:-;,I:;J.~~:II.·, .,-;:~:H:~. ~,'.;. '"t~"f'.i..~~..~)\~ij)":~-:.:.·"'~:~::0..~·~~.,i~/,:\i·}.~. ;:,~_' : ~ "," ~.,' __ '<, :'t\¿¡ ,;~'" ,\.~~~f;.~';':\,' ,~/?~~~j :t:~,~..:,'~,~~',.~J~,~~',~:\:j¿ ]'.,";:. ~,~~'~2i j:'\:'.',' '.:. " ~. .' '. .' .::~ "" 3 1 0/31/2002 3.426 166 Run CSG & CtvlT Birkbeck/Dinger ,.' Report No,: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 DR! LLI N G 5 ERVI c: E 5 5pe.....,.....,y- sun I I I I I " '.... ,'1· ...:;~,'>'." .~':' ~ ':, ~ " .:,.~I. '," . !,~' < .~~~:I,. :~:/':'~:!,\l:~". ,,~::' ~'~:i ,)::,;'~,~':~~:~'è~~)~~,~~:~T-l:~~i,~;.~~,~;~~;'k ~~'~~~i";~ il!.:~:{,*,~~it.~~{lt~;~~:;tt:r:':~\~~~(~ ~i.~'; ','~' : 4 11/1/2002 3,426 o Test BOPs Birkbeck/Dinger .', ',;..:-,. ~': .~",\:,~'¡"7",",~ . ,'," ~', ...,:. ':.~;;'\~'·:.\;'\'.,~.(I\ :";.~.~(i.'_~~j3...~>,~;~:"~,(.'~,:~,;·:k~:.;::.r~(,,r~..~~*'~J~"'t~~~'.,'J~,,=';.1'<,:,:"~.:.&:~~~~.~~~~¥?,_:~~~,;':~:':$,"~~~'~:"'~I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. ft/hr ft/hr ( ft/hr @ Pump 1 spm DH flow Gas" units unit~ ( units @ Pump 2 spm Total flow Temp Out Deg F ( deg F @ Pump 3 spm A V @ DP Pump Pres psi AV @ DC I I I I I I sper'.....V-5un DRiL.L.ING sERVIc::es Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ppg o % 1,0900 o t - ~~ ppg ppg ppg ;["'~" ,"" ·',:tœalt~~g;¡¡mJ~Œifn~m~:l:I:,IY.~II..llJfili:·' ., , ',1 ";J 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. . ..,' .~ Description of fillings: ;.:.,.~~~~~=1~~~¿;~~~_~,.,~,,1. · , 1 :~ ¡.~ 'fj -\ ~ L :~m. ,~ ~ ~ .~.'..~..~: ~ ~ ~ ~ Logging Engineer: Tom Mansfield / Reg Wilson · 10000 units = 100% Gas In Air ii .~'¡'( /4 \J '''·;:.''~;:~}~1f~~#~....~·;r.:f¿ff-,~: .'. j- ,. ;.~_'\...', '".~\ .' .'. .." '. '.' .,\':1·,,;';~" .... .. f . ..,~ ,...," ,".yþ,..':JJ ~~. ",.'" ....\,)"'., ".~>.1~_~~..._~~~~_.~~.~, BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Mudlogger's Morning Report Mud Wt In Mud Wt Out 8.60 ppg 8.60 ppg Visc 55 secs API flit PV 13 cP YI 16 Ibs/100ft2 8.5 ml GelE HTHP 6 / 8 / Mud Wt at Max Gas Ibs/100ft2 pH 9.0 Sd ", "~'...-.. :-., .',..~ l~:;',I:".'.~.",,<:"·,,, . . ¡ '.J' . :-. ,".,: 0;", '... ...... .,".... .".','" -~..I I ~-"~.: ! . '. I I ~ ... ~ W. {II ~ ~ . ~. s ,:. '." . ';. Bit No.: 2 Hycalog Type: RSX238HF+GS Bit Size: 12.25" Jets: ~ X~ 2.. X ~ TFA: Wt On Bit: na RPM: na Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run ~:!]I:::~.n141';U\f(11::~D~i(::¡r:,;.¡::t.:X;;¡J;~~.¡~~~·~_~. Trip Depth: 3426 ft Trip Gas: Mud Cut: ppg CI: 17500 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft : ".J:ta1fBi:l:ml:t:n'.Ulll¡.\¡:~.;,:x.:;;;:;~r:mI!,.,,~ø::œI,,¿~~ _. .!..~Ln~,J.:::::;;;;;:~I::::'Cll f~ 1!.([:::.~::~tl-'lJr,·. ....- , I I . .. ,.i ""'-:'.~.~.~ ~.~ . .' ... Current Lithology: % % % % ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg units units units ppg ppg ppg Drilling Breaks Drill Rate during Depth Gas during before after before after to to to to %LCM ft ft ft units units units % Lithology Sst Sltst Sh gpm :i ~". 1 040 gpm ,;::.; ~~~: fp m ~~i fpm ;~? ,;~ ppg .;fi o % ~Y '~W: )i1. 'Wf( 1.0900 ~I 1 ,050 ~ ~I " ~.I~~mUESiillIL~...JLU.nllmf~~F:[UYiq~""",~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 Description of fillings: ;"~;.\¡iS':::f..~~~\~'·'· ...~~·~W_~~~ ,~:~ 24 hr ReCê Tested BOPs. Ran in hole. Tested casing. Drilled cement, shoe, and 20' new formation. Swapped ;~. out mud system. Ran FIT to 12.5 ppg. Drilling ahead @ 4476'. I Tops: SV5 @ 3582' MO, 3343' NO; SV4 3983' MO, 3652' NO; SV2 4537' MO, 4059' NO I I ~ ~:,~~oo~: unRS=100%Gas~~ I Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 5 11/2/2002 4.4 76 1.050 Drilling Polya / Dinger BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 5perr'Y-5un DR!LLING SERVices I Mudlogger's Morning Report '. ....: . .....-.. I Current 24 hr Avg 24 hr Max R.O,P, 177 fUhr 219 ftIhr ( 572 ftlhr @ 4778 Gas* 58 units 52 unit~ ( 191 units @ 4674 Temp Out Deg F ( deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 123 spm DH flow 123 spm Total flow spm AV @ DP 2075 psi AV @ DC . . ;~1,,-' ~:.~ " ",'.... ~-'i:.:.- ~..' r~I¡'~~""~-',,'fJ'...,.';· . . ""~,,::",',~..: ,I~·,~..~. ~_~. ,,~,,"';.~~.~i" ,"'.?,::¡"~~~;%.-~...;:"~j'àf.-~'· 'It~~,.~:!.."I!'.q'~~ :~.~jr;.."(\"l ~.,~.'I..~":¡I,8'.~:,.':r.',~j'~·:'J:.t'9ti~~.~;;'I'¡',,~.f.::r:~· " ", ~"'':' ð.,r.." :" I Mud Wt In Mud Wt Out ppg ppg --- 8.80 8.80 Visc 44 secs API filt 8.5 ml PV 13 cP YI 16 Ibs/1 00ft2 Gel~ HTHP 6 / 8 Mud Wt at Max Gas Ibs/100ft2 pH 9.0 Sd :;A..',¡.¡.-."··....."-~..·.".,·~I\M'i,...,~.';',.1¡f.~:y"''I#;t;·~¡~;..'*,B."'~:¡;So/t':,~:>¡~"»~IH~~~l¡;;'\I1.'~~:t-,r'·:,-F;:Jt,~~..;>t~;,j·¡,~,·:hl;::r·:;'!:\r~~;¿;:~?-~"~'~!~;"'~''''';:''. ;.'.: ::!, ,'.';.,... .'''';>'~,'J.;..\ .'.1:".<.:'" .,.;..., I ~~ {~~~ Bit No.: 2 Hycalog Type: RSX238HF+GS Bit Size: 12.25" Jets: ~ X..E.... ~ X ~ _ _ TFA: '~Wt On Bit: 12 RPM: 120 Hrs. On Bit: 4.8 Total Revs on Bit: 64100 Footage for Bit Run . ... "'. ...I.ImC\w.:U:.~:~::nx:r::a::~::U;DL1.n:r::l~n:~Wr.Ul.IØE~r.¡n:um~~m.]it( I Trip Depth: Short Trip Depth Tight Spots: ~111tM~u.IJ.",...Q:! ft Trip Gas: Mud Cut: ft Short Trip Gas: Mud Cut: to to to ~~n~::nac:::~::rtl:nl ~llnlJUll 1;1 [ ppg CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft r m H!!rr WI m ]I i J!fØbf,J'C:~-::::1I::D::r:mIC..~~~'-. I % % % Current Lithology: % %LCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ( ft units ppg ft units ppg ft units ppg Drilling Breaks I Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to I to to to .~.. oz. " <,;.\ ,~ ~~; :g:~ 1:: "I,¡ :~J; ~~~ i- ,....... I I I I .... \' . ;";.':,,::;,,¡.;;~., Customer: Well: Area: Lease: Rig: Job No.: . ;, ,:.; .. ";.'. I',' ;.. \~', f'.... ':,. . . . 6 11/3/2002 7,056 2,580 Drilling Polya / Dinger '", ~":;ì.:, ~",; ;":_:.': :~;!~: ¡~.,,,: ,'.,":,}¡(.:,¡" ::~ ,:' :~;,,¡;:~~i)~:'~:{~.¿~~~'~~ v.;,:H\ ~~~.:-::ijI\!"~é':;;:~~ \-;':1:\.:1,;.;;, '." ,;~-,,:\~., ,: ,..~: ;,";';";:\'~\~·'~':.~:~'(i.'~·,·~ '{~'l...'~'--::' .""- :':::T~n'¡'~~ I; ",.ë,r.¿,:~,~~,::~~'·;,~~~j; ,~'~;:',!~,Y :,,'. ~', '\~·:~'\·.,\~~~;:'->~-e".',r:', :::: ::'::"",,~' \;~, .~ ,~.~: ' Trip Depth: Short Trip Depth Tight Spots: to ~;:::n~~:;¡C:Iuœ;;,g;;';;¡;::::1;;:m~'t"~.1 ft ft Trip Gas: Short Trip Gas: Mud Cut: Mud Cut: to _":I~w,,~..IL.~,:lJJl' ppg CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft on Ii ~ ij"'A~,1L.:..--:;:!ft::'" to .,.... l.! BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Gas" Temp Out 24 hr Avg 24 hr Max Pump and Flow Data ft/hr 107 ft/hr ( 595 ft/hr @ 4778 Pump 1 126 spm DH flow units 93 unit~ ( 664 units @ 6600 Pump 2 124 spm Total flow 1056 Deg F ( deg F @ Pump 3 spm A V @ DP Pump Pres 2551 psi AV @ DC ~ Mud Wt In Mud Wt Out 9.00 ppg 9.00 ppg Visc 54 secs API filt PV 14 cP YI 29 Ibs/100ft2 4.9 ml HTHP Mud Wt at Max Gas _ppg Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8.3 Sd 0.5 % Current Lithology: % % % % SpSr'I""""'Y- sun DRILLiNG SERVIC:ES Mudlogger's Morning Report R.O.P, Current 22 73 I . > : Bit No.. 2 Hycalog Type: RSX238HF-.GS Bit Size: 12.25" Jets: ~ X ~ ~ X ..2!.. TF A: 1.0900 ~'i Wt On Bit: 22 RPM: 77 Hrs. On Bit: 25.3 Total Revs on Bit: 24500 Footage for Bit Run 3,651 , .,. ~ ·'g::~:~~~1t:lr.tfJI~lll't[mIDU~Jl!K~œ~___['~If\I.OOì¡!)j,1¡Wli~~~~~ I I I I I ':'.;;"~."""': ~~. t::¡;'I~..""'~·~."'J.-·r·" ';........~.. .j¡ ,,' .~., "'.:-. .':.I"~·~ r" l;'t,¡.. . . '....~~!IfII~~~:,~-r.J\i.f:·~~.._,.~ '". ,:;:.' ~ . .... .... "':'" .r·...... . _ ..;.:.,.... 1(' .,.,.~: ..,$~. ~~.I~i.C;: ", _ -._..=,,:r::::r:tC", .~ mml 1111 IlRlU ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg units units units ppg ppg ppg Drilling Breaks Depth Drill Rate during Gas during after before after before to to to to "'''. Ui..l-.2·'::I"'~.. . .~"''"'':' ':'~'îitl'r"" ~~~~['~'=bìi''-' -U."Iß:'':''''"':t::r· '''''~' :n:'.: ,', ~..rUJI.:I-':'f'f~~.&Jt~~ ø....&".':L.!ømt.~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: o ",W.\!;C:~:'¿~"'~.jià'~~~"~i¡i:~"'!'fZ?:,~1'ik1¡fjB;Ðf_~:a~i:f'#'~\·!¡~:,~,*;~,1.:¡'~~~;"':<*hlf·~~~,1~*~*¿<t~~i'.~·\-I'{"'~·"\ '.'...' ~'-',r.., ~, 24 hr Reci Drilled ahead from 4476' md to 7056' md. '._. Note: No gas readings from 6845'-7200' MD. As per company man. ..~t ¡¡:1f I ~' "¥ '~~: Logging Engineer: Tom Mansfield / Reg Wilson '~~ÿ:,:,~:,?;~~~~ ,'\ ,:t",.,;,,:\.. ',., ; ,'.,. ."'> ".. Tops: SV1 @ 5096' MD, 4452' TVD; UGNU 5573' MD, 4807' TVD ft ft ft units units units ppg ppg ppg * 10000 units = 100% Gas In Air % Lithology Sst Sltst Sh oz. . . Ii, ~j/'I~'~ ¡~!i::'~.~~ .:~~\.:i3;~: ;'" ";~·..¡~i':- '"'."'-'.. ..·œlì..~(jI1_;r~:~1~~~~.f:f\:~~~4Ml~~1~,.:'" I r I I 7 11/4/2002 9,023 1,967 Drilling Polya / Dinger ):.~ .. ~< .., -",:'/;-,.' ·t< ,;'..; ~~;..,,~;,~..~¡i:.(:.~~~~~r~tit~:~:¡:"J..,!f":~f,~~~þ'~:~~~¡}~"::""''''¿t:- ~::'~~'t,qol,;~~~·~~~..l'<rr~(~~.'r~~b:;~,*,~'\~~~"¡.Y'~~~~~~:'~~":t'J~ ~\,;, I,.",:"" r^r..... .'····"t/,'i"f'J.~'\-í,,;..,;~·, ~~ '1'-.~,,'·W~.r;I'f':'~·~,,, ,"'~' ".J, 1-. .:". '"Iy~ ".~"';) :.'.... I I I ¡ I ~ sper'r'v-sun Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Bit No.: 2 Hycalog Type: Wt On Bit: 18 RPM: RSX238HF+GS Bit Size: 12.25" 155 Hrs. On Bit: 40.2 Jets: 4 X 12 -- Total Revs on Bit: 5 X 13 TF A: -- 557500 Footage for Bit Run Current 24 hr Avg 24 hr Max Pump and Flow Data 204 ftJhr 132 ftJhr ( 350 fU'hr @ 8356 Pump 1 123 spm DH flow 194 units 175 unit~ ( 439 units @ 8400 Pump 2 123 spm Total flow 1040 Deg F ( deg F @ Pump 3 spm A V @ DP 163 Pump Pres 3200 psi A V @ DC 265 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: Mud Cut: ppg CI: ft Short Trip Gas: Mud Cut: ppg Short Trip CI: to to to Feet of Fill on Bottom: :~i\U.~l~...J[ _uul·'~I:--;:_:Jl~:Iw:::rm;::.~:r~~f] _ Ilm~ 1 1I:~:;t:~?l¡- %LCM ft ft ft units units units D A ILL! !'J G 5 e A v I c:: e 5 Mudlogger's Morning Report ,:, .,..\..~. . 1"~ ~,~.. I ~1 ~~,t;~~,(:: ",,;;~i;.~'~~..K,,~,¡.~ ,~r< \'~ .'~,1 .:' :. . ,,~:.~;. ~yt>,:,"';"":-i~,,~~";,,,,::~\~:~':I·~'~':.~'f:' ~,'" .!:~~ {:i: ,,·~,:::":·,~,,'l~:\,".ó~;.:'· :ol':',>" .,: % Lithology Sst Sltst Sh oz. >'>~,':': ',,,;~-:~t~~ ,.~<.-i; ~,:~}/;0:f.f~j:~:>-(~V~ik~1'1~\',~«~·.~;';~~~:':~'~~~*$t\*",t.;if~*tt¡Ç·W'¡::::~~,~:&.~~tK__1k~~tfÞ,r~\w1W!$i~,1f~~~~1:i1,~~!~Œ1t~~{i~iJ4f.f;i~~~,:V,:jiJ.(·:::::;~~~~~If!;~~~\{~~\~:tF~ ~~~~\£{~~~j~~',\{I~~\:\L:·,)?\:?::·1!>·~·:;:·~;M~h;f;.7:>~:"<" --- HTHP Mud Wt at Max Gas ppg / 12 / 15 Ibs/100ft2 pH 8.3 Sd 0.5 % 1.0900 5,618 ppm ppm ft ppg ppg ppg Visc 52 secs API filt 6.0 ml - - PV 13 cP YI 24 Ibs/100ft2 Gels 7 Mud Wt In Mud Wt Out 9.20 ppg 9.20 ppg 1r-: 1"'1 r ¡ ~11~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 Description of fillings: ,i.,~,:~~,-~t:~:>'~i~~~~';¡¡;f)*.;,;<t~jj~~_~~~~&11Y:U~;i'{l!\~f1if.!i'f~:a~~~~j'!tJ~:~ I~, 24 hr Recé Drilled ahead from 7056' MD to 9023' MD. I, .~ ,iiit Tops: SCHRADER BLUFF @ 7669' MD, 6388' TVD; COLVILLE @ 8227' MD, 6800' TVD I ~ i Logging Engineer: Tom Mansfield I Reg Wilson . ... . · 10000 units = 100% Gas In Air ~ , '::;;·':;~17~:~~--~';X\i'f~il~~~~!i:J~~~~~~I~~j~:.~~r~~~>i1:~~;!!_II~:'~\1~%-;~\~Xj~~;'~~;~;2;A?!:j ·¢i~~:n~:~\!tImUM!i\JL1!Œ\\~rilill~lt.~'j~~.. Current Lithology: % % , _.__ 'II Jmi r II m 1111180 ß ~m( III n _~" -""lIE-qUi] m II _ % % - I mmœlm r;::~"::u.::rlfC ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft un~s ppg ft units ppg ft ft ft units units units Drilling Breaks Depth Drill Rate during after Gas during before after before to to to to I I' I I I .. . " 1,.. .. ~ ,.. .. ,-";';'" ' ~ ~1.r ~~':';'t' '. Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 8 11/5/2002 11,227 2,204 Drilling Polya / Dinger spe.....,r-y- SUI' DR! L L I !\J G 5 E R V I c:: E 5 Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Pump 1 Pump 2 Pump 3 Pump Pres Mudlogger's Morning Report ¡. ':',:.1 " '\'. '::,: ::, :.- .,~,~~.~ i. ~~,: "', "1,~··~:t,-,'·.: ,~,~ '..- ,r4.:'.-, 2~,'.' "'1~' ::~t~~~).;, .'~ . ,~:'';,:'",;,::'~{'d .',...:', {:: ~~~q~:,r.~;"~",,¡\J', '.ì. :;F~'~:/~tt~if~1~"i:'~~)...;·:· /'il~l ,'-~~~':: ·ï-;¡;'~".·':: "fS.~~~~t·~;';:~k~~::t~~~~'::';,.:~~~~, .1'.', :":':(:rt;,~~~·,~t,-¡,~·:. ~:''':~ ' ".' ~"<::.~~ -' I::'· :\~~,'~',..: t';_' ~'~'~.,~,~,.;J;:·:-;~.ft:;:.;-~ kj~~$:":"f»;";; ,'l';'~;...' ,~~tf:}~ ;'~~ "':,r- ~,i R.O.P. Current 1 286 10135 9437 Pump and Flow Data 123 spm DH flow 123 spm Total fJow spm AV @ DP 3200 psi AV @ DC 1040 163 265 24 hr Avg 126 ft/hr ( 388 unit~ ( ( 24 hr Max 374 ftlhr @ 1721 units @ deg F @ ft/hr units Deg F Gas* Temp Out 'Ç. '.. I _ " ~. ... ....."... ...... "'."I!:.....t:;I',,~ð~.1.,J.nI"'~...·_...·~·~r_..,..~"'..."!. '". ...'....·.71'.r:,. II .!".~, "'. ...~"'-...' '.. .. HTHP Mud Wt at Max Gas 7 / 12 / 15 Ibs/100ft2 pH 8.3 Sd Visc 52 secs API filt 6.0 ml PV 13 cP YI 24 Ibs/100ft2 Gels --- :,' , ~.; . : Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to , , ì .Ir.;;;;;;r.T:J=::::::::':Or,'1[B[~,:,~,:,;;:II.1Ilrm;;~:_,r«".",.......,1 ~ Current Lithology: % % , ' Mud Wt In Mud Wt Out 10.20 ppg 10.20 ppg ,¡,;;..~::j¡h','~' '''è!~:,~,·''',::"<¡,':·'~·''¡~~;,,.¡.~~I!f1nw,.~:,~';ii'::.,,~~<1'!j,f~t:<~~..1:':~,,:¡\~i:'''_~./~t':~~~·w:.~~?,i!#~1fldi..-i1·W,¥r'''~':I!>',':1.:;'·:':;::,'; ,~mì:""<¡'?"~:"'.:\1,"!'''':~ ,;,."t',::n: :~~ ". >::~<:, ' ,.:",', "", ." I Bit No.: 2 Hycalog Type: RSX238HF-+GS Bit Size: 12.25" Jets: ~ X ~ ~ X ~ _ _ TFA: 1.0900 Wt On Bit: 10 RPM: 80 Hrs. On Bit: 57.7 Total Revs on Bit: 824Krevs Footage for Bit Run 7,822 ïìM~~~,;;~n::X=::Zl=-";;';¡;X:::I:mL.,~:l~]A~lmYj~1t~JFI~ " I Mud Cut: ppg CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: NIUa:::I."," ..~~ % % I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg I ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to to to to ,ßl1~Ar~nI\:\[~UII~~~JI[aXI15¡i\]¡WJ¡]a.~.)IJI;ilttI¡;:~~.II~~lln1[_ ' 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. r ' Description of fillings: ¡ ):\f,~;~:;~;$;¡#.t~t~~,þ>~tM.~,," . ; , '~~~~t,·.NX~~!~~ft~~:Jt)ßJ/'~~~*;¡:;i':,'~;t.iri~Ö·Y~:'~:~ ~ ',î 24 hr Recé Drilled ahead from 9023' MD to 11227' MD. Drilling hard spot. ti; "'( 11~ Tops: COLVILLE@8227'MD,6800'TVD;HRZ@10546'MD,8606'TVD;BASEHRZ @10987'MD,8931'TVD; ~ KUPARUK @ 10998' MD, 8939' TVD ~ ';,\ ~~~~~~/R~W~OO " I I I I I I I I I spe""r'v-sun DRILLING SERVices . c. r:¡,~:~!i' ' Customer: Well: Area: Lease: Rig: Job No.: , . ~ I· 9 11/6/2002 11,778 551 Drilling Polya / Dinger BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report .. I \':. ,I ,:..~~, , : ..,:; (;' .>~:' :....,::.. .,,:': ,:_·",I~f' ,i;:l:'h.\{ I,.~, '~l'I'::';'~:"1-~ i')~.~~~~,;~':1·:~~~~ ,;.} 'i1'.' :~;;ò 1.:~_,;"¡:,".~::I~~~~;,,,~~·~\~·œ·,::,\·37 ~.~:' ~;' ~ ~;;;:;'~':",.'~,!.':,.:-' ,~.' ':.~":': ',:~~: ')'~'<').'~~,~;'; :..·~~¡,~~'~~rr:· ;"~'; ,.,~··."..'>t :::~:~.~\" \~'",' 7~' ~ :,J. .~.:,\:"" :',~\ :, Current 24 hr Avg 24 hr Max Pump and Flow Data : R.O.P. NA ftJhr 73 ftJhr ( 315 ft/hr @ 11380 Pump 1 112 spm DH flow "'., :" Gas· NA units 350 unit~ ( 1016 units @ 11318 Pump 2 112 spm Total flow 947 /; Temp Out 115 Deg F ( 115 deg F @ 11778 Pump 3 spm A V @ DP 148 ::.\ Pump Pres 2950 psi A V @ DC 241 .. ";., 'j"",.,'~:'".,)~,",,¡:,,,. ~;,'";t.l'r\';,'f~j)'Ì4!~¡';';:-~"W{:;i(.;¡~"~'¥i'#;':'.;·1\-;¡'~îI~M;,.¡.iWf''}i4n'4'J4,~f:i;¡~Aï¡!j1;'~I.$;\;~(;"'¡"I~'!!~J\I¥Y4P¡;;~~~~\t.iÏ~*"¡¡;f&t\]'t~."':;\\ft;\~~~W.l)!:~~"~,:i~'::i,'h:!\";~,\~~($-,;'i"':rM'~;'<;;\~,.~,,;,:i',{l';'":;', ,,' Mud Wt In Mud Wt Out 10.30 ppg 10.30 ppg --- Vise 44 secs API filt PV 12 cP YI 25 Ibs/100ft2 4.5 ml HTHP 10.0 Mud Wt at Max Gas ~ppg Gel~ 8 / 15 / 19 Ibs/100ft2 pH 8.8 Sd 0.25 % ¡i Bit No.: 2 Hycalog Type: RSX238HF-+GS Bit Size: 12.25" Jets: ~ X ~ ~X ~ _ _ TFA: 1.0900 _ t:~~.:~-=-=~UI~=::~:'=::~"~::~~~:::'~~~':~~~<Þ'~~::~-"'~ ,~ ':' '~ ' Trip Depth: 11778 ft Trip Gas: Mud Cut: ppg CI: ppm i! Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft --;,:.r.A!J.I~nI.1tL]~:'-r: _, lJ-..n,]::,'::Jt:::O:JCl:;)'-, . T][ 1 11! -"'~ro;~:=:r~'L- Current Lithology: 70 % SH 20 % CLYST 10 % SLTST % %LCM .. "::~. ..1I!Ull ~~I if Ii.. mill ..) IT ß l ~ II UH nMllR1Ít\ì mUlli III! II ],.. JLJfl1f.Jf':: N ~n .11I 'J ~~c;;r''''-:~_ Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh 11313' to 11456 150 280 55 400 1016 350 50 30 20 to to to "'m:ra;~l¡IU;¿IJ11iæ~~"r ~lnll¡I!II[~1 ~U~WI~II~~~It~" 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: o oz. ·~t, ;:. ~,', 1.~:~.'~3,:,,"t~~~,~..;~¡tiiti'~n:1';: ·~.¡.',i1I<~~';',:.f.l'¡1 ,~~;;.l'h,ill~~;·~1i~*li""f:'_f.'..;::.."'!#i4:~tt~~,~~«~~;If::~~~~:l~'1,£' ':'~\<; t,",'.~~~ >..:~';: . .'. ·.;,~"'~:·i~:\o¡i¡¡"';;:(': "~¡ 24 hr Rec; Drilled ahead from 11227' MD to 11778' MD, T.o. for 9 5/8" casing. ,;!~ r"'~N ~~~ ~¡¡¡¡..". ".: .~ .~~~; ; .,,-,~. Tops: KUPARUK @ 10998' MD, 8939' TVD; KUPARUK C @ 11313' MD, 9160' TVD ;~ Logging Engineer: Tom Mansfield / Reg Wilson ,.;.~~ * 10000 units = 100% Gas In Air . i(;",·':·,::ff,¡r.;\o:~~~~~ftt~~J~~~~~___f?;~:%:g I I I I I ,-"'V~"~: (~1':::I.~t 'l~:"~'~,:: ~.:~~j~~;~j%~' BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 10 11/7/2002 11 .778 o Run 9 5/8" CSG Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: spef"""'f"""'Y- sun CJ A I LL IN G 5 E A V I c:: E 5 Customer: Well: Area: Lease: Rig: Job No.: Current .' ~. -,": ¡II'...... ".":."~,,.,;,,,".".., :...,~, ,'.>:,~:",'~,,;-;::,,,,~.;" .:..~....~_.... r,·..··,I....I'L~i·,.,!,~~4'!-'~<,!í',,:,..·,-'II... ,'')'1''.,:." ...; " ",' ;f ~ .. - :. .', ~', ..~ ~.....,;.. . ~\., .. ~ . Trip Depth: 11778 ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to ··;:m~(c._"~_,~,~",."J.I\'I.I1~,J,.'I'."IJrJ"JIT T r Ii] II Current Lithology: % Mudlogger's Morning Report Temp Out ftJhr units Deg F 24 hr Avg ft/hr ( unit~ ( ( 24 hr Max ftJhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi AV @ DC .1(.." J .. ,. h;. ..'~. ~ .'...... r., ,".. ' .... þ ." ..~. .'. . '::' " ..'O ':I\"'~:~. '':""''~''\*~~'~._.'.'I,\.o..' ~T" ...~,j}Þì.-:..\J·._ Mud Wt In Mud Wt Out 10.50 ppg 10.50 ppg Visc 49 secs API filt PV 14 cP YI 28 Ibs/100ft2 -- :'. ··...~.r -:0 "':r;\-~...~"..."~: ~ ~f\.it.~..~·~' "~; ;¡'..: '¡:.'Ii"'\~,'" ~.;~~,..;,~I~. -:, ;..1~\~1~~~..~71-:':.~'f~~.x;..r1~'. ;"1i~!.t":.p ~"~"": ", '".1","1, ~"."' .~, . .~...: ,,:,'~.' ,. ..' r ,", ·\1 .'!. ·I;',.-..!'; .'".. ~- j·l':.... "" ,','" ..-",. 4.6 ml HTHP 10.0 Mud Wt at Max Gas Gel~ 9 / 15 / 20 Ibs/100ft2 pH 8.0 Sd ppg 0,25 % I :', Bit No.: 2 Hycalog Type: RSX238HF+GS Bit Size: 12.25" Jets: ~ X ~ ~ X ~ TFA: Wt On Bit: 25 RPM: 140 Hrs. On Bit: 65.3 Total Revs on Bit: 928KREVS Footage for Bit Run ··~:'~,'t'~I.ìJ:~P;.\t~4D'[:~,.¡;;;;."t'æ..i(U.,...~..lli\it.IIØIIU)1lllø~..'~···· 1 09ûü 8,373 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ¡ .. !"' Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to to to to I I I I I Mud Cut: Mud Cut: to :imL Iii. l JI X"WL, ppg CI: ppm ppg Short Trip CI: ppm Feet of Filion Bottom: ft % % % %LCM ·:~t"".~1:nr'WJT"" ..... , . . JI .."-,...&"'", ~'ê· 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. I Descr~~~io~ o::::,____~J!¿=,. .' ".~..'iL~...',.¡;~...."'...~:_.I.oM ..'~-~101 ,. . 1_ ", .. ·11 ..;1"1 ~"Þ~. J::,¡;~ft,~~"":,~~;,~~~~~1?~L;rrt~.~.:.t)r;1f~~t!}r.,,,".il..'~~~Is.'.~~~~~'}tai."k'~r.'J.~~"'·~""'.:·'/ .;:;_. :,~~\\~~J~¡~~~~~~..IfP;;'i?\~~···Jj_:'-~_ ,r;~. ~~·I¡,'..: ~,I.'". \'}r!, f~'I:"~'~I~·':,~"~·~;~·~.~' ~; 24 hr Ree, POOH went "';ell. wiíh no tight ~pots. Currently running 9 5/8" casing. ~ ,Jt .. 10000 units = 100% Gas In Air ' r . I . .....,. ", "....' : . , '. .r . '. . ~ ,~ ~,"( ',,,¡,r I r.,I' ,." \ '" " ,: .,' .',~.1...',~'&:·, ,\~~t\_,~ø~"l:1t',~~/~1l!~~ê~0,) . .~ J Logging Engineer: Tom Mansfield / Reg Wilson '~?:i~~:t~~~~t¢",.;",..·.~ '~,.~" Mud Wt In 10.50 ppg Visc 49 sees API flit 4.8 ml HTHP 10.0 Mud Wt at Max Gas ppg "'> Mud Wt Out 10.50 ppg PV 14 eP YI 27 Ibs/100ft2 Gel~~ 1 ~I ~ Ibs/100ft2 pH 8.0 Sd 0.25 % ~i " . ~f_'t ~." .",...i~'..¡"""": /:~:c·... ~oJ.~:'..:'..~~~r.,...;p';~·:',:~:.~:?~~~·f.~¡~~~?lO~..t~oia·.iI.,,~ï4!~"'~v~'~'~'.,,·.(~~~'O'J~\~~~(J~-!:7"~~i:":¡':~""~'¡~.~V~,x~~'~.~I:~:t';~~1t\.a;~·~¡ ~)U..~__:.,..." ~ .:' '.,- ,~. .:_,,>....." :." >~,.;::;.:"t':".; I r ," "11,' ;~....,.', ;~~: .~'.:::,'~~, ~>.:' :.;:::-~.,';;;'''' .>', . iI'~': :~.. .,:....:. .~<';. i Bit No.: 3 Type: RS161HGSW Bit Size: 81/2" Jets: ~ X ~ -2.- X ~ - - TFA: 0.7420 tþ~~ Wt On Bit: NA RPM: NA Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run ¡ " T;i~~~-=-I:¿~:1 Short Trip Depth ft Short Trip Gas: Mud Cut: - ppg Short Trip CI: ppm ~ Tight Spots: to to to Feet of Filion Bottom: ft ~Jtl~Jø;.1;:¡g:n,":l\::S::'1.;;'~·:-·~'",",I""..IJI"~~..u~{;r~1;_m_m~f1rQ)¡lU;;JÀ jlln~T...:m;'iM; .' r I I ( I I " >\I:'~:,K~V,.l?:~~t%td:~k_~..t\1i~,>~~t. I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg I ft units ppg ft units ppg ft units ppg I Drilling Breaks I Depth Drill Rate Gas % Lithology before during after before during after 5st Sltst Sh to I to to to ""., ur ^..!JiiJC '. " sper'r'v-sun Customer: Well: Area: Lease: Rig: Job No.: 11 11/8/2002 11 ,778 o Test BOPs Kidd / Dinger 24 hour accumulation of Steel Filings from Possum Belly Magnets: 0 oz. Description of fillings: ';"~\'~~ï"'Ø~.t9(~~I~~~~~tSf:~~~~~~\-::'?::~;.:1'~\~~ :) 24 hr Recí Ran 9 5/8" casing and landed @ 11753'. Circulate 11/4 casing volume with max gas of 186 units. . 'I Pumped cement and displaced with rig pumps. Bumped plug. Nipple up and test BOPs at report time. I t:~~i~~:;;:; ~J BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ::::::: R : L L: I'J G 5 e A v I I:: E 5 Mudlogger's Morning Report Current 24 hr Avg ftlhr ( unit~ ( ( 24 hr Max ftlhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC R.O.P, Gas* Temp Out ftlhr units Deg F 186 . . ..~, ~.. ,; -,,';. . .' :",:-";. '.;~~\'~ ~y,.,,,,",.'I'".".,_,-.':"" ·...:.,,:.....~:...·::.:~"~N·-...~i·~..~.'.,....~~.....-r:,::..s";...~¡.r~ -:;t.~·~.;.3..p.'·~".. ~~;. '~r.;.~';,<~+-~,~~.·: ~";:,,,\...;:~r~~....-f.l'~~!:..'/2I'\~~,~.....~~.~....c.:,. '<'f.'~, '··t. ~','~' ~...},...~..,.,::~. .,~::::.I""\.~,. '~ ;. " . . '. Current Lithology: % % % %LCM % -':- ~rø·:lV.I__UfKJ'L 1:-·- ' . C'~ units = 100% ~~s In ~:,'~ , . 1'"." -. .. ".~tF.A I " . :' .... J~"-:'! ~~~:S.: . , .. ." :-..,..... . BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 12 11/9/2002 11,778 o Drill Cement Kidd / Dinger Customer: Well: Area: Lease: Rig: Job No.: sper'I"'""1Y- sun DRILLING SERVICES I Mudlogger's Morning Report . "". ,~~ "¡.' .: ,~~ {", '"* ~:. ")~,,,~,":~:",;, ': ',~'¡" ',' .!"". ' ,'1 .:: k ~:~' ·~;.;"~,},··~~~'~':~~:~_~:'~~~i;":':~'~~,':"~~$'--l~¡~9~.\'}k.1.?1:,¡';~ ~,:;;;,,'~~:~~,~~"~ ··;tjJ,~; '~!":",/,{>.:.~,',:.~r.1~·~\*:~;~;~::,'~':·,ì:r,~.~~~-f::~;'~;~~:':~~.·~'t~'I.:::,:·:r.,:r~~~·;::':'\:~~ ':' ~ "j ;;,' I Current 24 hr Avg ftIhr ( unit~ ( ( 24 hr Max ftJhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi A V @ DC ftJhr units Deg F I .. ~., . 186 Visc 49 secs API filt PV 14 cP YI 27 Ibs/100ft2 4.8 ml HTHP 10.0 Mud Wt at Max Gas Gel~ 10 1 15 1 20 Ibs/100ft2 pH 8.0 Sd I Mud Wt In Mud Wt Out 10.50 ppg 10.50 ppg --- '..,' ''';'¡'''' ':" .~<I,: ';' :'. ';,;~';' ':,; ,.,'·F:j;..!>\ß,~~~r"~",,'r-';:; "t'O'¡'::~ii.!;;i-¡;¡:r~"'~~~~~f<~~v..q;:"'""'1íØS.¡4~;'t~~;~t.""'~·:~;f'{)¡<: ,,' i'··..~;>;:';\'··,.·,-l·ë;¡;·~<i..'; :·'.:.tI:,;M..~,:"'M.:';';':;::<·;';;~, ::: ~"":"" ,',¡" ' '. I Bit No.: 3 Type: RS161HGSW Bit Size: 8 1/2" Jets: ~ X ~ ~ X ~ _ _ TFA: 0.7420 Wt On Bit: NA RPM: NA Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run ~.·~~C'.I:rJ~Btl,Ø.,ri(__~""Itl.,,¡¡¡[:~~,., I 11778 ft ft Mud Cut: ppg CI: ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Filion Bottom: ft ~ if If t:J\T"U;;r:nIJI,U II Ilmnmmnn¡¡wïe::::.,J,J.Dr\m:x: Trip Gas: Short Trip Gas: to I % % % %LCM Current Lithology: % "'JmmlL ~ 11m[] m œn lfi .L.III . -, - lllllB ¡¡IU 11111 1m .11 ¡ in II ~ I]!I 111m J r- l!1iJmIIIII~f!C::.l I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks I oz. Gas during after % Lithology Sst 81tst Sh I I Depth Drill Rate during before after before to to to to I :'""'""~~~~l!{rE~:lJJml!~~I:lnmll~ll~j I~I ~~~[_.íi::¡'f! 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: o . ",~~~~r~~~~'" ,,:i";~1;~~. 24 hr Rec¡ Change bag on BOP. Nipple up riser and re-test bag. P/U 8.5" new bit 3, BHA, and trip in to shoe. Test casing to 3900 psi w/10.6 ppg mud. Top cement @ 11644', Lost rig power. Prepare to bleed in spike fluid. , : ft.,'", I Logging Engineer: Tom Mansfield / Reg Wilson ~/:~~1~~~~~. :".~,_'"': .,.. ..' * 1 0000 '¡~~ . J_~ , "10'''' \:t" '-.l ~ "','" :..~ ;\~ ' .:~ ,~,~ ,',.. .',' I I r I I I r I r I I ",' ');¡~'!;-~'P''':,". 13 11/10/2002 12,293 515 Drilling Kidd / Dinger .;-'!' '," :;:"...' '; ".'~~·:".~I'~:";~'" tfi"'" %LCM ft ft ft units units units Current R.O.P, 45 80 105 24 hr Avg 24 hr Max Pump and Flow Data ft/hr 29,3 ft/hr ( 178 ftJhr @ 12022 Pump 1 79 spm DH flow gpm\ units 100 unit~ ( 181 units @ 12017 Pump 2 78 spm Total flow 558 gpm /, Deg F ( 105 deg F @ 12232 Pump 3 spm A V @ DP 87 fpm ~~. Pump Pres 2825 psi AV @ DC 386 fpm \,~ Mud Wt In Mud Wt Out Visc 54 secs AP I filt PV 26 cP YI 31 Ibs/100ft2 ,<' ~ ',:':·~,Ó·:··t:.;\í?~::\f~t\\:~:!M::'; ,:t!;};;l"~,:.t\~t:=:-{.~'!' :>:;;:,,' ~:; ~..."':' >~. ,~'.. :.~;;; ~:'( ",. Drilling Breaks Depth Drill Rate during after 12.90 ppg 12.90 ppg --- 3.4 ml HTHP 8.0 Mud Wt at Max Gas ~ ppg Gels 13 / 44 / 68 Ibs/100ft2 pH 8.3 Sd 0.25 % ~t;: ,~ w~ Jets: ~X-E.... -2-X~ _ _ TFA: 0.7420 ~. Toml Re~~;n~;;:: ~:I.~~ to Feet of Fill on Bottom: ft ! ì r 1m [) f [IT '-.X".':¡- ~,,,ÜJ'.,, ].",,,J..JNmÂJ[mr:~:I:;;:1í "¡I), ,-';' ,,~ ppg ppg ppg % Lithology Sst Sltst Sh il 24 hour accumulation of Steel Filings from Possum Belly Magnets: 35 TOTAL oz. ;~ Description of fillings: predominately small slivers, some small chunks, some curley Qs f~ ~ ï~~\;;:~~=~~¡~~ ~ ~ ·1 r, , w ~ l r;:;~ .~. Logging Engineer: Tom Mansfield 1 Reg Wilson ~~I~: :~~~:··',':>x:.:::¡~~~~,. ,'",' ,. '.' ..,.,1\.1_. , .. .' 5pe....,....,y- sun DR! LLI N G SERV I c: E 5 Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report ,. ," .' :~.. > :~':.¡, ,,,;;t -,.' ~,~ '::.;.1.." ",: ~::;/ ~ ,':~\ 'f: ~ ~~'> ":-f ':";r'::;~:\" ~~'.,~:',....; ~j,; ~~ .:~'~Y~~'('it:::w<· ~:;~) );,~~~~'O~~'.:'¡~:I¡¡~~";"~.t~,..,;~¡,,::,··:,, :j>~it):· ~"~¡:¡.~;·''.:*','~'''''>~~~.:-:'~I ;,~:N~<ïJ ¡:;).", '~~i~~'~f-J;J~~:Ot'J',.:":\~:T~,~~,!'~'~~.~~,!..~~:j.;'f1Ò"~~(~. ~'":\i:,';N;,;'~ ""~ ,·,·"t';'~';';¡¡"~",;'i:'¡:';';"¡%!~~¡,"~i~~~'i!!J\\~tt.~i;j:;#,r\~~<;,."&.,?~~~\,~1!tii¡,,>tiih_'¡;(;$·¡'f;~~'roG¡¡it',\,i~;!;\.~'ø~:r$.;(..~%;;t¿):B:~~~!t~f,j)\'i'm:~J¡&~'Ø~",~JtP,\\\1~"W"; ". .~ .; ~ ·::,~,,~'·.:rX::~~~:, ·~~,;t~-r:~\,"":~ff·":';·s.~·..·~;~'~\:·~~'~'~~~"~"":~':'~"·~~·~~~'*,;J,.:1+,~~.,~·~1~~:r,~~.,::' ~~;;..;.;'~r~;"1'>,"""'~~,:,"":1~...·.,~,~~".~~~tf·!.",':«:¡,~«""::~';.~~,'~I~"t~~:r.~:,~:,~...~~ I·~.''''' .:":' ,', .....: Bit No.: Wt On Bit: 3 Type: 10-15 RPM: RS161HGSW Bit Size: 145 Hrs. On Bit: 8 1/2" 17.6 ,~~~;Ji~~jW'Ufl.!llimllill.:.:1It!~ÎÌiI Trip Depth: Short Trip Depth ïight Spots: to '::::E~U;lJ:~:.J'ICDt/bI)I ft ft Trip Gas: Short Trip Gas: to Current Lithology: 90 % SH ill: Iii! ~[,:U_...,JiI:::: % % 10 % SLTST ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg units units units ppg ppg ppg Gas during before after before to to to to .~.._.' , ,.'"......~'-. "-'"'" . - ...- ,",... ',_r ' . 'j JIIt,,"t' _ \-" * 1 0000 units = 1 00% Gas In Air . , .,..,' rI'~ ,."J""~:~' ',' ,,~ ·..'.0 .,¡:t,> " ,1' :r"., .... ,~~1~~t;~;i:~:g.#~~~~h~';~~~~~:£:;\'~~~'· r I I I I I I I I I I I ;ž····..:<'~i-#a~~:ì~r.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 .. : ,...., _ . .. :\ ~ "\... .r-. . '. . ." . . , . ..... . t.,::~·:1'.:..~ .......,.~..~.". .\..~·.~;:¡'.;.L· Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: .~. ;..·..,''..ri·....04...~~:tLo-...., ¡...~~.~ t., 14 11/11/2002 12,472 179 Bit Trip Kidd 1 Dinger , , .... ....'... . .... Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi AV @ DC --- %LCM units units units % Lithology Sst Sltst Sh 12.80 ppg 12.80 ppg Visc 59 secs API filt 3.8 ml HTHP 8.6 Mud Wt at Max Gas ~ ppg PV 23 cP YI 39 Ibs/100ft2 Gels 18 1 43 1 50 Ibs/100ft2 pH 8.4 Sd 0.25 % ,:' ,~',' ·1;'".~· ~~\'1';J~;'''' §>:~t....J."~}~.~ J~~~~t~:~~,~~...-':';:4.,~..~~·:m'~.,.(.:~"'-~~~:~·~..~,~y ··~~~~,~~¡'!:1'~~~:..~.~~~':'-*~~~:~?5~~\~,~~.::::'-).:..t~::.,;.: \1i~,iì'~!~~T;,:,~~~,~:r,¡~'.r i:.~ 'i-'.,=3If'.' .:~~~:' '..1i;·~t,·t··; :·;:I..I1Ç..pj:~~'·~~-'· .,. <.":;:. .~~~~, :!", ai,~·. . 24 hr Max ftlhr @ units @ deg F @ 12340 12472 12425 sper'r-'y-sun DRILLING SEAVIc::es Customer: Well: Area: Lease: Rig: Job No.: Bit No.: Wt On Bit: 3 Type: RS161HGSW Bit Size: 8 1/2" Jets: ~ X ~ ....3..... X ~ _ _ TFA: 0.7420 10-15 RPM: 145 Hrs. On Bit: 28.0 Total Revs on Bit: 329K Footage for Bit Run 694 "~Umt~~:.r::1:t;;;;,l\1:fJlfl\t¡¡In~,~:'::c¡;;~~.E' .. Current Lithology: ~n~WJ lilT j~1I 90 % SLTST 10 11r..w£::.:::.::·-~·'T--- % % _, II i ~ III r ;:'~ U:::J,:::::Yl'^.~ ". % SH J~~II In ¡ gl mmnLLI Mud Cut: ppg CI: 52000 ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft f[ :::r:L.l:~n:::C'··~Tl· iVllillii] ;;~r~::~:: ,,_. ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft Drilling Breaks after before Mudlogger's Morning Report Current 24 hr Avg 24.8 ftlhr ( 85 unit~ ( ( 72 97 105 Gas during after ppg ppg ppg . " '''-'';;¡:>::::trJf£ P~Jff~~~ii~.fJlUlm lIIII~.'''-·-·-'::E·' "fHa']r.mnnl1r[l~t~I?;~.nrnt3mJ~__j'. ,'.. 24 hour accumulation of Steel Filings from Possum Belly Magnets: 11 TOTAL oz. ~ ,. Description of fillings: predominately small slivers, some small chunks, some curley Qs i ?}j~:>';;'!¥.m,:£,.$:~J¡~~~mt~·, "., . , ," . ,. . . ·}~~~~~'.\*l<;~~t:i;~¡jh~~&~:?I(';¡/~:"~~ ; 124 hr Recé Drilled to 12472'. POOH for bit trip due to slow ROPs. P/U Hycalog DS70FNPV wI 4X12, 2X14 jets. s1 I: TFA=.742. RIH to 7024'. Change riser boot seals at report time. ~,; ¡;\~1 i )¡~ Logging Engineer: Tom Mansfield / Reg Wilson .. 10000 units = 100% Gas In Air ::~,"~ .,f·"~~..r.~~q~,~t'!J:~~~~~~~~1~!t:~';,_~~~&~~,y}¡·!~>~;:~,~\i;A;~\~*~,~~"'t.4:~,··~·.:~ ' ftlhr units Deg F Mud Wt In Mud Wt Out Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to ::.;:a¡r~ ......U1;.f.Ç:ç-,J:I['.J.1JDU:;;"::::iììI~~I..1 ~!! U units units units Depth Drill Rate during before to to to to I Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 5 hows: r sperry-sun CJAILLING SEAVICES I Mudlogger's Morning Report ~'~,,;:,,~t ,·,>I~j~~~'·,~ ;'" ~,~~ '.." ',,...-~. "',:' .".::....4.~~~:.. !~~j:;;·?~>t~'1~~'~~~~I,~~~j~,~.i~fi1.~-1'~~'~.~~~~~ij&~tft~~.K~\\~~t~:~~~:i..;~~"~~~tJ~~J{-K',:.~',;~~~~,·;'~ J.:_:~..':' .:~.~ '"íl~,,'~~:"'.?~~!:~~~~~~~f.:~'t~~ì~t~'~(~:~~? j)<·~·'t"'!l~":·k'::.:t~~t,,·:<,;: ' Current 24 hr Avg 24 hr Max Pump and Flow Data 42 ft/hr 65 ft/hr ( 241 ft/hr @ 12881 Pump 1 87 spm DH flow 170 units 150 unit~ ( 275 units @ 12988 Pump 2 86 spm Total flow 615 110 Deg F ( 110 deg F @ 13200 Pump 3 spm A V @ DP 96 Pump Pres 3925 psi AV @ DC 425 .. ( Jets: 4 X 12 -- Total Revs on Bit: I 15 11/12/2002 13,261 789 Drilling Kidd / Clump . ·.,~'i)")¡~r.'''~i·.;; {;,4i}:V'(,~.:~!\i;,4'!'""":tl$J\H!(.;,~tl~1g~i;~~i!~:;iÙWW~~\~,*~/A:k~""t~'A:4~~~';!~i£ì~~~\¡z,;.!ii.**f,'tì;;lt~W~,~"..,,;,,';11I~i!"r\\.'i~\;ij1);.,\;~tb'ìJ:~I:S;:'~;;:,t",t\"t'¡)' '!>\;\;'iP;;;'·,ì"té,',)~,::,,;,¿····' I Mud Wt In Mud Wt Out 12.80 ppg 12.80 ppg --- Visc 51 secs API filt ~ ml HTHP ~ Mud Wt at Max Gas ~ ppg PV 24 cP YI 34 Ibs/1 00ft2 Gel~ 15 1 50 1 64 Ibs/100ft2 pH 8.4 Sd 0.25 % _" ~.',.. ;", "~"Y' ::,',,¡r!':'<;;~~';"~:'H.:)';..'~" ''';¡;~'~,\;'~l''J'h·~~~W:~';\Y.~~~'¡'i,,&~.\'~~..},~*':'f¡i<f..w:;¡\:!('!INø.';:';M'¡"1.~~~~9;~·~'i_~·,:¡;" )''''-'f.:' ,,,,,. .,~j(,.I..\~';~~:!'¥~YI<·:'k.'b\;':.~':~~,.:""\ '. ,{:~,"";,.':,;,,.' ,;:' .. ,.', ", . I 4 Hyca Type: DS70FNPV Bit Size: 8 1/2" 20 RPM: 158 Hrs. On Bit: 12.2 ~'1:1i,('~~t'WK~ "" Trip Depth: 12472 ft Trip Gas: 138 Short Trip Depth ft Short Trip Gas: Tight Spots: to to ~'·");;:::~JUJI:UU;~:L:'~~.~ 1R ~l~ ][ID 2 X 14 TFA: -- 179K Footage for Bit Run ... .',..,.)ICI:-J~ Mud Cut: ppg CI: 51000 ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft tJI:;w~'(::C:X::;':;t.._ ill'ln 1 n. r:;;'MI]\:--}'Ir::::::£X I I Current Lithology: 90 % SH 10 % SLTST % -~,_....I'~5}]_ Jf 111111 .~."'II m I rrmll - - _.. Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg % I I . n:I. _ _ -.on .. ....__................._..'.. ..... Drilling Breaks I Gas during after Depth Drill Rate during before after before to to to to -'~" %LCM ft ft ft units units units 0.7420 789 ppg ppg ppg i~t 24 hour accumulation of Steel Filings from Possum Belly Magnets: 25 TOTAL ~~* Description of fillings: predominately small slivers, some small chunks, some curley OS ~M.~~I:, . "~ ' -. ,. . '~~~~~~I i4~K 24 hr Reci Change riser boot seals. RIH from 7024' to shoe. Slip and cut drill line, service top drive, crown and . ·1 draw works. RIH to bottom and drill ahead. Trip gas was 138 units i~ . I Kingak @ 12390' MD, 9985' TVD :~..'o'~ i~i\ Logging Engineer: Tom Mansfield 1 Reg Wilson ~~:·"¡\/~:;-:::;~,:.r. ':~f·~f'~~~~??~'~'i\j;~_~\ _ " ;: ,\',:'" ":".,",' " '" ..~~ ..,,;,, % Lithology Sst Sltst Sh oz. 1t 10000 units = 100% Gas In Air '. :~~~~~~~¡~~'1t:,;~~~",.~fi~:!I:~~\i~~::r;:(c"¡?~I;:~J~·~·:~·,: ·¡..~Sil: . '.,.. " :~~4~:~v:~JV;tW~.:~.ln,~~ ,t"~~~~,,*II~~f~~J~'m~W~\;..;"";'1 -·7..'\' ~ ....J~ Current 24 hr Avg 24 hr Max Pump and Flow Data 88 ftlhr 64 ftlhr ( 131 ftlhr @ 13436 Pump 1 87 spm DH flow gpm Gas" 240 units 115 unit~ ( 242 units @ 13499 Pump 2 87 spm Total flow 623 gpm Temp Out 110 Deg F ( 110 deg F @ 13500 Pump 3 spm AV @ DP 100 fpm Pump Pres 3965 psi A V @ DC 430 fpm ............- I I I I I I ;)'~i::t ~&~~:1~::~ ~:~ ';:' ""f'~; :,.' , ;\.,~,~ ,~< <:,t >:.<: ,':';: >f,..!{j~*¡~?~::: ~h'" . n~'i.~t)¡~~~~tè,\>;,Ì1"'; .,., "1",! .'~'~ :.~~:. '..I~:~,;,;:~ ','þ', ~~~~~.ii::(i:;::'·,!<',"'I~-: -, -': ':i:;J""'~ "..I 16 11/13/2002 13,500 239 Trip Out Polya / Clump SpSr'r"y-sun DRIL.L.ING seRVices Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 12.80 ppg 12.80 ppg --- 4.4 ml HTHP 10.0 Mud Wt at Max Gas ~ ppg Gel~ 15 1 50 1 64 Ibs/100ft2 pH 8.4 Sd 0.25 % Mud Wt In Mud Wt Out Visc 51 secs API filt PV 24 cP YI 34 Ibs/100ft2 BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 22173 Mudlogger's Morning Report I Bit No.: 4 Hyca Type: DS70FNPV Bit Size: 81/2" Jets: ~ X~ ~ X ~ TFA: 0.7420 Wt On Bit: 22 RPM: 158 Hrs. On Bit: 15.9 Total Revs on Bit: 214K Footage for Bit Run 1,026 . ~;;'~1][J1Tmxr:r.::rD:J;~.I:;:D::~:Jf.t'rtr:XT:m~:{1::1l:x:e'r.J~~t""" I I I I I I~" "¡", \~ . "": ·l"',~·.l .. .;,¡ -""',,~' ... . .01:1'_' -..:;,r. .... .,....."t... :'.-I;t.;'.40~s'::..:>¡.rv:r~', I("~" ."..~. ....~'.:.~..._.a.:"".. :,i:t'.¡.. . I"'.". . NA Mud Cut: ppg CI: ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft KQr~t~UjJ~! [WI 1 ~rllmn1ßI!!rm ..·~I!~: m ~:;~""r' ~ Trip Depth: 13500 ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to ~~JLJ:[Ð:I¡;;;;~;lIID;;;D"~LI..,l Current Lithology: 70 % SH 20 % SL TST 'C¡:::m_:n.:=:~:Jm.'o,.1 Llln !lll i ¡ mL ~ L ^t'l~:u:':J!r:rI\:J ~[II II __ W 10 % SS I m l.rmllll .llm~1 % m~ r··c;:' "':" %LCM ft ft ft units units units ft units ppg ft units ppg ft units ppg j ] II I:_~JI....,.._.._......... Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg % Lithology Sst 81tst Sh ~ ,,;,~-~ .~~~. ... . , ..... . ... " :#\; 24 hour accumulation of Steel Filings from Possum Belly Magnets: 5 TOTAL .~J: Description of fillings: predominately small slivers, some small chunks, some curley Os ';I' :1~¡·":',;;'~J~¡\I{~~;'~j/:¡'!-\I.ifi::;;~i.ï¡:~'\.>~~~~~____~~~'4.~~i$,¡¡:¡~¡~~~~~~~\~i~~-¡;';""!::"":' ,·,;Ïç-·t\ ~~. 24 hr Reci Drill from 13261' MD to 13500' MD, 10856' TVD , 8 1/2" Hole TO, Circ Bottoms Up, Trip out. ;~ ..~~ ~~ I Sag River @ 13470' MD. 10833' TVD '~i. Logging Engineer: Tom Mansfield 1 Doug Wilson * 10000 units = 100% Gas In Air ···,·~··,..·.,~~.'t:-~~1:1~:.ft!I1t~·!!~~-f~~_. . " . ~ '..: ,'. '::"',' .. ·~~'LIiUI..:.~~1im.~~1::~~K~.-"'~:;~;~;'/i.~~ ., .. ~ ~ ,~j",.,,~.,!:~'~ff..i$!o#:~1a-'!'~~~J~Pí~.\~~~~~~~~W6~~~1 ", , ~"".. I,~'\ ~~~"~~"~ ~~'I, ~..~~~...~~~~~r~::~:m~'''~'~~~.>T.~'i~l~ -. ,.....:It" ~ n ¡ Drilling Breaks Depth Drill Rate during after Gas during before after before to to to to ;:<0 ~~~............. , oz. ,.' , r I f I I I ppg sper-"'''''''Y- sun aAILL.ING SERVICES Customer: Well: Area: Lease: Rig: Job No.: 17 3/22/2003 13.500 % j ft Trip Gas: ft Short Trip Gas: to to , "r'--~·--·^'iL[,L] Mud Cut: ppg CI: ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft 1 [1~,2:JIJ;x;a'^'·:J'[it~. 1 ~r:Ã)fnr'.:~I,~,.JUUI:· Trip Depth: Short Trip Depth Tight Spots: f Current Lithology: !"I__.U,[. . f ~ ft units ""' ft units f ~ ft units ~.H I Depth to to to to Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33 E AK AM 22173 Test BOPs Kidd / Holt '~ ¡.; I % % ;:r~~lm _ %LCM Logging Engineer: Tom Mansfield / Doug Wilson * 10000 units = 100% Gas In Air Mudlogger's Morning Report .: ~~;',', ,}.: '~'},;~:\.~~'~':~~i';'l;~'-:': ':t)'~~,.~~::~~\'!'~':::~:~:;~,~~.\f"~(~;~~~.~~~'!~it!:·i...i:: ,¡.J ~~pJ~~'.:I,:,r~;~~~~~;~~~~il~"~7';'~.:.~~·,:~"~~~J~~'~~~~·~,~",*,~~~'~~'i\~j}):t~,~{~~~;ï'~'~~ ~~);:·~:\.(~~t~;'~~~~:~~i~~i:,Ö'~<· ,/;I!,\;~t"':'t~i'·'~::'~'('~~"~",~.l:~~j~~~~:~·,~ ,~,~~~1~"'" Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ftIhr ftIhr ( ftIhr @ Pump 1 spm DH flow Gas" units unit~ ( units @ Pump 2 spm Total flow Temp Out Deg F ( deg F @ Pump 3 spm AV @ DP Pump Pres psi AV @ DC "i;:;".::~Y·I~%ji~f;~~_.~~t_.~;;1t~~4~~~r¡~_.~: ,-,...~ s·.........Jt·,e.,~.".,:!;,J.;....: .~..-"....~,.,.I.)'~,~ . f,.,.....I..~...~\\· .~~·I"':__~.~I~J(.'·. ~'t.IJt(.~~~If:t~.~. ~..;~ ".~."\....'~;,:. ·:1·~:·.r;.~1f'.... b,:o.~.~~'·'iÞ.tr;..~..,..,~... ;"" " : t\1ud Wt In Mud Wt Out API filt I bs/ 1 00ft2 Mud 'Nt at Max Gas Ibsí100ft2 pH Sd "'~.~.- ¡ (IJJ!II.íi-"~C:[::~TïW;:.IIrnl~rmJH1~1·'--rr:·f~;;:~::;:t~~~:-r"Pr-H"" . .M:':,J...,,^ .~1iI."",_~,..",,,,,,....-,. ,- ..,.,..,.l.... ~~rt_M 24 hour accumulation of Steel Filings from Possum Belly Magnets: 5 TOTAL oz. Description of fillings: predominately small slivers, some small chunks, some curley as .("!.r;- ~~"~,;,~,,:x;::}:~~4tj:~~~',;s!;.~~~~~~_tl~f'~J.¡~I'~',,t~f6':!.,~:.""~~~,~~v.'{';~'¡':ßt~~,'¡'Cþ-\\~'i;:,;";"",,,~,'t!· "._<~~i.'~~!:¡~ '~;l.-'.~",. ' .:' 24 hr Reci Move rig over NS19. Nipple down tree. Nipple up BOPs and test same. Prep to RIH to displace diesel. HTHP / 8.50 ppg 8.50 ppg Visc 28 sees PV eP YI ml Gel~ --- .. ~."\ ~ '~1i~!.,.~-i.,·"::~~,,,···:·j"f·"-~ ~'\=)'.~. ';i".~- 'k:~··',:"·:. .'t~,: ..,," 1:,..i",¡S,~I~-~~"'~}··. II\zQf"'1""·:'.I~~o!t!~'df. ,1 t:· ~',: r - .- ." ',.. " .f"~··',.f;"=":-:M~4 .:.tJ'lt\£. .~. Bit No.: Type: Bit Size: Jets: _X_ _X_ TFA: Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run .~'tn~~~lm ¡ ¡lillI.IJJU¡.~lll1.' .._1.=:~.lt:t.R.U,~.,,-,-~'1>.. % % li]ìll[~ Connection Gas and Mud Cut ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ~ll H :[.=J.. - Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh . ~",''I.~\ I I I -~ ..,~: gpm ~ 256 gpm ~ 106 fpm *~ 373 fPmÎ : ..·..·,··"~",,··ot\CI~,.;...~~·.,"'~.",,.,..::¡c,,'v>oI·..'.·/i'jj·...·.,;·~,'-".~~,!,Y-.t!IÌi!!M¡',~'''::)~''·IU"",:j,-.",·<';.'',IV-·.··il-:,~q·., ,i:':"'..tÖ(~;r;··.þi:':'_·'"",-,,··,.,-·.. ..'...'" .':'.' ";""~ì';Î~. :~ Mud Wt In 9.30 ppg Visc 49 secs API filt 5.0 ml HTHP Mud Wt at Max Gas ppg .~~ MudWtOut 9.30 ppg PV 11 cP YI~lbs/100ft2 Gels~ 1 15 1 18Ibs/100ft2 pH ~Sd ~% t~ '~'¡:,;~,~~ 1!";-,~\f¡.~',¡';·''!:''-){jä:t.~,:'.~'''f¡~~.¡:¡;~.>:'M;~!f~~:tf.:¡iJe/~~J!.'~f.~~\~\:t.':£.~'·(~-m:'\2'-f'1...·&,4~$·:1,~;;~...~~t~{.··<&~ '¡"~'JÐiI:~}o.:...~.~~::~!';;: :;~:.~", ''-.~':.';; ',·:·~.:Wt ;'. ;~'''-'>If.,,; .' ~;, :,:r,,,;, -.;,.,¡~.j I . ",,'~~~¡;I..._....;~: ; .·'·-:-';'~~'B;~I_. Customer: BP Alaska Well: NorthStar NS 19 Area: North Slope Lease: NorthStar NS 19 Rig: Nabors 33E Job No.: AK AM 22173 ',I I......y. 18 3/23/2003 13,500 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: sper"'....,v-sun ( .'~.. I_~':..·': ..,:~;;¡:.,,,:;"¡".. ·,.~~~.....I.¡:"~'::~¡'I'I",:"~,~¡,;.I,~ ,~"..., .¿..wf'-1J'~.~~:.!.¡t'~I¡j~;~,,~;.J:~'~"~'+:..~~~~:~,*s:.;.,f¡..I)~~~~~~\......'..:';"'~ ..~;;-..,'\,.'".,,,,,':~';'."'';'~\,~: ~~~I!';"";;·:"· ::~~I"~"i~.'t',:~t..I!~t~t::·,,, ;'/~·'''';~~I~" .~. :~. '..~.~-~~:'~":~< .-. '.' '.' DRILLI N G seRVIc:es Drill CMT Kidd / Holt Mudlogger's Morning Report I Current 24 hr Avg ft/hr ( unit~ ( ( Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 72 spm DH flow spm Total flow spm AV @ DP 1400 psi AV @ DC 24 hr Max ft/hr @ units @ deg F @ I 10 ft/hr units Deg F Gas* Temp Out ( Bit No.: Wt On Bit: 6118 Jets: 3 X 15 X TFA: 0.5180 ------ 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 ¡ t . ~:~if~~3rtt'tŒrfC~~~~::,:'JI:r",(,~ I Type: STX-30CD Bit Size: RPM: Hffi.OnB~ '··~"':":JJ1lt.'::,U1m:&,--:cr:rt1%EJr,~" Trip Depth: 13500 ft Trip Gas: Short Trip Depth ft Short Trip Gas: ïight Spots: to to ,.x::::::lI:Œ_n --rx~;\lm'iU-:mra·-·x 11 ffl ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: I ~ 11 U-:ø.:Œ 6 Mud Cut: Mud Cut: to 1 I "Im"D"· ~r~T'-"" I! ¡ ~ jlll~1JJ I ~ I % %LCM % % % Current Lithology: I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks I I Drill Rate during Gas during Depth % Lithology Sst Sltst Sh after before before after to to to to ppm ppm ft ;.:tmi~!.:!J~:XEDS!!~I,~ItIJ~~~~,]I..mlfl1m1m'li~~~':':. 24 hour accumulation of Steel Filings from Possum Belly Magnets: 5 TOTAL oz. , Description of filling.s: predomin~tel~small ~_~~vers, some .:~al~hunks, some c"urley as . . .' I '. ," . . . N _ .1 .24b~~sR~~~COSi:~~~~~~~~~~~ ~ , ¡ r-: 11' Logging Engineer: Tom Mansfield 1 Doug Wilson ~'''¡~I~~ ·r~~~·.'~I:'~I:::~~~.~~.~.,~ " ~'~, ~,~~ * 10000 units = 100% Gas In Air ,,,. .... ~-,-,:,---~,"",'. , .:",. . ;. ~. ;~'.. ,\ . ~;~:':, '~, '~~:~\~:\~~RS'~,~/::~:. ,::.~.~~~{~:,: :,', <~: '~:,I ::~'~~"~6~~J?~~.~~~~~W: "\~".~ :.'<':~~>" (, :" ~!:::.~'~:~~)f~:ft\\~~~F~~~~t,~,!: {<\,<~,i;:I't~,J!.~~~~,:::-,;;':J, :<~':~\:". ,~·,~i~~:-,·;~'.~~:}~~~~(~.~~~~,:,1 ::¡" ~~:.<.,..,~" "S~:.'<~,~·+'~;'''·: ·;~:'..',{t:~~,.~~~,\;~'I~\'I:'f ~ ~" ,,; . -' . I-,.~ i t 11 I .:.~' ~ ,~,' Current 24 hr Avg 24 hr Max Pump and Flow Data ~ R.O.P, 65.4 ftlhr 18.5 ftlhr( 132 ftlhr @ 13785 Pump 1 spmDHflow gpm:0 ::~ Gas" 195 units 125 unit~ ( 510 units @ 13566 Pump 2 89 spm Total flow 316 gpm~j' femp Out 86 Deg F (86 deg F @ 13855 :~~~ ~res 1950 s~: ~~: ~~ ~~; :~~~ ~~'::::-9::7 ~;';:"1 Mud Wt Out 9.20 ppg PV 8 cP YI 28 Ibs/100ft2 Gels 10 / 12 / 13 Ibs/100ft2 pH 9.4 Sd 0 % .~:. :..) . ...,'.:.':.' '" ,.:,..... ;. .,..': .',,_,,'" "c,..:::~...~,~=·.,..."..: ..... ~::' ..,l'·..* ',r."~I"::ì';. ._.,.,..':~....,~~:......:.:~; ...··~,."''''II~r''..~ ~.;:;. ,... , } ~,.,.:,~ ',' ,.~ ...-.~ :- Bit No.: 6 Type: STX-30CD Bit Size: 61/8 Jets: ~X ~ _X _ TFA: 0,5180 ~~~ Wt On Bit: 25 RPM: 40 Hrs. On Bit: 19.1 Total Revs on Bit: 144K Footage for Bit Run 355 ~~_i1nt':tJr::·:f~rr:::,:~-1J:~r:m:wm:.~...'II,W.~!II.!I·il~.. . nW.~:~:Ii~~, . sper''''''Y- sun Customer: Well: Area: Lease: Rig: Job No.: OR I LL-I N G SERVIc::es Mudlogger's Morning Report BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 2355584 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 19 3/24/2003 13,855 355 Drilling Kidd / Holt /'':-: i:;: ~;'~!!J,"'~~~~~\ I'.'~ . .:r.;,. ~,:;,,': \;',.: :,~'~4~~\<\t~ :,-,.., 1-<,,'~~:>~';.~S~~~~.'~\~!r~<'JC'~';':~~~~'~~'~,f.!~~~~~t~:~.tt;\~\J~':'~~;'~ t~~i~:~.;,~::~~:~,\""~t~.~~*,,~:~~~~~~1~~~~~!r:~ì~ r,:<~r~;):: '~~~'~~~~_~~~~~.~Æ~<;\~;f~~:t:" ',' , Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks I I I I I Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: ïight Spots: to to . . ~,;';XI:;l:~;::'œ;::»:l!I!!Ir..!J.1B¡ m_-DI--'Œ::,,,,,,_~]m~ Current Lithology: ~ % Cgl 10 % ....a.Iln:..'Ii::IfJlllllf!1 J ~~mllJ m II II "¡rill 11,.811111 ! ! I J~ I I I Depth Drill Rate during 60 before 18 13782 to to to to NA TJlma .. Sst !II1f I after na before 75 Mud Cut: Mud Cut: to ! JIll i ppg CI: ppg Short Trip CI: Feet of Fill on Bottom: R;J~~';s;::r:'~,i'u.~ j¡ I !:tC.:..'t(.:l:fCí::::.J,:::a:'~I.. 10 . . 20 % 51st %LCM II.mIfUilll!JIIIIII:r W~II Jilin Ln;::.::});;;~4.:" % Ls J_n .11 Gas during 288 after na % Lithology Cgl 55t Ls Slst 60 10 10 20 .:~~m'"-;Z~l1!;;;"~~'~".'-"" :"l.Jn;~_,.._It,Øf. .....,. .~.. . ~, . ~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3.2 oz. Description of fillings: predominately small slivers, some small chunks, some curley Os ,\. . ~.."",, ,.:,,~~It'~ß!;·,,:t.':=-'::'\...~~'iii-(~(t,¡,~»~:~~~,~~~.~~~~,*~~;~,~¡.¡)~,:;<>~,'f.;·~,~:x~';:i:¡:'';~'!''~~~;~~:'';;~,:;'r.r.~1¡-;'?'¡:;{:",,:11,' ',;~. 24 hr Rec¡ Drilled float equip. and 20' of new hole. Ran FIT. Drilled ahead I it ;Î' Shublik @ 513612' MO, 10928' TVD; Ivishak @ 13782' MD, 11016' TVO ¡,*, :1 Logging Engineer: Tom Mansfield / Doug Wilson '~ì(":"':";I~<~\i~~~~~ " * 10000 units = 100% Gas In Air , " "".,,,~~m~~ì)::Vrl~~~'!;;:iqf;:¡:V;{~,~;'l~. , I ¡ . l' ....;. ,. " ~~~~':I~~~V;1t~1~11·:.; ::;;~';:~,~",)i',*~~~i;'::,~,'~~:'li·\ {:~"".. :}\f~i~~~tí\~._f·~':~\,;;~.'~~\~~~~ílJ.'·<~·X;~W~~l_\W~:~'{·:~~~ii~~,};::':~,\',Ü~:,.',>.~~,'~;;.f:~·'.;'~';}~:'-I~,~~::,:::',~:~~;f.';'.' ~ ,,::,:,:::,~/.~),.;,:,~,.,; ;~~<~;:~,:'~::""f~'~:;:}Åq·;~~{'::~:j::\\')\r··',\ ' ( sper"r"v-sun CR!LLING seRVices Customer: Well: Area: Lease: Rig: Job No.: I Mudlogger's Morning Report BP Alaska NorthStar NS 19 North Slope NorthStar NS 19 Nabors 33E AK AM 2355584 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 20 3/25/2003 14,063 208 POOH for liner Kidd / Holt I Current ,,;,;,':,"'¿l;'~";;~·h,,;¡'~t'~;'~:!';'H~·":.;~~;~~1'~·~~"')i~>?'f¡.\j:$~',\?-"~~~~if.~$~~,1_Ø.ùÞ1.~~~JI/~~~~I'f'\,~'t':¡¡;J~ìti~_"'~~~,¡ffl'~~~~~f',~",~,·,'1.,'~,"·:··':··': 24 hr Avg 40 ftIhr ( 175 unitH ( 24 hr Max ftIhr @ units @ deg F @ I ,'.; R.O,P. ,:;'f Gas· '\;~ Temp Out Pump and Flow Data Pump 1 spm DH flow Pump 2 spm Total flow Pump 3 spm AV @ DP Pump Pres psi A V @ DC ;¡)~{,,~,.,,~i¡"i<t;'<"4%i\\'Iii;~~~~!l~;~'tj¡:0\~~,*ø~_1#¡~~Wi4~__!~¡J!f;j¡à~rø~~\tt¡,tøt,iÙ~~;'::l":~'~;':;;;;'.'· ~1~· ftIhr units Deg F 89 288 :+ Mud Wt In Mud Wt Out 9.30 9.30 13984 13798 ppg ppg Visc 43 secs API filt PV 11 cP YI 24 Ibs/100ft2 4.2 ml HTHP Mud Wt at Max Gas ~ ppg Gels 10 /~/ ~lbs/100ft2 pH 9.0 Sd 0 % .~, ' I < " (' Bit No.: Wt On Bit: 6 Type: STX-30CD Bit Size: 61/8 Jets:.2.- X ~ _X _ TFA: 0.5180 25 RPM: 40 Hrs. On Bit: 24.3 Total Revs on Bit: 189K Footage for Bit Run 563 ,;;:::::::1t;;:::J(::f1:1:mD:i'IJ¡r::L::;::::L::,::xc:l(::mttÄrr:x:tn1:~:1:':::.~:;l:.J:1l(~ I Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to :r:r:~~.xrn;c:I:!Ji';':-.l:JL-'~;X'··\: ~ Current Lithology: 90 % Cgl 10 % "=:].JJI~ In ~ 11110 rn mll1JUllIlJlJI n 1111I1 nmmm m~ I Mud Cut: Mud Cut: to :n:ø:. ."~'OC'ijl)l-..n¡: ppg CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft j n II. "~D~"Ji:::"'1r:tl[:::::=: Sst 0/0 _ A!IIIII,,~IIII.J_.l.L__'w'__n'::I._ __n _ " % ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units Drilling Breaks %LCM ft ft ft units units units ppg ppg ppg I Depth Drill Rate Gas % Lithology before during after before during after Cgl 5st Ls Slst 13782 to 14063 18 60 na 75 288 na 90 10 to to to . ^lNia:~,r3iilIilJ[ ~!I:!{^W'lrì'~r..m:'''fll'Wrnt''~'Ii.~Itf&ŒJ~Î' ", ",",. J' _, ,~"'~~!.),'" "" ' 24 hour accumulation of Steel Filings from Possum Belly Magnets: 3.2 oz. . ,.Desc~iPt,i~n of ~lIin~s: predominately :~\~~I slivers, some small chunks, some curley ~s J'!I.. . ., '~', , ,I ,~ ".~~tJ."W'",~æ~'3'¡;~~, . 1~~:;.¡Ui,,,"t.~...~~,~,-.ç·.4..~: . '," .' .,'.,',..:,.f..",...':,.. 24 hr ReCi Drilled to 1.0. @ 1~063',MD. 11153' TVD., Circulated 4 hole volumes. MAD ~assed back to 7" shoe, I"", ;~ Opened PBL sub and pumped high VIS LCM sweep. Circulated hole clean. POOH to run Imer. " ~ ~ ;t~: ,,~ j J~' 'L:g~ingEngineer: ~om Man:~eld I DO~9 WiISO~. " '. . .' . ..,.' 100~.~.units = 1~~~~<:.:I'~i:i:,.' ! ~...~_~, .. -.',.." ,'H ," ,.,..~~~~&t!~/~.ii:"" , '.' ,.< ';$ }§~ ':',,: ,-~\-. ~1 \i "',' , ." "'";¡M¡'-"~\':·\"··':"';'";""\~},:"'i.f;:¡'J;\tJ,.~,>\>~-¿;,";:';'~':;;\~~'&\¢~~1.>~;"~~f'¡~!~~\;''''',\;;,!,\i¡~~;¡t';':\~''?!#(ii;;'!t:Ät:r:"''!!i~~}.~'iþt;~~:,'¢,~1W~i<::~1't\i¡;t¡y~::~,1;~;\"'·.,",\''';:;'~'' .,.<~¡ .~~ ~~f2 ~~ gpm.~ gpm ~~ ~~ fpm~.: . fpm ~i 1.1} ppg ~ o % ,;%~ , .' .~...r,. '_' ~.. ~ f\,,,,.~~,.....·;,l'ï'.~~".::'~'" '..if:,;,··../".. I ".' ".":' ".. ·:·_·\,...;~~~n\,tI.J--;~:í .;!,~«:"."'~.~j...':.t·:»I.~:-:,:&,,-:,·:..J~~'."'J.',~~l..'''ir.:;~~.J...z:¡:'~lj~?'. ',;,~...~~.:¡'~~oIJ.:.~,,:.., ~~. t : .... . " .. ,'4 r'. L ~1~""'" ;;... ~~ Bit No.: 6 Type: STX-30CD Bit Size: 61/8 Jets: 3 X 15 X TFA: 0.5180 ¡'';i W~::::p~~:;:it~ ';~-::=-7~ Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ¡ ïight Spots: to to to Feet of Fill on Bottom: ft ¡ .·~£¡lmi.l."'J::ll1jaflll&I.Ir~11.1IItt~;;UL" "." I', . ; l'}!. ,.I~".'t"'~"';I". .', . . ...".:.... .:~.~...~ Customer: BP Alaska Well: NorthStar NS 19 Area: North Slope Lease: NorthStar NS 19 Rig: Nabors 33E Job No.: AK AM 2355584 21 3/26/2003 14,063 o RIH wi liner Kidd 1 Holt ;" "., \ , ," :"t..:~¿··I" '.,. I·, .: ~ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: r spe........,v-sun ORI LL.I N G seRVIc:es [ Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.OP, ft/hr 40 ft/hr ( 89 ft/hr @ 13984 Pump 1 spm DH flow Gas* units 175 unit~ ( 288 units @ 13798 Pump 2 spm Total flow Temp Out Deg F ( deg F @ Pump 3 spm A V @ DP Pump Pres psi AV @ DC I . ".. .-':- '::>::'~"'{;':~"'I!~,~<;O,~~*''''''l' .':~,~')I~(if,~y.~!'<'\fJ¡þ-.AJ~;~~CQ'I!I\X·'tI.".~.."""""',;~;.>i...r"l...,,,IL"¡'!>f:"'tXo¡ojV.~'!!'III/I~"\11j"~,:,". '..:'",',''' 1, , . , , -:' ....:. . I --- Mud Wt In Mud Wt Out 9.30 9.30 43 secs API filt 7 cP YI 23 Ibs/100ft2 5,8 ml HTHP Mud Wt at Max Gas Gels 9 / 10 / 11 Ibs/100ft2 pH 8.1 Sd ppg ppg Visc PV I I [ units units units Current Lithology: H ~j:rJ~I]1 il minim J ~w I r % % % % %LCM In!' I nil mlllllll~.Ul:l=: m~ ! I ]r-:,:¡Ul....-. " -\I~H·11l'(fr: Connection Gas and Mud Cut ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units I.. Drilling Breaks Drill Rate Gas % Lithology before during after before during after Cgl 5st Ls Slst I ft ft ft I I Depth I to to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~'-"'~~~~..:Jnml¡Hlr--Hlr~~i;l.I~,~~·III~ï;\_'~]JJatI.. . " "",',j¡.Ì!"l,;~'!f~îMr~'¢~, '¡. :;, 24 hr Reci .:þ" ,ìJ qi;>t\ :,: ;. ¡~: *" :'<':f ,I :1 Logging Engineer: Tom Mansfield / Doug Wilson ~~r;,~,~_~'~'b.·'·"~r:-' ',o\,.c.,.'<"¡;'!":..",. '''''¡',>., ... .. .. :,~l/f.I:.IIQt ¡<¡ .. ., Finished POOH. RJU and ran liner to 7" shoe. Circulated 2800 stks. Continue RIH to bottom. 11; * 10000 units = 100% Gas In Air - ~ '" ~, , ,,-( ·...d...' Schlumberger r Job # 40008135 Customer BP ADW Well NS19 Field Northstar r Rig Nabors 33E AFE # NSD-831331 DD's Tunnell/Levad I Co. Men Polya I Clump PDM Run # 1 R/S 5/6 PDM Ser# 962-1126 Stages 4.0 PDM Size 9 9/16 Rev/Gal 0.113 I Mud Type Sea H20 Spud Mud Wt 8.7 BHT F Mud Vis 150 Item Description Vendor ( Bit#1 MX-C1 Hughes 6004905 TFA=1.031 2 95/8 Std PDM 1.83° Ana 962-1126 I Float 3 Orienting Sub Ana GLDD-105 I 4 MONEL STAB Ana HA-016 MONEL LC Ana 10-HA-013 5 I 6 MONELLC Ana 10-HA-011 7 MONEL STAB Ana HA-012 { 8 X-OVER Ana ANA614 I I I BHA# 1 Date In 29-0ct-02 Date Out 29-0ct-02 Hole Size 16 Time In 6:00 Time Out 12:05 Hole Sect Surface Depth In 201 Depth Out 330 Bha Type Steerable TVD In 201 TVD Out 339 Hrs BRT 6.08 Drlg Hrs 0.6 Drlg Ft 129 Avg ROP 215,00 Slide Hrs 0.1 Slide Ft 30 Slide ROP 300.00 Rot Hrs 0.5 Rot Ft 99 Rot ROP 198,,J0 Pump Hrs 1.8 Rotate % 77 Slide % 23 PDM Jet Blk Inclln Az In Bit>Srvy 40.00 Bearing Mud Incl Out 2.03 Az Out 68.98 T/F Corr Rubber RM100D Avg Dls 1.2 Max Ds 2.4 Plan Dls Sand % 1 RPM 50 GPM 650 SPP On 750 Solids % 3 DIg TQ 2.0 WOB 5 SPP Off 780 OD:- ID ·Stab,OD"" F.N. Bottom Conn Length Cum Length In/Out Top Conn 16 3x20 1x12 1.35 1.35 Jets 7 5/8 Reg P 9 9/16 Tool 15 7/8 1.06 7 5/8 Reg B 26.03 27.38 6 5/8 H-90 B 8 2 3/4 6 5/8 H-90 P 1.46 28.84 6 5/8 H-90 B 8 2 7/8 15 7/8 2.35 6 5/8 H-90 P 5.60 34.44 6 5/8 H-90 B 8 1/8 2 13/16 6 5/8 H-90 P 9.96 44.40 6 5/8 H-90 B 8 2 13/16 6 5/8 H-90 P 9.69 54.09 6 5/8 H-90 B 8 2 7/8 15 7/8 2.12 6 5/8 H-90 P 5.25 59.34 6 5/8 H-90 B 7x8 2 7/8 1.20 6 5/8 H-90 P 3.09 62.43 4 1/2 IF B I -,.~"."-,--"",,.~,"---.,.--,-----.---.--~--_._----,---.,..---- 'BHA Weight Dry wt 10,934 Buoyed wt 9,485 Incl Angle 1 Buoy+lncl wt 9,484 Bit Data lADe # 115 Footage 129 Hrs 0.6 k Revs 4 k Grade Comment Tool Motor Jars Bit #1 Hrs.ln 0.0 0.0 26.2 'Hrs." Out 1,8 0.6 26.8 1.8 BHA and Run Objective BHA and Run Results ~. ,-----..--,-.-.... .- ,~---,._,_....". --.-------,---,-,--.- Why POOH I Comments --"--,-----.._.,.._" ,.,. ,_.. .~._.'""""""~--,.---...~.._-_.._.._-_.""- Bit To I , "f" ~-\ \~ Schlumberger BHA# 2 I I Job # 40008135 Date In 29-0ct-02 Date Out 31-0ct-02 Hole Size 16 Customer BP ADW Time In 13:00 Time Out 10:00 Hole Sect Surface Well NS19 Depth In 330 Depth Out 3,426 Bha Type Steerable Field Northstar TVD In 330 TVD Out 3,218 Hrs BRT 45.00 I Rig Nabors 33E Drlg Hrs 19,3 Drlg Ft 3,096 Avg ROP 160A1 AFE # NSD-831331 Slide Hrs 7,5 Slide Ft 1.082 Slide ROP 144.27 DD's Tunnell / Starr Rot Hrs 11.8 Rot Ft 2,014 Rot ROP 170.ô8 I Co. Men Poly a / Birkbeck Pump Hrs 32,5 Rotate % 65 Slide % 35 PDM Run # 2 R/S 5/6 PDM Jet Blk Inclln 2.03 Az In 68.98 Bit>Srvy 67,00 PDM Ser# 962-1126 Stages 4.0 Bearing Mud Incl Out 38.46 Az Out 160.39 T/F Carr 355.0 PDM Size 9 9/16 Rev/Gal 0.113 Rubber RM100D Avg Dls 2.0 Max Ds 4.6 Plan Dls 2.5 r Mud Type Sea H20 Spud Mud Wt 9.3 Sand % 1.25 RPM 50 GPM 850 SPP On 2260 BHT F Mud Vis 75 Solids % 6.1 Dig TQ 14.0 WOB 10 SPP Off 2150 Item Description Vendor SIN Op JD Stab OD F.N. Bottom Conn Length Cum Length I In / Out Top Conn Bit#1 MX-C1 Hughes 6004905 16 3x20 1x12 1.35 1.35 TFA=1.031 Jets 7 5/8 Reg P 2 9 5/8 Std PDM 1.83° Ana 962-1126 9 9/16 Tool 15 7/8 1.06 7 5/8 Reg B 26.03 27.38 I ·Float 6 5/8 H-90 B 3 MONEL LC Ana 1 O-HA-O 13 8 1/8 2 13/16 6 5/8 H-90 P 9.96 37.34 6 5/8 H-90 B I 4 MONEL LC Ana 1 O-HA-O 11 8 2 13/16 6 5/8 H-90 P 9.69 47.03 6 5/8 H-90 B MONEL STAB Ana HA-012 8 2 7/8 15 7/8 2.12 6 5/8 H-90 P 5.25 52.28 5 6 5/8 H-90 B 6 MWD Ana 173 8 1/4 3 1/4 1.40 6 5/8 H90 P 28.63 80.91 6 5/8 H90 B 7 MONEL X-OVER Ana LWD SB-120 8 1/2 2 13/16 6 5/8 H90 P 1.41 82.32 { 6 5/8 FH B 8 DH Filter Sub Ana JB-15250-2 8 3 1/4 6 5/8 FH P 2.29 84.61 6 5/8 H90 B 9 Orienting Sub Ana GLDD-105 8 2 3/4 6 5/8 H-90 P 1.46 86.07 I *Mule Shoe 6 5/8 H-90 B 10 MONEL STAB Ana HA-016 8 2 7/8 15 7/8 2.35 6 5/8 H-90 P 5.60 91.67 6 5/8 H-90 B ( 11 MONEL DC Ana NMDC-HA-023 8 2 7/8 9 5/8 H-90 P 30.83 122.50 9 5/8 H-90 B MONEL DC Ana NMDC-HA-02C 7 15/16 2 13/16 6 5/8 H-90 P 30.91 153.41 12 6 5/8 H-90 B 13 MONEL STAB Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 P 5.49 158.90 6 5/8 H-90 B 14 MONEL DC Ana NMDC-HA-017 7 15/16 2 13/16 6 5/8 H-90 P 30.83 189.73 6 5/8 H-90 B 15 HYDJARS DAILEY 1417-1044 7 3/4 3 1.19 7 5/8 H90 P 30.83 220.56 5 1/2 IF B 16 26 Jts, HWDP 5" NAD 26 HWDP 5 3 4 1/2 IF P 781 .39 1001.95 I 4 1/2 IF B 17 DP 5" to Surface NAD DP 5 4 1/4 4 1/2 IF P 1001.95 4 1/2 IF B BHA and Run Results IAS planned __0_. .___'__o.o_'__._.____·.__~____,._.,,_, BHA Weight Dry Wt 70.386 Buoyed Wt 60,415 Incl Angle 38 Buoy+lncl Wt 47,608 Bit Data IADC # 115 Footage 3,096 Hrs 19.3 k Revs 147 k Grade 3-2-WT-A-E-I-RG-TD Tool Motor Jars Bit #2 Hrs. In 1,8 Hrs. Out 34.3 19.3 46.1 32.5 BHA and Run Objective Build angle, turn direction, TD -_·_,--____"_0.._-. _,__"____.__ 26.8 Why POOH I Comments 1.~~_~~_~~._~~_.3~~__~~Si.~~~_~~~~__._._._________._ Bit To GR=65.01', D&I=6"l.00',Gyro=96' ':Jomment ) !:r }...,)~ Schlumberger BHA# 3 I ' Job # 40008135 Date In 02-Nov-02 Date Out 07 -Nov-02 Hole Size 12 1/4 Customer BP ADW Time In 4:00 Time Out 3:00 Hole Sect Intermediate Well NS19 Depth In 3,426 Depth Out 11,778 Bha Type RSS Field Northstar TVD In 3,218 TVD Out 9.501 HrsBRT 119.00 I Rig Nabors 33E Drlg Hrs 64,5 Drlg Ft 8,352 Avg ROP 129,49 AFE # NSD-831331 Slide Hrs Slide Ft Slide ROP #DIV/O! DD's Rinke / Starr Rot Hrs 64.5 Rot Ft 8.352 Rot ROP 129.49 Co. Men Birkbeck /Dinger Pump Hrs 92.6 Rotate % 100 Slide % I PDM Run # R/S PDM Jet Incl In 38.46 Az In 160.39 Bit>Srvy 58.91 PDM Ser# Stages Bearing Incl Out 39.65 Az Out 129.83 T/F Corr N/ A PDM Size Rev/Gal Rubber Avg Dls Max Ds Plan Dls { Mud Type Polymer Mud Wt 10.2 Sand % .5 RPM 160 GPM 970 SPP On 3800 BHT F Mud Vis 44 Solids % 5.5 DIg TQ 21.0 WOB 25 SPP Off 3800 Item Description Vendor SIN OD ID Stab OD F.N. Bottom Conn Length Cum Length I Ji,l .Out Top Conn 3it#3 RSX238HF+G~ Hycalog 203404 12 1/4 4x125x13 1.00 1.00 TFA=1.090 Jets 6 5/8 Reg P 2 PO Bias Unit Ana BU-90080 9 1/4 Tool 11 13/16 1.35 6 5/8 Reg B 3.20 4.20 I 7 5/8 Reg B 3 PO Extention Sub 90163 9 1/4 Tool 7 5/8 Reg P 1.29 5.49 7 5/8 Reg P I 4 PO Control Collar Ana 90031 9 3/16 Tool 2.32 7 5/8 Reg B 10.07 15.56 *CU 301 6 5/8 Reg B XO FLOAT SUB Ana GLDD-118 8 2 7/8 6 5/8 Reg P 1.51 17.07 5 *Float 6 5/8 H90 B I 6 MONEL STAB Ana HA-013-SB 8 2 7/8 12 1/8 2.45 6 5/8 H-90 P 5.44 22.51 6 5/8 H-90 B 7 CDR (PWD) Ana 8143 8 7/16 3 1/4 15.21 6 5/8 H90 P 22.83 45.34 '- 6 5/8 FH B 8 MWD Ana 196 8 3/8 3 1/4 1.74 6 5/8 FH P 27.79 73.13 *fllter 6 5/8 H90 B 9 MONEL ST AS Ana HA-002-SB 8 2 7/8 11 7/8 2.40 6 5/8 H-90 P 5.55 78.68 6 5/8 H-90 B 10 MONEL DC Ana NMDC-HA-023 8 2 7/8 9 5/8 H-90 P 30.83 109.51 9 5/8 H-90 B I 11 MONEL DC Ana NMDC-HA-02C 715/16 2 13/16 6 5/8 H-90 P 30.91 140.42 6 5/8 H-90 B MONEL ST AS Ana HA-017-SS 8 2 7/8 12 3/16 2.40 6 5/8 H-90 P 5.49 145.91 12 6 5/8 H-90 B I 13 MONEL DC Ana NMDC-HA-017 7 15/16 2 13/16 6 5/8 H-90 P 30.83 176.74 6 5/8 H-90 B 14 HYDJARS DAILEY 1417-1044 7 3/4 3 1.19 7 5/8 H90 P 30.83 207.57 I 5 1/2 IF B 15 26 Jts. HWDP 5" NAD 26 HWDP 5 3 4 1/2 IF P 781.39 988.96 41/21FB 16 17 Stds. DP 5" NAD DP (17Std) 5 4 1/4 4 1/2 IF P 1603.62 2592.58 I 4 1/2 IF B 17 Porcupine Reamer STC A01821 7 1/2 3 12 1/4 1.25 4 1/2 IF P 5.08 2597.66 4 1/2 IF B 18 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF P 2.37 2600.03 4 1/2 IF B 19 DP 5" to Surface NAD DP 5 4 1/4 4 1/2 IF P 2600.03 4 1/2 IF B BHA and Run Objective Drill to TO and complete 2/100 curve. BHA Weight Bit Data Tool Hrs.ln Hrs. Out _.._..___._._,.__._.__.....,,,._....__~___~__.'..M._______._.~,. _..._ 92,6 Dry Wt 67,823 IADC # Motor BHA and Run Results Buoyed Wt 57.285 Footage 8,352 Jars 19.3 83.8 ..,_._~.__._--_.- ........ _,.._.._~_.~.·._,M___,_____._·_·_M_ ___....____.__ 64.5 Incl Angle 38 Hrs 64.5 Bit #3 Why POOH I Comments IT~_.____... Buoy+lncl Wt 45,141 k Revs 619 k RSS 92.6 . ..,,__"..._, _............_...____.__,__.___.___M___.______ Grade 1-0-WT-C-X-I-CT-TD Bit To IGR=39.651'. D&I=58.91',Res=28.65', Pres=30AO '::omment .... I' ," Schlumberger Job # 40008135 Customer BP ADW Well NS19 Field Northstar Rig Nabors 33E AFE# NSD-831331 DD's Rinke / Levad Co. Men Kidd / Dinger I PDM Run # n/a , PDM Ser# PDM Size Mud Type Polymer BHT F 168 Description I ( Item I Bit#4 RS161HGSW TFA=.742 PO Bias Unit Extention sub PO Control Collar *CU 252 X-OVER *Float NM STABILIZER I 2 3 I 4 5 I 6 NM FLEX LC 7 XO I 8 9"NBR shear @ 590 psi XO 9 10 CDR (PWD) I MWD *filter NM STABILIZER 11 12 I 13 NM FLEX 14 NM FLEX I I 15 NM FLEX 16 X-OVER *corrosion ring 3 Jts. HWDP 5" 17 18 HYOJARS 19 23 Jts. HWOP 5" 20 Dart Valve Sub BHA and Run Objective R/S Stages Rev/Gal Mud Wt 12.8 Mud Vis 58 Vendor Hycalog Ana Ana Ana Ana Ana Ana 203463 631-BU-60154 2476 631-CC-60010 AFS301 IMSlSS-FA 01 575-31-004-FL( STXOS-FE086 Ana Security 910732103 STLFS-HH-30C Ana Ana Ana Ana Ana Ana Ana NAD DAI LEY NAD BPX 7125 860 MSZSS-FA-OC 675-31-018-FC Date In 09-Nov-02 Time In 10:00 Depth In 11,778 TVD In 9,501 Drlg Hrs 28.4 Slide Hrs 0.0 Rot Hrs 28,4 Pump Hrs 37,3 PDM Jet Bearing Rubber Sand % 0.3 Solids % 17.0 OD 8 1/2" 6 3/4 6 7/8 6 1/2 6 3/4 6 15/16 6 9/16 6 3/4 6 3/8 6 3/4 6 3/4 6 3/4 MMFL-FA 025 6 5/8x5 1/16 6 3/4x 5 nXOS-FE 104: MMFL-FA 024) 11/16x5 1/1 6 3/4 3 HWDP 1416-1562 23 HWDP CM7996 5 6 1/2 5 Drill directional plan to 7" csg pnt. 6 3/4 ID' 4x122x14 Jets Tool 4 7/16 2 3/4 2 13/16 2 3/4 2 3/4 2 7/8 2 3/4 Tool Tool 2 13/16 2 13/16 2 13/16 2 13/16 2 3/4 3 2 3/4 3 3 1/8x4 1/2 BHA Weight BHA# 4 Date Out 11-Nov-02 Time Out 18:00 Depth Out 12,473 TVD Out 10,050 Drlg Ft 695 Slide Ft 0 Rot Ft 695 Rotate % 100 Incl In 39.65 Az In 129.83 InclOut 38.94 Az Out 118.76 Avg Dls 1.3 Max Ds 1.8 RPM 160 GPM 630 Dig TQ 17K WOB 20 Stâb'OD F.N. Bottom Conn ¡hI Out Tóp Conn 8 5/16 8 1/2 8 1/2 Dry Wi BHA and Run.Results ~i~_n_ot d~i~~!~~_~-ª-£:~. du~_!~~ow____._ Buoyed Wi ROP, RSS Bha generated 1.5/100 OLS at 40% setting. Incl Angle Why POOH I Coml7Jents ~5~_OH _!.~~..~i~.~_slow._~OP-.: Se~~~~.._~lIin~. Buoy+lncl Wi RSS performed excellent, no shock, ECO steady 13.9 throughout run. P/U OS-70 bit. Bit To Res=45.66', GR=56.66', PWO=47.41', 0&1=75.90' 58,089 46,763 38 36,850 Hole Size 8 1,2 Hole Sect Intermediate Bha Type RSS Hrs BRT 56.00 Avg ROP 24.47 Slide ROP 0,00 Rot ROP 24.47 Slide % 0 Bit>Srvy 75,90 T/F Carr n/a Plan Dls 0.0 SPP On 3450 SPP Off 3450 Length Cum Length 1.00 1.00 4 1/2 Reg P 4 1/2 Reg B 4 1/2 IF B 4 1/2 IF B 4 1/2 IF B 4 1/2 IF P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 IF B 41/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 XH B 4 1/2 XH P 5 1/2 FH B 5 1/2 FH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1 /2 I F B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B Bit Data Tool Hrs~ In Hrs. out IADC # PDC Motor 37.3 Footage 695 Jars 88.7 117,1 Hrs 28.4 Bit #4 0.0 28.4 k Revs 273 k RSS 0.0 37.3 Grade 1-1-WT-A-X-I-NO-PR. No balling at surface ':;omment NBR: O-O-NO-X-I-NO-PR. New condition. 2.10 3.36 4.36 9.70 14.06 1.35 15.41 2.45 5.62 21.03 11 .40 32.43 2.18 34.61 1.30 3.87 38.48 1.38 39.86 22.33 62.19 2.51 28.64 90.83 2.42 5.70 96.53 2.50 30.98 127.51 2.50 31.01 158.52 2.53 189.48 30.96 1.98 191.46 90.40 281 .86 1.70 314.48 32.62 690.99 1005.47 2.37 1007.84 I" Schlumberger I Job # 40008135 Customer BP AOW Well NS19 Field Northstar Rig Nabors 33E AFE # NSO-831331 DD's Rinke / Levad Co. Men Kidd / Dinger / Clump PDM Run # n/a R/S PDM Ser# Stages PDM Size Rev/Gal Mud Type Polymer Mud Wt 12.8 BHT F 188 Mud Vis 56 Descripüon Vendor I r I I I I I I I I I Date In 11-Nov-02 Time In 18:00 Depth In 12.473 TVD In 10,050 Drlg Hrs 15.5 Slide Hrs 0.0 Rot Hrs 15.5 Pump Hrs 22,2 PDM Jet Bearing Rubber Sand % .3 Solids % 17.3 OD ID . Item SIN' 2 Bit#5 OS70FNPV TFA=.742 PO Bias Unit Extention sub PO Control Collar *CU 252 X-OVER "'Float NM STABILIZER Ana IMSZSS-FA 01 6 3/4 Hycalog 201573 8 1/2 6 3/4 Ana 631-BU-60154 2476 Ana 631-CC-60010 6 7/8 3 4 Ana AFS301 6 1/2 5 6 NM FLEX LC Ana 575-31-004-FL( 6 15/16 7 XO 6 9/16 Ana STXOS-FE086 8 9" NBR Security 910732103 6 3/4 shear @ 590 psi XO Ana STLFS-HH-30C 6 3/8 9 10 CDR (PWD) Ana 7125 6 3/4 11 MWD "'filter NM STABILIZER Ana 860 6 3/4 12 Ana MSZSS-FA-OC 6 3/4 13 NM FLEX Ana 675-31-018-FC 6 3/4x 5 14 NM FLEX Ana MMFL-FA 025 6 5/8x5 1/16 15 NM FLEX Ana MMFL-FA 024) 11/16x5 1/1 16 X-OVER Ana 3TXOS-FE 104: 6 3/4 "corrosion ring 3 Jts. HWDP 5" NAD 3 HWDP 5 17 18 HYD JARS DAILEY 1416-1562 6 1/2 19 23 Jts. HWDP 5" NAD 23 HWDP 5 20 Dart Valve Sub BPX CM7996 6 3/4 BHA and Run Objective Drill directional plan to 7" csg pnt. Used bit. BHA and Run Results, I R:~ch~~'p~~n~~_d T~:_.._ . _. .__. RSS Bha yielded 1.5/100 DLS at 40% setting. Why POOH / Comments I ~~~.~~~g~__.~~~~..~~_~____ .._._._._____ OS-70 bit gave same OLS as RSS-specific bits. Bit To Res=45.66', GR=56.66', PWO=47.41', 0&1=75.90' m _,~___~_"..__,__,,_,,_________,_._.. _____.._,____."_~..___,_.__..,._h·" BHA# Date Out 13-Nov-02 Time Out 13:00 Depth Out 13.500 TVD Out 10,856 Drlg Ft 1,027 Slide Ft 0 Rot Ft 1,027 Rotate % 100 Incl In 38.94 Az In 118.76 InclOut 38,75 Az Out 126.33 Avg Dls 1.0 Max Ds 2.4 RPM 160 GPM 620 Dig TQ 22.0 WOB 22 "StabOD F.N. Bottom ,Conn In FÓÙt Top Conn 4x122x14 Jets Tool 8 5/16 4 7/16 2 3/4 2 13/16 8 1/2 2 3/4 2 3/4 2 7/8 2 3/4 Tool Tool 2 13/16 8 1/2 2 13/16 2 13/16 2 13/16 2 3/4 3 2 3/4 3 3 1/8x4 1 /2 BHAWeight Dry Wt 58,114 Buoyed Wt 46,783 Incl Angle 40 Buoy+lncl Wt 35.838 5 Hole Size 8 1:2 Hole Sect Intermediate Bha Type RSS Hrs BRT 43.00 A vg Rap 66.26 Slide Rap 0.00 Rot Rap 66.26 Slide % 0 Bit>Srvy 75.90 T/F Carr n/a Plan Dls 0.0 SPP On 4100 SPP Off 4100 Length Cum Length 4 1/2 Reg P 2.1 0 4 1/2 Reg B 4 1/2 IF B 4 1/2 IF B 4 1/2 IF B 4 1/2 IF P 4 1/2 XH B 2.45 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 IF B 1.30 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 XH B 4 1/2 XH P 5 1/2 FH B 2.51 51/2 FH P 41/2XH B 2.42 41/2 XH P 4 1/2 XH B 2.50 41/2 XH P 4 1/2 XH B 2.50 41/2 XH P 4 1/2 XH B 2.53 41/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 1 .70 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B Bit Data Tool IADC # POC Motor Footage 1,027 Jars Hrs 15.5 Bit #5 k Revs 149 k RSS Grade 1-0-VlfT-C-X-I-PJ-TD ::omment NBR:8-8-8 üunk) 1.00 3.36 9.70 1.35 5.62 11.40 2.18 3.87 1.38 22.33 28.64 5.70 30.98 31.01 30.96 1.98 90.40 32.62 690.99 2.37 Hrs~ In 117,1 37.3 1.00 4.36 14.06 15.41 21.03 32.43 34.61 38.48 39.86 62.19 90.83 96.53 127.51 158.52 189.48 191 .46 281.86 314.48 1005.47 1007.84 Hrs. Out 22.2 132.6 15.5 59.5 I ''''f ,.,): Schlumberger BHA# 6 I \ Job # 40008135 Date In 23-Mar-03 Date Out 26-Mar-03 Hole Size 6 1,8 Customer BP AOW Time In 8:00 Time Out 3:00 Hole Sect Production Well NS19 Depth In 13,500 Depth Out 14,063 Bha Type Steerable Field Northstar TVD In 10,856 TVD Out 11,153 Hrs BRT 67.00 ( Rig Nabors 33E Drlg Hrs 24,0 Drlg Ft 563 Avg ROP 23.46 AFE # NSO-831331 Slide Hrs 9.3 Slide Ft 165 Slide ROP 17.74 DD's Levad Rot Hrs 14.7 Rot Ft 398 Rot ROP 27.07 r Co. Rep. Kidd / Holt Pump Hrs 36,8 Rotate % 71 Slide % 29 PDM Run # 3 R/S 7/8 PDM Jet 8 Inclln 38.75 Az In 126.33 Bit>Srvy 56.1 ~ PDM Ser# 475-2458 Stages 2.0 Bearing OSB Incl Out 60.57 Az Out 130.51 T/FCorr 317.9 PDM Size 4 3/4 Rev/Gal 0.330 Rubber RM 1 000 AvgDIs 11.0 Max Ds 14.7 Plan Dls 8.0 I Mud Type Oril-N Mud Wt 9.2 Sand % 0.0 RPM 40 GPM 320 SPP On 1950 BHT F 150 Mud Vis 42 Solids % 4.8 DIg TQ 17.0 WOB 25 SPP Off 1830 Item Descript/cm Vendor SIN OD. ID StabOD, EN. Bottom Conn Length Cum Length I ' lnlol.Jt Top Cònn STX-30CO Hughes 5018660 6 1/8 3X15 0.75 0.75 Bit #6 TFA=.518 Jets 3 1/2 Reg P 2 43/4 POM SSS 1.5 Ana 475-2458 4 3/4 Tool 6 17.72 3 1/2 Reg B 23.47 24.22 ( *Float 3 1/2 IF B 3 AON4 Ana 74 4 3/4 Tool 5 3/4 17.78 3 1/2 IF P 24.86 49.08 3 1/2 IF B I 4 MWD - SlimPulse Ana 4741 4 13/16 Tool 1.48 3 1/2 IF P 33.84 82.92 Survey on bottom 31/2 IF B ARC5 Ana 62 4 3/4 Tool 1.47 3 1/2 IF P 23.17 106.09 5 3 1/2 IF B 6 NMOC Ana NMDC-EA-002 4 3/4 2 1/4 3 1/2 IF P 30.88 136.97 3 1/2 IF B 7 NMOC Ana NMDC-EA-003 4 3/4 2 1/4 3 1/2 IF P 31.01 167.98 I 3 1/2 IF B 8 PBL Sub (2-Port) leatherfo 475PBL 17 4 3/4 2 1/4 3 1/2 IF B 8.09 176.07 Autolock 3 1/2 IF P 9 HYDJAR DAILEY 1400-1407 5 1/4 2 1/4 5 1/4 1.85 3 1/2 IF P 30.12 206.19 HT40 10 6 Jts HWDP NAD 4" HWDP 4 2 11/16 HT40 P 184.06 390.25 HT40 B I 11 72 Jts. DP 4" NAD 72DP 4 4 3 5/16 HT40 P 2260.88 2651.13 HT40 B xo NAD 400008C 6 1/4 2 5/8 HT40 P 1.88 2653.01 12 4 1/2 IF B I 13 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF P 2.37 2655.38 4 1/2 IF B 14 DP 5" to Surface NAD DP 5 4 1/4 4 1/2 IF P 2655.38 I 4 1/2 IF B BHA and Run Objective Build to 60 deg at 8/100. Rotate to TO.BHA Weight ___.____..___.__.'n.______.___.__._.___._______ SlimPulse config. survey on bottom. Dry Wt 46,766 BHA and Run Results Bha yeild~~__~~:~L~g.~~~..~~_~.~lide. ____ Buoyed Wt 40,212 Dropped 0.3/100' rotate. Good run. Incl Angle 60 Why POOH ICommel1ts POOH for TO. Buoy+lncl Wt 20,106 ....-..-...------..--------- ·-·-------··------------S-ënlTIm cerg er I-" nvate Bit To Dens=30.62', Nuet=33.75', 0&1=56.11', GR=59.11', Res=88.89', GR=93.81' Bit Data IADC # 547 Footage 563 Hrs 24.0 k Revs 187 k Grade 4-8-wr -A-E-2/16-BT - TO Tool Motor Jars Bit #5 Hrs./n 0,0 111,4 0.0 Hrs..Out 36.8 135.4 24.0 36.8 '::;omment I ( I BHA #: 1 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF ( Depth In: 201.00 Inclination In: 2,09 Azimuth In: 79,21 Depth Out: 330.00 Inclination Out: 1,88 Azimuth Out: 80.40 ( Total ROP: 209.2 Comments: I I Md Froml (ft) 201.00 237.00 269,00 Md To I Rot/Slid I Durationl Course I (ft) (RIS) (hr:min) (ft) 237.00 R 0:12 36.00 269.00 S 0:05 32.00 330.00 R 0:20 61.00 I ( I I NS19_ Bhas.xls Slide Sheet Well: NS-19 Borehole: NS 19 UWl/API#: Tot Distance: 129.00 Dist Steering: 32,00 Dist Rotating: 97.00 % Steer: 24,8 % Rot: 75.2 Steering ROP: 384.0 TF r) I Flow ISPP On Etspp Off Et WOB I (gal/min) (psi) I (psi) I (1000 Ib~ 650 700 680 5.0 650 710 680 10.0 685 780 750 10,0 M 110 Page 1 of 1 Directional Driller: James Tunnell Directional Driller: Keith Starr Job#: Total Time: 0.6 Time Steering: 0,1 Time Rotating: 0,5 Rotating ROP: 181.9 RPM ITorq On Et Svy Md I (c/min) I I (ft) 50 2 o 0 250.00 50 3 % Steer: 13,5 % Rot: 86,5 Incl I Azmth I DLS J n (0) (0 /100 ft 2.09 79.21 0,74 7/18/2003-12:15 PM I BHA #: 2 Slide Sheet Client: BP Exploration Alaska Well: NS-19 Directional Driller: James Tunnell Field: Northstar Borehole: NS19 Directional Driller: Keith Starr Structure: Northstar PF UWl/API#: Job#: I Depth In: 330.00 Depth Out: 3426,00 Tot Distance: 3096,00 Total Time: 19,3 Inclination In: 2.40 Inclination Out: 38.46 Dist Steering: 1082.00 % Steer: 34,9 Time Steering: 7,5 % Steer: 39,1 Azimuth In: 86,37 Azimuth Out: 160,39 Dist Rotating: 2014.00 % Rot: 65.1 Time Rotating: 11,7 % Rot: 60,9 I Total ROP: 160.8 Steering ROP: 143,6 Rotating ROP: 171,9 Comments: ( I Md Froml Md To I Rot/Slid I Durationl Course I TF I Flow ISPP On ,SPP Off , WOB I RPM Forq on, Svy Md I Inct I Azmth I DLS J (ft) (ft) (RIS) (hr:min) (ft) (0) (gal/min) (psi) (psi) (10001bO (c/min) (ft) (0) (0) (°/100 ft 330.00 369.00 R 0:11 39.00 685 1050 1000 10,0 50 3 I 369.00 399.00 S 0:03 30.00 M 120 695 1080 1050 10.0 0 0 380.00 2.40 86.37 0.63 399.00 460.00 R 0:12 61.00 695 1080 1050 10.0 50 3 460,00 2,52 88,18 0,18 460,00 550.00 R 0:37 90.00 700 1100 1080 10.0 50 3 550.00 580.00 S 0:10 30.00 M 115 700 1280 1200 15.0 0 0 570.00 3.08 98,00 0,67 I 580.00 640.00 R 0:17 60.00 700 1280 1200 15.0 50 3 640.00 670.00 S 0:05 30.00 M90 700 1320 1300 15.0 0 0 660.00 3.99 98,18 1.01 670.00 730.00 R 0:30 60.00 700 1320 1280 15.0 50 3 730.00 760.00 S 0:15 30.00 G-4 700 1330 1310 15.0 0 0 750.00 4.71 97.46 0.80 I 760,00 820.00 R 0:26 60.00 700 1340 1300 15.0 50 3 820.00 850.00 S 0:09 30.00 G-22 700 1410 1370 15.0 0 0 840.00 5.21 96.01 0.57 850.00 910.00 R 0:19 60.00 700 1440 1340 15.0 50 4 I 910.00 950.00 S 0:14 40.00 GO 700 1450 1410 15.0 0 0 930.00 5.45 93.63 0.36 950.00 1000.00 R 0:15 50.00 700 1460 1410 15.0 50 5 1000.00 1045.00 S 0:09 45.00 GO 700 1440 1360 15.0 0 0 1021.00 6.21 95.40 0.86 1045.00 1092.00 R 0:15 47.00 700 1470 1360 15.0 50 5 1092.00 1137.00 S 0:23 45.00 G -10 700 1450 1440 15.0 0 0 1116.00 8.16 94.20 2.06 1137,00 1187.00 R 0:36 50.00 700 1470 1440 15.0 50 6 1183.00 8.78 94.22 0.93 1187.00 1281.00 R 0:52 94.00 700 1460 1410 15.0 50 6 1210.00 7.97 95.63 3.09 1281.00 1326.00 S 0:36 45.00 G 14 700 1460 1410 15.0 0 0 1304.00 8.33 96.03 0.39 I 1326.00 1374.00 R 0:28 48.00 700 1460 1410 15.0 50 6 1374,00 1416.00 S 0:44 42.00 G26 700 1430 1420 20.0 0 0 1398.00 8.56 100.08 0.68 1416.00 1469.00 R 0:34 53.00 700 1450 1420 20.0 50 7 1465.00 9.22 101.80 1.06 1469,00 1529.00 S 0:30 60.00 G20 700 1590 1420 35.0 0 0 1493.01 10.01 104.71 3.31 1529.00 1564.00 R 0:11 35.00 700 1590 1420 30.0 50 6 1564.00 1604,00 S 0:09 40.00 G -20 910 2170 2070 25.0 0 0 1587.65 12.78 108.05 3.01 1604.00 1658.00 R 0:12 54.00 910 2170 2070 15.0 50 6 1658.00 1698.00 S 0:09 40.00 G -30 900 2130 2080 15.0 0 0 1681.42 13.42 101.86 1.64 1698.00 1752,00 R 0:12 54.00 900 2150 2050 15.0 50 6 1752,00 1792.00 S 0:07 40.00 GO 1000 2400 2350 20,0 0 0 1775,63 15.12 102.66 1,82 1792,00 1847,00 R 0:08 55.00 1100 1820 2780 10,0 50 6 1847,00 1887.00 S 0:08 40.00 GO 1000 2720 2500 25.0 0 0 1869.88 15.99 104.49 1.06 1887,00 1917,00 R 0:12 30.00 1100 3000 2950 20,0 50 6 1917,00 1941,00 R 0:04 24,00 850 2050 1900 20.0 50 6 1941.00 1986.00 S 0:06 45.00 G 25 850 2050 1900 25,0 0 ° 1966,27 16,92 108,72 1.57 1986,00 2035.00 R 0:13 49,00 850 2000 1900 20.0 50 7 2035,00 2065.00 S 0:07 30,00 G40 850 2000 1900 30.0 0 0 2059,33 17,91 118,27 3.25 2065,00 2095,00 R 0:05 30.00 850 2050 1900 20.0 50 8 2095,00 2125,00 S 0:05 30,00 G 50 850 2000 1900 25.0 ° ° 2125,00 2131,00 R 0:01 6,00 850 2000 1900 25,0 50 8 2131.00 2161,00 S 0:04 30,00 G 50 850 2050 1900 25.0 0 0 2154,13 20,60 128.78 4,62 2161,00 2191.00 R 0:04 30,00 850 2000 1900 25.0 50 8 NS19_ Bhas.xls Page 1 of 2 7/18/2003-12: 15 PM 2191,00 2211,00 S 0:05 20,00 G45 850 2050 1900 25,0 0 0 2211,00 2225,00 R 0:06 14.00 850 2000 1920 25,0 50 8 I 2225,00 2265,00 S 0:12 40.00 G 70 850 2180 1970 25,0 0 0 2247.86 22.17 138,21 4.03 2265,00 2319,00 R 0:07 54,00 850 2030 1970 20,0 50 8 2319,00 2349,00 S 0:06 30,00 G45 850 2150 2000 25,0 0 0 2341.31 23,68 144,61 3.12 I 2349.00 2412.00 R 0:19 63.00 850 2150 2000 25.0 50 7 2412.00 2442.00 S 0:14 30,00 G45 850 2150 2000 25,0 0 0 2436,82 23.72 150,58 2,51 2442,00 2507,00 R 0:17 65,00 850 2150 2000 30,0 50 8 2507,00 2537.00 S 0:13 30.00 GO 850 2140 2070 40.0 O' ° 2531,73 25.59 154,31 2,56 I 2537.00 2602.00 R 0:20 65.00 850 2150 2070 30.0 50 10 2602,00 2632,00 S 0:15 30.00 GO 850 2220 2100 45.0 0 ° 2627.47 27,59 156.76 2,38 2632,00 2697,00 R 0:13 65,00 850 2250 2100 40,0 50 12 2697,00 2791.00 R 0:35 94.00 850 2250 2080 40.0 50 12 2719,67 28,18 158,16 0,96 I 2791,00 2821,00 S 0:15 30.00 G -20 850 2340 2320 40.0 0 0 2813.28 29.62 157.37 1,59 2821,00 2885.00 R 0:25 64,00 850 2330 2210 40.0 50 12 2885.00 2915.00 S 0:12 30.00 GO 850 2180 2100 25.0 0 0 2907,38 31,04 159,28 1.82 I 2915.00 2979.00 R 0:11 64.00 850 2240 2120 30,0 50 12 2979.00 3009.00 S 0:14 30.00 G -30 750 1840 1770 20.0 0 0 3001,93 33.23 158.59 2,35 3009.00 3073.00 R 0:16 64.00 850 2230 2120 35.0 50 12 3073.00 3103.00 S 0:19 30.00 G -10 850 2220 2130 20.0 0 0 3096.32 35.33 159.01 2.24 I 3103.00 3167.00 R 0:13 64.00 850 2240 2120 35.0 50 12 3167,00 3197.00 S 0:35 30.00 G -15 850 2250 2140 25,0 0 0 3190.07 37.48 158.75 2.30 3197.00 3260.00 R 0:26 63.00 850 2260 2140 25.0 50 14 I 3260.00 3290.00 S 0:39 30.00 G8 850 2260 2140 35.0 0 0 3283.35 39.51 159.73 2.27 3290.00 3354,00 R 0:37 64.00 850 2260 2150 35.0 50 14 3354.65 38.46 160.39 1.58 3354.00 3426.00 R 0:44 72.00 850 2260 2150 35.0 50 14 3426.00 38.46 160.39 0.00 I I I NS19_ Bhas.xls Page 2 of 2 7/18/2003-12:15 PM I r BHA #: 3 Slide Sheet Schlumberger Client: BP Exploration Alaska Well: NS-19 Directional Driller: Rinke Field: Northstar Borehole: NS19 Directional Driller: Starr Structure: Northstar PF UWUAPI#: 50-029-23122-00 Job#: I Depth In: 3426,00 Depth Out: 11778.00 Tot Distance: 8352,00 Total Time: 64,5 Inclination In: 37.26 Inclination Out: 39,65 Dist Steering: 0.00 % Steer: 0,0 Time Steering: 0,0 % Steer: 0,0 Azimuth In: 162.54 Azimuth Out: 129,83 Dist Rotating: 8352,00 % Rot: 100,0 Time Rotating: 64,5 % Rot: 100.0 I I Total ROP: 129,6 Steering ROP: 0,0 Rotatin9 ROP: 129,6 Comments: - I Duration I Md From I Md To I Avg ROPI Rot/Slid I RSS I TF I WOB I RPM rorq on, Flow ISPP on, Svy Md I Incl I Azmth I DLS 1 (hr:min) (ft) (ft) (ftIh) (RIS) SETTING (0) (1000Ibf) (cJmin) K fVls (gallmin) (ft) (0) (0) (°/100 ft) 0:24 3426.00 3446,00 50.0 R 0/0% - 10,0 60 7 800 1800 0:48 3446.00 3536,00 112.5 R - 10.0 100 7 1000 1700 3473,16 37,26 162.54 1,50 I 0:20 3536.00 3630,00 282.0 R -- 10.0 100 7 1060 1800 3567,79 37,27 163,28 0,47 0:11 3630.00 3724,00 512.7 R 326 /20% - 10.0 100 8 1060 1800 3660.71 38,34 163,19 1,15 0:16 3724.00 3818,00 352.5 R -- 10.0 100 9 1060 1800 3754.81 39.58 160.84 2,05 I 0:21 3818,00 3911,00 265.7 R - 10.0 100 10 1060 1820 3848.72 40.19 158.98 1,43 0:22 3911.00 4006.00 259.1 R 36/20% - 10.0 120 10 1060 1840 3942.86 40.72 159.91 0,85 0:17 4006.00 4100.00 331.8 R - 10.0 140 12 1060 1860 4036.84 41,28 160.34 0.67 0:25 4100.00 4194.00 225.6 R - 10,0 140 12 1060 1910 4131.09 41.84 160.36 0,59 0:18 4194.00 4287.00 310.0 R - 10.0 140 12 1060 1980 4224.22 42.59 160.05 0.84 I 0:14 4287.00 4382.00 407.1 R - 10.0 120 12 1060 2000 4318.90 42.86 161.96 1,40 0:27 4382.00 4475.00 206.7 R - 10.0 120 12 1060 2020 4412.65 43.77 162.13 0.98 0:18 4475.00 4569.00 313.3 R 67/40% - 10.0 120 12 1060 2090 4506.27 44.22 163.49 1.12 I 0:21 4569.00 4663.00 268.6 R - 10.0 120 12 1060 2080 4599.95 45.09 164.89 1.40 0:13 4663.00 4756.00 429.2 R 108/20% - 10.0 120 12 1060 2090 4693.76 46.10 165.11 1.09 0:15 4756.00 4850.00 376.0 R 135/40% - 10.0 120 12 1060 2090 4787.05 46.36 165.11 0.28 0:16 4850.00 4945.00 356.3 R - 10.0 120 12 1060 2090 4881.38 45.74 165.60 0.76 I 0:17 4945.00 5039.00 331.8 R - 10.0 120 12 1060 2120 4976.56 44.98 167.22 1.45 0:20 5039.00 5132.00 279.0 R - 10.0 120 12 1060 2230 5069.27 43.80 168.88 1.79 0:17 5132.00 5227.00 335.3 R - 10.0 125 12 1060 2220 5163.16 43.52 169.31 0.43 I 0:30 5227.00 5320.00 186.0 R - 10.0 125 12 1060 2180 5256.99 42.40 170.68 1.55 0:37 5320.00 5414.00 152.4 R 202/40% - 10.0 140 12 1060 2200 5351.82 41.30 171.11 1.20 0:35 5414,00 5508.00 161.1 R - 10.0 140 12 1060 2200 5445.49 40.56 170.36 0.95 0:32 5508.00 5603.00 178.1 R 254/20% - 10.0 140 12 1060 2250 5538.70 40.48 170.12 0.19 I 0:28 5603,00 5696.00 199.3 R - 10.0 140 12 1050 2250 5632.17 40.79 169.43 0.58 0:18 5696,00 5789.00 . 310.0 R - 10.0 140 12 1050 2250 5725.79 41.01 168.03 1.01 0:21 5789.00 5884.00 271.4 R - 10.0 140 12 1050 2300 5819.58 41.44 167.72 0.51 0:21 5884.00 5978.00 268.6 R - 10,0 140 12 1050 2300 5914.48 41,69 166.63 0.81 0:20 5978,00 6072.00 282.0 R - 10.0 140 12 1050 2350 6008.43 41.92 166.57 0.25 0:29 6072.00 6166.00 194.5 R 217 /20% - 10,0 140 12 1050 2350 6103,89 42.15 166,21 0.35 0:30 6166.00 6260.00 188.0 R - 10.0 140 12 1050 2400 6196.60 41.66 165,63 0,67 1 :12 6260,00 6354.00 78.3 R - 10.0 140 12 1050 2400 6291,19 41,26 165,39 0.46 0:42 6354,00 6448,00 134,3 R - 10,0 140 12 1050 2400 6385,20 41,04 164,89 0.42 0:43 6448,00 6542,00 131.2 R - 10,0 140 12 1050 2400 6479,36 40,60 164,31 0.62 0:55 6542.00 6636,00 102.5 R - 10,0 140 12 1050 2400 6573,13 40.19 163,89 0.52 1:44 6636,00 6730,00 54,2 R - 10,0 140 12 1050 2400 6667,61 40,22 162.97 0,63 0:26 6730,00 6825,00 219,2 R - 10,0 140 12 1050 2400 6762,57 40.17 162,28 0.47 0:48 6825,00 6918,00 116,3 R 0/0% - 10.0 140 13 1050 2450 6855,33 40,01 161,23 0.75 1:00 6918,00 7012.00 94,0 R - 10,0 140 13 1050 2450 6949,00 40,12 160.92 0.24 2:14 7012,00 7105,00 41,6 R - 10,0 140 13 1050 2500 7043,00 40,63 161.42 0,64 2:12 7105,00 7199,00 42.7 R - 10.0 140 14 1050 2500 7134,62 40.85 161.45 0,24 0:51 7199.00 7292,00 109.4 R - 10,0 140 14 1050 2500 7228.81 41,07 161,54 0.24 1:11 7292,00 7386,00 79.4 R - 10,0 140 14 1050 2600 7321.81 41.14 161,59 0,08 0:55 7386.00 7479,00 101.5 R - 10,0 140 14 1050 2600 7415,55 41,35 161,37 0.27 NS19_ Bhas,xls Page 1 of 2 7/18/2003-12:15 PM 7/18/2003-12:15 PM Page 2 of 2 NS19_ Shas.xls f 1 :01 7479,00 7573,00 92.5 R 71/20% - 10,0 125 14 1050 2780 7510.23 41,62 161.16 0,32 f 1:34 7573,00 7667,00 60,0 R - 10,0 120 14 1050 2800 7603,68 41,96 161.75 0,56 2:25 766700 7761.00 38.9 R - 15,0 120 14 1050 2850 7698,13 42,18 162,25 0,42 0:37 7761,00 7854,00 150.8 R - 15,0 140 14 1050 2900 7791,61 42.49 163,35 0,86 0:36 7854,00 7948,00 156.7 R - 15.0 140 15 1050 2900 7885,86 42.73 164,54 0,89 0:40 7948,00 8043,00 142,5 R 143/20% - 15,0 140 15 1050 2900 7980,62 42,80 164,87 0,25 I 0:42 8043.00 8138,00 135.7 R - 15,0 140 15 1050 2900 8074,92 42,29 165,36 0,64 0:36 8138.00 8233,00 158,3 R - 15,0 140 15 1050 2900 8170,10 41,63 165,89 0.79 0:51 8233,00 8327,00 110.6 R 180/20% - 15,0 140 15 1050 2900 8264,15 41.35 165,93 0,30 I 0:32 8327,00 8420,00 174,4 R - 15,0 140 15 1050 2900 8356.74 40,86 165.98 0.53 0:29 8420,00 8515,00 196,6 R - 15,0 140 15 1050 2900 8451,07 40,35 165,62 0,59 0:46 8515,00 8608,00 121,3 R - 15,0 140 15 1050 3020 8545,98 39.75 165,31 0,67 0:35 8608.00 8702,00 161,1 R - 20,0 140 15 1050 3200 8639.7 4 39,07 164,88 0.78 I 0:37 8702,00 8796,00 152.4 R 0/0% - 20.0 160 17 1050 3220 8733,61 38,53 164,95 0,58 0:35 8796,00 8889,00 159.4 R - 20,0 160 17 1050 3230 8827,51 38.08 164,87 0,48 0:30 8889.00 8984,00 190,0 R - 20.0 160 17 1050 3250 8921,50 37,58 165,28 0,60 I 0:14 8984,00 9033,00 210,0 R - 20.0 160 17 1050 3230 9015.74 37,08 165,13 0,54 0:17 9033.00 9077.00 155.3 R - 20,0 160 17 1050 3230 0:35 9077.00 9171.00 161.1 R 326/20% - 20.0 160 18 1050 3300 9107,66 36.72 165,47 0.45 0:35 9171,00 9265.00 161.1 R - 20.0 160 18 1050 3330 9200.89 36.84 165.74 0,22 I 0:44 9265.00 9358.00 126.8 R 315/40% - 20.0 160 18 1050 3250 9294.74 36.75 165,65 0,11 0:25 9358.00 9452.00 225.6 R - 20.0 160 18 1050 3240 9388.47 37.04 164.26 0.94 0:34 9452.00 9547,00 167.6 R - 20.0 160 18 1050 3330 9482.66 37.27 163.13 0.76 0:58 9547.00 9640.00 96.2 R 0/40% - 20.0 160 18 1050 3350 9576.82 37.56 162.03 0.77 I 0:32 9640.00 9734.00 176.2 R - 20.0 160 18 1050 3350 9670.56 38.12 162.39 0.64 0:35 9734.00 9827.00 159.4 R - 20.0 160 18 1050 3450 9766.59 38.76 163.44 0.95 0:34 9827.00 9921.00 165.9 R - 20.0 160 18 1050 3450 9858.64 39.61 163.56 0.93 I 0:26 9921.00 10015.00 216.9 R - 25.0 160 20 1050 3500 9952.13 40.03 164.95 1.05 0:28 10015.00 10110.00 203.6 R - 30.0 160 23 1050 3500 10046.07 40.20 166.02 0.76 0:26 10110.00 10203.00 214.6 R - 30.0 160 23 1050 3500 10140.69 40.24 166.28 0.18 0:38 10203.00 10297.00 148.4 R 292/60% - 30.0 160 23 1050 3200 10235.55 40.06 166.14 0.21 0:40 10297.00 10391.00 141.0 R - 25.0 160 20 1050 3200 10327.55 39.67 163.87 1.64 1:24 10391.00 10486.00 67.9 R 315/60% - 15.0 160 15 900 2800 10423.98 39.96 161.63 1.52 0:30 10486.00 10580.00 188.0 R - 25.0 160 21 1020 3800 10518.50 40.50 160.76 0.82 0:34 10580.00 10675.00 167.6 R - 25.0 160 21 1020 3800 10613.08 41.21 159.28 1.27 I 0:39 10675.00 10770.00 146.2 R 299/80% - 25.0 160 22 1010 3800 10706.75 41.72 158.08 1.01 0:40 10770.00 10866.00 144.0 R - 25.0 160 19 1010 3800 10803.10 42,44 155.77 1.77 0:38 10866.00 10961.00 150.0 R - 25.0 160 19 1010 3800 10898.83 43.87 153.06 2.45 0:40 10961.00 11056.00 142.5 R 270/100% - 25.0 160 19 1010 3800 10993.63 44.61 149.73 2.57 0:39 11056.00 11152.00 147.7 R - 25.0 160 19 1010 3800 11089.78 45.89 145.83 3.17 2:47 11152.00 11227.00 . 26.9 R 233/100% - 15.0 80 14 1010 3800 11183.79 46.01 140.54 4,05 0:56 11227.00 11248.00 22,5 R - 15.0 80 14 1010 3800 I 0:39 11248.00 11342.00 144.6 R 240/80% - 25.0 160 19 1010 3800 11279.60 45.24 136.10 3.41 1 :32 11342,00 11435.00 60.7 R - 25,0 160 19 975 3800 11375.97 45,41 132.07 2.98 2:06 11435,00 11531,00 45.7 R - 15.0 160 21 975 3800 11468.66 44.31 129,33 2.40 1:00 11531.00 11626.00 95.0 R - 15.0 160 21 975 3800 11564,20 42.54 129.17 1.86 11660,51 40,69 129.19 1,92 0:59 11626,00 11722,00 97,6 R - 20,0 120 21 950 3800 11714.41 39.65 129,83 2.08 0:24 11722,00 11778,00 140,0 R - 20,0 120 21 950 3800 7/18/2003-12:15 PM Page 1 of 1 NS19_ Bhas.xls I I I 0.78 0.92 150 150 150 160 160 3450 2950 2950 3450 3450 0/60% R 12115.00 12210.00 95.00 3:06 30.6 R 12210.00 12294.00 84.00 1:59 42.4 R 12294.0012305.00 11.00 0:26 25.4 R 12305.00 12400.00 95.00 6:50 13.9 R 12400.00 12473.00 73.00 4:04 18.0 18 12321.59 38,31 119,04 18 12392.29 38.94 118.76 18 17 17 14.0 15.0 15.0 15.0 20.0 630 560 560 630 630 337/60% I ROt/Slid) Md From I Md To ) course) Duration) Avg ROP) TF ) User 1) Flow )SPP on, WOB I RPM Forq on, Svy Md I Incl ) Azmth) DLS I (RIS) (ft) (ft) (ft) (hr:min) (ftIh) (0) (gaVmin) (psi) (10001bO (A) (ft) (0) n (0 /100 ft) R 11778,00 11798,00 20.00 2:48 7.1 - 293/40% 520 2700 10.0 100 13 11845.13 37,92 127,97 1,60 R 11798.00 11829.00 31.00 0:58 32.1 - 600 3350 30,0 120 17 11938.67 37,14 126.12 1.47 R 11829.00 11924.00 95.00 2:23 39.9 - 600 3200 30.0 160 17 12035.53 37,06 123,93 1.37 R 11924.00 12019.00 95.00 1:44 54.8 - 315/60% 615 3450 35.0 150 18 12130.52 37.45 121.12 1.84 R 12019.00 12115.00 96.00 4:06 23.4 - 625 3450 15.0 160 17 12227.28 38.30 120.23 1,04 I I Comments: I Rotating ROP: 24,5 Steering ROP: 0.0 Total ROP: 24,5 % Steer: 0,0 % Rot: 100,0 Total Time: 28.4 Time Steering: 0,0 Time Rotating: 28.4 Tot Distance: 695,00 Dist Steering: 0,00 % Steer: 0,0 Dist Rotating: 695,00 % Rot: 100,0 Depth Out: 12473,00 Inclination Out: 38,94 Azimuth Out: 118.76 Depth In: 11778,00 Inclination In: 37,92 Azimuth In: 127,97 I Directional Driller: Rinke Directional Driller: Levad Job#: Well: NS-19 Borehole: NS19 UWUAPI#: 50-029-23122-00 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Schlumberger Slide Sheet BHA #: 4 ( I 7/18/2003-12:15 PM Incl I Azmth I DLS I (0) (0) (°/100 ft) 40,33 120.76 1,40 41,66 121.87 1,58 40.20 122,42 1.58 38.54 124,11 2.06 37.73 124.29 0.86 36.56 123.95 1.24 35.88 123.77 0.72 35.75 123.97 0.18 35.82 124.12 0.12 37.80 126.04 2.40 38.74 126.97 2.26 % Steer: 0,0 % Rot: 100,0 Schlumberger Page 1 of 1 NS19_ Bhas,xls R 12877.00 12974.00 97.00 1:10 83.1 - 326 / 20% 615 3800 20.0 160 22 12894.01 R 12974.00 13069,00 95.00 1:23 68.7 - 620 3650 22.0 160 22 12989.65 R 13069.00 13165.00 96.00 1:53 51.0 - 0/40% 620 3900 22,0 160 21 13085.11 R 13165.00 13260.00 95.00 1:49 52.3 - 620 3950 20.0 160 21 13180.26 R 13260.00 13356.00 96.00 1:00 96.0 - o /80% 620 4000 22.0 160 20 13275.83 I 13371.09 R 13356.00 13451.00 95.00 1:00 95.0 - 620 4050 22.0 160 20 13419.91 R 13451.00 13500.00 49.00 0:41 71.7 - 620 4100 22.0 160 22 I I I I RotJSlid I Md From I Md To I Course I Duration I Avg ROPI TF I RSS I Flow ISPP on, WOB I RPM Forq on, Svy Md I (RIS) (ft) (ft) (ft) (hr:min) (ft/h) (0) Setting (gaVmin) (psi) (1000 Ibf) K ftlbs (ft) R 12473.00 12496.00 23,00 0:48 28.7 - o /60% 615 4200 10,0 130 18 R 12496.00 12592.00 96.00 1:36 60.0 -- o / 40% 615 4150 15.0 160 22 12511.86 R 12592.00 12687,00 95.00 1:27 65,5 -- 71/20% 615 3800 20,0 160 22 12607.94 R 12687.00 12783.00 96.00 0:40 144.0 - 615 3800 20.0 160 22 12703.08 R 12783.00 12877.00 94.00 2:03 45.9 - 36/20% 615 3800 20.0 160 22 12798.78 I I Comments: I Rotating ROP: 66.3 Steering ROP: 0.0 Total ROP: 66.3 Total Time: 15,5 Time Steering: 0,0 Time Rotating: 15,5 Tot Distance: 1027.00 Dist Steering: 0,00 % Steer: 0,0 Dist Rotating: 1027,00 % Rot: 100,0 Depth Out: 13500,00 Inclination Out: 38.74 Azimuth Out: 126,97 Depth In: 12473,00 Inclination In: 40,33 Azimuth In: 120.76 I Directional Driller: Rinke Directional Driller: Levad Job#: Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF I Slide Sheet Well: NS-19 Borehole: NS19 UWUAPI#: 50-029-23122-00 BHA #: 5 I - Customer: BP EXPLORATION ALASKA inch at sperry-sun Well: NS19 inch at Area: BEAUFORT SEA,ALASKA inch at Lease: NORTHST AR 7" inch at DRilliNG SERVICES Rig: NABORS DRLG RIG 33E 4 1/2" inch at Mud Company: BAROID inch at Bit Record Job No.: AK-AM 22173/ AK-AM-2355584 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number In Out Whr % GRADE 1 1 MX-C1 6004905 16 1.031 201 330 129 0.6 215 50 4k 0 USE NEXT BHA 2 RR1 MX-C1 6004905 16 1.031 330 3426 3096 19.3 160 50 147k 35 3-2-WT-A-E-I-RG- TO 3 2 RSX238HF+GS 203404 12.25 1.090 3426 11778 8352 64.5 129 160 619k RSS 1-0-WT -C-X-I-CT - TO 4 3 RS161HGSW 203463 8.5 .742 11778 12473 695 28.4 24.5 160 273K RSS 1-1-WT-A-X-I-NO-PR 5 4 OS70FNPV 201573 8.5 .742 12473 13500 1027 15.5 66.3 160 149K RSS 1-0-WT-C-X-I-PJ-TO 6 5 STX-30CO 5018660 6.125 .5180 13500 14063 563 24.3 23.8 40 189K 75 4-8-WT -A-E-2/16-BT - TO -- - ~ - - -"'-i -- - - -=--o¡ Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS19 13.375" inch at 3405 ft Area: BEAUFORT SEA, ALASKA 9.625" inch at 11753 ft lease: NORTHST AR 7" inch at 13480 ft DRILLING SERVICES Rig: NABORS DRilLING RIG 33E 4.5" inch at 14063 ft Mud Company: BAROID DRilLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22173 Depth MW Vis PV YP Gels Fltr HTHP Cake Sol Oil Water Sd CEC pH Pm I Pf / Mf Chlorides Calcium Comments Date ft Ib/gal sec LB/100 10S/10M mll30 ml@deg F 32's % % % % rngelhg ppm ppm 1U/~9/U~ 1U5U 9.U 1~1 ~3 5~ ~5/35/31 13.U 2 3.6 U.U 95.~ ~.U 1.U 6.5 U.UU U.U5/U.3U 11UUU ti4U lJrllllng 1 U/3U/U~ ~9ti1 9.3 15 1~ 35 ~U/3U/33 ~.6 ~ I.U U.5 ~~.5 1.25 I.U 6.~ U.2U U.15/U.5U 11UUU ti40 tm III ng 1U/31/U2 342ti ~.3 4I:S 14 2ti 13/24 ~.1 3 I.U 1.U ~2.U U.5U I.U 6.4 0.1U U.U5/U.5U 115UU ti40 kun 133/6" 1 1/U1/U2 342ti 6.ti 55 13 16 ti/6 6.5 1 2.U U.U 96.U U.UU U.U ~.U U.2U U.1U/U.4U 115UU 14U I est tsut'S 11/U2IU2 45UU 6.6 52 12 2U ti/6/9 5.U 1 3.4 1.U ~5.ti U.1U 1.U 9.U U.1U U.U5/U.3U 1/5UU 6UU lJrll II ng · 11/U3/U2 IU55 ~.U 54 14 29 6/13/15 4.~ 1 4.ti 1.5 ~3.~ U.5U 4.5 6.3 U.UU U.UUIU.5U 115UU 16U lJrll II ng 11/U41U2 9U11 9.2 52 13 24 1/12115 ti.U 1 6.4 1.5 ~2.1 U.5U I.U 6.3 U.UU U.U5/U.tiU 1/5UU 19U lJ rill In 9 11/U5/U2 112tiU 1U.2 41 15 26 fl1411 I 3.6 6.ti 1 1U.U 2.5 61.5 U.5U ~.2 6.2 U.UU U.UU/U.tiU 115UU 19U I\J rll ling 11/Uti/U~ 11/16 1U.3 44 12 25 6/1511~ 4.5 10.U 1 1U.U 2.5 6/.5 U.2:» ~.5 8.6 U.1U U.U5/U.IU 1/5UU lUO I rlppmg 11/U1/U2 11116 1U.5 49 14 26 ~/15/2U 4.ti 10.U 1 11.5 2.5 6ti.U U.25 ~.5 6.U O.UU U.UU/U./U 16UUU ltiU ~un 9 5/6" 11/U6/U2 11116 1U.:» 49 14 2f 1U/15/~U 4.6 10.U 1 11.:» 2.5 66.U U.2:» 9.U 6.U U.UU U.UU/U./U 16UUU 16U I est tsut's 11/U9/U2 11116 1U.5 49 14 26 1U/15/~U 4.6 1U.U 1 11.5 2.5 tsti.U U.25 9.U 6.U O.UU U.UU/U./O 1tsUUU ItsU ~rlll (;ement 1111U/U2 1225U 12.9 54 26 31 13/441ti6 3.4 6.U 1 2U.9 2.5 lti.ti U.25 6.3 ts.3 U.1U U.UU/1.UU :»2UUU tstiU h.1rllllng 11/11/U2 12412 12.6 59 23 39 16/43/5U 3.6 6.ti 2 19.9 2.5 I I.ti U.25 I.U 6.4 U.15 U.1U/1.1U 52UUU 6tiU I ripping 11/121U2 132UU 12.6 51 24 34 15/5U/ti4 4.4 10.U 2 2U.5 3.U lti.5 U.25 6.U 6.4 0.U5 U.U:»11.20 51UUU 64U ~rllllng 11/13/U2 135UU 12.6 55 25 32 13/46/titi 4.5 10.U 2 1/.1 2.5 ff.U U.25 6.U 6.U U.UO U.UU/1.5U 5UUUU 62U I U 6 1/2'" nOle U3/~3/U3 135UU 9.3 49 11 25 13/15116 5.U 2 I.U U.5 92.5 U U.5 9.U U.3U U.1 U/1 .UO 2U5UU 12UO [\mll (;ement · U3/~41U3 13156 8.~ 43 6 26 1U/12113 4.U 2 ti.3 1.5 9~.2 U U.5 9.4 U.3U U.1U/1.1U 21UUU 9tsU rurlllmg U3/~5/U3 14Oti3 8.3 43 11 24 1U/12113 4.2 2 1.1 1.3 91.ti U U.5 9.U U.25 U.U5/1.20 21UUU 9tsU ~UUH for Imer - · - Generated 7/18/2003 12:17 PM Page 1 of 4 \\\NS19 current Version DO 3,1 RT ( do31 rt_376 ) 3,1 RT Service Pack 2.01 I b¡.; Schlumberger 0 ... ... NS19 Final Survey :1 Report Date: March 25. 2003 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 149.630° Field: Northstar Vertical Section Origin: N 0,000 ft, E 0.000 ft Structure I Slot: Northstar PF 1 NS19 TVD Reference Datum: KB Well: NS19 TVD Reference Elevation: 56.3 ft relative to MSL Borehole: NS 19 Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL I UWl/API#: 500292312200 Magnetic Declination: 26.158° Survey Name I Date: NS 19 current / March 5, 2003 Total Field Strength: 57547,172 nT II Torti AHDI DDIJERD ratio: 186.135°17963,19 ft/6,272 10.714 Magnetic Dip: 80,948° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: November 07,2002 Location Lat/Long: N 70 29 28.468, W 14841 35,905 Magnetic Declination Model: BGGM 2002 Location Grid NIE VfX: N 6031001,380 ftUS, E 659828.230 ftUS North Reference: True North I Grid Convergence Angle: +1,23170016° Total Corr Mag North .> True North: +26,158° Grid Scale Factor: 0,99992902 Local Coordinates Referenced To: Well Head ( Row Comments Measured Inclination Azimuth TVD Vertical NS EW Closure Closure Tool Face DLS Number Depth Section Azimuth ( ft ) (deg) (deg) ( ft ) (ft ) ( ft ) (ft ) ( ft ) (deg) (deg) (deg/100 ft) 1 Tie-In 0.00 1.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 52.60M 0,00 2 Gyro 50.00 0.65 52.60 50.00 -0.41 0.61 0.23 0.65 20.32 54.47M 1.59 I 3 Gyro 100.00 1.07 54.47 99.99 -0.49 1.05 0.83 1.34 38.29 68.85M 0.84 4 Gyro 150.00 2.21 68.85 149.97 -0.38 1.67 2.11 2.69 51.61 74.71M 2.41 5 Gyro 169.00 2.35 74.71 168.95 -0.22 1.91 2.83 3.41 56.01 68.98M 1.43 6 Gyro 200.00 2.03 68.98 199.93 0.04 2.27 3.95 4.56 60.12 79.21M 1.25 7 Gyro 250.00 2.09 79.21 249.90 0.49 2.76 5.67 6.31 64.07 80.40M '0.74 8 Gyro 290.00 1.88 80.40 289.87 0.97 3.01 7.04 7.65 66.88 86.37M 0.53 9 Gyro 380.00 2.40 86.37 379.81 2.34 3.37 10.37 10.91 72.00 88. IBM 0.63 10 Gyro 460.00 2.52 88.18 459.74 3.93 3.53 13.80 14.25 75.65 98.00M 0.18 I 11 Gyro 570.00 3.08 98.00 569.61 6.92 3.20 19.15 19.41 80.52 98.18M 0.67 12 Gyro 660.00 3.99 98.18 659.43 10.37 2.42 24.64 24.76 84.40 97.46M 1.01 13 Gyro 750.00 4.71 97.46 749.17 14.59 1.49 31.40 31.44 87.28 96.01M 0.80 I 14 Gyro 840.00 5.21 96.01 838.84 19.28 0.58 39.13 39.14 89.15 -43.84G 0.57 15 Gyro 930.00 5.45 93.63 928.45 24.10 -0.12 47.46 47.46 90.14 14.19G 0.36 16 Gyro 1021.00 6.21 95.40 1018.98 29.39 -0.85 56.67 56.68 90.86 -5.00G 0.86 I 17 Gyro 1116.00 8.16 94.20 1113.23 36.22 -1.83 68.51 68.54 91.53 O.OOG 2.06 18 Gyro 1183.00 8.78 94.22 1179.50 41.82 -2.55 78.36 78.40 91.87 166.47G 0.93 19 Gyro 1210.00 7.97 95.63 1206.21 44.09 -2.89 82.27 82.33 92.01 9.15G 3.09 20 Gyro 1304.00 8.33 96.03 1299.26 51.96 -4.24 95.53 95.63 92.54 70.87G 0.39 I 21 Gyro 1398.00 8.56 100.08 1392.24 60.54 -6.18 109.19 109.37 93.24 22..79G 0.68 22 Gyro 1465.00 9.22 101.80 1458.43 67.38 -8.15 119.35 119.63 93.91 33.04G 1.06 23 MWD DMAG 1493.01 10.01 104.71 1486.05 70.61 -9.23 123.91 124.25 94.26 15.04G 3,31 24 MWD DMAG 1587.65 12.78 108.05 1578.82 84.27 -14.56 141.82 142.56 95.86 -68.51G 3.01 I 25 MWD DMAG 1681.42 13.42 101.86 1670.15 99.34 -20.01 162.33 163.56 97,03 7.00G 1,64 26 MWD DMAG 1775.63 15.12 102.66 1761.45 115.07 -24.95 185.02 186.69 97,68 30,31G 1,82 27 MWD DMAG 1869.88 15.99 104.49 1852.25 132.62 -30.90 209.58 211,85 98.39 54,22G 1,06 28 MWD DMAG 1966.27 16.92 108.72 1944.69 152.58 -38.72 235,72 238.88 99.33 75.49G 1.57 29 MWD DMAG 2059.33 17.91 118.27 2033.50 175.04 -49.85 261 . 15 265,87 100.81 57,23G 3,25 30 MWD DMAG 2154.13 20.60 128.78 2123.02 203.09 -67.20 287,01 294,77 103,18 69,90G 4,62 31 MWD DMAG 2247,86 22.17 138,21 2210.32 235,84 -90,73 311,65 324,59 106,23 61,77G 4,03 32 MWD DMAG 2341,31 23.68 144,61 2296.40 271.83 -119.18 334,28 354,89 109.62 91,78G 3,12 33 MWD DMAG 2436.82 23.72 150.58 2383,87 310.15 -151,55 354.82 385,83 113.13 41.47G 2,51 34 MWD DMAG 2531.73 25.59 154.31 2470,13 349.67 -186.66 373,09 417.18 116.58 29,S4G 2,56 35 MWD DMAG 2627,47 27,59 156,76 2555,74 392,28 -225.66 390,80 451,28 120,00 48,60G 2,38 36 MWD DMAG 2719,67 28,18 158,16 2637,23 435,00 -265.49 407,33 486.21 123.10 -15.20G 0,96 37 MWD DMAG 2813.28 29.62 157.37 2719,18 479,78 -307,36 424.45 524,05 125,91 35,01 G 1,59 38 MWD DMAG 2907,38 31.04 159,28 2800.41 526,74 -351,52 441 ,98 564,73 128,50 -9,81G 1.8:2 39 MWD DMAG 3001,93 33.23 158.59 2880.47 576.37 -398.45 460,07 608,62 130,89 6,60G 2,3: 40 MWD DMAG 3096.32 35,33 159,01 2958.46 628,85 -448.01 479,29 656,07 133.07 -4.21 G 2,2-'1 Generated 7/18/2003 12:17 PM Page 2 of 4 \\\NS19 current Version DO 3.1RT (do31rt_376) 3,1RT Service Pack 2.01 41 MWD DMAG 3190,07 37,48 158,75 3033.90 683,77 -499,91 499.34 706,57 135,03 17,11G 2.30 42 MWD DMAG 3283,35 39,51 159,73 3106,91 741,01 -554,20 519,91 759,89 136,83 158.68G 2,27 43 MWD DMAG 3354,65 38.46 160,39 3162,33 785.12 -596,37 535,21 801,31 138.09 133,13G 1,58 44 MWD DMAG 3473.16 37.26 162,54 3255.90 856,30 -665,31 558.34 868,55 140,00 89,02G 1,50 45 MWD DMAG 3567.79 37,27 163,28 3331,21 912,07 -720,08 575,18 921.60 141,38 -2,99G 0,47 46 MWD DMAG 3660,71 38.34 163.19 3404,62 967,43 -774,61 591,61 974.69 142,63 -50,92G 1,15 47 MWD DMAG 3754,81 39.58 160,84 3477,80 1025,21 -830,88 609,89 1030.69 143.72 -63,63G 2,05 I 48 MWD DMAG 3848.72 40.19 158.98 3549,86 1084.46 -887.42 630,58 1088.65 144.60 49.06G 1.43 49 MWD DMAG 3942,86 40.72 159,91 3621,49 1144.65 -944.62 652,02 1147,80 145,38 26.90G 0.85 50 MWD DMAG 4036.84 41,28 160,34 3692.42 1205,27 -1002,60 672,98 1207,52 146,13 1.36G 0,67 I 51 MWD DMAG 4131,09 41,84 160,36 3762.94 1266,70 -1061.49 694.01 1268.23 146.82 -15.64G 0,59 52 MWD DMAG 4224,22 42.59 160,05 3831,92 1328.22 -1120.36 715,20 1329.18 147.45 78.93G 0,84 53 MWD DMAG 4318,90 42.86 161,96 3901,47 1391,19 -1181,10 736.10 1391.70 148.07 7.37G 1.40 54 MWD DMAG 4412,65 43.77 162.13 3969.69 1454.00 -1242.28 755.93 1454,20 148.68 65.02G 0,98 I 55 MWD DMAG 4506.27 44.22 163.49 4037.04 1517,31 -1304.40 775,14 1517,33 149,28 49.02G 1,12 56 MWD DMAG 4599,95 45.09 164.89 4103.68 1581.03 -1367.75 793.07 1581,05 149,89 8.92G 1,40 57 MWD DMAG 4693,76 46.10 165.11 4169.32 1645.65 -1432.48 810.42 1645.84 150.50 O.OOG 1,09 58 MWD DMAG 4787.05 46.36 165.11 4233.85 1710,57 -1497.59 827,73 1711,11 151.07 150.53G 0,28 I 59 MWD DMAG 4881.38 45.74 165.60 4299,32 1775.94 -1563.29 844,90 1777.00 151.61 123.97G 0.76 60 MWD DMAG 4976.56 44.98 167.22 4366.20 1840.78 -1629.11 860.82 1842.56 152.15 136.05G 1.45 61 MWD DMAG 5069.27 43.80 168.88 4432.45 1902.31 -1692.56 874.26 1905.01 152.68 133.48G 1.79 I 62 MWD DMAG 5163.16 43.52 169.31 4500.38 1963.42 -1756.20 886.52 1967.27 153.22 140.68G 0.43 63 MWD DMAG 5256.99 42.40 170.68 4569.04 2023.37 -1819.17 897.64 2028.58 153.74 165.54G 1.55 64 MWD DMAG 5351.82 41.30 171.11 4639.68 2082.33 -1881.64 907.65 2089.11 154.25 -146.70G 1.20 65 MWD DMAG 5445.49 40.56 170.36 4710.45 2139.58 -1942.21 917.53 2148.03 154.71 -117.25G 0.95 I 66 MWD DMAG 5538.70 40.48 170.12 4781.31 2196.26 -2001.89 927.79 2206.44 155.13 -55.66G 0.19 67 MWD DMAG 5632.17 40.79 169.43 4852.24 2253.41 -2061.79 938.60 2265.38 155.52 -77.03G 0.58 68 MWD DMAG 5725.79 41.01 168.03 4923.00 2311.33 -2121.90 950.58 2325.10 155.87 -25.53G 1.01 69 MWD DMAG 5819.58 41.44 167.72 4993.55 2370.03 -2182.33 963.56 2385.59 156.18 -71.34G 0.51 I 70 MWD DMAG 5914.48 41.69 166.63 5064.55 2430.06 -2243.72 977.54 2447.42 156.46 -9.89G 0.81 71 MWD DMAG 6008.43 41.92 166.57 5134.58 2489.96 -2304.65 992.05 2509.10 156.71 -46.48G 0.25 72 MWD DMAG 6103.89 42.15 166.21 5205.48 2551.17 -2366.77 1007.10 2572.13 156.95 -141.89G 0.35 I 73 MWD DMAG 6196.60 41.66 165.63 5274.48 2610.60 -2426.83 1022.16 2633.31 157.16 -158;42G 0.67 74 MWD DMAG 6291.19 41.26 165.3.9 5345.37 2670.84 -2487.46 1037.83 2695.29 157.35 -123.96G 0.46 75 MWD DMAG 6385.20 41.04 164.89 5416.16 2730.45 -2547.26 1053.69 2756.59 157.53 -139.47G 0.42 76 MWD DMAG 6479.36 40.60 164.31 5487.42 2789.91 -2606.60 1070.04 2817.68 157.68 -146.58G 0.62 I 77 MWD DMAG 6573.13 40.19 163.89 5558.83 2848.75 -2665.04 1086.68 2878.08 157.82 -87.46G 0.52 78 MWD DMAG 6667.61 40.22 162.97 5630.99 2907.97 -2723.50 1104.08 2938.78 157.93 -96.67G 0.63 79 MWD DMAG 6762.57 40.17 162.28 5703.53 2967.69 -2781.98 1122.38 2999.86 158.03 -103.71G 0.47 80 MWD DMAG 6855.33 40.01 161.23 5774.49 3026.09 -2838.72 1141.08 3059.47 158.10 -61 .25G 0.75 I 81 MWD DMAG 6949.00 40.12 160.92 5846.18 3085.18 -2895.75 1160.63 3119.68 158.16 32.61G 0.24 82 MWD DMAG 7043.00 40.63 161.42 5917.79 3144.84 -2953.38 1180.28 3180.49 158.22 5.10G 0.64 83 MWD DMAG 7134.62 40.85 161.45 5987.21 3203.37 -3010.06 1199.32 3240.19 158.28 15.05G 0.24 ( 84 MWD DMAG 7228.81 41.07 161.54 6058.34 3263.80 -3068.62 1218.92 3301.84 158.34 25.17G 0.24 85 MWD DMAG 7321.81 41.14 161,59 6128.41 3323.62 -3126.62 1238.25 3362.89 158.39 -34.71G 0,08 86 MWD DMAG 7415,55 41.35 161,37 6198.90 3384,10 -3185.22 1257,88 3424.60 158.45 -27,34G 0,27 87 MWD DMAG 7510.23 41.62 161.16 6269.82 3445.53 -3244.62 1278.03 3487.25 158.50 49.37G 0,32 88 MWD DMAG 7603.68 41,96 161.75 6339.50 3506.49 -3303.66 1297.83 3549.44 158.55 56,89G 0.56 89 MWD DMAG 7698.13 42.18 162.25 6409.61 3568.30 -3363.84 1317.39 3612.61 158.61 67.70G 0.42 90 MWD DMAG 7791.61 42.49 163.35 6478.72 3629.60 -3423.98 1336.00 3675.40 158,68 73.85G 0,86 I 91 MWD DMAG 7885.86 42.73 164,54 6548.08 3691.42 -3485.30 1353,65 3738,94 158,77 72,77G 0,89 92 MWD DMAG 7980,62 42,80 164.87 6617.65 3753.55 -3547,36 1370.62 3802.94 158,87 147,17G 0,25 93 MWD DMAG 8074.92 42.29 165.36 6687,13 3815.00 -3608.98 1387,00 3866.33 158,98 151,96G 0,64 94 MWD DMAG 8170,10 41.63 165,89 6757,90 3876.17 -3670,63 1402.80 3929,55 159,08 174,61G 0,79 95 MWD DMAG 8264.15 41,35 165.93 6828.35 3935.98 -3731,06 1417,97 3991.42 159,19 176,18G 0,30 96 MWD DMAG 8356.74 40.86 165.98 6898.12 3994.40 -3790.11 1432.74 4051,88 159,29 -155,46G 0,53 97 MWD DMAG 8451,07 40.35 165.62 6969,74 4053.36 -3849.63 1447,80 4112.88 159,39 -161.73G O,5S 98 MWD DMAG 8545.98 39,75 165,31 7042.39 4112,11 -3908.75 1463.13 4173,61 159,48 -158,29G O,ôì 99 MWD DMAG 8639,74 39,07 164,88 7114,83 4169.48 -3966,27 1478.44 4232,86 159,56 175,38G 0.7é Generated 7/18/2003 12:17 PM Page 3 of 4 \\\NS 19 current Version DO 3,1RT (do31rt_376) 3.1RT Service Pack 2.01 I 100 MWD DMAG 8733,61 38,53 164.95 7187,99 4226.22 -4023,06 1493.74 4291 .42 159,63 -173,74G 0.58 101 MWD DMAG 8827,51 38.08 164,87 7261,67 4282.37 -4079,26 1508,90 4349,38 159,70 153.46G 0.48 102 MWD DMAG 8921,50 37,58 165,28 7335.91 4337.93 -4134,96 1523.75 4406,78 159,77 -169.75G 0,60 I 103 MWD DMAG 9015,74 37,08 165,13 7410.84 4392,98 -4190.21 1538,34 4463,67 159,84 150,58G 0.54 104 MWD DMAG 9107,66 36.72 165.47 7484.35 4446.12 -4243,59 1552,34 4518,61 159,91 53,52G 0.45 105 MWD DMAG 9200,89 36,84 165,74 7559,02 4499.78 -4297,66 1566,22 4574,16 159.98 -149,11G 0,22 106 MWD DMAG 9294,74 36,75 165,65 7634,17 4553.80 -4352.13 1 580, 11 4630,10 160.05 -71,39G 0,11 107 MWD DMAG 9388.4 7 37.04 164,26 7709,13 4608.07 -4406.4 7 1594,72 4686,16 160,10 -71.83G 0,94 108 MWD DMAG 9482.66 37.27 163.13 7784.21 4663,25 -4461,07 1610.69 4742,94 160,15 -66,98G 0,76 109 MWD DMAG 9576.82 37,56 162.03 7858.99 4719.00 -4515.65 1627,82 4800.09 160,18 21,67G 0,77 11 ° MWD DMAG 9670,56 38,12 162,39 7933,02 4775.13 -4570.41 1645.39 4857,56 160,20 45.98G 0,64 I 111 MWD DMAG 9766.59 38,76 163.44 8008,24 4833.23 -4627,47 1662.92 4917 ,20 160,23 5,14G 0,95 112 MWD DMAG 9858,64 39.61 163,56 8079.59 4889,69 -4683.24 1679.44 4975.26 160.27 65,28G 0,93 113 MWD DMAG 9952.13 40.03 164.95 8151,39 4947.62 -4740.86 1695.68 5034,98 160.32 76,56G 1,05 I 114 MWD DMAG 10046.07 40.20 166.02 8223.24 5005.84 -4799.45 1710.85 5095.27 160.38 76,70G 0,76 115 MWD DMAG 10140.69 40,24 166,28 8295.49 5064.42 -4858.77 1725.48 5156.06 160.45 -153.42G 0.18 116 MWD DMAG 10235.55 40.06 166.14 8367.99 5123.04 -4918.18 1740.06 5216.92 160,52 -105.87G 0,21 117 MWD DMAG 10327.55 39.67 163.87 8438.61. 5179.89 -4975.13 1755.31 5275.70 160.57 -79.43G 1,64 I 118 MWD DMAG 10423.98 39.96 161.63 8512,69 5240.01 -5034.09 1773.62 5337.39 160.59 -46.47G 1.52 119 MWD DMAG 10518.50 40.50 160.76 8584.85 5299.82 -5091.88 1793.30 5398.44 160.60 -54.31G 0,82 120 MWD DMAG 10613.08 41.21 159.28 8656.39 5360.67 -5150.01 1814.44 5460.30 160.59 -57.76G 1.27 I 121 MWD DMAG 10706.75 41.72 158.08 8726.58 5421.92 -5207.79 1836.99 5522.29 160.57 -65.92G 1,01 122 MWD DMAG 10803.10 42.44 155.77 8798.09 5485.96 -5267.18 1862.31 5586.72 160,53 -53.34G 1.77 123 MWD DMAG 10898.83 43.87 153.06 8867.93 5551.20 -5326.22 1890.60 5651.81 160.46 -73.53G 2.45 124 MWD DMAG 10993.63 44.61 149.73 8935.86 5617.29 -5384.26 1922.26 5717.11 160.35 -66.58G 2.57 125 MWD DMAG 11089.78 45.89 145.83 9003.56 5685.51 -5441.99 1958.68 5783.74 160.21 -90.03G 3,17 I 126 MWD DMAG 11183.79 46.01 140.54 9068.95 5752.60 -5496.05 1999.14 5848.34 160.01 -105.18G '4.05 127 MWD DMAG 11279.60 45.24 136.10 9135.97 5819.72 -5547.18 2044.64 5912.00 159.77 -88.02G 3.41 128 MWD DMAG 11375.97 45.41 132.07 9203.74 5885.72 -5594.84 2093.85 5973.81 159.48 -120.61G 2.98 I 129 MWD DMAG 11468.66 44.31 129.33 9269.45 5947.55 -5637.47 2143.40 6031.19 159.18 -176.50G 2.40 130 MWD DMAG 11564.20 42.54 129.17 9338.84 6009.12 -5679.03 2194.25 6088.19 158.87 179.60G 1.86 131 MWD DMAG 11660.51 40.69 129.19 9410.84 6069.04 -5719.43 2243.83 6143.83 158.58 158_59G 1.92 I 132 MWD DMAG 11714.41 39.65 129.83 9452.02 6101.69 -5741.55 2270.66 6174.24 158.42 -159.84G 2.08 133 MWD DMAG 11845.13 37.93 128.80 9553.91 6178.49 -5793.44 2334.00 6245.92 158.06 -121.72G 1.41 134 MWD DMAG 11938.67 37.14 126.63 9628.09 6231.35 -5828.31 2379.07 6295.17 157.80 -93.74G 1.65 135 MWD DMAG 12035.53 37.08 124.72 9705.33 6284.75 -5862.39 2426.54 6344.73 157.51 -78.81G 1.19 I 136 MWD DMAG 12130.52 37.46 121.85 9780.93 6336.29 -5893.94 2474.62 6392.36 157.22 -22.84G 1.87 137 MWD DMAG 12227.28 38.30 121.28 9857.30 6388.71 -5925.04 2525.24 6440.72 156.92 -87.99G 0.94 138 MWD DMAG 12321.59 38.33 120.15 9931.30 6439.89 -5954.90 2575.51 6488.00 156.61 -36.18G 0.74 139 MWD DMAG 12392.29 38.96 119.42 9986.52 6478.19 -5976.83 2613.83 6523.39 156.38 56.35G 1.10 140 MWD DMAG 12418.39 39.15 119.87 10006.79 6492.43 -5984.97 2628.12 6536.58 156.29 26.09G 1.31 141 MWD DMAG 12511.86 40.33 120.76 10078.66 6544.53 -6015.13 2679.70 6585.03 155.99 29.12G 1.40 142 MWD DMAG 12607.94 41.66 121.87 10151.18 6600.02 -6047.90 2733.54 6636.96 155.68 166.34G 1.58 I 143 MWD DMAG 12703.08 40.20 122.42 10223.06 6655.31 -6081.05 2786.31 6689.00 155.38 147.80G 1.58 144 MWD DMAG 12798.78 38.54 124.11 10297.04 6709.69 -6114,33 2837.07 6740.48 155.11 172.26G 2.06 145 MWD DMAG 12894.01 37.73 124.29 10371.94 6762.80 -6147.39 2885.71 6791.00 154.85 -170.18G 0,86 146 MWD DMAG 12989.65 36.56 123.95 10448.18 6814.92 -6179.78 2933.52 6840.70 154.61 -171 . 18G 1,24 147 MWD DMAG 13085.11 35.88 123,77 10525.19 6865.71 -6211.21 2980.36 6889,24 154,37 138,09G 0,72 148 MWD DMAG 13180.26 35,75 123.97 10602.35 6915.86 -6242.24 3026.59 6937,28 154.13 51.47G 0,18 149 MWD DMAG 13275,83 35.82 124.12 10679.87 6966.26 -6273.53 3072.89 6985,69 1 53.90 3Q,93G 0,12 150 MWD DMAG 13371,09 37.80 126.04 10756.14 7018.18 -6306.34 3119,58 7035,75 153,68 31,87G 2.40 151 MWD DMAG 13419,91 38.74 126.97 10794.47 7045,99 -6324.33 3143,88 7062.66 153,57 28.12G 2,26 152 Interpolated Azimuth 13494.38 40,55 128.45 10851.81 7090.07 -6353.40 31 81 .46 7105.45 153.40 7,19G 2,74 153 Interpolated Azimuth 13521.01 43.44 128.98 10871.60 7106.71 -6364,55 3195,36 7121.64 153,34 14.66G 10,93 154 MWD DMAG 13553.87 48,25 130.66 10894.49 7128.89 -6379.65 3213.45 7143,26 153,27 5,59G 15.0S 155 MWD DMAG 13587.50 51,28 131,04 10916.21 7153,19 -6396.44 3232.87 7167,00 153,19 8.91G 9,0: 156 MWD DMAG 13615.81 55.27 131,80 10933,13 7174,74 -6411 .45 3249.88 7188,08 153.12 -4,74G 14,2E 157 MWD DMAG 13652,60 59,10 131.43 10953,06 7204,14 -6431.98 3272,99 7216,84 153.03 4,27G 10.4.1 158 MWD DMAG 13684,92 60,50 131,55 10969,32 7230,68 -6450.49 3293,91 7242.83 152.95 -5Q,88G 4.3.:: 159 MWD DMAG 13712.77 61,53 130,12 10982.82 7253,75 -6466.41 3312.35 7265,41 152.88 -149.40G 5,82 160 MWD DMAG 13807,97 61.16 129,87 11028.47 7332.43 -6520,11 3376,35 7342.45 152,62 147.57G 0.45 161 MWD DMAG 13903,35 60,94 130,03 11074.64 7411,01 -6573,70 3440,33 7419,53 152,37 131.58G 0,27 I 162 MWD DMAG 13998,70 60.57 130,51 11121.22 7489,51 -6627.4 7 3503.81 7496,67 152.14 O.OOG 0,59 163 Projection to TO 14063.00 60,57 130.51 11152.81 7542.42 -6663,85 3546,39 7548,76 151.98 O.OOG 0,00 I Survey Tvpe: Definitive Survey I Survey Error Model: SLB ISCWSA 3-D 95.00% Confidence 2.7955 sigma SurvevlnQ ProQ: MD From ( ft ) 0,00 1465.00 MD To ( ft) EOU FreQ Survey Tool Tvpe 1465.00 Act-Stns SLB_FREE GYRO 14063.00 Act-Stns SLB_MWD+DMAG I I I I I I I I Version DO 3.1RT (do31rt_376) 3,1RT Service Pack 2.01 \\\NS 19 current Generated 7/18/2003 12:17 PM Page 4 of 4 I I I I I I I I I I I I I I I I I I I NS19 - Spud 10/29/02 P,ognosed Tops Actual Depths Formation TVDss I TVD,kb I MD,kb TVDss I TVD,kb I MD,kb Top Permafrost 1.I·i·\.! 1::::1)(, 1210 1149 1206 1210 Base Permafrost 1 ..~ 1(11 j )'(1 1:,SÓ 1519 1576 1586 SV6 - top confining zone 2.l)ö8 ,"O-+.:;; 3 I q~~ 3008 3065 3230 Surface casing point 3,150 3207 3399 3161 3218 3426 SV5 - base confining zone ~~ ~ (1 S _~_~ ~~5 _~ ~~) .(~2 3286 3343 3582 SV4 .~ ~) "7 S .~ (13 ~ .1Z)6~ 3595 3652 3983 SV2 - top upper injection zone ~L98S .¡(i·IS -1:' ¡ .~l 4002 4059 4537 SVl - top major shale barrier ~L~8 ! ~f-f3 S :;038 4395 4452 5096 TMBK - top lower injection zone - Top Ugnu ¿L 783 C-f840 5573 4750 4807 5573 WSl - top Schrader Bluff - Base Ugnu 5.795 :;8:;;2 6921 5795 5852 6921 CM3 - Base lower injection zone (top Colville) 6.896 6953 8387 6881 6938 8410 THRZ - Top HRZ 8.838 8895 10960 8698 8755 10735 BHRZ - Base HRZ 8,908 8965 11050 8813 8870 10901 Top Kuparuk 8.9 ¡ 7 8974 ¡ 106! 8881 8938 10996 Kuparuk C 9,123 9180 I !326 9103 9160 11250 Top Miluveach () .347 9404 11617 9408 9465 11742 Intermediate casing point 9,387 9444 11669 9444 9501 11778 Intermediate logging point 9,387 9444 11669 Decided not to run Top Kingak 9,925 9982 12371 9895 9952 12343 Fault 15 - throw = 200' 10200 10257 12731. ! 10258 10315 12816 Top Sag River 10,822 !0879 \3542 10778 10835 13478 Geol target #1 10.822 10879 13542 10822 10879 Intermediate casing point 10,852 10909 13581 10800 10857 13500 Top Shublik - 90 10,888 10945 13628 10873 10929 13612 Top :Ivishak 10,978 1 !O35 13775 10959 11016 13782 Total Depth 1/.020 11077 ¡ 468LÎ 11096 11153 14063 Oil - Water contact 11 , 1 00 11157 11 096 11153 14063