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Home My WebLink About195-135UNDER EVALUATION:. P2-3Z(PTD #1951350) Suspected Surface C~g Leak Page 1 of 2 ~.~ i~-° Schwartz, Guy (DOA sponsored) ~~V"' .--~"i From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, June 17, 2009 4:24 PM To: Schwartz, Guy L (DOA) Cc: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: P2-32 (PTD #1951350) Suspected Surface Casing Leak Guy, The OA is in fact cemented to surface. I have attached the wellbore schematic for reference. The cross-hatched shading on our schematics is for us to note cement in our annuli. Just for an update, the well failed an MITOA with nitrogen and has been reclassified as Not Operable. The plan is to secure the well with a tubing tail plug. Let me know if you have any other questions on this well, Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~Y tl~~l .~. ~ ~idi.~:d From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, June 17, 2009 3:49 PM To: NSU, ADW Well Integrity Engineer Cc: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: P2-32 (PTD #1951350) Suspected Surface Casing Leak Anna, Could you forward an updated Schematic on this well also? Is the OA (7 5/8" X 10 3/") on this well Arctic packed or cemented?? The schematic I have shows some shading in the OA . Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Regg, James B (DOA) Sent: Wednesday, June 17, 2009 9:35 AM To: Schwartz, Guy L (DOA) Subject: FW: UNDER EVALUATION: P2-32 (PTD #1951350) Suspected Surface Casing Leak 6/17/2009 UNDER EVALUATION: P2-(PTD #1951350) Suspected Surface C~g Leak Page 2 of 2 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, June 11, 2009 8:11 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr North (Gas Plants/GPMA); GPB, GPMA OTL; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Warner, Ross L; GPB, Wells Opt Eng; Chmielowski, Jessie Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Quy, Tiffany; Hill, Richard D.; Wysocki, Mark F Subject: UNDER EVALUATION: P2-32 (PTD #1951350) Suspected Surface Casing Leak All, Well P2-32 (PTD #1951350) has been confirmed to have bubbling in the conductor. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The well may remain online while diagnostic work is completed. The plan forward for the well is as follows: 1. D: Bleed OAP and monitor bubbling frequency 2. WIE: Order UT to evaluate potential pipe loss 3. D: MITOA with nitrogen to 500 psi Please call with any questions or concerns. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 6/17/2009 TREE= 4-1/16" CM/ WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV - 51.9' BF. ELEV - 11.9' KOP = Max Angle = 91° 1075' @ 12380' Datum MD = 11822' Datum TV D = 8800' SS ~ P2-32 I20" CONDUCTOR, I~ 80, ID=? I7-5/8" X 5-1/2" BKR G2 ZXP LTP w / 11' TIEBACK SLV, ID = 4.920" 7-5/8" X 5-1/2" BKR FLEX LOCK LNR HGR w / XO BUSHING, ID = 4.800" 7-5/8" CSG, 29.7#, L-80 VAM TOP, ID = 6.875" 10-3/4" CSG, 45.5#, NT-80LHE BTC , ID = 9.953" 3975' I 3992' I 4131' 4325' Minimum ID = 2.813" @ 11341' 3-1 /2" HES X NIPPLE 7-5/8" CSG, 29.7", L-80 XO TO 13CR-80 5-1/2" SCAB LNR, 17#, 13CR-80 VAM TOP, .0232 bpf, ID = 4.892" 3-1/2" TBG, 9.2# , 13CR-80 VAM TOP, .0087 bpf, ID = 2.992" 4-1/2" SCAB LNR, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.913" 5-1/2" TBG STUB (CUT 01/28/08) 4-1/2" TBG, 12.6#, 13CR-80 NSCT, .0152 bpf, ID = 3.958" 7-5/8" MARKER JOINT 17-5/8" CSG, 29.7#, 13CR, ID = 6.875" I 11479' 11518' 11534' 11621' 11990' -~ 2191' 114-1/2" CAMCO SSSV NIP, ID = 3.812" ~ 3892' 4-112" X 3-1/2" XO, ID = 2.992" 4090' 7-5/8" HES CEMENTER 4102' 7-5/8" BKR EXTERNAL CSG PKR, ID = 6.900" 5 *5889 4778 47 KBG2-9 DOM INT 16 05/20/08 4 *7927 6174 47 KBG2-9 DMY INT 0 04/18/08 3 *9115 6996 46 KBG2-9 SO INT 22 05/20/08 2 *10177 7740 45 KBG2-9 DMY INT 0 04/18/08 1 *11273 8494 47 KBG2-9 DMY WT 0 04!18/08 'SttA13UVtSArtIY NUIt 11341' 13-112" HES X NIP, ID = 2.813" 11371' 3-1/2" BKR KGH-22 ANCHOR SEA L ASSY, ID = 2.95" 11372' 5-1/2" X 3-1/2" BKR S-3 PKR, ID = 2.780" 11405' 3-1 /2" HES X NIP, ID = 2.813" 11467' ~5-1/2" X 4-1/2" PORTED XO, ID = 3.958" 11479' 3-1/2" MULESHOE w / NO GO, ID = 2.992" 11532' 4-1/2" X 5-1/2" CASING OVERSHOT 11564' 7-5/8" X 4-1/2" TM/ HBBP-T PKR, ID = 3.915" 11588' 4-1/2" OTIS X NIP, ID = 3.813" 111 6U8' 114-1/2" OTIS XN NIP, ID = 3.725" 11621' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 12070' 7-5/8" X 4-1/2" TM/ SS HYD LTP/ HGR, ID = 3.907" 4-1/2" PORTEDJT PERFORATION SUMMARY REF LOG: SWS CDR/SLIM-1 09/29/95 ANGLE AT TOP PERF: 89° @ 12313' Note: Refer to Reduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD 12313 - 13368 O 10/04/95 12237' I~4-1/2" TNV MLAS JT (12237' - 1 ~~ .~ .~ ~~ ~~ ~~~~ ~~~ .~ .~ .~ ~~ 4-1/2" LNR, 12.6# , 13CR NSCT, .0152 bpf, ID = 3.958" 13390' ~ ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/95 POOL 7 ORIGINAL COMPLETION 04102/08 N2ES RWO 05/20/08 BSE/PJC GLV C/O 10/26/08 ?/ PJC DRLG DRAFT CORRECTIONS 12/15/08 MNN/PJC FINAL DRAFT CORRECTIONS PRUDHOE BAY UNfT WELL: P2-32 PERMff No: 1951350 API No: 50-029-22593-00 SEC 14, T12N, R14E, 218' FNL & 1371' FWL BP Exploration (Alaska) 05/30/08 1i~111~~1ifG1-~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall _Inh IF N0.4727 1,t 20~p Company: State of Alaska ~~~~~~~ ~~ IV 1 ~ 0 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 _ Anchorage, AK 99501 2 S ~a~~ ti J 1 .... f\a. wF:..w n... Z-03 11975773 SFRT i ~ ~ 05/20/08 1 P2-32 12066522 MEM TEM SURVEY - 05/19/08 1 1 18-13B 12021159 MEM PROD PROFILE - ~ 1 05/18/08 1 1 Z-03 11975773 USIT - L(~ 05/19/08 1 1 W-29 11999017 INJECTION PROFILE (,( 05/26/08 1 1 15-39A 11999018 PRODUCTION PROFILE Q(p - c, 05/28/08 1 1 07-30A 11963095 SCMT - ~ 05/27/08 1 1 14-096 11982432 PROD PROFILE W/FSI - Q. v 05/27/08 1 1 A-34A 12057614 USIT -~0S /(~G(~~- 05/26/08 1 1 GNI-04 11824353 OH LDWG EDIT (DSI) ~ _ ( L 11/07/07 1 1 , ......vv r+vw•v ••,-cv~ac nc~Glr r v 1 JIVIYIIYl7 NIVY 1'1C1 VISIVIIV~.7 VIVC I.VF'T CN\.f1 I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ I ' ;1i ~t Alaska Data & Consulting Services 2525 Gambell Street, Suite 40: Anchorage, AK 99503-2 38 ATTN: Beth /',- Received by: -l/..~~'/ ' • STATE OF ALASKA So38~~ A~ OIL AND GAS CONSERVATION COM~ION MAY 2 2 2008 REPORT OF SUNDRY WELL OPERATION~iaska ®il ~ Gas Cons. Commission 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing igi Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ® Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Dritl Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-135 3. Address: ^ Service ^ Stratigraphic 6. API Number: , P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22593-00-00 7. KB Elevation (ft): 51 9, 9. Well Name and Number: PBU P2-32 - 8. Property Designation: 10. Field !Pool(s): ADL 365548 - Prudhoe Bay Field /Point McIntyre Pool 11. Present well condition summary Total depth: measured 13396 ' feet true vertical 9001= feet Plugs (measured) None Effective depth: measured 13396 feet Junk (measured) None true vertical 9001 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 4284' 10-3/4" 4325' 3699' 5210 2480 Intermediate 12174' 7-5/8" 12212' 8976' 8180 5120 Production Liner 1320' 4-1/2" 12070' - 13390' 8955' - 9001' 8430 7500 Liner 7558' 5-1/2" 3975' - 11533' 3447' - 8671' 7740 6280 ~~I~~~ ,~U~1 ~~ ~ 208 Perforation Depth MD (ft): Slotted Liner: 12312' - 13368' Perforation Depth TVD (ft): 8979' - 9000' 4-1/2", 12.6# x 3-112", 9.3#; 13Cr80; 11479'; Tubing Size (size, grade, and measured depth): R a-v2° 126# R. 13C:r8Q ' Packers and SSSV (type and measured depth): 3-1/2" x 5-1/2" Baker'SABL-3' packer; 11372 ; 7-5l8" x 4-1/2" TIW 'HBBP-T packer 11564' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut & pull tbg f/ 11527'. Cut & pull 7-518" casing f/ 4127'. Run 7-5/8" tieback, cement w/ 198.5 Bbls Class'G' (1114 cu ft! 953 sx). Failed pressure test. RDMO !Suspend. Move back on. Run 5-1/2" (17# / 13Cr80) Scab liner and cement w/ 150 bbls (842 cu ft / 720 sx). Run new Chrome completion (Surface to 11479'). 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 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 Mehrdad Nadem, 564-5941 308-071 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: ~ Signature Phone 564-4628 Date ~ erne Hubble 564-4628 Form 10-404 Revised 04/2006 i ~ Submit Original Only (~ i d.J~1~IM,~i~ ~~... 5~~ ,~uN~200~ ~~~ ~~ • • P2-32 Well History for Rig Workover Date Summary 12/27/2007 WELL S/I ON ARRIVAL. MIRU DC#2 TO TAG IBP, AWAIT TRI-PLEX TO ARRIVE. 12/28/2007 RAN 2.5" LIB SD @ 11483' SLM, HAD 4 SMALL NOTCHES ON ONE SIDE APPEARS TO BE ON THE LOW SIDE. RAN 2.45" CENT. 5' X 2.25" DD BAILER TO 11483' SLM, HARD BTM,-1/2 GALLON OF SAND & SCALE RECOVERED. WELL LEFT S/I OPER NOTIFIED. 1/9/2008 WELL SHUT IN ON ARRIVAL. DRIFTED TBG W/ 3.75" CENT & 1.5" SAMPLE BAILER. SD @ 10450' SLM, UNABLE TO WORK PAST (NO SAMPLE). 1/10/2008 T/I/0=690/450/0=SI. Temp=Sl. Monitor WHPs (eval SC leak depth). Slick line continues to work on well at this time. 1/10/2008 DRIFTED TBG W/ 3.00" x 4' D.D. BAILER. SD @ 11471' SLM, UNABLE TO WORK PAST. DRIFTED TBG W/ 10' x 3.50" PUMP BAILER FOUR TIMES. SD @ 11450' SLM .WORKED TO 11458' SLM. RECOVERED ABOUT 8.5 GALLONS ON SCALE /SAND. LEFT WELL SHUT IN. 1/11/2008 T/I/0= 700/830/0. Temp= SI. SC leak dapth (SC repair) Pending CTU mill. OA FL near surface ?. Installed secondary containment around conductor. Placed heater in cellar to thaw out cellar boards for easy access to cellar. 1/16/2008 T/I/O = 700/860/0. Temp = SI. SC leak depth (SC repair) Pending CTU mill. Plugged cement port @ the 6 o'clock position, on the conductor. OA FL @ 24'. Strapped SCxConductor @ 20". Pressured up OA w/N2 to 50 psi in 10 psi increments. SI N2 monitored for 10 min, OAP lost 50 psi in 10 min. No N2 or bubbling detected Note: Could not preform SC leak depth due to no heater. Final WHP's=700/860/0. 1/19/2008 T/IA/OA= 800/800/0 Temp= cold PPPOT-T (PASS) PPPOT-IC (PASS), (Pre RWO). PPPOT-T RU HP bleed tool onto SBMS monitor port, 100 psi to 0 psi. RU 2 HP bleed tools on THA 800 psi would not bleed down, checked LDS all were out of adjustment, cycle and torqued LDS, void bleed to 0 psi. Flushed void until clean returns achieved. Pressured void to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, all "ET style" LDS cycled all moved with no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void, 1100 psi to 0 psi. Flushed IC void until clean returns achieved. Pressured void to 3500 psi for 30 minute test, 3500/ 15 minutes, 3450/ 30 minutes. Bleed void to 0 psi, RD test equipment, cycle and torqued all LDS "ET style" all moved with no problems. ~~~ 1/22/2008 Perform weekly BOP test. MU and RIH with 2.875" OD PDM with 3.75" OD 5-blade convex junk mill. Started to see possible scale at 10560' CTMD. Milled scale down to 10866' CTMD. Still milling with slight motor work. 1/23/2008 Ran mill to 11570' CTMD, pumping FloPro sweeps. Did not tag, no significant motor work seen. POOH. Freeze protect well to 5200' with 60/40 methanol. Job Complete. 1/27/2008 WELL S/I ON ARRIVAL. TAG TOP OF IBP @ 11558' SLM W/ 3.70" CENT. DUMPED 100# OF SLUGGETS ON IBP. TAG TOP OF SLUGGETS @ 11539' SLM W/ 3.70: CENT. WELL LEFT S/I OPER NOTIFIED. 1/27/2008 WELL SHUT-IN ON ARRIVAL. RAN IN HOLE WITH 3.65 " JETCUTTER TO CUT 4.5" TUBING. 1/28/2008 Pumped 30 bbls of neat methanol into the TBG. 1/28/2008 CUT TBG AT 11,534' WITH JET CUTTER. TOOLS STUCK AT 56' WHILE POOH. 1/29/2008 Pumped 725 bbls of 1 % KCL and 91 bbls of 110° diesel into the TBG while taking IA returns to the flowline. U-Tubed Tx IA. Freeze protected the flowline with 7 bbls of neat and 7 bbls of diesel. CMIT-Tx IA PASSED to 1500 psi. Pumpec 2.6 bbls of diesel to achieve test pressure. TBG lost 10 psi & IA lost 30 psi / 1st 15 min. TBG lost 10 psi & IA held / 2nc 15 min. Bled to final WHP= 0/0/0. Casing annulus valves are open to gauges. 1/29/2008 CIRC OUT COMPLETED BY LITTLE RED WHILE STUCK IN HOLE WITH E-LINE. INSPECTED LINE AFTER CLOSING BOP'S. FOUND SLIGHT KINK AND RE-FORMED BY HAND (KINK FOUND IS NOT SUSPECTED TO BE THE PROBLEM THAT HUNG LINEUP IN GREASE HEAD AS KINK DEPTH WAS WELL ABOVE HEAD WHEN HUNG UP). ICE SUSPECTED TO BE THE CAUSE OF STUCK LINE. PUMPED TANNER THROUGH SYSTEM CLEANED LINE AND RIGGED BACKUP. PULLED UP AND SAW -900 LBS PULL AND LINE AND TQ.OLS PULLED FREE. COOH. WELL LEFT SHUT-IN. FINAL TBG/IA/OA=O/0/0. JOB COMPLETE. Page 1 • • P2-32 Well History for Rig Workover Date Summary 1/31/2008 T/I/0=250/250/0. Temp=Sl. Bleed WHPs to 0 psi (RWO prep). TBGP & IA FL at surface. Bled TBGP to a bleed trailer from 250 psi to 0 psi in 2.5 hrs (fluid & gas mix, 3 bbls of returns). IAP tracked TBGP during bleed. SI monitor for 1 hr, TBGP &IAP increased 40 psi fluid to surface. Final WHPs 40/40/0. NOTE: Well house, flow line and A/L have been removed, part of scaffolding has been removed also. Katch liner is installed around conductor will need to retrieve it when cellar has been cleaned out. 1/31/2008 T/I/0= 350/350/0. Temp= SI. Bleed WHP's to 0 psi (RWO prep). A/L line is disconnected. IA FL C~3 surface. Unable to bleed due to no available slop trailers. 2/1/2008 T/I/O = 320/300/0. Temp SI. WHP's to 0 psi (pre RWO prep). TBG FL @ surface. IA FL near surface. Bled TBG from 320 psi to 0 psi in 1 hour. During TBG bleed the IA deceased 300 psi from 300 psi to 0 psi. OAP unchanged.__ Monitored for 30 min. TBGP increased 150 psi. IAP increased 150 psi. Bled the TBG from 300 psi to 0 psi to a bleed trailer in 40 min (All liquid 3 bbls). IA decreased 300 psi during the TBG bleed. Monitored for 1 hour. TBGP &IAP increased 300 psi. OA unchanged. Repeated several time the result remained the same. IA casing valve closed for FB rig up, Flagged, tagged & noted on permit. Final WHP's = 300/300/0. 2/2/2008 T/I/0=200/200/0. Temp=Sl. Bleed WHP's to 0 psi (RWO prep). Bled IAP from 200 psi to 0 psi in 10 mins (46 gals). TP tracked IAP. Monitor 30 mins. TP &IAP increased 200 psi during monitor. Final T/I/0=200/200/0. 2/2/2008 T/I/O = 340/340/0 -Circ out well (Pre RWO) -Pumped 744 bbls 1 % KCI down TBG taking returns up IA down P2-31 flowline. Pumped 91 bbls diesel down TBG, U-tube to freeze protect TxIA. Pumped 2 bbls meth and 2 bbls diesel to freeze protect hardline. Near end of kcl surface casing had a leak at conductor pipe into containment in cellar. Slowed rate and leak stopped notified DSO and co rep. Bled pressure down to 0/0/0 psi. Rigged down and pressure increased to 250/300 psi. Bled down to 0/0 psi a second time and went to another job on pad. Checked again 20 minutes later and pressure increased again to 250/300/0. Well SI at departure at wing valve all other casing valves open to gauges. FWHP's=250/300/0 2/3/2008 T/I/O = 2100/400/0. Temp = SI. Assist FB w/ circ (SC Leak). LRS currently pumping on well. Flutes are 3'1"deep. Cellar is 4' deep with a spray in liner installed. Monitored cellar and flutes for during circ. No leaks detected. LRS bleed back pressures to 0 psi. RDMO. Final WHP's = 0/0/0. 2/3/2008 T/I/O = 350/340Nac. SI. Monitor for fluid in cellar (SC leak). LRS to circ-out fluid in well w/ 580 bbls 9.8 Ib brine,pumping down tubing and taking returns out IA w/hardline to well P2-31 flowline. Vac truck on location standing- by w/vac hose and stinger in cellar. Change out w/day shift @ 0700 hrs. 2/3/2008 T/I/0= 350/300Nac Temp= SI Circ-Out (Pre RWO). Pumped a 5 bbl neat methanol spear followed by 590 bbls 9.8 brine and capped with 20 bbls diesel into the tubing through the cut up the IA to the flow line of P2-31, U-Tube the diesel freeze protect into place. Bled all WHP's to 0 psi. Note: Annulus valves left open to the gauges at the time of departure. 2/4/2008 T= 0. Set 4" Ciw "H" BPV pre-rig. 1 -2' extension used, tag at 102". Page 2 BP EXPLORATION Operations Summary Report Page 1 of 13 Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To I Hours Task Code ~ NPT Phase Description of Operations 2/6/2008 05:00 - 09:30 4.50 MOB N WAIT PRE Released rig from operations on Y-07A C~ 05:00. -Move sub off well and move to edge of Y-Pad. -WOW to lay down derrick -Too cold to lav down derrick or for Peak trucks to operate: -42 09:30 - 00:00 14.50 MOB N WAIT PRE Continue to wait on weather. Ambient temp still below -35 deg. -Close cellar and repair drip pan under rig floor. -Remove Top Drive wash pipe packing and repair top seal. -Remove mats around well and clean up well area. -Weld #1 suction in pit #3. -Bridle up 2/7/2008 00:00 - 05:30 5.50 MOB N WAIT PRE Continue to wait on weather -too cold to lower derrick or for Peak trucks to operate. -Continue to clean rig and perform preventative maintenance. 05:30 - 00:00 18.50 MOB P PRE Temperatures around the field warmer than -35 deg. -Begin preparing for rig move, lay down derrick, mobilize Peak trucks. -Move camps, pits, and shops over to PM2 -Begin moving substructure to PM2 2/8/2008 00:00 - 14:30 14.50 MOB P PRE Continue moving sub from Y Pad to P2-32. 14:30 - 16:30 2.00 RIGU P PRE PJSM. Raise derrick and pin. Raise cattle shute. Install pins in torque rail -pull 50k on weight indicator. 16:30 - 20:30 4.00 RIGU P PRE Line up sub on well P2-32. Pin cellar side doors. Lay herculite. Stage new tree and adapter in cellar. Spot sub over well and close cellar. 20:30 - 00:00 3.50 RIGU N WAIT PRE Waiting on trucks to spot pits, camp, and shops due to rig 27e's move. -Install electic and hydraulic service loops, rig up floor, bridle down, berm around sub. 2/9/2008 00:00 - 09:00 9.00 RIGU N WAIT PRE Continue to wait for trucks to spot pits, camp, and shops. 09:00 - 13:30 I 4.501 RIGU I P 13:30 - 17:30 4.00 RIGU P 17:30 - 18:00 0.50 RIGU P 18:00 - 19:00 1.00 WHSUR P 19:00 - 23:00 I 4.001 WHSUR I P 23:00 - 00:00 ~ 1.00 ~ WHSUR ~ P 2/10/2008 100:00 - 01:30 I 1.501 WHSUR I P -Rig up floor, install secondary annulus valve, assemble new tree and adapter flange and hang off in corner of cellar. Remove jeep from pit complex. Chink-up cellar and rig floor. Change oil in top drive. PRE Spot pits in place. -Lay herculite, lay 3x12's, hook up lines, plug in electric lines, berm pits and cuttings tank area. PRE Spot camp, shop, and cuttings tank. Plug in units. PRE Pre spud meeting w/all personnel. DECOMP Rig up lubricator and test to 500 psi, Pull BPV with DSM. 'Ri Acce ted ~ 18:00 on 2/9/08 for P2-32 RWO. DECOMP Rig up circulation lines on tree and circ out freeze protect from well through choke to cuttings tank. -Reverse circ C~ 2bpm, 1100 psi to remove 35 bbls diesel from tbg -circ 3 bpm, 1350 psi to remove 56 bbls diesel from annulus -circ well surface to surface w/clean 9.8 ppg brine l~ 6 bpm, 1500 psi. Rig down and blow down circulation lines. DECOMP Attempt to dry rod TWC -hanging up on SSV. -Pump open SSV and FMC installed TWC w/dry rod. -Fill tree with water and prepare to test. DECOMP Test TWC from above to 3500 psi for 10 minutes and below to Printed: 4/21/2008 4:36:40 PM • • BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task 2/10/2008 100:00 - 01:30 01:30 - 04:00 04:00 - 05:30 Code NPT Phase I Description of Operations 1.50 WHSUR P 2.50 WHSUR P 1.50 WHSUR P 05:30 - 08:30 3.00 BOPSU~P 08:30 - 16:30 8.00 BOPSU P 16:30 - 23:00 ~ 6.50 ~ BOPSUf~ N 23:00 - 00:00 1.00 BOPSU N 2/11/2008 00:00 - 05:00 5.00 BOPSU N 05:00 - 10:00 I 5.001 BOPSUFi P 10:00 - 17:30 7.50 ~ BOPSU F{ N 17:30 - 22:00 ~ 4.50 ~ BOPSUF{N 22:00 - 22:30 I 0.501 BOPSUFI P DECOMP 1000 si for 30 minutes - ood tests. " Test witnessed by BP WSL Mark Staudinger and NTP Jon Castle. DECOMP Nipple down tree and adapter flange. Remove and plug hydraulic valve lines. DECOMP Inspect NSCT threads on tubing hanger. Threads were packed off with scale -cleaned threads and able to screw on XO. DECOMP Nipple up BOPE and install mouse hole. DECOMP PJSM. Make up 4-1/2" test joint w/hanger neck XO. -Test BOPE to 250 psi low / 3500 psi high. -Unable to get good tests on choke manifold -suspect ice or debri on bottom of seats -Install test joint and test stack -good test -Rig down 4-1/2" test joint -Make up 4" test joint -Test BOP Rams to 250 low / 3500 high, Hydril to 2500 psi high - good test -Lower Hydraulic IBOP failed. -Lay down 4" test joint and blow down top drive -Discover ice plug in kelly hose 'Test witness waived by AOGCC Rep, Bob Noble, and test witnessed by BPWSL Dick Maskell and NTP Charlie Henley RREP DECOMP Remove kelly hose from top drive and attempt to thaw with no success. -Remove kelly hose from standpipe and lay down on skate. -Thaw ice plug in kelly hose -about 1 foot long. -Install kelly hose to standpipe and topdrive RREP DECOMP Remove lower IBOP valve from topdrive RREP DECOMP Continue to remove, disassemble, reassemble, and install lower IBOP valve. -Reconnect and function test -good DECOMP Continue BOP test. -Install 4" test joint and make up to top drive. -Test IBOP/BOPE -good test. -Break out and lay down test jt, blow down top drive. -Line up and test standpipe/kelly hose connections to 3500 psi - ok -Test choke manifold valves -not holding (valve #2 failed) -Witness of test waived by AOGCC Rep, Bob Noble, and test witnessed by BPWSL Dick Maskell and NTP Charlie Henley RREP DECOMP PJSM. Remove and replace choke manifold valve #2. -Fill choke and look for leaks - no visible leaks -Test choke valve #2 to 250 low / 3500 psi high -good test DPRB DECOMP Rig up to pull TWC. -Install lubricator extension, rig up DSM, test to 500 psi -good. -Attem t to ull TWC - no gp. Suspect debris on TW -Lay down DSM and pick up a jt of DP - circ on top of plug -Attempt to pull plug w/DSM - no go -Add centralizers and attempt to pull - no go -Circulate down on top of plug again w/mule shoe. DECOMP Rig up w/ DSM again and pull TWC on 2nd run - no pressure un erneat -Rig down DSM Printed: 4/21/2008 4:36:40 PM • • BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task ', Code' NPT Phase ~ Description of Operations 2/11/2008 22:30 - 00:00 1.50 PULL P 2/12/2008 00:00 - 15:00 15.00 PULL P 15:00 - 16:00 1.001 BOPSUF#P 16:00 - 18:00 I 2.001 CLEAN I P 18:00 - 00:00 I 6.001 CLEAN I P DECOMP Make up landing joint and make up to tbg hanger. -Back out lock down screws -Pick up 4-1/2" tbg equipment -Pick up and unseat hanger w/ 125k up -Pull hanger to rig floor w/ 145k up DECOMP PJSM. Rig up 4-1/2" completion equipment. -Pull 4-1/2" 12.6# 13Cr-80 NSCT com letion -Spool control line and collect SS bands to SSSV ~ 2102' - entire control line recovered and 39 of 55 bands. Recovered 279 joints and cut joint at 19.86', 7 GLM's and SSSV. Clean cut with slight flare to 4-3/4" OD. Rig down handling equipment. Clear and clean floor. DECOMP MU 4" test 'oint install test plug. Test lower rams to 250 psi low, 3500 psi high as per AOGCC. Test witness waived by Bob Noble with AOGCC. Test witnessed by WSL Dick Maskell and Toolpusher Charlie Henley. Pull test plug, run in wear ring. DECOMP PJSM. Pick up and RIH with dressoff/scraper assembly to 327'. Change out handling equipment. DECOMP RIH with dressoff/scra er s mbl picking up 4" drillpipe to 6957'. Fill every 3000'. 2/13/2008 00:00 - 03:00 3.00 CLEAN P DECOMP PJSM. RIH with dressoff/scraper assembly picking up 4" drill pipe to 9800'. 03:00 - 04:00 1.00 CLEAN N SFAL DECOMP Hydraulic failure on Iron Roughneck. Replace line. 04:00 - 04:30 0.50 CLEAN P DECOMP PJSM. Service top drive. 04:30 - 06:00 1.50 CLEAN P DECOMP PJSM. Cut and slip 83' of drilling line. Grease and inspect draworks, brakes and tube Elmago Splines. 06:00 - 08:30 2.50 CLEAN N SFAL DECOMP Work on Iron Roughneck. 08:30 - 10:00 1.50 CLEAN P DECOMP Continue to PU 4" drill pipe to 10630'. 10:00 - 12:00 2.00 CLEAN N SFAL DECOMP Make more repairs to hydraulic line on Iron Roughneck. 12:00 - 13:30 1.50 CLEAN P DECOMP PU 4" DP to 11443'. Install blower hose. Fill pipe. Establish circulation at 170 gpm with 940 psi. Up weight 190k, down 132k, RT 157k. Torque 7k off bottom at 80 rpm. ~a4 stub at 115 7'. 13:30 - 16:30 3.00 CLEAN P DECOMP Rotate down over top of stub while circulating. Dress top of 4-1/2" stub until able to work over with no problems. 16:30 - 19:00 2.50 CLEAN P DECOMP Circulate 2 hi-vis sweeps surface to surface at 470 gpm with 3760 psi. Rotate at 40 rpm and reciprocate pipe. Shut down and blow down top drive. 19:00 - 22:30 3.50 CLEAN P DECOMP POOH to 327'. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH with BHA and lay down. Empty boot baskets and recover 4 more SS bands. Clear floor. 2/14/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Clear and clean floor. Lay tools down beaver slide. 01:00 - 02:00 1.00 EVAL P DECOMP PJSM. Spot and rig up E-line unit. 02:00 - 04:00 2.00 EVAL P DECOMP RIH with USIT. Lo from 4600' u to surface in cement mode. 04:00 - 05:00 1.00 EVAL N HMAN DECOMP Had to re-calibrate tools for different string length. 05:00 - 06:00 1.00 EVAL P DECOMP Complete USIT log to surface from 4600'. TOC in 10-3/4" x 7-5/8" annulus at 4315'. 06:00 - 07:00 1.00 EVAL P DECOMP PJSM. Rig down a-line unit. Clear and clean floor. 07:00 - 11:30 4.50 DHB P DECOMP PJSM. PU/MU HES, RBP and RIH to 4490'. Up weight 87k, down 81 k. Set RBP at 4485' top, 4492' bottom. 11:30 - 12:30 1.00 DHB P DECOMP PJSM. Test casing and RBP to 1000 si for 30 minutes - OK. 12:30 - 18:30 6.00 DHB P DECOMP u 1 stand drill pipe. Dump 1800# sand down drill pipe. Let fall 1 hour. Tag top of sand at 4444'. POOH. Lay down running Printed: 4/21/2008 4:36:40 PM • BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES I~ ~ ~ Hours Task Code NPT Phase Description of Operations Date ~ From - To 2/14/2008 12:30 - 18:30 6.00 DHB P DECOMP tool. Clear floor. 18:30 - 19:00 0.50 BOPSU P DECOMP Pull wear ring. Run in test plug. 19:00 - 20:30 1.50 BOPSU P DECOMP Chan a out to rams to 7-5/8". 20:30 - 21:00 0.50 BOPSU P DECOMP Test 7-5/8" rams to 250 psi low, 3500 psi high as per AOGCC. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. 21:00 - 21:30 0.50 BOPSU P DECOMP Pull test plug and run in wear ring. 21:30 - 22:00 0.50 CASE P DECOMP Make up 7-5/8" cutter assembly. 22:00 - 00:00 2.00 CASE P DECOMP RIH to 4122'. Rig up circulating lines to cuttings tank. 2/15/2008 00:00 - 02:00 2.00 CASE P DECOMP PJSM. Make up drill pipe single. Run in and tag collar at 4147'. Pick u to 4127'. Break circulation at 210 gpm with 975 psi. Up weight 80k, down 75k. Free torque 2500 ft/Ibs at 100 rpm. Begin cutting operations. Torque increased to 3500 ft/Ibs, lost circulation and pump pressure loss indicating cut through casing. Recovered returns. Shut down. Fluid U-tubing up annulus to cuttings box. Close Hydril and circulate out crude/diesel to cuttings box with warm 9.8 ppg brine and Safe-Surf at 210 gpm with 850 psi. Shut down, blow down lines and monitor well - OK. 02:00 - 03:00 1.00 DHB P DECOMP Break out top drive. Fluid out of balance. Circulate surface to surface at 350 gpm with 2400 psi. Shut down lay down drill pipe single. Blow down, remove blower hose. 03:00 - 04:30 1.50 CASE P DECOMP PJSM. POOH to cutter assembly. Over displacement of 9 bbls to hole during trip. 04:30 - 05:30 1.00 CASE P DECOMP Break and lay down 7-5/8" casing cutter BHA. 05:30 - 06:00 0.50 CASE P DECOMP Clear and clean rig floor. Pull wear ring. 06:00 - 08:00 2.00 CASE P DECOMP PJSM. PU handling equipment. MU spear and engage hanger. Back out lock down screws, (BOLDS). Pull 7-5/8" packoff and mandrel hanger to rig floor. Weight up 140k to unseat, 125k string weight. 08:00 - 08:30 0.50 CASE P DECOMP Break out and lay down spear. 08:30 - 15:30 7.00 CASE P DECOMP Rig up 7-5/8" handling equipment. Pull and lay down 7-5/8" casing from 4127,'. Recover 1 cut joint at 2 our u ators. Clear and clean floor. Install wear ring. Losses at 6 bph while Pullin casin . 15:30 - 18:30 3.00 CASE P DECOMP PJSM. Pick up and make up 7-5/8" dressoff/10-3/4" scraper assembly to 330'. 18:30 - 22:30 4.00 CASE P DECOMP RIH to 4067'. Make up top drive. Circulate at 240 gpm with 400 psi. Up weight 90k, down 80k, RT 86k. RIH and tag stub at 4128'. Washover 6' to 4 4'. Dressoff stub with 4k torque on bottom, 3k off bottom, at 80 rpm 22:30 - 23:00 0.50 CASE P DECOMP Circulate hi-vis sweep surface to surface at 450 gpm with 1300 psi. Shut down, monitor well - OK. Break out and blow down top drive. 23:00 - 00:00 1.00 CASE P DECOMP PJSM. POOH to 2290'. 2/16/2008 00:00 - 02:00 2.00 CASE P DECOMP PJSM. POOH to 330'. 02:00 - 03:00 1.00 CASE P DECOMP POOH and lay down dressoff/scraper BHA. 03:00 - 04:30 1.50 CASE P DECOMP Clear and clean floor. 04:30 - 08:00 3.50 CASE P DECOMP Pick up casing running tools to rig floor. Rig up handling tools to run casing. 08:00 - 17:00 9.00 CASE P DECOMP PJSM. Pick up and RIH with 7-5/8", 29.7#, L-80, Vam Top HC ~ to 1843'. Hole not taking proper displacement. Check casin surface equipment. Fluid leaking into cellar box. Hook up pump Printed: 4/21/2008 4:36:40 PM • BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase ~ Description of Operations 2/16/2008 08:00 - 17:00 9.00 CASE P DECOMP to cellar and continue in hole sucking out cellar into slop tank. Fill every 5 joints. Continue to run in hole with casing as per running order to 4120'. Leak into cellar stopped when packer was between 2438'-2638' indicating possible area of leak. Pick up pup joints and tag 7-5/8" stub at 4128'. Swallow stub to 4131'. Set down 30k. PU to 250k to check grapple - OK. Slack off to 155k, set slips and rig up cement head and circulating lines. PU to 225k and pull slips. 17:00 - 18:00 1.00 CASE P DECOMP PJSM. Pressure up on casing to 2100 psi and hold for 1 minute o set acker. Continue to ressure u to 3300 si and o en_ ES Cementer. 18:00 - 21:00 3.00 CEMT P DECOMP Circulate while rigging up cementers at 170 gpm with 130 psi and 250 gpm with 160 psi. Circulate hot 9.8 ppg to warm up well to 80 degrees prior to pumping cement. Fluid still leaking into cellar at approximately 4 bph. Hold PJSM for cement job. 21:00 - 23:30 2.50 CEMT P DECOMP Pump 5 bbls water and pressure test lines to 4500 psi - OK. Swap to rig and pump 5 bbls 9.8 ppg brine thru a Tee to flush lines. Pump 12 bbls 9.8 ppg brine with red dye. Swap back to cementers and follow with 198.5 bbls, 952 sacks, 15.8 ppg Class G cement at 5 bpm with 750 psi. Drop ES Cementer closing plug and kick out with 5 bbls water. Swap back to rig pumps and displace cement with 9.8 ppg brine at 5 bpm. 29 bbls away 140 psi 58 bbls away 135 psi 87 bbls away 327 psi 116 bbls away 770 psi With 122 bbls away red dye at surface. Shut down and close Hydril. Take returns to cuttings tank. Continue to pump. Continue to et returns to cellar but not cement returns. 145 bbls away 1430 psi 175 bbls away 1640 psi Slow pumps to 2 bpm. Bump closing plug with 181 bbls of 9.8 ppg, continue to pressure up to 2300 si and close ES ementer. ontinue to pressure up to 2650 psi to verify. Got back 20 bbls, 96 sacks, cement to surface, with no cement leakin into cellar. Bleed off and check for flowback. No flow. CIP at 2330 hours. 23:30 - 00:00 0.50 CEMT P DECOMP Rig down cement head and lines. 2/17/2008 00:00 - 02:00 2.00 CEMT P DECOMP PJSM. Pump retarder pill through stack. Blow down through kill line to cuttings box. Set slips, remove top drive. Break down cement head and XO, lay down. Rig up supersucker hose to rig floor. Suck out casing. Latch up to top drive. Pull 175k on string. Lay down cement equipment. 02:00 - 04:30 2.50 WHSUR P DECOMP PJSM. Remove mousehole, turnbuckles. Nipple down BOP stack. Split stack. Pick up BOP stack. Install emergency slips. Slack off with 198k in sli s. 04:30 - 08:30 4.00 WHSUR P DECOMP Rig u Wach's cutter. Cut casin .Pull cut casing to rig floor and lay down. Pick up and run in with packoff. Make several attempts to seat packoff with no success. Pull packoff. Packoff damaged. 08:30 - 14:00 5.50 WHSUR N SFAL DECOMP Left lower portion of packoff on stump. Drill and tap out threads to remove lower portion with all thread. Change out long bails on top drive. Perform rig maintenance while waiting on new Printed: 4/21/2008 4:36:40 PM • • BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To '~ Hours Task ', Code NPT ' Phase Description of Operations 2/17/2008 08:30 - 14:00 5.50 WHSUR N SFAL DECOMP packoff from FMC. Finish removing damaged packoff. Pick up running tool and run in secondary packoff. Back out running tool and lay down. Set BOP on packoff to set. 14:00 - 18:30 4.50 BOPSU P DECOMP PJSM. Nip le up BOP stack. Casing head threads damaged. Pick up stack. Remove 2 stu s on t g spoo ange an case threads. Re-install studs and nipple up BOP stack. Install riser and hook up turnbuckles. Install test plug. FMC test packoff to 3800 psi for 30 minutes - OK. PJSM. Change out upper rams to 3-1/2" x 6" variables. 18:30 - 00:00 5.50 BOPSU P DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Ken Healy. 2/18/2008 00:00 - 03:00 3.00 BOPSU P DECOMP PJSM. Continue to test ROPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Ken Healy. Test 4" and 4-1/2" test joints. Remove test plug. Run in wear ring. Lay down test joint. 03:00 - 04:30 1.50 CLEAN P DECOMP PJSM. Make up and run in hole with cement drill out BHA with 6-3/4" bit to 306'. 04:30 - 06:30 2.00 CLEAN P DECOMP RIH to top of cement. Tag top of cement at 4030' and pull up 50'. Up weight 90k, down 75k, RT 80k. 06:30 - 07:30 1.00 CLEAN P DECOMP Circulate heated 9.8 ppg brine at 270 gpm with 560 psi until returns reach 85-90 degrees. 07:30 - 09:00 1.50 CLEAN P DECOMP Drill out cement to 4095' at 300 gpm with 700 psi. Torque off bottom 3k, on bottom 5k at 80 rpm. WOB 10-15k. 09:00 - 09:30 0.50 CLEAN P DECOMP Circulate hi-vis sweep surface to surface at baffle collar. 09:30 - 10:00 0.50 CLEAN P DECOMP PJSM. RIH to top of sand at 4423'. Set 10k down to verify. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. Rack back one stand of drill pipe. Make up top drive. Close pipe rams. Pressure test casing to 3500 psi, with leak off of 750 psi in 20 minutes. Inspect all surface equipment. Test again leak off 500 psi in 12 minutes -failed test. Test again leak 650 psi in 16 minutes. 12:00 - 14:00 2.00 CLEAN P DECOMP PJSM. Blow down top drive. Romove blower hose. POOH to 305'. 14:00 - 15:00 1.00 CLEAN P DECOMP PJSM. Stand back drill collars. POOH and break bit. LD BHA. 15:00 - 16:00 1.00 ZONISO P DECOMP PJSM. Test casing to 3500 psi, under blind rams. Bleed 750 psi in 30 minutes. 16:00 - 16:30 0.50 ZONISO P DECOMP PJSM. PU and MU RTTS. 16:30 - 19:00 2.50 ZONISO P DECOMP PJSM. RIH to 4211'. 19:00 - 00:00 5.00 ZONISO P DECOMP PJSM. Set RTTS at 4221' below casing patch. Test below to 3500 si for 30 minutes - OK bleed off. Test above to 0 psi. pressure not holdino, bleed off. Move RTTS to 4119', above casing patch. Test below to psi. Lost 500 psi in 5 minutes -test faileri~{ileed off. Test to a~nn nci fnr sn mini rtac . C1K Toctc inriirata loak in ra Blow down. Release RTTS. Clear and clean floor. Remove 4-1/2" tubing from drillers side in pipe shed in preparation for laying down drill pipe. Printed: 4/21/2008 4:36:40 PM • BP EXPLORATION Page 7 of 13 ..Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Event Name: WORKOVER Start: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ', From - To Hours '~, Task Code NPT 2/19/2008 00:00 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 08:00 08:00 - 09:00 09:00 - 10:30 10:30 - 11:30 11:30 - 18:30 18:30 - 22:30 22:30 - 00:00 2/20/2008 00:00 - 01:00 01:00 - 03:00 03:00 - 06:00 06:00 - 09:00 09:00 - 10:30 10:30 - 11:30 11:30 - 16:00 16:00 - 17:30 17:30 - 19:00 19:00 - 21:00 4/7/2008 17:00 - 00:00 4/8/2008 00:00 - 12:00 12:00 - 19:00 3.00 ZONISO P 0.50 ZONISO P 0.50 RIGU P 1.00 BUNCO 3.00 BUNCO 1.00 BUNCO 1.50 BUNCO 1.00 BUNCO 7.00 BUNCO 4.00 BUNCO 1.50 RIGD P 1.00 BUNCO 2.00 BUNCO 3.00 BUNCO 3.00 BUNCO SFAL 1.50 WHSUR N SFAL 1.00 WHSUR P 4.50 WHSUR P 1.50 WHSUR P 1.50 WHSUR P 2.00 RIGD P Spud Date: 9/4/1995 End: Phase ~ Description of Operations DECOMP PJSM. POOH laying down drill pipe to 306'. DECOMP PJSM. Break out and lay down RTTS. RUNCMP PJSM. Pick up mule shoe and change out handling equipment. RUNCMP PJSM. RIH with stands to 4300'. RUNCMP PJSM. POOH laying down 4" drill pipe. RUNCMP PJSM. RIH with stands to 3581'. RUNCMP PJSM. Cut and slip 81' of drilling line. Adjust brakes, inspect draworks, gear shield baylor brake coupling and clutches. RUNCMP Rig service. Lubricate rig, top drive and crown. RUNCMP PJSM. POOH laying down drill pipe. LD drill collars, XO's and mule shoe. Pull wear ring. Break and lay down bumper sub and jars. Clear and clean floor. Load and strap 4-1/2" NSCT tubing. RUNCMP PJSM. Pick up and RIH with 4-1/2", 12.6#, L-80, NSTC tubi_g_ kill strin to 240 '. Pump out stack, install TWC. Run in and land hanger in profile. Run in lock down screws. Lay down landing joint. RUNCMP PJSM. Rig up circulating lines. Blow down to verify they are clear. Test the TWC from below and above to 1000 psi - OK. Rig down test equipment. Blow down lines. RUNCMP PJSM. Dump cement in 10-3/4" x 20" annulus. Suck out stack. Prep tools to ND BOP stack. RUNCMP PJSM. Remove mousehole. Let air out of boots. Remove riser and turnbuckles. ND BOP stack. clean out hanger. RUNCMP PJSM. Blow down hole fill and mud pumps. Pad operator OK orientation of tree. FMC installed blank flange on tree outlet. Nipple up tree. RUNCMP PJSM. FMC test void to 5000 psi for 30 minutes. Good test. Rig down FMC. Fill tree with diesel. Attempt to test tree to 5000 psi. Outlet flange leaking. Bleed off and tighten flange. Attempt to test again. Still leaking. Check out other flanges on tree. Several connections leaking. Tighten all flanges and connections. RUNCMP Attempt to test tree. Pump pop off leaking. Change out. RUNCMP Test tree to 5000 psi for 30 minutes -good test. Rig down test equipment. Drain tree. PU T-bar. RUNCMP PJSM. Pull TWC. Rig up to reverse circulate freeze protection. Rig up LRS in cellar. Pressure test lines to 3000 psi - OK. Line up and reverse circulate 90 bbls of diesel at 2 bpm. Take displacement to cuttings box. Shut down, line up and u-tube. Rig down and blow down lines. RUNCMP Install BPV. Test from below to 1000 si. Blead off. Rid d wn circulating lines. RUNCMP Unload 4-1/2" tubing from pipeshed. RUNCMP Secure the tree and remove secondary annulus valve. Clean out liner in cellar box. 7.00 MOB P SURE Back rig off C-30. Lay derrick over & prepare sub for rig move. Move sub off C-30 to lower C Pad. 12.00 MOB P SURE Transport camp, pits and shop from C-Pad to P2. Transport sub base to P2. PJSM. Raise derrick. 7.00 RIGU P SURE Spot sub over P2-32. Spot pits, shop and camp. Set cuttings tank. Rig up and spot out buildings. Printed: 4/21/2008 4:36:40 PM • BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES i Date From - To 'Hours Task ~' Code NPT Phase Description of Operations 4/8/2008 19:00 - 19:30 0.50 WHSUR P SURE Hold pre-spud meeting. Rig accepted at 1900 hours. 19:30 - 20:30 1.00 WHSUR P SURE Install secondary annular valve. 20:30 - 22:00 1.50 WHSUR P SURE Ri u DSM lubricator. Test to 500 si - OK. Pull BP .Rig 22:00 - 23:30 23:30 - 00:00 1.50 0.50 WHSUR WHSUR P P SURE SURE Rig up circulating lines. Reverse circulate out diesel freeze protect to cuttings tank with 9.8 ppg brine at 250 gpm with 500 psi. D rod TWC. Test from above to 3500 si for 5 minutes - OK. 4/9/2008 00:00 - 02:00 2.00 WHSUR P SURE PJSM. Test TWC from below to 1000 psi for 30 minutes. Lost 100 si in 15 minutes. Pum back u to 1000 si. Loose psi over 30 minutes. Ri down and blow down lines. 02:00 - 03:00 1.00 WHSUR P SURE Nipple down tree. Set tree/adapter in cellar. No damage to tree or adapter flange. Hanger threads in good shape with 7-1/2 turns. 03:00 - 04:30 1.50 BOPSU P SURE Nipple up BOP stack. Install mouse hole. 04:30 - 05:30 1.00 BOPSU P SURE Pick tools up and rig up for testing BOPE. 05:30 - 15:00 9.50 BOPSU P SURE Test BOPE to 250 si low, 3500 psi high and Hydril to 250 psi low 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL's Mitch Skinner and Dick Maskell and Toolpushers Bruce Simonson and Charlie Henley. 15:00 - 15:30 0.50 BOPSU P SURE Rig down test equipment. Blow down. 15:30 - 16:30 1.00 DHB P SURE Rig up DSM lubricator and extension. Test to 500 psi - OK. Pull TWC. Rig down lubricator and extension. 16:30 - 18:00 1.50 PULL P SURE MU landing joint. Rig up 4-1/2" tubing equipment. Screw into hanger. Back out lock down screws. Pull hanger to rig floor with 55k up weight. Lay down hanger and landing joint. Change out handling equipment. 18:00 - 20:00 2.00 PULL P SURE Pull and la down 4-1/2" kill strin from 2401'. 20:00 - 21:00 1.00 PULL P SURE Rig down 4-1/2" tubing equipment. Clear and clean floor. 21:00 - 22:00 1.00 CLEAN P DECOMP PJSM. Bring cleanout BHA to rig floor. 22:00 - 23:00 1.00 CLEAN P DECOMP PJSM. MU cleanout assembly to 197'. CO handling equipment. 23:00 - 00:00 1.00 CLEAN P DECOMP PJSM. PU and RIH with 4" drill pipe to 1131'. 4/10/2008 00:00 - 01:00 1.00 CLEAN N RREP DECOMP Remove and replace leaking hydraulic hose on iron roughneck. 01:00 - 04:00 3.00 CLEAN P DECOMP PU 4" drill pipe and run in hole to 4424' and to u .Hook up ower ose. Up weight 100k, down 80k, RT 90k. 04:00 - 05:00 1.00 CLEAN P DECOMP Dry drill to 4430'. Wash down to 4446'. 05:00 - 05:30 0.50 CLEAN P DECOMP Pump hi-vis sweep surface to surface at 400 gpm with 1390 psi. Some metal and rubber with sand to surface. Shut down, slack off and~ag up on sand at 4449'. Rig down blower hose. Blow down top drive. 05:30 - 07:30 2.00 CLEAN P DECOMP PJSM. POOH to washout assembly at 197'. 07:30 - 08:30 1.00 CLEAN P DECOMP Lay down drill collars. Break bit. Clean out boot baskets. Recovered rubber, cement, metal and sand. Clear and clean floor. 08:30 - 09:00 0.50 CLEAN P DECOMP Make up RCJB assembly to 19'. 09:00 - 11:00 2.00 CLEAN P DECOMP RIH to 4390'. Drop ball. Pick up 8 drill pipe singles. Tag at 4449'. Up weight 100k, down 75k, RT 85k. 11:00 - 11:30 0.50 CLEAN P DECOMP Pull up 45'. Break circulation at 295 gpm with 1000 psi. Rotate at 10 rpm with 3k torque. Wash to 4460' with 5k WOB. 11:30 - 14:00 2.50 CLEAN P DECOMP POOH to 19'. 14:00 - 14:30 0.50 CLEAN P DECOMP Lay down RCJB assembly. Recover cementer nose cone and metal from boot baskets. C ear an c can loor. Printed: 4/21/2008 4:36:40 PM • • BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ', Hours Task` Code I' NPT Phase Description of Operations 4/10/2008 14:30 - 15:30 1.00 DHB P DECOMP PU/MU RBP retrieving tool assembly. 15:30 - 19:00 3.50 DHB P DECOMP RIH to 4399'. Up weight 100k, down 75k. Tag top of sand at 4451'. Circulate at 340 gpm with 620 psi. Wash down to 4485'. Circulate hi-vis sweep surface to surface at 500 gpm with 1200 psi.~..atch RBP and release plug. Blow down top drive. POOH to RBP retrieving tool assembly. 19:00 - 20:00 1.00 DHB P DECOMP POOH and lay down retrieval tool and RBP. 20:00 - 21:00 1.00 DHB P DECOMP MU 7-5/8" RTTS assembl . 21:00 - 23:30 2.50 DHB P DECOMP ~iIH to 4212'. Set RTTS at 4204'. Rig up head pin. Test casing from below RTTS to 3000 si for 30 minutes. Lost 60 si. Bleed off. Rig down. Release RTTS. 23:30 - 00:00 0.50 DHB P DECOMP Service top drive. 4/11/2008 00:00 - 03:00 3.00 DHB P DECOMP PJSM. Cut and slip 90' of drilling line. Inspect and adjust brakes. Found more bad drilling line. Cut an additional 82' of drilling line. Inspect chains. Lube Elmago splines. Service crown. 03:00 - 04:00 1.00 DHB P DECOMP POOH to RTTS assembly. 04:00 - 05:00 1.00 DHB P DECOMP , La down RTTS and runnin tool. 05:00 - 08:00 3.00 CASE P RUNPRD PJSM. Rig up casing equipment. 08:00 - 09:30 1.50 CASE P RUNPRD PJSM. Make up 4-1/2" overshot assembly and 5-1/2" float equipment and RIH. Check floats. 09:30 - 10:00 0.50 CASE N SFAL RUNPRD .Repair NCS double stack tongs. Bolt sheared in tong head. 10:00 - 00:00 14.00 CASE P RUNPRD Make up and RIH with 5-1/2", 17#, 13Cr-80, Vam To HC liner to 6800'. Average torque 6580 ft/Ibs. Fill pipe every 5 joints. 4/12/2008 00:00 - 02:30 2.50 CASE P RUNPRD PJSM. RIH with 5-1/2" 17# 13Cr-80 Vam Top HC liner to 7563'. PU liner han er and liner to acker. 02:30 - 04:30 2.00 CASE P RUNPRD PJSM. Rig down casing equipment. Lay down beaver slide. Change out handling equipment for 4" drill pipe. 04:30 - 07:30 3.00 CASE P RUNPRD RIH with 5-1/2" liner on 4" drill pipe. Fill at 25 stands and bottom. See shear pins in overshot shear and tag up fully inserted. Calculate spaceout to be 4' from fully inserted. Pull to PU wt + 4'. 07:30 - 08:00 0.50 CEMT P RUNPRD Hold PJSM with all crew and contractors. 08:00 - 09:30 1.50 CEMT P RUNPRD Circulate and hook up cementers. Air up cement tanks. Repair damaged cable to rig floor computer. 09:30 - 10:30 1.00 CEMT P RUNPRD Pump 5 bbls water. Test lines to 4000 psi. Start mixing cement in tub and go downhole with 15.8 ppg Class G slurry with GasBlok. 4.5 bpm 650 psi -start. 4.2 bpm 750 psi - 75 bbls away. 4.5 bpm 900 psi - 125 bbls away. 4.0 bpm 625 psi - 156 bbls away. Total of 156 bbls/1104 sx cement mixed. 10:30 - 11:15 0.75 CEMT P RUNPRD Kick out DP wiper with 5 bbls water from cementers. Switch to rig and displace with 207 bbls 9.8 ppg brine. Did not see dart latch up with liner wiper plug. Bump liner wiper plug with 2700. psi. CIP at 1110 hours. Han er set. Bleed to 2500 psi then pump up to 3900 psi and set liner top packer. Slack off to 50k and bleed off pressure. Check floats - OK. Rotate 15 turns to the right. Pressure up to 1000 psi. PU 10' and release dogs. Maintain pressure, un-sting Printed: 4/21/2008 4:36:40 PM BP EXPLORATION Operations Summary Report Legal Well Name: P2-32 Page 10 of 13 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To 'il Hours Task ~~ Code I NPT ' Phase Description of Operations 4/12/2008 10:30 - 11:15 0.75 CEMT P RUNPRD and break circulation. 11:15 - 12:00 0.75 CEMT P RUNPRD Circulate BU until dye present in fluid. Shut down, open annular valve to cuttings tank, close bag and finish bottoms up with 25 bbls cement to surface. 12:00 - 13:00 1.00 CEMT P RUNPRD Rotate down to acker at 10 r m. Set down 55k and confirm set. Break and lay down cement head and equipment. Blow 13:00 - 13:30 0.50 CEMT P 13:30 - 15:30 2.00 CEMT P 15:30 - 16:30 1.00 CLEAN P 16:30 - 17:30 I 1.00 I CLEAN I P 17:30 - 19:00 1.50 CLEAN P 19:00 - 00:00 5.00 CLEAN P 4/13/2008 00:00 - 04:30 4.50 CLEAN P 04:30 - 05:30 I 1.001 CLEAN I P 05:30 - 06:30 I 1.001 CLEAN I P 06:30 - 13:30 I 7.00 I CLEAN I P 13:30 - 15:00 1.50 CLEAN P 15:00 - 23:00 8.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 4/14/2008 00:00 - 01:30 1.50 CLEAN P 01:30 - 06:30 ~ 5.00 ~ CLEAN ~ P 06:30 - 13:00 ~ 6.50 ~ CLEAN ~ P 13:00 - 19:30 I 6.501 CLEAN I P 19:30 - 20:00 I 0.50 I CLEAN I P 20:00 - 21:30 1.50 CLEAN N 21:30 - 22:00 0.50 CLEAN P 22:00 - 00:00 2.00 CLEAN P 4/15/2008 00:00 - 03:30 3.50 CLEAN P down cellar lines. RUNPRD Circulate S-S at 500 gpm with 1000 psi. RUNPRD PJSM. POOH from 3978'. Break and lay down running tool. CLEAN Pull wear ring. Make up flushing tool. Flush BOP stack. Run in wear ring. CLEAN PJSM. Bring up 2-7/8" handling equipment and tools to rig floor. Rig up elevators and powr tongs. CLEAN PJSM. Make up 2-7/8" cement drill out assembly to 110'. CLEAN PJSM. Pick up 2-7/8" PAC HT to 4087'. CLEAN PJSM. PU and RIH with 2-7/8" PAC HT to 7600'. Change out handling equipment to 4" drill pipe. CLEAN RIH with 2-7/8" drill out assembly on 4" drill pipe to top of landing collar for casing test. CLEAN PJSM. Rig up and test 5-1/2" x 7-5/8" casing to 3500 psi for 30 minutes. CLEAN Tagged top of cement at 11336'. Drill out cement, plug, landing co ar an oat co ar o o e at 57 . ump at 200 gpm with 3100 psi. Rotate at 50 rpm with 7-9k torque. WOB 4-9k. Swept hole as necessary. Added tubes for torque. Rubber and cement in returns. CLEAN Pump hi-vis sweep surface to surface at 200 gpm with 3300 psi. CLEAN Lay down single. Blow down, remove blower hose. Install air slips. POOH with 4" DP to 7484'. Up weight 170k. Change out handling equipment. POOH with 2-7/8" PAC drill pipe to 110'. CLEAN PJSM. Break and lay down 1 drill collar, bit, scraper, junk baskets and XO's. CLEAN PJSM. Finish laying down drill out assembly. Clean and clear floor. PU/MU clean out assembly to 166'. CLEAN PJSM. RIH with clean out assembly on 2-7/8" PAC. Change out handling equipment. RIH on 4" drill pipe to 11393'. CLEAN PU stand, MU top drive. Start circulation at 150 gpm with 1850 psi. Slack off and taca up at 11456'. Rotate at 45 rpm with 6k torque. Drill cement to 11486' with 3k WOB. Drill through landing collar and continue to wash to 11489'. Tag up again. Drill with 10k WOB. Rotate at 60 rpm with 7-8k torque. Drill to 11499'. Unable to make more progress. Try different parameters - no go. CLEAN Blow down. Remove blower hose. Hook up air slips. POOH to 7750'. Change out handling equipment. Pull out of hole with 2-7/8" PAC HT to milling assembly. CLEAN PJSM. Lay down 2 joints regular PAC and 1 DC. Break out mill. No wear or damage to mill. WAIT CLEAN Wait on orders from town. CLEAN MU PDC bit, drill collar, 2 joints regular PAC and XO. CLEAN PJSM. RIH with 2-7/8" PAC HT to 2913'. CLEAN PJSM. RIH PDC bit on 2-7/8" PAC HT to 7600'. Change out Printed: 4/21/2008 4:36:40 PM BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date Frorn - To ~ Hours Task ' Code j NPT Phase Description of Operations 4/15/2008 00:00 - 03:30 3.50 CLEAN P CLEAN handling equipment. Continue to RIH on 4" drill pipe to 11360'. 03:30 - 08:00 4.50 CLEAN P CLEAN Hook up blower hose. Make up top drive. Establish circulation at 175 gpm with 2900 psi. BIH and taa at 11499'. Drill out cement. Vary pump rates, rpm and WOB. Drill 10' in 3 hours. Continue to 11544'. No problem getting into stub at 11527'. 08:00 - 09:00 1.00 CLEAN N WAIT CLEAN PU out of stub. Wait on orders. 09:00 - 10:00 1.00 CLEAN P CLEAN Circulate sweep at 200 gpm with 3700 psi. 10:00 - 11:30 1.50 CLEAN P CLEAN Continue to drill to 1155 ' lack off to 11590'. Pump dry job. 11:30 - 14:00 2.50 CLEAN P CLEAN Strap out of hole to 10362'. POOH to 8400'. Losses encountered. 14:00 - 14:30 0.50 CLEAN P CLEAN Monitor well. Losses 60 bph, static. 14:30 - 19:00 4.50 CLEAN P CLEAN PJSM. POOH with drill out assembly to 164'. Filling hole with 9.2 ppg brine. 19:00 - 21:30 2.50 CLEAN P CLEAN Break and lay down drill out assembly. PU/MU RCJB assembly to 165'. 21:30 - 00:00 2.50 CLEAN P CLEAN RIH with RCJB assembly on 2-7/8" PAC to 5374'. Losse_ s from 1400 hours to 2300 hours 350 b 4/16/2008 00:00 - 04:00 4.00 CLEAN P CLEAN PJSM. RIH to 11350'. Make up top drive. Fill pipe. Losses slowed from 60 bph to 25 bph, with 9.2 ppg brine all the way around. Work down hole through ported XO with slight bobble, pull up work back through with no problem. Slack off and take 5-10k at 11515'. Pull up slack off again take 5k then continue through. Slack off and go through top of 4-1/2" stub with no weight, slight bobble on indicator. Continue into hole and out WLEG at 11621, no IBP. Stop at 11660' inside the 7-5/8" with no sign of the IBP. 04:00 - 04:30 0.50 CLEAN P CLEAN PJSM. Rig up to pull out sideways. 04:30 - 18:00 13.50 CLEAN P CLEAN POOH la in down drill i e. 18:00 - 18:30 0.50 CLEAN P CLEAN Break and lay down RCJB, drill collars and XO's. Nothing in junk baskets. Losses 35 bph. 18:30 - 19:30 1.00 CLEAN P CLEAN Clear and clean floor. 19:30 - 21:00 1.50 BOPSU P OTHCMP PJSM. Cut and slip 42' of drilling line. Inspect brakes and chains. Lube Elmago Splines. 21:00 - 00:00 3.00 BOPSU P OTHCMP PJSM. Pull wear ring. Make up test joint. Rig up cellar lines. Run in test plug. Test BOPE to 250 psi low, 3500 psi high as per AOGCC. Test witness waive y ohn Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. Unable to get high pressure tests. Trouble shoot and isolate valves. Still not testing. Pull test plug and inspect. Rubber seal on plug damaged. Bring out new test plug. 4/17/2008 00:00 - 07:00 7.00 BOPSU P OTHCMP PJSM. Test BOPE to 250 psi low, 3500 psi high as per AOGCC. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. Changed out test joint. Still having trouble with high tests. Grease choke manifold. Able to get good tests. Bleed off and blow down. Run in wear ring. 07:00 - 09:00 2.00 EVAL P OTHCMP PJSM. Clean and clear floor. Load out slick line tools, BOPE and lubricator. Bring up to rig floor. 09:00 - 13:30 4.50 EVAL P OTHCMP PJSM. Rig up lubricator and BOPE on lubricators., till loosing 30-35 b h. Fill hole under blinds. Make up line tools to head. Feed through lubricator extension. PU assembly with blocks. Interference between grabber and bales. Lay assembly down and re-rig. Hoist and MU caliper assembly. Fill stack, lower Printed: 4/21/2008 4:36:40 PM ~ ~ BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES I D i f O i ' i I pt perat ons NPT escr on o Date From - To Hours Task Phase ~ I Code 4/17/2008 09:00 - 13:30 4.50 EVAL P OTHCMP assembly. Test against blinds to 1000 psi - OK. 13:30 - 17:30 4.00 EVAL P OTHCMP RIH with caliper. Log out from 11637' to 11250'. POOH. Change out tools to impression block. 17:30 - 20:00 2.50 FISH P DECOMP RIH with impression block. Tag up at 11819'. POOH. m ression no e u inconc usive. ange over oo s to equalizer overshot. 20:00 - 00:00 4.00 FISH P DECOMP RIH with fishing tool. Tag at 11824'. POOH. No fish. Change tool to double bell guide retrieval tool. RIH to 11842'. Tag up, Work the hook. POOH. No fish. 4/18/2008 00:00 - 20:00 20.00 FISH P DECOMP PJSM Continue to run slick line to recover 4-1/2" 16P. Run #4 -Double Bell Guide - No success - 11842' Run #5 -Bailer -Recovered approximately 1 ga of scale, sand, sluggits, aluminum, brass, SS band material and various other material - 11858'. Run #6 -Bailer -Recovered approximately 1 ga of the same type of material - 11874'. Run #7 -Bailer -Recover 1/2 ga of same material - 11874'. Run #8 -Bailer -Recover 1/2 ga of same material - 11879'. Run #9 -Bailer -Recover 1/2 ga of same material - 11880'. Run #10 -Bailer -Caught IBP with flapper bottom at 11885'. Pulled up hole but lost it while POOH. Bailer had marks indicating we had hold of fish. Run in to try to latch up again. Run #11 - 2" JUS with 3.6" OD Bell Guide -Latched IBP and ulled to surface from 11530'. The IBP came out intact. 20:00 - 22:00 2.00 FISH P DECOMP PJSM. Break and lay down slick line tools and lubricator. Send tools down beaver slide. Remove wear ring. 22:00 - 00:00 2.00 BUNCO RUNCMP PJSM. Bring up casing tools to run 3-1/2" and 4-1/2", 9.2#/12.6#, 13Cr-80, Vam To comp~efion u~'f i~ig up. Clean and clear floor. 4/19/2008 00:00 - 00:30 0.50 BUNCO RUNCMP PJSM. Rig up to run completion tubing. 00:30 - 00:00 23.50 BUNCO RUNCMP PJSM. PU and RIH with 3-1/2"/4-1/2", 9.2#/12.6#, 13Cr-80, Vam Top completion tubing. Run control line from CAMCO BAL-O at 2191'. Taa no-oo 11452'. Pull up and space out no-go 12' off ported XO. Muleshoe at 11479'. Make up landing joint. Rig up control lines to hanger. Up weight 127k, down 90k. 4/20/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Complete installation of control line to Hanger. Land hanger. PU weight 127k, SO weight 90k, block weight 30k. 01:00 - 04:30 3.50 BUNCO RUNCMP R/U to reverse circulate. Reverse circulate clean 9.2 ppg. brine w/ corrosion inhibitor down annulus ~ 2 BPM. 04:30 - 07:00 2.50 BUNCO RUNCMP Drop 1 5/16" ball/rod assy. Pressure tubing to 4500 psi to set 5.5" X 3.5" SABL-3 Packer. Hold for 30 minutes for tubing test - OK. Bleed off to 1500 psi. Test annulus to 3500 si for 30 minutes - OK. Bleed off, bleed o tubing. Pressure up and shear DCK valve at 2250 psi. Pump both ways to verify. 07:00 - 08:00 1.00 BOPSU P RUNCMP Install TWC. Test from above and below to 1000 si - OK. Blow down and rig down hoses. 08:00 - 09:00 1.00 BOPSU P RUNCMP PJSM. Nipple down BOP stack. 09:00 - 14:30 5.50 WHSUR P RUNCMP PJSM. Test control lines to 5000 psi - OK. NU adapter flange and tree. Test adapter void to 5000 psi for 30 minutes - OK. Fill tree with diesel. Test to 5000 psi - OK. 14:30 - 15:30 1.00 WHSUR P RUNCMP PJSM. Rig up lubricator. Fill up and test to 700 psi with no leaks, bleed off. Remove TWC. Ria down lubricator- Printed: 4/21/2008 4:36:40 PM ~J BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: P2-32 Common Well Name: P2-32 Spud Date: 9/4/1995 Event Name: WORKOVER Start: 2/6/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/20/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT 'i Phase Description of Operations 4/20/2008 15:30 - 18:00 2.50 WHSUR P RUNCMP PJSM. RU Little Red Services. Pressure test lines to 3500 psi - OK. Pump 90 bbls of 60 degree diesel at 2 bpm with 1100 psi initial circulating pressure, 1800 psi final circulating pressure. Shut in and allow to u-tube. Bleed off, suck back 1 bbl. 18:00 - 19:30 1.50 WHSUR P RUNCMP Rig up DSM lubricator. Run in BPV. Remove lubricator. Test from below to 1000 psi - OK. Rig down LRS, lines in cellar and secondary annulus valves. Install guages on tree. 19:30 - 22:00 2.50 RIGD P RUNCMP PJSM. Install 5' pup in TD and set slips. Remove hydraulic service loop. Lower bridal lines to floor. Bridal up and remove electric survice loop. Hang from top drive. Rig down cattle chute. Pull pits away from sub. 22:00 - 00:00 2.00 RIGD P RUNCMP PJSM. Lay derrick down. Jack up sub. Move sub off off well. Prepare to move rig. Rip released at midnicaht. Printed: 4/21/2008 4:36:40 PM • TREE= 4-1/16" CM/ WELLHEAD= 13-5/8" FMC ACTUATOR = BAKER KB. ELEV = 51.9' BF. ELEV = 11.9' KOP = 1075' Max Angle = 91 @ 12380' Datum MD = 11822' Datum TV D = 8800' SS DRLG DRAFT 7-518", 29.7", L-80, VAMTOP HC XO BTC-M 4131' 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 4325' NOTES: HORIZONTAL WELLS - 70° @ 12024'. P Z -3 2 191' '-2 OME CSG, TBG 8 LNR*" SLB BAL O SSSV 41/2" , , -3975' 7-518" X 5-112" BKR LNR TOP PKR -4,114' 7-5/8" ES Cementer -4,120' 7-518" BKR ECP 4,131 7-5/S" casing patch (;AS I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5889 4778 47 KBG2- DCK BEK 0 04118/08 2 7927 6174 47 KBG2- DMY BK 0 04/18/08 3 9115 6996 46 KBG2- DMY BK 0 04/18/08 4 10177 7740 45 KBG2- DMY BK 0 04/18/08 5 11273 8494 47 KBG2- DMY BK 0 04/18/08 3-1/2". X Nipple, ID=2.813", 9Cr 11.372` ~~ 5-1 /2" x 3-1 /2" Baker SABL-3 7-5/8", 29.7^, L-80, BTGM XO 13CR-80, Nscc 11426' ~ ~ 11,405` 3-1/2", "X' Nipple, ID=2.75", 9Cr ~ 11,467'` 5-1/2" x 4-1 /2" Crossover-ported 11,467' - 5-1/2" 13CR, 17#, Vam Top HC 7-518" X 4-1!2" TIW HBBP-T PKR. ID =3.915" 11564' 11,518' 4-1/2", Unique Overshot 11,479` 3-1/2", 9.2#, 13Cr-80, Vam Top 11588' 4-1 i2" OTIS X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" ~~ 11619' Minimum ID = @ 11,405' 3-1 /2" X NIPPLE = 2.75" 7-5/8" CSG, 29.7#, 13CR.NSCC, ID = PERFORATION SUMMARY REF LOG: SWS CDR/SLIM-1 09!29/95 A NGLE AT TOP PERF: 89° @ 12313' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-112" SLTD 12313 - 13368 O 10/04/95 11608' 114-1/2" OTIS XN NIP, ID = 3.725" I 11621' 4-1/2" WLEG, ID = 4.00" ELMD TT NOT LOGGED 12070' 7-5/8" X 4-1/2" TNV SS HORIZ. PKR, ID = 3.907" 12117' 4-1 /2" PORTED JT 12237' 4-1/2" TMJ MLAS JT (12237' - 12272') ~ ~. ~ ~ ~\\ .`` .~ ~~ ~\ ~ .` .` 14-1 /2" 12.6# LNR SHOE, ID = 3.958" I DATE REV BY COMMENTS DATE REV BY COMMENTS 10104/95 ORIGINAL COMPLETION 04/21/08 N2ES RWO I 13390' I PBTD H 13390' PRUDHOE BAY UNIT WELL: P2-32 PERMfr No: 195-1350 API No: 50-029-22593-00 SEC 14, T12N, R14E, 218' FNL & 1371' FWL BP Exploration (Alaska) • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 19, 2008 3:15 PM To: 'Hubble, Terrie L' Subject: RE: P2-3-~. Terrie, In the interest of keeping the paperwork to a minimum since well operations will begin in the next week or so, no reports (404 or 407) are due at this time. If the work is successfully completed, all work should be reported with the 404 to close out 308-071. Tom Maunder, PE AOGCC From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, March 19, 2008 1:56 PM To: Maunder, Thomas E (DOA) Subject: FW: P2-32, 195-135 Hi Tom, S~.v~ ~~ ~ ~CGSrc S2rC ®°~~ S\C~C P ~~~ ~~~~ Have you had a chance to look into this reporting requirement yet? The only reason I am asking is that when the engineer gave me the paperwork to submit a Sundry to move back on this well to make the appropriate repairs, he indicated that in his conversation with you that we probably would not have to submit the Completion Report, since we are moving back on so quickly. The original sundry was to repair a 7-5/8" casing leak. The rig moved on, cut and pulled the 7-5/8" and ran a tieback. Unfortunately the tieback failed the pressure test. (Rig Released 02/20108) They suspended operations to evaluate repair options and have since submitted a Sundry to move on in late March or early April to make those repairs. If I need to do the 10-407, it is due tomorrow, so i need to get on it. :-) Thanks! Terrie From: Hubble, Terrie L Sent: Monday, March 17, 2008 10:10 AM To: 'Maunder, Thomas E (DOA)' Subject: RE: P2-32, 195-135 '~~' 1~AR ~ ~ 200 None yet. But, since we are moving back on the well so quickly, I didn't know if both the 404 and the 407 are required. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, March 13, 2008 4:53 PM To: Hubble, Terrie L 3/19/2008 • Subject: RE: P2-32, 195-135 What forms (404 or 407) have been filed? From: Hubble, Terrie t [mailto:Terrie.Hubble@bp.com] Sent: Thursday, March 13, 2008 3:55 PM To: Maunder, Thomas E (DOA) Subject: P2-32, 195-135 Hi Tom, We now have three outstanding 10-403's for this well. Page 2 of 2 308-004, Approved 01/14/08, To Repair this well, Subsequent Form Required: 10-404 Rig Released from this RWO on 02/20/08 308-061, Approved 02/27/08, To Suspend this well, Subsequent Form Required: 10-407 While they figured out what to do with the 7-518" casing leak 308-071, Approved 03/13/08, To Repair this well, Subsequent Form Required: 10-404 Work planned for March 25th So.... my question is this. What form(s) am I expected to submit for this well. :-) Thanks! Terrie 5~~~ , ~ J~ O~ \~cc~Src ~G~ `~ ~~~~oo~ ~ ~`3C~~s-C~~, ~ ~~ w~ ~ ~ ~~ S J~ ~`< .. ~,~-yam-- a NCO ~ .~ ~ ~ ohs- -- ~~ ~- 3~r~ 3/19/2008 4 • • ~,,,~ ~"'~ ~ ~~-- U ~ ~ ~ '~' SARAH PAUN, GOVERNOR L~ilt~-7~ OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 COrITSERQATIOl~T COM11iISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ' Greg Hobbs Senior Drilling Engineer BP Exploration Alaska., Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay FYeld, Pt. McIntyre Oil Pool, PBU P2-32 43~f Sundry Number: 308-071 1 ~ ~' 4 ~~ Dear Mr. Hobbs: 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 note that additional "boxes" have been checked in `"I~pe of Request". This approval supersedes the work plan approved by Sundry 308-004. 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. 4 Chair DATED this .~ day of March, 2008 Encl. ~~~' (~1~.0~ STATE OF ALASKA • °'t~'~~~ 3~ ALA~KA OIL AND GAS CONSERVATION COMMISSION `t E~ Y ~D APPLICATION FOR SUNDRY 20 AAC 25.280 APPROVA ~'~~ 3 ~I a- 008 1. Type of Request: ^ Abandon ,,~~((~~,,,~ /1 ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ((~~,,~~ ,'1 ' i Alter Casing,(~ 3 ~ i7 ®Repair Well ^ Plug Perforations ^ Stimulate ~~tf'tlV@lf' J ~1J Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Othe ~~~ ~~~~ 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-135 / 308-004 / 308-061 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22593-00-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU P2-32 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 365548 ,~ 51.9' ~ ~ Prudhoe Bay Field /Point McIntyre Pool ~2. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13396 ~ 9001 ~ 13396 9001 4485'& 11600' None Casin Len th Size MD TVD Burst Cotla se Structural Conduct r 80' 20" 80' 80' 1490 470 Surface 4284' 10-3/4" 4325' 3699' 5210 2480 Intermediate 12174' 7-5/8" 12212' 8976' 8180 5120 Production Liner 1320' 4-1l2" 12070' - 13390' 8955' - 9001' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft); Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner: 12312' - 13368' 8979' - 9000' 4-1/2", 12.6# L-80 & 13Cr 2401' & 11527' - 11621' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW 'HBBP-T' packer Packers and SSSV MD (ft): 11564' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 25, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foreg ing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Name Greg obb Title Senior Drilling Engineer Prepared By Name/Number: Signature Phone 564-4191 Date v~ ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~, BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 3S~C'~ P s ~ ~®~ ~ Subsequent Form Required: ~o` APPROVED BY / A roved B : COMMISSIONER THE COMM SION Date Form 10-403 Revised 06/2006 ,S (~I~yi A~ ~ ~ J .Z ~/~'~ Submit In Duplicate • • by c,~,y, P2-32 Rig Workover P2-32 rig workover (RWO) operations were suspended on February 20, 2008. AOGCC was notified of our decision and a Sundry has been submitted for the suspension. BP plans to repair the 7-5/8" casing leak with running a 5-1/2" scab liner with 3-1/2" 13CR completion tubing. Rigs can access PM2 by ice road only. As such, the proposed plan is to complete this work in the first part of April 2008. ODE: Mehrdad Nadem Well Type: Producer Estimated Start Date: March 25, 2008 Pre-riq prep work: 1. Bleed the production casing x kill string to zero psi. PPPOT T & IC for 30 minutes. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage. 2. If necessary, remove the well house from P2-31, P2-32, P2-33, and P2-34. Level the pad. Please provide total well preparation cost on the handover form. Proposed Procedure: 1. MIRU Nabors 2ES. 2. Circulate out freeze out and displace with brine. Pull BPV. Set TWC and test. 3. Nipple down tree. Nipple up and test BOPE to 250 psi low and 3,500 psi high. Pull TWC. 4. Back out lock down screws. Pull tubing hanger. Pull and LD kill string from 2,401'. 5. RU Baker VACS tool. RIH and clean sand off the RBP at 4,485'. 6. RIH with RBP retrieving tool. Retrieve RBP. POOH and LD retrieving tool. 7. RIH with 5-1/2" Vam top HC scab liner on 4-1/2" drillpipe. Swallow the 4-1/2" stub with 7-5/8" x 4-1/2" Unique machine overshot. Cement the scab liner to the liner top. Set hanger and packer. 8. PU 4-3/4" medium tooth rock bit cleanout BHA on 2-7/8" Pac Pipe crossed over to 4" drillpipe above the 5-1/2" liner top at 4,000'. 9. RIH to the Baker insert Landing Collar. Close Pipe rams and pressure test the 5-1/2' x 7-5/8" casing to 3,500 psi for 30 charted minutes. 10. Drill out of the shoe track to the ported 4-1/2" x 5-1/2" cross over. Pump hi-vis sweeps and circulate bottoms up at the maximum rate. POOH, stand back drillpipe. 11. RU 2-7/8" Pac pipe crossing over drillpipe above the liner top with a 3-5/8" junk mill at the end of the PAC pipe with a 5-1/2" scraper BHA. Space out the scraper such that the junk mill is within 5' of the IBP when the Scraper no-goes at the ported 4-1/2" x 5-1/2" cross over. Pump hi-vis sweep and circulate bottoms up until getting clean returns. POOH. LD drillpipe. 12. RU slick line with IBP retrieving tool and a bailer. Engage the fishing neck and retrieve the IBP. 13. POOH. RD slick line. • 14. Run new 3-1/2" Chrome tubing completion crossed over to 4-1/2" completion at 4,000'. 15. Displace the IA to packer fluid and set the packer. 16. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 17. Set BPV. ND ROPE. NU and test tree. RDMO. TREE _ 4-1 / 16" CNV WELLHEAD = 13-5/8" FMC AOTUATOR = BAKER KB. ELEV = 51.9' BF. ELEV = 11.9' KOP = 1075' Max Angle = 91 @ 12380' Datum MD = 11822' Datu m TV D = 8800' SS • P2-32 RWO 2008 NOTES: HORIZONTAL WELLS - 70° @ 12024'. v1E CSG, TBG &LNR"'* -2,200` 3-1/2" SSSV -4,000` 5-1 /2" 17#, 13CRIinertop -4,114` 7-5/8" ES Cementer -4,120` 7-518" BKR ECP 4,131 7-5/8" casing patch 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" GLM Depth Station MD TVD #5 5922' and 4800' tvd #4 7965' and 6200' tvd #3 9121' and 7000' tvd #2 10263' and 7800' tvd #1 11472' and 8630' tvd I 4325' I 7-5/8", 29.7", L-80 X 7-5/8", 29.7#, 13CR-80 XO 11426' 11564' 7-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.915" 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 11,480` 3-1/2", X Nipple, ID=2.813", 9Cr 11,500` 5-1/2" x 3-1 /2" baker SABL-3 packe 11,520` 3-1/2", "X' Nipple, ID=2.75", 9Cr 11,508`` 5-1/2" x 4-1/2" Crossover-ported t ~ 11,534' S-1/2" 13CR, 17#, Vam Top HC ~ 11,534` 4-1/2", Unique Overshot f 11,560` 3-1/2", 9.2#, 13Cr-80, Vam Top 11588' 4-1/2" OTIS X NIP, ID = 3.813" 11608' ~4-1/2" OTIS XN NIP, ID = 3.725" 11621' 4-1/2" WLEG, ID = 4.00" ELMO TT NOT LOGGED I 11619' I Minimum ID = 3-7Id~." XN ~ IP ~).. ~ 12070' 7-5/8" X 4-1/2" TNV SS HORIZ. PKR, ID = 3.907" 17-5/8" CSG, 29.7#, 13CR, ID = 6.875" I 4-1/2" PORTED JT 14-1/2" TM/ MLAS JT (12237' - 12272') PERFORATION SUMMARY REF LOG: SWS CDR/SLIM-1 09/29/95 ANGLE AT TOP PERF: 89° @ 12313' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnfSgz DATE 4-1/2" SLTD 12313 - 13368 C 10/04/95 ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ .`\\ ~`\\ PBTD 13390' ~ ~ .\ 4-1 /2" SLOTTED LNR, 12.6#, 13CR, .0152 bpf, ID = 3.958" 14-1/2" 12.6# LNR SHOD ID = 3.958" I DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/95 ORIGINAL COMPLETION 10/27/07 DAV/TLH GLV GO 10/06/01 CHIKAK CORRECTIONS 10/31/01 WB/TP SURF LOC CORRECTIONS 09/02/07 GJB/SV SET IBP (04/08/07) 09/17/07 PJC PERF CORRECTION 10/19/07 TEL/PJC GLV GO PRUDHOE BAY UNrf WELL: P2-32 PERMrr No: 195-1350 API No: 50-029-22593-00 SEC 14, T12N, R14E, 218' FNL & 1371' FWL BP Exploration (Alaska) 02/28/08 ~~[I~~~~~~~~~ NO. 4612 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Atth: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Aurora,GNI,Pt.Mac,Milne Pt,Endicott Well Joh it Inn Ilescrintinn rhfn RI f:nln. en 15-25A 12014000 LDL / r.~Co ~ 02/20108 1 A-12A 11963077 MCNL _ sr 3 01/19108 1 1 GNI-04 12031448 TEMP SURVEY (REVISED) ~~- ~ (0 01/22/08 1 1 P2-32 11968730 USIT - - f- 02/13/08 1 1 17-02 11996384 USIT /~;Q- ~' 02117/08 1 1 Y-07A 11962781 SCMT '}-1 ~ '- ~ 02!03/08 1 1 P2-58 12031456 USIT r90 - '~/ 02/25/08 1 1 MPH-12 12005205 MEM INJ PROFILE ~ _ j~-p $ ~ 02/15/08 1 1 4-141R-34 11975755 USIT Vie. ~ 02/25/08 1 1 S-126 11968731 JEWELRYIPERF/SBHP ~- M' U 02/15/08 1 1 PLtASt AGISNUWLtUGt KtIaIP I f3Y SIGNING ANU KETURNING UNE GUPY EACH TU: BP Exploration (Alaska) Inc. ry 900 EeBenlson Blvd Center LR2-1 ~~6~~VIV~i~ MpR ~ a ~oo~ Anchorage, Alaska 99508 "~' c"~" Date Delivered: PSI A i° t"t ^, ~:~~ir~c: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: • sa't d =,p, . • • ~.;° .~ s~ ~.._ _ `~ ~ 1 t ~ ~ + ~ ~ ~ ~ t ,~ ~ ~ p ,.r ~f ~ ~ ~_: !r t~,,~ ~. ~ s~~ ~ ~a i. ~~~r P-I ~ ~'~ L~i~. ~a / SARAH PALIN, GOVERNOR y~ tT/~rt~~ OI 1~a~t~~s~i1 Vrv7~7T 333 W. 7th AVENUE, SUITE 100 CO1~T5kR~tATIOl•T CO1~i1~iiSSIOls ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc. _ PO Box 196612 "~' ~ FED 20~~ ?J Anchorage, Alaska 99519-6612 l ~~ C 4~ Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, PBU P2-32 Sundry Number: 308-061 Dear Mr. Hobbs: 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 DATED this~day of February, 2008 Encl. ~ry~~~~ ~~ STATE OF ALASKA ~' F ~B 2 2 ALASK~OIL AND GAS CONSERVATION COMMISSION ~~ -PPLICATION FOR SUNDRY APPROVA~sk~ p~~ ~ ~~~ ~on~• ~ •,~ ,~ b~ 20 AAC 25.280 Onrhnrans 1. Type of Request: ^ Abandon ®Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension , ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-135 / 308-004 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22593-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU P2-32 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 365548 - 51.9' ' Prudhoe Bay Field /Point McIntyre Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13396 9001 13396 9001 4485'& 11600' None Casin Len th Size MD TVD Burst Colla se Structural Conductor 80' 20" 80' 80' 1490 470 Surface 4284' 10-3/4" 4325' 3699' 5210 2480 Intermediate 12174' 7-5/8" 12212' 8976' 8180 5120 Production Liner 1320' 4-1/2" 12070' - 13390' 8955' - 9001' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner: 12312' - 13368' 8979' - 9000' 4-1/2", 12.6# L-80 & 13Cr 2401' & 11527' -11621' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW'HBBP-T' packer Packers and SSSV MD (ft): 11564' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 19, 2008 ^ Oil ^ Gas ®Plugged ^ Abandoned 17. Verbal Approval: Date: 2/19/2008 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: Tom Maunder 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Name Greg Hobbs Title Senior Drilling Engineer Prepared By Name/Number: Phone 564-4191 Date ~~d~FS Terrie Hubble, 564-4628 Signature ~ ` ' d , a s Commission Use Onl Sundry Number: -~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~rp~1Z~Q ~G~p~1~G,c ~\S~Z r~p'~C~ P("ESSV C'F "C~S~~IprC.~~ O~ZGJ~Q'.. Subsequent Form Required: ~~ APPROVED BY A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Rid fj~/~006 .:-_~~.~~~~~?QOM ORIGINAL Submit In Duplicate • To: AOGCC From: Mehrdad Nadem - BPXA GPB Rotary Drilling Date: February 20, 2008 Subject: P2-32 Application for Sundry Approval -Suspension of Operations Sundry #: 308-004 This is to request AOGCC approve suspension of the rig workover operations on P2-32. This request is as a result of a leak in the 7-5/8" casing. The 7-5/8" casing was cut and pulled. Anew string of 7-5/8 casing was ran and was cemented to surface. The 7-5/8" casing was pressure tested against the RBP set at 4,485' NID. The 7-5/8" casing failed the pressure test at the casing patch. This suspension allows BP consider available options to repair the leak. ~y~~~h<S <~~~~ The well is secured with an IBP set at 11,600' MD and a RBP set at 4,485' MD. We plan to run a ~~ 4-1/2" kill string to 2,500', and will freeze protect the well before releasing the rig. ~(~~® P2-32 Operations Summary (Work scheduled to be completed) 1. RIH with to 2,500' MD with 4-1/2" 12.6# Kill string. 2. Land tubing, RILDS, Install TWC and test from below 1000psi. 3. ND BOP, NU Tree and test same to 5000 psi 4. Pull the TWC. 5. RU circulating lines, Test lines to 3500 psi and freeze protect the tubing and annulus to 2,000' MD. 6. Install BPV with DSM and test from below to 1000 psi. 7. Secure wellhead and tree with proper flanges, valves and gauges. Offload excess fluids and release rig to P2-58. 01-05 Application for Sundry TRH= a_v~F"r:nnr WELL~iEAD= 13-5/8" FMC ACTUATOR= BAKER KB. ELEV = 51.9' BF. ELEV = 11.9' KOP = 1075' Max Angle = 91 ~ 12380' Datum MD = 11822' Datum ND = 8800' SS 10-3/4" CSG, 45.5#, NT-80, D = 9.953" P2-32 RWO 2008 I 4325' I Minimum ID = 3.725" ~ 11608' 4-1/2" OTIS XN NIPPLE ~7-5/8", 29.7", L-80 X 7-5l8", 29.7#, 13CR-80 XO ~ $J81lfY NOTES: HORQONTAL WELLS - 70° (~ 12024'. "'CFIROME CSG, TBG & LNR'"' x2,500' Kill String 4,080` ES Cementer 4,090' BKR ECP 4,485` RBP with 1800# of sand 17-5/8" X 4-1l2" TNV I-~BP-T PKR, ID = 3.915" I 4-1 /2" OTIS X NIP, ID = 3.813" 77600' ELM -j2-1/2" BAK~iIBP(04/08/07) 11608' 4-1 /2" OTIS XN NIP, ~ = 3.725" 4-1/2" TBG, 12.8#, 13CR-80, .0152 bpf, ID = 3.958" 11619' 11621' 4-1/2" WLEG, ID = 4.00" _ ELMD TT NOT LOGGED 12070' 7-5/8" X 4-1/2" TNV SS HORIZ. 12117' J-j4-1/2" PORTED JT 7-5/8" CSG, 29.7#, 13CR, ~ = 6.875" 12212' t ~~ 12237' 4-1/2" TIW MLAS JT (12237' - 1 PERFORATION SUMMARY REF LOG: SWS CDR/SLM-1 09/29/95 ANGLEATTOPPERF: 89°~ 12313' Note: Refer to Production DB for historical pert data SIZE SPF MERVAL Opn/Sqz DATE 4-1/2" SLTD 12313 - 13368 C 10/04/95 D = 3.907" \~. ~~ ~~ ~ ~. ~ ~. PBTD 13390' .` ~` .~ 4-1/2" SLOTTm LNR, 12.8#, 13CR, .0152 bpf, D = 3.958" ~-~ 4-1/2" 12.8# LNR SHOE, D = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/98 ORIGINAL COMPLEf10N 10/27/07 DAV/TLH GLV GO 10/08/01 CHIKAK CORRECTIONS 10/31/01 WB/TP SURF LOC CORRECTIONS 09/02/07 GJB/SV SET 6P (04/08/07) 09/17!07 PJC PERF CORRECTION 10/19/07 TEUPJC GLV GO PRUDHOE BAY UNR WELL: P2-32 PERAMT No: 195-1350 API No: 50-029-22593-00 SEC 14, T12N, R14E, 218' FNL 8 1371' FWL BP ~cploration (Abska) P2_32 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, February 19, 2008 8:41 AM To: 'Nadem, Mehrdad' Cc: Hobbs, Greg S {ANC); Hubble, Terrie L Subject: RE: P2-32 (195-135) Mehrdad, et al, Looking at the procedure in the sundry (308-004), from your message it appears you got to somewhere after step 8. Is that correct? Were you able to cement the 7-5/8" casing? If the earlier steps in the procedure were accomplished successfully, there is a deep IBP in the tubing tail as well as the 7-5/8" RBP below where the casing was cut. The well should be secured. What are BP's plans for future work? It will be your option as to "operational SD" or "suspend". Either will require a sundry. How soon will the kill string be run or is it already in the well? 1 look forward to your reply. Tom Maunder, PE AOGCC IFrom: Nadem, Mehrdad [mailto:NademM@BP.com] Sent: Tuesday, February 19, 2008 7:1 i AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Hubble, Terrie L Subject: P2-32 Tom, We ran a new stung of 7-5/$" casing in P2-32 and cemented it to surface. The Bowen casing patch however is not passing pressure test. We are securing the well by running a kill string, and wilt freeze protect it. We plan to move off the well to decide on available option to deal with issue. Please let me know if you need additional information. Thanks, Mehrdad Nadem Operations Drilling Engineer Phone:907/5b4-5941 Ce) I: 907/440-0213 Errwil: nademm@bp.com 2/25/2008 P2-32 • Maunder, Thomas E (DOA) • Page 1 of 1 From: Maunder, Thomas E (DOA} Sent: Tuesday, January 15, 2008 4:42 PM To: 'Nadem, Mehrdad' Subject: RE: PZ-32 (195-135} Thanks for the update Mehrdad. I presume the CT BOP will be tested to 3500 psi. I will place a copy of this message in the file. Nothing further is needed. Also, please include the PTD number in the subject line. It helps flli~~ ;JAN ~ ~ Call or message with any questions. Zdd~ Tom Maunder, PE AOGCC From: Nadem, Mehrdad [maitto:NademM@BP.com] Sent: Tuesday, January 15, 2008 4:3fi PM To: Maunder, Thomas E (DOA) Subject: P2-32 Tom: as discussed, I added step pre rig work. This step was added to clean the fill in the tubing. 1. Bleed OA, to & T to zero psi. PPPOT T 8~ IC. Check the tubing hanger lock down screws for free movement. Completely back out. and check each lock down screw for breakage. 2. RU, drift 4-1l2" tubing. Lay stuggit on top of the IBP (It appears that there is no need to fay sluggit on the IBP due to the buildup of scale). 3. RU CTU, RIH and clean fi{I (scale). Sca{e was tagged at 11,471'. 4. Jet cut the 4-1l2" tubing in the first full joint above the packer set at 15,564'. 5. Circulate the well to seawater through the tubing cut. 6. Perfomt CMtT T x IA to 1,500 psi far 30 minutes. 7. Freeze protect the IA and tubing with diesel to 2,200'. 8. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure the well. 9. Remove the well house. Level the pad. Please provide total well preparation cast an the handover fom~. Thanks, Mehrdad Nadem Operations grilling Engineer Phone: 907/564-5942 Cell: 907/440-0223 Email: nademmC~bp.com 1/15/2008 • ~,~ ~ ~ ~~~~f 1~~ ~~ ~ '. ~ ~ ~ ~ s ~ s r i -~ L_1 ~i~.1 t L.~ ~~ ~»3 Lf ~d ~._._.7 SJ l~ ~ ~1~~ ALASSA OIL AI1TD GAS C01~TSER'QA~'IOr1T COl-II-IISSIOI~T Phil Smith Senior Drilling Engineer BP Exploration Alaska Inc. Anchorage, Alaska 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, PT McIntyre Oil Pool, PBU P2-32 Sundry Number: 308-004 Dear Mr. Smith: 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. DAT~D this day of January, 2008 Encl. ~.---- STATE OF ALASKA ~GV~~ y ~~ ALASKA OIL AND GAS CONSERVATION COM~ION lj O ~ ~Q~$ APPLICATION FOR SUNDRY APPROVALY"~~~ JAN 20 AAC 25.280 Alaska Oil & Gas Cati~~ C~mmss~pn 1. Type of Reque ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~ ~~ "Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-135 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22593-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU P2-32 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 365548 51.9' Prudhoe Bay Field !Point McIntyre Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13396 9001 13396 9001 11600 None asin Len h Size MD TVD Burst Colla 'se tructural and or 80' 0" 80' 80' 149 470 urface 4284' 10-3/4" 4325' 3699' 5210 2480 Intermediate 12174' 7-5/8" 12212' 8976' 8180 5120 Pr duction Liner 1320' 4-1 /2" 12070' - 13390' 8955' - 9001' 8430 .7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner: 12312' - 13368' 8979' - 9000' 4-1/2", 12.6# 13Cr 11621' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW 'HBBP-T packer Packers and SSSV MD (ft): 11564' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ .Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 10, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and erect to the best q'~,y knowledge. Contact Mehrdad Nadem, 564-5941 ~`a ~ Printed Name ~ SeTiior Drilling Engineer Nc~~ ;)rte „t~f' Title Prepared By Name/Number. Terrie Hubble, 564-4628 Signature ~ Phone 564-.4-'f9r~f~' Date ~~~(l~~ Commission Use On Sundry Num Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test '~,,~ Mechanical Integrity Test ^ Location Clearance Other: 3~~ ~5[~~~ ~5~ G-S e~Gh Subsequent Form Required: t.~b~` APPROVED BY D~ ~ A roved B C I SION R THE COMMISSION Date ~ CCC~ Form 10-403 Revised 06/2006 L/ `~ Submit In Duplicate _ .. ~~~:.~ x ~ ~~~~ DU~'~r SATE TREE= 4-1/16" CIW WELLHEAD = 13-5/8" FMC ACTUATOR = BAKER KB. ELEV = 51.9' BF. ELEV = 11.9' KOP = 1075' Max Angle = 91 @ 12380' Datum MD = 11822' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" I-~ 4325' Minimum ID = 3.725" @ 11608' 4-1/2" OTIS XN NIPPLE ~ 7-5/8", 29.7", L-80 X 7-5/8", 29.7#, 13CR-80 XO I ~ P2-32 I i SAFETY NOTES: HORIZONTAL WELLS - 70° @ 12024'. *** E CSG, TBG &LNR""'* 2102' ~-~4-1/2" CAMCO TRCF-4A SSSVN, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4754 4000 47 KBMG DMY BK 0 10/19/07 2 6948 5502 46 KBMG DMY BK 0 05/10/99 3 8100 6294 46 KBMG DMY BK 0 10/19/07 4 8968 6895 47 KBMG DMY BK 0 05/10/99 5 9680 7388 46 KBMG DMY BK 0 10/27/07 6 10426 7913 46 KBMG DMY BK 0 05/10/99 7 11498 8648 47 KBMG DMY BK 0 05/10/99 11564' ~-{ 7-5/8" X 4-1 /2" TM! HBBP-T PKR, ID = 3.915" 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 7-5/8" CSG, 29.7#, 13CR, ID = 6.875" I-I 12212' PERFORATION SUMMARY REF LOG: SWS CDR/SLIM-1 09/29/95 ANGLE AT TOP PERF: 89° @ 12313' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD 12313 - 13368 C 10/04/95 L4-1/2" PORTED JT 4-1/2" TNV MLAS JT (12237' - 12272') . ` ~ ~. ~ ~ ` ` .` ~` .~ ~ ~ 4-1/2" SLOTTED LNR, 12.6#, 13CR, .0152 bpf, ID = 3.958" ~~ 4-1/2" 12.6# LNR SHOE, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/95 ORIGINAL COMPLETION 10/27/07 DAV/TLH GLV GO 10!06/01 CH/KAK CORRECTIONS 10!31/01 WB/TP SURFLOCCORRECTIONS 09/02/07 GJB/SV SET IBP (04/08/07) 09/17/07 PJC PERF CORRECTION 10/19/07 TEUPJC GLV GO j 7l5tfif" I-14-1/2" OTIS X NIP, ID = 3.813" ~ 11600' ELM 2-1/2" BAKER IBP (04/08/07) 11608' 4-1/2" OTIS XN NIP, ID = 3.725" 11621' 4-1l2" WLEG, ID = 4.00 ELMD TT NOT LOGG~ 12070' 7-5/8" X 4-1 /2" TM/ SS HORIZ. PKR, ID = 3.907" 13368' I 13390' I PBTD 1-~ 1 PRUDHOE BAY UNIT WELL: P2-32 PERMff No: 195-1350 API No: 50-029-22593-00 SEC 14, T12N, R14E, 218' FNL & 1371' FWL BP Exploration (Alaska) TREF = 4-1 /1 Fi" C:MJ WELLHEAD = 13-5/8" FMC ACTUATOR= BAKER KB. ELEV = 51.9' BF. ELEV = 11.9' KOP = 1075' Max Angle = 91 @ 12380' Datum MD = 11822' Datu m TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" SAFETY RTES: HORIZONTAL WELLS - 70° @ 12024'. P2-32 RWO 2008 OME CSG, TBG &LNR*** 2200` - 4-1/2" HES X NIP 9CR 4250` ES Cementer 4325' 4280` -- BKR ECP Gas Lift Mandrels Minimum ID = 3.725" @ 11608' 4-1/2" OTIS XN NIPPLE 17-5/8", 29.7", L-80 X 7-5/8", 29.7#, 13CR-80 XO I ( 11426' I ST MD TVD DEV 4 TBD TBD TBD 3 TBD TBD TBD 2 TBD TBD TBD 1 TBD TBD TBD 11,410` 4-112", HES X NIP 3.813" 11,420` 4-1/2" 7-5/8" x 4-1/2" S3 PKR 11,4600` 4-1/2", HES X NIP 3.813" 11564' ~--~ 7-5/8" X 4-112" TNV HBBP-T PKR, ID = 3.915" 4-1/2" OTIS X NIP,ID = 3:813" 14-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" I 7-5/8" CSG, 29.7#, 13CR, ID = 6.875" 776UU: tLM I--~2-1/2" BAKERIBP(04/08/07) 11608' 4-1/2" OTIS XN NIP, ID = 3.725" 11619' 11621' 4-1/2" WLEG, ID = 4.00" - ELMD TT NOT LOGGED 12070' 7-5/8" X 4-1/2" TM/ SS HORIZ. PKR, ID = 3.907" 1 PERFORATION SUMMARY REF LOG: SWS CDR/SLIM-1 09/29/95 ANGLE AT TOP PERT: 89° @ 12313' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD 12313 - 13368 C 10/04/95 72117• (-~4-1/2"PORTEDJT I 12237' 4-1 /2" TNV MLA S JT (12237' - 1 ~ ~ ~ ~. ~ ~ ~~ ~. .`` ~\` PBTD .` 4-1/2" SLOTTED LNR, 12.6#, 13CR, .0152 bpf, ID = 3.958" ~~ 4-1 /2" 12.6# LNR SHOE, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/95 ORIGINAL COMPLETION 10/27/07 DAV/TLH GLV C/O 10/06!01 CHlKAK CORRECTIONS 10/31/01 WB/TP SURF LOC CORRECTIONS 09/02/07 GJB/SV SET IBP (04/08/07) 09/17/07 PJC PERF CORRECTION 10!19!07 TEL/PJC GLV Ci0 13368' I 13390' I PRUDHOE BAY UNIT WELL: P2-32 PERMff No: 195-1350 API No: 50-029-22593-00 SEC 14, T12N, R14E, 218' FNL & 1371' FWL BP Exploration (Alaska) • by cr~,y, P2-32 Rig Workover • The scope of the P2-32 RWO is to repair a leak in the 10-3/4" surface casing. Tubing will be cut and pulled above the existing packer. Production casing will be cut at about 4,300' MD, pulled, run and cemented to surface. New 4-1/2" 13CR tubing will be run and pressure tested. Well Type: Producer Estimated Start Date: February 10, 2008 Pre-ria area work: 1. Bleed OA, IA & T to zero psi. PPPOT T & IC. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage. 2. RU, drift 4-1/2" tubing. Lay sluggit on top of the IBP. 3. Jet cut the 4-1/2" tubing in the first full joint above the packer set at 15,564'. 4. Circulate the well to seawater through the tubing cut. 5. Perform CMIT T x IA to 1,500 psi for 30 minutes. 6. Freeze protect the IA and tubing with diesel to 2,200'. 7. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure the well. 8. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Proposed Procedure: 1. MIRU Nabors 7ES. 2. Nipple down tree. Nipple up and test BOPE to 250 psi low and 3,500 psi high. 3. Circulate out the diesel freeze protection, and displace the well to kill weight fluid. 4. Pull and LD the 4-1 /2" tubing from the jet cut. 5. RU E-line and run USIT in the 7-5/8' casing. The USIT will be used to confirm that top of cement in the 7-5/8" x 10-3/4". 6. Set a retrievable bridge plug in the 7-5/8" casing at -4,450' MD (depth determined from the USIT log). Test the RBP to 1000 psi for 30 minutes to confirm a competent seal. Turn the well over to 9.8 ppg brine and spot 50' of sand on top of the RBP. 7. Cut and pull the 7-5/8" casing in the middle of a joint and above TOC. 8. RIH with a new string of 7-5/8", 29.7#, L-80 casing, and patch into the 7-5/8" stub. An ES cementer and an external casing packer will be placed above the patch. 9. Cement 7-5/8" x 10-3/8" annulus to surface. The annular preventer will be closed during a part of the operations for the purposes of squeezing in the 10-3/4" casing x conductor. 10. Run new 4-1/2" Chrome tubing completion. 11. Displace the IA to packer fluid and set the packer. 12. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 13. Set BPV. ND BOPE. NU and test tree. RDMO. 85 i2,5 CDR,,':3L.T..H T'v'D 95 ..... iZ, 5 7'i2} .. . · i '.:', i',:, : 0 // i:t'. i..I i"-.! ii, A T i': .. 17: ~:>' ,:.".. 'v' :' ~./" 'i 8/" 0~/' 'i 9/9 (]~k / ' (/ .,"Cj '- / ~ "-' / '-'- '.." · ,, 0 .~/" 'i '.i~/' '.: .~ ~'::, . 0 ,i./' 'i 9/" 8 .. /' .,, /" . · i 0 .... 407 ~ C OH P L !: T i Oi'q D A T E ( t~/"3 /'"~'~( -'"' 2 /'" })7" c_,/(~,.,." Ar'e we ] ] We ii '¥ s C 0 H H E i"] W [% GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10134 Company: Alaska Oil & Gas Cons Comm Attn- Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 4/17/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # Log Description Date BL RF Sepia Disk P2-32 c~'- I ~¢ 96062 CDR/SLIM-1 950929 1 P2-32 CDR/SLIM-1 95092 9 I 1 P2-32 CDR/SLIM-1 TVD 950929 I 1 P2-32PB 95351 CDR/CDN 95091 7 1 ~2-32PB CDR 95091 7 I 1 P2-32PB CDN 95091 7 I 1 P2-32PB CDR TVD 95091 7 I 1 P2-32PB CDN TVD 95091 7 I 1 'P2-53 c[(q_ 0~[ PERFORATION RECORD 960408 I 1 'P2-53 STATIC BHP SURVEY 960408 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: , .PR 1996 Aiaske Oil & Gas Cons, Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GJAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 95-135 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22593 4. Location of well at surface 9. Unit or Lease Name i ~:::~':-- ................ Point Mclntyre 5062' NSL, 3909' WEL, SEC. 14, T12N, R14E ~:~-~'""-:-'-'"'-"" : 10. Well Number At Top Producing Interval 1500 NSL, 1946' WEL, SEC. 12, T12N, R14E P2-32 At Total Depth . Point Mclntyre 1738' NSL, 614' WEL, SEC. 12, T12N, R14E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 51.9' ADL 365548 12. Date Spudded09/04/95 .13. Date T.D. Reached09/28/95 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns10/03/95 N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13396' MD~9001' TVD 13390' MD~9001' TVD YES [] NO []I 2102 feet MDI 1800' (Approx.) 22. Type Electric or Other Logs Run GR/NEU/DEN 23. CASING, UNER AND CEMENTING RECORD SE'I-FING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'Fl'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surface 80' 30" 260 sx Arcticset (Approx.) 10-3/4" 45.5# NT8OLHE 41' 4325' 13-1/2" 1050 sx PF "E"/375 sx "G" 7-5/8" 29.7# NT95HS 38' 12212' 9-7/8" 460 sx Class "G" 4-1/2" 12. 6# 13CR-80 12070' 13390' 6-3/4" Uncemented Slotted Liner Slotted 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Slotted Liner 4-1/2", 13CR80 11621' 11569' 12312;13368' MD 8979'-9000' TVD (BKB) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected w/103 bbls 50/50 t/2600' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 10/9/95 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SlZE [GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure .?,ALCULATED.~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Kalubik 12001' 942' Kuparuk River 12038' 8949' 31. LIST OF A'Fi-ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P2-32 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: - POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 09/04/95 ( 1) MOVE RIG TD: 120'( 0) MW: 0.0 VIS: 0 09/05/95 (2) TD: 1155' (1035) 09/06/95 (3) TD: 2112' ( 957) DRILL T/l150' MW: 0.0 VIS: 0 MOVE & SPOT RIG. SET LEGS,SKID RIG FLOOR OVER WELL. HOOK UP ELECTRICAL & SERVICE LINES TO RIG FLOOR. INSTALL HANDRAILS, MANLIFTS IN CELLAR. NU DIVERTOR. RIG ACCEPTED @ 1000 HRS., 09/04/95. RU DIVERTOR. NU SURFACE STACK & DIVERTOR LINES. INSTALL DRIP PAN. MIX SPUD MUD. LAY HERCULITE & SET ROCKOVER TANKS. LEVEL DERRICK. MODIFY OFF DRILLERS SIDE DIVERTER LINE. SERVICE TOP DRIVE. TEST DIVERTOR. FUNCTION TEST DIVERTOR SYSTEM, INSPECT LINES. PERFORM ACCUMULATOR TEST. TEST WITNESSED BY STATE MAN JERRY HERRING. RUN BHA %1. PU MOTOR, BIT, STABILIZERS,COLLARS & MWD. DRILLED T/451'. SPUD @ 2130 HRS.,09/04/95. TOOK GYRO SURVEY @ 451'. CIRC WHILE RU ATLAS & TAKING GYRO SURVEY. ACCEPTABLE SURVEY OBTAINED @ 430'. GYRO F/430' TO SURFACE @ 50' INTERVALS. DRILLED T/985' TOOK GYRO SURVEY @ 910'. RUN GYRO WHILE CIRCULATING. ACCEPTABLE SURVEY OBTAINED @ 910'. DRILLED T/l150' RUN BHA %1, MU BHA #2 MW: 0.0 VIS: 0 RUN BHA %1. DRILLED T/1264'. TAKE GYRO SURVEY @ 1264'. OK. DRILLED T/1844' TAKE GYRO SURVEY @ 1750'. CIRC, SET BACK STD,RUN GYRO. OK. CBU @ 1844',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/215'. WIPER TRIP. RIH T/1844'. DRILLED T/2112'. TAKE GYRO SURVEY. RU SURVEY WIRELINE UNIT. OK. POOH T/215'. PULLED BHA. RUN DP,5" OD. RAN DP IN STANDS T/1350'. CBU @ 1350',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. KICKOFF PLUG. MIXED & PUMPED SLURRY, 127 BBL. PUMP 32 BBLS WATER, 127 BBLS CLASS 'C' PERMAFROST CEMENT, 2 BBLS WATER. BALANCE IN W/ 11 BBLS MUD. CEMENT PUMPED. PULL DP,5" OD. WAIT ON CEMENT. SERVICE DRILLFLOOR/DERRICK. CHANGE ROLLERS ON TOP DRIVE,CHANGE BOOT IN FLOWLINE,CUT DRILLING LINE, ADJUST BRAKES. RUN BHA %1. MU BHA %2. PU BHA, BIT, CHANGE BEND IN MOTOR. ORIENT. WELL : P2-32 OPERATION: RIG : POOL 7 PAGE: 2 09/07/95 ( 4) TD: 3149' (1037) 09/08/95 (5) TD: 4335' (1186) 09/09/95 (6) TD: 4335' ( 0) 09/10/95 ( 7) TD: 6350' (2015) POOH T/2900' MW: 0.0 VIS: 0 RUN BHA %2. MU BHA %2. SERVICE DRAW-WORKS. SERVICE RIG WHILE WOC. RU WESTERN ATLAS. OK. RUN BHA %2. RIH T/899'. TEST MWD @ 543'. WASH T/870'. TAG FIRM CEMENT. DRILL T/899'. CBU @ 899',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. WELLBORE SURVEY. TOOK GYRO MULTI-SHOT W/LINE SURVEY. ACCEPTABLE SURVEY OBTAINED @ 899'. RU BHA %2. DRILLED T/3149'. DRILLED CEMENT F/899' T/927'. OFF KICKOFF PLUG @ 927'. DRILLED & SURVEYED T/3149'. GYRO SURVEY @ 985' & 1546'. START WIPER TRIP. CBU @ 3149',150% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/2900'. RUN CASING T/1200' MW: 0.0 VIS: 0 RUN BHA %2. POOH T/1078'. AT TOP OF CHECK INTERVAL. RIH T/3149'. REAM THRU TIGHT SPOT @ 2847'. ON BOTTOM. DRILLED T/4335'. REACHED PLANNED END OF RUN-SECTION/WELL TD. CBU @ 4335',150 % HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/2776'. AT TOP OF CHECK INTERVAL. RIH T/4335'. MWD CHECK SHOTS WHILE RIH. ON BOTTOM. CBU @ 4335',150% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/220'. AT BHA. PULLED BHA. RUN 10-3/4" OD CASING. RU CASING HANDLING EQUIP. OK. RUN 30 JTS CASING T/1200' MU BHA %3 MW: 0.0 VIS: 0 RUN 10-3/4"0D CASING T/4325' (100 JTS) . HANGER LANDED. CBU @ 4325',225% HOLE VOLUME OBTAINED CLEAN RETURNS. MIXED & PUMPED 483 BBLS SLURRY. TEST LINES T/3000 PSI. PUMP 50 WATER, 406 BBLS LEAD @ 12%,77 TAIL @ 15.1%. DISPLACED 403 BBLS SLURRY. CIP @ 1400. PLUG BUMPED,2000 PSI. FLOATS HELD. RD CEMENT UNIT. RD LANDING JT & CIRC HEAD. OK. MIXED & PUMPED 40 BBLS SLURRY FOR TOP JOB. CIRC 20 BBLS OUT. LEAD CEMENT PUMPED. ND DIVERTOR. OK. WELLHEAD WORK. INSTALL ADAPTER SPOOL. MU UNIVERSAL STARTING (CASING HEAD). OK. NU ALL FUNCTIONS. RU ALL FUNCTIONS. IN POSTITION. TEST RAMS F/250 PSI T/5000 PSI. ANNULAR F/250 PSI T/3500 PSI. CHOKE MANIFOLD T/5000 PSI. OK. RU DRILLSTRING HANDLING EQUIP. CLEAR FLOOR. RU DRILLING TOOLS. SET WEAR BUSHING. MU & RUN BHA %3. DRILLED T/6350' MW: 0.0 VIS: 0 MU & RIN BHA #3. RIH T/4233',AT FLOAT COLLAR. TEST CASING T/3000 PSI. OK. RUN BHA %3. DRILLED T/4345'. DRILL F/C CEMENT, 10' NEW HOLE. PERFORM FORMATION TEST, 15.6 EMW. OBATAINED LEAK OFF 15.6 PPG EMW. RUN BHA %3. DRILLED T/5765'. START WIPER TRIP. CBU @ 5765',125% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/4165'. SOME SWABBING. PUMP & BACKREAM TO ELIMINATE SWABBING. AT TOP OF CHECK TRIP INTERVAL. RIH T/5765'. HOLE IN GOOD SHAPE. ON BOTTOM. DRILLED T/6350'. WELL : P2-32 OPERATION: RIG : POOL 7 PAGE: 3 09/11/95 (8) TD: 7083' ( 733) 09/12/95 (9) TD: 8750' (1667) 09/13/95 (10) TD: 9831' (1081) 09/14/95 (11) TD:l1085' (1254) 09/15/95 (12) TD:11636' ( 551) MU & RUN BHA #4 MW: 0.0 VIS: 0 RUN BHA #3. DRILL T/7083' HAD CHANGE IN TORQUE F/13000 FT LB T/18800 FT LB. BIT QUIT. CBU @ 7083',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/212'. PULLED T/6509' HOLE STARTED SWABBING. PUMPED OUT TO SHOE. PUMP DRY JOB POOH. PULLED BHA. LD JARS,MWD & BIT. RUN 5" OD DRILLPIPE T/7068'. DP HAD MULE SHOE ON BOTTOM. TAKE SURVEY. WELLBORE SURVEY. RU LOGGING, BRAIDED CABLE EQUIP. OK & IN POSITION. TOOK GYRO MULTI-SHOT WITH LINE SURVEY. IN HOLE REFERENCE GYRO. SURVEY EVERY 1000' IN. EVERY 100' OUT. ACCEPTABLE SURVEY OBTAINED @ 6990'. RD LOGGING, BRAIDED CABLE EQUIP. COMPLETE,EQUIP LD. PULL 5" OD DRILLPIPE. CBU @ 7083',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. PULLED DP IN STDS T/0'. WELLHEAD WORK. REMOVE WB. INSTALL WB. TIE DOWN BOLTS ENERGISED. SERVICE WEAR BUSHING. MU & RUN BHA #4. DRILLED T/8750' MW: 0.0 VIS: 0 RUN BHA #4. MU BHA #4. PU BIT #4,NEW JARS,NEW MWD. OK. RIH T/4325' @ 10-3/4" CASING SHOE. SERVICE BLOCK LINE. SLIP & CUT 94' OF DRILLING LINE. ADJUST BRAKES. GREASE RIG & TOP DRIVE. LINE SLIPPED & CUT. RUN BHA #4. RIH T/7083' -- BENCHMARK SURVEY @ 5451'. ON BOTTOM. DRILLED T/8504'. START WIPER TRIP. CBU @ 8504',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/7000'. BACK REAM 2 STDS F/7275' T/7087'. TIGHT & SWABBING. AT TOP OF CHECK TRIP INTERVAL. RIH T/8504'. ON BOTTOM. DRILLED T/8750'. RIH T/3000' MW: 0.0 VIS: 0 RUN BHA #4. DRILLED T/9831'. ADDING LUBE-TEX TO MUD. HAD CHANGE IN TORQUE FROM 17050 FT/LB TO 18600 FT/LB. BIT QUIT. CBU @ 9831',150% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/212'. HOLE IN GOOD SHAPE. NO SWABBING. NO TIGHT SPOTS. PULLED BHA. BIT #3 HAS LOOSE CONE #2,MANY LOST TEETH. PULLED FOR PR NOT TQ. TQ HAD DECREASED DUE TO ADDITION OF LUBE-TEX. BHA STOOD BACK. RUN BHA #5. RIH T/3000'. SHALLOW TEST MOTOR & MWD. DRILLING MW: 0.0 VIS: 0 RUN BHA #5. RIH T/4300' @ 10-3/4" CASING SHOE. SERVICE TOP DRIVE MOTOR. CHANGE OIL. RIH T/5455'. TOOK MWD SURVEY @ 5455'. OK. RIH T/9545'. BREAK CIRC, D2 DRILL, MONITOR WELL. AT TOP OF FILL @ 9545'. REAM F/9545' T/9831', CHECK SHOT SURVEY. ON BOTTOM. DRILLED T/11085'. DRILL F/9831' T/11085'. TORQUE INCREASE TO 900 AMPS, ADDING 1 PPG LUBETEX. DRILLED T/11636' MW: 0.0 VIS: 0 BHA #5, DRILLED T/11626'. CBU. POOH, MU BHA #6. RIH T/300'. STOPPED TO TEST EQUIPMENT. RIH T/4325', AT 10-3/4" CASING SHOE. RIH T/5478'. STOPPED TO TAKE MWD SURVEY, 5 CK SHOTS. ACCEPTABLE SURVEY OBTAINED AT 5478'. RIH T/il500', BREAK CIRC, REAM 120'. DRILLED T/11636' WELL : P2-32 OPERATION: RIG : POOL 7 PAGE: 4 09/16/95 (13) TD:11975' ( 339) 09/17/95 (14) TD:12344' ( 369) 09/18/95 (15) TD:ll300' ( 0) 09/19/95 (16) TD:11269' ( 0) 09/20/95 (17) TD: 11845' ( 576) 09/21/95 (18) TD:12047' ( 202) DRILLING MW: 0.0 VIS: 0 RUN BHA #6. DRILLED F/11636' T/11797'. OK. DRILLED F/11797' T/11950'. OK. DRILLED F/11950' T/11975'. FLOWCHECK WELL. WELL STABLE. POOH T/2000' MW: 0.0 VIS: 0 RUN BHA #6. DRILLED F/11920' T/12344'. CBU @ 12344, 100% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/12344', SHORT TRIP 10 STDS, HOLE CLEAN IN & OUT. CBU @ 12334, 100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/4323'. POOH/MAD PASSW WITH LOGGING. MAX PULL RATE-900FPH. POOH T/2000' POOH, MAD PASS COMPLETED. MU & RUN BHA #7 MW: 0.0 VIS: 0 RUN BHA #6. POOH T/744'. LD 24 JTS HWDP. PULLED BHA. PULL SOURCE,DOWNLOAD LWD, LD LWD, STBS, MONEL, BIT SUB, BIT. BATTERIES DEAD ON LWD,TAKE TO SHOP TO DOWNLOAD-INSURE HAVE LOGS. LOGS RETRIEVED 1200 HRS. RUN 5" OD DP T/12344' AT BOTTOM OF RESERVOIR. CBU @ 12344, 100% ANNULUS VOLUME OBTAINED BOTTOMS UP. CEMENT KICKOFF PLUG. MIXED & PUMPED 130 BBL SLURRY. PULL 5" DP. CBU @ 10205', 150% HOLE VOLUME OBTAINED CLEAN RETURNS. CIRC UNTIL SHAKER CIR. PULL DP. POOH. PRESSURE TEST. RU WELL CONTROL. PULL WEAR RING, INSTALL TEST PLUG. OK. MU & RUN BHA #7. CBU @ 11269 MW: 0.0 VIS: 0 RUN BHA #7. RIH T/4325' @ 10-3/4" CASING SHOE. REPAIR TOP DRIVE MOTOR. CHANGE OUT SWIVEL. OK. RUN BHA #7. RIH T/5460'. RETRIEVE BENCHMARK SURVEY. TOOK GYRO SURVEY @ 5460'. OK. RIH T/il200', AT TOP OF CEMENT. TAG STRINGER @ 11180, HARD CEMENT @ 11200. DRILLED CEMENT T/11269'. CIRC CONTAMINATED MUD @ 11269'. CBU @ 11269' DRILLED T/11845' MW: 0.0 VIS: 0 BHA #7, DRILLED CEMENT T/Il400'. CBU. COND CEMENT OUT OF MUD SYS. DRILLED T/11532'. CBU. TEST SURFACE MUD EQUPIMENT. DRILLED CEMENT T/11583'. CBU. DRILLED CEMENT T/11595', KICK OFF DEPTH. DRILLED T/11845' DRILLED T/12047' MW: 0.0 VIS: 0 BHA #7, DRILLED T/12040'. BIT QUIT, MOTOR STALLING OUT. CBU, POOH T/352'. PUMP DRY JOB, HOLE IN GOOD CONDITION. BHA STOOD BACK. BHA #8, CHANGE BIT, ORIENT MWD W/MOTOR. RIH T/4320', 10-3/4" CASING SHOE. RIH T/5460'. TOOK MWD SURVEY AT 5400'. RIH T/12040', BOTTOM. DRILLED T/12047' WELL : P2-32 OPERATION: RIG : POOL 7 PAGE: 5 09/22/95 (19) TD:12222' ( 175) 09/23/95 (20) TD:12222' ( 0) 09/24/95 (21) TD:12222' ( 0) 09/25/95 (22) TD:12232' ( 10) 09/26/95 (23) TD:12352' ( 120) 09/27/95 (24) TD:12668' ( 316) RU CASING HANDLING EQUIP MW: 0.0 VIS: 0 RUN BHA #8. DRILL T/12222'. CBU @ 12222', 150% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/11280', 10 STD SHORT TRIP. HOLE IN GOOD CONDITION. AT TOP OF CHECK TRIP INTERVAL. RIH T/12222'. ON BOTTOM. CBU @ 12222', 150% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/202', 10 STDS WET, HOLE FILL GOOD, PULLED CLEAN. PULLED BHA. DOWNLOAD LWD, LD BHA. RD DRILLSTRING HANDLING EQUIP. CLEAR FLOOR, STABS, BIT, ETC. OK. RU TOP RAM. PULL WEAR RING, SET TEST PLUG. CHANGE TOP RAMS TO 7-5/8", TEST DOORS T/2500 PSI. RUN 7-5/8" CASING. RU CASING HANDLING EQUIP. OK. RUN CASING T/866'. PU & CHECK FLOAT EQUIP, RUN 20 JTS OF CHROME CASING. CHANGE HANDLING EQUIP. RU CASING HANDLING EQUIP. LD CHROME TOOLS. PU LEFLEUR CIRC HEAD & L-80 TOOLS. LAID OUT DP F/DERRICK MW: 0.0 VIS: 0 RAN CASING T/12212'. CIRC AT THE SHOE, LAND ON MANDREL HANGER. LAST 500' WAS TIGHT GOING IN HOLE. HANGER LANDED. CIRC AT 12212'. MIXED AND PUMPED CEMENT SLURRY. PLUG BUMPED. SINGLED IN DP T/6200' MW: 0.0 VIS: 0 TESTED WELL CONTROL EQUIPMENT. BHA #9, SINGLED IN DP T/6200' PULL BHA MW: 0.0 VIS: 0 BHA #9, SINGLED IN DP T/12056'. CIRC, BROKE CIRC. TEST CASING. BHA #9. DRILLED CEMENT STARTING AT 12074', DRILL FLOAT COLLAR, CEMENT, FLOAT SHOE. CLEAN OUT RAT HOLE. DRILL 10' OF NEW HOLE. CBU. ATTEMPT TO CLEAR ANADRIL SLIM 1 TOOL, NOT GETTING SIGNAL. MWD/LWD FAILED, END BHA. POOH T/11285'. TRY AGAIN TO CLEAR ANADRIL TOOL, PUMP DRY JOB, POOH. PULL BHA. DRILLED T/12352' MW: 0.0 VIS: 0 RUN BHA #9. PULLED BHA, CLEAN MWD. RUN BHA #9. RIH T/12232'. PU 475' DP & STD BACK IN DERRICK. ON BOTTOM. CBU @ 12232'. BROKE CIRC, TRY TO GET MWD WORKING. DRILLED T/12268'. CBU @ 12268', MWD/LWD FAILED. POOH T/200' PULL BHA. C/O MWD, FLUSH BHA, CHECK BIT. BHA STOOD BACK. MU BHA #9. SURFACE CHECK MWD. RIH T/10000'. SERVICE DRILLFLOOR/DERRICK. SERVICE TOP DRIVE & DRAWWORKS. RUN BHA #9. RIH T/12268'. ON BOTTOM. DRILLED T/12352'. PULLED BHA MW: 0.0 VIS: 0 RUN BHA #9. DRILLED T/12688' CHANGE IN TORQUE F/11000' FT/LB TO 14000 FT/LB. BIT QUIT. CBU @ 12668', 150% HOLE VOLUME OBTAINED CLEAN RETURNS. MONITOR WELL. POOH T/200' @ BHA. PULLED BHA. WELL : P2-32 OPERATION: RIG : POOL 7 PAGE: 6 09/28/95 ( 25) TD:13102' ( 434) 09/29/95 (26) TD: 13396' ( 294) 09/30/95 (27) TD:13396 PB: 0 10/01/95 (28) TD:13396 PB: 0 10/02/95 (29) TD:13396 PB: 0 10/03/95 (30) TD:13396 PB: 0 DRILLING MW: 0.0 VIS: 0 RUN BHA #9. PULLED BHA C/O BIT & MWD. RUN BHA #10. SURFACE TEST MWD-FAILED. POOH C/O MW-D, SURFACE TEST OK. RIH T/12205' @ CASING SHOE. SERVICE BLOCK LINE. RUN BHA #10. RIH T/12688'. ON BOTTOM. DRILL T/13102'. RIH T/3000' MW: 0.0 VIS: 0 BHA #10, DRILLED T/13396', REACHED PLANNED END OF RUN. CBU, POOH T/200'. PUMP DRY JOB. BHA LAID OUT. BHA #11, RIH T/3000'. RUN CASING MW: 0.0 RUN BHA #11. RIH T/12210', @ 7-5/8" CASING SHOE. REAMED T/13396' @ BOTTOM. CBU @ 13396'. POOH T/12200', SHORT TRIP TO SHOE AT TOP OF CHECK TRIP INTERVAL. RIH T/13396'. CBU @ 13396'. POOH T/ 11330', PUMP DRY JOB, DROP RABBIT. SERVICE BLOCK LINE. RUN BHA #11. POOH T/223'. PULLED BHA. RU TUBING HANDLING EQUIP TO RUN 4-1/2" CASING. RU CHROME TOOLS. RUN CASING T/560'. PU GUIDE SHOE, PACKOFF BUSHING & SLOTTED LINER. LD DP T/9540' MW: 0.0 RUN CHROME SLOTTED LINER T/1334'. RU & RUN 2-1/16" TUBING INSIDE LINER, PU TIW LINER HANGER/PACKER. HANGER ASSY INSTALLED. CBU @ 1428'. RAN CASING ON LANDING STRING T/13390'. RUN SLOTTED LINER IN HOLE ON DP. TEST LINER HANGER VIA ANNULUS & STRING. OK. WORKED TOOLSTRING T/12071'. CBU @ 13390'. PULLED DP @ TOP OF LINER. CBU @ 12060'. LD DP T/9540'. RUN TUBING T/6870' MW: 0.0 STATE MAN DOUG AMOS WAIVED THE BOP TEST SINCE WE'RE SO CLOSE TO FINISHING UP. RUN CASING. LD DP T/12076'. RAN DP & PU/LAY OUT TUBULARS. SERVICE DERRICK/DRILLFLOOR, CENTER RIG OVER WELLBORE. OK. PULL DP. RD TUBING HANDLING EQUIP. SERVICE BOP STACK, CHANGE TOP & BOTTOM RAMS. RU TUBING HANDLING EQUIP. RUN TUBING T/6870' RD BOP STACK MW: 0.0 RUN 4-1/2" TUBING T/9100'. REPAIR HANDLING EQUIP. RUN TUBING T/11586' INSTALL TUBING HANGER. CBU @ 11620'. SET PACKER @ 11564', LAND TUBING. TEST PACKER VIA ANNULUS. OK. RD HANDLING EQUIP. ND BOP STACK. RD TOP RAM, CHANGE TO 5". RD BOP STACK. WELL : P2-32 OPERATION: RIG : POOL 7 PAGE: 7 10/04/95 (31) TD:13396 PB: 0 MIRU MW: 0.0 ND BOP STACK. INSTALL XMAS TREE & TEST VALVES. RETRIEVED HANGER PLUG. FREEZE PROTECT WELL. ADAPTER FLANGE LEAKING, XMAS TREE EQUIP FAILED-ABORT OPERATIONS. TEST ADAPTER SPOOL. FREEZE PROTECT WELL. OK. INSTALL HANGER PLUG. RIG RELEASED @ 1800 HRS. RD DRILLFLOOR/DERRICK. MIRU. SIGNATURE: (drilling superintendent) DATE: PAGE NO, *********** SURVEY PROGRAM COMPANY SHARED SERVICES DRILLING WELL NAME P2-32 HORIZONTAL SIDETRACK LOCATION I PT, MclNTYRE LOCATION 2 NSB~ ALASKA MAGNETIC DECLINATION 2B,37 GRID CONVERGENCE ANGLE 0,00 DATE: 23-SEP-95 APINUMBER ~00292259300 AFENUMBER 2C0074 WELL HEAD LOCATION: LAT(N/-S) 0o00 DEP(E/-W) AZIMUTH FROM ROTARY TABLE TO TARGET IS 76,69 TIE IN POINT(TIP) : MEASURED DEPTH 0,00 TRUE VERT DEPTH 0o00 INCLINATION 0o00 AZIMUTH 0o00 LATITUDE(N/-S) DEPARTURE(E/-W) 0,00 0,00 0o0 O.O0 I00,00 I00,0 100,00 200,00 100,0 199,99 300,00 100,0 299,99 400.00 100,0 399,99 500,00 I00,0 499,98 600,00 100,0 599,98 700.00 100,0 699,77 800,00 100o0 799,93 900,00 100,0 899,71 1000,00 1050.00 1100,00 1150,00 1200,00 1250,00 1300,00 1350,00 1400.00 1450,00 1500,00 1550,00 1600,00 1650,00 I700,00 1750,00 1800,00 1850,00 1900,00 1950,00 2000,00 2050,00 2100,00 2150,00 2200,00 Z250,00 2300,00 2350,00 2400,00 2450,00 100,0 999,00 50.0 1048,41 50,0 1097.63 50,0 1146,63 50,0 1195,44 50,0 1244,00 50,0 I292,24 50,0 1340,19 50,0 1388,08 50,0 1436,05 50,0 1484,0I 50,0 1531,98 50,0 1579,91 50,0 1627,73 50,0 1675,48 50,0 1723,04 50,0 1770,34 50,0 1817,20 50,0 1863,35 50.0 1908,76 50,0 1953.62 50,0 1998,26 50,0 2042,87 50.0 2087.33 50,0 2131,61 50,0 2175,74 50,0 2219,81 50,0 2264,01 50.0 2308,14 50,0 2352,07 SURU~¥ CALCULATIONS CIRCULAR ARC NETNOD TARGET STATION AZIHUTH LATITUDE SECTION IHCLN. .N/-S ft deg deg ft 0,00 0,00 0,00 0.00 0.40 0,46 78,75 0,08 1.54 0.85 69,72 0,41 2,44 0.21 50.70 0.79 2,99 0,50 I03,22 0,80 4,04 0,79 59,31 1,06 4,80 0,15 39,36 1,51 5,65 0,87 90,25 1,61 8,43 2,35 71,29 2,26 14,84 5.08 67.71 4.60 26.62 8,52 78.36 7.77 34,27 9,10 81,47 9,II 42,95 11',10 86,3I 10.00 52,74 11,85 87,73 10,52 63,40 13,I5 85,30 11,19 75,15 i4,44 87,55 11,92 88,I1 I6.04 84,65 12,83 I02,16 16.88 83,83 14,25 116.41 16,54 84,15 15,76 130.41 16,24 83,75 I7,25 I44,46 I6.60 81.78 19.03 158,56 16,22 76,16 21,72 172,77 16,84 73,05 25,50 187,35 17,14 72,34 29,85 202,15 17.38 72,98 34,27 217,5I 18,53 71,21 39,01 233,65 19.34 70,54 44,33 250,98 21,44 71,10 50,05 270.12 23,80 71,23 56,26 290,95 25,67 71,69 62,91 312,93 26,73 71,36 69,90 335,39 26,83 73,09 76,78 357,92 26,85 72,54 83,45 380.76 27,63 73,65 90,10 403,96 27,74 74,40 96,49 427,45 28,33 75,51 I02,57 451,07 28,05 77,53 108,10 474,43 27,71 80,02 112,65 497,90 28,38 79,74 116,78 521,7I 28,63 80,71 120,83 P2-32 O£PARTUR£ DISPLACEHEHT at AZIHUTH DLS E/-W deo/ ft ft de§ lOOft 0.00 0,00 0.00 0o00 0,39 0,40 78,75 0.46 1,48 1,54 74,41 0,40 2,32 2,45 71.27 0,65 2,89 3,00 74,45 0,41 3,90 4,05 74,88 0,55 4,58 4,82 71,77 0,65 5,42 5,66 73,50 0,78 8,I2 8,43 74,45 1o55 14,16 14,89 72.01 2,74 25.52 26.68 73,06 3,65 33,06 34,29 74.60 1.50 41,77 42.95 76,53 4.34 51,70 52.76 78,50 1,60 62,50 63.50 79,85 2,80 74,40 75,35 80,90 2,79 87,5! 88,44 81,66 3,54 101,60 102.60 82,01 1.74 115,90 116,97 82,26 0,71 129,93 131,07 82,44 0,64 143.95 145,20 82.47 1,32 157,80 159,29 82,16 3,26 I71,51 173,39 81,54 2,16 185,46 187,84 80,86 0,73 199,62 202,54 80,26 0,61 214,28 217,80 79,68 2.55 229.61 233,85 79,07 1,68 246,06 251,i0 78,50 4,22 264,26 270.18 77,98 4,72 284.10 290,98 77.51 3,76 305.03 312,94 77,09 2,14 326.49 335,39 76,77 1,57 348,05 357.92 76,52 0,50 369,95 380,76 76,31 1,86 392,28 403,98 76,18 0,73 414,98 427,47 76,11 1,58 437,94 451,09 76,13 1,99 460.87 474.44 76.26 2.43 484,01 497,90 76,43 1,36 507,53 521,71 76,61 1,05 · .~£ HO, 3 ..... P2-32 SURU£¥ CALCULATIONS ********* CIRCULAR ARC METHOD ********** M£ASUR£D IN?£RVAL V£R?ICAL DEPTH D£PTH ft ft ft 2500,00 50,0 2395,57 2550,00 50,0 2438,45 2600.00 50.0 2480.85 2650,00 50,0 2522,64 2700,00 50,0 2563,78 tARG£t StAtION AZIMUTH LAtitUDE SECTION INCLN, N/-S ft deg deg ft 546,28 30,46 82,26 124,47 571,88 31,45 82.13 127,97 598,22 32,55 83,41 131,30 625,49 34,06 83,43 134,44 653,69 35,19 83,95 137,56 DEPARTURE DISPLACEMENt at AZIMUTH £/-W ft ft deg 531,91 546,28 76,83 557,39 571,89 77.07 583,67 598,26 77.32 610,95 625,56 77.59 639,18 653,82 77.85 DLS deg/ 10Oft 3,97 1,98 2,58 3,02 2,34 2750,00 2800,00 2850,00 2900,00 2950,00 50,0 2604,3I 50,0 2644.00 50,0 2682,95 50.0 2721,00 50,0 2757,97 682.73 36,52 84,19 140,59 712,85 38,36 84,50 143,58 743,91 39,32 84,84 146,49 776,11 41,57 82,10 150,20 809,60 43,06 82.61 154,68 668,31 682,94 78.12 2,67 698,56 713,16 78,39 3,70 729.78 744,34 78,65 1,97 762,00 776,66 78,85 5.73 795,36 810.26 78,?? 3.06 3000,00 3100,00 3200,00 3300,00 3400,00 50,0 2793,27 100,0 2859.07 100,0 2922;68 100,0 2986,9I 100,0 3051,70 844,85 47,12 81,52 159,57 919,89 50,56 80,90 IZI,O? 996.89 50~45 80,01 I83,88 1073,46 49.62 78,40 198,23 1149,6i 49.61 77,60 214,07 830.42 845.61 79,12 8,27 904,81 920,84 79,2? 3,47 980,91 997,99 79,38 0,70 1056,19 1074,63 79,37 1,49 1130.70 1150.78 79,28 0,61 3500,00 3600,00 3700,00 3800,00 3900,0O 100,0 3116,80 I00,0 3183,59 I00.0 3252,45 100,0 3322,56 i00,0 33?3,48 1225,51 49,16 76,96 230,78 I299,93 47,03 76,37 247,94 1372,44 45,?3 75,82 265,36 1443,73 45,03 75,72 282,89 1514,22 44,63 76,00 300,1I 1204,74 1226,65 79,16 0,66 1277,I6 1301,00 79,01 2,17 1347,55 1373,42 78,86 1,17 1416,66 1444,63 78,71 0,90 1485,02 1515,04 78,57 0,45 4000,00 4100.00 4200,00 4300,00 44OO,OO 100,0 3465,01 100.0 3537,32 I00.0 3609,51 100.0 3680,82 100.0 3752,10 1584,10 44,04 76,I1 316,95 1653,18 43,34 76,04 333,58 1722,36 44,22 76,01 350,28 1792,46 44,8I 76,01 367,23 1862,59 44,26 75,34 384,58 1552,85 1584,86 78,46 0,60 1619,89 1653,88 78,36 O,ZO 1687,03 1723,01 78,27 0,88 1755,06 1793,07 78,18 0,59 1823,02 1863,14 78,09 0,72 4500,00 4600,00 4700.00 4800.00 4900,00 I00,0 3823,37 lO0,O 3894,03 I00,0 3963,27 100,0 4031,44 ,vv,u 4099,92 1932,71 44,84 74,88 402,61 2003,43 45,23 74,69 421,i8 2075,53 47,13 74,52 440,34 2148,64 46,92 74,34 459,97 2221,45 46,64 74,63 479,47 1890,81 1933,20 77,98 0,66 1959,09 2003,85 77,87 0,41 2028,64 2075,68 77,75 1,90 2099,13 2148o93 77,64 0,25 2169,34 2221,70 77,54 0,35 5000,00 5100,00 5200,00 5300,00 5400,00 100,0 4168,36 I00,0 4236,97 100,0 4305,80 100,0 4374,28 I00,0 4442,32 2294,32 46,98 74,92 498,61 2367,04 46.37 75,0i 517,49 2439,56 46,65 75,15 536,16 2512,40 46,?0 75,I9 554,81 2585,66 47,36 75.26 573,51 2239,69 2294,52 77,45 0,40 2309,95 2367,20 77,37 0,61 2380,05 2439,70 77,30 0,30 2450.49 2512,51 77,24 0,25 2521,36 2585,76 77,19 0,46 5500,00 5600,00 5700,00 5800,00 5900,00 I00,0 4510,42 100,0 4579,3I 100,0 4648,50 100,0 4717,08 I00,0 4785,09 2658,87 46,79 75,33 592,09 2731,34 46,13 75,73 610,21 2803,53 46,30 75,95 627,87 2876,30 47,11 76,20 645,38 2949,61 47,I8 76,38 662,76 2592,18 2658,95 77,13 2662,37 2731,41 77,0? 2732,37 2803,58 77,06 2803,02 2876,36 77.03 2874,24 2949.66 77,02 0,57 0,72 0,23 0,83 0,15 .,~E NO. 4 .... P2-32- ************* ANADRILL SURVEY CALCULATIOHS ********* CIRCULAR ARC ME?HOD ********** MEASURED IHTERVAL VERTICAL DEPTH D£P?H ft ft ft 6000.00 100.0 4852.75 6100.00 100,0 4920,40 6200,00 100.0 4988.02 6300.00 100.0 5055.65 6400.00 100.0 5123.96 TARGET STATION AZIMUTH LATITUDE SEC?ION IHCLN. ft deg deg ft 3023.25 47.67 76.49 680.03 3096.89 47.18 76.31 6?7.34 3170.56 47.73 76.42 714.71 3244.22 47.16 76.71 731.83 3317.26 46.67 76.56 748.71 DEPARTURE DISPLACEMENT at AZIMUTH ft ft deg 2945.82 3023.29 77.00 3017.40 3096.93 76.99 3088.99 3170.60 76.97 3160.64 3244.26 76.96 3231,70 3317,29 76,96 DLS ~9/ lOOft 0,50 0,51 0,56 0,61 0.50 6450,00 6480,00 6510,00 6540,00 6570.00 50.0 5158.3I 30.0 5179.03 30.0 5199.86 30.0 5220.73 30.0 5241.60 3353.58 46.52 76.52 757.16 3375.28 46.12 76.59 762.21 3396,86 45.92 76,65 767.20 3418.42 45.96 76.78 772.16 3439.97 45.85 76,6? 777,10 3267.02 3353.62 76.95 0.30 3288.I3 3375.31 76.95 1.34 3309,13 3396,90 76,95 0,68 3330,11 3418,46 76,95 0,34 3351.08 3440.00 76.?4 0.43 6600,00 6630,00 6660,00 6690.00 6720,00 30.0 5262.48 30.0 5283.27 30.0 5303.95 30.0 5324.61 30.0 5345.25 3461.51 45.94 76.71 782.06 3483.14 46.35 76.61 787.05 3504,87 46',48 76,48 792,11 3526,63 46,48 76,30 797,22 3548.40 46.59 76.59 602,33 3372.04 3461.54 76.94 0.30 33?3.09 3483.18 76.94 1.39 3414.23 3504.91 76.94 0.54 3435.37 3526.66 76.93 0.44 3456.54 3548.43 76.93 0.79 6750.00 6780.00 6610.00 6840.00 6870.00 30.0 5365.80 30.0 5386.27 30.0 5406.74 30.~ 5427.32 30.0 5447.98 3570.25 46.92 76.75 807.37 3592.19 47.04 77.44 812.26 3614,11 46.8? 77,61 817.00 3635,93 46,46 77,75 621,66 3657.69 46.54 77,76 826,27 3477.80 3570.28 76.93 1.16 3499.18 3592.22 76.93 1.73 3520.59 3614.14 76,93 0.65 3541.91 3635.97 76.94 1.47 3563,18 3657,73 76.94 0,26 6900,00 6?30,00 6?60,00 6990,00 7027,59 30.0 5468.70 30.0 5489.55 30.0 5510,41 30.0 5531.29 37.6 5557.48 3679.38 46.07 77.73 830.68 3700.?5 45.89 77.21 835.56 3722,51 46,01 77,32 840,31 3744,04 45,74 77,17 645,06 3771,01 45.95 76,42 851,23 3584.37 3679.41 76,75 1.57 3605.43 3700.99 76.95 1.38 3626,46 3722,55 76,95 0,47 3647,47 3744,08 76,96 0,97 3673,72 3771,05 76,95 1,54 7121,24 7216,06 7310,23 7404,96 7503,21 93.7 5622.42 ~4.8 5687.95 94.2 5752.76 94.7 5817.58 98.2 5884.83 3836,49 46,25 76,49 867,03 3907.02 46,31 75,95 883,35 3975,32 46,71 78,42 898,50 4044,39 46,95 77.68 912,81 4116,00 46.65 77,56 928,16 3739.33 3838.53 76.95 0.33 3805.88 3907.05 76.93 0.42 3872,49 3975,36 76,94 1,95 3940,08 4044,44 76,96 0,62 4010,04 4116,05 76,?7 0,32 7596,08 7690,92 7785,23 7878,01 7973,01 92.9 5948.55 94.8 6013.00 94.3 6076.82 92.8 6140.17 95.0 6205.53 4183.54 46.71 78.87 941.96 4253.06 47.66 78.95 955.34 4322.45 47.17 78.97 968,64 4390.19 46,71 78.13 982.09 4459,11 46,33 78,24 996,21 4076,18 4183,60 76,99 1,03 4144,45 4253,13 77,02 1,01 4212,60 4322,53 77.05 0.53 427?.04 43?0.2? 77.07 0.82 4346.51 4459.21 77.09 0.41 8068.35 8162.95 8258.15 8353.42 8448.23 95.3 6271.68 94.6 6337.64 95.2 6404.00 95.3 6470.21 94.8 6535.95 4527.77 45.81 76.00 1011.51 4595.57 45.78 76.40 1027.68 4663,84 45.64 76,55 1043,65 4732.33 46,I1 75.59 1060,14 4800,60 46,09 73.75 1078,20 4413.45 4527.~8 77.09 1.78 4479.30 4595.68 77.08 0.31 4545.67 4663.94 77.07 0.13 4612,16 4732.43 77.05 0.78 4678.04 4800.68 77.02 1.40 .,,r., NO, 5 --- .~- P2-32. HEASURED INTERVAL YERTICAL DEPTH DEPTH 8541,95 93.7 6600,94 8637,I7 95,2 6666,81 8731,92 94,8 6732,24 8828.37 96,4 6798,76 8922,69 94,3 6863,54 9018,14 9112,95 9204,41 9301,68 9398,49 9492,53 9585,55 9684,92 9775,41 9862,79 9954,62 I0052,01 10145,86 10238,61 10334,75 I0433,59 10524,78 10622,27 10713,17 10808,80 10902,21 11001,44 11092.09 11185,82 11281,86 11377,75 II472,96 11566,31 11611,56 11661,75 11704,64 11742,71 11776,74 11800,98 I1832,63 ?5,5 6929,t8 94.8 6994.61 91,5 7057,67 97,3 7124.66 96,8 7191,62 94,0 7257,04 93,0 7321,83 99.4 7391,21 90,5 7454,65 87,4 7516,40 91,8 7581,84 97,4 7651,49 93,9 7718,I9 ?2,8 7783.02 96,1 7849,52 98,8 7918,22 91,2 798!,24 97,5 8048,07 90,9 8110,69 95,6 8176,36 93,4 8240,36 ~9,2 8308,88 90,7 8371,27 93,7 8435,08 96.0 8500,30 95,9 8565,54 95,2 8630,41 93,3 8694,15 45,3 8724,06 50,2 8755,68 42,9 8782,17 38,1 8805,42 34,0 8825,85 24,2 8839.96 31,7 8857,6I ************* AHADRILL ************** SURVEY CALCULATIOHS ********* CIRCULAR ARC METHOD ********** TARGET STATIOH AZIHUTH LATITUDE SECTION IHCLN, N/-S ft deg deg ft 4868,04 46.11 73,93 1096,99 4936,68 46,34 72,92 1116.61 5005.14 46,32 74,73 I135,70 5074,93 46.48 74.38 1154.30 5143,42 46,76 74,47 1172,70 DEPARTURE DISPLACEMENT at AZIHUTH E/'W ft ft deg 4742.89 4868,10 76,98 4808,79 4936.73 76,93 4874,61 5005,17 76,89 4941.93 5074,95 76,85 5007,96 5143.44 76,82 5212,66 46,35 73,93 1191,57 5281,23 46.39 75,12 1209,88 5347,45 46,42 75.93 1226,44 5417,97 46,53 75,30 1243,96 5487,87 45,94 76,55 1260,96 5074,65 5212.67 76,79 5140.78 5281,23 76,76 5204,91 5347,45 76,74 5273,23 5417,97 76,73 5341,04 5487,87 76,72 5555,42 45,90 76,88 1276.49 5622.17 45,81 78,00 1291,00 5~93,28 45i64 79,03 1305,17 5757,75 45,32 78,60 1317,68 5819,56 44,75 77,61 1330,43 5406,78 5555,42 76,72 5471,93 5622,17 76,72 5541,66 5693,28 76,75 5604,95 5757,75 76,77 5665,45 5819,56 76,78 5883,97 44,35 77,94 1344,07 5952,03 44,34 76,75 1358,98 6018,05 45.06 76,87 1374.04 6084,39 46,27 77,96 1388.49 6153,80 46.18 77,42 1403,29 DLS deg/ lOOft 0,14 0,80 1,38 0.31 0,3I 6224,86 45.76 76,75 1419,I8 6290,76 46.80 77,40 1433,91 6361,75 46,67 75,92 1450,29 6427,63 46,25 76,19 1466.I7 6497,13 46,99 77,54 1481,96 0,60 0,91 0,64 0,48 1,12 6565,18 46,52 76,27 1497.37 6636,95 46,13 76,80 1514,09 6702,72 46,88 76,96 1529,01 6771,36 47,32 74.63 1545,86 6841,83 47,14 75,64 1563,95 0.26 0,87 0,76 0,50 1,03 6912,09 47.11 75,62 1581,39 6981,77 46,99 75.90 1598,53 7049,97 46,89 76,00 1615,09 7083,?0 50,35 74.00 1623.89 7122,82 51,55 73,21 1634,90 5728,41 5883,98 76,80 0,51 5794,83 5952,04 76,80 0,85 5859,10 6018,06 76,80 0,77 5923,85 6084,40 76,81 1,55 5991,68 6153,82 76,82 0.42 7156,48 52,18 72,50 1644,84 7186,57 52,53 73.80 1653,58 7213,72 53,68 72,5? 1661.45 7233,38 55.I2 72.17 1667,41 7259,59 57,08 73,23 1675,22 6060,95 6224,88 76,82 0,65 6125,18 6290,78 76,82 1,25 6194,25 6361,77 76,82 1,11 6258,20 6427,65 76,81 0,51 6325,88 6497,15 76,82 1,29 6392,16 6565,19 76,82 1,11 6461,96 6636,97 76,81 0,55 6526,00 6702,73 76,81 0,83 6592,55 6771,37 76,80 1,88 6660,69 6841,84 76,79 0,79 6728,77 6912,10 76,77 6796,32 6981,78 76,76 6862,48 7049,98 76,76 6895,27 7083,91 76,75 6932,65 7122,82 76,73 0,04 0,25 0,13 8,33 2,69 6964,89 7156,48 76,71 1,96 6993,74 7186,57 76,70 2,86 7019,78 7213,72 76,68 4,41 7038,57 7233,38 76,67 6,13 7063,66 7259,59 76,66 6,77 .~E NO. ************* ANADRILL SURVEY CALCULATIONS ********* CIRCULAR ARC M£THOD ********** -P2-32 MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft f~ 11864,61 32,0 8874,38 11896,10 31,5 8889,80 11929,43 33,3 8905,15 11960.70 31,3 8918,55 11989.99 29,3 8929,98 TARGET STATION AZIMUTH LATITUDE SECTION IHCLN. H/-S ft de9 deg ft 7286,78 59,65 75,18 1682,63 7314,23 61,72 76,07 1689,44 7343,82 63,44 76,66 1696,42 7372,07 65,83 77,24 1702,79 7399,02 68,20 77,87 1708,60 DEPARTURE DISPLACEMENT at AZIMUTH ft ft deg 7089,85 7286,78 76,65 7116,45 7314,23 76,65 7145,20 7343,82 76,64 7172.72 7372,07 76,65 7199,05 7399,03 76,65 DLS deg/ lOOft 9,58 7,02 5.40 7,81 8,36 12023,71 12054,99 12084,44 12117.78 12159,93 33,7 8941,68 31,3 8951,00 29,5 8958,33 33,3 8964,82 42,1 8970,81 7430,64 71,20 79,14 1714,90 7460.46 74,10 78,73 1720,63 7488,97 77,10 79,23 1726,08 7521,63 80,42 79,25 1732,19 7563,30 83,24 79,45 1739,90 7230,04 7430,64 76,66 7259,33 7460,46 76,67 7287,34 7488,97 76,67 7319,46 7521,63 76,69 7360,45 7563,30 76,70 9,57 9,35 10,32 9,96 6,71 12201,00 12259.10 12282,60 12323.00 12354,50 41,1 8974.69 58,1 8977,58 23,5 8978,09 40.4 8978,76 31,5 8979,07 7604,15 85,90 78,70 1747,64 7662,15 88,40 77,63 1759,54 7685,64 89,10 77,20 1764,66 7726,04 89,00 76,90 1773,72 7757,53 89,90 77,60 1780,67 7400,59 7604,15 76.71 7457,38 7662,15 76,72 7480.31 7685,64 76,73 7519,68 7726,04 76,73 7550,40 7757,53 76,73 6,72 4,68 3,49 0,78 3,62 12379,80 12417,10 12448,00 12480,60 12512,10 25,3 8978,91 37,3 8978,46 30,9 8978.37 32,6 8978,60 31,5 8979,07 7782,82 90,80 78,40 1785,93 7820.1I 90.60 77,60 1793,68 7851.00 89,70 78.10 1800,19 7883.59 89,50 78,10 1806,91 7915,08 88,80 78,30 1813,35 7575.15 7782,83 76,73 4,76 7611,63 7820,11 76,74 2,21 7641,84 7851,01 76,74 3,33 7673,73 7883,60 76,75 0,60 7704,57 7915,08 76,76 2,31 12543,90 12574,70 12600,60 12627,50 12653,60 31,8 8979.99 30,8 8981,36 25,? 8982,64 26,? 8983,68 26,1 8984,47 7946,85 87,90 78,30 1819,79 7977.62 87,00 77,60 1826,22 8003.47 87,30 79,00 1831,46 8030,34 88,30 78,30 1836,75 8056,41 88,20 78,30 1842,04 7735,69 7946,86 76,76 2,83 7765.78 7977.62 76,77 3.70 7791,11 8003,48 76,77 5,52 7817,47 6030,35 76,78 4,53 7843,01 8056,42 76,7~ 0,34 12689,20 12721,30 12752,30 12784,70 12815.80 35.6 8985,44 32,1 8986,08 31,0 8986,65 32,4 8987,21 31,1 8987,70 8091,98 88,70 79,00 !849,05 8124,05 89,00 78,?0 1855,20 8155,01 88,90 79,70 1860,95 8187,35 89,10 80.50 1866,52 8218,38 89,10 80,40 187i,68 7877.90 8091,99 76,79 2,41 7909,40 8124,06 76,80 7?39,86 8155,03 76,81 2.60 7971,77 8187,37 76,82 2,55 8002,43 8218,40 76,84 0,32 12845,10 12877,20 12906.80 12942,20 12971.90 29,3 8988,01 32,1 8988.40 2?°6 8989,13 35,4 8990,42 29,7 8991,79 8247,59 89,70 81,50 1876.29 6279,60 88,?0 80,40 1881.34 8309,12 88,30 81,10 1886,10 8344,41 87,50 80,40 189!,78 8374,01 87.20 80,40 1896,73 8031,37 8247,63 76,85 4.27 8063,07 8279,64 76,87 4.24 8092,27 8309,16 76,88 3,11 8127,19 8344,46 76,90 3,00 8156,44 8374,07 76,91 1,01 13004,60 13034,80 13068,40 13101,60 13130,00 32,7 8993,45 30,2 89?4,48 33,6 8994,71 33,2 8994,91 28,4 8995.51 8406,60 87,00 80,40 1902,18 8436,71 89,10 81,10 1907,03 8470,i9 90,10 81,80 1912,02 8503,27 89,20 81,10 1916,96 8531,58 88,40 8I,i0 1921,35 8188,64 8406;67 76,92 0,61 8218,43 8436,78 76,94 7,33 8251,65 8470,28 76,95 3,63 8284,48 8503,38 76,97 3,43 8312,54 8531.70 76,99 2,81 SURVEY CALCULATIONS MEASURED INTERVAL V£RTICAL TARGET STATION AZIMUTH LATITUDE D£PARTUR£ DISPLACEMENT at AZIMUTH DLS DEPTH DEPTH SECTIDH IHCLH, H/-S £/-W de9/ ft ft ft ft de~ de§ ft ft ft de~ lOOft 13164,60 34,6 8996,41 8566,04 88,60 82,00 1926,43 8346.75 8566,17 77,00 2,66 13196,80 32,2 8997.00 8598,09 89,30 82,50 1930,78 8378.65 8598,23 77,02 2,67 13226,10 29,3 8997,18 8627,24 90,00 82,50 1934,60 8407,70 8627,40 77,04 2,39 13261,70 35,6 8?97.43 8662.65 89,20 82,50 1939,25 8442,99 8662,84 77,06 2,25 13293.10 31,4 8998,03 8693,89 88,60 82,50 1943,34 8474.I2 8694,09 77,08 1,91 13322,10 2?,0 89?8,79 8722,71 88,40 83,20 1946,95 8502,88 8722,94 77,10 2,51 SURVEY PROJECTED TO TD 13395,00 72.? 9000,83 8795,11 88,40 83,20 1955,58 8575,24 8795,40 77,15 0,05 PAGE NO. ANADRILL SCHLUMBERGER *********** SURV£¥ ANALYSIS COMPANY SHARED SERVICES DRILLINg WELL NAME P2-32 HORIZONTAL SIDETRACK LOCATION I PT, MclNTYRE LOCATION 2 NSB~ ALASKA DATE: 28-SEP-95 MAGNETIC DECLINATION 28,37 GRID CONVERGENCE ANGLE APl NUMBER 500292259300 APE NUMBER 2C0074 JOB NUMBER 36548 ..~E NO. 2 ft TVD INC CNG -- ft deg 0,0 0,00 0,00 100,0 100,00 0,46 200,0 199,99 0,39 300,0 299,99 -0o64 400,0 399.99 0,29 500,0 499,98 0,29 600,0 599,98 -0,64 700,0 699,97 0,72 800,0 799,93 1,48 900,0 899,71 2,73 1000,0 1050,0 I100,0 1150,0 1200,0 1250,0 1300,0 1350,0 1400,0 1450,0 1500,0 1550,0 1600,0 1650,0 1700,0 1750.0 1800.0 1850.0 I900.0 1950.0 2000.0 2050,0 2100,0 2150.0 2200.0 999,00 3,44 1048.41 0,58 1097,63 2,00 1146.63 0.75 1195,44 1,30 I244.00 1,29 1292,24 1,60 1340,19 0,84 I388,08 -0,34 1436,05 -0,30 1484.0i 0,36 1531.98 -0.38 1579.91 0.62 1627,73 0,30 1675,48 0,24 1723,04 1,15 1770.34 0,81 1817,20 2.10 1863.35 2.36 I908.76 1,87 I953,62 1,06 1996,26 0,10 2042.87 0,02 2087.33 0.78 2131,6I 0,11 2250,0 2175,74 0,59 2300,0 2219,8I -0,28 2350,0 2264,01 -0,34 2400.0 2308.14 0,67 2450,0 2352,07 0,25 ************* ANADRILL ************** SURVEY ANALYSIS ********* CIRCULAR ARC I~E?HOD ********** CU~INC_CHG deg I_RA?~ AZH.CHG CU~AZ~_CNG deg/lOOft de§ deg ?URN_RATE deg/lOOft 0,00 0,00 0,00 0,00 0,00 0,46 0.46 78,75 78.75 78,75 0,85 0.39 -9,03 69,72 -9,03 0,21 -0,64 -19o02 50,70 -19,02 0,50 0,29 52,52 103,22 52,52 0,79 0,29 -43,91 59,31 -43,91 0,15 -0,64 -19,95 39,36 -19,95 0,87 0,72 50,89 90,25 50,89 2,35 1,48 -18.96 71,29 -18,96 5,08 2,73 -3,58 67,71 -3,58 8.52 3,44 10,65 78,36 I0,65 9,10 1,16 3,11 81,47 6,22 I1.I0 4,00 4,84 86,31 9,68 11,85 1.50 1.42 87,73 2,84 13,15 2.60 -2o43 85.30 -4,86 14,44 2,58 2,25 87,55 4,50 16,04 3,20 -2,90 84,65 -5,80 16.88 1.68 -0,82 83.63 -I.64 16.54 -0.68 0.32 84,15 0,64 16,24 -0.60 -0.40 83,75 -0,80 16.60 0,72 -1,97 81.78 -3,94 16,22 -0,76 -5,62 76.16 -11,24 I6.84 1,24 -3.I1 73,05 -6,22 17,14 0.60 -0.71 72.34 -1,42 IZ,38 0,48 0,64 72,98 1,28 18.53 2.30 -1.77 71.21 -3,54 19.34 1,62 -0.67 70,54 -1,34 21.44 4.20 0.56 71.10 1.12 23.80 4.72 0.13 71,23 0.26 25,67 3,74 0,46 71,69 0,92 26,73 2,12 -0,33 71.36 -0,66 26,83 0.20 1,73 73,09 3,46 26,85 0,04 -0,55 72,54 -1,10 27,63 1,56 1,1I 73,65 2,22 27,74 0,22 0,25 74,40 1,50 28,33 1,18 1,11 75,5I 28.05 -0,56 2.02 77,53 27.7I -0,68 2.49 80.02 28.38 1,34 -0,28 79,74 28,63 0,50 0,97 80,71 2,22 4.04 4,98 -0.56 1,94 P2-32. CLOSURE TOOL FACE DLS DLSRT ft deg deg/lOOft 0o00 0,00 0,00 0,00 -0,01 90,00 0,46 0,46 0,06 19,30 0,40 0,06 0,23 174,32 0,65 0,25 0,00 0.00 - 0,41 0,25 0,13 82,74 0,55 0,15 0,41 174,73 0,65 0,10 0,31 59,38 0,78 0,13 0,33 29.34 1,55 0.77 0,12 75.78 2,74 1,19 1,69 25,47 3,65 0,91 1,25 40,85 1,50 4,30 0,12 25.37 4,34 5,69 -1,67 21,29 1,60 5,48 1,21 6,62 2,80 2,40 -5,53 23,64 2,79 0,02 -7,66 26,86 3,54 1,50 -9,52 15,81 1,74 3,60 -11.35 164,68 0.7I 2.07 -3,50 23.20 0,64 0,13 -14,62 58.01 1,32 1,37 -15,19 106.15 3,26 3,88 -14.67 56,48 2.16 2,21 -13.65 35.01 0,73 2,86 -13.13 160.03 0,61 0.23 -11,37 26,24 2,55 3,87 -9,72 15,34 1,68 1,74 -7,94 5.57 4,22 5.08 -6.09 1.44 4,72 1,01 -12.61 38,75 3,76 1.92 -2.20 7,94 2,14 3,24 -0,45 83.46 1,57 1,14 1,08 85,65 0,50 2,14 2.51 33,58 1.86 2.73 -4,19 6,10 0,73 2,26 4,30 41,98 1,58 1,69 4.37 107,24 1,99 0.83 3,52 107,38 2,43 0.87 2,22 10.95 1,36 2,12 3,59 72,81 1,05 0,63 .,SE NO. 3 ---. _:. ?2-32 *~*********** ANADRILL ************** SURVEY ANALYSIS ********* CIRCULAR ARC M£THOD ********** ~D f~ ft INC CHG deg CUMINC CHG I RAT£ AZM CNGCUMAZM CHG TURN RATE deg deg/lOOft deg deg deg/lOOft CLOSURE TOOL FACE DLS DLSRT ft deg deg/lOOft deg/IOOft**2 2500,0 2550,0 2600,0 2650,0 2700,0 2395,57 2438,45 2480,85 2522,64 2563.78 1,83 0,99 1,10 1,51 1,13 30.46 3.66 1.55 82.26 3.10 31.45 1.98 -0.i3 82.13 -0.26 32,55 2,20 1,28 83,41 2,56 34,06 3,02 0,02 83,43 0,04 35,19 2.26 0,52 83,95 1,04 -1,32 23,35 3,97 5,83 -3,79 3,80 1,98 3,96 -6,60 32,20 2,58 1,20 -9,82 0,00 3,02 0,87 0,75 62,03 - 2,34 1,37 2750,0 2800,0 2850,0 2900,0 2950,0 2604,31 2644,00 2682,95 2721,00 2757,97 1,33 1,84 0,96 2,25 1,49 36.52 2.66 0.24 84.19 0.48 38.36 3.68 0.31 84.50 0.62 39,32 1,92 0,34 84,84 0,68 41o57 4,50 -2.74 82,10 -5,48 43,06 2,98 0,51 82,61 1,02 -17,05 6,06 2,67 0,68 -21,10 5,99 3,70 2,05 -25,45 12,77 1,97 3,46 -29,26 39,36 5,73 7,53 -13,28 14,80 3,06 5,35 3000.0 2793,27 4,06 47,12 8,12 -I,09 81,52 -2,18 3100,0 2859,07 3,44 50,56 3,44 -0,62 80,90 -0,62 3200,0 2922,66 -0,I1 50,45 -0,11 -0,89 80,01 -0,89 3300,0 29~.91 -0,83 49,62 -0,83 -1.61 78.40 -1,61 3400.0 3051.70 -0.01 49.61 -0.01 -0.80 77.60 -0.80 -35,89 11,15 8,27 10,41 -41,81 7,93 3,47 4,79 -46,88 99,38 O,ZO 2,78 -50,25 124,44 1,49 0,79 -32,59 13,15 0,61 0,88 3500,0 3116,80 -0,45 49,16 -0,45 -0,64 76,96 -0,64 3600,0 3183,59 -2,13 47,03 -2,13 -0,59 76.37 -0,59 3700,0 3252,45 -I,10 45,93 -I,10 -0,55 75,82 -0,55 3800,0 3322,56 -0.?0 45,03 -0,90 -0,10 75,72 -0,10 3900,0 3393,48 -0,40 44.63 -0.40 0,28 76,00 0.28 -52.77 133.00 0.66 0.05 -52.75 168.56 2.17 1.51 -52.00 160,29 1,17 1,00 -50,85 175,44 0,90 0,27 -51,99 91,20 0,45 0,46 4000,0 4100.0 4200,0 4300,0 44O0,O 3465,01 -0,59 44,04 -0,59 0,11 76,11 3537,32 -0,70 43,34 -0,70 -0,07 76,04 3609,51 0,88 44,22 0,88 -0,03 76,01 3680,82 0,59 44,81 0,59 0,00 76,01 3752.10 -0.55 44.26 -0.55 -0,67 75.34 0,11 -49,06 172,51 0,60 0,15 -0,07 -48,32 176,41 0,70 0,11 -0,03 -47,51 1,47 0,88 0,18 0,00 -46,68 1,39 0,5? 0.29 -0.67 -49.83 153.76 0.72 0.13 4500,0 4600,0 4700,0 4800,0 4900,0 3823,37 0,58 44,84 0,58 -0,46 74,88 -0,46 3894,03 0,39 45,23 0.3? -0,19 74,69 -0,I? 3963,27 1,90 47,13 1,90 -0,17 74,52 -0,17 4031,44 -0,21 46.92 -0.21 -0,18 74,34 -0,18 409?,?2 -0,28 46,64 -0,28 0,29 74,63 0,2? -43.50 29.I8 0.66 0,06 -41,15 19.12 0,41 0.25 -38,53 3.74 1,90 1,49 -35,64 148,26 0,25 1,66 -45,44 139,76 0,35 0,10 5000,0 5100,0 5200,0 5300,0 5400,0 4168,36 0,34 46,98 0,34 0,29 74.92 4236,97 -0,61 46,37 -0,61 0,09 75,01 4305,80 0,28 46,65 0,28 0,14 75,15 4374,28 0,25 46,90 0,25 0,04 75,19 4442,32 0,46 47,36 0,46 0,07 75,26 0,29 0,09 0,14 0,04 O,OZ -30,40 31,?0 0,40 0,05 -28,21 173,84 0,61 0,21 -26,17 I9,74 0,30 0,32 -24,24 6,83 0,25 0,05 -32,84 143,11 0,46 0,21 5500,0 5600,0 5700,0 5800,0 5900,0 4510,42 -0,57 46,79 -0,57 0,07 75,33 4579,21 -0,66 46,13 -0,66 0,40 75,73 4648,50 0,17 46,30 0,17 0,22 75,95 4717,08 0,81 47,11 0,81 0,25 76,20 4785,09 0,07 47,18 0,07 0,18 76,38 0,07 0,40 0,22 0.25 0,18 -20,58 175,24 0,57 0,11 -19,11 156,4I 0,72 0,15 -18,04 42,84 0,23 0,49 -17.26 12.75 0,83 0.60 -22,37 6,66 0,15 0,68 .~£ HO. 4 --- r P2'32 ************~ ANADRILL SURUEY ANALYSIS CIRCULAR ARC METHO0 MD TUD INC CHG CUMINC CHG ft ft deg deg 6000,0 4852,75 0,49 6100,0 4920,40 -0,49 6200,0 4988,02 0,55 6300,0 5055,65 -0,57 6400.0 5123,96 -0,49 I_RATE AZM.CHG CUMAZM_CNG TURN_RATE deg/lOOft deg de9 deq/1OOft 47,67 0,49 0,11 76,49 0,I1 47,18 -0.49 -0,I8 76,31 -0.18 47.73 0,55 0,11 76,42 O,ll 47,16 -0,57 0,29 76.71 0,2? 46.67 -0,49 -0.15 76,56 -0,15 CLOSURE TOOL.FACE OLS DLSRT ft deg deg/lOOft deg/lOOft**2 -16,42 9.35 0,50 0,35 -16,05 164.99 0,51 0,01 -15,63 8,23 0,56 0.05 -15,47 159,62 0,61 0,05 -16,75 61,84 0,50 O,11 6450,0 5158,31 -0,15 6480,0 5179,03 -0o40 6510,0 5199,86 -0.20 6540,0 5220,73 0,04 6570,0 5241,60 -0.11 46,52 :0,30 -0,04 76,52 -0,08 46.I2 -I,33 0,07 76.59 0,23 45,92 -0,67 0.06 76,65 0,20 45,96 0,13 0,I3 76,78 0,43 45,85 -0,37 -0,09 76,69 -0.30 -15,31 170,81 0,30 0,40 -15,26 172,49 1,34 3,47 -15,23 169,12 0,68 2,22 -15,24 66,68 0,34 1,14 -15,40 167,69 0,43 0,32 6600,0 6630,0 6660,0 6690,0 6720,0 5262,48 0,09 5283,27 0,41 5303,95 0,13 5324,61 0,00 5345,25 0,i1 45,94 0,30 0,02 76,71 0.07 46,35 1,37 -O,lO 76,61 -0,33 46,48 0,43 -0,13 76,48 -0,43 46,48 0,00 -0,I8 76,30 -0,60 46,59 0.37 0,29 76,59 0,97 -15,26 6,92 0,30 0,43 -15,25 I0,07 1,39 3,62 -15,19 36,64 0,54 2,83 -15.08 90,06 0,44 0,34 -15,26 148,02 0,79 1.19 6750,0 5365,80 0,33 6780,0 5386,27 0.12 6810,0 5406,74 -0.15 6840,0 5427,32 -0,43 6870,0 5447,98 0,08 46,92 1,10 0,16 76,75 47,04 0,40 0,69 77,44 46,89 -0,50 0,17 77,61 46,46 -1,43 0,14 77,75 46,54 0,27 0,01 77,76 0,53 2,30 0,57 0,47 0,03 -14,98 19,25 1,16 1,24 -15,13 76,83 1,73 1,87 -15,45 140,76 0,65 3,60 -15,83 166.7I 1,47 2,76 -14.99 62,60 0,26 4,03 6900,0 5468,70 -0,47 6930,0 5489,55 -0,18 6960,0 5510,41 0.12 6990,0 5531,29 -0,27 7027,6 5557,48 0,2I 46,07 -1,57 -0,03 77,73 -0,I0 45,89 -0,60 -0,52 77,21 -1,73 46,0I 0,40 0,1I 77,32 0,37 45,74 -0,90 -0,15 77,17 -0,50 45,?5 0,56 -0,75 76,42 -2,00 -16,63 178,20 1,57 4,35 -16,93 I15,92 1,38 0,62 -17,14 30,?6 0,47 3,05 -17,35 158,27 0,97 1,68 -16,23 0,00 1,54 1,51 7121,2 7216,! 7310,2 7405,0 7503,2 5622,42 0,30 5687,95 0,06 5752,76 0,40 5817,58 0.24 5884,83 -0,30 46,25 0,32 0,07 76,49 0,07 46,3I 0,06 -0,54 75,95 -0,57 46,71 0,42 2,47 78,42 2,62 46,95 0,25 -0,74 77,68 -0,78 46,65 -0,30 -0,12 77.56 -0,12 -17,13 9,93 0,33 1,29 -16,56 81,44 0,42 0,10 -17,16 78,27 1,95 1,63 -18,80 66,30 0,62 1,40 -17,40 68,96 0,32 0,31 7596,t 7690,? 7785,2 7878,0 7973,0 5948,55 0,05 6013,00 6076,82 -0,50 6140,17 -0,46 6205,53 -0,38 46,71 0,06 1,31 78,87 1,41 47,66 1,01 0,08 78,95 0,08 47,17 -0,53 0,02 78,97 0,02 46,71 -0,49 -0,84 78,13 -0,91 46,33 -0,40 O,ll 78,24 0,12 -21,76 87,31 1,03 0,77 -24,45 3,78 1,01 0,02 -27,20 176,79 0,53 0,51 -29,41 126,91 0,82 0,32 -19,% 163,I3 0,41 0,44 8068,4 6271.68 -0,52 8162,9 6337,64 -0,04 8258,2 6404,00 0,06 8353,4 6470,2I 0.27 8448,2 6535,95 -0.03 45,81 -0.54 -2,24 76,00 -2,35 45.78 -0,04 0,40 76,40 0,42 45,84 0,07 0,15 76,55 0,16 46,11 0.29 -0,96 75.59 -1,0I 46.09 -0,03 -1,84 73,75 -1,94 -31,72 108,61 1,78 1,44 -31,15 97,38 0o31 1,56 -30,89 58,87 0,13 0.19 -30,I5 68,76 0,78 0,68 -31.20 168,49 1,40 0,65 rAGE NO, 5 ~ P2-32 ************* ANADRILL ************** SURVEY ANALYSIS ********* CIRCULAR ARC METHOD ********** ~D ft ft INC CNG deq CUHINC CHC I RATE AZM CHG CU~AZM CNG TURN de9 deg/tOOft deg de9 deg/lOOft CLOSURE TOOL FACE DLS DLSRT ft de9 deg/lOOft de~/lOOft**2 8541,9 8637,2 8731,9 8828,4 8922,7 6600,94 6666,81 6732,24 6798,76 6863,54 0,02 0,23 -0,02 0,15 0,28 46,11 0,02 0,18 73,93 0,19 46,34 0,25 -1.01 72,92 -1,06 46,32 -0.02 1,81 74,73 1,91 46,48 0,16 :-0,35 74,38 -0.36 46.76 0.30 0,09 74,47 0,10 -24,38 80.99 0,14 1.34 -20,46 72,56 0,80 0,70 -I7,04 91,56 1,38 0.61 -14,44 58,81 0,31 1,11 -27,74 91,74 0,31 0,00 9018,1 9113,0 9204,4 9301,7 9398,5 6929.18 -0,41 46,35 -0,43 -0,54 73,93 -0,57 6994,61 0.04 46.39 0.05 1,19 75,12 1,26 7057.67 0,03 46,42 0,03 0,81 75,93 0,89 7124,66 0.11 46,53 0,12 -0,63 75,30 -0,65 7191,62 -0,59 45,94 -0,61 1,25 76,55 1,29 -8,72 136,79 0,60 0,30 -6,13 87,50 0,91 0,33 -4,78 87,38 0,64 0,29 -3,46 76,26 0,48 0.16 -11,73 12,99 1,12 0,65 9492,5 9585,5 9684,9 9775,4 9862,8 7257,04 -0,04 45,90 -0.04 0,33 76.88 0.35 7321,83 -0,I0 45,8i -0,10 1,!2 78,00 1,20 7391,21 -0,16 45,64 -0,I6 1,03 79,03 1,04 7454,65 -0,33 45,32 -0,36 -0.43 78,60 -0,48 7516,40 -0,56 44,75 -0.64 -0,99 77,61 -1,I3 -2,55 98,96 0,26 0,92 -3,42 97,21 0,87 0,66 -5,69 102,70 0.76 0oll -8,08 137,08 0.50 0,29 -2,52 123,75 1,03 0,61 9?54,6 10052,0 10145,? I0238,6 10334,8 7581,84 -0,40 44,35 -0,44 0,33 77,94 0,36 7651,49 0,00 44,34 0,00 -1,19 76,75 -1,22 7718,19 0,72 45,06 0,76 0,12 76,87 0,13 7783,02 1,21 46,27 1,31 1,09 77,96 1,18 7849,52 -0,09 46,18 -0,09 -0,54 77,42 -0,56 -10,83 150,40 0,51 0,57 -11,61 90,76 0,85 0,36 -11,74 6,57 0,77 0,09 -12,59 33,12 1,55 0,85 -9,61 129,07 0,42 1,18 10433,6 10524,8 10622,3 10713,2 10808,8 7918,22 -0,42 45,76 -0,43 -0,67 76,75 -0,68 7981,24 1,03 46,80 1,13 0,65 77,40 0,71 8048,07 -0,13 46,67 -0,13 -1,48 75,?2 -1,52 8110,69 -0,42 46,25 -0,46 0,27 76,19 0,30 8176,36 0,74 46,99 0,78 1,35 77.54 1,41 -14,29 131,45 0,65 0,23 -14,74 24,66 1,25 0.65 -14,70 97,33 1,11 0,14 -13,97 154,90 0,51 0,67 -13,80 103,07 1,29 0,82 10902,2 11001,4 ii092,1 11185,8 11281,9 8240,36 -0,47 46,52 -0,50 -1,27 76,27 -1,36 8308,88 -0,39 46,13 -0.39 0,53 76,80 0,53 8371,27 0,75 46,88 0,82 0,16 76,?6 0,18 8435,08 0,44 47,32 0,47 -2,33 74,63 -2,49 8500,30 -0,18 47,14 -0,19 1,01 75,64 1,05 -14,45 117,40 1,11 0,19 -14o25 135,46 0,55 0,57 -14,47 8,98 0,83 0,31 -13,40 76,36 1,88 1.12 -14,19 53,34 0,79 1,13 11377,8 11473,0 11566,3 11611,6 11661,8 8565,54 -0,03 47,1I -0,03 -0,02 75,62 -0,02 8630,41 -0,12 46,99 -0,13 0,28 75,90 0,29 8694,15 -0,10 46,89 -0,11 0,10 76,00 0,11 8724,06 3,46 50,35 7,64 -2,00 74,00 -4,42 8755,68 1,20 51,55 2,39 -0,79 73,21 -1,57 -10,18 151,11 0,04 0.79 -9.05 120,46 0,25 0,22 -8,17 145,12 0,13 0,13 -7,15 24,12 8,33 18,12 -11,48 I03,98 2,69 I1,24 11704,6 11742,7 I1776,7 11801,0 11832,6 8782,17 0,63 52,18 1,47 -0,71 72,50 -1,66 8805,42 0,35 52,53 0,92 1,30 73,80 3,41 8825,85 1,15 53,68 3,37 -1,21 72,59 -3,56 8839,96 1,45 55.12 5,97 -0,42 72,17 -I,73 8857,61 1,95 57,08 6,17 1,06 73,23 3,35 -2,79 41,82 1,96 1,70 -0,93 71,53 2,86 2.35 0,73 40,54 4,41 4,57 2,21 13,41 6,13 7,10 -5,05 27,30 6,77 2,0I MD ft 11864,6 11896,1 11929,4 11960,7 11990,0 12023,7 12055,0 12084,4 12117,8 12159,9 12201,0 12259.1 12282.6 12323,0 12354,5 .~ NO. 6 TVD INC_CHG ft deg 8874,38 2.57 8889,80 2,07 8905,15 1,72 8918,55 2,39 8929,98 2,38 8941,68 3,00 8951,00 2.90 8958,33 3,00 8964,82 3,32 8970,81 2,82 8974,69 2,66 8977,58 2,50 8978,09 0,70 8978,76 -0,10 8979,07 12379,8 8978,91 0,90 12417,1 8978,46 -0,20 12448,0 8978,37 -0,90 12480,6 8978,60 -0,20 12512,i 8979,07 -0,70 12543,9 12574,7 12600.6 12627,5 12653,6 12689,2 12721,3 12752,3 12784,7 12815,8 8979,99 -0,90 8981,36 -0,90 8982,64 0,30 8983,68 1.00 8984,47 -0.10 8985,44 0,50 8986,Q8 0.30 8986,65 -0,I0 8987,21 0,20 8987,70 0,00 12845,1 8988,01 0,60 12877,2 8988,40 -0,80 12906,8 8989,I3 -0.60 12942,2 8990,42 -0,80 12971,? 8991,79 -0.30 13004,6 8993,45 -0,20 13034,8 8994,48 2,10 13068,4 8994,71 1,00 13101,6 8994,9I -0o90 13130.0 8995,51 -0.80 ************* ANADRILL ************** SURV£¥ ANALYSIS ********* CIRCULAR ARC METHOD ********** CU~INC_CHG I_RATE AZM.CNG CUMAZM.CHG TURN RATE de9 deq/lOOft deq deg deg/~OOft 59.65 8,05 1,95 75,18 6.I0 61,72 6,57 0,89 76,07 2,B3 63,44 5,17 0,59 76,66 1,77 65,83 7,63 0,58 77,24 1,84 68.20 8,12 0,63- 77,87 2,17 71,20 8.89 1,27 79,14 3,77 74,10 9.27 -0,41 78,73 -1.30 77,10' 10.19 0,50 79,23 1.69 80,42 9,96 0,02 79,25 0,05 83,24 6,69 0,21 79,45 0.49 85,90 6,47 -0,75 78,70 -I,84 88,40 4,30 -1.07 77,63 -1,84 89,I0 2,98 =0,43 77,20 -1,83 89,00 -0,25 -0,30 76,?0 -0,74 89,90 2,86 0,70 77,60 2,22 90.80 3,56 0,80 78,40 3.16 90,60 -0,54 -0,80 77.60 -2,14 89,70 -2,91 0,50 78,10 1,62 89.50 -0.61 0,00 78,10 0.00 88,80 -2,22 0,20 78,30 0,63 87,?0 -2,83 0,00 78,30 0,00 87,00 -2,92 -0.70 77,60 -2,27 87,30 1,16 1,40 79,00 5,41 88,30 3,72 -0,70 78,30 -2,60 88,20 -0,38 0,00 78,30 0.00 88,70 1,40 0,70 79,00 1,97 89,00 0,93 -0,10 78,90 -0,31 88.90 -0,32 0,80 79,70 2,58 89,10 0,62 0.80 80,50 2,47 89,10 0,00 -0,10 80,40 -0,32 89,70 2,05 1,10 81,50 3,75 88,90 -2,49 -1,10 80,40 -3,43 88,30 -2,03 0,70 81.10 2,36 B7,50 -2,26 -0,70 80,40 -1,98 87,20 -1o01 0,00 80,40 87,00 -0,61- 0,00 80,40 0.00 89,10 6,95 O,ZO 81,10 2,32 90,10 2,98 0.70 81.80 2,OB 89,20 -2,71 -0,70 81,10 -2,11 88,40 -2.82 0o00 81,10 0,00 ~. P2-32 CLOSURE TOOL_FACE DLS DLSRT ft de9 deg/lOOft deq/lOOft**2 5,ZI 33,34 9,58 8,80 5,72 20,78 7,02 8,14 5,88 17.06 5,40 4,85 5,75 12,42 7,81 7,71 4,03 24,56 8.36 1,86 4,34 21,88 9.57 3,59 3,17 7,67 9,35 0,69 2,03 9,16 i0,32 3,29 0,58 0,00 9.96 1,09 5,35 13,93 6,71 7,Zl -3,06 15,83 6,72 0,02 -4,55 23,17 4,68 3,5I -4,85 31.47 3,49 5,05 -5.10 108,49 0,78 6,71 -1,36 4,17 3,62 9,0I -5,99 41,62 4,76 4,51 -6,84 104,04 2,21 6,83 -7,47 I51,01 3,33 3,62 -8,27 0,00 0,60 8,37 -5,41 37,86 2,31 5,42 -9,99 0,00 2,83 1,63 -10,67 142,21 3,70 2,83 -11,40 77,92 5,52 7,04 -12,32 34,95 4,53 3,67 -9,I0 164,37 0,34 16,08 -14,27 54,44 2,41 5,83 -15,53 17,19 0,98 4,47 -16,94 97,14 Z,6O 5,22 -18,87 75,97 2,55 0,16 -13,05 0,00 0,32 7,16 -23,09 61,38 4,27 13,50 -25,47 126,04 4,24 0,12 -27,57 130,64 3,i1 3,80 -30,07 138,89 3,00 0,32 -20,9I 90,00 1,0I 6,71 -34,10 0,00 0,61 1,22 -36,24 18,41 7.33 22,25 -39,03 34,98 3,63 11,00 -41,78 142,15 3,43 0,60 -31,99 0,00 2,81 2,19 SURV£¥ ANALYSIS CIRCULAR ARC P2-32 MD TUD IHC_CHG CUMINC_CHG I.RAT£ AZM.CHG CUMAZM_CHG TURH_RATE ft ft deg deg deg/lOOft deg deg deg/lOOft CLOSURE TOOL FACE DL$ DLSRT ft de9 deg/lOOft de~/iOOft*~2 13164,6 8996,41 0,20 88,60 0.58 0,90 82,00 2,60 -46.g0 77o47 2,66 0,43 13196,8 8997,00 0,70 89,30 2.17 0,50 82,50 1,55 -50.02 35,50 2,67 0,02 13226.1 8997,18 0,70 90.00 2,39 0,00 82,50 0.00 -52,98 0,00 2,39 0.96 13261,7 8997,43 -0.80 89.20 -2.25 0,00 82,50 0,00 -56,57 0,00 2,25 0,40 13293,1 8998,03 -0,60 88,60 -l,gl 0,00 82,50 0,00 -43,~7 0,00 1,91 1,07 13322,1 8998,79 -0,20 88,40 -0,69 0,70 83,20 2,41 -62,88 105,77 2,51 2,06 SURVEY PROJECTED TO TO 13395,0 9000,83 0,00 88,40 0,00 0,00 83.20 0o00 -71,14 90,00 0,05 3,37 B.P. EXPLORATION POINT MclNTYRE P2-32 NORTH SLOPE, ALASKA Gyro Multishot Survey in 5" Drillpipe Survey date' 11 September, 1995 Job number' AK0995G293 ORIGINAL Date.~~~ --__ SR293.DOC gyro/data CONTENTS JOB NUMBER :AK0995G293 t. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR293.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR293.DOC gyro/data' DISCUSSION JOB NUMBER: AK0995G293 Tool 080 was run in P2-32 on ATLAS 7/32" Wireline inside 5" Drillpipe. without problems. The survey was run SR293.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0995G293 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR293.DOC gyro/data' 2. SURVEY DETAILS SR293.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0995G293 CLIENT: B.P. EXPLORATION RIG: POOL 7 LOCATION: POINT MclNTYRE WELL: P2-32 LATITUDE: 70.37500 LONGITUDE: W SURVEY DATE: SURVEY TYPE : DEPTH REFERENCE: MAX. SURVEY DEPTH: 11 -Sept, 1995 MULTISHOT IN 5" drillpipe ROTARY TABLE EVELATION 55.0 asl 6990 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100'and 30'open hole UTM CO-ORDINATES: TARGET DIRECTION: 76.69 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR293.DOC gyro/data~ 3. OUTRUN SURVEY LISTING SR293.DOC A Gyro da t a D i r e c t i o na i Survey for PRUDHOE BAY DRILLING WELL: POINT MCINTYRE P2-32 Location: POOL RIG #7, NORTH SLOPE, ALASKA Job Number: AK0995G293 Run Date: ll-Sep-95 00:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.375000 deg. N Sub-sea Correction from Vertical Reference: 55 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction- 76.690 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A" G y r e d a t a D i r e c t i o n a i S u r v e y PRUDHOE BAY DRILLING WELL: POINT MCINTYRE Location: POOL RIG #7, Job Number: AK0995G293 P2 -32 NORTH SLOPE, ALASKA MEASURED I DEPTH feet N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -55.0 0.00 0.0 0.0 0 - 6990 FT. GYRO MULTISHOT RUN IN 5" DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO AN R.K.B. HEIGHT OF 55 FT. ABOVE SEA LEVEL. Page HORIZONTAL' COORDINATES feet 0.00 N 0.00 E 100.0 .46 78.75 100.0 .4 45.0 .46 .4 78.7 200.0 .85 69.72 200.0 1.5 145.0 .40 1.5 74.4 300.0 .21 50.70 300.0 2.4 245.0 .65 2.4 71.3 400.0 .50 103.22 400.0 3.0 345.0 .41 3.0 74.5 500.0 .79 59.31 500.0 4.0 445.0 .55 4.0 74.9 600.0 .15 39.36 600.0 4.8 545.0 .65 4.8 71.8 700.0 .87 90.25 700.0 5.6 645.0 .78 5.7 73.5 800.0 2.35 71.29 799.9 8.4 744.9 1.56 8.4 74.5 900.0 5.08 67.71 899.7 14.8 844.7 2.73 14.9 72.0 1000.0 8.52 78.36 999.0 26.6 944.0 3.65 26.7 73.1 1050.0 9.10 81.47 1048.4 34.3 993.4 1.50 34.3 74.6 1100.0 11.10 86.31 1097.6 43.0 1042.6 4.35 43.0 76.5 1150.0 11.85 87.73 1146.6 52.7 1091.6 1.59 52.8 78.5 1200.0 13.15 85.30 1195.4 63.4 1140.4 2.81 63.5 79.9 1250.0 14.44 87.55 1244.0 75.1 1189.0 2.79 75.4 80.9 1300.0 16.04 84.65 1292.2 88.1 1237.2 3.55 88.4 81.7 1350.0 16.88 83.83 1340.2 102.2 1285.2 1.73 102.6 82.0 1400.0 16.54 84.15 1388.1 116.4 1333.1 .69 117.0 82.3 1450.0 16.24 83.75 1436.0 130.4 1381.0 .65 131.1 82.4 1500.0 16.60 81.78 1484.0 144.5 1429.0 1.34 145.2 82.5 .08 N .39 E .41 N 1.48 E .79 N 2.32 E .80 N 2.89 E 1.05 N 3.91 E 1.51 N 4.58 E 1.60 N 5.43 E 2.26 N 8.13 E 4.60 N 14.17 E 7.77 N 25.53 E 9.11 N 33.06 E 10.00 N 41.78 ~ 10.52 N 51.71 11.19 N 62.51 E 11.92 N 74.40 E 12.83 N 87.51 E 14.25 N 101.60 E 15.76 N 115.90 E 17.24 N 129.93 E 19.03 N 143.95 E A Gyro d a t a D i r e c t i o n a I Survey PRUDHOE BAY DRILLING WELL: POINT MCINTYRE Location: POOL RIG #7, Job Number: AK0995G293 P2-32 NORTH SLOPE, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL C O O R D I N A T E S feet 1550.0 16.22 76.16 1532.0 1600.0 16.84 73.05 1579.9 1650.0 17.14 72.34 1627.7 1700.0 17.38 72.98 1675.5 1750.0 18.53 71.21 1723.0 158.6 1477.0 3.27 159.3 82.2 172.8 1524.9 2.16 173.4 81.5 187.3 1572.7 .74 187.8 80.9 202.1 1620.5 .61 202.5 80.3 217.5 1668.0 2.54 217.8 79.7 21.72 N 157.80 E 25.50 N 171.51 E 29.85 N 185.46 F 34.27 N 199.62 39.01 N 214.28 E 1800.0 19.34 70.54 1770.3 1850.0 21.44 71.10 1817.2 1900.0 23.80 71.23 1863.4 1950.0 25.67 71.69 1908.8 2000.0 26.73 71.36 1953.6 233.6 1715.3 1.67 233.9 79.1 251.0 1762.2 4.23 251.1 78.5 270.1 1808.4 4.71 270.2 78.0 290.9 1853.8 3.76 291.0 77.5 312.9 1898.6 2.15 312.9 77.1 44.33 N 229.61 E 50.05 N 246.06 E 56.26 N 264.26 E 62.91 N 284.10 E 69.90 N 305.03 E 2050.0 26.83 73.09 1998.3 2100.0 26.85 72.54 2042.9 2150.0 27.63 73.65 2087.3 2200.0 27.74 74.40 2131.6 2250.0 28.33 75.51 2175.7 335.4 1943.3 1.58 335.4 76.8 357.9 1987.9 .50 357.9 76.5 380.7 2032.3 1.86 380.8 76.3 404.0 2076.6 .73 404.0 76.2 427.4 2120.7 1.57 427.5 76.1 76.78 N 326.48 E 83.45 N 348.05 E 90.10 N 369.94 E 96.49 N 392.28 E 102.58 N 414.97 E 2300.0 28.05 77.53 2219.8 2350.0 27.71 80.02 2264.0 2400.0 28.38 79.74 2308.1 2450.0 28.63 80.71 2352.1 2500.0 30.46 82.26 2395.6 451.1 2164.8 1.98 451.1 76.1 474.4 2209.0 2.43 474.4 76.3 497.9 2253.1 1.36 497.9 76.4 521.7 2297.1 1.05 521.7 76.6 546.3 2340.6 3.97 546.3 76.8 108.09 N 437.94 E 112.65 N 460.86 , 116.78 N 484.01 ~ 120.83 N 507.52 E 124.47 N 531.90 E 2550.0 31.45 82.13 2438.5 2600.0 32.55 83.41 2480.9 2650.0 34.06 83.43 2522.6 2700.0 35.19 83.95 2563.8 2750.0 36.52 84.19 2604.3 571.9 2383.5 1.98 571.9 77.1 598.2 2425.9 2.59 598.2 77.3 625.5 2467.6 3.01 625.6 77.6 653.7 2508.8 2.35 653.8 77.9 682.7 2549.3 2.66 682.9 78.1 127.96 N 557.38 E 131.29 N 583.66 E 134.44 N 610.94 E 137.56 N 639.17 E 140.58 N 668.30 E A Gyro d a t a D i r e c t i on a i Survey PRUDHOE BAY DRILLING WELL: POINT MCINTYRE Location: POOL RIG #7, Job Number: AK0995G293 P2 -32 NORTH SLOPE, ALASKA Page 3 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL' COORDINATES feet 2800.0 38°36 84.50 2644.0 2850.0 39.32 84.84 2683.0 2900.0 41.57 82.10 2721.0 2950.0 43.06 82.61 2758.0 3000.0 47.12 81.52 2793.3 712.8 2589.0 3.71 713.2 78.4 743.9 2628.0 1.95 744.3 78.7 776.1 2666.0 5.74 776.6 78.8 809.6 2703.0 3.06 810.2 79.0 844.8 2738.3 8.25 845.6 79.1 143.57 N 698.55 146.48 N 729.77 150.19 N 761.99 154.67 N 795.35 159.57 N 830.41 3100.0 50.56 80.90 2859.1 3200.0 50.45 80.01 2922.7 3300.0 49.62 78.40 2986.9 3400.0 49.61 77.60 3051.7 3500.0 49.16 76.96 3116.8 919.9 2804.1 3.48 920.8 79.3 996.9 2867.7 .70 998.0 79.4 1073.4 2931.9 1.49 1074.6 79.4 1149.6 2996.7 .61 1150.8 79.3 1225.5 3061.8 .66 1226.6 79.2 171.08 N 183.87 N 198.22 N 214.06 N 230.78 N 904.80 E 980.90 E 1056.18 E 1130.69 E 1204.73 E 3600.0 47.03 76.37 3183.6 3700.0 45.93 75.82 3252.4 3800.0 45.03 75.72 3322.6 3900.0 44.63 76.00 3393.5 4000.0 44.04 76.11 3465.0 1299.9 3128.6 2.18 1301.0 79.0 1372.4 3197.4 1.17 1373.4 78.9 1443.7 3267.6 .91 1444.6 78.7 1514.2 3338.5 .45 1515.0 78.6 1584.1 3410.0 .59 1584.9 78.5 247.94 N 265.37 N 282.90 N 300.12 N 316.96 N 1277.15 E 1347.54 E 1416.65 E 1485.01 E 1552.83 E 4100 . 0 43 . 34 76 . 04 3537 . 3 4200.0 44.22 76.01 3609.5 4300.0 44.81 76.01 3680.8 4400.0 44.26 75.34 3752.1 4500.0 44.84 74.88 3823.4 1653.2 3482.3 .71 1653.9 78.4 1722.3 3554.5 .88 1723.0 78.3 1792.4 3625.8 .59 1793.1 78.2 1862.6 3697.1 .72 1863.1 78.1 1932.7 3768.4 .66 1933.2 78.0 333.58 N 350.28 N 367.24 N 384.59 N 402.61 N 1619.88 E 1687.01 ~ 1755.04 1823.00 E 1890.79 E 4600 . 0 45 . 23 74 . 69 3894 . 0 4700 . 0 47 . 13 74 . 52 3963 . 3 4800 . 0 46 . 92 74 . 34 4031 . 5 4900 . 0 46 . 64 74 . 63 4099 . 9 5000.0 46.98 74.92 4168.4 2003.4 3839.0 .41 2003.8 77.9 2075.5 3908.3 1.91 2075.9 77.8 2148.6 3976.5 .25 2148.9 77.6 2221.4 4044.9 .36 2221.7 77.5 2294.3 4113.4 .40 2294.5 77.4 421.18 N 440.34 N 459.98 N 479.48 N 498.62 N 1959.07 E 2028.62 E 2099.10 E 2169.32 E 2239.67 E A Gyro da t a D i r e c t i o na i Survey PRUDHOE BAY DRILLING WELL: POINT MCINTYRE Location: POOL RIG #7, Job Number: AK0995G293 P2-32 NORTH SLOPE, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 5100.0 46.37 75.01 4237.0 5200.0 46.65 75.15 4305.8 5300.0 46.90 75.19 4374.3 5400.0 47.36 75.26 4442.3 5500.0 46.79 75.33 4510.4 2367.0 4182.0 2439.5 4250.8 2512.4 4319.3 2585.6 4387.3 2658.8 4455.4 .62 2367.2 77.4 .30 2439.7 77.3 .26 2512.5 77.2 .46 2585.7 77.2 .57 2658.9 77.1 517.50 N 536.17 N 554.82 N 573.51 N 592.09 N 2309.92 E 2380.02 E 2450.46 E 2521.32 2592.15 E 5600.0 46.13 75.73 '4579.3 5700.0 46.30 75.95 4648.5 5800.0 47.11 76.20 4717.1 5900.0 47.18 76.38 4785.1 6000.0 47.67 76.49 4852.8 2731.3 4524.3 2803.5 4593.5 2876.3 4662.1 2949.6 4730.1 3023.2 4797.8 .72 2731.4 77.1 .23 2803.6 77.1 .83 2876.3 77.0 .15 2949.6 77.0 .50 3023.3 77.0 610.20 N 627.86 N 645.38 N 662.75 N 680.02 N 2662.34 E 2732.34 E 2802.98 E 2874.20 E 2945.79 E 6100.0 47.18 76.31 4920.4 6200.0 47.73 76.42 4988.0 6300.0 47.16 76.71 5055.7 6400.0 46.67 76.56 5124.0 6450.0 46.52 76.52 5158.3 3096.9 4865.4 3170.5 4933.0 3244.2 5000.7 3317.2 5069.0 3353.5 5103.3 .51 3096.9 77.0 .56 3170.6 77.0 .61 3244.2 77.0 .50 3317.3 77.0 .29 3353.6 77.0 697.34 N 714.71 N 731.82 N 748.70 N 757.16 N 3017.37 E 3088.96 E 3160.61 E 3231.66 E 3266.9~ E 6480.0 46.12 76.59 5179.1 6510.0 45.92 76.65 5199.9 6540.0 45.96 76.78 5220.8 6570.0 45.85 76.69 5241.6 6600.0 45.94 76.71 5262.5 3375.2 5124.1 3396.8 5144.9 3418.4 5165.8 3439.9 5186.6 3461.5 5207.5 1.36 3375.3 76.9 .67 3396.9 76.9 .34 3418.4 76.9 .43 3440.0 76.9 .32 3461.5 76.9 762.20 N 767.20 N 772.15 N 777.10 N 782.05 N 3288.09 E 3309.09 ~ 3330.07. 3351.04 E 3372.01 E 6630.0 46.35 76.61 5283.3 6660.0 46.48 76.48 5304.0 6690.0 46.48 76.30 5324.6 6720.0 46.59 76.59 5345.3 6750.0 46.92 76.75 5365.8 3483.1 5228.3 3504.8 5249.0 3526.6 5269.6 3548.4 5290.3 3570.2 5310.8 1.37 3483.1 76.9 .54 3504.9 76.9 .44 3526.6 76.9 .78 3548.4 76.9 1.18 3570.2 76.9 787.05 N 792.10 N 797.22 N 802.32 N 807.36 N 3393.06 E 3414.19 E 3435.33 E 3456.50 E 3477.76 E A Gyro da t a D i r e c t i o na i S u rve y PRUDHOE BAY DRILLING WELL: POINT MCINTYRE Location: POOL RIG #7, Job Number: AK0995G293 P2 -32 NORTH SLOPE, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HOR I Z ONTAL' COORDINATES feet 6780.0 47.04 77.44 5386.3 6810.0 46.89 77.61 5406.8 6840.0 46.46 77.75 5427.4 6870.0 46.54 77.76 5448.0 6900.0 46.07 77.73 5468.7 3592.1 5331.3 1.73 3592.2 76.9 3614.1 5351.8 .65 3614.1 76.9 3635.9 5372.4 1.46 3635.9 76.9 3657.6 5393.0 .26 3657.7 76.9 3679.3 5413.7 1.57 3679.4 76.9 812.26 N 817.00 N 821.65 N 826.27 N 830.87 N 3499.14 E 3520.55 E 3541.87 E 3563.14 3584.33 m 6930.0 45.89 77.21 5489.6 6960.0 46.01 77.32 5510.4 6990.0 45.74 77.17 5531.3 3700.9 5434.6 1.38 3700.9 77.0 3722.5 5455.4 .49 3722.5 77.0 3744.0 5476.3 .98 3744.0 77.0 835.55 N 840.30 N 845.06 N 3605.39 E 3626.42 E 3647.43 E Final Station Closure: Distance: 3744.04 ft Az: 76.96 deg. A Gyro da t a D i r e c t i o na i S u rve y for PRUDHOE BAY DRILLING WELL: POINT MCINTYRE P2-32 Location: POOL RIG #7, NORTH SLOPE, ALASKA Job Number: AK0995G293SS Run Date: ll-Sep-95 00:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.375000 deg. N Sub-sea Correction from Vertical Reference: 55 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 76.690 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o n a i Survey PRUDHOE BAY DRILLING WELL: POINT MCINTYRE P2-32 Location: POOL RIG #7, NORTH SLOPE, Job Number: AK0995G293SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. -55.0 0.00 0.00 0.0 0.0 0.00 0 - 6990 FT. GYRO MULTISHOT RUN IN 5" DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO AN R.K.B. HEIGHT OF 55 FT. Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 0.0 0.0 0.00 N 0.00 E ABOVE SEA LEVEL. 100.0 .67 73.78 155.0 1.0 .43 200.0' .50 59.26 255.0 2.0 .54 300.0 .37 79.59 355.0 2.7 .52 400.0 .66 79.06 455.0 3.6 .49 500.0 .44 48.33 555.0 4.5 .60 600.0 .55 67.36 655.0 5.3 .72 700.0 1.69 79.81 755.0 7.2 1.21 800.0 3.86 69.31 855.0 12.0 2.21 900.0 7.00 73.64 955.0 21.4 3.24 1000.0 9.37 82.12 1055.0 35.4 1.88 1100.0 12.07 87.31 1155.0 54.6 1.80 1200.0 14.80 86.89 1255.0 78.1 2.97 1300.0 16.77 83.93 1355.0 106.6 1.41 1400.0 16.38 82.97 1455.0 136.0 .92 1500.0 16.51 74.66 1555.0 165.4 2.73 1600.0 17.28 72.70 1655.0 195.8 .67 1700.0 19.07 70.76 1755.0 228.4 1.95 1800.0 23.37 71.20 1855.0 266.7 4.62 1900.0 26.73 71.41 1955.0 313.6 2.13 2000.0 27.06 72.84 2055.0 364.1 .87 1.5 76.4 2.4 72.7 3.0 73.0 4.0 74.7 4.8 73.2 5.7 72.8 8.4 74.0 14.9 73.1 26.7 72.6 43.0 74.9 63 .5 78.7 88.4 81.1 117.0 82.1 145.2 82.5 173 . 4 81.9 202.5 80.5 233.9 79.3 270.2 78.1 335.4 77.1 380.8 76.5 .26 N .99 E .62 N 1.94 E .80 N 2.63 E .94 N 3.45 E 1.30 N 4.28 E 1.56 N 5.05 E 1.97 N 6.91 E 3.55 N 11.46 E 6.37 N 20.49 E 9.23 N 34.23 E 10.63 N 53.56 E 12.13 N 77.39 E 14.72 N 106.03 E 17.95 N 135.47 E 23.53 N 164.39 E 32.37 N 193.55 E 42.61 N 224.64 E 55.13 N 260.97 E 70.11 N 305.69 E 85.26 N 354.02 E A Gyro da t a D i r e c t i ona i Survey PRUDHOE BAY DRILLING WELL: POINT MCINTYRE P2-32 Location: POOL RIG #7, NORTH SLOPE, Job Number: AK0995G293SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 28.05 74.99 2155.0 416.4 2200.0 27.78 79.51 2255.0 469.7 2300.0 28.75 80.81 2355.0 523.4 2400.0 31.88 82.63 2455.0 582.1 2500.0 34.95 83.84 2555.0 647.7 1.18 2.34 1.25 2.22 2.49 427.5 76.1 474.4 76.2 546.3 76.6 598.2 77.2 653.8 77.8 99.72 N 404.30 E 111.72 N 456.19 E 121.07 N 509.15 E 129.26 N 567.63 E 136.89 N 633.14 E 2600.0 38.63 84.60 2655.0 721.6 2700.0 42.94 82.57 2755.0 806.9 2800.0 50.35 80.94 2855.0 915.2 2900.0 50.03 79.20 2955.0 1035.4 3000.0 49.59 77.56 3055.0 1153.4 3 .22 3 .28 3.77 1.10 .61 744.3 78.5 810.2 79.0 920.8 79.3 1074.6 79.4 1226.6 79.3 144.39 N 154.31 N 170.36 N 191.09 N 214.91 N 707.36 E 792.66 E 900.18 E 1018.77 E 1134.44 E 3100.0 47.94 76.62 3155.0 1268.1 3200.0 45.90 75.81 3255.0 1375.0 3300.0 44.84 75.85 3355.0 1476.0 3400.0 44.12 76.10 3455.0 1574.3 3500.0 43.55 76.04 3555.0 1670.1 1.53 1.16 .70 .57 .75 1301.0 79.1 '1444.6 78.9 1515.0 78.6 1584.9 78.5 1723.0 78.3 240.60 N 266.01 N 290.77 N 314.60 N 337.67 N 1246.15 E 1350.06 E 1447.92 E 1543.34 E 1636.32 E 3600.0 44.59 76.01 3655.0 1767.0 3700.0 44.29 75.32 3755.0 1865.4 3800.0 45.01 74.79 3855.0 1964.3 3900.0 46.90 74.54 3955.0 2066.9 4000.0 46.82 74.44 4055.0 2173.7 70 72 55 73 28 1793.1 78.2 1933.2 78.1 2003.8 77.9 2075.9 77.8 2221.7 77.6 361.09 N 385.32 N 410.92 N 438.05 N 466.69 N 1730.40 E 1825.74 E 1921.34 E 2020.30 E 2123.24 E 4100.0 46.91 74.86 4155.0 2280.1 4200.0 46.44 75.05 4255.0 2386.0 4300.0 46.83 75.18 4355.0 2491.8 4400.0 47.25 75.28 4455.0 2599.2 4500.0 46.36 75.59 4555.0 2705.7 .39 .53 .27 .48 .67 2294.5 77.5 2439.7 77.4 2512.5 77.3 2658.9 77.2 2731.4 77.1 494.88 N 522.38 N 549.56 N 576.96 N 603.81 N 2225.92 E 2328.26 E 2430.60 E 2534.48 E 2637.54 E A Gyro d a t a D i r e c t i on a i S u rve y PRUDHOE BAY DRILLING WELL: POINT MCINTYRE P2-32 Location: POOL RIG #7, NORTH SLOPE, Job Number: AK0995G293SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 4600.0 46.38 75.97 4655.0 4700.0 47.15 76.30 4755.0 4800.0 47.65 76.49 4855.0 4900.0 47.46 76.37 4955.0 5000.0 47.16 76.70 5055.0 5100.0 46.54 76.53 5155.0 5200.0 45.91 76.70 5255.0 5300.0 46.75 76.66 5355.0 5400.0 46.38 77.75 5455.0 5476.3 45.74 77.17 5531.3 2810.4 2917.1 3025.6 3134.5 3243.5 3350.0 3453.7 3558.7 3665.0 3744.0 .28 .45 .50 .53 .61 .31 .36 .97 .70 .98 2876.3 77.1 2949.6 77.0 3096.9 77.0 3170.6 77.0 3244.2 77.0 3353.6 77.0 3461.5 76.9 3570.2 76.9 3679.4 76.9 3744.0 77.0 629.52 N 2739.01 E 655.06 N 2842.67 E 680.59 N 2948.15 E 706.22 N 3053.97 E 731.65 N 3159.90 E ., 756.34 N 3263.55 E 780.27 N 3364.46 E 804.71 N 3466.56 E 827.82 N 3570.28 E 845.06 N 3647.43 E Final Station Closure- Distance: 3744.04 ft Az: 76.96 deg. gyro/data 4. QUALITY CONTROL SR293.DOC Quality Control Comparisons PRUDHOE BAY DRILLING WELL: POINT MCINTYRE P2-32 Location: POOL RIG #7, NORTH SLOPE, ALASKA Job Number : AK0995G293 / AK0995G293 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 500.0 .37 .79 -.420 1000.0 8.41 8.52 -.107 1500.0 16.39 16.60 -.213 2000.0 26.55 26.73 -.176 2500.0 30.16 30.46 -.301 3000.0 46.52 47.12 -.592 3500.0 49.10 49.16 -.064 4000.0 43.83 44.04 -.212 4500.0 44.62 44.84 -.218 5000.0 47.04 46.98 .057 5500.0 46.97 46.79 .176 6000.0 47.41 47.67 -.263 INRUN Az 67.04 80.69 81.25 72.14 81.55 82.51 76.23 75.42 75.76 74.91 74.88 77.00 For Inclinations Greater than 10 degrees- Average Inclination Difference = -.1805 deg. Average Azimuth Difference = .00383 deg. OUTRUN Az 59.31 78.36 81.78 71.36 82.26 81.52 76.96 76.11 74.88 74.92 75.33 76.49 Delta 7.737 2.334 -.526 .782 -.709 .982 -.730 -.689 .878 -.006 -.454 .509 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0995G293 TOOL NUMBER: O8O MAXIMUM GYRO TEMPERATURE: 76.2c MAXIMUM AMBIENT TEMPERATURE: 95 c MAXIMUM INCLINATION: 50.56 AVERAGE AZIMUTH: 76,96 WIRELINE REZERO VALUE: no correction REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 8~24~95 CALIBRATION USED FOR FINAL SURVEY: 8/24/95 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES .065 .05 .1 USED .08 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS: M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 6990 45.74 77.17 5531.3 845.06N 3647.43E FINAL SURVEY 6990 45.74 77.17 5531.3 845.06N 3647.43E SR293.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0995G293 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 6990 45.74 45.74 45.74 45.74 45.74 AZIMUTH M,D. ft 1 2 3 4 5 6990 77.04 77.30 77.23 77.39 77.32 SR293.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR293.DOC gyro/data' EQUIPMENT REPORT JOB NUMBER: AK0995G293 DOWNHOLE ELECTRONICS' SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0098 DATA S ECTI O N A0032 POWER SECTION A0027 BACKUP TOOL No. 722 GYRO SECTION A0054 DATA S ECTI O N A0025 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0074 A0079 A0071 A0122 A0074 A0082 A0035 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 7/32 RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 17.5 feet 2 1/4 INCHES TOTAL WEIGHT OF TOOL: 145Lbs SR293.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0995G293 9/10/95 1145 9/10/95 2030 2230 0030: 0230 0530 0830 9/11/95 1200 ARRIVE ON THE SLOPE LEAVE FOR Point Mac. PU TOOL. ZERO TO r.k.b... START INRUN. 3000' 6990 FT. pull out of the hole. rtn to Atlas RTN ANCHORAGE SR293.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 September 18, 1995 Directional Information B.P. Exploration (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re: Point McIntyre, Well # P2-32, North Slope, Alaska Enclosed please find one (1) original and five copies (5) of the completed survey of Well #P2-32 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Robert ~Shoup Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation MEMORAND /I TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Blair Wondzell, ~ P. I. Supervisor ¢>/e FROM: Jerry Herring/~¢3~ SUBJECT' Petroleum In~pectdr DATE: September 4, 1995 FILE NO: e21 kidcd.doc Diverter Test- Pool 7 ARCO Prudhoe Bay Unit Pt. Mclntyre P-32 PTD # 95-0135 Monday, September 4, 1995: I traveled to ARCO's Pt. Mclntyre field to witness a diverter test on Pool 7 drilling well P2-32. The Diverter Test Report is attached. The diverter system consist of two 10" lines installed 180° apart with three knife valves controlling the direction of flow. I found the diverter system to be installed properly and the function test went smoothly. The rig and pad was in good condition. Summary: I inspected the diverter system and witnessed a successful function test on Pool 7 drilling well P2-32 on the Pt. Mclntyre Field. Attachment: e21 kidcd.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Drlg Contractor: POOL Operator: ARCO PBU Well Name: Pt. Mac 2-32 Location: Sec. 14 T. t2N Operation: Development Rig No. 7 PTD # Date: X Exploratory: 95-0135 Rig Ph. # Les Peak R, Oper. Rep.' Rig Rep.: 14E 9~4~95 659 - 4815 Jim Davidson Meridian UM TEST DATA MISC. INSPECTIONS: Location Gen.: OK Well Sign: Housekeeping: OK (Gen.) Drlg. Rig: Reserve Pit: N lA Flare Pit: DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 10 Vent Line(s) Length: 105 & t Line(s) Bifurcated: YES Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: YES OK OK N/A in. in. 10 ft. ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: 0 Systems Pressure Attained: 2 Nitrogen Bottles: (6) BOTTLES 2,300 (Ave.) 3000 psig 1800 psig min. 30 sec. min. 16 sec. MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: OK OK psig DIVERTER SCHEMATIC (10") Normally Open Pipe Shed Boiler and Generators (Second Level) (3) 10" Knife Valves Outside Valves Connected Via HCR Control ~ 20" Annular Preventer With 10" FO HYdraulic Knife Valve ~ 2_~::-T-~ -. ~ .... (10") Normally Closed Mud System (RIG LAYOUT IS APPROXIMATE) Non Compliance Items Remarks: 0 Repair Items Within n/a Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - OpedRep c- Database c - Trip Rpt File c - Inspector AOGCC REP.: ' .~'. FI-022 (Rev. 7/93 E21KIDCD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 31, 1995 Steve Shultz, Senior Drlg. Engineer BP Exploration (Alaska), inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Point Mclntyre P2-32 ARCO Alaska, Inc. Permit No 95-135 Surf Loc 5062'NSL, 3909'WEL, Sec. 14, T12N, R14E, UM Btmhole Loc 1798'NSL, 656'WEL, Sec. 12, T12N, R14E, UM Dear Mr. Schuitz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt .you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the B©PE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. Yours very truly, Russell A. Dougl~s~ Commissioner BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill [] lb. Type of well. Exploratoryr-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 51 feet Point Mclntyre 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365548 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^AC 25.025) 5062' NSL, 3909' WEL, SEC 14, T12N, R14E Point Mclntyre At top of productive interval 8. Well number Number 1454' NSL, 2116' WEL, SEC 12, T12N, R14E P2-32 U-630610 At total depth 9. Approximate spud date Amount 1798' NSL, 656' WEL, SEC 12, T12N, R14E 09/02/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 034624 1798 feet No Close Approach feet 3601 13360' MD/9024' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 5co feet Maximum hole angle 86 o Maximum surface 3330 psig At total depth (TVD) 8800'/4590 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NTSOLHE BUtt 4310' 41' 41' 4351' 3702' 1050 sx PF 'E', 3755x 'G', 250 sx PF 'C' 9-7/8" 7-5/8" 29.7# NT95HS NSCC 12117' 40' 40' 12157' 8949' 373 sx Class 'G' 6-3/4" 4-1/2" 12.6# 13Cr-8O NSCT 1360' 12000' 8920' 13360' 9024' Slotted 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 Measured depth True Vertical depth Structural ~ ' .... Conductor - '-' ~' ~ ~' Surface Intermediate AUG :5 0 ~995 Production Liner AiS, Sk~ Oil & Gas Cons, Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] .Refraction analysis l-I Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby.? d, ify./,,-~A :, tha~,,~th/_..~ z~z~-. /J foregoing_._ i~,,,~e ~correct to the best of my knowledge Signed/~ _~,...~-x.__._~ _~ ~ Title Senior Drilling Engineer "-'~ ~" '~--...'Commission Use Only Permit Number APl number Approval date See cover letter ~,~-/",.~,~4'" 50-C)2.- ~- 2.-.2, ,_4'"¢,~ for other requirements Condit~:)ns of approval Samples required [] Yes [] No Mud Icg required []Yes ~ No Hydrogen sulfide measures ,~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; ~5M; I-I10M; I-I15M; Other: O RIL~,NAL SIGNI~D By by order of~'/~, ~ ,/~ ,_...,/,/ /'~. Approved by RUSSELL A. DOUGLASS Commissioner tne commission Date Form 10-401 Rev. 12-1-85 Submit in/ I Well Name: IP2-32 Well Plan Summary Type of Well (producer or injector): I Horizontal Producer Surface Location: 218' FNL 1371' FWL Sec 14 T12N R14E UM Target Location: 1454' FSL 2116' FEL Sec 12 T12N R14E UM Bottom Hole Location: 1798' FSL 656' FEL Sec 12 T12N R14E UM I AFE Number: I Estimated Start Date: ] 9/1/95 I Rig: [Pool #7 I ] Operating days to complete: I 27 ]MD: I 13360 ] I TVD: ] 9024' I I KBE: 151.9' I Well Design (conventional, slimhole, etc.): [ Slimhole Horizontal Objective: [ Pt. Mclntyre eastern flank producer Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1835 1787 K-15 6549 5222 West Sak 9187 7047 Minimum required MW 9.5 ppg K-10 Truncated K-5 Truncated HRZ 11,886 8881 Kalubik 11,912 8891 Kuparuk 12,001 8921 Minimum required MW 9.9 ppg TD 13,360 9024 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80' GL 80/80 13 1/2" 10 3/4" 45.5# NTSOLHE Butt 4310' 41'/41' 435173702' 9 7/8" 7 5/8" 29.7# NT95HS NSCC 12,117' 40'/40' 12157'/8949' 6 3/4" 4 1/2" Slot 12.6# 13Cr-80 NSCT 1360' 12000'/8920' 13360'/9024' Tubing 4 1/2" 12.6 13Cr-80 NSCT 11,962' 38'/38' 12000'/8920' Well Plan Summary Alaska Oil & Gas Cons. Commission Anchorage Page 1 Evaluation Program: SURFACE PRODUCTION CASED HOLE LOGS Anadrill directional MWD only Anadrill MWD/GR/CDN/CDR from 150' above top Kupamk to TD MAD pass on this run at 900 fph to top K-15 (+5200' TVD) and continue MAD pass to surface at up to 1800 fph. Contingent Atlas triple combo. None Mud Program: I Special design considerations [ Plan to use Ho-Pro mud in the 6-3/4" horizontal section Surface Mud Properties: I SPUD Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 9 15 to to to to to to to 9.5 300 60 60 80 10 25 Intermediate Mud Properties: I LSND WBM Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 5 to to to to to to to 10.0 50 15 10 20 10 10 Production Mud Properties: ] Flo-Pro Xanvis Polymer Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8 50 30 18 20 8 6 to to to to to to to 9.2 60 50 23 30 10 8 NOTE: Directional: ]KOP: 1500' Maximum Hole Angle: Keep annular velocities around drill pipe at or above 180 ft/min wherever possible. 86° Close Approach Well: None The above listed wells will be secured during the close approach. Gas Cons. Commisffi~ ~chorage :- Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Well Plan Summary Page 2 PROPOSED DRILLING AND COMPLETION PROGRAM WELL P2-32 . . 5~ . . . . 10. MIRU. NU diverter and function test same. Drill 13-1/2" hole. Run and cement 10-3/4", 45.5#, NT-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4350 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3350 psi based on a gas column to surface from 8500' TVDss and an oil column to 8800' TVDss. Function test BOPE to 5000/250 psi. Test 10-3/4" casing to 3000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 10-3/4" shoe. Directionally drill a 9-7/8" PILOT hole from a target at the top of Kuparuk (1454' FSL, 21t6' FEL, sec 12, T12N, R14E) to +50' below the top of Kuparuk, logging porosity/resistivity/GR while drilling. Lay a 1200' balance cement plug from TD to 200' above the horizontal section KOP. Dress off the kick off plug to 11,500' MD and begin kick off to 86° inclination, holding azimuth at 77°. Directionally drill 9-7/8" hole to the 7-5/8" casing point in the Kuparuk River sandstone. Run a 7-5/8", 29.7#, NT-95 NSCC casing string to within 10' of 9-7/8" TD and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dead crude oil. Directionally drill approximately 1360' of 6-3/4" horizontal hole section with MWD:GR tools. Run 4-1/2", 13Cr-80 slotted liner with liner hanger and liner top packer from TD to 150' inside 7-5/8" casing shoe. Set hanger and packer. Change over to NaC1 completion fluid. Run tieback seal assembly on the 4-1/2", 12.6g, 13Cr-80 NSCT tubing. Sting seals over polished riser and land the tubing on the tubing hanger. Test the tubing annlus to 35000 psi. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install Christmas tree and test to 5000 psi. Freeze protect the tubing and annulus with Diesel from surface to 2100' TVDBKB. Drilling Hazards/Risks The BHL is 2000' east of water injector P2-29. Static reservoir pressure was measured in the injector in June at 4314 psi (9.42 ppg emw). The reservoir pressure at the P2-32 location is expected to be 50 psi to 100 psi lower than P2-29i. Three faults occur in the vicinity of the horizontal well. A small normal fault, located 300' northwest of the P2-32 Well Plan Summary Page 3 horizontal TD location, trends NW-SE. A second fault located 420' southeast of this same TD location trends SW-NE and dips toward the well. A third fault located 600' SW of the horizontal target trends W, NW-E,SE. This is the north-dipping, northern fault of the mid-field horst block. The pilot hole has moderate geological risk due to proximity to the horst block fault located 400' to the south at the Top Kuparuk tar get point. Errors associated within the mapped fault location and drilling position uncertainty could combine to produce a faulted pilot hole in the worst case. Therefore, an in-hole gyro reference survey will be obtained in the surface casing prior to drilling ahead to the pilot hole Top Kuparuk target. The pilot hole must not drift south of the planned pilot hole Top Kuparuk target in order to avoid this fault (potentially a fault zone). P2-32 Well Plan Summary Page 4 BPX-Shared Services Drilling Alaska State Plane~ Zone4 Pt Mac · PM2 P2-32 As-Built P~-32 Wp6 Hztl Well VERTICAL VIEW SCALE 100 ft. / DMSION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 8400 -- 8500-- 8600-- 8847 867l. CRITICAL POINT DATA TIE IN M~ KOP / START 500 OF DUILD 8 [.O0'/tO0 Ft START OF BUILD 800 11.50'/t00 START OF BUILD 1100 8 E,O0'/~O0 START OF BUILD 1400 ~ 2.50'/100 END OF BUILD 1700 B. Peem=~eo~¢ 1815 START DF 1918 CURVE 8 2.50'/100 ~t ~N9 0~ CUR~8989 UG4A (K-[5)6518 W, S=k 9144 START OF 1l~00 ~URVE 8 ~,00'/100 ~ END DF CURVE l1536 START OF ll673 CURVE 8 8.00'~100 Ft THRZ li884 T. K=~bl~ 11908 T. KuO=~u~ 11996 END DF CURVE 12157 TD T&rget 13360 0.00' 0,00' 3.00' 7.50' 13.50' El,O0' 81,00' 21,00' 46.84° 46.84' 46.84' 46,84' 47.66' 47,66' 64.57' 66.50' 73,53' 86.48' 86.48' AzI, 79,00' 79,00' 79,00' 79.00' 79,00' 79.00' 79,00' 79,00' 76.55' 76.55' 76.55' 76.55' 76,57' 76,57' 76,68' 76.69' 76.78' 76.78' 76.78' TVD N~SN 0 OE 500 0 N 0 E 800 [ N 8 E 1099 7 N 35 E t393 17 N 88 E [680 34 N176 1787 48N EE 816 1883 49 N 858 E ~718 170 ~1 794 ~ 5197 773 3311 7017 1~15 N 5159 E 8647 1611 N 6814 E 8671 1617 NN 6839 EE 8764 1640 6938 888l 1681 NN 7[08 ~ 889t 1686 7[30 8921 1705 7810 8949 1741 ~q 7364 EE 9024 8015 N 8533 E 8100 , t900t 1700< 1500-- 8189195 E, 18 pm HORIZONTAL VIE~ (TRUE NORTH) SCALE ~00 ft./ Dl%qS[0N SURVEY REF: WELLHEAD 8700-- 8764 8800-- 8949 9000-- 9084 9t00-- 9t81 9847 9300 7497 7574 7689 ~TM 8767 6600 6800 7000 7800 7400 7600 7800 8000 8800 8400 8600 6700 6800 6900 7000 7[00 7800 7300 7400 7500 7600 7700 7800 7900 BO00 8100 8800 8300 8400 VERTICAL SECTION PLANE: 76.71 CASING POINT DATA TVD N/S E/W 3708 409 N 1793 1741N 7364 90848949 8015 N 8533 OD MD Inc Azl tO 3/4 ~n 4351 46,84' 76.55' 7 5/8 in la157 86.48' 76.78' 4 L/8 In 13360 86.48' 76.78' · I I 8500 8600 I 8700 BBO0 Tmrget N~me TVD NS EW O~ld X G~ld Y UB3 Target 8949 [74t N7364 E688930 6000890 TKU P[to~ T~rget 8901 [672 N707~ E688640 6000214 TD T~rget 9024 8015 N8533 E690091 6000594 iPROPOSED BHL TVD 9083.90 MD 13360.04 VS 8787.35 N/S 20[5.39 X E/W 8532.57 E 8800 D=~e P~otted , ~I89/95 Cre~ted By ;,~ Checked By Approved 9y AUG 50 1995 Oft & Gas Cons, Commissio~ ,, 'Anchorage 2-32 Cement Cement Supplier: Halliburton Surface StringI Surface stdng cement based onshoe volume ~lus 375 sacks of tail slurry, plus lead to surface, both slurries with 70% excess. Spacer 7 5 bbls Fresh water LEAD (TYPE 'E' PERMAFROST) Volume 1050 Sacks (2279 ft3) (406 bbls) iCasing depth 435~ ft Length 3684 ft Casing size 10.75 in Yield 2.17 ft3/sack Casing ID 9.95 in Density 1 2IPPg Casing weight 45.5 Ib/ft TOC 40 ft MD Bit diameter 13.5 in Mix water 11.55 gps 50° - 65° Fresh Excess factor 1.7 Thicken time 4 hrs Shoe track 8 0 f t ClRCTEMP 5 0! Deg F TAIL (Class 'G' + 2% CaCI2 accelerator Top of Lead 40:ft Volume 375 Sacks (431 ft3) (77 bbls)_ Top of Tail 3724 ft ILength 627 ft Yield 1.15 Density 15.8 ppg TOC 3724 ft Mix water 5 gal/sk Fresh Thicken time 3.5 hrs TOP JOB (Type 'C' PERMAFROST) Volume 250 Sacks (266 ft3) (47 bbls) Yield 0.94 ft3/sack Density 15.6 Mix water 3.7 gal/sk Fresh Production String I Base cement volume on 1000' above the Kuparuk reservoir plus 90% excess. Adjust volume accordingly. Lab test cement/spacer/mud program to ensure compatibility before job. Ensure thickening times are adequate relative to pumping job requirement. Displace at maximum rate without inducing losses (10-12 bbl/min) Preflush 2 0 bbls Fresh water Spacer 7 0 bbls NSCI SPACER LEAD (Class 'G' +3% Econolite) Volume 0SacksI (0 ft3) (0 bbls) Additives: 0.4% CFR3 dispersant 2.0% HALAD 344 Fluid loss Casing depth 12157 ft ILength 0 ft Casing size 7.625 ~n Yield 3.24 ft3/sack Casing ID 6.875 in IDensity 1 1 ppg Casing weight 29.7 b/ft TOC 111 57 ft MD Bit diameter 9.875 n Excess factor 1.9 TAIL (CLASS G' Premium) Shoe track 80 ft Volume 373 Sacks (429 ft3) (76 bbls) CIRCTEMP 1 40 Deg F Additives: 0.2% CFR3 dispersant Top of Lead 11157 ft 0.4% HALAD 344 Fluid loss Top of Tail 11 157 ft 0.15% HR-5 Length 1000 ft Yield 1.15 ft3/sack Density 15.8 ppg TOC 111 57 ft MD I ! Thicken time 4-5 hrs AUG 1995 0ii & Gas Cons. Co_mmissi0.[ ~chorage I Open hole cement kick off plug CLASS G Premium Yield 1.15 Additives: 0.2% CFR3 dispersant Density 15.8 0.4% HALAD 344 Fluid loss Thicken time 4-5 hrs 0.15% HR-5 CIRCTEMP 1 40 Deg F DP capacity 0.017176 bbl/ft Drillpipe size 5:in Drillpipe ID 4.276 in Stand length 9 0 ft Tooljoint ID 3.5 in ~Tooljt length 4 ft OH depth 12157 ft Hole diameter 9.875 ~n Excess factor 1.25 cemnt in DP 857 ft CIRCTEMP 1 40 Deg F Top of cement 11300 ft Preflush 2 0 bbls Fresh water I MixVolume 440 Sacks (506 ft3) (90 bbls) Length 857 ft TOC 11 300 ft MD Drillpipe at TD - excess Drillpipe at TD gage hole Fluid Water cement Length 183 ft 822 ft 228 ft 1027 ft Depth 11153 ft 11335 ft 10902 ft 11130 ft Volume Short tripped - excess Short tripped gage hole Fluid Water cement Water cement Length 169 ft 760 ft 211 ft 950 ft Depth 11228 ft 11397 ft 10996 ft 11207 ft Volume Calculated Volumes Gage OH 0.09477 bbls/ft Drillpipe 0.01697 bbls/ft OH Annulus 0.07047 bbls/ft Capacity used 0.017176 AlaSka Oil & Gas Cons. Comrnissior~ Anchorage WELL PERMIT CHECKLIST COMPANY ~__ ~ UNIT# FIELD & POOL INI~ CLASS GEOLAREA //M.Co ON/OFF SHORE ADMINISTRATION ENGINEERING 3. 4. 5. 6. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool .............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force .......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ......... y~ N 16. CMT vol adequate to circulate on conductor & surf csg. N CMT vol adequate to tie-in long string to surf csg . . . 18. will °over all kno productive horizons ....... Y 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate ...................... ~ N 26. BOPE press rating adequate; test to ~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~ 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis 9f shallow gas zones .......... X N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./. Y N [exploratory only] GEOLOGY: ENGINEERING: CO~/~S ION: Comments/Instructions: HOW~o - A:~ORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER . ............................ . .~,PR '1 9 ]996 Oil & Gas Cons. Commissior~ Anchorage COMPANY NAME : ARCO ALASKA, INC. WELL NAME : P2-32PB FIELD NAiV~E : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22593-70 REFERENCE NO : 95351 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-APR-I996 09:07 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 96/04/16 ORIGIN : FLIC REEL NAME : 95351 CONTINUATION # : PREVIOUS REEL : COf~MENT : ARCO ALASKA, INC., POINT MCINTYRE P2-32PB API# 50-029-22593-70 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/16 ORIGIN : FLIC TAPE NAME : 95351 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, INC., POINT MCINTYRE P2-32PB API # 50-029-22593-70 TAPE HEADER POINT MCINTYRE MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR '. LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB ~ER : LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN 1 95351 PERRY SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING P2 -32PB 500292259370 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 16-APR-96 BIT RUN 2 BIT RUN 3 14 12N 14E 218 1371 51.70 51.70 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 4323.0 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 16-APR-1996 09:07 3RD STRING PRODUCTION STRING RE~APJfS: Well drilled 14-SEP through 17-SEP-95 with CDR/CDN. Ail data was collected in a single bit run. MAD data was collected from 11626' to 4076'. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 96/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630206 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~4M 630206 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~4~ 630206 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~M 630206 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OP~4~I630206 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~I 630206 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630206 O0 000 O0 0 1 1 1 4 68 0000000000 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 16-APR-1996 09:07 PAGE: 3 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FET MWD HR 630206 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630206 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 630206 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630206 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630206 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630206 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630206 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12345.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 17.874 FET.MWD -999.250 GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 CALN.MWD -999.250 NPHI.MWD -999.250 DEPT. 4074.500 RA.f~6rD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 CALN. MWD -999.250 NPHI.MWD -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE ' FLIC VERSION ' O01CO1 DATE : 96/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS ~ape verification Listing Schlumberger Alaska Computing Center 16-APR-1996 09:07 PAGE: 4 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630206 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD 0H~630206 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD OHbfl~ 630206 O0 000 O0 0 2 1 1 4 68 0000000000 VRA MAD 0~630206 O0 000 O0 0 2 1 1 4 68 0000000000 VRP MAD OP~4~ 630206 O0 000 O0 0 2 1 1 4 68 0000000000 GR MAD GAPI 630206 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11619. 000 VR P . MAD 3. 624 RA.MAD 3.353 RP.MAD GR.MAD -999.250 3. 516 VRA . MAD 3.387 ** END OF DATA ** ~IS T~ape Verification Listing Schlumberger Alaska Computing Center 16-APR-1996 09:07 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/16 ORIGIN .. FLIC TAPE NAME : 95351 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~VT : ARCO ALASKA, INC., POINT MCINTYRE P2-32PB, API # 50-029-22593-70 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/04/16 ORIGIN : FLIC REEL NAME : 95351 CONTINUATION # : PREVIOUS REEL : CO~94ENT : ARCO ALASKA, INC., POINT MCINTYRE P2-32PB, API# 50-029-22593-70 ~P~ ~ 9 10~96 Oil ~ ~as Cons. Co~&s&~ * ALASKA COMPUTING CENTER . ****************************** . ............................ ....... SCHLUMBERGER * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : P2-32 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292259300 REFERENCE NO : 96062 I LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-APR-1996 10:47 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE . 96/04/12 ORIGIN · FLIC REEL NAME : 96062 CONTINUATION # : PREVIOUS REEL : COf~MENT : ARCO ALASKA INC., POINT MCINTYRE P2-32, API #50-029-22593-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 96/04/12 ORIGIN : FLIC TAPE NAME . 96062 CONTINUATION # : 1 PREVIOUS TAPE : CO~4MENT : ARCO ALASKA INC., POINT MCINTYRE P2-32, API #50-029-22593-00 TAPE HEADER POINT MCINTYRE MWD/M~D LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA SURFACE LOCATION P2 -32 500292259300 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 12-APR-96 BIT RUN 1 BIT RUN 2 BIT RUN 3 SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 14 12N 14E 218 1371 51.70 51.70 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 4323.0 6.750 7.525 12205.0 LIS Tape Verification Listing 12-APR-1996 10:47 Schlumberger Alaska Computing Center REM_ARKS: Well drilled 16-SEP through 29-SEP-95 with CDR~SLIM1. MAD data from 4074' to 11688' collected with CDR. Bit runs 2,3 w/CDR, run 4 (bit runs 4,5,6,7 combined due to data format w/SLIM1/GR. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE · 96/04/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630206 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~4~ 630206 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHT4~ 630206 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0H~630206 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OHMi~ 630206 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~ 630206 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630206 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630206 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630206 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-APR-1996 10:47 PAGE: ** DATA ** DEPT. 13395.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 53.400 FET.MWD GR.MWD -999.250 DEPT. 12000.000 ~.MWD 5.152 RP.MWD 11.720 VRA.MWD VRP.MWD 17.030 DER.MWD 7.422 ROP.MWD 19.792 FET.MWD GR.MWD -999.250 DEPT. 10000.000 RA.MWD 3.581 RP.MWD 3.393 VRA.MWD VRP.MWD 3.409 DER.MWD 3.453 ROP.MWD -999.250 FET.MWD GR.MWD 97.899 DEPT. 8000.000 RA.MWD 3.557 RP.MWD 3.115 VRA.MWD VRP.MWD 3.054 DER.MWD 3.242 ROP.MWD -999.250 FET.MWD GR.MWD 101.784 DEPT. 6000.000 RA.MWD 3.412 RP.MWD 3.237 VRA.MWD VRP.MWD 3.208 DER.MWD 3.293 ROP.MWD -999.250 FET.MWD GR.MWD 101.537 DEPT. 4074.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD GR.MWD 33.944 -999.250 -999.250 7. 419 1. 601 3. 595 -999. 250 3.406 -999.250 3.466 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 96/04/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE ' FLIC VERSION · 001 CO1 DATE : 96/04/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-APR-1996 10:47 PAGE: 4 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NOT4~ SAMP ELEM CODE (HEX) DEPT FT 630206 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD OH~M 630206 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD 0H3~4 630206 O0 000 O0 0 2 1 1 4 68 0000000000 VRA MAD OH~OI 630206 O0 000 O0 0 2 1 1 4 68 0000000000 VRP MAD OH~OI 630206 O0 000 O0 0 2 1 1 4 68 0000000000 DER MAD OH~ff4630206 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR 630206 O0 000 O0 0 2 1 1 4 68 0000000000 GR MAD GAPI 630206 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11688.000 VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD RA.MAD -999.250 RP.MAD -999.250 VRA.MAD -999.250 599.415 GR.MAD -999.250 DEPT. 8000.000 RA.MAD 3.557 RP.MAD 3.115 VRA.MAD 3.406 VRP.MAD 3.054 DER.MAD 3.242 ROP.MAD 928.857 GR.MAD 101.784 DEPT. 10000.000 RA.MAD 3.581 RP.MAD 3.393 VRA.MAD 3.595 VRP.MAD 3.409 DER.MAD 3.453 ROP.MAD 968.121 GR.MAD 97.899 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-APR-1996 10:47 PAGE: DEPT. 6000.000 RA.MAD VRP.MAD 3.208 DER.MAD 3.412 RP.MAD 3.237 3.293 ROP.MAD 476.277 VRA.MAD GR. MAD 3.466 101.537 DEPT. 4074.500 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD -999.250 VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 GR.MAD 33.944 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE · 96/04/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/12 ORIGIN : FLIC TAPE NAME : 96062 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT . ARCO ALASKA INC. , POINT MCINTYRE P2-32, API #50-029-22593-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/04/12 ORIGIN : FLIC REEL NAME ' 96062 CONTINUATION # : PREVIOUS REEL : COMPiENT : ARCO ALASKA INC., POINT MCINTYRE P2-32, API #50-029-22593-00